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196-158
STATE OF ALASKA OIL AND GAS CONSE VAT ON COMMISSION NOV 15 2019 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well C s : ... Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6, Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 10/24/2019 196-158 4 319-249 3, Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 9/18/1996 50-029-20064-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 9/24/1996 PBU 02-04A Surface: 1064' FNL, 1771' FWL, Sec. 36, TI 1N, R14E, UM • 9 Ref Elevations KB 64.00 17. Field/Pool(s): Top of Productive Interval: 3367' FNL, 1248' FVJL, Sec. 36. T11N, R14E, UM ' GL 31.00 BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1442' FNL, 1207' FWL, Sec. 36, Tl 1N, R14E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface / Surface ADL 028308 4b. 41d. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 688525 y- 5950159 Zone - ASP 4 - 11766'/9007' x 74-017 TPI: x- 688061 y- 5947845 Zone - ASP 4 - 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MDf VD: Total Depth: x- 687971 y- 5949768 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13, Water Depth, if Offshore: 21. Reddll/Lateral Top Wrdow MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9306'18823' r 22. 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 OR, MWD 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 30" 157.5# 8 35' 115' 35' 1 115' 39" 20" 1334994 K -59H-40 35' 1207' 35' 1207' 26" 755 ax Fondu 13-3/8" 72# N-80 34' 2694' 34' 2694' 17-1/2" 625 sx Fontlu, 365 sx Class'G' 9-5/8" 70/400/435# L-80300-95 33' 9306' 33' 8823' 12-1/4" 420 sx Class'G', 1708 ax Class'G' 7" 26# 1 L-eo 31' 8509' 31' 8092' Tieback 677 ax Class'G' 2-7/8" 6.5# '--r.613- 1 11766' 8246' 9007' 3-3/4" 39 Bbl. Class'G' 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# 13Cr80 8740' 8402'/ 7992' x5-1/2" 17# L-80 x 4-1/2" 12.6# N-80 8572'/ 8151' r�+ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. AT _0(zs Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed'D information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED 2290'- 2300' Perforate Tubing and 7" Tieback Liner New Surface 105 Bbls Class'G', 57 BUS Class'G' Surface .5 Blois AS 1 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Data of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Pedotl �► Flow Tubing Press Casinc Press: Calculated 24 Hour Rete �► Bbl: Gas -MCF: Water Bbl: Oil Gravity- API(Conn: Form 10407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINALon Iy ,�'f �y n�eu�R►g RBDMSNOV 2 2 2019 � &as 12/4,114 (1 28. CORE DATA Conventional Corefs) Yes ❑ No 0 Sidewall Cores Yes ❑ No D 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 71 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9330' 8843' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 23SB-Zone 2B 9330' 8843' 21 TS - Zone2A 9537' 8971' - Zone 1 9657' 9023' - Formation at total depth: Zone 1 9657' 9023' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram 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. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael Authorized Title: M SPRNIfi.t Contact Email: Michael. Hibbert@BP.com Authorized Signature. Date: 4l h Contact Phone: +1 907 564 4351 INSTRUCTIONS General: This form is designed for submitting a complete and correctwell 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 in given 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 forthe 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 farm: 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 orwell test results. Forth 10407 Revised 5/2017 Submit ORIGINAL Only =- DRYHOLE SPF 30'GOND, 114' AOR= REMOVED :LEV= 64' A 9494 - 9504 O :LEV = SURFACE 20;7 0" CSG, 133#/ 120T 4rgk = 94' 11128' 94#. K -55/H-0(), n MD = 9355' D = 18.750" n TVD = 88WW- yam. LNR 1604' = 9764-9776 47# HYD 563 05/19/04 XO O L-00 1.0733 bpf, D = 8.681• 1 13-3/8" CSG. 72#. N-80. D = 12347- 2984' >02-04A SAFETY NOTES: WELLGLE *ORI WELL OR •" 4-12" CHROME TBG "` ORIG WELLBORE NOT SHOWN 1' 30•, 20", & 13-3/8' CUT BB -OW Minimum ID = 2.387" @ 8679' 3-1/2" x 2-7/8" XO 7• LNR 260, L-80 BTC -M, .0383 bpf, D = 6.276' FULLY ABANDONED WELL IS CUT OFF 5.31 BELOW TUNDRA (10/25/19) 4-1/2' TBG, 12.6#, 13CR-80 VAM TOP 8579' -- .0152 bpf, D = 3.958' 5-12" TBG-PC,17#, L-80, .0232 bpf, D = 4.892" 8616' / 4-12" TBCrPC,12.6#, N-80, 8740' 1_4-1'2=2 0152 bpf, D = 3.958" 9-5/8" CSG, 47#, S00-95, D = 8.681" 9306' PH2FORATION SUMMARY RE= LOG. BHCS on 10/9/1970 ANGLEAT TOP PERR 78-@ 9736' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2" 6 9494 - 9504 O 03/15/05 2" 6 9736-9756 O 05/19/04 2" 6 9764-9776 O 05/19/04 2• 4 9862-10222 0 11/09/99 2-1/8" 4 10250-10350 O 0927/96 2-1/8• 4 10450-10750 C 0927196 2-1/8" 4 10830 -11150 C 09/27/96 2" 4 11250-11290 C 11/09/99 2" 4 11350-11580 C 11/09/99 9-5/8' =3.813• BG & TAXI - 2463' 95/8' CSG PATCH (1027/80) - 8366' TOP 8 SOT & T& TBG CMT GAS LFT MANDRR S ST I MD I TVD DEV TYPE I VLV I LATCH I PORT I DATE 23502 1 3494 6201 5976 14 25 KBG2 KBG2 -DONE -SO BK I BK 1 16 20 07116/08 07/16/08 -S IA #2 & 1 = COV HIED BY CMT 8-372'—I 4-12" HES X NP, D = 3.813' o40� 7" X 4-12• BKR S-3 PKR D = 8438' 4-12' HES X NP, D = 3.813" mer 4-1/2" PX PLUG (06/11/171 8481' 7" HES ES CEMWIH2 7'X5-12' PORT®XO 8609• 9-5/8"X 5-1/2" UNIQUE OVER& DATE REV BY COMMENTS 8572' 9-5/8" X5-12' BKR SAB PKR 8579' 4-12" MU LESHOE, D=3.958" 8615 5-12" x4—w— XO, D = 3.958- SIDETRACK (02-04A) 05/14119 8673- 71 4-1/2"GSEAL SUB, D=3.000• 8675' 4-12" OTB X NO? D = 3.813" (B 8679' 3-1/2" X 2-7/8" XO, D = 2.387" 8738' 1-14-12" BKRSHEAROUTSUB(BENNO 6712' B -MD LOGO ON 06!24/89 9-5/8" MLLOUT WPDOW 9306' - 9321' 10386' 2-7/8" BKR GBP, 05/19/04 _F 10805 2-7/8• BKRCBP, 07/1411 0 11766' ID=2.441" 11766' DATE COMMENTS DATE REV BY COMMENTS 10M4/70ORIGNAL COMPLETION 05192/19 MRD/JMD CEMENT PLUG (04126/19) 09130196CO SIDETRACK (02-04A) 05/14119 JNUJMD CORRECTED CMT DEPTH 07109108RWO MKP/JMD 08/01/19 LLG/JMD TBG & CSG PUNCH 07131/19 0620117 SET PX PLUG (06111/17) 08/13/19 JJUJMD CMT PLUG 08111/19) 0228119 DRY HOLE TREE 10/31/19 JA/JMDFULLYABANDONED WE0321!19 TBG PUNCH (03/11/19) 11M4/19 JNUJMD ADDED BF HES CBP, 05/11/02 2-7/8' DAVIS LYP FLOAT SHOE PRUDHOE BAY UNIT WELL: 02-04A PERMIT No: 1961580 API No: 50-02320064-01-00 SEC 36, T11 N, R14E, 1065' FNL & 1771'F SP Exploration (Alaska) 0/0/100. RD 2 "Cameron valves on I/A. RU 2" 5000 Integrals with 1502 block valves and caps on working and companion sides. O/A would not bleed down. Started bleed at 100psi 7/14/2019 and ended at 100psi 7bbl's all fluid. Job Complete. See log. FWHP 0/0/100. ***WELL S/I ON ARRIVAL*** (P&A) DRIFT TO 2,400' SLM / 2,419' MD W/ 4-1/2" X-CATCHER (No issues). PERFORM BASELINE PRESSURE / TEMP LOG W/ H.E.S. MAXFIRE TOOL TO 2,300' MD. PUNCH 4-1/2" TBG & 7" LNR FROM 2,290' MD TO 2,300' MD W/ H.E.S. MAXFIRE & 10'x 2.00 PERF GUN. GOOD INDICATION OF T x IA x OA COMMUNICATION. 7/31/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/UO = 0/0/252 Confirm circulation paths (P&A) Pumped 10 bbls of 50/50 meoh down tubing, up the IA to an open top tank. Confirmed returns at open top tank. Line up to take returns from the OA. Pump 5 bbls 50/50 meoh, 50 bbls of 140* surfactant wash and 75 bbls of 9.8 ppg NaCl. Shut down for 2 hours and allow brine to swap with the diesel in the OA. 8/1/2019 ***Continued WSR to 08/02/19*** After 2 hour soak circulated remaining 74 bbls of 80* 9.8 ppg NaCl down tubing taking returns from OA. Freeze protected surface lines, FWHP's 0/11/7 Valve positions at 8/2/2019 departure, SV/C MV/C IA/OTG OA/OTG, 1/4 Valves SI to OTT, DSO notified of well status SLB Fullbore pumping crew Objective: Plug and Abandon TxIAxOA from 2300' MD to surface.. MI/RU/PT SLB cementers. Pumped 5 bbls 50/50 to verify circulation down TBG with IA returns to OTT. Pumped 5 bbls 50/50 to verify circulation down TBG with OA returns to OTT. Pumped 2 bbls FW spacer followed by 105 bbls 15.8 ppg class G CMT down TBG with OA returns to OTT, clean cement returns. Pumped 57 bbls 15.8 ppg class G CMT down TBG with IA returns to OTT, clean cement returns. S/I SV/SSV. **Continued on 08/12/19 WSR** 15.8 ppg class G cement TxIAxOA TOC = surface 8/11/2019 EST BOC TxIAxOA = 2300' MD / 2300' TVD **Continued from 08/11/19 WSR** SLB Fullbore pumping crew Objective: Plug and Abandon TxIA from 2300' MD to surface. Secure well, DHD blow N2 across IA to flush Integral CSG valves, unable to blow N2 across OA without companion valve. Flush surface lines, choke 8/12/2019 manifold, release equipment. IA/OA = OTG. SV/MV/QTR turns = C. DSO Notified. RDMO T/I/O = 10/10/VAC. Temp = SI. WHPs (Post P&A). No wellhouse, flowline, or AL. Dry hole tree and temporary scaffolding installed. 8/13/2019 SV, MV = C. IA, OA = OTG. 03:30 *** Permanent P&A. *** Excavate around wellhead to 17'. Cut wellhead 11'6" below pad grade. 20" X 30" conductor annulus full of gravel. Removed 1' of gravel and topped with AS-1 cement. Pad elevation 31.2', tundra elevation 25.0'. Wellhead cut = 5.3' below tundra grade. AOGCC witness of TOC and marker plate install is Jeff Jones. Pulled shoring box and backfill excavation with gravel. 10/24/2019 *** Job Complete *** M~, V ♦ 1 `1 � � *+g a Z� AIX rN • l 0 +t 4 N 71 ay THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Michael Hibbert Well Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 02-04A Permit to Drill Number: 196-158 Sundry Number: 319-249 Dear Mr. Hibbert: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, teL. Chrmelowski Commissioner DATED this 12 day of June, 2019. ZBDMB*t-" 3UN 13 2919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED r)�;-s C <r e./17 MAY 14 2019 1. Type of Request Abandon ® • Plug Perforations ❑ Fracture Stimulate ❑ RepairWell ❑ types q(LutQ{Av� gO Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing❑ Chane rlhEltla(W,-6>(ref n Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0 • 5. Permit to Drill Number. 196-158 ' 3, Address: P.O. Box 196612 Anchorage, AK 99519-8812 Siretigraphic ❑ Service ❑ 6. API Number: 50-029-20064-01-00 . 7. If perforating: B. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No R1 PBU 02-04A ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028308 • PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (tt): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 2984, Junk (MD): 11766 9007 2984 2984 84as, lines, lM5,11210 None Casing Length Size MD TVD Burst Collapse Conductor 80 30" 35-115 35-115 880 Surface 1172 20" 35-1207 35-1207 2320 / 1530 15001520 Intermediate 2680 13-3/8" 34-2694 34-2694 5380 2670 Intermediate 9273 9-5/8" 33-9306 33-8823 6870/8150/6820/7510 4760/5080/3330/4130 Tieback Liner 8478 7" 31-8509 31-8092 7240 5410 Liner 3093 2-7/8" 8673-11766 8246-9007 1 10570 1 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9494- 11580 8951 - 9009 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 / L-80 / N-80 29-8740 Packers and SSSV Type: 4 1W" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8402/7992 5-1/2" Baker SAB Parker 8572/8151 12. Attachments: Proposal Summary 0 Wellbore Schematic m 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development m Service ❑ 14. Estimated Date for Commencing Operations: June 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 ` 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert, Michael be deviated from without prior written approval. Contact Email: Michael.HibbertCMBP.Wm Authorized Name: Hibbert, Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engineer Authorized Signature: Date: d COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Suntlry Number: n I n /✓\/"A1 Plug Integrity ❑ Test q Mechanical Inlegn Tes[ ❑ Location Clearance AABOP Other: P,S O)Lo CGOC tJ M2 C WT �j �i. �. 41" . W Post Initial Injection MIT Req'd9 Yes ❑ No ❑ .i Spacing Exception Required? Yes ❑ No !� Subsequent Form Required: )0_ q �� T • APPROVEDBYTHE q Approved by: COMMISSIONER COMMISSION Date: ( I / Form 10-403 Revised 04/2017 ORIGINAL IBDMS E�'JUN 13 2019 1,6.R Submit Form and Approved application is valid for 12 months from the date of approval.s7(t attachments in Duplicate Ae � 5-/6 -/y 02-04A P&A Detailed Procedure Rev 3 Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Paulina Meixueiro (907) 564-5971 History 02-04 was completed in 1971 with a Gen 1 wellhead and three string casing design. The outer casco sing is set in permafrost. GWO has determined that these wells are at risk for sudden wel ead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Well 02-04A was secured in June 2017 with a tubing tail plug. In March 2019 slickline punched the tubing from 8,350'-8,355'. The tubing and IA were circulated to 9.8 ppg brine. The tubing tail plug was tagged and a CMIT-TxIA passed. A lower cement plug was placed in the tubing and IA from 8,350'- 3,400'. This cement was tagged and tested on 5/10/19. The TOC was tagged at 2984'. The well passed a CMIT-TxIA to 2500 psi. Objective Complete the full plug and abandonment of well 02-04A. Place the surface cement plug, cutoff wellhead 3' below tundra grade, and install marker plate. Procedural steps Valve Shop 1. Swap casing valves to integral valves at WSL discretion. Slickline/Ful[bore 1. Perforate 4-1/2" and 7" from 2290'-2300'. This depth was chosen to avoid the potentially tight restriction in the 7" x 9-5/8" annulus where there is a casing patch from 2433'-2453'—. ➢ Down tubing and up IA with 9.8 ppg brine – 5-10 bbls ➢ Down tubing and up OA with 50 bbls of hot surfactant wash ➢ Down tubing and up OA with 9.8 ppg brine – 75 bbls 3. Shutdown pumping for –1-2 hours and let 9.8 ppg brine in the OA swap with the diesel that was in the OA between 2,300'-3,400' 4. Pump an additional 60 bbls of 9.8 ppg brine down the tubing taking returns form the OA. Fullbore 5. Pump �ce, mpt job down tubing while taking returns from the IA and OA. The top of cement in the tubing, IA, and OA will be at surface. ➢ 2 bbls MEOH ➢ 2 bbl FW spacer ➢ 157 bbis of Class G cement (actual volume is 137 bbls) Take returns from the OA until clean returns are seen at surface. Take an additional 10 bbls of clean returns to get good quality cement at surface in the OA ➢ Swap to taking returns from the IA and pump until clean returns are seen at surface. Take an additional 10 bbls of returns to get good quality cement at surface in the IA. ➢ Shut in tubing IA and OA. DHD 6. Assist Fullbore with cement job and pump a little N2 across the wellhead to remove some cement and at least increase the chance of opening the valves. This will make it safer to verify no pressure before cutting. 7. Bleed all Wellhead Pressures to 0 psi. 8. Monitor Wellhead Pressures after at least 24 hours has elapsed since the pressures were bled to 0. Special Projects 1. Notify AOGCC Inspector of�llhead removal. (24-hour minimum notice) 2. Photo document all steps. 3. Cut off all casings and wellhead —3' below tundra grade. 4. Top off tubing and annuli with cement if needed. 5. Install marker cap on outermost casing string. The marker plate should have the following information bead welded onto it: a. BP Exploration Alaska b. Permit to Drill number - 1961580 C. Well Name — 02-04A d. API Number -50-029-20064-01-00 it TFfE= CIN V%LU FAD= ACIWl1JR= cwv BA10611C Ka, BEV - BF. B B/ _ 84' KOP= Maa Angle = 94• � 11128 NIUM&C= 8x55 DakimM= 89001 S6 D - 16 750• 14977�98' 8LT1Z FD 553 XO TO L-80 DS 02-04 Current Status 1..0733 bpi, D = 6.861• 1 1}3AT CSG, 72a, MBD, D = 12.347- 0484' and IA cemented from 8350' MD to 2984' Minimum ID =2.387" @ 8679' 3-112" x 2-718" XO "Casing Cement — @ 6536' w/ 30% washout. logged cement from 6007'-2740' gh stage collar @ 6007' logged cement from 2438' to 1740' gh stage collar @ 2438' rated from EZ cementer @ 1665' to LOW bpr D 3 958' 1 9-615 Cnr- 47u Snn n5 In A an V PERPONATION SLAWRY Rff LOO BRCS w 101WI970 ANGLE AT TOP PERF: 78• C 9736 Nola: Refer to %dlebon 03 for histm cai pert data SIZE SPF INTERVAL OpYSgz DATE 2' 6 9494 - 9604 O 03r151O5 2 6 9736.9756 O 0511904 2 6 9764-9776 O 0511904 2• 4 9862 - 1= 0 1109199 2-118' 4 10250-10350 0 9627M 2-118' 4 10450 - 107W C 0®'27!96 2-1/B" 4 lra v - 111.56 C 114•J7/96 2• 4 11250-11290 C 1110999 2• 1 4 11M -115M C 1109199 NOTES: W ELL ANGLE > 70• @ 9666' 'CHROME TBG •'• ORIG WELLBORE NOT 20•, i 13-318• CUT W3.0 W GAS LFT MAPDRaS ST MD NO DEI/ TYPE I VLV I LATCH PORE DATE 2 1 3502 I 6201 3494 I 5976 14 I 25 KBG2 I KB02 OOkE SO BK BAS 16 20 07/18X18 07/1&08 X 4-117' BKR S3 RSR,. D = 3.670' 12• HES X NP. ID - 3.613• 12' RS PLUG (0&11117) HFS Es C&AWrBt X 8-1/T aKR SAB PKR I WIW H5-112•X4-12'XO.D=3.956• I 9.518' MLI..OI/P WINDOW 9306 - 9321' 10.886' 2-78' BKR C&.0511WO4 TD 11746' 1121W IA 3 PRUDHOEBAY UNT VU131_ 02-04A FHW W: 1961580 AR 1h 50-029-20064-01-00 SEC36,T11HR14E,1065'F1L61771'FN. DATE REV BY COWA3,ITS 047E FEV BY ODMYSdIS 10r1N0 ORi©NILL COMPLETION 12/14/10 CMJMD ORLGORAFTOORPECR7NS 08f70196 CTO911DEiRACK(02-04A) OV04111 KSBIPJC FI44LMOCOdRR7TIONS 07MMO WES RNO 0501117 PLHAU 30•, 20. 6 13-31W COfdiB:�11DK' 0711WOB KOC75V OLV CJO(07H&M 05x02117 RIWJAD ADDEDCUTTOWCOND&20-CSC 12114MO CWJMD WRP RUE)(07M) OSM17 .BIJMO SET PXPLLJD(06MV1 BP Fxplonbon(Alaska) 12/14110 CWJMD PEW COFJEL11ON(03/1505) Lid 3 u:: X91 N13.LNFAD- CM ACTUATOR= BAKER KB LLLV = OP BF FLEV - 6 KOP=_ O Abz-Ante= - 94'�1112P Dabmkv= 9355 Diti1mTVD= saw S5 ID=18758 Ibing, IA, and OA cemented from 2300' MD surface .0733 bpf. D - 8.681' 'CM 724. 480. D = 12 NOTES: WELL AMA E> 70' Q 9666' DS 02-04 Proposed Status "CHROMETEG"'OWWRI RENOT and IA cemented from 8350' MD to 2984' Minimum ID = 2.387" @ 8679' 1 3-1120 x 2-716" XO 7- LNR. 266, L-80 BTC -M, -�� -8477 .0387 bpt, D = 6276' - - .0152 bpr, D = 3.958' rOr,FC,176, L-80..0¢32 bpf, D= 4.892' 6616' TOP OF 2-7/6'LJ6i-CT 0677 4-12' TBGPC,128ti, 4180, .0152 Opl. D = 3.868' PEWORNI ON SU JIM AW FEF LOG: BHCS on 101911970 ANOL.E AT TOPREW: 78' C 9736 Not_ Refer b Production DB for hiewdeel pert data SIZE SPF HTERVAL OprJSgz DATE 2' 6 9694 - 9504 O 01115M 2' 6 9736-9756 O 0511901 7 6 9764 - 9776 0 05719N4 7 4 9862-lum O lU09199 2-115' 4 18250 -10350 0 0927198 2-1/r 4 10450- 10750 C 0927796 244 4 lr6t'n - 11150 C 119 /7 71 9 0 2' 4 11250 -11290 C 1110699 2' 1 1 1 11350 - 115W C I 11MM a X M, D= GAS LFTMAA43F>8S 6201 15976 25 I KBG2 L_ - I S.K..20 372' 412'FW X W D 3813' 402' 7' X 4-12' BKR S-3 RCR D - 3 870- 1-1/C L1fY FP9YnP n=3Ptl•1 6{16' (--{5-12'X4-12'XO,D=3.95r PRLCHOEHAY 1.947 WELL 02-04A FU MT W: /1961580 Afl W. 50-029.20084-01-00 SLC 36, Tl IR R14E. lOW M & 1771' FNL 6673' 4.118' 0 SEAL SA D • 3.000' 6676 4-WOTISXNP,D•3.IWHr(1 9-5v FALLOW VWCCYw 9]96'-9321' I 11 UN9q I 4 PRLCHOEHAY 1.947 WELL 02-04A FU MT W: /1961580 Afl W. 50-029.20084-01-00 SLC 36, Tl IR R14E. lOW M & 1771' FNL DATE REV BY OURGAEl 5 DATE FEV BY cowke 5 1011490 OR MALCOMPLETION 12/14/19 CFHAC CF&GDRAFr OD 6 01103=6 CTD3WE RACK(0&04A) 01/04111 KSFYPAC FML MG WRIM110 L9 07mme Fos I&VO 05101117 RIH'J6D 3P, 20' 613318' COMB 07119418 KOCJS7 GLV C/O (07116r08) 05/02117 PJffJAD ADDEDCWT03(rOOM&20'CSG 12M4110 C16FJAA WRPFW.®(07MR) 00!20117 JB1JA0 SEr PXPLUG(06mw7) BP Expbranon (Alaaba► 12M4110 fii1,IAD PEW OORRBC;TON (03115!05) 4 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 02-04A (196-158) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 V O 10,000 M _ w O o a+ � N V' ,y ~O 1,000 u 7 V M 100 3 O s H 10 1 lan-1995 •Cum. Jan -2005 Prod •153,943,013 Produced Gas (MCFM) a GOR Produced Water (SOPM) Produced Oil (BOPM) wr = liLn\I'�•1�1 = W' Awl U� C1LL " llzzllw�7 �� �—� iii■ �� �Ra����C��� aa�•riii���. MSO I�.�N•�=a����l CI����C ��_� Jan -2000 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) a GOR Produced Water (SOPM) Produced Oil (BOPM) 10,000,000 Ou v 1,000,000 O_ O 100,000 O 7 S 10,000 0 1 Jan -2020 SPREADSHEET_1961580_PBU_02-04A_Prod-Inject_Curves_Well_Oil_V120_20190516.xlsx 5/16/2019 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 02-04A (196-158) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 C G 100,000 LL u �0 10,000 m _ t7 O w O m m LL c 1,000 - V 7 V C 100 0 0 r H 10 • 1 1 ■ � 1 ® VIII■ � VIII♦ =iRio— ■■4�'yllt�,ii mow!'-•�i"r�� I '' �' Y��iinri��ir'"�■ ----------------------- ------------------------- 1 - Jan -1995 Jan-2000 Jan -2005 Jan -2010 Jan -2015 Produced Gas (MCFM) = GOR -. Produced Water (BOPM) Produced Oil (BOPM) 10,000,000 m m 1,000,000 N O M 100,000 � z 0 10,000 T 0 t W lu 1,000 0 c 100 a m 0 10 T 1 Jan -2020 SPREADSH EET_1961580_PBU_02-04A_Prod-I nject_Cu Nes_W ell_Oil_V320_20190516.xlsx 5/16/2019 STATE OF ALASKA RE C E i 'V f" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I J ACJ 4 r 1. Operations Performed . -1— Abandon '—Abandon ❑ Plug Perforations 0 Fracture Stimulate Cl Pull Tubing ❑ OperationsAMC CI Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing 13 Change AppR 9` IOU, Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Omer: Secure Reservoir 0 2. Operator Name' BP Exploration (Alaska), Inc 4. Well Class Before Work Size: 5. Permit to Drill Number 196-158 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ Conductor AK 99519-6612 Stretigraphic ❑ Service ❑ 1 6. API Number: 50-029-20064-01-00 7. Property Designation (Lease Number): ADL 028308 15. Well Class after work: Exploratory ❑ 8. Well Name and Number: PBU 02-04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 2320 / 1530 1500/520 Intermediate PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: 34-2684 34-2694 5380 2670 2984, 8436, Total Depth: measured 11766 fast Plugs measured 10386, 10805, 11210 feet true vertical 9007 feet Junk measured None feet Effective Depth: measured 2984 feet Packer measured 8402, 8572 feet true vertical 2984 feet Packer true vertical 7992.8151 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 35-115 35-115 880 15. Well Class after work: Exploratory ❑ Surface 1172 20" 35-1207 35-1207 2320 / 1530 1500/520 Intermediate 2660 13-3/8" 34-2684 34-2694 5380 2670 Intermediate 9273 9-5/8" 33-9306 33-8823 6870/8150/6820!/510 4760/5080/3330/4130 Tieback Liner 8478 T' 31 -8509 31-8092 7240 5410 Liner 3093 2-7/8" 8673-11766 8246-9007 10570 11160 Perforation Depth: Measured depth: 9494-11580 feet True vertical depth: 8951 -9009 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): 41/2" 12.6% 13Cr80 x 5-1/2' 179 L-80 x 41/2" 126# N-80 4-1/2' Baker S-3 Parker 5-1/2' Baker SAB Parker including volumes used and final pressure: 29-8740 8572 29-8309 7992 8151 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: Shut -In 14. Attachments:(mu,re per20MC25.070.25.071,a25.283) Daily Report of Well Operations 21 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 15. Well Class after work: Exploratory ❑ Development El Service ❑ Stratigraphic ❑ 16. Well Status after work: 1 GSTOR ❑ WINJ ❑ Oil 0 Gas ❑ WDSPL ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Worthington, Area J Sundry Number or N/A if C.O. Exempt: 319-027 Contact Name: Hibbert, Michael Authorized Title: Interventions 8 Integrity Engineer Contact Email: Michael. HibbertQBP.corn 01 Authorized Signature: ' f Contact Phone: +1 907 564 4351 �r ,�yD�atte:: Form 10404 Revised 04/2017 j� i1tp �i►r91 RBDMS! L -/MAY 151019 Submit Original Only T/1/0=300/400/170 R/D production tree, R/U Dryhole tree P&A #4. Torqued to API specs. 2/26/2019 PT'd to 4250 psi. Pass. FWP's 300/400/170 see log for details. ***Job Complete*** TWO = 280/400/170. Temp = SI. WHPs (WIE Req). No well house, flowline, or scaffold. Dryhole tree installed. 3/1/2019 SV, MV = C. IA = OTG. 16:30 ***WELL S/I UPON ARRIVAL*** (p&a) R/U SWCP 4516 SLICKLINE UNIT 3/10/2019 ***CONT WSR ON 3/11/19*** ***WELL S/I ON ARRIVAL***(P&A) RIG UP SWCP 4522 3/10/2019 ***MOVE TO WEATHER TICKET*** ***CONT WSR FROM 3/10/19*** (p&a) DRIFTED TUBING W/ 11' x 2 7/8" DUMMY GUN (3.16" rings), 2.5" SAMPLE BAILER, TAG PRONG @ 8,418' SLM RAN PDS GR/40 ARM CALIPER FROM 2,000' SLM TO SURFACE (good data) RAN SLB E-FIRE, TUBING PUNCH 8,350'- 8,355' MD (all charges fired LRS CIRC OUT WELL WITH 9.8 ppg BRINE AND F/P LRS PERFORMED PASSING CMIT-TxIA TO 1420psi 3/11/2019 ***CONT WSR ON 3/12/19*** T/1/0=0/540/150. (LRS Unit 72 -Assist Slickline: Circ Well /AOGCC CMIT) Pump the following down the TBG, Up the IA, to 02-34's flowline: 5 bbls of 60/40 Meoh, 100 bbls of Hot Freshwater w/ F103 + U067 362 bbls of 9.8 ppg NaCl Brine, 5 bbls 60/40 to FP surface line, Let U-tube for 30 min between Tubing & IA Freeze Protect Outlet Well's 02-34 Flowline. Pumped 5 bbls 60/40 spear followed with 28 bbls crude, 6 bbls 60/40 down FL, Pressured up FL to 1500 psi, Pre AOGCC CMIT-TxIA PASSED at 1426/1420 psi. Pumped 1 bbls 60/40 down TxIA to reach test pressure, T/IA lost 24/25 psi in 1st 15 min and 17/17 psi in 2nd 15 min for a total loss of 41/42 psi in 30 min test, Bled back 1 bbl 3/11/2019 **WSR Continued on 03-12-19*** ***WSR Continued from 03-11-19*** LRS Unit 72 - Assist Slickline: Circ Out Wellbore / AOGCC CMIT-TxIA) AOGCC State Wittness (Jeff Jones) CMIT-TxIA PASSED at 1688/1714 psi (1 500psi target pressure, psi max applied pressure). Pumpeds eo in o e A. T/IA lost 22/22 psi during the 1st 15 min and 13/13 psi during the 2nd 15 min for a total loss of 35/35 psi during the 30 min test. Bled back 2.5 bbls. SIL had control of the well upon departure. 3/12/2019 lFinal T/1/0= 0/1/145. ***CONT WSR FROM 3/11/19*** (p&a) PERFORMED AOGCC WITNESSED PLUG TAG @ 8,418' SLM (Jeff Jones) PERFORMED AOGCC WITNESSED CMIT-TxIA TO 1500psi (Jeff Jones; see Irs log) 3/12/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/I/O = Vac/Vac/170. Temp = SI. WHPs (WIE Req). QA cemented to surface. Dry hole tree and temporary scaffold installed. No well house or flowline. 3/15/2019 SV, MV = C. IA, OA = OTG. 12:15 T/I/O = VACNAC/170. Temp = SI. WHPs (WIE request). No wellhouse, AL, or flowline. Temporary scaffolding installed. Dry hole tree. 4/3/2019 ISV, MV = C. IA, OA = OTG. 00:30 Daily Report of Well Operations 02-04A T/I/O = VACNAC/170. Temp = SI. WHPs (WIE request). No wellhouse, AL, or flowline. Temporary scaffolding installed. Dry hole tree. 4/16/2019 SV, MV = C. IA, OA = OTG. 15:30 T/1/0=0/0/175bTemp=Sl (LRS Unit 76 - Assist Schlumberger Cementers) Spot unit, 4/25/2019 transports and rigged up to choke trailer. LPT/HPT pass. **"WSR Continued on 04 -26 - **SLB Fullbore Pumping Crew** Job Scope: Plug and Abandonment w/balanced cement plug (TBGxIA) MIRU SLB and LRS pumpers. PJSM and PT lines. 4/25/2019 Continued on 04/26/19 WSR **"WSR Continued from 04-25-2019*** (LRS Unit 76 -Assist Schlumberger Cementers) Pumped 5 bbls meth spear down TBG taking returns up IA to confirm flow path on well and FL of 02-34 prior to SLB cement crew pumping. SLB Pumped cement. Displace Cement w/ 47 bbls 9.8 NaCl Brine. Freeze Protect Outlet Well's 02-34's flowline w/ 5 bbis 60/40 followed by 31 bbls crude. Flush Hardline/Clear Choke Trailer w/ 6 bbls tail of 60/40. AFE sign hugn on MV ***FLUID PACKED WELL*** Tree valves= 2 SV, MV closed CV's OTG 4/26/2019 IFWHP= 211/232/250 **Cont. from 04/25/19 WSR** **SLB Fullbore Pumping Crew** Job Scope: Plug and Abandonment w/balanced cement plug (TBGxIA). LRS pumped 5 bbls 60/40 spear down the TBG taking returns from the IA to OTT and 02-34 FL to verify circulation path. SLB pumped the following down the TBG taking returns from the IA to 02-34 FL: 2 bbls fresh water, 167 bbls 15.8 ppq class G cement, 2 bbls FW spacer. Launched 1x6" foam wiper ball. LRS displace cement down the TBG and into the IA w/47 bbls 9.8 ppg NaCL and 5 bbls 60/40. U -tubed 60/40 to FP TxIA to —150'. FWHP's=221/232/250 15.8 ppg Class G cement in TxIA Est. TOC in TBG and IA = 3400'MD / 3395' TVD 4/26/2019 Est BOC in TBG and IA = 8355'MD / 7948' TVD T/1/0=20/0/160. LRS unit 72, Assist SSL (PLUG AND ABANDONMENT) MIT -COMBO and TAG CEMENT. Pre State CMIT-TxIA to 2500 psi. Failed BP criteria but Passed AOGCC criteria at 2639 psi, (2750 psi Max Applied Pressure). T/I/O lost 61/49/15 psi during the first 15 minutes. T/l/O lost 36/27/12 psi during the second 15 minutes. Pumped 2.4 bbls of 50/50 McOH to achieve test pressure. Bled back 1.5 bbls to T/1/0= 29/32/152. AOGCC (Adam Earl) witnessed CMIT-TxIA to 2500 psi. PASSED AOGCC criteria but Failed BP criteria at 2679 psi (2750 psi Max Applied Pressure). T/I/O lost 40/32/15 psi during the 1st 15 minutes. T/l/O lost 28/18/9 psi during the second 15 minutes. Pumped 1 bbl of 50/50 McOH to achieve test pressure. Left the pressure on the well and started a third test. CMIT-TxIA to 2500 psi PASSED BP criteria at 984n psi T 1/0 lost 22/15/6 psi during the first 15 minutes. T/I/O lost 17/13/6 psi during the second 15 minutes. T/I/O lost 39/28/12 psi during the 30 minute test. Bled back 1 bbl to final T/1/0= 15/18/161. 5/10/2019 Tags were hung on IA and MV. AFE sign hung on MV. S/L had control of the well and DSO ***WELL S/I ON ARRIVAL***(p&a) LRS PERFORM PASSING CMIT-Tx1A(aogccwitnessed -Adam Earl) RAN 2.50" S -BAILER, TAG TOC @2984' SLM (aogcc witnessed, -Adam Earl) 5/10/2019 ***WELL LEFT S/I DSO NOTIFIED ON DEPARTURE*** 02-04A :Lcv = s3.Ta- 17K -LH -40, 1207' = p le= 94• 11128' 94#HdO, n MD = 9355' D =18.750' nTVD= 55 55 95/8LNR 1604' 47# HYD 563 XO TO L-80 733 bpf, D = 8.681' SO, 72#, N-80, D = 12.347' 2684' TOC (OS/10M 9) 2984• L-80 Tce XO TO L-80 BTCM Minimum ID = 2.387" @ 8679' 3-112" x 2-718" XO 7- LNR 26#. L-80 BTC -M, .0383 bpf, D = 6.276' SAFETY NOTES: WELL ANGLE> 701 @ 9656- *** 4-112" CHROME TBG "• ORIG WELLBORE NOT SHOWN*** 14-12• HES X NP. D = 3.813' 1 2433' - 2453' 9-5/8• CSG PATCH (1027/80) 2984' - 8366' TOP & BOT OF W & TBG CMT GAS LFT MANDRELS ST I MSD I ND I DEV I TYPE I VLV I LATCH PORI DATE 2 1 3502 6201 3494 14 5976 25 KBG2 KBG2 *DOME *SO BK BK 16 20 07/16108 07/16/08 *STA #2 & 1 = COV B2® BY CMT 8372' 4-12• HES X NP, D = 3.813 - HIS X NP, D = 3.81 PX RUG (06/11/17) 4-12• Tlfl 2, N-80, — 8740• j\ .0152 bpf, D = 3.958' 9-5/8• CSG, 47#, 500-95, D = 8.681' PBRFa7nTION suk4u4,IRv FEFLOG. BHCS on 10/9/1970 ANGLE AT TOP I$7F: 78" @ 9736' Note: Refer to Production DB for historical perf data SIZE SPF 84$9• -17" X 5-12" PORTED XO Opn/Sgz DATE 2" 8509' 9-5/8• X 5-12• UNDUE OVERSI 9494 - 9504 O 03/15/05 8572' 9-5/8' X 5-1/2' BKR SAB PKR 6 TBG, 12.6#, 13C 1.0152 86567186''4-12' MULESHOE, D= 3.958- bpf, D = 3.958' 2" 6 5-1/2- TBG -PCI 7W, L-80, .0232 bpf, D = 4.892 6 , O 5-4-1122'• x4-12TO, o = 3.958- TOP OF 2-7/8' LNR - CT 8673' 4 8673' 4-12' GSEAL SUB, D = 3.000' O 11/09/99 8675' 4-12' OTB X FP, D = 3.813• (E 4 10250 -10350 8679' 3-12" X 2-7/B' XO, D = 2.397" 4-12• Tlfl 2, N-80, — 8740• j\ .0152 bpf, D = 3.958' 9-5/8• CSG, 47#, 500-95, D = 8.681' PBRFa7nTION suk4u4,IRv FEFLOG. BHCS on 10/9/1970 ANGLE AT TOP I$7F: 78" @ 9736' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2" 6 9494 - 9504 O 03/15/05 2" 6 9736-9756 O 05/19/04 2" 6 9764 - 9776 O 05/19/04 2" 4 9862-10222 O 11/09/99 2-1/8" 4 10250 -10350 O 09/27/96 2-1/8' 4 10450 -10750 C 09/27/96 2-1/8' 4 10830 -11150 C 0927196 2- 4 11250 - 11290 C 11/09/99 2" 1 4 1 11350-11580 1 C 11/09/99 BKR SHEAROUT SUB (BEHIND LII TUBNG TAL (ElE9ND CT LINBQ 8712' —I ELMD LOGGED ON 0624189 9-5/8" MLLOLIT VMUOW 9306'- 9321' 86' 103 2-718' BKR CBP, 05/19/04 10805' CI BP, BKR CP, 07/14/03 ® 11766' 2-7/8' LNR-CT,6.5#, L-80 FL4S, .0058 bpf, D = 2.441' 11766' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14!70 ORIGINAL COMPLETION 0820117 JBIJMD SET PX PLUG 06/11117 018 09136 CTD SIDETRACK 02449 0228/19 KP/JMD DRYHOLE TREE 07MSM N2ES RWO 0321/19 LLGIJMD TBG PUNCH 3/11/19) 0194/11 KSBIPJC FINAL DRUG CORRECTIONS 05102/19 MRD/JMD CEMENTPLUG 04/26/19 05101117 RIH/JMD 30.20•&13-318• CORRECTIONS 05/14/19 JNUJMD CORRECTED CMT DEPTH 05102/17 RIHMMD ADDED CMT TO 30' COND & 20• CSG PRUDHOE BAY UNIT WELL: 02-04A PERMIT No: 1961580 API No: 50-029-20064-01-00 BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Section: 36 Township: Drilling Rig: N/A Rig Elevation: Operator Rep: Lee Gray Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Intermediate2: 95/81, O.D. Shoe@ Production 7" O.D. Shoe@ Tubing: 5.5' x 4.5" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 12, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 02-04A BPXA , PTD 1961580 / Sundry 319-027 11N Range: 14E Meridian: Umiat N/A Total Depth: 11766 ft MD Lease No.: ADL 028308 Suspend: P&A: X 115 Feet 1207 Feet 2694 Feet 9306 Feet 8509 Feet 8740 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on De th Btm De th To MW Above Verified Fullbore Bridge plug 8436 ft MD 8424 it MD 9.8 ppg brine I Wireline tag OA 325 295 283 274 Initial 15 min 3n min ea min 0e�Pll+ Tubing 1723 1701 1688 1688 IA 1786 1749 - 1727 1714 P OA 325 295 283 274 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: ✓ Sundry 319-027 was revised and approved 3/19/19. 4.5" PX plug was set in X nipple at 8436 ft MD prior to my arrival and holes were punched in the tubing above the plug for the first abandonnent cement plug. 60/40 methanol was used for the test - 3 bbls pumped, 2.5 bbls returned. The CMIT-TxIA was continued an additional 15 minutes. Attachments: none rev. 11-28-18 2019-0312_Plug_Verification_PBU_02-04AJj THE STATE °fALASKA GOVERNOR MIKE DUNI.EAVY Michael Hibbert Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-04A Permit to Drill Number: 196-158 Sundry Number: 319-027 Dear Mr. Hibbert: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaskci.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 .Sday of February, 2019. SCANNED FFA' 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CIEElVE JAN 2' 1. Type of Request- Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operatio0s.shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory El Development 0 5. Permit to Dnll Number 196-158 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic 1-1Service❑ 6. API Number 50-029-20064-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? e. Well Name and Number. Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 02-04A 9. Property Designation (Lease Number): 10. FielNPools: ADL 028308 a PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD' I MPSP (psi) Plugs (MD): 8436, Junk (MD): 11766 9007 8436 8024 10386,10805,11210 None Casing Length Size MD TVD Burt Collapse Conductor 80 30" 35-115 35-115 880 Surface 1172 20" 35-1207 35-1207 2320 / 1530 15001520 Intermediate 2660 13-3/8" 34-2694 34-2894 5380 2670 Intermediate 9273 9-5/8" 33-9306 33 -826870/8150/6820!/510 4760/5080/3330/4130 Tieback Liner 8478 7" 31-8509 31 - 8092 7240 5410 Liner 3093 2-7/8" 8673 -11766 8246-9007 1 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9494- 11580 8951 - 9009 5-1/2" 17# x 4-1lT' 12.8# 13Cr80 / L-80 / N-80 29 - 8579 18616 - 8740 Packets and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8402 / 7992 5-1/2" Baker BAB Packer 8572/8151 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 1, 2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert, Michael be deviated from without prior written approval. Contact Email: Michael.Hlbbert@BP.com Authorized Name: Hibbert, Micha Contact Phone: +1907 564 4351 Authorized Title: Well IntervenbcQs E Authorized Signature: Date: V u— 14; COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / / — — 1 Plug Inte rity M- BOP Test ❑ Mechanical Integrity Test 1 Location ClearanceHf' Otherf:l—�CtJW�•e-ia�r Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No @� Subsequent Form Required: 10—LIC h7 ABVTHE Approved by: COMMISSIONER COMMISSION Date l Form 10403 Revised 04/2017 ORIGINAL BDMS±OFEB 0 5 209i � O i tzLt/I q �bmit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 02-04A P&A Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Paulina Meixueiro (907) 564-5971 Expected start date: February 1, 2019 History 02-04 was completed in 1971 with a Gen 1 wellhead and three string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. 02-04A was a sidetrack drilled in October 1996 and completed in Z1. It was made not operable in May 2017 as it was identified as sharing similar well construction design to 02-03 (20" casing landed in the permafrost). This well had an RWO in July 2008 which repaired the 20" surface casing and 9-5/8" production casing leaks. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps 5� ELine or Relay/Fullbore Z 1. AOGCC Witnessed CMIT TxIA to j,5w psi. 2. AOGCC Witnessed tag top of PX plug @ 8436' MD. Flag wire for depth control. 3. Run GR and caliper from 2000' to surface (log all the way into the tree - this log is for future subsidence surveillance/analysis.) 4. MU 5' tubing punch and punch from 8350'— 8355' MD. (This step may be moved to E -Line if E -fire is not available). 5. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine. 5 bbls MEOH 100 bbls of surfactant wash 290 bbls 9.8 ppg brine Fullbore 1. Pump cement job down tubing with returns from IA. The top of cement in the IA will be at surface and at —2800' MD in the tubing. 5 bbls MEOH Y 5 bbl FW spacer 260 bbls of Class G cement per design (this includes —20 bbls of excess cement) r Foam wiper ball 2 bbls FW spacer 40.5 bbls 9.8 ppg brine FP near surface with methanol if temperatures warrant — 9.8 ppg brine is a freeze protectant down to -5F. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours E-Line/Fullbore 1. AOGCC Witnessed MITT to 2200 psi 2. AOGCC Witnessed Tag TOC 3. Perforate —2500'— 2505' MD through 4-1/2" tubing and 7" casing. 4. CMIT-TxOA to 120^ 0 psi. _This is to confirm the 13-3/8" casing/shoe can hold the hydrostatic cement column for the next cement plug. Fullbore/Special Projects 1. Remove IA gate valves and replace with integral valves at WSL discretion. 2. RU to pump down the tbg and take returns from the OA. Pump the following: ➢ 5 bbis of MEOH ➢ 40 bbls 9.8 ppg brine ➢ SD for one hour to let diesel swap in OA ➢ 60 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 150 bbls 9.8 ppg brine ➢ FP near surface with methanol if temperatures warrant — 9.8 ppg brine is a freeze protectant down to -5F. If proceeding straight into cement job then this may be unnecessary. 3 Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump surface (lateral) cement plug as follows down tubing: ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 154 bbls 15.8 ppg cement per design (20 bbls of excess cement) 4. Blow some N2 across the top of the IA prior to cement reaching thickening time. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours DHD 1. Bleed tubing and IA pressures and monitor for 24 hours. Special Projects "P� C' c 6 e-u-�—w�J'Q r'-1 ) � �e P 5 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Take pictures of cement and welded plate. 4. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 02-04A PTD # 196-158 API # 50-029-20064-01-00 by 40% koj 02-04A P&A Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Paulina Meixueiro (907) 564-5971 Expected start date: February 1, 2019 History 02-04 was completed in 1971 with a Gen 1 ellhead and three string casing design. The outer casing nng is se in p res . WO as det mined that these wells are at risk for su en we movemen , as demonstrated by 02-03 and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate H SE consequence associated with this potential risk. 02-04A was a sidetrack drilled in O tober 1996 and completed in Z1. It was made not operable in May 2017 as it was identified as shario similar well construction design to 02-03 (20" casing landed in the permafrost). This well had a RWO in July 2008 which repaired the 20" surface casing and 9-5/8" production casing leaks. i Objective / Place cement plugs in the p4ellbore. Excavate and cut casings 3' below original tundra level and install marker cap. / Procedural steps i 0 ELine or Relay/Fullbore // -Z;b 1. AOGCC Witnessed CMIT TxIA to 1 psi. 2. AOGCC Witnesse tag top of PX plug @ 8436' MD. Flag wire for depth control. 3. Run GR and cali r from 2000' to surface (log all the way into the tree - this log is for future subsidence sury illance/analysis.) 4. MU 5' tubing p nch and punch from 8350'- 8355' MD. (This step may be moved to E -Line if E -fire is not available). 5. Circulate do n tubing and up IA with surfactant wash followed by 9.8 ppg brine. / ➢ 5bb MEOH — �}Ssvr� G��m� r�`��+ ^S/� rl.1vkSd� ➢ 10 bbls of surfactant wash OOf 29 bbls 9.8 ppg brine Fullbore 1. Pump cement job down tubing with returns from IA. The top of cement in the IA will be at surface and at 2200' MD in the tubing. ➢ 5 bbls MEOH ➢ 3 bbl FW spacer ➢ 270 bbls of Class G cement per design (this includes -20 bbls of excess cement) ➢ Foam wiper ball ➢ 2 bbls FW spacer ➢ 31.5 bbls 9.8 ppg brine ➢ FP near surface with methanol if temperatures warrant — 9.8 ppg brine is a freeze protectant down to -5F. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 pp Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours E-Line/Fullbore L 1. AOGCC Witnessed MITT to 2500 psi 2. AOGCC Witnessed Tag TOC 3. Perforate -1800'— 1805' MD through 4-1//tubing " casing. Fullbore/Special Projects 1. Remove IA gate valves and replace with inat WSL discretion. 2. RU to pump down the tbg and take return. Pump the following: ➢ 5 bbls of MEOH ➢ 74 bbls 9.8 ppg brine ➢ SD for one hour to let diesel sw p in OA ➢ 60 bbls hot (160 deg) freshw er + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 135 bbls 9.8 ppg brine ➢ FP near surface with met nol if temperatures warrant — 9.8 ppg brine is a freeze protectant down to -5F. If oroceedin straight into cement job then this may be unnecessary Once clean brine is consist circulated out of the annuli, ➢ 5 bbls MEOH ➢ 5 bbls freshwater sE turned from the OA indicating that all hydrocarbons have been surface (lateral) cement plug as follows down Tubing: ➢ 94 bbls 15.8 ppg c ment per design (20 bbls of excess cement) 4. Blow some N2 across th top of the IA prior to cement reaching thickening time. CementT pe/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 pp Slurry emperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Com essive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours DHD 1. Bleed tubing and IA pressures and monitor for 24 hours. MEMORANDUM TO: Jim Regg ��, 5�)41�� P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 10, 2019 Plugging Data: Test Data: Tvpe Pluq Founded on Depth Btm Depth To MW Above SUBJECT: Well Bore Plug & Abandonment Balanced 8350 ft MD 2984ftMD-1 Wireline tag 2690 PBU 02-04A OA FROM: Adam Earl 403 397 . BPXA - Petroleum Inspector PTD 1961580; Sundry 319-027 Section: 36 Township: 11N Range: 14E - Meridian: Umiat - Drilling Rig: NA Rig Elevation: NA Total Depth: 11766 ft MD Lease No.: ADL 028308 Operator Rep: Eric Dickerman Suspend: P&A: X Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 30" - O.D. Shoe@ 115 Feet Csg Cut@ na Feet Surface: 20" O.D. Shoe@ 1207 Feet Csg Cut@ na Feet Intermediatel: 13 3/8" O.D. Shoe@ 2694 Feet Csg Cut@ na Feet Intermediate2: 9 5/8" O.D. Shoe@ 9306 Feet Csg Cut@ na Feet Production: 7" O.D. Shoe@ 8509 Feet Csg Cut@ na Feet Liner: 2 7/8" O.D. Shoe@ 11766 - Feet Csg Cut@ na Feet Tubing: 5 1/2" x 4 1/2" O.D. Tail@ 8740 " Feet Tbg Cut@ na Feet Plugging Data: Test Data: Tvpe Pluq Founded on Depth Btm Depth To MW Above Verified Tubing Balanced 8350 ft MD 2984ftMD-1 Wireline tag 2690 P i OA 427 412 403 397 . Initial 15 min ,An min ds min ao�„u Tubing 2747 2707 - 2679 2657 IA 2755 2723 _ 2705_ 2690 P i OA 427 412 403 397 . Remarks: I traveled out to PBU 02-04A to witness a plug tag and pressure test. I walked down the wellhead and rig -up. They were tied into the tubing with a jumper hose to the tubing -casing (inner) annulus (for combined test of the tubing and IA). The jumper hose was shut after the pressure up. Volumes for the MIT were 1 BBL in and 0.9 BBL bleed back. The wireline tag followed with an anticipated top of cement (TOC) @3400 ft MD. The wireline string had a 24 -foot bailer on bottom and down weight of 275 lbs. They tagged TOC @ 2,984 ft MD with at least 12 to 15 good hits at the same depth. The wireline bailer came back with firm i cement. Attachments: none rev. 11-28-18 2019-0510_Plug_Verification_PBU_02-04A_ae.docx Special Projects �) LA, S o c�� � _y � I I Z4�F S 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Take pictures of cement and welded plate. 4. Bead weld marker cap on outermost casing string (30" Conductor) to rea as follows: BPE�Le, 4-65 �;_e�uel-4 1� lV—YD'`J xploration Alaska, Inc, 02-04A PTD # 196-158 API # 50-029-20064-01-00 d�� KU LLLV - BF AEV c KCP= 0.4R_AQ* = Deh1mWD = 58' LW 47x. L-60 STC M �--1 733 bol. D=8.681' I L DS 02-04 Current Status I.W 2611. L-eo TU X0 7O L -6o Bra4 H 3897- P' Casing Cement — @ 6536' w/ 30% washout. 'logged cement from 6007'-2740' gh stage collar @ 6007' 'logged cement from 2438' to 1740' gh stage collar @ 2438' anted from EZ cementer @ 1665' to 5-112' TBC-PC,I7A, L-00..0132 bpf, D = 4.892' 6616' 4-1? TBGPC,12.80, N-80, .0152 bpi, D - 3.968'__ r9 -5f8' Lg(s 47A .RM -AS. In= A AA1' P8*<JHA FUN SLAWRV FU LOG: BFCS m IOM/1970 ANGLE AT TOP PERF: 78' ® 9736' wte Refer to RoduGl6n M for hiBta sd pa 2' 6 ID- ----1 —_ + 20' CSG, 13340 94'_ 11418 94R, K-550"", 9355 jn= 1e 750' _ 7 58' LW 47x. L-60 STC M �--1 733 bol. D=8.681' I L DS 02-04 Current Status I.W 2611. L-eo TU X0 7O L -6o Bra4 H 3897- P' Casing Cement — @ 6536' w/ 30% washout. 'logged cement from 6007'-2740' gh stage collar @ 6007' 'logged cement from 2438' to 1740' gh stage collar @ 2438' anted from EZ cementer @ 1665' to 5-112' TBC-PC,I7A, L-00..0132 bpf, D = 4.892' 6616' 4-1? TBGPC,12.80, N-80, .0152 bpi, D - 3.968'__ r9 -5f8' Lg(s 47A .RM -AS. In= A AA1' P8*<JHA FUN SLAWRV FU LOG: BFCS m IOM/1970 ANGLE AT TOP PERF: 78' ® 9736' wte Refer to RoduGl6n M for hiBta sd pa 2' 6 9736-9756 O 05119104 7 6 9764-9776 O OW19104 7 4 9862-10222 O 11109199 2-18' 4 10250-10350 O 09271% 2-18' 4 10450-10750 C 092786 2-18' 4 10B10-111.50 C MW7M 7 4 11250- 11290 c 11f09A79 7 4 11350-11580 Cr 1/109799 NOTES: W ELL ANGLE > 70'0 9666' 'CHROME TBG— ORIGWEL BORENOT IS' 4-12'FMXNP,D=3.813• GAS LFTMAN RELS 6201 5976 L 251KBG21 30__l _ B 372 4-IIr FUS X NP. D' 3.913' 64189' Hr x "T Pa 8605 9-5/8'X5-12' OTISX NP, D•: x 2-7W X0 D= tI.TT1ANG TAI (1186N0 CT LIMMO ._8712' - n_WDLoccJTIGNAenMAe 9-58'WLLOW WINLTP7! 9x -9321' 10388' 2718' BKR GBP. 05/19104 [mj -L 11765 DATE REV BY COL1.84rS DATE REV BY COW! BM 10114170 OFIG04AL COMPLEnON 12/14710 CR+JWD DTB_G ORAFr CDFZI' T1DP6 0&30186 CTOSI)ETRACK(O2.04A1 01104!11 KSBIPJC FINAL OR -G COF?F?I37TDMS 07MOMS IQS IWO 05101717 R64JWU 3P. or 813-38' C0F4iCCTKVJ5 07119108 KOCISV GLV 00 (07/16=) 05012117 RJWJMD AOOBDCWTOWODPD820'GS 1211410 UWAD WRPPUl®(07108) O&MJT JINJWD SErp5(PLuG(06HN17) 12114110 CWFJMD FERE 00RFECTION(03f15M5) -F 718' BKR ®P, 0111.1103 F-rF-J PFUCHOE BAY lNr WELL 02-04A FEFUT W '1961580 ARM* 50-029-2(064-01-00 BP Fxplantion (Alma) 9 u9 .A KG. FLLV = U4' BF. E EV KOP= _^ Wx Angle - 94'@ 11128 = 18 750" Cement Job #1— Tubing cement from 8350' to 2800' IA cement from 8350' to surface. 11316- CSG. 724. N -B0. D = 12.347• DS 02-04 P&A Status 1" LWi, 264. L -BO TC9X0 TO L -BO 6TCM j- j 38YT /8" Casing Cement — C @ 6536'w/ 30% washout. IT logged cement from 6007'-2740' Hugh stage collar @ 6007' IT logged cement from 2438' to 1740' Hugh stage collar @ 2438' mented from EZ cementer @ 1665' to TOPOF&710"LNR-cr 8873' ID=1966 9-58" CAC• PERWRA WN SLU ARY REF LOG. BHCS w 1019!1970 ANGLE AT TOPPHLc 78.09736' NARefer rn Roduchon BB for hasmricalpeO Oars . S2E SF INTERVAL OpNSgz DATE 7 6 9494.9504 D 03115M 7 6 9736.97% O 0519'50 7 6 9764-9776 O 0x11904 7 4 9862- 10222 0 11A9'99 2-108' 4 10250 - 10350 O 0927196 2-18• 4 10450 -10750 c 0927196 2-18• 4 tfWW-111.50 4. W27% 7 4 1125D -1129D C 11100199 7 1 1 11350 -11580 I C 11109199 ZNOTFS: WELL ANGLE> 70° @ 9656' 4.12" CHROME TW'** ORIG W ELLHORE NOT N •'• nent Job #2 — ing cement from 2500' to surface cement from 2500' to surface 9115' 4-12'F$X N', D=3.913" IS'- gy--'9-5/0•CSG'ATCII(10127/80) X 4-112• BKRS-3 FnR, D= 1WWSX11P,0-3.813•_ I2• Pic R -W (W11n n 1 8481' 1 8616' H5-la-X4-12-xo,1D=3.956 887b 4-ta• G SEAL SUB, D - 3.00 6515 a1n•oTsxNv,D=3813• 8679' 112• x 2-715 x0. D= 2367 9-515 MLLOUT WPUDW 93W-9321' ' 10386' H2 719" BKR CGP, D5119*4 J 10005' 2-71W BKR COP. 0 FH TD 11786 P 1-r-44-7—dr-1 1 GAS LIFT MANDRELS PRUDIGESAY LM WELL: 02-04A PBiMTM F1961500 AMM: 50-029-20064-01-00 SFC 36, T11R 814E 1065' FNL 81771' FN - ST M® NO OEYJTYFEJ 07119108 KDC!'3V GLV CYO (07!18/09) 0502!17 RMJMD ADDEDCMTT0W0OND!l2TCSC VLY ILATCHIPORTI JDlJMO SET PIC PLUG (OSA 1117) DATE 2 3502 13494 1 14 KBG2 DOME BK 18 0T/18MB 1 1 6201.j_2L6_j 25 KBG2 SO BK 20 87116IOB X 4-112• BKRS-3 FnR, D= 1WWSX11P,0-3.813•_ I2• Pic R -W (W11n n 1 8481' 1 8616' H5-la-X4-12-xo,1D=3.956 887b 4-ta• G SEAL SUB, D - 3.00 6515 a1n•oTsxNv,D=3813• 8679' 112• x 2-715 x0. D= 2367 9-515 MLLOUT WPUDW 93W-9321' ' 10386' H2 719" BKR CGP, D5119*4 J 10005' 2-71W BKR COP. 0 FH TD 11786 P 1-r-44-7—dr-1 1 PRUDIGESAY LM WELL: 02-04A PBiMTM F1961500 AMM: 50-029-20064-01-00 SFC 36, T11R 814E 1065' FNL 81771' FN - LATE REV SY COMPANTS DATE FEU BY COM EMITS 69114170 ORIGINAL COMPLETION 12114110 CRW&M DFILGDRAFr' OOF01; NS Oe130A6 CTDS67ETPACK(02-04A) OVOUll KSWPJC FINAL DiLG C013I,TDP6 07MMO WEE RIND 05DB17 FL0IJMD 30•, 20.8 /3-318" cOR143 JNS 07119108 KDC!'3V GLV CYO (07!18/09) 0502!17 RMJMD ADDEDCMTT0W0OND!l2TCSC 12/14110 CRIYJMD WRPRJL®(07/08) 0620117 JDlJMO SET PIC PLUG (OSA 1117) BE Exploration(Alaska) 12/14110 CF81JMU PAW CORRECNON(03MW5) 77d Nom= QVI VWLLFE0.D= HTERVAL ACTUATOR= BAKER KB. ELEV = 8T BF_ R -E/ O K10P= 7 Mhz An01e_= _^ 94' @ 1112V DalumL6= 0355 DaamND=- 88wss- DS 02-04 P&A Status Lam'= 1 20' CSG, 13301 1207 94F, K-550+40, D-18750' 4.518' LNR. 1604' Cement Job #t — ubing cement from 8350' to 2000' IA cement from 8350' to surface. 113/8' CSG, 720, K86, D = 12.347' I i 5-1rJ' "Casing Cement — @ 6536' w/ 30% washout. logged cement from 6007'-2740' gh stage collar @ 6007' logged cement from 2438' to 1740' gh stage collar @ 2438' anted from EZ cementer @ 1665' to ao..vt3s nvr, v = a eaz--I 6616• 10P OF 2-78' LNi- CT 8673' 4-M7 TBC-PC,1280, N -M, .0152 bp1. D = 3.958' 9-5!8'C'4 47n_AfIn aSD AAAI•. FER-ORA IXXJ SL.MNARY FH LOG: BHC5 on 1019!1970 ANGLE AT TOPPE7F": 78" ® 9736 - Nob: Refer to Roduckin DB for historical pert data SIZE I SPF HTERVAL OpNSgz DATE 7 6 9494-9500 O (WIMW 7 6 9736-9756 O 0617 7 8 9764-9776 O 0611 7 4 9862-10222 0 11 2-116` 4 10250-10350 0 2 -VB' 4 10450-10750 C 196 2-18' 4 1nRin - 111.=i1) C n997NR 7 4 11250 -11290 C 11109199 7 4 11350 - 11580 C 71!0919'9 LL ANGLE> 70° @ 9666' 7BG "' GRID W LLLBORE NO� nent Job #2 — ing cement from cement fronE-18E 5 LFT MANWELS 3T M D TYPE I VLV I LATCH I PORT I DATE 294 4 KBG2 DOM£ 8JC t8 07It810B / 5976 25 I KBM SO BK 20 07H 6106 447 HES XNI D-3813' 4-12• Ri( FLUG (0811 1117) - 7- rEs ES MANTER T X S 112' FOKIED XO Mill' X 5-1M UNKX FOVER 9.518' X 5.12' BKR SAB PIR v -e- rtwa.esrxx, u = jv 12'X 4 -1/T XO, 0=9.4 12' O SEAL SLB, D - 3. 12' OTIS X W,, D- 3.81 12' X 2 -W8 -.KO D= 2 3 I 874W h4.12'T1861GTAE.(9MNDOTL 8717 E L6 LOCOED t*LX124Jq 9-58' MLLOUI WN70W 9706'-932Y--- - 10388' 2-718' BKR CBS. 05/19104 10805' - - 2-78' 8KR OEP, 0711483 11766' D-2.441- 11766' DATE REV BY COKOAN S DATE FEV BY OOMANIS 10fl4r10 OR INALCOMPLETION 12114110 CFHJMD DLG CRAFT CORPE-CTION3 0810086 CTD SIDETRACK (02 -WI 0184111 KSWPJC PWALDR-6(XXOD=.T10N6 07MSMS I2M RWO 05101117 R"JMD 30', 20. 8 13-3/8" CORTiCTIONS 0711988 KOCJSV GLV 00 (07/16M) 051=17 R64JMD ADDED CMT TO 30' COED 620' CS 12/14/10 CMAID W W PLLLED (0780) W=17 J NJMD SET PX PLLIG (06M 1117) 12/14/10 CWJMD PEW COR;ECRON (03M W06) 9110E RdAIOE BAY I.MT WELL 02-04A FBW fb: 7961580 AR Nr. 50-029-20064-01-00 SEC 36, TI IN, R14F 1065' HTL 81771' R BP Exploration (Alaska) 5 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual \\lell History file and weather or not it is a\.'ailable in the LaserFiche file. P1ease insure that it remains as the first page in this file. t'9Þ ~I History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Materia1 Added to LaserFiche File Other # Yes No Yes No Yes No ~1aps # Mud Logs # Genera1 NOles or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433. or email us at: AOGCC_Librarian@admin.state.ak.us • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22 ` pp g � 2011 `� 5g Au T� LIG x 20 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission $ 333 West 7 Avenue d � as C ox i p s n Anchorage, Alaska 99501 ct�a r�►gtq Subject: Corrosion Inhibitor Treatments of GPB DS -02 Dear Mr. Maunder, : 3__> LA Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 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 • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top 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 gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 2 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 l STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMION _ ., ,, REPORT OF SUNDRY WELL OPERATIONS ~' '~~ `~ 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 196-158 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20064-01-00 7. KB Elevation (ft): '! 64 00 9. Well Name and Number: . '~ PBU 02-04A 8. Property Designation: 10. Field /Pool(s): ADL 028308 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11766 feet true vertical 9007 feet Plugs (measured) assa.1o32s'oloao5' a Effective depth: measured 10386 feet Junk (measured) N/A true vertical 9052 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 1207' 20" 1207' 1207' 1530 520 Surface 2694' 13-3/8" 2694' 2694' 4930 2670 Intermediate Production 9306' 9-5/8" 9306' 8823' 8150 5080 Liner 3093' 2-7/8" 8673' - 11766' 8246' - 9007' 10570 11160 Tieback Casing 8509' 7" 7240 5410 8 5 09' //(/ ~~~~ pggp....~;~~ I/~ ,/~f/}/y.~{~~ Perforation Depth MD (ft): 9736' - 10350' Perforation Depth TVD (ft): 9046' - 9053' 4-1/2", 12.6# 13-Cr80 8579' Tubing Size (size, grade, and measured depth): 5-1 /2" x a-1 /2°_ 17# x 126# l_-80 / N-80 Packers and SSSV (type and measured depth): 7" x 4-1 /2", Baker S-3 Packer, 8402' 9-5/8" x 5-1 /2" Baker SAB Packer 8572' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8462'. Cut and pull 9-5/8" casing from 1644'. Run 9-518" (47#, L-80, TC-II) tieback to surface. Cement w/ 410 bbls Class 'G' (2302 cu ft / 1708 sx). Run 7" (26#, L-80, TC-II) from surface to 8509'. Cement w/ 140 bbls Class 'G'(786 cu ft / 677 sx),Clean out and run new Chrome tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 308-161 Printed Name Sondra Stewman Title Drilling Technologist ~ Prepared By Name/Number: gnature ~ Phone 564-4750 Date Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~j (~ ~ (`~ I ~ ( /, L c` J~~f~if~ (~{~~(~~~ ~~ ~g~y WELLHEAD = ACTUATOR = KB. ELEV = 64' BF. ELEV = KOP = 2922 Max Angle = 94 @ 11128' Datum MD = 9355' Datum TVD = 8800' SS 20" 94#, J-55 1,207` O ~ -0 4A S NOTES: **CHROME TBG"' 1,604` - 9-5/8" 47#, L-80, Hydril 563 Csg. 1,627` - 9-5/8" ES Cementer, 15.8 ppg cmt 209 - 4-1/2" HES X Nipple ID=3.813" 2433' - 2453` 9-5/8" CSG PATCH (10/27/80) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 3502 3495 14 KBG2 DOME BK 16 07/16/08 1 6201 5976 25 KBG2 SO BK 20 07/16/08 13-3/8" CSG, 72#, N-80, ID = 12.347"-1 2694' ~_ Estimated top of cement 7"x9 518" 3400' Minimum ID = 2.441" @ 8679' 3-1/2" x 2-7/8" XO 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID=4.892" 8615' TOP OF 4-1/2" TBG-PC 8615' 4-1/2" HES WRP DP Measurment 8,660` - TOP OF 2-7/8" LNR - CT ~~ 8673' 3897` 7", 26#, L-80, TCII Csg to surface. 8472` - 7", 26#, L-80, BTC-MOD Csg. 8372` - ` 4-1/2" HES X Nipple ID=3.813" " " X8402 - 7 x 4-1/2 Baker S-3 Packer 8436` - 8481 ` 4-1/2" HES X Nipple ID=3.813" " ES C - ementer 7 8489` - 5-1/2" x 7" 13CR Ported Crossover 8495` - ` 5-1/2", 17# Unique overshot-13CR 1/2" 12 4 6# 1 CR VAMTOP Tb 8579 - . - , - g. 3 8572' 9-5/8" X 5-1/2" BAKER SAB PKR 8615` 5-1 /2" X 4-1 /2" XO, ID = 3.958" 8673' 4-1/2" G SEAL SUB, ID = 3.000" 8675' 4-1/2" OTIS X LANDING NIP, ID = 3.813" (BEHIND LINER) 8679' XO 3-1/2" X 2-7/8", ID = 2.441" 8738' 4-1/2" BAKER SHEAROUT SUB 4-1/2" TBG-PC,12.6#, N-80, .0152 bpf, ID = 3.958" 8740' 8740` 4-1/2" TUBING TAIL (BEHIND CT LINER) 8712' ELMD 06/24/89, 9-5/8" CSG, 47#, S0095, ID = 8.681" I~ 9306' PERFORATION SUMMARY REF LOG: BRCS on 10/9/1970 ANGLE AT TOP PERF: 78 @ 9736' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9736 - 9756 O 05/19/04 2" 6 9764 - 9776 O 05/19/04 2" 4 9862 - 10222 O 11/09/99 2-1/8" 4 10250 - 10350 O 09/27/96 2-1/8" 4 10450 - 10750 C 09/27/96 2-1l8" 4 10830 - 11150 C 09/27/96 2" 4 11250 - 11290 C 11/09/99 2" 4 11350 - 11580 C 11/09/99 9-5/8" MILLOUT WINDOW 9306' - 9321' 10386' -j 2-7/8" BKR CIBP, 05/19/04 10805' 2-7/8" BKR CIBP, 07/14/03 11210` 2-7/8" HES CIBP, 05/11/02 11766' ~ 2-7/8" DA V IS LYNCH I FLOAT SHOE 2-7/8" LNR-CT,6.5#, L-80 FL4S, .00579 bpf, ID = 2.441" 11766' 11766' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/70 ORIGINAL COMPLETION 09/30/96 LAST WORKOVER 07/09/08 N2ES RWO 07/19/08 KDGSV GLV GO (07/16/08) PRUDHOE BAY UNfr WELL: 02-04A PERMfr No: "1961580 API No: 50-029-20064-01 SEC 36, T11 N, R14E, 4072.32' FEL & 1438.43' BP Exploration (Alaska) Cameron Cameron PBU 02-04A Well History • Date Summary 5/10/2008 WELL S/I ON ARRI T TO X-OVER C~3 8615' MD TAGGED LINER TOP C~3 8668' SLM W/ 3.25" LIB. TAGGED 5.5" X 4.5" X-OVER ~ 8616" SLM W/ 4.25" CENT. FIRST ATTEMP TO SET WRP FAILED. O- RING FAILED ON E-FIRE TOOL. SECOND ATTEMPTS SET 4.5" WRP @ 8671' MD. 2' ABOVE LINER TOP. T/i/O/00=1650/50/0/15. Temp=Sl. T FL (pre-RWO). T FL ~ 5465' (127 bbl's). 5/11/2008 T/I/O/OOA=300/100/0/0 MIT T PASSED to 3500 psi_(Pre RWO) Pumped 140 bbls crude down TBG to pressure up to 3500 psi. T lost 40 psi in 15 mins, T lost 40 psi in 2nd 15 mins, ran test an additional 15 mins, T lost 20 psi in 3rd 15 mins for a total loss of 100 psi in 45 mins. Bleed back 6 bbls crude. Freeze protected flowline. FWHP's= 200/100/0/0'*'Annulus casing valves open to gauges, Master and wing valves tagged on departure. Preformed tubing draw down test on WRP from 1675 Ibs to 1400 Ibs dumped 50 Ibs of sluggets on top of WRP 08671' MD, performed a second tubing draw down test on WRP from 1450 Ibs to 250 Ibs (Pass), 5/12/2008 INITIAL T/I/O = 50/75/0 SSV CLOSED. RAN 4.15" SCP JET CUTTER. ,CUT TUBING IN MIDDLE OF FIRST FULL JOINT BELOW SLIDING SLEEVEAT_84Fi2'. TUBING PRESSURE INCREASED FROM 200 TO 950 PSI AFTER SHOOTING CUTTER. IAP AND OAP DID NOT CHANGE. TUBING WAS FLUID PACKED DURING JOB. FINAL T/I/O = 950/75/0 5/14/2008 T/I/O=SSV/180/0. SI. Install secondary containment pre FB CMIT x IA (RWO prep). -30 conductor. Well house and cellar are full of snow. Ordered heater. 5/18/2008 Load fluids, RU to tbg 5/19/2008 T/I/O = 900/0/0 Circ Out Well (RWO Prep) Pumped 8 bbls meth spear, 926 bbls 1 %KCL, 150bb1s 110'F Diesel down tbg taking returns up IA through jumper to FL. U-tube freeze protect. Attempted to CMIT TxIA, lost roughly 1000psi in 15min. CMIT canceled due to PC leak. Bled T and IA to zero. After 80 minutes, T/I/O = 180/180/0. MITOA PASSED to 2000psi. OA lost 80psi 1st 15min, 40psi 2nd 15min, for a total of 120psi in 30min. Bled OA to zero. During MITOA, maintained open bleed from sealed conductor. Few drips in bleed tank, likely due to expansion. No fluid visible at surface, or in flutes. 5/20/2008 T/I/0=120/275/40 Obj: RWO prep. Pumped 5 bbls meth, followed by 840 bbls of 9.8 brine down TBG taking returns up the IA and down the F/L. Pumped 40 bbls of diesel down TBG to U-Tube, Freeze protecl TBG and IA. Pumped 5 bbls meth and 40 bbls of diesel down F/L to F/P.bleed pressues to 0 Rig down (annulus valves open to gauges well tagged) FWHP=O/0/0 5/23/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL), PPPOT-OC (PASS). Pre RWO. PPPOT-T: External Alemite check installed. Stung into test void to check pressure (0+ psi), bled pressure to 0 psi. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 150 psi in first 15 min, lost 50 psi in second 15 min (PASS). Functioned all LDS, all moved freely with no sign of bent or broken pins. functioned support pins, all moved freely. PPPOT-IC: Support bushing. Functioned LDS, all moved freely with no sign of bent or broken pins. Pressure test failed to 3500 psi, would not hold pressure. 5/31/2008 T/I/O =Vac/0/0 Set 5 1/8" ISA BPV #511 03108" 1-2' ext. used....no problems 6/4/2008 T/I/O = 0/0/0 Moved frontside I/A valve to backside. Torqued to 480 ft.lbs. & tested to 3500 psi. Installed VR plug & blind flange on frontside. 6/17/2008 T/I/0= 0/0/0 Pull 5-1/8 "ISA BPV Thru Drv Hole Tree. No EXT Used. Tagged C~3 84". No Problems. Set 5- 1/8 ISa BPV # 519 Thru Dry Hole Tree. No EXT Used Tagged C~3 84" No Problems • • PBU 02-04A Well History Date Summary 6/19/2008 T/I/0=0/0/0. Pull 5-1/8" ISA BPV #5i9 thru stacjC. RKB=18.75' + 6' lub ext. 18' ext used, tagged C~ 88". Nc problems. 6/21/2008 T/I/0=0/0/0, Temp= N/A. Drill LDS. Drilled 5 broken LDS on 9 5/8" hanger, and 1 broken LDS on 7" support bushing with Wash's drill. Installed blanks in all drilled locations. 7/8/2008 T/I/0=0/0/0. Pulled 4" CIW BPV thru tree with 1 - 2' ext. at 102". No problems. 7/12/2008 T/I/O=Vac/0/140. PuIL4-1116" CIW "H" BPV thru tree post rigs 1-2' ext used, tagged 03100". No problems. 7/16/2008 PULLED B&R FROM 8416' SLM PULLED BK-DGLV FROM STA.#2 (3502'MD) & BEK-DGLV IN STA.#1 (6201'MD) SET BK-DOME IN STA.#2 (3502' MD) & BK-OGLV IN STA.#1 (6201' MD) PULLED RHC PLUG BODY FROM 8425, SLM ATTEMPT TO EQUALIZE WRP C~ 8660' SLM. SAT DOWN HIGH & RECOVERED RUBgFR IN EOU_ T~OI 7/17/2008 THREE 3.0" BAILER RUNS W/WRP EQUALIZING BTM TO 8634'-8636' SLM BAILER RETURNS OF SAND, PARRAFIN, RUBBER, AND METAL SHAVINGS TWO ATTEMPTS TO PULL 4-1/2" WRP ~ 8644' SLM. FRICTION BITE/SLIPPING OFF 3.0" BAILER RUN W/WRP EQUALIZING BTM TO 8634' SLM. RECOVERED CHUNK OF ALUMINUM ATTEMPTED TO PULL WRP, SLIPPING OFF, TOOLS BACK W/ PARRAFIN, 7/18/2008 FOUR 11'x3.0" PUMP BAILER (BALL BTM) RUNS TO 8641' SLM BAILERS RECOVERING APPROX. 1 TO 2 CUPS OF METAL, RUBBER, PARAFFIN, & SAND EACH RUN TOOK IMPRESSION OF FILL/METAL ~ 8642' SLM W/ 3.70" LIB FOUR MORE BAILER RUNS W/ FLAPPER AND WRP EQUALIZING BTM'S TO 8642' SLM BAILERS RECOVERING -2 CUPS OF VARIOUS MATERIALS EACH RUN RAN 2-5/8" HYDROSTATIC BAILER RUN TO 8643' SLM. BACK EMPTY RAN 11'x3.0" PUMP BAILER W/ BALL BTM TO 8642' SLM. RECOVERED 1 CUP OF FILL W/ RUBBER RAN 2.85" CENT., DOUBLE KNUCKLE, & 1.27" SPEAR TO 8642' SLM. WORK TOOLS TO BREAKUP HARD FILL RAN TO 8642' SLM W/ 11'x3.0" PUMP BAILER W/ FLAPPER BTM. POOH 7/19/2008 RAN 10' X 3.0" BAILER SEVERAL TIMES, RECOVERED 4 TO 5 CUPS OF FILL ATTEMPT TO SET 4 1/ " W ATHFRFORD P i IN TOOL -COULD NOT GET DOWN TO FISHING NECK ABORT JOB -POSSIBLE COIL JOB 7/24/2008 CTU #6, Fish WRP; MIRU. RIH with Weatherford 3.125" Venturi junk basket. Dry tag down at 8649' ctmd. PUH. PU ~ 8646' ctmd. Clean on top of WRP. POOH. Break down venturi. Recover 1 cup of 1/2" x 3/4" rubber chunks. MU and RIH with fishing tools. tag upon. Attempt to latch WRP. Made 10 attempts with no indication that we were latching up. POOH to pickup motor and venturri basket with a urn over s oe. 7/25/2008 MU &RIH Motor and venturi basket with burn over shoe. RIH to 8649' ctmd. Reciprocate over WRP. Stalled and had slight over pulls. POOH. Recovered small quantity of material in venturi. Burn over shoe showed extensive wear on leading edge. Apnaarc to haves swallow d annrox. 6" over WRP. Need to clean over an additional 8". Sent burn over shoe back to shop for re-dress. RBIH with same BHA but with carbide cutting material on leading edge of burn shoe. Dry tagged down at 8650' ctmd. Reciprocated while pumping from 8649' to 8651' ctmd. Saw some motor work but did not appear to be weight dependent. POOH. Recovered about 1/4 cup of sluggets and metal shavings. MU &RIH fishing tool string, tap up and set as much wt as possible with no luck latching up: Jarred down on it with no luck. POOH. • • PBU 02-04A Well History Date Summary 7/26/2008 Continue POOH, MU &RIH Motor and Venturi basket with burn over shoe. Tagged up 50' at 8600', rotated throuah.,Set down on WRP at 8648' CTM. Reciprocate on top of WRP. Saw little or no motor work. POOH. No additional wear seen on burn shoe. Very small amount of sluggits found in venturi. RBIH with venturi junk basket alone. Reciprocated atop fish at 8648' ctmd. POOH with venturi. Venturi clean, no recovery. null and RIH with sn" D.iN rag wRP at 8656' CTM. Jet 6.6 bbls 7.5% HCL around top of WRP. MU fishing BHA. 7/27/2008 RIH with fishing BHA. Tagged up at 8655' CTM. Jarred down 50 times, could not latch fish. POOH. RIH with Baker BHA with BiDi HippTripper, G Spear, WRP overshot. Sat down on fish at 8650' ctmd. Activated Hipp Tripper. Shifted equalizer sleeve and latched WRP. Pulled WRP free. PUH. Could not pulled past 8520' ctmd (inside 4 1/2" tailpipe?). Can move fish down. Acts like a slip or hard edge hanging up - easy to RIH. Pumn nff of fiGh and IPave at 8520' tmd. POOH with Hipp Tripper BHA. MU and RIH with Baker fishing tools. Larch up to WRP at 8620' CTM. Jarred through what_appeared to be collars from 8516' to 8346' CTM. Then pulled at normal wt, with no over pulls. 7/28/2008 Continue POOH. FP well with 30 bbls of 50/50 methanol. Retrieve WRP, all slips were intact but missing 1 and 1/2 out of 3 packer elements. RDMO. 7/28/2008 RAN 4 1/2" BLB & 3.74" 3-PRONG GRAB TAG T.O.L. C~3 8643' SLM, NO RECOVERY. RAN 2 7/8" 8LB & 2.25" 3-PRONG GRAB TO 9202' SLM, NO RECOVERY RAN SAME AGAIN TO 9454' SLM NO RECOVERY. RAN 5' x 2.25" P. BAILER TO DEVIATION C 9655' SLM, RECD 2 EACH -1-2" PIECES OF ELEMENT • • BP EXPLORATION Operations Summary Report Page 1 of 15 Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase ~'i Description of Operations 6/16/2008 00:00 - 07:00 07:00 - 22:00 2:00 - 23:00 7.00 15.00 .00 MOB RIGU HSUR P P P PRE PRE ECOMP PJSM. Move rig from 02-01 B to 02-04A. Drive rig up ramp. Back rig over well. Ric accent at 07.00 hours. PJSM. Jack up rig 5 mats high. Make adjustments to sub. Spread herculite. Build stairs for extra height of rig. Spot pits. Jack up and mat up to match sub. Hook up interconnect. Build berms and spot cuttings box. Install secondary valves on IA and OA. Take on 9.8 ppg brine. Spot out buildings and hook up. PJSM. Ri u DSM lubricator. Pressure test to 500 si - OK. O en master and ull BPV. Install circulating lines. 23:00 - 00:00 1.00 WHSUR P DECOMP PJSM. Begin to circulate out freeze protect. Fluid dripping at the 13-3/8" 3000 clamp and the 20-1/4" 2000 clamp and bull plugs. Fluid wiped off tree, no fluid in cellar or secondary containment. Shut down, tighten clamps and plugs. Prepare to resume circulating. 6/17/2008 00:00 - 03:00 3.00 WHSUR P DECOMP PJSM. Finish fixing leaks on wellhead. Reverse circulate diesel out of tubing. Switch around and circulate diesel out of annulus. Continue to displace well with 9.8 ppg brine at 250 gpm with 700 psi until clean. Recovered 50 bbls non-recyclable diesel. Monitor the well for 10 minutes. Blow down and rig down lines. 03:00 - 04:00 1.00 WHSUR P DECOMP PJSM. Run in DSM lubricator. Test to 1000 psi - OK. Run in BPV and set. Leave lubricator hooked up. Line up and pressure up on BPV from below. Pressure up to 1000 psi with 2.7 bbls and monitor lubricator for pressure. Pressure bled off ... ~.._ 100 psi but no pressure observed on lubricator. Bleed off and recover 2.0 bbls. Pull lubricator and rig down. 04:00 - 07:00 3.00 WHSUR P DECOMP PJSM. Nipple down tree and adapter flange. Bleed control lines and void areas. 07:00 - 15:00 8.00 BOPSU P DECOMP Nipple up clamp bottom x 13-5/8" flange top crossover adaptor flange. Split the BOP stack at the double gate and upper mud cross. PJSM at crew change. Nipple down the bottom double gate. Pick up double gate and set on adaptor flange from wellhead. 15:00 - 18:00 3.00 BOPSU P DECOMP PJSM. Switch the rams to 3-1/2" x 6" variables on bottom and blind/shear rams on top. Install a 4-1/2" test joint and close bottom rams and bag on joint. 18:00 - 00:00 6.00 BOPSU P DECOMP Remove the HRC choke and kill lines from mud cross and lay down in the cellar. Rig up to pick up mud cross spool. Nipple up top spool to double gate. Install API rings and studs on bottom mud cross spool. Pick up the stack and install mud cross on wellhead adaptor flange. Nipple up both flanges. 6/18/2008 00:00 - 09:00 9.00 BOPSU P DECOMP Continue to nipple up BOPE. Finish nippling up flanges on mud cross to adaptor and BOPE. Nipple up choke and kill lines to mud cross. Install 3-1/2" x 6" rams. Close bottom doors, put air boot on top of Hydril. Clean cellar. Printed: 7/23/2008 2:23:37 PM • c: BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/18/2008 09:00 - 10:30 1.50 BOPSU P DECOMP Attempt to fill BOPE & choke with water. Kill HCR valve not opening. 10:30 - 14:00 3.50 BOPSU N SFAL DECOMP PJSM. Change out bonnet on HCR valve & replace with spare. 14:00 - 15:00 1.00 BOPSU P DECOMP PU test tools and check all gland nuts on wellhead. Fill stack and check for leaks. 15:00 - 22:00 7.00 BOPSU P DECOMP Test BOP's. Test 250 psi low / 3500 psi high. Test witnessed by WSL Bill Decker, Kris Honas & Vincent Volpe and Toolpusher Cleve Coyne & John Castle. Test witness waived by AOGCC rep Bob Noble. Test VBR's with 4" and 5-1/2" test joint. Test annular with 4" test joint. Upper and lower IBOP test failed. Finish remaining tests on manual kill &HCR kill prior to changing out IBOP's. 22:00 - 00:00 2.00 BOPSU N SFAL DECOMP Remove saver sub & hydraulic IBOP. Change out with new valves. 6/19/2008 00:00 - 01:30 1.50 BOPSU N SFAL DECOMP Finish changing out upper and lower IBOP's. 01:30 - 03:00 1.50 BOPSU P DECOMP Pressure test IBOP's to 250 psi low, 3500 psi high. Test witnessed by Nabors Tool Pusher John Castell and BP WSL Kris Honas. Rig down testing equipment and blow down lines. 03:00 - 04:30 1.50 BOPSU P DECOMP Pull the blanking plug. Rig up DSM lubricator /extension and test. _._ Pull the BPV. Rig down lubricator. 04:30 - 06:30 2.00 PULL P DECOMP Engage tubing hanger with landing joint. Back out tubing lock down screws. Pull hanger to floor. Hanger came free at 180K. UD landing jt & hanger. 06:30 - 07:00 0.50 PULL P DECOMP R/U casing tools, casing tools & control spool. 07:00 - 08:00 1.00 PULL P DECOMP Well out of balance. Circulate 9.8 ppg brine around and pump a dry job with 10.1 ppg brine. 08:00 - 11:00 3.00 PULL P DECOMP PJSM. UD 5-1/2", 17#, L-80, PC tubing from 8423' to 6178'. Recovered 1 pup (10.15'), 58 jts, 1 SSSV assembly, 2 SS bands and 31 rubber clamps. 11:00 - 11:30 0.50 PULL P DECOMP R/D control line spool. 11:30 - 18:30 7.00 PULL P DECOMP UD tubing from 6178' to jet cut. Cut joint flared to 6 inches. Strap on recovered cut joint = 20.97'. Pictures in well folder. Recovered a total of 224 full joints of 5-1/2" tubing. Clean & clear rig floor. 18:30 - 20:00 1.50 PULL P DECOMP R/D casing equipment and send down the beaver slide. Bring Baker BHA tools for scraper run to rig floor. 20:00 - 22:00 2.00 BOPSU P DECOMP PJSM. Pump out stack. PU test joint and install test plug. MU TIW & dart in 4" test joint. Attempt to fill stack: fluid leaking by test lu C/O test plug and run in lock down screws to energize seals on test plug. Test 4" test joint, TIW & dart in 3-1/2" x 6" rams to 250 psi low / 3500 psi high. 22:00 - 23:00 1.00 BOPSU P DECOMP Remove test plug, UD test joint & valves. Clear rig floor. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U Baker scraper BHA with bull nose, 9-5/8" scraper, bit sub, bumper sub, jars, and 6 drill collars. RIH to 214' MD. Total losses = 47 BBLS. 6/20/2008 00:00 - 03:00 3.00 CLEAN P DECOMP PJSM on Picking up drill pipe. RIH with scra er BHA ickin u 4" drill i e to 3500' MD. Slack off weight loss less than 4K while going through 9-5/8" Printed: 7/23/2008 2:23:37 PM • BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 6/20/2008 00:00 - 03:00 3.00 CLEAN P DECOMP casing patch at 2433' MD. 03:00 - 03:30 0.50 CLEAN P DECOMP Circulate bottoms up until clean returns. 550 GPM, 1400 psi. Pump a dry job. 03:30 - 05:00 1.50 CLEAN P DECOMP POOH with scraper BHA to 217' MD racking back 4" drill pipe. 05:00 - 06:00 1.00 CLEAN P DECOMP Rack back drill collars and Lay down Baker scraper tools. Clean & clear rig floor. 06:00 - 08:30 2.50 EVAL P DECOMP PJSM. Rig up SLB E-line. PU tools from beaver slide. 08:30 - 11:00 2.50 EVAL P DECOMP Pressure test packoff & lubricator to 500 psi. RIH to 3000'. Log up with CCL & USI_T. TOC C~ 1740'. POH. RD tools & lubricator. 11:00 - 12:00 1.00 FISH P DECOMP PJSM. Pick up and make up a 9 5/8" Halliburton Retrievable bridge plug. 12:00 - 13:00 1.00 FISH P DECOMP RIH with RBP to 2400' on 4" drill pipe. PU to 2390' & set RBP. Slack off 15K and overpull 5K to ensure set. Release from plug. Top of plug set at 2385'. 13:00 - 16:00 3.00 FISH P DECOMP Pressure test RBP to 3500 psi for 10 min and chart. Grey locks leaking -tighten up. Duma 2200# of 20-40 mesh river sand. Ta sand ~ 2 70'. 16:00 - 17:00 1.00 FISH P DECOMP POH. UD tools. Clear rig floor. 17:00 - 21:00 4.00 FISH P DECOMP R/U SLB a-line. Pressure test lubricator to 500 psi. RIH with 5 strand string shot. Locate collar & shoot ~ 1657' (String shot 3' ab ve and below collar at 1664' with 4' CCL . R/D SLB. 21:00 - 22:30 1.50 FISH P DECOMP PJSM. P/U and M/U BHA #2 with 8-1/4" multi string cutter, X-over, 8-1/2" stabilizer, and X-over to 4" drill pipe. RIH to 1601'. 22:30 - 23:00 0.50 FISH P DECOMP Open knifes and tag collar ~ 1664'. PU to 1644'. Obtain V - parameters without knives: torque = 750 ft Ibs ~ 80 rpm. Extend knives and cut 9 5/8" w/ 60 RPM ~ 1-2K ft-Ibs torque, 262 GPM ~ 840 psi. Blades torqued up to 10K after cut due to compression in 9-5/8" casing. Bled off DP and shut bag. 'rculation thru cut oint at 2 b m 1100 si, PUW = 55K, SOW = 55K, ROT WT = 55K. 23:00 - 00:00 1.00 FISH P DECOMP PJSM. R/U LRS and pressure test lines to 2500 psi. Pump 100 bbls of 110 degree diesel ~ 84 GPM ~ 1160 psi. Discard dead crude returns to cuttings tank for disposal. 6/21/2008 00:00 - 01:30 1.50 FISH P DECOMP PJSM. Continue to pump 100 bbls of 110 degree diesel ~ 84 GPM C~ 1000 psi. Discard dead crude returns to cuttings tank for disposal. Let hot diesel soak in 9-5/8" x 13-3/8" annulus for 30 minutes. 01:30 - 03:00 1.50 FISH P DECOMP Circulate 110 degree 9.8 ppg brine down drill pipe through 13-3/8" x 9-5/8" annulus until returns began to clean up ~ 6 bpm, 950 psi. Open bag and circulate bottoms up in 9-5/8" x Drill pipe annulus at 6 bpm, 800 psi. 03:00 - 04:00 1.00 FISH P DECOMP POH with Baker multi string casing cutter BHA racking back drill pipe and laying down cutter. 04:00 - 04:30 0.50 FISH P DECOMP Attem t to J into bushin above 9-5/8" mandrel han er Run in a lock down screw to stop bushing from spinning without success. L/D J tool. 04:30 - 07:30 3.00 FISH P DECOMP M/U a 9-5/8" casin sear Engage 9-5/8" casing hanger through the bushing. Pull 9-5/8" hanger and bushing to rig floor. Printed: 7/23/2008 2:23:37 PM • BP EXPLORATION Operations Summary Report Page 4 of 15 Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/21/2008 04:30 - 07:30 3.00 FISH P 07:30 - 08:30 1.00 FISH P 08:30 - 14:30 I 6.001 FISH I P 14:30 - 15:30 1.00 FISH P 15:30 - 19:00 3.50 CLEAN P 19:00 - 19:30 0.50 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 21:00 0.50 CLEAN P 21:00 - 22:00 1.00 CLEAN P 22:00 - 00:00 2.00 EVAL P 6/22/2008 00:00 - 00:30 0.50 EVAL P 00:30 - 04:00 3.50 EVAL P 04:00 - 05:00 1.00 EVAL P 05:00 - 06:30 1.50 FISH P 06:30 - 07:30 1.00 FISH P 07:30 - 08:00 0.50 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 12:00 3.50 FISH P DECOMP Hanger came free at 212K lbs. 100K to the floor. DECOMP UD hanger. CBU 10.5 BPM ~ 750 psi. Dead crude trace in DECOMP PJSM. R/U casing equipment. UD 9 5/8" casing from 1644' to to cut jt. UD 36 jts, 2 pups, cut jt - 25.85' & 9 centralizers. Cut jt flared w/small piece missing from face of cut. DECOMP R/D casing tools. Clean & clear rig floor. DECOMP PU and MU 12.25" bit & 13 3/8" scra er, Could not get BHA past the wellhead. Take off bit and run scraper, hung up in same spot. MU 12.25" bit to scraper & use weight of block/top drive to push BHA through wellhead. RIH to 201' with BHA. DECOMP RIH from 201' to 1633' with bit and scraper on 4" drill pipe. DECOMP CBU ~ 550 GPM, 890 psi. Pump dryjob. DECOMP POH from 1633' to 201' racking back drill pipe. DECOMP UD scraper & bit. Clear & clean rig floor. DECOMP RU SLB E-line and pick up USIT/CCL tools. DECOMP Finish R/U SLB E-line for USIT log, DECOMP RIH with USIT/CCL tool. Log from 1620' to surface in cement evaluation mode. Make second pass near TOC from 1300' to 1100'. TOC ~ 1190' MD. DECOMP R/D SLB E-line and UD tools. DECOMP PJSM. R/U to RIH with 13-3/8" composite bridge plug on drill pipe to 1035'. DECOMP CBU for 15 min w/ 95 degree Brine. Set composite bridge plug ~ 1030'. Test CBP to 500 psi and chart._ DECOMP POH. UD running tool. DECOMP M/U mule shoe &RIH to 935'. DECOMP Dump 2200# of 20/40 mesh river sand down drill pipe on top of 1007'. POH. 12:00 - 12:30 0.50 FISH P DECOMP Clean & clear rig floor. 12:30 - 13:30 1.00 FISH P DECOMP M/U 11 3/4" multi-string cutter with 12.25" stabilizer, 3 drill collars. RIH to 917'. 13:30 - 16:30 3.00 FISH P DECOMP Locate collars ~ 941' & 976'.. - PUW = 45K. SOW = 45K. - ut in with 6 P 1-2K ft-Ibs, 260 GPM ~ 740 psi. Pipe jumped, close bag and could not circulate. Continue cutting, cut 13 3/8" casing ~ 986'. 16:30 - 18:30 2.00 FISH P DECOMP Displace 13 3/8" x 20" annulus with 100 BBL of 180 degree diesel with Little Red Services. Circulated 42 GPM ~ 210 psi. Swap to rig pumps and chase diesel with 110 degree 9.8 brine C~ 142 GPM, 1740 psi. Sent Dead Crude to cuttings tank for 's osal. 18:30 - 22:00 3.50 FISH P DECOMP Attemp to POH with multi-string cutter. Unable to pull cutter free. Could only come up 3' and could not go down. Rotation difficult, stalling out. Unable to work pipe with torque applied. Attempted to PU to 100K, 150K, and 200K while putting up to 15K of torque on pipe. Closed annular preventer around pipe to dampen upward motion if pipe comes free. Continued to work pipe increasing PU each time with 200K, 250K, 275K, 300K, 325K. Pipe came free on final attempt at 345K., 22:00 - 22:30 0.50 FISH P DECOMP Inspect crown, drawworks & derrick. Re-wrap drilling line on Printed: 7/23/2008 2:23:37 PM • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 6/22/2008 22:00 - 22:30 0.50 FISH P DECOMP drawworks. 22:30 - 00:00 1.50 FISH P DECOMP POH from 980'. UD multi string cutter. Cutter body has 2 minor scrapes/gouges between blade keepers. Tool in good overall condition. Clean & clear rig floor. 6/23/2008 00:00 - 09:00 9.00 WHSUR P DECOMP PJSM before each new task. N/D HCR choke and kill lines. R/U slings to mud cross. Remove the air boot. M/U a 4.5" donut test joint to top drive. Close pipe rams and annular around test joint. N/D BOPE at flange between rams and mud cross. Lift rams and annular reventer with to drive and test joint. Remove the mud cross and set on stump. NU double ate & H dril back on stack & chain down. 09:00 - 12:00 3.00 WHSUR P DECOMP Remove 13 3/8" Grey lock clamp from wellhead & remove upper TBG spool assembly. RU WACHS inside cutter & cut 13 3/8" below the double actin sli s. 12:00 - 16:30 4.50 WHSUR P DECOMP Remove Perma-head wellhead from cellar. RU WACHS outside cutters. Cut 30", 20" & 13 3/8". Remove all wellhead equipment from cellar. Remove Bell Nipple. 16:30 - 20:00 3.50 WHSUR P DECOMP Install 20" bell nipple. Install & weld a 20" riser to existing 20" casin . 20:00 - 21:00 1.00 FISH P DECOMP P/U & M/U 13 3/8" spear. Spear 13 3/8" casing; pulled free ~ 90K. Pull casing to floor. 21:00 - 22:00 1.00 FISH P DECOMP Pump Safe Surf-O sweep, 570 GPM ~ 180 psi. Returns contained clabbered up crude. 22:00 - 22:30 0.50 FISH P DECOMP UD spear & 13 3/8" cut joint. 22:30 - 23:00 0.50 FISH P DECOMP RU equipment to pull 13-3/8", N-80, 72#, BTC casing. 6/24/2008 00:00 - 02:00 2.00 FISH P DECOMP UD 13 3/8" casin from 986' average breakout torque from 4K-24K). Recovered 25 its & cut jt (9.64').; 02:00 - 03:00 1.00 FISH P DECOMP RD power tongs and casing equip. Clean & clear rig floor. 03:00 - 04:30 1.50 FISH P DECOMP Pick up a 17-1/2" mill tooth bit and make up to drill collars. Change out handling equipment and install blower hose. 04:30 - 06:00 1.50 FISH P DECOMP RIH with 17-1/2" bit to 986' MD rotating at 35 RPM and circulating at 500 GPM, 530 psi. 06:00 - 07:00 1.00 FISH P DECOMP Circulate high vis sweeps at 530 GPM, 680 psi while rotating and reciprocating pipe. 07:00 - 08:00 1.00 FISH P DECOMP POH with 17-1/2" bit and lay down same. Clear the floor. 08:00 - 08:30 0.50 FISH P DECOMP Service the top drive. 08:30 - 10:00 1.50 FISH P DECOMP Make u a dress off BHA to dress the inside and t 13-3/8" casin stub. RIH with BHA to 961'. 10:00 - 12:00 2.00 FISH P DECOMP Obtain milling parameters. SO 55K, PU 58K, ROT 58K, 107 GPM, 120 psi 1 K TQ. Dress off stub at 986' with 6K WOB and 45 RPM. Unable to get washover mill over 13-3/8" stub 12:00 - 13:00 1.00 FISH P DECOMP Circulate bottoms up. 500 GPM, 370 psi. 13:00 - 14:00 1.00 FISH P DECOMP POH and lay down dress off mill. 14:00 - 15:30 1.50 FISH P DECOMP Make u a dress off mill to dress off inside of 1 - RIH to 986'. 15:30 - 17:00 1.50 FISH P DECOMP Rotate bull nose into 13-3/8" stub. Mill to and inside of 1 - PU 55K, SO 55K, ROT 55K, 1 K TQ, 190 GPM, 80 psi. 17:00 - 18:00 1.00 FISH P DECOMP POOH and lay down mill. 18:00 - 18:30 0.50 FISH P DECOMP Pick u a Baker Multi-Strin Cutter for 13-3/ " in Printed: 7/23/2008 2:23:37 PM • • BP EXPLORATION Operations Summary Report Page 6 of 15 ~ Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 6/24/2008 18:30 - 00:00 5.50 FISH P DECOMP RIH. Tagged sand dumped on composite bridge plug at 998'. Picked up 2' and placed knives at 994' MD.. Cut 13-3/8" casin for -1 hour at 100 RPM, 2K TO, 270 GPM, 800 psi. No pressure change or good indication pipe cut. POH to inspect BHA. Knives not worn deep enough to cut throuah 13-3/8" casing. RIH and find partial cut with knives, continue to cut 13-3/8" increasing pump pressure to 2100 psi, 425 GPM. Good indication of cut with 250 psi pressure drop after Lost 100 bbls of 9.8 ppg brine over 24 hours. Currently 10 bph loss rate. 6/25/2008 00:00 - 01:00 1.00 FISH P DECOMP POOH with Multi-String Cutter from 994' and lay down. 01:00 - 03:30 2.50 FISH P DECOMP MU a 13-3/8" casing spear. RIH and engage the 13-3/8" fish at 986' MD. 3:30 - 06:00 .50 ISH P ECOMP Good cut on bottom offish by Multi-String Cutter. Top of fish had been cut down the middle -1 foot by the outside dress off mill. Make up a dress off assembly with inside and outside cutters. RIH to 994' and attempt to dress off the 13-3/8" casing stub. nable to et over 13-3/8" stub with wash over shoe after several attem ts. 06:00 - 09:00 3.00 FISH P DECOMP POOH and lay down dress off shoe. Cut 1/2 the teeth off the outside cutters of the dress off assembly. Run back in hole with modified dress off BHA to 994'. 09:00 - 11:00 2.00 FISH P DECOMP Attempt to get over 13-3/8" stub with modified dress off assembly. Unable to get over stub after several attempts... 11:00 - 12:30 1.50 FISH P DECOMP Consult with Anchorage team on plan forward. 12:30 - 15:00 2.50 FISH P DECOMP Make up a 12.25" string mill to dress inside of 13-3/8" stub. RIH to 1007' MD. Passed mill through stub 7 times. 15:00 - 16:00 1.00 FISH P DECOMP POOH and lay down string mill. Clear and clean the rig floor. 16:00 - 18:00 2.00 FISH P DECOMP Make up a reverse circulating junk basket assembly and RIH to 994'. Wash down to 1017'. PU 55K, SO 55K, ROT 55K, 60 RPM, 500 TO, 400 GPM, 1000 psi. 18:00 - 19:30 1.50 FISH P DECOMP Circulate a high vis sweep ~ 540 GPM, 1150 psi. Continue to circulate until clean returns. 19:30 - 21:00 1.50 FISH P DECOMP POOH with reverse circulating junk basket and lay down. Recovered two metal feces -6" Ion x 1"wide. Clean and clear the rig floor. 21:00 - 22:00 1.00 FISH P DECOMP Service the rig, top drive, crown and drawworks. 22:00 - 23:30 1.50 FISH P DECOMP Wait on 13-3/8" RTTS to arrive on location for use as contingiency barrier. 22:30 - 23:00 0.50 FISH P DECOMP Make up a joint of drill pipe to RTTS and place in the pipe shed for use if necessary. 23:00 - 00:00 1.00 FISH P DECOMP Make up a 12-1/4" mill tooth bit with boot baskets, jars, bumper sub, and drill collars to 123'. Printed: 7/23/2008 2:23:37 PM • • BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/26/2008 00:00 - 00:30 0.50 FISH P DECOMP RIH with 12.25" mill tooth bit, boot baskets and jars to 994'. Work pipe into 13-3/8" stub after sevveral attempts. Continue in hole to 1017'. 00:30 - 10:00 9.50 FISH P DECOMP Obtain drilling parameters. Wash down to 1027'. Mill funk on olua down to 1030'_. Begin drilling 13-3/8" composite bride lu from 1030'to 550 GPM, 616 psi, 70 RPM, 3.5K TO, 18K WOB. Sli s released, ush lu to 9-5/8" stub and finish drillin from 1642' to 1644'. 10:00 - 11:00 1.00 FISH P DECOMP Circulate high vis sweep while rotating and reciprocating pipe. 545 GPM, 800 psi. 11:00 - 13:00 2.00 FISH P DECOMP POOH with 12.25" bit and lay down. Minor wear on teeth indicating bit reached 9-5/8" stub. 13:00 - 13:30 0.50 FISH P DECOMP Pick up the contingiency 13-3/8" RTTS from pipe shed. Break off 10' pup joint. Lay down RTTS. 13:30 - 18:30 5.00 FISH P DECOMP Make up an 11-3/4" washpipe assembly with 12" burn shoe, and boot baskets. Make up a tapered mill inside washpipe. Make up jars, bumper sub and drill collars to 342'. 18:30 - 20:30 2.00 FISH P DECOMP RIH with washpipe/taper mill assembly to 13-3/8" stub at 994'. Work 12" burn shoe into 13-3/8" casing with difficulty; used rotation to right and left. Continue in hole to 9-5/8" stub at 1644'. Wash over 9-5/8" casing past the collar at 1664'., Continue to wash down to 1680' to dress the inside of the stub with the tapered mill. PU 70K, SO 70K, ROT 70K, 70 RPM, 1-2K TO, 320 GPM, 250 psi. Worked burn shoe and washpipe over connection several times with out problems. 20:30 - 21:30 1.00 FISH P DECOMP Circulate a high vis sweep. 540 GPM, 710 psi. 21:30 - 22:00 0.50 FISH P DECOMP POOH with washpipe /taper mill assembly to 64'. 22:00 - 00:00 2.00 FISH P DECOMP Lay down the washpipe /taper mill assembly. Averaoe loss rate of 1 bbl/hr over 24hrs.. 6/27/2008 00:00 - 01:00 1.00 FISH P DECOMP POOH with 9-5/8" washover /taper mill assembly and lay down. Clean and clear the rig floor. 01:00 - 02:30 1.50 FISH P DECOMP Make up an 8-1/2" bit and one stand of drill collars. RIH to 1654' MD. Ta 'unk in 9-5/8" casin and ush down hole 1985' M Took 5-10K under SO weight to move junk down hole. 02:30 - 03:30 1.00 FISH P DECOMP POOH with 8-1/2" bit and stand back drill collars. 03:30 - 05:30 2.00 FISH P DECOMP Bring Baker Backoff Tools to rig floor. Make u Backoff BHA with stabilizer, 6 collars, Backoff tools, and 3 collars. Printed: 7/23/2008 2:23:37 PM • • BP EXPLORATION Operations Summary Report Page 8 of 15 ~ Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: ~~ ' NPT ~~ Phase Description of Operations Date From - To Hours Task Code ~ - - ~ _ __ ~ 6/27/2008 03:30 - 05:30 2.00 FISH P DECOMP RIH to 322'. 05:30 - 07:00 1.50 FISH P DECOMP RIH to 1630' MD filling pipe every stand with fresh water for differential pressure. 07:00 - 08:30 1.50 FISH N HMAN DECOMP POOH to 198' to put shear pins in Backoff Tooi. 08:30 - 11:30 3.00 FISH N HMAN DECOMP RIH with Baker Backoff Tool to 1834' MD filling pipe every stand with fresh water. Bottom anchor on Backoff tool stacking out on 9-5/8" stub. Unable to get Backoff tool inside 9-5/8" casin . 11:30 - 15:00 3.50 FISH N DFAL DECOMP POOH with Backoff Tool and lay down. 15:00 - 18:00 3.00 FISH N DFAL DECOMP Bring a new lower anchor to rig floor. Make up a new Backoff assembly using Duct tape around anchors. RIH with Backoff.assembly to 1890' MD filling pipe with fresh water every stand. 18:00 - 18:30 0.50 FISH P 18:30 - 20:30 2.00 FISH P 20:30 - 22:30 2.00 FISH P 22:30 - 00:00 1.50 FISH P 6/28/2008 00:00 - 01:00 1.00 FISH P 01:00 - 03:00 2.00 FISH P DECOMP Rig up test lines and test pump. DECOMP Set the lower and upper anchors on the Backoff tool on each side of the 9-5/8" collar at 1665'. Bring pressure up to 2000 psi to break connection at 1665'. Bleed pressure to zero and wait for Backoff Tool to reset. Repeat process 10 times to back off 9-5/8" casing. Drop 2-1/4" ball to open circ sub with 1400 psi. Circulate out fresh water C~3 520 GPM, 550 psi. PU 72K, SO 75K. DECOMP POOH from 1890' and lay down the BHA. DECOMP Make up a 9-5/8" spear and RIH to 1051' MD. DECOMP RIH to 1645' MD and tag top of 9-5/8" backed off casing. Continue in hole another 8 feet and engage fish with spear. DECOMP Finish backing out 9-5/8" casing stub and POOH. La down fish ands ear. Length of recovered fish = 19.67'. 03:00 - 04:30 1.50 FISH P DECOMP Clear the rig floor. PJSM. Rig up to run 9-5/8", 47#, L-80, Hydril 563 casing. 04:30 - 09:30 5.00 CASE P TIEB1 Make up Baker screw in sub, landing collar, and ES cementer. Bakerlok all connections below ES cementer. Continue to RIH with 40 joints of 9-5/8", 47#, L-80, Hydril 563 casing. Make up each joint to 18K ft-Ibs. Screw casino into original 9-5/8" BTC casino at 1665'. Slack off to 75K overpull and hold. 09:30 - 14:00 4.50 CASE P TIE61 Pressure test casing and connection to 1500 psi for 10 Circulate 110 degree F, 9.8 ppg brine until returns reach 85 degrees F. 14:00 - 15:00 1.00 CEMT P TIEB1 PJSM with all parties involved in cement job. Make up cement head to 9-5/8" casing. Rig up cement lines and pressure test to 4000 psi. Changed out valve on cement hose. Re-test to 4000 psi - Good. Batch mix first tub of 15.8 ppg Class G cement ~ 14:49 hours. 15:00 - 16:15 1.25 CEMT P TIEB1 Pump 410 bbls (1708 sks) of 15.8 ppg Class G cement. Printed: 7/23/2008 2:23:37 PM • • BP EXPLORATION Operations Summary Report Page 9 of 15 ~ Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABORS 2ES Rig Number: Date 6/28/2008 From - To I Hours I Task I Code I NPT I Phase 15:00 - 16:15 1.25 CEMT P TIEBi Start pumping at 5 bpm, 800 psi. Increase pump rate to 6 bpm. 6 bpm, 1150 psi, 100 bbls away. 6 bpm, 1100 psi, 300 bbls away. Pumped 50 bbls of 2 Ib/bbl CemNet in bbls 315 - 365. 4 bpm, 600 psi, 410 bbls away. Released the closing plug and kicked it out with 5 bbls of H2O. 16:15 - 16:45 0.50 CEMT P TIE61 Switch to rig pumps. Displaced cement with 9.8 ppg brine. Cement returns at surface after 23 bbls displaced. ES cementer closed with 1500 psi. Bled pressure and checked that ES cementer was holding. 91 bbls of excess cement returned to surface. 16:45 - 18:00 1.25 CEMT P TIEB1 Rig down Schlumberger cementers. Rig down cementing head. Continue to hold 50K tension on 9-5/8" casing. Clear the rig floor. Suck out 20" riser and 9-5/8" casing. 18:00 - 22:00 4.00 CEMT P TIEB1 Obtain a Hot Work Permit from drill site 2 pad operator. Make two cuts on 20" riser with WACHS cutter. Monitor % LEL through out job. Cut laterally down 20" with torch and remove ~3' section. Make another 20" WACHS cut near the 30" conductor pipe. Lift and suspend bottom section of 20" riser high enough for WACHS cutter to cut 9-5/8" casing. Center 9-5/8" casing inside 20". 22:00 - 00:00 2.00 CEMT P TIEB1 Wait on cement to reach 500 psi compressive strength befo 00:00 - 06:00 6.00 CEMT C TIEB1 Wait on cement to rea 500 psi compressive strength. Spot tools and equipment in cellar for wellhead work. Clean and maintenance rig. 06:00 - 12:00 6.00 WHSUR C TIEBi Install a centralizer gusset between 20" and 9-5/8" casing. Rig up the WACHS cutter and cut 9-5/8" casing. Pull and lay down the cut 9-5/8" casing. Remove the 20" riser. Dress the 9-5/8" casing cut. Install a new 9-5/8" x 13-3/8" Cameron/McEvov Slip-Lock Energize the seals and test to 3800 psi (80% of collapse). Energize the slips on the wellhead. 12:00 - 20:30 8.50 BOPSU C TIEB1 PJSM. Nipple up the BOP stack with standard configuration (mud cross, vana es, mu cross, ou a ga e, an annu ar . Intall the flow nipple, choke and kill line HCR valves and test plug. Change the top rams to 3.5"x6" variable. Move the blind/shear rams back to bottom of double gate. Grease the choke manifold and install the riser. 20:30 - 00:00 3.50 BOPSU P TIEB1 Pressure test BOP's. Test the annular to 250 psi low, 2500 psi high with a 4" test joint. Test VBR's to 250 psi low, 3500 psi high with a 4" test joint. Test witness waived by AOGCC rep Chuck Scheve. Description of Operations Printed: 7/23/2008 2:23:37 PM C] • BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours !, Task Code NPT ' Phase Description of Operations 6/29/2008 20:30 - 00:00 3.50 80PSU P TIEB1 Test witnessed by BP WSL Kris Honas and Nabors Tool Pusher Bruce Simonson. 6/30/2008 00:00 - 01:30 1.50 BOPSU P TIEB1 Test BOP's to 250 psi low 3500 psi high with 4" test joint. 01:30 - 02:00 02:30 - 03:30 03:30 - 09:30 09:30 - 10:30 10:30 - 11:30 Test witness waived by AOGCC rep Chuck Scheve. Test witnessed by Nabors Tool Pusher Bruce Simonson and BP WSL Kris Honas 0.50 BOPSU P TIEBi Pull test plug, install wear ring and blow down lines. 1.00 CLEAN P CLEAN PJSM. Make up an 8-1/2" tri-cone bit with boot baskets, bit sub, bumper sub, and jars. RIH 1550' MD. 6.00 CLEAN P CLEAN Pressure test casing to 1500 psi for 5 minutes prior to drilling 1.00 CLEAN P 1.00 CLEAN P 11:30 - 12:00 I 0.501 CLEAN I P 12:00 - 14:00 2.00 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 16:30 1.50 CLEAN P 16:30 - 17:30 I 1.001 CLEAN I P 17:30 - 18:30 1.00 CLEAN P 18:30 - 19:30 1.00 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 21:30 1.00 CLEAN P 21:30 - 23:30 2.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 7/1/2008 00:00 - 01:30 1.50 DHB P Obtain drilling parameters. Wash down to closing plu at 1627' MD. ri out 80 RPM, 1-2K TO, 10K WOB, 450 GPM, 770 psi. CLEAN RU lines and pressure test 9-5/8" casin to 3500 si for 3 charted minutes. Bled off 150 si. CLEAN Obtain drilling parameters: PU, SO, ROT 85K, 1 K TO, 60 RPM. Tag junk at 2338'. Dry drill junk pumping as needed to fill boot baskets down to 2339'. Lost 5K of weight on bit. CLEAN Circulate bottoms up at 400 gpm, 690 psi. Composite, sand and rubber found in returns. D drill to 2343' without taking any weight. Pick up 10' and circulate a high vis sweep at 400 gpm. Ta to of sand at 2345'. CLEAN POOH and lay down bit and 3 drill collars. CLEAN MU a reverse circulating junk basket with two boot baskets, bumper sub and jars. CLEAN RIH with RCJB to ES cementer at 1628'. Set down 15K. rotate through ES cementer down to 1651'. 30 RPM, 3-8K TO. CLEAN RIH to top of sand at 2345. Drop ball and open RCJB. D rill 30 RPM, 3-4K TO, PU, 72K, SO 75K, ROT 75K. CLEAN Circulate bottoms up at 320 GPM, 3860 psi, 30 RPM. CLEAN POOH and break out reverse circulating junk basket and boot baskets. Lar a iece of composite plu recovered with muleshoe bottom -8" Ion and 5" OD . Smaller pieces of rubber and composite also recovered. CLEAN Make RCJB and boot baskets back up and RIH to top of sand at 2350'. CLEAN Mill down with RCJB to 2360'. PU 73K, SO 76K, ROT 75K, 1 K TO. CLEAN POOH with RCJB and lay down. Recovered 4 small pieces of rubber and one small piece of composite (2" x 0.5" x 0.125"). CLEAN Lay down BHA and clear the floor. DECOMP Make u Halliburton's RBP fishin tool. RIH to fishing neck on RBP. RIH and swallow fishing neck on RBP. Printed: 7/23/2008 2:23:37 PM U BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date ~ From - To Hours ~ Task Code NPT 7/1/2008 ~ 01:30 - 02:30 1.00 I DHB P 02:30 - 03:00 I 0.501 DHB P 7/2/2008 03:00 - 03:30 I 0.501 DHB I P Spud Date: 9/2/1970 Start: 6/10/2008 End: Rig Release: 7/9/2008 Rig Number: Phase Description of Operations DECOMP Circulate the hole clean at max rate 550 GPM, 800 psi. Returned sand and small pieces of rubber and composite. Continued to circulate until no pieces of composite returned. DECOMP Rotate fishing tool on RBP fishing neck to engage. Pick up 5K over to confirm latch. Rotate to release packer element. Pick u 25K over RBP released. Slackoff to confirm release. Allow packer element to relax for 2 minutes. Taking weight on pick up and slack off. Pick up while rotating to ensure full release. Pick up to 95K over per Halliburton hand. RBP free. DECOMP POO . No overpulls. Packer element not on RBP. 03:30 - 04:00 0.50 DHB P DECOMP Lay down RBP. Pick up drill singles and run in hole. Make up a RCJB at Baker Fishing with 8.25" OD x 5.25" ID. Discuss plan forward with Anchorage Team. SIZE OF FISH: 5-1/2" ID x 8" 04:00 - 07:00 3.00 CLEAN P DECOMP PJSM. PU DP to 1027' and stand back in derrick. 07:00 - 08:30 1.50 CLEAN P DECOMP PJSM. PU RCJB assembly to 228'. 08:30 - 10:30 2.00 CLEAN P DECOMP RIH to 4610'. 10:30 - 14:30 4.00 CLEAN P DECOMP PU drill pipe to 8071'. 14:30 - 17:00 2.50 CLEAN P DECOMP W hand ream with RCJB at 300 m with 3900 psi to top of stump at 8498'. Up weight 175k, down weig t 145k, RT 162k. Torque 4-5k at 20 rpm. 17:00 - 18:30 1.50 CLEAN P DECOMP Drop dart and open circ sub. Pump hi-vis sweep surface to surface at 500 gpm with 2250 psi. Pump dry job. Brine weight in and out 9.6 ppg. 18:30 - 19:30 1.00 CLEAN P DECOMP PJSM. Cut and slip 112' of drilling line. Service drawworks and crown. 19:30 - 20:00 0.50 CLEAN P DECOMP Service top drive. 20:00 - 23:30 3.50 CLEAN P DECOMP POOH with RCJB to 228'. 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM. La down RCJB assembl . No rubber seal recovered. Clear and clean floor. 00:00 - 02:00 2.00 CLEAN P DECOMP PJSM. PU Dressoff BHA assembly to 234'. 02:00 - 04:30 2.50 CLEAN P DECOMP with dr ff I t tubin t m '. Up weight 176k, down weight 145k, RT 160k. 04:30 - 05:30 1.00 CLEAN P DECOMP Dress over and swallow 15' of tubin stum . Dr 60 rpm with 5-6k torque. Work up and down several times. Pump at 200 gpm with 1200 psi. 05:30 - 06:30 1.00 CLEAN P DECOMP Pump sweep S-S at 475 gpm with 200 psi. Pump dry job. 06:30 - 09:30 3.00 CLEAN P DECOMP POH to BHA at 234'. 09:30 - 12:30 3.00 CLEAN P DECOMP PJSM. LD dressoff BHA. Clean and clear rig floor. 12:30 - 14:00 1.50 BOPSU P RUNPRD Pull wear ring. Set test plug. Change upper rams from 3-1/2" x " I to 7" m 14:00 - 15:30 1.50 BOPSU P RUNPRD Test 7" rams with' 7" test joint to 250 psi low/3500 psi high. 15:30 - 18:30 3.00 BOPSU P RUNPRD Drain BOP stack, pull 7" rams. Change out 7" rams. Continue rigging up to run 7" tieback. 18:30 - 19:00 0.50 BOPSU P RUNPRD Re-test 7" rams with 7" test joint to 250 psi low/3500 psi high as per AOGCC. Witness waived by Chuck Scheve with AOGCC. Test witnessed by WSLs Mitch Skinner and Adrienne McVey and Toolpusher Ken Helf. Good test. RD test equipment. 19:00 - 00:00 5.00 CASE P RUNPRD Pick up Unique overshot, HES baffle collar, and HES ES cementer. RIH with 7", 26#, L-80, BTC-M tieback string to Printed: 7/23/2008 2:23:37 PM ~ ~ BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT `Phase Description of Operations 7/2/2008 19:00 - 00:00 5.00 CASE P RUNPRD 3720'. Average makeup torque 7800 ft-Ibs. 7/3/2008 00:00 - 09:00 9.00 CASE P RUNPRD PJSM. Run total of 113 joints of 7", 26", L-80, BTC-M casin . Rig up an run 7°, 26# L-80 T -II casin .Tor ue turn each joint of TC-II to 10,100 ft-Ibs. Run in to tubing stub and swallow same. Saw shear pins and both 4' & 12' in shear. Bottom out and space out 3' from fully inserted and no coupling in wellhead area. 195 klbs down. 225 klbs up. 09:00 - 10:30 1.50 CEMT P RUNPRD MU cement head and lines. Open ES cementer with 3300 psi - OK. Circulate thru open cementer and cut brine weight to 9.4 PPg• 10:30 - 10:45 0.25 CEMT P RUNPRD PJSM with rig crew and service company personnel. 10:45 - 12:45 2.00 CEMT P RUNPRD Prime up cement unit. Test cement line to 4000 psi. Line up on rig pump and pump 25 bbls viscosified seawater. Switch to Little Red and um 130 bbls diesel - 2 bpm at 1800 psi final pressure. 12:45 - 13:30 0.75 CEMT P RUNPRD Switch to cement unit. Pump 23 bbls Mudpush II spacer at 11.5 pg. Mix & pump 140 bbls (675 sx) Class U cemen at ~~~ . 95 bbls awa 6 m ~ 1400 psi. 140 bb s awa m ~ si. Release closin lu for cementer. 13:30 - 16:00 2.50 CEMT P RUNPRD Displace with 9.4 ppg brine. 6 bpm ~ 525 psi at start. 6 bpm ~ 580 psi at 100 bbls away. 6 bpm at 550 psi at 200 bbls away. Started getting diesel back. Divert to slop tank and continue displacement. Slow to 2 bpm for last 15 bbls. Bump plug with 2500 psi and see cementer close. Increase to 2900 psi and hold for 5 min. Bleed off pressure but flowback did not stop. Re-pressure to 3500 psi and hold for 15 min. Bleed off -. no flowback. Cementer is closed. CIP at 15:30 hrs. Ri dow cementers. 16:00 - 18:00 2.00 CEMT P RUNPRD PJSM. Rig up and pump 5 bbl top job down 9-5/8" x 20" annulus. Rig down cementers, flush lines. 18:00 - 22:30 4.50 CEMT P RUNPRD WOC until cement reaches 500 psi compressive strength. Clean rig, clean trip tank and pits 1 & 2, prepare to change out tubing spool 22:30 - 00:00 1.50 CEMT P RUNPRD LD cement head. Suck brine from casing with Supersucker. Prepare to lift stack for casing cut. 7/4/2008 00:00 - 02:30 2.50 BOPSU P RUNPRD Slit BOP stack. Set 7" emer ency slips with 120,000 Ibs tension. RU Wachs cutter and cut 7" casing. LD cut casing. Stand back BOP stack. 02:30 - 05:00 2.50 BOPSU P RUNPRD Install tubing spool with 7" secondary packoff. NU BOP. Test packoff and break between tubing spool and base flange to 4300 psi. Good test. 05:00 - 07:00 2.00 BOPSU P RUNPRD Install secondary annulus valve on IA. Change out top rams to 3.5" x 6" VBRs. 07:00 - 09:00 2.00 BOPSU P RUNPRD MU 4" test joint. Set test plug. Fill stack and check for leaks. Test 3.5" x 6" VBRs with 4" and 4.5 test joints to 250 psi low/3500 psi high. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. AOGCC witness of test waived by Bob Noble. RD test equipment. Install wear ring. 03:00 - 10:30 1.50 CLEAN P CLEAN PU 6-1/8" cleanout assembly and RIH to 216'. 10:30 - 13:30 3.00 CLEAN P CLEAN RIH to 8350'. 13:30 - 19:30 6.00 CLEAN P CLEAN Tag cement stringers at 8350. Plug rubber in returns. Tag solid cement at 8455. Tag and drill ES cementer at 8482. Test Printed: 7/23/2008 2:23:37 PM n .~ r~ BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: ~ ~ Date From - To Hours Task I Code ! NPT Phase , Description of Operations 7/4/2008 13:30 - 19:30 6.00 CLEAN P CLEAN casing to 3500 psi for 10 minutes; good test. Drill baffle collar and clean out to 5.5" x 7" XO at 8491'. 70 RPM, 5-5.3K ft-Ibs torque, 400 gpm/2280 psi, 3-5K WOB. Up weight 175K, down weight 135K, rotating weight 145K. 19:30 - 20:30 1.00 CLEAN P CLEAN Pump high-vis sweep S-S at 450 gpm/2750 psi. No increase in cuttings. Brine weight in and out 9.4 ppg. 20:30 - 21:30 1.00 CLEAN P CLEAN Test 7" to 3500 si for 30 minutes; bled off 100 psi in 15; inutes and 100 si in second 15 minutes, Double-block surface equipment and re-test; same result. Consult with Town; proceed with operations. 21:30 - 00:00 2.50 CLEAN P CLEAN Pump dry job and POH from 8491' to 2365'. 7/5/2008 00:00 - 01:30 1.50 CLEAN P CLEAN Continue POH from 2365' to 216'. 01:30 - 03:00 1.50 CLEAN P CLEAN LD 6-1/8" cleanout assembly. Clean out junk baskets. Clean and clear rig floor. 03:00 - 05:00 2.00 CLEAN P CLEAN RU 2-7/8" PAC pipe handling equipment. PU next cleanout assembly (Baker 4-5/8" mill to clean out 5-1/2" tubing) and RIH to 465'. 05:00 - 08:00 3.00 CLEAN P CLEAN FjIH with 4-5/8" mill cleanout assembly, Tag fill at 8491'. Up weight=170 klbs, down weight=135 klbs, rotating weight=150 klbs ~ 30 rpm. 4K ft-Ibs free torque. Establish circulation at 150 gpm, 460 psi. 08:00 - 09:30 1.50 CLEAN P CLEAN Wash and ream from 8491' to 8606'. 200 gpm/760 psi, 30 rpm, 4K ft-Ibs free torque. Top drive stalled at 8606; tagged 4-1/2" x 5-1/2" crossover. Pull up and tag several times with same result. 09:30 - 11:30 2.00 CLEAN P CLEAN Pump ahigh-vis sweep S-S at 326 gpm/1995 psi. Lots of sand in returns. Pump second sweep; clean returns. Pump dry job. Brine weight in/out=9.4 ppg. 1 f :30 - 14:30 3.00 CLEAN P CLEAN POH from 8606' to 465'. 14:30 - 17:00 2.50 CLEAN P CLEAN LD 4-5/8" mill BHA. Clean out boot baskets; got back cement and a few pieces of aluminum. RU to run 2-7/8" PAC pipe. 17:00 - 18:00 1.00 CLEAN P CLEAN MU 3-5/8" RCJB cleanout assembly to 470'. 18:00 - 20:00 2.00 CLEAN P CLEAN RIH from 470' to 8599'. Drop ball. Pumped ball on seat with 95 gpm/2070 psi. Tag 4.5" x 5.5" crossover at 8606'. Up weight=170 klbs, down weight=140 klbs, rotating weight=155 klbs. 20:00 - 22:00 2.00 CLEAN P CLEAN Wash and ream from 8606' to 8645'. Pumping at 100 gpm/2050 psi. 4200 ft-Ibs free torque, 4700 ft-Ibs working torque at 30 rpm. W0B=3-5klbs. Weight and torque increase at 8645'; tagged top of junk catcher. Pull up and tag again to reconfirm. Set down 8 klbs. Sand in returns. 22:00 - 23:30 1.50 CLEAN P CLEAN Pump 25 bbl high-vis sweep 2000' up annulus through RCJB. Shut down and drop dart to open circ sub; pump second high-vis sweep through circ sub and displace well to seawater. Sand back with first sweep. Sand cleaned up with second sweep. Seawater weight in/out=8.5 ppg. 23:30 - 00:00 0.50 CLEAN P CLEAN POH from 8645' to 7477'. 7/6/2008 00:00 - 01:30 1.50 CLEAN P CLEAN Continue POH from 7477' to 470'. 01:30 - 04:00 2.50 CLEAN P CLEAN LD 3-5/8" RCJB assembl .Empty RCJB and boot baskets; retrieved -0.5 gal cement, small metal pieces, and banding. Clean and clear rig floor. 04:00 - 05:30 1.50 CLEAN P CLEAN PU 4" GS spear and BHA to 465'. 05:30 - 07:00 1.50 CLEAN P CLEAN RIH with 4" GS s ear to 8645'. Establish circulation at 184 Printed: 7/23/2008 2:23:37 PM • • BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: i Date ~~~~ From - To 'I Hours Task ~~ Code'.... NPT ~~~, Phase Description of Operations 7/6/2008 05:30 - 07:00 1.50 CLEAN P CLEAN gpm/2225 psi. Up weight=175K, Down weight=140K. 07:00 - 11:00 4.00 CLEAN P CLEAN Tag junk catcher at 8645'. Set down 5K. Repeat to confirm. Slack off and latch GS profile with spear. Up weight=200K, down weight=175K. Junk catcher came free with 240K. Open circ sub and pump dry job. Seawater weight in/out=8.5 ppg. 11:00 - 14;30 3.50 CLEAN P CLEAN POH with junk catcher from 8645' to 465'. 14:30 - 16:00 1.50 CLEAN P CLEAN LD 4" GS spear BHA. LD lunk catcher. Junk catcher contained ~0.5 al of rubber cement and metal. 16:00 - 17;00 1.00 CLEAN P CLEAN PU 3-5/8" RCJB assembly to 471'. 17:00 - 19:30 2.50 CLEAN P CLEAN RIH from 471' to 8600'. 19:30 - 20:30 1.00 CLEAN P CLEAN Break circulation at 100 gpm/2200 psi. Up weight=175K, down weight=142K, rotating weight=158K. Free torque=4500 ft-Ibs. Wash to 8652' and tag top of sluggits. Wash and ream down to WRP at 8660'; set down 5K. 20:30 - 22:00 1.50 CLEAN P CLEAN Pump high-vis sweep 2000' up annulus through RCJB. Pump at 100 gpm/1650 psi. Open circ sub and pump sweep to surface at 450 gpm/1800 psi. Minimal cuttings returned with sweep. Pump dry job. Stand back 1 stand. Seawater weight in/out=8.5 ppg. 22:00 - 00:00 2.00 CLEAN P CLEAN POH and LDDP from 8600' to 7293'. 7/7/2008 00:00 - 03:30 3.50 CLEAN P CLEAN PJSM. Continue POH LDDP from 7293 to 3607'. 03:30 - 05:00 1.50 CLEAN P CLEAN PJSM. Cut and slip drilling line. 05:00 - 06:00 1.00 CLEAN P CLEAN Service rig and top drive. 06:00 - 08:30 2.50 CLEAN P CLEAN Continue POH LDDP from 3607' to 471'. 08:30 - 10:30 2.00 CLEAN P CLEAN LD 3-5/8" RCJB assembly. Clean and clear rig floor. 10:30 - 12:00 1.50 BOPSU P CLEAN Pull wear bushing. Suck out BOP stack. Install test plug. 12:00 - 17:00 5.00 BOPSU P CLEAN Test BOPE to 250 si low/3500 si hi h (2500 psi high on annular preventer). Test rams with 4-1/2" test joint. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. Witness of test waived by Bob Noble of AOGCC. 17:00 - 17:30 0.50 BOPSU P CLEAN LD test joint. Blow down choke manifold, top drive and cellar lines. 17:30 - 19:30 2.00 BUNCO RUNCMP RU to run 4-1/2" completion. 19:30 - 00:00 4.50 BUNCO RUNCMP PJSM. MU and RIH with STLNAM Top tubing tail (muleshoe, no-go locator, X-nipple with RHC-M plug, Baker S-3 packer). Bakerlok all connections below packer. Run 4.5", 12.6#, 13Cr-80 VAM To completion to 2103'. Makeup torque on STL (first 2 joints) 1900 ft-Ibs; ma eup torque on VAM Top 4440 ft-Ibs. 7/8/2008 00:00 - 09:00 9.00 BUNCO RUNCMP PJSM. Run 4 1/2", 12.6#, 13Cr-80, Vam Top tubing to 8491'. Bottom out on no-go collar. 09:00 - 10:00 1.00 BUNCO RUNCMP Space out. RIH with landing joint and land hanger. Depth set at 8579'. 10:00 - 10:30 0.50 BUNCO RUNCMP Rig down tubing running equipment. 10:30 - 12:30 2.00 BUNCO RUNCMP PJSM. Reverse circulate 130 bbls clean seawater, follow with 91 bbls clean seawater with corrosion inhibitor, followed by 65 bbls of clean seawater with no corrosion inhibitor. Pump at 3 bpm with 360 psi. 12:30 - 14:30 2.00 BUNCO RUNCMP PJSM. Drop ball and rod. Pressure tubing up to 3500 asi. Set __ .___. acker and hold for 30 minutes for tubin ressure test - OK. Bleed pressure to 1500 psi. Pressure up on annulus to 3500 si and test for 30 minutes - OK. Bleed off annulus and tubing to zero. Pressure up annulus and shear DCR at 1800 psi. Printed: 7/23/2008 2:23:37 PM BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: 02-04 Common Well Name: 02-04 Spud Date: 9/2/1970 Event Name: WORKOVER Start: 6/10/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/9/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT ~, Phase Description of Operations 7/8/2008 12:30 - 14:30 2.00 BUNCO RUNCMP Pump both ways to confirm. 14:30 - 15:00 0.50 BOPSU P RUNCMP PJSM. Dry rod TWC. Test from both sides to 1000 psi - OK. 15:00 - 16:30 1.50 BOPSU P RUNCMP PJSM. Ni le down BOP stac 16:30 - 22:30 6.00 WHSUR P RUNCMP Prep hanger neck. NU adapter flange and tree. Test void to 5000 psi for 30 minutes - OK. Attempt to test tree. Fluid leaking out of Autoclave Vent Port. Re-torque adapter flange to 1900 ft/Ibs. Still leaking. 22:30 - 00:00 1.50 WHSUR N SFAL RUNCMP Suck out tree. ND tree and adapter flange. Inspect metal to metal seal. The SRL Seal showed some damage. 7/9/2008 00:00 - 03:30 3.50 WHSUR N SFAL RUNCMP PJSM. Change out SRL seal. Nipple up adapter and tree. Re-test void to 5000 psi for 30 minutes - OK. Fill tree and test valves and for leaks - OK. 03:30 - 04:00 0.50 WHSUR P RUNCMP PJSM. Ri u DSM lubricator. Test to 500 psi - OK. Pull TWC. 04:00 - 04:30 0.50 WHSUR P RUNCMP Rig up LRS for freeze protect. 04:30 - 06:30 2.00 WHSUR P RUNCMP PJSM. Test LRS lines to 4500 psi - OK. Pump 75 bbls diesel freeze protect at 4 bpm with 1600 psi. Line up and U-tube for 1 hour. 06:30 - 11:00 4.50 WHSUR P RUNCMP Install BPV. Attempt to make up tree cap. Unable to make up Otis connection. Gather up new flange assembly. Rig down pits. Install new connection. Test to 5000 psi - OK. 11:00 - 12:00 1.00 RIGD P RUNCMP Secure well with guages and needle valves. Prep rig for move to 02-40. Release rig at 12:00 hours. Printed: 7/23/2008 2:23:37 PM 02-04A RWO • Maunder, Thomas E (DOA) • Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Monday, July 07, 2008 2:01 PM To: 'Nadem, Mehrdad' Subject: RE: 02-04A (1 _ 8) RWO Mehrdad, t5,co_`~ I remember a call, but not the specifics. It appears that the goal of delivering a repaired, producible well will be realized. Having "fall-back" size options is a good luxury to have available. required pressure tests, I don't see an issue here. Call or message with any questions. Tom Maunder, PE AOGCC So long as the well satisfactorily passes any From: Nadem, Mehrdad [mailto:NademM@BP.com] Sent: Monday, July 07, 2008 9:55 AM ~,~-.~ ~ ~~~ ~` ~ ~~~~ To: Maunder, Thomas E (DOA) Subject: 02-04A RWO Tom, This is a follow up to my telephone call c change of plans in the RWO operations on 02-04A. The change of plan was the result of having difficulty washing over the 13-3/8" stub. The initial plan was to tieback the 13-3/8" to surface, fully cement it, and place the wellhead on this new string. As an alternate, we placed the well head on the 9-5/8", and ran the 7" scab liner to surface as tieback. This string was cemented to 3,400' leaving the future sidetrack options open. I have attached a new schematic to this message. I am available to provide you with additional information at your request. Best Regards, Mehrdad Nadem Operations drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademmC`~bp.com «02-04A RWO 2008-MOD.jpg» 7/7/2008 8,380'- 4112" HES XNipple IQ=3,813" $,400' - ~" x 4112" Baker S-3 Packer I If • $,420' - 4112" HES X N fipple ID~.$13" $,480' - 41 fi7' 1'2.ti#, 13CR-;Jr1~:IT4P r $~5~0' - 4 1fi2" t'?.~, 13%8-STL ` 8,410'- ~". 26#, L-$0, BTC-hAC1D 8,412' - ~ 112" x7" 13C R Ported Crossover $,4~2' -5-11'1', 17# Unique overshot•13CR ~~' 9-fir6' X ~11I 9AKER5~4B PKR $613 9-11Z' X It-1FZ XO, ID- 3958' ~~ ~-112'GSB0.LSUB,ID-3.DDD' ~+s ~I.1JI OTISX LANDING NP, ID- 3813' (B EH ND LINER) $~7~' XD 3-111' X2-7J8', D-2.1,1' TREE- l.IGBlOY WELLHEAD- I,IC~il1Y ACTUATOR- ~_. AXELSt7N I~ . EL E+1 • 61.' B F. EIEV - _ I4O P - _ 1.~c A1gle - 9t ~ 11126' Det~m LID- 9395' Daum lV D - -_._ _ . 86m' SS 133 CSG, 72ip, N~80, ID- ^2,900' - ~~~~~~ ~~~ I 3Q CO ND ~ER:~T~REEHASAAD~f~ UPUUP,RDFRO~ I 1,210' - 13.31$" HES ES Cementer 886' - 13-3~" 72#, N-$0, Stub 2,000' - 4112" H ES )C N i pp le I Q=3.815' 1,954' - 9-61r~' E S Cementer 1 X664' - 9-518" 47#. L-80. Hyd, IQ=$.881„ NinimumlD = 2.41" 8679' ~ 112" X 2-718'X(7 5.111' THG-PC,17a7, LSO, D2~2 bpt, D - 4,8912' $61g lOP OF h11I 7EG-PC $619 4112" HES UURP - 8,640' y lOP OF2-7~ LNR-CT $673' Gas Lift Mandrels S T MD TVf? TYPE 2 3x27 3x00 4111' x 1" 1 6228 6000 411Z' x 1" 8738 +-111' 8A KER SHEA RD UT SU9 I ~-111' TBG-PC,1216~1, N-~, .D1 S2 bpi, ID- 3958' I $712' I~ El ~7ip,Sd096,ID-8b81' ~ ' ~ 2-7r8' L NR~'Tb SA'. L~0 F LAS, .CDSt 9 bpt, D - 2.~ ~1' I I 11766' I DATE RE'+i BY COLILIENTS DW,TE RBJ BY COI.II.IENTS 1411484 ORIGINAL COMPLEf14N C13127A6 RPH+PJC WAh/HiSFTY NOTE DELETE 491841J6 LAST '~nIORF~DV ER 05111 ~Q2 ATQ+'TL H S Ef C19 P 0711 ~A3 61A140q K SET 8143 CB P 0&~~Q3 ATDFrLH PAIGH DEPTHCORR~TiDN OSJ19At 9JLIcNI ADPERPS;SETCBP P RUDHO E 8 AY UNIT WELL: 02-0~A P6illlf M1b:'9961680 API N0: 50-029-3106-01 36, TI 1N, R1 ~E, X07282 FEL & 1 ~3$.~3 F 6R Eeplorallon (Ala ~Na j P6~PDRATC-N SU~II.IP~RY REF LOG: BHCS or iDJ9119B0 ANGLEATTOP PERF:78~ 9736' Note: Refe rb Prodiotb~ DB tar i tbrkalpe rt~ia SIZE SPF FRER~IAL Op1~gI DATE 2' 6 97 36 - 9796 0 05J'19V04 2' 6 976 -9776 4 OS1910~ 2' ~ 9862 -10722 O 11A9/99 2~1 ~ t 10290 -1 D3S0 0 09V17196 2-1 ~ ~ 10150 -10150 C 09117196 2-1 ~ ~ 10630 -11150 C 09127!56 2' ~ 1 1250 -1 1290 C 11A9V99 2 i 1 1350 -1 1580 C 11A9V90 I 918' ~IILLOUrWINCOW 9306'-9321' I 11210' 3~T~ HES CIBP, D'SI11A2 2-7r8' QAV fS LYNCH F LOAT SHD E 06/27/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth vc~,~~ J U ~. ~~ 2008 Wall .Inh fk I nn nee nH..n . NO. 4763 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 nMw DI f~..lwr nn N-04A 11962603 _, L e ~G ._..~; ~, PRODUCTION PROFILE 06/23/08 1 1 L2-06 11999020 PRODUCTION PROFILE ~r^ ~ ..y ~'-~'"'_ : ;-, .,, 06/15/08 1 1 L3-31 12005214 MEMORY SBHP A~ ~~~~~ s~ Ea~~-~j`rt~~~`~ 06/11/08 1 1 C-02 11982437 PRODUCTION PROFILE ; ~} "~' •~ ~ ~- -'-;~ ~. ° ``'' 06/20!08 1 1 E-39A 12066529 SCMT ,~~~~ ~~- ~,~ ~ ~' ~°' ~°`-~ 06/19/08 1 1 MPC-09 12005215 MEM PROD PROFILE /L,~- ~- ~.1?~ P~,,t::~~^'~"' 06/12/08 1 1 W-31 12014027 LDL ¢ r}"`~ _- ,^-<~ + ~ <~"- "? "~) 06/15/08 1 1 02-04A 11962602 USIT .- e ~ ~"'P (~ 06/22/08 1 1 02-04A 12086662 USIT j `=~ f~ .._ / •`° ~- d t' X1.0 06/20/08 1 1 r~cwac nc,nlvvrv~~vuc nc~.ciri tl7 .71larVlrVla HNU Fit! UFfIVINta VIVt I:VF'Y tA~:F1 I U: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ii "!+1i• Date Delivered: Alaska Data & Consulting Services r 2525 Gambell Street, Suite 400'f Anchorage, AK 99,503-2838 ' ATTN: Beth i ,' j / ~ ~ _.. Received by: , ,. i • • • • ?__, b, ~:,~^~ a"~.a~ ~.) -~°~ ..} ~~~~ a)~.~~~, I (.,:3 G1~~i..l C~~..J ~~~ ..1 .~ ~t~ SARAH PAL/N, GOVERNOR COI~TSER~TIO CO IISSIpH Mehrdad Nadem Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 02-04A Sundry Number: 308-161 ~tc~~~i~l~~ M~~' ~ $ 2008 Dear Mr. Nadem: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 i 1~~ V 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, --~r~_.. Daniel T. Seamount, Jr. ~ Chair DATED thisz~ day of April, 2008 Encl. .~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~~ `~~~1 ass 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Ot Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ RWO Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Ex location Alaska Inc. Development 0 Exploratory ^ 198-1580 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20064-01-00 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: Spacing Exception Required? Yes ^ No ^~ 02-04A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 028308 64 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): 11766 9006.8 10386 9052 10386, 10805, 11210 --- Casing Length Size MD TVD Burst Collapse Conductor 372 20" 133# K-55 30 - 402 30 - 402 2320 1500 Conductor 805 20" 94# H-40 402 - 1207 402 - 1207 1530 520 Surface 2669 13-3/8" 72# L-80 25 - 2694 25 - 2694 4930 2670 Production 1999 9-518" 47# SOO-95 25 - 2024 25 - 2024 8150 5080 Production 3946 9-5I8" 40# SOO-95 2024 - 5970 2024 - 5767 6820 3330 Production 2395 9-5/8" 43.5# SOO-95 5970 - 8365 5767 - 7957 7510 4130 Production 1328 9-518" 47# SOO-95 8365 - 9693 7957 - 9035 8150 5080 Production Patch 20 9-5/8" 53:5# L-80 2433 - 2453 2433 - 2453 7930 6620 Liner 3093 2-7/8" 6.5# L-80 8673 -11766 8246 - 9007 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9736' -11580' 9046 - 9009 5-1/2" 17# / 4-1/2" 12.6# L-80 / N-80 8615 / 8740 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8" Baker SAB PKR / 5-1/2" Otis RQM SSSV Nipple 8572 / 2186 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 1-May-2008 Oil Q Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name Mehrdad Nadem ;l; ~~~~' Title Drilling Engineer ~~~- Signature ~- ~~ ~' Phone Date Prepared By Name/ Phone # u ~ h _.-- 564-5941 4/28/2008 , ,~ . DeWavne R. Schnorr 564-5174 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~-' ~,s~- Q ~ ~ ~~~ -I~ r~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~ t ~~ P5 ~S~ ,.. _ ~~. ~~~~~ kk a 1D00 Subsequent Form Required: ~f1 APPROVED BY A roved b : COMMISSIONER THE COMMISSION Date: pp y ~ o~ $ ~,~~o Form 10-403 f~evised 006 Submit in Duplicate by G~~~ 02-04A Rig Workover • The. primary objectives of the 02-04 RWO are to repair the leaks in the 9-5/8" production casing and the 20" surface casing. The scope of this workover includes cut and pull of the 5-1/2" tubing, removing the HOMCO 9-5/8" casing patch, cut and pull of the 9-5/8" and the 13-3/8" casing above top of cement, and running new 9-5/8" and 13-3/8" casing strings to surface. The 20" casing and the 30" conductor will be cut at ground level. Anew 13-3/8" wellhead will be installed. A 7" scab liner will be run, and will fully be cemented from the 5-1/2" tubing stub to -2,900' MD. The completion will tubing will be 4-1/2", 12.6#, 13CR. Well Type: Producer Estimated Start Date: June 1, 2008 Pre-rig prep work: 1. Bleed OOA, OA, IA & T to zero psi. PPPOT T, IC, and OA. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage. 2. RU slickline. RIH and set a WRP in the 4-1/2" tubing at -8,640'. Lay 100# of sluggit on top of the WRP 3. MIT T to 3,500 si for 30 minutes prior to the jet cut. If this test fails, pressure test the WRP with a retainer to 3,500 ps~-mTinules. is is to establish the WRP as a barrier during ND. 4. Jet cut the 5-1/2" tubing in the middle of a first full joint above the sliding sleeve at 8,423'. 5. Circulate the well to seawater through the tubing cut. 6. Perform CMIT T x IA to 3,500 psi for 30 minutes. Determine the leak rate if it fails. 7. MIT OA (9-5/8" x 13-3/8") to 2,000 psi for 30 minutes. 8. Freeze protect the IA and tubing with diesel to 2,200'. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanaer. Secure the well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Proposed Procedure: 1. MIRU Nabors 2ES. 2. Nipple down tree. Nipple up and test BOPE to 250 psi low and 3,500 psi high. 3. Circulate out the diesel freeze protection, and displace the well to kill weight fluid. 4. Pull and LD the 5-1/2" tubing from the jet cut. 5. RU E-line and run USIT in the ~-5/8" casing. The USIT will be used to confirm the top of cement in the 9-5/8" x 13-~ atsfnulus. 6. Set a retrievable bridge plug in the 9-5/8" casing below the planned cut (depth of cut is determined from the USIT log). Test the RBP to 3,500 psi for 30 minutes to confirm a competent seal. Spot 50' of sand on top of the RBP. 7. Cut and pull the 9-5/8" casing in the middle of the second joint above TOC. 8. RU E-line and run USiT in the 13-3/8" casing. The USIT will be used to confirm the top of cement in the 13- " x 20" annulus. ~~g • • 9. Cut and pull the 13-3/8" casing in the middle of the second joint above TOC. 13-3/8" casing also will be cut internally at surface below the double acting slips. 10. RIH with a new string of 13-3/8" casing and cement to surface. _ ~ ry~\~s:~•~ ~,P,~,~~~. ~ ec~SS-~s~. 11. Cut the 30" conductor and 20" casing at ground level. ~,.y~LGS~~-~- 12. Install new McEvoy wellhead. ~ 13. RIH with a new string of 9-5/8" casing and cement to surface. 1"~-'~~~~ ~l~/b~~ 1Z~~ 14. Run a 7" scab liner and cement to the top of liner. The scab liner will swallow the 5-1/2" scab liner with a crossover and an overshot. 15. RU 2-7/8" Pac pipe stinger with RCJB, RIH and remove debris from the top of WRP. 16. RU and run 4-1/2", 12.6#, 13CR tubing to surface. 17. Displace the IA to packer fluid and set the packer. 18. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 19. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = MCEVOY WELLHEAD = MCEVOY ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP = ? Max Angle = 94 @ 11128' Datum MD = 9355' Datum TVD = 8800' SS • 02 2186' -~5-1/2" OTIS ROM SSSV NIP, ID = 4.562" 2433' - 2453' s-5/s" CSG PATCH (10/27/80) ' 13-3/8" CSG, 72#, N-80, ID = 12.347" ~ 2694' Minimum ID = 2.441" @ 8679' 3-1 /2" x 2-7/8" XO 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID = 4.892" ~ 8615' TOP OF 4-1/2" TBG-PC 8615' 8423' I-~ 5-1/2" OTIS SLIDING SLV, ID = 4.562" 8547' S-1/2" BOT PBR ASSY 8572' 9-5/8" X 5-1/2" BAKER SAB PKR 8615' 5-1/2" X 4-1/2" XO, ID = 3.958" TOP OF 2-7/8" LNR - CT ~ 8673' 8673' 4-1/2" G SEAL SUB, ID = 3.000" 8675' 4-1/2" OTIS X LANDING NIP, ID = 3.813" (BEHIND LINER) 8679' XO 3-1/2" X 2-7/8", ID = 2.441" $7$$' 4-1/2" BAKER SHEAROUT SUB " " ' 4-1/2 TBG-PC,12.6#, N-80, .0152 bpf, ID = 3.958 8740 8740' 4-1/2" TUBING TAIL (BEHIND CT LINER) $712' ELMD 06/24/89 9-5/8" CSG, 47#, S0095, ID = 8.681" ~ 9306' PERFORATION SUMMARY REF LOG: BHCS on 10/9/1970 ANGLEAT TOP PERF: 78 @ 9736' Note: Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9736 - 9756 O 05/19/04 2" 6 9764 - 9776 O 05/19/04 2" 4 9862 - 10222 O 11/09/99 2-1/8" 4 10250 - 10350 O 09/27/96 2-1/8" 4 10450 - 10750 C 09/27/96 2-1/8" 4 10830 - 11150 C 09/27/96 2" 4 11250 - 11290 C 11 /09/99 2" 4 11350 - 11580 C 11 /09/99 ~1 9-5/8" MILLOUT WINDOW 9306' - 9321' 103186' 2-7/8" BKR CIBP, 05/19/04 10805' 2-7/8" BKR CIBP, 07/14/03 11210' 2-7/8" HES CIBP, 05/11/02 11766' 2-7/8" DAVIS LYNCH FLOAT SHOE 2-7/8" LNR-CT,6.5#, L-80 FL4S, .00579 bpf, ID = 2.441" 11766' 11766' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/70 ORIGINAL COMPLETION 03/27/06 RPWPJC WANERSFTY NOTE DELETED 09/30/96 LAST WORKOVER 05/11/02 ATD/TLH SET CIBP 07/14/03 BM/KAK SET BKR CIBP 08/20/03 ATD/TLH PATCH DEPTH CORRECTION 05/19/04 BJMcN/K ADPERFS; SET CIBP PRUDHOE BAY UNIT WELL: 02-04A PERMIT No: 1961580 API No: 50-029-20064-01 SEC 36, T11 N, R14E, 4072.32' FEL & 1438.43' BP Exploration (Alaska) TREE = MCEV OY WELLHEAD = MCEVOY ACTUATOR= AXEL S ON KB. ELEV = _.__ _ _ 64' BF. ELEV = KOP= Max Angle = 94 @ 11128' __ Datum MD = 9355' Datum TVD = 8800' SS O ~ -0 4A RW O 0" "OCTOR CS~G~ HAS MOVED UPWARD FROM 13-3/8" CSG, 72#, N-80, ID = 12.347" 2694' -2,900` - 7" x 9-5/8" Baker Packer - Minimum ID = 2.441" @ 8679' 3-1 /2" x 2-7I8" XO 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID = 4.892" ~ 8615' TOP OF 4-1/2" TBG-PC 8615' 4-1/2" HES WRP - 8,640` TOP OF 2-7/8" LNR - CT 8673' ~~ 1,210' - 13-3/8" HES ES Cementer 1,200' - 13-3/8" 68#, L-80, ID=12.347# 1,207` - 20#" 94#, J-55 ' 2,190` - 9-5/8" ES Cementer 2,200` - 9-5/8" 47#, L-80, Hyd, ID=8.861" 8,340' - 4-1/2" HES X Nipple ID=3.813" 8,360` - 7" x 4-1/2" Baker S-3 Packer 8,380` - 4-1/2" HES X Nipple ID=3.725" ''' I I 8,410` - 4-1/2" 12.6#, 13CR 8,418' - 7", 26#, L-80, BTC-MOD 8,420` - 5-1/2" x 7" 13CR Ported Crossover 8,400` -5-1/2", 17# Unique overshot-13CR 8572' 9-5/8" X 5-1/2" BAKER SAB PKR 8615' - j 5-1/2" X 4-1/2" XO, ID = 3.958" 8673' 4-1/2" G SEAL SUB, ID = 3.000" 8675' 4-1/2" OTIS X LANDING NIP, ID = 3.813" (BEHIND LINER) 8679' XO 3-1 /2" X 2-7/8", ID = 2.441" 8738' 4-1/2" BAKER SHEAROUT SUB 14-1/2" TBG-PC,12.6#, N-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, S0095, ID = 8.681" I--I 9306' PERFORATION SUMMARY REF LOG: BHCS on 10/9/1970 ANGLE AT TOP PERF: 78 @ 9736' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9736 - 9756 O 05/19/04 2" 6 9764 - 9776 O 05/19/04 2" 4 9862 - 10222 O 11 /09/99 2-1/8" 4 10250 - 10350 0 09/27/96 2-1/8" 4 10450 - 10750 C 09/27/96 2-1/8" 4 10830 - 11150 C 09/27/96 2" 4 11250 - 11290 C 11 /09/99 2" 4 11350 - 11580 C 11 /09/99 2-7/8" LNR-CT,6.5#, L-80 FL4S, .00579 bpf, ID = 2.441" 9-5/8" MILLOUT WINDOW 9306' - 9321' 2-7/8" BKR CIBP, 05/19/04 10805' I-12-7/8" BKR CIBP, 07/14!03 2-7/8" HES CIBP, 05/11/02 11766' ~~ 2-718" DAV IS LYNCH I FLOAT SHOE 11766' M DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/70 ORIGINAL COMPLETION 03/27/06 RPH/PJC WAVER SFTY NOTE DELETED 09/30196 LAST WORKOVER 05/11/02 ATD/TLH SET CIBP 07/14/03 BM/KAK SET BKR CIBP 08/20/03 ATD/TLH PATCH DEPTH CORRECTION 05/19/04 BJMcN/K ADPERFS; SET CIBP PRUDHOE BAY UNIT WELL: 02-04A PERMIT No: 1961580 API No: 50-029-20064-01 SEC 36, T11 N, R14E, 4072.32' FEL & 1438.43' BP Exploration (Alaska) $74~-14-1/2" TUBING TAIL (BEHIND CT LINER) 871 ELMD 06/24/89 02-04A --- RWO approval Sundry request Page i of 1 Maunder, Thomas E (DOA) From: Schnorr, DeWayne R (PRA) [DeWayne.Schnorr@bp.com] Sent: Tuesday, April 29, 2008 4:33 PM y To: Maunder, Thomas E (DOA) ~'~ Subject: 02-04A -- RWO approval Sundry request Hi Tom. 1 just talked with Mehrdad Nadem, and asked him if he could tell me more about why we needed the rush Sundry approval to move onto well 02-04A. Mehrdad told me that he did not need the approval until June 01, 2008. I misunderstood him when I was talking with him yesterday. Please except my apology for the miscommunication on this well. Thanks DeWayne 4/29/2008 02-04A (PTD #1961580) Internal Waiver Cancellation - Trouble Well e e Subject: 02-04A (PTO #1961580) Internal Waiver Cancellation - Trouble Well From: "NSU, AOW Well Integrity Engineer" <NSUAOWWe11IntegrityEngineer@BP.com> Date: Mon, 27 Mar 2006 13:03:38 -0900 To: "AOGCC - ·Winton Aubert (E-mail)..<winton_aubert@admin.statc.ak.us>. jim_regg@admin.state.ak.us, "NSU, ADW Well Operations Supervisor" <NSUADWWeIlOperationsSupervisor@.BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "GPB, FSl/SIPíSTP Area Mgr" <GPBFSITL@BP.com>, "Dean, James A" <James.Dean@BP.com>, "GPB, FSl OS Ops Lead" <GPBFSIDSOpsLead@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUAOWWe1UntegrityEnginecr@]BP.com>, "NSLJ, ADW WI Tech" <NSUADWWITech@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com> All, An internal waiver was issued for a Production Casing leak on well 02-04A (PTD #1961580) on 08/24/03. Although the tubing and surface casing pass mechanical integrity tests, the PC leak into formation is not secure at this time. The well is currently shut-in with plans to load the IA to secure the PC leak. If successful, the well will again be evaluated for PC leak waiver. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, )lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 3/28/2006 4:23 PM RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 Z005 REPORT OF SUNDRY WELL OPERATIQlitI~I&GasCons.cnmmission 1. Operations Performed: Anchnr~n Abandon 0 Repair Well 0 PluQ PerforationsD Stimulate 0 1000000000EJ Alter CasingD Pull TubingD Perforate New PoolO waiverD Time ExtensionD Change Approved ProgramD Operation Shutdown 0 Perforate ŒJ Re-enter Suspended WellD ) STATE OF ALASKA ) 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒJ ExploratoryD 5. Permit to Drill Number: 196-1580 6. API Number 50-029-20064-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.00 8. Property Designation: ADL-028308 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 02-04A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 11766 feet true vertical 9006.8 feet Plugs (measured) 10386,10805,11210 Effective Depth measured 10386 feet Junk (measured) None true vertical 9052.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 372 20" 133# K-55 30 402 30.0 402.0 2320 1500 CONDUCTOR 805 20" 94# H-40 402 - 1207 402.0 - 1207.0 1530 520 LINER 3093 2-7/8" 6.5# L-80 8673 - 11766 8246.0 - 9006.8 10570 11160 PRODUCTION 1999 9-5/8" 47# SOO-95 25 - 2024 25.0 - 2024.0 8150 5080 PRODUCTION 2395 9-5/8" 43.5# SOO-95 5970 - 8365 5766.8 - 7957.2 7510 4130 PRODUCTION 20 9-5/8" 53.5# L-80 2433 - 2453 2433.0 - 2453.0 7930 6620 PRODUCTION 1328 9-5/8" 47# SOO-95 8365 - 9693 7957.2 - 9034.5 8150 5080 PRODUCTION 3946 9-5/8" 40# SOO-95 2024 - 5970 2024.0 - 5766.8 6820 3330 SURFACE 2669 13-3/8" 72# L-80 25 - 2694 25.0 - 2694.0 4930 2670 Perforation depth: Measured depth: 9494 - 9504, 9736 - 9756, 9764 - 9776, 9862 - 10222, 10250 - 10350 True vertical depth: 8950.5 - 8955.28,9045.58 - 9049.34,9050.5 - 9051.78,9053.1 - 9055.13,9054.43 - 9052.74 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 19 5-1/2" 17# L-80 @ 8547 4-112" 12.6# N-80 @ 8615 Packers & SSSV (type & measured depth): 5-1/2" Baker SAB Packer @ 8572 9-5/8" Homco Patch Packer @ 2433 9-5/8" Homco Patch Packer @ 2449 8547 8615 .. ~) 1 200'~ ~t~NNED MA'f 1. - '- 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFl MAY 1 0 2005 Prior to well operation: Subsequent to operation: Oil-Bbl 416 369 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 24.8 17 150 25.8 16 150 Tubing Pressure 758 719 13 14. Attachments: ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒJ GasD Development ŒJ Service D Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature ,,£1 ~ C~ Form 10-404 Revised' 4/2004 Title Production Technical Assistant ORIGINAhtne 564-4657 Date 5/5/05 ') ) 02-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/15/05 PERFORATED INTERVAL 9494 - 9504 FT CORRELATED TO SLB COMPENSATED NEUTRON LOG DATED 8-DEC-2003 FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 ) MCEVOY MCEVOY . ............ .... ... ·····ÄXË[SÓN ··"'64,ì' . .................................... .....1 1REE = WELLI-EAD = 'AcTUATOR;;;···· RB:ËLËV";" Bï=~..ËLËV·~··,··· KOP = _? .!0~::~09)~·;;....·..·..·"'..···......···.... ....94·~..1~,,~?W Datum MD = 9355' D3tlim~Wt)=~"~ .. ... ... ,~.... ,-- a8bdiSŠ 02-04A ) SAFETY NOTES: ***P RODUCTlON CSG X FORMATION COMM. OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = 1000 PSI (08/24/03 WAIVER)*** TREE HAS MOVED UPWARD FROM 30" CONDUCTOR CSG. (I 2186' H5-1/2" OllS RQM SSSV NIP, ID = 4.562" 113-3/8" CSG, 72#, N-80, ID = 12.347" l-l ~ &' 8 g ~ 2433' - 2453' H9-518" CSG PATCH (10/27/80) 1 ~ 2694' M in imum ID = 2.441" @ 8679' 3-1/2" x 2-7/8" XO I I 1 8423' 1-15-112" OllS SLIDING SLV, ID = 4.562" 1 l J 1 8547' 1-15-1/2" BOT R3RASSY 1 :8: ~ 8572' H9-5/8" x 5-112" BAKERSAB A<R 1 15-1/2" 1BG-PC,17#, L-80, .0232 bpf, ID = 4.892" l-t ITOP OF 4-1/2" TBG-PC l-t 8615' 8615' \ / 8615' ITOP OF 2-7/8" LNR- CT l-i 8673' '" 1 1 8673' 8675' I 8679' 8738' 14-112" 1BG-PC,12.6#, N-80, .0152 bpf, D =3.958" H 8740' 8740' 8712' 19-5/8" CSG, 47#, S0095, ID = 8.681" 1-1 9306' .. ~ PERFORA 1l0N SlJvllv1ARY RB= LOG: BHCS on 10/9/1970 ANGLEA TTOP PERF: 78 @ 9736' Note: Refer to R"oduction œ for historical perf data SIZE SPF INlERVAL Opn/Sqz DATE 2" 6 9736 - 9756 0 05/19/04 2" 6 9764 - 9776 0 05/19/04 'Z' 4 9862 - 10222 0 11/09/99 2-1/8" 4 10250 -10350 0 09/27/96 2-1/8" 4 10450 - 10750 C 09/27/96 2-1/8" 4 10830 - 11150 C 09/27/96 'Z' 4 11250 - 11290 C 11/09/99 'Z. 4 11350 -11580 C 11/09/99 [TO - 12-718" LNR-CT,6.5#, L-80 FL4S, .00579 bpf, ID= 2.441" - HXO 5-1/2" X 4-112", ID =3.958" 1 1-14-1/2" G SEAL SUB, ID = 3.000" 1 1- 4-1/2" OllS X LA NDlNG NP, ID = 3.813" (B8-IIND LINER) Hxo 3-1/2" X 2-718", ID =2.441" 1 1-t4-1/2" BAKER SHEAROUTSLB 1 1-i4-1/2" TLBING TAIL (B8-IIND Cf LINER) H ELMD 06/24189 1 I 9-5/8" MILLOur WINDOW 9306' - 9321' 10386' H2-7/8" BKRCIBP, 05/19/041 l 10805' H2-7/8" BKRCIBP, 07/14/031 11210' 1~2-7/8"HESCIBP,05/11/02 1 DATE 1 0/14/70 09/30/96 01/05/01 05/11/02 03/10/03 07/14/03 [)A. lE RBI BY COMrvENTS 08120/03 A TD/lLH PATCH DEPTH CORRECfION 08129/03 KC/TLH WANER SAFETY NOTE 05/19/04 BJrvcl\VKK ACPERFS; SEr aBP REV BY CX)MMENTS ORIGINAL COM PLETION LAST WORKOVER SIS-MD RNAL A TD'TLH SET CIBP JM>ITP WAN ER SAFErY NOTE BM'KAK SET BKR aBP 1- 2-7/8" DAVS LYNa-t FLOAT SHOE 11766' 11766' PRUD-iOE BAY UNIT W8..L: 02-04A ÆRMT No: 1961580 API No: 50-029-20064-01 sæ 36, T11 N, R14E, 4072.32' FEL & 1438.43' Fr\l 8P Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Repair WellD Pluq Perforations[K] Pull TubingD Perforate New PoolO Operation Shutdown 0 Perforate ŒJ 4. Current Well Class: Stimulate D OtherD WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 196-1580 Exploratory D Service 0 Development [!] Stratiqraphic D 9. Well Name and Number: 02-04A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-20064-01-00 64.00 8. Property Designation: ADL-0028308 11. Present Well Condition Summary: Total Depth measured 11766 feet true vertical 9006.8 feet Size 20" 133# K-55 20" 94# H-40 2-7/8" 6.5# L-80 9-5/8" 47# SOO-95 9-5/8" 40# SOO-95 9-5/8" 53.5# L-80 9-5/8" 43.5# SOO-95 9-5/8" 47# SOO-95 13-3/8" 72# N-80 Plugs (measured) 10386.10805.11210 Junk (measured) None MD TVD Burst Collapse 30 402 30.0 402.0 2320 1500 402 - 1207 402.0 - 1207.0 1530 520 8673 - 11766 8246.0 - 9006.8 10570 11160 25 - 2024 25.0 - 2024.0 8150 5080 2024 - 5970 2024.0 - 5766.8 6820 3330 2433 - 2453 2433.0 - 2453.0 7930 6620 5970 - 8365 5766.8 - 7957.2 7510 4130 8365 - 9693 7957.2 - 9034.5 8150 5080 25 - 2694 25.0 - 2694.0 4930 2670 Effective Depth measured 10386 feet true vertical 9052.0 feet Casing Conductor Conductor Liner Production Production Production Production Production Surface Length 372 805 3093 1999 3946 20 2395 1328 2669 Perforation depth: Measured depth: 9736 - 9756, 9764 - 9776, 9862 - 10222, 10250 - 10350, 10450 - 10750 True vertical depth: 9045.58 - 9049.34, 9050.5 - 9051.78, 9053.1 - 9055.13, 9054.43 - 9052.74, 9049.49 - 9035.62 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 5-1/2" 17# L-80 5-1/2" 17# L-80 4-112" 12.6# N-80 5-112" Baker SAB Packer 9-5/8" Howco Patch Packer 9-5/8" Howco Patch Packer @ 19 @ 8547 @ 8615 @ @ @ RE'CE~\\/ED 8547 8615 8740 ~" : J :.'; j n ?('14 ¡\ßa8k,~ t)!,~ [~ [",,,,, Í'... ' ., ., ':<I;,) ~Jns. {;ommia.-:,Ifio '\~ do. "~D'lY1fIJ - '\fl,nûl'rr,q[ , , 8572 2433 2449 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ~~C~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Signature Form 10-404 Revised 4/2004 Oil-Bbl 703 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 32.5 0 200 Tubing Pressure 754 215 786 36.2 205 0 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development ŒJ ServiceD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 8/3/04 : t ~"I - 1, III .:..' , ,I~\ij\'~ 1 t r:. U'\W\~j 02-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/18/04 MEM GR/CCL. SET CIBP. ADPERF. CTU #5. MIRU. RIH WITH PDS GR/CCL INSIDE 2.2" CARRIER. CONTINUED ON 5/19/04 WSR. 05/19/04 Set CIBP @ 10386' 05/19/04 MEM GR/CCL. SET CIBP. ADPERF. CONTINUED FROM 5/18/04. MEM GR/CCL LOG INTERVAL 10500' TO 9000'. FLAG PIPE AT 10400' AND 9700' CTMD. POOH. TIE INTO SWS MCNL DATED 08-DEC-2003. MAKE -10.5' CORRECTION. MU AND RIH WITH BAKER 2-7/8" CIBP, CORRECT TO CENTER OF ELEMENT AT FLAG. SET CIBP AT 10386'. POOH. MU/RIH W/ 12' OF 2" GUNS. TIE INTO FLAG @ 9700'. CANNOT GET BELOW 9866' TO TAG CIBP. SHOOT 9764'.9776' INTERVAL, POOH. MU/RIH W/ 20' OF 2" GUNS. SHOOT 9736'-9756' INTERVAL. POOH. FLUIDS PUMPED BBLS 55 105 160 50/50 Methonal 1 % KCL TOTAL Page 1 TREE = WELLI-EAD = AClUATOR = KB. ELEV = BF, ELEV = KOP = Max Angle = Datum MD = Datum NO = MCEVOY MCEVOY AXELSON 64' 02-04A SAFETY NOTES: *"~PRODUCTlON CSG X FORMATION COMM. OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = 1000 PSI (08/24/03 WAIVER)*** TREE HAS MOVED UPWARD FROM 30" CONDUCTOR CSG. _? 94 @ 1"112B' 9355' 8800' SS @) 2186' H5-1/2" 011S RQM SSSV NIP, 10 = 4,562" I g 113-31~' CSG, 72#, N-1!O, ID = 12.347' H 2694' r-J & g ~ 2433' - 2453' H9-518" CSG PATCH (10/27/BO) I Minimum ID = 2.441" @ 8679' 3-1/2" x 2-7/8" XO I I I 8423' H 5-1/2" 011S SLIDING SLV, ID = 4.562" I L J 1 8547' 1-i5-1/2" BOT FBRASSY I :8: ~ 8572' 1-i9-5/B" x 5-1/2" BAKERSAB A<R I I 5-1/2" 1BG-PC, 17#. L-BO, ,0232 bpf. ID = 4,B92" l-t 8615' TOP OF 4-1/2" TBG-PC 1-1 8615' \ I 8615' I-1X05-1/2"X4-1/2",ID=3,95B"I TOP OF 2-7/B" LNR- CT l-i 8673' 8673' 8675' 1-14-1/2" GSEAL SUB,ID= 3,000"1 1- 4-1/2" 011S X LA NDlNG NP. ID = 3,B 13" (BEHIND LINER) 1-1 XO 3-1/2" X 2-7/B". ID = 2.441" I I 8679' I 4-112"1BG-PG.12.6#.N-BO..0152bpf, D=3,958" 1-1 8740' I 8738' 1-14-1/2" BAKER SHEAROUT SLB I 8740' 1-i4-1/2" TLBING TAIL (BEHIND CT LINER) 8712' H ELMD 06/24/B9 I 19-5/8" CSG, 47#, S0095,ID = 8.681" 1-1 9306' .. ~ I 9-5/8" MILLOur WINDOW 9306' - 9321' PERF ORA 110N SUMrw\RY REF LOG: BHCS on 10/9/1970 ANGLEA TTOP PERF: 78 @ 9736' Note: Refer to RoductlOn DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9736 - 9756 0 05/19/04 2" 6 9764 - 9776 0 05/19/û4 2" 4 9862 - 10222 0 11/09/99 2-1/8" 4 10250-10350 0 09/27/96 2-1/8" 4 10450 - 10750 C 09/27/96 2-1/8" 4 10830 - 11150 C 09/27/96 2" 4 11250 - 11290 C 11/09/99 2" 4 11350-11580 C 11/09/99 (TD- 11766' I 2-7/8" LNR-CT.6.5#, L-BO FL4S, .00579 bpf, 10 = 2.441" - 11766' I 10386' H2-7/8" BKRCIBP. 05/19/041 I 10805' H2-7/8" BKRCIBP. 07/14/031 11210' 1-12-7/8" HES CIBP, 05/11/02 I 1- 2-7/8" DAVIS LYNCH FLOAT SHOE DATE 1 0/14/70 09/30/96 01/05/01 05/11/02 03/10/03 07/14/03 co MM I3\JTS ORIGINAL COM PLETION LAST WORKOV ER SIS-MD ANAL A TDlTLH SET CIBP JIVP/TP WAIV ER SAFErY NOTE BI\NKAK SET BKR aBP BP Exploration (Alaska) REV BY DA TE REV BY COMMENTS 08/20103 A lD/TLH PATCH DEPTH CORRECTION 08/29/03 KC/TLH WAIVER SAÆTY NOTE 05/19/04 BJM:NiKK ADPERFS: SEr aBP PRUDHOE BAY UNIf WElL: 02-04A ÆRMIT No: 1961580 API No: 50-029-20064-01 SEC 36, T11 N. R14E 4072.32' FEL & 1438.43' FNL ids ~ I', WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center lR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WEll DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FilM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 ! q b.- j ç 8 I ,) ;-.Á ÌtJ os 02-04A 5/19/04 Mech. CH 1 Caliper Survey Print Name: J1t~ ðfjvJ .~ \N ~lV'~ 0 k(Ovx~ Date: ~ r.' J""N- À ~ Q ." Signed: PRoACIivE DiAGNOSlic SERViCES, INC., PO Box I ~bY SIAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pdslg'memorylog.com \Vebsite: \n\w.memorylog.com 01/23/04 Schlumberger NO. 3098 Alaska Data & Consulting Services Company: ~tate of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ¡' Co~r ( Well Job # Log Description Date Blueline Prints CD PSI-05 '\ 40009587 OH EDIT LWD ARC & ADN (PDC) 09/25/03 1 t.:) ~ q --:2, PSI-05 \. 40009587 MD VISION RESISTIVITY 09/25/03 1 PSI-05 '\. 40009587 TVD VISION RESISTIVITY 09/25/03 1 PSI-05 7~rr~ --)"Q,Cj 40009587 MD VISION DEN/NEUTRON 09/25/03 1 PSI-05 / ~ ,- I 40009587 TVD VISION DEN/NEUTRON 09/25/03 1 PSI-05 / 10703940 RST-SIGMA 10/25/03 1 1 );.:',1 '2-F1 ~ PSI-OS J 10679041 RST-SIGMA 12/20/03 1 1 IN--:'''il D-18A "';:Q ') \ " \ A ~ 10564487 RST -SIGMA 06/19/03 1 1 J;} ~9>X' 05-08 :.:; '1 -l)~:::} L..J 10674406 RST-S1GMA 12/31/03 1 1 )(~I. ~~ Ct 02-04A C l 0- \ r'""") W 10728382 MCNL 12/08/03 1 1 ~:::) .~ g r E-08A ¡!:jr~~?f.F~ 10728384 PRODUCTION PROFILE 01101/04 1 l \ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. Anchorage, AK 99503-5711 Anchorage, Alaska 99508 ATTN: Beth Date Delivered --\=<-n\ : Á ~~). SJ 6"'0 );;.Jf-';'v'" . Received by: RECEIVED I '~'¡'.I -; C! f) 1111 A \...' i', "~ ...) .. ¿.v\.- ¡.~ ,A.!~~ka Oil & Gas Cons.Commistdon -. . ~',."lr't.\r\}¡l~~Lt'\ L"E. D A. 0) 20~1J Anr,h~ '''''-...''~ c. 1..:1)\\,A ~hn.¡'C::,II.,. r rJ; ~.P: ~;)! - tH- ,..) _..~ \~r\ ...;~ .. .",,; .", ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD SuspendD Operation ShutdownD Perforate D VarianceD Annular DisposalD Alter CasingD Repair WellD Plug Perforations[]] Stimulate D Time ExtensionO OtherD Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name' BP Exploration (Alaska), Inc. 196-1580 . Development I]] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20064-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 02-04A 8. Property Designation: 10. Field/Pool(s): ADL-0028308 Prudhoe Bay Field 1 Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11766 feet true vertical 9006.8 feet Plugs (measured) 10805, 11210 Effective Depth measured 10805 feet Junk (measured) None true vertical 9033.2 feet Casing Length Size MD TVD Burst Collapse Conductor 372 20" 133# K-55 30 - 402 30.0 - 402.0 2320 1500 Conductor 805 20" 94# H-40 402 - 1207 402.0 - 1207.0 1530 520 Liner 3093 2-7/8" 6.5# L-80 8673 - 11766 8246.0 - 9006.8 10570 11160 Production 1999 9-5/8" 47# 800-95 25 - 2024 25.0 - 2024.0 8150 5080 Production 3946 9-5/8" 40# 800-95 2024 - 5970 2024.0 - 5766.8 6820 3330 Production Patch 20 9-5/8" 53.5# L-80 2433 - 2453 2433.0 - 2453.0 7930 6620 Production 2395 9-5/8" 43.5# 800-95 5970 - 8365 5766.8 - 7957.2 7510 4130 Production 1328 9-5/8" 47# 800-95 8365 - 9693 7957.2 - 9034.5 8150 5080 8urface 2669 13-3/8" 72# N-80 25 - 2694 25.0 - 2694.0 4930 2670 Perforation depth: Measured depth: 9862 -10222,10250 -10350,10450 -10750 True vertical depth: 9053.1 - 9055.13.9054.43 - 9052.74.9049.49 - 9035.62 RE Tubing (size, grade, and measured depth): 5-1/2" 17# L-80 @ 19 - 8547 CE IVED 5-112" 17# L-80 @ 8547 - 8615 4-1/2" 12.6# N-80 @ 8615 - 8740 DEe .2 3 2003 Packers & SSSV (type & measured depth): 9-5/8" Homco Patch Packer @ 2433 Alaska Oil & G 9-5/8" Homco Patch Packer @ 2453 as Cons. Commíss' 5-1/2" Baker 8AB Packer @ 8572 Anchorage Ion 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 384 13.38 0 2256 Subsequent to operation: 781 17.44 76 854 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of LOQs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasD WAG D GINJD WINJD WDSPLD Prepared b Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: N/A Production Technical Assistant 564-4657 Date 12/17/03 Jj~N 2 ~ 2004 "., . .. ~, ( 02-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/14/03 Perform weekly BOP test. Kill well with 1% KCL. RIH with PDS logging tool in carrier to 10850. No problems. POH logging and flag pipe at 10700. Log up to 10200 ,at 40 fpm, sit 5 min. POH, verify good data.Correct -6 Foot depth. MU, BOT 2 7/8 CIBP. Knock well pressure down, rih and set CIBP at 10805 Foot. POH Fill well with dead crude. Notify DSO well ready to POP. FLUIDS PUMPED I BBLS I g~::L I 380 215 595 TOTAL Page 1 .. ", ( ( TREE = MCEVOY SAFETY NOTES: ***PRODUCTlON CSGX WELLHEAD = MCEVOY 02 04A FORMATIONCOMM.OPERATlNGLlMITS: MAX ACTUATOR = AXELSON - lAP = 500 PSI MAX OAP = 1000 PSI (08/24/03 KB ELEV = 64' , BF: ELEV = W AlVER)*** TREE HAS MOVED UPWARD FROM KOP =? 30" CONDUCTOR CSG. Max Angle = 94 @ 11128' Datum MD = 9355' 2186' 5-1/2" 011S RQM SSSV NIP, 10 = 4.562" Datum TVD = 8800' SS 2433' - 2453' -19-5/8" CSG PATCH (10/27/80) I 113-3/8" CSG, 72#, N-80, 10 = 12.34T' I Minimum ID = 2.441" @ 8679' I I -15-1/2" OTIS SLlDINGSLV, 10=4.562" 1 3-1/2" X 2-7/8" XO -19-5/8" X 5-1/2" BAKER SAB PKR I 15-1/2" TBG-PC,17#, L-80, .0232 bpf, 10 = 4.892" I -1 1 XO 5-1/2" X 4-1/2", 10 = 3.958" TOP OF 4-1/2" TBG-PC I ITOP OF 2-7/8" LNR - CT I 8673' 8673' -14-1/2" G SEAL SUB, 10 = 3.000" 1 8675' 4-1/2" OTIS X LANDING NIP, 10 = 3.813" (BEHIND LINER) 1 8679' I-1XO 3-1/2" x 2-7/8",10 = 2.441" 1 I 8738' 1-14-1/2" BAKER SHEA ROUT SUB 1 14-1/2" TBG-PC,12.6#, N-80, .0152 bpf, 10 = 3.958" I 8740' 8740' -14-1/2" TUBING TAIL (BEHIND CT LINER) 1 8712' 1-1 ELMO 06/24/891 19-5/8" CSG, 47#, S0095, 10 = 8.681" I 9-5/8" MILLOUT WINDOW 9306' - 9321' ÆRFORA TION SUMMARY REF LOG: BHCS on 10/9/1970 ANGLE AT TOP PERF: 90 @ 9862 Note: Refer to Produetion DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9862 -10222 0 11/09/99 2-7/8" DAVIS LYNCH 2-1/8" 4 10250 - 10350 0 09/27/96 FLOAT SHOE 2-1/8" 4 10450 - 10750 0 09/27/96 2-1/8" 4 10830 - 11150 C 09/27/96 2" 4 11250 - 11290 C 11/09/99 2" 4 11350 - 11580 C 11/09/99 TD 2-7/8" LNR-CT,6.5#, L-80 FL4S, .00579 bpf, 10 = 2.441" DA TE REV BY COMMENTS DA TE REV BY COMMENTS PRUDHOE BA Y UNIT 10/14/70 ORIGINAL COMPLETION 08/20/03 ATD/TLH PATCH DEPTH CORRECTION WELL: 02-04A 09/30/96 LAST WORKOVER 08/29/03 KC/TLH WAIVER SAFETY NOTE PERMIT No: 1961580 01/05/01 SIS-MD FINAL API No: 50-029-20064-01 05/11/02 A TD/TLH SET CIBP SEC 36, T11 N, R14E, 4072.32' FEL & 1438.43' FNL 03/10/03 JMP/TP WAIVER SAFETY NOTE 07/14/03 BMlKAK SET BKR CIBP BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ SET ClBP Pull tubing _ Alter casing _ Repair well _ Other_X SET ClBP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 64 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1061' FNL, 3509' FEL, Sec. 36, T11 N, R14E, UM (asp's 688525, 5950160) 02-04A At top of productive interval 9. Permit number / approval number 3248' FNL, 3938' FEL, Sec. 36, T11 N, R14E, UM (asp's 688151, 5947966) 196-158 At effective depth 10. APl number 1838' FNL, 4432' FEL, Sec. 36, T11 N, R14E, UM (asp's 687621, 5949363) 50-029-20064-01 At total depth 11. Field / Pool 1438' FNL, 4072' FEL, Sec. 36, T11 N, R14E, UM (asp's 687971, 5949768) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11766 feet Plugs (measured) Set CIBP @ 11210' (05/10/2002) true vertical 9007 feet Tagged TD @ 11625' (11/08/1999) Effective depth: measured 11210 feet Junk (measured) true vertical 9013 feet Casing Length Size Cemented Measured Depth True Vertical Depth Structural 114' 30" 147' 147' Conductor 1174' 20" 755 sx Fondu Flyash 1207' 1207' Surface 2661' 13-3/8" 625 sx Fondu Flyash, 2694' 2694' 365 sx Class 'G' Intermediate 9273' 9-5/8" 420 sx Class 'G' 9306' 8823' Sidetrack Liner 3093' 2-7/8" 39 bbls Class 'G' 8673' - 11766' 8246' - 9007' Perforation depth: measured Open Perfs 9862'-10222', 10250'-10350', 10450'-10750', 10830'-11150' Open Perfs Below CIBP 11250'-11290', 11350'-11580". true vertical Open Perfs 9053'-9055', 9054'-9053', 9049'-9036', 9032'-9015', Open Perfs Below CIBP 9013'-9013', 9014'-9009' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC TBG @ 8615' MD; 5-1/2" x 4-1/2" XO @ 8615'; 4-1/2", 12.6#, N-80, PC Tubing @ 8740' MD. i:! :'~ ? ' :' ! .... . Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SAM PKR @ 8572'. i: !:." 5-1/2" Otis RQM SSSV Nipple @ 2186' MD. 13. Stimulation or cement squeeze summary,r .: '"'" '. ',~ i'~ ',-'ii'"~,/:'~ .... : . ,. ~.., ,,j Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ;,~.[~:(:;;~j i: .,' · 14. Representative Daily Average Production or Injection Data " Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 05/03/2002 948 37665 0 1392 Subsequent to operation 05/14/2002 979 40390 0 1153 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing~js tr~e and correct to the best of my knowledge. DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · L SUBMIT IN DUPLICATE 05/1 O/2OO2 05/1 O/O2 02-04A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PACKERS/ BRIDGE PLUGS: CAST IRON BRIDGE PLUG; JEWELRY LOG-- DEPTH CONTROL EVENT SUMMARY MIRU. PUMP DOWN WELL TO REDUCE PRESSURE TO ENTER WELL. RUN MHA AND SWS MEMORY LOG (CCL-GR) IN 22.73' 2.2" CARRIER WITH NOZZLE ON BOTTOM. LOG FROM 11,050 TO 11,450' PAINT FLAG @ 11,150'. DOWN LOAD LOG DATA AND MAKE CORRECTIONS. RIH WITH HFS 2-7/8" CIBP. SET @ 11,210' MD. POOH. RDMO. <<<LEFT WELL SI & DID NOT FP FOR DSO TO POP>>>. Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 35 50/50 METHANOL WATER 134 1% KCL WATER 169 TOTAL Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of OPerator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1061' FNL, 3509' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 1342' E & 3250' S of NW cr Sec. 36, T11 N, R14E, UM At effective depth At total depth 1438' FNL, 4072' FEL, Sec. 36, T11N, R14E, UM Perforate _X Other_ 5. Type of Well: Development__X Explorato~__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 02-04A 9. Permit number / approval number 96-158 10. APl number 50-029-20064-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 114' Conductor 1143' Surface 2630' Production 9242' Liner 3093' 11766 feet Plugs (measured) 9007 feet 11625 feet Junk (measured) 9010 feet Tagged PBTD @ 11625' MD (11/08/1999) Size Cemented ' Measured Depth True vertical Depth 30" 114' 114' 20" 755 Sx Fondu Flyash 1207' 1207' 13-3/8" 625 sx Fondu Flyash & 365 Sx 2694' 2694' Class G 9-5/8" 420 sx C~ass G 9306' 8823' 2-7/8" 39 bbls Class G 1 1766' 9007' Perforation depth: measured 9862' - 10222'; 10250' - 10350'; 10450' - 10750'; 10830' - 11150'; 11250' - 11290'; 11350' - 11580'. true vertical 9053' - 9055'; 9054' - 9053'; 9049' - 9036'; 9032' - 9015'; 9013' - 9013'; 9014' - 9009'. Tubing (size, grade, and measured depth) 5-1/2"17#, L-80 PCT @ 8615' MD; 4-1/2"12.6#, N-80 PCT @ 8740' MD. 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8573' MD. 5-1/2" OTIS RQM SSSV @ 2187' MD. Packers & SSSV (type & measured depth) RECEIVED NOV 1999 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~ul~lorage 14. Prior to well operation Subsequent to operation OiI-Bbl 1085 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 18741 0 1922 13050 436 Casing Pressure Tubing Pressure 1264 1113 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil__X Gas__ Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -,~/~~ ~ Title ARCO Engineering Supervisor Erin dba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLIcATE'~~ 02-04A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/07/1999: 11/08/1999: 11/09/1999: RU work platform & CTU. PT'd BOPE. MU Mem GR/CCL logging tools. Killed well w/1% KCL Water. RIH & logged well f/10600' - 11400' MD. Tagged PBTD @ 11625' MD. POOH w/logging tools. RIH w/per[ guns & shot 620' of Add Per[orations @: 9862' - 10222' MD (Zone 4) Reference Log: MWD-GR 9/25/1996. 11250' - 11280' MD (Zone 4) 11350' - 11580' MD (Zone 4) Used 2" carriers & all shots @ 4 SPF, random orientation, balanced press, & 60° phasing. POOH w/guns. ASF. Ran nozzle to top of 2-7/8" Liner & turned displaced well to Crude. RD. Returned well to production & obtained a valid well test. RECEIVED 1 9 1999 PERMIT DATA 96-158 MWD SRVY 96-158 MWD SRVY AOGCC Individual Well Geological Materials Inventory T DATA PLUS /9230-11766 · ~/SPERRY 9230-11766 *REDO* Page: 1 Date: 08/12/98 RUN RECVD FINAL 11/12/96 11/21/96 96-158 NGP-TVD 96-158 NGP-MD FINAL 02/26/97 FINAL 02/26/97 96-158 NGP-MD ~-L~9316-11763 FINAL 03/26/97 96-158 NGP-TVD 760-8934 FINAL 03/26/97 96-158 7929 ~'~PERRY GR 4-7 04/11/97 96-158 TDTP ~E'~9250-9650 FINAL 08/22/97 96-158 8082 96-158 TDTP 96-158 8385 d~/SCHLUM TDTP ~350-ii243 ~CHLUM TDTP 1 08/22/97 FINAL 06/11/98 T 1 06/11/98 DAILY WELL OPS ~R.-'-q/l'~ /~, / TO ~/9~/'~/~ / Are dry ditch samples required? yes ~/And received? / / / Was the well cored? yes ~Analysis & description received? ~_y_~s no Are well tests required?, 'yes ~o Received? ~y~-S~~ Well is in compliance-~'~'~-~- Initial COMMENTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11236 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 6/9/98 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape ID.S. 2-4A 98233 TDTP 7~'- ~~-~' ' 980114 1 1 1 D.S. 7-2A 98253 TDTP '~:~_., ~¢.// 980206 1 I 1 D.S. 7-37 98250 RST-BORAX ~ ~~ 980220 I I 1 D.S. 18-06A 98126 GR/CCL (W/A LOG) ~ ~:~//(-/~ 980115 I -- SIGNED: ..... DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. GeoQuest 500 W. International Airport Fload Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11270 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 8/20/97 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D_.S. 1-15A 97356 CNTG ~' '-~0~'0 970516 1 1 1 D.S. 1-11 97357 CNTG -~c_. '<~('~;~1 970515 I I 1 D.S. 2-4A 97314 TDTP ~ ~0~'~ 970502 1 1 1 D.S. 15-27 97310 TDTP ~ ~~ 970530 I I 1 ,,, SIGNED:r'~~' ~ ~ ~'~--~~.~.~.~~~--~ DATE: AUG22 1997 AJ~k~a ()il & Ga~ ~;~S. Please sign ~nd return one copy of thJs transmittal to 8berrie ~t the ~bove ~ddress or f~x to (~07) 562-6521. Th~k you. I-I !:t I I__1__ I I~ G S I:: I:t L/I I-- 1:: S WELL LOG TRANSMITTAL To: State of Alaska March 27, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 02-04A, AK-MW-60132 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 02-04A: 2"x 5"MD Gamma Ray Logs: 50-029-20064-01 2" x 5" TVD Gamma Ray Logs: 50-029-20064-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia Note: Transmittal & Logs are replacemems for well (02-04A). Please discard previous Logs & Transmittal dated February 26, 1997. This Transmittal, dated March 27, 1997, will replace the Please accept our apology for any inconvenience this previous transmittal dated March 26, 1997. change may have caused. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company O !:! I I--I--I I~ G SE i:lk/I C: E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 02-04A, AK-MW-60132 March 26, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20064-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 Ft i I--I--I IM G S E I::iL~I r- E S WELL LOG TRANSMITTAL To: State of Alaska February 26, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS 02-04A, AK-MW-60132 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 02-04A: 2" x 5" MD Gamma Ray Logs: 50-029-20064-01 2" x 5" TVD Gamma Ray Logs: 50-029-20064-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10600 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole& Open Hole) 11/27/96 Well Job # Log Description Date BL RF Sepia LIS Tape MPK-37 PERFORATING RECORD 961 1 1 6 I 1 ...... ~PK-37 PRODUCTION PACKER 961 11 6 1 1 MPF-58 "~" ~ ~'~"1 96357 CDR 961005 I 1 1 MPF-58 96357 CDR TVD 961 005 1 1 -- -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b . CIFi I Ll--I N G S ~ !:!~./I C ~ S November 19, 1996 AOGCC Howard Okland 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-04A c~o-- Ig~ Dear Mr. Oakland, The distributed MWD surveys for this well had an error. The Sub-Sea TVD was incorrect. Please destroy the previous data delivered November 7, 1996 and replace it with this corrected information. Enclosed are two hard copies of the above mentioned file(s). Well 2-04A MWD survey, tie in point 9,230.00', window point 9,316.00', interpolated depth 11,766.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino. Company mi:Ill_liNG S I:= FR U' I r' I=: S November 7, 1996 AOGCC Howard Okland 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-04A Dear Mr. Oakland, Enclosed are two hard copies of the above mentioned file(s). Well 2-04A Please call me at 563-3256 if you have any questions or concerns. Regards, MWD survey, tie in point 9,230.00', window point 9,316.00', interpolated depth 11,766.00'. William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Classification of Senace Well OIL ~-~ ,3-AS r~ SUSPENDED [---'] .ABANDONED [~] SERVICE E~ Name of Operator 7 Permit Number ARCO Alaska. Inc 96-158 Address P.O. Box 100360. Anchora~le. AK 99510-0360 Location of we~l at sLLdace 1771' E & 1064' S of NW cr Sec 36, T11N, R14E UM At Top Producing Inte~'Val 1342' E & 3250' S of NW cr Sec 36, T11N, R14E. UM At Total Depth 1438' FNL 4072' FEL Sec. 36. T11N, R14E, UM 5 Elevation in feet (indite KB, DF, e.~c.) 64' RKB Date Spuddea 9/18/96. 6 Lease Designation and SenaJ No. ADL 283O8 13 Date T.D. Reached j14 Date Comp., Susp. or Aband. 9/24/96. t 9/28/96. 8 / PI Number 50-029-20064-01 9 Unit or Lease Name PRUDHOE BAY UNIT 10 Well Number 2-04A It Field and Pool PRUDHOE BAY FIELD PRUDHOE BAY OIL POOL J15 Water Depth, it offshore J16 No. of Completions N/A 'eel MSLJ 1 11766' MD / 9007 TVD 11730' MD / 9009' 'TVD YES NO 2186' feet MD 1900' (approx) I 22 Type Electric cr Ot~e-r Logs Run GR, MWD. 23 CASING, LINER AND CEMENTING RECORD ~ SETTING DEPTH MD I CASING SIZE I ~,'~q-. PER FT. GRADE TCP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157.5 # B Surf 114' 39' 20" ' 134 # H-40/J-55 Surf 1207' 26' 13-3/8" 9-5/8" 2-7/8" 72# Surf 2694' 17-1/2" 47,4.3.5,& 40# SOO-95 Surf 9306' 12-1/4" 6.5# U80 8873' 11766' 3-3,/4" 25 TUBING RECORD 755 Sx Fondu Flyash 625 Sx Fondu Flyash & 365 Sx CIG 420 Sx Class G I 39 bbls Class G 24 Pedorations c~en to Production (MD+TVD of Top and Bottom ana interval, size &nd number) 10250 - 10350' MD: 9046 - 9044' TVD; at 4 spf. 10450 - 10750' M D: 9041 - 9027' TVD; at 4 spf. 10830 - 11150' M D: 9024 - 9007' TVD; at 4 spf. SIZE 5-1/2" Tb~ 4-1/2" Tb~ DEPTH SET(MD) PACKER SET(MD) to 8615' 8572' 8615-8740' ] ACID, FRACTURE, CEMENT S~UEEZE, ETC DEPTH INTERVAL (MD) N/A AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST .D..~te First Procluc~n 10/4/96. ~-te of Test iHours Testecl 10/16/96. ! 6 Row Tubing ICasJng Pressure Press 194 I Me~;,~ of C~eration (Flowing, gas lift, etc.) j ='oW~n~ PRODUCT;CNFO~ TEST PEr,CD ~ CALCULA-ED 2444OUR F&TE~ OIL-BBL GAS-MCF. OIL-BBL GAS-MCF 2194 I 25OO WATER-BBL WATER-BBL 52 ICHOKE SIZE i GAS-OIL RATIO - 1139 lOlL GRAVITY-APi /corr) 28 CORE DATA B.def description cf litholo..Cy~, porosity, ff,-~ctures, apparent d~ps &-,a presence of oil, gas or water. Sul:x'nrt core chips. *Note: 2-,.~4A C"oil Tubing Side~-~c~ Ddlling Operations Summ~-y attached. This 10-407 su~.rrted as direc,%,cl per 10-401 a.~prove~3 cn 9/!5'96 (Permit # 96-158). F-~ rrn 10-407 Rev. 7-1-80 CONTINUED ON REVEFL~ S~)E Submit in duplicate NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and tJrr~ of each phase. Top Sadlerochit 8996' 8547' N/A 31. UST Ot: ATTACHMENTS Summary of 2-O4A Coil Tubing Horizontal Sidetrack Ddllincj operations. 32. I hereto/cer~fy t~at the foregoing is true and correct to the best of my knowledge Signed .~/~ ~_'_~.~x.~.z~[_~u' ~'--/'~.~. Title IFn,ineerin,$u[:~ervisor Date /~/.~/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water dis.Dos,al, 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 1 6, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Mebhod 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". Form 10-407 2-04A DESCRIPTION OF WORK COMPLETED COILED TUBING HORIZONTAL SIDETRACK DRILLING 9/17/96: Milled a pilot hole through the cement plug from 9254' to 9305' MD. 9118196: Completed pilot hole milling to 9306' MD. POOH w/BHA. milling a window through the 9-5/8" casing at 9306' MD. BHA. MU & RIH w/window milling BHA. Started Motor quit: POOH w/BHA. RIH w/milling 9119196: Milled window to 9315' MD. POOH w/BHA. RIH w/finishing mill & milled window to 9314' MD. 9/20/96: Completed window milling to 9319' MD, then drilled formation to 9325' MD. Backreamed window & POOH w/BHA. MU & RIH w/drilling BHA. Displaced well to FIo-Pro & drilled 3.75" sidetrack build section to 9500' MD. 9121196: Drilled build section from 9500' to 9800' MD. horizontal section from 9800' to 10170' MD. POOH w/BHA. RIH w/drilling BHA & continued drilling 9/22/96: Drilled horizontally to 11002' MD w/periodic short trips to window. 9/23 Drilled Drilled /96: to 11020' MD. POOH w/BHA. Swapped out mud to new Flo-Pro. to 11414' MD w/short trips to backream tight spots. MU & RIH w/drilling BHA. 9/24 Drilled 11735' /96: horizontally from 11414' to 11766' MD. Had mud loss of 3 bph after crossing possible fault at MD. Backreamed hole & stuck BHA at 11733' MD. Worked pipe. Pulled free & POOH w/BHA. 9/25/96: Repaired injector head & PT BOP. MU & RIH w/2-7/8" liner assembh.,. Circulated to condition hole for cementing. Landed liner at 11730' MD. 9/26/96: Liner slipped downhole to 11766' MD. Pumped 39 bbls of CIG cement & set liner at 8673 - 11766' MD. Bumped liner plug & POOH w/liner running tool. WOC. MU & RIH w/1.75" DP string on CT. Displaced well to 1% KCl Water, then shut in well & PT liner at 2000 psi/10 minutes; no leakoff. POOH w/BHA. 9/27/96: POOH standing back pipe. MU & RIH w/2-1/8" perforation guns & shot run #1 pedorations at 4 spf. POOH w/perf guns. MU & RIH w/2-1/8" perforation guns & shot run #2 perforations at 4 spf. Perforation intervals were shot at: 10250 - 10350' MD (ZIBt 10450 - 10750' MD (ZIB') 10830 o 11150' MD (ZIB/ 9/28/96: POOH w/peal guns. RIH & set SSSV. FP tubing, RD CTU, set BPV, ND BOPS, NU master. Released CTU. Placed the well on production w/N2 lift & obtained a valid welltest. S ~RRY-S'JN DRILLING SERVICES .ANCHORAGE ALASKA PAGE .~RCO ALASKA iNC. PBU/2-4A 500292006401 NORTH SLC?E BOROUGH COMPUTATi ~N DATE: i I/19 / 96 DATE OF SURVEY: 092596 MWD SURVEY JOB NUMBER: AK-MW-60132 :fELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ~KA iNC TRUE, SUB-SEA MEASD VERTI~.L VERTICAL DEPTH DEPTH DEPTH COURS !NCI=N DG COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9230 . 00 $756.20 8692 . 20 9300.00 ~B17.77 8753.77 9316.00 ~831.64 8767.64 9325.27 ~839.54 8775.54 9360 . 44 5 868.09 8804 . 09 28 0 28 47 31 0 32 i0 39 22 S 38.00 W .00 2265.40S 490.80W S 38.00 W L.14 2291.64S 511.30W S 38.00 W 13.75 2297.92S 516.21W S 45.90 W 46.36 2301.52S 519.45W S 57.05 W 27.57 2314.13S 535.57W -2316.50 -2345.94 -2353.00 -2357.11 -2372.38 9382.99 $885.03 8821.03 43 i9 9415.07 ~906.84 8842.84 50 55 9441.79 -922.91 8858.91 55 i2 9476.62 S94!.83 8877.83 59 3 9502.02 ~954.38 8890.38 61 47 S 65.84 W 31.12 2321.20S 548.65W S 67.26 W 23.88 2330.53S 570.21W S 75.16 W 28.53 2337.36S 590.41W S 82.71 W 21.30 2342.93S 619.09W N 89.45 W 28.92 2344.20S 641.12W -2381.65 -2394.65 -2404.94 -2415.49 -2420.65 9534.02 2969.26 8905.26 62 50 9556.22 S979.51 8915.51 62 13 9598.19 2999.48 8935.48 61 I0 9622.39 ~010.33 8946.33 65 34 9655.87 3022.83 8958.83 70 39 N 80.76 W 24.26 2341.78S 669.31W N 74.08 W 26.84 2337.49S 688.52W N 60.72 W 28.13 2323.36S 722.53W N 57.03 W 22.72 2312.17S 741.04W N 47.01 W 3i.64 2293.05S 765.45W -2423.25 -2422.43 -2414.54 -2406.80 -2392.30 9677.64 ~029.82 8965.82 71 53 9710.92 3039.52 8975.52 74 16 9754.79 S049.15 8985.15 80 25 9762.69 S050.34 8986.34 82 15 9778.64 9051.99 8987.99 85 52, N 39.98 W 31.10 2278.10S 779.62W N 32.07 W 23.83 2252.37S 798.32W N 23.11 W 24.35 2214.48S 818.08W N 21.52 W 30.63 2207.25S 821.04W N 19.77 W 25.13 2192.41S 826.63W -2380.10 -2358.08 -2324.27 -2317.69 -2304.07 9813.07 9053.15 8989.15 90 9840.82 ~053.09 8989.09 89 9870.29 ~053.13 8989.13 89 9899.49 3053.33 8989.33 89 9939.09 ~053.93 8989.93 88 15 58 54 18 56 N 18.71 W 13.12 2159.93S 837.97W N 13.18 W 19.96 2133.26S 845.59W N 12.38 W 2.72 2104.52S 852.11W N 10.80 W 5.80 2075.92S 857.97W N 10.80 W .91 2037.02S 865.39W -2274.11 -2249.20 -2222.07 -2194.96 -2157.99 9970.07 9054.58 8990.58 88 40 10000.44 S055.30 8991.30 88 35 !0035.17 S055.97 8991.97 89 12 10062.22 ~056.20 8992.20 89 49 10095.52 9056.20 8992.20 90 10 N 8.69 W 6.86 2006.50S 870.63W N 7.81 W 2o91 1976.46S 874.99W N 6.23 W 4.89 1942.00S 879.23W N 6.58 W 2.60 1915.12S 882.25W N 4.6¢ W 5.90 1881.98S 885.51W -2128.88 -2100.08 -2066.91 -2040.99 -2008.95 10119.22 ~056.12 8992.12 90 10 10149.92 9056.05 ~992.05 90 5 10183.22 9055.84 8991.84 90 37 10209.87 9055.41 8991.41 91 13 10241.49 ~054.66 8990.66 91 29 N 4.65 W .00 1858.36S 887.43W N 2.89 W 5.74 1827.73S 889.45W N 3.07 W 1.68 1794.48S 891.18W N 2.19 W 4.02 1767.86S 892.40W N .43 W 5.62 1736.26S 893.12W -1986.04 -1956.26 -1923.83 -1897.85 -1866.88 S~ _~Y-SUN DRILLING SERVICES ANCHORAGE ALAS~ PAGE .ARCO ALASKA INC. PBU/2-qA 500292006401 NORTH SLOPE BOROUGH COMPUTATION DATE: !!/19/96 DATE OF SURVEY: 092596 MWD SURVEY JOB NUMBER: AK-MW-60132 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD \-ERTICAL VERTICAL DEPTH DEPTI{ DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGLrLAR COORDINATES DEGREES DG/100 NORTH/SOUTlq EAST/WEST VERT. SECT. 10278.74 9053.75 8989.75 91 19 10309.37 9053.19 8989.19 90 47 10329.17 9052.97 8988.97 90 26 10359.57 9052.60 8988.60 90 58 10389.24 9051.94 8987.94 91 34 N 1.50 E 5.20 1699.039 892.78W N 2.73 E 4.37 1668.43S 891.65W N 1.68 E 5.59 1648.64S 890.89W N .27 E 4.95 i618.25S 890.37W N .96 W 4.63 1588.59S 890.55W -1830.17 -1799.85 -1780.25 -1750.24 -1721.08 10420.59 9050.86 8986.86 92 22 10458 . 54 9049 . 03 8985 . 03 93 9 !0494.59 9047.29 8983.29 92 22 10520.42 9046.22 8982.22 92 22 10540.37 9045.30 8981.30 92 54 N .45 E 5.15 1557.26S 890.69W N .78 W 3.85 1519.36S 890.79W N 2.01 W 4.05 1483.379 891.67W N 2.89 W 3.40 1457.58S 892.77W . _ _ N 4.47 W 8.35 !437.709 894.05W -1690.27 -1652.99 -1617.72 -1592.54 -1573.19 10575.44 9043.60 8979.60 92 40 10604.44 9042.34 8978.34 92 16 10629.77 9041.29 8977.29 92 27 10665.39 9039.66 8975.66 92 48 10690.87 9038.39 8974.39 92 54 N 5.07 W 1.82 1402.79S 896.97W N 6.58 W 5.38 1373.979 899.91W N 6.58 W .71 i348.83S 902.81W N 7.99 W 4.07 !313.549 907.32W N 8.69 W 2.77 1288.36S 911.01W -1539.35 -1511.50 -1487.27 -1453.33 -1429.21 10721.42 9036.89 8972.89 92 43 10748.74 9035.68 8971.68 92 22 10778.84 9034.41 8970.41 92 27 10811.99 9032.93 8968.93 92 38 10844.07 9031.50 8967.50 92 27 N 10.27 W 5.20 N 11.33 W 4.08 N 10.98 W 1.20 N 7.46 W 10.62 N 5.35 W 6.59 1258.269 916.03W 1231.46S 921.15W 1201.959 926.97W 1169.279 932.27W 1137.429 935.85W -1400.48 -1374.99 - 1346.98 -1315.75 - 1285.05 10878.19 9029.91 8965.91 92 54 10899.57 9028.75 8964.75 93 20 10943.22 9026.13 8962.13 93 31 10957.59 9025.27 8961.27 93 20 10991.77 9023.60 8959.60 92 16 N 5.88 W 2.02 N 4.82 W 5.36 N 3.42 W 3.23 N 1.66 W 12.29 N 1.40 W 3.19 1103.519 939.18W I082.259 941.17W 1038.80S 944.30W !024.479 944.94W 990.349 945.85W -1252.25 -1231.69 -1189.47 -1175.48 -1142.05 11032.32 9021.77 8957.77 11061.97 9020.22 8956.22 11097.22 9018.33 8954.33 11127.97 9016.37 8952.37 11151.34 90!4.88 8950.88 92 54 93 4 93 4 94 13 93 4 N .08 W 3.59 N 2.38 E 8.31 N 5.72 E 9.46 N 7.83 E 7.79 N 9.24 E 7.75 949.84S 946.37W 920.24S 945.78W 885.14S 943.29W 854.679 939.67W 831.619 936.21W -1102.28 -1073.05 -1038.06 -1007.43 -984.12 11178.87 9013.76 8949.76 91 34 11219.69 9012.88 8948.88 90 52 11238.47 9012.64 8948.64 90 37 11269.67 9012.49 8948.49 89 54 11306.32 9012.92 8948.92 88 46 N 11.88 E 11.02 N 16.62 E 11.74 N 18.38 E 9.47 N 20.49 E 7.14 N 25.06 E 12.85 804.579 931.17W -956.62 765.039 921.13W -915.92 747.129 915.48W -897.30 717.70S 905.10W -866.51 683.929 890.92W -830.75 _RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/2-4A 500292006401 NORTH SLOPE BOROUGE COMPUTATION DATE: il/19/96 DATE CF SURVEY: 092596 MWD SURVEY JOB NUMBER: AK-MW-60132 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH C~S INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. L1338.79 9013.57 8949.57 88 56 N 27.87 E 8.67 654.86S 876.46W L1360.37 9013.67 8949.67 90 31 N 30.33 E 13.57 636.01S 865.96W L1390.69 9013.32 8949.32 90 47 N 31.04 E 2.49 609.94S 850.49W L1425.12 9012.58 8948.58 91 40 N 35.78 E 14.00 581.21S 831.54W L1449.84 9011.88 8947.88 91 34 N 39.65 E 15.65 561.67S 816.43W -799.59 -779.18 -750.78 -719.16 -697.25 11476.99 9011.02 8947.02 92 ! N 41.41 E 6.68 541.05S 798.80W L1484.49 9010.75 8946.75 92 6 N 41.41 E 1.18 535.42S 793.84W L1507.67 9009.95 8945.95 91 50 N 45.62 E 18.19 518.63S 777.89W L1538.62 9009.29 ~945.29 90 37 N 47.03 E 6.02 497.26S 755.51W L!564.82 9009.27 S945.27 89 28 N 50°02 E 12.23 479.91S 735.89W -673.83 -667.42 -648.07 -623.08 -602.53 Li611.57 9009.81 ~945.81 89 12 N 54.24 E 9.04 451.22S 698.99W 11646.74 9009.67 S945.67 91 13 N 58.98 E 14.65 431.87S 669.64W 11671.19 9009.26 8945.26 90 41 N 62.50 E 14.56 419.93S 648.31W L1704.49 9008.98 8944.98 90 15 N 61.97 E 2.07 404.42S 618.85W L1731.07 9008.54 8944.54 91 40 N 64.08 E 9.55 392.36S 595.17W -567.77 -543.53 -528.00 -507.52 -491.47 L1748.69 9007.79 8943.79 93 9 N 66.02 E 13.88 384.94S L1766.00 9006.84 S942.84 93 9 N 66.02 E .11 377.92S 579.21W -481.34 563.42W -471.63 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 678.43 FEET AT SOUTH 56 DEG. 8 MIN. WEST AT MD = 11766 ~-ERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 10.19 DEG. TIE-IN AT 9,230.00' MD WINDOW POINT AT 9,316.00' MD PROJECTED SURVEY AT 11,766.00' MD ~.RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA iNC. PBU/2-4A 500292006401 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/19/96 DATE OF SURVEY: 092596 JOB NUMBER: AK-MW-60132 KELLY BUS,tING ELEV. = 64.00 FT. OPERATOR: ARCO 3~T_LASKA INC INTE-RPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPIIqt TRUE SUB-SEA MEASD VERTI~LVERTICAL DEPTH DEPTH DEPTH TOTAL P. ECTANG~ COORDINATES MD-TVD VERTICAL NORTH/SOUTH F2%ST/WEST DIFFERENCE CORRECTION 9230 . 00 2756.20 8692.20 10230.00 _a054.96 8990.96 11230.00 9012.73 8948.73 11766.00 ~a006.84 8942.84 2265.40 S 490.80 W 473.80 1747.75 S 893.04 W 1175.04 701.24 755.16 S 918.15 W 2217.27 1042.23 377.92 S 563.42 W 2759.16 541.89 ~ CALCULATION PROCEDURES ARE BASED ON THE USE CF THREE-DIMENSION MINIMUM CURVATURE METHOD. RECEIVED ~ARY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU/2-4A 500292006401 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/19/96 DATE OF SURVEY: 092596 JOB NUMBER: AI{-MW-60132 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUT~ EAST/WEST MD-TVD VERTICAL DI FFERE/qCE CORRECTION 9230.00 8756.20 8692.20 2265.40 S 490.80 W 473.80 9238.81 8764.00 8700.00 2268.63 S 493.33 W 474.81 1.01 9355.30 8864.00 8800.00 2312.29 S 533.06 W 491.30 16.49 9522.63 8964.00 3900.00 2342.94 S 659.28 W 558.63 67.33 11766.00 9006.84 8942.84 377.92 S 563.42 W 2759.16 2200.53 ~ CAL~TION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 13, 1996 Erin Oba, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 2-04A ARCO Alaska, Inc. 96-158 1771 'E & 1064'S ofNW cr Sec 36, T1 IN, R14E, UM 1072'FNL, 3594'FEL, Sec 36, T11N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659- 3607. David W. ~ohnston N ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/encl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill _ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28308- Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1771' E & 1064' S of NW cr Sec 36, T11N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1342' E & 3250' S of NW cr Sec 36, T11N, R14E, UM. 2-04A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1072' FNL, 3594' FEL, Sec 36, T11N, R14E, UM. September 13, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 11250' MD / 9007' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9300' MD Maximum hole angle 94° Maximum surface 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L80 FL4S 2600' 8650' 8224' 11250' 9007' 30 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9700 feet Plugs(measured) PBTD tagged at 9549' MD (5/7/96). true vertical 9164 feet Effective depth: measured 9549 feet Junk (measured) true vertical 9034 feet Casing Length Size Cemented Measured depth True Vertical depth Structural 114' 30" 1207'114' 1207' 114' VED Conductor 1143' 20" 755 Sx Fondu Flyash RECEI Surface 2630' 1 3-3/8" 625 Sx Fondu Flyash & 2694' 2694' 365 Sx Class G Production 9628' 9-5/8" 420SxClassG 9692' 9158' SEP 1 0 1996 Perforation depth: measured 9358 - 9364'; 9396 - 9407'; 9446 - 9452'; 9554 - 9569' Alaska 011 & Gas Oons, C0mml~i( true vertical 8869 - 8874'; 8902 - 8911" 8945 - 8950'; 9038 - 9052' Al~h0r~ 20. Attachments Filing fee __x Property plat __ BOP Sketch _~x Diverter Sketch _ Drilling program x Drilling fluid program__ Time vs depth plot_ Refraction analysis __ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~.._ '~ , ~ Titlle Engineering Supervisor Date '~'- ' Commission Use Only Permit NumberCjl~(,.¢"/.~'0¢ IAPl numberS0- ~o o~-o, I Approval date ~-~/¢;~..~,~ I otherSee cover letter fOrrequirements Conditions of approval Samples required __Y e s _J[_ N o Mud Icg required __ Y e s ~, N o Hydrogen sulfide measures .~ Y e s N o Directional survey required _,~ Yes __ N o Required working pressure for BOPE __ 2M; __ 3 M · __ 5 M · __ I 0 M · __ I 5 M '-['~__.~3500 psi for CTU Other: Original Signeo David W. Johnston by order of / /_ Approved by Commissioner the commission Date 7 "'-/ Form 10-401 Rev. 7-24-89 Submit in triplica DS 2-4A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to ~ 9270' md. Mill window in 9-5/8" casing at ~9300' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight ( 8.9 ppg Flo Pro as drilling fluid). Directionally drill 3-3/4" x 2000' horizontal well to access Zone lB reserves. Build angle to ~94°. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. · Return well to production. RECEIVED SEP 10 199G Alaska Oil & Gna Cone. Comrrdi~ion Anehorale September 10, 1996 DS 2-4A PROPOSED CTD COMPLETION 5-1/2" Tubing 5-1/2" Otis Sliding Sleeve 8423' 9-5/8" Baker SAB Pkr. 8572' 4-1/2."Otis 'X', 8675' 3.813" ID 4-1/2" Tubing tail 8712' 2186' 5-1/2" Otis RQM SSSV Nipple (4.562" ID) 4-1/2" GS FN on top of liner @ ._+8650' Window Cut in 9-5/8" casing with CT, ~ 9300 - 9305' 3-3/4" Open hole Original perforations cement sqz'd. 2-7/8" FL4S liner TD@_+ llZ50' 9-5/8" Casing Shoe @ 9692' RECEIVED ~EP ~ 0 l*Jg$ Oil & ~i~ Cent. Gommls~ion IIIII II · I _ 2--~1 ERIIEC'I'~ONAL ~IDET~ACK Il III I FaORTH RE~I... TO ORI0 . . II i II 2-45TOG 8400~ AI~CO ALASKA lng. g000 - 2-04ORGR PLANE OF VERT SECTIt U Departure Scale I inch ' 800 fl ~_.~_ .,, , , _..7' TO 89~4E;.0 6 DI lO.Oe;XlOlD TI 92.4( -4 · __~ 4 DI 4.~4'-/1ee Tt'90.~ Vedical Section Sca~ 1 inch ' 300 R FILE N~E : C:~CO~K~4~-&~.OW2 DRA~ BY : BIMO H~IPU'~O 8.76* RE~TWE TO GRID ~RTH DATE · SEPT. 10. t996 iii ii iii III j_ji ii I ! I I ii ii ~ L iiii i i i ii .......... 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" ....... ~- - ~ ......... ~ .... ~ .... ' .......... ~l ............ L :~ ~.)'~i 37 O~T~ 8~7~ -~.Oi -0~.5', 02, 0.0~ 0.2] 5~7~'S, ~?~0.~ .......... ;,, ~ '1~;~ .....~ ........f~ ~ ~/Z'~'~ '~~ ~j -a~.~7 ...... ~ ...... 'bTb' o~j 6~~~ ...... ~_ ~'[ ~ I ~ ~..~ ~n n~ ~ o~ .... ~=-- ~7~ ~ ~3.'~ '~'~'-~-~" ~ ~J u.uF -~" ~, ~ ~ ~; ...... ~ ' ', ~_ ~. : J ' ~'~-~:" ~,~.o~ 3~ ~'~ ~' ~:~'~'"':~ .~'~'~ ..... 3.~ .......... o.c': o~ ,~,~-~-~5~ : .. ,~,,- '- · SEPt (~' lggG Sent by: FROM DRILE× ALASKA .g~_~07 562 4452_ 09/10/96 14:37_. Job 317 Page 5/5 RECEIVED SEP 1 0 1996 Alaska 0tl & ~t,i {3m~. c~n Arc.rage Shop Fuel Water Boilers Mud ~ks 60~40 I Trplx Pump Room Pipe rack/ Dowell Drilling Equipment Trailer Fir'~e' Ext. Preferred Major Equipment Layout for CT Drilling in DS 2-4A C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Offs 7" WLA Quick I Conn~o~ ~ Annular BOP (Hydri,),7-1/16" ID .,~ 5,000 psi working pressure Alignment Guide 7-1/16", 5M Ram Type Dual / Gate BOPE Flanged Fire Resistant Manual Valve Kelly Hose To Dual \ ChokeManifold \ HCR Cutters or Combination Cutter/Blinds Slip/Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Earns 0.458' (5.5") Manual Master Valve 2" Pump-In ~Tubing Hanger 9-5/8" Annulus 13-3/8" Annulus Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree STATE OF ALASKA ',-. ALA~,..A OIL AND GAS CONSERVATION .~MMISSION APPLIC TION FOR SUNDRY A 'PROVALS 1. Type of Request: A~-~I. o~ X Suspend Opera~x)n snutciown Ar~er ca. sa3g Repair well Plugging X C.".ange aC~'oveO orogram Pull ~ubing Variance : , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1771' E & 1064' S of NW cr Sec 36, T11 N, R14E, UM. At top of productive interval 1342' E & 3250' S of NW cr Sec 36, T11N, R14E, UM. At effective depth At total' depth 1142' E & 3517' S of NW cr Sec 36, T11N, R14E, UM. Re-enter suspended well Time extension S~mulaze Per/orate OU'~ , 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay' Unit 8. Well number 2-04 9. Permit number 70-17 10. APl number 50 - 029-20064 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9700 feet true vertical 9164 feet Effective depth: measured 9549 feet true vertical 9034 feet Casing Length Size Structural 114' 30" Conductor 1143' 20" Sudace 2630' 13-3/8" Production 9628' 9-5/8" Plugs(measured) PBTD Tagged @ 9549' MD (5/7/96). Junk(measured) Cemented 755 Sx Fondu Flyash 625 Sx Fondu Flyash & 365 Sx Class G 420 Sx Class G Measured depth True vedicaldepth 114' 114' 1207' 1207' 2694' 2694' Perforation depth: measured 9358 - 9364'; 9396 - 9407'; 9446 - 9452'; 9554 - 9569' S~P 0 3 199G true vertical 8869 - 8874'; 8902 - 8911'; 8945 - 8950'; 9038 - 9052' Alaska Oil & G~s Oon~. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8615' MD; 4-1/2", 12.6~, N-80, PCT@ 8740' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 8572' MD; 5-1/2", Otis RQM SSSV @ 2186' MD. 13. A~achments Description summary of proposal x. Detailed operations program BOP sketch x 14. Estimated date for commencing operation September, 1996 16. If proposal was verbally approved Name of ap.prover Date aooroved 15. Status of well classification as: Oil .X. Gas . Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' -'7 .~igned /~......_,_~,~,_.,~ ._.,C' f,,,f, c.%~ T'rtle Engineedna~ Supervisor / - FOR (30MMI~;RION LI~I~ ONLY ~nditions of approval: N~ Commission so representative may witness Plug integrity~-% BOP Test . Location clearance Mechanical Integrity Test Subsequent form required 10-~ ~,~/') CrigJnai Signed By David W. Johnston ,pproved by order of the Commissioner ~rm 10-403 Rev 06115188 i / Date ,~, ~../?~/ Approval No. ~, -t/(/ )HeLu rp. ed SUBMIT ll'J TI:IIDI ~P ^-~:: · WELL PERMIT CHECKLIST COMPANY FIELD&POOL ~DMINISTRATION .......... A~,~ DATE . 6. 7. 8. 9. 10. 11. 12. 13. GEOL AREA ~ c~o .d'"t. Permit fee attached ....................... Lease number appropriate ................... ~ '"~" t~,YJ- N Unique well name and number ................. Well located in a defined pool ................. .~ ~_~' Well located proper distance from ddg unit boundary ..... LN Well located proper distance from other wells ......... ~,N Sufficient acreage available in drilling unit. .......... ,~ }~N If deviated, is wellbore plat included .............. Operator only affected party ................... (~)N Operator has appropriate bond in force ............. ~1~ N Permit can be issued without conservation order ....... ~ N Permit can be issued without administrative approval .... :~~ N Can permit be approved before 15-day wail ........ N PROGRAM: exp [] dev [] redrll _~ serv [] wellbere seg [] ann. disposal para req [] UNIT# i ~ ~ ,~"'"0 ON/OFF SHORE REMARKS "EN'GiNEERiNG 'GEOLOGY 14. Conductor s~ng provided ................... Y N"~ 15. Surface casing protects ail known USDWs .......... Y N ~' i ~ 16. CMT vol adequate to circulate on conductor & surf csg .... Y N ( 17. CMT vol adequate to tie-in long string to surf csg ....... Y__ N ~ 18. CMT will cover ail known productive horizons ......... .~Y~N 19. Casing designs adequate for C, T, B & permafrost ...... ..~(~N 20. Adequate tankage or reserve pit. ......... ...... (,.~N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... (..Y,J N 22. Adequate wellbore separation proposed ........... .~ N 23. If diverter required, is it adequate ............... i~bl:~[~'~'-~i 24. Ddlling fluid program schematic & equip list adequate .... N 25. BOPEs adequate ........................ N 26. BOPE press ralJng adequate; test to ,:~~ psig 27. Choke manifold complies w/APl RP-53 (May 84) ...... .~<)N ~:~:~-- ~ 28. Work will occur without operation shutdown .......... 29. Is presence of H2S gas probable .............. 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpress_u_~zone~: .--~'-. '~-... Y N 32. Seismic analysis of shallo~as-zo-r~ ............. Y N 33. Seabed ~y(if off-shore) ............. Y N GEOLO. GY: ENGINEERING: COMMISSION: '- JDH ~ JDN Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . * ****************************** * ............................ * * ....... SCHLUMBERGER ....... * * ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 2 - 4A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292006401 REFERENCE NO : 98233 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/ 5 ORIGIN : FLIC REEL NAME : 98233 CONTINUATION # : PREVIOUS REEL : COJ~fENT : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE . 98/06/ 5 ORIGIN : FLIC TAPE NAME : 98233 CONTINUATION # : 1 PREVIOUS TAPE : COI~4Ed~T · ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 2-4A API NTJ]~ER: 500292006401 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-JUN-98 JOB NUMBER: 98233 LOGGING ENGINEER: YURI MORGAN OPERATOR WITNESS: JEFF HUPP SURFACE LOCATION SECTION: 3 6 TOWNSHIP: 1 IN RANGE: 14E FI~L : 1064 FSL: FEL: FWL : 177 ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: GROUND LEVEL: 30.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 000 2. 875 11766.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUM~ER: PASS NUMBER: DATE LOGGED: 21-MAR-97 LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 11221.0 11212.5 11207.5 11202.5 11198.5 11183.0 11033.5 11015.0 11011.0 11000.5 10993.5 10968.5 10958.5 10954.0 10953.5 10941.0 10818.0 10783.0 10776.0 10759.0 10746.0 10701.5 10667.0 10662.5 10652.0 10626.0 10533.5 10511.0 10506.5 10441.5 10426.5 10410.0 10406.5 10401.5 10392.5 10384.5 10379.5 10366.0 10352.5 10345.5 10341.5 10242.0 10233.0 10232.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88887.0 88887.0 11220.0 11220.0 11212.5 11212.5 11206.5 11206.5 11201.5 11201.5 11197.0 11197.0 11181.5 11181.5 11032.5 11032.5 11013.5 11013.5 11009.0 11009.0 10999.5 10999.5 10995.0 10995.0 10969.5 10969.5 10960.0 10960.0 10955.0 10955.0 10941.0 10941.0 10818.5 10818.5 10784.0 10784.0 10776.0 10776.0 10760.0 10760.0 10745.5 10745.5 10701.0 10701.0 10667.5 10667.5 10662.5 10662.5 10652.0 10652.0 10625.0 10625.0 10532.5 10532.5 10510.0 10510.0 10506.0 10506.0 10441.0 10441.0 10426.0 10426.0 10408.0 10408.0 10405.5 10405.5 10401.5 10401.5 10391.0 10391.0 10383.0 10383.0 10378.5 10378.5 10366.0 10366.0 10352.5 10352.5 10344.0 10344.0 10340.5 10340.5 10240.5 10240.5 10231.5 10231.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10228.5 10226.5 10225.5 10224.5 10212.5 10212.0 10210.5 10197.0 10195.0 10167.0 10163.0 10091 . 5 10089.0 10048.5 10044.5 10030.5 10027.5 10019.0 10016.0 10016.0 10013.0 9994.0 9991.0 9989.0 9986.0 9981 . 0 9978.0 9963.0 9960.0 9952.5 9950.0 9941 . 0 9938.5 9924.5 9922.5 9922.5 9920.0 9920.0 9917.5 9906.0 9903 . 5 9897.5 9896.5 9887.0 9885.0 9863 . 0 9860.5 9860.5 9857.5 9852.5 9851.0 9849.5 9848.0 9846.0 9844.5 9831 . 5 9830.5 9823.5 9822.0 981 O. 5 9808.5 9802.0 9800.5 9797.5 9796.0 9786.0 9784.0 9782.0 9780.5 9759.5 9758.0 9729.5 9728.0 9706.5 9705.0 9696.0 9693.5 9682.5 9681.0 9679.0 9670.5 9669.0 9666.5 9666.5 9664.0 9662.0 9663.0 9656.0 9654.5 9650.0 9648.5 9634.5 9633.0 9624.0 9622.0 9599.5 9598.0 9592.5 9590.0 9579.5 9577.5 9562.0 9560.0 9543 . 0 9540.5 9541.0 9538.5 10226.5 10224.5 10210.5 10195.0 10163.0 10089.0 10044.5 10027.5 10016.0 10013.0 9991.0 9986.0 9978.0 9960.0 9950.0 9938.5 9922.5 9920.0 9917.5 9903.5 9896.5 9885.0 9860.5 9857.5 9851.0 9848.0 9844.5 9830.5 9822.0 9808.5 9800.5 9796.0 9784.0 9780.5 9758.0 9728.0 9705.0 9693.5 9679.0 9666.5 9664.5 9662.0 9654.5 9648.5 9633.0 9622.0 9598.0 9590.0 9577.5 9560.0 9540.5 9538.5 5-JUN-1998 15:44 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-U--JN-.1998 15:44 9535.5 9533.5 9533.5 9533.5 9531.0 9531.0 9527.5 9525.5 9525.5 9516.0 9513.5 9513.5 9508.0 9505.5 9505.5 9493.5 9490.5 9490.5 9438.5 9436.0 9436.0 9431.0 9429.0 9429.0 9414.0 9412.5 9412.5 9377.5 9375.0 9375.0 9374.0 9372.0 9372.0 9323.5 9321.0 9321.0 100.0 97.5 97.5 $ RE,LARKS: CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 2-4A ON 14-JAN-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASE PASS #1 GRCH TO THE BASELINE GA~k~A RAY GR.MWD; AND BASE PASS #1 SIGM TO GR.MWD. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE H~ER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE · 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILENUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCRE~IENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11226.0 9320.0 TDTP 11240.0 9320.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTEDDEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: BASELINE DEPTH GRCH TDTP $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BASE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 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 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SBPZN TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 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) TCAF TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 1185490 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11300.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBP~N. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL. TDTP -999.250 GR.MWD 109.510 DEPT. 9300.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL. TDTP -999.250 GR.MWD 20.860 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUN~L~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11226.0 9320.0 TDTP 11240.0 9320.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88887.0 11227.0 11226.0 11221.5 11220.5 11221.0 11220.5 11213.0 11213.0 11213.0 11207.0 11206.5 11203.0 11202.0 11202.0 11201.0 11198.5 11197.0 11193.5 11191.5 11187.0 11185.0 11184.0 11182.0 11169.5 11170.0 11165.0 11165.0 11139.0 11139.5 11125.0 11123.5 11123.0 11122.0 11111.0 11110.0 11109.0 11107.0 11091.5 11088.0 11086.0 11084.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 11047.0 11046.0 11045.5 11044.0 11034.0 11033.0 11033.5 11032.5 11022.5 11022.5 11015.0 11014.0 11011.0 11009.5 11001.0 11000.0 10996.5 10995.0 10985.5 10988.0 10978.5 10979.5 10969.0 10970.0 10968.5 10969.5 10959.0 10961.0 10958.5 10960.5 10954.5 10955.0 10942.0 10941.5 10927.0 10927.0 10912.0 10913.5 10892.5 10890.5 10889.0 10886.5 10858.5 10861.5 10818.0 10818.5 10815.0 10816.0 10804.5 10803.0 10797.0 10797.0 10793.0 10794.0 10786.0 10787.5 10784.0 10784.5 10776.0 10776.5 10775.5 10776.5 10772.0 10773.5 10768.0 10768.5 10766.0 10767.0 10759.5 10761.0 10759.0 10760.0 10757.0 10757.5 10741.5 10743.0 10708.5 10708.0 10684.5 10683.5 10677.5 10677.5 10667.0 10668.5 10661.0 10661.5 10660.5 10661.0 10656.0 10655.5 10652.5 10652.0 10642.5 10640.5 10637.5 10636.5 10624.0 10624.0 10606.0 10607.0 10534.0 10533.0 10533.5 10532.5 10522.0 10521.5 10511.0 10510.5 10507.5 10506.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 10502.0 10485 5 10453 5 10442 0 10441 5 10438 5 10435 0 10426.5 10408.5 10406.5 10406.0 10402 5 10397 5 10394 5 10393 0 10387 5 10385 5 10375 5 10363 0 10360 0 10350 0 10341.5 10340.5 10333.0 10332.5 10328.5 10326.5 10307.0 10285.5 10239.0 10233.0 10232.5 10229.0 10226.5 10218.5 10218.0 10212.0 10196.5 10195.0 10185.0 10170.0 10162.0 10160.0 10149.0 10129.0 10100.0 10066.0 10048.5 10032.5 10026.0 10019.5 10016.0 10005.5 9981.0 9976.5 10500.0 10485.0 10452.5 10441.0 10438.0 10426.0 10405.5 10394.5 10392.0 10386.0 10375.0 10362.5 10341.5 10331.5 10306.5 10283.0 10238.0 10231.0 10227.0 10225.0 10217.5 10210.5 10195.0 10183.5 10158.5 10147.0 10128.5 10099.0 10063.0 10029.5 10023.5 10016.5 10013.5 10003.5 9978.5 10441.5 10434.5 10426.0 10407.0 10405.5 10402.5 10396.0 10384.0 10364.0 10359.5 10349.5 10340.0 10332.0 10328.0 10325.0 10231.5 10225.5 10217.5 10210.0 10194.0 10166.0 10158.0 10045.0 9973.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 10 9963.0 9946.5 9940.5 9925.0 9922.0 9906.0 9898.5 9897.0 9893.0 9873.0 9870.0 9865.0 9862.5 9852.0 9845.0 9841.0 9828.0 9818.5 9810.5 9804.5 9802.0 98OO. 0 9798.0 9790.5 9786.0 9779.0 9760.0 9759.5 9751 5 9733 0 9730 0 9725 0 9684 5 9682 0 9681 0 9671 5 9668 5 9667 0 9664 0 9661 5 9659 5 9656 0 9650 0 9649 5 9644.5 9634.5 9634.0 9624.0 9602.5 9592.5 9592.0 9589.5 9588.0 9579.5 9562.0 9960.5 9938.5 9920.0 9904.0 9896.5 9892.5 9872.0 9863.5 9860.5 9851.0 9839.5 9826.0 9817.5 9809.0 9803.0 9801.0 9799.0 9796.5 9789.0 9784.5 9778.0 9758.5 9750.0 9724.0 9682.0 9679.0 9666.5 9662.0 9658.0 9654.5 9648.5 9644.0 9633.0 9622.5 9600.5 9590.5 9587.5 9586.5 9560.0 9946.0 9923.5 9897.5 9867.5 9844.0 9803.5 9758.5 9732.0 9728.5 9679.0 9668.0 9665.0 9661.0 9648.5 9633.0 9590.0 9588.5 9586.5 9578.0 9560.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 11 9555.5 9548.0 9541.0 9527.5 9524.0 9522.5 9516.5 9516.0 9507 5 9504 0 9497 5 9493 5 9489 5 9467 5 9448 5 9438 5 9438 0 9434 0 9431 5 9414 0 9405 0 9400.0 9396.0 9377.0 9376.0 9375.5 9374.5 93 62.5 9344.0 9326.0 100.0 $ 9539.0 9520.5 9513.5 9505.5 9490.5 9448.0 9436.5 9432.5 9429.5 9412.5 9403.5 9397.5 9375.0 9374.0 9372.0 9359.5 9553.5 9546.0 9525.5 9521.0 9515.0 9501.5 9495.5 9492.0 9486.5 9465.5 9435.5 9430.0 9394.5 9373.5 9343.0 9324.5 9324.0 98.5 98.0 REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTHCORRECTED DATA FOR BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASE PASS #2 GRCH TO BASE PASS #1 GRCH; AND BASE PASS #2 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 12 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 2 1 1 SIGM TDTP CU 1185490 O0 000 O0 0 2 1 1 TPHI TDTP PU-S 1185490 O0 000 O0 0 2 1 1 SBHF TDTP CU 1185490 O0 000 O0 0 2 1 1 SBHNTDTP CU 1185490 O0 000 O0 0 2 1 1 SIGC TDTP CU 1185490 O0 000 O0 0 2 1 1 SIBH TDTP CU 1185490 O0 000 O0 0 2 1 1 TRAT TDTP 1185490 O0 000 O0 0 2 1 1 SDSI TDTP CU 1185490 O0 000 O0 0 2 1 1 BACK TDTP CPS 1185490 O0 000 O0 0 2 1 1 FBAC TDTP CPS 1185490 O0 000 O0 0 2 1 1 TCAN TDTP CPS 1185490 O0 000 O0 0 2 1 1 TCAF TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1185490 O0 000 O0 0 2 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 11239.000 SIGM. TDTP 19.689 TPHI. TDTP 33.485 SBHF. TDTP 33.713 SBPZN. TDTP 41.543 SIGC. TDTP 2.323 SIBH. TDTP 41.835 TRAT. TDTP 1.869 SDSI.TDTP 0.312 BACK. TDTP 218.222 FBAC. TDTP 52.732 TCAN. TDTP 48181.047 TCAF. TDTP 19586.848 TCND. TDTP 29115.656 TCFD.TDTP 10005.605 TSCN. TDTP 10193.588 TSCF. TDTP 4143.958 INND. TDTP 885.284 INFD.TDTP 374.837 GRCH. TDTP -999.250 TENS.TDTP 77.000 CCL. TDTP -0.099 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 13 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 9318 000 41 770 0 203 17869 645 3845 485 79 000 SIGM. TDTP 15. 846 TPHI. TDTP SIGC. TDTP 1. 715 SIBH. TDTP BACK. TDTP 2 62. 447 FBAC. TDTP TCND. TDTP 26901. 113 TCFD. TDTP INND. TDTP 890.924 INFD. TDTP CCL. TDTP -0. 097 31 . 600 SBHF. TDTP 42. 328 TRAT. TDTP 47. 351 TCAN. TDTP 8699. 934 TSCN. TDTP 296. 334 GRCH. TDTP 26.686 1.930 43803.344 9426.326 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION . O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11226.0 9290.0 TDTP 11240.0 9290.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 14 BASELINE DEPTH GRCH TDTP 88888.0 88888.5 88888.0 11212.5 11213.0 11212.5 11201.5 11201.0 11187.5 11186.0 11184.5 11183.5 11133.5 11131.5 11103.0 11100.0 11089.0 11086.5 11065.0 11065.0 11033.5 11032.5 11015.5 11015.0 11011.5 11009.5 11004.5 11003.0 11000.0 11000.0 10985.5 10987.5 10969.0 10970.0 10968.0 10969.5 10964.5 10966.0 10957.5 10960.0 10953.5 10955.0 10943.5 10944.0 10941.5 10942.5 10941.0 10941.0 10914.0 10913.5 10892.0 10890.5 10817.5 10819.0 10792.0 10793.5 10785.0 10787.0 10780.0 10782.0 10778.5 10779.0 10775.5 10776.5 10776.5 10767.5 10768.0 10759.5 10761.0 10753.5 10754.5 10750.0 10751.0 10743.5 10743.0 10708.0 10708.0 10693.5 10695.5 10683.5 10683.5 10680.0 10679.5 10666.5 10668.0 10660.5 10661.0 10659.5 10660.0 10651.0 10652.5 10645.5 10646.5 10621.0 10620.5 10612.5 10614.0 10607.0 10607.5 10592.5 10593.5 10572.0 10574.0 10533.0 10532.5 10532.5 10523.0 10522.0 10522.0 10521.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 15 10511.0 10510.5 10508.0 10507.5 10506.5 10506.5 10471.5 10472.0 10441.0 10441.0 10431.5 10431.5 10429.5 10429.5 10426.0 10426.5 10408.5 10407.0 10406.0 10405.5 10405.5 10405.5 10402.0 10402.5 10401.5 10401.5 10396.0 10396.0 10395.0 10394.5 10392.0 10391.5 10383.0 10383.0 10374.5 10375.5 10373.5 10373.0 10362.5 10364.0 10362.0 10362.5 10353.0 10353.5 10352.5 10353.5 10350.0 10350.0 10340.5 10341.5 10340.5 10337.5 10337.5 10332.5 10332.0 10328.0 10327.5 10309.5 10306.5 10283.5 10281 . 0 10239.5 10238.5 10232.5 10230.5 10228.5 10227.5 10225.5 10225.0 10225.0 10212.0 10210.5 10211.5 10210.5 10196.0 10195.0 10185.0 10183.5 10160.5 10158.5 10122.5 10119.0 10118.5 10117.5 10088.5 10087.5 10048.5 10045.5 10033.0 10029.5 10030.0 10028.0 10026.0 10023.5 10016.0 10013.5 9998.5 9997.5 9992.0 9991.0 9980.0 9978.5 9976.5 9974.0 9962.5 9960.5 9947.5 9946.0 9947.0 9944.0 9940.0 9938.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 16 9924.5 9914.0 9906.0 9883.0 9878.0 9875.5 9873.5 9864.5 9862.5 9852.0 9845.5 9845.0 9841.5 9829.5 9817.5 9810.0 9807.5 9804.0 9799.5 9797.5 9786.0 9782.0 9765.0 9759.5 9752.5 9751.5 9735.0 9732.5 9729.5 9724.5 9707.0 9701.0 9694.5 9693.5 9681.0 9674.5 9671.5 9668.5 9666.5 9663.5 9661.0 9656.0 9649 5 9634 0 9624 0 9597 0 9592 0 9588 0 9579 5 9575.0 9561.5 9555.0 9541.0 9535.0 9532.0 9922.5 9912.5 9904.0 9882.0 9875.5 9872.0 9863.5 9860.5 9851.0 9844.5 9840.0 9829.0 9817.5 9809.0 9802.5 9799.0 9796.5 9784.5 9781.0 9758.5 9750.0 9735.0 9728.0 9724.0 9707.5 9699.5 9694.0 9679.0 9673.5 9666.5 9662.0 9655.0 9648.5 9633.5 9622.5 9596.0 9590.5 9586.5 9575.5 9560.0 9539.0 9533.5 9531.0 9874.0 9844.0 9807.5 9763.5 9751.0 9731.5 9699.0 9691.0 9679. 0 9668.0 9664.5 9661.0 9648.5 9633.0 9590.0 9578.0 9553.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 17 9531.0 9529.0 9530.0 9529.5 9527.0 9525.5 9517.5 9515.5 9515.5 9513.5 9507.0 9505.0 9503.5 9501.5 9497.5 9495.5 9492.0 9490.5 9488.5 9486.5 9466.5 9464.5 9464.5 9462.0 9438.0 9436.5 9437.5 9436.0 9433.5 9432.0 9432.5 9431.5 9431.0 9429.5 9430.5 9429.0 9414.0 9412.5 9406.5 9406.5 9396.5 9395.0 9375.0 9373.5 9373.5 9372.0 9360.5 9359.5 9343.0 9342.5 9326.0 9324.5 9320.5 9319.5 100.0 99.0 98.5 REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASE PASS #3 GRCH TO BASE PASS #1 GRCH; AND BASE PASS #3 SIGM TO BASE PASS #1SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PA GE: 18 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NURi~ SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1185490 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11240. 000 SIGM. TDTP 18. 083 TPHI. TDTP 35. 380 SBHF. TDTP SBI~N. TDTP 42. 044 SIGC. TDTP 2. 709 SIBH. TDTP 43 . 049 TRAT. TDTP SDSI. TDTP O. 268 BACK. TDTP 353. 358 FBAC. TDTP 120. 288 TCAN. TDTP TCAF. TDTP 19478. 762 TCND. TDTP 29940. 855 TCFD. TDTP 10035. 420 TSCN. TDTP TSCF. TDTP 4178.226 INND.TDTP 828.180 INFD. TDTP 358.135 GRCH. TDTP TENS. TDTP 79. 000 CCL. TDTP -O. 097 35.728 1.964 50085.547 10743.430 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 19 DEPT. 9288.500 SIGM. TDTP 15.494 TPHI.TDTP SBHN. TDTP 46.604 SIGC. TDTP 0.449 SIBH. TDTP SDSI.TDTP 0.179 BACK. TDTP 290.070 FBAC. TDTP TCAF. TDTP 16207.693 TCND. TDTP 23466.719 TCFD. TDTP TSCF. TDTP 3388.796 INND. TDTP 897.064 INFD. TDTP TENS. TDTP 80.000 CCL. TDTP -0.100 24. 497 SBHF. TDTP 52. 414 TRAT. TDTP 49. 466 TCAN. TDTP 7732. 808 TSCN. TDTP 274. 762 GRCH. TDTP 37.476 1.729 35441.164 7410.240 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION . O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE · 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NOMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11226.0 10080.0 TDTP 11240.0 10080.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 20 88888.0 11221.5 11219.5 11213.0 11212.5 11201.5 11197.5 11196.5 11191.5 11183 0 11170 0 11084 5 11065 5 11050 5 11033 5 11012 5 11011 0 11008 0 11004 5 11001 5 10996.5 10990 0 10972 0 10969 0 10959 5 10954 5 10944 0 10941 0 10930 5 10910 0 10888 5 10878 0 10862 0 10840 5 10818 0 10812 5 10802 5 10792 5 10792 0 10789 0 10784 0 10777 5 10776 0 10768 0 10755.0 10727.0 10701.5 10681.0 10677.5 10661.0 10660.0 10656.0 10652.0 10637.5 88888.5 88887.0 11220.5 11220.0 11213.0 11197.0 11191.5 11182.0 11082.5 11065.0 11049.5 11032.5 11011.5 11009.5 11006.5 11000.0 10995.0 10991.0 10970 0 10961 0 10955 5 10944 0 10941 5 10930 0 10911 0 10890 5 10879 0 10861 0 10818.5 10814.0 10803.0 10793.5 10784.5 10776.5 10768.5 10755.5 10728.5 10701.5 10679.5 10677.5 10660.5 10655.5 10652.0 10636.5 11212.5 11201.0 11196.5 11170.0 11003.0 10969.5 10839.5 10793.5 10789.0 10776.5 10661.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-0-UN-1998 15:44 PAGE: 21 10626 0 10617 5 10576 0 10548 0 10534 0 10523 0 10511 0 10506 5 10493.0 10473.5 10442.0 10441.0 10427.0 10412.5 10408.5 10406.5 10402.0 10401.0 10397.0 10392.5 10389.0 10383.5 10379.0 10363.5 10352.5 10351.0 10342.0 10341.5 10338.5 10332.0 10326.0 10262.5 10257.0 10242.5 10233.5 10232.0 10227.0 10226.5 10212.5 10196.5 10195.0 10169.5 10163.0 10149.5 10114.5 100.0 $ 10625 0 10617 0 10574 0 10550 0 10533 0 10521 5 10510 5 10506.0 10492.5 10473.5 10441.5 10426.0 10410.5 10405.5 10400.5 10391.5 10383.0 10378.5 10362.5 10353.0 10350.0 10341.5 10337.5 10332.0 10327.5 10262.0 10240.5 10231.0 10224.5 10210.5 10195.0 10167.0 10159.0 10146.5 10114.5 100.0 10441.0 10407.0 10402.5 10396.0 10388.5 10340.0 10337.0 1 0254.0 10231.5 10225.5 10210.5 10194.0 99.0 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASE PASS #1 GRCH; AND BORAXPASS #1 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 22 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD NUMB S~'vlP ELI~I CODE (HEX) CCL TDTP V 1185490 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11239 SBHN. TDTP 45 SDSI.TDTP 0 TCAF. TDTP 18695 TSCF. TDTP 3931 TENS. TDTP 76 DEPT. 10079 SBPZN. TDTP 43 SDSI.TDTP 0 TCAF. TDTP 22138 TSCF. TDTP 4549 TENS.TDTP 76 000 SIGM. TDTP 17. 807 TPHI. TDTP 29. 995 SBHF. TDTP 33. 534 651 SIGC. TDTP 1. 656 SIBH. TDTP 51. 220 TRAT. TDTP 1. 827 205 BACK. TDTP 190. 315 FBAC. TDTP 51. 030 TCAN. TDTP 44682. 625 738 TCND. TDTP 27715. 742 TCFD. TDTP 9313. 672 TSCN. TDTP 9396. 422 573 INND. TDTP 2119. 483 INFD. TDTP 359. 374 GRCH. TDTP -999.250 000 CCL. TDTP -0. 099 000 SIGM. TDTP 16. 983 TPHI. TDTP 41. 133 SBHF. TDTP 332 SIGC. TDTP 1. 472 SIBH. TDTP 46. 164 TRAT. TDTP 176 BACK. TDTP 213. 437 FBAC. TDTP 36. 896 TCAN. TDTP 457 TCND. TDTP 29237. 547 TCFD. TDTP 9176. 078 TSCN. TDTP 447 INND. TDTP 1874. 857 INFD. TDTP 302.192 GRCH. TDTP 000 CCL. TDTP -0. 102 27. 820 2.146 59613. 977 12250. 658 -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NtrMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 24 PASS NUMBER: 5 DEPTH INCREMENT: O. 5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11226.0 10100.0 TDTP 11240.0 10100.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NURi~ER: 1 BASELINE DEPTH 88888.0 11215.5 11212.5 11197.5 11196.5 11191.0 11190.0 11171.5 11166.5 11165.0 11160.0 11159.0 11150.5 11144.0 11134.0 11132.0 11115.5 11114.5 11094.5 11083.0 11076.0 11068.0 11063.0 11057.5 11049.0 11047.5 11044.5 11040.5 11031.5 11030.5 11020.5 11017.0 11012.5 11011.0 11009.0 11004.0 11001.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88888.0 11215.5 11213.0 11212.5 11197.5 11196.5 11191.5 11191.0 11172.5 11167.0 11165.0 11159.0 11158.0 11148.0 11145.5 11133.5 11132.0 11113.5 11113.0 11093.5 11080.5 11075.5 11067.5 11062.0 11055.0 11049.5 11046.5 11043.5 11040.5 11030.5 11029.5 11019.5 11014.0 11011.5 11010.0 11008.5 11002.5 11000.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 25 10996.5 10990.5 10978 5 10972 0 10969 0 10965 0 10959 5 10959 0 10954 0 10951 5 10947 0 10944 0 10934 0 10930.5 10926.0 10903.5 10883.5 10875.5 10871.5 10864.0 10842.0 10823.5 10818.0 10810.5 10792.5 10777.0 10776.0 10770.0 10767.5 10761.5 10756.5 10748.5 107'45.0 10741.5 10728.5 10725.0 10715.5 10710.5 10707.0 10704.0 10696.5 10691.0 10688.0 10678.0 10672.5 10671.0 10669.5 10658.0 10652.0 10643.0 10640.5 10625.5 10618.5 10615.5 10590.0 10995.5 10970.5 10961.0 10955.5 10944.0 10819.0 10812.5 10793.5 10776.5 10769.0 10757.5 10744.5 10671.5 10652.0 10988.0 10976.0 10970.0 10963.0 10958.5 10950.0 10944.5 10931 5 10929 0 10924 0 10901 5 10882 5 10875 5 10870 5 10863 0 10841 5 10824 0 10777.0 10769.0 10761.0 10755.5 10748.5 10741.5 10728.0 10724.5 10715.5 10711.5 10706.0 10704.0 10696.0 10691.5 10687.5 10677.0 10673.0 10670.5 10658.0 10644.5 10640.0 10625.5 10618.5 10615.0 10590.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 26 10587.0 10581 0 10575 5 10572 0 10560 5 10557 0 10553 5 10549 5 10541 0 10538 5 10534 0 10532 0 10528 5 10522 5 10518 0 10513 5 10511 5 10507 0 10484 0 10481 0 10475 5 10464 5 10454 5 10442 0 10441 0 10439 5 10434 5 10426.5 10420 5 10403 5 10397 5 10393 0 10377 0 10374 5 10365 0 10360 0 10353 0 10346 0 10342.0 10338.0 10331.5 10325.0 10315.5 10311.0 10291.0 10286.0 10274.0 10240.5 10230.0 10228.5 10227.0 10226.5 10212.5 10200.5 10196.5 10574.5 10533.0 10521.5 10511.0 10475.5 10442.0 10438.5 10426.5 10392.0 10373.5 10353.0 10341.5 1022 6.5 10224.5 10211.0 10195.5 10586.5 10581.5 10572.0 10560.0 10554.5 10551.5 10549.0 10541.5 10539.0 10532.5 10529.0 10522.5 10518.5 10514.0 10512.0 10506.5 10485.0 10481.5 10465.0 10454.5 10441.5 10434.5 10420.5 10403.0 10396.5 10377.0 10364.5 10359.0 10343.5 10340 5 10337 0 10329 5 10323 5 10313 0 10309 0 10288 5 10283 5 10271 5 10240.0 10229.0 10226.0 10211.0 10199.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 27 10195.0 10160.0 10159.5 100.0 99.5 $ 10194.0 99.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #2 GRCH TO BASE PASS #1 GRCH; AND BORAXPASS #2 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 28 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) BACK TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TSCNTDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1185490 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11240.000 SIGM. TDTP 18.178 TPHI.TDTP 32.686 SBHF. TDTP SBHN. TDTP 42.510 SIGC. TDTP 2.191 SIBH. TDTP 44.086 TRAT. TDTP SDSI. TDTP 0.248 BACK. TDTP 234.962 FBAC. TDTP 58.869 TCAN. TDTP TCAF. TDTP 19041.816 TCND. TDTP 28073.137 TCFD. TDTP 9249.600 TSCN. TDTP TSCF. TDTP 3836.625 INND. TDTP 2178.007 INFD. TDTP 370.501 GRCH. TDTP TENS. TDTP 76.000 CCL. TDTP -0.104 DEPT. 10099.000 SIGM. TDTP 15.746 TPHI.TDTP 39.923 SBHF. TDTP SBPZN. TDTP 40.211 SIGC. TDTP 2.080 SIBH. TDTP 40.211 TRAT. TDTP SDSI.TDTP 0.174 BACK. TDTP 242.067 FBAC. TDTP 45.471 TCAN. TDTP TCAF. TDTP 25561.855 TCND. TDTP 31503.223 TCFD.TDTP 10227.264 TSCN. TDTP TSCF. TDTP 5259.056 INND. TDTP 1934.624 INFD. TDTP 317.581 GRCH. TDTP TENS.TDTP 76.000 CCL. TDTP -0.102 34.675 1.890 47578.484 9586.313 -999.250 30.655 2.160 68526.297 14098.490 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 29 **** FILE HEADER **** FILE NA~IE : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NERVJBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SO!V~VARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11226.0 10090.0 TDTP 11240.0 10090.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11221.0 11217.5 11216.0 11214.0 11212.5 11202.0 11197.5 11191.0 11185.0 11184.0 11166.0 11165.0 11162.0 11159.0 11138.5 11133.0 11113.5 11093.5 11080.5 11067.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88889.0 88887.5 11220.5 11218.5 11215.5 11213.5 11212.5 11201.5 11197.5 11192.0 11191.0 11184.5 11182.5 11167.0 11165.0 11163.0 11160.5 11138.5 11133.0 11113.5 11093.5 11080.5 11067.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 30 11063.0 11050.0 11049.0 11041.0 11037.0 11034.0 11032.0 11019.5 11015.0 11014.0 11003.0 10997.0 10991.0 10990.5 10981.5 10979.0 10978.5 10972.0 10969.5 10965.5 10960.5 10960.0 10954.5 10952.5 10947.5 10945.0 10942.0 10941.0 10938.5 10934.5 10927.0 10904.0 10895 5 10887 5 10884 0 10874 0 10872 5 10824 0 10818 5 10801 5 10793 0 10789 5 10784 0 10778 5 10777 5 10769 0 10768.0 10761.5 10757.5 10755.5 10749.0 10743.0 10729.5 10728.0 10725.0 11049.5 11033.0 11014.5 10995.5 10991.5 10978.0 10970.5 10961.5 10955.5 10944.5 10941.5 10938.5 10894.0 10885.5 10870.0 10819.0 10801.5 10794.0 10785.0 10777.0 10768.5 10756.0 10728.5 11062.0 11049.0 11040.5 11037.0 11030.5 11018.5 11012.5 11002.0 10988.5 10978.0 10976.0 10970.0 10963.0 10958.0 10950.5 10945.0 10938.5 10931.5 10924.0 10901.5 10882.5 10870.5 10824.0 10794.0 10789.5 10777.0 10768.0 10761.0 10756.5 10748.5 10742.0 10728.0 10724.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 31 10716.0 10708.0 10705.0 10702.0 10691.5 10688.0 10684.5 10677.0 10675.5 10673.5 10669.5 10667.0 10660.0 10659.0 10655.5 10626.0 10613.0 10593 5 10588 0 10573 0 10567 0 10565 0 10560 5 10549 0 10536 0 10534 0 10524 5 10524 0 10519 5 10516 5 10512.5 10509.5 10508.5 10507.5 10495.5 10483.0 10482.5 10475.0 10474.0 10462.5 10454.5 10448.5 10442.5 10441.0 10434.5 10427.5 10423.0 10409.5 10407.5 10407.0 10404.0 10401.0 10398.0 10394.0 10390.0 10702.0 10684.5 10675.0 10660.5 10656.0 10587.0 10564.5 10533.0 10522.0 10511.0 10506.5 10495.0 10482.5 10474.0 10460.5 10442.0 10426.0 10406.0 10392.0 10715.5 10707.0 10704.0 10691.5 10687.5 10677.0 10673.0 10670.5 10666.5 10658.5 10625.5 10612.5 10593.5 10572.5 10565.5 10560.0 10549.0 10535.5 10522.5 10518.5 10516.0 10509.5 10507.0 10482.0 10474.5 10454.5 10448.0 10441.5 10434.5 10421.5 10407.0 10406.0 10403.0 10400.0 10397.0 10389.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 32 10384.5 10383.5 10378.5 10377.0 10370.5 10369.0 10366.0 10364.5 10355.0 10351.5 10351 . 0 10350.0 10348.5 10346.0 10342.5 10340.5 10342.0 10341.5 10327.0 10324.0 10315.0 10313.0 10311.5 10309.0 10308.0 10306.5 10306.0 10303.5 10301 . 5 10299.0 10291 . 0 10288.5 10286.0 10283.5 10274.0 10270.0 10234.0 10231.5 10233.5 10232.0 10230.0 10229.0 10229.5 10227.0 10227.5 10226.0 10226.5 10225.0 10220.0 10216.0 10212.5 10210.5 10210.5 10197.5 10195.5 10196.0 10194.0 10138.0 10137.0 100.0 99.0 98.0 $ RE~i~gKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASE PASS #1 GRCH; AND BORAX PASS #3 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 33 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SIGMTDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SBt~N TDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1185490 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11239.500 SIGM. TDTP 18.751 TPHI.TDTP 32.442 SBHF. TDTP SBHN. TDTP 46.337 SIGC. TDTP 1.508 SIBH. TDTP 53.171 TRAT. TDTP SDSI.TDTP 0.248 BACK. TDTP 266.698 FBAC. TDTP 81.589 TCAN. TDTP TCAF. TDTP 18241.469 TCND.TDTP 27415.590 TCFD. TDTP 9060.174 TSCN. TDTP TSCF. TDTP 3702.448 INND. TDTP 2223.812 INFD.TDTP 357.465 GRCH. TDTP TENS.TDTP 75.000 CCL. TDTP -0.102 35.206 1.868 45307.422 9187.646 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 34 DEPT. 10088 SBHN. TDTP 37 SDSI. TDTP 0 TCAF. TDTP 24522 TSCF. TDTP 5032 TENS. TDTP 76 000 SIGM. TDTP 16.130 TPHI.TDTP 41.053 SBHF. TDTP 915 SIGC. TDTP 2. 081 SIBH. TDTP 37. 915 TRAT. TDTP 260 BACK. TDTP 245. 501 FBAC. TDTP 42. 534 TCAN. TDTP 492 TCND. TDTP 30858. 531 TCFD. TDTP 9855. 039 TSCN. TDTP 847 INND. TDTP 1789. 624 INFD. TDTP 312. 122 GRCH. TDTP 000 CCL. TDTP -O. 102 25.438 2.175 66163.953 13579.086 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP THE ARITHMETIC AVERAGE OF THE THREE BASE PASSES WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SBttNPNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1185490 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 36 ** DATA ** DEPT. 11239.000 SIGM. PNAV 18.938 TPHI.PNAV 30.672 SBHF. PNAV 33.141 SBHN. PNAV 42.826 SIGC. PNAV 2.370 SIBH.PNAV 44.817 TRAT. PNAV 1.814 SDSI.PNAV 0.292 BACK. TDTP 87.341 FBAC. TDTP 27.452 TCAN. PNAV 47026.719 TCAF. PNAV 19771.305 TCND.PNAV 28605.633 TCFD.PNAV 10030.078 TSCN. PNAV 9909.281 TSCF. PNAV 4165.034 INND.PNAV 852.595 INFD.PNAV 371.686 GRCH. TDTP -999.250 DEPT. 9317.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHlV. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 240.065 FBAC. TDTP 41.360 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 17.238 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11249.50 9302.50 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 37 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): 14-JAN-98 8C0-609 1900 14-JAN-98 11730.0 11250.0 9350.0 11243.0 1800.O NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ATTB GA~IA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... ATT-B TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 11766.0 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): DEPTH CORRELATED TO SPERRY-SUN NGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM 3 Static logging passes made (displaced ~/ crude) from 9350' to 11200' LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 38 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST S~Y: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=O~ CHOKE: 60, STIP=2100 psi THIS FILE CONTAINS THE RAW TDTP DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS1 CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SBP~NPS1 CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PSi CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PSi 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PSi CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 39 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) TCANPS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TCAFPS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TCFDPS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 1185490 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11249.500 SIGM. PS1 -999.250 TPHI.PS1 -999.250 SBHF. PS1 SBHN. PS1 -999.250 SIGC. PS1 -999.250 SIBH. PS1 -999.250 TRAT. PSi SDSI.PS1 -999.250 BACK. PSI -999.250 FBAC. PS1 -999.250 TCAN. PS1 TCAF. PS1 -999.250 TCND.PS1 -999.250 TCFD. PS1 -999.250 TSCN. PS1 TSCF. PS1 -999.250 INND. PS1 -999.250 INFD.PS1 -999.250 TENS.PSi GR.PS1 88.000 CCL.PS1 0.000 DEPT. 9302.500 SIGM. PS1 19.736 TPHI.PS1 27.860 SBHF. PS1 SBHN. PS1 42.072 SIGC. PS1 1.699 SIBH. PS1 42.933 TRAT. PS1 SDSI.PS1 0.230 BACK. PSi 238.762 FBAC. PS1 41.359 TCAN. PS1 TCAF. PS1 16253.027 TCND.PS1 22784.258 TCFD.PS1 6915.983 TSCN. PS1 TSCF. PS1 2637.237 INND.PS1 907.127 INFD. PS1 253.143 TENS.PSi GR.PS1 18.233 CCL.PS1 -999.250 -999.250 -999.250 -999.250 -999.250 79.000 33.277 1.719 41364.758 5987.650 78.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 40 **** FILE H~ER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVTgMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11248.50 9304.00 TDTP LOG HEADER DATA DATE LOGGED: 14-JAN-98 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1900 14-JAN-98 TD DRILLER (FT) : 11730.0 TD LOGGER (FT) : 11250.0 TOP LOG INTERVAL (FT) '. 9350.0 BOTTOM LOG INTERVAL (FT): 11243.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ATTB GA~k~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER ATT-B TDT- P 8.000 11766.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 41 FLUID RATE AT WELLH~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY-SUN NGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM 3 Static logging passes made (displaced w~ crude) from 9350' to 11200' 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST SUA~IARY: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=O¢ CHOKE: 60, STIP=2100 psi THIS FILE CONTAINS THE RAW TDTP DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 42 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SBPZNPS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TCAFPS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 1185490 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 11248.500 SIGM. PS2 SBHN. PS2 -999.250 SIGC. PS2 SDSI.PS2 -999.250 BACK. PS2 TCAF. PS2 -999.250 TCND.PS2 TSCF. PS2 -999.250 INND.PS2 GR.PS2 0.000 CCL.PS2 -999 250 -999 250 -999 250 -999 250 -999 250 -0 232 TPHI.PS2 -999.250 SBHF. PS2 SIBH. PS2 -999.250 TRAT. PS2 FBAC. PS2 -999.250 TCAN. PS2 TCFD. PS2 -999.250 TSCN. PS2 INFD.PS2 -999.250 TENS. PS2 -999.250 -999.250 -999.250 -999.250 77.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 43 DEPT. SBPZN. PS2 SDSI.PS2 TCAF. PS2 TSCF. PS2 GR.PS2 9304 000 42 279 0 234 15819 748 2594 375 30 210 SIGM. PS2 SIGC. PS2 BACK. PS2 TCND.PS2 INND. PS2 CCL.PS2 19.496 TPHI.PS2 1.655 SIBH. PS2 266.589 FBAC. PS2 22511.543 TCFD.PS2 886.364 INFD.PS2 -999.250 29.092 SBHF. PS2 43.457 TRAT. PS2 48.878 TCAN. PS2 6757.584 TSCN. PS2 261.245 TENS.PS2 32.250 1.758 40978.289 5988.343 79.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~ffrn~RY VENDOR TOOL CODE START DEPTH ........................... TDTP 11248.50 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH .......... 9273.50 14-JAN-98 8C0-609 1900 14-JAN-98 11730.0 11250.0 9350.0 11243.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 44 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... ATTB GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... ATT-B TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 11766.0 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY-SUNNGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM 3 Static logging passes made (displaced w~ crude) from 9350' to 11200' 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST SUMMARY: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=0% CHOKE: 60, STIP=2100 psi LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PA GE: 45 THIS FILE CONTAINS THE RAW TDTP DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 46 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) INFD PS3 CPS 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 1185490 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11248.500 SIGM. PS3 -999.250 TPHI.PS3 -999.250 SBHF. PS3 SBP~N. PS3 -999.250 SIGC. PS3 -999.250 SIBH. PS3 -999.250 TRAT. PS3 SDSI.PS3 -999.250 BACK. PS3 -999.250 FBAC. PS3 -999.250 TCAN. PS3 TCAF. PS3 -999.250 TCND.PS3 -999.250 TCFD. PS3 -999.250 TSCN. PS3 TSCF.PS3 -999.250 INND.PS3 -999.250 INFD. PS3 -999.250 TENS. PS3 GR.PS3 428.718 CCL.PS3 -0.194 DEPT. 9273.500 SIGM. PS3 16.529 TPHI.PS3 27.095 SBHF. PS3 SBHIV. PS3 46.085 SIGC. PS3 0.594 SIBH. PS3 51.579 TRAT. PS3 SDSI.PS3 0.212 BACK. PS3 295.047 FBAC. PS3 53.343 TCAN. PS3 TCAF. PS3 13677.293 TCND.PS3 22599.156 TCFD.PS3 6961.640 TSCN. PS3 TSCF. PS3 2846.754 INND. PS3 921.134 INFD.PS3 261.894 TENS. PS3 GR.PS3 16.419 CCL.PS3 -999.250 -999.250 -999.250 -999.250 -999.250 78.000 45.735 1.780 31628.055 6582.978 78.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 47 FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUM~ER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y VE1VDOR TOOL CODE START DEPTH STOP DEPTH ..................... 11250.50 10062.00 LOG HEADER DATA DATE LOGGED: 14-JAN-98 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1900 14-JAN-98 TD DRILLER (FT) : 11730.0 TD LOGGER (FT) : 11250.0 TOP LOG INTERVAL (FT) : 9350.0 BOTTOM LOG INTERVAL (FT): 11243.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ATTB GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)'. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 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): TOOL NUMBER ........... ATT-B TDT- P 8.000 11766.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 BLUELIArE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 48 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY-SUNNGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM 3 Static logging passes made (displaced w~ crude) from 9350' to 11200' 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST SUA~IARY: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=O% CHOKE: 60, STIP=2100 psi THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 5-JUN-1998 15:44 PAGE: 49 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX1 PU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SBPZNBX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH BX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX1 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX1 CU 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 BACK BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TCANBX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TCNDBX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TCFDBX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 INNDBXi CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 INFD BX1 CPS 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX1 LB 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX1 GAPI 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 CCL BX1 V 1185490 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 11250.500 SIGM. BX1 -999.250 TPHI.BX1 -999.250 SBHF. BX1 -999.250 SBHN. BX1 -999.250 SIGC.BX1 -999.250 SIBH. BX1 -999.250 TRAT. BX1 -999.250 SDSI.BX1 -999.250 BACK.BX1 -999.250 FBAC.BX1 -999.250 TCAN. BX1 -999.250 TCAF.BX1 -999.250 TCND.BX1 -999.250 TCFD.BX1 -999.250 TSCN. BX1 -999.250 TSCF. BX1 -999.250 INND.BX1 -999.250 INFD.BX1 -999.250 TENS.BX1 75.000 GR.BX1 428.718 CCL.BX1 -0.137 DEPT. 10061.500 SIGM. BX1 16.872 TPHI.BX1 39.575 SBHF. BX1 23.387 SBHN. BX1 40.623 SIGC.BX1 1.892 SIBH. BX1 40.623 TRAT. BX1 2.111 SDSI.BX1 0.197 BACK. BX1 216.038 FBAC.BX1 36.426 TCAN. BX1 59748.492 TCAF. BX1 22421.141 TCND.BX1 29599.398 TCFD.BX1 9491.982 TSCN. BX1 12187.363 TSCF. BX1 4573.414 INND.BX1 1933.779 INFD.BX1 290.167 TENS.BX1 76.000 GR.BX1 24.648 CCL.BX1 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 5O **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VE1VDOR TOOL CODE START DEPTH STOP DEPTH 11252.50 10082.50 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ATTB GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 14-JAN-98 8C0-609 1900 14-JAN-98 11730.0 11250.0 9350.0 11243.0 1800.0 NO TOOL NUMBER ........... ATT-B TDT- P 8. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 51 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) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11766.0 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY-SUN NGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM 3 Static logging passes made (displaced w~ crude) from 9350' to 11200' 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST SUAff4ARY: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=O¢ CHOKE: 60, STIP=2100 psi THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 52 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX2 PU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNBX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX2 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX2 CU 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN BX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX2 CPS 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX2 LB 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX2 GAPI 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX2 V 1185490 O0 000 O0 0 12 1 1 4 68 0000000000 ....................................................................................... LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 53 ** DATA ** DEPT. 11252.500 SIGM. BX2 SBH1V. BX2 -999.250 SIGC. BX2 SDSI.BX2 -999.250 BACK. BX2 TCAF.BX2 -999.250 TCND.BX2 TSCF.BX2 -999.250 INND.BX2 GR.BX2 85.744 CCL.BX2 DEPT. 10082.000 SIGM. BX2 SBPZN. BX2 37.307 SIGC. BX2 SDSI.BX2 0.259 BACK. BX2 TCAF. BX2 24957.402 TCND.BX2 TSCF.BX2 5129.265 INND.BX2 GR.BX2 33.187 CCL.BX2 -999.250 TPHI.BX2 -999.250 SIBH. BX2 -999.250 FBAC.BX2 -999.250 TCFD.BX2 -999.250 INFD.BX2 -0.258 15 056 2 978 239 224 31293 031 1909 739 -999 250 TPHI.BX2 SIBH.BX2 FBAC. BX2 TCFD.BX2 INFD.BX2 -999.250 SBHF. BX2 -999.250 TRAT. BX2 -999.250 TCAN. BX2 -999.250 TSCN. BX2 -999.250 TENS.BX2 40.656 SBHF. BX2 37.307 TRAT. BX2 43.826 TCAN. BX2 9931.867 TSCN. BX2 322.722 TENS.BX2 -999.250 -999.250 -999.250 -999.250 75.000 27.076 2.204 67883.719 13951.512 75.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 012 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E '. EDIT .013 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUU~iBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11252.50 10072.50 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 54 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 14-JAN-98 8C0-609 1900 14-JAN-98 11730.0 11250.0 9350.0 11243.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ATTB GA~ff4A RAY TDTP THERMAL DECAY $ TOOL NUMBER ATT-B TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 11766.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATTIRE (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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO SPERRY-SUN NGP (21 MAR 97) LOGGED FROM DS CTU #1; ALL TDT PASSES LOGGED @30 FPM LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 55 3 Static logging passes made (displaced w~ crude) from 9350' to 11200' 3 passes made from 10100' to 11200' while pumping Borax (100,130, & 160 BBLS BORAX DISPLACED). Perferation Intervals: 1025' - 10350', 10450' - 10750', 10830' - 11150'. WELL TEST SUMMARY: OIL RATE=1201 bopd, GOR=13791 scf/stb, WC=0% CHOKE: 60, STIP=2100 psi THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - C~ ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX3 PU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SBPiNBX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT BX3 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX3 CU 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 56 NAME SERV UNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) BACK BX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC BX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDBX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TCFDBX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 INFD BX3 CPS 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX3 LB 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX3 GAPI 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX3 V 1185490 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 11252.500 SIGM. BX3 -999.250 TPHI.BX3 -999.250 SBHF. BX3 -999.250 SBHN. BX3 -999.250 SIGC. BX3 -999.250 SIBH.BX3 -999.250 TRAT. BX3 -999.250 SDSI.BX3 -999.250 BACK. BX3 -999.250 FBAC.BX3 -999.250 TCAN. BX3 -999.250 TCAF.BX3 -999.250 TCND.BX3 -999.250 TCFD.BX3 -999.250 TSCN. BX3 -999.250 TSCF. BX3 -999.250 INND.BX3 -999.250 INFD.BX3 -999.250 TENS.BX3 78.000 GR.BX3 616.000 CCL.BX3 -0.204 DEPT. 10072.000 SIGM. BX3 16.490 TPHI.BX3 41.654 SBHF. BX3 26.414 SBHN. BX3 40.539 SIGC.BX3 2.012 SIBH. BX3 40.539 TRAT. BX3 2.177 SDSI.BX3 0.187 BACK.BX3 255.331 FBAC.BX3 41.243 TCAN. BX3 60307.516 TCAF. BX3 22055.043 TCND.BX3 29285.785 TCFD.BX3 9226.057 TSCN. BX3 12379.250 TSCF. BX3 4527.212 INND.BX3 1770.907 INFD.BX3 298.254 TENS.BX3 75.000 GR.BX3 29.594 CCL.BX3 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE . FLIC VERSION . O01CO1 DATE . 98/06/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JUN-1998 15:44 PAGE: 57 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/ 5 ORIGIN : FLIC TAPE NAME : 98233 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/ 5 ORIGIN · FLIC REEL NAME : 98233 CONTINUATION # : PREVIOUS REEL : CO~T~T : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... ..RECEIVED AUG 2 2 1997 A~a Oil & Gas Con& C4)mtl)~t~ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 2-4A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292006401 REFERENCE NO : 97314 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE '. **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC REEL NA~E : 97314 CONTINUATION # : PREVIOUS REEL : COf~4~2~T : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 **** TAPE HEADER **** SERVICE NA~iE : EDIT DATE : 97/08/19 ORIGIN : FLIC TAPE NA~E : 97314 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 2 - 4 API NUMBER: 5002920064 O1 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-AUG-97 JOB NUMBER: 97314 LOGGING ENGINEER: G. ELMORE OPERATOR WITNESS: D. CISMOSKI SURFACE LOCATION SECTION: 36 TOWNSHIP: 1 iN RANGE: 14E FNL : 1064 FSL : FEL: FWL : 177 ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: GROUND LEVEL: 30.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 8578.0 47. O0 2ND STRING 5. 500 8615.0 17. O0 3RD STRING 2. 875 11766.0 6.50 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(~iEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 24-SEP-96 LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 9634.0 9625.0 9610.0 9606.0 9602.5 9592.0 9589.5 9569.0 9561.5 9550.0 9541 0 9538 5 9535 5 9527 5 9515 5 9508 0 9498.0 9494.5 9492.5 9487.5 9474.0 9451.0 9447.5 9438.5 9434.0 9430.5 9414.0 9403 5 9382 0 9377 0 9375 5 9374 0 9369 5 9360.5 9358.5 9355.5 9337.0 9328.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88887.0 9633.0 9624.5 9609.0 9604.5 9600.0 9589.5 9587.0 9566.5 9560.0 9547.5 9538.5 9536.5 9533 5 9525 0 9513 5 9505 5 9495 5 9492 5 9490 0 9485 5 9472.0 9449.5 9446.0 943 6.0 9431.5 9428.5 9412.0 9400.5 9380.0 9375.0 93 73.5 9372.0 9367.5 9358.5 9356.0 9352.5 9333.5 9324.5 96.5 TDTP 88887.0 9633.0 9624.5 9609.0 9604.5 9600.0 9589.5 9587.0 9566.5 9560.0 9547.5 9538.5 953 6.5 9533.5 9525.0 9513.5 9505.5 9495.5 9492.5 9490.0 9485.5 9472.0 9449.5 9446.0 9436.0 9431.5 9428.5 9412.0 9400.5 9380.0 9375.0 9373.5 9372.0 93 67.5 9358.5 9356.0 9352.5 9333.5 9324.5 96.5 REMARKS: CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON ARCO ALASKA, INC. WELLD.S. 02-04A. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #1 GRCH TO GR .MWD; AND PASS PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 SIGM TO GR.MWD. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE hI]RiBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCRE~fENT: O. 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9636.0 9218.0 TDTP 9648.0 9218.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NU~4BER : BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS TDTP PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 4 ** 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 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER~ ~ LOG TYPE CLASS MOD ATU?~B SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 1 1 1 4 SIGM TDTP CU 500728 O0 000 O0 0 1 1 1 4 TPHI TDTP PU-S 500728 O0 000 O0 0 1 1 1 4 SBHF TDTP CU 500728 O0 000 O0 0 1 1 1 4 SBHN TDTP CU 500728 O0 000 O0 0 1 1 1 4 SIGC TDTP CU 500728 O0 000 O0 0 1 1 1 4 SIBH TDTP CU 500728 O0 000 O0 0 1 1 1 4 TRAT TDTP 500728 O0 000 O0 0 1 1 1 4 SDSI TDTP CU 500728 O0 000 O0 0 1 1 1 4 BACK TDTP CPS 500728 O0 000 O0 0 1 1 1 4 FBAC TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TCAN TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TCAF TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TCND TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TCFD TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TSCN TDTP CPS 500728 O0 000 O0 0 1 1 1 4 TSCF TDTP CPS 500728 O0 000 O0 0 1 1 1 4 INND TDTP CPS 500728 O0 000 O0 0 1 1 1 4 INFD TDTP CPS 500728 O0 000 O0 0 1 1 1 4 GRCH TDTP GAPI 500728 O0 000 O0 0 1 1 1 4 TENS TDTP LB 500728 O0 000 O0 0 1 1 1 4 CCL TDTP V 500728 O0 000 O0 0 1 1 1 4 GR MWD GAPI 500728 O0 000 O0 0 1 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 9700 000 -999 250 -999 250 -999 250 -999 250 -999 250 9214 500 47 084 0 273 7621 648 1545 248 1305 000 SIGM. TDTP -999. 250 TPHI. TDTP SIGC. TDTP -999. 250 SIBH. TDTP BACK. TDTP - 999. 250 FBAC. TDTP TCND. TDTP -999. 250 TCFD. TDTP INND. TDTP -999. 250 INFD. TDTP CCL. TDTP -999.250 GR.MWD SIGM. SIGC. BACK. TCND . INND. CCL . TDTP 10. 519 TPHI. TDTP TDTP i. 537 SIBH. TDTP TDTP 46. 764 FBAC. TDTP TDTP 8922. 422 TCFD. TDTP TDTP 547. 794 INFD. TDTP TDTP O . 000 GR. MWD -999. 250 SBHF. TDTP - 999. 250 TRAT. TDTP -999. 250 TCAN. TDTP - 999. 250 TSCN. TDTP - 999. 250 GRCH. TDTP 51. 970 12.480 SBHF. TDTP 80.805 TRAT. TDTP 8.039 TCAN. TDTP 3389.802 TSCN. TDTP 109.409 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 28.886 1.440 13659.865 2769.463 17.344 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE · 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' 0 O1 CO1 DATE · 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH ......................... GRCH 9636.0 TDTP 9648.0 STOP DEPTH .......... 9218.0 9218.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MF~AS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS 1TUFiBER : 1 BASELINE DEPTH 88888.0 9643.0 9634.0 9623.5 9615.0 9606.0 9598.0 9592.5 9592.0 9590.5 9589.5 9588.0 9579.0 9561.5 9555.0 9551.0 9547.5 9542.5 9542.0 9540. 5 9538.5 9536.0 9531.5 9530.0 9526.5 9523.0 9519.5 9515.5 9508.0 9504.5 9498.0 9497.0 9493.0 9492.5 9452.0 9448.5 9441.0 9438 0 9437 5 9433 5 9431 5 9430 0 9415 5 9413.5 9403.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88886.0 88886.0 9632.0 9623.0 9615.5 9604.5 9589.5 9587.0 9585.5 9560.0 9549.5 9540.0 9538.5 9536.5 9527.5 9520.5 9517.0 9514.0 9505.5 9495.5 9490.0 9449.5 9439.5 9436.0 9431.5 9428.5 9412.0 9400.5 9641.0 9595.5 9590.0 9587.5 9576.5 9560.0 9553.5 9545.0 9539.5 9534.5 9530.0 9525.0 9523.0 9502.0 9495.5 9492.5 9446.5 9435.0 9430.0 9412.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 9396.5 9376.5 9374.5 9373.5 9358 5 9346 5 9330 0 9323 0 9322 5 9312 5 9308 5 9305 5 92975 9254.5 9252.0 9246.0 9235.0 9229.0 100.0 9375.0 9372.0 9356.5 9343.5 9319.5 9295.5 9251.5 9248.5 96.5 9394.0 9373.0 9325.5 9319.5 9309.5 9305.5 9302.0 9243.0 9231.5 9226.5 97.5 REMARKS: THIS FILE CONTAINS TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FOP3~AT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 8 ** SET TYPE - CHAN ** NAi~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELECt CODE (HEX) DEPT FT 500728 O0 000 O0 0 2 1 1 4 SIGM TDTP CU 500728 O0 000 O0 0 2 1 1 4 TPHI TDTP PU-S 500728 O0 000 O0 0 2 1 1 4 SBHF TDTP CU 500728 O0 000 O0 0 2 1 1 4 SBHN TDTP CU 500728 O0 000 O0 0 2 1 1 4 SIGC TDTP CU 500728 O0 000 O0 0 2 1 1 4 SIBH TDTP CU 500728 O0 000 O0 0 2 1 1 4 TRAT TDTP 500728 O0 000 O0 0 2 1 1 4 SDSI TDTP CU 500728 O0 000 O0 0 2 1 1 4 BACK TDTP CPS 500728 O0 000 O0 0 2 1 1 4 FBAC TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TCAN TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TCAF TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TCND TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TCFD TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TSCN TDTP CPS 500728 O0 000 O0 0 2 1 1 4 TSCF TDTP CPS 500728 O0 000 O0 0 2 1 1 4 INND TDTP CPS 500728 O0 000 O0 0 2 1 1 4 INFD TDTP CPS 500728 O0 000 O0 0 2 1 1 4 GRCH TDTP GAPI 500728 O0 000 O0 0 2 1 1 4 TENS TDTP LB 500728 O0 000 O0 0 2 1 1 4 CCL TDTP V 500728 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9646. 000 SIGM. TDTP 1 6. 902 TPHI. TDTP 31 . 955 SBHF. TDTP 26. 604 SBHN. TDTP 43. 026 SIGC. TDTP O. 909 SIBH. TDTP 87. 044 TRAT. TDTP 2. 032 SDSI. TDTP 0. 488 BACK. TDTP 53. 222 FBAC. TDTP 1 6. 567 TCAN. TDTP 16576. 480 TCAF. TDTP 6202.132 TCND. TDTP 9434. 096 TCFD. TDTP 2959. 443 TSCN. TDTP 3359. 972 TSCF. TDTP 1257. 142 INND. TDTP 537. 034 INFD. TDTP 102 . 539 GRCH. TDTP -999. 250 TENS. TDTP 1305. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 002 SERVICE · FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9636.0 9190.0 TDTP 9648.0 9190.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 9634 0 9623 5 9610 0 9605 0 9592 0 9589 5 9586.5 9579.0 9568.5 9561.5 9561.0 9558.0 9555.0 9551.0 9548.0 9546.5 9541.0 9540.5 9538.0 953 6.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887 9633 9623 9611 0 9604 5 9589 5 9585.0 9560.0 9548.0 9544.5 9538.5 9536.5 0 88887.0 0 9633.0 0 9590.0 9587.5 9576.5 9566.0 9560.0 9557.0 9553.5 9546.0 9539.0 9534.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 10 9534.5 9533.5 9531.5 9529.0 9524.5 9525.0 9524.0 9522.5 9520.0 9521.0 9516.0 9514.5 9515.0 9514.0 9507.0 9505.5 9497.5 9495.5 9497.0 9495.5 9495.0 9493.5 9494.0 9492.0 9492.0 9490.0 9487.5 9485.5 9485.5 9451.5 9449.5 9448.0 9446.0 9447.5 9446.5 9438.0 9436.0 9437.0 9435.0 9434.5 9432.5 9433.0 9431.5 9431.0 9430.0 9430.0 9428.5 9418.0 9417.0 9413.0 9412.0 9399.5 9397.0 9396.0 9394.0 9376.0 9375.0 9374.5 9373.0 9373.5 9373.0 9373.0 9371.5 9367.0 9364.5 9353.0 9352.5 9323.0 9319.5 9313.5 9310.0 9308.0 9306.0 9296.5 9295.0 9277.5 9276.5 9240.0 9239.5 9237.5 9235.5 9234.0 9232.5 100.0 98.5 98.0 $ REMARKS: THIS FILE CONTAINS TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 SIGM TO PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB ;FUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOY,IB SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 500728 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 500728 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 500728 O0 000 O0 0 3 7_ 1 4 68 0000000000 TSCF TDTP CPS 500728 O0 000 O0 0 3 7_ 1 4 68 0000000000 INArD TDTP CPS 500728 O0 000 O0 0 3 i 1 4 68 0000000000 INFD TDTP CPS 500728 O0 000 O0 0 3 ! 1 4 68 0000000000 GRCH TDTP GAPI 500728 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 500728 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 500728 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 12 ** DATA ** DEPT. 9647.000 SIGM. TDTP 17.139 TPHI.TDTP SBHN. TDTP 42.897 SIGC. TDTP 1.385 SIBH. TDTP SDSI. TDTP 0.689 BACK. TDTP 77.317 FBAC. TDTP TCAF. TDTP 5178.615 TCND. TDTP 8589.666 TCFD.TDTP TSCF. TDTP 1048.119 INND. TDTP 537.255 INFD. TDTP TENS. TDTP 1280.000 CCL.TDTP 0.000 DEPT. 9188.000 SIGM. TDTP SBPiN. TDTP 116.918 SIGC. TDTP SDSI.TDTP 2.325 BACK. TDTP TCAF. TDTP 0.000 TCND. TDTP TSCF. TDTP 0.000 INND. TDTP TENS. TDTP 1265.000 CCL.TDTP 14.256 TPHI.TDTP 0.375 SIBH. TDTP 7.361 FBAC. TDTP -999.250 TCFD.TDTP -0.250 INFD. TDTP 0.000 31 . 486 SBHF. TDTP 85. 530 TRAT. TDTP 23. 743 TCAN. TDTP 2620. 585 TSCN. TDTP 93. 314 GRCH. TDTP O. 000 SBHF. TDTP 191. 665 TRAT. TDTP 2. 629 TCAN. TDTP -999. 250 TSCN. TDTP -O. 089 GRCH. TDTP 32.433 2.006 14059.426 2845.539 -999.250 153.626 0.000 0.000 0.000 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION . O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVUM~ER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gam~a Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 13 RENARKS: THE ARITHFIETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 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 NU~IB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 500728 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 500728 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 500728 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 500728 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 500728 O0 000 O0 0 4 1 ! 4 68 0000000000 TRAT PNAV 500728 O0 000 O0 0 4 1 ! 4 68 0000000000 SDSI PNAV CU 500728 O0 000 O0 0 4 ! ! 4 68 0000000000 BACK TDTP CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 14 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) INND PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 500728 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 500728 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9647.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV SBP~N. PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV SDSI.PNAV -999.250 BACK. TDTP 22.463 FBAC. TDTP 12.103 TCAN. PNAV TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP DEPT. 9214.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV SBPiN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV SDSI.PNAV -999.250 BACK. TDTP 46.764 FBAC. TDTP 8.039 TCAN. PNAV TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 17.344 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 97/08/19 ~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 15 PASS NUFIBER : 1 DEPTH INCREMFIVT: 0.5000 FILE SERV~4ARY VENDOR TOOL CODE START DEPTH TDTP 9676.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlV2~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~T4PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL STOP DEPTH 9197.5 2-MAY-97 CP 42.2 1144 2-MAY-97 11730.0 0.0 9250.0 9650.0 1800.0 NO TOOL NUMBER ........... CGRH 788 TDI C 11766.0 CRUDE 8.60 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SA&IDS TONE 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 16 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 N~ COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 12/21/76 ESTIMATED GOC 9354' GAS UNDERRUNFROM 9380' - 9396' ALL LOGGING PASSES LOGGED AT 1800 FPH. PUMP RATE DURING PASSES: 1 BBL/MIN. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 88 1 0.5 FT 11 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAi',IE SERV UNIT SERVICE API API API API FILE NUMB NU?4B SIZE REPR PROCESS iD ORDER # LOG TYPE CLASS MOD ~VUMB SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 500728 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 17 NAME SERVUNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TRAT PS1 500728 O0 SDSI PS1 CU 500728 O0 BACK PS1 CPS 500728 O0 FBAC PS1 CPS 500728 O0 TCANPS1 CPS 500728 O0 TCAFPS1 CPS 500728 O0 TCND PSl CPS 500728 O0 TCFD PS1 CPS 500728 O0 TSCN PS1 CPS 500728 O0 TSCF PS1 CPS 500728 O0 INND PSi CPS 500728 O0 INFD PS1 CPS 500728 O0 TENS PS1 LB 500728 O0 GR PS1 GAPI 500728 O0 CCL PS1 V 500728 O0 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9676.500 SIGM. PS1 SBHN. PS1 124.351 SIGC. PS1 SDSI.PS1 2.644 BACK. PSi TCAF. PS1 0.000 TCND.PS1 TSCF. PS! 0.000 INND.PS1 GR.PSi 12.648 CCL.PS1 DEPT. 9197.500 SIGM. PS1 SBHN. PS1 46.845 SIGC. PS1 SDSI.PS1 0.293 BACK. PSi TCAF. PS1 7528.705 TCND.PS1 TSCF. PS! 1525.577 INND.PS1 GR.PS1 18.625 CCL.PS1 40.207 TPHI.PS1 0,000 SBHF. PS1 0.000 SIBH. PS1 205.608 TRAT. PS1 34.959 FBAC. PS1 34.222 TCAN. PS1 -419.736 TCFD.PS1 -381.449 TSCN. PS1 -1.188 INFD.PS1 -1.163 TE~JS.PS1 0.026 65.824 0.000 0.000 0.000 1445.000 9.462 TPHI.PS1 9,854 SBHF. PS1 45.129 1,868 SIBH. PS1 74.481 TRAT. PS1 1.326 42.609 FBAC. PS1 2.629 TCAN. PS1 12492.613 8265.719 TCFD. PS1 3333.496 TSCN. PS1 2531.437 567.415 INFD.PS1 124.595 TENS.PSi 1305.000 0,000 ** END OF DATA ** **** FILE TRAILER **** FILE ~=~,]E : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUR~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9684.5 9197.5 TDTP $ LOG HEADER DATA DATE LOGGED: SOFT~';ARE 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 G~ RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 2-MAY-97 CP 42.2 1144 2-MAY-97 11730.0 0.0 9250.0 9650.0 1800.0 NO TOOL NUMBER CGRH 788 TDIC 11766.0 CRUDE 8.60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 19 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 12/21/76 ESTIMATED GOC 9354' GAS UArDERRUN FROM 9380' - 9396' ALL LOGGING PASSES LOGGED AT 1800 FPH. PU~_¢P RATE DURING PASSES: 1 BBL/MIN. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #2. $ LIS FOP~T DATA ** DATA FOR2r~AT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 ~ 66 1 5 66 ~ 73 7 65 8 68 0.5 9 65 FT 1! 66 i1 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 2O TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SBh2VPS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 500728 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 500728 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 500728 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 500728 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 500728 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 500728 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9684.500 SIGM. PS2 9.462 TPHI.PS2 9.854 SBHF. PS2 SBHN. PS2 46.845 SIGC.PS2 1.868 SIBH. PS2 74.481 TRAT. PS2 SDSI.PS2 0.293 BACK. PS2 42.609 FBAC.PS2 2.629 TCAN. PS2 TCAF. PS2 7528.705 TCND.PS2 8265.719 TCFD. PS2 3333.496 TSCN. PS2 TSCF. PS2 1525.577 INND. PS2 567.415 INFD.PS2 124.595 TENS.PS2 GR.PS2 65.313 CCL.PS2 0.030 45.229 1.326 12492.613 2531.437 1225.000 ** E~ OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 21 **** FILE TRAILER **** FILE NAFIE : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lVTJMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCRemENT: 0. 5000 # FILE SUiCVARY VENDOR TOOL CODE START DEPTH TDTP 9691.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRI~¥G (TOP TO BOTTO~_,f) VENDOR TOOL CODE TOOL TYPE GR GA2V~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 9167.5 2-MAY-97 CP 42.2 1144 2-MAY-97 11730.0 0.0 9250.0 9650.0 1800.0 NO TOOL NtS,IBER CGRH 788 TDIC LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 22 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) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 11766.0 CRUDE 8.60 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOrW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 12/21/76 ESTIMATED GOC 9354' GAS UNDERRUN FROM 9380' - 9396' ALL LOGGING PASSES LOGGED AT 1800 FPH. PUMP RATE DURING PASSES: 1 BBL/MIN. THIS FILE CONTAINS THE RAW TDTP DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FOR~IAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 -LIS Ta~-e Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 23 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 500728 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 500728 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 IArNDPS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 500728 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 500728 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 500728 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 500728 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9691.000 SIGM. PS3 10.601 TPHI.PS3 13.740 SBHF. PS3 SBt{N. PS3 49.693 SIGC. PS3 1.275 SIBH. PS3 89.162 TRAT. PS3 SDSI.PS3 0.306 BACK. PS3 66.293 FBAC. PS3 8.590 TCAN. PS3 TCAF. PS3 6978.114 TCND.PS3 8340.348 TCFD.PS3 3162.902 TSCN. PS3 TSCF. PS3 1427.018 INND. PS3 561.494 INFD. PS3 97.363 TENS.PS3 GR.PS3 111.188 CCL.PS3 0.017 10.142 1.503 13138.400 2686.791 1095.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 17:35 PAGE: 24 DEPT. 9167.500 SIGM. PS3 SBHN. PS3 123.064 SIGC. PS3 SDSI.PS3 1.910 BACK. PS3 TCAF. PS3 0.000 TCND. PS3 TSCF. PS3 0.000 INND.PS3 GR.PS3 14.023 CCL.PS3 14 640 0 251 209 664 -2363 154 -7 127 0 000 TPHI.PS3 SIBH. PS3 FBAC. PS3 TCFD. PS3 INFD.PS3 0.000 SBHF. PS3 203.193 TRAT. PS3 50.676 TCAN. PS3 -599.263 TSCN. PS3 -1.723 TENS.PS3 129.825 0.000 0.000 0.000 1265.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC TAPE NAME : 97314 CONTINUATION # : 1 PREVIOUS TAPE : CO£~qENT : ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN · FLIC REEL NA~4E : 97314 CONTINUATION # : PREVIOUS REEL : COMMENT ' ARCO ALASKA INC, D.S. 2-4A, PRUDHOE BAY, 50-029-20064-01 Sperry-Sun Drilling Services LIS Scan Utility Fri Mar 21 09:05:05 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/03/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services _.,~ PRUDHOE BAY UNIT 1~ ~~~ ~~ 7D/MAD LOGS ~// WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-60132 B. JAHN GOODRICH/KAR 02-04A 500292006401 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 21-MAR-97 MWD RUN 6 AK-MW-60132 B. JAHN GOODRICH/KAR MWD RUN 5 AK-MW- 60132 B. JAHN GOODRI CH/KAR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 7 AK-MW-60132 A. WORTHINGT GOODRICH/KAR 36 liN 14E 1064 1771 72.30 .00 GRQUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 9692.0 5.500 8615.0 3.800 4.500 8740.0 3.750 11766.0 1. ALL DEPTHS ARE-MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. THE WINDOW WAS CUT IN 9 5/8" CASING. THE TOP WAS AT 9316'MD, 8759'SSTVD. THE BOTTOM WAS AT 9321'MD, 8763'SSTVD. 4. MWD RUN 1 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). SINCE THIS RUN IS LOGGED IN THE ORIGINAL BOREHOLE IT IS NOT PRESENTED. 5. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THESE RUNS CONTAIN NO DATA AND ARE NOT PRESENTED. 6. MWD RUNS 4 THROUGH 7 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 7. THERE WAS AN APPARENT GAMMA RAY SHIFT OF 25 AAPI UNITS HIGHER AFTER THE FIRST BATCH OF FLO-PRO MUD WAS ADDED. K-ION RANGED FROM 30500 TO 31600 PPM. THE SHIFT WAS NOTED BECAUSE THE TIE-IN NEAR 9200'MD SHIFTED HIGHER. THE MUD WAS CHANGED AT THE END OF RUN 4 AT 9326'MD, 8768'SSTVD. 8. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM LYNN GETTINGER OF ARCO ALASKA, INC. ON 11/25/96. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11763'MD, 8934'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9291.0 11737.0 ROP 9316.0 11763.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 4 9316.0 9326.0 5 9326.0 9800.0 6 9800.0 11007.0 7 11007.0 11763.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type ................... 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9291 11763 10527 4945 9291 ROP 0.67 1698.55 85.3327 4895 9316 GR 20.61 1288.42 69.5745 4893 9291 Last Reading 11763 11763 11737 First Reading For Entire File .......... 9291 Last Reading For Entire File ........... 11763 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... t.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... VersiQn Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9291.0 ROP 9316.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9300.5 9324.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHNfM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 20-SEP-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9326.0 9316.0 9326.0 29.0 32.2 TOOL NUMBER NGP 46 3.800 3.8 Biozan/Seawater .00 .0 .0 0 .0 .000 .000 .000 .000 84.4 .3 REMARKS: FINISH MILLING WINDOW. POOH FOR BUILD ASSY. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRD4 MWD 4 AAPI 4 - 1 68 4 2 ROP4 MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9291 9324.5 9307.75 68 9291 GRD4 20.61 21.91 21.1885 20 9291 ROP4 0.67 21.48 11.7767 18 9316 Last Reading 9324.5 9300.5 9324.5 First Reading For Entire File .......... 9291 Last Reading For Entire File ........... 9324.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and ~og header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9299.0 ROP 9326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE:~ STOP DEPTH 9773.0 9799.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY {S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHN94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 21-SEP-96 MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 9800.0 9326.0 9800.0 32.2 85.9 TOOL NUMBER NGP 246 3.750 3.8 Flo-Pro 8.80 54.0 9.3 6.7 .000 .000 .000 .000 60.9 .3 DRILL BUILD SECTION. POOH FOR HORIZONTAL DRILLING ASSY. CHANGED OUT ORIENTER. $ Data Format Specification Record Data Record Type .................. 0 Data ~pecif%cation Slock Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRD5 MWD 5 AAPI 4 1 68 4 2 ROP5 MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9299 9799.5 9549.25 1002 9299 GRD5 24.38 1288.42 59.1696 949 9299 ROP5 23.28 1650.56 82.5921 948 9326 Last Reading 9799.5 9773 9799.5 First Reading For Entire File .......... 9299 Last Reading For Entire File ........... 9799.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9773.0 10980.5 ROP 9800.0 11006.5 LOG HEADE.R DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE 23-SEP-96 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11007.0 9800.0 11007.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 88.6 93.5 TOOL NUMBER NGP 246 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3.750 3.8 Flo-Pro 8.90 60.0 9.5 5.0 .3 .000 .000 .000 .000 REMARKS: DRILL HORIZONTAL SECTION. POOH FOR MOTOR. 70.3 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service O~der Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRD6 MWD 6 AAPI 4 1 68~ 4 2 ROP6 MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9773 11006.5 10389.8 2468 9773 GRD6 39.79 261.56 73.1695 2416 9773 ROP6 29.99 1698.55 86.9786 2414 9800 Last Reading 11006.5 10980.5 11006.5 First Reading For Entire File .......... 9773 Last Reading For Entire File ........... 11006.5 File Trailer Service name ............. STSLIB'.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10980.5 11737.0 ROP 11002 . 0 11763.0 $ LOG HEADER DATA DATE LOGGED: 24-SEP-96 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): MSC V. 1.32 NGP; SPC V. 5.74 MEMORY 11763.0 11007.0 11763.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 88.8 94.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 46 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 8.80 59.0 10.0 6.2 .000 .000 .000 .000 72.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .3 REMARKS: DRILL HORIZONTAL SECTION.TD WELL AT 11766 MD, 8934.54SSTVD. RAN INTO STICKY SHALES DECIDED TO TD WELL. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GRD7 MWD 7 AAPI 4 1 68 4 2 ROP7 MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 10980.5 11763 11371.8 1566 GRD7 28124 194.18 70.8574 1514 ROP7 24.27. 1098.68 85.6208 1523 10980.5 10980.5 11002 11763 11737 11763 First Reading For Entire File .......... 10980.5 Last Reading For Entire File ........... 11763 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
