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Home My WebLink About182-180Date: 5/19/2020 Transmittal Number: 93759 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 The digital zip file for the well log package listed below is being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format 01-23 9/16/2019 GYROData Gyro Survey Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ Received by the AOGCC 05/19/2020 PTD: 1821800 E-Set:33139 Abby Bell 05/19/2020Received by: 1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 182-180 11/8/1982 11/23/1982 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 637' FNL, 550' FWL, Sec. 08, T10N, R15E, UM 306' FNL, 4719' FEL, Sec. 07, T10N, R15E, UM 419' FNL, 5032' FEL, Sec. 07, T10N, R15E, UM Surface: x- y- Zone -697879 5940265 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 3/27/2020 15. 50-029-20854-00-00 16. PBU 01-23 Well Name and Number: 10698' / 8681' 40.01 17. TPI:y- Zone -692602 ASP 4x-5940459 Total Depth: x-y-Zone -692292 ASP 45940338 11452' / 9224' None DNR Approval Number:19. 79-179 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: CBL / CCL / GR, DIL / SP / BHCS / GR, FDC / CNL / GR / Cal, CBL CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 91.5# 72# 40#/47# 29# L-80 L-80/S-95 L-80 37' 33' 10240' 10548' 11447' 37' 33' 8359'9220' 8578' 8-1/2" 12-1/4" 1957# Poleset 500 sx Class 'G', 300 sx CS I, 136 Bbls Class 'G' 330 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 5-1/2" 17# 13Cr80 x 4-1/2" 12.6# L-80 10336' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 10698' Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): H-40 116'30"20" 13-3/8"36'2596'17-1/2"2300 sx CS III, 400 sx CS II36'2595' 10185' / 8318' Set Whipstock Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 116' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028329 319-438 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF 40.61 (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 74.00 Water Depth, if Offshore:13. N/A Zero API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: N/A 1900' (Approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 10:09 am, Apr 23, 2020 Abandon Date 3/27/2020 HEW RBDMS HEW 4/27/2020 xGSFD 4/27/2020 DSR-4/27/2020MGR01MAY20 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Hyatt, Trevor Contact Email: Trevor.Hyatt@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4627 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 5058' 7772' 9900' 10141' 10288' 10530' 10570' 10679' 10978' 11058' 11353' 4674' 6541' 8104' 8285' 8394' 8564' 8593' 8668' 8834' 8867' 8932' Ugnu Colville Mudstone HRZ Base of HRZ Kingak Sag River Shublik Sadlerochit - Zone 4 CGL - Zone 3 Base of CGL - Zone 2 TDF - Zone 1 Zone 1 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 11353'8932' Top of Productive Interval 11058'8867' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Pre-Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths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ll depths reported in Drillers Depths** ACTIVITYDATE SUMMARY 9/16/2019 ***WELL SHUT IN ON ARRIVAL***(gyro survey) PERFORM GYRO STATION SURVEYS AT 100', 200', 300', 400', 500', 1000', 2000',2885', 2975', 3150', 3840', 5200', 6200', 7150', 8300', 8600', 9800', 9965', 10500', AND 11000'. LOG REPEAT PASS FROM 11000' TO SUFACE LOGGING STATION STOPS AT 10500', 9800', 8600', 8300', 7150,6200,5200,3150,2980,2885,2000,1000,50, ***JOB COMPLETE, WELL TURNED OVER TO DSO*** 10/21/2019 ***WELL S/I ON ARRIVAL*** (pre rig) RIG UP HES SLICKLINE UNIT 046 ***CONT. ON 10/22/19 WSR*** 10/22/2019 ***CONT. FROM 10/21/19 WSR*** (pre rig) SET 5-1/2" SLIP STOP CATCHER @ 5305' SLM PULLED RK-S/O @ 5250' MD PULLED RK-LGLV @ 3174' MD SET RK-DGLV's @ 3174' & 5250' MD PERFORM PASSING MIT-IA (see data tab) PULL 5-1/2" SLIP STOP CATCHER @ 5305' SLM DRIFT FREELY @ 150 FPM W/ 3.70" x 20' DMY WHIPSTOCK, TAG HARD BTM @ 11,105' SLM (upcoming whipstock target depth = 10,691' ELMD) ***JOB COMPLETE, WELL LEFT S/I*** 10/23/2019 ***WELL SHUT IN ON ARRIVAL*** SET BAKER 4-1/2" x 7" DELTA WHIPSTOCK TOW AT 10,691' ELMD, 30* ROHS. ***JOB CONTINUES ON 24-OCT-19 WSR*** 10/24/2019 ***JOB CONTINUES FROM 23-OCT-19 WSR*** RDMO ELINE ***JOB COMPLETE, HAND WELL BACK OVER TO DSO*** 11/3/2019 T/I/O=0/100/0. 7" RU New temp valve as 2nd SV. RU 7" 5000 tree cap. Torqued to API spec. PT to 4000psi. Passed. Job Complete. See log. Final WHP's 0/100/0. SV, 2nd SV, WV, SSV = C. IA, OA = OTG. 11/6/2019 CTU 9 1.75" CT . Scope; Mill XN/ Mill Window MIRU. Perform BOP test for window milling. MU & RIH w/ Baker left handed milling MHA. Load well w/ 235 bbls Slick 1% KCl w/ Safelube, cap w/ 10 bbls 60/40 Methanol. ...In progress... 11/7/2019 CTU 9 1.75" CT. ***Continue from 11/6/19*** Scope; Mill XN/ Mill Window Finished milling through XN nipple. Freeze protect coil & POOH. Mill gauged @ 3.81" GO / 3.80" NO GO, Centralizer gauged @ 3.80" GO / 3.79" NO GO. RIH w/ window mill. Start time mill at 10721.5'. Unable to get past 10,726.1' without stalling. POOH to inspect mill. ***Continued on 11/8/2019 WSR *** Daily Report of Well Operations PBU 01-23 Daily Report of Well Operations PBU 01-23 11/8/2019 CTU #9 - 1.75" coil ***Continued from 11/7/19 WSR*** Job Scope: Mill XN/Mill window POOH with window milling BHA. Side cutters on 3.80" window mill are completely worn smooth, OD = 3.57". MU different 3.80" window mill and RIH. Start 10726.3. mill to target depth 10739. Make 5 passes backreeming from 10,731' - 10,718'. Dry tag TD, clean tag. POOH. Freeze protect coil and well with 60/40. Laydown window milling BHA. Mill is under-gauged at 3.55". String Reemer gauges at 3.79". Lost set screw from CTC (3/8" x 1/2"). RD ***In Progress*** 11/9/2019 CTU #9 - 1.75" coil. ***Continued from 11/8/19 WSR*** Job Scope: Mill XN/Mill Window Remove scaffolding. RDMO ***Complete*** 12/4/2019 T/I/O=2200/250/0. Pre CDR2. Set 6" J TWC #421 @140". LTT Passed. PT tree cap to 500psi. Passed. Job Complete. See log. Final WHP's TWC/250/0. MV=O, SSV,SV,WV=C. I/A,O/A=OTG. 12/7/2019 T/I/O = TWC/250/0. Pre CDR2. Remove 6" Production upper tree. Install CDR Tree #7 and Kill line #4. Torque to API specs. Final Tree configuration = Single MV, integrol with cap on WV, Kill line with 2 HWO valves, Test Spool on top of SV, Blind flange on top of Test spool. Torque MV x THA to API specs. Shell Test against TWC to 350/5000psi (PASS) PT against TWC to 350/3500psi (PASS) PT Top side MV x Bottom side SV to 350psi (PASS). PT against Top side MV x Bottom side SV to 3500psi. High (PASS). ***Job Complete*** RDMO 1/9/2020 T/I/O = TWC/150/20. Temp = SI. Bleed WHPs (Pre-Rig). No AL, FL, wellhouse, or scaffolding. IA FL @ near surface. OA cemented to surface. Bled IAP to BT from 150 psi to 0 psi in 3 hrs. Energized fluid to surface (<15 gals). Bled OAP to BT in 1 minute. All gas. Monitor for 30 minutes. IAP increased 8 psi. OAP unchanged. Final WHPs = TWC/08/0. SV, WV = C. MV = O. IA, OA = OTG. 23:59 1/9/2020 T/I/O = TWC/150/20. Temp = SI. WHPs & IA FL. No AL, wellhouse, FL, & scaffolding. IA FL @ near surface. SV, WV = C. MV = O. IA, OA = OTG. 02:00 1/11/2020 T/I/O = TWC/30/10. Temp = SI. Bleed IAP & OAP to 0 psi (Pre RIG). No AL, wellhouse, or flowline. CDR tree installed. IA FL @ near surface. OA cemented to surface. Bled IAP to BT from 30 psi to 0 psi in 10 min (Gas). Held open IA bleed for 2 hrs. Bled OAP to BT from 10 psi to 0 psi in 1 min (Gas). Monitored during RD. IAP increased 2 psi. Final WHPs = TWC/0+/0+. SV, WV = C. MV = O. IA, OA = OTG. 17:20 1/11/2020 T/I/O = TWC/30/10. Temp = SI. WHPs (pre CTD). Wellhouse & scaffold removed. CDR tree installed. IAP increased 22 psi, OAP increased 10 psi from 1/9/20. WV = C. MV = O. IA, OA = OTG. 05:00 1/12/2020 T/I/O = TWC/25/10. Temp = SI. WHPs (Pre Rig). No AL, flowline, scaffold, or wellhouse. CDR tree installed. Pad prep in progress around well. WHPs unchanged overnight. IAP increased 25 psi & OAP increased 10 psi overnight. SV, WV = C. MV = O. IA, OA = OTG. 1620 hrs. Daily Report of Well Operations PBU 01-23 3/21/2020 T/I/O = TWC/170/30. Temp = SI. Bleed WHPs (pre-rig). No AL, flowline, scaffold or well house. CDR tree installed. IA FL @ near surface. Bled IAP to BT from 170 to 0 psi in 1 hour (mixed gas/liquid, 8 gallons). Monitored 30 min. IAP regained 20 psi, OAP unchanged. OA FL @ near surface. Bled OAP from 30 psi to 0 psi in <1 min (all gas). Monitored 30 min. IAP & OAP unchanged. Final WHPs TWC/20/0. SV, WV = C. MV = O. IA, OA = OTG. 17:00 3/22/2020 T/I/O = TWC/40/04. Temp = SI. WHPs (Post Bleed). No AL, flowline, scaffold, or wellhouse. CDR tree installed. IAP increased 20 psi, OAP increased 04 psi overnight. SV, WV = C. MV = O. IA, OA = OTG. 20:40 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-23 Permit to Drill Number: 182-180 Sundry Number: 319-438 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.oloslka.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, Daniel T. Seamount, Jr. Commissioner DATED this 2-�day of September, 2019. iBDMS\,U OCT 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill p . Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development p. 5. Permit to Drill Number 182-180 3, Address: P.O. Box 196612 Anchorage, AK 995196612Stretigrephic ❑ Service ❑ B. API Number: 50-029-20854-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? B. Well Name and Number: Will Planned perforations require a spacing exception? Yes ❑ No El PBU 01-23 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028329 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): 11452 9224 11087 8957 2475 11087 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 37-116 37-116 1490 470 Surface 2560 13-3/8" 36-2596 36-2595 5380 2670 Intermediate 1 10515 1 9-5/8" 33-10548 33-8578 5750 / 6870 / 8150 3090 / 4760 15080 Production Liner 1207 7" 10240 - 11447 8359-9220 1 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 1 Tubing Grade: Tubing MD (ft): 11060- 11223 1 5-1/2"17#X4-1/2"12.6# 13Cr80 / L-80 10336 Packers and SSSV Type: 5-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 10185, 8318 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development 21 Service ❑ 14. Estimated Date for Commencing Operations: 10/7/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended IZ ' 16. Verbal Approval: Date: 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: Hartley, Josephine be dwated from without prior written approval. Contact Email: Josephine.Hartley@bp.cem Authorized Name: Mdaughlin, Sean M Contact Phone: +19075644570 Authorized Title : Engine ring Team Lead - CTD Authorized Signature: S e, Date: 9-Z3-11 U COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1''J11 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location1� Clearance ❑ d at Other: Va-W14 w GG f0 zQ Ate- z+1•r//4..s., �Ti/ti6R►��✓p�16[isK6wT a��/'�R Boil 7 esr"3racPsi Post Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes ❑ No 13 Subsequent Form Required: /0—yap/ APPROVED BYTHE c112 Approved by: COMMISSIONER COMMISSION Date 1Z 7�1 Form 10-49 Revised 04/2017 O R I G I N A L S°MsLC OCT °' �0t9 Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil &Gas Conservation Commission Vbp From: Josi Hartley CTD Engineer Date: September 20, 2019 Re: 01-23 Sundry Approval Request Sundry approval is requested to plug off the 01-23 production as part of the drilling and completing the proposed 01-23A coiled tubing sidetrack. History of 01-23: 03-23 was originally drilled and completed in 1982, and in 2007 a workover was performed to repair a casing leak. The current wellbore is shut in due to high GOR with no remaining value and has been released for sidetrack. ✓ Proposed plan for 01-23A: The coil sidetrack 01-23A will be a 2500' U-shaped "replacement" well targeting the reserves previously accessed by 01-03A, which has been permanently shut in because the surface casing shoe is set within the permafrost. A second offtake point will also be added in the GDWFI/GD area south of 01-03A. The CST will be drilled on or around November 1't, 2019. During pre -rig work it is proposed to run a gyro survey, mill the XN nipple at 10303' MD, drift and set a 4-1/2" x 7" delta whipstock at 10720' MD in the 7" production liner, and mill the window with service coil. The rig will move in, test BOPE and kill the well. The well will kick off in Zone 4, land in Zone 2 to locate the OWC, then toe up into Zone 4. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing 01-23 Droduction via the liner cement mob or liner top Packer if the liner lao oressure test fails (alternate plug placement Per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. 2. 1 E I Mill XN. 3. C Drift and Set 4-1/2" x 7" Delta Whipstock at 10,720' MD 4. C Mill Window Rig Work (scheduled to begin December V, 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2475 psi). 2. Drill production section: 4.25" OH, 2758' (12' DLS planned). 3. Run 3-1/4" x 2-7/8" 13Cr liner to TD. 4. Pump primary cement job: 45.15 bbls, 15.3 ppg Class G, TOC at TOL (10,250 MD)*. 5. Freeze protect well to a min 2,500' TVDss. 6. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) W 3 t4 Post -Rig Work: 1. V: Tree work as needed 2. CT: PT Liner Lap, Log RPM, Perforate 50-100' 3. SL: Set LTP if needed & PT LTP. Set KO GLD. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL (^'590 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. ' • Pipe rams, blind rams, CF pack off, and choke manifold will be pressure tested to 250 psi and psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • Maximum H2S reading on pad/facility: 194 ppm (4/9/1990). Most recent H2S sample on 01-23: 16 ppm (10/30/2018) Reservoir Pressure: • The reservoir pressure on 01-23 is expected to be 3385 psi at 9104' TVDSS (7.15 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2475 psi. Josi Hartley CC: Well File CTD Engineer Joe Lastufka 564-4570 Returns Tank Farm -----------, C PUMP _SLB CT PUMP I I I° I I ®I ��IIIII L._. Coiled Tubin�Unit ISourcewater Tank Par' ! TT1B-== 6-318'CJW WELLHEAD= FM:GENN ACTUATOR= BAKER OKB. ELEV = 74' BF. ELEV = ? KOP= 2805 Max Angle = 48" @ 6900' Datum M)= 10973 Datum TVD = SSW SS, 'CSG. 400, L -SO, TG11, D= 13-38' CSG, 720, L-60, D = Minimum 10 = 3.725" @ 10303' 4-112" HES XN NIPPLE 5-12'TBG, 170, 13CR410, /AM TOP, .0232 bpf, D = 4.892' ITOP OF 7"LNR I 4-12- TBG, 12.60, L-80, TCA .0152 bpf, !D= 3.958' F13EORATION SUMMARY REF LOG: BRCS ON 11/23/82 ANGLE AT TOP FERF: 43" @ 11060' Note: Refer to Production DB for historical pert data SIZE SPF WERVAL OprWSgz SHOT SOZ 3-3/8" 6 11060-11080 O 05123/18 1 M G 3-318' 6 11098-11108 C 02116/11 4 3-318" 4 11140 - 11170 C 01/06/89 SO 3-318" 6 11183-11190 C 01/31/90 7100 3-3/8' 6 11196-11203 C 01131/90 RK 3-318" 6 11213-11223 C 02/23198 7102 17- LNR. 290. L-80, .0371 bpf, D = 6.184" 1 E SAFETY NOTES: "`36 PPM H2S"' 01-23 5 -12 -CHROME TBG 1 2208• 1 GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DOTE 5 3174 3167 15 1 M G DOME R( 16 08130/15 4 5250 4812a41LAG SO RK 20 08130/15 3 7100 6089 0MY RK 0 05/31/15 2 8563 7102 CMY RK 0 01/01/07 1 9915 8114 DMY RK 0 05/31/15 DATE REV BY I COMMENTS DATE REV BY COMMENTS 112&82 ORIGINAL COMPLETION 01/24/18 JMG/JM) PtAl®ROCKSCREEN(0123118) 01/02/07 WEE RWO 05130118 M31JM) SETTiUG/CMT/ADPHWS 0823/15 TJFTJM) PULL ROCK SCREEN (05!30/15) 06/23/15 CJN'JMO GLV CK)(05/31/15) 08/30/15 GTW/J GLV C/O (08/30/15) 12/03/15 RCT/JM) SET RDGC SCREEN (11/17/15) 5-1/2' FES X NP, D = 4 9-58" X 5-1/2' BKR S-: 5-112"X 4-12" XO. ID = Fam FILL PRUDHOE BAY UNIT WELL, 01-23 PERMIT No: 18218M AR No: 50-029-2085400 TION, R15E 636' FFL 8 549' FWL BP B(ploradon (Alaska) PROPOSED REV 5 Minimum ID =_" 812-TBG,17#,13CR A0, 10186• VAM TOP, .0232 bpf, D =4.892' TOPOF7"LNR 10240' TOPOF_LNR 10315' 4-12• TBG, 12.6#, L80, TC:k 10325- .0152 bpf, D = 3.958' 3-12' LNR_#,13CR45 STL, 10330' .0087 bpf, D = 2.992' 4-12'X 7'BKR DELTA WHIPSTOCK(_/ /� 10720' 7• LNR 29#, L-80_0371 bpf, ID = 6.184' —10720• 3-1 /4' LNR, e.6#,13CRA5 TC 11, .0079 bpf, D = 2.85' 10780' PBiFORATDN SUMMARY Rff LOG: ON ANGLEAT TOP FT3TF: .0 Npte: Refer to Production DB for historical pert data SIZE I SPF I NTE iVAL Opn/Sg I SHOT I SOZ PBiD13212• .0058 bpf, D = 2.441" 13478- 1 2208' 1 I I:z GAS LFT MANDRELS 5 3174 3167 15 MMG DOME RK 16 4 5250 4812 46 Mr1G SO RK 20 3 7100 6089 48 NTA. DW RK 0 2 8563 7102 44 MNG DW RK 0 1 9915 8114 41 MNG DMY RK 0 10161• 5-12•HPSXNP If]=4 Sat" 10172' —19-5/8• X 5-12" BKR S-3 R(R D = 3.850• 10196• 5-1/2• X 4-12" XO, D = 3.958• 10198' 4-12" HES X NP, D = 3.813" 10303• 4-12" H6 10315' 3.70' DEPLOYSLV, D=3.00' 10320' 3-12' _ X NP, D = 2.813' 10326• 4-12" WLEG, D=3.958• 10330' 3-12" X 3-1/4' XO, D = 2.786' MLLOUT WINDOW (01-23A) 10780• 3-1/4• X 2-7/8' XO, D = 2.377' DATE REV BY COMMENTS DATEREV BY COMMENTS 1128/82 ORIGINAL COMPLETION 08/06/19 JWJMD BUILT PROPOSED REV 3 010207 N4ES RWO 0822119 JWJMD BOLT PROPOSED REV / / CTD ST 01-23A 0822119 JWJMD BUILT PROPOSED REV 5 0520/19 JMD BULTPROPOSED 06/12!19 JMD BUILT PROPOSED REV 06/13/19 JMD BULT PROPOSED REV 2 PRUDHOE BAY UNIT WELL: 01-23A PERMIT No: API No: 50-029-20854-01 BP Exploration (Alaska) 5 Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis Top of 7" Otis 0.0 ft , —CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub 7-1/16" 51, Flange x 7' Otis Boz Top of Annular 6.0 ft yddl 7 1/16 Top of Annular Element 6.7ft Annular Bottom Annular CL Blind/Shears 9.3 ft CL 2-3/8" Pipe/Slips 10.1 ft 61 B2 Ba 84 Kill Line CL 2-3/8" x 3-1/2" VERs 12.6 ftIN CL 2-318" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose . TI . T2 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS k IA OA LDS Ground Level 0 Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Ste Task Res onsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or J"Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then , it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engin6ers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. III° • 1 e 2 1 8 0 BM<ER PRINT DISTRIBUTION LIST 2 9 12 7 1UGHES a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 WELL NAME 01-23 900 E.Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE February 17,2018 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizaresanbhge.corn TODAYS DATE March 7,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM, Final Surveys) (Compass) PERSON ATTENTION #OFnPRINTS #UI-I'FON I S ' #OF COPIES #OF COPIES #OF COPIES V V V V V tnY 1 BP North Slope. 0 1 1 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico 0 3-344 700 G StreStre et SCANNED MAR 2 3 2010 70 Anchorage,AK 99501 3 ExxonMobil,Alaska 0 0 1 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 1 0 Attn:Makana Bender An ho 7th Ave,Alaska Suite9101 1� _ _ Anchorage,Alaslw 99501 �((,' I 5 DNR-Division ofOil&Gas *** 0 0 1 1 0 GarretBrown 550 Avenue, RECEIVED 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 **Stamp"confidential"on all material deliver to DNR J MAR 0 8 2018 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,1R2-1 AOGCC C^ 900 E.Benson Blvd. V IV Anchorage,Alaska 99508 Attn:Gerardo Cedillo TOTALS FOR THIS PAGE: 0 2 5 4 0 STATE OF ALASKA } •LASKA OIL AND GAS CONSERVATION COMMIS • REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon 0 Plug Perforations ❑ 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:Sand Consolidation WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:, 182-180 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 g AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 0 50-029-20854-00-00 7. Property Designation(Lease Number): ADL 0028329 • 8. Well Name and Number: . PBU 01-23 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: 'E 1 V Total Depth: measured . 11452 feet Plugs measured feet > 9 C true vertical • 9223 feet Junk measured feet 1 J Effective Depth: measured 11404 feet Packer measured 10185 feet true vertical 9188 feet Packer true vertical 8317 feet C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 37-116 37-116 1490 470 Surface 2562 13-3/8"72#L-80 36-2598 36-2598 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1207 7"29#L-80 10242-11449 8359-9221 8160 7020 Perforation Depth: Measured depth: 11098 11108 feet 11140-11170 feet 11183-11190 feet 11196-11203 feet 11213-11223 feet True vertical depth: 8964-8972 feet 8995-9017 feet 9027-9032 feet 9036-9041 feet 9049-9056 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker S-3 Packer 10185 8317 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals ed(measured: 11098'-11108i,111140'-11170'),11183'-11190',11196'-11203',11213'-11223'. SCANNED �` z 20E, Treatment descriptions including volumes used and final pressure: 10 Bbls 50/50 Methanol/Water,456 Bbls 3%KCL,242 Bbls Liquid N2,17 Bbls Musol,3 Bbls Sandtrap A,3 Bbls Sandtrap B,2 Bbls Sandtrap C,1 Bbl Acetic Acid,1 Bbl HC-2 Foamer, 188 Bbls Fresh Water,2257 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 18 647 5 1177 177 Subsequent to operation: Shut-In 1500 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development IZ Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: , Oil H Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,,i---4-4 Phone +1 907 564 4424 Date 9/15/15 Form 10-404 Revised 5/2015 VT-1--- ! 4,1 / i Ci RBDMS SEP 17 2015 Submit Original Only// • • C, O• CD CD CD CD 0 0 CD CC N- O CO co N CO O O O ti O N LO 0 N CO 'Sr LO N- CO 0 y o 0 0 0 0 0 0 � rnmLoticov (V) a �ra) r— °o - - Nv CO 0 (0 (o ( N- CO C) a) N N CO LO O CO 10 N COct N N- CO C)) CO CO H co CO O) co r- co co O C() N N N N- CO CO CD °O CA (T () 0) co C co (,) O N M r C)) c) N N CA O r O O O GI I I i i i N O Q N r� mcOo � NN0 DI r CO (h C'O N CO = pQ • W '- IO o Occoo0O10 Pco NI-CS) _1 °J° °J° IC) O = m 4:k k k 4:k —I 0o L O rr-- *k . 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O 0 % S ° % < CD e E O C Z m@@ < - 2 = Cr) �'e 2c:13) a a \ / - y — e o e e o = g p = _ E � 6 ) /a \ £ e 2 £ r � '5 C C C5 E \ $ 9 w WS o D _ e o ._ o _ @ y 2 m e e o G@ I E 2 e I 13 E O / 5 2 O 2 r n 2 m m 3 < I ± En $ co cr) co CN`-- � \ ¥ I HEE= 6-3/8"aw .:IIMELLI-EAD= MC GEN II • SiOY NOTES: "•36 PPM H2S*** ACTUATOR= BAKER 5-1/2"CHROME TBG OKI3.El.EV= 74' 0 1 —2 3 E3F.REV= ? a' -4 1 , 404 •, • • KOP= 2805' 1 VO 0'. 2097 —hES ES CEMENTER 4 Max Angle= 48°,..690(/' .1 '4 •I • • Datum MD= 10973' ii,d •4 .• Datum TVD= 8800'SS 9-5/8"CSG,40#,L-80,TC-11,D=8.835' H 2104' I I 22()8 13-3/8"CSG,72#,L-80,13=12.347" —1 2596' -41 GAS LFT k4APEIRE_S ST PV TVD DEV TYPE VLV LATCH FORT DATE 11 5 3174 3167 15 WAG CONE PIK 16 08/30/15 Minimum ID =3.725" @ 10303' 4 5250 4812 46 WAG SO RK 20 08/30/15 4-1/2" HES XN NIPPLE 3 7100 6089 48 k&G LW FE0 05/31/15 2 8563 7102 44 MMG MY RK 0 01/01/07 1 9915 8114 41 11.4016 LIMY RK 0 05/31/15 I I 10161' H5-1/2"HES X NP,0=4.562" 5-1/2"TBG,17#, 13CR-80, --I 10186' 10177 —9-5fir X 5-1/2"BKR S-3 PKR,ID=3.850" VA M TOP,.0232 bpf,0=4.892" 10186 1—5-1/2'X 4-1/2"XO,V=3.958' I I 1 10198' —4-1/2"HES X NP,D=3.813' TOP OF 7'LNR 1— 10240' I I 10303' —14-1/7 HES XN MP,ID=3.725' 1 4-1/2"TE3G,12.6S,L-80,TC-1, — 10325' ' . 10325' —I 4-1/2-VVLEG,D=3.958" .0152 bpf,,t)=3.958' - 9-5/8'CSG,47#,L-80,13=8.681" I— 10548' A L PB;FORATION SUMMARY I REF LOG: Be-ICS ON 11/23S2 ANGLE AT TCP PERF: 43'©11098' I Note:Refer to Producbon DB for historical perf data SEE I SR F, INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 11098-11108 0 02/16/11 3-3/8' 4 11140-11170 0 01/06/89 3-3/86 11183-11190 0 01/31/90 3-3/8' 6 11196-11203 0 01/31/90 3-3/8" 6 11213-11223 0 02/23/98 I _ _ - 11288' SUM —SL TAGGED TOP OF FILL(09/24/14) T LNR,290,L-80,.0371 bpf,0=6.184" —I 1144T '"•••••••111.1 1..1... •••••.141*••**4 7D — 11452' ...............1 DATE RB/BY COMMENTS , DATE , RB/BY COMENTS PRUDHOE BAY INT 11/28/82' ORIGINAL COMPLETION 06/23/15 TJFVJAD FULL ROCK SCREal(05/30/15) WELL: 01-23 01/02/07 144ES FM10 06/23/15 CJN/JMD GLV 00(05/31/15) PERMIT No:'1821800 01/02/12 LEC/PJC SET ROCK SCREEN(12/19/11) 08/30/15 GTVV/JMD GLV CIO(08/30/15) AR No: 50-029-20854-00 05/28/14 RS/AU RLL ROCK SCREEN(05/23/14) SEC 8,T1ON,R15E 636'FM-&549'Pd'& 06/09/14 RK/JMD MO/SET ROCK SCRN(06(05-064) 10/02/14 TLINJM).00 ROCK SCRNTAG FLL(9/24/14) BP Exploration(Alaska) Imag~!al~roject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing (done) RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: [] Diskettes, No, [] Other, No/Type [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) •,,"s Logs of various kinds [] Other BY: BEVERLY BREN VINCENT ~L MARIA LOWELL Project Proofing BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELl. Scanning Preparation ~ x 30 = IF0 + ~C~ '= TOTAL PAGES ~0 ?- BY: ~.Y BREN Production Scanning Stage 1 BY: Stage 2 (SCANNING IS COMPLETE AT THIS POI~I' UNLES~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE OASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) YES 'X NO OUNT MATCHES NUMBER IN SCANNING ~ BRE. WNCENT SHER¥~ MAR,A LOWEL~ ~A~.: ~. IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ' ~S NO ReScanned ¢individual page [special attention] scanning completed) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg Eki AUG ` 7 LL'!2. Alaska Oil and Gas Conservation Commission Q 333 West 7 Avenue 1 Anchorage, Alaska 99501 t 0 t Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -196 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -226 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 „_� 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA _ 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA • STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well 11 Plug Perforations U Stimulate 11 Other 11 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Q Exploratory ❑ ' 182 -180 -0 3. Address: P.O. Box 196612 Stratigraphic0 Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 .. 50- 029 - 20854 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028329 ' ' PBU 01 -23 9. Field /Pool(s): PRUDHOE BAY, PRUDHOE OIL 10. Present Well Condition Summary: Total Depth measured 11452 feet Plugs measured None feet true vertical 9223.29 feet Junk measured None feet Effective Depth measured 11404 feet Packer measured 10182 feet true vertical 9188.19 feet true vertical 8388 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 74 20" 91.5# H-40 40 - 114 40 - 114 1490 470 Surface 2557 13 -3/8" 72# L -80 39 - 2596 39 - 2521.43 4930 2670 Production 2065 9 -5/8" 40# L -80 30 - 2095 30 - 2095 5750 3090 Production 8444 9 -5/8" 47# L -80 2095 - 10539 2095 - 8571 6870 4760 Liner 1207 7" 29# L -80 10240 - 11447 8357.66 - 9145.64 8160 7020 Perforation depth Measured depth See Attachment feet i7 � True Vertical depth See Attachment feet FEB a U 6 Tubing (size, grade, measured and true vertical depth) 5 -1/2" 17# 13CR -80 29 -10998 29 -8892 4 -1/2" 12.6# L -80 10193 -10334 8892 -8427 Packers and SSSV (type, measured and true vertical depth) 9- 5/8 "X5- 1 /2 "BKR S -3 PKR 10182 8388 Packer SSV 11. Stimulation or cement squeeze summary: , Intervals treated (measured): FEB 2 2 2011 Treatment descriptions including volumes used and final pressure: : . 12. Representative Daily Average Produc ,. ' •' • - I IMP CIS. I p Oil-Bbl Gas -Mcf Water -Bbl Casinitnehenve Tubing Pressure Prior to well operation: SI Subsequent to operation: 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 — Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ' 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG El 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or /A if C.O. Exempt: N Contact Joe Lastufka Prepared by J Lastufka 564 -4091 Printed e al Joe Lastufka Title Data Manager Signatu - ' I 1 Phone 564 -4091 Date 2/22/2011 RBDMS FEB 2 2 2011 ' .73/ Form 10 -404 Revised 10/2010 S ubmit Original Only • 01 -23 182 -180 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -23 6/18/83 PER 11,140. 11,170. 8,995.1 9,017.04 01 -23 6/18/83 PER 11,183. 11,190. 9,026.55 9,031.67 01 -23 6/18/83 PER 11,196. 11,203. 9,036.06 9,041.18 01 -23 1/6/89 RPF 11,140. 11,170. 8,995.1 9,017.04 01 -23 1/6/89 RPF 11,183. 11,190. 9,026.55 9,031.67 01 -23 1/6/89 RPF 11,196. 11,203. 9,036.06 9,041.18 01 -23 1/31/90 RPF 11,183. 11,190. 9,026.55 9,031.67 01 -23 1/31/90 RPF 11,196. 11,203. 9,036.06 9,041.18 01 -23 2/23/98 APF 11,213. 11,223. 9,048.5 9,055.81 01 -23 2/16/11 APF / 11,098. 11,108. 8,964.38 8,971.7 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 01 -23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/15/26111T/1/0=1700/1600/0 Load and Kill (Pre E -line Perforating) Pumped 5 bbls meth and 1290 bbls crude down tbg to load and kill. FWHPs= 400/1400/0 Valve positions at time of departure; SV,WV,SSV shut. MV, IA, OA open f l 1 l I l ( 2/16/2011; ***JOB CONTINUED FROM 15- FEB- 2011* * *(E -LINE PERF) INITIAL T /I /O = 300 /1350 / 0 1PT GOOD. RIH WITH MH- 22(5X3) /ERS /PEK -C /CALB/ FIRING HEAD/ 3.375" GUN . 1OAL = 19', WEIGHT = 300 LB, OD = 3.375 ", FISHING NECK = 1 -3/8 ". CONDUCT CORRELATION PASS AND TIE INTO SHORT JOINTS ON CEMENT BOND LOG !DATED 27 -NOV -1982. SHOOT 11098' - 11108' INTERVAL WITH 3.315" HSD 3406 PJ HMX GUN 6 SPF AND 60 DEG PHASING: CCL TO TS = 3.67', CCL STOP ;DEPTH = 11094.3'. FINAL VALVES: SSV CLOSED, SWAB CLOSED, WING CLOSED, MASTER OPEN. RDMO AND HANDOVER TO DSO. . ** *JOB COMPLETED * ** FLUIDS PUMPED BBLS 6 METH 290 CRUDE 1 DIESEL 297 TOTAL TREE = 6 -3/8" CIW • WELLHEAD = FMC GEN ID S TES: 5 - 1/2" CHROME TBG ACTUATOR". BAKER 0 1 -2 3 KB. ELEV = 74' BF. ELEV = ? �• i KOP = 2805' • 9 ∎ ■♦ 4 2092' H HES ES CEMENTER I Max Angle = 48° @ 6900' ,j� � �∎ Datum MD = 10973' �. • Datum TV D = 8800' SS 19 -5/8" CSG, 40 #, L -80, TC-11, ID = 8.835" H 2104' 1 1 1 2208' 1- 15 -1/2" HES X NIP, ID = 4.562" 1 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I--I 2596' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3174 3167 15 MMG DOME RK 16 02/24/10 Minimum ID = 3/25" @ 10303' 4 5250 4812 46 MMG DMY RK 0 02/24/10 4-1/2" HES XN NIPPLE 3 7100 6089 48 MMG DOME RK 16 02/24/10 2 8563 7102 44 MMG DMY RK 0 01/01/07 1 9915 8114 41 MMG SO RK 24 02/24/10 u 1 10151' 1 — I5 - 1/2" HES X NIP, ID = 4.562" I 5 -1/2" TBG, 17 #, 13CR -80, — 10186' 1 I 10172' 19 - 5/8" X 5 -1/2" BKR S -3 PKR, ID = 3.850" 1 VAM TOP, .0232 bpf, ID = 4.892" _ 1 10186' 1 — I5 - 1/2" X 4 -1/2" XO, ID = 3.958" I 10198' 1 - 14 - 1/2" HES X NIP, ID = 3.813" 1 1TOPOF 7" LNR 1 - 1 10240' ' ' 10303' — 14 -1/2" HES XN NIP, ID = 3.7251 4 -1/2" TBG, 12.6 #, L -80, TC-II, — 10325' 1 ` I 10325' 1-14 -1/2" WLEG, ID = 3.958" 1 .0152 bpf, ID= 3.958" 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10548' 1 • • PERFORATION SUMMARY 1 REF LOG: BHCS ON 11/23/82 ANGLE AT TOP PERF: 43° @ 11140' 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 11140 - 11170 0 01/06/89 1 3 -3/8" 6 11183 - 11190 0 01/31/90 3 -3/8" 6 11196 - 11203 0 01/31/90 3 -3/8" 6 11213 - 11223 0 02/23/98 1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11447' t�1 10004 111 1 TD H 11452' 1.�...1.1.�.1a DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/28/82 ORIGINAL COMPLETION 02/27/10 DAV /PJC GLV C/O (02/24/10) WELL: 01 -23 01/02/07 N4ES RWO ! 11/24/10 LT /PJC EXCLUDER SCREEN (11/23/10) PERMIT No: 1821800 01/15/07 DAV /PAG GLV C/O 02/26/11 ET/ PJC PULL SCREEN (02/09/11) API No: 50- 029 - 20854 -00 03/05/07 MWS /PJC DRLG DRAFT CORRECTIONS SEC 7, T10N, R15E, 5028.91' FEL & 357.21' FNL 08/04/07 SWC/SV GLV C/O 07/22/08 KC/JMD GLV C/0 (07/20/08) BP Exploration (Alaska) 09!05/08 Sehfumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll .Inh S ~~~~~~~ ~~~ ~ 4 2fl0~s t .,.. ne ..w.. NO.4865 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 n~.~ n~ L-20511 40016965 OH MWD/LWD EDIT O6/OS/OS 2 1 B-37 - 40017206 OH MWD/LWD EDIT 06!15/08 2 1 N-01A• 12014032 RST 07/05/08 1 1 B-036 - 12083399 MCNL - cfG 06/07/08 1 1 01-03A 12017505 RST ~ -ap - $Gf 07/15/08 1 1 01-23 12057631 RST G ~ O 07/16/08 1 1 F-05A 12083402 MCNL Co -(O 07/12/08 1 1 09-30 - 11962609 RST - L.~ 07/24/08 1 1 .a.-.+v.~nv.~a.cvvc flcvc~r ~ o ~ JI~]i\11YV NIYV nCl Vn1V IIY~i VIYC l.Vr'T CN~.n 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ` ~ - 'k ~ ~ ~^ Anchorage, Alaska 99508 t~ ~ y^,_ Date Delivered: ,_~_, .,,nr~ft Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950'1838 ATTN: Beth Received by: • h „t,' ;. 07/23/08 ~7~i~~~6~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII _Inh !F NO.4786 Company: State of Alaska Alaska Oil & Gas Cons Comm ~~~~ ~~ ~ ~ ~. L~~U Attn: Christine Mahnken d, UU 333 West 7th Ave, Suite 100 Anchorage, AK 99501 i .... ne ...:,... WB-05 12021166 MEM SBHPS / 06/13/08 1 G-16 11 82438 PRODUCTION PROFILE /~ ~ a 06/21/08 1 R-12 12034908 PRODUCTION PROFILE ~ - (~7 j - 07/14/08 1 1 01-03A 12017505 PRODUCTION PROFILE ~~J~~ `(p 07/15/08 1 1 J-15B 11970838 SCMT 07/17/08 1 1 01-23 12057631 PRODUCTION PROFILE - 07/16/08 1 1 B-18 12071875 LDL _ U G 07/20/08 1 1 4-04/T-26 11999025 LDL / ~ 07/12/08 1 1 J-14A 12066524 MCNL O (-' 05/25/08 1 1 G-15B 11963096 MCNL '~_(~(p ' 05/30/08 1 1 L3-19 11968944 RST ~7j5 - 06/07/08 1 1 L2-11 12014019 RST ~ 06/05/08 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 r Date Delivered: ?="i Alaska Data & Consulting Service 2525 Gambell Street, Suite 40~ Anchorage, AK 99 3-2838 ATTN: Beth --~,~ Received by: u 01-23 (PTD #1821800) Classified a,ERABLE - Passed MITIA Regg, James B (DOA) . Page 1 of 1 Sent: To: From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Monday, August 13, 2007 9:26 PM Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Seltenright, Ana Maria; GPB, FS1 OS Ops Lead Cc: Roschinger, Torin T. Subject: 01-23 (PTD #1821800) Classified as OPERABLE - Passed MITIA tb\ \ D( \Ð:1 ~ Hi all, / Well 01-23 has been reclassified as Operable given the well passed a MITIA after setting dummy GL Vs. Please be aware of the liquid packed annulus. Thank you, Anna scANNED AUG 232007 From: Roschinger, Torin T. Sent: Tuesday, July 31, 2007 7:49 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Seltenright, Ana Maria Cc: NSU, ADW Well Integrity Engineer Subject: 01-23 (PTD #1821800) UNDER EVALUATION for sustained casing pressure - TxIA communication All, Well 01-23 (PTD #1821800) has been found to have sustained casing pressure on the IA. The wellhead pressures were 2450/2450/0 psi on 07/31/07. A subsequent TIFL failed later that same day. The well has been classified as Under Evaluation and may be produced under a 28-day clock. Due to the high shut-in pressure (2450 psi) on this well, it will be put back on-line to restrict the lAP to the FTP around 1900 psi. The plan forward for this well is as follows: 1. 0: TIFL - FAILED 2. S: Set DGLVs in STA# 4 & 5 3. F: MIT-IA to 3000 psi, LLR if fails A wellbore schematic has been included for reference. Please call with any questions or concerns. Thank you, Tarin Roschinger Well Integrity Engineer Office (907) 659-5525 Pager (907) 659-5100 Ext. 1923 8/14/2007 ~ . STATE OF ALASKA ....:5-07 C ·Ei\lì,:: ALAZ OIL AND GAS CONSERVATION COM~'ON RE..,1 ..' .~ ª-, REPORT OF SUNDRY WELL OPERATIONS 0 2 'í f 1. Operations Performed: Atª$k~ Oil & Gí1$ Caos.. 'þ" , o Abandon 181 Repair Well o Plug Perforations o Stimulate o ~htøl8Qûspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 182-180 /' 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20854-00-00 / 7. KB Elevation (ft): 74' oj 9. Well Name and Number: PBU 01-23 v 8. Property Designation: ADL 028329 I 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool f 11. Present well condition summary ( Total depth: measured 11452 feet -. true vertical 9223 I feet Plugs (measured) 10192 Effective depth: measured 11404 feet Junk (measured) None true vertical 9188 feet /~asing """ Collapse Length Size MD TVD Burst Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2595' 13-3/8" 2595' 2594' 4930 2670 Intermediate 10548' 9-5/8" 10548' 8577' 6870 4760 Production Liner 1207' 7" 10240' - 11447' 8358' - 9220' 8160 7020 StAHNED FES 0 7 2007 Perforation Depth MD (ft): 11140' - 11223' Perforation Depth TVD (ft): 8995' - 9056' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 10325 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-112" Baker 'S-3' Chrome packer 10172' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled tubing. Cut and pulled 9-518" casing from 2104'. Tieback new 9-5/8",40#, TCII casing to surface. Cement with 136 Bbls Class 'G'. Run new 5-1/2" x 4-1/2" Chrome tubina to surface. 13. ReDresentative Daily AveraQe Production or Injection Data Oìl-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: N/A Subsequent to operation: 1,259 88,935 -0- 1,800 226 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. J hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-344 Printed Name Terrie Hubble Title Technical Assistant Signature /(Ó ^~ 0 ~ 02"p. ,) I Prepared By Name/Number: I Phone 564-4628 Date 01 , (J7 Terrie Hubble 564-4628 I . . Form 10-404 RevIsed 04/2006 RBDMS 8Ft FEB () 6 200i Mb6 SubmIt Onglnal Only DIgItal Wel1file W~II Events for SurfaceWell - 01' Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> 01 -> 01-23 Date Range: 18/Jun/2006 to 13/Dec/2006 Data Source(s): AWGRS Events Source Well AWGRS 01-23 Date 12/07/2006 AW_GJSS 01-23 09/17/2006 AWGRS 01-23 09/17/2006 AWGRS 01-23 07/24/2006 AWGRS 01-23 07/23/2006 AWGRS 01-23 07/20/2006 A.WGRS 01-23 AWGRS 01-23 AWGB,S 01-23 AWGRS 01-23 AWGRS 01-23 Awc:;,Bs 01-23 AWGRS 01-23 AwGRS 01-23 AWÇ;,RS 01-23 AWGRS 01-23 AWGR5. 01-23 AWGKS 01-23 07/20/2006 07/19/2006 07/19/2006 07/19/2006 07/19/2006 07/18/2006 07/18/2006 07/17/2006 07/17/2006 06/29/2006 06/21/2006 06/20/2006 . Page 1 of 2 Description T/I/O= N/A/O/O, Pre-Rig wellhead MIT PPPOT-T [passed) PPPOT-IC [ passed) Installed high pressure bleeder tool on upper ports on adapter. Pumper clean returns on off side. Pressure up test port to 5000 psi, pressure dropped to 4200 psi in 15 min, this was testing the hanger body seal and neck seals on adapter. Moved to lower tubing hanger test port, pressured up void between lower hanger seal and body seat to 5000 psi for 30 min, body seal on tubing hanger seem to be holding.. Possible leak path for other test, would be by S seals on adapter or inner mandrel on tubing hanger. There should be no problems with getting a BOP test. Test IC casing hanger to 3,000 for 30 minutes. Roll LDS on both spool. All LDS moved free. IBP MONTHLY RENTAL FOR 08/18/06 - 09/18/06. MOs 2. NOTE IBP SET 07/18/06 NOTE: WATCH FOR IBP PULLED DURING RWO SET BPV, PRE RIG ***WSR continues from 7/23/06***. T/I/O= 0/0/20. MIT- OA to 2500 psi (pre rig) [PASSED on the second attempt] Lost 50 psi / 1st 15 min and 10 psi / 2nd 15 min. Well shut in upon arrival. Pumped 14 bbls of 48* diesel to achieve test pressure. Final WHP= 0/0/0. T/I/O= 0/0/20. MIT-OA to 2500 psi. ***WSR continues on 7/24/06*** ***CONTINUED FROM 19-JUL-2006*** BLED TBG & IA PRESSURES TO 0 PSI, MONITORED FOR NO-FLOW. FREED CABLE FROM FLOWTUBES, SMOOTHED, ABLE TO PULL THROUGH. RIG DOWN TOOLS AND LEAVE LITTLE RED TO COMPLETE FREEZE PROTECT POST CIRC OUT. ***JOB COMPLETE*** T/I/O= 250/220/300 Assist E-line, (Circ out well) Pumped 5 bbls methanol, 1080 bbls 1 % KCL, 168 bbls diesel down tubing taking returns up the IA & down the flowline through cosasco jumper line. U-tubed diesel to IA from tubing for one hour. Freeze protected flowline with 5 bbls meth, 75 bbls crude,S bbls diesel, Bled well to 0 psi. FWHP's=O/O/O T/I/0=250/220/300 Assist E-Line (wire blown up hole), (Circ out well) Pumped 5 bbls methanol, 1080 bbls 1 % KCL, 0 bbls diesel down tubing taking returns up the IA & down the flowline through cosasco jumper line. U-tubed diesel to IA from tubing for one hour. Assist E-line w/Stuck Tool String. **Load/TraveIjStand By Time** T/I/0=0/2/85 Temp=SI Bleed IA & OA to 0 psi (assist E-line). OA FL @ 150'. Bled OAP from 85 psi to 0+ psi in 90 minutes. Bled lAP from 2 psi to 0 psi in 10 minutes. TBGP went from 0 to VAC. Final WHPs=VAC/O/O+ ***CONTINUED FROM 18-JUL-2006*** CABLE STUCK IN FLOWTUBES AT 128' FROM SURFACE. PUMPED KCL TO KILL WELL. ***CONTINUED on 20-JUL-2006*** continued from 7-17-06 Assist E-Line CMIT TXIA 3500 psi" Pass" Rwo Prep) (Shut in) pumped 72.5 bbls of 80* crude down IA to reach 3500 psi for CMIT TXIA rig up 1/2 jumper hose to equalize T X IA psi wing leaking call for grease crew. Bleed TXIA psi down bled back 20 bbls 1st test 1st 15 min lost 30/30 psi 2nd 15 min lost % psi for a total of 30/30 psi in 30 min pumped a total of 97 bbls of crude bleed well head psi down bled back 18 bbls get gas Final Whp's 800/800/500 ***CONTINUED FROM 17-JUL-2006*** SET BAKER 3-3/8" IBP AT 10170' MD. SETTING IN IBP IN PBR ASSY. POSITIVE INDICATION OF SET. JET CUT 5-1/2" TUBING AT 10147' MD USING 4.150" SLB POWER CUTTER. POSITIVE INDICATION OF CUT SEEN ON SURFACE. TOOL STUCK AT 128'. ATTEMPTING TO FREE TOOL. ***JOB CONTINUED ON 19-JUL-2006*** ARRIVE LOCATION AND FIND CRUDE OIL ON TREE AND IN CELLAR. BAD O-RING IN TREE CAP APPEARS TO HAVE LEAKED. RIG UP AND RUN IN HOLE WITH BAKER 3-3/8" IBP. ***JOB CONTINUED ON 18-JUL-2006***. T/I/0=200/620/420 Assist E-Line CMIT TXIA 3500 psi (Rwo Prep) (Shut in) rd to location open permit pjsm start rig up T/I/O= 830/625/470 Temp=S/I TBG, lA, OA FL (EL IBP) TFL is at surface, IA FL = 1350' (59 bbls), OA FL = 130' (7.5 bbls) Integral on IA. ***** CONTINUE FROM 06/20/06 ***** (pre rwo) RIH W 3.625 SWAGE AND 10' * 1 3/4" P.BAILER TO 10,273' (SLM) BAILER HAD APPOX. THREE CUP OF PLASTIC COATED TUBING. RAN KJ, 2' STEM AND 3.675 BROACH. TO 10,272 (SLM) WORK TOOLS THROUGH OBSTRUCTION TWICE. UNABLE TO PASS THROUGH AGAIN. FOUR SMALL CHUNKS OF METAL ON TOP EDGE OF BROACH. 4 1/2" XXN PLUG STILL IN HOLE. ***WELL LEFT 5/1*** DSO NOTIFIED *** CONTINUE FROM 06/19/06 **** (pre rwo) ATTEMPTING TO CLEAR OBSTRUCTION IN http://digitalwellfile.bpweb. bp.comIW el1E vents/Home/Default.aspx 2/1/2007 uigItal Wel1fi1e A'WJißS 01-23 06/19/2006 AWGRS 01-23 06/19/2006 AwGßS 01-23 06/18/2006 . Page 2 of2 TUBING FROM 10,226' (SLM) USED BROACHES, SWA. AND B. L. BRUSH. IN PROGRESS.- **** CONTINUE TO 06/21/06 **** IBP MONTHLY RENTAL FOR 04/07/06 - 06/07/06. MOs 10 & 11. NOTE IBP SET 07/07/05 NOTE: PULLED ON 06/18/06 *** CONTINUE FROM 06/18/06 *** (rwo prep) MADE SEVERAL RUNS WITH BAILERS, SWEDGES & B/L BRUSH TO CLEAR OBSTRUCTION (@ 10230' SLM) FROM ABOVE XN NIPPLE. RECOVERING PLASTIC COATING IN BAILER. IN PROGRESS. *** CONTINUE TO 06/20/06 *** *** CONTINUED FROM 06/17/06 *** (pre rwo) PULL BAKER IBP FROM 10,185' SLM. RECOVERED RUBBER IBP ELEMENT. **** CONTINUE TO 06/19/06 *** http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default. aspx 2/1/2007 · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/13/2006 06:00 - 12:00 6.00 RIGD P PRE Rig down off of M-15 Well Slot. Lower and Scope Derrick. Prepare for moving Rig, Modules and Camp. 12:00 - 00:00 12.00 MOB P PRE Move Rig to DS 01-23. 12/14/2006 00:00 - 05:00 5.00 RIGU P PRE RU Rig and Modules on 01-23 Well Slot. Layout Herculite and Rig Mats. Spot Sub, Pits, Pipe Shed, Camp and the Shop. Raise and scope Derrick. RU Lines to Tree for circulating. Hook up lines to Tiger Tank. Begin taking on hot seawater. Accepted Rig at 05:00 hrs on 12/14/2006. 05:00 - 08:00 3.00 RIGU P PRE Continue taking on Sea Water in Pits. Lay lines to Tiger Tank. 08:00 - 09:30 1.50 KILL P DECOMP Pick-up Lubricator and pull BPV. 09:30 - 14:30 5.00 KILL P DECOMP Test Lines at 250/3500 psi. Open Well. Tbg = 0 psi...IA = 0 psi. Circulated Well through the Jet Cut at 10,147' with 120 deg F. Sea Water at 5.0 bpm1700 psi. 680 bbls pumped. Monitor Well dead. 14:30 - 16:00 1.50 WHSUR P DECOMP FMC Serviceman set FMC BPV (note can not install Blanking Plug until Tree is removed). Test BPV from below at 1000 psi x 10 minutes (note can not test from above with-out Blanking Plug installed). Good test. 16:00 - 19:00 3.00 WHSUR P DECOMP Nipple down Production Tree. FMC Serviceman installed Banking Plug on top of BPV. 19:00 - 22:00 3.00 BOPSU P DECOMP Nipple up BOPE. Rig up test equipment. 22:00 - 00:00 2.00 BOPSU P DECOMP Test BOPE per BP/AOGCC requirements a t250/3500 psi. Good test. Test witnessed by AOGCC...J. Chrisp. 12/15/2006 00:00 - 03:30 3.50 BOPSU P DECOMP Complet BOPE test. Rig-down test equipment. Blow down lines. 03:30 - 06:00 2.50 WHSUR P DECOMP Pull Banking Plug with Landing Joint. Pick-up Lubricator and pull BPV. Lay down same. 06:00 - 07:00 1.00 WHSUR P DECOMP Pick-up BFT 5 1/2" Double Spear. Plant Spear in Tubing Hanger. BOLDS. Pull Hanger free at 160K. Pull to the Floor at 175K (dragging). Lay down Spear and tubing Hanger. 07:00 - 08:00 1.00 PULL P DECOMP Rig-up to lay down 5 1/2" Tubing. Rig-up SWS Spooling Unit. 08:00 - 10:30 2.50 PULL P DECOMP Lay down 54 Jts of 5 1/2" Tubing to the SSSV. Recovered Control Lines, 6 Bands, and 27 Clamps...complete. 10:30 - 11 :00 0.50 PULL P DECOMP Lay down SSSV. Rig-down Spooling Unit. 11 :00 - 21 :00 10.00 PULL P DECOMP Continue to single down 5 1/2" Tubing and GLMs in Pipe Shed. Pin ends on almost every joint sererely deterioated. Recovered 242 full Joints, 27' Jet Cut Stub (6 1/4 flare. Good clean cut), 12 GLM Assemblies, SSSV. Rig-down 51/2" Tubing handling equipment. Clear Floor. 21 :00 - 22:00 1.00 PULL P DECOMP Rig-up 3 1/2" Drill Pipe handling equipment. Finish loading Drill Pipe and complete tally. 22:00 - 23:30 1.50 PULL P DECOMP Make-up BHA #2 as follows: 8.1/2" Bit, 95/8" Csg Scraper, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, XO, 9 ea 6 3/8" Drill Collars, XO. 23:30 - 00:00 0.50 PULL P DECOMP Start to RIH with BHA #2 and single 3 1/2" Drill Pipe from Pipe shed. 12/16/2006 00:00 - 06:00 6.00 PULL P DECOMP Continue to RIH with BHA #2 with 3 1/2" Drill Pipe from the Pipe Shed. 06:00 - 06:30 0.50 PULL P DECOMP Service Rig. Inspect Derrick. Check PVT alarms. 06:30 - 08:30 2.00 PULL P DECOMP Finish RIH with BHA #2 and 3 1/2" Drill Pipe. PUW = 180K. SOW = 103K. Tagged the top of the 51/2" Jet Cut stump at 1 0, 152' (BHA #2, 310 Jts, and 24' of Jt #311). 08:30 - 11 :00 2.50 PULL P DECOMP Mix and reverse in with a 40 bbl sweep. Continue to reverse Printed: 1/2/2007 12:56:47 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/16/2006 08:30 - 11 :00 2.50 PULL P DECOMP circulate Well bore until clean at 5 bpm/1350 psi. Total bbls pumped = 775. Saw an occasional small amount of scale and derbis in returns. 11 :00 - 12:30 1.50 PULL P DECOMP Cut and Slip Drill Line. 12:30 - 16:00 3.50 PULL P DECOMP Trip-out standing back in Derrick with 3 1/2" Drill Pipe and BHA #2. 16:00 - 17:00 1.00 PULL P DECOMP Set back Drill Collars. Break out and lay down BHA #2. 17:00 - 18:00 1.00 EVAL P DECOMP Prep for E-Line operations. Nipple down Flow Nipple. Nipple up Shooting Flange. SWS spot Logging Unit. 18:00 - 23:30 5.50 EVAL P DECOMP Pre-tour safety meeting. Pre-tour Rig checks. RU Schlumberger E-line with full pressure control and wireline BOPs. Lined up on kill line to pump into well if needed. MU USIT logging tool. Pressure test against well bore to 500 psi - OK. 23:30 - 00:00 0.50 EV AL P DECOMP RIH with US IT logging tool on wireline. J 12/17/2006 00:00 - 01 :00 1.00 EVAL P DECOMP Continue RIH with US IT logging tool on wireline. 01 :00 - 06:30 5.50 EV AL P DECOMP Bottom out at 10,095' WLM. Begin logging up in corrosion mode to 2,600'. Finish logging to surface in cement evaluation mode. Re-Iog over interval at approximately 5,000' due to losing USIT signal for a short amount of time. Re-Iog over TOC. TOC early field pick = 2,170'. 06:30 - 09:00 2.50 EV AL P DECOMP Finish Logs. Lay down Tool. Download data. Review data with Anchorage Engineer. Top of Cement = 2,170'. Back-off collar = 2,088'. Target for Cut = 2,066'. 09:00 - 10:30 1.50 EVAL P DECOMP Make-up 3-strand String Shot (12'). Log String Shot into place and straddle the Casing Collar at 2,088' with the TS at 2,082' and the BS at 2,094'. Fire shot. Looked good. 10:30 - 11 :30 1.00 EVAL P DECOMP Pull out with Tool. Rig down E-Line. 11 :30 - 13:00 1.50 EVAL P DECOMP Nipple down Shooting Flange. Nipple up Flow Nipple. 13:00 - 14:00 1.00 EVAL P DECOMP Clear and clean Floor. 14:00 - 18:00 4.00 PULL P DECOMP Shut-down for Required Safety Stand-Down with Paul's Crew. All 4es Crews, Tool Pushers, and WSL have attened at least one or more Safety Stand-Down(s). 18:00 - 18:30 0.50 PULL P DECOMP Pre-tour safety meeting and Rig inspection. 18:30 - 19:00 0.50 PULL P DECOMP PU and MU 95/8" RBP with Halliburton reps. 19:00 - 21 :00 2.00 PULL P DECOMP TIH with 95/8" RBP and setting tool assembly on 3 1/2" DP from the Derrick. 21 :00 - 22:00 1.00 PULL P DECOMP In with 113 Joints of DP. UW = 60K , DW = 58K. Set 9 5/8" RBP @ 3,588' mid-element. The top of the RBP is @ 3,583'. Lay down 2 Joints of DP and MU Headpin. Pressure test the 9 518" against the RBP to 1,000 psi for 10 mins, charted - OK. It took -1 bbl to achieve test pressure. 22:00 - 23:30 1.50 PULL P DECOMP Break off Headpin and dump 44 sacks (2,200 Ibs) of sand down the DP on top of RBP. MU Headpin and flush out the DP by pumping a DP volume at a rate of 5 bpm I 200 psi. Break off Headpin and RIH to tag the top of sand. Tag TOS @ 3,530'. 23:30 - 00:00 0.50 PULL P DECOMP MU Headpin. Pressure test the 9 5/8" against the RBP with sand on top to 1,000 psi for 10 mins, charted - OK. It took -1.75 bbls to achieve test pressure. Break off Headpin. 12/18/2006 00:00 - 02:00 2.00 PULL N WAIT DECOMP Wait on vac trucks to deliver hot 9.8 ppg brine. 02:00 - 03:30 1.50 PULL P DECOMP First vac truck arrives on location. Hook up to the vac truck and begin displacing the well to 120 degree, 9.8 ppg brine directly from the truck taking seawater returns into the Pits. Circulating Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/18/2006 02:00 - 03:30 1.50 PULL P DECOMP at a rate of 4 bpm I 250 psi. Pumped a total of 255 bbls into the well. Clear and clean Rig Floor. 03:30 - 05:00 1.50 PULL P DECOMP TOH with RBP Setting Tool Assembly standing back DP in the Derrick. Break down and lay down RBP Running Tool Assembly. 05:00 - 06:00 1.00 PULL P DECOMP PU and MU BHA #3......81/4" Multi-String Cutter per Baker rep. 06:00 - 06:30 0.50 PULL P DECOMP Service Rig. Inspect Derrick. Check PVT alarms. 06:30 - 08:00 1.50 PULL P DECOMP Rig up lines from choke Manifold and Wellhead to Slop Tank. OAP = 700 psi. Bleed down to 50 psi. 08:00 - 09:00 1.00 PULL P DECOMP Trip in with BHA #3 and 3 1/2" Drill Pipe (56 total joints). Pick-up 10' Pup Joint. 09:00 - 10:30 1.50 PULL P DECOMP Make-up Kelly. PUW = 58K. SOW = 58K. Locate top collar at 2,061' and locate bottom collar at 2,105' (Note this the the 44' Casing Joint that is at 2,044' - 2,088' on the Log). Pull-up 18' from bottom collar to 2,087' (Note this is 2,070' on Log). Start cut at 10:00 hrs. 6 bpm/1000 psi. RPM = 50 - 60. Amps = 90 - 100. OAP = 100 psi. After 30 minutes Casing appears to be cut. Stalled out on torque. OAP jumped up to 220 psi. However..... 10:30 - 13:30 3.00 PULL P DECOMP Knives appear to be hung up (casing in compression setting down on knives?). Unable to rotate. Pull up to 125K. Continue to work free. Work torque in an attempt to rotate. Continue to work up to 185K. Finally came free...with much joy. 13:30 - 14:00 0.50 PULL P DECOMP Set back Kelly. Lay down Pup Joint, Head Pin and Circulating Hose. 14:00 - 19:00 5.00 PULL P DECOMP PJSM with All. Start to circulate out Arctic Pack. Pump 120 bbls of -120 deg 9.8 Ib/gal Brine at 5.75 bpm/1 ,000 psi. Got instant returns from 13 3/8" x 9 5/8" Annulus. Adjust Choke and stabilize OAP at -350 psi. Spot 120 bbls of hot diesel in IA and let soak for 45 mins. Pump a 50 bbl pill of Safe-Surf-O around and shut down to wait on more brine and dirty truck to return. 19:00 - 23:00 4.00 PULL N WAIT DECOMP Wait on another truck of hot 9.8 ppg brine and the dirty truck to return prior to continuing Arctic Pack removal. The brine truck showed up at 20:00 hrs. Offload the brine into the Pits and send the truck for 150 bbls of hot water to mix with Arctic Pack returns. At 23:00 hrs, the truck is back and ready to begin circulating again. 23:00 - 00:00 1.00 PULL P DECOMP Begin taking returns out of open top tank to make room for more returns. 12/19/2006 00:00 - 02:00 2.00 PULL P DECOMP Break circulation down the DP taking returns up the OA into an open top tank. Pumping 140 degree diesel with Little Red Hot Oil at a rate of 2 bpm I 600 psi. Pumped a total of 125 bbls of diesel. Pump 14 bbls of hot 9.8 ppg brine down the DP to spot the diesel in the OA and allow to soak for 1 hour. RD Little Red Hot Oil. 02:00 - 04:00 2.00 PULL P DECOMP Circulate out the diesel with hot 9.8 ppg brine down the DP and up the OA. Break circulation at a rate of 4 bpm I 400 psi. Pumped a total of 160 bbls. RD circulating equipment. PU single Joint of DP to be on even stands. 04:00 - 05:00 1.00 PULL P DECOMP TOH with BHA #3 standing back DP in the Derrick. 05:00 - 06:00 1.00 PULL P DECOMP On surface with BHA #3. Inspect Cutter Assembly. All Knives Printed: 1/212007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/19/2006 05:00 - 06:00 1.00 PULL P DECOMP intact and in place. However, the bottom 2.40' of BHA below the Knives was twisted/broken off and missing. The fish is 8 1/4" OD on bottom and 4 1/4" OD on top. 06:00 - 07:30 1.50 PULL P DECOMP Service Rig. Check PVT alarms. Inspect Derrick. Discuss Plan forward with Anch Eng. Clear and clean Floor. Steam heat Wellhead. 07:30 - 09:30 2.00 PULL P DECOMP Make-up 9 518" Casing Spear wlSingle Grapple. Plant Spear in Casing. FMC Serviceman BOLDS. Pull 9 5/8" Casing Hanger to Floor with a normal expected string weight of 95K. However, the Hanger came free and started moving up-hole at -50K due to being landed in compression. Inspect Hanger. Release Spear and lay down same. 09:30 - 10:30 1.00 PULL P DECOMP Rig-up Floor and Pipe Shed to handle and lay down 9 5/8" Casing. 10:30 - 17:00 6.50 PULL P DECOMP POOH & UD 9 518" casing. Recovered 49 full jts + 26.75' cut off jt. Also recovered 8 free floating centralizers & 2 Bow Spring centralizers. Max Break out torq = 44K, Min Break out torq = 32K. Ave torq = 38K. 17:00 - 18:00 1.00 PULL P DECOMP RID casing tools. Clear & clean rig floor. 18:00 - 19:00 1.00 PULL P DECOMP Wait on plan forward. Con't to clear & clean fllor. RlU tools to handle DP. 19:00 - 21 :00 2.00 PULL P DECOMP Clean pits 1 & 2. Flush out & drain BOP stack. Had to suck out stack wi Vac truck. Install Wear Bushing. Run in 2 lock down screws. 21 :00 - 22:00 1.00 CLEAN P DECOMP P/U & MIU BHA # 4 as follows: 8.5" Taper Mill, 2 - Boot Baskets, Bit Sub, String Magnet, Bumper Sub. Oil Jars, XO, 9 * 6 1/4" DCs, XO. TL= 316.16'. RIH wI same. 22:00 - 23:00 1.00 CLEAN P DECOMP RIH wi BHA # 4 on 18 stands of 3 1/2" DP & 1 single jt. P/U Kelly. 23:00 - 00:00 1.00 CLEAN P DECOMP Tag up on 95/8" casing stub @ 2087'. P/U 6' & break circulation. RIH & slowly tag & stack out wi 3K. P/U & begin rotating. Rotate down thru top of casing stub. Only 1 small spot @ top of stub where resistance was recorded. Wor up & down several times while rotating. Stop rotating & work string up & down thru casing top wlo problems. P/U Wt = 58K, S/O Wt = 58K. Rot Wt = 58K. 60 RPMs. 5 BPM @ 300 psi. Max torq = 1800 ft-Ibs. 12/20/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Finish working thru top of casing stub wlo rotation. Set back kelly & blow down lines.Set back kelly. POOH & stand back 3 1/2" DP. 01 :00 - 02:00 1.00 CLEAN P DECOMP Break out & UD BHA #6. Clean out junk baskets. Clean string magnet. Recovered small amount ot Arctic Pack. Clear floor. 02:00 - 03:00 1.00 CLEAN P DECOMP MIU BHA #6 as follows: 8" magnet, 2 - Boot Baskets, Bit Sub, String Magnet, Bumper Sub, Oil Jar, XO, 9 * 6 1/4" DCs, XO. TL= 315.07'. RIH wI same. 03:00 - 05:00 2.00 CLEAN P DECOMP RIH wi BHA #6. 33 stands + 2 singles. Had to rotate wi chain tongs to drop thru top of 9 5/8' stub @ 2087'. 05:00 - 06:00 1.00 CLEAN N WAIT DECOMP Wait on 9.8 ppg brine. Trucks were not available due to spill @ GC2. Work magnet on top of fish. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Rig. check PVT Alarms. 06:30 - 10:30 4.00 CLEAN N WAIT DECOMP Continue to wait on 9.8 Iblgal Brine. Continue to wait on Dirty Vac for remaining Arctic Pack disposal. 10:30 - 11 :00 0.50 FISH P DECOMP Off-load 9.8 Iblgal Brine. Make-up Kelly. PUW = 75K. SOW = Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/20/2006 10:30 - 11 :00 0.50 FISH P DECOMP 72K. Circulate at 2.0 bpm/150 psi. Tag fish at 3,528'. Wash down 3-ft. Shut down pump. Set down 3K. 11 :00 - 13:00 2.00 FISH P DECOMP Trip-out with 3 1/2" Drill Pipe and BHA #6. 13:00 - 14:00 1.00 FISH P DECOMP Lay down Magnet BHA. No metal recovery. Clean Boot Baskets. Recovered some small cement pieces. Clear Floor. 14:00 - 14:30 0.50 FISH P DECOMP Make-up BHA #7 as follows: Overshot, XO, Bumper Sub, Oil Jar, XO, 9 ea Drill Collars, XO. 14:30 - 15:30 1.00 FISH P DECOMP Trip in with BHA #7 and 31/2" Drill Pipe. 15:30 - 16:00 0.50 FISH P DECOMP Make-up Kelly. PUW = 75K. SOW = 72K. Pump rate at 2.0 bpm/150 psi. Rotate slowly and wash down to 3,531'. Shut down pump and rotation. Set down 5K. 16:00 - 17:30 1.50 FISH P DECOMP Set back Kelly. Trip-out with 31/2" Drill Pipe and BHA #7. 17:30 - 19:00 1.50 FISH P DECOMP Break out & UD BHA. Recovered 100% of fish. UD same. 19:00 - 21:00 2.00 FISH P DECOMP P/U & MIU BHA #8 as follows: 8" Tapered Mill, Bit Sub, XO, Csg Scraper, XO, 2 - Boot Baskets, Bit Sub, XO, Bumper Sub, Jars, XO, 9 * 61/4" DCs, XO. TL = 319.81'. RIH wi same. 21 :00 - 22:30 1.50 FISH P DECOMP Trip in hole & fill DP every 5 stands. Ran 18 stands & 1 single. P/U kelly & break circul;ation, 4 BPM @ 200 psi. Entered stub @ 2087'. Con't in hole 6.5' & tag scraper on top of stub gently. P/U off stub. P/U, SIO wts = 59K. 22:30 - 23:30 1.00 FISH P DECOMP Circulate & sweep hole clean. Had small amount of Arctic Pack in returns. Pumped 6 BPM @ 400 psi. pumped 350 bbls. SID & monitor well. Well static. 23:30 - 00:00 0.50 FISH P DECOMP Set back kelly & blow down lines. POOH w/3 1/2" DP. 12/21/2006 00:00 - 01 :00 1.00 FISH P DECOMP Stand back DCs. Break out & UD BHA. 01 :00 - 03:00 2.00 FISH P DECOMP Clear & clean rig floor. RlU Wash Pipe handling equip. 03:00 - 04:00 1.00 FISH P DECOMP P/U & MIU BHA #9 as follows: Mill Shoe, 2 jts Wash Pipe, WIO Boot Basket, XO, XO, Boot Basket, XO, 2 - Boot Baskets, Bit Sub wi Float, XO, Bumper Sub, Jar, Pump Out Sub, XO, 9 * 6 1/4" DCs, XO. TL = 374.57'. RIH wi Same. 04:00 - 04:30 0.50 FISH P DECOMP RID Wash Pipe handling equip. 04:30 - 05:00 0.50 FISH P DECOMP Finish M/U BHA. 05:00 - 06:00 1.00 FISH P DECOMP RIH w/3 stands of DC. Tagged up @ 353'. Work thru tight spot & pick back up above tight spot wi 15K overpull. Mill shoe gauge is 12.187". ID of csg = 12.347" Con't to RIH wi BHA. 06:00 - 06:30 0.50 FISH P DECOMP Service Rig. Check PVT Alarms. 06:30 - 07:00 0.50 FISH P DECOMP Continue to trip-in with 3 1/2" Drill Pipe. Make-up Kelly. 07:00 - 08:30 1.50 FISH P DECOMP PUW = 60K. SOW = 60K. RTW = 60K. Pump Rate 3.0 bpm/200 psi. 30 -45 RPMs. Swallow 9 5/8" Casing Stump at 2,088' 4esmd. Continue down over the back-off coli at at 2,105' 4esmd. Bottom out at 2,127'. Short trip Stump and back-off Collar, twice with no problems. Circulate bottoms-up at 6.0 bpml500 psi. 08:30 - 09:30 1.00 FISH P DECOMP Set back Kelly. Trip-out with 3 1/2" Drill Pipe and BHA #9. 09:30 - 12:00 2.50 FISH P DECOMP Lay down Wash pipe Assembly. Clear & clean rig floor. 12:00 - 14:30 2.50 FISH P DECOMP P/U & MIU BHA #10 as follows: Bull Nose, XO, XO, 9 - DCs, XO, Blanking Sub, L. Anchor, Power Sect., U. Anchor, XO, Pump Out Sub, XO. TL = 320.03 Fill BHA wi diesel & RIH. 14:30 - 16:30 2.00 FISH P DECOMP RIH wi BHA #10 on 31/2" DP. Fill each stand while running in hole. 16:30 - 17:30 1.00 FISH P DECOMP Locate & space out Back Off Assy over coupling @ 2108'. Set anchors. Pressure up & break connection wi 1300 psi. Can't to cycle tool until 6 revolutions were made in string. Pressre Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/21/2006 16:30 - 17:30 1.00 FISH P DECOMP decreased to 500 psi, then increased up to 1000 psi. Unset tool. 17:30 - 18:00 0.50 FISH P DECOMP RID circulating head. Drop ball & allow to fall. Pressure up & shear Pump Out Sub. RID circ equip. Blow down lines. 18:00 - 18:30 0.50 FISH P DECOMP Crew change. Check PVT alarms, Inspect derrick. 18:30 - 19:00 0.50 FISH P DECOMP POOH WI BHA #10. 19:00 - 20:30 1.50 FISH P DECOMP Break out & UD BHA # 10. 20:30 - 21 :30 1.00 FISH P DECOMP Clear & clean rig floor. 21 :30 - 22:00 0.50 FISH P DECOMP MIU BHA #11 as follows: Bull Nose, Spear, Spear Extension, Stop Sub, XO. TL = 10.13'. RIH wi same. 22:00 - 23:00 1.00 FISH P DECOMP RIH wi BHA #11. Ran 21 stands + 2 singles. 23:00 - 23:30 0.50 FISH P DECOMP P/U kelly. Tag up on stub @ 2087'. P/U & SIO Wt = 42K. Engage spear & P/U w/3K. Back out from casing w/9 1/2 turns. Fish free. 23:30 - 00:00 0.50 FISH P DECOMP Set back kelly. Blow down lines. Start POOH wi 3 1/2" DP. 12/22/2006 00:00 - 00:30 0.50 FISH P DECOMP POOH wi BHA #11. Stand back 31/2" DP. 00:30 - 02:00 1.50 FISH P DECOMP Break out & UD spear & fish. Recovered 17.10' cut off jt. Had damage on top & pin looked good on bottom. Now have box looking up @ 2104'. Move DCs to right side. 02:00 - 04:00 2.00 FISH P DECOMP Clear & clean rig floor. Pull Wear Bushing. Service choke manifold & BOP valves. 04:00 - 04:30 0.50 BOPSU DECOMP Install test plug. RlU test equip. 04:30 - 06:00 1.50 BOPSU DECOMP Pressure test BOPE as per BP/AOGCC requirements. Test wtinessing waived by Jeff Jones wi AOGCC. LP 250 psi. HP 3500 psi. 06:00 - 06:30 0.50 BOPSU DECOMP Service Rig. Inspect Derrick. 06:30 - 10:00 3.50 BOPSU DECOMP Complete BOPE Test. Rig down test equipment. Blow down lines. Pull Test Plug. 10:00 - 12:00 2.00 CASE P TIEB1 RlU casing tools & torq turn equip. to run 9 5/8" csg. 12:00·13:30 1.50 CASE P TIEB1 P/U Screw-in sub, Check & inspect same. MIU Screw-in sub (pin down), Baffle Plate, XO & ES Cementer Assys. Baker Lok same & RIH.. 13:30 - 18:00 4.50 CASE P TIEB1 RIH wI 9 5/8" casing string. Ran 50 jts 40# & 1 jt 47#. L-80, TCII csg. Torq turned all TCII connections to 12600 ft-Ibs. Installed 1 free floating centralizer/jt, except for last jt. 18:00 - 18:30 0.50 CASE P TIEB1 Crew Change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 CASE P TIEB1 Carefully tag up on casing stub. P/U 1 jt of csg to use as Tong jt to screw into collar. 19:00 - 19:30 0.50 CASE P TIEB1 Slowly lower Screw-in sub into 9 5/8" Box @ 2104'. MIU connection w/9 1/4 turns. Max Torque 13600 ft-Ibs. P/U slowly to 250K. Connection held. SIO same. Fill casing. 19:30 - 20:00 0.50 CASE P TIEB1 RlU test equip & circ head. Pressure test casing to 2000 psi for 30 min. Charted same. Test good. 20:00 - 21 :00 1.00 CASE P TIEB1 Circulate well to heat up annulus fluids. Pumped 115 degree in got 72 degree out. Circ 5.5 BPM @ 160 psi. Pumped 325 bbls. Con't to heat fluid. 21 :00 - 22:00 1.00 BOPSU P TIEB1 NID BOP stack & P/U same. 22:00 - 23:00 1.00 CASE P TIEB1 P/U on casing string. Center pipe, install & set slips w/100K. 23:00 - 00:00 1.00 BOPSU P TIEB1 NIU BOPE. 12/23/2006 00:00 - 02:30 2.50 CEMT P TIEB1 MIU cementing head on casing. Break circulation & heat up annulus fluids. Pumped 5 1/2 BPM @ 450 psi. Had 100 deg. fluid in & 81 deg. fluid out. Pumped total of 750 bbls. RlU cementers & lines. Spot in vac trucks. Printed: 1/212007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/23/2006 02:30 - 06:00 3.50 CEMT P TIEB1 Wait on cementers. Having computer problems. Hold PJSM. Prep to cement casing. 06:00 - 11 :00 5.00 CEMT P TIEB1 Hold PJSM with Crew just coming on tower. Prime-up. Attempt to pressure test lines. However found ice blockage in line. Sort out line problems. Then discover the fresh water Vac Truck had a frozen valve. Thaw-out valve. Start Job. Prime-up, pump 5 bbls of warm 9.8 Brine, test lines to 500/4500 psi...good. Start Cement at 5.0 bpm/415 psi with a density of 15.821b/gal. With 48 bbls of cement pumped away the Blender "powdered-out". Had to shut down for -15 minutes to clear Blender. Resume pumping cement with and average of 4.9 bpm/325 psi. Pumped a total of 136 bbls (calculated 13 3/8" x 9 518" AV = 121.5 bbls). Shut-down Pumps. Drop Wiper Plug (tattle-tail tripped). Start Displace with -3/4 bbls of "wash-up Cement" followed by 9.8 Ib/gal Brine. Start Brine. displacement at 6.1 bpm/250 psi. Caught up to Cement column with 75 bbls pumped. Continue to displace at 6.0 bpm/650 psi. With 110 bbls displaced routed returns from Tiger Tank to Slope Tank. Continue to displace Cement at 6.0 bpm/900 psi. With 145 bbls displaced reduce rate to 2.0 bpm/650 psi. Bumped Plug with 161.0 bbls away at 775 psi (calculated displacement 159.0bbls). Plug down at 10:39 hrs .1 Pressured up to 1800 psi to close Tool. Increase pressure to 2100. Bleed pressure and recovered 3/4 bbls. Check Floats...holding. Shut-down. Est good Cement returned to surface = 7 - 10 bbls. Release SWS Cementers. 11 :00 - 12:00 1.00 CEMT P TIEB1 Blow down lines. Wash-out OA Valve. Drain BOP Stack. Rig-down Cement Head and XO. Suck-out 9 5/8" Casing to "cut area". 12:00 - 13:30 1.50 BOPSU TIEB1 Nipple-down BOP Stack and Tubing Spool. Pick-up Stack. Clean-off top of Slips. Prep for WACHS Cutter. 13:30 - 14:30 1.00 BOPSU WAIT TIEB1 Wait on WACHS cutter. Presently in use on Rig 16. 14:30 - 16:00 TIEB1 Rig-up Cutter. FMC measure and make cut on 9 5/8" Casing. 16:00 - 16:30 TIEB1 Cut complete. Lay down 9 5/8" x 47 Ibltt Cut-off Stub = 23.78'. Install Pack-off. 16:30 - 18:00 1.50 BOPSU TIEB1 N/U BOPE. 18:00 - 18:30 0.50 BOPSU TIEB1 Crew change. Check PVTs. Inspect derrick. 18:30 - 19:30 1.00 BOPSU P TIEB1 Finish NIU BOPE. 19:30 - 20:00 0.50 WHSUR P TIEB1 Pressure test Pack off to 3800 psi for 30 min. Tested Good. 20:00 - 20:30 0.50 BOPSU N SFAL TIEB1 Install test plug. R/U test equip. Attempt to test breaks. Would not hold LP test. Pull test plug. Seal damaged. 20:30 - 21 :30 1.00 BOPSU SFAL TIEB1 Wait on test plug & additional seals. 21 :30 - 22:30 1.00 BOPSU SFAL TIEB1 Install 2 nd test plug. Pressure up to 250 psi. test 5 min, Ok. Pressure up to 3500 psi. NO test. IA dripping. 22:30 - 00:00 1.50 BOPSU SFAL TIEB1 Drain stack. Pull test plug. Seals damaged. Change seal. & dope same. Attempt re-test. IA leaking, NO test. Call for FMC service tech. & new plug. Drain stack. 12/24/2006 00:00 - 01 :00 1.00 BOPSU SFAL TIEB1 Flush out stack & spool. Wait on new test plug. 01 :00 - 01 :30 0.50 BOPSU TIEB1 Install 3rd test plug. pressure up wlo RILDS. pressure up to 3500 psi & hold for 5 min. ~?~joy, testeMood. Pulled test plug. Inspected seals, seal damaged. Apparent damage in bowl of spool. 01 :30 - 02:00 0.50 WHSUR P TIEB1 Install Wear bushing. Call town engineer & discuss tbg spool Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/24/2006 01 :30 - 02:00 0.50 WHSUR P TIEB1 problems. FMC recommending change out. Plan fwd is to clean out cement & test casing then change out spool. 02:00 - 03:30 1.50 CASE P TIEB1 M/U BHA # 12 as follows: 81/2" Bit, 2 - Boot Baskets, Bit Sub, Bumper Sub, Oil Jars, XO, 9 * 6 1/4" DCs. XO. TL = 307.60'. RIH wi same. 03:30 - 04:30 1.00 CASE P TIEB1 RIH wI BHA #12 on 31/2" DP. 04:30 - 05:00 0.50 CASE P TIEB1 Install L. Kelly valve & attempt to test, no good. Installed extra tested floor valve. 05:00 - 06:00 1.00 CEMT P TIEB1 Break circulation & begin drilling cement. Tagged @ 2074'. 06:00 - 07:30 1.50 CEMT P TIEB1 PUW = 57K. SOW = 57K. RPMs = 80. Pump Rate = 6.0 bpm/450 psi. WOB = 2 - 10K. Continue to drill cement. Drill out ES-Cementer at 2,092'. Stop oat 2,098'. 07:30 - 08:30 1.00 CEMT P TIEB1 Test Casing and ES-Cementer at 3,500 psi/10 minutes. Good test. Record on chart. 08:30 - 10:30 2.00 CEMT P TIEB1 Continue to drill out remaining shoe Track. CPump Hi-vis sweep and circulate bottoms-up. 10:30 - 12:00 1.50 CEMT P TIEB1 Test 9 5/8" at 3,500 psi/40 minutes. Lost -75 psi. Good Test. Record on chart. Also tested re-built Lower Kelly Valve that had faild during weekly BOP test. Blow down and rig down lines. 12:00 - 13:30 1.50 CEMT P TIEB1 Continue to Trip in with 8 1/2" Bit. Tag Shoe Track junkITop of Sand at -3,530'. Wash into sand -3'. circulate bottoms-up. 13:30 - 14:30 1.00 CEMT P TIEB1 Trip-out with 31/2" Drill Pipe and BHA #12. 14:30 - 15:00 0.50 CEMT P TIEB1 Lay down BHA. Empty Boot Baskets....cement, rubber, metal cuttings from Shoe Track. 15:00 - 16:30 1.50 WHSUR P TIEB1 Nipple down BOP Stack and set back on stump. Inspect Tubing Spool (attempt to determine what is causing the Test Plug rubbers to be torn up. Discussed replacing the Tubing Spool with Anch Eng eairler in the day). Inspection revealed several rough areas. Due to the posibility of the the Tubing Hanger not testing after running the Completion and setting the Packer we went ahead and changed out the Tubing Spool. 16:30 - 17:30 1.00 WHSUR P TIEB1 NID tbg spool. Remove 2 nd annular valve.. Steam, clean & prep new tbg spool for installation. 17:30 - 18:00 0.50 WHSUR P TIEB1 Begin installation of new tbg spool. 18:00 - 18:30 0.50 WHSUR P TIEB1 Crew change. Check alarms on PVTs. Inspect derrick. 18:30 - 19:30 1.00 WHSUR P TIEB1 Nipple up newq tbg spool. Install 2nd annular valve. 19:30 - 20:00 0.50 WHSUR P TIEB1 Pressure test pack off to 3800 psi for 30 min. Tested Good. 20:00 - 21 :00 1.00 BOPSU P TIEB1 NIU BOPE. 21 :00 - 21 :30 0.50 BOPSU P TIEB1 RlU test equip. Pressure up & & perform body test on breaks. Lp 250 psi. HP 3500 psi. Tested Good. Charted same. 21 :30 - 22:00 0.50 BOPSU TIEB1 Blow down lines. RID test equip. Drain stack. Pull & Ud Test plug. Install Wear Bushing. Run in 2 lock down screws. UD running tool. 22:00 - 23:00 1.00 CASE P TIEB1 P/U & M/U BHA #13 as follows: 8 1/2" mill Shoe, RCJB, 2- Boot Baskets, Bit Sub, Bumper Sub, Oil Jars, XO, 9 * 6 1/4" DCs, XO. TL = 319.36'. RIH wI Same. 23:00 - 00:00 1.00 CASE P TIEB1 RIH wi BHA #12 on 3 1/2" DP. Ran 33 stands + 2 singles. 12/25/2006 00:00 - 00:30 0.50 CASE P TIEB1 P/U kelly & dry tag fill @ 3533'. Break circulation @ 2 BPM, 280 psi. Wash to 3539' Hit hard junk. string started to torq. Increased pump to 3 BPM @ 400 psi. Con't to rotate & stalled RT after 5 min. Torq from free rotation of 1800 ft-Ibs to 9000 ft-Ibs. 45 RPMs. P/U & over pulled 50K. Jars fired. SIO, circ & Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/25/2006 00:00 - 00:30 0.50 CASE P TIEB1 workdown to 3341'. Work, pull pipe & came free. P/U Wt = 77k, SIO Wt = 72K, Rot Wt = 75K. 00:30 - 01 :30 1.00 CASE P TIEB1 Circulate bottoms up. Pumped 4 BPM @ 1320 psi. 01 :30 - 02:00 0.50 P TIEB1 Blow down lines. Set back kelly. Prep to POOH. 02:00 - 03:00 1.00 CASE P TIEB1 POOH & stand back DP. 03:00 - 04:00 1.00 CASE P TIEB1 Break out RCJB & empty same. Recovered 7 pcs of cement, 3 pcs of baffle plate ring. & complete cone from float valve. Redress RCJB. Empty boot Baskets. Recovered 2 1/2 gals of cmt, metal cuttings,sd, & pcs of rubber. Re-make up BHA to re-run. 04:00 - 05:00 1.00 CASE P TIEB1 RIH wi BHA # 12 (Re-run) 33 stands. Set slips. 05:00 - 06:00 1.00 CASE P TIEB1 Monitor & secure well. Prep to stand down for Christmas. 06:00 - 00:00 18.00 CASE P TIEB1 Merry Christmas, Suspend operations for Christmas stand _ down. 12/26/2006 00:00 - 06:00 6.00 CASE P TIEB1 Con't Christmas shut down. Circulated well to heat up fluids. 06:00 - 06:30 0.50 CASE P TIEB1 Service Rig. Check PVT alarms. Inspect Derrick. 06:30 - 07:00 0.50 CASE P TIEB1 Make-up Kelly. PUW = 78K. SOW = 73K. RWT = 75K. Tag top of remaining Junk/Sand at 3,536' with RCJB. Bring Pump on at 4.5 bpm/1900 psi. Work down through sand to 3,555'. 07:00 - 08:30 1.50 CASE P TIEB1 Circulate bottoms-up at 5.0 bpm/2100 psi. Recovered Sand and some rubber. 08:30 - 10:30 2.00 CASE P TIEB1 Trip-out with 3 1/2" Drill Pipe and RCJB. Empty RCJB and recovered several large chunks of the Baffle Plate metal, more rubber, and a few pieces of cement. 10:30 - 11 :00 0.50 CLEAN P INTERV Re-Ioad same BHA for run #3. 11 :00 - 12:00 1.00 CLEAN P INTERV RIH wi RCJB assembly on 31/2" DP. Kelly up. 78K up wt, 73K down, 75K rotating wt. 12:00 - 12:30 0.50 CLEAN P INTERV Tag up @ 3555', kick on pump @ 5 bpm 12600 psi & cleanout to 3563'. 12:30 - 13:00 0.50 CLEAN P INTERV Circulate bottoms up @ 5 bpm I 2600 psi. 13:00 - 14:30 1.50 CLEAN P INTERV POOH & stand back 31/2" DP. 14:30 - 16:00 1.50 CLEAN P INTERV Break out & UD BHA. Recovered 1 small pc of metal in RCJB. Empty boot baskets. Clear & clean rig floor. 16:00 - 16:30 0.50 CLEAN P INTERV M/U RBP retreiving tool. 16:30 - 18:00 1.50 CLEAN P INTERV RIH wi Retreiving tool to 3562'. M/U circulating head. Begin reversing out. 18:00 - 18:30 0.50 CLEAN P INTERV Crew change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 CLEAN P INTERV Reverse out remaining sand on top of RBP from 3562 to 3583'. Reverse until clean. Pumped 5 BPM @ 720 psi. 19:00 - 20:00 1.00 CLEAN P INTERV Displace well. Pump 40 bbl sweep & chase wi clean seawater. Pumped 5 BPM @ 720 psi. Pumped total of 250 bbls. 20:00 - 20:30 0.50 CLEAN P INTERV Engage RBP & SIO wi 15K. Put 1 RH turn in string & P/U. RBP free. Allow rubbers to relax. & monitor well. P/U Wt = 75K, SIO wt = 70K. Push plug down & add 1 single. 20:30 - 21 :30 1.00 CLEAN P INTERV Circulate bottoms up & monitor well. No GTS. Well static. Pumped 4 1/2 BPM @ 500 psi. 21 :30 - 23:00 1.50 CLEAN P INTERV POOH & stand back 33 stand of 3 1/2"DP. 23:00 - 23:30 0.50 CLEAN P INTERV UD RBP & running tool. Clear & clean rig floor. 23:30 - 00:00 0.50 CLEAN P INTERV M/U BHA # 16 12/27/2006 00:00 - 00:30 0.50 CLEAN P INTERV M/U BHA #16 as follows: Bull Nose, Type D Spear, XO, XO, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XO. TL = 306.63'. 00:30 - 03:00 2.50 CLEAN P INTERV RIH wi BHA #16. Ran 103 stands + single. 03:00 - 03:30 0.50 CLEAN P INTERV P/U kelly. Tag up on fish @ 10152'. Con't in hole & swallow Printed: 1/2/2007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/27/2006 03:00 - 03:30 0.50 CLEAN P INTERV spear to 10159'. P/U Wt == 183K, SIO Wt == 103K, Rot Wt == 135K. P/U wI 5K & insure set. Rotate pipe slowly. Put 20 turns in pipe. Lost weight, P/U slowly & fish not free. Repeat & put 30 turns in string. P/U pie free but dragging. Then weight dropped off. P/U to DP connection. Fluid level dropped out of sight. 03:30 - 05:00 1.50 CLEAN P INTERV Attempt to fill hole. Filling hole wi fill up pump. Pumped 150 bbls, no returns. 05:00 - 05:30 0.50 CLEAN P INTERV Monitor well. Set Back kelly & blow down lines. 05:30 - 06:00 0.50 CLEAN P INTERV POOH wi BHA & fish. Using double displacement while POH. 06:00 - 07:00 1.00 CLEAN P INTERV Lubricate & service rig. Check PVTs & crown 0 matic, OK. 07:00 - 10:30 3.50 CLEAN P INTERV PJSM. POOH wi 3 1/2" DP. 10:30 - 12:00 1.50 CLEAN P INTERV PJSM. Stand back collars & UD fish. Recovered cut jt & (2) pup jts == 15.83', & seal assembly == 18.23'. Emptied out sluggit like material from fish above IBP. 12:00 - 13:00 1.00 CLEAN P INTERV PJSM. Pick up Tri State type "B" spear BHA. 13:00 - 16:00 3.00 CLEAN P INTERV PJSM. RIH wi spear assembly on 31/2" DP. 16:00 - 17:30 1.50 CLEAN P INTERV PJSM. Slip & cut 84' of drilling line. 17:30 - 18:00 0.50 CLEAN P INTERV P/U 2 singles. P/U kelly. 18:00 - 18:30 0.50 CLEAN P INTERV Crew change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 CLEAN P INTERV RIH & tag up on fish. BHA + 103 stands + 2 singles + 25' of kelly, 10173'. Engage spear into fish, swallow to 10179'. Jar 1 time @ 35K over,jar 2 times @ 65K over. P/U 10 K overpull. Put 16 turns in string, then let torq out. P/U wi 3 K overpull & put 14 turns in string. Fish popped free. Dump 20 bbls of seawater down hole. P/U Wt == 156K, SIO Wt == 126K, Rot Wt == 135K. 19:00 - 19:30 0.50 CLEAN P INTERV Set back kelly & blow down lines. UD 2 jts & prep to POOH. 19:30 - 23:00 3.50 CLEAN P INTERV POOH w/3 1/2" DP. Stand back 103 stands. 23:00 - 23:30 0.50 CLEAN P INTERV Break out spear & recover 21' fish. Seal Bore Recepticle == 19.75'; K-anchor == 1.25'. 100% recovery. Calc. top of packer @ 10194' 23:30 - 00:00 0.50 CLEAN P INTERV Clear & clean rig floor. 12/28/2006 00:00 - 01 :00 1.00 CLEAN P INTERV P/U & M/U BHA #18 as follows: Pkr Mill, 2 - Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 61/4" DCs, XO. TL == 310.15'. RIH wi same. 01 :00 - 03:30 2.50 CLEAN P INTERV RIH wi BHA # 18 on 31/2" DP. 03:30 - 06:00 2.50 CLEAN P INTERV P/U kelly & tag up on top of packer @10191'. 103 stands + BHA + 2 singles + DP pup + 10' of kelly. establish milling parameters & mill packer. P/U Wt == 153K, SIO Wt == 130K, Rot Wt == 140K. Free torq == 2800 ft-Ibs. Mill w/10-15K WOB, 60 RPMs, Torq == 3-7K. Pump 2 BPM @ 20 psi. No returns. Est. 3.5' to mill until pkr is free. 06:00 - 15:00 9.00 CLEAN P INTERV Continue milling on packer with above stated parameters. Varied techniques including some light spudding and a bit of dry drilling. Pumping @ 6 bpm 11450 psi, achieved returns. Observed returns diminished to no returns @ 3 bpm. Packer finally dropped after milling approximately 31/2' to 10,194.5'. Picked up a single & pushed to liner top @ 10,231'. Stand back kelly. (10 hrs milling time). 15:00 - 16:00 1.00 CLEAN P INTERV Rig service, check crown 0 matic & PVT system, OK. 16:00 - 19:30 3.50 CLEAN P INTERV PJSM. POOH w/3 1/2" DP & milling assembly. 19:30 - 20:30 1.00 CLEAN P INTERV Break out & UD BHA # 18. Inspect shoe, minor wear, looks good. Empty Boot Baskets & Clean tools. Recovered 1 1/2 Printed: 1/212007 12:56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 12/28/2006 19:30 - 20:30 1.00 CLEAN P INTERV bucket of millings, scale & balled EP Mud lube. 20:30 - 21 :00 0.50 CLEAN P INTERV Clear & clean rig floor. 21 :00 - 21 :30 0.50 CLEAN P INTERV P/U & M/U BHA # 19 as follows: Itco Spear, Stop Sub, Bumper Sub, Jars, XO, 9 - DCs, XO. TL = 300.82'. RIH wi same. 21 :30 - 00:00 2.50 CLEAN P INTERV RIH wi BHA #19 on 3 1/2" DP. 12/29/2006 00:00 - 02:00 2.00 CLEAN P INTERV Con't to RIH wi BHA #19. Ran 103 stands. P/U 3 singles & 1 DP pup. 02:00 - 02:30 0.50 CLEAN P INTERV P/U kelly & pump 3 BPM. RIH & tag up 26' in on kelly @ 10229'. Swallow to 10232'. P/U wi 18K. Set back down & insure bottomed out. P/U wi 161 K. Spud down on fish wi bumper jar 2 times to insure set. P/U wi 158K 1 Kover P/U wt. P/U Wt = 157K, SIO wt = 128K. 02:30 - 03:00 0.50 CLEAN P INTERV Set back kelly & blow down lines. 03:00 - 07:00 4.00 CLEAN P INTERV POOH wi BHA & packer. Had 20 -30K over pull @ spots, then weight dropped off. 07:00 - 09:00 2.00 CLEAN P INTERV PJSM. UD BHA & fish. Recovered packer remnants, (2) jts tbg, XlN nipple & 14' pup. 09:00 - 10:00 1.00 CLEAN P INTERV Clear I clean rig floor. 10:00 - 11 :00 1.00 CLEAN P INTERV PJSM. P/U 95/8" scraper I magnet BHA. 11 :00 - 16:00 5.00 CLEAN P INTERV PJSM. RIH wi scraper I magnet BHA on 31/2" DP. Tag liner top @ 10,233' DPM. 104 stands, (1) single & 7'. 16:00 - 21 :00 5.00 CLEAN P INTERV R/U & POOH & UD DP. Laid down 150 jts. 21 :00 - 21 :30 0.50 CLEAN P INTERV Crew change. Inspect derrick. Check PVT alarms. 21 :30 - 22:30 1.00 CLEAN P INTERV Con't to POOH & UD DP. Laid down to jt # 200. 22:30 - 00:00 1.50 CLEAN P INTERV Cut & slip 84' of drilling line. 12/30/2006 00:00 - 02:00 2.00 CLEAN P INTERV Finish POOH & UD DP. Laid down total of 312 jts. 02:00 - 03:00 1.00 CLEAN P INTERV POOH & UD 9 * 6 1/4" DCs. 03:00 - 04:00 1.00 CLEAN P INTERV Break out & UD BHA # 20. Cleaned Magnet & emptied Boot Baskets. Boot Baskets had small amount of EP Lube & scale wI some millings. 04:00 - 05:00 1.00 CLEAN INTERV Clear & clean rig floor. BOLDS. Pull & UD Wear Bushing. 05:00 - 06:00 1.00 CLEAN INTERV R/U to run completion. 06:00 - 06:30 0.50 RUNCO RUNCMP Clear I clean rig floor. 06:30 - 07:00 0.50 RUNCO RUNCMP PJSM. Service rig, check crown 0 matic, PVT system, OK. 07:00 - 09:30 2.50 RUNCO RUNCMP PJSM. Rig up torque turn equipment. 09:30 - 10:30 1.00 RUNCO RUNCMP PJSM. Make up tailpipe assembly, Baker Lock all connections below the packer. 4 1/2" connecdtions torque turned to 4440 Nibs. 10:30 - 00:00 RUNCMP RIH w/5 1/2", 17#, 13cr80 VAM TOP tbg. Using Jet Lube Seal Guard Thread Compound & torque turning 5 1/2" connections to 6580 Nibs. 12/31/2006 00:00 - 04:00 4.00 RUNCMP Con't to RIH w/5 1/2" 17# 13 Cr80 Vam Top HC tubing. Ran total of 241 jts. Torq turned all connections to 6580 ft-Ibs. 04:00 - 05:00 1.00 RUNCMP M/U hanger & landing jt. Land completion. RILDS. UD landing jt. P/U Wt = 155K, SIO Wt = 125K. 05:00 - 06:00 1.00 RUNCMP Clear floor. R/U tubing tools & Torq turn equip. 06:00 - 06:30 0.50 RUNCMP Crew Change. Inspect derrick. Check PVT alarms. 06:30 - 10:00 3.50 RUNCMP R/U & pump 290 bbls of 120 degree seawater down annulus. No returns. 3 BPM @ 30 psi. Follow wi 450 bbls of 120 degree inhibited seawater. Same rate & pressure. 10:00 - 11 :30 1.50 RUNCMP Replace line on #2 charge pump. 11 :30 - 13:00 1.50 RUNCMP Con't to pumping 450 bbls of 120 degree inhibited seawater down annulus. 3 BPM @ 30 psi. No returns. Printed; 1/212007 12;56:47 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-23 01-23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/13/2006 1/1/2007 Spud Date: 11/8/1982 End: 1/1/2007 Drop Rod/Ball & allow to fall. Fill tbg & pressure up to 3500 psi, set packer. Bleed fill & get air out of annulus & tbg. 14:30 - 16:30 2.00 RUNCMP Pressure up on tbg to 3500 psi & test for 30 min. Bleed tbg to 1500 psi & SI.. Pressure up on annulus to 3500 psi & test for 30 min. Bleed off tbg & shear DCR valve. Break circulation both ways, down annulus & down tbg. Pumped 3 BPM @ 200 psi. Charted setting & testing operations. 16:30 - 17:30 1.00 WHSUR P RUNCMP Set TWC. Test & chart from below & above TWC. 1000 psi for 10 min. 17:30 - 18:00 0.50 BOPSU P RUNCMP NID BOPE. 18:00 - 18:30 0.50 BOPSU P RUNCMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:30 1.00 BOPSU P RUNCMP Con't to N/D BOPE & DSA. 19:30 - 20:00 0.50 WHSUR P RUNCMP N/U adapter flange. 20:00 - 21 :00 1.00 WHSUR P RUNCMP Pressure test hanger void to 5000 psi for 30 min. Test Ok. 21 :00 - 22:00 1.00 WHSUR P RUNCMP N/U 7" Cameron tree. Fill tree wi diesel. 22:00 - 22:30 0.50 WHSUR P RUNCMP Test tree to 5000 psi for 30 min. 22:30 - 23:30 1.00 WHSUR N WAIT RUNCMP Wait on DSM. 23:30 - 00:00 0.50 WHSUR P RUNCMP P/U lubricator. 1/1/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Pull TWC. UD lubricator & TWC. 00:30 - 01 :00 0.50 WHSUR P RUNCMP RIU little Red Services. Hold PJSM. Pressure test lines to 3500 psi, Ok. 01 :00 - 02:30 1.50 WHSUR P RUNCMP Freeze protect well Pumped 160 bbls of diesel. had diesel returns. Pump 3 BPM @ 350 psi. Final circulating pressure 525 psi. 02:30 - 03:30 1.00 WHSUR P RUNCMP RIU & allow well to U-tube. 03:30 - 04:00 0.50 WHSUR P RUNCMP Drain wellhead. P/U BPV on T-bar & attempt to set. Having much difficulty. Call for lubricator to set BPV. 04:00 - 05:00 1.00 WHSUR P RUNCMP Wait on lubricator to set BPV. 05:00 - 05:30 0.50 WHSUR P RUNCMP Re-dress BPV & set wi T-bar. Pressure up & test BPV to 1000 psi for 10 min. Charted same. 05:30 - 06:00 0.50 RUNCO P RUNCMP RI D test lines. Secure well. Clear cellar. RELEASE RIG @ 0600 hrs. Printed: 1/212007 12:56:47 PM . . FRANK H. MURKOWSKI, GOVERNOR AliASIiA. OIL AND GAS CONSERVATlONCO~SSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-23 Sundry Number: 306-344 Dear Mr. Reem: -yo " 4 F}r,íl'P- s.··.,,·.""'A'ft.,\....'~n nr; ,¡f,.1 i;.\,;.;J \,.iI'!,;.If"\J"~~:;'...... .."t J 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, DATED this It'day of October, 2006 EncL ( 1r;} -~tö . ()tf !V-/()#Dþ IPC ~O/Qb I \L.~I;:¡~/UJ/!1~ ~jJ ~tJ STATE OF ALASKA _ OCT 1 0 Z006 l'¡~! ,'. ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & G C C " \K'I APPLICATION FOR SUNDRY APPROVAL as ons. ommlsslon , v Anchorage 20 AAC 25.280 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 182-180 / 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20854-00-00 / 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 01-23 Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028329 74.0 Prudhoe Bay Field / Prudhoe Bay Pool 12.. PRESENT WELL CONDITION SUMMARY .. .... . ....>.. . > ...... . .... ... Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11452 9223 11404 9188 10172' & 10282' None Casino Lenoth Size MD / TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2595' 13-3/8" 2595' 2594' 5380 2670 Intermediate Production 10548' 9-5/8" 10548' 8577' 6870 4760 Liner 1207' 7" 10240' - 11447' 8358' - 9220' 8160 7020 wt. jr- Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 11140' - 44ZO'8' II tl.~ 8995' - 9041' 5-1/2" x 4-1/2", 17#x 12.6# L-80 x N-80 10299' Packers and SSSV Type: 9-5/8" x 5-1/2" BOT 3-H I Packers and SSSV MD (ft): 10192' r 5-1/2" Otis SSSV 2186' 13. Attachments: 14. Well Class after proposed work: / ~ Description Summary of Proposal o BOP Sketch o Exploratory ~ Development D Service o Detailed Operations Program 15. Estimated Date for Octobt5, J06 16. Well Status after proposed work: CommencinQ Operations: ~Oil DGas o Plugged D Abandoned 17. Verbal Approval: Da~ o WAG OGINJ OWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bryan McLellan, 564-5516 Printed Namravid ~eem Title Drilling Engineer Prepared By Name/Number: Signature ~ J-7~ C-. R lIo~_ Phone 564-5743 Date iof9/U06 Sandra Stewman, 564-4750 Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~) ( n _ ;~-: J-:_ . D Plug Integrity ~OP Test 0 Mechanical Integrity Test D Location Clearance Other: --rf c,. T- /SoPE +CJ ~SOO ¡pr,¿ . RBDMS BFl OCT 11 2DD6 Subsequent Form Required: 10 - 4 . ~, APPROVED BY /ð--IO,p Approved By: T / L ~'SSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 \.,.../ l / Submit In Duplicate ORIGINA . . G 01-23 Rig Workover Scope of Work: Pull 5-%" completion, cut and pull 9-5/8" casing above the surface casing shoe, run premium threaded 9-5/8" tieback and cement 9-5/8" x 13-3/8" annulus to surface, run 5-%" Chrome ~ completion. MASP: 2~i Well TYl2.t;;'~~ucer Estimated Start Date: October 25, 2006 Pre-ri re work: 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time. PPPOT-T & IC. Done 5/29/06 - both assed, all LOS's functioned OK. 2 Pull IBP and XXN plug. It will be necessary to troubleshoot a tubing restriction just above the XXN lu at 10230' md. DONE 6/21/06 Unable to pull XXN lug. 3 Drift 5-1/2" tubin for 'et cutter. 4 Set Baker IBP at 10170' md (referenced to SLB IBP setting record, 7 -July-2005, correlation pass), which is in the BOT PBR. Note: The PBR will be pulled by the rig with the IBP in place. Jet cut the tubing at 10,147' md (referenced to SLB IBP setting record, 7-July-2005, correlation pass), which is 3 ft below the top coupling on the 14' u 'oint directl below the bottom GLM. 5 Circulate well with seawater and diesel freeze protection thru the cut. CMIT TxlA to / 3500 psi. If CMIT TxlA fails, attempt a CMIT TxlAxOA to 2500 psi. IF CMIT TxlA asses, MITOA to 2500 si. 6 Set a BPV in the tubin han er. 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-1/2" tubing string to the cut. 3. Run a cement evaluation log to determine top of cement in 9-5/8" x 13-3/8" annulus. 4. Cut and pull 9-518" casing above TOe. / 5. Tie back 9-5/8" casing with ES ceme~t or., 6. Cement 9-5/8" x 13-3/8" annulus to rfa¡ie. / 7. Mill and remove Packer and 4- W' tu' . .., ¡ftail. 8. Run new 5-1/2" Chrome tubing completion with packer at -10150'. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. ./ 11. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = WELJ.,HEA D. = . ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= FMC GEN 1 FMC AXELSON 74' ? 2805' 48 @ 6900' 10973' 8800' SS . 01-23 / I + NOTES, IAXOACOMM. . 2186' -15-1/2" OTIS RQM SSSV NIP, ID = 4.562" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2874 2873 6 OTIS T-2 2 5129 4727 46 OTIS R0-5 3 6958 5993 46 OTIS RO-5 4 8219 6857 45 OTIS RO-5 5 8948 7385 42 OTIS RO-5 6 9030 7446 42 OTIS RO-5 7 9433 7750 41 OTIS RO-5 8 9512 7810 41 OTIS RO-5 9 9790 8019 42 OTIS RA 10 9865 8076 41 OTIS RO-5 11 10061 8224 47 OTIS RO-5 12 10132 8277 41 OTIS R0-5 -13-3/8" BAKER IBP(07/18/06) I -15-1/2" BOT PBR A SSY I -19-5/8" X 5-1/2" BOT 3-H PKR, ID = 4.75" I -15-1/2" X 4-1/2" XO I 10230' -1 UNKNOWN OBSTRUCTION, ID = 3.675" 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 3.725" @ 10282' 4-1/2" XN NO GO NIPPLE IJETClJTTBG (07/18/06) I 10147' PERFORA TION SUMMARY REF LOG: BHCS ON 11/23/82 ANGLE AT TOP PERF: 43 @ 11140' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11140 - 11170 C 01/06/89 3-3/8" 6 11183 - 11190 C 01/31/90 3-3/8" 6 11196 - 11203 C 01/31/90 3-3/8" 6 11213 - 11223 C 02/23/98 -14-1/2" OTIS XN NO GO NIP I -14-1/2" XXN PLUG (07/01/06) I 1-14-1/2" BOT SO SUB I -14-1/2" TIJBING TAIL I H ELMD TT LOGGED 10/31/88 I 5-1/2" TBG-PC, 17#, L-80, ,0232 bpf, ID = 4,892" I TOPOF4-1/2"TBG-NPC I TOPOF 7" LNR I 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958"1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1 [§] 11452' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11447' DATE 11/28/82 06/05/03 07/07/05 06/18/06 06/19/06 07/01/06 REV BY COMMENTS ORIGINAL COMPLETION CMOfTLP MAX ANGLE GJB/PJC SET IBP @ 10193 RCT/PJC PULL IBP@ 10193' RCT/PJC OBSTRUCTION TBG RCT/PJC SET XXN PLUG @ 10282 DA TE REV BY COMMENTS 07/18/06 DFRfPJC SET IBP & JET ClJT PRUDHOE BA Y UNrr WELL: 01-23 PERMrr No: '1821800 API No: 50-029-20854-00 SEC 7, T10N, R15E, 5028.91' FEL & 357.21' FNL BP Exploration (Alaska) TREE = FMC GEN 1 01t3 Com~tion WELLHEtAD.= FMC Proposed ACTUA TOR = AX8..S0N KB. 8..EV = 74' BF. 8..EV = ? K KOP- 2805' . r -2200 1-15-1/2" HES X NIP, ID - 4.562" I Max Angle = 48 @ 6900' I Datum MD = 10973' ST MD 1VD DEV 1 TYPE VLV LATCH PORT DATE Datum1VD= 8800' SS 1 9897 8100 5.5"xH OCR 2 8560 7100 5.5"x1.5 DMY I 9-5/8" CSG, 40#, TCII, fully cemented to surface I -2250 I 3 7117 6100 5.5"x1.5 DMY 1---- -A ... ~ 4 5234 4800 5.5"x1.5 DMY I HES ES CEMENTER H -2250 5 3157 3150 5.5"xH DMY ~ I 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2596' 1 . I -15-1/2" HES X NIP, ID = 4.562" I I :8: ~ I -10170' 95/8" x 5-1/2" Baker S-3 Chrome packer 15-1/2" TBG 17#, 13Cr80, ID =4.892" I 10190' I I . 1-14-1/2' HES X NIP, ID = 3.813" I TOP OF 7" LNR I 10240' . . . 1-14-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG 12.6#,13Cr80, ID =3.958" H 10300' I /) '- -~ 9-5/8" CSG, 47#, L-80, ID = 8.681" I 10548' ~ 10300' 4f1/P" TUBING TAILl ] ~.. ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/23/82 ANGLEATTOPÆRF: 43 @ 11140' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11140 - 11170 0 01/06/89 3-3/8" 6 11183 - 11190 0 01/31/90 3-3/8" 6 11196 - 11203 0 01/31/90 3-3/8" 6 11213-11223 0 02/23/98 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11447' I [§] 11452' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 11/28/82 ORIGINAL COMPLETION 10/09/06 BJM W8..L: 01-23 06/05/03 CMOITLP MAX ANGLE ÆRMIT No: '1821800 07/07/05 GJB/PJC SETIBP@ 10193 API No: 50-029-20854-00 06/18/06 RCT/PJC PULL IBP@ 10193' SEC7, T10N, R15E, 5028.91' FEL & 357.21' FNL 06/19/06 RCT/PJC OBSTRUCTION TBG 07/01/06 RCT/PJC SET XXN PLUG @ 10282 BP Exploration (Alaska) 01-23 (PTD # 1821800) Classified as Problem Well ) ) Subject: 01-23 (PTD #1821800) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Date: Fri, 24 Jun 2005 20:47:53 -0800 To: "Yancey, Alex N" <Alex.Yancey@BP.com>, "GPB, FSlISIP/STP Area Mgr" <GPBFS1TL@BP.com>, "GPB, FSl DS Ops Lead" <GPBFS1DSOpsLead@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, Ops Mgr" <GPBOpsMgr@BP.com>, "GPB, FSl DS1 Operator" <GPBFS1DS10perator@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com>, "Mielke, Robert L." <robert.mielke@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Ho1t@BP.com> All, Well 01-23 (PTD #1821800) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 06/22/05 were 2440/2420/660. The well failed a TIFL on 6/21/05. The plan forward for this well is as follows: 1. DHD: TIFL- FAILED 2. SL: Set TTP, Caliper 3. EL: LDL pending Caliper report Attached is a wellbore schematic. Please call with any questions. «01-23.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 SCAN\~Eú JUL 2 2, l.005 Content-Description: 01-23.pdf Ol-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 ¡)reS5ù\¡"€. ~trv f (to ~lT'y P J4 2A 2D{~ btß70f5: 35,2, '70 ðA b('Or:s' I 5-3?--Cr't 12l~ ~ scp < 4S-c~ ¡lLTl(P; Ò ~- ¡ŒJ Cü 4-12 - I . - J~Q¿(j l~{/lo'5' 1 of 1 7/13/2005 8:52 AM TREE = WB..LHEAD = A CTljð" TOR = KB. ELEV = BF. ELEV = KOP= Max Ange = Datum MD= DatumTVD = FMC G8\J 1 FMC AXELSON 74' ? 2805' 48 @ 6900' 10973' 8800' SS 5. 1v NOTES: IA X OA COMM. 01-23 e 2186' H 5-1/2" 011S RQM SSSV NIP, ID = 4.562" I GA S LIFT I'v\L\ NCRB..S ST M) TVD DEV TY Æ VL V LA TQ-\ PORf DATE 1 2874 2873 6 OT6 T-2 ~ 2 5129 4727 46 OT6 RO-5 L 3 6958 5993 46 OT6 RO-5 4 8219 6857 45 OT6 RO-5 5 8948 7385 42 OT6 RO-5 6 9030 7446 42 OT6 RO-5 7 9433 7750 41 OT6 RO-5 8 9512 7810 41 OT6 RO-5 9 9790 8019 42 OT6 RA 10 9865 8076 41 OTIS RO-5 11 10061 8224 47 OT6 RO-5 12 10132 8277 41 OT6 RO-5 13-318" CSG, 72#, L-80, D = 12.347" 1-1 2596' ~ Minimum ID = 3.725" @ 10282' 4-1/2" XN NO GO NIPPLE 10171 ' H 5-112" BOT R3RASSY 1 .... , :8: :8: 10192' H 9-5/8" X 5-112" BOT3-H PKR, ID =4.75" I 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID= 4.892" 1--1 10208' \ I H 5-112" X4-112" XO I ITOP OF 4-1/2" TBG-f\PC 1-1 10208' 10208' 1 TOP OF 7" Lt--R 1--1 10240' .. II . I 10282' H 4-1/2" 011S XN f\D GO NIP I 10298' H 4-1/2" BOT SO SUB 1 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID= 3.958"1-1 10299' 1 10299' H 4-1/2" TLBltG TA IL 1 9-518" CSG, 47#, L-80, ID= 8.681" 1-1 10548' ¡--4 ... 10274' H B..M) IT LOGGED 10/31/88 I PffiFORA TION SUMIIIARY REF LOG: BHCS ON 11/23/82 ANGLEATTOPÆRF: 43 @ 11140' I\bte: Refer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz DA. TE 3-3/8" 4 11140 - 11170 0 01/06/89 3-3/8" 6 11183-11190 0 01/31190 3-3/8" 6 11196-11203 0 01/31190 3-3/8" 6 11213 - 11223 0 02123198 I I 7" LNR, 29#, L-80, .0371 bpf, ID= 6.184" l-i 11447' [2§]i 11452' - DATE 11/28/82 11/07/00 01/02/01 03/30/01 09/26/02 02/09/03 SIS-LG SIS-LG RN'TP BM'TP ATD'TP COrvTv1ENTS DA. TE REV BY COrvTv1ENTS ORIGINAL COMPLETION 06l05,{)3 CM)!TLP MAX ANGLE CONVERfBJ TO CANVAS REVISION CO RREGr IONS WA W ER SAFETY NOTE ŒLErEWAIVffi SAFETY NOTE FRLDHOE SA Y UNIT \llÆLL: 01-23 PERMIT No: 1821800 A R No: 50-029-20854-00 SEC 7, T1 ON, R15E, 5028.91' FB.. & 357.21' FNL REV BY BP Exploration (Alas ka) 1-23 Wellhead Welding ~-- Subject: 1-23 Wellhead Welding Date: Mort, 12 Jul 1999 23:13:04 -0900 From: "PRB Problem Wells" <P 1041 @mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us, john_spaulding@admin.state.ak.us, lou_grimaldi~admin, state.ak.us, chuck_scheve~admin.state, ak.us CC: "Justin K Balkenbush" <JBALKEN~mail.aai.arco.com> Well 1-23 has developed a small leak on the wellhead speed nipple. Wanted to inform you we have scheduled welders to seal weld the leaking threads this Thursday, 7/15. This will involve making a total of 6 weld passes around the circumference of the wellhead. We are taking extensive precautions to safe out the wellhead - set tubing plug, circulate out all gas and oil, maintain N2 purge across wellhead, steam clean area, line with fire blankets, etc. Give me a call if you have any questions or would like more information. I will be leaving the office early Tuesday morning, you can contact Justin Balkenbush in my absense at 659-5710. Joe Anders Problem Well Specialist 659-5102 1 of l ?/1 g/OO O'Oh AM ,-.- ~--... STATE OF ALASKA /~ ,~ OIL AND GAS CONSERVATION COMMISSI¢"--' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Pedorate _X Pull tubing_ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development._Z 74' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic _ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 637' FNL, 550' FWL, Sec 8, T10N, R15E, UM. 1-23 At top of productive interval: 9. Permit number/approval number: 450' FNL, 4502' FEL, Sec 7, T10N, R15E, UM. . 82-180 At effective depth: 10. APl number: 50-029-20854 At total depth: 11. Field/Pool: t 355' FNL, 5030' FEL, Sec 7, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11452 feet Plugs (measured) PBTD Tagged at 11303' MD (2/13/98). true vertical 9223 feet Effective Depth: measured 11303 feet Junk (measured) true vertical 9114 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1957# Poleset 79' 79' Surface 2521' 13-3/8" 2300 Sx CS III & 2595' 2594' 400 Sx CS II Production 10474' 9-5/8" 500 Sx Class G & 10548' 8577' 300 Sx CS I Liner 1207' 7" 330 Sx Class G 11447' 9220' Perforation Depth measured 11140'- 11170'; 11183'- 11190'; 11196'- 11203'; 11213'- 11223' true vertical 8995' - 9017'; 9027' - 9032'; 9036' - 9041'; 9049' - 9056' iTubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC Tbg @ 10208' MD; 4-1/2", 12.6#, N-80, NPC Tbg @ 10299' MD. Packers and SSSV (type and measured depth) BOT 3-H Packer@ 10192' MD; Otis RQM SSSV@ 2186' MD. _ ,,~ ~ t'~ t3. Stimulation or cement squeeze summary Intervals treated (measured) see attached d ~ ~I O ~ '~-% ~ ~ Intervals treated (measured) 0 RIG IN A L ~ pU~$.P,,O~f~RSQ.~CO~T'T~'~$~O~ 14. Representitive Daily Average Production or Injection Dala . - ~.~30~0 - Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2606 52458 38 1562 Subsequent to operation 2818 47225 264 1576 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run_ Daily Report of Well Operations _ Z Oil _Z Gas _ Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~.,,~ '~, ~ Title: Engineering Supervisor Date ,~:~'-~- ~'~' Erin Oba Prepared I~ Paul Rau[ 263-4990 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 1-23 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/13/98: Tagged PBTD @ 11303' MD. 2/23/98: MIRU. RIH w/perforating gun & shoot 10' of perforations as follows: Added Perforations: 11213'- 11223' MD Ref. Log: BHCS 11/23/82. Used a 3-3/8" carder and shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. RD. Returned the well to production and obtained a valid welltest. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy I Well Log Description BL RR Sepia RF Sepia Mylar Disk ..~ _ ~. 1-9A ~ I I ~ ~ ~ DUAL BURST TDT-P (8-7-94) "~ ~~ 1 ~S~ 1-9A ] -I - ~ D~ DUAL BURST TDT-P (9-25-94) ~ ~, ~.. 1 ~s. ~-~7 7 ~ - 0 0~ DUAL aUTST T~T-P (4-7-~4) '~ ~-/~ ~ ~. ~-~ ~%--~~ CNT" (;'~Z'~) ~H,I ~, 1 ~S. 1-23 ~- l~O DUAL BURST TDT-P (11-15-93) ~~ 1 ~. 1-30 ~ -Ill CNmD (8-6-94) ~H . ~ 1 ~. 1-31 ~~ ~ cNTH (3-1-93) ~.~ ~ '/ 1 ~A. ]-32 ~ ~-/~ 7 DUAL BURST TDT-P (3-6-93) ~'~ ~ ~ c ~. 1 , , . ~ ~ ~' ~ " , .5.~-33 ~ ~- I'~ DUAL BURST TDT-P (3-28-94) /. U ~ ~ ~; ~ x. 1 '~.~1-~4 ~-//~ CNT. (;-~s-~) ,~~~E ~ ~ .... I ( ~A. 2-2 70,~d3~ DUAL BURST TDT-P (2-26-93) ~'~~~ ~ ~ x~ 1 ~S. 2-4 ~ ~' ~1 7 CNTD (~11-94) ~L( ~~. _~ ~' ... 1 ~.S~-5 ~ O - O ~.~O CNTD (5-7-94) I I~' ~ ~ ~ ~ ..~ 1 ~S. 2-12 7 ?-~ 71 CNTH (2-23-93) ~ ~~ ~ ~ ~ ~ ~, ~. ..~. I SIGNED: '- DATE: J~N 0 ~ Oil'& Gas 'Cons. Please sign and return one copy of this transmittal to Sherrie at.the above address. · Thank you. Page 1 ARCO Alaska, Inc~ P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 * ( lI-13A /o * ll-13A 11-13A - ~,.11-13& ! }'17-15 c17-15 11-15-93 Dual Burst TlYr-P (Borax) Run 1, ~' 11-9-93 Dual Burst TIYr-P IBoeu) Run 1, ~, 11-18-93 IFSIT (Corrosion) ~ Color Run 1, ~' 11-18-92 usrr (Cement)~ Color Run 1, if' 11-33-92 PFC/GR ¢~* ~ ~ Run 1, 5' 11-10-92 PeffRecord ~ Run L ~' 11-11-93 USIT (Cement & CorroslonF Color Run 1, I~' 11-13-92 CBTJ Color Run 1, if' 11-13-92 CET / Color l~m 1, ~' 11-9-93 ~ (Cement & CorfoMon) ~Color l~m 1, ~' Please sign and return 'the attached copy u receipt of dat~ Have A Nice Dayl D // / Sonya Walhce DEC 3 0 1992 APPROVE ATO-1529 Alaska 011 & Gas Cons. Commission ~# 92265 Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHIIJAI~ PB WE~ FII2~ R&D #BPX # ~rATE OF AIASKA TEXACO * The correct API# for 11-13A is 50-029-21229-01. STATE OF ALASKA ALASr~".OIL AND GAS CONSERVATION REPOR, OF SUNDRY WELL O, 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 637' FNL, 550' FWL, Sect. 8, T10N, R15E, UM At top of productive interval 450' FNL, 4502' FEL, Sect. 7, T10N, R15E, UM At effective depth At total depth 355' FNL, 5030' FEL, Sect. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Strafigraphic 6. Datum of elevation(DF or KB) 74 KB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-23 9. Permit number/approval number 82-180 90-038 10. APl number 50 - 029-20854 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11,452 feet Plugs(measured) 9,233 feet Effective depth: measured 11,404 feet true vertical 9,188 feet Junk(measured) feet Casing Length Size Cemented Measured depth True vertical depth Surface 79' 20" 1957# Poleset 79' 79' ~ ,x Co~d~t, ~ 2595' 2595' I ntemediate 2521' 13 3/8" ~0o,x co,~=, .~o =x c~ '~ ~d 10,548' 8577' Production 10,474' 9 5/8" ~o =x c~,~ ~ Liner 1207' 7" 330 sx Cl 'G' 11,477' 2919' Perforation depth: measured 11,140'-11,170'; 11,183'-11,190'; 11,196'-11,203' ...~. true vertical 8996'-9003'; 9027'-9032'; 9036'-9041' Tubing (size, grade, and measured depth) 4 1/2", 17#, L-80, PCT @ 10,208' MD; 4 1/4", 12.64¢, N-80, NPC tail @ 10,299' MD *", Packers and SSSV (type and measured depth) Otis RQY SSSV @ 2186' MD, BeT 3-H Packer @ 10,192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A 14. Treatment description including volumes used and final pressure 670 4 ~56 Representative Dai _ly Averaee Production or Iniection Data OiI-Bbl (~ O ~ ~, Water-Bbl Casing Pressure 60 50' 1565 3578 98 Tubing Pressure 1530# 1458# 1 Prior to well operation Subsequent to operation 16. Status of well classification as: Oil X Gas Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~-04 Rev 06/15/88 KSN SUBMIT IN DUPLICATE DS 1-23 WELLWORK SUMMARY API #50-029-20854 January 31, 1990 11183-11190'MD 11196-11203'MD Depth per BHCS 11/23/82 Flowed well (reperfs, increase shot density) (reperfs, increase shot density) A F;.: ('-: 0 A L A ;ii: !'( A, Z N (3 .. c,, ..:_,"'". -(:: 0 X i '-:.:) E:' 7¢ 6 A N C H C:' F;:. A C'- E, A L A S' K A · ;-4. .-. i-".--".'..' PERF Rb.L ....... i --' '7 "~-- ~ - 9 E:' f-' F' ~' '", R / P,cZ R F" .,~. , ---- ..~ I... L.. ~--I ! -23 i -"-d; i --9(:;, F'F'RF RECOF;.:D ..'~, -. !~ '7.' -- "::' -- 0 f.';', ,_.i" ,'-, i:_.. ~- ~1 l-;¢"r':"-. / ...".;, IZ' lC, iL' ~; '--' 9 i --':::' 7 - '::-" '""' ,? F' i i'..-i.' N E R / T iii: i'"i i::' I::' ,.,. .. ., N- ' _:- ! ! 2''- -'''''-' - c;' ;:; t.~h.'.'"UUL '-':'_.-'- .... i i '::'._ -- a, .- c.',, ;:;., V E R T T. ,...~ 0 G f:;-i 8 i -2'7-9,S, S'P T NNER.-."-,"'EHF' 6-2 '...'-.5-9(:) COLLAR/PERF -,.:.6 i ,-:-,-.-i ,.~-f.:::,:? EF'iLOG/PDK-i ¢:;;'-", OVEI?i_AY ~ ;5-0 ~.-6-".-'-'~-3, -""C,i ~ ,'-.c, '" TBG CUT ) i . ,.,.- ,...~ __ l... t-1 i '.. .. . i 4-i '? i -24-',--.';.) LEAK DETECTION i 5:-2i 2.-.3- 9 £.~ COLLAR/PERF PI_EASE SIGN AND RETURN THE ATTACHED ,. HAVf-' A NiCE DAY! ..... ,.:. r.-, L i.. Y HOF'FECKER ATO-i 529 C:-]P Y AS R. ECEIF'T OF DA'FA. FEB '2 0 i?,.qO C1 . ~:,$S~glZ APPROVED -.-,,,,, '~i~ % G~s Cons. Corn . '-- : ~,~.~,.: ~ : · TRANS:~ 9(5 ~:; ~9 A~mhorage 5" DISTRiBUT]:ON :~ CENTRAL ~--'rLES, ,. -..'"'PHILLIPS ¢¢ CHEVRON F'B WELL F]:LE~..' D~ M R * D ~'- EXTENSTON EXPLORATION ~: BF'X = E'~'XON,. ~--~- ?TATE OF ~LA£'!<A MHRATHON -,,-'"' TEXACO =,~ MOBIL ARCO .~I_~KA, Z;"~C J'-"~ O. BOX ANCHORAGE, ALAS'K A 99~' DATE' i-i6-90 REFERENCE' ARCO CASED HOLE FINALS i -4 i,_?-'::'~-.q.c',__, ,..., F' ]: T3" i -2.'5 i 2-i..,'=: _ o ,',~,.z F' R 0 D U C T I 0 N. F' R 0 r= i I_ E/P I T $. · .z_--.~-z i 2-i 4-89 GAS' LIFT S'LJRVEY 7-i 7" i 2--'"'r-3-89 LEAK DETECTION ~ . 9-8 i -3-90 COLLAR/F'ERF i i-2S i-6-9(~ CO!_LF4R/PERF i 2-i i i '~-i 8-89 PF,'O['~lr:i ION PROF'IL~:' iS-S:'-) i2-i4-8',° LEAl< DETECT'ION i 6-i ¢', i 2-'2">-89, PROi':.I IF:T T f-~N. _ _ ,. _ . PROFILE RUN i , RUN i, RUN 2, RUN i , RUN i, RUN '1, RUN i, RUN i , F~'.Ur.~ 'i, PLEASE SiGN RECE]:VED BY _~' HAVE A NICE DAY,2~ .R~r.~~g~..~..~...,.. SALLY HC)FF'ECKER ATO-i 529 AND RETURN THE ATTACHED COPY ~£' IkECElPf' OF' APPROVED '¥RAN~'-~ 90 DISTRIBUTION DATA. · .-'"' CENTRAL. FILES -.-"-F'HILLIF'$ · ,,-'"' CHEVRON - PB WELL FILES' D & M R & D ~ EXTENS'ION EXPLORATION ~ BPX ~ EXXON ~ STATE OF ALM.~KA MARATHON ~'~- TEXACO ~ MOBIL 5" ") ",& 5" ~." STATE OF ALASKA ALASKP~"L AND GAS CONSERVATION C(--'MISSION APPLICA, ION FOR SUNDRY A[-'HROVAI S i Abandon Suspend Operation shutdown Re-enter suspended well 1. Type of Request: Alter casing Repair well Change approved program Pull tubing Plugging Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 637' FNL, 550' FWL, Sect. 8, T10N, R15E, UM At top of productive interval 450' FNL, 4502' FEL, Sect. 7, T10N, R15E, UM At effective depth At total depth 355' FNL, 5030' FEL, Sect. 7, T10N, R15E, UM 8. Well number 1-23 9. Permit number 82-180 10. APl number 50 - 029-20854 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11,452 feet 9223 feet Plugs(measured) Effective depth: measured true vertical Casing Length Surface 79' Intermediate 2521' Production 10,474' Liner 1207' 11,404 feet 9188 feet Junk(measured) Size 20" 13 3/8" 9 5/8" 7" Cemented 1957# Poleset 2300 sx Coldset II and 400 sx Coldset II 500 sx Cl 'G' & 300 sx Coldset I 330 SX C 1°. 'G' Measured depth True vertical depth 79' 79' 2595' 2595' 10,548' 8577' ,., ~'~ i..2919' Perforation depth: measured 11,140'-11,170'; 11,183'-11,190'; 11,196'-11,203' true vertical 8996'-9003'; 9027'-9032'; 9036'-9041' Tubing (size, grade, and measured depth) 4 1/2", 17#, L-80, PCT @ 10,208' MD; 4 1/4", 12.6#, N-80, NPC tail @ 10,299' MD Packers and SSSV (type and measured depth) Otis RQY SSSV @ 2186' MD, BeT 3-H Packer @ 10,192' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation January 1990 16. If proposal was verbally approved Oil X. Russ Douglas 1/16/90 Name of al)prover Date approved Service 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed ~dT'{'~/~ Title Operations Engineering Manager 15. Status of well classification as: Gas Suspended FOR COMMI.~ION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 DS 1-23 Description Summary of Proposed Wellwork API #50-029-20854 Permit # 8-885 ARCO Alaska, Inc. proposes to reperforate within the Sadlerochit interval in well 01-23. The proposed perforation intervals are as follows: Interval to be shot Shot Density 11183-11190'MD 11196-11203'MD Zone Interval 6 SPF 2B 7' 6 SPF 2B 7' Reference Log: BHCS 11/23/82 A 500 PSI WP wireline lubricator and BOP, tested on 4000 PSI working pressure prior to the job will be utilized for this operation. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company 6 4 2 COILED TUBING UNIT 8C)P EGUIPI4ENT 2 NIRELINE: BOP EOUIP~NT 1. SO00 PS~ ?" W[LLHL4D CONN[C10R 2. ~ PSI ~[Lm[ ~ (V~~L[ SIZE) 3. ~ 4. ~ PSI 4 1/6" rL~ TUB[ PACK-orr AF,'CO ALA.~'KA, INC~ i:-",.O~ BOX ~0-0~6~ ANCHORAGE~ ALASKA 995~0 DATE' t t--.S-89 RIEF'E]RENC;E' ARCO MAGNETIC TAPE(,.~) WII'H L..I4~'TINC;(~') t -23 t 0-20'--89 CNL (~'~ F'A,"~';~) ..JOB:,":4(-) i 5 '::~--~ t 0-.t 8-89 CNL..-A (3 F'A~/~', ), RUN 2 ,.JOB~I:'Z:;?:;~:""~'? ,.-_":'-'.~ 5,_ t ':.')-25-89 CNI_ ( 3 F' A,? ;'_,." ) JO..R ._.':' ,'! ,'.).... ''~:.. ,... '-' -4--32 t (')-"23-'89 CNL. (3 F:'A;~','-~) ,..If-)B~:40 t 9 ~5.-.'t'?' t0--2-?-89 CNL. (3 PA;~'$) ..JOB:~-1024 'F'L.E:'A,S'E: ~'IGN AND RE£1'LJRN 'I"HE A"I"TACFIED COPY A,S' RECE:]:P'T' OF' DA'TA, ,S'AL .... L Y HOF:'F'ECKER(,_,,,/~,L.,_~.,~-: ....,, ~ .~ ~'g; ,..._ ~ G:~I'~.,. ..... I!~F-$..,... CrJ!O'!~"~':'° ' ' 'I'F,'AN,s'~APPROVE:D89 :.71~.'~,,.) 4 ........ A'TO- i 529 DISTRIBUTION CENTRAl_ FILES (CH) :~ PI"tlI..LIF:',.~; C. HEVRON F'B WE:L..I.. F'ILE,S' D & M R & D TAMMA$ BROWN ([IH) ~ BPX EXXON -~ STA'¥1.'.Z OF ALA,S'KA HARAI'HON TEXACO MOBIL. TI'JE CORRECTED AP1 FOR "~-"'~' ' ~ ,...5 IS' 50-029-20'766, THE CORI;:ECTED APl FOR 15-t'7 I~' 50-.-029-2i t26, ARCO ALASKA, INC~ F'.O. BOX i. 80360 ANCHORAGE, ALASKA 995 t O DATE' REFERENCE ' PLEASE SIGN RECEIVED BY HAVE A NICE SALLY HOFFE AT0-t529 ARCO CASED HOLE FINALS 0-t 3-89 PRODUCTION PROFILE G-22-89 CNL-GR 0-2i -89 F'DK-t O(~/GR/CCL 0-i 6-89 PRODUCTION PROFILE 0-~9-89 PERF RECORD ~-2¢,-89 CNL-GR 0-15-89 PRODUCTION PROFILE ~-t5-89 PRODUCTION PROFILE ~-I4-89 PRODUCTION PROFILE 0- t 8-89 CNL 8-i 6-89 TEMP SURVEY ~-25-89 CNL-GR 0-23-89 CNL-GR 0-2S-89 F'DK-~ (~,.':)/GR/CCL 0-i6-89 PRODUCTION PROFILE ,:3-i i-89 PRODUCI"ION PROFILE 0-ii-89 INJECTION F!ROFILE 0-7-89 PRODUCTION PROFILE 8- i 3-89 TEMP 0-i4-89 COMPLEI"ION RECORD 6-i3-89 LEAK DETECTION G-4-89 TEMP 8-i4-89 F'RODUCTION PROFILE -i 8-89 PIT~ AND RETURN THE ATTACHED COPY AS RECEIPT OF DAY! CKER RUN i, RUN t , RUN i , RUN t , RUN i, RUN t , RUN t, RUN I, RUN t , RUN ;.'.]., RUN i , RUN t , RUN t, RUN t, RUN i, RUN t , RUN t , RUN t, RUN i , RUN t , RUN i , RUN t , RUN i , RUN ~ , DATA 1 5" 5" 5' 5" 5' 5' 5' 5' 5" 5' 5' 5' 5' 5" 5" 2'&5" 5' · 5" 5' 5' CAMCO AI'LA~ ATLAS CAMCO $CFI ATLAS CAMCO CAM(SO CAHCO ~CH CAMCO ATLAS ATL..AS ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO $CH CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES . CHEVRON D & M EXTENSION EXPLORATION EXXON MARAI'HON MOBIL *** THE CORRECTED "-' PHILLIPS F'B WELL FILES R & D '"' BF'X ~ SI'ATE OF ALASKA ~~ Oil & 6as Cons. Commissio 50-029-205t 6. -~c.o~e THE Pn~'pr:r'l'ED API$ FOR -,-.o~ IS 5¢-e29-2¢766 THE CORRFCTED AF'I.$ I-OR i4-25 IS 50-029-20757 AF'I~ FOR i G-ii ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager . February 1, 1989' C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive A~chorage, Alaska 99501 Re: DS 1-23 Approval No. 8-885 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SLW/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 1-23)W1-3 detailing work per- WELLS3/107 AR3B--6132-C ,---,, STATE OF ALASKA ~"--- AL, ;AOILANDGASCONSERVATIONCOMMI,. ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pedorate __ · Pull tubing __ Alter casing ~ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska, Inc. 5. Type of Well: / Development .Y_. Exploratory __ 6. Datum elevation (DF or KB) 74' RKB 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 637' FNL, 550' FWL, Sec. 8, At top of productive interval 450' FNL, 4502' FEL, Sec. 7, At effective depth T10N, R15E, UM T10N, R15E, UM At total depth 355' FNL, 5030' FEL, Sec. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 7, T10N~ R15E, 11452 feet 9223 feet Stratigraphic Service Plugs(measured) feet Junk(measured) 11404 feet 9188 ~ UnitorPropertyname Prudhoe Bay Unit 8. Well number 1-23 9. Permit number/approval number 8-885 10. APl number 50-- 029-20854 11. Field/Pool Prudhoe Size Cemented Measured depth Surface 79' Intermediate 2521' Production 10474' Liner 1207' Pedorationdepth: measured 20" 1957# Poleset 79' 13-3/8" 2300 sx Coldset II & 2595' 400 sx Coldset II 9-5/8" 500 sx C1 'G' & 10548' 300 sx Coldset I 7" 330 sx C1 'G' 11447' 11138-11148'; 11148-11168'; 11181-11188'; 11194-11201' true vertical 8994-9001'; 9001-9016'; 9025-9030'; 9034-9039' Tubing (size, grade, and measured depth) 4½", 17 "/, L-80, PCT @ 10208' MD;4½", 12.6#, N-80, Packers and SSSV (type and measured depth) m~= Rmv g.~.~v M 7186' MD. BOT 3-H macker ¢ 10192' MD 13. Stimulati(~n or cement squeeze summary Attached NPC tail @ 10299' MD Intervals treated (measured) Treatment description including volumes used and final pressure feet Bay Oil Pool -~ueverticaldepth 79' 2595' 8577' 9219' Oil & Gas Cons, Commissiol;~ ..... ~,:..: ~r~chorage 14. Prior to well operation Subsequent to operation Representative DaJl¥ Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 2419 10816 103 1533 1038 146 ~bingPressure 1863 487 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil Z Gas_ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,~,.'z4.~ fC~.~'~..~' Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 WELLS3/107 S. L. Ward, 265-1305 SUBMIT IN DUPLICATE Objective: Drill Site 1-23 CTU CEMENT SQUEEZE GAS SHUT-OFF To cement squeeze a behind pipe channel from the current perforations up to the gas/oil contact. 1 2/07/88 1 2/09/88 12/16/88 1 2/17/88 1/06/89 RU slickline unit. Tag PBTD @ 13345' SLM. Unable to get surge tool past the x-over at 10202' SLM. Preform coiled tubing acid wash across the following intervals: 11138-11168' MD 11181-11188' MD 11194-11201' MD The following treatment was pumped: a, 1000 gals. of 12% HCI 1000 gals of 12-3% HCI-HF 500 gals. of 12% HCI RU coiled tubing. Fluid pack wellbore. Cement squeeze the folowing intervals with 30 bbls of cement: Reference: SWS CBL 11/27/82 11138-11168' MD 11181-11188' MD 11194-11201' MD Contaminate cement. Wait on cemrnt overnight. Circulate out contaminated cement. Reperforated the following intervals: Reference: SWS CBL 11/27/82 11138-11168' MD Reperf 4 spf 11181-11188' MD Reperf 6 spf 11194-11201' MD Reperf 6 spf Returned well to production ad obtained new well test. S LW 1/27/89 ARCO ALASKA, INC. F'.O. BOX 100360 ANCHORAGE, ALASKA 99510 DATE · t -~ 2-89 REFERENCE' ARCO CASED HOLE FINALS t-2~ t-6-89 . CO/.I. AR/PERF RUN ~, 5" S-26 t2-S~-88 PERF RECDRD RUN i 5 '"~.7 t t-88 PDK t0~ RUN t T-SS t-4-89 TENP ~URVEY R~JN t, 5" 9-5 t2-S0-88 F'FC RLJN t , ~" t4-S9 t-5-89 PFC R~JN t, 5" t4-S9 t-7-89 F'RODUCTION F'ACKER. RLIN t, 5" t4-40 t2-29'-88 CBT RUN 1, 5" t4-40 t-4-89 GAMMA RAY RUN t, 5" ' "'- ~" i ...... AS PLEASE £IGN AND RETU~RN .FHE ATTACHL=D COPY RECEIPT OF DATA HAVE A NICE D'AY.~''~ - ,~s~.~ & ~as Cons. Comrni~io~x SALLY HOFF'ECKEr-( A'FO-i 529 TRAN$ 9 APPF OV : .......... DISTRIBUTION A'FI...AS ,.S'CH AT L.,..i,.. ;~'CI-t A'i'i..A,S~ ATLA£' ATL..A.~;' SCI-{ ATL. AS CENTRAL FILES .~ PHILLIPS CHEVRON PB WELL I::'ILE,S' D & M R & D X l' '"' S A P C E ENSION EXF'LORATION ~ EXXON ~ ~ S'FATE OF ALASKA MARATFION ~ TEXACO MOBIL ** THE CORRECI'ED AF'I~: FOR THIS I. OG IS 50--(~29..-.2t809. ARCO ALASKA, INC_. P.O. BOX f 6,.r:.,S6C, "~'" ANCHORAGE: AL.A,?I<A 99.%. J, DATE' i i-28-88 Rr_...iFE.;F;.'ENCE' ARCO CASED HOLri; F-ZNAL. S i -23 i C~-.S i -88 COI__I. At:;.'. 5-'"8 i i '-'i '7"-88 COi_LAR ~.".;""iil i i .... i '7 .... 88 C 0 I... !....,'"',. I:;.'. / P E i:;,' F' F:'WDW i "' i i i '-'.~"-: 6'"'88 "i"EHF:' I:;.'. U N i., !ii." F;..' U N i: RUN i., '.S" RUN'i , .5:" C A M C: 0 A "l" i... A S Al'LAS C A H C 0 : i'" t'" ["'~ A t .... :..~:.N T I-. T L. i.E ,'~i: :'\ ?i L. .,. · ~'"' Ci-ilE V F,..'O N i') & I'1 · ,-i'.:_' X'i"E N S ! 0 N iii: × F' 1... 0 R ~ T :t: 0 N · ,.'"' E X X 0 N M A l':.:A'f'i-iO N .it. X ' i"~ ?': 'l* I ':r I"~ ~...~ £:, J, L. .11. · ,,- i::' i"i :I: L.. L.. I F' .S' i':'B WELl._ 'F'It...E,S' i:;.: ,::!.: '0 ~ ;F, AF'C · ,,.'"' STATE f'iF'_ AI..A,S'F.: A · ~' 'f'EXAF:FI · ii- ....... A~ q ALASKA, INC~ P~O~ BOX ANCHORAGE, ALASKA DATA BHF ..... :~:]"AT I C C-'-F:,'AD i ENT BI-IF ....... ;";'TAT t C: GRADIENT B H F ........ ~'-)" 'i" A T i C (~ R A D i E N T iii!-: i"i F ....... F L. 0 W I N G 5 R A D I E N T BHf' ....... .?TATIC (~RADIFNT B H F ....... .? i' A T I C (~ R A D i E N"i' B H F: ....... E! T A T ]] C ('~ R A D i E N T R Iii; C ii: I P'T' 0 F' D A T A,. CENTRAl... FI CHEVRON DaM EXTIEN;"':: ! ('..IN EXPi_OF;.:A'.r I ON ... ,.-.,.... *. MARATHON ARC'O Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 21, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission. 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-23 Permit No. 82-180 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/SLW/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 1-23)W1-3 WELLS3/79 ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfieldCompany AR3B--6132-C 1. Type of Request: '---- STATE OF ALASKA ~ AL..KA OIL AND GAS CONSERVATION COMM,..~ON APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing m Repair well m Plugging m Time exlension ~ Stimulate __ Change approved program __ Pull tubing __ Variance m Pedorate __ Other 2. Name of Operator ARCO Alaska. Inc, 3. Address ?. O. Box 100360, 4. Location of well at surface 637' FNL, 550' FWL, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Sec. 8, T10N, R15E, UM 6. Datum elevation (DF or KB) 74' RKB Unit or Property name Prudhoe Bay Unit 8. Well number DS 1-23 At top of productive interval 450' FNL, 4502' FEL, At effective depth Sec. 7, T10N, R15E, UM ~totaldepth 355' FNL, 5030' FEL, Sec. 7, TION, R15E, UM 9. Permitnumber 82-180 lO. APInumber 50-- 029-20854 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11452 feet Plugs(measured) 9223 feet Eflemive depth: measured 11404 ~m Junk(measured) trueve~ical 9188 ~et Casing Length Size Cemented Measured depth Surface 79' 20" 1957# Poleset Intermediate 2521' 13-3/8" 2300 sx Coldset II & 400 sx Coldset II Production 10474' 9-5/8" 500 sx C1 'G' & 300 sx Coldset I Liner 1207' 7" 330 sx C1 'G' Pedorationdepth: measured 11140-11170'; 11183-11190'; 11196-11203' truevedical 8995-9017'; 9027-9032'; 9036-9041' ~bing(size, grade, and measureddeCh) 5~", 17#, L-80, PCT @ 10208' MD; 4½", 12.6#, N-80, NPC PackersandSSSV(tyjoeand measureddemh) Otis RQY SSSV @ 2186' MD, BOT B-H packer @ 10192' MD ~uevedicaldepth 79' 79' 2595' 2595' 10548' 8577' 11447' 9219' tail @ 10299' MD 13. Attachments Description summary of proposal v/ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation November 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby ce¢ify that the foregoing is true and correct to the best of my knowledge. si,ned FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test m Location clearance __ ~) /_/-- Mechanical Integrity Test_ Subsequent form required 10- ~.., ' , -r.~pproveo Copy Returned 0RI6INAL S'6NED BY __/_/_7'~-" ~ Approved by order of the CommissiorL~NNIE O. SM!TH Commissioner JApproval No. Form 10-403 Rev 06/15/88 WELLS3/79 S. L. Ward, 265-1305 DS 1-23 CTU CEMENT SQUEEZE Workover Oblective: To cement squeeze a cement channel from the current perforations up to the gas/oil contact. · , 1 · Make a slickline run to PBTD, Last PBTD was 11338' MD on 1/20/88, RIH with CT. Wash the pedorations with HCI, Ensure the mechanical integrity of the tubing. RIH with CT and fluid pack the wellbore with filtered seawater. 5. Pump 25 bbls of cement followed by 2 bbls of water and 50 bbls of contaminant. Hold 500 psi surface pressure for 60 minutes. Squeeze off the following perforations: 6, 7. Zone Perforations SPF 2 11140-11170' MD 4 2 11183-11190' MD 6 2 11196-11203' MD 6 (Reference: Jet or reverse out the contaminated cement. BHCS 11/23/82) Reperforate the intervals as shown in Step 5. 8. Test the well. Other Well Information Current status: Cycle well Expected static BHP: 3698 psi at 8930' ss Expected fluid in wellbore at reperforation: Seawater SLW/001 6 5 4 2 COILED 'I'UB~,N{3 UNIT BOP E0U I PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAI~S 3. 5000 PSI 4 1/~;"HYDRAULIC SLIPS 4. ~X)0 PS1 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 HIRELINE BOP EOUIPHENT _ 1. 5000 PSI 7" W£LLHEA~ CONNECIOR FLANGE! 2. 5000 PSI WIRELIN[: RAU.5 (VARIABLE SIZE) : 3. 5000 PSI 4 1/6" LUI3RICATOR 4. 5000 PSI 4 1/1~" FLOW TUBE PACK-OFF ARCO ALASKA, INC, P.O. BOX t6)836Q ANCHORAGE, ALASKA DATE: 2-t6-88 REFERENCE: ARCO CASED HOLE FINAl.. t-4 1 -t3 4-7 4-t8 4-22 7-t3 9-,'54 tt-t8 t3-t t-3-5 t3-t7 f 3-28 1 4-22 t6-2 16-5 t 6-'i9. ~ 6-2~- f7-8 t-22-88 t-2t-88 t-28-88 t-2e-88 t-24-88 2-4-88 2-3-88 t-29-88 2-5-88 t-23-88 t-38-88 t-24-88 t-23-88 t-23-88 t-22-88 t-27-88 t-25-88 t-28-88 2-t-88 t-28-88 t-29-88 t-31-88 t-25-88 t-25-88 PR,PRFI_E/FM/TP/FD/W RUN FL_OWMETER RIIN PRD,PRFLE/FM/TP/FD/W RUN PRD.,PRFLE/HPFM/TEMP/DEN RLIN PRD,PRFI..E/HPFM/TEMP/DEN/WH!.IT RIJN PITS/TEMP RI. IN PITS/GR/TEMP RI.IN PITS RLIN PITS/TEHP RIJN PITS RUN FLOWMETER RI.IN PIT~/TEMP RUN PRD.PRFLE/NPFM/WNLIT RUN PRD.PRFL.E/HPFM/WH[!T/GR RLIN GAMMA RAY RI.IN PRD,PRFL. E/HPFM RUN PRD.PRFLE/SPIN/TEMP/WHUT RIJN INJ~PRFLE/FM/TP RUN INJ,PRFLE/HPFM/TEMP RLIN PITS/TEMP RLIN PRODIJCTION PROFILE RIJN PRD,PRFL. E/SPIN/TEMP/GR/WHUT RUN PRD,PRFLE/HPFM/GR/WHUT RLIN INJ~PRFLE/HPFM RUN INJ,PRFLE/HPFM RIJN PLEASE SIGN AND RETUR RECEIVED BY HAVE A NICE PEGGY BENNE' AT0-~529 ~ THE~TTACHED COPY A,.~ R'~.PT OF' DATA ' ' ~ AJaska 0ii & Gas Cons. Co~ms[o~ ~ ...... ~cho~ TRANS ~88t APPROVED DISTRIBUTION CENTRAl_ FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIl_ ,,. PHI I..I._ I P,~' PB WELL F.TL R & D SAF'C . ,.~TATE OF ALASKA TEXACO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMcn CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO FIOWMETER RI IN t, ~ · CAMC~ PRD.PRFLE/FM/TP/FD/W RI.IN t, 5' CAMCO PRO., PRFL E/HPFM/TFMF'/DFN RIIN t ~ ~T · ~AMCll pRO, PRFL..F./HPFM/TEMP/DEN/WHI.IT RIJN PIT,T/TEMP RIIN PTTS/~R/TEMP RI.IN 9, PTTX ~ ~ ~~ 7 PITE/TEHP ~ ~~~' ~ ~ 5' CAMCO FLOWMETE~ r ~ "~ ' ~ -: i~. O ......... t, 5" CAMCO PIT.~/TEMP ~ ~;;i,--'.~-~ - ; - ' RUN PRO. PRFLE/HPFM/WHI[~ 0i~ ~ Gas ~o~s. ~~S~.JRUN ~ ~ 5' CAMCO PRD~ PRFLE/HPFM/W~~R ~c~o~a~ RUN ~ , 5' ~AM~n GAMMA RAY RUN t, 5' CAMCO PRD~PRFL~/HPFM RUN ~ ~ 5' CAMC~ PRD.PRFLE/~PIN/TEMP/WHUT RUN ~ ~ 5' CAMCO INJ ~ PRFL~/FM/TP RUN INJ.PRFLE/HPFM/TEMF' RUN ~ ~ 5' CAMCO PIT~/TEMF' RUN 1, 5' CAMCO PRODUCTION PROFILE RUN t, 5' CAMCO r'R~. PRFL. E / SP I N/ T~HF' / ~ ~' /~HUT Rll~ PRD.PRFLE/HPFH/GR/WHUT RLIN ~, 5' CAHCO .. TNJ. PRFL E/HPFH RUN [NJ.PRFLE/HPFH RUN ], 5' CAHCO PLEAXE SIGN AND RETURN THE ATTACHED COPY AE RECE RECEIVED BY HAVE A NICE DA PEGGY BENNE1 AT0-1529 TRAN~ ~88105 APPROVED m DT£TRI~ll' ION CENTRAL FILES CHEVRON D& M EXTENSION EXPLORATION EXXON MARATHON MOBIL C:vo --- O/vL T' ARCO AI_A.~KA, INC, P. O, BOX ANCHORAGE, AI...A£K A 99548 DATE: 2-~ 6-88cD E ~- REFERENCE: ARCO CA.~'ED HOLE FINAl. 4-t6 ~-'!9 4-48 4-22 ?-t~ 9-54 ~-~8 t 3-5 ~ 3-28 t 4-22 t6-2 t 6-5 'i 6-'i 9 t 6-'i 9 't 6-2G t7-2 ~ ?-8 t -22-88 t -22-88 t -2t -88 t -28-88 t -2G-88 t -24-88 2-4-88 2-3-88 t -29-88 2-5-88 ~ -23-88 ~ -24-88 ~ -2~-88 ~ -23-88 ~ -22-88 '~ -27-88 ~ -25-88 t -28-88 2-t -88 t -28-88 t -29-88 f -3t -88 ~ -2.5-88 t -25-88 PR,PRFI..E/FM/TP/FD/W F[.OWMETER PRD,PRFLE/FM/TP/FD/W PRD,,PRFLF/HPFM/TEMP/DEN PRD.PRFL. E/HPFM/TEMP/DEN/aH/IT PIT~/TEMP PIT~/GR/TEMP PIT~ F'IT~/TEMP PIT£ FI_OWMETER PITE/TEMP PRD~PRFI_E/HPFM/WHI.IT PRD,PRFL. E/HPFM/WH[IT/~R GAMMA RAY PRD~PRFL. E/HPFM PRD.PRFLE/$PIN/TEMP/~HUT INJ~PRFLE/FM/TP INJ.PRFI_E/HPFM/TEMF' PIT$/TEMP PRODUCTION PROFILE PRD.PRFLE/$PIN/TEMP/GR/WHUT PRD~PRFLE/HPFM/GR/WHUT INJ~PRFLE/HPFM INJ.PRFLE/HPFM GN AND RET[ i~l~'' RECEIVED B RI.IN RI IN RI.IN RI. IN RI.IN RI. IN RI.IN RI_IN RI.IN RIIN RI.IN RLIN R_I.IN RI. IN RUN RUN RLIN RUN RLIN RUN RUN RUN RLIN RUN RUN RECEIPT OF DATA.. RAMCO CAMCO CAMCO RANCh CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAHCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PEGGY BENNETT AT0-~529 TRAN~ ~88~Q5 APPROVED DI~TRI~L.ITION ~ CENTRAl_ FILES -.-"'CHEVRON D & M · EXTENSION EXF'I..ORATION .' EXXON MARATHON ~ MOBIl_ -... PHILLIPS PB WEL I.. F.'IT. L EX "- ~AF'C XTATE OF AI..A~KA TEXACO ARCO Alaska, In( Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager .. September 30, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-23 Approval No. 7-436 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operatons detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp At t a chment OCT o l Alaska 0il & Gas Cons. Anchorage cc: Standard Alaska Production Company P1 (DS 1-23)W1-3 WELLS/~0c7o Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-O STATE OF ALASKA ALA,_.,A OIL AND GAS CONSERVATION COl ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 637' FNL, 550' FWL, Sec. 8, T10N, R15E, UM 5. Datum elevation (DF or KB) 74' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-23 At top of productive interval 450' FNL, 4502' FEL, Sec. At effective depth At total depth 355' FNL~ 5030' FEL~ Sec. 11. Present well condition summary Total depth: measured true vertical 7, T10N, R15E, UM 7~ T10N, R15E~ UM 8. Approvalnumber "~ 82-180 9. APInumber 50-- 029-20854 10. Pool Prudhoe Bay Oil Pool 11452 feet 9223' feet Plugs (measured) Feet Effective depth: measured 11404 feet true vertical feet 9188 Casing Length Size Structural Conductor 79' 20" Surface 2595 ' 13-3/8" Intermediate Production 10548 ' 9-5/8" Liner 1207' 7" Junk (measured) Cemented Measured depth True Vertical depth 1957# Poleset 79' 79' 2300 + 400 Sx 2595' 2595' 500 + 300 Sx 10548' 8577' 330 Sx 11447' 9219' Perforation depth: measured 11140-11170', 11183-11190', 11196-11203' true vertical 8995-9017', 9027-9031', 9036-9041' ~bing(size, grade and measured depth) 5½", 17#, L-80 plastic-coated tubing @ 10300' Packers and SSSV(type and measured depth) Otis RQY SSSV @ 2200',BOT packer @ 10196' OCT 0 8, GaS cons. 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1192 1177 0 -- 1137 642 0 -- Tubing Pressure 227 220 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~~~ Operations Engineering Manager Signed Title Form 10-404 Rev. 12-1-85 WELLS/107 P. V. Lantero, 263-4312 Date Submit in Duplicate~/' STIMULATION SUMMARY DS 1-23 On August 6, 1987, the following treatment was pumped: 2000 gals 15% HC1 atomized with 500 SCF/BBL of nitrogen 2000 gals 12% HC1 1.5% HF atomized with 500 SCF/BBL of nitrogen 2000 gals 2% NH,C1 water atomized with 500 SCF/BBL of nitrogen 200 gals 2% NH~C1 water mixed with 300 lbs of OSR-100 and 25 gals of Matri~eal 0 2200 gals 15% HClatomized with 500 SCF/BBL of nitrogen 2200 gals 12% HC1 1.5% HF atomized with 500 SCF/BBL of nitrogen 2200 gals 2% NHAC1 water=atomized with 500 SCF/BBL of nitrogen 1890 gals diesel with 10% EGMBE (reciprocated across perforations in order to remove the oil soluble resin) atomized with 500 SCF/BBL of nitrogen 180 bbls crude atomized with 500 SCF/BBL of nitrogen RECEIVED OCT0! Alaska 011 & Gas Cons. Commission Anchorage WELLS/107 ARCO Alaska, Inc Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 7, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-23 Permit No. 82-180 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company Pi(DS 1-23)W1-3 WELLS/~[ ^,as~a, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS,,,A OIL AND GAS CONSERVATION COM,,,~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~(' Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator A~CO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 637' FNL, 550' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 450' FNL, 4502' FEL, Sec. 7, T10N, R15E, UM At effective depth At total depth 355' FNL, 5030' FEL, Sec. 7, T10N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 11452 feet 9223 ' feet Plugs (measured) 5. Datum elevation (DF or KB) 74' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-23 8. Permit number 82-180 9. APInumber 50-- 029-2OR54 10. Pool Prudhoe Bay Oil Pool feet Effective depth: measured 11404 feet true vertical 9188 feet Casing Length Size Structural Conductor 79' 20" Surface 2595 ' 13-3/8" Intermediate Production 10548 ' 9-5/8" Liner 1207 ' 7" Perforation depth: measured Junk (measured) Cemented Measured depth True Vertical depth 1957# Poleset 79' 2300 + 400 Sx 2595' 500 + 300 Sx 10548' 330 Sx 11447' 11140-11170', 11183-11190', 11196-11203' true vertical 8995-9017' 9027-9031' 9036-9041' ~bing(size, grade and measured depth) 5½", 17#, L-80 plastic-coated tubing @ 10300' Packers and SSSV(typea. nd measured depth) Otis RQY SSSV @ 2200',BOT packer @ 10196' 79' 2595' 8577' 9219' 12.Attachments Description summary of proposal I~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby-certify that the_~ true and correct to the best of my knowledge Signed ~/'¢-~~'/ Title Operations Engineering Manager Date ~//'Z/¢~ Commission Use Only Conditions of approval Notify commission so representative may witness[] Plug integrity [] BOP Test [] Location clearancelAppr°vaIN°' Approved by 7- ~' '-- ¢;r by order of ~-~l'n'rrrfsston~Ef* the commission Date Submit in triplicate Form 10-403 Rev 124-85 WELLS/107 P. V. Lantero, 263-4312 DRILL SITE 1-23 SELECTIVE STIMULATION PROCEDURE 1. MI and RU pump trucks and transports. 2. Roll all acid compartments before pumping fluids downhole. 3. Stimulate the well as follows: Note: Ail fluids except displacement crude and diverter carrier fluid should be filtered to 2 microns. A. 2000 gals of 15% HC1 w/additives and atomized with 500 SCF/BBL nitrogen B. 2000 gals of 13% HCl-ll/2% HF w/additives and atomized with 500 SCF/BBL nitrogen C. 2000 gals of 2% NH4C1 water w/additives and atomized with 500 SCF/BBL nitrogen D. 200 gals of 2% NH4C1 water w/CMHEC blended with 200# of oil soluble resin (coarse) E. 2200 gals of 15% HC1 w/additives atomized with 500 SCF/BBL nitrogen F. 2200 gals of 13% HCl-ll/2% water w/additives atomized with 500 SCF/BBL nitrogen G. 2200 gals of 2% NH4C1 water w/additives atomized with 500 SCF/BBL nitrogen H. 1000 gals of diesel w/10% EGMBE atomized with 500 SCF/BBL nitrogen I. Displace with 265 bbls of crude atomized with 500 SCF/BBL nitrogen J. Displace with 5 bbls of diesel 4. Return well to production immediately. RD and release equipment. 5. Test well for new capacity and put into test 24 hours after job is completed at a choke setting of 50°. Contact Drill Site Engineer concerning any questions about the well test. Volume of tubing/liner to top of perforations: Volume of tubing/liner to bottom of perforations: 269 bbls 273 bbls WELLS/107 ARCO Al.a:~ka, Inc. · ]'~ . F'~ 0. Box ~ (-),.'-}~,c.~ Anchorage, A[~ka 995 '~ ~ DATE' NoYember 2~, t98~ REFERENCE' ARCO Ca~ed Hol. e Final. d.~ CH CNL. Ru.n t..,~'" GO D,?..? 'l '-'2~3 t O-oS-c=. .. .o F'Lea:~:e .sign and re'l: U.; n . . , · ATO- ~ 429F AnCh0raca TI:~,'AN~ ~ q:449 D I .'i' '¥ I:;,' ! B U T I 0 N Ch err on F'h i L L i p ~ D & M P B WeLL F'i Le'.~' Exp Lora'f i on Serv ices R & D E..'.x~en~ion ExpLoration ,S'ohio Exxon ~'ta~e of ALaska Hara~hon Texaco ARCO ALaska, Inc. F'.O~ Box t00360 Anchorage, Alaska 995i0 DATE' November 2~., t985 REFERENCE' ARCO Magnefic Tap e I)5' t.-.,, -~3---85 CH/CN£' tape f~3399S4 w/Lief GO Pt. eaxe .'~'ign and re'turn '~he a'~tached copy am' re(zeipt of da'l'a~ Rec e i red HAVE A NICE DAY! t<eLLy Mc:F'arLand AT[.l- ~ 429F 'I'RAN$ ~ ~45'~' 5198 s~..~ oil & G~s Cons, Commission Anchorage DISTRIBUTION Ch evl- (i)!.! D & M Exp[oratic, n Services' Ex xon Ma r a ~ h on Mob i ~ Phi [Lip~ PB WeLL Fi Les' R & D $oh i o State of ALaska Texaco ARCO Alaska, Inc. Post Office E~--"'360 Anchorage. ;ka 99510 Telephone 907 277 5637 September 21, 1983 Reference: Arco Cased Hole Finals D'S. 1-23 7-27-83 EPL D.S. 3-20 7-16-83 CBL/VD 7-19-83 CBL/VD D.S. 14-25 7-18-83 CBL/VD Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 1 5" Sch~ ase sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 533 D & M Dallas Drilling ~xxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D Caroline Smith Sohio ARCO Alaska, inc. Post Office E>,_,,, 360 Anchoraqe. Alaska 99510 "re~chc,~e 007 ?7;'7 55?- September 9, 1983 Reference' Arco Pressure Data D S 1-4 ~* 8-26-83 8-26-83 D S 1-22 ¢.t 8-12-83 8-19-83 D S !-23~/' 7-27-83 ~-1'7-27-83 D S 1-24 8-19-83 8-19-83 D S 12-8B¢-" 8-3-83 8-3-83 D S 16-11-- 7-30-83 Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Pressure Build-up Data Sheet Horn'er Plots w/listing Pressure Build-up Data Sheet Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Pressure Build-up Data Sheet Static Survey GO GO Sch Camco Camco Camco se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 506 Chevron D & M Dallas Drilling Exxon Ge t ty Marathon DI£T~IBUTION . Nort~ ~.~e. ology ' /'/ '"' "' '"~7 ; Prudhoe Bay R & D Caroling Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Teiephor',-e ~07 277 ~637 August 15, 1983 Reference: Arco Cased Hole Finals D.S. 1-23 6-17-83 D.S. 14-23 6-13-83 6-11-83 6-8-83 6-27-83 6-9-83 6-8-83 6-8-83 6-12-83 6-27-83 6-9-83 Perforating Record Run 1 5" Sch CBL after squeeze Run 11 5" Sch CBL after squeeze Run 9 5" Sch GR/CCL Run 2 5" $ch Temperature Log Run 2 5" Sch Perforating & Retainer Setting Record Run 3 5" Sch CET Run 2 5" Sch CBL Run 1 5" Sch Perforating Record Run 10 5" Sch CET Run 2 5" Sch Perforating & Retainer Setting Record Run 8 5" Sch ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 468 Chevron D&M Dallas Drilling Exxon Getty Marathon Mo bi I DISTRIBUTION Caroling Smith Sohio ARCO Alaska, Inc. "'-'"- Prudhoe Bay E,.~,,~.eering Post Office Box 360 Anchorage, Alaska 9~510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 14, 1983 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501' Dear Mr. Chatterton: Re: DS 1-19 Permit No. 82-125 DS 1-20 Permit No. 82-146 DS 1-21 Permit No. 82-152 DS 1-22 Permit No. 82-174 D~--~ Permit No. 82-180 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/la Enclosures cc: Sohio Petroleum Co. ARCO Ala~,-. ~n~:. Js ~ $.',Jhs ~[~-ry of All[,n!icRIchfleldCompeny .. .... ~ STATE OF ALASKA ~'- ALASKA ..,L AND GAS CONSERVATION G~. IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well ~,// OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-180 '~. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-20854 4. Location of well at surface 9. Unit or Lease Name 637' FNL, 550' FWL, Sec. 8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 450' FNL, 4502' FEL, Sec. 7, T10N, R15E, OM 1-23 At Total Depth 11. Field and Pool 355' FNL, 5030' FEL, Sec. 7, T10N, R15E, OM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74' RKBI ADL 28329 Prudhoe Bay oil Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116' No. of Completions 11/08/82 11/23/82 12/10/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11452 'MD,9223".'TVD l1404'MD,9188'TVD YES~ NO [] Inipple@2186feetMD 1900' (approx). ! 22. Type Electric or Other Logs Run CBL/CCL/GR. DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~" ql.5~ R-40 .q~f 79' 30" 1957 # ?oleset 13-3/8" 72.0~ L-80 Surf 2595' 17-1/2" 2300 sx Cold SetIII & 400 sx Co'ld Set 9-5/8" 47.0# L-80/S00~.~5 Surf 10,548' 12-1/4" 500 sx Class G & 3(~0 sx Cold Set I 7" 29.0# L-80 10,240' 11,447' 8-1/2" 330 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 10,208' !0 ~ 1_7] ' 11140-11170 MD (30') 8995-9017 TVD 4 spf 11183-11190 MD (7') 9027,9032 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11196-11203 MD (.7') 9036-9041 TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Ref: BHCS 11/23/82 N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/20/83 F lowing Date of Test Hours Tested . PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/12/83 12.4 TEST.PERIOD ~ 877 447 0 83I 510 FlowTubing Casing Pressure _ ~CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 733 N/A 24-HOUR RATE ~ 1698 865 0 22.3 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ·" ., . · . . ?.!,<:~.'..::i:~i · .'," ~',.I ;' :~:.~: . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... "' GEOLOGIC MARKERS ': - ' FORMATION 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 10,679 ' 8667 ' N/A G/O Contact 10,737' 8707' O/W Contact 1 .,254'-11,292 ' 9078'-9106 ' Base Sadlerochit Not Reach6] 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~. ~.~_.~,~~----~$~.~ Title Regional EnqineerDate ~/~--~ 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 7, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-19 Permit No. 82-125 DS 1-20 Permit No. 82-146 DS 1-21 Permit No. 82-152 DS 1-22 Permit No. 82-174 ~D$ ~-~ '-i Permit NO. 83-180 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmi Attachments cc: Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany ~--. STATE OF ALASKA ALASKA _ ,L AND GAS CONSERVATION C( ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS .,' OTHER [] ~~~ 1. DRILLING WELL [] COMPLETED WELL)~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-180 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 5o- 029-20854 4. Location of Well 637' FNL, 550' FWL, Sec. 8, TION, R15E, UM (Surface) 450' FNL, 4502' FEL, Sec. 355' FNL, 5030' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 7, TION, R15E, UM (Top Prod) 12. TION, R15E, UM (Total Depth) 6. Lease Designation and Serial No. ADL 28329 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1-23 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations )~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10o407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105~170). Began perforating operation 6/17/83. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 11148-11168' MD 4 spf (20' ref: CBL 11/27/83), flowed to tank for cleanup, monitored rate, and took shakeouts. Well did not flow sufficient rates to cleanup. POH - all shots fired. RIH wi th gun #2, a select fi re type gun, shot'll138-11148' MD and 11194-11201' MD 4 spf (17' ref: CBL 11/27/83), flowed to tank for cleanup, monitored rates and took shakeouts. POH - all shots fired. RIH with gun #3, shot 11181-11188' MD 4 spf (7' ref: CBL 11/27/83), flowed to separator. POH - all shots fired. RD. Completed perforating 6/17/83. Ran SSSV. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~~1~ ~.~.~ Title Re§5onal [ngSneer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 28, 1983 Reference: Arco Pressure Data D.S. 1-19 6-17-83 D.S. 1-20 6-18-'83 D.$. 1-21 6-18-83 ~.S. 1-22 6-19-83 D.S. 1-23 6-19-83 D.E. 13-6 ,~/~5-25-83 Static Survey Static Survey Static Survey Static Survey Static Survey Hornet Plots w/Listing Camco Camco Camco Camco Camco Sch . /~ease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 404 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY PHILLIPS D & M SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH ARCO Alaska, Inc. Prudhoe Bay neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 3, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: D.So 1-19 DoS. 1-20 D.S. 1-21 D.S. 1-22 Permit No. 82-125 Permit No. 82-146 Permit No. 82-152 Permit No. 82-174 Permit No. 82-180 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TKKW/lmi Attachments cc: Sohio Petroleum ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA ~,~L AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 550' FWL, 637' FNL, Sec. 8, T10N, R15E, OM (surf) 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 12. 6. Lease Designation and Serial NO. ADL 28329 7. Permit No. 82-180 8. APl Number 50-- 029-20854 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 1-23 11, Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional draw- down be necessary to unload the wells, it may be flowed to a tank for initial clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: BHCS 11/23/82 11140-11170' MD 11183-11190' MD 11196-11203' MD 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. · ___.,_neer The space below for Commission use Conditions of Approval, if any: Approved by. BY LONNiE C. SMITH By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bx.-'~,~360 Anchorage, ~ Ka 99510 Telephone 907 277 5637 Janaury 13, 1983 Reference: Arco Directional Data D.S. 1-23 11-9-82 Magnetic Survey Teleco P~~ease sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 038 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBILE DRILLING GETTY PHILLIPS D & M SOHIO MARATHON DALLAS CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO'Alaska, Inc.,,~.-%, Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are monthly reports for December on these drill sites: 1-24 13-14 1G-7 2z1'1 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for: 1-22 13-13 1-23 14-6 6-24 lC-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store 'it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28:llm Attachments ~laska Oil & Gas C(;n,s, Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichlieldCompany ~' ~ '~" STATE OF ALASKA NO: A 1 ~ I ~ ~ [. ALASKA'k,,,- AND GAS CONSERVATION C~-"VlJSSlO WELL COMPLETION OR RECOMPLETION F 'PORT AND LOG 1. Status of Well Classification of Service Well OIL FX1 GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-180 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o-029-20854 4. Location of well at surface 9. Unit or Lease Name 637'FNL, 550'FWL, Sec. 8, T10N, R15E, UM L~^.;~O~:~i Prudhoe Bay Unit At Top Producing Interval I VF2tFIED 10. Well Number 450'FNL, 4502'FEL, Sec. 7, T10N, R15E, UM lsur~. Y- i 1-23 At Total Depth ~ B..~~j, 11. Field and Pool 355'FNL, 5030'FEL, Sec. 7, T10N, R15E, UM - Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 74'RKBI^DL 28329 Prudhoe Bay 0il Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 11/08/82 11/23/82 12/10/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey / 20. Depth where SSSV set [ 21. Thickness of Permafrost 11452'MD 9223'TVD 11404'MD 9188'TVD YES~(] NO[]I~ipple @ 218i~etMD ]1900' (approx) 22. Type Electric or Other Logs Run CBL/CCL/GR, DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 1957# Poleset 13-3/8" 72.0# L-80 Surf 2595' 17-1/2" 2300sx Cold Set III & 400sx Cold Set] 9-5/8" 47.0# .-80/S009.~ Surf 10,548' 12-1/4" 500sx Class G & 300:x Cold Set I 7" 29.0# L-80 10,240' 11,447' 8-1/2" 330sx Class G 24. Perforations open to Production '(MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" . 10,208' 10,171' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of OPeration (Flowing, gas lift, etc.) / Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GASoMCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE j~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · RECEIVED J AN i 4 1983 Alaska 0ii & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ . :GEOLOGIC MARKERs ' ' · " ' ' -" · :FOR M'A.TI'O N 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 10,679' 8667' G/0 Contact 10,737' 78707' 0/W.Contact 1,254'-11,29 9078'-9106' N/A Base Sadlerochi Not Reache~ 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~'~'~~'~'z''~-'-' Title Area Drilling Eng,,re '/' ~/~ <~ INSTRUCTIONS General: This form is designed for submitting a Complete and correct well completion report and Icg 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". DS 1-23 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 0230 hrs, 11/08/82. Drld 17-1/2" hole to 2607'. Ran 66 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2595'. Cmtd 13-3/8" csg w/2300 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. Welded patch in 20" conductor. NU .BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10564'. Ran 236 jts 9-5/8" 47#/ft, L-80/S00-95, BTC csg w/shoe @ 10548'. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Cmtd 9-5/8" csg w/500 sx Class G. Drld cmt to 10516'; ran CBL/CCL/GR f/10490'-10000'. (Note: CBL showed top of cmt @ 10190'. On 11/21/82, approval was rec'd from Lonnie Smith to proceed based on obtaining a good CBL & obtaining a satisfactory shoe tst after drlg out.) Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11452' TD (11/23/82). Ran DIL/SP/BHCS/GR f/11452'-9-5/8" shoe & f/11426'-10516'. Ran FDC/CNL/GR/Cal f/11426'-10516' cont w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Cold Set I, & 131 bbls Arctic Pack. Ran 31 jts 7" 29#/ft, L-80, BTC csg f/10240' - 11447'. Cmtd 7" lnr w/330 sx Class G cmt. Drld cmt to 11404' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Tstd lnr lap to 3000 psi - ok. Ran CBL f/11378'-10140'. Ran 5-1/2" completion assy (including GLMs) w/tail @ 10208' & pkr @ 10171'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2186'. Secured well & released rig @ 2400 hrs, 11/28/82. Gyroscopic survey ran 12/10/82. JG:ltc 01/05/83 Ala$~ Oil & gas Cons. C°m~ission Anchorage HO8 , Vl':'il::.;"f '.[CAL. :.E:l:iEC:"f']:CIl',~ I":AI Pill P"f'EI"I II',l I:-'I....ANF':' t.-I.F F.'F,,IE.F...:::,~I_ r_i I REr'i:T ]' 01",1 '..' I\! .. 86 DEG. · 20 MIN. W R E C: 0 R D 0 F :iE:l..I R V E Y IRADIUC:; OF CURVA-I"URE METI---IO[) .... lOB NO: A128';i'IR()'2,4'2--OG C: (:1 I"'1P I_1 'r' A -[' T CI h..I 'T' I M E D A T I:.:-: o ..... 'F'" (-) ,'.':, ,", .':::i 1 :.-:: ()...- D E C-- ,=,c., .,:_":' F.':' A (:;E !',10 .' 1 I"lEi:A'.'-i:l...IF;~li:::[) I:)R]:FT :OF~]:F:"T' C (:) U I:;: :.:.i; E: VEi:RT]:F:AL. ',,.'I!~.F~'T'ICAL. L:..IJB.~:E[..P~ I::;~ El. C 'r icl Iq G U I .... A R C: I i-~ ,.=; I..I R E OIEF:"I"H ANr.}LI!E I:':i :1: RI:::C T' I 01',1 I_E.I',!(3'T'I.,I 'OEI'""I"H SECT 101',1 'T'VD 12 0 0 IR D I I",1 A T I.'.--. 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COMPANY DS lr Well Number: 23 WELL NAME ?~n~dboe Bay, North $!oce, Alaska LOCATION TYPE OF SURVEY Directional Single Shot I A I SURVEY BY AilEi~II~& Gas Cons, fJotnmi,~ ion Anchora e ) Controlled Drilling Consultants (Chapman/Suermaum) - g RE:C:OF;~D OF SUF',~VEY I:? ,'q t") T l. lL: OF CUF~V~TI_IRE HE'FHOD DS 1, WEL..L_ NO: 23 TE:L. IEC© (C:DE:) TIME DATE I='RUPFIOE BAY: NF'~RI'H ...... F:L FIF'E., ALASKA 1._, MEASURE.Ii DRIFT DRIFT C:OLIIR'.=-:F VERTICAL VERTIC:AL. SLIBSEA R E C T A N O U L A R C L 0 S U R E r~OGLEG ...................... 'r: ........................... ~-' J" DE:PI"H. (IN(}L.E [IIF'~I.ECTICdq. U-=:IqCCFIq DEF'TFI SECTIF~N I'VD C 0 0 R D I N A T E S DI.:,TAN_.E DIRECI'ION F:EVERITY : F'EET I] M D I'I F:'EE;'i' FEEl" FEET FEET FEET FEET II M DG/10C)Fl".',~;: (), 0 ("~ () 0 !:.!.? ........... O, ¢;!(';! ................... !:! ._ !.:! f~! ................ =7~ .. !';~(.:.! .................. .!'2 ,. .!:.! ~2 .......................... J2.,...gC! ................................ f-!..J;~¢_ .......... .... ,=','",::' . . . ~,,:'o=:' .-, ,:- c, ,:: c)O (] 00 ~?191 ¢~C) 0 00 0.C)0 0 00 ,:' .J :'J ... ~. (') () 0 () "~' "J :' "J ' '"' 'J .... ~ .............. 2 L:: 0.5, :3 12 N 74 0 W :,7.' 1. 0.2 :=: 04.8'.-} !5.7:3 2'7:30.8'P 1.62 N 5.64 W 5, 86 N 74 0 W 1 :]i:(')¢)(), .............................. 11 Zl.',.:.': ".=; F:C) ¢/ W 1¢)=; 2g':.'i= (')4 ~:C.) 94 2924. (")4. 2 94 N 30 °1 W :=:0 :3178, 1/_.., 12 '.3 75 0 W 178. :':: 170 ..... 71 72.27 3 (')9 A .71 6...,,= '~"-~ 'S 72 , ,:,.::'-"- W 7:3. 11 'S 85 0 W 2. ._, . .' .... ..".47 ~., 164..0:. W 16,_,.6.- .., o. 1.. W ,'. '.~'~ 162.31 33/=,?~..-,,~ ,-,,-, ,-. - ¢¢ ~' ,", c- ~','-, .-, ,-, ", :'=.': 4./'/', 2 .1. :."' 4. S ':'"S ¢'~ W 2 :::: 8. 34. 43 ,. ,~ .,_ · . ,_~._ .. .............................................................................. :::/-':? ~") 24 4.'::_' S '- .... (~)W 1 ..:, 4 '-"~'-' ':¢ 4 99 9 '- = 72 ':' :::'.-' 4 ............,:,,, ':- .: .... :.4... ,- ~ 1 .. I ._4._, 1 0. '94 27, ._, ,.'--",..94 . 14 W ._9'='~.._.. ,:,,-,._,= .=,'-' _ ._ 57 W ' 2.1 "::"-'(')5 '="':~ 24 S ':"/-, (] W 1'-'~= 3749 66 ~" ':' 3675 /,6 34 ,?.:2 '=' ................,-,., ,:,¢).', 17 307 ¢¢"-} W .':-:¢)9 90 "=' ',,."=' ,.,, . -- m .--' .,,..m , -- ii , .- . - # 0 , - -' , ._.- :]'?F.:'?. :::4 3() S 8'7 0 tO 184. :3 '?,' 0 7'; . 7134.01,74 38131.7:=: 4.0.27 L=; (405. 15 W 4(37. 14 S ::':4 19 W 2, '79 4-17/:, c,:~ 18 ::3 87 0 W 187 4(')5~ 22: =; ...... o,p c. · _1o 39F:1 '"" 46. 14. ¢; 517.24 W 517! ..-. o4 54 W 2 57 ,, .. · . . -.,..,.. ,, ~-:, , _ . .~2 ~, ._ · ~, . 4.4. 2¥.;. 4.6 24 S 88 0 W 4. r":;54., 46 :'=:6 L=: 88 0 W · 5041. 46 12 S 88 0 W 56C.):'::, 4.6 1:2 h.I :=-.:9 0 N 641.98 S 85 18 W 3,11 689.18 S 85 27 W 2.38 782.67 S 85 45 W 0.16 1135.15 S 86 27 W 0.08 1540.31 S 87 15 W 0.39 ..::, .v ,:, 4 4.6, .'::/-, N :::9 0 W 381 .... 13.:31 1:::¢'}/-,,'-'¢' .,=-~ c, .=: ,:¢ 31 68,'-/2 S 1814 4-1 W 1815 71 ':' 87 49 W ().10 /..-.5o-/. 4.6 ,'{.:=: N ::::'~, .... ' (.i'" W ....... '-'-"-'._,.~..:;'. ._67~"'- i :'~i;?, .~:'l:::Cj'.-~r) ........ .~,~;72' 9,:.-, ............ )-:~'::='i~-i~ ........ ~'i'-.P'4:";i;:.f'~4 ....... ~'f;~'5":'i~F, .... §'-',;-:ir~'-~'~-'H ......... 62-04 '. ! '7C):::6. ........... 4.:3 0 N 88 (') W 529. /=,F)30. F)/-. 2575,61 5'=-7.=;/-. 06 52 C)9 c-, ~,.~¢,4._ o , '2:3 W ~.,.~c,a...- ~-.-f. 7~._, c-.. :::--t~: 51 W 0,27 74.27 4.7:30 N F.:8 (') W :::'Pl. /=,2'72 ';~._'"l '-"='I .'F'I 62:3 95 ,'?'F,' 2:_::73 ...... · .' ,:, :, 4 1 . 41 S .4:3 W 287:3.7'F,' :_.; 89 10 W 0.1:2: ................................................................................................................................... '7970. 4 ./:, 12 N :=: :5: 0 W 54. :=:, 666. 4.. :5:1 3260,89 /-, ..... F,'P 0, 31 2 :=:. 16 F-: :=: 269 '-'~,:,'" W 3269. ~f')_. ¢'._, E:'.::~ .2:0 W 0.24 :-=: :24/=.. ,l 5 (') N :38 0 W 276. 6 :=: 57.41 :':: 453. ('}0 678 :'::. 41 21.28 S :=: 466.46 W :=:466, 52 L=; 8 ? :'::9 W ('). 4 :=: :iit:5/=,O. 4:3 4.2 N ,='-"=' ......... 0 W ......... 314.~ .....7i'):=.: 1 ¢~.~-', '-- ;:':,/_-,77 ...... 40- ......... 7(_)<)7' ......, ;=~'=-; ._, .......... 1 .=,.'~'- 6z.':;'"-'~,:, ...... ;:' ';';='- ~-'-.=,6,=,._,. ,=, 1 ............. W -':;- ~'~'--':',:,6c ..... =,4. ....... ":':--' ;~; ;=.=, ,=, .'~ ........................ 47 N 0.4.1 :=:'?'F.' 115, 4.1 54 N L=::::: 0 W 4-:':: 5. 7401. 10 :=:'? 72. :=: 2 7:2::27, 10 :3. :30 S :2:9:31. 1:3 W :3981. 18 :=: 89 57 W 0.41 '?307. 4.1 6 N :=::_:.: 0 W 2:12. 7634.78 417'?.47 7560.78 2:.91 N 4.187.79 W 4187.79 N 89 57 W 0.26 '?65o. 3'~.; 36 N'-:--:7 0 W .... :;:~:~:~ 7:~i..w:.~ i7 '44ni ,~'~8~:_::2~:17 ........... 1]~:.~:.0' N .... ~4409~'~.4"-~J ..... 44.i5:~,-.-~.~7 ~-:~.~-~, ~W- ........ ~ 48 101.42:. 4-1 4-:2 N :=:2 0 W 49:=:. 8270. i'F.~ 472.'::2. :36 8176.19 44.37 N 4729.20 W 4729.41 N 89 28 W 0.79 · '-'='-' .... '-' .~' . . _ 47,'79.24 89 10:507. 4-/=. 18 N '79 0 W :=:64. ,= ..... =, 1 'P/-, 49'7 :=: 81 ,=, 4._ 7.96, :36 08 N 4'.-':,,' 78 5 (') W N 1 W 1. i':: S;' - 112:=,.~ 4:=: 0 N 79 0 W 74.::'-:. '-?¢)/-.4.(')2 "=""'=~'=, ........... .......... -+:.._, I i ,c::,=.,.=, (-) (')2 186.37 N 54'.--.'4 44- W 5497 60 N 8:---: 2: W (-~ 4-4 114.2:2. 4. :3 0 N 79 0 W 16'7. 91:=:6. 16 560:3.0L=: 9112. 16 20:3. 11 N 5606.24 W 5610. 10 N :37 52 W ,(').00 FINAL. C::L..O::;LIRE - I)IRECTION: N 87 PEGS 52 M INS :27 SEC:S W ,--'' " · c-- ' · ...... D I .=, I A NL. E .... 61 U..[ (.) I- E= E I DRIFT CHART'S RELA'TED DATA FILE ARCO ALASKA, INC. !--DS--t.~--WELL--~O ~' 23 T~L. ECO. PRUDHOE BAY, NORTH SLOPE, ALASKA (CDC-) SURVEY FILE NUMBER 1464 BOTTOM HOLE ASSEMBLY VALUES USED FOR DEPTH ARE MD DEPTH DESCRIPTION 2607; _ -- ._ ~,~,, ~ / ~ ~ ~~ . 4627.00 LOC:I<ED ASC..:EMBL~v.~ ,, 8319.00 LO,-'I.:'ED ASSEMBL,,,::~, .' ' Whipstock ~ A PETROIANE COMPANY DRILLING--DAYS VALUES USED FOR DEPTH ARE MD [,AY DEPTH 1 626. O0 '~ 2607.00 ................ 3 ............. 2~07. O0 2607. O0 4110.00 ~5~0.00 7 7150.00 8 o060. O0 .":'~ -- E: 75 O, .. 00 10 1I 12-- ?618. ,00 10090.00 t 0._.,64.. 0 O' ...... e , WEIGHT ON BIT · ~ WEt~H~=-I~E~-~-VEN--PER~--I-O~O-psuNDS VALUES USED FOR DEPTH ARE MD DEPTH WEIGHT 110. O0 70.00 2607. O0 6~,. 00 4627"~" O0 6-5'~'(;0 831~. O0 60.00 S~060. O0 65.00 REVOLUTIONS PER MINUTE V A -L-U ES-EtS EB-F~F~--DEP~-H-ARE--MD DEPTH R~ P.-~- M. ............. 1.10.00 1~0,-00 2607.00 60.00 4627.00 120.00 831~.'00 ........ 105~-00 A PETROLANE COMPANY 906 0. 00 110.0 0 ' I ' ' ft , i II Il }1 11 I{ ltl! ltll il~ ]11! I i I ] Jill 1' I If ~ Il ! ~ i I i i ! . ' , '-i . i ! ~ ! i i- I l I I i I I I i I I i I [ i I I I I I ~' . ~ ;' ''ii {' 'i-Till i I '[ i i i Ill- j ! iii ill{ !Il! il!! llff illi I Il fill I il il i llil 1il 'lib"'"'"' '"'"'il I l! i,,,, ,, ,~, ,~,~ ~,, ,,, i ii i ', il{! ~ ul-,. . , I t,~. L,,.., ' III i ~l I, ...... { {,{, ,i.,. 1 , I il I'il . ,i '~ {j'"llll i i I Ii I II l' ii i il' II I' I ~'l[ ,!i .,i,t ii.ii, . ' i ~, t, i, il i J,,~lti ~ ! ~i :iii ill Ijjl !'i .:ilil.', I i i' .ltl! t I ii 'il Ii i' . I1! ]1!1 Iltl il:il: t t t t I!1 I f I Ii ill I1 I ' ~ ' i i t f.J ~ i I I ~ I t E-! i I {'i i' I , I I I i i.i [ I I I I I I I I 1 '" '"' 'Ii' ,I" "'i """" ""'' '" "" '"II'lI ,, ,, ,,,... ,,, !,,,:,,,,, ,,,, ,,,, ~,,,,,, i ill{ illi Jll ' l'l'i ii~l llll I. I !'F !{'f ii ! ! I i !,i i t { i ! ~{ I 1 t. i I It J,~ ii [ } i 'J I iL ! I { i } ! { I I i , i ! J i ~1 { [ ; ~ t ~:~ t { ! I I ; i Fl ~ I I { i ~ I i Iii i I J i ~ i iii~ ~III { J'i; ..... ] . I I i t I I If ! ~i-il r , ~Jf~{ 1[ i : ! i '~-i I ~i300[ !3 i X~- . , , I I I I i I t } I '- i ~ .... ....... ~=}I! {Iii [[l.i~ill! Jill ! 111 I I I I !{ I i I I il ,,~, ' ' ii i i il tiI ! ! I !1 i I ~-iJ i "~ i_{ , ill} i. l I i I ~l ~ I } I i I- { I l~ l.I I I i I I I I I ~ { I I l ~it,. ~ii-I it!L ;ii-il ~:iti"~,%li,' I J l ill{- !~l ~ :I lit_ iii iii, _!!{I ,fl] ifil i~ ~ ,l !!Il ii I { I! I i I1 iii m'i{i iiil il!} il.l! ~1 ~- !iii ili._L Il .i. l!{! lit~ ~11{ ii I il i I i I ~i I ! i i i ~ -i~i i i i l..i I i i ~ i I i i .i i i i i I I I ! ! t I I I I I ! I I I ! i I I I i "'"ii '"i i-'"i "ii ',,, .,'x ill-~! ,I- . .... i. ,,t{ ~t,~ i~ i~i !!ii l'l ![I ~I i,~[ , [iii iltt Ill] {, , ~Ji JJ[ i, . iLil ~ ii i{ii lill i[ii !li~ I [ ii. Li ii I il i itli ii ~ jill iiii i{ii il{i illi ~{~1' ii{ il_ii ltllill I Ill i Lit! ,l.l~'tl{ ,'il 'ill t''' 'Il' Iii, 'ill ' !{ilili illi %ili llli llll !Iii iill iii! 'iii ii' ~ill-u~L~f , , , ' · i ', i ' ' ' ' ~ ' ' ' ' ~ii l!ti iiii il! ii..I iLii i~i i~i ~mt~ iiiL iiii ;iii ~iii il!l iii illll'l{.tl jilt llli i1.il IIii ll!~ ~'117'' iill I1ti ~ili ill! !!Il ~ i i ~ I I!i! i!iJ itltii~L! ili!!%jL! iJ~i iii, Illi iiiill !{Ji!!tii ii]ii i'Ll[ ,iii ~Li! i~ll ifli Ilit !!l! ill[ 'ii i--ll '"' '"' iti' '"' '"' '"' ; i i i ! i I i ! ! i i i L i.l i i i ! f I 11 I I t I } t i i I I ] [ i { i I I i I i i ' I .,i.. i i . ~ { i i { i { i ! i ! ~[Fr! [ { { ! '~ i ~ !. I I I i i F{ i { i { i i i l.{ I i I i i i i ! " '! "' ~'" "'' ' L~ " ........ i i!!i ~,~ iiiiit i ~! iiil ~i ii !ii;. :ill ii; !!~: ~iii !i! : , % Teleco Oilfield Services Inc. 220 A Center Court Anchorage, Alaska 99502 December 14, 1982 ARCO ALASKA ROWAN 35 .WELLSITE 1 #23 JOB 184AK Attached please find a copy of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank you for the opportunity to serve you. We at Teleco realize the importance of good service and hope that you will-continue to use our ~D services in the future. Please feel free to contact me if-you have any questions. Enclosures SB-ck Sincerely, Steve Billeaud Yield Service Supervisor ? TELEEO Teleco Oilfield Services Inc. 220 A Center Court Anchorage, Alaska 99502 JOB 184AK ARCO OF ALASKA ROWAN 35 WELLSITE 1 #23 Tool 268-22 Surface Gear 171 FSE Ron Suermann arrived on site at 1000 on 11/9/82. Tool went in hole at 0130' 11/11. Drilled with jet assembly and rotary from a vertical depth of 2595' to 2630' and angle of 4.5. We had a magnetic tool face of S80W. 0800 11/11 continued drilling from 2630' to 4176'. Angle of hole was 39.3 with hole direction of S88W. We made one bit run during this period to pick up a new bit° 0800 11/12 continued rotary drilling to a depth of 5603', with an angle of 46.2, and hole direction of N89.4W. We made 2 bit runs to change BHA and dull bit. We made ~one of the two due to a cone nozzle blow out. 0800 11/13 continued rotary drilling to a depth of 7127' with an angle of 47.8 and hole direction of N86.6W. We made one dull bit run. Job going well. 0800 11/14 continued rotaty drilling to a depth of 7970' and an angle of 46.2, hole direction of N88.3W. We made 2 bit runs, one due to the lose of a nozzle jet. 0800 11/15 continued rotary drilling to a depth of 8775' with 42 of angle and a direction of N88.7W. We made one bit run and changed BHA. 0800 11/16 continued to rotary drill to a depth of 9494' with 40.1 angle in the hole, a direction of N88.3W. We made one bit run and changed the BHA. 0800 11/17 continued~ rotary drilling to 10083' with 41 angle and a hole direction of N82.5W. We made one bit run. 0800 11/18 continued rotary drilling to 10507' with 46.3 angle and a hole direction of N79.2W. Hit casing point, pulled out of hole to lay Teleco down. End of job. t I::'AGE CLISTOMEi't : ARCO LOC;ATION : PRUDHOE BAY, AI_A`SKA NELL. P~D : DS.-.1 ~ELL NO, : DRIL. I....ING CO, : ROWAN CLIS"r[IMER JOB NO. : TELECO JGB NO. : 184.-AK MAGNETIC DECLINAT'ION : 50,30 E 2.5 RIG NO. TELECO OIL. FIEL, D SERVICES OF' AI..ASt(A, INC. E',I 1G NIELSON WY. , AN[:}..IOF~AC~I~, ALASKA, 9~5[~2. TEL : (987) 279-8G31 DATA REI)I...ICEED BY RADILIS OF [;UI'~.VA"I'LIRE MEI"HOD I'YPE OF SIJRVEY : MAGNETIC START DATE : 11/09/82 F:'II',IISH DATE : 11/19/82 PI....AI'qE (:IF PROPOSED DIRECTION IS : N 80 W REPORT PREPARED BY : RON SLIERMAIq :: .-.,: ::=: :,.-. m= == :: :: ..-=. =.-. = :::: == == :: :: ~. :: =: :=: ::: _ :: ~ = = = ::; = ::: :~: := ::: =: = = _ = =: = = = = _ = = .-: ~ = = = = = ~ :: := := = = = = = :: ::: :.-..~. == := = ::: ~_. ;;= = = =: :::: :::: =:: .-: :::.-, :: _--= =:: :.q ::: = ~: :=: -..~: ::: ::: :;:: =.~: :::: ::', :m :::: :'.' r, :::: ::':: :.-= r.'.' ::= ::: :::: :~:: :::~ :::: :~:: :.-. ',::~. ::::: ::;: '-'= ::: :::: ,-.= :::: .',.:: ;::~ ::::: ::u: :.::: ::: =:: '-":; :::~: :,'4 :;:,~ .=: MEEASURED DRIFT TRUE VERTICAL DRIFT TOTAL. COORDINAI'ES C L 0 IS LJ R E S DOG -" I...EG I')E. PTH ANGLE. VERT I CAL. SEC T I ON D I RECT I ON D I STAN(]E, ANC..iI..,.E SEVER I T Y DEG N[N DEPl"H DEGREES DD MM ,SS DEG/~00 F'l". 2805 3. 18 2804.88 3. G9 'N 74.00 W 4.59 N 3.39 W 0.00 ................................. 2805 5. 18 28~4.88 3.69 N 7~.80 W 3880 11.~8 2998. 19 29.31 S 88.8~ W 5,93 N 28,98 W 29,58 N 78 25 56 W 4,5FJ8 5178 1~. 18 5170.8S 70,7~ S 75.~8 W 3.42 S 71.16 W 71.25 S 87 14 4~ W 2. G1FS 54S6 21.24 3445.42 161,83 S 85,~ W 1~,58 S 1G2. 3020 54,42 3579.55 2.52.55 S 85.00 W 25.89 S 234.84 W 230.57 S 85 42 40 W 8.630 5885 29,24 3736.13 32~,65 S 8~,00 W 3.5.5~ S 332,81 W 334.50 S 84 14 89 W 2.87~ 3989 34.30 3892.2~ 426.29 S 88.00 W 38.69 S 430.05 W 431~78 S 84 51 32 W 2.830 417~ 39.18 4041.80 537,95 S 88.00 W 42,81S 542.2:6 W 545,93 S 85 38 25 W 2.587 435~ 45.00 4177,47 660.~9 S 88,00 W 46,89 S 66a.99 W 86G.64 S 85 57 58 W 3,115 4425 46.24 4223,57 707,11 S 89.00 W 48.1:5 S 712,21 W 713.85 S 80 08 01 W 2,582 4554 46.30 4312.37 800,25 S 88,00 W 50.58 S 805,75 W 807.34 S 80 24 28 W 0.583 5041 46,12 4648.21 1150.99 S 88,00 W 82.89 S 1158.21W 1159.91 S 88 55 31W 0,082 5005 46.12 5037.20 .1555..57 N 8~.00 W 66.45 ~ 1563.82: W 1565.25 S 87 34 03 W 0.385 5~84 46,38 52~,94 1830.90 N 8~,00 W 61,61N 183~,G~ W 1840,72 N 88 04 54 W 0.105 0507 ~6.48 5658.62 2211.00 N 89.00 W 54.97 N 2220.26 W 2220.94 hi 88 34 54 W 0.058 7036 48.00 6016.69 2800,05 N 88.00 W 44.78 N 2B09,52 W 260~,90 N 80 01 01 W 0.20G 7927 47.30 6279.59 2889.27 N 88.00 W 34.68 N 289~).77 W 2898.97 N 89 18 52 W 0.128 7~70 48.12 6850.95 3285,19 N 88,00 W 20.85 N 5294.08 W 5294,75 N 8~ 38 14 W 0,23~ 8246 ~5,00 ~844.08 3482,26 N 88,00 W 15,~7 N 3491, Z5 W 3491.7~ N 89 48 14 W 0.435 85G0 45.42 7068.59 3701.55 N 89.00 W 8.22 hi 5711.18 W 5711.19 hi 8~ 52 22 W 0.470 89~5 Z~1.54 7387,77 3998.70 N 89.00 W 3.06 Iq 4006.6~ W 4000.63 N ~ 57 22 W 0.414 9307 41,00 762:1.44 4203,2:4 N 88.00 ia 2.55 N 4213.36 W 4213.30 N ~ 58 05 t4 0.33.5 ~850 39,38 7882.84 4425.25 N 87.00'W 12.05 N 4~35.22 W 4435.24 NOg 5~ 40 W 0.476 10145 41.42 8256.88 ~74~.29 N 82.00 W 42.82 N 4754,90 W 4755.09 N 89 29 02 W 0.786 I l I I ~,.~, LI F:~ ~/[-':' "'~' a E3 P [-] I...-( '"F PAGE JOB I',IUMBE:F~ : 18z~.,.-At{ ' 'CUSTOME[~. : ARCO PAl) : DS-1 ~,IEL. L. NO, : 23 ~ MEASURED DRIFT I"RUE VERTICAl_ DRIFT 'I'I]TAL COORDINATES C L. 0 S lJ R E S DOG ..- L. EG DEP'rH ANGL. E VE RTI C~L SEC T [ ON D I RECT I ON D I STANCE ANGLE SEVER [ TY DEG MIN DEPTH DEGREES DD MM SS DEG/leO F'f,' 10507 48.18 8518.72: ag97.~8 N 79,00 W ~'~4,55 N 5004,2g W 5005.00 N 89 01 55 W 1.587 ;30TTOPI I..IOI_E CLOSL.IRE: 5005 FEET AT N 89 1. 55 PRE'.PARED BY AI~ACLIS COMPLITER SERVICE 820 W. 71S'¥. AVE, ENTIRE CONTENTS COPYRIGHT 1~02 ABACUS COMDUTER SERVICE AI'JCHORf~IC~E, ALASI.%! I i Suggested form to be inserted in each "Active" well folder to cb. eck for timely compliance with our regulations. ~~ ?~ ~ I-~3 , Operator, Well Name and Number Reports-and Materials to be received by: /-- ~ Date .Required Date Received R.emarks Completion Report Yes ,, Mud Log ,, Core Chips Core Description .__ Registered Survey..,~-<Plat--'~/ ~ ~. ~ Inclination Survey Drill St~ Test Re~s /~,~-~C- ~"~--~ J~/~'~.- ~u~on T~t Re~s ARCO Alaska, Inc. Post Office Box 360 Anchorage, .z -~(a 99510 Telephone 90/ Z77 5637 January 3, 1983 RE: ARCO Directional Surveys D.S. 1-23 11-11,82 D.S. 7-16 11-18-82 D.S. 12-20 11-12-82 Directional Single Shot Directional Single Shot Directional Single Shot · ~please sign and return the attached copy as receipt of data. Becky Benedi ct AFA - 403 E/W E/W E/W Transo #003 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Alaska Oi~ & Gas Cons. commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan? Posl Office Box 360 Anchorage. A-~,ska 99510 TelephOne S .)77 5637 December 22, 1982 RE: ARCO Cased Hole Finals D.S. 1-12~ 11-25-82 D.S. 1-18~ 11-24-82 D.S. 1-23~ 11-27-82 D.S. 2-6J 11-27-82 D.S. 4-11 f'10-17-82 D.S. 12-4/ 9-26-82 D.S. 12-8B ~1-25-82 D.S. 12-20J11-28-82 D.S. 13-18~ 9-28-82 D.S. 14-14x 9-3/4/5-82 D.S. 16-12~ 10-14-8-2 CH CNL Run 3 5" CH CNL Run 3 5" CBL/VD Run 1 5" CH CNL Run 3 5" Spinner 5" Spinner 5" CH CNL Run 2 5" CBL/VD Run 1 5" Spinner 5" Spinner 5" Spinner 5" ' P~e~ease sian and return the attached copy as receipt of data. SCH SCH SCH SCH Camco Camco SCH SCH Camco Camco Camco Becky- Benedi ct AFA- 403 Trans. #671 DISTRIBUTION NORTH GEOLOGY R &D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ~ ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompan¢ ARCO Alaska, Inc. Post Office 360 Anchorage. A.aska 99510 Telephone 907 277 5637 December 20, 1982 RE." ARCO Open Hole Fi nals D.S. 1-23 11-23-82 Prolog (Field Analysis) 5" D/A D.S. 1-23 11-23-82 DIL 2" & 5" D/A D.S. 1-23 11-23-82 FDC/GR 2" & 5" D/A D.S. 1-23 11-23-82 FDC/CNL/GR 2" & 5" D/A D.S. 1-23 11-23-82 BHCS/GR 2" & 5" D/A D.S. 1-23 11-23-82 CNL 5" D/A /~Piea. se sign and return the attached copy as receipt of data. Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Becky Benedi ct AFA- 403 Trans. #664 DISTRIBUTION NORTH. GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALA~~_ DALLAS ARCO Alaska, Inc. Post Office ~ 360 Anchorage.. .ska 99510 Telephone 907 277 5637 December 20, 1982 RE: ARCO Cased Hole Final D.S. 1-23 11-21-82 CBL/VDL Sig. Run 1 5" ~Please sign and return the attached copy as receipt of data. D/A Becky Benedi ct AFA- 403 Trans. #666 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF~,,-~'~.A~ J~ ~. [ .~I~- D~ AlasY, a Oil & Gas oons, commissior, Anchorage ARCO Alaska, Inc. Post Office B~c~;360 Anchorage, ~ ka 99510 Telephone 907 277 5637 December 9, 1982 RE: ARCO Magnetic Tapes l~'i\~)~& --'-~D.S. 1-23 11-23-82 D.S. 12-20 11-24-82 D.S. 13-13 11-24-82 D.S. 7-15 11-10-82 ECC 1532 Open Hole #66117 Open Hole #66120 Open Hole #66037 D/A SCH SCH SCH Run 1 Run 1 & 2 Run 1 Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Transo #651 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS A. lask[~ 0il & Gas Cons~ ~Jommission Anchorage ARCO Alaska, Inc. ~'"~ - Post Office/ 360 Anchorage, _ _aska 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine. Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for November on these drill sites' 1-22~ 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 A1 so enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F-7 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDuSen District Drilling 'Engineer PAV:JG-sm Attachments GRU1/L3 ARCO Alaska. Inc. is a subsidiary of AllanticRichfieldCompany - -- ~-". STATE OF ALASKA "-'-' ALASKA{ .AND GAS CONSERVATION CO~' '~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-180 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20854 9. Unit or Lease Name FWL, 637' FNL, Sec. 8, TION, R15E, UM Prudhoe Bay Unit 4. Location of Well 550' at surface 5. Elevation in feet (indicate KB, DF, etc.) 74' RKB 6. Lease Designation and Serial' No. ADL 28329 10. Well No. 1 -23 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool November 82 For the Month of. ,19 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0230 hfs, 11/08/82. Drld 17-1/2" hole to 2607'; ran, cmtd & tstd 13-3/8" csg. Dr]d 12-1/4" hole to 10564'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 11452'; ran logs; ran, cmtd & tstd 7" csg. Ran CBL & 5-1/2" completion assy. Secured well & released rig @ 2400 hrs, 11/28/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 79'. Instld w/1957# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe ~ 2595'. Cmtd w/2300 sx CS III & 400 sx CS 9-5/8", 47.0#/ft, L-80/S00-95, BTC csg w/shoe ~ 10548'. Cmtd w/500 sx Class 7", 29.0#/ft, L-80, BTC csg f/10240'-11447'. Cmtd w/330 sx Class SEE DRILLING HISTORY II. 14. Coring resume and brief description None 15. Logs run and depth where run CBL/CCL/GR f/10490'-10000' DIL/SP/BHCS/GR f/11452'-9-5/8" shoe & f/11426'-10516' FDC/CNL/GR/Cal f/11426'-10516' cont w/CNL/GR to 13-3/8" shoe CBL f/11378'-10140'. 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Area Drilling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 G R U 1 N R 1 Submit in duplicate DS 1-23 DRILLING HISTORY NU 20" Hydril & diverte, r. Spudded well @ 0230 hrs, 11/08/82. Drld 17-1/2" hole to 2607'. Ran 66 its 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2595'. Cmtd 13-3/8" csg w/2300 sx Cold Set III & 400 sx Cold Set II. ND 20" Hydril & diverter. Welded patch in 20" conductor. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10564'. Ran 236 its 9-5/8" 47#/ft, L-80/SO0-95, BTC csg w/shoe @ 10548'. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Cmtd 9-5/8" csg w/500 sx Class G. Drld cmt to 10516'; ran CBL/CCL/GR f/10490'-10000'. (Note: CBL showed top of cmt @ 10190'. On 11/21/82, approval was rec'd from Lonnie Smith to proceed based on obtaining a good CBL & obtaining a satisfactory shoe tst after drlg out.) Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11452' TD (11/23/82). Ran DIL/SP/BHCS/GR f/11452'-9-5/8" shoe & f/11426'-10516'. Ran FDC/CNL/GR/Cal f/11426'-10516' cont w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Cold Set I, & 131 bbls Arctic pack. Ran 31 its 7" 29#/ft, L-80 BTC csg f/10240'-11447'. Cmtd 7" lnr w/330 sx Class G. Drld cmt to 11404' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Tstd lnr lap to 3000 psi - ok. Ran CBL f/11378'-10140'. Ran 5-1/2" completion assy (including GLMs) w/tail @ 10208' & pkr @ 10171'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2186'. Secured well & released rig @ 2400 hrs, 11/28/82. JG:sm 12/03/82 GRU1/DH1 RECEIVED DEC 1 5 ]S 82 Rlaska Oil & Gas Cons. Commission Anchorage TO: THP. IY: FROM: MEMORANDUM Stme of Alaska C. V./C~e~on ~nnie C. SmAth / TELEPHONE NO: Corem& ssi o~e r Ben !~Norm~ n Petroleum Inspector 1982 SUBJECT: Witness BOPE Tests on ARCO's DS 1-23 Sec. 9, TllN, R10E, UPi Prudhoe Bay_. Unit Tuesday,~N~ovember..' 9,_ 1982 - I departed my home at 12:20 ~.m,'for a 12:50 p.m."Sh°wup and 1:50 p.m. departure via A!as~ Airlines flight $61 for Deadhorse arriving at 3:30 p,m. W~ather: -21OF,. clear, light wind. WednesdaY, November 10, 1982 - BOPE tests on Sohio's B-20 ~e~e completed, th~'' 'subject"of a separate report. BOPE tests on DS 1-23 began at 8:20 p.m. and were completed at 11:20 p.m. BOPE inspection report is attached. Thursd_ay,.~qovember '11,_1982 - BOPE tests on ARCO's Kuparuk ~E-25 were completed, the ~ubject of a separate report. ~riday,_ Novemker 12~ 1982 - Standing by on DS 13-13. Saturday, November 13, 1982 - BOPE tests on ARCO's DS 13-13 ~ere completed 'the subject of a separate report. ' Sunday, November ~14, 1982 - BOPE tests on ARCO's DS 12-20 ~e~e completed, the 'subject of a separate report. I_departed Dead-horse via Alaska Airlines flight ~66 at 9:45 a.m. arriving in Anchorage at 11:25 a.m. and at my hon~ at 11:55 a.m. In summary, I witnessed successful BOPE tests on ARCO's DS 1-23. O&G #4 4/8i ~TATE OF ALASKA ALASKA OIL & GAS CDNSERVATION CCMMISSION B .O.P.E. Inspection Report .Inspector Operator. ~ ~' Representative Well .. D--~ /--%~ . . Permit # Location: Sec ? T~/R/O~M U~ /~~;sing Set Dril ling Contractor ~-~~ Rig ~ ~- Representative Location, General. ~D/~ Well-,Sign ~/~ ,,, Ceneral Housekeeping _d)//-...' Reserve -pit ~%)~ Rig ~/~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCUML~ATOR SYSTEM Ful 1 Charge Pressure ~ Pressure After Closure ,. Pump incr. clos. pres. 200 psig. Full Ch~.e PressUre Attained: N2 ~/~70~ m/~-~; Controls: Master Remote psig psig min~sec min. ~ sec. psig Blinds switch cover~ Upper Kelly. Lo~er Kelly ~ali ~pe Inside BOP Kelly and Floor Safety Valves - Test Pressure Test Pres sure ~ Test Pressure ~)/~- Test Pressure Choke Manifold Va s. No. flanges_ Adj ustab le Chokes Hydrauically operated choke / Test Pressure Test Time' Test Results: Failures' O hrs Repair or Replacement of failed equipment to be made within Inspector/Ccmmission office notified. Remarks :_ -~-,.~7'.r Zg'~':'~;,~ ,,g 7' F,'-~ //~'~ ~~ C~,,-/-/,~,~e7'~ -~.'w' //;~ ,~~ ........ days and Distribution orig. - AO&GCC cc - Operator cc - Supervisor C~tober 29, !982 Mr. Mark A. Major Area Drilling Engineer ARCO Alaskm, Inc. P. O. Box 360 Anchorage, Alaska 99510 Pr,ad_hoe Bay Unit DS 1-23 ARCO Alaska, I~c. Permit No. 82-180 Sur. IGc. 637'F~L, 550'FWL, Sec. 8, T10~, ~lSE, U~. ~tmhole Lac. 278'~L, ll'FEL, Sec. 12, T101~, R14E, Dear Mr. F~ajor: Mnc!osed is the approved application for permit to drill the aho%~ referenced well. If corin~ is conducted, a one cubic inch chip from each foot of recovered core is req~aired. Samples of well cuttings and a mud log are not required. A continuous .directional survey is required as yer 20 AAC 25.050(b)(5). If a%railable, a tape containing the digitized log information shall be submitted on all logs for copying except exFerimental logs, velocity surveys and dip~eter surveys. ~any rivers in Alaska and their drainage systems have been classified as im~rtant ~or the spa%w~ing or migration of anadr~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promul.~ated thereunder (Title 5, Alaska Aumlnistrative Code). Prior to com[c.encin9 o~rations you may be. contacted by the Habitat Coordinator's office, Department of Fish and Came. Pollution of any %raters of the State is prohibited by AS 46, Chapter 3, Article' 7 and the regulations prc~ulgate~ thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by th~ Federal ~ater Pollution Control Act, as amended. ~'rior to ¢~ncing o~rations you may be.- contacted by a representative of the ~.partment of Environmental Conservation. TO ai~ us in scheduling ~lel~ ~rk, p/ease ~:otify 'this office 24 hours prior to com~--ncing installation of the blowout Mr. Mark A. Ma3-~r Prudhoe Bay ~it DS 1-23 -2- October 29, 1982 prevention equipment so that a representative of the Commission may be pres~nt to witness testing of the equipment before the surface. casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to c~mencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of s~spension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. Very truly yOurs, C. V. Chatter~gno~.~..-~~ C? '?~"~ ~'~'~,~". Chai r~n of ' - - ~' ~'~-" - -- ~ ~ .... AlaSka Oil and ~s Conservation C~ssion Eac lo sure Department of Fish & Game, Rabitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC ~ be ARCO Alaska, Inc. Post Office B.. , Anchorage, Alaska 99510 Telephone 907 277 5637 October 25, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 1-23, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 1-23 and the required $100 filing fee. Attachments to the application include /-~a plat de~,iling the section and plan views of the proposed wellbore;~ proximity plat showing the subject wellbore's position to the neare~l~ well drilled;(~a sketch and description of the BOP equipment;~ind a sketch and description of the surface hole diverter system. Since we estimate spudding this well November 8, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: 1 lm Enclosures GRU2/L19 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '-' ALASKA OiL AND GAS CONSERVATION ~,OMMISSION P£RMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, lnc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 637' FNL & 550' FWL of Sec. 8, T10N, R15E, UN At top of proposed producing interval 312' FNL & 4522' FEL of Sec. 7, T10N, R15E, UM At total depth 278' FNL & 11' FEL of Sec. 12, T10N, R14E, UM 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 1-23 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 74', PAD 40' I ADL 28329 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed ! NW of Deadhorse 2 miles ADL 28329, 11 feet well DS 1-22, 120 feet ! 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date " 11452'MD, 9209'TVD feet 2501 11/08/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3700 . psig@____ Surface KICK OFF POINT2700 feet. MAXIMUM HOLE ANGLE 45.3 oI(see 20 AAC 25.035 (c) (2) psig@. 9209 ft. TD (TVD) 4495 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH OUANTITYOF CEMENT SIZE Hole Casing Weight B0" 20" 91.5# 7-1/2" 13-3/8" 72# i 2-1/4" 9-5/8" 47# 8-1/2" , 7" 29# 22. Describe proposed program: CASING AND LINER Grade CouplingJ H-40 Welded L-80 BTC L-80 BTC L-80 BTC Length MD TOP TVD 76' 34' I 34' 2566' ' 34' I 34' I 10525' I 32' I 32' 1195' 10257' 18369' MD BOTTOM TVD 110' 110' 2600' 12600' I 10557' 18580' 11452' 19209' (include stage data) 2200 lbs, Poleset 2300sx Cold Set III + 400 sx CS II 800sx Class "G" Cmt 350sx Class "G" Cmt ARCO Alaska, Inc., proposes to directionally drill this well to 11452' MD (9209' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. The well will be completed with 5-1/2", 17#, L-80 plastic-coated tubing with provisions for a subsurface safety valve. A nonfreezing fluid will be left in all uncemented annuli within the permafrost zone. The packer will be set above the Sadlerochit and Sag River formations. A separate Sundry Notice will be submitted before the well is perforated. A surface diverter will be used on this well. DS 1-22 will be 120' away at the surface. DS 1-14 will approach within 158' at 2700' but will not be crossed. ,~ ;- ,-~ I'~ ", ~.~ No ~ e~losr. O_rossir~ wilt ~ ~Co~rcd ~~h~ do~n~..g OCT 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ The space below for Commission use CONDITIONS OF APPROVAL SampleS[lYES requiredENO II MUdr_lYEsIog required~,NO [~¢-Y ESDirecti°nal Survey required I APl number Permit number ~~ ~A~ //} ! - I SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVEDBY_CZ,~/. ( ~~ ,COMMISSIONER DATE Ootdae]: 29, 1982 by order of the Commission Form 10-401 GRU2/PD15 Submit in triplicate : ! i · ! -4,t 23--i 4559" l · 13-5/8" BOP STACK DIAGRAM / ,. ANNULAR PREVENTER ~_~BL I ND RAMS , PIPE RAMS Accumulator Capacity Test 1. Check and .fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. · · 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed Pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- vi sor. 17. Perform complete BOrE test once a week and functionally operate BOrE daily. Rev. 5/13/81 SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC. I0" HYD. OPR. BALL VALVE WE,L,L BORE (SEE DETAIL) IQ' HYD. OPR. BALL VALVE ALL 90'" TURNS ARE "TEE" CUSHION I ~LL QBORE - I RESERVE PIT AREA NOTE' FLOWL INE DR ILL ING R I SER L1 20" 2000 PSI WP ANNULAR PREVENTOR ,,,,, k,.,.'"-- I 0" D IVERTER LINE'--' ~ ~, Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE / I O" HYDRAULIC OPERATED BALL VALVES "DETAIL" 202601O2 5 ~o . 4c~lt: I'-- 4-00' PKO1'K~c'f'~o ~'c ~, dqoN, F, 15~, LJM. I HEREBY CERTIFY THAT i >--,,M PROPERLY REGISTERED AND 'LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHE'R DETAILS ARE CORRECT, AS OF: IC)//'7/~,~. / 1/23 LAT = 70°14'27.348'' LONG = 148° 24'06.631" Y = 5,940,265.01 X = 697,879.04 NW CORNER CELLAR BOX ELEV = 40.01 1/24 LAT = 70°14'26.187'' LONG = 148024'05.982 y = 5,940,147.66 X = 697,904.48 NW CORNER CELLAR LOX ELEV = 40.11 1/25 LAT = 70°14'25.029'' LONG = 148024'05.333'' Y = 5,940,030.52 X = 697,929.87 NW CORNER CELLAR BOX ELEV = 39.98 1/26 LAT = 70°14'23.869'' RI:CE VEI LONG = 148°24'04.690'' y = 5,939,913.14 OCT :[ 5 ]982 x = 697,955.09 Nw CORNER CELLAR BOX ELEV = 39.95 Alaska 0il & Gas Cons. Commission 1./. ! ..~ ..., ARCO A[ast.,a, Subsidiary of A!lcnlic Richfield Compony ~. CHECK LIST FOR NEW WELL PERMITS Company ,, Lease & Well No. ITEM (1) Fee (2) Loc AP PROVE DATE ,, :(~2 thrW-'8) 3. 4. 5. 6. 7. 8. (9' thru 11) 10. 11. (4).Casg 12 thru 12. 13. 14. 15. 16. 17. 18. 19. 20. (5) 'BO PE ~ Lb _~.f~2_ (21 thru 24) 21. 22. 23. 24. YES, Is the per it fee ached m att ......................................... we ..........,.......,... Is 11 to be located in a defined pool .~ .... Is well located proper distance from property line '''''''''''''''''C~"'~ ~/' ~...~ Is well located proper distance from other wells ..... ............~ Is sufficient undedicated acreage available in this ~ggl--.....-'..- Is well to be deviated and is well bore plat included ................~.~ Is operator the only affected party ...~ ................. ''''' ' ''''' 'i~'~ Can permit be approved before ten-day wait ............................ __ Does operator have a bond in force Is a conservat±on order needed Is administrative approval needed ,. NO Is conductor string provided ............................. , .......... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons . . Will surface casing protect fresh water zones ======================= Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....... Are necessary diagrams of diverter'~'~'g~i~g~;'~;;~g~g~ Does BOPE have sufficient pressure rating - Test to-~t~ psig .. Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. REMARKS 25. Additional requirements ............................................. ~ Additional Remarks: o ~Z ~ o Geology: Engineering LCS -- ~rVA ~ JKT~-~ RAD -er: 08/19/82 INITIAL GEO. UNIT ON/OF POOL CLASS STATUS AREA NO. SHORE j ,..,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. :hlU,~ber.qer ,laske Comput in 26-0CT-1994 **** REEL SEA, DER **** $~:R~ICE MAt4E : EDIT DAT~ : 94/07/13 O~I~IM: : FLIC REEL NA~E : g4~2g P~EVIOUS ~EE[, : CO~'~EMT : ARCO ALASKA INC, DS 1'23, PRUOHOE BAY ,50-029'20854-00 **** TAPE HE.~.DER **** SERVICE NAME : EDIT O~T~ : 94/07/1.3 OPI~I~ : FbIC TAPF NAME : 94~29 CONTIMUATIOk~ ~ ,: PPEVIOUS TAPE : COMMENT : ~RCO ~LASK,~ IN'C, DS 1-23, PRUDHOE BAY ,50-029-~0854-00 C~.SMD HOLE WIt~ELINE bOGs OPERATOR: LOGCING COMPANY: T~P'~ CR~ATI~N D~TE: 008 NUMRE~: LOGGING ENGINEER: OPERATOR WITNESS: SH~wACE LOCATION SECTION: TO~ISRIP: RANGE: FNL~ FSL: FFL: FwL: ELEVATI~N(FT FROM ESL KELLY BUSHING: DERRICK FLOOR: GROU~D bEVKL: W~L~, CASING RFC~R~ ~ST STRING ~RD STRING PRODUCTION STRING DS 1-2~ 500292085400 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 1,2-~UL-94 94229 G. SCHWARTZ J JULIAN ION 637 55O 74,00 73.00 40.00 OPEN HOLE CASING DWILbFRS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHt (LB/FT) 12.250 ~'~ 625 105~8.0 47.00 ~.500 7.000 I1447.0 29.00 5.500 10208.0 ~7.00 CIIRVE SWIFT DATA - Ab!,, PASSES T~ STANDARD(MEASURED DEPTH) PAGE: 1 ~$ Ta~e vet!~X¢~t~on [.,i~t~nq :hlum~et~et Alask, a ~omputln~ ~ente~ .. 26-OCT-1994 15:16 DATE LOGGED: , -------'--EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH 1.125~ 0 5 111,9 0 1 09 1108~ 0 10963,5 1. 0941, . 5 1,0929,0 10901,0 1.0870~ !0830,0 10807,0 !.0789,0 1. 0733 5 o 05:5 !0705.0 10688,0 1.0676 0 1067~!5 10672 0 10667.5 100.0 ~RCH TDTP 88885.0 88BB ~.. 1.1255.0 11255.0 ~1191.0 ~1191 0 11088,5 11088o0 10963,5 10963 0 10941,5 10941,:5 10929,5 10901.0 10869.5 1.0869,5 10829.0 :10829,0 1.0806.0 10704.0 10671.0 10666.0 98.5 I07B~ 0 1,0704.0 10686.5 10676.5 10671.0 98.5 THE INFOR~ATION P~RTAINING TO THE OPEN HOLE G~ SUCH AS R~N NUN~ER, PASS NUMBER [,O~GING DATE AND ~DGGING CO~PAN¥ WAS NOT PPOVIDE6 WITH THE TAPE SUPPLIED BY THE CT, lENT. 'tHE DRPTH CORPECTIONS SHOWN ABOVE R~FLECT C~SED TO OPeN HOLE GR A~D C~SED HOLE SIGH TO OPE~ HOL~ ALL OTHFR TDTP CURVES W~]RF CARRIED WITH THE S FILF NA.E : EDTT .001 SF...RVICE : vFRSInN : 001C~1 [)a"r~ : 94/07/13 FT[~F TYPE : L~ST FI~,E TaPe Verf,,fication List~;ng :lnlumberqer AlaSka Comput,l, ng Center 26-0CT-1994 15:l, 6 FIL~ HE~:DER 0.5000 DFPTH I~C~EMENT: # FIL~ SUmmARY LDWG TOOL CODE GRCM TDTP S,'I, ART DEPTN 117..59.0 ~I~7~.0 STOP DEPTH ~mmmmmmm4m~mmm ~,06~5,0 CURVE, SHIFT DATA - PASS TO PASS C MEASURED DEPTH) .,mASELINE CURYE FOR $~IFTS LDWG CURV~ CODE: PASS NUMBER: -'--------EOUIVALENT UNSHIFTED DEPTH---------- ~ASE5I~E DE'PT~ $ ~E~ARKS: THIS FILE CONTAINS PASS #I OF T~E TDTP, NO PASS TO PASS S~IFTS WErE APPLIED TO THIS DATA, $ # LTS FOR~,AT DATA PA~E: 3 TABLE TYP~ : CONS C~ ARCO ALASKA INC. FN PRUDH05 BAY ADI~ 50-029-20~54-00 FI, 637' FN[, & 550' FWb S~CT 8 TO~ 10N R~N6 15E Cog~ NnRTH SLOPE STAT ALASKA NaTT USA ,IT~Y J JULIAN SON 45295~ pDAT EPD TT 0. L~F APD PT 74, E~B PT 74. EDF FT 73. ECS ~T ~0, Company Name Field Name Well ~ame API Serial Number Field Location Section Townsmip Range County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log ~easured From ADOre Permanent Datum Elevation Ot Kelly Bushin~ Elevation of Derrick Floor Elevat~,oD of Ground Level "$ Ta~,e Ver~,fJ, cat. lon List,~,ng :hlu~berger Alaska Computi, n~ Center 26-0CT-1994 15:16 PAGE: 4 TUN! VALU DEFI TDD FT I1452, Total DePth -Drill. er f31,1 VT 112~0, BOttOm LOg interval TLI FT 10665, TOP Lo~ Interval DFT SEAWATER/BORAX Drlll. l~g FlUid YYPe TLAB 12101 15-NOV-92 Time Log~er at Bottom B~T DEcF 120, 8ottOm Hole. Temperature TABLE TYPE : CU~V D~PT De~th $1GU Sigma (Neutron Capture Cross Section) ?~H! TDT Porosit.¥ SSHF 8oreho]e Sigma - far detector SBHN Rorehole Sigma - Near detector SIGC Sigma Correction $I8~ Corrected Borehole sigma I RAT ~atlon Totalgear toFar counts DS~ Standard deviation of Sigma BAC~ ~ack~round Count Rates - Near Detector F~AC Bac~round Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts amalyzed - far detector (TDTP) ~CND Total capture counts - Near detector TCFD Total capture Counts - far de:rector T~C, Total Selected Counts - Near Detector ?SCF Total Selecte~ Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector G~C~ Gamma Ray tn Casing T~K Surface Tension G~ APl-Corrected Gamma ~av ~m~~mm~mmmm~m~~~m~~mmm~~m~mmmm~ DATA FORMAT SPECIFICATION ~ECO~D *~ SET TYPE - 64EB *~ ';~'''_ PE ..... R~R CODE'''''''~'~'' I 66 2 66 3 73 4 66 5 66 6 73 7 65 [$ Ta~e Vertflcati. on titst~na :hlumt~erger A!as~a ComPutlno Center 26-OCT-Igg4 15:16 PAGEi TYP:~ REP~ CODE YAbUE 8 68 0,5 9 65 FI 11 66 13 66 0 14 65 15 66 16 66 0 66 O ~m~mw~~mm~m~mmm~mmm~mw~ ** SET N A N. ~ $ ~ R V U N I T '~D TYPE -'CHAN ** ' · SERVICE AP1 API AP1 APl PIL6~ NUMB NUMB SIZE REPR PEOCE$6 ORDER # bOG TYPE CLASS MOD NUMB SANP ELE~ CODE (HEX) mmmmmmmmmmmmmm 00 000 00 0 1 1 1 4 68 0000000000 00 000 00 0 I ~ 1 4 68 0000000000 O0 000 O0 0 I 1 ! 4 68 0000000000 O0 000 O0 0 1 I 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1, 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 ! 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 ~ 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 ~ 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 O00000OO00 O0 000 O0 0 I 1 t 4 68 0000000000 O0 000 O0 0 1 1 I 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 DEPT F'T 452954 $IG" TDTP Ct.{ 452954 TPH! TDTP PU-$ 452954 SBHr TDTP CU 452954 SBa~ TDTP CU 45~954 SIGC TDTP CU 452954 $IBR T'D~P CU 45~954 ~"~AT TDTP 452954 SDS~ TDTP CU 452954 BIC~ TDTP CPS 452954 F~AC TDTP COS 452954 TCA~ TDTP CPS 452954 TCAW TDTP C~S 45~954 TCND TDTP CPS 452954 TCFD TDTP CPS 452954 T$C~ TDTP CPS ,452954 T$CF TDTP CPS 45~954 INND ?DTP CPS 452954 INFO TDTP CPS 4,5~954 G~C~ ?D?P GAPT 45~954 TF~ TDTP LR 452954 G~ OH GAPI 4:52954 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DFPw 11307.000 SIGM.TDTP $~H~ll?DTP -999.250 SI~C.TPTP S~$I.~DTP -999.250 BACK,TDTU TCA~.TDTP m999.250 TCNiJ,TDTP TSCW.TDTP -909.250 I/~NO,TDTO T~S,TDTP -999.250 eR,UR -999.250 TPHI.TDTP -999.250 -999.250 SIFH.TDTP -999.250 -999.250 FBAC.TDTP -999.250 -999,250 TCFO,TDTP -999.~50 -q99.~50 XNFD,TDTP -999.~50 -9999,000 5BHF.TDTP TRAT.TDTP TCAN.TDTP T$CN.TDTP GRCH.TDTP -999.250 -999-.250 -999.250 -999.250 -999,250 '$ Ta~e yerlficat~,,on l[.,lst~n~ :hlumberger .A].,as~a Computing Center DEPT. SBHM.TDTP SDST.TDTP TCA~.TDTP T$CF .TDTP TM~t$.TDTP 105~,7.000 -999.250 -999.250 -999.250 -999.250 -999.250 SIGC*TDTP BACK'TDTP TCND;.TDTP INMD.TDTP GR.O~ EMD OF DATA 26-0CT-1,994 -999.250 TPRI,'TDTP -999.~50 SiBft:.TDT'P -'99g.~50 FBAC.TDTP -999 i~50 TCFD:,,TDTP -999~ 50 INFD.TDTP 7~,..984 -999.~50 $1~HF'.TDTP 999,.~ TCAN.TDTP .999.~50 TSCN,,TDTP . 999. 250 GRCH,TDTP 9AGE= -999. -999. '-999. -999, ~999. 250 250 250 250 250 **~* FILE TR.A I [,,ER **** FILF B!A~E .' EDIT .001 S~RVICE : FLIC V~RSlO~ : O01~COl DATF : 94107/~:3 ~AX REC SIZE : ~.024 f"IbF TYPE : LO **** FILE HEADER **** FILE NA~E : EDIT .002 $ERVIC~ : F&IC V~RSlON : 001CO1 DAT~ ~ 94/07/~ ~X R~C,SIZ~ : ~0~4 FILM TYPE : LO FTLF NUMBER: 2 EDITED CURVES DeDth shifted and cl~mme~ curves for each pass in separate P~S$ NU~BER~ 2 DFPTH INC~E~ENT: 0.5000 FILE SU~M~RY LDWG TOOl,, CODE START DEPTH STOP DEPTH ....... " CiIRVE SHIFT D~TA - PASS TO PASS(MEASUrED DEPTH) ~ASEbINE CURVE FOR SHIFTS .......... FQUIVALEMT UNSHIFTED DEPTH PASE[,,IME DEPTH GRCH TDTP Tare Vertf:~¢at~,on Li. st~n~ :hlumberger Alaska Compu. tlnq Center 26-0CT-199,4 15:1,6 PAGE~ 88888,0 888 . 88890, ~1268:.5 11270,5 1125~,0 1125~,0 1124 .5 ~,1248.5 1.1~0~,5 tt206,5 11192,0 11193,5 1 117~,5 111.74,0 1~088'0 t3089,5 1 ~068,5 . 1. ~070,0 1~0~1.5 1..10J3,5 ~.0962'5 ~0964.0 10962,0 {0963,5 10939,0 10940,0 10882.0 ~0883.5 loe2e.$ 1.0829,5 ~o8z2.o ~,o~52.o lo754.5 20704.5 ].,0705.5 1, o7o3.s 10686.5 10688.0 ~o68~ 5 ~o67o:5 lo672.o 1,0663 0 2.0664.5 ~00:0 ~01.5 I0~.5 RE~A~KS: THIS FILE CONTAINS PASS #2 OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH AND PASS #2 SIGN TO PASS #1 SIG~. ALL OTHER TDTP CURVES WERE CARRIED .ITH THE SIGM SHIFTS. LT$ FORMAT DATA T~BLE TYPE ; CONS CN ARCO ALASKA INC. Company Name F~' P~UDHOE BAY Field Name WN DS 1-23 Well Name APIN 50-029-20854-00 API Serial Number Fi, 637' FNL & 550' FWL Fle~d },oeatio~ S~CT 6 Section TO~ 1ON Township R~N~ 15E Range COU~ NORTH SLOPE Countv S~AT A[.,ASK~ State or Province N~'rT USA NatioD WITU O JULIAN Witness Name SON 452954 Service Order Number i$ WaDe. VeriffCat,lon Listln~ :hlUmherger A].as~a Computing center 26-OCT-..!~, 994 TUN! VALU DEF~ ' PDAT ~S5 Permanent eatum 0 ~levatlon of Permanent Datum b~F bog ~easured From A~D WT 74, Absve Permanent Datum EKB FT 74, Elevate. on of Kelly Bushln~ EDF FT 73. Elevatlon o~ Derrick Floor ElevatiOn of Ground Level E~L FT ~0 TDD FT 11~52, Total.Depths- Driller BLI FT ~.280, Bottom 50~ X,terval TLI FT ~0665 To~ ln.~ Fluid Type DFT SEAWAtER/BORAx Drll~Oq Interval 'fLAB 1~.~0! 15-N0¥-92 Time 5ogoer at BOttom B~T DEGF 1~0, ,Bottom HOle Temperature TABLE TYPE ~ CU~V DEFI ,, D~PT DeDth SIG~ Sl. qma (Neutron caPture Cross section) TPHI TDT PorosltV SBHF Borehole $1qma - ~ar.detector SBHN Borehole $~gma - Near detector SIGC Sigma Correction $IBH Corrected Borehole Stoma T~AT Ration Total Near to Far counts SDS~ Standard deviation of SiGma BACW BacK,round CouDt Rates - Near Detector FBAC BacK,round CouDt Rate - Far Detector TCAN Total counts analvzed- near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCF~ Total capture Counts - far dectector T$CN Total Selected Counts - Near Detector T$CF Total Selected Counts - Far Detector IN~)D Inelastic count rate - near detector INFP Inelastic count rate - far ~etector G~CN ~amma ~av In Castn~ ~FN$ Surface Tension 26-0CT-~994 15:~,6 PAGE: DATA FOR~,,~AT SPECIF.~CA, TIUN RECORD TYPE R~P~ CODE YABUE 1 66 0 2 66 0 3 73 84 4 66 1, 5 66 6 73 7 65 11, 66 ~,2 ~ 66 0 14 65 ~T 15 66 68 16 66 0 66 .mmmmm~mmmm~m~mm#mm~m#mmmmmmmmmm ** SET TYPE.- CHAN ** N~ME SERV UNIT SERVICE API API APl APT FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ~BM CODE (HEX) D_,PT 54 O0 000 O0 2 1 4 68 0000 000 CU 459954 O0 000 O0 0 2 1 I 4 68 0000000000 SIG" TDTP TPHI TDTP PU-S 452954 O0 000 O0 0 2 1 1 4 68 SBHF TDTP CU 452954 O0 000 O0 0 2 I 1 4 68 SBHN TDTP CU 459954 O0 000 O0 0 2 i 1 4 68 SIGC TDTP Ct) 452954 00 000 O0 0 2 I 1 4 68 STB~ TDTP CU 45~954 O0 000 O0 0 2 1 I 4 68 T~AT TDTP 459954 00 000 O0 0 2 1 1 4 69 SDSI TDTP CU 452954 O0 000 O0 0 2 1 1 4 68 B~Cw TDTP CPS 452954 O0 000 O0 0 2 I 1 4 68 FBAC TDTP CPS 452954 O0 000 00 0 2 1 1 4 68 ICA~! TDTP CPS 452954 O0 000 O0 O 2 1 1 4 68 TCA? TDTP CPS 4.52954 oO 000 00 0 2 1 1 4 68 TCND TDTP CPS 459954 O0 000 O0 0 2 1 i 4 68 TCFD TDTP CPS 459954 O0 000 O0 0 9 1 1 4 6~ TSC~ TDTP CPS 459954 O0 000 O0 0 9 1 I 4 68 TSCF TDTP CPS 452954 O0 000 O0 0 2 1 1 4 68 I~]ND TDTP CPS 45~954 OO 000 O0 0 2 1 I 4 6R INFD TDTP CPS 459954 O0 000 O0 0 9 1 1 4 68 G~CM TDTP GAPI 452954 O0 000 OO 0 2 1 1 4 6~ TFNS TDTP LB 452954 O0 000 O0 0 2 1 1 4 6~ 0000000000 0000000000 0000000000 0000000000 0000000000 OO00OO0O0O ooonoooooo 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmmm~mmmmmmmmmmmm#mmm~mmmmmm~mmmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DaTa :hlumberger lasKa Comput n.. 26-0CT.1994 15:~.6 PAGE: 10 SBHN'T'DTP 5 .6~7 SIGC.TDTP $D$7 TD?P 1.182 BACK.TDTP TCAF:TDTP 6~,36.022 3~.057 TPHI.TDTP 3.155 $ I B t.I, T D T P 1.51.334 FBAC,~DTP 16174,063 TCFD.TDT. 161.1.925 XNFD'TDT~ D~PT 10665..000 $IG~;:TDTB 19.652 TpHI,TDTP SRH~:TDTP 51'922 SIGC'TD'TP 3.335 SIBH,TDTP SDSI.TDTP 0 81.5 BACK.TDTP 147.303 FBAC'TDTP TCAW.TDTP 59'3'?~297 TCMD,TDTP ~.72'68.340 TCFD'TDTP T..CF TDTP 1.189 406 INND.TDTP 1484 ~.~0 INFD-TDTP T~N~.TDTP 14601.000 38.862 7 683 4555.571 ]05.115 29.:443 6~.013 30.792 151.556 5303,321 SB~F TDTP TRAT~TDTP TCA~.:TDTP TSC~.TDTP GRCM.TDTP SBHF.TDTP TPAT.TDTP TCAN.TDTP TSCN.TDTP GPCH.TDTP 639 1978 352 1959.854 :-999,250 47.159 2'520 14960'81.1 2997,066 60¥313 END OF DATA ** **** FILE TR~ILE~ FILE ~A~E : EDIT ,002 SERVICE VERSION : 001C01 DATE : 94/07/13 M~X R~C SIZE : 10~4 FIL~ TYPE L~ST ~ILE : **** FILE HERDE~ F]'L~ NA~E : EDIT .003 $~RVlCE : FLIC VF~$ION : O01CO1 DaTF ~ 94/07/~3 MAX REC S~ZE : 1024 FILF TYPE : LO D~ST FILE F]LF ~EADER EDITED CURVES nepth shifted and el~pued curves PaS~ NUMBER: 3 DmFTH INCRE~E~T: 0.5000 FTL~ SUMMARY LDWG TOOL CODE START DEPTH TDTP 11273.0 for each pass 10665,0 separate files, '$ TaDe Verl. f!.catJon L~st~no :hlUmberger AlasKa Computlno Center 26-0CT-~,994 15."16 PAGE~ 11 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPT{4) 8ASELIME CURVE FOR SHIFTS bDWG CURVE CODE: GRCR PASS N0~BER: i ,BASE[,IME, DEPTH ~1~70,5 11~63,0 ~1~58,5 ~. 125~ 0 1~174 5 11135 0 11083 0 i 1003 0 10964 5 1, 0964 0 10941~5 10929 5 10916,5 1.0900,5 0~72.5 0870.0 ]_0813.5 I0807.0 10789.0 ]0784.5 ]0757.0 ~0705.5 ~.0676.0 ~067~.5 ~0~70.0 ~00.0 ----------EOUIVALEMT UMSHIFTED DEPTH----'----- GR CH 88 87 11258.0 11,230.0 11206.0 11174.0 10963,5 10941,5 10929.0 ~0900,0 10870,0 10829,5 10807.0 10785.0 1.0705,5 1067~.5 10670,5 1.00.5 TDTP ..~ 11270,0 11~6~.5 ~1257,0 1.,1193,5 1.1134,5 1.100~ 5 10964~0 10941,0 1.0916,0 10872.0 1.0813.5 10788,5 10757.0 10676,0 100.0 ~EMA~KS: THIS FILE CONTAINS PASS ~3 OF T~E TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT PAS~ #3 G~CH TO P~SS GRCH ,AND PASS #3 SIG~ TO PASS #1 SIGN. ALL OTHER TDTP CURVES ~ERE CARRIED ~ITH THE SIGM SHIFTS. $ bis FORMAT DATA :hlumberger ~,~as~.~ ¢omputln~ Center 26-0CT-1994 15:16 TUNI VALU DEF! Chi ARCO AL, RSKA, IMC. FN PRUDHOE BAY WN DS 1-23 ADIN 50-029-20854-00 FL 657' FN5 & 550' FWL S~CT 8 R ~ N ~ 15 E COUN NORTH SLOPE N~TI USA ~'ITM j JULIAN S0~¢ 452954 EDD F I" 0 APD FT 74. EKB FT 74. EDF FT E~L FT TVD ~T ~ [52. TL~ WT lob6 DDT ~EAWA~ER/BODAX TLAP 12:01 IL-NOV-92 B~T DEGF 120, Company Name Field Name Well Name ,APl Serial Number Field Location Section Township Range County State or Province Nation Witness Name Service Order ~lumber Permanent,datum Elevatlo~ of Permanent Datum ~Og ~easured From ve Perma · t Datu~ b nn Elevation of Kelly Bushina Elevation of Derrlc~ Floor Elevation of Ground Level, Total Depth'- Driller Bottom 6og Interval To Log Interval Drilling Fluid TYpe Time Logger at Bottom Bottom Hole Temperature TABt, E TYPR : CURV D~FI DF, pT Be STG. Sigma (Neutron Capture Cross section) TPHT TPAT SDST FmAC TCAN TCAF TCN~ TCFD T$C" TSCW I~NO TnT Porosity .orehole Sigma - far detector ~orehole Sigma - Hear detector Sigma Correction Corrected Bore~o]e Sigma ~atlon Total Near to Far counts Standard deviation of Sigma Back.round Count Rates - Near Detector Back.round Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total captt{re Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector Inelastic count rate - near detector '$ ?a~e verlflcatlon :hlumberger A],,aska Computing Center . . IN'FO Inelastic count rate - far detector G~CH ~amma Ra~ in Casing I~ENS Surface Tension DATA FORMAT SPECIFICATION RECORD ** ** SET TY, E 64EB ** TYPE REPR CODE VAbUE 1 66 0 2 66 0 3 73 84 4 66 5 66 6 73 7 65 8 6~ 66 12 13 66 0 14 65 15 66 68 16 66 1 0 66 DFP? FT 452954 O0 000 O0 0 3 ! 1 4 b8 SIGM TDTP CU 452954 O0 000 O0 0 3 1 1 4 68 TPH! TDTP PU-$ 452954 O0 000 O0 0 3 1 1 4 68 S~HF TDTP CU 452954 O0 000 O0 0 3 1 1 ~ 68 SPHN TDTP CU 45~954 O0 000 O0 0 3 1 1 4 68 STGC TDTP CU 452954 O0 000 O0 0 3 1 1 4 68 SIBH TDTP C~! 452954 O0 000 O0 0 3 1 1 4 68 TDAT TDTP 45~954 O0 000 O0 0 3 1 I 4 68 SDS! TDTP CU 452954 O0 000 O0 0 3 I 1 4 68 BACK TDTP CPS 452954 O0 000 O0 0 3 I I 4 68 FRAC TDTP CPS 452954 O0 000 O0 0 3 1 1 4 68 TCAN TDTP CPS 452954 ~0 000 O0 0 3 1 1 4 68 TCAr TDTP CPS 452954 O0 000 O0 0 3 1 1 4 68 TCND TDTP CPS 4-52954 O0 000 O0 0 3 1 I 4 68 TCFD TDTP CPS 45~9~4 ~0 000 O0 ~ 3 I 1 4 68 T~C~ TDTP CPS 45~954 O0 000 O0 0 ) ! 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o00 0000000000 0000000000 0000000000 0000000000 GO00000000 0000000000 o000000000 0000000o00 0o00000o00 000000000o :hlumberger AlasKa Compu, tinq Center 26-0CT-!994 1,5:16 PAGE~ NA:~'~ SERV UNIT 8~RVICE: APl AP1 APl API FILE NUMB NUMB 8iZE REPR PRDCE8$ I SC~ TDTP CPS 452954 00 O00 00 0 3 I I 4 68 0000000000 NND TDTP CPS 452954 O0 000 00 0 ] 1 1 4 68 0000000000 INFD TDTP CPS 452954 O0 000 O0 0 3 1 i 4 68 0000000000 GRCH TDTP GAPI 452954 00 000 00 0 3 1 I 4 68 0000000000 TENS TDTP GB 4!52954 00 . 000 00 0 i 4 68 0000000000 1¸4 ** DAT.~ ** DFP 1~.273'000 SI,,,t~,,TDTP 32.244 TPHI:'TDTP SBH TDTP 50:.463 SIGC.TDTP ~..820 SIBH:,TDTP SDS? TDTP 1.290 BACK.TDTP 204.819 FBAC.TDTP TCAF.TDTP 5861.7.~.0 TCND;..:TDTP ~5398.088 TCFDi:,TDTP T$CF.TDTP 630.563 INND.TDTP 1496.979 INFD-YDTP TENS.TDTP ~.575.000 END O~ DATA 45.464 SBHF.TDTP 0,666 TRAT..TDTP ~0.1.40 TCAN...TDTP 4094..656 TSCN.TDTP 268.259 GRCH,TDTP 45.300 2~06 19045:~4 ~83~.327 '99 ~250 **** FIL~ TRAILER FTLF NAME : EDIT .003 SERVICE : FLTC V~R$ION : 001CO1 DATF : 94/07/~3 FTL~ TYPE : LO LAS? FILE : **** FTLE HEADER FILF NA~E : ~DIT .004 S~RVICE : FLIC VERSION : OOlCOl DATE : 94/07/13 ~aX RFC SIZ~ : 1024 FIL~ TYPE : LO LAST FILE FTLE NUmBeR: 4 EDI?ED CURVES DePth shifted and cl~pPed curves for each pass ~n separate files, P~SS NUMBER: 4 DFPTH INCRE~EN'r: 0.5000 :hlumberger Alaska Comptltino Center 26-0CT-1994 15:16 PAGE: FIL~ SUMMARY I:,DWG TOOt, CODE START DEPT~ STOP DEPTH G~CH 11259,0 10665,0 TDTP I1~73.0 10665,0 # , CURVE SHIFT DAT~ - PASS TO PASS(MEASUrED DEPTH) ~ASELI~E CURVE FOR S~IFTS L~W~ CURVE CODE: ~RCH PASS NUMB~R~ ----------EQUIVALENT UN$MIFT~D BASELINE D~PTH ~8~.0 ~.1~62.5 ~1~5~.o ~120~ 5 ~1205 0 11190i5 1.1~74 ~ ~112] 5 ~1077 5 1100~ 5 10~63 5 1 0963 ~ ~0941 5 ~0915 5 10911 0 ~869.5 ~.0829,5 10812.5 108O7 0 10705:5 10704,5 10687,5 1.0676o0 ~0669, 100.0 $ ~CH TDTP 88888.0 88888.0 11~70,5 JI~62.0 I1~58.0 11208.5 11~08,0 11193,5 11182,5 11174.0 1,1124.0 11078.0 11001.5 10964.0 10963.5 10942,0 ~0916.0 10911.5 1087n.0 1.0870.0 10830.0 10813,0 10807.0 ~0705.0 10705.0 10688.0 10676,0 1067~.0 10670,5 101.0 100,0 ~E~ARK$: THIS ~ILE CONTAINS BORAX PASS #1 OF T~E TDTP. THE DEPTH CORRECTIONS S~OWN ABOVE R~FLECT BORAX PASS ~! GRCH TO BASE PASS $I CRCH AND BORAX PASS ~1 SIGM TO BASE PASS $1 SIGN. ALL OTHER TDTP CURVES WErE CARRIED WITH THE ~IG~ S~IFTS, $ LTS FORMAT DATA :S Ta~e Verl~lca. t~on LiSting :~lh~berger ~lasK Computln~ Center 26..0CT'1994 15:16 T~B]~E '.rYP~ : CONS T U ~ ! V A t, U A~CO ALASKA INC. FT FT FT FT FT FT FT CN APIN Fb TO~N COU~ STAT P~AT L~F A~D E.~F TDD gl, I TLI DFT TLAP PRUDHOE BAY 0-02g'20854-00 637' FNL & 550' FWL :"ORTH SLOPE ALASKA USA O JULIAN 452954 1~280, Company Name Field Name Well Name API Serial Number Field Location Section Township Range Couht, v State or Province Nation. Witness Name Service Order Number Permanent datum EleYat~on ot Permanent Datum Log ~easured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derric~ Floor ElevatioD of Ground Level Total DePth- Driller Bottom bog Imterval 10665, Top Log Interval SEAWATE~/B0~AX Drilling Fluid Type 12:01 I5-NOV-92 Time Logger at Bottom B~T DEGF 120. Bottom Hole Temperature T~BLE TYPF : CURV DEFI ...... ept h SIG~ io.~a (Neutron Section) TPH~ TDT Porosity S~HF Borehole Sigma - far detector SIGC SIO~ T~AT B~CK F~AC TCAW TCAF TCN~ TCFD T~CW TSC~ INN~ Borehole Sigma Near detector Sigma Corre~tio~ Corrected Borehole Sigma Ration Total Near to. Far counts Standard deviation of Sioma Back,round Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector Total counts analyzed - far detector (TDTP) Total caDture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selecte~ Counts - Far Detector Inelastic count rate - near detector IS Ta~e Verification I, istin~ ~hlumberger AlasKa Co~put.in~ Center DEFI NFD Inelastic count rate - far detector ~CH Gamma Ra, v tn~,.Ca,,slng T~NS Surface Tension DATA FORMAT SPECIFICATION RECORD ** SET T¥~E - 64EB *~ T'~PE REPR CODE VALUE 66 0 i 66 0 3 73 84 4 66 5 66 6 73 7 65 8 68 0.5 9 65 11 66 t2 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 mmm~m~mmmmmmmmmmmmmmmmmm~mmmm $IG~ TDTP TPHT TDTP SBHW TOTP SBH" TDTP STGC TDTP $IBw TDTP T~AT TDTP SDS! TDTP B~CK TDTP F~AC TDTP TCA~ TOTP TCAw TDTP TCND TOTP TCF~ TDTP TSC~ TDTP CU 452954 O0 PU-$ 452954 O0 CU 452954 O0 CU 452954 o0 CU 452954 O0 CU 452954 00 459954 O0 C~ 452954 O0 CPS 45~954 O0 CPS 45~95~ O0 CPS 452954 ~0 CPS 452954 00 CPS 45~954 O0 CPS 45~954 O0 CPS 45~954 O0 000 O0 0 4 000 o0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 n 4 000 O0 0 4 000 O0 0 4 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 6~ 0000000000 1 1 4 68 0000000000 1 i 4 68 0000000000 :hlumberger Alaska COm utin~ Center 26-0¢?-.19g.4 PAGE: NAMer SF, RV UNIT SERVIC~ API API ADI AP1 FILE NUMB NUMB SIZE REPR ID ORDER ,~ LOG TYPE C~A, SS MOD NUMB SAMP EGE~ CODE (H~X) TSCF TDTP CPS 45~954 O0 000 O0 0 4 1 ~ 4 6~ 0000000000 INND TDTP CPS 4!:59,954 O0 000 O0 0 4 i 1, 4 68 0000000000 INFO TDTP CPS 459,954 O0 00() O0 0 4 I I 4 68 0000000000 (;~CH TDTP GAPI 45~954 O0 000 O0 0 4 1 1 4 68 0000000000 ..... ~ T 1 ~,N,. DTP LB 452954 O0 000 O0 0 4 1 1. . 4, 68 0000000000 DATa ** D~PT 1~273.000 SI~M.TDTP 34.157 TPHI'TDTP 40'~87 SBHF.TDTP : . H:~T TP 6~.917 TRAT.TDTP SSH~ TDTP 51 455 SIGC:,TDTP 3.054 SIB D' ~DS,T.TDTP 1.297 BACK~TDTD 185.5~1 FBAC. TDTP 55.674 TCAN.TDTP fCAF.TDTP 6268,-342 TCND.TDTP ~5857.~89 TCFD,.TD~P 49,55 636 TSCNoTDTP TSCFoTDTP 650.404 INND,~TDTP ~694.643 INFD*TDTP 304~4~ GRCH°TDTP TENS.TDTP 1400-000 ~? ~0653.500 SICM..TDTP 17.00~ TPHI..TDTP ~5.0~0 SBHF.TDTP H~TDTP 98.3.07 SIGC.:TDTD 0.'I18 SI~H.~DTP 141.4 6 TRAT.TDTP SDS~.TDTP 0.467 BACK.TDT~ .140.~46~ FB~C:~:TDTP ~ ~0 ~CAN.TD~P TCAF.TDTP 7571.B77 TCND°TDTP 9996.459 TCFDi. TDTP 42.~ ,~.~ 7 TSCN.TDTP CF.TDTP ~557'612 INND.TDTP 1516.97~ INFD.'TDTP ~90.,919 GRCH.TDTP TEN$.TDTP 1450.G00 ** E~D OF DATA ** 451. 938 2,767 99,433 '999'250 72.965 I. !06 1~161i 96 ~501 25 78.000 **** FILE FTLE NAME SFRViCE VERSION M~X R~C $IZ~ FIL~ TYPE LnST FIt. E **** FILE F!bF NAME SERVICE V~RgIO~ D~IF ~X RFC F'TLF TYPE mRAILER EDIT .004 FLIC O01COl 04/07113 1.024 LO HEADER **** EDIT .005 O01CO1 94/07/13 1024 LO :hlumherqer Al. as~a ComPuting center 26-0CT-1.994 15:16 PA~E: 19 EDITED CURVES Depth shifted and clipped curves for each Pass ~D separate P~S8 ~{J~B~R: 5 DEPTH ~NCREMENT: 0,5000 LDWG TOOL CODE START DEPTH STOP DEPTH GRCH X1259,0 ~.0665,0 TDTP ~URVE S~IFT DATA.- PASS TO ~ASS(M~Asu~ED DE~TH) 8ASESINE CURVE FOR.SHIFTS ~o~c Curve con£~ PASS ~IIMBER~ BASELINE DEPTH )1227 5 11226,5 ~1205 5 11205,5 ~ 11,90,0 11193.5 ~1185,5 ~1003,0 ~.1003,0 ~094~,5 ~0~4~.5 ~0870,0 ~0870,0 ~0870,0 ~.0830,0 ~0830,0 ~0776,0 ~0705,5 10705,5 ~0705,0 ~0705,0 ~0~7~,0 10672,0 10670.0 10670,5 10o.0 10o.5 100.0 '--'------EQUIVALENT UNSH1FTED DEPTH---------- GRCH TDTP, THIS FILE CONTAINS BORAX PASS #~ OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT BORAX PASS #2 GRCH TO SASE PASS #1GRCH AND BORAX PASS #2 SIGM TO BASE PASS ~1'IGMSIG~sH~FTS,AhL OTHER TDTP CURVES WERE CARRIED WIT~ THE $ iS TaPe VerifAiCata~On L~stin~ ~hlumberqer /.ask Compt]t n0 Center 26-0CT-1.994 15:16 C~ ARCO ALASKA INC. FN P~UDHOE W~ DS APIN 50~029-20854,09 FL 63 ' FNL & 550 S~CT B ToWN R~.N~ COUN NORTH SLOPE STAT ALASAA NAT~ USA WIT~ J dIJBIAN SON 452954 APD FT 74, E~B FT 74. EDF FT 73, E~L ~T 40 T D FT BLI FT ~1280., D~ S~AWA~ER/BORAX TLA~ 12~01 15-NOV-92 BHT DEaF 120, FW5 Field Name Well Name &PI S her erlalNum Sect!Fge~o~°Ca'tl°n ?ownship Range County State or Prov~nce Nation Witness Name Service Order Number Permanent datum Elevat on of Permanent Datum Log ~easured From ADore Permanent Datum Elevation ot KellY BushinO Elevat$on o~ Derrick Floor Elevatlon o~ Ground Level Total DePth- Driller Bottom Loq Intervai Top Lou Interval Drilling Fluid ~ype Time Loo~er at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEF! SIGM TPHT STGC SIBH TPAT SDST BACK FBAC TCAN TCAF TCND T~FD T~C~ T$CF i~ND SlOmm (Neutron Capture Cross section) TDT Porosity Borehole Sigma - ~ar detector Boreho]e Sigma - Near detector Sion, a Correction Corrected Borehole SlQma Ration Total Near to_.Far counts Standard deviation of Sigma Rac~oroumd Count Rates - Near Detector BacKgrOUnd Count Rate - Far Detector Total. counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total caoture Counts - far decree%or ~otal Selected Counts - Near Detector Total Selected Counts - Far Detector ~nelastlc count rate - near detector Tare Ver~,~,l,,catioD Llst, in~. 26-0CT-~,994 15:16 rhlU~ber~er A,l, as~a Comput,inc~ Center INFO Inelastic count rate - far detector GRCH ~amma Ray ,i,n~Castng TFNS ~ SurfaceTension PA~E: ** DAT~ FORMAT SPECIFICATION RECORD ** SET TYPE 64E. ** TYPE REPR CODE VALUE ! 66 0 2 ~6 0 3 73 4 66 5 66 6 73 7 65 . 9 65 1~ 66 12 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET ID $IG~ TDTP CU TPHT TDTP PU-S SBHF TDTP CU $~M~ TDTP CU 8IGC TDTP CU $IBH TDTP CU T~4T T~TP S~$I TDTP CU B~CE TDTP CPS F~AC TOTP CPS TC4F TDTP CPS TCAF TDTP CPS TCND TDTP CPS TCFD TDTP CPS T$C~' TOTP CPS TYPE - CHAN * ORDER # LOG 5 954 O0 452954 O0 45~954 00 452954 O0 452954 O0 452954 O0 452954 O0 452954 O0 45~9~4 O0 45~954 O0 452954 O0 452954 O0 452954 00 45~.954 O0 452954 O0 452954 O0 , ~Pl AP1 PI FII, E N B NUMB TYPE CLASS MOD NUMB SA~P ~bEM CODE (HEX) O0 O0 1 1 4 68 0 000000 000 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 1 4 000 O0 0 5 1 1 4 000 O0 0 5 1 1 4 OOO O0 0 5 1 I 4 000 O0 0 5 1 I 4 000 O0 0 5 1 1 4 000 O0 0 5 1 I 4 000 O0 0 5 I I 4 000 O0 0 5 1 I 4 000 O0 0 5 1 1 4 000 O0 0 5 I I 4 000 O0 0 5 1 I 4 000 O0 0 5 1 1 4 000 O0 0 5 1 1 4 68 68 68 68 68 68 68 68 68 68 68 68 68 GO00000000 0000000000 O00000000n 0000000o00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 iS Tame Verlf~,cat~,on bist,{ng :hlumbergerAlaska Computin~ Center NAME SERV UNIT 8EP'VICE API API API API FILE NUMB NUMB SIZE REPR PRUCES8 . . ID ORDER # LOG TYPE CLASS MOD NUMB SA)~P ~LEM CODE TSCF :TDTP CPS 45~954 O0 000 O0 0 5 1 1 4 68 O000000000 INNS TDTP CPS 452954 O0 000 O0 0 5 1 I 4 68 0000000000 INFD TDTP CPS 452954 O0 000 O0 0 5 1 i 4 68 0000000000 G~C~ TDTP GAPI 45~954 O0 000 O0 0 5 I 1 4 68 0000000'000 T~NS TDTP DB 45~9~4 O0 000 O0 0 5 . 1 1 4 68 0000000000 ¸22 ** D~T~ ** DEPT, 11273*000 Si~:' TDTP 30i724 TPHI,TDT~ $,H~.TDTP 52,.3~1 8I~ :TDTP 4 ~57 $IBH,'.TDTP SDS~,TDTP . 1,254 BACK.,TDTP 195 670 FBAC:,TDTP TCAF,TDTP 5'8~6"143 TCND,TDTP ~4597,.576 TCFD,.TDTP TSCF,TDTP 635,6~2 INND.TDTP 1428,764 INFD,TDTP TEN$.TDTP 1,480o000 ** EMO O~ DATA ** ~.605,608 999,250 **** FILE TRAILER **** FILM NAME : EDIT .005 SERVICE : FDIC VERSION : O0).CO1 D~TE : g4/07/~.3 M~X REC STZE : ~024 FIDE TYPE : bO **** FILE NEADER **** FILE NA~E : EDIT .006 SFRVICE : FDIC VERSION : 00lCD1 DAT~ : 94/07/13 M~X REC SIZE : ~.024 FIL~ TYPE : bO Flb~ HE~DER AVERAGED CUPVE$ Compensated Neutron: Arithmetic averaoe of edited passes for all curves, Pulsed Meutron~ Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static Dasellne sasses for all otBer curves, DFpTH 1MC~E~ENT 0,5000 TaMe Ver~,.fication List].ng ,'hlumbergerA. las~a Computin~ Center 26-0CT-1994 15:16 PAGE: ¸23 # PASSES INCLUDED iN AVERAGE 5DWG TOOL CODE PASS NUMBERS TDTP 1, ~, ~E~ARKS: E A~ITHPETiC ~VERAG~ OF THE T~REE PASS WAS COMPUTED AFTER ALI, DEPTH CORRECTIOMS WERE $ LIS FORMAT DATA CN ARCO ALASKA INC,' F~ PRUDHOE BAY WN DS 1-23 API~ 50-029-20854-00 SEC~ 8 TOW~ iON COUW NORTH si, OPE STAT' ALASKA NATY USA WIT~ J JULIA~ $~N 452954 PDAT ~IS.h L~F APb FT 74, EKB FT 74, EDF FT ECL FT 4O BLI ~T TLI WT ~0665, DFT SEAWATEr/BOrAX Trna, l~:O1 15-NOV-92 8~T ~EGF ompaD~ Name ~leld, ame We~l Na~e AP Serial Number Field LocatloD Section Township Range County State or Province Nation Witness Name Service Order Number Permanent datu'm Elevation of Permanent Datum Lo~ ~easured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation oZ Ground Level Total Depth - Drill. er Bottom boq I~terval To~ Bo~ Interval Dr llin~ Fluid Type Time hocker at Bottom Bottom hole Temperature TYPE ~ CUPV DFpT Depth $!G~ Sigma (Neutron Capture Cross Secti6n) TPHY TDT Porosity SBH~ goTebo].e Sigma - far detector S~H~ Borehole Sigma - Near detector TaPe Verification tist~,.ng lhlumbe,r, ger Alaska ComPUt~,,n~ Center DEF! !C $1om~ Correction YBH Corrected Borehole S{],qma TRAT ,ation Total Near to, Far counts SDS! Standard deviation of Sinma B~C~ BacKground Count Rates - Near Detector FA,AC BaeKoround Count Rate - Far' Detector TCA~! Total counts analyzed'-'near deteCtor..(TDTP] CAF Total counts analyzed - far detector (TDTP) CND Total capture counts - Near detector TCFD Total, capture Counts - far dectector TSC~ Total Sciected Counts- Wear Detector T$C~ Total Selected Counts - Far Detector IMND Inelastic count rathe - near detector CH Gamma Rav in. Cas no T~N8 8u, rface Tension PAGE~ ¸24 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 6~EB ** TYPE REP:R CUDE. VALUE 1 66 0 2 66 0 3 73 84 4 66 5 66 b 73 7 65 8 68 9 65 FT 1! 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAM ** .... '"'"'"'";'"' ....... .............. ...... 3; .......... ......... ...... Nt~E S~RV UNI SERVIC~ A I AP1 APl A IFILE N B NUmB SI REPR ~O ESS ID ORDE~ # LOG TYPE CLASS MOD ~!U~B SAMP ELEM CODE (HEX) '5 PT~ ...................FT 4529~''''''''3'~4 O0 0 ............ O0 0 ~ .............. 1 I ' ....... 4 ~ ..........0000003~3''' STGU PNAV CU 45~954 O0 000 O0 0 6 1 1 4 6~ 0000000000 TPHT PNAV PU-S 45~954 O0 000 O0 O 6 1 1 4 68 0000000000 hlumberger lasKa Corn uting Cemter 26-0CT-1994 15:1.6 PAGE: ORDER APl API AP1 APl FiLE NUMB NUM~ $IZ~ R LOG TYp~.CL,~S8 MOD ~U~B SA~P ELE'M C 000 O0 0 6 ! 1 4 000 O0 0 6 1 1 4 000 O0 0 6 1 I 4 000 O0 0 6 1 1 4 000 O0 0 6 1 1 4 000 O0 0 6 1 I 4 000 O0 0 6 1 1, 4 000 O0 0 6 1 1 4 000 O0 0 6 1 1 4 000 O0 0 6 I 1 4 000 O0 0 6 1 1 4 000 O0 0 6 i I 4 000 O0 0 6 1 1 4 000 O0 0 6 1 1 4 000 O0 0 6 1 1 4 000 O0 0 6 I 1 4 ~,~c ~v c~, 4~~ oo SIBN PN'AV Ct,:) 452954 O0 $OST PNAV CU452954 O0 TeA" P"~V CPS 45~9n" O0 TeND PNAV CPS .452954 O0 INND PNAV CP6 452954 O0 gPk PROCESS ODE (HEX) 68 0000000000 69 0000000000 68 0000000000 68 0000000000 68 0000000000 68 000:0000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 oo ooo oo o 6 ~ ~ 4 ~, .to ooo o.o o ~ ~ ~ 4 ~ ,ooooooo.~.o.o. 2¸5 ** DATA ** DEPT. 11273 SRH~.PNAV 50 SDSI.PNAV 1 TCAE.PN~V 6016 T$CF.PN~V 648 TEN$.PNAV 1571 000 762 .317 .778 * 349 ,510 DEPT. 10665.000 SBHN.PN~V 51.658 SDST.PNAV 0.846 TCAF.PN'AV 5936.~54 T$CF.PNAV ~208.656 TEN~.PNAV 1441.522 ** END OF DATA ** SlGM*PNAV 33.865 TPHI:'PNAV 49 128 SBHF.PNAV $IGC,.PNA. V 2.461 $iBH,PNAV 61:349 TRAT.PNAV BACK.PNAV 1.64.347 FBAC.PNAV 85.198 TCAN.PN~V TCND.PNAV 157~4.512 TCFD.PNAV 422~.158 T$CN.PNAV INMD'PNAV 1551.599 INFD.PMAV 285.852 GRCH.PNAV $I~M.PNAV 20.3218 TPHI..PNAV 29.~19 SOHF.PNAV SIGC.PNAV 2.895 $IBH.PNAV 61.550 TRAT.PNAV BACK.PNAV 135'5~0 FBAC.PNAV 29.85] TCAN.PNAV TCND.PNA¥ 17223.9~1 TCFD.PNAV 5172.881 TSCN.PNAV INND.PNAV 1487.521 INFD.PNAV 29~.222 GRCH.PNAV 44,434 3,036 19473.730 1943:768 -999,250 44.922 2.495 14813.318 3015.932 51.750 **** FILE TRAILER **** FILE NA~E : EDIT ,006 SERVICE : FLIC VERSION : O01CO1 DATE : 94/07/13 MAX RFC SIZE : 1024 FILE TYPE : LO L~ST FILE ~ :hlumberger AlasKa Computing Center 26-0CT'1994 15:16 **** FILE HEADER **** FILE NA~E ~ EDIT ,007 S~IRVICE : {~LIC V~RSION : 001 0 DaTE : 04 /13 L~ST FILE : FIL~ NU.~BER 7 CURVES Curves and 100 header data ~or each Pass in ~seParate PASS NU~BER~ ~ D~PTH INCRE~iENTI 0 5000 # FILM SUMMARY VENDOR TOOL CODE START DEPTH .......,.... D.. I1~90,5 LOG HEA~ER ~ATA STOP D~PTH DATE LOGGED: SOFTWARE VERSION~ TI~E LOG~E~ ON BOTTOm: TD DRILLER (FT): TD LOGGER(FT): ~OP bOG INTERVAL (FT): . ~OTTO~ LOG INTERVAL CFT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL ST~ING (TOP TO BOTTOm) VENDOR TOOL CODE TOOl., TYPE TDTP OLLA~ LOCATOR iles raw bacl<oreund Pass in last, 10665.0 11280.0 1800.0 NO TOOL NUMBEP CAb U~ 27~ TDTP TDTm TDTP TDTP TDTP $ AUXILLIARY MEASUREMENTS ATC 64~ THERMAL DECAY TIME TND PB 78 THEPMAL DEC~Y TIME TNC P 50 THERMAL DECAY TIME TNG P 21 AIIXIhLIARY MEASUREMENTS AT~ 160 BORENOLE A~D CASING DATA OPEN MOLE BIT SIZE DRILLE~$ CASING DEPTH LOGGERS CASING D~PTH 12,250 10548.0 RO~EgOLE CONDITIONS FLUID TYP~: FLUID DENSITY (t,B/G): SEAWATER/BORAX Tape Yer~ificatlon ~,lst~,,no :hlU~,ber~ger AlasKa Comput~,.ng Center # BOTTS~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEV'EL F'LU~D RATE A,T WE/,LHEAD W~T~R CUTS GAS/OIL RATIO: CMO~E NEUTRON TOOL TOOL TYPE (EP!THE~MAL OR THERMAL): M~TRIX~ MATRIX DENSITY: HOLM CORRECTION (IN): ObUE[~INE COUNT RATE NORMALIZATION iN OIL ZONE ~TOP NORmALiZING WINDOW BASE NORMALIZING WINDOW B~UELINE COUNT RATE SCALES SET BY'FIELD ~NGI~EER FAR COUNT PATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT R.AT~ bOW SCALE (CPS): NEAR COUNT RATE HIGH $CA~E (CPS): TO05 STANDOFF' TIED INTO BHC DATED 11-23-8~. ~ROCEDURE: :t20.0 THERMAL SANDSTONE 2.65 1. DISPLACED WELL WITH 500 BBL$ S~AWATER & 5 BBL$/MIN .[~OG B,~S~ PASS NO ! WHILE PUMPING ~.5 BBL$/MIN_$EAWATER. ~.LOG BASE PAS~ NO'2 WHILE PUMPING ~.5 BPS SEAWATER. 4. SWITCH OVER TO DORAX SOLUTION AND LOG BASE PA~S NO.3 (~ATE BU~PED TO 5BP~ ...SEAWATER ACROSS PERF$.) . TO'iA~ OF 600 BBL$ SEAWATER WAS PU~PE~ ~: DISPLACED 180 BBLS BORA~ {7LBS/BB~) W~H DEAD CRUDE. 6, LOG BORAX NO. 1 AFTER 40 BBLS OF BORAX IN FORMATION. ONE TUBING VOLUME : 270 BBLS. 7. LOG BORAX PASS NO. 2 AFTER 94 BBLS OF BORAX IN FORMATION. (TOTAL BORAX IN FORMATION aFTER LOGGING = 1~0 CONCL[~SION: NO CH~N~EL IS SEEN UPWARD FRO~ TOP RERFS TO GOC. $ L?S FORMAT DATA I~B~,E TYPE : CONS TUNT VAI.,U DEFI C~,' A~CO ALASKA INC. Company ~,ame FN PW~DHOE BAY Field 5~ame :hlumberqer las~a Comput ng Center 26-0CT-1994 15:1.6 PAGE~ 28 TUNI VILU DEFI , W~ DS 1-23 API~ 50-029'20854-00 FI, 637' FNL & 550' FWL SKCT TO~ iON COD~ NORTH SLOPE STAff' AbASKR SON ~5~UblAN954 PDAT NSL EPD FT APb VT 74, E~8 FT 74, EDF F~ E~L ~T ~0 TDD FT 11~52. BLI FT 11280. TI.,I FT ~0665 DFT SEAWAtEr/BORAX TLAP 1~:01 15-NOV-92 B~T DEGF Well Name APl Serial Number Field Location Section Townshi~ Range County State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datu~ bog ~easured From ~bove Permanent Datum ~levat~on of KellY Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth- Driller Bottom 6o~ Interval TOD LOg Interval Drlllln~ Fluid Type Time Logger at Botto~ Bottom Hole Temperature T~B~LE TYPK : CU~V DEFI STGu Slama (Neutron Capture Cross section) TPHI TDT Porosity SRH~ Borehole SJ. gma - far detector SRHN Borehole St~ma - Near detector SIGC Siama Correction $IB~ Corrected Borehole $iqma TRAT ~atlon Total Near to Far counts SDSI Standard deviation of Sl~ma BAC~ Backoroumd Count Rates - Near Detector FRAC BacKground Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector T~C~ Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector I~Kn Inelastic count rate - far detector TKNS Surface Tensio~ £S ,~ap.e veri, f,,~,.cation Listin<~ :hlumberger AlasKa ComputinO Center 26-0CT-~,994 15:I6 P'A~E~ ** ~ATA Ft]R~AT SPECIFICATION RECORD ** ** SET TYPE - 64EB **. TYPE REPR CODE VA~UE I 66 0 2 6:6 0 5 66 7 65 11 66 1,2 13 66 0 14 65 Fi 16 66 0 66 , ** SET TYPE -,CHAN ** NAME SERV UNiT SERVICE API API APl AP1 FIt, E NUmB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CbA$S MOD NUMB SAMP EbEM CODE (HEX) DEPT FT 452954 O0 000 O0 0 7 1 1 4 68 SIG" PS~ CU 452954 O0 000 O0 0 7 1 1 .4 68 TPHI PS~ PU 452954 O0 000 O0 0 7 i I 4 68 SBH~ PS! CU 452954 O0 000 O0 0 7 1 I 4 68 SgH~! PS! CU 452954 O0 000 O0 0 7 1 ~ 4 68 S~GC PS! CU 452954 O0 000 O0 0 7 I 1 4 68 $IBN PS1 CU 452954 O0 000 O0 0 7 1 1 4 68 TRAT PS! 452954 O0 000 O0 0 7 1 1 4 68 SDST PS~ CU 452954 O0 000 O0 0 7 I I 4 68 B~CK PS~ CPS 452954 O0 000 O0 0 7 1 i 4 68 EMAC PS~ CPS 452954 O0 000 O0 0 7 1 1 4 68 TCAN PS] CPS 452954 O0 000 O0 0 7 1 1 4 68 TCA~ ~3~. CPS 452954 O0 000 O0 0 7 1 I 4 68 TCND PS! CPS 45~954 O0 000 O0 0 7 1 1 4 68 TCED PSi CPS 45~954 O0 000 O0 0 7 1 1 4 68 T~CN PS1 CPS 45~954 O0 000 O0 O 7 1 1 4 68 T$CF P$~ CPS 45~954 O0 000 O0 0 7 1 1 4 68 I~ND PS1 CPS 452954 O0 000 O0 0 7 1 I 4 60 I~FD PS1 CPS 452954 O0 000 O0 0 7 1 1 4 68 TENS PSi LB 452954 O0 000 O0 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o0o 0000000o00 0000000000 0000000o00 0o00000000 0000000000 0000000000 000000000o 0000000000 0000000000 0000000000 ooooooonoo oooooooo0o ooooooonoo mmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmm [8 Tape Ver,lflcat~on Listinq .-hlumberger AlasKa Computlnq Center * * D ,~ T A ,, DEPT. SDSI:PS1.. TCAF.PS1 TSCF..PS1 26'0CT-11994 15:16 D~pq" SDS.]:.:, PM 1 TSC~. PS 1 0'360 BACK:,PSi 11 FBAC,PS 14539,850 TCND:i:,:PSI 20360,836 TCFD'PSI 2968'51[:9 INND*.PSI 1523.121 INFD..PSI. 53 793 SIGC~PS1 ~,942 96T4,?03 TCND;~PSI i~679 320 TCFD:iiPS1 1963.540 INND'PSI ** END O~ DATA ** 61.88 TRAT.PS1 21.988 TCAN.PS~. 7801~..264 TSCN.PS1 302'366 TENS,PS1 1,:732 sBHF.PS1 4.138 TRAT,PS1 0-558 TCAM,PS! 6~ 6~:743 TSCN,P$1 00,.540 T~NS,PSI 44.946 1.796 26118.008 5332',366 1060.000 91 o 154,493 1.405.000 **** FILE TRAILER **** FILF NAUE : EDYT ..007 SERVICE : FLIC VERSION D~TE : 94/07/13 MAX REC SIZE : 1024 FthE TY~E : LAST FILE : **** FILE HE~DER **** FILF NA~E : EDIT ,008 SERVICE : VERSION : 001C0! D~TM : M~X REC SIZE : 10~4 FILE TYPE : LO L~ST FILE : FILE READER FTLE NUmBeR 8 RaW CURVES Curves and loq header data for each DaSS in seuarate PR$$ ~U~OER: 2 DEPTH INCREMENT: 0,5000 FTb~ SUMMARY VEWDOR TOOL CODE START DEPTH STOP DEPTH ............. i-; ........ . ........ D 1 2.0.0 10649,0 hOG HEAOE~ DATA files! raw bacKoround Oass in last fi :hlumbetger AlasKa ¢omPut.,.tna Center 26-0CT-~[994 15:16 .PAGE: DATE hOGtiE, : SOFTWARE VERSION TIME LOGGER ON BOTTOF,: TD DRILLER TD LOGGER(FT) TOP LOG INTERVAL (FT): B:OTTO~ bOG IMTKRVAL LOGGING SPEED (FPHR) ...... DEPTH CO~I'rRoI, .,J~.ED ,,ES/NO) .,1 32,6 I S- OV'92 ~145~.0 10665O 1,1280:0 1800.0 TOOL STRING(TOP TO BOTTOM) VENDO~ TOOL CODE TO05 TYPE TDTP TDTP TDTP TDTP TDTP TDTP $ BOREPOLE AND CASING DATA OPEN ~O[,E BIT SIZE fiN): DRILLERS CASING DEPTH (FT3~ LOGGERS CASING DEPTH T005 CO~LAR LUCATOR CAb 1.I8 2~6 AUXILLIARY ~EASURE~ENTS ATC 644 THERNAL DECAY TIME TND PB 78 THERMAL DECAY TI~E TNC P 50 THERMAL DECAY TIME TNG P 2,! 250 ROREHOLE CONDITIONS FLUTD TYPE: FLOID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) BOTTO~ HOLE TEmPERATUrE (DEGF) FGUID SALINITY (PPN3: FLUID RATE AT WELl, HEAD WATER C~ITS (PCT): GAS/OT~ RATIO: CHUTE (DEG): SEAWATER/BORAX 120.n ~EUTROS TOOL TOO[, TYPE (EPITHE~MA5 O~ THERMAL): M~TRIW DENSITY: HOLE CORRECWION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW RASE NORMALIZING WTNDOW (FT): Pht!Et, INE COUNT RAT~ SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)~ FAR COUNT RATE BIGH SCALE (CPS): NEAR COUNT RATE LOw SCALE ~EAR COUNT RATE HIGH SCALE (CPS): TOOL STA~'~DOFF :S Tape YerJ,,flcatlon List~n,a, :hlu~,~erger Alaska ComptltlnO Center # TIED INT[] BHC Dar,...D'E" 11,-~3-82. ! DiSPI..,A..ED WELL WITH 500 FBI.,5 SEAWATER & 2,LOG BASE PASS NO.1 WHILE PUMPING 2.5 BSLS/MIN SEAWATER. 3.hOG BASE PASS NO,2 WHILE PO~PING 2.5 BP~ SEAWATER.. 4. SWITCH OVE~ TO BOR.AX SOLUTION AND.. LOG HA. SE PASS (RATE BU~PED TO 5BP~ ...SEAWATER ACROSS PERFS') o,., TOTAL OF 600 BBL$ SEAWATER WAS PU~PED. 5, DISPLACED ~80 BBL$ BORAX (TLB$/BBb) WITH DEAD CRUDE. 6..LOG BORAX NO:. ~ AFTER 40 BBLS OF BORAX IN FORMATION, ONE TUBING VOLU~E = 270 BBLS. AFTER 94 BBL$ OF BORAX 'IN 7. LOG BORAX'~AS$ NO 2 ' FORMATION, (TOTA~ BORAX IN FO~.ATION AFTE~ 50GGIN~.~ 130 BBbS) CO N'¢LU$ ! O~: . $ FORMAT TABLE ~¥PE : CONS TUNI VALU DEFI ....... ARCO AbASKA INC. PRUDHOE BAY WN DS 1-23 API~~ 50-029-20854-00 Fi, 637' FNL & 550' FW~ TO~ R~NG 1hE COU~ NORTH St, OPE STAT ALASKA Nat! USA W?T~ J JULIA~ SON 452954 PDAT L~F APD FT E~S ~T 74, EDF FT 73, E~L ~T TDD FT 1~452. TLI FT DFT SEAWATER/BORAX TLA~ 1~:0! 15-NOV-92 B~T DEGF d Name Well Name ~P'I Serial Number Field Location Section Township ~ange County State or Province ~ation Witness Hame Service Order Number Permanent datum Elevation of Permanent Datum tog ~easured From aDoYe Permanent Datum Elevation of Kelly Bushing Elevation of Derric~ Floor Elevation of Ground Level Total Depth - Dr~ller Bottom 6oq Interval Top 5o~ Interval Drilling FlUid Time bo~ger at Bottom Bottom Hole ~emperature 1, ucherger A,~,as~ ComPutin~ Center .. Z6 0¢T-1,994 15:16 TYPE : CUl~V DEFI D~PT Depth STG~ Siama (Neutron Capture Cross section) TPH! TDT Porosity SSHF Borehole Sigma -far detector $B}{N 8orehole Sigma - Near detector S!GC Sigma Correction SIB. Corrected Bo~ebole~ S~,gma T~AT Ration Total Near to Far coUntS SDSI Standard deviation of Slgma BACK BacKground Count Rates - Near Detector FBAC BacKground Count Rate ~ Far Detector TCA~ Total counts analyzed - near detector TCAF Total counts analyzed.- far detector (TDTP) TCND Total. capture cotlnts - Near detector TCFD Total'capttlre Counts - far dectector TSCN Total Selected Counts.- Near Detector T$CF Tota. i Selected Counts - Far Detector I~ND Inelastic count rate - near detector INFD Inelastic count rate - far detector TFN8 Surface Tension ,. PAGE: DATA FORMAT SPECTFICATIO~ RECORD ** SET TYPE - 64EB TYPE REP~ CODE 1 66 2 66 0 3 73 ~0 4 66 5 66 6 73 7 65 8 68 0,5 9 65 11 66 12 1~ 68 1) 66 0 14 65 15 66 68 16 66 1 0 66 :hlun berger Alaska Co~putin~ Center 26-0CT-1994 15:t6 PAGE: ** SET TYPE - CMAN ** , ~MM SERV UMIT SER¥~CE ID ORDE~ # FBAC P$2 CPS 452954 TSC~ ~$~ ¢P$ 452954 INNO PS~ CPS 452954 APl AP! AP1 APl FILE NUM. B NUmB SIZE REPR PROCESS hOG TYPE Cb,ASS MOD NUMB SAMP Eb~M CODE {HEX) O0 000 ,00 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 00 000 00 O0 000 O0 '00 000 O0 00 000 00 O0 000 O0 O0 000 O0 00 000 00 00 000 00 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 0 8 I I 4 68 0000000000 0 8 :1 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 I I 4 68 0000000000 0 8 I 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 I I 4 68 0000000000 0 8 I 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 I 1 4 68 0000000000 0 8 1 1 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 1 1 4 68 0000000000 34 DFPT. 11290 000 $IGM*PS2 S~H~!.PS2 53:793 $IGC*PS2 SDSI.PS?. 0.572 BACK,PS2 TCAF.PS~ 9674.703 TCND*PS2 TSCF.PS~ ]1963.5~0 INND.PS2 DFPT. 10649.000 SIgM..PS2 SBH~.PS2 54.0]0 SI~C.PS2 SDST,PS2 0.463 BACK.PS2 TCAF.PS~ 11074.023 TCND.PS2 TSCF,PS2 2215.478 INND.P$2 16 1 140 19679 1614 15 1 149 20129 1607 .728 TPHI*PS2 21.732 SBHF.PS~ .942 SIBH,PS2 64 13 ' . 8 TRAT.PS2 .349 FBAC,PS2 ~0.558 TCAN.PS2 .320 TCFD,PS2 6586.743 TSCN.PS2 .431 INFD.P$2 300.540 TENS.PS2 ,224 TPHI,PS2 20.296 SBHF.PS2 .627 $IBH.P$2 64.511 TRAT.PS2 .655 FBAC.PS2 32.554 TCAN.PS2 ,938 TCFD,PS2 6926.668 TSCN.PS2 .818 INFD,PS2 ~10.40] TENS.PS2 43,355 2.116 20469,910 4154,493 1285,000 43,514 2.053 22734.24b 4548.231 1445.000 ** END Or DATA Tape Verfftcat~..on l..~ist~,nq :bltlmberger Alas~:a Computing Center 26-0CT-1994 15:16 PAGE: 35 **** FILE TRAILER FIL~ NA~E : EDIT .008 $~RVlCE : FLIC VERSION : O0~CO1 DAT~ : 94/07/13 ~llX RfC $lZ~ : 10~4 FIL~ TYPE LAST FILE : **** FILE HE~DER **** FILE MA~E : EDIT .009 ~ERVICE : FLIC V~RSION : 001C01 DATF : 94/07/13 M~X R~C SIZE : ~0~4 FILM TYPE : bO LAST FILE : FILE ME~DER R~W~CURVES urves and 1~ header data ~or each mass in separate PASS MU~BER: D~PTH INC~EMEMT: 0,5000 FIL~ SUMMARY VENDOR TOOL CODE aT.ART DEPTH STOP DEPTH TDTP ~1~89.5 ~0654.5 LOG HEADER DAT~ DATE LOGGED: SOFTWARE VERSION: WI~E LOGGER ON TD DRILLER TD LOGGER(FI): TOP LOG INTERVAL (FT)~ ,OTTOM LOG XNTERVAL (FI)~ LOGGING SPEED ~EPTH COnTrOL USED (YES/NO): files; raw bac~oround pass in last TOO[, STRING (TOP TO BOTTOm) VENDO~ TOSL CODE TOOL TYPE COLLAR LOCATOR TDT~ TDT~ TDTP TDTP TDTP !.5-NOV-9~ 32.6 1201 11452.0 10665.0 11280.0 1800.0 NO 15-Nov-g2 TOot, CA[, ~ 6 AUXIbLIaRY .EASURE~E~TS ATC 644 THERMAL DECAY TIME TND PB 7~ TNE~;~L QECAY TIME TNC P 50 T~E~MAL DECAY TIME T~:G P AUXILLIARY ~E~SURE~NTS ~TM 160 TaPe Yerificatfon [,isLing :hlumberger Alaska ComPutln~ Center 26-OCT-t994 15:16 # S RO~EHOLE AN[) CASING DATA OPeN HOLE SIT SIZE fiN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH RORE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TE~DERATURE (DEGF): BOTTO~ HOLE TEMPERATURE FLUID SALINITY FLUID LEVEL !FT)~ FLUID RATE AT WELl,HEAD (BPS) W,ATER CUTS (PCT): GAS/OIL RATIOS CHOKE NEUTRON TOOL TOOL TYPE (EPI~,,,ER~AL ()R THER~AL): MATRIX DENSITY: HOL~ CORRECTION (IN): BLU~LINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW eFT): RLUELINE COUNT R~TE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIG~ SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RAT~ HIGH SCALE (CPS): TOOL STANDOFF TIED INTO BHC DATED 12 25 SEAWATER/BORAx 120,0 THERNAL SANDSTONE 2.65 ~ROCEDURE~ 1. DISPLACED WELL WITH 500 BBLS SEAWATER & 5 BBLS/MIN 2.LOG BASE PASS NO.~ WHILE PUMPIN~ ~.5 BOLS/SIN SEAWATER. 3.LOG BASE PASS NO.2 WHILE PUNPING 2.5 BP~ SEAWATER. (RATE BUNPED TO 5BPN ,g~EAWATER aC~USS P[RFS.) TOT"L OF 600 BBLS WATER WAS PU~PED ~*~ISPLACED 180 BB~S aO~X (7LBSZBBL) WITH DEAD CRUDE. b. bOG BORAX NO. ~ AFTER ~0 BBbS OF BORAX IM FORMATION. ONE ~UBING VOLU~E = 270 BBLS. 7 LO~ BORAX PASS NO. 2 AF'IER 94 BBLS OF BORAX IN FLR~ATION, (TOTAL BORAX IN FUPMATIOM AFTER LOGGING : ~]0 BBLS) CONCLUSIOn: NO CHANNEL IS SEE~ UPWARD P'~O~ TOP PERFS TO GOC. $ PAGE: 36 TaPe VerificatiOn Listing :hlumberger AlasKa Computino Center 26-0CT-1994 i5:16 PAGE: 37 #T b.,,,$ FORMAT DATA TABLE TYPE TUNI VALU DEF! CN ARCO ALASKA INC. FN PRUDHOE BAY aPI~ 50-029-20854-00 FL 6~7' F~L & 5'50' FWb S~CT 8 TO~ ' 10N RAN~ ISE COU. NORTH SLOPE STAT ALASKA NATI USA WIT~ J jULIA~ SON 452954 PDAT APD ~T EKB FT 74, EDF FY 73, E6L FT 40 TDD FT 11~52, BI,I FT 11280, TI, I FT 10665. D~T SEAWATgR/BORAX TLA~ 1~:01 15-NOV-9~ BH~ DEaF Company Name Field Name Well. Name AP1 Serial Number Field [,,ocatlon Section. Township Range ountv Irate or ProvinCe ~et~on Witness Name, Service Order Number Permenent datum Elevation o~ Permanent DBtum oq ~easured From ~bove Permanent Datum Elevation of Kelly Bushing EleVation of De~rick Floor Elevation of Ground Level Tota! Pept~ - ~riller Bottom bo~ fnterval ?op ~oa Interval Dril i6g Fluid Type Time bog~er at Bottom Bottom Hole Temperature TYPE ~ CURV DEFI L;UF-~ Uepl~n SlG~ Sigma (Neutron Capture Cross section) TPHI SBHF STBH SDS? FBAC TCAN TCAF TCND TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Correcte~ Fore~ole ~atlon Total Near to Far counts Standard deviation of Sigma ~acg~round Count Rates - Near Detector Back,round Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts -Near detector Tame Verlilcati, on Listing :hlumbergerA'las~a Computing center D~FI TCFD Total caDtllre Cour~ts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Select, ed Counts'-Far Detector INND Inelastic count rate - Dear detector INFD Inelastic count, Tare -far detector T~NS , 'Surface Tension PAGE .' : 3 B DATA FOR~A,T SP~CI,.FICATION RECORD SET TYPE - 64EL ** TYPE , R'gP~ CUDE 'VALUE ~ 66 0 2 66 0 3 73 80 8 68 0.5 9 65 ~1 66 ~2 ~2 68 X3 66 0 15 66 68 ~6 66 0 66 ** SET T~PE - CHAN ** I ERV UNIT 8 IC~ APl API lPI FILE OMB NUMB S ZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEh CODE (HEX) DFPT~ FT 452954 OO OOO OO 0900001 1 4 68 O0 0000 S/Gu PS3 CU 452954 O0 000 O0 0 9 1 1 4 68 TPH! P$3 PU 452954 O0 000 O0 0 9 ! I 4 68 SFH~ P$3 CU 452954 O0 000 O0 0 9 ! ~ 4 68 $~H~ P$3 CU 452954 O0 000 O0 0 9 1 1 4 68 $IGC P$3 CU 452954 O0 000 O0 0 q 1 ~ 4 68 SIBR PS3 CU 452954 O0 000 O0 0 ~ i 1 4 68 TRA? PS3 452954 O0 000 O0 0 9 1 1 4 68 SDSI PS3 Ct) 452954 O0 000 O0 0 q 1 I 4 68 B~CF PS3 CPS 452954 O0 000 O0 0 q I i 4 68 FBAC PS3 CPS 452954 O0 000 O0 0 9 1 I 4 68 TCAN PS3 CPS 45~954 O0 000 O0 0 9 1 1 4 68 TCA~ PS3 CPS 452954 O0 000 O0 0 9 i 1 4 68 0000000000 0000000000 0000000000 GO00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS TaPe Ver~¢ation List~ne .~hlumberger AlasKa ComPuting Center 26-0CT-]~ 994 TCN~ TSCF I N ND SERV UNIT SERVICE APl API APl APl FILE NUMB NUMB SIZ~ REPR .PROCESS ID ORDER ~ LOG TYPE CLASS ~OD NUMB SA~P' ELE~ CODE (HEX) PS3 CPS 452954 O0 000 O0 0 9 ! ~ 4 6~ 0000000000 PS~ CPS 45~954 O0 000 O0 O. 9 1 I 4 68 0000000000 P$3 CPS 45~954 O0 000 O0 0 9 1 1 4 68 0000000000 P$3 CPS 45~954 O0 000 O0 0 9 i 1 .4 68 0000000000 PS3 CPS 452954 O0 000 O0 0 9 ~ ~ 4 68 0000000000 IB~FD P$3 :CPS 45~954 O0 000 O0 0 9 I 1 4 68 0000000000 T~NS PS3 ~B 452954 O0 000. O0 0 9 1 4 ,68 0000000000 '. ¸39 D~PT I~289:,500 SI~M,:PS3 15.224 TpHI.~pS3 20.296 SBHF..P$3 SBH~:Ps] 54*030 SIGC,*PS3 1'627 SIBH,PS3 64,511 TRAT,PS3 SDS! P$3 0,463 BACK'PS3 149,655 FBA. C,P$3 ~.554 TCAN,PS3 TCAF:P$3 ~1074 0~3 TCND.P$3 ~0129.938 TCFD,PS3 6926.668 T$CN.P$3 TSCF.PS] 2215:478 INND,PS3 1607.818 'INFD*PS3 310,403 TENS.PS3 D~P:T, 10654'500 SIGM*PS3 17.569 TPHI,PS3 2~ 866 SBHF.PS3 SBHN,PS3 49-439 SIGC,PS3 2.08]. SIBH,PS3 5~697 TRAT.PS3 SDSI.~$3 0.677 BACK.PS3 1.59.306 FBAC.PS3 35,255 TCAN.P$3 TCAFoPS3 8939,$69 TCN~-PS3 ~9320.336 TCFD:,PS~ 6364.357 TSCN-PS3 TSC:F.PS3 1851.529 INND.PS3 1482.658 INFD.PS3 297.107 TENS.PS3 END OF 43,514 053 4548,231 1200,000 44,572 2,169 19385,238 40~5.085 1480,000 **** FILE TRAILE~ **** FTLF ~AME : EDIT .009 S~RVICE ~ FLIC VERSION : O01CO1 DaT~ : 94/07/13 ~AX REC SIZE : 10~4 FILE TYPE : LO **** FILE HEADER **** FTLF NA~E : EDIT .010 SFRVICE : FLIC VERSION : O01CO1 D~TE : 94/07/~3 ~X RFC STZE : 1024 FILF TYPE : LO L~ST Fi~,E : £$ Ta~e ~er,~f~cation List~nO :hlUmberger Alaska Computing center 26-OCT-..1,, 994 15:~.6 PAGE: 40 FTL~ HEADER FILF NUMBER R ~cCURYE$ .... urves and log header data for each pass in.seParate files;raw background Pass in last DFPTM INC~E~ENT) 0,5000 YENDOR~TO0[, CODE START DEPTH TDTP HEADE~ DATA DATE SOFTWARE VERSION: TI~,E LOGGER ON .BOTTOm: TD TD LOG~ER(FT), TOP LO~ INTErVaL (FT ~OTTO~ 50G INTERVAL F'T .... LOGGING SPEED DEPT~ CONTROL USeD (YES/NOJ: TOOt STRING (TOP TO BOTTOM) V'EN~OR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDT~ TDTP TDTP BOWEHOLE A~D C~$ING DATA OPEg HOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CA$IMG DEPTH BORE~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTO~ HOLE T~NPERATURE FLUID SALINITY (PP~): FLUID LEVEL FLUI[) R~TE AT WELLHEAD ~ATER CUTS (PCT): GAS/OIL RATIO~ CgOKE ~EUTRO~ TO~L TOOL TYPE (EP!T~ER~AL OR TH~R~AL)~ MaTriX: · STOP DEPTH mmmmmmmmmm 10644.5 15-NOV-92 1452.0 1066~.0 11280.0 ~.800,0 TOOL NUMBER COLLAR LO~..ATOR CAL U8 2-6 AUXILLIARY.MEASURE~ENTS ATC 64,4 THERMAL DECAY TI~E TND PB 78 THERMAL DECAY TIME TNC P 50 THERMAL DEC~Y TIME TNG P 21 AUXILLIARY MEASUREMENTS ATM 160 1 4RO. o SEAWATER/BORAX 1.20.0 THERmAl, SANDSTON~ 'S ?a~e Verificat~on L~$~n~ :hlumberger A)..as)<e Computtn~ Center 26-0CT-t994 15~X6 # ~ATRIX DENSITY:, HOLE CORRECTION BLUElY!NE COUNT RATE NORMALIZATION I~ OIL ZONE TOP NO~ALIZIN~ WINDOW ~ASE NOR~ALIZING WINDOW ,LUELINE COUNT RATE SCALES SET BY FIFLD ~.EAR COUNT RA~ ........ 50W SCALE (CPS I: N'E~R COU~T ~a. TK ~IGH SCALE (CPS): TO05 STANDOFF (IN): TIED INTO BHC DATED 11-23-8~o 1, D~SPLACED WEL~ WIT~ 500 Ba~S SEAWATER & 5 2,LOG BASE PASS NO,~., WHILE PU~PXNG ~,5 BBL$/~IN SEAWATEr, ],LOG B~SE P~$$ NO,~ WHI~E PU~PIN~ ~,5 BP~ SE~'WATER,. ,SWITCH OVER TO BORAX $05UTION AND. LOG BASE. PASS NO,3 ~ATE BU~PED TO 5BP~ ,~,.SEAWATER ACROSS PERFS,.) . .,, TO~'AL OF 600 BB5$ S~AWATER 'WAS PUM. P~D, , DISPLACED 180 BBLS BORAX (75BS/B~L) WITH 'DEAD CRUDE, , L~G BORAX NU* .~. AFTER 40 BBLS OF BORAX IN FORMATION, ME ~UBING VOLUME : 270 BBLS. ' 7 LO~ BORAX PASS NO, 2 AFTER 94 BBL$ OF BORAX IN F6R~ATION, CTOTaD BORAX IN FORMATION ~FTER bOGGING CONCLUSION: NO CHANNEL IS S~EN UPWARD FROM TOP PERF$ TO GOC, $ FORMAT DATA PAGE: 41 TAOLE TYPE I CO~S TIiINI VALU DEFI CN ARCO ALASKA 1NC° ompang Name FN PRUDHOE BAY Field Name WN DS 1-23 Well hame API~ 50-02q-20854-00 ~9I Serial Number FI.. 637' FNL & 550' FWL Fie~d Location SFCT ~ Section TOW~' 10N Township R~NC 15E Range COU~~ NORTH SLOP£ County STAT ALASKA State or Province NLTT USA Nation wIT~' d JULIA~! Witness Name SON 452954 Service Order ~umber P~AT ~$h Permanent datum Tape yeti. fi, carl, on List~no :hlU~berger Alas~,a Computtn~ Center 26-0CT-~, 994 I5:16 TUN! VAbU DEF! EPD FT O, ~levation of Permanent Oatum L~F RKO Log Measured From APD FT 74, AboVe Permanent Datum ~:FB FT 74. ~lev,ation of Kelly Bushing EDF FT 73, Elevation of De E~L FT 40 ,: Elevation of Ground Level TDD FT 1~52. Total DePth ~ Dr~.ller BLI FT 11280. ~ottom LOg Interval TLI ~T 10665o Top LOg Interval DFT SEAWATER/BORAX Drl, llihg Fluid Type TLAB 12101 15-NOV-9'2 Time Lo~qe~ 9t ,Bottom BHT DEGF !20, .... Bottom H6le Temperature TABLE TYPE : CU~V DEF! D~PT Depth $IG~ Sigma (Neutron Capture Cross Section) TPHI TDT POrOSitY SBMF Bore~ol:e S~gma - far detector SB~N ~orehole ,Sigma - Near detector SIGC Sl.~ma Correction SIB~ Corrected Borehole Sigma T~,AT Ration Total Near rD..Far counts SD$I Standard deYfation of Sigma BACK Background Count Rates - Near Detector FBAC Back,round Count Rate - Far Detector TCAN Tota! coonts analyzed - near detector (T~T~) TCAF Total counts analyzed -far detector (TDTP) TCND Total capture counts - Near detector TCF~ Total capture Counts - far dectector T~CN TOtal Selected Counts - Near Detector T$CF Total Selected Counts - Far Detector INND Inelastic count rate - near detector I~FD Inelastic count rate - far detector TFNS Surface Tension ** DATA FORMAT SPECIFICATION RECO~D ** ** SET TYPE - 64EB ** memmmmmmmmmmemmmmmmmmmmmmeemmm I 66 0 2 66 3 73 8O ~:$ ~ra~e Yert:ficat~on :hlumberger Al, as)<e ¢oroPut~no Cente 26-0CT-1. 994 15:1.6 43 4: 66 5 66 6 73 7 65 8 68 0,5 9 65 il 66 12 1~ 66 0 14 65 PT 15 66 68 16 66 ! .0 66 TYPE - CHAN.** SERVICE APl APi APl A 0RD~H #. LOG TYPE · ** SET NA~ S~RV UNIT ID DMPT FT $~G~ PS4 CU TmH! PS4 PU SBHF PS4 CU SBH~ PS4 CU $IGC PS4 CU $78H PS4 CU TRAT PS4 SDS~ P$4 CU B~C~ PS4 CPS f'~AC PS4 CPS TCA~ P84 CPS TCA~ PS4 CPS TCND PS4 CPS TCFD P$4 CPS TSCZ ~$4 CPS TSCF PS4 CPS I~ P$4 CPS INFD PM4 CPS 452954 00 000 O0 0 452954 00 000 00 0 45~954 00 000 00 0 452954 00 000 00 0 452954 O0 000 O0 0 452954 00 000 00 0 452954 O0 000 O0 0 45~9~4 00 000 00 0 45~954 00 000 00 0 452954 00 000 00 0 45~954 00 000 .00 0 452954 00 000 00 0 45~954 00 000 O0 0 452954 O0 000 00 0 45~954 O0 000 O0 0 45~954 00 000 O0 0 452954 O0 000 O0 0 452954 00 000 00 0 45~954 O0 000 00 0 # m,mm.mmmmmmmmm ,mm O0 000 PI FILE NUMB NUMB SIZE REP~ PROCESS OD.NUMB 8AMP .~LEM CODE (HEX) 10 1 1 4 68 0000000000 10 1 I 4 68 0000000000 10 I 1 4 6~ 0000000000 10 1 1 4 68 0000000000 10 1 1 4 6~ 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 1,0 1 1 4 68 0000000000 10 1 1 4 68 0000000000 1,0 1 1 4 68 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 10 I 1 4 68 0000000000 10 1 1 4 68 0000000000 10 1 1 4 68 0000000000 10 1 I 4 68 0000000000 10 DFPT, 6DSI,PS4 TCAF.P$4 TSCP.~S4 11289.500 103,491 0,339 0.000 O,OOO $IGM,PS4 SlGC-PS4 BACK,PS4 TCND,P$4 12,074 TPHI,P84 0.000 SBHF.P$4 0.01! SIBH,PS4 127.003 TRAT.P$4 958.874 FBAC.PS4 71.898 TCAN.P$4 -2936,318 TCFD,PS4 -809.729 TSCN.PS4 -8,800 INFD,P$4 -2.4~4 TENS.PS4 122.232 0.000 0,000 0.0~0 1030,000 S Ta~e veriffcat]:on Listinq ~hlumberger AlasEa Computtn~ Center 26-0CT-~.994 15:I6 PAGE~ 44 DEPT, 10644.500 SIfl'M:'PS4 lI.556 TPMI%PS4 SPH~.PS4 97.0.19 SIGC:.P$4 0.045 8IBH,PS4 SDS~ ,PS4 0'2~9 BACK.PS4 1.36.09~ FBAC'PS.4 TfA~,PS4 14754,396 TCMD:.PS4 12544.]89 TCF~.PS4 TSCF.PS4 .30~,994 INND,PS4 1680.571 INFD*PS4 10.459 SBHF.PS4 1.33.~50 TRAT;,P$4 29.031 TCAN;..P$4 6277.178 TSCN.PS4 310.119 TENS-PS4 69:; 993 l. 451 1380.000 ** E~D OF DATA ** **** FILE TRAILER **'** $~RVICE : FLIC VERSION : O0!CO1 DAT~ ~ 04/07t13 MAX REC SIZE : 10~4 FiL~ TYPE ~ L0 L,~ST FILE : **** FILM HEADER **** FI,bE NA~E ~ EDIT .011 SERVICE ~ FLiC VERSION : 001C01 DATE : 94/07/~,3 ~X REC $~ZE : 10~4 FIbS TYPE : LO L~$T FILE : R~w CURVES Curves and log ~eader data for each pass in separate PaSS ~UMBER: 5 DFPTH INCREMENT: 0.5000 F~L~ SUmmaRY VEFDOR TOOL CO~E START DEPTH STOP DEPTH ................. ......... 11~90.5 10653,5 $ bOG HEADER DATA ~TE L~G~ED: SOFTWARE VERSION~ TI~E bOG~E~ ON BOTTOm: · [) DRILLER (PT): TO LOGGER(FT): TOP LOG INTEPVAb (WT): POTTOM LqG INTERVAL (ET): files; raw bac~oround pass in last 15-NOV-9~ 32.6 1201 15-MOV-92 11452.0 0665.0 :hlumberqer Alaska ComPutln.g CeDter 26-0CT'1994 15:16 45 DEPTH CONT~,OL USED (YES/N(]): TO05 ST~I~G (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP T~TP TDTP TDTP TDTP TDTP 80~HOLE AND C~SING DATA OPEN ~OLE BIT SIZE (iN): DRILLERS CASING DEPTH ( LOGGERS CASING DEPTH (FT): ~O~EHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G)~ SURFACE TEMPErATUrE (PELF) BOTTO~ MOLE TE~PERAT[,]RE (DE,F) FLUID $~LINITY (PPM)~ FLUID LEVEL (FT)~ FI,UID RATE ~'r WELLHEAD WATER C!~TS (PCT)~ GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPIT~E~MAL OR THERMAL): ~ATRIX: MATRIX DEL]SITY: HO5~ CORRECTION (IN): # RFM~RKS: 1800,0 NO COLLA~ LOCATOR 'CAL UB 276 AI]XILLIARY ME, ASUR:E~ENTS ATC 644 THERMAL DEC~Y TIME TND PB 78 THERMAL DECAY TIME TNC P 50 THERMAL DECAY :TI~E TN~ P'i21 AUXILLIARY MEASUREMENTS ~T~ ~60 ,12 25 SEAWATER/BORAX THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION I~r nit, ZONE TOP NORMALIZING WINDOW (~T): BASE NORMAhIZING WINDOW ~L!)EI,INE COUNT R~Ig SCALES SET BY ~I~LD ENGINEER PA~ COUNT RATE LOW SCALE (CPS): ~AR COUNT RATE HIGH SCALE (CPS): NEAR COUNT R~TE LOW SCALE (CPS): NEAR COUNT RAT~ HIgH SCALE (CPS): TOOL STAHDnFF (IN): TIED INTO BHC DATED ~ROCEDURE~ 1. DISPLACED WELL WITH 500 BBLS SEAWATER & 5 BBL$/MIN 2,LOG BAS~ PASS NO.I WHILE DUMPING ~.5 BOLS/~IN SEAWATER. 3.DOG S~S~ PASS NO.~ WH~GF PU.P~NG ~.5 BP~ SEawATeR. [$ Ta~e Ver{..~.{cation L1stin~ ~hlumber~er Alaska ComPuting Center 26-0CT-1994 15:~6 4. SWITCH OVE~ TO BORAX SOLUTION AND. LOG BASE PASS NO,3 ( ATE BUMPf, D TO 5BP~ ..,.&EAWATER ACROSS PERFS.,) ... TOTAL OF 600 BBLS SEAWATER WAS PU~PED. 5. DISPLACED 180 BBL~ BORAX (,7~B$/BBL) ~ITH DEAD CRUDE ~. LOG BORAX NU..~ ABTER 40 BB~S OF BORAX IN FO~MATION] ONE TUBING VOLU~E'= 270 BBLS. E,,OG BORAX PASS NO. 2 AFTER g4 BBLS OF BORAX IN 6R~AT,ION. (TOTAL BORAX I~ FORMATION AFTER 50GGIN~ c 1~0 CONCh JS ! NO CHAN~]EL YS SEEN UPWARD FRO~ TOp PERFS TO GOc, $ ~I$ FORMAT DATA TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA iNC, FN PRUDHOE BAY APiN 50-029-~0854-00 FL 6~7' FNL & 550' FWL $~CT 8 TO~ ION R~N~ COU~ NORTH sLOPE ~TAT ALASKA NAT! USA WITN J JULIAN 80N 452954 PDAT EPD FT 0 APD FY 74. E~B ~T 74. EDF Wy EGL FT 40 TOD FT 11~52. BLi FT 11280, TLI FT 10665 DFT sEAWAtER/BORAX TLAm 12:0! 15-N0¥-92 B~T DEGF 120, Compan~ Name Field .'ame Well Name API Serial Number Field Location Sectto~ Township Range County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log ~easured From ADore Permanent Datum Elevation of Kelly Bushin~ Elevation of Derric~ Floor Elevation of Ground Level Total DePth - Driller Bottom Log Interval Top 5og Interval Drilling Fluid Type Time Logoer at ~ottom Bottom Hole Temperature TABLg TYPE : CURV DEFI DFPT Depth S~G" Sigma (Neutron Capture Cross Section) [$ Ta~e Verification List~.ng :hluR~bergerAla, SKa Computlnq Center 26-0CT-1994 1.5:1,6 DEFT T ' ~ ?PHI ,.D~ POrositY 5~HF ~orehole S~ma - far detector $~HN Borehole Sigma - Near detector SIGC Sigma Correction STBH Cot ected Borehole Si~, ma TRAT Rat[on Total Near to ~a:~ counts SDST Standard devlation of Sigma BACK BaCKgrOund Count Rates- Near Detector FBAC BacKground Count,Rate - Far Detector TCAN Total counts analyzed - near detector (TDT9) TCAF Total. counts analgzed-'far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far decteCtor TSC)~ Total Selected Counts - N'ear ~etector T$CF Total Selected Counts-Far. Detector INND Inelastic count rate - near detector INf'D Inelastic count rate - far detector TFN8 Surface Tension m~~mmm~m~~mm~m~m~mmm~m~~~m~~m~ .. .PAGE: · 4 ? DATA FORMAT SPECIFICATION RECO.D SET TYPE - 64EB ~mmm~~~mm~m~~~ TYP~ REPR CODE VALUE ~m~m~m~~m~m~m~~ 1 66 0 2 66 0 3 73 80 4 66 1. 5 66 b 7 65 8 6~ 9 65 FT 11 66 12 12 68 13 66 0 14 65 F~ 16 66 1 0 66 mmmeemmmmmmmmmmmmmmmmmmmmeemmm :hlumberger lasKa ComPut no Center 26-0CT,,~{,994 15{16 PAGE= ** SET ?YPE -. C NA~S~,.R¥ U~IT SE~V'ICE ID ORDE~ # mmmmmmmm~mm~mm~m~~mmm ' APl API APl APl FILE N:U~B NUMB SIZE REPR PROCESS LOG TYPE CLASS MOD NUmB SA~P EhEM CODE (HEX) 00 000 00 0 11 1 I 4 68 O000OO00OO 00 000 00 0 11 1. 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 .11 1 1 4 68 0000000000 O0 000 00 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 i 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 I 4 68 0:000000000 O0 000 O0 0 11 1 1 4 6~ 0000000000 O0 000 O0 0 11 1 I 4 68 0000000000 O0 000 O0 0 1.1 1 i 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 1 4 68 0000000000 O0 000 O0 0 11 1 i 4 68 0000000000 O0 000 O0 0 1.1 1 1 4 68 0000000000 O0 000 O0 0 1,1 1 1 4 68 0000000000 O0 000 O0 0 11 I 1 4 68 0000000000 O0 000 O0 0 11 I I 4 68 0000000000 O0 000 O0 0 ll I I 4 68 0000000000 O0 000 00. 0 11 1 1' 4 68. 0000000000 48 DATA ** DEPT. SBH',PS5 SDST,P$5 TSCP,PS5 11290,~00 97. 0 229 14754:396 3033.994 D~PT, 10653,500 SBH".PS5 98,643 SOS! PS5 0,496 TCAFiP$5 6643,361 TSCP,PS5 1337,588 SIC.,~.P$5 11..556 TPHI.PS5 10.459 SBHF.PS5 IGC..PS5 0.045 SIBH PS~ 133.150 T~AT,PS5 ~ACK,PS5 136,091 FBAC:PS~ 29,031 TCAN,PS5 TC~iD.PS5 12544.389 TCFD, PS5 6~77.1.78 TSCN.PS5 INND,PS5 ~680.571 INFD~PS5 3~0.1~9 TENS.PS5 SlGM.PS5 17,092 TPHI,PS5 20,326 SBHF,PS5 $IGC.PS5 O.lO0 SIBH.PS5 148.960 TRAT,PS5 BACK,PS5 155.490 FBAC.PS5 33.376 TCAN.PS5 TCND.PS5 9612,088 TCFD.PS5 3773.212 TSCN.P$5 INkeD.PS5 1517.665 INFD,PS5 287.970 TENS.PS5 69,993 1.,451 21411,~68 4402,950 1070,000 79,645 1,859 12350,549 2486,684 1360,000 ** E~D OW DATA ** '$ Ta~e ver.~:f~Icat,~,.on ..r,.i~t~.n~ ,,hluRtberger ~laska, ComputJ,.nq center 26-0CT-~..994 15:16 .PA~E: 49 **** FILE T'~AILE~ ~**$ FI'L~ ~A. YE : EDIT ,Oil $~RVICE : FLIC VERSION : O0~CO1 DATF : 94/07/J. 3 FIL~ T~PE : LO DAT~ O~I6iN : FLIC TAPE NA~E., : 94~29 CONTINUATION# PREVIOUS TAPE COMmEnT : ARCO ALASKA INC, DS ~'~, PRUDMOE BAY ,50-029'~0~54~00 O~I~IN : F~IC REEL NA~E : 94~29 CONTINUATIOn! # : P~EVIOU$ ~EEL : CO~ENT : ARCO ALASKA INC, DS ~-~3, PRUDMDE BAY ,50-029-~0854-00 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. 1-23 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 11-23-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC Resistivity Focused DIFL .2-2000 RILM " Medium " " ,. RILD " Deep " " .. GR1 Gamma Ray 1 DIFL-BHC/AL 0-100, 100-200 SP Spontaneous Potential " " -100-0, 0-100 GR Gamma Ray CN/GR-CD/CN-CDL 0-100, 100-200 ., CAL Caliper " " 6 - 16 CN Compensated Neutron CN/GR-CD/CN 60 - 0 DENP Density Porosity CD/CN " .. DEN DenSity CDL 2 - 3 CORR Correction " -.5 - .5 ,. AC Acoustic BHC/AL 150-50 , . " -~c[V~~ .... - " ~' ,[ 0.t982 . , ARCO ALASKA INC. Oil &Gas Cans. 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'~ ._5 ¢, a. ;:> 5 n. 1 -0.8 5.~ _ 1.6 65.q. 5~..0 -0.7 0.0 5.5 0.0 5.5 0.0 5.5 0.0 5.5 0.0 5.5 0.0 2919. 7.6 o.0 o.0 n.o o.n o.o 0.o '0 <~ .r~,~:: o,:o o.n 5.5 5.5 29~9, 7,5 0,0 0.0 rl,O 0.0 0.0 2959. 12.3 0.0 0.0 n.o n.n 0.0 · ' o.~.o'... :':o~o' 0.~::::::: :o-o o. o 5,5 1.. a ...... 5~_,._0 .... D_~_._.s_ ..... -__o., 5. 0.0 __ --5.5 _ 1..8._ 5~.r-, 4n..__2___.,0.4, . . 0.0 5.5 1 ,.6 ....6_n._._¢,_ .... ~.~_.3 ...... ?_0.6 0.0 5..~ I .7 5g.3 q~.l -0.6 9_..0_ ........ 5_.5 ....... _!_.G ...... 6.5._~ ..... 4.~. 2 -0_.7~_ PA~E ~ ARCO ALASKA INC. D.S. 1-2~ GR1 IS RUN WITH DIFL. FT, API API MV ~999, 6.8 0.0 0.0 A.O O.rl 0.0 ___ o ~.~a :~'~0,9~, o.o ._ ~019. 9.7 0.0 0.0 N.O O.N 0.0 ~.. .o.. :...~n~ X059. 11.5 0.0 0.0 0.0 O.n _ 0.0 -.o~ xo59. le.o o.o o.o n.o ~:,.: zo79. 12.8 o.o o.o n.o n.n o.o ::i" o. · <~O'o 5099. 19.1 0.0 0.0 A.O ,';0~ 0 ~119. 25.5 0.0 0.0 0.0 O.n 0.0 o 0.0 0,0 __ . 0,0 0 ,f~ ~279. 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D.S. 1-25 GR1 IS RUN WITH DIFL. FT, AP1 AP1 AC__ IN G/_C_ . o, o, .~9.~.~.9 o.o o.o n.o a.n o.o o.__o_ .... ~_.. ~i'-~o ~o 2 _ . ~5~ ~. ~ 8. ~ o. 0 o. 0 n. 0 o. n o. 0 0 ~0. 5. _ ~57g, 20,6 0.0 0.0 n.O n,n 0.0 O~ .... ~_~ ........~_.~0 ....... ~6~_6 ..... 5~_ -0.~ ':.'.o." a' ~ ~: :,o~ ~se~. ee.~ o.o o.o o.o ~8~9, 21.2 0,0 0,0 ~6~. ~o.o o o o.o .... :~ ~S ~; ~ 0 .'S ...... ~.~e.. .... e~.~ ~6~e. ~.~ '::: .... . ............ ......... ~'~S6'; ...... ~ o:'o~"~'~-<.~:~.o~6:~ ..... s., ~. z -~-~ -' ~'.-~~2 ~759. 21.2 0.0 0.0 n.O O.n 0.0 0.0 5.~ ~.1 34.~ ~x.~ -0,2 _. ~O~'.n. :0~o: o.o ~77~. 26.4 0.0 0.0 ~.0 ~i~. 27.6 o.o o.o n.o o.n o.o o.o ~o'. ~.o o:~o ~ o.o sel~. ~1.o o.o o.o n.o o.n o.o o.0 · ~oi ~ o~ o. 0 ., 2.1 _ .~.~.7 4X 3 -0,2 ~, l ~ i ,.? ....... 9~_.~_.__-_0__._~__ ~ ,_~ ...... ~.5.__6 ...... ~._O_~__~. 2 -. ~.1 32._~ 5u.2 -0.2 _.~._~ .... ~.2 ..~ ....... ~_~-.._~ ...... 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IS RUN WITH DIFL. -R~.iLM ::, RI~L.n : SP FT, AP1 API MU ~999. 47.0 0.0 0.0 n.O o.n 0.0 -9019. 4,4.0 0.0 0,0 R.O O.ri 0.0 r,:~.,', o 'o~ o__ g039. 44.4 0.0 0.0 0.0 O.n 0.0 ~',. 0;o.~ . q059. 45.3 0,0 0.0 1,1.0 O.n 0.0 __. AC CAL IN G/C %_ o, ~079. q. 8.1 0.0 0.0 0.0 0.0. 0.0 · ~ . ..o'..~ ::o~o ~o~e. 51.~ o.o o.o n.o o.n o.o 9119. 54.5 0.0 0.0 ri.O 0.1,1 0.0 · O,o' i::o;o: 9139, 53,6 0.0 0.0 1,1,0 0.0. 0.0 g279. 39,9 0.0 0.0 n,O n.n o.0 ~.~:. O: . 0..0 0.0 5.4 P.~ 19.7 3~.4 -0.2 · , 0.0 5.4 ;~.2 .?5.Q .3_x.~O -0.2 g299. 59,0 0o0 0.0 n.o o.n o.o '~ 0 0.0 5.4 2.3 20.9 3~.4 -0~1 0.0 --. 5.3~ .... ~.3. 22.~ ..4n_.6 -0ol _. 5.4 ~.3 ~2.~ 4~.9 -0.1 5.4 2.2 25.S 4n.8 -0.2 9339, 46.7 0.0 0.0 1,1.0 O.O, 0.0 ,.':..'..: ,:o.:.'~ g359. 62.0 0.0 0.0 0.0 O.n 0.0 ~7~. 32..2 0.0 0.0 rl.Ofi.rri 0.0 , :.. ".O.'j ::: 0; 0 :~ g~99. 42.5 0.0 0.0 ri.O n.n 0.0 ,' .:." 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'.:~ ii ~i :~:'i:: ::: : .:..:.....:~'~: .... ...:::::::::::::::::::::::::::::::: .............. : ......... ~ ....... -:37.0 11399. 82.9 ~7.3 6.2 ~.0 5.x ~12.A , 11~19, 25.9 52.6 5.1 ~.~ ,~.P -20.7 _ 11~+59, 0.0 52.6 PROGqAM: LZSC~N REViSiON: 5,1 ,,,.~V 89 1: Op P&RT **** REEL LiS AT 01 L.&S HEAOE~ LIS ~:.?/10/29 0! '5 PASS CN/t.,!S AT 11~S,Z,-1n6~6. .~., FT,' (~,.) c..u .=4' ; :.- c.b' PASS 1.001 l NC TAPE CE~TH UNiT I2 Ni T ;'-- ~ i Li LE {-_.TS 5'fTYS * DATA 113 O, O, 113 1 5 112 2 11E 1 4 111 1 6 111 1 6 1t0 1 110 1 10; 1 103 1 108 1 .. o ,-.'- ! LSN O 0. n 00 /- 24706 aa 000 0.9~032 3.76210 vu. O00 0.f,'~2_71,, . ~O.OOO _3 Xl 58.1 O0.OOO 5.62680 2.50719 50 0~ · ~.j 29.1~13 52.54 00.1120 O0,O .... 7,07709 ~ ~O~S~ ~O.OCO 5.7~'~ q :~v 02.8395 O0 5,5/~6x3 (TYP~ C.SSN n · O 0 00 _S©, OOOOO ~ '". 0:5 _.._~ L; LJ 1o'~ ~54~ 34.07123 1 A9 23n! lX:? 2~01 2tl 294.313~ ~u~.$Os7 17 35'*~1 255·~894 255.2694 2;~.6~148 - 15. c, 4:-~ 1 21 5 · -7481 268.5212 a!~.2748 27.~9721 3.OUUu~.~ 36.41042 ~ ~!300¢,¢ 27.~4064 ? O'"OOu~ 27.c97£1 29.34897 1 . 090C'30 27.~9721 1 3,. OOOO00 ZT.oo721 1!.51412; 19.9344~ -'~ o0721 3. 00009?, 17.~9721 19,771 I .O'-9uOu ..... 2c.72337 T :N - .50 '3. '3009 "'~.u"' 0009''''~u u 195.4153 33.45905 54.76764 21.77547 40.41042 10.45577 31.4406& 3-4 33.3602~ I 9.76080 4~ 16177 !5.51415 73.03442 25. '~,1 aoo S0.Fl135 ?,5 · 771 5 =1.19204 33.72337 CN~A O,O00000O 9.00C0000 !2.01 .,737 0.73§7671 :-01 110C.;12 "'.x. ~,8,:5,21,, 47E-01 O. 6~+12939E-01 1164.534 ,.-., ,~. 77777475-""1~. ~ : ~ 115!.157 ,3.73B51 ~-4 =-01 1154.~14 O 109731 1134.204 0.129~896 11 .,31,210 !3. 9 qO37-q4E-m1.,,.: 1 I 76. 091 O. 79A79638-0! 11°X 42.. (.. · 9. 957461,5 E- 01 1190 · c,!~ 7 O. 7373706,Z-~1 I n'?in, c'..nn ? 4. :;6564 ? ?, S579! 21.84 3! 9 1 t7 5. 574 ~ U 0 215.9645! 11~. 19.72209 97! 2'71 .70 2¢~.99710 1 · O. O000C 0.866753 20.56.5 2~. I 1 5 '3.799 0.19,':-6016 TOTAL DATA RECOqDS STARTING TaPE DEPTH FiLE TRAILER **** : 74 = 1 I ~50. O0 eNDING DEPTH = 10654.00 **** ~IL~ HEADER **** 1024 ONE TAPE DEPTH 'jNiT : FT I AP1 I F / MM I ' ~ L,. ,~ ! L~, 1 CT< I *Tq I vCT I PCT ! C/~ 1 CTS 1 CTS 1 v~ T ~YTES 4 DEPTH CLSN LSN 113=1.O'~'''~.~u u · uOuOeOO O.OOO000O 11SOl.GOO 55.6424~ 11251.0CO 1 ~ ,~OOo 2 7 ~.. 4 ~ ~...:5,, (~ TYPE~ O) SSN SN 0 O, n"-O00 1~-~ z~,n- 26.25215 081 5 9°~' RYTES Cq CCL 27.9972! 3C'.. 51a05 I. OO;,no'~' T E C N~' - = ""' :-; 0. $,} 0000 ,,..., ! 1 ?.,. 492f. '54.51.L:35 TTmN CNR A 0. O0000OO 1177.440 0.7195623=-01 1170.7.<,,.5 3. ,~1 67399E-i31 111 =1. COO I $., 07.3.,1 ? i 4. ~7806 ! 99. 9431 S?. ql ~p~ 199 1105t.n00 1,, -~a$6.6 -.- ,-.~ · .., .: 31.28717 287,9231 1 25 · 1 4~6 227. 9231 , ,.,,.,,.uuO 16. ·,.4941. 39 5~'~42 31~ ,'-277 10801.0;90 24. ~7341 IA.n2P2~- PO~ ~:41P 64· 089'~.~¢ ~' 20'9.341 2 10751.9Oa z3. 22330 P3.3;'~-6~ P49.41x-~ 93.39460 249.4160 10701 P9 27.997~! SO 5469~ ). uu._,,ono-,., 17 9ay ~1 U,£ 1 · 009003 27.99721 I~.02967 3.9000q0 12.09473 I· 00"'3 O:Jv, "' 97~1 c 7 . 0 22.44014 I · CO0'""n'-3,...' ~7.997¢1 26.74554 1.0~onu, u £ 7.0s,,721 1,5. 3~571 27,99711 :7 °~4x7 ~ onnno¢ 17,99721 ~'0 526~ .... nOOO 3 49,03867 20.43924 3&.5469 2'.'1 .78189 10. '76907. 7C,02962 37 · :'3.5306 1 ~ n9473 · .,, · 4.055475 26.44014 I 9.1 0373 ~,...74554 27.36571 ~O 92667 31 .33437 ~4 107 ¢,1 24.52632 22.93539 19.9613,°.. 11Ol %' 0.7!01074~-01 11 6 '~ . ,54 7 0.74331 7:3,_=-01 1176.720 0.1267712 1151 .4.24 n._.. 5 ,g ~x 07 'z¢, ,'3 ¢-p~ ~ 1 1140.163 O. 7/-751471 E-gl 1160.941 9.1002155 40. 327 765x666E-a1 1172,646 0.9;51397=-01 115_=,.;45 0.1069337 TOTAL rjQTA RECORDS : 74 STAqTING TAPE O~PTH = !135!.00 FiLE T~AILER ~** E N 01 -?'-i g D=PTH 10~ 55. O0 FiLE ?~SS i024 12 PL~ 1 1 ! 1 1 ! 1 1 1 ! 1 UNTT Ami F/MM LR Lg CTS rTS PCT 'PCT Cl,~ CTS CTS V'3LT YTES 4 4 4 4 4 4 I ! 354,093 -9°~ . 1139~.000 11£54.000 I 7. *: 'z >' q: ? i i 2¢-4 OCS . ~ . · !3.0zx. 44 55.74577 1t154.000 I 3.0057~ P Q?P9~ 111~ 15.6309& 54.52375 11054.000 'z1 125.7820 11 0O~ · 321320~ 1 29 !1.78976 87.15907 10~''''/ O0 t7 71:'1~ 79. $687'P (T Y"' S S N -9?9 -990 :25C9 44. P!;' z! ,;, 5336 214.9/--96 51.S5275 195.5581 196,5581 !93.2470 19~.2470 !&,77065 I ~-~4 =/-,1 7 ,-.--* . 341 7 25. 53216 295.1~5 ?gq !a~~, ~. ~ · = -~ ..~ 27.79854 2!.52541 223,872~ O) ?9 4 S Y T ~' S S. r3 999. ?. ~ :30 , . , ~' 17. ,-': :P 76 ~ I . .3 u- u J u '_- 24.50805 3 ·OC,.._~C: ?x, ~973C 31 .?"139 t ~ OFlr' O0 ~3 77!1~ 2P.~Q~nc} 20.99730 3! .7!431 1.0"'Or, OOu _ 26 .¢9730 15,6138-' ! O0n q n -'' 26.99750 15.8205d z. OO=mm¢ 2 ". 99 7.-£ C 22, O:i'. 663 7. O Lq 0000 2~.99730 26.&8134 I oonooo Tm f h.!r -9 99 · 240 C 7,,.,,. 4357 ;~ ¢1 4~.. 01 41%. 2~.50606 01 557 201 39 33. 28679 37.77116 25.165~6 35.71431 1 9 · 05099 19.61385 13.9921~ lC;.a2355 i4.06305 26.6,2665 26. ~_,gl 95 39.4~!34 TT=N C N2 -';0o . ? :5..'3,9 t1,~2.55~ 9. .767930~E-~I, , ~ 1195.152 83x403~-r1 O. 70':?0241 ~--01 11 99.."514 O. 67zO1, ., 1 5E-~1,,.., 11¢2 46'¢; · · '~ O · 701 -z c399.F.-C1 116,5.145 0.1103237 1155.529 0.1 09z.,9 ? 6 11 5% · 781 0.8937979~-C1 11,~;9.379 C. 791 ....¢,./6 S E-01 22.39334 0.10012.'36 10 10 10 27 . 21 23/4 27! · 7576 1 ~J . 3-a: 33 ~ 10;- ~5L94 ??1 7':~76 5. o~,uu 23. ;~4255 Z49.8!03 1 9. 8721 5 95 37057 2~o 810~ 1 0e~ 6,752281 32.17815 14.42345 72.0'~400 ?..2951 ~7215 1123,94.3 9.759051ZE-01 1133,651 0.9913421E-01 1139.711 ,3.9544301~-01 7'4' 1 ! 35 4.00 E N O I N .'.$ TAPE 1065~ no **** TAp~ TRAILER LiS 89110120 01 TOTAL ..... mECO~O~ !~',, TH!~lo ._lOGICAL TA~¢., : ?35 **** REEL LiS 8~/10/~0 ATL&S 0t TR~!LER **~* TOTAL RECORDS IN THiS TOTAL RECORDS IN THiS End of. ex,~cutio~':.. :, W-'--'4:,.., 1 Elapsed e~ecutzon ~im,e = I L ....*""AL REnt : PHYSICAL RE~L: NOV ~9 I :31o minute , 24,0 seconds, SYSTEM RETUPN CODE = 0 COMPANY NAME : ARCO ALASKA INC. WELL NAFIE : D.S. 1-23 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292085400 REFERENCE NO : 98383 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 98/07/29 ORIGIN : FLIC REEL NAME : 98383 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA, DS 1-23, PRUDHOE, API# 50-029-20854-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/29 ORIGIN : FLIC TAPE NA~E : 98383 CONTINUATION # : 1 PREVIOUS TAPE : COMFiENT : ARCO ALASKA, DS 1-23, PRUDHOE, API# 50-029-20854-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NA~E : D . S . 1-23 API NUMBER: 500292085400 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 29-JUL-98 JOB NUFIBER: 98383 LOGGING ENGINEER: R STEPHENSON OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 ON RANGE: 15E FNL: 637 FSL: FEL: FWL: 550 ELEVATION (FT FROM MSL O) KELLY BUSHING: 74. O0 DERRICK FLOOR: 73. O0 GROUND LEVEL: 40. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 000 7. 000 11447.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (I~-~SURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 11252.5 11246.0 11244.0 11243.5 11236.0 11235.0 11226.0 11219.5 11219.0 11212.5 11211.5 11208.5 11208.0 11199.0 11198.5 11192.5 11191.5 11186.5 11186.0 11184.5 11172.5 11172.0 11168.5 11168.0 11162.0 11142.5 11138.0 11137.5 11136.5 11132.5 11124.5 11124.0 11109.0 11107.0 11106.5 11094.0 11087.0 11077.5 11066.5 11066.0 11063.5 11062.5 11052.5 11038.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.0 88889.0 11246.0 11242.0 11234.5 11226.5 11219.5 11213.0 11209.0 11200.5 11194.0 11188.5 11186.0 11174.0 11169.5 11161.5 11145.0 11140.5 11137.5 11133.5 11126.5 11114.0 11111.5 11097.0 11089.5 11080.5 11070.5 11067.0 11056.0 11043.0 11253.5 11245.5 11242.0 11234.5 11226.5 11219.5 11213.0 11209.0 11200.5 11194.0 11188.5 11186.0 11174.0 11169.5 11161.5 11145.0 11140.5 11137.5 11133.5 11126.5 11114.0 11111.5 11097.0 11089.5 11080.5 11070.5 11067.0 11056.0 11043.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11024.0 11028.5 11028.5 11010.5 11016.0 11010.0 11016.0 10975.0 10975.5 10975.5 10967.5 10971.0 10971.0 10961.0 10964.0 10959.5 10964.0 10959.0 10961.5 10952.5 10954.5 10954.5 10945.0 10947.5 10944.5 10947.5 10939.5 10942.5 10939.0 10942.5 10932.0 10936.0 10927.0 10930.5 10918.5 10921.5 10914.5 10917.5 10909.5 10913.0 10909.0 10912.5 10904.5 10908.0 10903.5 10908.5 10898.0 10901.5 10901.5 10892.0 10896.5 10896.5 10882.0 10885.0 10881.5 10885.0 10877.0 10881.0 10876.5 10881.0 10871.0 10874.0 10870.5 10874.0 10865.5 10869.5 10869.0 10851.5 10854.5 10851.0 10854.5 10848.5 10852.5 10847.5 10852.5 10842.5 10845.0 10842.0 10845.5 10836.5 10840.0 10840.0 10830.5 10834.0 10834.0 10828.0 10831.0 10831.0 10823 . 0 10826.0 10826.0 10816.5 10821.0 10821.0 10810.0 10813.5 10806.0 10810.0 10810.0 10804.5 10807.5 10807.5 10799.5 10803.0 10798.5 10803.0 10795.0 10800.0 10800.0 10793.0 10797.5 10797.5 10790.0 10793.5 10793.5 10787.0 10790.0 10786.0 10790.0 10774.~ 10777.5 10777.5 10768.5 10771.5 10768.0 10771.5 10762.0 10764.0 10761.0 10763.5 30-JUL-1998 11:28 PAGE: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 10751.5 10754.0 10750.0 10754.0 10748.5 10751.5 10748.0 10751.5 10740.0 10743.5 10730.5 10733.0 10733.0 10726.0 10726.5 10726.5 10718.0 10720.0 10720.0 10708.5 10712.5 10712.5 10702.5 10706.0 10701.5 10706.5 10698.5 10701.0 10701.0 10689.0 10693.0 10687.5 10692.5 10684.5 10688.0 10683.0 10688.0 10682.0 10685.5 10677.5 10681.0 10677.0 10681.0 10675.0 10678.5 10678.5 10669.5 10673.0 10673.0 10667.0 10670.5 10666.0 10670.5 10664.5 10668.5 10663.5 10668.0 10662.0 10665.0 10661.0 10665.5 10656.5 10659.5 10659.5 10651.0 10654.0 10654.0 10647.5 10650.0 10644.0 10647.5 10641.0 10643.5 10644.0 10637.5 10640.5 10637.0 10640.5 10633.0 10636.0 10636.0 10627.0 10631.0 10631.0 10626.0 10629.5 10629.5 10620.0 10623.0 10619.5 10623.0 10616.5 10620.5 10615.5 10620.5 10609.5 10613.5 10613.0 10605.0 10607.5 10604.5 10607.5 10600.5 10604.5 10604.5 10597.0 10601.0 10596.5 10601.0 10593.0 10597.5 100.0 104.5 104.5 $ CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 1-23 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAM~A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAM~A RAY, CARRYING ALL RST CURVES PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center WITH THE SIGMA SHIFTS. $ $ 30-JUL-1998 11:28 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 1 DEPTH INCREFIFiTT : 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11248.0 10594.5 RST 11260.0 10594.5 $ CURVE SHIFT DATA - PASS TO PASS (MEAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. RE~zARJfS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAFiE 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 1208479 NBAC RST CPS 1208479 FBAC RST CPS 1208479 SBNA FIL CU 1208479 SFNA FIL CU 1208479 SBFA FIL CU 1208479 SFFA FIL CU 1208479 TRAT FIL 1208479 IRAT FIL 1208479 CIRNFIL 1208479 CIRFFIL 1208479 BSALRST PPK 1208479 SIBF RST CU 1208479 TPHI RST PU-S 1208479 SFFC RST CU 1208479 SFNC RST CU 1208479 SIGM RST CU 1208479 DSIG RST 1208479 FBEF RST UA 1208479 CRRARST 1208479 GRCH RST GAPI 1208479 TENS RST LB 1208479 CCL RST V 1208479 GR BCS GAPI 1208479 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: ** DATA ** DEPT. 11310.000 NBAC. RST '999.250 FBAC.RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST DEPT. 10550.000 NBAC. RST gFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST -999.250 TENS.RST **. END OF DATA ** -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF.FIL -999.250 SFFC.RST -999.250 FBBF. RST -999.250 CCL.RST -999.250 -999.250 -999.250 -999.2S0 -999.250 -999.250 -999.280 -999.250 -999.250 -999.250 -999.2~0 -999.250 SBNA.FIL TRAT. FIL BSAL.RST SFNC. RST CRRA.RST GR.BCS SBNA. FIL TRAT. FIL BSAL. RST SFNC . RST CRRA. RST GR. BCS -999.250 -999.250 -999.250 -999.250 -999.250 38.686 -999.250 -999.250 -999.250 -999.250 -999.250 57.411 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01COi.. DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 ' ~ FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in S~4~?rate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~F~ARY LDWG TOOL CODE START DEPTH GRCH 11279.0 RST 11292.0 STOP DEPTH 10603.5 10603.5 LIS Tape Verification Listing Schlumberger Alaska Computin9 Center SO-JUL-1998 11:28 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11252.0 11246.5 11243.0 11242.0 11239.0 11238.5.. 11233.5 11234.5 .11231.5 11227.0 11227.0 11224.0 11220.5 11222.5 11218.5 11219.5 11214.0 11211.5 11212.5 11208.0 112~9.0 11207.0 11202.5 11205.0 11198.5 11197.5 11200.0 11189.5 11189.0 11191.0 11185.5 11189.0 11178.0 11180.0 11174.0 11171.5 11174.0 11170.0 11168.0 11169~5 11167.0 11164.5 11165.5 11163.0 11161.5 11161.5 11148.5 11147.0 11147.0 11142.0 11138.5 11140.5 11137.5 11135.0 11133.0 11133.5 11130.0 11123.0 11126.5 11119.5 11114.0 11111.5 11105.5 11101.5 11099.0 11098.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88889.0 11253.0 11245.5 11237.5 11234.5 11232.0 11224.0 11214.0 11207.0 112~0.0 11191.5 11187.0. 11175.5 11167.0 11162.5 11149.5 11144.5 11139.5 11135.5 11131.5 11122.0 11111.0 11105.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 11098.5 11087.0 11086.5 11083.5 11073.5 11072.0 11068.5 11068.0 11064.0 11063.0 11062.0 11052.5 11050.5 11035.5 11032.0 11024.0 11012.0 11006.0 11003.0 10998.5 10998.0 10991.5 10987.0 10981.5 10977.5 10974.5 10972.5 10966.5 10966.0 10961.0 10959 5 10955 0 10951 5 10950 5 10947 5 10944 0 10939.5 10938.5 10934.5 10931.5 10926.0 10925 0 10915 5 10908 5 10907 0 10901 5 10900 5 10897 5 10896.5 10889.0 10882.5 10879.0 10876.5 10876.0 10875.0 11089.5 11086.5 11075.5 11070.5 11067.0 11066.0 11056.0 11033.0 11004.0 11001.5 10993.5 10982.0 10976.5 10971.0 10964.5 10954.5 10951.0 10947.5 10942.5 10939.0 10930.0 10913.0 10905.5 10901.5 10881.0 10878.5 11101.5 11089.5 11086.0 11076.5 11072.5 11067.5 11055.5 11041.0 11028.5 11016.5 11011.5 11006.5 11002.0 10988.0 10983.0 10975.0 10970.0 10964.0 10958.5 10952.0 10942.5 10935.0 10928.5 10919.0 10910.5 10903.5 10900.0 10892.5 10885.0 10882.5 10880.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 10 10871.5 10874.5 10870.5 10874.0 10867.5 10871.0 10867.0 10871.5 10851.0 10854.5 10848.5 10852.5 10847.5 10852.5 10840.5 10843.5 10838.5 10841.5 10830.0 10833 . 5 10827.0 10831.0 10826.0 10829.0 10824.5 10827.5 10823.0 10826.0 10821.5 10826.0 10819.0 10823.0 10815.0 10820.0 10813.5 10817.5 10812.5 10816.5 10809.5 10813.5 10808.5 10812.5 10807.0 10810.5 10804.0 10807.5 10801.0 10805.0 10804.5 10797.0 10801.5 10796.5 10797.5 10793.5 10798.5 10790.0 10793.5 10787.5 10790.0 10784.5 10789.0 10784.0 10787.0 10777.0 10779.5 10776.5 10779.5 10768.5 10771.5 10772.0 10766.0 10768.5 10760.0 10764.0 10756.5 10760.0 10751.5 10754.0 10750.0 10754.5 10748.0 10751.0 10746.0 10749.5 10743.5 10746.5 10737.5 10740.5 10735.5 10739.0 10731 . 0 10733.0 10729.0 10731.0 10728.5 10732.0 10726.0 10727.0 10724.0 10725.0 10722.0 10726.5 10720.0 10721.5 10722.5 10717.0 10720.0 10715.0 10717.5 10712.0 10715.5 10711.0 10716.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 11 10702.0 10706.0 10701.0 10706.0 10699.5 10703.0 10699.0 10703.0 10696.5 10699.0 10692.5 10695.5 10689.5 10694.0 10687.5 10692.0 10687.0 10692.0 10683.0 10688.0 10681.0 10685.0 10680.5 10685.0 10678.0 10681.5 10677.5 10682.0 10675.0 10678.5 10674.0 10678.0 10671.0 10674.5 10669.0 10673.0 10667.0 10670.5 10663.5 10668.0 10668.0 10662.0 10665.0 10660.5 10665.0 10658.0 10661.0 10656.0 10659.5 10652.0 10656.5 10651.5 10654.0 10650.5 10654.0 10646.5 10649.5 10646.0 10650.0 10645.5 10648.0 10642.5 10645.5 10640.0 10643.5 10639.0 10642.5 10636.0 10639.5 10632.5 10636.5 10631.0 10634.5 10626.5 10630.0 10624.0 10629.0 10621.5 10625.0 10619.0 10623.0 10615.5 10620.0 10612.5 10617.0 10610.0 10613.5 10609.0 10613.0 10607.0 10611.0 10610.5 10606.0 10608.5 10605.0 10608.5 10603.5 10607.0 10602.0 10605.5 100.0 103.5 103.5 $ THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2ANDGRCHBASE PASS #1, ALSO SIGMA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 12 BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST 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 92 4 66 1 5 66 6 73 7 65 8 68 O.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 ELE~ CODE (HEX) DEPT FT 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 CIRFFIL 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMRST CU 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 13 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DSIG RST 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 GRCHRST GAPI 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1208479 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11292.000 NBAC.RST 3575.260 FBAC. RST 4666.555 SBNA.FIL SFNA.FIL 32.122 SBFA.FIL 56.033 SFFA.FIL 33.026 TRAT. FIL IRAT. FIL 0.478 CIRN. FIL 0.544 CIRF. FIL 0.950 BSAL.RST SIBF.RST 49.812 TPHI.RST 52.536 SFFC. RST 31.241 SFNC.RST SIGM. RST 31.243 DSIG.RST -1.444 FBEF. RST 61.875 CRRA.RST GRCH. RST -999.250 TENS.RST 1195.000 CCL.RST -0.002 DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST GRCH.RST 10603.500 NBAC.RST 2421.212 FBAC. RST 3798.181 SBNA.FIL 29.328 SBFA.FIL 41.153 SFFA.FIL 28.599 TRAT. FIL 0.514 CIRN. FIL 0.919 CIRF. FIL 1.787 BSAL.RST 31.192 TPHI.RST 29.272 SFFC. RST 26.817 SFNC.RST 27.189 DSIG.RST -0.473 FBEF. RST 60.523 CRRA.RST 365.266 TENS.RST 1128.000 CCL.RST 0.010 60.469 1.216 77.218 30.882 2.087 49.631 1.020 26.035 26.706 1.951 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 14 FILE HEADER FILE NUFIBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREFIENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11279.0 10595.0 RST 11291 . 5 10594.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ND?4~ER : .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST ............................ 88888.0 88887.0 88888.5 11257.0 11257.5 11252.0 11253.0 11249.0 11248.5 11246.5 11245.5 11244.0 11242.0 11243.0 11242.0 11237.0 11235.0 11232.5 11232.0 11225.5 11225.0 11224.0 11224.5 11221.0 11221.5 11220.0 11219.5 11218.0 11219.0 11216.0 11217.0 11215.0 11215.0 11214.5 11214.5 11211.5 11212.5 11209.0 11209.0 11207.0 11207.0 11204.0 11204.5 11198.5 11199.5 11197.5 11199.5 11194.5 11196.5 11192.5 11194.5 11189.5 11191.5 11186.0 11187.0 11185.5 11187.0 11181.5 11183.0 11178.0 11179.5 11180.0 11174.5 11175.0 11171.5 11174.0 11170.5 11171.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 15 11168.5 11167.0 11164.0 11161.0 11158.0 11153.5 11151.5 11150.5 11143.0 11138.5 11137.5 11137.0 11135.0 11132.5 11130.5 11128.5 11126.0 11122.0 11121.0 11119.5 11117.0 11099.0 11074.0 11068.0 11062.5 11060.5 11044.5 11029.0 11024.0 11020.5 11012.0 11011.5 11007.0 11002.5 11000.5 10998.5 10997.5 10996.5 10993 5 10985 5 10982 5 10981 5 10975 0 10973 5 10969 5 10966.0 10965.5 10960.5 10959.5 10958.5 10955.5 10951.5 10950.5 10946.0 10945.0 11169.5 11165.5 11159.5 11153.5 11151.0 11140.5 11137.5 11133.5 11131.5 11124.5 11120.0 11026.0 11016.5 11013.0 11008.0 11004.5 11002.0 10999.0 10985.0 10978.0 10974.5 10970.5 10964.5 10961.5 10954.5 10950.5 11167.0 11162.5 11156.0 11145.0 11140.0 11136.0 11131.5 11126.5 11124.5 11122.0 11101.5 11077.0 11072.5 11067.5 11064.5 11049.5 11033.0 11028.5 11017.0 11007.0 11004.5 11001.5 10986.0 10983.0 10974.5 10969.5 10964.0 10958.5 10952.0 10948.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 16 10943.5 10947.0 10940.0 10942.5 10938.5 10942.5 10937.0 10941.5 10933.5 10939.0 10931.0 10934.5 10925.0 10928.0 10928.5 10915.0 10918.5 10914.0 10917.5 10911.5 10915.0 10909.0 10912.5 10908.5 10913.0 10907.5 10911.0 10906.5 10909.5 10904.0 10907.5 10897.5 10901.5 10901.5 10892.0 10896.5 10889.0 10893.0 10885.0 10886.5 10879.5 10883.0 10877.5 10881.5 10875.5 10879.5 10874.0 10877.5 10872.0 10874.0 10867.5 10871.5 10871.0 10865.5 10869.5 10853.5 10857.5 10851.0 10854.5 10854.5 10847.5 10852.5 10846.0 10852.5 10840.5 10843.5 10838.0 10843.5 10837.5 10840.0 10834.5 10838.5 10830.0 10833.5 10827.5 10831.0 10826.0 10829.0 10824.5 10827.5 10823.0 10826.0 10815.5 10820.5 10820.5 10812.5 10816.5 10809.5 10813.5 10808.5 10812.5 10805.5 10809.5 10805.0 10809.5 10804.0 10807.5 10803.0 10806.5 10801.0 10804.5 10799.0 10803.0 10796.5 10801.0 10793.5 10798.5 10791.0 10794.0 10790.0 10793.5 10786.0 10789.5 10784.5 10787.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 17 10781.0 10779.5 10779.0 10776.5 10772.5 10768.5 10763.0 10756.5 10752.0 10750.5 10747.5 10746.0 10743.0 10736.5 10731.0 10729.0 10726.5 10724.0 10720.0 10715.0 10713.5 10712.5 10709.5 10702.0 10701.5 10695.5 10693 0 10691 0 10688 5 10687 0 10684 5 10681 5 10680 5 10677.0 10675.5 10674.0 10671.0 10669.0 10668.0 10664.5 10663.5 10661.5 10660.5 10659.5 10656.0 10651.5 10650.0 10646.5 10640.0 10639.5 10636.5 10636.0 10632.5 10631.5 10628.5 10783.0 10776.0 10771.0 10759.5 10754.5 10751.5 10749.5 10739.0 10717.5 10712.0 10706.0 10698.5 10697.0 10693.0 10688.5 10685.5 10682.0 10678.0 10673.0 10668.5 10665.0 10663.5 10659.5 10653.5 10650.0 10643.5 10640.0 10636.5 10633.0 10784.0 10782.0 10780.0 10772.0 10765.0 10759.0 10754.5 10746.5 10733.5 10730.5 10727.0 10725.0 10723.0 10718.0 10715.0 10706.5 10699.0 10692.0 10685.0 10678.5 10674.5 10672.0 10668.0 10664.5 10654.0 10649.5 10642.5 10639.5 10634.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 18 10626. 10624. 10621. 10619. 10618. 10616. 10615 10615 10611 10607 10604 10602 10600 10596. 10596. 100. $ 5 10630.0 0 10629.0 5 10625.0 0 10623.0 0 10621.5 5 10620.5 5 10620.5 0 10618.5 5 10616.5 5 10611.5 10610.5 5 10608.5 5 10605.5 5 10604.5 5 10601.0 0 10601.0 0 105.0 104.5 RE,lARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST 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 92 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 30-JUL-1998 11:28 PAGE: 19 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI_.d~S MOD ~ SgMP ELEbl CODE (HEX) DEPT FT 1208479 O0 000 O0 0 3 1 1 4 68 NBAC RST CPS 1208479 O0 000 O0 0 3 1 1 4 68 FBAC RST CPS 1208479 O0 000 O0 0 3 1 1 4 68 SBNA FIL CU 1208479 O0 000 O0 0 3 1 1 4 68 SFNA FIL CU 1208479 O0 000 O0 0 3 1 1 4 68 SBFA FIL CU 1208479 O0 000 O0 0 3 1 1 4 68 SFFA FIL CU 1208479 O0 000 O0 0 3 1 1 4 68 TRAT FIL 1208479 O0 000 O0 0 3 1 1 4 68 IRAT FIL 1208479 O0 000 O0 0 3 1 1 4 68 CIRNFIL 1208479 O0 000 O0 0 3 1 1 4 68 CIRF FIL 1208479 O0 000 O0 0 3 1 1 4 68 BSAL RST PPK 1208479 O0 000 O0 0 3 1 1 4 68 SIBF RST CU 1208479 O0 000 O0 0 3 1 1 4 68 TPHI RST PU-S 1208479 O0 000 O0 0 3 1 1 4 68 SFFC RST CU 1208479 O0 000 O0 0 3 1 1 4 68 SFNC RST CU 1208479 O0 000 O0 0 3 1 1 4 68 SIGM RST CU 1208479 O0 000 O0 0 3 1 1 4 68 DSIG RST 1208479 O0 000 O0 0 3 1 1 4 68 FBEF RST UA 1208479 O0 000 O0 0 3 1 1 4 68 CRRARST 1208479 O0 000 O0 0 3 1 1 4 68 GRCHRST GAPI 1208479 O0 000 O0 0 3 1 1 4 68 TENS RST LB 1208479 O0 000 O0 0 3 1 1 4 68 CCL RST V 1208479 O0 000 O0 0 3 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 ** DEPT. 11291.500 NBAC.RST 3568.420 FBAC.RST 4707.500 SBNA.FIL SFNA.FIL 32.572 SBFA.FIL 53.656 SFFA.FIL 34.043 TRAT. FIL IRAT. FIL 0.490 CIRN. FIL 0.541 CIRF. FIL 0.936 BSAL.RST SIBF. RST 48.054 TPHI.RST 49.643 SFFC. RST 32.071 SFNC. RST SIGM. RST 32.045 DSIG.RST -0.874 FBEF.RST 61.031 CRRA.RST GRCH.RST -999.250 TENS.RST 1238.000 CCL.RST -0.002 DEPT. 10594.500 NBAC. RST 2338.859 FBAC.RST 3566.255 SBNA.FIL SFNA.FIL 26.231 SBFA.FIL 45.438 SFFA.FIL 25.546 TRAT. FIL IRAT. FIL 0.516 CIRN. FIL 0.950 CIRF. FIL 1.799 BSAL.RST SIBF. RST 34.685 TPHI.RST 32.522 SFFC.RST 23.564 SFNC.RST SIGM. RST 23.724 DSIG.RST -0.342 FBEF. RST 59.866 CRRA.RST GRCH.RST -999.250 TENS.RST 1140.000 CCL.RST 0.020 61. 526 1.165 72. 515 30. 828 2. 023 50. 087 1. 030 35.878 23. 372 1. 965 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 2O **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUf4~ER: 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 INCREME2Fr 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS ~ERS .......................... 1, 2, 3, RST $ REMARKS: THIS FILE CONTAINS THE ARITHFIETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SETTYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 21 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 NUFiB NUF~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 CIRFRSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARSAV 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 GRCHRST GAPI 1208479 O0 000 O0 0 4 1 1 4 68 0000000000 ....................................................................................... ** DATA ** DEPT. 11298.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV IRAT.RSAV -999.250 CIRN.RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC. RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV GRCH. RST -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 22 DEPT. 10550. 000 NBAC.RST -999.250 FBAC.RST SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV SIBF. RSAV -999 . 250 TPHI. RSAV -999 . 250 SFFC. RSAV SIGM. RSAV -999. 250 DSIG. RSAV -999. 250 FBEF. RSAV GRCH. RST -999. 250 -999. 250 SBNA. RSAV -999. 250 TRAT. RSAV - 999.250 BSAL. RSAV -999 . 250 SFNC. RSAV - 999.250 CRRA. RSAV -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 1 DEPTH INCREblENT: 0.5000 FILE SUF~IA~Y VENDOR TOOL CODE START DEPTH RST 11298.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIM~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 10539.0 28-MAY-98 8C1-205 2123 28-MAY-98 11310.0 11310.0 10590.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 23 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~F~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 11291.0 TOOL NUMBER ........... CGRS-A RST-A 7.000 11447.0 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) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 ~ COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN WITH SCHLUFiBERGER CBT LOG OF NOV. 27 1982 405 BBL OF CRUDE PUMPED TO FLUID PACK THE WELL LOGGING PASSES MADE WITH A PUMPING RATE OF 2 BPM A TOTAL OF 658 BBL OF CRUDE AND 10 BBL OF DIESEL WERE PUMPED THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAF~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CP5V PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V 1208479 O0 000 O0 0 $ 1 1 4 68 0000000000 RCFR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 1208479 O0 000 O0 0 $ 1 1 4 68 0000000000 FSCR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 25 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) HVPV PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS1 UA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 GDCUPS1 MA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 EXCUPS1 UA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 UA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 XP5V PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SHCUPS1 MA 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 PPK 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS1 CU 1208479 O0 000 O0 0 $ 1 1 4 68 0000000000 SBNA PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1208479 O0 000 O0 0 $ 1 1 4 68 0000000000 SIBF PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C.[~S MOD NUIVlB S~IP ELI~,I CODE (HEX) TRAT FIL 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 KHZ 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS1 1208479 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11298.500 CS.PS1 NPDE.PS1 1468.240 NSCE. PS1 AQTM. PS1 0.661 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.855 FSCR.PS1 HVPV. PS1 162.842 BMCU. PS1 NBEF. PS1 27.860 FBEF. PS1 BSTR.PS1 58.832 BSPR.PS1 XPSV. PS1 5.089 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS1 -999.250 IRAT. FIL SFFA.PS1 -999.250 SBNA.PS1 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS1 -999.250 SFFC. PS1 SIGM. SIG -999.250 TRAT. PS1 GR.PS1 67.293 RDIX. PS1 CTM. PS1 95.215 XTM. PS1 CACU. PS1 2.500 BUST. PSi TPHI.PS1 -999.250 TPHI.SIG 2195.122 2.264 202.066 0.000 0.000 0.099 32.519 56.865 1.111 12.158 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 25O -999 250 5163 000 93 750 3 000 -999 250 TENS.PSI 864.000 NPHV. PS1 CRRA.PS1 2.041 NSCR.PS1 CP5V. PS1 5.109 CP2V. PS1 RCLC. PS1 0.000 RCRC. PS1 FPHV. PS1 1542.970 FPDE. PS1 AQTF. PS1 0.661 SF6P. PS1 GDCU. PS1 60.668 EXCU. PS1 NPGF. PS1 0.992 FPGF. PS1 MARC. PSi 0.000 XHV. PS1 X~42V. PS1 -12.368 RXFR.PS1 R3fAK. PS1 0.000 SHCU. PS1 CIRN. PS1 -999.250 CIRF. PS1 DSIG.PS1 -999.250 FBAC. PS1 NBAC. PS1 -999.250 SFNA.PS1 SBFA.PS1 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS1 SIGM. PS1 -999.250 SIBF. SIG TRAT. SIG -999.250 TRAT. FIL CRNI.PS1 452.904 CRFI.PS1 TAV. PS1 95.031 FICU. PS1 BUSP. PS1 3.000 RSXS. PS1 CCLC. PSl 0.029 RSCS. PS1 1496.583 0 142 12 056 0 000 1497 079 152 376 3 551 0 997 200 370 0.000 26.016 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 221.889 2.329 8878.00O 8463.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 27 **** FILE TRAILER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 2 DEPTH INCREFiENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST 11321.0 $ LOG HEADER DATA STOP DEPTH .......... 10548.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GA~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 28-MAY-98 8Cl -205 2123 28-MAY-98 11310.0 11310.0 10590.0 11291.0 TOOL NUMBER ........... CGRS-A RST-A 7.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 28 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 11447.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE Tb~4PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REM_ARKS: TIED IN WITH SCHLUMBERGER CBT LOG OF NOV. 27 1982 405 BBL OF CRUDE PUMPED TO FLUID PACK THE WELL LOGGING PASSES MADE WITH A PUMPING RATE OF 2 BPM A TOTAL OF 658 BBL OF CRUDE AND 10 BBL OF DIESEL WERE PUMPED THIS FILE CONTAINS 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 73 368 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 29 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS2 S 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BMCUPS2 UA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 GDCUPS2 MA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 30 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) MARC PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BSALPS2 PPK 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BSALSIG PPK 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 31 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) BUST PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 1208479 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11310.000 CS.PS2 NPDE.PS2 1468.202 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 ~42V. PS2 -12.172 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE.PS2 1.719 FSCR.PS2 HVPV. PS2 162.598 BMCU. PS2 NBEF. PS2 29.671 FBEF. PS2 BSTR.PS2 60.956 BSPR.PS2 XPSV. PS2 5.089 XP2V. PS2 RXLC.PS2 0.000 PO~C.PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT. PS2 GR.PS2 86.828 RDIX. PS2 CTM. PS2 94.238 XTM. PS2 CACU. PS2 2.500 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG 1767.709 2.125 202.308 0.000 0.000 -0.195 34.277 60.455 1.150 12.188 0.000 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 12160 000 93 750 3 000 -999 250 TENS.PS2 CRRA.PS2 CP5V. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2 V. PS2 RXAK . PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP.PS2 CCLC. PS2 1066.000 NPHV. PS2 1496 583 2.038 NSCR.PS2 0 202 5.099 CP2V. PS2 12 158 0.000 RCRC. PS2 0 000 1540.529 FPDE. PS2 1499 368 0.661 SF6P. PS2 154 423 60.996 EXCU. PS2 3 551 0.989 FPGF. PS2 0 994 0.000 XHV. PS2 200 127 -12.348 RXFR.PS2 0 000 0.000 SHCU. PS2 31 544 -999.250 CIRF. PS2 -999 250 -999.250 FBAC. PS2 -999.250 -999.250 SFNA.PS2 -999.250 -999.250 SFNA.SIG -999.250 -999.250 SFNA.FIL -999.250 -999.250 SIBF. PS2 -999.250 -999.250 SIBF. SIG -999.250 -999.250 TRAT. FIL -999.250 447.793 CRFI.PS2 219.775 95.031 FICU. PS2 2.295 3.000 RSXS.PS2 8878.000 0.002 RSCS.PS2 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 32 **** FILE HEADER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3FI~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST $ LOG HEADER DATA DATE LOGGED: 11322.0 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 .......... 10536.0 TOOL STRING (TOP TO BOTTOM) VE1VDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESERVOIR SATURATION $ BORE~OLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 28-MAY-98 8Cl -205 2123 28-MAY-98 11310.0 11310.0 10590.0 11291.0 TOOL NUMBER ........... CGRS-A RST-A 7.000 11447.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 33 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN WITH SCHLUMBERGER CBT LOG OF NOV. 27 1982 405 BBL OF CRUDE PUMPED TO FLUID PACK THE WELL LOGGING PASSES MADE WITH A PUMPING RATE OF 2 BPM A TOTAL OF 658 BBL OF CRUDE AND 10 BBL OF DIESEL WERE PUMPED THIS FILE CONTAINS 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 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 34 TYPE REPR CODE VALUE 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 ELE~ CODE (HEX) DEPT FT 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CRRAPS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CP5V PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 C~2V PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BMCUPS3 UA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS3 UA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 XM2V PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RXPR PE3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 1208479 O0 000 00 0 7 1 1 4 68 0000000000 RXRC PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SHCUPS3 MA 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 35 NAFIE SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~I CODE (HEX) ....................................................................................... BSALPS3 PPK 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BSALSIG PPK 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1208479 00 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 KHZ 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 K~Z 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 1208479 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 36 ** DATA ** DEPT. 11310.000 CS. PS3 1497.527 TENS.PS3 NPDE. PS3 1463.586 NSCE. PS3 2.287 CRRA.PS3 AQTM. PS3 0.441 CHV. PS3 202.066 CPSV. PS3 CM2V. PS3 -12.191 RCFR.PS3 0.000 RCLC.PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 FSCE. PS3 1.860 FSCR.PS3 0.109 AQTF. PS3 HVPV. PS3 163.818 BMCU. PS3 34.863 GDCU. PS3 NBEF. PS3 30.132 FBEF. PS3 61.595 NPGF. PS3 BSTR.PS3 62.685 BSPR.PS3 1.176 MARC.PS3 XPSV. PS3 5.089 XP2V. PS3 12.188 XM2V. PS3 RXLC~PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC. PS3 SFFA.PS3 -999.250 SBNA.PS3 ~999.250 SBFA.PS3 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS3 -999.250 SFFC.PS3 -999.250 SIGM. PS3 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG GR.PS3 207.052 RDIX. PS3 46973.000 CRNI.PS3 CTM. PS3 84.473 XTM. PS3 84.473 TAV. PS3 CACU. PS3 2.500 BUST. PS3 3.000 BUSP. PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC. PS3 1185.000 2.044 5.089 0.000 1525.880 0.441 60.668 0.995 0.000 -12.387 0.000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 451 856 94 888 3 000 0.002 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL $IBF. PS3 SIBF. SIG TRAT. FIL CRFI. PS3 FICU. PS3 RSXS. PS3 RSCS. PS3 1491.700 0.486 12.158 0.000 1495.744 151.864 3.945 0.999 200.127 0.000 30.894 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 221.050 2.319 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/29 ORIGIN : FLIC TAPE NAFIE : 98383 CONTINUATION # : 1 PREVIOUS TAPE : CO~ : ARCO ALASKA, DS 1-23, PRUDHOE, API # 50-029-20854-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JUL-1998 11:28 PAGE: 37 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/29 ORIGIN : FLIC REEL NAME : 98383 CONTINUATION # : PREVIOUS REEL : COMF~a~f : ARCO ALASKA, DS 1-23, PRUDHOE, API# 50-029-20854-00 *CASED HOLE EDIT* WELL: D.S. 1-23 FIELD: PRUDHOE BAY API #50-029-20854-00 COMPANY: ARCO ALASKA INC. COMMENTS: 3 RST monitor passes & average CNTY: NORTH SLOPE STATE: ALASKA LOG: 28-MAY-98 TAPE: 29-JUL-98 6250 BPI *LDWG FORMAT* KB ELEV: 74.0' RUN #: ONE START: 11291.0' STOP: 10590.0' JOB #: 98383