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195-164
Rixse, Melvin G (DOA) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Monday, April 22, 2019 7:42 AM To: Rixse, Melvin G (DOA) Subject: RE: 10-407 Schematic, PTD 195-164,18-34 P&A Mel, This IA cement is historical. Back in 2002, that cement was placed in an attempt to repair an identified PC/Cretaceous Leak at -6,900'. It was logged from 4,962' to -6,800' with an SCMT, though I can't recall the date off the top of my head. The cement in the tubing from the stuck retainer at 6,910' to 4,468' (SLM) was pumped fullbore. We did see a squeeze build as the cement entered the Cretaceous, through the tubing and PC holes at -6,900'. Please give me a call if you have further questions. This one got a little complicated as we went through both the design and the execution of the P&A program. Kind regards, Beau From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Sunday, April 21, 2019 1:49 PM To: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Subject: 10-407 Schematic, PTD 195-164, 18-34 P&A Beau, The final schematic shows TOC in the IA at 4962' from the circulation of punches at . Should this be 6900'? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin. Rixse(1a alaska.go ). TREE== FMC ABANDONDED VWLU-EAD= CNV ACTUATOR= BAKER OKEL ELEV = 53.65' BF. E -EV = WA KOP= 1434' Max Angle = 94' @ 11170' Datum Opn/Sgz Datum 3-3/8" 6 SPF, bD= WA ICMT(10/09/18) ND= 8800'SS 10-3/4" CSG, 45.5#, L-80, D = 9.953' 4-1/2' TBG RJNCH (08/19/18) P OF CEMENT N IA 4982' TOP OF CEMENT I PC & TBG LEAK I Minimum ID = 3.725" @ 9201' 4-1/2" HES XN NIPPLE 1 4-12' TBG, 12.6#, L80, .0152 bpf, D = 3.958" 7-5/8" CSG. 29.7#. S95. D = 6.875" I 5-1/2' LNR 17#, L-80, .0232 bpf, D = 4.892' SAFETY NOTES: RSH @ 9148' (CATCHER SUB COVERED (10/28103) 'AOGCC 18-34 WITNESS NOTIFICATION; CUTOFF WELLHEAD; INSTALL MARKER PLATE' 1300' -SURFACE TBG&OA TOP OFDPZI 1959' 2171' 4-1/2' HES CP -2 TRSV SSSV NP, D = 3.812' 2171' 4-112" TRSV LOCKED OPEN, HYDRAULICS N COMMUNICATION w/TBG (09/14/18) CAMCO GAS LFT MANDRELS IsTIMD17VDIDEVI RY PERFORATION SUMMARY DATE I RE/ BY I COMMENTS 0820/18 NXWJM) TBG PINCH (08/19118) 0521101 Tiff LOG: Z -DEN ON 1126/95 I VLVLATCH MD TRSV LOt3®OPEN (09104!18) ANGLEAT TO' PERF: 86 @ 10450' DATE Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 10450 - 11020 S 02/07/98 3-318" 4 11085-11105 O 12/03/95 3-318" 4 11115-11300 O 12/03/95 3-318" 4 11370-11890 O 12/03/95 5-1/2' LNR 17#, L-80, .0232 bpf, D = 4.892' SAFETY NOTES: RSH @ 9148' (CATCHER SUB COVERED (10/28103) 'AOGCC 18-34 WITNESS NOTIFICATION; CUTOFF WELLHEAD; INSTALL MARKER PLATE' 1300' -SURFACE TBG&OA TOP OFDPZI 1959' 2171' 4-1/2' HES CP -2 TRSV SSSV NP, D = 3.812' 2171' 4-112" TRSV LOCKED OPEN, HYDRAULICS N COMMUNICATION w/TBG (09/14/18) CAMCO GAS LFT MANDRELS IsTIMD17VDIDEVI I REV BY COMMENTS ORIGINAL COMPLETION DATE I RE/ BY I COMMENTS 0820/18 NXWJM) TBG PINCH (08/19118) 0521101 TYPE I VLVLATCH MD TRSV LOt3®OPEN (09104!18) PDRT DATE 1 CIATDIA&TBG(10/09/18) 4 32 KBMG-M DMY BK 0 O6H2101 2 �46082374�6360876 TWJMD TBG TOC TAGGED 07N6/ 32 KBMGM =1 BK 0 12/13/95 3 9100 7987 33 KBMG-M EMPTY - - 01/12/02 " STA 9 2 = MWKM LATCH (12/13185) - 8910' CTM 1-� CMT RETAINER MILLED & PUSHED (03/27/18) 13" BKR BP PUSHED (03/25/18) TOP OF CEMENT N 4-1/2" TBG FAS DRLL SOZ PCR PKR D = 3.675 = 3 66' (01/08/0 14-1/2" HES XN NP, D = 3.725' 1 922W -J4-1/2" WLEG, D = 3.958 BMD TT LOG NOT AVAILABLE TOP OF DPZ3 9260' TO TD 1 11050' 1 DATE 12104/95 I REV BY COMMENTS ORIGINAL COMPLETION DATE I RE/ BY I COMMENTS 0820/18 NXWJM) TBG PINCH (08/19118) 0521101 RPYTP CORRECTIONS 09/06/18 MD TRSV LOt3®OPEN (09104!18) 12/11/11 DTR/TAD GLVaO(01/12/02) 10/11/18MD CIATDIA&TBG(10/09/18) 0927/17 JGUAU P SHE37 BP DH (0921/17 12113118 :BTWJMDTBG & PC PU NCH (11114/18) 0329/18 TFAIJMDOMTRETMLLED'BPPUS 01/15/19 MDCMTDTBG&OA(01/10/19) 07/17/18 TWJMD TBG TOC TAGGED 07N6/ 02/28/19 BO'JMD ABANDONlDf31 FISH- RUBBER ELEMENT FROM BP (LOST 0220198) I(LOST 12/13/95)1L---- P RUDHOE BAY UNT WELL: 18-34 PERMIT No: 1951640 AR No: 50-029-22611-00 SEE; 24, TI 01. R14F- 3589.41' FEL & 1314.62' FNL BP 6(ploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG nr_vIII v L...is MAR 2 7 2019 Is. 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 CIH�g/��f DeveloprtfEn[ p Exploratory IService ❑ Stratigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6, Date Comp., SUSP., o11/kban/d.. 2/27/2019 �� 14. Permit to Drill Number/Sundry 195-164 • 317519 & 318433 3, Address: P.O. Box 196612 Anchorage, AK 995195612 7. Date Spudded: 10/31/1995 15. API Number: 50-029.22611-00-00 4a. Location of Well (Governmental Seclion): Surface: 3661' FSL, 48' FEL, Sec. 24, Ti1N, R14E, UM Top of Productive Interval: 3526' FSL, 4582' FNA, Sec. 19, TI N, R15E, UM Total Depth: 3964' FSL, 1688' FWL, Sec. 20, T1 IN, RISE. UM 8. Date TO Reached: 11/25/1995 16. Well Name and Number: PBU 1844 - 9 Ref Elevations KB 53.65 GL 15.90 • BF N/A 17. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL - 10. Plug Back Depth(MD/TVD): Surface / Surface 18, Property Designation: ADL 028307 & 028321 - 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691729 y- 5960248 Zone - ASP 4 TPI: x- 696361 y- 5960233 Zone - ASP 4 Total Depth: x- 698410 Y- 5960725 Zone - ASP 4 11. Total Depth (MDrFVD): - 12153'/ 8703' 19. DNR Approval Number: 79-190 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MDfrVD 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No IZ Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-ddll/Lateral Top Wndow MD/TVD: N/A 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 lag, 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 MWD, GR, CN, ZDL, Temp, DLL, LIND / FE, HEX, DIP, CIBL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TWO HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM 20" 91.5#E&95 Surface 118' 30" 260 sx Arctic Set(Appmx.) 10-3/4" 45.5#Surface 3640' 13-1/2" 1140 sx PF'E', 375 sx Class'G', 260 PF 'C' 7-5/8" 29.7#Surface XSurfa�9403' 8241' 9-7/8" 239 sx Class'G', 290 sx Class'G' 5-1/2" 17# 8111' 8703' 6-3/4" 300 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MDf VD of Top and Bottom; Perforation Size and Number; Date Pam): /� 7 1 ip-mj&i DATE ZPer Z I Z `f `i VERIFIED 25. TUBING RECORD GRADE I DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# L-80 9229' 9171'/ 8046' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulichacluring used during completion? Yes ❑ No 0 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MO) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Pmduction Method of Operation (Floynng, gas lift, etc.): N/A Date of TesCHours Tested Production for Test Period --► Oil -RIA Gas -MCF: Water -Bbl: Chinks Sive Gas-Oil Ratio Flow Tubing Press Casing Press: Calculated 24 Hour Rate I Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API loom: Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ARf/n/„ RB =--^/MAR 2 8 2019 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 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 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10030' 8656' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9335' 8184' Shublik 9391' 8231' Sadlerochil - Zone 4 9458' 8288' CGL - Zone 3 9574' 8382' Base of CGL - Zone 2 9662' 8451' TDF - Zones 10030' 8656' Base Sadlemchit- Kavik 11044' 8719' Formation at total depth: - Kavik 11044' 8719' 31. List of Attachments: Summary of Daily Reports, 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name. Obngewitch, Beau Authorized Title: SIM cia Contact Email: BEAU.OBRIGEWITCH@bp.com �1 Contact Phone: Authorized Signature. ate. 3 Z / q +1 907 564 4854 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 "it completion report and 10404 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 la. 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-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a bdef 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 forth: "It schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 512017 Submit ORIGINAL Only Ih9VIIIIIIIIIa_I61:9 18-34 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 7363'-7368' Tubing Punch 6910' Set Cement Retainer 4468' 43 Bbls Class'G' 4446'-4456' Tubing Punch 2000' 166 Bbls Class'G' 1300'- 1310' ITubing & Casing Perforation Surface 82 Bbls Class'G' T/I/0= 670/713/0 Temp=Sl (LRS Unit 70 - MIT -OA) MIT -OA ***Passed*** to 1125 psi, Max Applied Pressure = 1200 psi, Pressured OA to 1194 psi wi s diesel. bg lostpsi list 15 minutes and 15 psi in 2nd 15 minutes, for a total loss of 69 psi during 30 minute test. Bled TBG to 0 psi, returned -2 bbls. 1/26/2018 FWHP's 800/700/5 CTU#8 1.75" CT Job Scope: FCO/Push IBP/Tbg-Punch/P&A MIRU CTU. Begin Weekly BOP test. 3/23/2018 ***Continued on 03/24/18*** CTU#8 1.75" CT Job Scope: FCO/Push IBP/Tbg-Punch/P&A Perform Weekly BOP Test. MU & RIH w/ 3.0" JSN. Tag IBP at 7408'. Made several failed attempts to push the IBP downhole. Inject at 1 bpm at 1100 psi thru PC leak for 30 bbls. Circulate 100 bbls of 80 degree Diesel/Xylene (50/50 mixture) bottoms up. Chase ooh at 80% with 125 degree diesel taking returns to 18-33 flowline. 3/24/2018 ***Continued on 03/25/18*** T/1/0=900/788/10 Temp= SI (LRS Unit 70 -Assist Coiled Tubing: Diesel/Xylene) Pumped 102 bbls of 80* diesel/xylene followed by 178 bbls of 135* diesel to assist CTU. 3/24/2018 **WSR continued on 3-25-18** CTU#8 1.75" CT Job Scope: FCO/Push IBP/Tbg-Punch/P&A Lay down tools. MU & RIH w/ HES GR/CCL Logging Tools w/ 3.70" JSN. Tag top of IBP at 7379' ctm. Log from compression up to 7100'. Flagged pipe at 7324'. Pooh. Receive good data ( -2' Correction). Correlate to Tubing Tally 12/3/1995. Corrected Top of IBP at 7378.65'. MU & RIH w/ HES 2" x 5' Tubing Punch BHA. Correct depth at flag. Pre Tbg Punch Injectivity: 1 bpm @ - 2000psi. Tbg Punch from 7363.13'- 7368.13'. Bottom shot - 10' from top of IBP. Unable to shoot closer due to risk of getting beside IBP with bowspring decentralizer on bottom of punch gun. Pooh. Post Punch Injectivity: 1 bpm @ - 2000psi. No change in injectivity which was expected with holes already at 6900'. All shots fired, ball recovered. MU & RIH w/ WFT One Trip Cement Retainer. Tag high at 6887' ctm. Unable to get past this depth. Suspect this depth is above the existing TAA holes. Discuss with APE. Pooh to pick up motor & mill. Lay down tools. Cement retainer is gone. Assume it is at 6887'. Notify APE. MU WFT 2-7/8" milling assembly w/ 3.78" 5-bld junk mill. 3/25/2018 ***Continued on 03/26/18*** **WSR continued from 3-24-18** (LRS Unit 70 - Assist Coiled Tubing: Diesel/Xylene) Pumped 16 bbls of diesel to assist CTU. FWHP=1450/1293/279 CTU still on well upon 3/25/2018 departure. CTU#8 1.75" CT Job Scope: FCO/Push IBP/Tbg-Punch/P&A RIH with WFT milling assembly. Tag retainer at 6887'. Mill from 6887' to 6902'. Stacking weight & quit seeing motor -work. Pooh to inspect bha. At surface, BHA looks & tested good. MU & RIH w/ WFT 3-1/8" Venturi with 3.5" Mule Shoe. Dry tag 6902'. Make two Venturi passes from 6980' to 6902'. Pooh. Recover one cup of cement. Stack down and change packoffs. Cut 150' of pipe. 3/26/2018 ***Continued on 03/27/18*** 3/27/2018 SSSV Cement Kit Purchase for P&A Daily Report of Well Operations 18-34 CTU#8 1.75" CT Job Scope: FCO/Push IBPlrbg-Punch/P&A Stack back up. MU Baker 3-1/8" milling assembly w/ 3.70" reverse clutch mill. Dry tag at 6902'. Mill down to 6910' in 3hrs. Similar results from previous milling run. Not seeing much of any motor-work. Cade predicts —4k available WOB. Pump gel sweep & chase ooh. Inspect BHA. No wear to face of mill. Only wear is on the outer edge of the 3.70" mill. Discuss job with CT Supt & APE. Decision was made to rig down CTU. Freeze Protect Tbg w/ 40 bbls 60/40 Methanol. Rig Down CTU. *** Top of WFT One Trip Cement Retainer at 6910' ctm - This is the deepest depth Coil milled to. **** 3/27/2018 ***Job Incomplete"* ****WELL S/I UPON ARRIVAL**** (Plug & abandonment) DRIFTED W/ 10'x 2-7/8" DUMMY GUN, S-BAILER TO 6,892' SLM (Small sample of cement) RAN PDS 40 ARM CALIPER LOG FROM 6,892' SLM TO SURFACE (Good data) 4/23/2018 ****CONT JOB ON 4/24/18**** WHP: 1600/0/0 Temp= S/I (LRS Unit 46 -Assist Slickline: D&D Hole Finder) Load Diesel. RU and PT. Standby for S.Line 4/23/2018 *** Job continued on 04/24/18 *** ****CONT. JOB FROM 4/23/18**** (Plug & abandonment) RAN 4-1/2" D&D HOLE FINDER, S/D @ 6,883' SLM (Unable to set higher, slipstop stuck in open position) LRS PUMPED —5 BBLS DIESEL DOWN TBG W/ D&D HF @ 6,883' SLM (Unable to catch pressure) RE-RUN 4-1/2" D&D HOLE FINDER, SET @ 6,810' SLM (Above STA#2 glm) LRS PRESSURED UP TBG TO 2,500 psi (Holding solid, see LRS log) 4/24/2018 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** ***Job continued from 04-23-18 *** (LRS Unit 46 -Assist Slickline: D&D Hole Finder) Pump 6.3 down TBG to pressure up on plug. Slickline in control of well upon departure. 4/24/2018 FWHP= 1880/0/0 T/I/0= 1680/Vac/Vac (LRS Unit 76 - Injectivity Test) Pumped 38 bbls 50/50 down TBG to establish an injectivity rate of 5 bpm @ 1990 psi for 20 bbls, Tags hung on well, Valve position @ departure- WV, SV, SSV= Closed, MV= Open, IA & OA= OTG, 6/12/2018 1 FWHP= 1600/Vac/Vac T/1/0=1543/440/0 Temp=Sl (SLB pumping- Plug and Abandon) MIRU SLB pumping. Pumped down TBG 5 bbls FW spacer, 43 bbls 15.8 ppq Class G cement, lauch 2 x 5" foam balls w/2 bbls FW spacer on each side, displace w/68.2 bbls 9.8 ppg NaCL. Saw a slight squeeze as leading 10 bbls cement went through TBG holes into IA PC leak @ 6900'. Estimated TOC in TBG 4,750' D. Tag hung on MV. Valve positions upon departure: SV, SSV closed, FL disconnected; MV, IA, OA= open. FWHP's=566/1153/0 Class G 15.8 ppg cement in TBG from 6900' MD/6160' TVD to 4750'MD/4320' TVD in TBG 'MD/ 7/12/2018 Daily Report of Well Operations 18-34 ***WELL S/I ON ARRIVAL*** (Plug & abandonment) TAGGED TOC @ 4,468' SLM w/ 3.25" CENT, 2-1/2" S-BLR. (State witnessed) LRS PERFORMED PASSING 2,500 psi CMIT (State witnessed) BRUSHED TRSV @ 2,171' MD. 7/16/2018 ***WSR CONTINUED ON 7/17/18*** T/1/0=0/600/0 SI (LRS Unit 46 -Assist Slickline: AOGCC MIT) PRE-TEST CMIT TxIA to 2439/2395 psi ***PASSED*** (3rd attempt) Target pressure=2250 psi Max applied=2500 psi Pumped 3 bbls 50/50 down TxIA to achieve test pressure of 2500 psi. 3rd attempt 15 min loss of 16/24 psi, 30 min loss of 15/20 psi, for total loss of 31/44 psi in 30 mins. Bleed TAA to 0 psi, bled back -2.5 bbls. AOGCC CMIT-TxIA PASSED @ 2458 & 2353 psi. Witnessed by Bob Noble. First 15 min. TBG loss 27 psi and IA loss 97 psi. Second 15 min. TBG loss 19 psi and IA loss 45 psi. For a total loss of 46 and 142 psi. SL on well upon departure. Tags hung on WV/IA CVs OTG 7/16/2018 FWHP= 0/0/0 ***WSR CONTINUED FROM 7/16/18*** (Plug & abandonment) RIGGED DOWN SWCP 4518 7/17/2018 ***JOB COMPLETE, WELL LEFT S/I*** T/l/O = Vac/220/Vac. Temp = SI. Bleed IAP to 0 psi (Eval P & A). No AL. Flowlines disconnected. IA FL @ surface. Bled IAP to BT from 220 psi to 0 psi in 10 min (Fluid, 1/4 bbl). Monitored for 30 min. IAP increased 5 psi. Final WHPs = Vac/5Nac. 7/18/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 TWO = Vac/10Nac. Temp = SI. WHPs (post bleed). No AL. Flowline disconnected. WV locked out. IAP increased 5 psi since bleed overnight. 7/19/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00 T/l/O = Vac/90/Vac. Temp = SI. WHPs (Post bleed). No AL. IA FL @ surface. IAP increased 80 psi since 04:00 this morning. 7/19/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 T/I/O = Vac/130Nac. Temp = SI. WHPs (post P & A). No AL. IA FL @ surface. IAP increased 40 psi since 16:30 yesterday. 7/20/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:45. T/I/O = Vac/170Nac. Temp = SI. WHPs (post P & A). No AL. IA FL @ surface. IAP increased 40 psi overnight. 7/21/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:45. T/l/O = VAC/220NAC. Temp = SI. WHPs (post P&A). No AL or flowline. IA FL @ surface. IAP increased 50 psi overnight. 7/22/2018 SV, WV = C. SSV, MV = O. IA, OA = OTG. 16:30 TWO = Vac/250/Vac. Temp = SI. WHPs (Post P&A). No AL. Flowline removed. IA FL @ surface. IAP increased 30 psi overnight. 7/23/2018 SV, WV = C. SSV, MV = O. IA, OA = OTG. 13:40 T/I/O = Vac/440/Vac. Temp = SI. WHPs (Post P&A). No AL. Flowline removed. IA FL @ surface. IAP increased 190 psi from 7/23/18. 7/30/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:20. T/I/O = Vac/500/Vac. Temp = SI. WHPs (Post P&A). No AL. Flowline removed. IA FL @ surface. IAP increased 60 psi from 7/30/18. 8/2/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:50. T/I/O = Vac/560Nac. Temp = SI. WHPs (Post P&A). No AL. Flowline removed IA FL @ surface. IAP increased 60 psi from 8/2/18. 8/5/2018 SV, WV, SSV = C. MV = O. IA, OA OTG. 10:30 TWO = VAC/610NAC. Temp = SI. WHPs (APE). No AL. Flowline removed. IAP increased 50 psi since 08/05/2018. 8/8/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:45 Daily Report of Well Operations 18-34 T/I/O = VAC/690NAC. Temp = SI. WHPs (APE). No AL. Flowline removed. IAP increased 80 psi since 08/08/2018. 8/12/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 TWO = Vac/760/Vac. Temp = SI. WHPs (APE req). No AL. Flowline removed. IA FL @ surface. IAP increased 70 psi from 08/12/18. 8/16/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00. T/I/O = VAC/760NAC. Temp = SI. Tbg FL (WIE Request). No AL or Flowline. TBG FL @ near surface. IA FL @ surface. 8/17/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 T/I/O = Vac1772Nac. Temp + SI. AOGCC MIT -T PASSED to 2478 psi. Max pressure = 2500 psi, Target pressure = 2350 psi. State Witnessed by Lou Labeinstein. Used 0.35 bbls of DSL to pressure TP from a Vac to 2510 psi. Tbg lost 24 psi in the 1st 15 mins and 8 psi in the 2nd 15 mins for a total loss of 32 psi in 30 mins. Bled TP to 0 psi (0.64 bbls). AOGCC MIT -IA to 2362 psi PASSED, Max pressure = 2500 psi, Target pressure = 2350 psi. State Witnessed by Lou Labeinstein. Used 1.1 bbls of DSL to pressure IAP from a 765 psi to 2503 psi. IA lost 100 psi in the 1st 15 mins and 41 psi in the 2nd 15 mins for a total loss of 141 psi in 30 mins. Bled IAP to 750 psi (0.8 bbls). Hung Tags & AFE sign. Final WHPs = 20/750/Vac. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 8/18/2018 ***WELL SHUT-IN ON ARRIVAL*** (SLB E -LINE TUBING PUNCH) INITIAL TWO = 0/850/0 PSI RIG UP, PT LUBRICATOR TO 3700 PSI RUN 1 - RIH W/ 1-23ZA/MH-22 (1.375" FN)/SWIVELIWEIGHT X2/CCL/MPD/10' X 1.56" PUNCHER, 1 SPF, 0 DEG PHASE. CAL = 35', CAW = 300 LBS, MAX OD = 1.69". TUBING PUNCH INTERVAL = 4445'- 4455', CCL TO TOP SHOT = 5.75', CCL STOP DEPTH = 4439.25'. RUN 2 - RIH W/ 1-23ZA/MH-22 (1.375" FN)/SWIVEL/WEIGHT X2/CCL/MPD/10' X 1.56" PUNCHER, 1 SPF, 0 DEG PHASE. CAL = 35', OAW = 300 LBS, MAX OD = 1.69". TUBING PUNCH INTERVAL = 4445.5'- 4455.5', CCL TO TOP SHOT = 5.75', CCL STOP DEPTH = 4439.75'. ALL PASSES TIED INTO TUBING TALLY DATED 3 -DEC -1995 FINAL T/I/O = 0/500/0 PSI. 8/19/2018 1 "'JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** 8/28/2018 Load fluids and Road to location, ***WSR Continued on 08-29-18*** **"WSR Continued from 08-28-18*** T/I/O= 690/693/23 Temp= S/I Circ -Out (PLUG AND ABANDONMENT) Pumped 10 bbls 60/40 spear followed with 100 bbls 180* surfactant wash F103, 301 bbls 9.8 brine followed with 10 bbls diesel down 18-34 TBG taking returns up IA to FL of 18-32, U-tube to put FP in place, Pumped 8 bbls 60/40 thru hardline to 18-32 for surface lines and Flowline FP. Bleed all pressures to 0 psi, Hanf AFE sign, caution tags. 8/29/2018 Notify DSO. WV'SV'SSV=closed MV=open IA/OA=OTG. FWHP's 0/0/0. TWO = 4Nac/Vac. Temp = SI. WHPs (P&A). No AL. Temp hardline rigged to IA. 8/30/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 08:10 TT" -'A=01'010 Temp = S/I (LRS Unit 76 -Assist Slickline: Lock Out TRSSSV) Pumped a total of 3.4 bbls diesel down TBG to pressure up on SSV for SL. RDMO IA and OA= OTG SL in control of well upon LRS departure. 9/3/2018 FWHP's = 50/0/0 Daily Report of Well Operations 18-34 `**WELL S/I ON ARRIVAL SWCP 4518***(plug & abandonment) RAN FLAPPER CHECKER TO SSSV @ 2,171' MD. (Picks clean even when control line psi dumped) RAN 4-1/2" CP-2 EXCERCISE TOOL TO 2,171' MD. RAN 4-1/2" CP-2 LOCKOUT TOOL TO 2,171' MD. (Attempted to lockout @ 2,000, 2,500 & 3,000 psi) RAN 4-1/2" CP-2 EXCERCISE TOOL TO 2,171' MD. RAN 4-1/2" CP-2 LOCKOUT TOOL TO 2,171' MD. (Attempted to lockout @ 2,000, 2,500 & 3,000 psi) RAN 4-1/2" CP-2 EXCERCISE TOOL TO 2,171' MD. RAN 4-1/2" CP-2 EXCERCISE TOOL TO 2,171' MD. 9/3/2018 ***WSR CONTINUED ON 9/4/18*** ***WSR CONTINUED FROM 9/3/18*** (Plug & Abandonment) ATTEMPTED TO LOCK OUT 4-1/2" CP-2 TRSV @ 2,171' MD. RAN 4-1/2" BLB w/ 2.80" GAUGE RING TO CP-2 TRSV AT 2,171' MD, ATTEMPT TO FREE UP FLOW SLEEVE. EXCERCISE 4-1/2" CP-2 TRSV @ 2,171' MD WITH EXCERCISE TOOL. LOCKED OUT 4-1/2" CP-2 TRSV w/ LOCKOUT TOOL @ 2,171' MD. PURGED 3 GALLONS OF HYDRAULIC FLUID THROUGH CONTROL LINE. RAN FLAPPER CHECKER TO CP-2 TRSV @ 2,171' MD, FLAPPER APPEARS LOCKED OPEN. 9/4/2018 ***WELL TURNED OVER TO DSO*** TWO = SSV/0/0. Temp = SI. Plug & Abandonment (Cement Control line). Flowline is 9/5/2018 removed. Purniped 2 gallons squeeze crete in to control line. Tag hung. TWO = SSV/0/0. Temp = SI. PT control line (P&A). Sample on well head not set up. Install heater on THA and wait another day. 9/8/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. TWO = SSV/0/0. Temp = SI. PT control line (P&A). PT control line -PASS- to 2735 psi. Tags hung. 9/9/2018 1 SV, WV, SSV = C. MV = O. IA, OA - OTG. T/1/0 SSV/01Vac. Temp = SI. WHP's. (WE request). IA & OA, No bleed needed. 9/27/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 19:44 T/1/0=0/0/VAC. Pre P&A. RD working side 2" FMC 120 I/A valve and RU 2" intergal with 2" block valve. RD 2" companion O/A blind and remove 2' VR plug and RU 2" intergal with 2" block valve. RD working side O/A 2" FMC 120 valve and RU 2" intergal with 2" block valve. 10/6/2018 No PT required. ***Job Complete*** Final WHP's 0/0/0. See Io TWO = 850/0/0. Temp = SI. Pump N2 (Assist Fullbore w/ cementjob). No AL. Purged one bottle N2 across IA valves taking returns to OT. 10/9/2018 1SIb cementers in control of well on departure. SLB Fullbore Pumping Crew. Job Scope: Plug & Abandonment down 4-1/2" TBG taking returns from the IA. Pumped 5 bbls FW spacer to verify flow path/returns. Pumped 166 bbls 15.8 ppq Class G cement, 1 bbls FW spacer, dropped 2x5" foam wiper ba Is. Displaced TBG CMT with 24 bbls 9.8 ppg NaCL, and 6 bbls 60/40 to FP @ surface and place TOC in TBG 2,000'. CMT returns at surface in IA,a. 17 bbls brine away, clean CMT returns verified @ 2 bbls 60/40 away. SD, wash up lines. DHD blow N2 across IA casing valves. Tree and well head serviced. **Job Complete** 15.8 ppg Class G Cement in TBG from 4446'MD/4070"TVD to 2,000'MD/1973'TVD 10/9/2018 115.8 ppg Class G Cement in IA from 4446'MD/4070 TVD to surface Daily Report of Well Operations 18-34 ***WELL S/I ON ARRIVAL*** (SLB E -LINE PERFORATING) INITIAL T/I/O = 0/0/0. MIRU & PT. RUN 1: DRIFT W/ 2" X 10' DUMMY GUN TO 1350'. RUN 2: PUNCH TBG/PC AT 1300'- 1310'W/2" POWERFLOW, 6 SPF, 60 DEG PHASED. PRESSURE UP TBG TO 2000 PSI. NO RESPONSE SEEN ON THE OA. , RDMO. WELL S/I ON DEPARTURE. FINAL TWO = 200/0/0. 11/14/2018 ***JOB COMPLETE ON 14-NOV-2018*** Wireless install (WOLP). Installed and pressure tested wireless pressure gauges on annuli. 11/16/2018 FCO complete and ready to turn over to Operations. TWO = 149/Vac/Vac. Temp = SI. Injectivity test (P&A). No AL. Tbg FL @ surface. OA FL near surface. Increased OAP with DSL to get FTS and obtain positive pressure. Used 0.6 bbls of DSL to pressure up Tbg to 1900. When 1900 psi was reach TP started falling and OAP increasing stabilizing out @ Vac/Vac/50. Established a LLR down the Tbg @ 2.9 GPM @ 800 psi. During LLR OAP increased from 207 psi to 943 psi. Bled WHPs to 0 psi (5 bbls). Hung tags. Final WHPs = 0/Vac/0. 11/18/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:15 Initial T/1/0=0/0/0 (LRS Unit 46 - Circ -out TBG x O for Plug and Abandonment) Arrive on 12/22/2018 location, spot equipment *** WSR continue 12/22/18*** WSR continued from 12/22/18 (LRS Unit 46 - Cir -out TBG x O for Plug & Abandonment) Per SDS, F103 requires a shower trailer. GWO Safety to discuss concentrations and 12/23/2018 requirements of shower trailer ***Job postponed*** T/I/0= 0/0/0. Temp=S/I (LRS Unit 72 - Circ Out TxOA) Pumped the following down the tubing, up the OA, to surface return tanks: 10 bbls of 60/40 Meoh, 50 bbls of 160*F Freshwater w/ 4 gal U067 + 4 gal F103 92 bbls of 9.8 Brine FP with 7 bbls of 60/40 Meoh and U -Tube TxOA. 12/23/2018 FWHP= 0/0/0 T/1/0=0/0/0 SI Confirm Injectivity thru well and hardline Pre -cement (PLUG AND ABANDONMENT) Pumped 5 bbls 60/40 thru hardline to confirm flow path for WSL. Valve 1/5/2019 positions=SV/1NV SSV closed MV open CVs SI Hardline SI FWHP=0/0/0 Initial T/I/0= 0/0/0 Temp=S/1. (SLB - TxO Surface P&A) LRS pumped the following fluids down TBG, up OA w/ returns to tank. ***Refer to LRS AWGRS for more details*** 10 bbls 60/40 100 bbls 130 deg F FW SLB pumped the following fluids down TBG, up OA w/ returns to tank 5 bbls 80 deg F FW 82 bbls 15.8 PPG Class G CMT (72 + 10 Excess) ***LRS in control of valves after pumping cement*** 1/9/2019 TBG and OA Cemented from 1300' MD to surface. T/I/0= 0/0/0. Temp = SI. Assist SWS Circ Cement down TBG and up OA to surface. (Plug & Abandon). Pumped 10 bbls of 60/40 Meoh, 100 bbls of 130* F freshwater and another 5 bbls of 60/40 Meoh to warm up well bore. Monitor WHPs while SWS pumped cement. Flushed all surface equipment with 4 bbls of 60/40 Meoh. SV, SSV, OA closed. MV open. IA OTG. DSO 1/9/2019 notified upon departure. Pre P&A. Pulled wellhouse and moved to Pad 10 staging area. Hung well sign on well. 1/24/2019 ***Job Complete*** TWO = 0/0/0. Temp = SI. Strap T, IA, & OA (pre P&A). T, & OA cemented to surface. IA cement tagged @ 48". 2/5/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 Daily Report of Well Operations 18-34 TWO = CMT/0/0. RD Upper tree, RU Temp #83. PT'd against MV 350/5000 PSI (Pass). 2/8/2019 Charted and Retained. RDMO. ***Job Complete***. Job Scope: Cut and Remove Wellhead Initiate CSE, Cut and Remove Wellhead permits, and lift plan. Spot crane and rig -up to tree/wellhead. Cut thru 20" conductor, surface and pruduction casing, and 4-1/2" tbg in 1 hr 25 minutes @ 3.5' below tundra grade. Send wellhead to valve shop. Remove saw. Clean Blue -goo from condcutor to prevent ignition during welding of marker cap. Discovered split in conductor. AOGCC inspector on location. Inspector will advise AOGCC office of compromised conductor and inform when okay to weld on cap. Photo document all. Pics in Well Pictures Folder. 2/16/2019 Job Scope: Inspect split in casing. Remove Blue -goo from casing Clean up split in casing. Confirm the split is on a designed relief seam. Document in pics in Well Pictures Folder. MAx OD of 20" is 20-5/8" min. is 20-1/4". Max ID of 20" is 19-3/4", min/ 2/17/2019 is 19-3/8". 20" marker plate will fit and allow for fillet weld. Job Scope: Dig down at split in conductor and confirm there is no Blue -goo. Hand excavate down -7" at split in conductor no Blue -goo - found only hard cement inside and outside crack 2/20/2019 in conductor. Job Scope: Weld marker plate on casing strings 3' below tundra. (Post wellhead cut) TBT/CSE/HOWF w/OSM. Open HWOF and CSE permits. Air quality checks and excavation inspection completed by Wells HSE advisor. Spot equipment and weld truck. Start gas monitoring, notify BP radio of CSE. Weld plate on 20" conductor and sleeve on split complete. WSL got final pictures. AOGCC still needs to verify marker cap. Could not make it to location due to other commitment running long. Try tomorrow to complete 2/21/2019 linspection. Area secured and DSO notified. AOGCC representitive Lou Laubenstein approved marker cap and authorized backfill. 2/27/2019 Location handed over to Excavation crew. Job Scope: Excavate around Wellhead / Install Shoring Box (Permanent Plug and Abandon) Used an excavator to dig -12'x12' hole around wllhead to -14' deep (-75 cy). Assembled Engineered Modular Shoring Box and placed in excavation hole for wellhead cutting. After wellhead cut, cap welded and AOGCC inspection complete, pulled Shoring Box. Backfilled excavation hole with removed gravel and deliniated around excavatoin hole footprint. 2/28/2019 1 **Job Complete** A"k wJ or A"k MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 'n c TO: Jim Regg ���j'� DATE: 2/27/19 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector PBU 18-34 BPXA PTD 1951640; Sundry 318-333 2/27/2019: 1 traveled to Prudhoe Bay Unit Drill Site 18 to inspect the surface abandonment of well 34. The casing was cut below the required 3ft from ground level, the marker plate had already been installed and a repair was made to the casing (refer to Inspection Report "Surface Abandonment' dated 2/16/2019). The marker plate had all the correct information on it and was in order. There was no sign of oil spillage or seepage. 2019-0227_ Surface _Abandon _ PBU_ 18-34 11.docx Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �l 11 1 DATE: February 16, 2019 P. I. Supervisor 1 FROM: Jeff Jones SUBJECT: Surface Abandonment Petroleum Inspector PBU 18-34 BPXA PTD 1951640; Sundry 318-333 2/16/2019: 1 traveled to PBU 18-34 for an inspection of their surface abandonment. BPXA had excavated around the well and cut off the wellhead prior to my arrival. A i steel bar was used to pound on the cement at surface to verify it was competent. The cement in the inner strings were hard but in the conductor the cement came apart and was frozen mud, soil and "blue -goo". The conductor had a relief slot that had frozen and split open wider — refer to the attached pictures. The BPXA representative at the ' wellsite indicated they plan to excavate deeper, clean out the conductor and repair the crack, and then install a marker plate. Attachments: Photos (3) 2019-0216—Surface—Abandon—PBU-1 8-34jj. docx Pagel of 3 Surface Abandonment — PBU 18-34 (PTD 1951640) Photos by AOGCC Inspector J. Jones 2/16/2019 2019-0216_Surface_Abandon_PBU_18-34_jj.docx Page 2 of 3 Marker Plate Cracked conductor Cracked conductor 2019-0216_Surface_Abandon_PBU_ 18-34_jj.docx Page 3 of 3 p rD /95---/L4 Loepp, Victoria T (DOA) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Wednesday, May 23,2018 3:27 PM To: Loepp,Victoria T(DOA) Subject: RE: PBU Well 18-34 (PTD 195-164, Sundry 317-519) Second Update to Approved Sundry Program Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for approving this change. Enjoy the long weekend. SCANNED JUN 182U)8 Kind regards, Beau From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Wednesday, May 23, 2018 10:49 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Subject: RE: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Beau, Approval is granted for the changes to the approved sundry outlined below. Please include this approval with the original sundry. Thanx, Victoria From:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Sent:Wednesday, May 23,2018 6:47 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Victoria, Thank you for taking a meeting with us last week to discuss our P&A plans in person. From my perspective, it was a very productive conversation. Per our discussion, here is the updated plan for placing the cement plug in 18-34,showing the contingency for using either coil or fullbore: 1 F O lnjectiyity Test Done— Failed (MIT-OA Passed) 2 C - - ' -- • - = - - - ; -e.'- - -..-. A —Attempt Failed (Delete Step) 3 S - -- - ; - - -- - • --- - :; - ! - e - - - Complete (Tbg Holes ID'd) 1 4 F Av _ : - - •- -- - - - - - - g: ` - - - - = Complete 5 F IrB; ;ctivs y L down tubing, taking returns to cretaceous 6 rCement tubing, place min 10 bbls cement in cretaceous: a. For injectivity > 2 bpm pump plug Fullbore from surface b. For injectivity < 2 bpm place 'ug with coil 7 SP a. Drift and Tag TOC; Pressure Test as needed; Requires AOGCC Witness Notification b. Bleed all wellhead pressures to 0 psi 8 FP A/SL: Pressure Test 9 DP Monitor wellhead pressures a minimum of 24 hrs after pressures bled to 0 10 EP Tubing Punch 11 OP Cement Control Line 12 DP WOC 3 Days, PT Control Line 13 OP Surface Cement Plug in IA 14 EP Perforate Tubing, IA Cement, and PC 15 OP Surface Cement Plug OA and Tubing 16 OP Remove Wellhouse 17 OP Cut off Wellhead; Install Marker Plate; Requires AOGCC Witness Notification As requested by you, Guy, and Mel, here is the 90-day T/1/0 for wel18-34, showing no IA repressurization since we began our intervention work in March: 2 Well:18-34 4.000- -2C0 3.806 - 190 3,600- - 180 3,400- - 170 3200 - - 160 3.000 - - 150 2.c - 140 TI 2.600 - - 130 _ T 2,400 - - 120 2.200 - - 110 4 ` -'- C 3 C 2,000 - - 100? C 1.800 - -90 - C 1,6 -80 ■ E C 1,400 - -70 +• h 1.200 - -60 l 1.000 - -50 606 -30 466 -20 200 - - 10 02123118 03109/18 03123118 04106118 04/20/18 0504/18 05`1&18 Please accept my apologies for the tardiness of this email, I had an unforeseen absence from the office the past two days. Please let me know if I can provide any further information with regards to this proposed change to P&A program. Kind regards, Beau From: Loepp,Victoria T(DOA)<victoria.Ioepp@alaska.go,> Sent: Monday, May 14, 2018 10:38 AM To: Obrigewitch, Beau<BEAU.OBRIGE'''ITCH@bp.com> Subject: RE: PBU Well 18-34 (PTD 195-164, Sundry 317-519)Second Update to Approved Sundry Program 3 Beau, • • If there's Cretaceous injectivity through the tubing and PC leaks,could another retainer be set and cement squeezed while monitoring IA pressure? Victoria From: Obrigewitch, Beau [ ?tn:BEAU.OBRIGEWITCH@bp.corr] Sent:Thursday, May 10, 2018 10:38 AM To: Loepp,Victoria T(DOA) < 'ictoria.loepp@alaska.gov> Subject: RE: PBU Well 18-34 (PTD 195-164, Sundry 317-519)Second Update to Approved Sundry Program Victoria, The IA pressurization is not from the Ivishak below the packer. Based on the surface pressures we are observing, it is from the cretaceous,through the PC leak. We cannot get back below the depth of the stuck retainer, and therefore cannot get more cement deeper in the IA. Our current plan is to place 2,700' of cement in the IA at surface. To eliminate the source of the IA pressurization,the cretaceous,we will squeeze 10 bbls of cement through the tubing and PC holes into that formation. Thank you for your prompt response to this request. Please let me know if you have any further questions, or if you'd prefer a phone conversation. Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. Hanging Out In 740C Office: (907) 564-4854 Cell: (907) 952-6271 From: Loepp Victoria T(DOA) <,ictoria.loepp@alaska. o\,> Sent:Thursday, May 10, 2018 9:44 AM To: Obrigewitch, Beau< .OBRIGEWITCH@bp.c > Subject: RE: PBU Well 18-34 (PTD 195-164, Sundry 317-519)Second Update to Approved Sundry Program Beau, This revision does not address the PC leak that is causing IA pressurization across the IA cement. Could this IA pressurization be from the reservoir across the packer?With the "leaking" IA cement, lateral plugging does not exist. Is there a way to get more cement in the IA? Thanx, 4 Victoria • • Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Sent:Wednesday, May 09, 2018 2:42 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gc > Subject: PBU Well 18-34 (PTD 195-164, Sundry 317-519) Second Update to Approved Sundry Program Good afternoon Victoria, As we have progressed the wellwork approved under Sundry 317-519,to include the previously approved change to t e OA cement(email attached), we have become unable to place the deep cement plug as planned. We experienced a t of failure while attempting to set a cement retainer in which it partially set prematurely at 6,910'. We unsuccessfully attempted to mill and push the retainer. After Coil moved off the well Slickline was able to pull a caliper from the top f the retainer to surface.The caliper located the previously-known tubing holes at 6,889'. We previously confirmed h les in the 7-5/8" Production Casing very near this same depth. We have redesigned the P&A completion of this well to place cement in the tubing across the existing IA cement, as shown in the attachment"18-34 Proposed Rev2". For your reference, I've also attached the originally-approved and revised Wellbore Schematics "18-34 Proposed Original" and "18-34 Proposed Rev 1", respectively. We believe we have injectivity into the Cretaceous through the known tubing and PC holes at—6,900', and intend to pump this revised cement plug from surface using Fullbore.The designed TOC in the tubing has not changed from the original approval. Our revised process for accomplishing this is as follows (there are no changes to the surface cement plugs, but all steps are shown for clarity): 1 F OA Injectivity Test )one— Failed (MIT-OA Passed) 2 C Drift; Tag & Push IBP; Diesel/Xylene Cleanout; Tubing Punch; Cement IA—Attempt Delete Step) 3 S ! •• - -- .e- ; -- -•• •-- -s; '- ` -e - omplete (Tbg Holes ID'd) 4 F A/SL: Pressure testing as needed while SL runs DB,D Holefinder Complete Injectivity test down tubing, taking returns to cretaceous 0 Cen- it tubing, taking returns to cretaceous 7 SP a. Drift and Tag TOC; Pressure Test as needed; Requires AOGCC Witness Notification b. Bleed all wellhead pressures to 0 psi 8 FP A/SL: Pressure Test 9 DP Monitor wellhead pressures a minimum of 24 hrs after pressures bled to 0 10 EP Tubing Punch 11 OP Cement Control Line 5 • 12 DP WOC 3 Days, PTentrol Line 13 OP Surface Cement Plug in IA 14 EP Perforate Tubing, IA Cement, and PC 15 OP Surface Cement Plug OA and Tubing 16 OP Remove Wellhouse 17 OP Cut off Wellhead; Install Marker Plate; Requires AOGCC Witness Notification Please review our proposal and let me know if you need anything else from me. Once we have received AOGCC concurrence with this updated plan,we will resume our work to abandon this well. Kind regards, Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. Hanging Out In 740C Office: (907) 564-4854 Cell: (907) 952-6271 6 • • P T12 1 64, Loepp, Victoria T (DOA) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Monday, May 14, 2018 12:59 PM To: Loepp,Victoria T(DOA) Subject RE: PBU Well 18-34 (PTD 195-164, Sundry 317-519) Second Update to Approved Sundry Program Follow Up Flag: Follow up Flag Status: Flagged SCANNED JUN 1 $2 18 Victoria, Since we have begun working on this well the IA pressure has been bled off to, and remains at,zero.We are currently observing—1,600 psi on the tubing at surface (Cretaceous is the pressure source).Since we do not see any IA repressurization, it is unlikely we would observe any during a cement job,even though a retainer. Kind regards, Beau From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday, May 14, 2018 10:38 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Subject: RE: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Beau, If there's Cretaceous injectivity through the tubing and PC leaks,could another retainer be set and cement squeezed while monitoring IA pressure? Victoria Obrigewitch, mailto:BEAU.OBRIGEWITCH@bp.com] g Beau [ Sent:Thursday, May 10, 2018 10:38 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Victoria, The IA pressurization is not from the Ivishak below the packer. Based on the surface pressures we are observing, it is from the cretaceous,through the PC leak. We cannot get back below the depth of the stuck retainer,and therefore cannot get more cement deeper in the IA. Our current plan is to place^'2,700'of cement in the IA at surface. To eliminate the source of the IA pressurization,the cretaceous,we will squeeze 10 bbls of cement through the tubin and PC holes into that formation. • • Thank you for your prompt respoto this request. Please let me know if you have any further questions,or if you'd prefer a phone conversation. Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. Hanging Out In 740C Office: (907)564-4854 Cell: (907)952-6271 WE'D o;.e•i weft oewru:.h.w From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Thursday, May 10, 2018 9:44 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Subject: RE: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Beau, This revision does not address the PC leak that is causing IA pressurization across the IA cement. Could this IA pressurization be from the reservoir across the packer?With the"leaking" IA cement, lateral plugging does not exist. Is there a way to get more cement in the IA? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservatipn Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From:Obrigewitch, Beau<BEAU.OBRIGEWITCH b .com> Sent:Wednesday, May 09,2018 2:42 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: PBU Well 18-34(PTD 195-164,Sundry 317-519)Second Update to Approved Sundry Program Good afternoon Victoria, 2 As we havero ressed the wellwlapproved under Sundry 317-519,to incl•he previously approved change to t e p g OA cement(email attached),we have become unable to place the deep cement plug as planned.We experienced a to I failure while attempting to set a cement retainer in which it partially set prematurely at -6,910'.We unsuccessfully attempted to mill and push the retainer.After Coil moved off the well Slickline was able to pull a caliper from the top of the retainer to surface.The caliper located the previously-known tubing holes at "6,889'.We previously confirmed holes in the 7-5/8" Production Casing very near this same depth. We have redesigned the P&A completion of this well to place cement in the tubing across the existing IA cement,as shown in the attachment"18-34 Proposed Rev2". For your reference, I've also attached the originally-approved and revised Wellbore Schematics"18-34 Proposed Original" and"18-34 Proposed Rev 1", respectively.We believe we hav- injectivity into the Cretaceous through the known tubing and PC holes at-6,900',and intend to pump this revised cement plug from surface using Fullbore.The designed TOC in the tubing has not changed from the original approval. Our revised process for accomplishing this is as follows(there are no changes to the surface cement plugs, but all steps are shown for clarity): 1 F Done— Failed (MIT-OA Passed) 2 G . - - . - • _ .. .•--- ' _• _ - - - - ; - - ' -• _ ' —Attempt Failed (Delete Step) 3 S ! • - -- •-- ; - - •-_ - •_- --; • - • 9: 9 - - _ "-e- Complete (Tbg Holes ID'd) 4 F - : - •- - - - - • - - - - 9: 9 - e - Complete 5 F Injectivity test down tubing, taking returns to cretaceous 6 0 Cement tubing, taking returns to cretaceous 7 SP a. Drift and Tag TOC; Pressure Test as needed; Requires AOGCC Witness Notification b. Bleed all wellhead pressures to 0 psi 8 FP A/SL: Pressure Test 9 DP Monitor wellhead pressures a minimum of 24 hrs after pressures bled to 0 10 EP Tubing Punch 11 OP Cement Control Line 12 DP WOC 3 Days, PT Control Line 13 OP Surface Cement Plug in IA 14 EP Perforate Tubing, IA Cement, and PC 15 OP Surface Cement Plug OA and Tubing 16 OP Remove Wellhouse 17 OP Cut off Wellhead; Install Marker Plate; Requires AOGCC Witness Notification Please review our proposal and let me know if you need anything else from me.Once we have received AOGCC concurrence with this updated plan,we will resume our work to abandon this well. Kind regards, Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. Hanging Out In 740C Office: (907)564-4854 Cell: (9007)) 9'522-6271 ��I Y V 3 p7i9 44 • 1111 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, February 23, 2018 11:24 AM To: 'Obrigewitch, Beau' Subject: RE:PBU Well 18-34(PTD 195-164, Sundry 317-519) Update to Approved Sundry Program Beau, Approval is granted for the change outlined below to the approved sundry 317-519. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SCANNED (K State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa.alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From:Obrigewitch, Beau [mailto:BEAU.OBRIGEWITCH@bp.com] Sent:Tuesday, February 20,2018 3:52 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:PBU Well 18-34(PTD 195-164,Sundry 317-519) Update to Approved Sundry Program Good afternoon Victoria, I've attached 2 Wellbore Schematics regarding this well.The first one"18-34 Proposed Suspension 2700" is the one that is in the program that was approved for execution under Sundry 317-519.The second one"18-34 Proposed Suspension OA Upsqueeze 1300" is the proposed state to leave the well in. The first step of that approved program was to attempt to gain injectivity into the OA. lnjectivity was not achieved,as the OA passed a mechanical integrity test to BP's standards.This precludes us from downsqueezing the OA from surface to the shoe. As noted in the program, if the OA injectivity test failed, a revised program would be written, in which the OA would be upsqueezed through a perforation penetrating both the tubing and the 7-5/8" Production Casing. Our process for accomplishing this is as follows(there are no changes to the deep plug that coil is placing, but all steps are shown for clarity): 1 • • I F GA-1•Rje cth'ty Toot Done— Failed (MT-0A Passed) 2 C Drift; Tag & Push IBP; DieselfXylene Cleanout; Tubing Punch; Cement IA and Tubing 3 S a. Drift and Tag TOC; Pressure Test as needed: Requires AOGCC Witness Notification b. Bleed all wellhead pressures to 0 psi 4 F A/SL: Pressure Test 5 D Monitor wellhead pressures a minimum of 24 hrs after pressures bled to 0 6 E Tubing Punch 7 0 Cement Control Line 8 D WOC 3 Days, PTControl Line 9 0 Surface Cement Plug in IA 10 E Perforate Tubing, IA Cement, and PC 11 0 Surface Cement Plug OA and Tubing 12 0 Remove Wellhouse 13 0 Cut off Wellhead; Install marker Plate; Requires AOGCC Witness Notification Please review our proposal and let me know if you need anything else from me.Once we have received AOGCC concurrence with this updated plan,we will resume our work to abandon this well. Kind regards, Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska) Inc. Hanging Out In 740C Office: (907)564-4854 Cell: (907)952-6271 2 TREE= _ Perf Tbg to. S TES: RSH @ 9148'(CATCHER SUB w�L AD CNV OA 1,300 18-34 Suspended COV w1SILTtSAND. PC&TBG LEAK ACTWITOR= BAKH2C KB.ELEV= 53.7' (10/28/03) BF = ' TOC in TubingI KOP= 1434' ITubini id OA Cmt - 1,300' n h=._ 94@11170' - 2,000' -. 1 ; 1 Datum MD= WA 2171' H4-1/2"HES CP-2 TRSV SSSV NP D=3.812" Datum TVD= 8800'ss Tubing Punch Tubing and IA Cmt - 2,700' 2,700' CA GAS LIFT MANDRELS CSG,45.5#,L-80,0=9.953' 3972' ST MD TVD DEV TYPE VLV LATCH PORT LATE 1 4027 3684 32 KBMG-M DMY BK 0 06/12/01 TOP OF CEMENT N IA 4962• - 2 6834 6076 32 KBMG-M 'MY BK 0 12/13/95 0•#•# •+ 3 9100 7987 33 KBMG-M EMPTY — -- 01/12/02 #�# •Vi 'STA#2= BROKEN LATCH(12/13/95) BTM OF CEMENT NIA 6800' •..� �V., Top of Cement in Tubing - 4,750' Pc&TBG LEAK —( —6900' Squeeze Packer - 7,515' -- I Top of Cement In IA 6,900' 1 Tubing Punch - 7,525' �•�•�•�•�•� 8607' --I TOP OF CEMENT IN 4-1/2"TBG Minimum ID =3.725" @ 9201' �___ 8870' J FAS DRILL SOZ PKR 4-1/2" HES XN NIPPLE 4.4.4".j�� '4...4 8900-8910 --I TBG PUNCH 4*.444* ►�� 4.'4'* ****4''►� 9167' H 7-5/8'X 4-1l2"BAKER S-3 PKR ID=3.875 V� �t4 9180' HI-IES FAS DRILL PLUG,OD=3.66"(01/08/02) L 9201' J--{4-1/2'HES XN NP,ID=3.725" j 4-1/2"TBG, 12.6#,L80,.0152 bpf,ID=3.958" —I 9225' 9225' H4-1/2"WLEG,ID=3.958 --I ELMD TT LOG NOT AV A LABLE TOP OF 5-1/2"LNR H 9249' 7-5/8'CSG.29.7#,S-95,ID=6.875" —{ 9401' , , PERFORATION SUMMARY REF LOG:Z-DEN ON 11/26/95 i 11050' FISH-RUBBER ELB%4ENT ANGLE AT TOP PERF:86 @ 10450' I FROM BP(LOST 02/20/98) Note:Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ' 3-3/8" 4 10450- 11020 S 02/07/98 3-3/8" 4 11085- 11105 0 12/03/95 3-3/8" 4 11115- 11300 0 12/03/95 ' 3-3/8" 4 11370- 11890 0 12/03/95 12148' —FISH-BK VVOBBLE RING (LOST 12/13/95) PBTD H 10278' 5-112"LMR 17#,L-80,.0232 bpf,D=4.892' —I 12153' ••••44.4 DATE REV BY COMMENTS DATE REV BY COP fl'1TS PRUDHOE BAY UMT 12/04/95 ORIGINAL COMPLETION 06/15/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18-34 05/21/01 RN/TP CORRECTIONS 09/13/03 CMD/TLP DATUM MD CORRECTION PERMIT No:'1951640 01/09/02 TMWKK SET FES FAS DRLL PLUG 10/28/03 ATEYELH FC&TBG LEAK&IA CMT AR No: 50-029-22611-00 01/12/02 DTR/tlh FISH(CATCFER w/SAND) 11/09/03 DAV/TLP SET BAKER IBP SEC 24,T11 N,R14E,3589.41'FEL&1314.67 Fist 02/26/02 M-VKAK ESL FISH 12/11/11 DTR/TAD GLV CIO(01/12/02) 8/31-9/2/02 CS/JF/KK SET PKR;TBG RJNCI-t CMT BP Exploration(Alaska) TREE • FMC CNV • S TES: RSH @ 9148'(CATCHER SUB `"'aD= 118-34 Suspended Coy w/SILT/SAND. PC&TBG LEAK ACTUATOR= BAKER KB.ELEV= 53.7' (10128103) BF-REV= 7 Tubing Punch KOP= 1434' ,,, 2,700' Max Angle= 94 @ 11170' o — 2171' —{Sour Hes CP-2 TRsv sssv ,D=3,812"J Datum M3= NIA OA Down Sqz Datum TVD= 8800'SS Cmt - 3,972' .Tubing and IA Cmt - 2,700' CAMC°GAS LIFT MANDRELS 10-3/4"CSG,45.5#,L-80,D=9.953" 3972' , ST MD IV') DEV TYPE VLV LATCH PORT DATE 1 4027 3684 32 KBMG-M DMY BK 0 06/12/01 TOP OF CEMENT IN IA 4962' 2 6834 6076 32 KBMG-M 'MY BK 0 12/13/95 V4 .'r3. 3 9100 7987 33 KBMG-M EMPTY -- 01/12/02 4. •.v, \STA#2= BROKEN LATCH(12/13/95) .64 BTM OFCEMENT NIA 6800' ••. 44 Top of >✓ciiielii iii i uuiii -- 4,750' PC&TBG LEAK H -6900' ^` l [Squeeze Packer I 7,515' I Top of Cement in IA - 6,900' Tubing Punch - 7,525' CyiTr• 8607' -1 TOP OF CEMENT IN 4-1/2"TBG Minimum ID =3.725" @ 9201' �,44.- 8870' --{FAS DRILL SQZ PKR 4-1/2" HES XN NIPPLE w•j�Avg1y4 `.44444........ '4 4 4 4 8900-8910 --{TBG PUNCH kV....�V........,C.i R21. �� 9167' —{7-5 /8"X 4-1/2"BAKER S-3 RCR,ID=3.875 ,'4'4.44►� 440- 9180' --I HES FAS DRILL PLUG,OD=3.66"(01/08/02) ' L 9201'_J-14-112"HES XN NP,ID=3.725"j 4-1/2"TBG,12.6#,L80,.0152 bpf,D=3.958" H 9225' 9225' H4-1/2"WLEG,ID=3.958 HELMD Tr LOG NOT AVALABLE TOP OF 5-112"LNR H 9249' IS 7-5/8•CSG,29.7#,S-95,D=6.875' j---[ 9401' i , FERFORAT1ON SUMMARY REF LOG:Z-DEN ON 11/26/95 11050' —FISH-RUBBER ELEMENT ANGLE AT TOP PERF:86 @ 10450' I FROM IBP(LOST 02/20/98) Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ' 3-3/8" 4 10450- 11020 S 02/07/98 3-3/8" 4 11085- 11105 0 12/03/95 3-3/8" 4 11115- 11300 0 12/03/95 3-3/8" 4 11370- 11890 0 12/03/95 12148' —FISH-BK WOBBLE RING (LOST 12/13/95) PBTD H 10278' ••1,1,,/ 5-1/2"LNR 17#,L-80,.0232 bpf,0=4.89T H{ 12153' •4•�4.404 141.6.41 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/04/95 ORIGINAL COMPLETION 06/15/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18-34 05/21/01 RN/TP CORRECTIONS 09/13/03 CMO/TLP DATUM MD CORRECTION PERMIT Na:'1951640 01/09/02 TMNYKK SET HES FAS DRLL RUG 10/28/03 ATDrTLH PC&TBG LEAK&141 CMT API No: 50-029-22611-00 01/12/02 DTR/tlh FISH(CATCHER w/SAND) 11/09/03 DAV/TLP SET BAKER IBP SEC 24,T11 N,R14E,3589.41'FEL&1314.62'EN_ 02126/02 M-YKAK PULL FISH 12/11/11 DTR/TAD GLV 00(01/12102) 8/31-9/2/02 CS/JF/KK SET PKR;TBG PUNCH;CMT BP Exploration(Alaska) of T� • (y/,'s THE STAT Alaska Oil and Gas ofA LA S KA Conservation Commission 333 West Seventh Avenue : GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Beau Obrigewitch Well Integrity Engineer Sr 4t4ED IAN 2 alb b BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-34 Permit to Drill Number: 195-164 Sundry Number: 317-519 Dear Mr. Obrigewitch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this (3 day of December, 2017. RBnlS 4 2617 STATE OF ALASKA RECEIVED *LASKA OIL AND GAS CONSERVATION COMMI N Or} l'Zi 13) it APPLICATION FOR SUNDRY APPRO NOV 0 2 2617 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 g )nOt (i�(1i.,��f[�j] Suspend IZI • Perforate ❑ Other Stimulate 0 Pull Tubing0 Chan A ( Ge Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 195-164• 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p• 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-22611-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 18-34 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028307&028321• PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12153 8703 6594 5873 6594,8607,8870,9180 11050,12148 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 38-118 38-118 1490 470 Surface 3938 10-3/4" 38-3975 38-3640 5210 2480 Intermediate 9367 7-5/8" 36-9403 36-8241 8180 5120 Production Liner 2904 5-1/2" 9249-12153 8111-8703 7740 6280 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11085-11890 8718-8699 4-1/2"12.6# L-80 34-9229 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 9171/8046 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary IZI Wellbore Schematic El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Il ' Service 0 14.Estimated Date for Commencing Operations: November 15,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL ❑ Suspended IZI • 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch,Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Name: Obrigewitch,Beau Contact Phone: +1 907 564 4654 Authorized Title: Well Integri Engin er Authorized Signature: • ff., Date: 11 041 l' ICOMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ,^ 377 - 5! `1 Plug Integrity prBOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: i,-1U i , 6-/C.) C V P-Y1 vJ ±— • Post Initial Injection MIT Req'd? Yes 0 No lJ Spacing Exception Required? Yes 0 No Ii, Subsequent Form Required: /D _ 407. APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:iZ IC;)14 3 1/"TL l2/./)7— \ili ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • bp 460400 18-34 Reservoir Abandonment/ Surface Plug / Suspend Well Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Christopher Stone (907) 564-5518 Estimated Start Date November 15, 2017 History Greater Prudhoe Bay Well 18-34 was initially drilled and completed in 1995. The well was selectively producing from Zone 1A and it was a producer for all its life. It produced approximately 1.5 MMbbl until made Not Operable and shut-in due to IA repressurization. - An LDL ran in July 2001 identified a leak in the 7-5/8" Production Casing at 6,900'. Water samples indicated the water is LPC injection water, confirming a cretaceous leak. Later in early 2002 cement was circulated into the IA from the tubing, and then pumped down the IA from surface into formation in an attempt to repair the PC Leak. An MIT-IA passed to 2,000 psi but the MIT-T failed with a LLR = 6.6 gpm. Another LDL was run in 2003, this time confirming a leak in the Tubing at 6,900', and the PC Leak appearing at the same location. A Slim Cement Mapping Tool log was also run, confirming cement in the IA from 4,900' to 6,800'. The well was secured on 11/09/2003 with an IBP set at 6,600', changing its status to Long Term Shut In. The IBP was positive pressure tested on 12/09/2011 with a passing CMIT-TxIA to 2,200 psi, confirming the well is secure. Meanwhile, the IA continues to exhibit repressurization behaviour, currently ast •ilizin out_ar..ound 1,05.0..psi. This pressure increase is thought to originate from the PC leak even though the IA passes a pressure test. In September 2017, in support of the Suspension wellwork, an attempt was made to pull the IBP from 6,600'. The IBP was tagged at 6,576' SLM, indicating it had not migrated since being set, and it was equalized. Slickline was unable to retrieve the IBP to surface after multiple attempts, but was able to push it downhole to 7,409' SLM. The bottom-hole reserves produced well have been accessed by another ebore_andhecst of repang' 8 34 bysetrakiagdrestoring the surface kit exceeds the cost of drilling a new well. Therefore, knowing the risks posed by the current conditions of this well the safest logical conclusion is to suspend it. Objective Attempt to push the IBP further downhole, clean out suspected asphaltines with diesel/xylene, punch the tubing, and place a deep cement plug in the tubing and across the IA. Down squeeze the OA, shoe to surface. Punch the tubing and place a surface cement plug above the downhole safety valve. Cut off all casings and wellhead -1' below pad level. The well will remain in suspended status until the final _/ removal of the casings and welding of marker plate 3' below the original Tundra level. • • Procedural steps Fullbore 1. Perform injectivitey test down OA with diesel to max pressure of 1,200 psi. Coiled Tubing 2. Rig up to drift/tag and push IBP. WSL and Coil Superintendent discretion as to the size of the nozzle/BHA. Slickline left the IBP at 7,409' SLM on 9/21/17. It is desired to push the IBP deep enough to tubing punch at 7,525'. If IBP does not move deeper, or does not move easily, it is acceptable to leave it where it is, or ends up after attempting to push. 3. Clean out well with -100 bbls diesel/xylene. Preference is to take returns to production through neighboring well flowline, but flowback tanks may be required. Diesel/xylene returns from downhole are E&P exempt and can be taken to FS1 or GC2 Hydrocarbo Recycle, or GNI if solids are a concern. Any excess diesel/xylene that is not returned from downhole will be taken to FS1 Hydrocarbon Recycle. 4. POOH, displacing with diesel to keep tubing full of diesel to surface. 5. Ensure that any flowline used to flow back returns is freeze protected as appropriate. 6. Drift and tag IBP with larger nozzle (drift O.D. to be based on O.D. of tubing punch and cement squeeze packer). 7. Paint coil flag at final IBP tag depth. 8. Run 5' Tubing Puncher just above IBP. 9. Cement IA and Tubing as Follows: • Make up and run in with Weatherford One-Trip squeeze packer to -10' above tubing punch. • 10 bbls freshwater spacer • 19 bbls class G cement through tubing punch, into IA, holding pressure on CT x Tubing annulus, to mitigate against cement migration into tubing. Circulate cement up IA to PC leak at 6,900' and unsting from packer. • 42 bbls class G cement while pulling out of hole, laying cement in tubing to -4,750', taking one- for-one returns. There is a known tubing leak at 6,900', providing direct communication with the Cretaceous through the PC leak in the same area. The diesel and cement in the wellbore will be underbalanced to the Cretaceous, with CT x Tbg annulus surface pressure expected to be -930 psi with TOC at 4,750' MD. Note CT x Tbg annulus pressure. • 5 bbls freshwater spacer • Diesel, as needed for displacement and cleanup of coil, leaving diesel from TOC to surface. It is important to maintain constant pressure on the CT x Tbg annulus, to prevent the Cretaceous from flowing and to avoid squeezing cement through the tubing and casing holes into formation. • If needed, return to surface for final cement equipment cleanup. • Once cement reaches 500 psi compressive strength, RBIH with nozzle and displace diesel from TOC with 9.8 ppg brine. Leave -1,000' diesel for surface freeze protect in tubing. Note: These cement volumes are calculated from the desired tubing punch depth of 7,525', and assume IA does not have cement stringers or other capacity-reducing restrictions. Cement Calculations - Cement Plug #1 (Deep Tubing/IA Plug) 7-5/8" x 4-1/2" volume from 7,525' MD to 6,800' MD (0.0262 bpf) 19 bbls 4-1/2" volume from 7,525' MD to 4,750' MD (0.0152 bpf) 42 bbls Total Cement to Pump (10 bbls excess) 71 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab+/-0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc(20-100 cc/30 min) Compressive Strength 2000 psi in 48 hrs 2 • • r Thickening Time Minimum 5 hours 1 Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 2 Minimum required thickening time: 5 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 30 140 2250 0:45 45 160 2075 1:00 60 160 2075 1:15 71 160 2075 2:00 71 160 2075 3:00 71 160 2075 4:00 71 160 2075 5:00 71 160 2075 Slickline & Fullbore 10. Drift and tag TOC with sample bailer. Notify AOGCC Inspector of the timing of the Cement plug tag and pressure test (24 hour minimum notice). 11. CMIT-TxIA to 2,500 psi. If fails perform MIT-T and MIT-IA to 2,500 psi. If the MIT-T or MIT-IA fail, attempt to get LLR, RDMO. 12. Bleed all Wellhead Pressures to 0 psi. DHD 13. Monitor Wellhead Pressures after at least 24 hours has elapsed since the pressures were bled to 0. Note: If either of the MITs fail, or if the Wellhead pressure builds up during the 24 hr monitor period, call Intervention Engineer for a plan forward. Valve Shop 14. Drop OA Gate Valve and install integral Valve. Fullbore / Special Projects 15. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash up water diverted upstream of the OA. Mix cement on the fly. Pump the following schedule at maximum rate below 1200 psi treating pressure (or max OA injectivity test pressure). • 10 bbls of 60/40 or 10 bbls neat MEOH • 80 bbls hot surfactant wash (180°F FW + 2 gal/bbls of F103 and 2 gal/bbl of U067) • 10 bbls of 13.5 ppg MUDPUSH II Spacer • 20 bbls of neat cement 3 • • • 50 bbls of cement with 15-ppb aggregate • 120 bbls of neat cement 16. No displacement behind cement. Slow rate to -1 bpm as aggregate gets to the casing shoe. (-180 bbls of cement away/10 bbls left to pump). Swap to take returns from upstream of the OA while still on cement (S/D pumping as needed), and as the last couple of barrels are pumped (3-5 bbls left to pump). Ensure that returns are swapped to taking cement returns to surface before the last of the cement is pumped downhole to ensure nothing but cement goes down the OA. SI the OA and flush lines through a different route than down the OA. Note that the OA may be on a vacuum and may suck any wash up water that is pumped across the OA down into the OA if allowed to do so. 17. At WSL discretion, a small amount of diesel can be pumped through the valve, and into the OA, to clean the valve. Keep in mind if diesel is pumped into the OA, it will likely be present when the wellhead is cut off in the last step of this program. Grease valve. Cement Calculations - Cement Plug #2 (Fullbore OA Down Squeeze) 10-3/4" x 7-5/8" volume from 3972' MD to surface (0.0397 bpf) 158 bbls Total Cement to Pump (32 bbls excess) 190 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/-0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc (20-100 cc/30 min) Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 150 90 3100 1:00 190 80 3260 2:00 190 70 3260 3:00 190 60 3260 4:00 190 50 3260 5:00 190 40 3260 Note: The following steps assume Fullbore was able to down squeeze the OA. If that attempt was unsuccessful, a revised program will be submitted to cement the OA, IA and Tubing in one rig-up. 4 • • E-Line 18. Punch 4-1/2" tubing at -2,700' MD. Special Projects 19. Injectivity test down the control line with hydraulic oil. 20. Cement control line w/ 1.2 gals of squeezecrete or finecem (-1300'). Reference small volume cement RP. If pump pressures allow (<5000 psi), fill the entire control line with cement (Control line is 1,060ft/gal; total displacement to 2171' MD is 2 gallons). DHD 21. Wait on cement 3 days and pressure test control line to 2,500 psi. Fullbore 22. Circulate cement down tubing and up the IA to cement both the IA and tubing from -2,700' to surface, per the following pump schedule: • 10 bbls 60/40 or 10 bbls neat McOH (WSL Discretion), taking returns from IA • 50 bbls hot surfactant wash (180°F FW + 2 gal/bbls of F103 and 2 gal/bbl of U067), taking returns from IA • 135 bbls 9.8 ppg brine until clean returns are observed, taking returns from IA • 5 bbls freshwater spacer, taking returns from IA • 122 bbls 15.8 ppg cement per design. Take returns from IA until at least - 5 bbls clean cement is returned. Cement Calculations -Cement Plug #3 (Fullbore IA and Tubing) 7-5/8" x 4-1/2" volume from 2,700' MD to surface (0.0262 bpf) 71 bbls 4-1/2" volume from 2,700' MD to surface (0.0152 bpf) 41 bbls Total Cement to Pump (10 bbls excess) 122 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab+/-0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc(20-100 cc/30 min) Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 90 90 1000 1:00 122 80 0 2:00 122 70 0 3:00 122 60 0 5 • • 4:00 122 50 0 5:00 122 40 0 phafo 4OC � U�-� Special Projects A/ h JCV ite CG n572-re -fo ss 71-hAs 23. Cut off all tubulars and wellhead —14 below pad level and top off cement in all tubulars. Install marker cap on outermost casing string. • Marker Plate to meet requirements in SOP: Through-Tubing Abandoment, Section 5.8: i. Minimum 1/4" Thick ii. Minimum 18" Diameter • Bead weld to the marker plate the following information: BP Exploration Alaska, Inc PTD: 195-1640 Well: PBU 18-34 API: 50-0229-22611-00 Note: The well will remain in suspended status until excavation, casing removal to 3' below original Tundra level, and marker plate welding occur at final pad remediation. 6 • • iife,e/ • Pre Job Schematic: TREE= FMC 1hH LHFAD- CNV SAFETY NOTES: RSH I 9148'(CATCHER SUB ACTUATOR= BAKER G • COVERED et/SILT/SAM/ PC 8 "TBG LEAK Ka.BEV= 53.r. (10x25/03) BF BEV= ' KOP= 1434' Max Angle= 94-11 11170~ 2171' H4-1/2"IES CP-2 TRSV SSSV NP,13=3-812' I Datum k0= NA TVD= 8800 SS CAItOGAS LFT M4.I4 S 10-3/4"r-c(,45.58,L-80,13=0.953" H 3972' I— ST ND TVD DEV TYPE _ V-V LATCH PORT DAM 1 4027 3684 32 K&MG-M Lam' BK 0 06/12101 [TOP OF Ct IMI N 1A 4982' • 2 6834 6076 32 KBMG-M `I& 8K 0 12/13/95 44 3 9100 7987 33 (9113-A BA-11Y - - 01/12/92 1114 04 • 'STA#2= BROKEN LATCH(12113195) — 14 ' BTLI OF C PMNT NIA — 88(10' I ..1: ♦4 PC 813G LEAK -$900' 44 Q__--1 7409'SLM -I3'BKR BP P1151-E1)(0921/17) 880T TOP OF caiEttir IN 4-1/2"TBG Minimum ID =3.725"ig 9201' 1 1 8870' FAs D LL SQZ F!(R 4-112" HES XN NIPPLE I .1.x.1.+.1! — 100./.4 1 8900.8910 113G PI-0401I�1111. Mil i 11/1,�y9167' —17-518'X 4-112"BAKI31 S-3 FKR,II3=3.875 Itaa ,..414.44 8180' HES FAS DILL PLUG,00=3.88'(01/08/021 I 9201' -°14-1/2"FES XN NP,ID=3.725" 4-1/2'TBG,12.68,L90,.0152 bpf,13=3.958" — 9225' J - 1-9225' —14-1/2'WLE ,13=3.958 -it3ME7 TT LOG NOT AVM.ABLE 1 TOP OF 5-1/2"LNR --f 9248' J 7-518'CSG,29.78,595,13=6.875' H 9801' _ A 11, ' Io4St2 PERFORATION SIJJ4LRY REF(OG 7-DFN ON 11/26/95 11050 P15*1,Rt8BER E., /I ANGLE AT TOP ESiF.86 10450 a FOM EP(LOST 02/20198) Note:Refer so Ptoducbon 08 for Historical pert data SEE SiF INTERVAL Opn/Sgz DATE 3-NB' 4 10450-11020 S 02/07/98 3-318" 4 11085-11105 0 12/03/95 3-318' 4 11115-11300 0 12/03/95 3318" 4 11370 11890 0 12/03/95 ' 12148' —FISH-BK 1NOBBLE RING (LOST 12113/95) P81D 10278' j 5-1/2"LNR,178,L-80,,0232 bpi,0=4.89r H 12153' 11141414.41+101 t €1ATF ' REV BY COSKENT'S I]ATF REV BY Com, PRICHOEBAY UHT 12104/95 ORIGINAL COM PLETION 06/15103 ChID/T1P KB ELEVATION CORRECTION VAELL: 1834 05121101 (NIP CORREC TICKS 09113/03 CIAO/TSP LATIUM)CORREC TION FERN No.'1951640 01/09/02 TMNKK SLUES FAS OWL I'LUG 10/28/03 A ILYIL11 FC8113G LEAK 4 IA(NII AR ND: 50.029-72611-00 01/12/02 . OTTellh FEiH(CATCFERw/SAND) 11/09/03 t]4V/T_PSET BAKER IBP SEC 24,T11N,R14E,3589.41'FEL&1314.67Fit 02/26/02 MA-VKAK RAI FISH 12/11/11 OTR'TAD GLV dO(01112102) 5/31 912102 CS/JF/KK SETFKR TBG PUNCH CMI 09127/17 JGUJIIO PUSFE3)SPIDH(09/21/17) Bp 61p1oratloa(Alaska) 7 • • Post Job Schematic: IREEr FMC VIlH LrEAD- pw SAFETY NOTES: RSH.9148"(CATCHER SUB _-.-_ 18-34 Suspended COWED w186_T/SAli7_ PC&TBG LEAK ACTUATOR= BAKER C KB.B fV= 5a7 (10/28193) OF.e.EV= ? Tubing Punch - KOP= 1434' __ 2,700' N. I�x Angle= 94 11170 2171' —4-112'NES cP2 TRW SSSV NP,D=3 517 J Datum MD= 14:,..A OA Down Sqz Q ^' Datum TVD= 8800,96 _Tubing and IA Cmt -- 2,700' Cmt - 3072' \ 41 \ cnnro 0,w,errNo�� 10-3/4"CSG 45.5#„L-80,D=9.953' H 397T I :-.i M) ' TVD DEV TYPE VLV LATCH Rf)R1 1 DATE 1 4027 3684 32 KBP(3-k1 (MY ' BK 0 06/12/01 TOP OF CEMENT IN IA H 4962' S - 2 6834 6076 32 KBML1 *easy BK 0 12/13195 ► t 3 9100 7987 33 ICBM,.M RFT( - - 01/12/02 ► ►►i� -STA#2= BROKEN LATCH(12/13/95) 8TM OF CE 4T W IA 6800' Iii. : ' Top of Cement in Tubing --4,750' I PC&TBG LEAK H -6900' }, ' Squeeze Packer- 7 515' I Top of Cement in IA 6,900' Tubing Punch 7,525' sair HTOPOFCEMENT 044-V2"T8G I 46446. Minimum ID=3.726"@ 9201' -.......-s I esro' HFAS DRILL SCE� 4-1/2" HES XN NIPPLE wow, 14141* 40 8900.8910 '• rzi►.4,►a►i,�1�i 1c 9167" H7_5,8-x 4-112-&AKER S-3/TCR.0=3.875 ►►+►"!�1►i I 9160' H HES FAS Mu.°UJG.00=3.66-(01/08/02) I I 1 9201' H4-1/2"HES XN NP,D=9.725" I 4-117 TBG,12.8#,L80,.0152 bpf,D=3.958' I--9225 9220' -14-112"w ,D-3.968 HELM:I TT LOG NOT AVALABLE I TOP OF 5-1/2'LFA!H 6249' 7-6/Y SVZ,20.7*,4-05.0-5.975• 0441'---1 I, FEFFORATIDNSLIA4ARY 11050' RSH-Rumex maim REF Lour z-DEN ON 11'56/95 i FROM BP(LOST 02/20/90) ANGLEAT TOP PERF:86 rig 10450' Nota_Rotor to Production DB for historical pert data SIZE SPF MSZVAL OpF/Sge CATE 3-38' 4 10450-11020 S 02/07/98 3-3/8' 4 11085-11105 0 12/03/95 3-3/8" 4 11115-11300 0 12(03/95 ' 3-318" 4 11370-11890 0 12/03/95 12148' —FISH-13K V1KJ68LE RNG (LOST 12/13195) r$it 102T3 1 ►►l, ►►4 5-1/7 LNR,175,L-80,.0232 bpf,ID 4.897 H 12133' 4►4►4�4r4��4r/ (ATE -'REV BY _ Oah& 4TS DATE REV BY COMENTS PRUDHOE BAY UNIT 12/04195 ORIGINAL COMPLETION Deo 15/C 3 4T1.9Y1LP'i'B LLEV C.114N C4PPid_'TY�M V14ZL: 18-34 05/21/01 RWTP CORRECTIONS 09/13/03 CMDTTLP DATUM M7 CORRECTION F13?141 Pb:'1951640 01/09/72 IM'SKK SET HES FAS DRILL PLUG 10128/03 A TLYTLH FC&ii3(.)LEAK 3,I4 c M AM Pb: 50-029-22611-00 01/12/02 DTR* RSH(CA TOUR w/SAND) 11'109/03 DAV/TLP SET BAKER EP SEC24,T11f0.R14E 3589.41'FE.81314.62 FN. 02/26/02 MH!KAK PULL FISH 12011/11 DTRTAD GLV 00(01/12102) 8/31-912102 CS/JF/KK SETPKR TBG PlkEtt CMT BP Exploration(Alaska) 8 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, November 28, 2017 9:41 AM To: 'Obrigewitch, Beau' Subject: RE: PBU 18-34(PTD 195-164, Sundry 317-519) Suspend/Cement to Surface Beau, For the first cement plug,could the TOC be tagged while coiled tubing is rigged up versus tagging with slick line?A coiled tubing tag is preferred over a slick line tag. Thanx, Victoria From:Obrigewitch, Beau [mailto:BEAU.OBRIGEWITCH@bp.com] Sent: Monday, November 27,2017 10:53 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU 18-34(PTD 195-164,Sundry 317-519)Suspend/Cement to Surface Victoria, Thank you for reviewing our application for Sundry Approval to Suspend Well 18-34. The most likely source of the IA repressuriation is the PC leak,with communication across the IA plug.This plug was pumped from surface,down the IA, in 2002.We no longer place these plugs in this manner,as our experience has proven we get better isolation by squeezing from the tubing and up the IA. We would prefer to not tag the TOC in the tubing with Coiled Tubing,as this would require an additional CT rigup a minimum of 3-5 days after pumping the cement plug.The difference between tagging with Coiled Tubing vs Slickline is that CT could stack a few thousand pounds of weight,while Slickline could only tag/stack a few hundred pounds.This plug,since it is being placed by CT,along with a cleanout/contamination run,gives us high confidence the TOC will be where it is designed to be,and there will be no cement stringers or dams to hang up a Slickline drift and tag. Please let me know if I may be of further assistance. Kind Regards, Beau Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska)Inc. Hanging Out In 740C Office: (907)564-4854 Cell: (907) 952-6271 Y M "ba(men,Ofil.tnu.1M14 1 • • • From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Monday, November 27,2017 9:44 AM To:Obrigewitch, Beau<BEAU.OBRIGEWITCH@bp.com> Subject: PBU 18-34(PTD 195-164,Sundry 317-519)Suspend/Cement to Surface Beau, What do you think the source of the current IA repressurization is? If it's from the PC leak at—6900'MD, is there communication across the IA plug("2000' MD height)? Can the TOC in the tubing("4750'MD) be tagged with CT? What is the difference in tag weight between the CT and slickline? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�.alaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loegq@alaska.gov • 2 • • xN N , Thousand Cubic Feet of Gas ("MCF") per Month MN o , O —, m O O '.h. , O O O O 0 p O O O O O N O O �I O O O O O O m _., rl .-1 ,i rl ,1 W _ 1 Tr fill - � o tID 7� s't's Yee a !� O 111 !!1cnr Lo G1 111 I Pr g >co i Cr M I 3 vl V el-1 1 E/ ° I 1 ' 3 a O 1 Y G U Z 3 0 p I �4 1 Q w LU J 2 Q LIJ 2 1J c • • Y. Ce a1 • ..."'..-,.../ / .1. i L-• e ra Om } ° � 4 1, V C ! I a Q ° . t LA a a «—.' J °. '- • _ 86.r o Q cp i • Pl e, 11Z , .., 1 -i-- O ° <-6,.., s0° sroP I a° � / Oa , Ute// -I =2O CL 3 csl`P, W 3 iI ssr. O O O O O O 4Pr O O O O O r-1 O OO O •-1 O O O ei O O a-1 O ei' a--1 1111.101A1 aad aaleM to siaaae8 Jo LOOM Jed HO to sue yOF ? • • \\ //7„ 6 THE STATE Alaska Oil and Gas ®f C mnservation Commission WI _- 333 West Seventh Avenue ' GOVERNOR BILL WALKER ' Anchorage, Alaska 99501-3572 0 � Main: 907.279.1433 ALAS r. Fax: 907.276.7542 www.aogcc.alaska.gov December 15, 2016 Ryan Daniel Well Integrity Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 �� NE® CSAR 3 1 2-017'Anchorage, AK 99519-6612 Re: Docket Number: OTH-16-038 Prudhoe Bay Unit(PBU) Well Plug and Abandonments for 2017 By letter dated November 2, 2016, BP Exploration (Alaska), Inc. (BPXA) proposed a multi-year well plug and abandonment(P&A) program. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A program for the wells listed below for the calendar year 2017. 1. V-201 Rig P&A 2. J-26 Non rig P&A 3. R-01 Non rig P&A 4. C-38 Non ri P&A /f tasttoLto Non lit P: 6. 05-18 Non rig P&A Ir This program was developed as an alternative to P&A's required due to the suspension expiration this year of 18 wells (20 AAC 25.110). BPXA has proposed a level loaded P&A program that prioritizes all P&A candidates based on well mechanical condition and the associated risks with impaired barriers. The wells are assumed to have no future utility to be considered P&A candidates. The process proposed for development and AOGCC approval of the P&A program for future years is described as follows. Prior to or during the fourth quarter of each year, BPXA will propose to the AOGCC the P&A candidates for the upcoming calendar year as well as a plan for the two subsequent years. The AOGCC will review the proposal considering number of P&A's proposed, the number of rig decompletion P&A's planned versus non rig P&A's as well as the P&A well stock composition and number. The pace of the P&A program approved by the AOGCC may require adjustment based on the number and status of P&A stock wells. BPXA has the option to return to performing the required P&A's based on suspension expiration date if agreement cannot be reached on the level loaded pace and composition. Docket Number:OTH-16-038• • December 15,2016 Page 2 of 2 Approximately 90 wells are suspended and will require P&A in the next 10 years. To facilitate the level loaded approach based on risk, the AOGCC is requesting that the following information for suspended wells be provided in table format before March 31, 2017. 1. Well name 2. Permit to Drill (PTD) number 3. Date suspension expires 4. Mechanical condition of the well 5. Qualitative assessment of risk 6. Future Utility 7. Rig decompletion required for P&A or nonrig P&A 8. Comments It is understood that this table will be dynamic and updated as information becomes available. It is recommended that BPXA start the annual process well in advance to allow co-owner review and approval of AOGCC requirements prior to year end and to also allow the P&A's to be accomplished during the following calendar year. Please direct any comments or questions to Victoria Loepp at Victoria.loeppnalaska.gov. Sincerely, a:4i°9244-1(4----- Cathy P. Foerster Chair, Commissioner • bp BP Exploration(Alaska)Inc. Ryan Daniel,Well Integrity Engineering Team Leader Post Office Box 196612 Anchorage,Alaska 99519-6612 November 2nd, 2016 Cathy P. Foerster Commission Chair Alaska Oil and Gas Conservation Commission 333 West 7"'Avenue Anchorage, Alaska 99501 Subject: Request for approval to implement well plug and abandonment strategy Dear Chair Foerster, BP Exploration (Alaska) Inc. (BPXA), as operator on behalf of the Prudhoe Bay Unit (PBU) working interest owners, requests approval to implement a multi-year well plug and abandonment(P&A) program in lieu of AOGCC requirements regarding P&A of certain observation and suspended wells. Currently, AOGCC sundry approvals and other orders require P&A plans of the wells listed in Attachment 1 by the end of 2016. BPXA requests approval, in lieu of that requirement, to institute a multiyear level loaded P&A program that prioritizes P&A well candidates based on: (a) well future utility benefiting PBU hydrocarbon recovery, and (b)well mechanical condition and associated risk factors. Two technical meetings have been held with AOGCC engineering staff members in the last few months to review the proposed P&A program. Subsequently, AOGCC Senior Petroleum Engineer Victoria Loepp requested, by email on 9/20/2016, submission of a written request. If the AOGCC approves this request, then BPXA will submit a 3 year forward looking P&A plan to the AOGCC in the 4th quarter of every year. The plan would include a review of the status of the previous year's plan. The wells listed in the P&A plan could change from year to year, as the well population is dynamic in nature, and assessments of future well utility benefiting PBU hydrocarbon recovery and well conditions and risk factors may change with time. • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 2 of 6 BPXA proposes, as the initial annual P&A plan, the following: Year 1: To be scheduled in the 2017-2018 time frame List Well Name Well Status Scope 1 V-201 Suspended Rig P&A 2 J-26 Not Operable Non Rig P&A 3 R-01 Not Operable Non Rig P&A 4 C-38 Not Operable Non Rig P&A 5 18-34 Not Operable Non Rig P&A 6 05-18 Not Operable Non Rig P&A Year 2: To be scheduled in the 2018-2019 time frame List Well Name Well Status Scope 1 B-02 Suspended Rig P&A 2 05-18 Not Operable Non Rig P&A 3 15-03 Not Operable Non Rig P&A 4 15-10 Not Operable Non Rig P&A 5 18-25 Not Operable Non Rig P&A 6 13-10 Not Operable Non Rig P&A Year 3: To be scheduled in the 2019-2020 time frame List Well Name Well Status Scope 1 G-03 Not Operable Rig P&A 2 H-04 Not Operable • Non Rig P&A 3 N-03 Not Operable Non Rig P&A 4 D-27 Not Operable Non Rig P&A 5 Y-12 Not Operable Non Rig P&A 6 Y-08 Not Operable Non Rig P&A While it is BPXA's intention to P&A these wells as scheduled, efforts may be impacted by well status changes and by environmental and other risk factors and restrictions affecting the P&A program. A multiyear level loaded P&A program ensures that BPXA has the flexibility to preserve well stock that has potential future utility benefiting PBU. It is also both more efficient in terms of implementation and execution over time with available contractor Rig/Non Rig intervention equipment and workforce, and establishes a more "fit for purpose" and risk based approach to end of life well stock management. For information purposes Attachment 2 contains a list of all currently suspended PBU wells. . . BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 3 of 6 In summary, BPXA believes the proposed multiyear level loaded P&A strategy provides a more beneficial, efficient and risk based approach to management of "end of life" well stock than a P&A strategy based on suspended well renewal dates. BPXA respectfully requests AOGCC approval to implement the proposed P&A program in lieu of progressing the P&A plans for wells listed in Attachment 1 by the end of 2016. If you have any questions, please call me at 748-1140 Sincerely, Ryan Daniel BPXA Wells Integrity Engineering Team Leader • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 4 of 6 Attachment 1: AOGCC Required P&A list List Well Name Well Status Scope 1 BP-03-11-13 Observation Non Rig P&A 2 BP-01-10-14 Observation Non Rig P&A 3 BP-02-10-14 Observation Non Rig P&A 4 BP-11-10-14 Observation Non Rig P&A 5 BP-17-10-15 Observation Non Rig P&A 6 BP-13-10-14 Observation Non Rig P&A 7 BP-14-10-14 Observation Non Rig P&A 8 BP-19-10-15a Observation Non Rig P&A 9 BP-19-10-15b Observation Non Rig P&A 10 BP-19-10-15c Observation Non Rig P&A 11 WGI-01 Suspended Non Rig P&A 12 2-30 Suspended Non Rig P&A 13 G-13 Suspended Non Rig P&A 14 V-201 Suspended Non Rig P&A 15 S-14 Suspended Non Rig P&A 16 W-09 Suspended Non Rig P&A 17 Y-25 Suspended Non Rig P&A 18 J-30 Suspended Non Rig P&A • • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 5 of 6 Attachment 2: Suspended well list dated 24th Oct 2016 Suspended Wells-AOGCC Suspend BP Exploration (Alaska) Inc Suspended Number: Renewal Wells Expires: PRUDHOE BAY UNIT K-13 1871010 1/6/2020 PRUDHOE BAY UNIT B-02A 1961110 3/1/2020 PRUDHOE BAY UNIT 04-12 1780180 3/15/2020 PRUDHOE BAY UNIT Y-22A 1881150 9/2/2020 PRUDHOE BAY UNIT R-36 1941440 9/2/2020 PRUDHOE BAY UNIT H-12 1800670 9/2/2020 PRUDHOE BAY UNIT U-01 1920110 9/2/2020 PRUDHOE BAY UNIT H-10A 1971900 9/2/2020 PRUDHOE BAY UN LIS L3-01 1890750 9/3/2020 PRUDHOE BAY UNIT Y-37A 2020460 9/27/2020 PRUDHOE BAY UN WBH WBST 03 1760340 9/27/2020 W BEACH ST 1-A 1860560 9/27/2020 PRUDHOE BAY UNIT 07-27 1870820 9/27/2020 PRUDHOE BAY UN PTM 12 1910370 9/27/2020 PRUDHOE BAY UNIT S-10A 1911230 11/2/2020 PRUDHOE BAY UN PTM P2-55 1920820 11/2/2020 PRUDHOE BAY UN MA NK-41A 1971580 11/2/2020 PRUDHOE BAY UN NIA NK-11A 2020020 11/2/2020 PRUDHOE BAY UNIT 04-04A 1950240 11/19/2020 PRUDHOE BAY UNIT 14-39 1881380 11/20/2020 SOURDOUGH 3 1960080 1/5/2021 PRUDHOE BAY UN BORE 02-01 1980350 1/5/2021 PRUDHOE BAY UN NWE 04-01 2020520 1/5/2021 PRUDHOE BAY UNIT 06-17 1820900 3/4/2021 PRUDHOE BAY UNIT A-41 1941580 3/18/2021 PRUDHOE BAY UNIT H-15 1810610 3/30/2021 PRUDHOE BAY UN PBU L2-18A 1981060 9/7/2021 PRUDHOE BAY UNIT 15-47 1951740 12/24/2021 PRUDHOE BAY UNIT 09-44/09-44A 2091570 3/19/2022 PRUDHOE BAY UNIT OWDW-SW 1002380 4/9/2022 PRUDHOE BAY UNIT F-11 B 2041940 5/27/2022 PRUDHOE BAY UN LIS LGI-08 1860570 9/5/2022 PRUDHOE BAY UNIT 13-05 1811030 11/24/2022 • • BPXA Request for Approval to Implement P&A Program November 2nd, 2016 Page 6 of 6 PRUDHOE BAY UNIT 07-10 1980160 12/13/2022 PRUDHOE BAY UNIT 04-26 185314 6/16/2023 PRUDHOE BAY UNIT Y-02 2011730 9/24/2023 PRUDHOE BAY UNIT 09-07 1990220 2/26/2026 DRILLPAD Z NO 08A 1931280 10/2/2023 PRUDHOE BAY UN LIS L4-02 1891040 11/14/2023 PRUDHOE BAY UNIT Z-70 2131330 1/18/2024 E BAY STATE 1 1740060 4/24/2024 PRUDHOE BAY UNIT 13-98 1822070 4/24/2024 PRUDHOE BAY UNIT M-05A 1970810 6/6/2024 PRUDHOE BAY UNIT 18-09 1980790 7/7/2024 PRUDHOE BAY UNIT G-30 2091510 7/27/2024 PRUDHOE BAY UNIT Z-68 2130930 8/26/2024 PRUDHOE BAY UNIT F-12 . 1791070 7/1/2025 PRUDHOE BAY UNIT 15-24 1911280 9/11/2025 AURORA UNIT S-108 2011000 9/11/2025 PRUDHOE BAY UNIT Y-38 1950460 9/11/2025 PRUDHOE BAY UNIT WGI-01 1790310 , 10/31/2025 PRUDHOE BAY UNIT 02-30B 2001260 10/31/2025 PRUDHOE BAY UNIT G-13A 2001630 10/31/2025 PRUDHOE BAY UN ORIN V-201 2012220 10/31/2025 PRUDHOE BAY UNIT S-14A 2040710 10/31/2025 PRUDHOE BAY UNIT W 09A 2041020 10/31/2025 PRUDHOE BAY UNIT Y-25A 2081400 10/31/2025 PRUDHOE BAY UNIT J-30 2140750 11/17/2025 PRUDHOE BAY UNIT E-18B 2041390 12/31/2025 PRUDHOE BAY UN NIA NK-14A 2060310 12/31/2025 DRILLPAD I NO 100 2050100 12/31/2025 PRUDHOE BAY UNIT 04-07 1750770 3/29/2026 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. z¢ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~ianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well r MPI-09 MPI-09 .;zÙQ - {\..) J .~_ '. ~I-Q.~T--- 0 îL~ 'NK-08A lj NK-08A 18-34 i"Ç'" i(,l.{ 04-05A j (j.~.. ¡ 3 k 18-05A '1(.). -.1. t q 07-36 Î Q'7 - ( ~ 'I 14·36 16' J '. I (.] C-13A I q 7 - ; '1 J U-12 18S--fjJ... R-21 j Šj '. I .1.. t) R-12 í93 -. 0; .)" E-16 /SC - c' J J-23 I 8 7... C J I F-31 I..~ ~ - / ') 7 H-35 q ç - J l.f q Job# 10563225 10980572 10772241 10560316 10703956 10564525 10703939 10563112 10866557 10564527 11075900 10674388 10687647 10564529 10663003 10703943 10563217 10563216 Log Description. INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PSP GLS PPROF WIDEFT PSP LDL PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG INJECTION PROFILE MEM PROD & INJECTION PROFILE LDL PRODUCTION PROFILE PSP PPROF W/GHOSTIDEFT PRODUCTION PROFILE SBHP SURVEY SBHP SURVEY PPROF W/GHOST PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ) ( ;V'V (,L v¡ y MNN=r ::-.~ -_~. ~J!) S;:;q d ..~. ..1:.0 v '\ (,Zt'í' ).-- Date 10/05/03 06/09/05 04/04/04 10/22/03 11/27/03 09/27/03 10/24/03 10/13/03 07/14/04 09/29/03 07/05/05 10/27/07 09/20/03 10/01/03 03/10/04 10/28/03 09/28/03 09/27/03 ~l.· R 2005 - I.; 07/20/05 \ 12f,.~"'. ¡ (0. i' NO. 3438 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /) J J : Received bY:!.~ ^'. "-/ -' ('I I j I. ¡)U~·,- \...- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _ IA CEMENT SQZ Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 54 feet 3. Address Exploratory__ 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 1619' FNL, 48' FEL, Sec. 24, T11 N, R14E, UM (asp's 691729, 5960248) 18-34 At top of productive interval 9. Permit number / approval number 1777' FNL, 796' FEL, Sec. 19, T11N, R15E, UM (asp's 695941, 5960199) 195-164 At effective depth 10. APl number 1727' FNL, 1842' FEL, Sec. 19, T11 N, R15E, UM (asp's 694893, 5960222) 50-029-22611-00 At total depth 11. Field / Pool 1315' FNL, 3592' FEL, Sec. 20, T11 N, R15E, UM (asp's 698410, 5960726) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12153 feet Plugs (measured) Tagged top of CMT @ 7527' SLM (09/10/2002) true vertical 8703 feet FAS Drill SQZ Pkr @ 8870' HES FAS Drill Plug r,¢ 9180' Effective depth: measured 7527 feet Junk (measured) Fish (Rubber Element) @ 11050' (02/20/1998) true vertical 6666 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 115' 20" 260 sx Arctic Set (Aprox) 150' 150' Surface 3937' 10-3/4" 1140 sx PF 'E', 375 'G', 3972' 3638' 260 PF 'C' Intermediate 9366' 7-5/8" 239 sx 'G', 290 sx 'G' 9401' 8240' Liner 2904' 5-1/2" 300 sx Class 'G' 9249' - 12153' 8112' - 8703' Perforation depth: measured Open Perfs 10450'-11020', 11085'-11105', 11115'-11300', 11370'-11890' true vertical Open Parrs 8711'-8719', 8718'-8716', 8716'-8708', 8707'-8699' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 9167' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 9225' MD. Packers & SSSV (type & measured depth) IA Cement Packer from 4962'-9167'. 7-5/8" x 4-1/2" Baker 'S-3' Packer @ 9167'. 4-1/2" HES CP-2 TRSV SSSV Nipple @ 2171' MD. ~it ~ ~" ~ l V E~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 0CT 0 42002 14. Representative Daily Average Production or Iniection DAta 01L~ (~1~.~011~ C01]l~fli§§i0r~ Oil-Bbl Gas-Mcf Water-Bbl~'j~i~ uasl/~Cl ~ress~J¥8 Tubing Pressure Prior to well operation Shut-In Al'101i0rl~[lt~ ' Subsequent to operation Shut-In 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 is true and correct to the best of my knowledge. DeWayne R. Schnorr~~ ~ Prepared b~/DeWar/ne R. Schnorr 564-5174 SCANNED NOV 0 5 002 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE O7/29/2OO2 O8/O7/2OO2 08/1 O/2OO2 O8/2O/2OO2 08/21/2OO2 O8/29/2OO2 08/31/2002 09/01/2002 09/O2/2OO2 09/05/2002 O9/O7/2OO2 09/1 O/2OO2 09/1 O/2OO2 09/11/2002 O9/23/2OO2 07/29/02 08/07/02 08/1 O/O2 O8/2O/02 O8/21/02 O8/31/O2 18-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CEMENT SQUEEZE: DRIFT/TAG ANN-COMM (AC-EVAL AND REPAIR): AC-FLUID LEVEL CEMENT SQUEEZE: RST / CNL / PNL ANN-COMM (AC-EVAL AND REPAIR): AC-MITT CEMENT SQUEEZE: SSSV C/O OR STROKE T/I/O = 2200/2140/0. TBG FL @ Surface. (Prep for TBG Punch). CEMENT SQUEEZE: PACKER PLUG; TUBING PUNCH CEMENT SQUEEZE: PACKER PLUG CEMENT SQUEEZE: CEMENT SQUEEZE T/I/O = 2250/2050/0, Monitor WHP's (post IA Squeeze). T/I/O = 2250/2000/0, WHP's (Post IA Sqz). ANN-COMM (AC-EVAL AND REPAIR): AC-MITIA CEMENT SQUEEZE: DRIFT/TAG ANN-COMM ANN-COMM EVENT SUMMARY TAGGED FILL ABOVE HES FAS DRILL PLUG @ 9150' WLM W/2 25 CENTRALIZER. NOTE: HOLD OPEN SLEEVE IN TRSV @ 2161'WLM. ID = 3.00". <<< RDMO. WELL LEFT SHUT IN. >>> T/I/O = 2100/2160/0. SHOT TUBING AND IA FLUID LEVELS (PRE-RST) AS FOLLOWS. TUBING @ 552' AND IA FL @ SURFACE. RAN RST GRAVEL PACK LOG TO LOOK FOR FILL IN IA. LOGGED A BASE GR PASS WITH NEUTRONS OFF FROM 9140 TO 6500 AT 6000 FPH, MADE 2 PASSES WITH NEUTRONS ON FROM 6500 TO 9140 AT 6000 FPH THEN MADE A DOWN PASS AT 426 FPH WITH NEUTRONS ON FROM 6800 TO 7050 AND 8500 TO 9140. FOUND FLUID INTERFACE IN IA AT 6870 AND IN TUBING AT 6960. FILL IN IA FROM 9010 TO 9100. PUMPED 20 BLS OF METHANOL DOWN THE TUBING AT 0.3 BPM FOR AN INJECTIVITY RATE OF 0.3 BPM AT 3000 PSI. PULL HOLD OPEN SLEEVE \ RUN FLAPPER CK. CYCLE TRSV SEVERAL TIMES LOOKS GOOD (WELL SHUT IN ) MADE 2 RUNS. RUN 1 - RIH WITH 10' TUBING PUNCHER - 4 SPF, 0 DEG PHASE, PJ-1564, 1.56". PUNCHED TUBING FROM 8900-8910' MD. POOH. RIH RUN 2 - BAKER 10 SETTING TOOL WITH HALLIBURTON FAS-DRILL SQUEEZE PACKER FOR 4.5" TUBING. SET DOWN ON CLOSED SSSV, POOH, CYCLED SSSV, RIH TO GLM @ 9100' DMD, CORRELATED AND SET SCANNED ~"~0~/ a ~ ?002 Page I 18-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/31/02 (continued) PACKER @ 8870' MD. POOH. TRIED UNSUCCESSFULLY TO BLEED OFF TUBING PRESSURE AT SURFACE. RDMO, PAD OPERATOR NOTIFIED OF WELL STATUS. 09/01/02 VERIFY SHUT IN OF HES PUMP THROUGH PACKER. 09/02/02 CEMENT SQUEEZE- MIRU DS CTU #5 FOR STANDBY CLEANOUT. RIG UP CEMENTERS. PUMPED 125 BBLS OF 13.8 PPG 'G' WITH 4% BENTONITE CEMENT DOWN TUBING. DISPLACED WITH CRUDE TO 8607', (4 BBLS ABOVE SQUEEZE PACKER). PUT 69 BBLS CEMENT BEHIND PIPE. SHUT-IN TUBING AT PIS TO KEEP CEMENT IN PLACE. PUMPED 67 BBLS (SAME CEMENT) DOWN IA. DISPLACED WITH CRUDE TO 4962'. PUT 18 BBLS OF CEMENT BEHIND PIPE, FOR A TOTAL OF 87 BBLS CEMENT BEHIND PIPE. OBSERVED A 160 PSI INCREASE IN lAP AFTER CEMENT ENTERED CRET. AND BEFORE SHUTTING DOWN PUMPING. TRAPPED 2384 PSI ON TUBING AND 1790 PSI ON THE IA. <<< JOB COMPLETED >>> 09/1 O/O2 1.) BLEED TUBING FROM 2250 PSI TO 1800 PSI. IA TRACKED FROM 2150 PSI TO 1850 PSI. 2.) BLEED IA FROM 1850 PSI TO 1250 PSI. TUBING PRESSURE WENT UP TO 2250 PSI. 3.) MONITOR PRESSURE FOR 30 MINUTES AND IA CAME UP TO 1380 PSI AND TUBING PRESSURE STAYED AT 2250 PSI. RDMO. 09/1 O/O2 TAG TOC @ 7527'. SLM. CEMENT WAS SUPPOSED TO BE @ 8607' MD. <<< STARTED DRIFT RUN WITH WHSlP AT 1800 PSI. AFTER COMPLETING THE RUN, THE WHSlP WAS 2200 PSI. >>> <<< NOTIFIED DSO, WELL LEFT SI >>> 09/11/02 T/I/O =2180/1720/0 MONITOR WIP'S (POST MIT-CA) 09/23/02 T/I/O = 2060/2000/VAC (TBG & IA FLs for J. Moore). INITIAL TBG @ SURFACE, INITIAL IA FL @ SURFACE. Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 20 METHANOL 300 2% KCL WATER 16 FRESH WATER 335 CRUDE 20 2.5# BIOZAN 192 13.8 PPG CEMENT (125 BBLS CEMENT DOWN TUBING, 67 BBLS CEMENT DOWN IA.) 885 TOTAL SCANNED i~0V 0 ~ 2002 Page 2 TREE = Frv~ WELLHEAD= ClW ACTUATOR= BAKER C KB. REV = 54' BF. ELEV = ? KOP = 1434' ..M,~..&n,.¢ ~....=... ~ ~ !~ !77. Datum MD = 12365' Datum TVD= 8800' SS I 10-3/4 " CSG, 45.5/¢, L-80, ID = 9.953" H 3972' TOP OF CEIVENT IN IA H 4962' 18-34 IMinimum ID = 3.725" @ 9201' [ 4-1/2" HES XN NIPPLE 4-1/2"TBG, 12.6#, L80,0.0152bpf, ID= 3.958" H 9225' I TOPOF5-1/2"LNR ~--~ 9249' 7-5/8"CSG, 29.7#, S-95, ID=6.875" ~ 9401' PERFORATION SUIV~ARY REF LOG: Z-DEN on 11/26/95 ANGLE AT TOP PERF: 86 @ 10450' Note: Refer to Production DB for historical perf data SIZE SPF INTB~VAL Opn/Sqz DATE 3-3/8" 4 10450-11020 S 02/07/98 3-3/8" 4 11085-11105 O 12/03/95 3-3/8" 4 11115-11300 O 12/03/95 3-3/8" 4 11370-11890 O 12/03/95 I H10278' I 5-1/2" LNR, 17#, L-80, 0.0232 bpf, D :4.892" H 12153' I · SAFETY NOTES: RSH @ 9148 (CATHER SUB COVERED w/SILT/SAND 2171' H 4-1/2" I-ESCP-2 TRSV SSSV NIP, ID: 3.812" 8607' t--I 8870' 8900-8910 ~--~ 9167' H 9180' H GAS LIFT MANDRELS TYPE IVLVlLATOHI ~O~TI DATE CA-KBMO-MI I BKI I CA-KBMe-MI I ~3K I J TOP OF CEMENT IN 4-1/2" TBG FAS DRILL SQZ PKR I TBG PUh~CH I 7-5/8" X 4-1/2" BAKERS-3 PKR, ID =3.875 HES FAS DRILL PLUG, OD = 3.66" 9201' 9225' H 4 -1/2"FESXNNIP, ID=3.725" ] H 4-1/2" TUBINGTAIL WLEG, ID= 3.958 I B_MD'I-rL (LOG NOT AVAILABLE) 11050' J-1 FISH- RUBBERELBVIENT I FROM IBP (LOST 02/20/98) 12148' H RSH- BK WOBBLERING '1 (LOST 12/13/95) DATE REV BY COIVIVII~qTS DATE REV BY COMMB'4TS 12/04/95 ORIGINAL COMPLETION 01/12/02 DTRAIh FISH (CATCPER w/SA ND) 01/10/01 SlS-Isl CONVBRTEDTO CANVAS 02/26/02 IVI-I/KAK PULL FISH 02/22/01 SIS-LG REVISION ~/31-9/2/0; CS/JF/KK SEI- PKR; TBG PUNCH; CMT 05/21/01 RNFI'P CORRECTIONS 01/09/02 TiVN/KK SET HES FAS DRILL PLUG PRUDHOE BAY UNIT WRL: 18-34 PERMIT No: 1951640 APINo: 50-029-22611-00 Sec. 24, T11N, R14E, 3589.41 FB. 1314.62 FhJ.. BP Exploration (Alaska) CANN=D NOV O 5 2002 oe. ] ARY 0.3 2001 .... STATE OF ALASKA · .~SKA OIL AND GAS CONSERVATION COMMIS~..,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2, Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _Z 54' RKB 3. Address: Explorato~/_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 3661' NSL, 48' WEL, Sec 24, T11 N, R14E, UM. 18-34 At top of productive interval: 9. Permit number/approval number: 3503' NSL, 4161' EWL, Sec 19, T11N, R15E, UM. 95-164 At effective depth: 10. APl number: 50-029-22611 At total depth: 11. Field/Pool: 3968' NSL, 1688' EWL, Sec 20, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12153 feet Plugs (measured) true vertical 8703 feet~j~ ; /~" Effective Depth: measured 12078 feet Junk (measured) true vertical 8703 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 260 Sx Arcticset 115' 115' Surface 3937' 10-3/4" 1140 Sx PF 'E' & 3972' 3638' 375 Sx Class G & 260 Sx PFC Production 9366' 7-5/8" 529 Sx Class G 9401' 8240' Liner 2904' 5-1/2" 300 Sx Class G 12153' 8703' Perforation Depth measured 11085 - 11105'; 11115 - 11300'; 11370 - 11890' Gel Squeezed: 10450- 11020' true vertical 8718 - 8716; 8716- 8708'; 8707- 8699' Gel Squeezed: 8711 - 8719' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tbg @ 9225' MD. ~:i-~;;;,;:; ..... ?.: ':'"; ;':.i!:;. · Packers and SSSV (type and measured depth) Baker S-3 Packer @ 9167' MD; HES CP-2 TRSV SSSV @ 2171' MD" 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1385 29455 0 1258 Subsequent to operation 885 8373 14 618 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil ._~ Gas Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~~ '~,"). ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 18-34 DESCRIPTION OF WORK COMPLETED MARASEAL GEL SQUEEZE FOR GAS SHUTOFF 2/5/98: MIRU CTU & PT equipment. RIH & set an Inflatable Bridge Plug in the 5.5" liner at 11050' MD. POOH. RD. 2/7/98: MIRU & PT equipment. Pumped a Fullbore Gel Squeeze to seal off a possible fault for Gas Shutoff, through the open perforation interval located above the Bridge Plug at: Pumped: 10450 - 11020' MD (Z1) Ref. Log: Z-DEN 11/26/95. a) 330 bbls of 80.0 F Seawater @ I - 4 bpm, followed by b) 197 bbls Crosslinked Maraseal Gel at 2.0 bpm, followed by c) 110 bbls Crude, followed by d) 10 bbls Diesel, followed by e) Shutdown. Placed 148 bbls of Maraseal Gel behind pipe at 2600 psi final squeeze pressure. Rigged down. 2/20/98: RIH w/CT & jetted out Gel from liner to Bridge Plug. element lost in hole. RD. Latched & POOH w/Bridge Plug minus the rubber 2/22/98: Attempted to fish rubber element; no recovery. Placed the well on production & obtained a valid well test. Oil rate decreased by 500 BOPD, but the decrease in the gas rate of 21082 MscfD resulted in a net incremental oil rate benefit of 554 BOPD. i 0 .... h. 0 7 0 ~ / 13 9 !:i; A. r" ',:: d r" ~/ 'v,/,:.:~ s t h e DAZLY '¢tEL..L c!'i~ch samp'ies weii cor'ed? )~,, ~ ~, ---. fO(.,?2 r" e q u. '¥ r"ed ? i'"1 () 0 F:! I I--I--I IM G S E !::t~/I 1-- E S To: State of Alaska June 14, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 18-34, AK-MW-50114 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 18-34: 2" x 5" MD Gamma Ray Logs: 50-029-22611-00 2" x 5" TVD Gamma Ray Logs: 50-029-22611-00 1 Blueline ~ 1 Folded Sepia 1 Blueline~''~ 1 Folded Sepi~'~ RECEIVED ,JUN 14 1996 Alaska Oil & Gas Cons, Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company I-II:III_LING S I~ I=t L/I 1-- I=: S WELL LOG TRANSMITTAL RE: AK-MW-50114 To: State of Alaska /~ 2p~' )d June 13, 1996 Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evahaation Logs - DS 18-34 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 magnetic tape with LIS listing. RECEIVE , ,JUN '1 3 1995 ~morage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company 'i:~' "?~ GeoQuest :i~:~ :':, 500 W. International Airport Road :~::ii ~ !~ Anchorage, Al( 99518-1199 ~ · ATTN: Sherrie ,! ,i NO. 10223 Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 9!9501 Field: Prudhoe Bay Anadrili Anadrill Well Job # Log Description Date BL RF Sepia , Survey Program Calculation ~owDW'sE -~ ...... [ :I"EMPERATI J[q E' OVE.RLAY 960429 1 I , _ ' .... OWDW-NW PUMP-IN TEI~PE--~URE SURVEY 960430 1 1 OWDW-SW v/ PUMP-IN TEMPERATURE SURVEY 960430 I 1 D.S. 7-03A / ........... ~ / PRODUCTION PROFILE LOG 960503 I 1 D.S.' 7-03A t,/ ...... DUAL BURSI-~TDT-P 960504 I 1 ,D.S. 11-26 ~/ ' ' pER~ORATI~-G-R-~'c~)RD ............ 960425 I I .......... .. ~ D.S. 14-03 / ,, pERFoRAT!N_G DEi~TH CONTROL _.95 ! 1 08 I 1 D.S.' 14-17 J ~ .... !NFLATABLE BRIDGE PLUG ,9.,51108 I 1 D.S.~ 15-14 v/ TUBING PATCH RECORD 9511 20 I I ..... O.S.: 15-15 ---'"' PERFORATING RECORD 9511 23 I 1 D.S., 15-16 ? TUBING PA~.i_CH RECORD 95111 7 I 1 .... D.S. 15-39 v~ TDT-,,,P BORAX LOG ,960429 I 1 ,,. i D.S. 1'~-5 ~/ / PERFORATIO-~4 RECORD ,, 951111 I 1 __ D.S. ~ 6-10 ~/ PERFORATION RECORD 95111 2 1 1 D.S. 18-34 ~' TDT-P BORAX LOG 960428 I 1 __ -- , , . · __ 6/4/96 Anadrill Performance Letter [., :: ~,~: .;, ~i ~[iPlease sign and return one oopy °I this transmittal to Sher'rie at the above aa~ress, lhank ~ou. DATE: GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10214 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 5/29/96 Field: Prudhoe Bay Well '~,~'~I~ ~ Anadrill Anadrill Anadrill Floppy Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter D.S. 18-34 96131 TDT-P BORAX 960428 I Alaska C~.l & G~s Cons. Commission Anchorage ARCO Alaska, In . UO~)O Post Offic~ .~o× in "~, Anchorage, Alaska 99510~0360 9,~, 276 1215 Teiephone cn~ TRANSMITTAL TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Robert Crandall DATE: March 5, 1996 AIRBILL: AIRLAND646233 CHARGE CODE:42366 AFT#: ABV-06-03-05-01 WELL NAME: PBU 18-34 SAMPLE TYPE: State corechips SAMPLES SENT: 10622'-11699' SENT BY: ANGELA T. LANGSTON/DAN PRZYWOJSKI UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: Arco Alaska, Inc. 619 E. Ship Creek Ave Suite 104 Anchorage, AK. 99510 Attn: Dan Przywojski DATE: dAR AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG .. 1, Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 95-164 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22611 4. Location of well at surface 9. Unit or Lease Name 3661' NSL, 48' WEL, SEC. 24, T11N, R14E '~'~'c.~rt. ?'-~.~' Prudhoe Bay Unit ~"'}. ~: .:'.'x .... ~,.~_-.__~:;".~_'~*'~C~'?~ 10. Well Number 3503'NSL, 4161'EWL, SEC. 19, T11N, R15E .~ '~.'J,~...~'_ i'ii' --~-,~,-,)'5;': 11. Field and Pool At Total Depth .. 3968' NSL, 1688' EWL, SEC. 20, T11N, R15E ~:' ~ i Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 53. 65 ADL 028321 12.10/3Date1/95Spudded 13.11~25~95Date T.D. Reached 14.12/04/95Date Comp., Susp. or Aband. 15. Water Depth,N/A if feet°ffsh°reMSL 16.oneNO. of Completions 17. Total Depth (MD+-rVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 12153'MD/8703'TVD 12078'MD/8703'TVD YES [] NO [] 2171 feet MD 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, CN, ZDL, Temp, DLL, L WD/FE, HEX, DIP, CIBL 23. CASING, LINER AND CEMENTING RECORD SE'FrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ... 20" 91.5tt H40 Surface 115' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.511 L-80 35' 3972' 13-1/2" 114o sx PF 'E', 375 'G', 260 PF 'C' 7-5/8" 29. 711 USS95 35' 9401' 9- 7/8" 239 sx 'G', 290 sx 'G' 5-1/2" 1711 L80 9249' 12153' 6-3/4" 300 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2" 9225' 9167' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10450' - 11020' 8711'- 8719' Freeze Protect with 100 Bbls Diesel 11085' - 11105' 8718'- 8716' 11115' - 11300' 8716'- 8708' 11370'- 11890' 8707' - 8699' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 16, 1996 Flowing Date of Test Hours Tested ]'ESTPRODUCTION FORpERiOD II~ DIL-BBL GASoMCF WATER-BBL CHOK~SlZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED,.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA ., Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. FEB 29 1996 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9335' 8203' Shublik 9391' 8231' Sadlerochit 9458' 8295' FEB 29 i996 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~r~ ff~~'~ Tit,eSeniorDrillingEngineor Date ~-"/~l~q INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: I 8-34 Rig Name: Doyon 9 AFE: 4J0295 Accept Date: 1 0/29/95 Spud Date: 1 0/31/95 Release Date: 1 2/04/95 Oct 30 1995 (1) Rig moving. Oct 31 1995 (2) Rig moved 100 %. Rigged up Divertor. Made up BHA no. 1 . Held drill (Fire). Drilled to 336 ft. Nov I 1995 (3) Drilled to 1965 ft. Nov 2 1995 (4) Laid down 95 ft of 5 in OD drill pipe. Reamed to 1968 ft. Drilled to 2381 ft. Held safety meeting. Drilled to 2541 ft. Circulated at 2541 ft. Pulled out of hole to 1131 ft. R.I.H. to 2541 ft. Held drill (Kick while drilling). Drilled to 3988 ft. Nov 3 1995 (5) Circulated at 3988 ft. Held safety meeting. Pulled out of hole to 2541 ft. R.I.H. to 3988 ft. Circulated at 3988 ft. Pulled out of hole to 1069 ft. Pulled BHA. Held safety meeting. Pulled BHA. Downloaded MWD tool. Rigged down Drillstring han- dling equipment. Rigged up Casing handling equipment. Held safety meeting. Ran Casing on landing string to 3972 ft. Circu- lated at 3972 ft. Pumped spacers- volume 75 bbl. Mixed and pumped slurry - 445 bbl. Mixed and pumped slurry - 77 bbl. Dis- placed slurry-374 bbl. Mixed and pumped slurry - 44 bbl. Rigged down Casing handling equipment. FEB 29 1996 Anchorage Operations Summary for: 18- Nov 4 1995 (6) Rigged down Casing handling equipment. Rigged down Divertor. Held safety meeting. Installed Casing spool. Rigged up BOP stack. Held safety meeting. Worked on BOP - All functions. In- stalled Wear bushing. Made up BHA no. 2. R.I.H. to 3881 ft. Serviced Block line. Circulated at 3881 ft. Held safety meet- ing. Held drill (Kick while tripping). Tested Kelly cocks. Tested Casing - Via string. Drilled cement to 3988 ft. Drilled to 3998 ft. Circulated at 3998 ft. Performed formation integri- ty test. Drilled to 4069 ft. Nov 5 1995 (7) Drilled to 5023 ft. Circulated at 5023 ft. Held safety meeting. Pulled out of hole to 3972 ft. R.I.H. to 5023 ft. Drilled to 5498 ft. Held safety meeting. Drilled to 6090 ft. Nov 6 1995 (8) Drilled to 6450 ft. Held safety meeting. Drilled to 6760 ft. Circulated at 6760 ft. Pulled out of hole to 5644 ft. R.I.H. to 6760 ft. Circulated at 6760 ft. Pulled out of hole to 5644 ft. Pumped out of hole to 4534 ft. Pulled out of hole to 3900 ft. Held safety meeting. Pulled out of hole to 211 ft. Pulled BHA. Made up BHA no. 3. R.I.H. to 3000 ft. Nov 7 1995 (9) R.I.H. to 6662 ft. Reamed to 6760 ft. Drilled to 6890 ft. Cir- culated at 6890 ft. Circulated at 6890 ft. Pulled out of hole to 6300 ft. Circulated at 6300 ft. R.I.H. to 6890 ft. Drilled to 6896 ft. Circulated at 6886 ft. Held safety meeting. Circu- lated at 6886 ft. Pulled out of hole to 6312 ft. Circulated at 6312 ft. Pulled out of hole to 5835 ft. Nov 8 1995 (10) Pulled out of hole to 1075 ft. Pulled BHA. Made up BHA no. 4 . Held safety meeting. Made up BHA no. 4. R.I.H. to 6906 ft. Circulated at 6906 ft. Drilled to 6938 ft. Circulated at 6938 ft. Took MWD survey at 6902 ft. Flow check. Circulated at 6894 ft. Held safety meeting. Circulated at 6894 ft. Took MWD sur- vey at 6808 ft. Drilled to 7065 ft. Page 2 operations summary for: 18-_ Nov 9 1995 (11) Drilled to 7256 ft. Held safety meeting. Drilled to 7446 ft. Circulated at 7446 ft. Pulled out of hole to 3972 ft. Held safety meeting. Pulled out of hole to 1075 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 7415 ft. Nov 10 1995 (12) R.I.H. to 7446 ft. Mixed and pumped slurry- 58 bbl. Displaced slurry - 109 bbl. Pulled out of hole to 6886 ft. Circulated at 6886 ft. Mixed and pumped slurry - 116 bbl. Displaced slurry - 85.5 bbl. Pulled out of hole to 5836 ft. Circulated at 5836 ft. Held safety meeting. Pulled out of hole to 3 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 5623 ft. Circulated at 5623 ft. R.I.H. to 5718 ft. Washed to 5856 ft. Reamed to 6809 ft. Cir- culated at 6809 ft. Nov 11 1995 (13) Circulated at 6809 ft. Reamed to 7446 ft. Drilled to 7476 ft. Circulated at 7476 ft. Held safety meeting. Pulled out of hole to 1075 ft. Pulled BHA. Made up BHA no. 6 . Downloaded MWD tool. R.I.H. to 2604 ft. Laid down 1395 ft of 5 in OD drill pipe. Held safety meeting. Laid down 1209 ft of 5 in OD drill pipe. Made up BHA no. 6. R.I.H. to 3900 ft. Serviced Block line. R.I.H. to 7011 ft. Nov 12 1995 (14) R.I.H. to 7476 ft. Circulated at 7476 ft. Drilled to 7626 ft. Held safety meeting. Drilled to 7794 ft. Circulated at 7794 ft. Drilled to 8040 ft. Held safety meeting. Drilled to 8330 ft. Nov 13 1995 (15) Drilled to 8485 ft. Held safety meeting. Drilled to 8645 ft. Circulated at 8645 ft. Pulled out of hole to 2472 ft. Held safety meeting. Pulled out of hole to 1077 ft. Pulled BHA. Made up BHA no. 7. R.I.H. to 2502 ft. Nov 14 1995 (16) R.I.H. to 8645 ft. Circulated at 8645 ft. Drilled to 8671 ft. Held safety meeting. Drilled to 9117 ft. Held safety meeting. Drilled to 9311 ff. Page 3 Operations Summary for: 18-. i! Nov 15 1995 (17) Drilled to 9417 ft. Circulated at 9417 ft. Pulled out of hole to 3972 ft. Held safety meeting. R.I.H. to 9359 ft. Circulated at 9417 ft. Pulled out of hole to 7009 ft. R.I.H. to 9417 ft. Circulated at 9417 ft. Pulled out of hole to 211 ft. Pulled BHA. Nov 16 1995 (18) Pulled BHA. Removed Bore protector. Rigged up Casing handling equipment. Ran Casing to 2000 ft (7.625 in OD). Held safety meeting. Ran Casing to 9401 ft (7.625 in OD). Circulated at 9401 ft. Rigged up Cement head. Batch mixed slurry - 200 bbl. Displaced slurry - 428 bbl. Rigged down Casing handling equip- ment. Held safety meeting. Installed Casing hanger. Laid down Drillpipe to 2000 ft. Nov 17 1995 (19) Laid down Drillpipe to 9000 ft. Rigged up All rams. Tested All functions. Installed Bore protector. Held safety meeting. Made up BHA no. 8. Functioned downhole tools at 1000 ft. Pulled BHA. Made up BHA no. 8. Pulled BHA. Made up BHA no. 8. Ser- viced Draw works. Held safety meeting. Singled in drill pipe to 8000 ft. Nov 18 1995 (20) Singled in drill pipe to 8500 ft. Serviced Lines / Cables. Sin- gled in drill pipe to 9320 ft. Tested Casing - Via annulus and string. Held drill (Kick while drilling). Drilled cement to 9422 ft. Circulated at 9422 ft. Held safety meeting. Circular- ed at 9422 ft. Drilled to 9694 ft. Circulated at 9694 ft. Held safety meeting. Pulled out of hole to 1000 ft. Pulled BHA. Made up BHA no. 9. R.I.H. to 1500 ft. Nov 19 1995 (21) R.I.H. to 9630 ft. Reamed to 9694 ft. Drilled to 9737 ft. Held safety meeting. Drilled to 10025 ft. Held safety meeting. Drilled to 10182 ft. Circulated at 10182 ft. Pulled out of hole to 9700 ft. Page 4 Operations Summary for: 18- Nov 20 1995 (22) Pulled out of hole to 989 ft. Pulled BHA. Made up BHA no. 10 . R.I.H. to 5000 ft. Held safety meeting. R.I.H. to 9677 ft. Reamed to 9804 ft. R.I.H. to 10041 ft. Reamed to 10182 ft. Drilled to 10363 ft. Held safety meeting. Drilled to 10500 ft. Nov 21 1995 (23) Drilled to 10622 ft. Held safety meeting. Circulated at 10622 ft. Pulled out of hole to 9400 ft. Flow check. Pulled out of hole to 990 ft. Pulled BHA. Held safety meeting. Made up BHA no. 11 R.I.H. to 10622 ft. Circulated at 10622 ft. Held safety meeting. Circulated at 10622 ft. Cored to 10682 ft. Circulated at 10682 ft. Pulled out of hole to 9400 ft. Circu- lated at 9400 ft. Pulled out of hole to 9000 ft. Nov 22 1995 (24) Pulled out of hole to 967 ft. Pulled BHA. Held safety meeting. Laid out Aluminium sleeve core. Made up BHA no. 12. Held safe- ty meeting. R.I.H. to 9400 ft. Serviced Block line. Took MWD survey at 9677 ft. R.I.H. to 10565 ft. Reamed to 10682 ft. Drilled to 10922 ft. Held safety meeting. Drilled to 11200 ft. Nov 23 1995 (25) Drilled to 11433 ft. Held safety meeting. Drilled to 11583 ft. Circulated at 11583 ft. Pulled out of hole to 9400 ft. Flow check. Pulled out of hole to 1080 ft. Pulled BHA. Made up BHA no. 13 . R.I.H. to 5000 ft. Held safety meeting. R.I.H. to 11544 ft. Washed to 11583 ft. Cored to 11643 ft. Circulated at 11643 ft. Nov 24 1995 (26) Circulated at 11583 ft. Pulled out of hole to 9400 ft. Flow check. Pulled out of hole to 967 ft. Pulled BHA. Held safety meeting. Serviced core barrel. Tested All functions. Made up BHA no. 14. R.I.H. to 9400 ft. Circulated at 9400 ft. R.I.H. to 11607 ft. Washed to 11643 ft. Cored to 11703 ft. Circulated at 11703 ft. Held safety meeting. Pulled out of hole to 9400 ft. Circulated at 9400 ft. Pulled out of hole to 967 ft. Pulled BHA. Laid out Aluminium sleeve core. FEB 29 1996 Page 5 Aqchorage Operations Summary for: 18-. Nov 25 1995 (27) Laid out Aluminium sleeve core. Made up BHA no. 15. R.I.H. to 9400 ft. Serviced Block line. R.I.H. to 11561 ft. Reamed to 11703 ft. Drilled to 11890 ft. Held safety meeting. Drilled to 12049 ft. Nov 26 1995 (28) Drilled to 12153 ft. Circulated at 12153 ft. Held safety meet- ing. Pulled out of hole to 11703 ft. R.I.H. to 11890 ft. Cir- culated at 12153 ft. Pulled out of hole to 9400 ft. Circulated at 9400 ft. Pulled out of hole to 1080 ft. Pulled BHA. Rigged up Service lines. R.I.H. to 200 ft. Held safety meeting. Rigged up RIGS survey instruments. R.I.H. to 5000 ft. Nov 27 1995 (29) R.I.H. to 9610 ft. Rigged up RIGS survey instruments. Ran elec- tric logs. Held safety meeting. Ran electric logs. Rigged down Logging/braided cable equipment. Pulled out of hole to 200 ft, Rigged down RIGS survey instruments. Made up BHA no. 16. R.I.H. to 6000 ft. Held safety meeting. R.I.H. to 10935 ft. Reamed to 11264 ft. R.I.H. to 12000 ft. Nov 28 1995 (30) R.I.H. to 12153 ft. Circulated at 12153 ft. Pulled out of hole to 11868 ft. Reamed to 11988 ft. Pulled out of hole to 9400 ft. Held safety meeting. Circulated at 9400 ft. Pulled out of hole to 948 ft. Pulled BHA. Rigged up Logging/braided cable equip- ment. Made up BHA no. 17. R.I.H. to 9840 ft. Logged hole with LWD: Formation evaluation (FE) from 9875 ft to 9985 ft. Held safety meeting. Logged hole with LWD: Formation evaluation (FE) from 9985 ft to 12000 ft. Nov 29 1995 (31) Rigged down Service lines. Pulled out of hole to 9400 ft. Cir- culated at 9400 ft. Pulled out of hole to 100 ft. Pulled BHA. Held safety meeting. Pulled BHA. Made up BHA no. 18 . R.I.H. to 9400 ft. Serviced Lines / Cables. Reamed to 11073 ft. R.I.H. to 12153 ft. Circulated at 12153 ft. Held safety meet- lng. Laid down 400 ft of 3.5 in OD drill pipe. Circulated at 11750 ft. Pulled out of hole to 9400 ft. Circulated at 9400 ft. Laid down 1250 ft of 3.5 in OD drill pipe. Page 6 Operations Summary for: 18-. Nov 30 1995 (32) Pulled out of hole to 950 ft. Pulled BHA. Ran Casing to 500 ft (5.5 in OD). Held safety meeting. Ran Casing to 2886 ft (5.5 in OD). Rigged up Drillstring handling equipment. Ran Drillpipe in stands to 9400 ft. Circulated at 9400 ft. Ran Drillpipe in stands to 12153 ft. Circulated at 12153 ft. Pumped spacers - volume 90 bbl. Batch mixed slurry- 64 bbl. Displaced slurry- 126 bbl. Reverse circulated at 9267 ft. Pulled Drillpipe in stands to 8250 ft. Circulated at 8250 ft. Pulled Drillpipe in stands to 0 ft. Dec I 1995 (33) Pulled Drillpipe in stands to 0 ft. Held safety meeting. Made up BHA no. 19 . Held safety meeting. Made up BHA no. 19. R.I.H. to 12078 ft. Circulated at 12078 ft. Held safety meet- ing. Circulated at 12078 ft. Pulled out of hole to 8780 ft. Tested Casing - Via string. Pulled out of hole to 7430 ft. Dec 2 1995 (34) Pulled out of hole to 3752 ft. Held safety meeting. Pulled BHA. Tested All functions. Rigged up sub-surface equipment - Gun as- sembly. Held safety meeting. Rigged up sub-surface equipment - Gun assembly. Ran Drillpipe in stands to 12078 ft. Pulled out of hole to 11894 ft. Held safety meeting. Dec 3 1995 (35) Perforated from 10450 ft to 11890 ft. Laid down Drillpipe to 9015 ft. Rigged down sub-surface equipment- Gun assembly. Rigged up Top ram. Held safety meeting. Ran Tubing to 5800 ft (4.5 in OD). Dec 4 1995 (36) Ran Tubing to 9224 ft (4.5 in OD). Held safety meeting. Reverse circulated at 9224 ft. Set Production packer at 9170 ft with 4000 psi. Installed Hanger plug. Rigged down Tubing handling equipment. Rigged down BOP stack. Held safety meeting. Rigged down BOP stack. Installed Xmas tree. Retrieved Hanger plug. Freeze protect well - 100 bbl of Diesel. Dec 5 1995 (37) Freeze protect well - 100 bbl of Diesel. Page 7 FEB 2.9 1996 ,..~a,~, Cons. Co~'~F~iss[of~ Anchorage SPE SUN' DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU/18-34 ~' 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ TRUE SUB- SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES PAGE , °' ~ ? ~-' j" /T' ., MWD SURVEY ' ~ ," ,, JOB NUMBER: AK-MW-50114 ' ':.' KELLY BUSHING ELEV. = 53.65''FT~ OPERATOR: ARCO ALASKA INC ELS TOTAL RECTANGULJIR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -53.65 0 0 160.72 160.72 107.07 0 4 251.24 251.24 197.59 0 7 339.00 339.00 285.35 0 10 429.00 429.00 375.35 0 12 N .00 E .00 N 50.26 E .05 S 78.68 E .11 S 64.68 E .07 S 17.77 E .17 .00N .00E .00 .07N .09E .09 .09N .24E .24 .01N .46E .46 .20S .63E .61 518.00 518.00 464.35 0 37 609.00 608.96 555.31 2 8 698.00 697.87 644.22 3 4 788.00 787.72 734.07 3 27 876.00 875.53 821.88 4 3 S 45.48 E .52 S 76.89 E 1.80 N 83.25 E 1.45 N 79.88 E .47 N 79.35 E .67 .69S 1.03E .97 1.42S 3.04E 2.91 1.52S 7.03E 6.88 .76S 12.11E 12.00 .28N 17.78E 17.74 964.00 963.24 909.59 5 11 1055.00 1053.77 1000.12 6 24 1148.00 1146.14 1092.49 6 54 1244.00 1241.36 1187.71 7 43 1340.00 1336.31 1282.66 9 10 N 86.16 E 1.44 S 89.49 E 1.41 S 88.11 E .56 S 84.19 E 1.01 S 85.78 E 1.52 1.12N 24.80E 24.81 1.35N 33.98E 33.97 1.12N 44.75E 44.68 .28N 56.93E 56.75 .94S 70.99E 70.64 1434.00 1428.91 1375.26 10 33 1529.00 1521.98 1468.33 12 31 1625.00 1615.00 1561.35 16 1 1720.00 1705.94 1652.29 17 35 1814.00 1794.69 1741.04 20 49 N 89.71 E 1.68 S 83.68 E 2.49 S 86.84 E 3.74 S 84.69 E 1.77 S 83.73 E 3.46 1.44S 87.06E 86.61 2.53S 105.99E 105.38 4.41S 129.58E 128.71 6.46S 156.97E 155.82 9.60S 187.73E 186.20 1910.00 1883.70 1830.05 23 8 2006.00 1971.38 1917.73 24 52 2100.00 2055.79 2002.14 27 21 2196.00 2140.37 2086.72 29 6 2292.00 2224.39 2170.74 28 45 S 86.66 E 2.67 S 87.62 E 1.85 N 87.37 E 3.53 S 88.24 E 2.83 S 88.64 E .43 12.57S 223.54E 221.62 14.50S 262.56E 260.33 14.33S 303.90E 301.53 14.04S 349.29E 346.77 15.30S 395.71E 392.91 2387.00 2306.53 2252.88 31 32 2483.00 2387.69 2334.04 33 1 2579.00 2467.99 2414.34 33 25 2675.00 2547.84 2494.19 34 1 2768.00 2624.80 2571.15 34 16 S 87.25 E 3.03 S 87.30 E 1.55 S 86.24 E .73 S 86.81 E .71 S 84.71 E 1.30 17.04S 443.38E 440.25 19.48S 494.59E 491.07 22.44S 547.11E 543.13 25.67S 600.30E 595.85 29.53S 652.36E 647.37 2864.00 2704.46 2650.81 33 33 2960.00 2784.91 2731.26 32 34 3052.00 2862.61 2808.96 32 10 3148.00 2943.61 2889.96 32 44 3245.00 3025.26 2971.61 32 37 S 86.08 E 1.09 S 87.01 E 1.16 S 85.43 E 1.01 S 83.92 E 1.03 S 87.72 E 2.12 33.84S 705.75E 700.20 37.00S 758.03E 752.01 40.25S 807.18E 800.69 45.03S 858.47E 851.39 48.85S 910.68E 903.07 SP~'~ f-SUN DRILLING SERVICES ANCHOR_~GE ALASKA PAGE 2 SIiARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 MWD SURVEY JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3340.00 3105.36 3051.71 3433.00 3184.11 3130.46 3528.00 3264.92 3211.27 3624.00 3346.50 3292.85 3719.00 3426.47 3372.82 32 25 S 86.96 E .47 51.22S 961.70E 31 50 S 89.62 E 1.65 52.70S 1011.13E 31 36 S 88.39 E .72 53.57S 1061.08E 32 0 S 86.43 E 1.15 55.86S 1111.62E 33 17 S 88.91 E 1.96 57.93S 1162.82E 953.70 1002.81 1052.50 1102.65 1153.49 3814.00 3505.69 3452.04 3908.00 3584.15 3530.50 3927.00 3600.06 3546.41 4105.76 3751.08 3697.43 4201.60 3832.80 3779.15 33 42 N 89.68 E .92 58.27S 1215.25E 33 8 S 88.96 E .99 58.59S 1267.02E 33 9 S 89.44 E 1.39 58.74S 1277.41E 31 30 N 89.94 E .94 59.17S 1373.01E 31 28 S 89.97 E .06 59.16S 1423.08E 1205.69 1257.24 1267.58 1362.78 1412.67 4297.91 3915.15 3861.50 4392.73 3996.57 3942.92 4488.24 4078.91 4025.26 4583.78 4160.64 4106.99 4679.02 4241.25 4187.60 31 0 N 89.47 E .58 58.94S 1473.03E 30 39 N 89.13 E .40 58.35S 1521.62E 30 13 N 89.46 E .49 57.75S 1570.00E 32 9 N 88.12 E 2.15 56.69S 1619.45E 32 11 N 88.63 E .29 55.25S 1670.14E 1462.45 1510.91 1559.16 1608.52 1659.14 4774.11 4321.96 4268.31 4869.56 4403.29 4349.64 4964.34 4483.97 4430.32 5059.66 4565.10 4511.46 5154.66 4646.17 4592.52 31 38 N 88.40 E .58 53.95S 1720.40E 31 29 N 88.50 E .18 52.60S 1770.35E 31 48 S 88.32 E 1.79 52.68S 1820.07E 31 30 S 88.38 E .32 54.12S 1870.08E 31 19 S 88.80 E .30 55.34S 1919.58E 1709.33 1759.21 1808.73 1858.43 1907.65 5249.75 4727.55 4673.90 5345.37 4809.69 4756.04 5440.35 4891.11 4837.46 5534.73 4971.88 4918.23 5629.77 5053.13 4999.48 30 58 S 86.46 E 1.33 57.37S 1968.73E 30 36 S 86.22 E .41 60.50S 2017.58E 31 22 S 85.56 E .88 64.00S 2066.36E 30 55 S 86.37 E .64 67.44S 2115.06E 31 34 S 86.69 E .70 70.42S 2164.27E 1956.43 2004.84 2053.13 2101.35 2150.12 5724.36 5133.72 5080.07 5819.70 5215.07 5161.42 5914.30 5295.86 5242.21 6010.56 5378.22 5324.57 6106.35 5460.33 5406.68 31 33 S 85.72 E .54 73.70S 2213.67E 31 18 S 85.44 E .30 77.53S 2263.25E 31 22 S 87.37 E 1.06 80.62S 2312.35E 30 58 S 86.90 E .50 83.11S 2362.12E 31 1 S 89.01 E 1.14 84.86S 2411.42E 2199.06 2248.12 2296.77 2346.14 2395.10 6201.67 5541.31 5487.66 6296.92 5621.53 5567.88 6392.39 5702.12 5648.47 6487.99 5783.00 5729.35 6583.37 5863.76 5810.11 32 37 S 88.74 E 1.69 85.85S 2461.67E 32 36 S 88.54 E .12 87.07S 2513.00E 32 13 S 88.41 E .40 88.43S 2564.17E 32 12 S 87.97 E .25 90.04S 2615.12E 32 4 S 87.42 E .34 92.09S 2665.81E 2445.08 2496.12 2546.98 2597.59 2647.93 SP5 :-SUN~ DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 MWD SURVEY JOB ~BER: AK-MW-50114 KELLY BUS~{ING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6678.33 5944.19 5890.54 6775.06 6025.99 5972.34 6935.84 6161.92 6108.27 6967.75 6188.94 6135.29 6999.57 6215.89 6162.24 32 9 32 21 32 12 32 6 32 7 S 87.85 E .26 94.17S 2716.25E S 89.18 E .76 95.50S 2767.86E S 86.63 E .85 98.64S 2853.65E S 87.72 E 1.84 99.48S 2870.61E S 87.64 E .15 100.16S 2887.52E 2698.00 2749.30 2834.50 2851.32 2868.11 7031.54 6242.98 6189.33 7127.12 6324.21 6270.56 7221.88 6405.06 6351.41 7317.43 6486.82 6433.17 7412.87 6568.78 6515.13 32 0 31 36 31 17 31 2 30 35 S 87.91 E .61 100.82S 2904.48E S 87.73 E .43 102.73S 2954.81E S 88.33 E .46 104.44S 3004.21E S 88.76 E .35 105.69S 3053.64E S 89.42 E .59 106.47S 3102.52E 2884.94 2934.92 2983.99 3033.13 3081.77 7441.36 6593.31 6539.66 7537.20 6674.40 6620.75 7633.77 6754.81 6701.16 7728.07 6833.79 6780.14 7823.45 6914.30 6860.65 30 34 33 48 33 26 32 47 32 2 S 89.63 E .38 106.59S 3117.02E S 88.82 E 3.40 107.30S 3168.07E S 88.09 E .57 108.74S 3221.53E S 86.73 E 1.04 111.06S 3272.99E S 86.69 E .79 113.99S 3324.05E 3096.20 3147.00 3200.13 3251.21 3301.82 7918.38 6994.75 6941.10 8013.82 7075.41 7021.76 8109.10 7155.20 7101.55 8204.55 7235.09 7181.44 8300.17 7315.44 7261.79 32 4 32 32 33 42 32 38 33 1 S 85.84 E .48 117.28S 3374.33E S 86.93 E .79 120.49S 3425.24E S 88.41 E 1.48 122.60S 3477.27E S 88.48 E 1.12 124.01S 3529.47E S 88.33 E .41 125.46S 3581.29E 3351.63 3402.07 3453.72 3505.61 3557.11 8395.68 7395.96 7342.31 8490.06 7475.55 7421.90 8581.65 7552.88 7499.23 8677.16 7633.79 7580.14 8773.17 7713.98 7660.33 32 2 32 57 31 50 32 22 34 18 S 87.63 E 1.10 127.26S 3632.62E S 86.69 E 1.11 129.78S 3683.26E S 86.01 E 1.29 132.90S 3732.24E S 86.68 E .67 136.13S 3782.89E S 86.22 E 2.04 139.41S 3835.55E 3608.09 3658.33 3706.85 3757.04 3809.22 8867.80 7792.40 7738.75 8963.92 7872.60 7818.95 9059.91 7953.01 7899.36 9154.93 8032.51 7978.86 9250.96 8113.17 8059.52 33 45 33 9 33 2 33 21 32 22 S 85.20 E .84 143.36S 3888.37E S 84.31 E .81 148.21S 3941.13E S 87.36 E 1.74 152.01S 3993.39E S 89.94 E 1.52 153.23S 4045.40E S 88.39 E 1.34 153.98S 4097.51E 3861.49 3913.64 3965.38 4017.09 4068.94 9359.84 8205.00 8151.35 32 35 9457.76 8287.12 8233.47 33 24 9489.35 8313.33 8259.68 34 28 9520.84 8339.09 8285.44 35 41 9552.62 8364.74 8311.09 36 40 S 87.05 E .69 156.31S 4155.94E S 89.00 E 1.36 158.14S 4209.24E S 88.70 E 3.43 158.50S 4226.88E S 89.00 E 3.88 158.86S 4244.97E N 88.90 E 4.99 158.84S 4263.73E 4126.96 4179.90 4197.44 4215.43 4234.13 SP5 :-SUN' DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 MWD SURVEY JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9583.93 8389.67 8336.02 9615.23 8414.27 8360.62 9647.30 8439.19 8385.54 9678.90 8463.43 8409.78 9709.02 8486.08 8432.43 37 45 38 38 39 24 40 24 42 1 N 87.00 E 5.04 158.16S 4282.66E N 86.40 E 3.05 157.04S 4301.98E N 86.80 E 2.50 155.84S 4322.13E N 85.70 E 3.87 154.52S 4342.36E N 84.50 E 5.98 152.82S 4362.13E 4253.04 4272.38 4292.57 4312.83 4332.67 9741.06 8508.98 8455.33 9772.53 8529.63 8475.98 9803.65 8548.40 8494.75 9834.89 8566.27 8512.62 9866.40 8583.70 8530.05 46 42 51 16 54 32 55 39 57 9 N 83.00 E 15.00 N 84.20 E 14.77 N 85.60 E 11.10 N 85.60 E 3.59 N 86.20 E 4.99 150.37S 4384.39E 4355.06 147.73S 4407.98E 4378.79 145.53S 4432.70E 4403.61 143.56S 4458.25E 4429.23 141.69S 4484.42E 4455.47 9898.12 8600.42 8546.77 9927.08 8614.76 8561.11 9956.90 8628.39 8574.74 9988.93 8641.58 8587.93 10020.75 8653.01 8599.36 59 15 61 22 64 12 67 9 70 45 N 86.00 E 6.64 N 86.60 E 7.54 N 86.70 E 9.53 N 87.70 E 9.61 N 87.00 E 11.50 139.86S 4511.31E 4482.42 138.23S 4536.42E 4507.57 136.68S 4562.89E 4534.08 135.26S 4592.04E 4563.24 133.89S 4621.70E 4592.91 10052.55 8662.44 8608.79 74 43 N 84.90 E 14.01 10084.47 8669.74 8616.09 78 50 N 84.20 E 13.08 10116.36 8675.41 8621.76 80 39 N 84.00 E 5.71 10144.69 8679.58 8625.93 82 22 N 83.70 E 6.16 10176.62 8683.49 8629.84 83 33 N 83.40 E 3.78 131.74S 4651.98E 4623.26 128.78S 4682.91E 4654.33 125.56S 4714.12E 4685.70 122.56S 4741.98E 4713.71 119.00S 4773.46E 4745.39 10206.77 8686.82 8633.17 10238.30 8690.20 8636.55 10268.22 8693.33 8639.68 10299.40 8696.50 8642.85 10329.92 8699.77 8646.12 83 46 83 55 84 3 84 17 83 24 N 84.10 E 2.42 N 84.70 E 1.96 N 84.50 E .78 N 85.60 E 3.59 N 85.80 E 2.99 115.74S 4803.25E 4775.35 112.68S 4834.45E 4806.69 109.88S 4864.07E 4836.45 107.20S 4894.97E 4867.47 104.92S 4925.23E 4897.81 10362.05 8703.30 8649.65 10392.70 8706.37 8652.72 10425.15 8709.43 8655.78 10457.32 8712.01 8658.36 10489.39 8713.21 8659.56 84 0 84 28 84 41 86 6 89 34 N 85.30 E 2.45 N 85.70 E 2.01 N 85.50 E .91 N 86.00 E 4.65 N 85.10 E 11.15 102.45S 4957.07E 4929.74 100.05S 4987.47E 4960.24 97.58S 5019.68E 4992.54 95.20S 5051.66E 5024.60 92.71S 5083.60E 5056.64 10520.11 8712.73 8659.08 92 14 10544.09 8711.78 8658.13 92 18 10575.26 8710.92 8657.27 90 49 10603.64 8710.54 8656.89 90 42 10635.66 8710.09 8656.44 90 55 N 84.60 E 8.84 N 84.50 E .51 N 84.00 E 5.01 N 84.30 E 1.14 N 84.40 E .72 89.96S 5114.19E 5087.36 87.68S 5138.04E 5111.31 84.56S 5169.04E 5142.47 81.67S 5197.27E 5170.84 78.51S 5229.13E 5202.86 SPt f-suN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 MWD SURVEY JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10665.94 8709.53 8655.88 91 11 10699.52 8708.79 8655.14 91 19 10734.83 8708.09 8654.44 90 56 10765.52 8708.25 8654.60 88-25 10797.45 8709.54 8655.89 86 56 N 84.60 E 1.14 75.61S 5259.27E N 85.50 E 2.70 72.72S 5292.71E N 85.20 E 1.35 69.85S 5327.90E N 83.20 E 10.48 66.75S 5358.43E N 81.10 E 8.04 62.40S 5390.03E 5233.13 5266.70 5302.00 5332.68 5364.54 10826.60 8711.10 8657.45 86 55 10856.58 8712.59 8658.94 87 23 10888.37 8713.98 8660.33 87 35 10920.53 8715.25 8661.60 87 52 10952.53 8716.58 8662.93 87 20 N 81.40 E 1.03 57.97S 5418.80E N 81.50 E 1.60 53.52S 5448.41E N 78.30 E 10.08 47.95S 5479.67E N 75.10 E 9.98 40.56S 5510.94E N 71.80 E 10.44 31.45S 5541.59E 5393.59 5423.47 5455.10 5486.89 5518.21 10982.45 8717.74 8664.09 88 12 11013.81 8718.58 8664.93 88 41 11045.48 8718.88 8665.23 90 13 11074.97 8718.12 8664.47 92 44 11106.64 8716.31 8662.66 93 49 N 70.00 E 6.66 21.67S 5569.83E N 69.70 E 1.83 10.87S 5599.26E N 68.90 E 5.42 .32N 5628.88E N 69.20 E 8.61 10.86N 5656.41E N 69.50 E 3.54 22.01N 5685.99E 5547.19 5577.44 5607.92 5636.25 5666.69 11138.17 8714.11 8660.46 11169.97 8711.75 8658.10 11199.75 8709.55 8655.90 11231.88 8707.98 8654.33 11264.03 8707.67 8654.02 94 10 94 20 94 9 91 25 89 41 N 70.30 E 2.76 32.82N 5715.53E N 69.50 E 2.57 43.72N 5745.31E N 69.90 E 1.47 54.02N 5773.16E N 69.60 E 8.58 65.13N 5803.27E N 70.00 E 5.52 76.23N 5833.44E 5697.05 5727.66 5756.29 5787.25 5818.26 11293.34 8707.82 8654.17 11324.96 8707.83 8654.18 11356.95 8707.17 8653.52 11388.77 8705.72 8652.07 11418.29 8704.17 8650.52 89 45 90 11 92 9 93 3 92 58 N 71.40 E 4.78 85.91N 5861.10E N 71.90 E 2.13 95.87N 5891.11E N 71.70 E 6.16 105.86N 5921.49E N 71.90 E 2.87 115.78N 5951.68E N 72.80 E 3.05 124.72N 5979.77E 5846.65 5877.41 5908.54 5939.48 5968.23 11448.78 8702.50 8648.84 11477.83 8701.20 8647.55 11509.68 8700.91 8647.26 11541.50 8701.35 8647.70 11572.88 8701.82 8648.17 93 19 91 47 89 15 89 8 89 8 N 72.10 E 2.55 133.90N 6008.80E N 73.50 E 7.14 142.48N 6036.52E N 74.00 E 8.10 151.39N 6067.09E N 74.90 E 2.85 159.92N 6097.74E N 75.40 E 1.59 167.96N 6128.07E 5997.94 6026.30 6057.53 6088.80 6119.71 11604.89 8702.09 8648.44 11636.94 8701.80 8648.15 11668.52 8700.90 8647.25 11699.68 8699.58 8645.93 11731.94 8698.70 8645.05 89 54 91 6 92 10 92 39 90 29 N 75.40 E 2.41 176.03N 6159.05E N 75.80 E 3.95 184.00N 6190.09E N 76.10 E 3.52 191.66N 6220.71E N 75.00 E 3.84 199.43N 6250.85E N 75.40 E 6.81 207.67N 6282.03E 6151.27 6182.88 6214.05 6244.75 6276.52 SPE ' SUN' DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 MWD SURVEY JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11763.06 8698.60 8644.95 89 52 N 76.40 E 3.76 11795.16 8698.55 8644.90 90 18 N 75.50 E 3.11 11827.27 8698.33 8644.68 90 27 N 76.10 E 1.93 11859.21 8698.24 8644.59 '89 52 N 75.40 E 2.85 11891.23 8698.83 8645.18 88 0 N 76.00 E 6.16 215.25N 6312.21E 6307.24 223.04N 6343.35E 6338.93 230.92N 6374.47E 6370.62 238.78N 6405.43E 6402.14 246.69N 6436.45E 6433.73 11923.30 8700.14 8646.49 87 18 N 77.20 E 4.33 11952.83 8701.29 8647.64 88 14 N 76.30 E 4.41 11984.84 8702.06 8648.41 89 1 N 77.50 E 4.47 12016.85 8702.28 8648.63 90 10 N 77.70 E 3.68 12048.84 8702.49 8648.84 89 4 N 77.40 E 3.56 254.11N 6467.62E 6465.42 260.88N 6496.34E 6494.62 268.13N 6527.50E 6526.29 275.00N 6558.76E 6558.03 281.90N 6590.00E 6589.74 12080.74 8702.73 8649.08 90 3 N 76.10 E 5.10 12153.00 8702.65 8649.00 90 3 N 76.10 E .00 289.21N 6621.05E 6621.31 306.57N 6691.19E 6692.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6698.21 FEET AT NORTH 87 DEG. 22 MIN. EAST AT MD = 12153 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 85.05 DEG. SPI Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -53.65 .00 N .00 E .00 1000.00 999.09 945.44 1.34 N 28.05 E .91 .91 2000.00 1965.94 1912.29 14.40 S 260.03 E 34.06 33.15 3000.00 2818.62 2764.97 38.12 S 779.53 E 181.38 147.32 4000.00 3661.17 3607.52 59.13 S 1317.34 E 338.83 157.46 5000.00 4514.27 4460.63 53.23 S 1838.85 E 485.73 146.89 6000.00 5369.17 5315.52 82.81 S 2356.69 E 630.83 145.11 7000.00 6216.25 6162.60 100.17 S 2887.75 E 783.75 152.92 8000.00 7063.76 7010.11 120.09 S 3417.82 E 936.24 152.49 9000.00 7902.80 7849.15 150.16 S 3960.76 E 1097.20 160.96 10000.00 8645.77 8592.12 134.83 S 4602.27 E 1354.23 257.04 11000.00 8718.27 8664.62 15.66 S 5586.31 E 2281.73 927.50 12000.00 8702.32 8648.67 271.41 N 6542.30 E 3297.68 1015.95 12153.00 8702.65 8649.00 306.57 N 6691.19 E 3450.35 152.67 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP ~.Y-SU~ DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -53.65 53.65 53.65 .00 153.65 153.65 100.00 253.65 253.65 200.00 353.65 353.65 300.00 .00 N .00 E .00 N .00 E .07 N .08 E .09 N .24 E .01 S .50 E .00 .00 .00 .00 .00 .00 .00 .00 .00 453.65 453.65 400.00 553.66 553.65 500.00 653.72 653.65 600.00 753.87 753.65 700.00 854.07 853.65 800.00 .28 S .66 E .96 S 1.31 E 1.74 S 4.74 E 1.12 S 10.09 E .00 S 16.25 E .00 .00 .01 .01 .07 .07 .22 .15 .42 .20 954.37 953.65 900.00 1054.88 1053.65 1000.00 1155.56 1153.65 1100.00 1256.40 1253.65 1200.00 1357.57 1353.65 1300.00 1.06 N 23.93 E 1.35 N 33.97 E 1.09 N 45.66 E .11 N 58.59 E 1.14 S 73.78 E .72 .31 1.23 .51 1.91 .68 2.75 .84 3.92 1.16 1459.16 1453.65 1400.00 1561.52 1553.65 1500.00 1665.23 1653.65 1600.00 1770.31 1753.65 1700.00 1877.41 1853.65 1800.00 1.42 S 91.67 E 3.26 S 113.34 E 5.05 S 140.72 E 8.02 S 172.85 E 11.73 S 210.98 E 5.51 1.60 7.87 2.36 11.58 3.71 16.66 5.09 23.76 7.10 1986.45 1953.65 1900.00 2097.60 2053.65 2000.00 2211.20 2153.65 2100.00 2325.55 2253.65 2200.00 2442.40 2353.65 2300.00 14.16 S 254.34 E 14.37 S 302.81 E 14.27 S 356.68 E 15.77 S 412.11 E 18.43 S 472.49 E 32.80 9.04 43.95 11.15 57.55 13.60 71.90 14.35 88.75 16.86 2561.82 2453.65 2400.00 2682.01 2553.65 2500.00 2802.91 2653.65 2600.00 2922.90 2753.65 2700.00 3041.41 2853.65 2800.00 21.82 S 537.66 E 25.89 S 604.22 E 31.34 S 671.93 E 35.96 S 738.08 E 39.80 S 801.55 E 108.17 19.41 128.36 20.19 149.26 20.90 169.25 19.99 187.76 18.51 3159.93 2953.65 2900.00 3278.71 3053.65 3000.00 3397.14 3153.65 3100.00 3514.77 3253.65 3200.00 3632.44 3353.65 3300.00 45.72 S 864.89 E 49.57 S 928.84 E 52.56 S 992.21 E 53.38 S 1054.15 E 56.14 S 1116.08 E 206.28 18.52 225.06 18.78 243.49 18.43 261.12 17.63 278.79 17.66 SP .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3751.51 3453.65 3400.00 3871.57 3553.65 3500.00 3991.02 3653.65 3600.00 4108.77 3753.65 3700.00 4226.04 3853.65 3800.00 58.26 S 1180.67 E 58.24 S 1247.11 E 59.08 S 1312.42 E 59.17 S 1374.58 E 59.16 S 1435.84 E 297.86 19.08 317.92 20.06 337.37 19.45 355.12 17.75 372.39 17.27 4342.82 3953.65 3900.00 4459.00 4053.65 4000.00 4575.53 4153.65 4100.00 4693.67 4253.65 4200.00 4811.33 4353.65 4300.00 58.72 S 1496.14 E 57.89 S 1555.29 E 56.83 S 1615.06 E 55.06 S 1677.94 E 53.40 S 1739.92 E 389.17 16.78 405.35 16.18 421.88 16.52 440.02 18.14 457.68 17.66 4928.66 4453.65 4400.00 5046.22 4553.65 4500.00 5163.41 4653.65 4600.00 5280.19 4753.65 4700.00 5396.50 4853.65 4800.00 52.13 S 1801.27 E 53.92 S 1863.06 E 55.44 S 1924.13 E 58.34 S 1984.37 E 62.25 S 2043.62 E 475.01 17.33 492.57 17.56 509.76 17.19 526.54 16.78 542.85 16.30 5513.48 4953.65 4900.00 5630.38 5053.65 5000.00 5747.75 5153.65 5100.00 5864.86 5253.65 5200.00 5981.90 5353.65 5300.00 66.75 S 2104.16 E 70.44 S 2164.59 E 74.61 S 2225.88 E 79.34 S 2286.65 E 82.31 S 2347.40 E 559.83 16.98 576.73 16.90 594.10 17.36 611.21 17.11 628.25 17.04 6098.55 5453.65 5400.00 6216.32 5553.65 5500.00 6335.05 5653.65 5600.00 6453.30 5753.65 5700.00 6571.43 5853.65 5800.00 84.80 S 2407.40 E 86.03 S 2469.57 E 87.60 S 2533.55 E 89.39 S 2596.64 E 91.80 S 2659.48 E 644.90 16.65 662.67 17.77 681.40 18.72 699.65 18.25 717.78 18.13 6689.50 5953.65 5900.00 6807.80 6053.65 6000.00 6926.06 6153.65 6100.00 7044.12 6253.65 6200.00 7161.68 6353.65 6300.00 94.39 S 2722.20 E 95.75 S 2785.39 E 98.33 S 2848.45 E 101.06 S 2911.14 E 103.45 S 2972.90 E 735.85 18.07 754.15 18.30 772.41 18.26 790.47 18.06 808.03 17.56 7278.72 6453.65 6400.00 7395.29 6553.65 6500.00 7512.36 6653.65 6600.00 7632.38 6753.65 6700.00 7751.70 6853.65 6800.00 105.26 S 3033.68 E 106.38 S 3093.58 E 107.04 S 3154.43 E 108.71 S 3220.76 E 111.79 S 3285.77 E 825.07 17.04 841.64 16.57 858.71 17.07 878.73 20.01 898.05 19.32 '.Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 SHARED SERVICES DRILLING PBU/18-34 500292261100 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 7/95 DATE OF SURVEY: 112595 JOB NUMBER: AK-MW-50114 KELLY BUSHING ELEV. = 53.65 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7869.88 6953.65 6900.00 115.45 S 3348.65 E 916.23 18.18 7988.00 7053.65 7000.00 119.75 S 3411.37 E 934.35 18.12 8107.24 7153.65 7100.00 122.57 S 3476.23 E 953.59 19.24 8226.59 7253.65 7200.00 124.33 S 3541.36 E 972.94 19.36 8345.71 7353.65 7300.00 126.20 S 3606.05 E 992.06 19.11 8463.95 7453.65 7400.00 128.96 S 3669.08 E 1010.30 18.25 8582.55 7553.65 7500.00 132.93 S 3732.71 E 1028.90 18.60 8700.68 7653.65 7600.00 136.86 S 3795.46 E 1047.03 18.12 8821.18 7753.65 7700.00 141.20 S 3862.55 E 1067.53 20.51 8941.29 7853.65 7800.00 146.98 S 3928.82 E 1087.64 20.11 9060.67 7953.65 7900.00 152.03 S 3993.81 E 1107..02 19.38 9180.24 8053.65 8000.00 153.25 S 4059.32 E 1126.59 19.56 9298.90 8153.65 8100.00 154.71 S 4123.17 E 1145.25 18.66 9417.67 8253.65 8200.00 '157.74 S 4187.19 E 1164.02 18.78 9538.80 8353.65 8300.00 158.97 S 4255.49 E 1185.15 21.13 9666.09 8453.65 8400.00 155.11 S 4334.11 E 1212.44 27.29 9812.72 8553.65 8500.00 144.96 S 4440.08 E 1259.07 46.63 10022.86 8653.65 8600.00 133.75 S 4623.71 E 1369.21 110.14 12153.00 8702.65 8649.00 306.57 N 6691.19 E 3450.35 2081.13 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LAi~RY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: 12 December 1995 Transmittal of Data ECC #: 6535.00 Sent by: HAND CARRY Data: ~-LDWG Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Received Date LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 4 December 1995 Transmittal of Data ECC #: 6535.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: 18-34 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 ZDL/CN FINAL BL+RF Run # 1 1 CN FINAL BL+RF Run # 1 1 DLL FINAL BL+RF Run # 1 1 BH PRO FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~CEIVED Received by Date: ri F! I L_I_I I~ G c~ E I=IL~ I I-- E S December 8, 1995 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Dear Mr. Grant, / Re: Survey Data 12-36, 18-34, 2-12A, 18-10A Enclosed are two hard copies of the above mentioned file(s). Well 12-36 MWD survey, surface to 13400'. DEC (~.;, .,,.,,,,.. Alaska Oil & Gas Well 18-34 MWD survey, surface to 12153' Well 2-12APB1 MWD survey, tie in point 10046, window point 10105', interpolated depth 10808'. Well 2-12A Well 18-10APB1 MWD survey, tie in point 10046, window point 10105', interpolated depth 11403' MWD survey, tie in point 10800' window point 10805', interpolated depth 12932' Well 18-10APB2 MWD survey, tied into 18-10APB1 at 12441', kickoff point 12462', interpolated depth 13120' Well 18-10A MWD survey, tied into interpolated depth 13780' 18-10APB2 at 12504', kickoff point 12520', · Please call me.at 563-3256 if you have any Regards, Sandra Lufkin Dept. Specialist uestions or concerns. q Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company .**E. MORANDU-' "'tate of Alaska Alaska Oil and Gas Conservation Commission TO: David J o.9.bq~l-- DATE: Chairmar4~~- November 3, 1995 THRU: Blair Wondzell, '.~~- FILE NO' P. I. Supervisor ~rf'¥/'~ FROM: Jerry Herring,~ ~ SUBJECT: Petroleum lnsi~"~;~ aefkkccd.doc BOPE Test, Doyon Rig 9 Prudhoe Bay Field, DS18-34 PTD 95-164 Friday, November 3, 1995: I traveled to ARCO's DS18 and witnessed a BOPE test on Doyon Rig 9 drilling well 18-34. The BOPE test report is attached for reference. I arrived on the pad as requested at 10:00 AM. A walk-through of the rig was completed and I found the rig to be in good condition and the BOP equipment still being installed. The BOPE test began at 2:00 PM and lasted for 3 hours. There was one failure, the lower Kelly IBOP failed, was replaced and retested good. Tim Krupa and Jim Wark did an excellent job conducting the BOPE test. Summary: I witnessed a BOPE test on Doyon Rig 9 drilling well DS18-34. The test lasted 3 hours and there was one failure. Attachment: aefkkccd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 10-3/4" Test: Initial X Workover: DOYON Rig No. 9 PTD # 95-164 ARCO Rep.: DS18.34 Rig Rep.: Set @ 3972' Location: Sec. Weekly Other DATE: 11/3/95 Rig Ph.# 659-4831 Richard Bordes Tim Krupa 24 T. 11N R. 14E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. OK Quan. Test Press. P/F 1 250/5,000 P ~ 250/5,000 P ~ 250/5,000 P ~ 250/5,000 P f 250/5,000 P 2 250/5,00O P 5 250/5,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5, 000 P 250/5, 000 F/P 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 13 Test Pressure P/F 250/5,000 P 36 250/5,000 P ~ P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 Bottles 2450 (Ave.) 3,100 ] P l, 725 P 0 minutes 32 sec. 2 minutes 23 sec. OK Remote: OK Psig. TEST RESULTS Number of Failures: i' ~ ,Test Time: ~ours, Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within, n/a d-aye. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Lower Kelly IBOP fared, was replaced and retested good.~' Fire protective rubber coating on ram control lines deteriorating and should be changed out. I found the rig in good condition and crew in good spirits. .'~ Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? Waived By: YES X NO 24 HOUR NOTICE GIVEN YES X NO Witnessed By: Jerry Herring FI-021 L (Rev.12/94) AEFKKCCD.XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 23, 1995 Terry Jordan, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: -Prudhoe Bay Unit 18-34 ARCO Alaska, Inc. Permit No 95-164 Surf Loc. 3661'NSL, 48'WEL, Sec. 24, T11N, R14E, UM Btmhole Loc. 4301'NSL, 2891'WEL, Sec. 20, T11N, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (B©PE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contactin~oleum field inspector 659-3607. ! BY ORDER OF THE ISSION /encl c: Dept of Fish & 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 I~llb. Type of well. Exploratoryl-q Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Plan RTE = 51.2 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchoraae. Alaska 99519-6612 ADL 028321 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3661' NSL, 48' WEL, SEC. 24, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3571' NSL, 4763' WEL, SEC. 20, T11N, R15E 18-34 U-630610 At total depth 9. Approximate spud date Amount 4301' NSL, 2891' WEL, SEC. 20, T11N, R15E 10/30/95 $200,000.00 :12. Distance to nearest 13. Distance to nearest well F14. Number of acres in property 15. Proposed depth (MD and TVD) property line / ADL 028322 2891 feet LPC02, 76' at 6900' MD feet 2560 12902' MD / 8725' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 600 feet Maximum hole angle 9o o Maximum sudace 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 30" 20" 91.5# H40 Weld 80' 30' 30' 110' 110' 260 sx AS (Approx.) 13-1/2" 10-3/4" 45.5# NTSO NSCC 3972' 30' 30' 4002' 3669' 1141 sx P!:r, 375 sx Class 'G' 9-7/8" 7-5/8" 29.7# JSS-95 Mod BTC 9373' 30' 30' 9408' 8254' 309 sx Class 'G' 6-3/4" 5-1/2" 17# LSO NSCT 3649' 9258' 8130' 12902' 8725' 593 sx Class 'G' ':19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural "- Conductor Surface ~ ~. L~ W [~ Intermediate ' ' Production . Liner 0(~T I cO 1995 Perforation depth: measured true vertical A~ask~ (Jil & Gas Cons. Conlmissiori ~n~.hnrnnn 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drill'i~'g-'~r-o~ram [] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce,/tify that the foregoi~g~s true and correct to the best of my knowledge j~.. Signed ,~t~li~ ~.~fi~,//, / .~~' Title Senior Drilling En~lineer Date//~"//~'"d~( ' 'f ' \ Commissio U Permit Number IAPI numbe' '? .,., ,., IApproval. date, ISee cover letter ~,._~_//~' ~" .-, 1.50- 0 ~_~-- ~__2._~:~_/'J I FO/'~.~"~_ Ifor other requirements Conditions of approval ~amp~es required ~ Yes J~ No Mud Icg rbquir~d' []Yes I~ No Hydrogen sulfide measures J~ Yes [] No Directional survey requirec~ ~l~ Yes [] No Required working pressure for DOPE [] 2M; 1-13M; ,~5M; I-I10M; [-115M; Other: Original Signee ~ by order of Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in I Well Name: I 18-34 Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 3661' FSL, 48' FEL, SEC 24, Ti IN, R14E Target Location: 3571' FSL, 4763' FEL, SEC 20, TI iN, R15E Bottom Hole Location: 4301' FSL, 2891' FEL, SEC 20, T11N, R15E I AFE Number: 14J0295.0 I Estimated Start Date: October 30 1995 I Rig: I DOYON 9 I Operating days to complete: 30 IMD: I 12902' I ITvD: I8725' I [KBE: 154' I Well Design (conventional, slimhole, etc.): Formation Markers: [ Slimhole Horizontal Formation Tops TVD MD (BKB) Base of Permafrost 1970 1970 10-3/4" Casing 3669 4002 10' tvd above the TT4/T5/SV3 TT4/T5/SV3 3679 4013 UGNU 5639 6324 WEST SAK 6289 7091 ~, ,.... L. i ~ 12 ~ SEABEE (K-12) 6484 7321 K-5 7554 8583 (~CT '1 _q 1~5 PUT RIVER 8164 9302 - - LCU (KINGAK) 8169 9308 A~aSga 0il & Gas cons. ~0rnmiss~ SAG RIVER 8199 9343 Anchorage SHUBLIK 8244 9396 7-5/8" Casing 8254 9403 10' tvd below the top of Shublik Sadlerochit (Z 4B) 8294 9456 Zone 3 8394 9590 Zone 2 8469 9696 'CGOC 8649 10005 Zone lB 8709 10276 Beginning of Horiz. 8725 10852 End of Horiz. 8725 12902 5-1/2" Liner Shoe Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 30" 20" 91.5# H40 WELD 80' 30' 1107110' 13-1/2" 10-3/4" 45.5# NTB0 NSCC 3972' 30' 4002'/3669' 9-7/8" 7-5/8" 29.7# USS-95 Mod BTC 9373' 30' 9408'/8254' 6-3/4" NA 1/2" 1/2" Logging Program: 17# 12.6#[ L80 I NSCT[ LB0 NSCT 3649' 9258'/8130' 12902'/8725' 9250' surface 9250' [ Open Hole Logs: I Cased Hole Logs: 13-1/2" MWD Dir. 9-7/8" MWD Dir from surface shoe to intermediate casing point. 6-3/4" MWD Dir/GR. Coring 180' in production interval. DPC GR/NEU/DEN/RES and CIBL//RES from TD to 7-5/8" Csg point. None Mud Program: Special design considerations I MI Flow Pro ® Polymer system in 6-3/4" horizontal hole section. Surface Mud Properties: [ 13-1/2" hole section Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 8.5 15 to to to to to to to 9.2 300 60 60 80 10 25 Intermediate Mud Properties: [ 9-7/8" hole section Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 20 10 5 30 8.5 4 to to to to to to to 10.1 70 30 15 50 10 7 Production Mud Properties: ] 6-3/4" hole section Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 10 15 5 30 8 <6 to to to to to to to 9.0 30 20 10 50 9 <6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. ~ t, , ~ i · ~ Directional: OCT 't D t995 I KOP: I 600' MD [ blaa~ 0it & Gas Cons. Commission [ Maximum Hole Angle: [ 90 degrees Close Approach Well: LPC-02, 76' away at 6900' MD The above listed wells will be secured as necessary during the close approach. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 10-3/4" 1141/12.0/2.17 375/15.8/1.16 Perm & Class "G" 7-5/8" none 309/15.8/1.15 Class "G", to 1000' above Put River 5 1/2" none 593/15.8/1.2 Class "G" Request for Annular Injection: Disposal' Cuffings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: All drilling and completion fluids can be annular injected. Request to have well DS 18- 34 for annular pumping. Request to AOGCC for Annular Pumping Approval for DS 18-34: 1. Approval is requested for Annular Pumping into the DS 18-34 10-3/4" x 7-5/8" casing annulus. 2. As referenced in Area Injection Order #4, there are no drinking water aquifers in the Prudhoe Bay Field Eastern Operating Area (including the Lisburne Oil Pool), as the average level of Total Dissolved Solids (TDS) at the ambient water within the proposed project area is above 10,000 ppm. There are no domestic or industrial use water wells located within one mile of the project area. The 10-3/4" casing shoe will be set at 4002' MD (3615' TVD) which is below the Permafrost and in shale formations in the Sagavanirtok above the Ugnu Formation. The burst rating (80%) for the 10-3/4" 45.5# NT-80 casing is 4170 psig while the collapse rating (80%) of the 7-5/8" 29.7# L-80 casing is 3830 psig. The break down pressure of the Ugnu formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2307 psi for a 10.0 ppg fluid in this well (Assumes worst case in which 7-5/8" casing is filled with gas). MASP = 3830 psig - ((fluid density ppg - 1.9) X 0.052 X 10-3/4" Casing Shoe TVD) A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. . . , . AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Prudhoe Bay DS 18-34 0 0 Submitted for 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. Ailchor,~gc 18-34 Drilling/Coring & Completion Procedure , . . . . . . 10. 11. MIRU drilling rig. N/U diverter and function test same. Ensure diverter setup conforms to diagram posted with AOGCC. Drill 131/2" hole to surface casing point (10' TVD above the SV3) as per the Recommended Practices for Surface Hole, VI.0. Run and cement 103/4'' surface casing. NU BOPE, function test and pressure test to 5000 psi. PU 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of ' new hole and perform leak off test. Expected leak-off is 12.3 ppg EMW. RIH and drill 97/8'' hole to 10' TVD into the Shublik formation using MWD as per Recommended Practices for Intermediate Hole VI.0. Note: Pick up MWD with gamma ray on the last bit trip prior to drilling the Put River. MU and RIH with 75/8" casing string and cement as per well plan. MU 63/4'' MWD BHA and PU 31/2'' DP. Clean out to 75/8'' landing collar and test casing to 3500 psi for 30 min. Drill 10' of new hole. Displace to 9.0 ppg used FIo Pro mud system. Drill 63/4'' build section to the Zone 1 target, at a rate of 8°/100 feet, following the Recommended Practices for Production Hole, VI.0. Upon reaching the target horizontal interval as determined by the rig-site geologist, change over the mud system to a new 9.0 ppg Fio-Pro system. This should be the first core point. Mud samples will be collected after mud changeover and while coring for ana!ysis. Hold pre-coring meeting prior to picking up the first coring assembly (non-routine operation). Identify hazards and fully brief rig team on both tours. Review SSD Drilling Policy section 11.0 on coring in the meeting. 12. 13. 14. Pick up coring BHA for the first core of 60' length. RIH and cut core as per Baker- Hughes Inteq coring procedures. CBU. POOH with core. Monitor returns for hydrocarbons, line up trip tank, and flow check well before pulling out of hole. Baker-Hughes Inteq and the on-site geologists will take responsibility for sample catching and proper handling of the cores on surface. Please accommodate them and assist them when possible. Pick up coring BHA with 60' core barrel if the results from the first coring run are satisfactory (if not, consider running a 30' barrel). RIH and cut core as per Baker- Hughes Inteq coring procedures. CBU and POOH with core, following the same _ procedures as in Step 13. -~-.~;. -,,.---.~ 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. PU 63/4" drilling assembly and drill horizontal section to the last core point as determined by the rig-site geologist, in consultation with the rig supervisor concerning hole conditions. PU coring BHA for the third 60' core section. RIH and cut core as per Baker-Hughes Inteq coring procedures. OBU and POOH with core, following the same procedures outlined in Step 13. PU 6-3/4" drilling assembly and RIH. Drill to TD of well, monitoring torque and drag trends closely. CBU and POOH. RU Atlas wireline. Run drillpipe-conveyed GR/RES/ZDEN/NEU logs. POOH. Run DPC STAR 2-combination CBIL/RES logs. POOH and RD wireline. Run hole opener to TD of 63/4'' hole. Circulate hole clean. Run 51/2'', L-80 solid liner assembly to bottom. Space the liner hanger and packer 150' above the 75/8" casing shoe. Cement the liner in place with the total cement volume based on 30% excess across the reservoir, 150' liner lap, top of cement 200' above the liner with drillpipe in the hole, and 80' shoe volume. Set liner hanger and packer. Unsting running tool and reverse circulate excess cement from the wellbore. POOH. RIH with 43/4'' mill. Clean out to landing collar. Test liner and liner lap to 3500 psi for 10 minutes. Displace well to clean, filtered, inhibited seawater. Test liner and liner lap to 3500 psi for 30 minutes. RIH with 33/8'' drillpipe conveyed perforating guns and perforate the 51/2'' liner. POOH and lay down guns. RIH with 41/2'' L-80 completion with SSSV, GLMs, and 75/8" x 41/2" packer. Packer should be set with the wireline reentry guide spaced out to be in the liner tieback stem. Set packer and test tubing to 4000 psi. Refer to the Recommended Practices for Running Tubing, V3.2. Set 2-way check valve. Test to 300 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull 2-way check valve. Test 41/2''x 75/8" annulus to 3500 psi with 2000 psi on tubing. Shear RP valve. Freeze protect well through shear valve in top GLM station. Release rig. Notes: 0CT '1 9 1995 ~ask~ ~Jii & Gas Cons, Commission ~ ~chorage o Anticipated BHP: o Maximum surface pressure o Planned Completion Fluid: a! b. c, 3600 psi @ 8610' ss 2727 psi @ 8610' ss 8.6 ppg filtered sea water The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). The Cretaceous/Ugnu interval may be overpressured due to injection. Mud weights of 9.8-10.1 ppg may be required. d. No potential hazardous levels of H2S are anticipated in this well. e. Drilling Hazards: Minor gas zones have been encountered around the K5 (4775' TVDss) to HRZ interval. The Put River is a gas bearing sand at 8110' TVDss. It is not well developed in this area and is probably in pressure communication with the Sadelrochit. The required mud weight should be 9.8-10.2 PPg. · Gas zone from Top of Sag River to the current GCC. · Structurally, this well is Iow-risk. There are minor faults in the surrounding area, but they should not be a factor. The nearest deep close approach well is'LPC-02, which is 76' away at 6900' MD. Deep well close approach analysis shows that all wells fall within an acceptable risk range. OCT 'i 9 ~995 Oit & Gas Cons. Commission Anchorage o- ~oo- 400- 600- 80~- 933- lCOO - _~red Services Dri~'ng ~.a State Plane: Zone~ ~U · EOA' DS18 18-34 As-built 18-34 WplO VERTICAL VIEW SCAL~ 200 ft. / in. TV]) REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD ~xoo, ~ o ~ TIE IN 0 o. co. Ii 6c-~ ~II KD~ / ~TA~T ~-- ~JILD Ii 1.5~/1¢0 Ft E lG~ ~ ~7.~ E ~33 ~ ~ ~ ~3 ~ ~ ~ ~IL~ HALLIBURTON HORIZONTAL VIEW (TRLr8 NORTH) SCALE 400 ft./ in. SURVEY REF: WELLHEAD 600 I~CO 5 In OD, ~[ 189.~1 ~!3, 8694 TV % - OCT t 9 1995 81~W; ~i! ~ Gas Cons. Commission '"'-:-~chorage CRITICAL POINT DATA HI) Inc Azl, TVD N/S E/U TIE IN 0 0.00' 92.00' 0 0N 0E KOP / START 600 O, OO'92,00' 600 0N 0 E DF BUILD ~t 1,50'/100 START OF BUILD933 5.00' 98.00' 933 IS 15E 8 2,00'/100 END OF BUILD 8083a8.00' 92.00' abas 18s 339E START DF BUILD 238388.00' 92,00' 8893 17S 480E 8 2.00'/100 Ft ENDDFBUILD 258332.00' 92,00' 8466 20S 579E T5 401338.00' 98.00' 3679 47S1337E T3 469132.00' 92.00' 4254 59S1696£ K15 531032.00' 92.00' 4779 71S2024E Ugnu 632438,00' 92.00' 5639 89S8561E West S~k 709138,00' 92.00' 6889 104S 2967 E K12 732132.00' 92.00' 6484 108S 3088 E KIO 793432.00' 92.00' 7004 119S 3413 E K5 858338.00' 98.00' 7554 131S 3757 E Put River 930832.00' 92.00' 8164 144S 4138 E KJngak 930832.00' 98,00' 8169 145S 4141 E Sag River 934332.00' 92.00' 8t99 145S 4159 E Shub/ik 939638.00' 98.00' 8844 146S 4188 E START OF 940332.00' 98,00' 8850 146S 4191 E CURVE iR 8.00'/100 ?t ~ 10 3/41n0~, Ii4~tg, 36S9 TYD Top Sad / 9456 36,15'90.45' 8894 147 S 4821 E 13~ .............. ~X~ 3~'a 4o13 ~ TS Zone 4 / 48 ~ Zone 4A / 9541 48.78'88.54' 8359 146 S 4875 E X-Ray ~ END ~FCURVE 956945.00' 88,00' 8379 146S4294E ~ Zone 3 959045.00' 88.00' 8394 145S4309E ~0- ~ Zone 2/ 2C 969645.00' 88.00' 8469 143S4384E ~ START DF 974045,00' 88,00' 8500 148S 4415E ~ CURVE 4~oo- ~ 8.00'/lOg Fi la~i ................... ~ssl ................. ~ ~a~' ~ ~m~; wa o Zone 88 / 977447, 77'87,93' 8584 141~ 4440E Tan9o ~-- ~ Zone 8A / 9937 60,88' 87,66' 8619 136 S 4578 E uu- ~ Romeo ~ Zone 13 / 10005 66,20' 87,57' 8649 133 S 4632 E m ~ Lower Romeo 4600- ~ END OF CURVE 10876 87,91' 87. E7' 8709 tel S 4895 E ~ START DF 1063387,91' 87,87' 8788 104S 5251E m ~ CURVE 4779.~ .................... ~to .................... 48~- ~ END DF CURVE1085290,86' 70.00' 8725 61S5465E m ~ EHL 1290290,86' 70,00' 8694 640N7391E m 4 ~ B694 640 N ?~l E 6991~ 5961080 B694 789 ~ 7305 E 69~10 5961827 i~t ....................................................... ~ ~*. ...... ~ ..... o~In tE~l ~,e6' 70. C0' 8694 639 N 7390 E 889 ..............................~ ................... ~ I gS 741g.53 a*~ ~ J N/S 639.78 N ¢;t ................................... 6 _~ ............. _ _ _: ................................................................... h ~ ................................................ 41b~ ................................ ~7 S/B mn OD E 9409 p~ ~54 TYD s~ .......................................... ~~~ ~,~e~ ~ ~ ~ )~M ............................................ ~_~ 4411 _~-~- ~ %'~ ~ ~ % ~ %~ ~ ~RTIC~ SEC~ON P~E: 85.05' WELL P~N PROFILE SUMMARY StaN UO~End UD~Plonned Activity 0 600 ~Dpitt 13 1/~' hole ve~%ic=lty ~o KOP. 600 933 !Start oF build ~t 1.5'/100' ~o 5' incUna~ion =~ 92' azimu(h, 933 2583 i~tart oF bui[~ ~ E'/100' (o indin=tion oF 32' o~ an azimuth oF 9~'. ~RTIC~ ~ 2583 4008 iM=int=rn t=ngent ~o 10 3/4' c=sln9 point. SC~ 100 It. / ~. 4008 9408 ~9pl~[ out 9 7/8' hole. Malnt=ln i~ngent ~o 7 5/8' ccsln9 point ~ ~: ~ 9408 9569 i~tap~ o~ curve at 8'/100' ~o 45' lncLlna~lon =~ 88' azrau(h. ~RTIC~ ~EC~ON REF: ~ 9569 9740 ~Ma[nloln ~anoen% ~hpouoh Zone 3. 9740 10876 igtapt oF cupve a~ 8'/100' lo 88' inclination at an azinuth o~ 87', 84oo~ 10276 10633 ;Main~ain tangent. [~ 10633 10858 ~Start o~ curve at 8'/t00~ to 90.8' ~ncUn~tlon and 70' ~z[Muth. 8500 ~ 4[~' ~ 9740 ~ ST~T ~ ~ E 8.~3'/1~ Fl 85~4 47.77' ~ ~4 ~ Zone ~ / ~~s~' a 9840 ~ 8SO0 / 8619 ----4543------ ~' e 9937 P~ Z~e ~ Ro,~o 6~80' e 10~5 ~ Zone t~ / Lowe~ ' 97.91' a 10e76 ~ ~ ~ ~vz ................. ~.86' s725/-- 87.9l' 8800 1 VERTICAL SECTION PLANE: 85.05" Survey Reference: W-ELLI-IEAD Reference World Coordinates: Lat. 70.17.45 N - Long. 148.26.51 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 5960248.31 N 691728.66 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD BPX-Shared Services Drilling Alaska State Plane: Zone4 PBU: EOA: D$18 18-34 As-buiJt 18-34 Wpl0 Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Comp?ted using WIN-CADDS REV2.1.B . V,ertical section Plane: 85.05 deg. APPROV[-D WELL DESIGN OCT 1 9 199,5 Oil & Gas Cons. Commission ..... --, gnchorage ' P~el Date: 10/13/95 Time: 2:56 pm Wellpath ID: 18-34 Wpl0 Last Revision: 10/11/95 Measured Incl Drift Subsea TVD Course Depth Dir. Depth Length (ft) (deg.) (deg.) (ft) (ft) (ft) TIE IN 0.00 0.00 0.00 -53.90 0.00 0.00 KOP / START OF BUILD @ 1.50 deg/100 ft 600.00 0.00 0.00 546.10 600.00 600.00 700.00 1.50 92.00 646.09 699.99 100.00 800.00 3.00 92.00 746.01 799.91 100.0(} 900.00 4.50 92.00 845.79 899.69 100.00 START OF BUILD @ 2.00 deg/100 ft 933.33 5.00 92.00 879.01 932.91 33.33 1033.33 7.00 92.00 978.46 1032.36 100.00 1133.33 9.00 92.00 1077.48 1131.38 100.00 1233.33 11.00 92.00 1175.95 1229.85 100.00 1333.33 13.00 92.00 1273.76 1327.66 10~.00 1433.33 15.00 92.00 1370.79 1424.69 100.00 1533.33 17.00 92.00 1466.91 1520.81 100.00 1633.33 19.00 92.00 1562.01 1615.91 100.00 1733.33 21.00 92.00 1655.98 1709.88 100.00 1833.33 23.00 92.00 1748.69 1802.59 I00.00 1933.33 25.00 92.00 1840.04 1893.94 100.00 2033.33 27.00 92.00 1929.91 1983.81 I00.00 END OF BUILD 2083.33 28.00 92.00 1974.26 2028.16 50.00 START OF BUILD @ 2.00deg/100~ 2383.33 28.00 92.00 2239.15 2293.05 300.00 2483.33 30.00 92.00 2326.61 2380.51 100.00 TOTAL Rectangular Offsets (ft) (ft) 0.00N 0.00 E 0.00 N 0.00 E 0.05 S 1.31 E 0.18 S 5.23 E 0.41 S 11.77 E 0.51 S 14.53 E 0.87 S 24.97 E 1.36 S 38.88 E 1.96 S 56.23 E 2.69 S 77.01 E 3.53S 101.19E 4.50S 128.73 E 5.57 S 159.61E 6.77 S 193.79 E 8.07 S 231.23 E 9.49 S 271.88 E 11.02 S 315.68 E 11.83 S 338.76 E 16.74 S 479.51E 18.44 S 527.96E GRID Coordinates Closure Northing Easting Dist. Dir. (ft) (ft) (ft) (deg.) 5960248.31 691728.66 5960248.31 691728.66 5960248.30 691729.97 5960248.26 691733.89 5960248.20 691740.43 5960248.17 691743.19 5960248.08 691753.65 5960247.94 691767.56 5960247.78 691784.92 5960247.59 691805.71 5960247.36 691829.90 5960247.10 691857.46 5960246.81 691888.36 5960246.49 691922.55 5960246.14 691960.01 5960245.76 692000.68 5960245.35 692044.51 5960245.13 692067.59 5960243.82 692208.42 5960243.37 692256.89 0.0C@ 0.00 O.OC@ 0.00 1.31@ 92.00 Vertical Section (ft) 0.00 0.00 1.30 Build Walk DLS Cum. Rate Rate Dogleg (dg/100ft) (dg/100ft) (dg/100ft) (deg) Expected Total Rectangular Coords fit) fit) 0.00 0.00 0.00 0.0 0.00 N 0.00 E Max Hor Min Hor Dir. Vert Error Error Max Err Error (ft) (ft) (deg.) (ft) 0.00 0.00 0.00 0.00 MWD 0.00 0.00 0.00 0.0 0.00N 0.00 E 2.46 2.46 0.00 0.82 1.50 0.00 1.50 1.5 0.05 S 1.31 E 2.62 2.62 2.00 0.97 5.22@ 92.00 5.20 1.50 0.00 1.50 3.0 11.7?@ 92.00 11.69 1.50 0.00 1.50 4.5 14.54@ 92.00 14.43 1.50 0.00 1.50 5.0 24.9~@ 92.00 24.80 2.00 0.00 2.00 7.0 38.9£@ 92.00 38.62 2.00 0.00 2.00 9.0 56.2?@ 92.00 55.85 2.00 0.00 2.00 11.0 76.49 100.51 127.87 2.00 0.00 2.00 13.0 2.00 0.00 2.00 15.0 2.00 0.00 2.00 17.0 77.0~@ 92.00 101.25@ 92.00 128.81@ 92.00 159.71@ 92.00 193.91@ 92.00 231.37@ 92.00 272.04@ 92.00 315.88@ 92.00 338.9e@ 92.00 158.54 2.00 0.00 2.00 192.49 2.00 0.00 2.00 229.67 2.00 0.00 2.00 0.20 S 5.23 E 2.81 0.47 S 11.77 E 3.03 0.58 S 14.52E 479.81@ 92.00 528.28@ 92.00 2.79 2.00 1.12 2.98 2.00 1.28 3.12 3.05 2.00 1.33 1.04 S 24.97 E 3.43 1.67 S 38.87 E 3.84 2.50 S 56.22 E 4.36 3.53 S 76.98 E 5.04 4.79 S 101.14E 5.87 6.27 S 128.67 E 6.86 19.0 8.00S 159.53 E 8.04 21.0 9.97 S 193.68 E 9.39 23.0 12.21S 231.09 E 10.92 14.72 S 271.69 E 12.65 17.51S 315.46E 14.57 18.99 S 338.51E 3.25 2.00 1.50 3.47 2.00 1.68 3.70 2.00 1.86 270.04 313.56 336.48 476.28 524.41 2.00 0.00 2.00 25.0 2.00 0.00 2.00 27.0 2.00 0.00 2.00 28.0 0.00 0.00 0.00 28.0 2.00 0.00 2.00 30.0 3.94 2.00 2.06 4.19 2.00 2.27 4.46 2.00 2.49 4.75 2.00 2.73 5.05 2.00 2.99 5.37 2.00 3.27 5.71 2.00 3.56 6.06 2.00 3.89 15.59 6.24 2.00 4.06 27.94 S 479.12E 21.78 31.15 S 527.52 E 24.05 7.56 2.00 4.81 7.95 2.00 5.19 Survey Tool BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: .10/13/95 Wellpath ID: 18-34 Wpl0 , Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool END OF BUILD 2583.33 32.00 92.00 2412.32 2466.22 100.00 20.23 S 579.43E 5960242.89 692308.39 579.7~@, 92.00 575.53 2.00 0.00 2.00 32.0 34.66S 578.93E 26.52 8.35 2.00 5.61 BPHM-PBD CASING POINT OD = 10 3/4 in, ID = 9.76 in, Weight = 55.50 lb/ft. 4001.63 32.00 92.00 3615.10 3669.00 1418.29 46.46 S 1330.56E 5960235.92 693059.89 1331.37@ 92.00 1321.59 0.00 0.00 0.00 32.0 46.46S 1330.56E 0.00 0.00 0.00 0.00 BPHM-PBD T5 4013.30 32.00 92.00 3625.00 3678.90 11.67 46.68 S 1336.74E 5960235.86 693066.08 1337.55@ 92.00 1327.73 0.00 0.00 0.00 32.0 85.61 S 1335.38E 62.40 15.55 2.00 10.21 BPHM-PBD T3 4691.33 32.00 92.00 4200.00 4253.90 678.03 59.22 S 1695.82E 5960232.56 693425.34 1696.85@ 92.00 1684.39 0.00 0.00 0.00 32.0 109.76 S 1694.05E 79.53 19.06 2.00 12.50 BPHM-PBD K15 5310.40 32.00 92.00 4725.00 4778.90 619.07 70.67S 2023.68E 5960229.56 693753.37 2024.91@ 92.00 2010.04 0.00 0.00 0.00 32.0 131.82S 2021.54E 95.19 22.27 2.00 14.61 BPHM-PBD Ugnu 6324.49 32.00 92.00 5585.00 5638.90 1014.09 89.42 S 2560.74E 5960224.68 694290.70 2562.3£@ 92.00 2543.48 0.00 0.00 0.00 32.0 167.95 S 2557.99E 120.87 27.56 2.00 18.09 BPHM-PBD West Sak 7090.96 32.00 92.00 6235.00 6288.90 766.47 103.60 S 2966.65E 5960221.01 694696.83 2968.4{~@ 92.00 2946.67 0.00 0.00 0.00 32.0 195.26 S 2963.45E 140.28 31.57 2.00 20.74 BPHM-PBD K12 7320.90 32.00 92.00 6430.00 6483.90 229.94. 107.85 S 3088.43E 5960219.92 694818.66 3090.31@ 92.00 3067.62 0.00 0.00 0.00 32.0 203.45 S 3085.09E 146.11 32.78 2.00 21.53 BPHM-PBD KI0 7934.07 32.00 92.00 6950.00 7003.90 613.17 119.19 S 3413.16E 5960217.00 695143.56 3415.24@ 92.00 3390.17 0.00 0.00 0.00 32.0 225.29 S 3409.46E 161.64 35.99 2.00 23.66 BPHM-PBD K5 8582.62 32.00 92.00 7500.00 7553.90 648.55 131.18 S 3756.63E 5960213.94 695487.21 3758.92@ 92.00 3731.32 0.00 0.00 0.00 32.0 248.40 S 3752.54E 178.08 39.39 2.00 25.90 BPHM-PBD Put River 9301.92 32.00 92.00 8110.00 8163.90 719.30 144.49 S 4137.57E 5960210.56 695868.34 4140.09@ 92.00 4109.69 0.00 0.00 0.00 32.0 274.03 S 4133.05E 196.31 43.17 2.00 28.40 BPHM-PBD Kingak 9307.81 32.00 92.00 8115.00 8168.90 5.90 144.60 S 4140.69E 5960210.53 695871.47 4143.22@ 92.00 4112.80 0.00 0.00 0.00 32.0 274.24 S 4136.17E 196.46 43.20 2.00 28.42 BPHM-PBD Sag River 9343.19 32.00 92.00 8145.00 8198.90 35.38 145.25 S 4159.43E 5960210.37 695890.21 4161.9~@ 92.00 4131.40 0.00 0.00 0.00 32.0 275.50 S 4154.88E 197.35 43.38 2.00 28.55 BPHM-PBD Shublik 9396.25 32.00 92.00 8190.00 8243.90 53.06 146.23 S 4187.53E 5960210.12 695918.33 4190.0~@ 92.00 4159.32 0.00 0.00 0.00 32.0 277.39 S 4182.95 E 198.70 43.66 2.00 28.73 BPHM-PBD START OF CURVE @ 8.00 deg/100 ft 9403.44 32.00 92.00 8196.10 8250.00 7.19 146.36 S 4191.34E 5960210.08 695922.14 4193.89@ 92.00 4163.10 0.00 0.00 0.00 32.0 277.64 S 4186.75 E 198.88 43.70 2.00 28.75 BPHM-PBD CASING POINT OD = 7 5/8 in, ID =.6 5/8 in, W~i~ht = 39.00 lb/ft. 9408.17 32.37 91.85 8200.10 8254.00 4.73 146.45 S 4193.85 E 5960210.07 695924.66 4196.41@ 92.00 4165.60 7.81 -3.22 8.00 32.4 146.45 S 4193.85E 0.00 0.00 0.00 0.00 BPHM-PBD Top Sad / Zone 4 / 4B 9456.45 36.15 90.45 8240.00 8293.90 48.29 146.98 S 4221.02E 5960210.24 695951.83 4223.58@ 91.99 4192.62 7.83 -2.89 8.00 36.2 279.38 S 4216.43E 200.45 43.53 1.98 29.66 BPHM-PBD 9503.44 39.85 89.32 8277.02 8330.92 46.99 146.91 S 4249.95 E 5960211.07 695980.74 4252.49@ 91.98 4221.44 7.86 -2.42 8.00 40.0 280.49 S 4245.37 E 202.02 43.36 1.95 30.51 BPHM-PBD Zone 4A / X-Ray 9540.69 42.78 88.54 8305.00 8358.90 37.25 146.44 S 4274.53 E 5960212.18 696005.30 4277.04@ 91.96 4245.98 7.88 -2.10 8.00 43.0 281.08 S 4269.98E 203.38 43.21 1.92 31.20 BPHM-PBD END OF CURVE 9568.82 45.00 88.00 8325.27 8379.17 28.13 145.85S 4294.02E 5960213.27 696024.77 4296.5£@ 91.95 4265.45 7.89 -1.90 8.00 45.2 281.34S 4289.50E 204.46 43.10 1.89 31.73 BPHM-PBD Zone 3 9589.65 45.00 88.00 8340.00 8393.90 20.83 145.34 S 4308.74E 5960214.17 696039.47 4311.19@ 91.93 4280.16 0.00 0.00 0.00 45.2 281.46 S 4304.24E 205.27 43.21 1.88 31.84 BPHM-PBD Zone 2 / 2C 9695.72 45.00 88.00 8415.00 8468.90 106.07 142:72 S 4383.70E 5960218.74 696114.33 4386.02@ 91.86 4355.06 0.00 0.00 0.00 45.2 282.08 S 4379.31 E 209.38 43.81 1.80 32.40 BPHM-PBD 9735.77 45.00 88.00 8443.32 8497.22 40.05 141.73 S 4412.00E 5960220.47 696142.59 4414.27@ 91.84 4383.34 0.00 0.00 0.00 45.2 282.31 S 4407.65 E 210.93 44.03 1.77 32.61 BPHM-PBD START OF CURVE @ 8.00 deg/1 IX) ft Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 3 Date: 10/13/95 Wellpath D: 18-33~ Wpl0 Measured Incl Drift Subsea TVD Course T O T A L GRID Coordinates Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Survey Tool Depth Dir. Depth Length Rectangular Offsets Northing Easting Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) 9739.70 45.00 88.00 8446.10 8500.00 3.93 141.63 S 4414.78E 5960220.64 696145.37 4417.05@ 91.84 4386.12 0.00 0.00 0.00 45.2 282.34S 4410.44E 211.08 44.06 1.77 32.63 BPHM-PBD Zone 2B / Tango 9774.35 47.77 87.93 8470.00 8523.90 34.65 140.74 S 4439.85E 5960222.19 696170.41 4442.08@ 91.82 4411.17 8.00 -0.20 8.00 48.0 282.61 S 4435.55E 212.52 43.90 1.74 33.30 BPHM-PBD 9839.70 53.00 87.81 8511.65 8565.55 65.35 138.87 S 4490.14E 5960225.37 696220.63 4492.28@ 91.77 4461.43 8.00 -0.18 8.00 53.2 283.28 S 4485.94E 215.57 43.59 1.68 34.57 BPHM-PBD Zone 2A / Romeo 9937.49 60.82 87.66 8565.00 8618.90 97.79 135.64S 4571.94E 5960230.74 696302.31 4573.95@ 91.70 4543.21 8.00 -0.15 8.00 61.1 284.59 S 4567.92E 220.82 43.11 1.57 36.45 BP~I-PBD 9939.70 61.00 87.66 8566.08 8619.98 2.21 135.56 S 4573.87E 5960230.87 696304.24 4575.88@ 91.70 4545.14 8.00 -0.14 8.00 61.2 284.61 S 4569.86E 220.94 43.10 1.57 36.49 BPHM-PBD Zone' lB /Lower Romeo 10004.78 66.20 87.57 8595.00 8648.90 65.08 133.13 S 4632.09E 5960234.81 696362.37 4634.01:@ 91.65 4603.35 8.00 -0.13 8.00 66.4 285.51 S 4628.22E 224.71 42.81 1.49 37.65 BPHM-PBD 10039.70 69.00 87.53 8608.31 8662.21 34.92 131.76S 4664.34E 5960237.03 696394.58 4666.2C@ 91.62 4635.60 8.00 -0.12 8.00 69.2 285.99 S 4660.55E 226.81 42.67 1.45 38.24 BPHM-PBD 10139.70 77.00 87.41 8637.53 8691.43 100.00 127.54S 4759.80E 5960243.74 696489.90 4761.51@ 91.53 4731.07 8.00 -0.12 8.00 77.2 287.56S 4756.27E 233.23 42.30 1.33 39.79 BPHM-PBD 10239.70 85.00 87.31 8653.17 8707.07 100.00 122.99 S 4858.38E 5960250.86 696588.32 4859.94@ 91.45 4829.68 8.00 -0.11 8.00 85.2 289.06 S 4855.14E 239.91 42.07 1.22 41.05 BPHM-PBD END OF CURVE 10276.19 87.91 87.27 8655.42 8709.32 36.49 121.27 S 4894.76E 5960253.54 696624.64 4896.2~@ 91.42 4866.06 8.00 -0.11 8.00 88.1 289.56S 4891.62E 242.36 42.04 1.17 41.43 BPHM-PBD START OF CURVE @ 8.00 deg/100 ft 10633.04 87.91 87.27 8668.41 8722.31 356.85 104.26S 5250.96E 5960279.86 696980.27 5252.01:@ 91.14 5222.41 0.00 0.00 0.00 88.1 294.27 S 5248.86E 266.46 42.27 0.81 44.70 BPHM-PBD 10733.04 89.25 79.38 8670.89 8724.79 100.00 92.64 S 5350.17E 5960294.08 697079.14 5350.98@ 90.99 5322.25 1.34 -7.89 8.00 96.1 288.55 S 5349.18E 273.01 42.62 0.44 45.64 BPHM-PBD 10833.04 90.60 71.49 8671.01 8724.91 100.00 67.52 S 5446.88E 5960321.73 697175.16 5447.31:@ 90.71 5420.77 1.35 -7.89 8.00 104.1 268.92S 5447.73E 279.16 43.26 359.92 46.57 BPHM-PBD END OF CURVE 10851.96 90.86 70.00 8670.77 8724.67 18.92 61.28 S 5464.74E 5960328.44 697192.84 5465.08@ 90.64 5439.09 1.35 -7.89 8.00 105.7 263.70 S 5465.95E 280.30 43.41 359.82 46.75 BPHM-PBD CASING POINT OD = 5 in, ID = 4.13 in, Weight = 21.40 lb/ft. 12901.00 90.86 70.00 8640.01 8693.91 2049.04 639.46N 7389.99E 5961079.65 699099.11 7417.61@ 85.05 7417.61 -0.00 -0.00 0.00 105.7 639.46N 7389.99E 0.00 0.00 0.00 0.00 BPHM-PBD EHL 12901.96 90.86 70.00 8640.00 8693.90 0.96 639.78N 7390.89E 5961080.00 699100.00 7418.53@ 85.05 7418.53 0.00 0.00 0.00 105.7 326.81N 7432.34E 410.43 44.44 353.30 66.92 BPHM-PBD OCT 1 9 1995 Alaska Oil & Gas Cons. Commission ',Anchorage WELL PERMIT CHECKLIST CO~AN~ ,'Z~C__.~ iN= WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv Q ADMINISTRATION 1. 2. 3. 4. 5. 6. ~ 7. 8. 9. 11. 12. Permit fee attached .................. Lease number appropriate ............... Y Unique well name and number .............. Y Well located in a defined pool .............. Well located proper distance from drlg unit boundary... Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ I. Y Operator only affected party ............. Operator has appropriate bond in force ........ Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... I. Y~ ENGINEERING 14. Conductor string provided ............... ~:~ N 15. Surface casing protects all known USDWs~. ....... .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . ._~ 18. CMTwill cover all known productive horizons ...... ~ 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. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25~. BOPEs adequate ..................... ~j~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of E2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~ · Data presented on potential overpressure zones ..... Y ,4I ,~ 32. Seismic analysis of shallow gas zones .......... /N ~~ 33. Seabed condition survey (if off-shore) ....... ./ Y N ' 34. Contact name/phone for weekly progress reports . . ./~ . Y N [ exploratory only] ~ GEOLO~_~: ENGINEERING: COMMISS ION: Comments/Instructions: '-~OW/jo - A:U=ORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~e Subfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT r¢ /MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 6672.00 HENNINGSEN R. BORDES 500292261100 ARCO ALASKA INC. SPERRY-SUN DRILLING SERVICES ll-JUN- 96 MWD RUN 8 M. HALL J. HABERTHUR MWD RUN 9 M. HALL J. HABERTHUR MWD RUN 10 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: M. HALL J. HABERTHUR WELL CASING RECORD MWD RUN 11 M. HALL J. HABERTHUR 24 liN 14E MWD RUN 12 M. HALL J. HABERTHUR 3661 53.65 ~ 50 90 15 90 Date OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 13.500 10.750 3988.0 3RD STRING 9.875 7.625 9401.0 PRODUCTION STRING 6.000 12152.0 REMARKS: MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 - 6 WERE DIRECTIONAL ONLY, NO DATA IS PRESENTED. MWD RUNS 7 - 12 WERE DIRECTIONAL WITH GAMMA RAY. GAMMA RAY DATA FROM 8601 - 9372' WAS AQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS (DGR/SGRC). GAMMA RAY DATA FROM 9372 - 12082' WAS AQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTORS (NGP/SGRD). RECEIVED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8589.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 8589.0 8601.0 9581.5 9593.5 9754.5 9764.0 9757.0 9768.0 9770.0 9779.5 9775.5 9784.5 9805.5 9815.5 9814.0 9823.0 9823.5 9831.5 9840.0 9848.0 9872.5 9881.5 9892.5 9900.5 9978.0 9987.0 9992.5 10003.0 10015.0 10025.5 10027.5 10035.0 10030.0 10037.0 10120.5 10129.0 10128.5 10136.0 10221.0 10227.5 10275.5 10281.5 10289.5 10296.5 10309.5 10317.0 10341.5 10350.5 10442.0 10450.0 10689.0 10696.5 10919.0 10930.5 10936.5 10948.0 11052.0 11058.5 11061.0 11068.0 11082.0 11086.5 11102.0 11108.5 11140.5 11146.0 11361.0 11361.0 11464.5 11467.0 11884.5 11889.0 11904.5 11907.0 12149.5 12152.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD all bit runs merged. STOP DEPTH 12079.0 (open hole, WALS, 26-NOV-95) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 7 8645.0 9417.0 8 9417.0 9696.0 ~WD MWD MWD MWD $ REMARKS: · 9 9696.0 10183.¢ 10 10183.0 10622.0 11 10622.0 11583.0 12 11583.0 12152.0 MERGED PASS. ROP WAS SHIFTED WITH GR. CN WN FN COUN STAT /? ?SHIFT. OUT $ : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 85 Tape File Start Depth = 12150.000000 Tape File End Depth = 8589.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 21370 datums Tape Subfile: 2 216 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LiS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8601.0 $ 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 9372.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMM RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 7. 15-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 9417.0 8645.0 9417.0 0 32.4 34.3 TOOL NUMBER P0426CG6 9.875 3988.0 FW- GEL 10.30 47.0 10.0 1800 5.8 .000 .000 .000 .000 .0 131.0 .0 .0 .00 .000 .0 0 CN WN FN COLIN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 Tape File Start Depth = 9420.000000 Tape File End Depth = 8600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4924 datums Tape Subfile: 3 83 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LiS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9334.0 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 9608.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 18-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 9696.0 9303.0 9696.0 0 37.4 38.6 TOOL NUMBER NGP 184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.750 9401.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FW CELL POLYMER 9.20 71.0 10.0 42000 .0 .000 .0 .000 120.6 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STAiN-DOFF (IN) : EWR FREQUENCY (HZ) : .0 REMARKS: MWD RUN 8. CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 9700.000000 Tape File End Depth = 9325.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23624 datums Tape Subfile: 4 72 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LYS '~<P~ FILE HEADER FILE NUMBER: 4 RAW MIND Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9574.0 $ 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 10116.0 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 9. 19-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 10183.0 9696.0 10183.0 0 38.5 80.7 TOOL NUMBER NGP 204 6.750 9401.0 FW CELL POLYMER 9.30 71.0 10.0 44000 .0 .000 .0 .000 129.0 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 15 Tape File Start Depth = 10185.000000 Tape File End Depth = 9570.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8618 datums Tape Subfile: 5 78 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: hms FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10029.0 $ 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 10531.0 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 10. 20-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 10622.0 10183.0 10622.0 0 84.0 92.2 TOOL NUMBER NGP 184 6.750 9401.0 FW CELL POLYMER 9.30 74.0 10.5 56000 .0 .000 .0 .000 133.0 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 15 Tape File Start Depth = 10630.000000 Tape File End Depth = 10025.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27258 datums Tape Subfile: 6 78 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10503.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO 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 (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 11. STOP DEPTH 11512.0 22-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 11583.0 10622.0 11583.0 0 86.9 94.3 TOOL NUMBER NGP 204 6.750 9401.0 FW CELL POLYMER 9.10 71.0 9.5 47000 .0 .000 .0 .000 141.6 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COLIN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ TIP Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 26 Tape File Start Depth = 11590.000000 Tape File End Depth = 10500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15162 datums Tape Subfile: 7 89 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LiS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11501.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 12082.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 25-NOV-95 ISC 2.11 / MSC 1.32 CIM 3.93 / NGP 5.74 MEMORY 12152.0 11583.0 12152.0 0 87.3 90.5 TOOL NUMBER NGP 184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.750 9401.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO PRO 9.25 72.0 8.0 45000 .0 .000 .000 .000 .000 .0 169.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 12. CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 16 Tape File Start Depth = 12152.000000 Tape File End Depth = 11500.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31174 datums Tape Subfile: 8 79 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 9 is type: 96/ 6/10 01 **** REEL TRAILER **** 96/ 6/10 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 10 JUN 96 10:39p Elapsed execution time = 2.03 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * , ............................ * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 18-34 FIELD N~4E : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292261100 REFERENCE NO : 96131 RECEIVED MAY ,~ ] 1,99G Alaska Oil & Gas 0ohs. Oommission Anchorage L~S Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/22 ORIGIN : FLIC REEL NAME : 96131 CONTINUATION # : PREVIOUS REEL : CO~4~IENT : ARCO ALASKA INC, D.S. 18-34, PRUDHOE BAY, 50-029-22611-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/05/22 ORIGIN : FLIC TAPE NAME : 96131 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC, D.S. 18-34, PRUDHOE BAY, 50-029-22611-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 18-34 API NUMBER: 500292261100 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-MAY-96 JOB NUMBER: 96131 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: J. JULIAN SURFACE LOCATION SECTION: 24 TOWNSHIP: 1 iN RANGE: 14E FNL : FSL: 3661 FEL: 48 F~L : ELEVATION (FT FROM MSL O) KELLY BUSHING: 53.70 DERRICK FLOOR: 50.90 GROUND LEVEL: 15.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 625 9401 . 0 29.70 2ND STRING 5. 500 12153.0 17. O0 3RD STRING 4. 500 9225.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: LOGGING COMPANY: ATLAS BASELINE DEPTH 88888.0 11843.5 11826.0 11632.5 11543.0 11437.5 11357.5 11262.5 11261.0 11157.5 11097.0 11096.5 11072 0 11050 0 1O885 5 10673 5 10624 5 10623 5 10544 0 10507 5 10338 5 10337 0 10333 5 10313 0 10308 0 10283 5 10223 5 10122.0 10121.5 10049.5 10031.5 10031.0 10028.0 10018.0 9995.0 9994.5 9989.5 9979.0 9937.0 9905,0 9895.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88884.5 11822.5 11630.0 11542.0 11361.0 11265.0 11159.0 11096.0 11070.5 11049.0 10671.0 ! 0620.5 10541.5 10505.0 10337.0 10334.5 10332.0 10311.0 10307.5 10281.5 10222.0 10120.5 10048.0 10032.5 10027.0 10015.5 9992.5 88884.5 11840.0 11822.5 11630.0 11542.0 11438.0 11361.0 11265.0 11159.0 11096.0 11070.5 11049.0 10882.5 10671.0 10620.5 10541.5 10505.0 10337.0 10334.5 10332.0 10311.0 10307.5 10281.5 10222.0 10120.5 10048.0 10032.5 10027.0 10015.5 9993.0 9988.0 9988.0 9977.0 9977.0 9935.0 9935.0 9902.5 9902.5 9893.0 9893.0 97.5 97.5 REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED TDTP BORAX PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 LOG ON ARCO ALASKA INC. D.S. 18-34. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT CASED HOLE GR TO ATLAS OPEN HOLE GR AND CASED HOLE SIGM TO ATLAS OPEN HOLE GR. ALL OTHER TDTP CURVES WERE CARIED WITH THE SIGM SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENOMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUI~VlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11872.0 9892.0 TDTP 11912.0 9892.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS TDTP BASE PASS #1. NO PASS TO PASS DEPTH SHIFTS WERE APPLIED TO THIS DATA. $ # LIS FORMAT DATA TABLE TYPE : CONS T UNI VAL U DEFI CN ARCO ALASKA, INC. PRUDHOE BAY Company Name Fi el d Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 4 TUNI VALU DEFI WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN 1 iN Township RANG 14E Range COUN NORTH SLOPE Court ty STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent da tum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRA T LCO1 SDSI BACK FBA C TCAN TCAF TCND TCFD TSCN TSCF INND INFD GRCH TENS Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Local Computation 1 Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector Inelastic count rate - near detector Inelastic count rate - far detector Gamma Ray in Casing Surface Tension LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:~3 PAGE: DEFI CCL CCLAmplitude GR API-Corrected Gamma Ray ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** 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 500380 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 500380 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 500380 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 500380 O0 000 O0 0 t 1 1 4 68 0000000000 SIGC TDTP CU 500380 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 500380 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 500380 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 500380 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 500380 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 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) TSCF TDTP CPS 500380 INND TDTP CPS 500380 INFD TDTP CPS 500380 GRCH TDTP GAPI 500380 TENS TDTP LB 500380 CCL TDTP V 500380 GR ATL GAPI 500380 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11913 SBHN. TDTP -999 LCO1. TDTP -999 TCAN. TDTP -999 TSCN. TDTP - 999 GRCH. TDTP -999 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP 250 TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP 250 TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP 250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR. ATL DEPT. 9563. 500 SBHN. TDTP -999. 250 LCO1. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP -999. 250 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP TENS. TDTP - 999. 250 CCL. TDTP - 999. 250 GR. ATL -999. -999. -999. -999. -999. 97. -999 -999 -999 -999 -999 32 250 250 250 250 250 836 250 250 250 250 250 320 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 £~LYREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 ~XREC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 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 STOP DEPTH GRCH 11872.0 9895.0 TDTP 11912.0 9895.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS lVTJMBER: 1 BASELINE DEPTH .............. 88888 0 11899 5 11891 5 11887 5 11883 5 11879 5 11871 5 11867.5 11863.5 11819.5 11815.5 11803.5 11799.5 11795.5 11791.5 11787.5 11783.5 11779.5 11763.5 11759.5 11755.5 11743.5 11739.5 11735.5 11715.5 11711.5 11707.5 11703.5 11699.5 11695.5 11691.5 11687.5 11683.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.5 88887.0 11898.5 11890.5 11885 5 11881 0 11877 0 11869 5 11865 5 11861 0 11817 0 11812 5 11800 5 11797 0 11793 0 11790 0 11785 0 11782 0 11777 5 11761 5 11757 0 11753.5 11741.5 11737.0 11733.5 11713.5 11709.0 11705.5 11701.5 11697.0 11693.5 11689.0 11685.0 11680.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 11682.5 11675.5 11671.5 11667.5 11662.5 11655.5 11651.5 11647.5 11643.5 11639.5 11635.5 11631.5 11627.5 11591.5 11587.5 11583.5 11575.5 11563.5 11562.5 11559.5 11555.5 11551.5 11547.5 11543.5 11531.5 11530.5 11527.5 11526.5 11523.5 11522.5 11519.5 11518.5 11515.5 11511.5 11507.5 11503.5 11502.5 11499.5 11494.5 11487.5 11483.5 11482 5 11478 5 11475 5 11471 5 11463 5 11459 5 11455 5 11451 5 11447 5 11443 5 11439 5 11435 5 11415 5 11411 5 11682.0 11662.0 11563.5 11531.5 11527.0 11523.0 11519.5 11503.5 11496.0 11484.0 11480.5 11672.5 11667.5 11663.0 11651.0 11648.0 11645.0 11640.0 11636.0 11632.5 11628.5 11625.5 11589.5 11586.0 11583.0 11575.0 11564.5 11561.0 11556.5 11552.5 11549.0 11544.5 11532.5 11529.0 11525.0 11520.5 11516.5 11512.0 11507.5 11504.0 11500.5 11488.5 11485.0 11477.0 11472.5 11464.5 11461.0 11457.5 11453.0 11449.0 11444.5 11440.5 11437.0 11417.0 11412.5 L~S Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 11407.5 11394.5 11387 5 11379 5 11374 5 11363 5 11359 5 11355 5 11342 5 11331.5 11322.5 11319.5 11318.5 11314.5 11311.5 11307.5 11306.5 11303.5 11302.5 11299.5 11295.5 11294.5 11291.5 11290.5 11286.5 11283.5 11282.5 11279 5 11278 5 11275 5 11274 5 11271 5 11270 5 11267 5 11266.5 11263.5 11259.5 11258.5 11211.5 11207.5 11182.5 11179.5 11175.5 11171.5 11167.5 11163.5 11162.5 11159.5 11155.5 11154.5 11151.5 11150.5 11146.5 11143.5 11139.5 11396.5 11378.0 11346.0 11325.5 11321.0 11317.5 11309.5 11305.0 11297.0 11292.5 11288.5 11285.5 11280.5 11277.0 11273.0 11269.5 11261.5 11185.0 11165.0 11157.5 11153.0 11148.5 11408.5 11387.5 11379.5 11365.0 11361.5 11357.0 11331.5 11321.0 11311.5 11306.5 11303.0 11299.5 11297.5 11292.0 11284.0 11280.5 11276.5 11273.0 11269.0 11264.5 11260.5 11209.5 11206.0 11178.0 11175.0 11172.5 11168.5 11164.0 11159.5 11155.0 11151.5 11143.5 11140.0 L~S Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 10 11138.5 11135.5 11134.5 11131.5 11130.5 11127.5 11126.5 11123.5 11122.5 11119.5 11118.5 11111.5 11107.5 11106.5 11103.5 11102.5 11099.5 !1098.5 11095.5 11094.5 11091.5 11090.5 11087.5 11086.5 11083 5 11082 5 11078 5 11071 5 11070 5 11067 5 11066 5 11063 5 11051 5 11050 5 11047 5 11046 5 11043 5 11039 5 11038 5 11035 5 11034 5 11031.5 11027.5 11023.5 11019.5 11018.5 11015.5 11014.5 11011.5 11002.5 10999.5 10998.5 10995.5 10991.5 10987.5 11140.5 11135.0 11130.5 11126.5 11123.0 11118.5 11106.5 11103.0 11099.0 11094.5 11090.5 11086.0 11081.5 11077.0 11069.0 11065.5 11049.5 11046.0 11038.0 11033.5 11017.5 11013.0 11001.0 10996.5 11136.0 11131.5 11127.5 11123.0 11119.5 11111.5 11107.0 11101.5 11099.0 11095.0 11090.5 11086.0 11082.5 11070.5 11066.0 11062.5 11050.5 11046.0 11042.5 11038.5 11033.0 11030.5 11025.5 11021.5 11018.0 11013.0 11009.5 10997.5 10994.0 10989.5 10986.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 11 10983.5 10970.5 10967.5 10966.5 10963.5 10962.5 10959.5 10958.5 10955.5 10954.5 10951.5 10950.5 10947.5 10946.5 10943.5 10942.5 10939.5 10938.5 10935.5 10931.5 10930.5 10927.5 10926.5 10923.5 10919.5 10918.5 10914.5 10911.5 10906.5 10902 5 10895 5 10891 5 10890 5 10887 5 10883 5 10879 5 10875 5 10855 5 10851.5 10847.5 10843.5 10839.5 10835.5 10819.5 10815.5 10795.5 10791.5 10787.5 10783.5 10779.5 10767.5 10763.5 10759.5 10747.5 10743.5 10968.5 10965.0 10960.5 10957.0 10952.5 10948.0 10945.0 10940.0 10934.5 10926.5 10924.0 10916.0 10911.5 10903.5 10899.0 10887.0 10981.5 10965.5 10962.0 10958.5 10953.5 10949.0 10945.0 10941.5 10937.5 10934.0 10929.0 10925.5 10921.5 10918. 0 10909.0 10893.0 10888.5 10884.0 10880.5 10876.0 10872.5 10852.5 10849.0 10846.0 10842 0 10837 5 10834 0 10818 0 10813 5 10793 5 10789 0 10784 5 10780 5 10777.0 10765.0 10761.5 10756.5 10744.5 10741.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 12 10739.5 10727.5 10723.5 10719.5 10710.5 10683.5 10679.5 10675.5 10659.5 10655.5 10651 5 10647 5 10642 5 10638 5 10627 5 10623 5 10619 5 10618 5 10615 5 10611.5 10610.5 10603.5 10599.5 10595.5 10591.5 10587.5 10583.5 10579.5 10575.5 10571.5 10567.5 10563.5 10559.5 10555.5 10551 5 10547 5 10543 5 10539 5 10535 5 10531 5 10523 5 10519 5 10510.5 10507.5 10503.5 10471.5 10467.5 10455.5 10451.5 10447.5 10443.5 10442.5 10439.5 10438.5 10435.5 10708.0 10640.0 10636.5 10616.5 10609.0 10508.0 10440.0 10435.5 10736.5 10724.5 10720.0 10716.5 10680.5 10676.0 10672.5 10656.5 10652.0 10648.0 10644.5 10624.5 10619.5 10615.5 10612.0 10608.5 10600.5 10596.0 10592.0 10587.5 10584.5 10580.5 10576.0 10572.5 10569.0 10564.0 10561.0 10556.5 10553.0 10549.5 10545.5 10542.0 10538.0 10533. $ 10531 . 0 10523.0 10518.0 10506.0 10501.5 10469.5 10466.0 10454.0 10449.0 10446.0 10442.5 10438.0 10434.0 L~S Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 13 10434.5 10431.5 10430.5 10427.5 10423.5 10411.5 10407.5 10403.5 10399.5 10395.5 10391.5 10387.5 10383.5 10375.5 10371.5 10370.5 10367.5 10366.5 10363.5 10362.5 10359.5 10358.5 10355.5 10354.5 10351.5 10350.5 10347.5 10346.5 10343 5 10342 5 10339 5 10338 5 10335 5 10327 5 10323 5 10322 5 10319 5 10318 5 10315 5 10314 5 10311 5 10310 5 10307 5 10306 5 10303 5 10302 5 10299 5 10298 5 10295 5 10291 5 10287 5 10282.5 10279.5 10278.5 10275.5 10432.0 10429.5 10369.5 10365.0 10362.0 10357.5 10353.0 10349.5 10345.0 10341.0 10336.5 10320.5 10317.0 10313. 0 10309.5 10305.5 10302.0 10297. 0 10281.0 10276.5 10429.0 10425.5 10422.0 10410.0 10405.5 10402.5 10398.0 10395.0 10391.0 10385.5 10381.5 10374.0 10370.0 10366.5 10361.5 10357.0 10354.0 10350.0 10345.5 10342.0 10338.5 10333.5 10325.5 10322.0 10318.0 10313.5 10310. 0 10306.5 10302.5 10298. 0 10293.0 10289.5 10286.0 10278. 0 10273.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 14 10271.5 10267.5 10262.5 10260.5 10258.5 10257.5 10255.5 10254.5 10253.0 10251.5 10250.5 10250.5 10239.5 10238.5 10238.5 10235.5 10234.5 10235.0 10231.5 10230.5 10231.0 10226.5 10226.0 10269.0 10266.0 10254.0 10249.5 10237.5 10233.0 10228.0 TABLE TYPE : CONS TUNI VAL U DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Fi el d Name ['~I D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Secti on TOWN 11 N Town ship RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature L~S Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 15 TABLE TYPE : CURV DEFI DEPT Depth SICM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCLAmplitude * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 92 1 0.5 FT 11 0 FT 68 1 1 · LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 16 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500380 O0 000 O0 SIGMTDTP CU 500380 O0 000 O0 TPHI TDTP PU-S 500380 O0 000 O0 SBHF TDTP CU 500380 O0 000 O0 SBPZNTDTP CU 500380 O0 000 O0 SIGC TDTP CU 500380 O0 000 O0 SIBH TDTP CU 500380 O0 000 O0 TRAT TDTP 500380 O0 000 O0 LCO1 TDTP 500380 O0 000 O0 SDSI TDTP CU 500380 O0 000 O0 BACK TDTP CPS 500380 O0 000 O0 FBAC TDTP CPS 500380 O0 000 O0 TCAN TDTP CPS 500380 O0 000 O0 TCAF TDTP CPS 500380 O0 000 O0 TCND TDTP CPS 500380 O0 000 O0 TCFD TDTP CPS 500380 O0 000 O0 TSCN TDTP CPS 500380 O0 000 O0 TSCF TDTP CPS 500380 O0 000 O0 INND TDTP CPS 500380 O0 000 O0 INFD TDTP CPS 500380 O0 000 O0 GRCH TDTP GAPI 500380 O0 000 O0 TENS TDTP LB 500380 O0 000 O0 CCL TDTP V 500380 O0 000 O0 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11911. 000 SIGM. TDTP 18. 380 TPHI. TDTP 29. 641 SBHF. TDTP SBHN. TDTP 51. 846 SIGC. TDTP 1. 209 SIBH. TDTP 74. 343 TRAT. TDTP LCO1 . TDTP 2. 549 SDSI. TDTP O. 406 BACK. TDTP 200. 401 FBAC. TDTP TCAN. TDTP 30247. 625 TCAF. TDTP 11866. 373 TCND. TDTP 25118. 449 TCFD. TDTP TSCN. TDTP 5736. 967 TSCF. TDTP 2250. 655 INND. TDTP 2971 . 358 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP -481 O. 000 CCL. TDTP O. 000 DEPT. 9892.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF, TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP LCO1. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAN. TDTP -999. 250 TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP GRCH. TDTP 42.688 TENS. TDTP -999.250 CCL. TDTP -999.250 41.756 1.778 47.794 7486.086 399.296 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** L'IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 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 SUR~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11872.0 9893.0 TDTP 11912.0 9893.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11891.5 11887.5 11883.5 11879.5 11871.5 11867.5 11863.5 11859.5 11827.5 11823.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 8889O.O 88884 11888 11885 11881 11877 11869 11865 11861.0 11857.5 11825.5 11820.5 LiS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09: 43 PAGE: 18 11819.5 11815.5 11811.5 11791.5 11787.5 11783.5 11779.5 11767.5 11763.5 11759.5 11755.5 11751.5 11747.5 11739.5 11735.5 11731.5 11719.5 11715.5 11711 5 11691 5 11687 5 11683 5 11679 5 11611 5 11603 5 11599 5 11595 5 11591 5 11587 5 11583 5 11579 5 11575 5 11571 5 11570 5 11567 5 11566 5 11563 5 11559 5 11558 5 11555 5 11554 5 11551 5 11550 5 11547.5 11543.5 11539.5 11523.5 11519.5 11515.5 11511.5 11507.5 11503.5 11499.5 11483.5 11479.5 11572.5 11569.0 11561.0 11556.5 11551.0 11817.0 11812.5 11809.5 11789.5 11786.0 11781.5 11778.0 11766.0 11761.0 11757.5 11754.0 11749.5 11746.0 11738.0 11733.5 11730.0 11718.0 11713.5 11710.0 11690.0 11686.5 11682.0 11678.0 11610.5 11602.5 11599.0 11595.0 11592.0 11587.5 11583.5 11579.0 11575.0 11571.5 11567.0 11563.5 11559.5 11556.0 11552.5 11548.0 11544.0 11540.5 11524.5 11521.0 11516.5 11513 0 11508 5 11504 5 11501 0 11485 0 11480 5 LiS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 19 11475.5 11471.5 11470.5 11467.5 11463.5 11459.5 11455.5 11451.5 11450.5 11447.5 11443.5 11439.5 11435.5 11431.5 11419.5 11415.5 11402.5 11398.5 11390.5 11386.5 11382.5 11370.5 11366.5 11362.5 11358.5 11355.5 11354.5 11350.5 11346.5 11335.5 11322.5 11318.5 11315.5 11314.5 11310.5 11306.5 11302.5 11278.5 11274.5 11270.5 11266.5 11262 5 11239 5 11235 5 11227 5 11223 5 11219 5 11215 5 11211 5 11207 5 11195 5 11191 5 11178 5 11175 5 11174 5 11471.0 11453.0 11405.0 11401.5 11393.5 11390.0 11387.0 11375.0 11370.5 11367.0 11363.0 11358.5 11354.5 11351.0 11327.0 11322.5 11318.5 11315.0 11311.0 11307.5 11283.5 11280.0 11275.5 11271.0 11267.0 11182.0 11178.0 11477.0 11473.5 11470.0 11465.5 11461.5 11457.0 11453.5 11449.5 11445.0 11441.0 11437.5 11433.0 11421.0 11417.5 11356.0 11335.5 11320.5 11244.5 11240.0 11232.0 11227.0 11223.5 11219.0 11215.5 11211.0 11199.0 11194.5 11178.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 2O 11170.5 11166.5 11163.5 11162.5 11158.5 11155.5 11154.5 11150.5 11147.5 11146.5 11143.5 11142.5 11139.5 11134.5 11130.5 11123.5 11119.5 11115.5 11114.5 11110.5 11103.5 11099.5 11095.5 11094.5 11091.5 11090.5 11087.5 11083.5 11082.5 11079.5 11078.5 11075.5 11066.5 11062.5 11058.5 11054.5 11051.5 11050.5 11047.5 11046.5 11043.5 11039.5 11035.5 11031.5 11027.5 11026.5 11023 5 11022 5 11019 5 11015 5 11014 5 11011 5 11010 5 11007 5 11006 5 11173.5 11170.0 11166.5 11161.5 11157.0 11153.0 11148.5 11145.0 11137.0 11132.5 11116.5 11110.5 11094.5 11090.0 11082.0 11077.0 11065.0 11062.0 11058.0 11054.5 11050.0 11046.5 l1026.5 11023.0 11015.0 11012.0 11007.0 11165.0 11157.5 11150.5 11145.0 11140.5 11124.5 11121.5 11116.5 11104.5 11100.0 11096.0 11091.5 11087.5 11084.5 11078.5 11075.5 11051.5 11046.5 11043.5 11039.5 11035.0 11030.5 11026.5 11022.0 11017.5 11013.0 11010.5 11006.5 L'IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 21 11003.5 10999 5 10998 5 10994 5 10991 5 10990 5 10987 5 10983 5 10979 5 10967.5 10963.5 10959.5 10955.5 10954.5 10951.5 10950.5 10947.5 10946.5 10935.5 10931.5 10923.5 10922.5 10919.5 10918.5 10915.5 10914.5 10911.5 10907.5 10906.5 10902.5 10898.5 10891.5 10887.5 10883.5 10879.5 10875.5 10867.5 10863.5 10859.5 10855.5 10851.5 10827.5 10823.5 10819.5 10815.5 10807.5 10803.5 10799.5 10795.5 10791.5 10787.5 10783.5 10779.5 10771.5 10767.5 10999.0 10996.0 10991.5 10955.5 10952.5 10947.5 10923.5 10918.5 10915.5 10907.5 10902.5 10898.5 11003.5 10999.0 10991.0 10987.5 10983.0 10978.5 10966.5 10963.5 10959.0 10954.5 10950.5 10946.0 10934.0 10929.5 10921.5 10918.0 10914.0 10909.0 10906.0 10890.0 10885.5 10881.0 10878.0 10874.5 10866.5 10862.0 10858.5 10854.0 10850.5 10826.5 10822.0 10818.0 10815.0 10807.0 10802.5 10798.0 10794.0 10790.5 10786.5 10782.0 10778.5 10770.5 10766.0 · L'IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE 22 10763.5 10759.5 10755.5 10731.5 10727.5 10723.5 10711.5 10706.5 10698.5 10694.5 10690.5 10687.5 10686.5 10683 5 10682 5 10666 5 10659 5 10655 5 10651 5 10646 5 10643 5 10639.5 10635.5 10631.5 10627.5 10623.5 10607.5 10603.5 10591.5 10587.5 10583.5 10575.5 10571.5 10567.5 10563.5 10559.5 10555.5 10535.5 10531.5 10523.5 10519.5 10515.5 10511.5 10507.5 i 0495.5 10475 5 10471 5 10467 5 10463 5 10459 5 10455 5 10451 5 10439 5 10435 5 10431.5 10708.0 10700.0 10695.5 10692.0 10688.5 10684.0 10668.0 10648.5 10762.0 10757.5 10754.5 10730.5 10727.0 10722.5 10709.5 10685.5 10681.0 10657.0 10651.5 10649.0 10641.0 10636.5 10633 0 10628 5 10624 5 10621 0 10605 0 10601 5 10589 5 10585 0 10581 5 10573.5 10570.0 10566.0 10561.5 10557.0 10554.0 10534.0 10530.5 10522.5 10518.0 10514.5 10510.5 10506.0 10494.0 10475.0 10470.5 10467.5 10462.5 10459.0 10455.0 10450.5 10438.5 10435.0 10431.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 23 10427.5 10426.5 10423.5 10421.5 10419.5 10419.0 10415.5 10414.5 10411.5 10411.0 10407.5 10407.5 10395.5 10395.5 10391.5 10393.0 10387.5 10388.5 10383.5 10384.0 10379.5 10379.5 10375.5 10375.5 10374.5 10375.0 10371.5 10371.0 10370.5 10370.5 10367.5 10367.5 10366.5 10366.0 10363.5 10363.0 10355.5 10355.0 10351.5 10350.5 10350.5 10350.0 10347.5 10347.0 10346.5 10345.5 10343.5 10343.5 10342.5 10341.5 10339.5 10339.5 10338.5 10338.0 10335.5 10335.0 10331.5 10331.0 10330.5 10330.0 10327.5 10327.5 10326.5 10325.5 10323.5 10323.5 10322.5 10321.5 10319.5 10318.5 10318.5 10318.0 10315.5 10315.0 10314.5 10314.0 10311.5 10311.5 10310.5 10310.5 10307.5 10307.5 10303.5 10302.5 10302.5 10302.5 10299.5 10299.0 10298.5 10298.0 10295.5 10294.5 10294.5 10295.0 10291.5 10289.5 10290.5 10290.0 10287.5 10286.0 10282.5 10282.0 10279.5 10278.0 10278.5 10277.5 10275.5 10274.5 10271.5 10269.5 ~IS Tape Verification Listing Schlumberger Alaska Computing Center 29-~Y-1996 09:43 PAGE: 24 10270.5 10267.5 10266.5 10263.5 10262.5 10258.5 10251.5 10247.5 10246.5 10243.5 10242.5 10239.5 10235.5 10231.5 10227.5 10223.5 10219.5 10215.5 10211.5 10207.5 10203.5 10199.5 10195.5 10191.5 10190.5 10186.5 10171.5 10167.5 10163.5 10159.5 10147.5 10146.5 10143.5 10142.5 10139.5 10138.5 10135.5 10131.5 10127.5 10123.5 10119.5 10115.5 10111.5 10107.5 10106.5 10103 5 10102 5 10099 5 10098 5 10095 5 10094 5 10090 5 10087 5 10086 5 10083.5 10269.5 10266.0 10261.5 10258.0 10246.0 10242.5 10190.5 10187.0 10147.0 10144.0 10139.0 10107.0 10102.5 10099.0 10094.5 10090.0 10086.5 10266.5 10263.0 10251.0 10246.5 10242.5 10237.5 10233.0 10229.0 10226.5 10222.0 10218.5 10212.5 10209.0 10204.0 10200.0 10196.5 10192.0 10188.0 10171.0 10166.5 10163.0 10157.5 1 O145.5 10142.5 10139.5 10135.0 10131.5 10127.5 10123.0 10119.5 10115.5 10110.5 10107.0 10102.5 10099.0 10095.5 10087.5 10084.0 ~IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 25 10079.5 10078.5 10075.5 10074.5 10071.5 10070.5 10067.5 10066.5 10063.5 10062.5 10059.5 10055.5 10054.5 10051.5 10050.5 10047.5 10043.5 10042.5 10039.5 10038.5 10035.5 10031.5 10030.5 10027.5 10026.5 10023 5 10022 5 10019 5 10018 5 10015 5 10011 5 10010 5 10007.5 10006.5 10002.5 9999.5 9998.5 9995.5 9990.5 9987.5 9986.5 9983.5 9979.5 9974.5 9971.5 9970.5 9967.5 9966.5 9963.5 9959 5 9955 5 9951 5 9950 5 9947 5 9946 5 10078.5 10075.0 10070.5 10066.5 10064.0 10056.0 10051.5 10043.5 10040.0 10032. 0 10027.5 10023.0 10018.5 100!0.5 10005.5 10002.0 9997.0 9989.0 9985.5 9973.5 9969. 0 9965.5 9949.5 9945.0 10079 5 10075 5 10072 0 10068 0 10063 0 10059 5 10055.0 10051.0 10047.5 10044.0 10041.0 10037.5 10033.5 10028.5 10025.0 10021.0 10015.5 10010.0 10006.5 9998.5 9995.0 9987.0 9983.5 9978.5 9970.5 9966.0 9962.0 9959.0 9954.5 9951.0 9947.0 ~IS Tape Verification Listing Schlumberger Alaska Computing Center ~9-MAY-1996 09~43 PAGE: 26 9943.5 9942.5 9942.5 9941.5 9939.5 9938.5 9935.5 9935.0 9931.5 9931.0 9927.5 9926.5 9923.5 9922.5 9919.5 9919.0 9915.5 9914.0 100.0 99.0 98.5 $ REMARKS: THIS FILE CONTAINS TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH PASS #3 TO GRCH PASS #1 AND SIGM PASS #3 TO SIGM PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN 1 iN To~cnship RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature ~IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 27 TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ~IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 28 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 500380 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 500380 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 500380 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 500380 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 500380 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 500380 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 500380 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11908. 500 SIGM. TDTP 20. 796 TPHI. TDTP 30. 952 SBHF. TDTP SBHN. TDTP 51. 004 SIGC. TDTP O. 939 SIBH. TDTP 72. 337 TRAT. TDTP LCO1. TDTP 2. 501 SDSI. TDTP O. 697 BACK. TDTP 205. 293 FBAC. TDTP TCAN. TDTP 26259 . 840 TCAF. TDTP 10501 . 666 TCND. TDTP 25037 . 234 TCFD. TDTP TSCN. TDTP 5672.126 TSCF. TDTP 2268.360 INND. TDTP 3183.496 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP -4820. 000 CCL. TDTP O. 000 DEPT. SBHN. TDTP LCO1. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP 9891 500 42 080 1 978 46163 602 9596 900 -999 250 SIGM. TDTP 14.130 TPHI. TDTP 16. 483 SBHF. TDTP SIGC. TDTP 1.374 SIBH. TDTP 46.140 TRAT. TDTP SDSI.TDTP 0.314 BACK. TDTP 253.245 FBAC. TDTP TCAF. TDTP 23336.199 TCND. TDTP 31444.574 TCFD. TDTP TSCF. TDTP 4851 . 336 INND. TDTP 2946. 997 INFD. TDTP TENS. TDTP -4865. 000 CCL. TDTP O. 000 39.008 1.737 54.788 7584.063 400.842 35.951 1.511 47.933 11787.951 461.711 ** END OF DATA ** ~LIS Tape Verification Listin9 Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 29 **** FILE TRAILER **** FILE NAMiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11960.0 10356.0 TDTP 11996.0 10356.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888 0 11899 5 11895 5 11891 5 11887 5 11883 5 11879.5 11839.5 11835.5 11831.5 11827.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88891.0 88885.5 11897. 11894. 11889. 11886. 11880 11878 11838 11835 11830 11826 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-~Y-1996 09:43 PAGE: 3O 11823.5 11819.5 11811.5 11807.5 11803.5 11799.5 11795.5 11791.5 11787.5 11783.5 11779.5 11775.5 11767.5 11763.5 11759.5 11755.5 11751.5 11743.5 11739.5 11735.5 11731.5 11727.5 11723.5 11719.5 11715.5 11711.5 11707.5 11703.5 11699.5 11679.5 11675.5 11671.5 11667.5 11663.5 11659.5 11643.5 11639.5 11635.5 11623 5 11619 5 11615 5 11603 5 11599 5 11595 5 11587 5 11583 5 11579 5 11575 5 11571 5 11559 5 11555 5 11551 5 11547 5 11543 5 11539 5 11822.0 11818.5 11810.5 11807.0 11802.5 11797.5 11794.5 11790.5 11785.5 11782.5 11778.5 11774.0 11766.0 11761.5 11757.0 11752.5 11749.5 11741.5 11737.0 11734.0 11730.0 11726.5 11722.0 11718.0 11713.5 11710.5 11705.5 11702.0 11698.0 11679.0 11674.5 11670.5 11666.0 11661.5 11658.0 11643.5 11639.5 11634.5 11622.5 11618.0 11614.5 11602.5 11598.0 11594.5 11586.5 11583.5 11579.5 11576.0 11571.5 11559.5 11556.0 11552.5 11548.0 11544.5 11540.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 31 11538.5 11535.5 11531.5 11530.5 11526.5 11523.5 11519.5 11515.5 11511.5 11507.5 11503.5 11498.5 11494.5 11490.5 11487.5 11486.5 11483.5 11482.5 11479.5 11478 5 11474 5 11471 5 11470 5 11467 5 11466 5 11463 5 11462 5 11458 5 11455 5 11451 5 11447 5 11446 5 11443 5 11442 5 11439.5 11438.5 11435.5 11431.5 11427.5 11423.5 11419.5 11403.5 11402.5 11398.5 11394.5 11391.5 11390.5 11387.5 11383.5 11382.5 11379.5 11378.5 11375.5 11374.5 11371.5 11541.5 11533.5 11529.0 11501.0 11496.5 11492.5 11488.0 11484.0 11481.0 11477.0 11472.0 11468.0 11464.5 11460.0 11448.0 11444.5 11440.0 11404.0 11399.5 11395.5 11392.0 11384.0 11379.0 11376.0 11536.0 11531.5 11522.0 11519.5 11516.5 11512.0 11509.0 11504.5 11487.5 11483.5 11480.0 11472.0 11469.5 11464.5 11456.5 11453.0 11448.5 11445.0 11441.0 11438.5 11434.5 11429.5 11425.5 11422.5 11407.5 11394.5 11390.0 11387.0 11383.5 11379.5 11374.5 ~IS Tape Verification Listing Schlumberger Alaska Computing Center 29-~Y-1996 09:43 PAGE: 32 11367.5 11363 5 11351 5 11311 5 11307 5 11303 5 11286 5 11283 5 11282 5 11275 5 11270 5 11266 5 11179 5 11178 5 11174 5 11170 5 11166.5 11162.5 11158.5 11154.5 11146.5 11142 5 11139 5 11138 5 11135 5 11131 5 11130 5 11126.5 11123.5 11119.5 11115.5 11114.5 11111.5 11110.5 11106.5 11102.5 11099.5 11095.5 11091.5 11086.5 11082.5 11066.5 11062.5 11047.5 11043.5 11042.5 11039.5 11038.5 11035.5 11034.5 11031.5 11030.5 11026.5 11018.5 11014.5 11288.0 11283.5 11271.5 11267.0 11178.0 11173.5 11169.5 11165.0 11161.0 11157.5 11153.0 11145.0 11141.5 11138.0 11130.0 11126.5 11114.5 11111.0 11106.5 11103.0 11087.0 11082.5 11066.5 11062.0 11042.0 11038.5 11034.0 11030.0 11026.5 11018.5 11014.0 11371.0 11366.5 11354.5 11311.0 11308.5 11304.0 11284.5 11277.0 11178.0 11141.0 11137.0 11132.5 11124.5 11120.0 11116.5 11112.0 11100.0 11095.5 11091.0 11047.0 11042.5 11038.0 11035.0 11030.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 33 11010.5 11007.5 11003.5 11002.5 10998.5 10994.5 10990.5 10986.5 10979.5 10975.5 10966.5 10963.5 10962.5 10959.5 10958.5 10955.5 10954.5 10951.5 10950.5 10947.5 10943.5 10939.5 10935.5 10931.5 10927.5 10923.5 10919.5 10915.5 10911.5 10907.5 10903.5 10902.5 10899.5 10898.5 10895.5 10891.5 10887.5 10883.5 10879.5 10871.5 10867.5 10863.5 10859.5 10855.5 10851.5 10847.5 10827.5 10823.5 10819.5 10815.5 10811.5 10807.5 10803.5 10799.5 10795.5 11010.5 11002.5 10998.0 10994.0 10989.5 10986.0 10967.0 10962.0 10958.5 10954.0 10950.5 10902.5 10899.0 11006.5 11003.0 10979.0 10974.5 10962.5 10958.0 10954.0 10949.5 10945.0 10940 5 10937 0 10933 0 10928 5 10925 0 10921 5 10918 0 10914 5 10909 5 10906.5 10901.5 10897.5 10894.5 10890 5 10887 0 10881 0 10877 5 10869 5 10865 0 10862 0 10857 5 10852 5 10849 5 10845 0 10825.0 10821.5 10817.5 10812.5 10809.0 10805.0 10801.5 10796.5 10791.5 'LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 34 10791.5 10787.5 10783.5 10779.5 10775.5 10771.5 10767.5 10763.5 10759.5 10755.5 10751.5 10747.5 10743.5 10739.5 10735.5 10731.5 10727.5 10723.5 10715.5 10711.5 10707.5 10703.5 10702.5 10699.5 10698.5 10687.5 10683.5 10682.5 10678.5 10674.5 10663.5 10659.5 10655.5 10651.5 10647.5 10643.5 10638.5 10635.5 10634.5 10631.5 10630.5 10626.5 10623.5 10622.5 10619.5 10618.5 10614.5 10610.5 10607.5 10603.5 10599.5 10595.5 10587.5 10583.5 10579.5 10702.5 10698.0 10682.0 10677.5 10674.0 10638.0 10635.0 10630. 0 10625.5 10621.5 10618. 0 10613.5 10609.5 10787.5 10784.5 10782.5 10778.5 10774. 0 10769.5 10766. 0 10762.5 10759. 0 10753.5 10750. 0 10746. 0 10742.5 10739. 0 10734.5 10731. 0 10725.5 10723. 0 10714.5 10710.5 10705. 0 10702.5 10697.0 10684.5 10680.5 10660.0 10655.5 10651.5 10647.0 10643.0 10639.5 10631.5 10628.5 10620.5 10617. 0 10605. 0 10601.5 10597. 0 10593.5 10585.5 10581. 0 10577. 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 35 10575.5 10571.5 10562.5 10562.0 10559.5 10555. $ 10551.5 10547.5 10543.5 10539.5 10535.5 10531.5 10527.5 10523.5 10519.5 10507.5 10503.5 10499.5 10495.5 10491.5 10479.5 10475.5 10471.5 10467.5 10463.5 10451.5 10447.5 10435.5 10431.5 10427.5 10423.5 10411.5 10407.5 10403.5 10399.5 10395.5 100.0 99.5 $ 10574.0 10569.5 10557.5 10554.0 10550. 0 10545.5 10542. 0 10538. 0 10534.5 10531.0 10526.0 10521 5 10518 0 10506 0 10501 5 10497 5 10494 0 10491. 0 10477.5 10473.5 10470.5 10465.5 10463.0 10451.0 10446.5 10434.5 10430.0 10425.5 10422. 0 10410.0 10405.5 10400.5 10398.0 10394.5 99.0 REMARKS: THIS FILE CONTAINS THE TDTP WELL FLOWING PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH FLOWING PASS TO GRCH BASE PASS #1 AND SIGM FLOWING PASS TO SIGM BASE PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN ~N APIN ARCO ALASKA, INC. PRUDHOE BAY D.S. 18-34 500292261100 Company Name Field Name Well Name API Serial Number 'LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 36 TUNI VALU DEFI FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN liN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 37 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 500380 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 TDTP 500380 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 500380 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500380 O0 000 O0 0 4 t 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 I~VND TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 500380 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 500380 O0 000 O0 0 4 1 ! 4 68 0000000000 TENS TDTP LB 500380 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 500380 O0 000 O0 0 4 1 1 4 68 0000000000 'LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 38 ** DATA ** DEPT. 11993.500 SIGM. TDTP 21.418 TPHI.TDTP 27.885 SBHF. TDTP SBHN. TDTP 53. 997 SIGC. TDTP 3.163 SIBH. TDTP 78. 669 TRAT. TDTP LCO1. TDTP 2. 449 SDSI. TDTP O. 368 BACK. TDTP 94. 367 FBAC. TDTP TCAN. TDTP 31332. 254 TCAF. TDTP 11901. 469 TCND. TDTP 22335.910 TCFD. TDTP TSCN. TDTP 3411.066 TSCF. TDTP 1393.027 INND. TDTP 3134.816 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP -4830. 000 CCL. TDTP O . 000 DEPT. 10355. 000 SIGM. TDTP 18. 605 TPHI. TDTP 20. 164 SBHF. TDTP SBHN. TDTP 46. 779 SIGC. TDTP 1 . 012 SIBH. TDTP 57. 322 TRAT. TDTP LCO1. TDTP 2. 073 SDSI. TDTP O. 358 BACK. TDTP 311. 642 FBAC. TDTP TCAN. TDTP 48460. 438 TCAF. TDTP 23380. 211 TCND. TDTP 34033 . 406 TCFD. TDTP TSCN. TDTP 9789. 008 TSCF. TDTP 4722. 803 INND. TDTP 4026. 570 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP -4740. 000 CCL. TDTP O. 000 50.513 1. 610 24. 012 6011 . 080 406. 641 3 6. 835 1.510 75. 502 13226. 672 760. 620 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SURK~A~Y LDWG TOOL CODE START DEPTH STOP DEPTH L'IS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 39 GRCH 11872.0 10185.0 TDTP 11912.0 10185.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11586.5 11578.5 11574.5 11570.5 11550.5 11546.5 11534.5 11446.5 11442.5 11438.5 11398.5 11390.5 11386.5 11378.5 11374.5 11370.5 11366.5 11354.5 11350.5 11346.5 11342.5 11322.5 11318.5 11314.5 11310.5 11306.5 11294.5 11290 5 11274 5 11270 5 11266 5 11262 5 11182 5 11166 5 11162 5 11158 5 11154.5 11146.5 11142.5 11138.5 11134.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 88890.5 11589.0 11581.0 11577.5 11573.0 11553.0 11549.5 11537 5 11451 0 11447 0 11443 5 11404 0 11396 0 11393 0 11385.0 11381.5 11377.5 11372.0 11360.0 11355.5 11351.5 11348.0 11326.5 11322.5 11318.0 11314.5 11310.0 11298.0 11293 5 11277 5 11274 0 11270 0 11265 5 11184 0 11168 0 11164 5 11160 5 11155.5 11147.5 11142.5 11139.5 11135.5 TDTP 88890.5 11589.0 11581.0 11577.5 11573.0 11553.0 11549.5 11537.5 11451.0 11447.0 11443.5 11404.0 11396.0 11393.0 11385.0 11381.5 11377.5 11372.0 11360.0 11355.5 11351.5 11348.0 11326.5 11322.5 11318.0 11314.5 11310.0 11298.0 11293.5 11277.5 11274.0 11270.0 11265.5 11184 0 11168 0 11164 5 11160 5 11155 5 11147 5 11142 5 11139,5 11135,5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 40 11130.5 11126.5 11122.5 11094.5 11090.5 11086.5 11082.5 11038.5 11034.5 11030.5 11018.5 11014.5 10998.5 10994.5 10990.5 10986.5 10966.5 10958.5 10954.5 10950.5 10946.5 10942.5 10938.5 10934.5 10930.5 10926.5 10910.5 10906.5 10706.5 10698.5 10694.5 10690.5 10686.5 10678.5 10674.5 10666.5 10594.5 10570.5 10566.5 10562.5 10434.5 10426.5 10374.5 10370.5 10366.5 10354.5 10350 5 10298 5 10294 5 10266 5 10262 5 1 O258 5 10246.5 10242.5 100.0 11130 5 11130 5 11126 11123 11095 11090 11086 11082 5 11126 0 11123 0 11095 5 11090 5 11086 0 11082 11038.0 11038 11033.5 11033 11030.0 11030.0 11018.0 11018.0 11015.0 11015.0 10999.0 10999.0 10994.0 10994.0 10990.5 10990.5 10987.0 10987.0 10966.5 10966.5 10958.5 10958.5 10955.0 10955.0 10950.5 10950.5 10947.0 10947.0 10942.5 10942.5 10939.0 10939.0 10935.0 10935.0 10930.5 10930.5 10927.0 10927.0 10911 0 10911.0 10907 10707 10698 10694 10690 10686 10677 5 10907.5 5 10707.5 0 10698.0 5 10694.5 0 10690.0 0 10686.0 5 10677.5 10674.5 10674.5 10666.5 10666.5 10593 . 0 10593 . 0 10569.0 10569.0 10564.5 10564.5 10561 . 0 10561 . 0 10434.5 10434.5 10426.0 10426.0 10374.0 10374.0 10369.5 10369.5 10366.0 10366.0 10354.0 10354.0 10350.5 10350.5 10298.5 10298.5 10294.0 10294.0 10266.0 10266.0 10261.5 10261.5 10258.0 10258.0 10246.0 10246.0 10242.5 10242.5 100.0 100.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 41 REMARKS: THIS FILE CONTAINS BORAX PASS #1. THE ABOVE DEPTH SHIFTS REFLECT GRCH BORAX PASS #1 TO GRCH BASE PASS #1 AND SIGM BORAX PASS #1 TO SIGM BASE PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. FN PRUDHOE BAY WN D.S. 18-34 APIN 5002922611 O0 FL 3661' FSL & 0048' FEL SECT 24 TOWN 11N RANG 14E COUN NORTH SLOPE STAT ALASKA NAT I USA WITN J. JULIAN SON 500380 PDAT MSL EPD FT O . LMF RKB APD FT 53.7 EKB FT 53.7 EDF FT 50.9 EGL FT 15.9 TDD FT 12078. BLI FT 11920. TLI FT 9900. DFT PRODUCED FLUIDS TLAB 11:15 28-APR-96 BHT DEGF 184. Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRAT Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 42 DEFI LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude ** 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 !1 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 A~MB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500380 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 500380 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 43 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C.[d~SS MOD NUMB S~2~IP ELt~ CODE (HEX) SBHNTDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 500380 O0 000 O0 0 5 1 1 4 68 0000000000 LCO1 TDTP 500380 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 500380 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 500380 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 500380 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 500380 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 500380 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11914. 500 SIGM. TDTP 19. 400 TPHI. TDTP SBHN. TDTP 50. 724 SIGC. TDTP 1. 465 SIBH. TDTP LCO1. TDTP 2. 666 SDSI. TDTP O. 434 BACK. TDTP TCAN. TDTP 28200. 875 TCAF. TDTP 10576. 836 TCND. TDTP TSCN. TDTP 5859. 515 TSCF. TDTP 2197. 631 INND. TDTP GRCH. TDTP -999. 250 TENS. TDTP -4885. 000 CCL. TDTP DEPT. 10185. 000 SIGM. TDTP 14. 354 TPHI. TDTP SBHN. TDTP 74. 484 SIGC. TDTP O . 186 SIBH. TDTP LCO1. TDTP 2. 298 SDSI. TDTP O. 251 BACK. TDTP TCAN. TDTP 39267. 320 TCAF . TDTP 17084 . 176 TCND . TDTP TSCN. TDTP 7801.107 TSCF. TDTP 3394.057 INND. TDTP GRCH. TDTP 29. 969 TENS. TDTP -4910. 000 CCL. TDTP 32 449 72 235 107 047 25547 539 2924 967 0 000 26 773 130 813 218 030 20751 773 2628 455 0 000 SBHF. TDTP TRA T. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP SBHF. TDTP TRA T . TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 36.597 1.831 33.242 7352.636 411.145 56.740 1.799 42.141 7409.798 435.197 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE .. FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: O . 5000 # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11872.0 9895.0 TDTP 11912.0 9895.0 $ # 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 88888.0 88890.0 11876.5 11878.5 11795.0 11797.5 11785.0 11786.5 11763.5 11765.5 11705.0 11707.5 11666.5 11666.5 11666.5 11595.0 11598.0 11574.5 11574.5 11570.5 11571.0 11518.5 11519.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 45 11515.0 11490.5 11486.5 11482.5 11478.5 11474.5 11470.5 11454.5 11454.0 11446.5 11445.5 11442.5 11441.5 11434.5 11433.0 11394.5 11386.5 11382.5 11378.5 11374.5 11370.5 11358.5 11354.5 11330.5 11322.5 11298.5 11294.5 11290.5 11286.5 11270.5 11266.5 11262 5 11236 5 11221 5 11178 5 11142 5 11138 5 11106 5 11102 5 11086 5 11082 5 11050 5 11046 5 11042 5 11038 5 11034 5 11030.5 11026.5 11022.5 11010.5 11006.5 10994.5 10990.5 10954.5 10950.5 11492.5 11488 5 11485 0 11481 5 11477 5 11473 0 11457 0 11449.5 11445.0 11437.0 11397.5 11389.5 11386.0 11383.0 11377.5 11374.0 11362.0 11357.5 11333.5 11325.0 11301.0 11296.5 11291.0 11287.0 11270.5 11266.5 11262.0 11177.0 11141.0 11137.5 11105.5 11102.0 11086.0 11081.5 11049.5 11046.0 11041 5 11037 5 11034 5 11030 0 11026 0 11023 0 11011 0 11006 5 10994.5 10990.0 10954.0 10950.5 11519.0 11492.5 11488.5 11485.0 11481.5 11477.5 11473.0 11457.0 11449.5 11445.0 11437.0 11397 5 11389 5 11386 0 11383 0 11377 5 11374 0 11362 0 11357 5 11333.5 11325.0 11301.0 11296.5 11291.0 11287.0 11270.5 11266.5 11262.0 11238.5 11223.0 11177.0 11141.0 11137.5 11106.0 11102.0 11086.0 11081.5 11049.5 11046.0 11041.5 11037.5 11034.5 11030.0 11026.0 11023.0 11011 0 11006 5 10994 5 10990 0 10954 0 10950 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 46 10898.5 10814.5 10696.0 10694.5 10691.5 10690.5 10686.5 10680.0 10678.5 10675.5 10674.5 10592.5 10544.5 10485.0 10454.5 10450.5 10446.5 10442 5 10434 5 10430 5 10426 5 10418 5 10414 5 10374.5 10370.5 10354.5 10350.5 10346.5 10338.5 10334.5 10326.5 10322.5 10318.5 10314.5 10310.5 10306.5 10302.5 10298.5 10294.5 10290.5 10222 5 10218 5 10214 5 10210 5 10198 5 10194 5 10154 5 10142 5 10138.5 10134.5 10130.5 10126.5 10122.5 10118.5 10114.5 10898.5 10815.5 10695.5 10691.0 10687.5 10679.5 10675.0 10455.0 10450.5 10446.0 10442.5 10434 5 10431 5 10427 0 10419 0 10415 5 10374 5 10370 0 10354.0 10350.5 10346.0 10338.0 10334.5 10326.5 10322.0 10317.5 10313.5 10310.0 10306.0 10301.5 10298.0 10294.0 10289.5 10221.5 10218.0 10213.5 10209.0 10197 0 10193 5 10154 5 10142 5 10137 5 10134 0 10130 0 10126.5 10122.5 10119.0 10114.5 10898.5 10815.5 10695.5 10691.0 10686.0 10679.0 10675,0 10590,0 10543,0 10484.5 10455.0 10450,5 10446.0 10442,5 10434,5 10431,5 10427.0 10419,0 10415.5 10374 5 10370 0 10354 0 10350 5 10346 0 10338 0 10334 5 10326 5 10322 0 10317 5 10313 5 10310, 0 10306, 0 10301.5 10298,0 10294.0 10289.5 10221.5 10218.0 10213,5 10209.0 10197.0 10193.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 47 10090.5 10086.5 10082.5 10078.5 10074.5 10070.5 10066.5 10062.5 10058.5 10050.5 10046.5 10042.5 10038.5 10034.5 10026.5 10022.5 10018.5 10010.5 10006.5 10002.5 9990.5 9986.5 9974.5 9970.5 9966.5 9950.5 9946.5 9942.5 100.0 $ 10090.5 10086.0 10082.5 10079.5 10074.5 10071.0 10067 0 10064 5 10060 0 10052 0 10047 5 10042 5 10040 5 10036 0 10028 0 10023 0 10017.5 10009.5 10006.5 10001.0 9989.0 9985.5 9973.5 9969.0 9965.5 9949.5 9945.0 9941.5 99.0 99.0 REMARKS: THIS FILE CONTAINS BORAX PASS #2. THE ABOVE DEPTH SHIFTS REFLECT GRCH BORAX PASS #2 TO GRCH BASE PASS #1 AArD SIGM BORAX PASS #2 TO SIGM BASE PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN ARCO ALASKA, INC. PRUDHOE BAY D.S. 18-34 5002922611 O0 3661' FSL & 0048' FEL 24 liN 14E NORTH SLOPE ALASKA USA J. JULIAN Company Name Field Name Well Name API Serial Number Field Location Section Township Range Co un ty State or Province Nation Wi tness Name LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 48 TUNI VALU DEFI SON 500380 PDAT MSL EPD FT O . LMF RKB APD FT 53.7 EKB FT 53.7 EDF FT 50. 9 EGL FT 15.9 TDD FT 12078. BLI FT 1192 O. TLI FT 9900. DFT PRODUCED FLUIDS TLAB 11:15 28-APR-96 BHT DEGF 184. Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector GRCH Gamma Ray in Casing TENS Surface Tension CCL CCL Amplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 49 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 500380 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 TDTP 500380 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 500380 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 500380 O0 000 O0 0 6 ! 1 4 68 0000000000 TCND TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 500380 O0 000 O0 0 6 ! 1 4 68 0000000000 TSCN TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 500380 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 500380 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 500380 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 500380 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 5O ** DATA ** DEPT. 11915. 000 SIGM. TDTP SBHN. TDTP 77. 000 SIGC. TDTP LCO1 . TDTP 2. 312 SDSI. TDTP TCAN. TDTP 21372. 352 TCAF. TDTP TSCN. TDTP 4590. 606 TSCF. TDTP GRCH. TDTP -999. 250 TENS. TDTP DEPT. 9894. 000 SIGM. TDTP SBHN. TDTP 81. 814 SIGC. TDTP LCO1 . TDTP 1. 685 SDSI. TDTP TCAN. TDTP 36218. 844 TCAF. TDTP TSCN. TDTP 7757. 732 TSCF. TDTP GRCH . TDTP 35.188 TENS. TDTP 18. O. O. 9243. 1985. -4925. 12. O. O. 21499. 4605. -4945. 617 TPHI. TDTP 27. 793 SBHF. TDTP 642 SIBH. TDTP 140. 606 TRAT. TDTP 404 BACK. TDTP 160. 180 FBAC. TDTP 395 TCND. TDTP 17336. 035 TCFD. TDTP 406 INI~-D. TDTP 2854 . 494 INFD. TDTP 000 CCL. TDTP O. 000 59.485 1.669 36.438 5750.688 427.815 232 TPHI.TDTP 13.963 SBHF. TDTP 52.925 156 SIBH. TDTP 127. 589 TRAT. TDTP 1 . 364 226 BACK. TDTP 241 . 365 FBAC. TDTP 42. 197 754 TCND. TDTP 19998. 609 TCFD. TDTP 9459. 721 043 INND. TDTP 2859.982 INFD.TDTP 484.307 000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 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 TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 51 RE~P~KS: THIS FILE CONTAINS THE ARITtfi~ETIC AVERAGE OF TDTP BASE PUMPIN PASSES #1, #2, AND #3. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. FN PRUDHOE BAY WN D.S. 18-34 APIN 5002922611 O0 FL 3661' FSL& 0048' FEL SECT 24 TOWN 1 iN RANG 14E COUN NORTH SLOPE STAT ALASKA NATI USA WITN J. JULIAN SON 500380 PDAT MSL EPD FT O . LMF RKB APD FT 53.7 EKB FT 53.7 EDF FT 50.9 EGL FT 15.9 TDD FT 12078. BLI FT 11920. TLI FT 9900. DFT PRODUCED FLUIDS TLAB 11:15 28-APR-96 BHT DEGF 184. Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Wi tness Name Service Order Number Permanent da tum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRA T SDSI BACK FBAC Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 52 DEFI TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector LCO1 Local Computation 1 GRCH Gamma Ray in Casing ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 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 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 500380 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 500380 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 53 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BACK TDTP CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 INND PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 500380 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PNAV 500380 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 500380 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11908. 500 SIGM. PNAV 19. 626 TPHI. PNAV 31 . 451 SBHF. PNAV SBHN. PNAV 49. 472 SIGC. PNAV 1.260 SIBH. PNAV 68. 344 TRAT.PNAV SDSI. PNAV O. 506 BACK. TDTP 115. 069 FBAC. TDTP 32. 370 TCAN. PNAV TCAF. PNAV 12042.117 TCND.PNAV 26610.102 TCFD.PNAV 7867.983 TSCN. PNAV TSCF. PNAV 2408.970 INND. PNAV 3051 . 011 INFD. PNAV 400. 868 LCO 1 . PNAV GRCH. TDTP -999. 250 39.433 1.805 31337.328 6262.370 2.596 DEPT. 9889.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF.PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 249.247 FBAC. TDTP 45.168 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 LCOi.PNAV -999.250 GRCH. TDTP 15.625 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listin9 Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 54 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 ~ REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMEaX~: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 11912.0 9892.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY 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) : 28-APR-96 CP42.2 1115 28-APR-96 12078.0 9900.0 11920.0 1800.0 NO TOOL NOY4BER CGRS-A-862 CPSC-A-867 CPLS-A-783 TDIC-A-797 TDT SET 230 12153.0 PRODUCED FLUIDS LIS Tape Verification Listin9 Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 55 BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 184.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELIN=E 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): 1.0 REMARKS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST): OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) MAKE 3 BASE PASSES WHILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BO~ MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BO~ PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS BASE PUMPIN PASS #1 $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name FiN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN 1 iN Township LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 56 TUNI VALU DEFI RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector IArND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude ........................................................... LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 57 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS2 PU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNPS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS2 500380 O0 000 O0 0 8 1 1 4 68 0000000000 LCO1 PS2 500380 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS2 CU 500380 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS2 CPS 500380 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS2 CPS 500300 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS2 LB 500380 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS2 GAPI 500380 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS2 V 500380 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09: 43 PAGE: 58 ** DATA ** DEPT. 11921.000 SIGM. PS2 22.569 TPHI.PS2 38.459 SBHF. PS2 SBPiN. PS2 120.003 SIGC. PS2 0.008 SIBH. PS2 466.335 TRAT. PS2 LCO1.PS2 2.761 SDSI.PS2 0.750 BACK. PS2 112.741 FBAC. PS2 TCAN. PS2 104485.828 TCAF. PS2 37842.570 TCND. PS2 27920.152 TCFD.PS2 TSCN. PS2 6936.217 TSCF. PS2 2512.152 INND.PS2 2918.764 INFD.PS2 TENS.PS2 -4700.000 GR.PS2 38.781 CCL.PS2 0.004 DEPT. 9891.500 SIGM. PS2 12.792 TPHI.PS2 14.447 SBHF. PS2 SBItN. PS2 41.617 SIGC. PS2 1.172 SIBH. PS2 44.863 TRAT. PS2 LCO1.PS2 1.855 SDSI.PS2 0.215 BACK. PS2 248.843 FBAC.PS2 TCAN. PS2 59838.570 TCAF. PS2 32254.113 TCND. PS2 35787.656 TCFD.PS2 TSCN. PS2 12386.584 TSCF. PS2 6676.602 INND.PS2 3091.342 INFD.PS2 TENS. PS2 -4780.000 GR.PS2 15.313 CCL.PS2 0.000 130.006 1.908 32.370 8173.233 399.125 32.506 1.460 45.033 14771.633 502.715 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1vTJMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCRE~IENT: 0.5000 FILE SU~k4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE 59 TDTP 11912.0 $ 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 STRING (TOP TO BOTTOM) VEArDOR TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERMAL DECAY TDTP THERM3LL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE COiVDITIONS 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 9895.0 28-APR-96 CP42.2 1115 28-APR-96 12078.0 9900.0 11920.0 1800.O NO TOOL NUMBER CGRS-A-862 CPSC-A-867 CPLS-A-783 TDIC-A-797 TDT SET 230 12153.0 PRODUCED FLUIDS 184.0 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 6O NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST): OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) MAKE 3 BASE PASSES WHILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BORAX MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BORAX PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS BASE PUMPIN PASS #2 $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN 1 iN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum I~4F RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Ty~e TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBPiN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCLAmplitude ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 62 * * 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 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS3 PU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS3 500380 O0 000 O0 0 9 1 1 4 68 0000000000 LCO1 PS3 500380 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS3 CU 500380 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS3 CPS 500380 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS3 LB 500380 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS3 GAPI 500380 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS3 V 500380 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA DEPT. 11925.000 SIGM. PS3 17.034 TPHI.PS3 SBHN. PS3 45.347 SIGC. PS3 2.533 SIBH. PS3 LCO1.PS3 2.421 SDSI.PS3 0.359 BACK. PS3 TCAN. PS3 40783.297 TCAF. PS3 16843.336 TCND.PS3 TSCN. PS3 5692.017 TSCF. PS3 2350.779 INND.PS3 TENS.PS3 -4805.000 GR.PS3 35.688 CCL.PS3 DEPT. 9894.500 SIGM. PS3 13.837 TPHI.PS3 SBHN. PS3 46.024 SIGC.PS3 1.457 SIBH. PS3 LCO1.PS3 1.974 SDSI.PS3 0.352 BACK. PS3 TCAN. PS3 43459.641 TCAF. PS3 22010.570 TCND.PS3 TSCN. PS3 8745.045 TSCF. PS3 4429.016 INND.PS3 TENS. PS3 -4815.000 GR.PS3 38.063 CCL.PS3 24 050 84 187 213 356 24525 359 2894 747 0 013 16.297 54.509 250.789 30173.211 2965.396 0.000 SBHF. PS3 TRAT. PS3 FBAC. PS3 TCFD.PS3 INFD.PS3 SBHF. PS3 TRAT. PS3 FBAC. PS3 TCFD.PS3 INFD.PS3 35.054 1.742 38.433 7581.460 415.229 36.897 1.503 48.391 11085.178 473.220 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 63 * * * * FILE TRAILER * * * * FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 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 SUFk4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11912.0 9893.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 28-APR-96 CP42.2 1115 28-APR-96 12078.0 9900.0 11920.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER TDTP THERMAL DECAY CGRS-A-862 TDTP THERMAL DECAY CPSC-A-867 TDTP THERMAL DECAY CPLS-A- 783 TDTP THERMAL DECAY TDIC-A- 797 TDTP THERMAL DECAY TDT SET 230 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 64 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) : 12153.0 PRODUCED FLUIDS 184.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST): OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1 ) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) ~E 3 BASE PASSES ~-HILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BORAX MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BORAX PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS BASE PUMPIN PASS #3 $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 65 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN liN Township RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation WITN J. JULIAN Witness Name SON 500380 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRA T LCO1 SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN TSCF Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Local Computation 1 Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 66 DEFI INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS4 CU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS4 PU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS4 CU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS4 CU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS4 CU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS4 CU 500380 O0 000 O0 0 t0 1 1 4 68 0000000000 TRAT PS4 500380 O0 000 O0 0 10 1 1 4 68 0000000000 LCO1 PS4 500380 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS4 CU 500380 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TCAN PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09~43 PAGE: 67 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) TCND PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS4 CPS 500380 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS4 LB 500380 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS4 GAPI 500380 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS4 V 500380 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 11924.000 SIGM. PS4 13.727 TPHI.PS4 SBHN. PS4 41.690 SIGC. PS4 1.932 SIBH. PS4 LCO1.PS4 2.643 SDSI.PS4 0.199 BACK. PS4 TCAN. PS4 36718.984 TCAF. PS4 13893.871 TCND.PS4 TSCN. PS4 5905.011 TSCF. PS4 2234.361 INND.PS4 TENS. PS4 -4825.000 GR.PS4 52.750 CCL.PS4 DEPT. 9892.500 SIGM. PS4 13.326 TPHI.PS4 SBHN. PS4 42.433 SIGC. PS4 1.315 SIBH. PS4 LCO1.PS4 1.982 SDSI.PS4 0.265 BACK. PS4 TCAN. PS4 53388.383 TCAF. PS4 26938.477 TCND. PS4 TSCN. PS4 11092.920 TSCF. PS4 5597.217 INND.PS4 TENS. PS4 -4870.000 GR.PS4 28.094 CCL.PS4 23 036 68 937 187 684 25613 816 3138 758 0 008 16.549 46. 814 250. 026 33620. 563 2957.131 0.000 SBHF. PS4 TRAT. PS4 FBAC.PS4 TCFD.PS4 INFD.PS4 SBHF. PS4 TRAT. PS4 FBAC. PS4 TCFD. PS4 INFD. PS4 30.961 1.822 60.660 7505.928 420.282 32.582 1.536 46.715 12862.109 455.936 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION · 001C01 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 68 **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE · FLIC VERSION . O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11996.0 10356.0 TDTP $ LOG H~ER 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): 28-APR-96 CP42.2 1115 28-APR-96 12078.0 9900.0 11920.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER TDTP THER~ DECAY CGRS-A- 862 TDTP THERMAL DECAY CPSC-A-867 TDTP THERMAL DECAY CPLS- A- 783 TDTP THERMAL DECAY TDIC-A- 797 TDTP THERMAL DECAY TDT SET 230 $ 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): 12153.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 69 BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 184.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST) : OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) MAKE 3 BASE PASSES WHILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BORAX MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BORAX PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS THE WELL FLOWING PASS. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Section TOWN liN Township LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 70 TUNI VALU DEFI RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent da tum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TROT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCLAmplitude LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 71 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** 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 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS1 CU 500380 O0 000 O0 0 tl 1 1 4 68 0000000000 TPHI PS1 PU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS1 CU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNPS1 CU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS1 CU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS1 CU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PSi 500380 O0 000 O0 0 11 1 1 4 68 0000000000 LCO1 PS1 500380 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS1 CU 500380 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS1 CPS 500380 O0 000 O0 0 !1 1 1 4 68 0000000000 FBAC PSl CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TCAN PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS1 CPS 500380 O0 000 O0 0 11 i 1 4 68 0000000000 TSCF PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 INND PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS1 CPS 500380 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS1 LB 500380 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS1 GAPI 500380 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS1 V 500380 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 72 ** DATA ** DEPT. 12006.000 SIGM. PS1 22.725 TPHI.PS1 SBHN. PS1 238.016 SIGC.PS1 0.000 SIBH.PS1 LCO1.PS1 2.490 SDSI.PS1 17.210 BACK. PSi TCAN. PS1 42927.719 TCAF. PS1 17238.602 TCND.PS1 TSCN. PS1 3446.557 TSCF.PS1 1384.043 INND.PS1 TENS. PSi -4830.000 GR.PS1 89.375 CCL.PS1 DEPT. 10354.000 SIGM. PS1 18.394 TPHI.PS1 SBHN. PS1 43.866 SIGC. PS1 1.409 SIBH. PS1 LCO1.PS1 2.089 SDSI.PS1 0.407 BACK. PSi TCAN. PS1 48501.711 TCAF. PS1 23214.730 TCND.PS1 TSCN. PS1 9791.957 TSCF. PS1 4686.796 INND.PS1 TENS.PSi -4740.000 GR.PS1 39.719 CCL.PS1 29 389 SBHF. PS1 927 399 TRAT. PS1 90 746 FBAC. PS1 22389 465 TCFD.PS1 3139 456 INFD. PS1 0 017 19 542 50 569 310 172 34067 484 3832 506 0 000 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD. PS1 188.837 1.634 24.931 5998.153 406.666 35.141 1.516 75.703 13221.998 769.179 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE · FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 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 SUR~iARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09: 43 PAGE: 73 TDTP 11912.0 $ 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): 10185.0 28-APR-96 CP42.2 1115 28-APR-96 12078.0 9900.0 11920.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL 1V-UMBER TDTP THERMAL DECAY CGRS-A- 862 TDTP THERMAL DECAY CPSC-A- 867 TDTP THERMAL DECAY CPLS-A- 783 TDTP THERMAL DECAY TDIC-A- 797 TDTP THERMAL DECAY TDT SET 230 $ 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~¢PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL 12153.0 PRODUCED FLUIDS 184.0 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 R~TE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 74 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 RE~HL~KS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST): OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) MAKE 3 BASE PASSES WHILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BORAX MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BORA~ PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS BORAX PASS #1. $ LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY Field Name WN D.S. 18-34 Well Name APIN 500292261100 API Serial Number FL 3661' FSL & 0048' FEL Field Location SECT 24 Sec tion TOWN 11N Town ship RANG 14E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Na ti on WITN J. JULIAN Wi tness Name SON 500380 Service Order Number PDAT MSL Permanent da rum EPD FT O. Elevation of Permanent Datum LMF RKB Log Measured From APD FT 53.7 Above Permanent Datum EKB FT 53.7 Elevation of Kelly Bushing EDF FT 50.9 Elevation of Derrick Floor EGL FT 15.9 Elevation of Ground Level TDD FT 12078. Total Depth - Driller BLI FT 11920. Bottom Log Interval TLI FT 9900. Top Log Interval DFT PRODUCED FLUIDS Drilling Fluid Type TLAB 11:15 28-APR-96 Time Logger at Bottom BHT DEGF 184. Bottom Hole Temperature LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 75 TABLE TYPE : CURV DEFI DEPT Depth SIGM Sigma (Neutron Capture Cross Section) TPHI TDT Porosity SBHF Borehole Sigma - far detector SBHN Borehole Sigma - Near detector SIGC Sigma Correction SIBH Corrected Borehole Sigma TRAT Ration Total Near to Far counts LCO1 Local Computation 1 SDSI Standard deviation of Sigma BACK Background Count Rates - Near Detector FBAC Background Count Rate - Far Detector TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCLAmplitude ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 76 ** 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 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM PS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI PS5 PU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF PS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNPS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC PS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH PS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT PS5 500380 O0 000 O0 0 12 1 1 4 68 0000000000 LCO1 PS5 500380 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI PS5 CU 500380 O0 000 O0 0 12 1 1 4 68 0000000000 BACK PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TCANPS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TCND PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 INND PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 INFD PS5 CPS 500380 O0 000 O0 0 12 1 1 4 68 0000000000 TENS PS5 LB 500380 O0 000 O0 0 12 1 1 4 68 0000000000 GR PS5 GAPI 500380 O0 000 O0 0 12 1 1 4 68 0000000000 CCL PS5 V 500380 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 11928.000 SIGM. PS5 15.890 TPHI.PS5 31.846 SBHF. PS5 SBHN. PS5 114.006 SIGC. PS5 0.283 SIBH. PS5 413.657 TRAT. PS5 LCO1.PS5 2.837 SDSI.PS5 0.235 BACK. PS5 142.101 FBAC. PS5 TCAN. PS5 21718.816 TCAF. PS5 7656.035 TCND.PS5 26324.172 TCFD.PS5 TSCN. PS5 6425.686 TSCF. PS5 2265.099 INND.PS5 2398.824 INFD.PS5 TENS.PS5 -4895.000 GR.PS5 53.344 CCL.PS5 0.008 DEPT. 10184.000 SIGM. PS5 14.270 TPHI.PS5 26.895 SBHF. PS5 SBHN. PS5 72.766 SIGC. PS5 0.212 SIBH. PS5 126.127 TRAT. PS5 LCO1.PS5 2.318 SDSI.PS5 0.229 BACK. PS5 213.131 FBAC. PS5 TCAN. PS5 39699.727 TCAF. PS5 17127.633 TCND. PS5 21016.188 TCFD.PS5 TSCN. PS5 7904.657 TSCF. PS5 3410.302 INND.PS5 2681.590 INFD.PS5 TENS.PS5 -4915.000 GR.PS5 34.156 CCL.PS5 0.000 117.428 1.999 56.190 7302.413 458.424 56.314 1.808 40.560 7504.668 418.271 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 77 **** FILE TRAILER **** FILE NA~E : EDIT .012 SERVICE : FLIC VERSION · O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 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: O. 5000 FILE SUN~Vi~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 11912.0 9895.0 TDTP $ LOG H~ER DATA DATE LOGGED: 28-APR-96 SOFTWARE VERSION: CP42.2 TIME LOGGER ON BOTTOM: 1115 28-APR-96 TD DRILLER (FT) : 12078. 0 TD LOGGER (FT) : TOP LOG INTERVAL (FT): 9900.0 BOTTOM LOG INTERVAL (FT) : 11920.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VEA~OR TOOL CODE TOOL TYPE TOOL NUMBER TDTP THERMAL DECAY CGRS-A-862 TDTP THERMAL DECAY CPSC-A-867 TDTP THERMAL DECAY CPLS-A- 783 TDTP THERMAL DECAY TDIC-A- 797 TDTP THERMAL DECAY TDT SET 230 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 78 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (?T) : LOGGERS CASING DEPTH (FT) : 12153.0 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 184.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 12000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 R~ARKS: TIED INTO NEUTRON LOG 11/26/95 SURFACE RATES FOR FLOWING PASS (FROM 4/27 TEST): OIL= 2013 WATER= 159 BWPD, GAS= 5833 MSCFPD, CHOKE= 90 DEG, FTP= 528 ***** JOB SEQUENCE ***** 1) MAKE FLOWING TDT PASS 2) PUMP 250 BBLS CRUDE INTO WELL 3) MAKE 3 BASE PASSES WHILE PUMPING @ 2 BPM 4) AFTER PUMPING 675 BBLS CRUDE & 250 BBLS BORAX MADE 1ST BORAX PASS WHILE PUMPING AT 1 BPM 5) PUMPED AN ADDITIONAL 35 BBLS BORAX & 50 BBLS CRUDE STARTED 2ND BORAX PASS WHILE PUMPING AT 1 BPM TOTAL PUMPED: 675 BBLS CRUDE + 285 BBLS BORAX + 116 BBLS CRUDE. THIS FILE CONTAINS BORAX PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 79 TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA, INC. FN PRUDHOE BAY WN D.S. 18-34 APIN 5002922611 O0 FL 3661' FSL & 0048' FEL SECT 24 TOWN 1 IN RANG 14E COUN NORTH SLOPE STAT ALASKA NA TI USA WITN J. JULIAN SON 500380 PDA T MSL EPD FT O . LMF RKB APD FT 53.7 EKB FT 53.7 EDF FT 50. 9 EGL FT 15.9 TDD FT 12078. BLI FT 11920. TLI FT 9900. DFT PRODUCED FLUIDS TLAB 11:15 28-APR-96 BHT DEGF 184. Company Name Field Name Well Name API Serial Number Field Location Section Township Range Court ty State or Province Nation Wi tness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling Fluid Type Time Logger at Bottom Bottom Hole Temperature TABLE TYPE : CURV DEFI DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRA T LCO1 SDSI BACK FBAC TCAN TCAF TCND TCFD TSCN TSCF Depth Sigma (Neutron Capture Cross Section) TDT Porosity Borehole Sigma - far detector Borehole Sigma - Near detector Sigma Correction Corrected Borehole Sigma Ration Total Near to Far counts Local ComputatiOn 1 Standard deviation of Sigma Background Count Rates - Near Detector Background Count Rate - Far Detector Total counts a~alyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total Selected Counts - Far Detector LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 8O DEFI INND Inelastic count rate - near detector INFD Inelastic count rate - far detector TENS Surface Tension GR API-Corrected Gamma Ray CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~q CODE (HEX) DEPT FT 500380 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM PS6 CU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI PS6 PU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF PS6 CU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 SBHNPS6 CU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 SICC PS6 CU 500380 O0 000 O0 0 13 1 ! 4 68 0000000000 SIBH PS6 CU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT PS6 500380 O0 000 O0 0 13 1 1 4 68 0000000000 LCO1 PS6 500380 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI PS6 CU 500380 O0 000 O0 0 13 1 1 4 68 0000000000 BACK PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TCA1VPS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFPS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 81 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUA~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) TCNDPS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 INND PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 INFD PS6 CPS 500380 O0 000 O0 0 13 1 1 4 68 0000000000 TENS PS6 LB 500380 O0 000 O0 0 13 1 1 4 68 0000000000 GR PS6 GAPI 500380 O0 000 O0 0 13 1 1 4 68 0000000000 CCL PS6 V 500380 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. SBPiN. PS6 LCO1.PS6 TCAN. PS6 TSCN. PS6 TENS. PS6 11933 000 78 030 2 243 35184 125 7008 844 -4920 000 DEPT. 9894.000 SBHN. PS6 85.275 LCO1.PS6 1.662 TCAN. PS6 26724.625 TSCN. PS6 5722.664 TENS.PS6 -4940.000 SIGM. PS6 15.796 TPHI.PS6 24.264 SBHF. PS6 SIGC.PS6 0.378 SIBH. PS6 215,735 TRAT. PS6 SDSI.PS6 0.249 BACK. PS6 213.619 FBAC, PS6 TCAF. PS6 15689.061 TCND.PS6 19661.641 TCFD, PS6 TSCF. PS6 3125.335 INND.PS6 2623.105 INFD.PS6 GR.PS6 52,688 CCL.PS6 0.000 SIGM. PS6 13.385 TPHI.PS6 13.571 SBHF. PS6 SIGC. PS6 0.255 SIBH. PS6 133.834 TRAT. PS6 SDSI.PS6 0.309 BACK. PS6 246.223 FBAC. PS6 TCAF. PS6 16080.158 TCND.PS6 17100.992 TCFD.PS6 TSCF. PS6 3443.317 INND.PS6 2875.715 INFD. PS6 GR.PS6 46.750 CCL.PS6 0.000 62.579 1.723 39.476 7137.060 396.953 56.720 1,312 40.449 7819.551 459.468 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE . FLIC VERSION · O01CO1 DATE · 96/05/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-MAY-1996 09:43 PAGE: 82 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/05/22 ORIGIN : FLIC TAPE NAME : 96131 CONTINUATION # : 1 PREVIOUS TAPE COf~4ENT : ARCO ALASKA INC, D.S. 18-34, PRUDHOE BAY, 50-029-22611-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 96/05/22 ORIGIN · FLIC REEL NAME : 96131 CONTINUATION # : PREVIOUS REEL : COf~4ENT : ARCO ALASKA INC, D.S. 18-34, PRUDHOE BAY, 50-029-22611-00 Run 1' 26 - November - 1995 DLL/ZDL/CN/GR 9563 11974 - Logging Services WESTERN ATLAS £ape Subfile '2 is'type: TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION ......... ~ i O-N~:- TOWNSHIP: RANGE: FNL: FSL: FEL: '- FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: ~GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6535.00 R. ECK B. GRABB REMARKS: D.S. 18-34 500292261100 ARCO ALASKA INC. WESTERN ATLAS LOGGING SERVICES 08-DEC-95 OPEN HOLE RUN 2 RUN 3 24 liN 14E 3661 48 53.65 50.90 15.90 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 9401.0 6.750 12153.0 DLL/ZDL/CN/GR. CIRCULATION STOPPED @ 15:30, 25-NOV-95. DLL/ZDL/CN/GR/CAL COMBINATION WAS RUN DRILLPIPE CONVEYED. AFTER LOG CALIPER VERIFICATION NOT AVAILABLE DUE TO DRILLPIPE CONVEYED LOGGING OPERATION. SPIKE ON ZDL AT 11880' DUE TO PCL OPERATION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED-OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9563.0 11914.0 DLL 9622.0 11974.0 SDN 9595.0 11935.0 2435 9632.0 11912.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9607.0 LL3 EQUIVALENT UNSHIFTED DEPTH RHOB NPHI 9606.5 all runs merged; 9635.5 9635.5 9640.5 9640.0 9650.0 9649.5 9657.0 9658.0 9657.5 9658.5 9667.5 9667.0 9684.0 9683.5 9683.0 9683.0 9687.5 9687.5 9704.5 9704.0 9718.5 9718.0 9718.0 9718.5 9738.5 9737.5 9739.0 9738.5 9758.0 9758.0 9770.5 9769.0 9769.5 9769.5 9780.0 9779.5 9803.5 9801.0 9802.5 9806.0 9806.0 9806.5 9804.5 9813.5 9812.5 9814.0 9813.0 9813.0 9818.5 9818.0 9820.5 9820.5 9831.5 9830.5 9831.0 9833.5 9833.5 9834.0 9833.0 9836.5 9835.5 9835.5 9838.0 9837.5 9837.5 9841.0 9840.0 9847.0 9846.0 9847.0 9849.5 9849.0 9873.0 9873.0 9870.5 9872.5 9892.5 9891.5 9892.0 9893.0 9892.0 9896.0 9894.5 9895.5 9898.0 9897.5 9898.0 9898.5 9902.5 9901.5 9918.5 9917.5 9919.0 9937.5 9937.5 9939.5 9939.0 no case 9976. 9990. 9992. 10000. 10015. 10032. 10048. 10058. 10061. 10067. 10095. 10098. 10102. 10120. 10125. 10128. 10181. 10190. 10218. 10222. 10222. 10250. 10277. 10278. 10285. 10305. 10307. 10311. 10312. 10327. 10332. 10334. 10342. 10369. 10473. 10483. 10502. 10605. 10610. 10621. 10625. 10637. 10658. 10691. 10724. 10951. 11044. 11049. 11061. 11062. 11087. 11105. 11335. 11335. 11359. 11440. 11542. 11633. 11727. 11729. 9992.5 10061.0 10095.5 10191.0 10218.0 10625.5 11049.0 11062.5 11633.5 11729.5 9975.5 9989.5 9991.5 9999.0 10014.5 10029.5 10047.0 10058.0 10093.0 10119.0 10127.0 10180.0 10221.0 10249.5 10276.5 10283.5 10304.5 10307.0 10310.5 10331.5 10334.5 10368.5 10473.5 10619.5 10657.5 10724.5 10951.5 11044.0 11062.0 11087.0 11336.0 11440.5 11542.5 11727.5 9975.5 9989.5 9993.0 10000.5 10015.0 10029.5 10046.5 10058.0 10067.0 10093.0 10096.0 10101.5 10120.0 10124.5 10180.0 10220.5 10249.5 10278.0 10285.5 10304.5 10307.0 10312.0 10326.5 10331.0 10334.5 10342.5 10368.5 10473.5 10482.5 10502.0 10604.0 10609.5 10619.5 10636.5 10657.5 10691.0 10724.5 10951.5 11044.0 11062.0 11087.0 11105.5 11334.5 11359.5 11727.5 11836.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DLL SDN 2435 $ REMARKS: 11836.0 11836.0 RUN NO. PASS NO. MERGE TOP 1 4 9563.0 1 4 9622.0 1 4 9595.0 1 4 9632.0 MERGE BASE 11914.0 11974.0 11935.0 11912.0 MAIN PASS. LL3, SP, MTEM, TEND, & TENS WERE SHIFTED WITH LLD. DRHO, PEF, CALl, & RB WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ??MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT $ : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 LL3 DLL 68 1 OHMM 4 3 LLD DLL 68 1 OHMM 4 4 SP DLL 68 1 MV 4 5 MTEM DLL 68 1 DEGF 4 6 TEND DLL 68 1 LB 4 7 TENS DLL 68 1 LB 4 8 RHOB SDN 68 1 G/C3 4 9 DRHO SDN 68 1 G/C3 4 10 PEF SDN 68 1 BN/E 4 11 CALl SDN 68 1 IN 4 12 RB1 SDN 68 1 DEG 4 13 NPHI 2435 68 1 PU-S 4 14 FUCT 2435 68 1 CPS 4 15 NUCT 2435 68 1 CPS 4 4 17 310 01 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 17 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 60 * DATA RECORD (TYPE~ 0) 966 BYTES * Total ~ata Recora . 327 Tape File Start Depth = 11986.000000 Tape File End Depth = 9538.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 78353 datums Tape Subfile: 2 527 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9562.5 DLL 9622.0 ZDL 9590.0 2435 9569.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: STOP DEPTH 11914.5 11974.0 11940.5 11921.0 TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT KNJT ISO ISO KNJT MODL GR CN KNJT ZDL KNJT TEMP PCM RB KNJT MIS DLL FTS $ SWIVEL SUB CABLEHEAD TENSION KNUCKLE JOINT BRIDLE ISOLATOR BRIDLE ISOLATOR KNUCKLE JOINT MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB- SUB KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): 26-NOV-95 FSYS REV. J001 VER. 1.1 1530 25-NOV-95 1204 26-NOV-95 12153.0 11986.0 9563.0 11974.0 1800.0 TOOL NUMBER 3944XA 3974XA 3921NA 3997XA 3997XA 3921NA 3517XA 1309XA 2435XA 3921NA 2222EA/2222MA 3921NA 2806XA 3506XA 3975XA 3921NA 3967XA 1229EA/1229MA 6.750 9401.0 LOGGER"S CASING D~_TH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA PRO-FLO 9.10 60.0 9.0 4.4 170.5 .086 .035 .075 .000 .080 .000 THERMAL SANDSTONE 2.65 .000 .0 70.0 170.5 60.0 .0 72.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG SHR ZDL 68 1 4 17 310 01 1 4 17 220 09 1 4 17 220 10 1 4 17 010 01 1 4 17 660 99 1 4 17 635 99 1 4 17 635 99 1 4 17 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 631 01 1 4 46 995 99 1 15 CNC 2435 68 1 16 CNCF 2435 68 1 17 CN 2435 68 1 18 LSN 2435 68 1 19 SSN 2435 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 817 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 966 BYTES * 76 _ 43 995 99 4 43 995 99 4 43 890 01 4 43 334 31 4 43 334 30 Tape File Start Depth = 11986.000000 Tape File End Depth = 9538.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 195861 datums Tape Subfile: 3 906 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 .2500 VENDOR TOOL CODE START DEPTH GR 11439.0 DLL 11498.0 ZDL 11470.0 2435 11508.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT KNJT ISO ISO KNJT MODL GR CN KNJT ZDL KNJT TEMP PCM RB KNJT MIS DLL FTS $ SWIVEL SUB CABLEHEAD TENSION KNUCKLE JOINT BRIDLE ISOLATOR BRIDLE ISOLATOR KNUCKLE JOINT MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB-SUB KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): STOP DEPTH 11720.0 11780.0 11747.0 11718.0 26-NOV-95 FSYS REV. J001 VER. 1.1 1530 25-NOV-95 1111 26-NOV-95 12153.0 11986.0 9563.0 11974.0 1800.0 TOOL NUMBER 3944XA 3974XA 3921NA 3997XA 3997XA 3921NA 3517XA 1309XA 2435XA 3921NA 2222EA/2222MA 3921NA 2806XA 3506XA 3975XA 3921NA 3967XA 1229EA/1229MA 6.750 9401.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 18-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA PRO-FLO 9.10 60.0 9.0 4.4 170.5 .086 .035 .075 .000 .080 .000 THERMAL SANDSTONE 2.65 .000 .0 70.0 170.5 60.0 .0 72.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG SHR ZDL 68 1 CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S 4 17 310 01 1 4 17 220 09 1 4 17 220 10 1 4 17 010 01 1 4 17 660 99 1 4 17 635 99 1 4 17 635 99 1 4 17 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 631 01 1 4 46 995 99 1 4 43 995 99 1 4 43 995 99 1 17 CN 2435 68 1 PU-L 4 18 LSN 2435 68 1 CPS 4 19 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) Total Data Records: 126 966 BYTES * 76 43 890 43 334 43 334 01 31 30 Tape File Start Depth = 11792.000000 Tape File End Depth = 11416.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 108454 datums Tape Subfile: 4 213 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS 95/12/ 8 01 **** REEL TRAILER **** 95/12/ 9 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 9 DEC 95 ll:19a Elapsed execution time = 4.29 seconds. SYSTEM RETURN CODE = 0
