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187-101
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 21 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ElWINJ ❑ WAG EJWDSPL El No. of Completions: Zero Development 0 Exploratory ❑ I Service ❑ Stratigraphic Test ❑ 2. Operator Name. 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 5/25/2019 187-101 318-171 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 196612 Anchorage, AK 99519$612 10/1/1987 50-029-21757-00-00 4a. Location of Well (Governmental Section): 8, Date TO Reached. 16, Well Name and Number: 10/17/1987 PBU K-13 r Surface: 1804' FNL, 1143' FWL, Sec. 04, T1 IN, R14E, UM 9 Ref Elevations KB 54.30 z 17. Field/Pool(s): r Top of Productive Interval 1327' FNL, 4099' FEL. Sec. 08, T11N, R14E, UM GL 23.90 1 BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1448' FNL, 4236' FEL, Sec 08, TI IN, R14E, UM 10. Plug Back Depth(MD/TVD) 18. Property Designation: Surface I Surface ADL 028303& 028304 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number. Surface: x- 671407 y- 5975416 Zone - ASP 4 12150'/ 9008' 1 95-001 TPI: x- 666290 y- 5970496 Zone- ASP Total Depth: x- 666155 y- 5970372 Zone - ASP 4 12. SSSV Depth(MD/iVD): None PO Thickness of Permafrost MDf VD: 1951' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top Wndow Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/ND: NIA 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary DIL / BHCS / CNL-Poro /Laser -Lag /CCL / GR /CBT / VOL JUN 21 201.. 23, CASING, LINER AND CEMENTING RECORD CASING Wr. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING REC – AMOUNT TOP BOTTOM TOP BOTTOM 20" Surface 111' Surface 111- 13-3/8" 72# L-81 S95 Surface 2806' Surface 2806' 17-1/2" 3900 ou 8 Arctic Set It 9-5/8" 47# L90 Surface 11200' Surface 11200' 12-1/4" 2325 co R Class 'Gr 7' 26*29 -i L-90 10956' - 12150' 812fi' 9008' 8-1/2" 356 ou R Class'G' F:4 -1 24. Open to production or injection? Yes ❑ No RI 25. TUBING RECORD If Yes, list each interval open (MDyTVD of Top and Bottom; Perforation Size and Number; Date Perftl): GRADE DEPTH SET (MD) PACKER SET (MD/TV 3-1l2" 9.3# L-80 11003' 10892'18078' x 2-7/8" 6.5# L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ���(y����,,"s1))r��,�ry�yr[ ^�ACw* _ItTE 2G _Z (111, lJinformation Was hydraulic fmctunng used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed VERIFIED/ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached - 27_ PRODUCTION TEST Data First Production: Not on Production Method of Operation (Flowing, gas lift. etc.): N/A Date of Test: Hours Tealed: Production for Test Penod y Oil -Bbl. Gas -MCF: Water -Bbl Chake Size Gas -Oil Ratio: Flow Tubing Press Caainq Press: Calculated 24 Hour Rate —10 Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (coff): Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only -7N19 .0"ll RBDMSI 'JUN 2 5 2019 28. CORE DATA Conventional Cores) 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 11884' 8815' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 11202' 8310' Shublik A 11259' 8353' Sadlerochit - Zone 4A 11356' 8425' CGL - Zone 3 11535' 8559' Base of CGL - Zane 2 11614' 8617' TDF - Zone 1 11884' 8815' Base Sadlerochit - Kavik 12005' 8903' r Formation at total depth: Kavik 12005' 8903' ' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael Authorized Title: S S ecialist Contact Email: Michael.Hibbert@BP.com Authorized Signature: Dale: I'V( Contact Phone: +1 907 564 4351 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Ia. 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 1 b. 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 forth 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 lags within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071, Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: K-13 26• Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 6998 - 7003' Tubing Punch 4478' 175 Bbls Class'G' 1612' 226 Bbls Class'G' 15001- 1505' Tubing & Casing Perforations 1300'- 1305' Tubing & Casing Perforations 5001-505, Tubing & Casing Perforations 250'- 255' Tubing & Casing Perforations 1250' Cement Retainer / 2/2 Bbls Cement 1200' - Surface 160.5 Bbls Class'G' Surface —63 Gal AS I **`WELL SHUT IN ON ARRIVAL*** (p&a) ATTEMPTED TO RUN 10'x 2.50" DD BAILER, UNABLE TO PASS 6' SLM DRIFT W/ 10'x 2.00" DD BAILER TO 9180' SLM, SEE RESISTANCE @ 6' SLM 7/13/2018 *"*JOB COMPLETE, WELL LEFTS/]*** ***JOB STARTED ON 26-JULY-2018*** (SLB ELINE TBG PUNCH) WELL SHUT IN ON ARRIVAL. INITIAL TWO = 0/0/0. RUN 1 RIH W/ 5' OF TUBING PUNCH. 7/26/2018 ***JOB CONTINUED ON 27-JULY-2018** *'"JOB CONTINUED FROM 26-JULY-2018*** CONTINUE RUN 1 PUNCH TUBING FROM 6997.5' TO 7002.5'. / CCL TO TOP SHOT = 10.6'. CCL STOP DEPTH = 6986.9'. FINAL T/I/O = 280/260/240 WELL SHUT IN ON DEPATURE 7/27/2018 ***JOB COMPLETE*** T/1/0=130/130/130 SI Perform Circ Out (PLUG AND ABANDONMENT) Pumped 100 bbls Hot soapy water followed by 525 bbls NaCL down TBG taking returns up IA out hardline to K- 04 FL. WV/SV?SSV = closed MV/IA/OA= OTG. Pad-op notified of well status upon LRS 7/31/2018 departure. 8/7/2018 Cost Placeholder for marker cap CTU#8 1.75" CT Job Scope: P&A Cement Plug MIRU CTU. 8/11/2018 ***Continue Job on 8/12/18 WSR*** CTU#8 1.75" CT Job Scope: P&A Cement Plug MIRU CTU. RIH w/ Slim 1.75" BDJSN to 7000'. Circulate 150 bbis of 9.8ppg NaCl Brine up the IA. Lay in 175 bbls of Class G Cement taking IA only returns. Lay in cement in Tbg & IA up to 4492'. Pump pipe displacement with 9.8ppg Brine to surface. Estimated TOC in Tbg & IA @ - 4492' ctm. At surface, pump gel pill out to tanks, Jet BOP s. Pump - ri all. Rig Down . Final Whp's= Opsi/Opsi/Opsi. 8/12/2018 ***Job Complete*** ***WELL S/I ON ARRIVAL***(p&a) RAN 2.66" CENT & 2.50" BAILER, TOOLS S/D @ 7' SLM, SLID DOWN TO 10' SLM. RAN 2.20" CENT & 1-3/4" S.BAILER, TAGGED @ 4478' SLM. FULL BAILER OF CEMENT. 8/16/2018 LRS ATTEMPTED MIT-T - FAIL. 110 ALL COMMUNILATING, T/I/0= 0/5/5 Assist slickline with AOGCC (PLUG AND ABANDONMENT) Pumped a total of 6 bbls down TBG. TBG, IA, OA pressures all came up at the same time. Bled pressures down as low as possible, bled back 3 bbls. FWHP: 70/10/17 RDMO: 8/16/2018 VALVES= S.LINE ***CONT FROM 8-16-18 WSR*** RIG DOWN SWCP 4522 8/17/2018 ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 8/17/2018 ***WSR continued from 08/16/2018**** Road unit back to yard. T/l/O = 70/3/6. Temp = SI. NFT PASSED (eval P&A). No AL or flowline. Bled TP pressure from 70 psi to 0 psi to BT in 1 hour. (2.5 bbls). During bleed IAP and OAP decreased to 0 psi. Held open for 30 minutes at 0 psi, no observable flow. Final WHPs = 0/0/0. 8/22/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 Daily Report of Well Operations K-13 TWO = O/VactVac. Temp = SI. CMIT-TxlAxOA FAILED. No AL. Max applied pressure = 1500 psi. Conductor cemented to surface. There is 18" of fluid in cellar w/ dark fluid on top. No LELs in cellar or anywhere else in WH. Vac'd out cellar (22 bbls). Secondary containment installed in cellar. Used 6.4 bbls amb Diesel to pressure TWO to 712/704/700 pumping through IA. At 700 psi, fluid began to leak from the conductor at the 2 o'clock position and from the starting head at the 3 o'clock position. Monitored for 15 min. WHPs decreased 37 psi and the fluid inflow from the conductor and starting head = -1 cup. Bled T/I/O to 0 psi (3 bbls). Hung tags. Final WHPs = 20/0/0. 8/25/2018 SV, WV, SSV = C. MV=O. IA, OA = OTG. 18:10 9/11/2018 Cost placelholder for foam balls for future P&A T/I/O = SSV/0/0. Temp = SI. Cement Balance line (Pre P&A). No AL. No flowline. Secondary containment installed around conductor. No injectivity on control line (04-05-18). Pumped -2 gallons of cement down the balance line. Tag hung. Cement sample left on wellhead. FWPs = SS /0/0. 10/1/2018 SV, SSV = C. WV = LOTO. MV, IA, OA = OTG. 1200 hrs. SLB Fullbore Pumping Crew. Job Scope: Plug & Abandonment down 3-1/2"" TBG taking returns from the IA. Pumped 5 bbls Meth Spear, 10 bbls FW spacer to verify flow path/returns. Pumped 226 bbls 15.8 ppg Class G cement, 2 bbls NaCl spacer, dropped 2x6"" foam wiper balls. Displacea I tSU L;M I wi ore balls + 13.4 bbls after balls = 15.4 bbls) and 2 bbls methanol for a total displacement of 17.6 bbls. TOC in TBG @ 2,000'. PMT returns at surface in IA @ 223 bbls cmt away, clean CMT returns ven ie s 0away. ,, wasb�es. Tree and we[ wel f ead serviced. **Job Compete* 1'8 ppg Class G Cement in TBG from 3196' MD / 2934' TVD to 2 000'MD/1993'TVD 10/15/2018 Class G Cement in IA from 3196 MID 12934'TVD to surface ***WELL S/I ON ARRIVAL***(P&A) DRIFTED WITH 2.25" CENT & 1-3/4" S.BAILER(mule/ball), NO ISSUES THROUGH TIGHT SPOT, TAGGED TOC @ 1606 SLM. (SBLR FULL OF CEMENT) DRIFTED WITH 2.25" CENT & 6'x 1-3/4" DRIVE DOWN BAILER(mule/flapper), SD @ 1612' SLM, BEAT DOWN TO 1614' SLM (AOGCC Witnessed Guy Cook. BAILER FULL OF CEMENT). LRS MIT -T TO 2500# -PASS. (AOGCC Witnessed Guy Cook). DRIFTED WITH 2.25" CENT & 6'x 1-3/4" DRIVE DOWN BAILER(mule/flapper), SD @ 1612' SLM (AOGCC Witnessed Guy Cook. BAILER FULL OF CEMENT). 10/20/2018 ***CONT ON 10-21-18 WSR*** T/1/0=0/0/0 Assist Slickline (PLUG AND ABANDONMENT) AOGCC MIT -T to 2495 psi passed per the state but not by BP's standard. Pressured up Tbg to 2755 psi w/ .19 bbls 60/40 meth. Tbg lost 195 psi in 1st 15 mins and 85 psi in 2nd 15 mins for a total loss of 280 psi in 30 min test. Pressured up Tbg to 2733 psi w/ 1.37 bbls 60/40 meth. Tbg lost 161 psi in 1st 15 mins and 74 psi in 2nd 15 mins for a total loss of 235 psi in 30 min test. FAIL ***Job Cont to 10-21- 2018 WSR*** 10/20/2018 ***CONT FROM 10-20-18 WSR***(P&A) LRS PERFORMED PASSING MIT -T TO 2500#. DRIFTED TO 1612' SLM WITH 2.50" CENT. UNABLE TO PASS 30' SLM WITH 2.61" & 2.71" CENT. 10/21/2018 ***WELL LEFT S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS*** Daily Report of Well Operations K-13 ***Job Cont from 10-20-2018 WSR*** MIT -T to 2611 psi PASS Target pressure = 2500 psi Max Applied pressure = 2750 psi. Pressured up on Tbg to 2641 psi. Tbg lost 17 psi in 1 st 15 mins and 13 psi the 2nd 15 mins for a total of 30 psi in 30 min test. Bled Tbg to 30 psi and got back -1 bbl. Stine in control of well per LRS departure. FWHP's=30/-2/-12 IA,OA=OTG 10/21/2018 ***Tag hung on MV ***JOB STARTED ON 23 -OCTOBER -2018*** (SLB ELINE: PERF/JET CUT) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 0/0/0. RUN 1: PUNCH 1500'- 1505' WITH 2" HYPERJET, 6 SPF, 60 DEG PHASED. DID NOT SEVER CONTROL LINE. PRESSURE RESPONSE NOT SEEN AT OA. RUN 2: RIH WITH 2.5" P OUT CENTRALIZER TO SMALLER OD. RUN 3: RIH WITH 2.5" POWERCUTTER. SAT DOWN AT 35'. REMOVE CENTRALIZERS. RUN 4: RIH WITH 2.5" POWERCUTTER. SAT DOWN AT 35'. PRESSURE UP TUBING TO 1000 PSI. PRESSURE FALLS TO 550 PSI AFTER 30 MINUTES, OA REMAINS AT 0 PSI. BLEED OFF TUBING PRESSURE AND PRESSURE UP TO 1000 PSI AGAIN. PRESSURE RAPIDLY FALLS OFF, STILL NO PRESSURE RESPONSE ON OA. 10/23/2018 ISTAND BY FOR WINDS. T/1/0=0/0/0 SI Assist EL as directed (PLUG AND ABANDONMENT) Pumped 4.8 bbls DSL down TBG in attempt to pressure up. See log for details. EL on well upon departure. CVs 10/24/2018 OTG FWHP=160/5/0 ***JOB CONTINUED FROM 23 -OCTOBER -2018*** (SLB ELINE PERF) RUN 5: PUNCH 1300'- 1305WITH 2" HYPERJET, 6 SPF, 60 DEG. PRESSURE COMMUNICATION STILL NOT OBSERVED ON OA. RDMO. NOTIFY PAD OP AND HANDOVER RAP. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 0/0/0. ***JOB COMPLETE ON 24 -OCTOBER -2018*** 10/24/2018 T/I/O = Vac/Vac/5. Temp - SI. Cellar Watch (Assist Fullbore). No AL. Monitored conductor and cellar during pumping operations. When LRS reached 1200 psi on the OA (and IAP was tracking), fluid started bubbling up between the surface casing and the conductor cement. Also, bubblling was visible at the lower SH connection. LRS bled back and all bubbling quit when the OA reached -15 psi. No communication established TbgxOA. 11/5/2018 LRS in control of well on departure. 1800 hrs. T/1/0=0/0/0 (PLUG AND ABANDONMENT) Pumped 17 bbls diesel down TBG and established a LLR - 0.43 bpm @ 1100 psi. No communication with OA. Pumped a total of 4.9 bbls diesel down OA and pressured up to 1200 psi. IAP tracked with OA. Bubbling occurred at the 10 o'clock position between SC and cement and also developed a leak at the lower SH joint. Bled OAP, IAP tracked down. Bled back - 0.9 bbls. Bubbling has stopped. RDMO. Hung info tags on OA and WV. Swab/SSVNW=Shut. IA/OA=OTG. 11/5/2018 FWHP's=60/3/12 T/1/0 = SSV/20/20. Temp = SI. OA strap (P&A). No AL, SSV pannel or flowline. OA FL @ surface. Bleed OAP to 0 psi, IAP tracking OA bleed, -3 gallons returned. SI OA bleed for OA BUR. OA BUR = 0 psi. Used all string on location 70' down, OA did not encounter any obstruction. Final WHPs = SSV/0/0. 11/22/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00 Daily Report of Well Operations K-13 T/I/O = SSV/0/0. Temp = SI. Strap TOC in OA (P&A). No AL, no flowline, no control panel. Secondary containment installed in cellar and cellar is 70" deep. OA FL @ surface. Preformed 1 hr LTI (PASS). Remove bullplug and after several attempts could not go past 74'. Install bullplug RDMO. Final WHPs = SSV/0/0. 11/29/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 ***WELL S/I ON ARRIVAL*** (P&A) HES RELAY UNIT #46 MIRU & PT TO 4000 PSI. BEGIN STAND-BY FOR ENGINEER. 1/30/2019 ***JOB CONTINUED ON 31 -JAN -2019*** ***JOB CONTINUED FROM 30 -JAN -2019*** (P&A) HES RELAY UNIT #46 RUN 1: PUNCH TBG & PC 500'- 505'W/ 2" MAXFORCE HMX, 60 DEG. PHASE, 6 SPF GUN. RUN 2: PUNCH TBG & PC 250'- 255'W/ 2" MAXFORCE HMX, 60 DEG. PHASE, 6 SPF GUN. PRESSURE UP TUBING TO 500 PSI AFTER SECOND SHOT, IAAND OATRACK RDMO. _ . 1/31/2019 ***JOB COMPLETE ON 31 -JAN -2019*** TWO = SSV/0/0. Temp = SI. Verify sombrero installed in cellar. No AL. 37" sombrero installed in the 70" deep cellar. Will need to pull grating and confined space to retrieve. 2/9/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:40 TWO = 90/20/30. Temp = SI. Cellar Watch (assist Fullbore). No AL, SSV Panel, or flowline. Monitored conductor and cellar during pumping operations. Small bubbling at 3 & 4 o'clock postions on starting head pup joint. Final WHPs = 30/30/50. 2/10/2019 LRS in control of well upon departure. 05:00 T/1/0=85/20/30 Temp=S/I (LRS Unit 42 - OA Integrity Test, LLR) Establish injectivity down the tubing, thru tubing punches, to OA, to formation w/ a total of 33 bbis 60/40 meth. 1.5 bpm @ 600 psi, 2.5 bpm @ 800 psi, 3.5 bpm @ 1040 psi 2.0 bpm @ 700 psi, 3.0 bpm @ 860 psi, 4.0 bpm @ 1100 psi ***Notice minimal, but steady bubbling between starting head and conductor (see DHD AWGRS for details)*** Line up down Tubing, taking returns up OA to surface tanks. Establish 1-1 returns to tank w/ 5.71bbls 60/40 meth. FP hardline with 2bbls 60/40 meth. See log for details. RDMO. SSV/Swab/W V=Shut. IA/OA=OTG. 2/10/2019 FWHP's=1/1/10 TWO = 10/10/0. Temp = SI. WHPs (LTSI). No AL or flowline. Fluid in conductor to top of flutes -3" from top. Secondary containment installed. 2/26/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 3/13/2019 Cost placeholder for trucking costs CTU 9 1.75" coil 0.156WT HS -90 Objective P&A Spot unit in. Standby until am due to harmony outtage. 3/16/2019 ***In progress*** Daily Report of Well Operations K-13 CTU 9 1.75" coil 0.156WT HS -90 ***Cont. from WSR 3-16-19*** Objective P&A MIRU CTU. Make up 2.25" JSN and RIH. Tag at 1628' CTMD and circulate with surf -wash Fill -and to remove hydrocarbons from well. Make up inflatable cement retainer and RIH. Set at 1250' and attempt circulation., Pump 2.2bbis cement below retainer. Unsting from inflate retainer and attempt to lay in. Return line from back of choke trailer to tank manifold is frozen somewhere. Troubleshoot/try and thaw with neat methanol. Rigged up new 2" hardline from choke manifold to OTT farm. Continue troubleshooting. ...Job in Progress... 3/17/2019 CTU 9 1.75" coil 0.156WT HS -90 ***Cont. from WSR 3-16-19*** Objective P&A Attempted to lay in cement and unable due to frozen hardline. Made several attempts to get iron thawed but ran out of thickening time. POOH, displace all cement to OTT. Jet tree/bops. Open up well and establish OA only returns, good. RIH jetting with brine taking OA only returns. Contaminate/jet with Powervis, circulating through OA only (circulate a total of 60bbls of brine and 25bbls PVIS through OA). 9.8 Brine and PVIS in OA. Continue jetting/contaminating tubing with slk 1%KCL and PVIS , taking CTBS only returns down to 1200'. Chase back to surface. Break down BOT spotting valve and mu a 2.25" JSN to jeVFP well. Swap to Cementing BHA with 2.0" BDJSN and RIH. Circulate tubing and OA over 9.8 ppg brine. Lay in 15.8 ppg class G cement from 1180 to 5013 taking CA returns. Stop at 500' to circulate until cement at surface. Continue laying in cement to surface to ing tubing returns until clean cement returned. Jet wellhead and FP down to 2' below master. 3/18/2019 �oGt. o/i r4't ***Job Complete`** 5ce- Pre P&A. Pulled wellhouse / floor kit and moved to Grieve Pad. Hung well sign on wen. 3/20/2019 1 ***Job Complete*** TWO = VaGVac/Vac. Temp = Sl. Bleed WHPs to 0 psi (post P&A). No well house, flow line or scaffold. Current integral installed on OA. T, IA & OA FLs @ near surface. WHPs on Vac, bleed unnecessary. 3/21/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 3/27/2019 T/I/0=0/0/0 LTT master valve passed T/1/0=0/0/0. Pre P&A. RD 3" upper tree, IA, companion IA and OA. Concrete in both IA's and OA. RU tree cap and integral flanges with 1502 caps. ***JOB COMPLETE***See log for 5/6/2019 idetails. Final WHP's 0/0/0. Job Scope: P&A. Excavate around Wellhead / Install Shoring Box (Permanent Plug and Abandon) Used an excavator to dig -14'x14' hole around wllhead to -13.6' deep. Assembled Engineered Modular Shoring Box and placed in excavation hole for wellhead cut. Cut wellhead below tundra. Found 9 5/8" Production casing collapsed at the cut, there was a void in the 9 5/8" fluid down to 19' 9" and a void in the 3.5"down to 30' 1" fluid also. Pad elevation 24'3", tundra elevation 21' 6", Final excavation depth 12', well head cut 10' 1"from surface, Wellhead is cut 4' 1" below tundra grade 5/21/2019 **Job In Progress" Cement top job (post cut). Poured - 12 gallons of AS -1 cement down tubing and -51 5/23/2019 gallons of AS -1 cement down 9 518. To ob complete. job Scope: P&A. Cement top job set up, State inspector on location @ 08:30 (witnessed by 5/25/2019 Bob Noble). Weld marker plate on well stub, pull shoring box and cover hole with rig mats. i - P&A - Removed rig mats covering excavation and began backfilling with excavator loader. Back filled with approximately 120 yards of dirt/gravel. Excavation site filled and <ed with deliniators. Rixse, Melvin G (CED) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Wednesday, June 26, 2019 1:36 PM To: Rixse, Melvin G (CED) Subject: RE: PTD 187-101, Sundry 318-171, K-13 final abandonment Hi Mel, It is our understanding that the OA was cemented in Dec 1997 during a surface casing leak cement job. This was determined when the OA was perforated at 250', 500', 1300' and 1500' and no flow path was established down the tubing to the OA at surface. This was also corroborated by a consistent plumb bob tag in the OA at 73'. When Coiled Tubing laid in the cement plug from 1250' to surface the job was designed to allow a balanced cement plug to be placed in the OA between 1500' and 250' in all areas that were not previously cemented. Give me a call or let me know if you want any. more details. Thanks, Michael From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, June 26, 2019 11:10 AM To: Hibbert, Michael <Michael.Hibbert@BP.com> Subject: PTD 187-101, Sundry 318-171, K-13 final abandonment Michael, It is not clear to me from the operations report (dated 3-18-2019) when BPXA pumped cement to surface on the OA on this well. I realize cement was observed at surface on the OA after cutting off the well head, I just am not clear when it was pumped and whether cement returns from the OA were observed at surface. Can you clarify? I will add your response to the final 10-407. ITU 9 1 75- cal 0 156w7 HS -90 "'Cont from WSR 3-16-19"' lolecLve P&A .ttempted to lay in cement and unable due to frozen hardline Made several attempts to get on thawed but ran out of f itkening Kane POOH, displace all coment to OTT Jet eetbops. Open up well and establish OA only returns, good. RIH fe@mg with bane taking to only returns Conlaminate;lef with Pawervrs, circulahrg through OA only (oreulale a Iota f 60bbls of brine and 25bbls PAS through CAf. 9 B Bnne and PVf5 m CA Contnue wing!conlarmmating tubing with slk f %KCL and PVIS . taking CTBS only returns dcmm to 200Chase back to surface. Break down 80T spolhng valve and mj a 2.25` JSN to !t. -Fp well. Swap to Cementing BRA oath 2 0' BDJSN and RIH. Circulate tubing and OA ver 9.e pp4 brine. Lay n 15.8 ppg class G cement from 1180 to 500' taking OA returns •Cap at 500' to circulate until cement at surface. Continue laying in Cement to surface taking ruing returns until clean cement returned. ,let wellhead arttl FP flown t0 2' below master Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell . Xf* G ;0-4 T = _ 3' MCET/OY WELLH5kD= MCEVOY ACTUATOR= ORB KB. E54= 54.3' BF. BEV = SURFACE )COp= 2000' Max Ante = 52' @ 9253' hffnuD= 1193V DstimTVD = 8800 SS MARKER CAP INSTALLED & BACKFILLED (OS/27H9) WELL CUT 7' BELOW TUNDRA IN TBG & IA PUNCH Minimum ID = 2.313 @ 10936- 2-718" OTIS X NIPPLE ITOP OF 7-LNR J—j 70956' 2-71W TAILRPE 6.50, L-80, 11003' .00579 W. ID = 2.441' 9-5/8' CSG, 479, L-80, D = 8.681' 11199' L-80, .0383 17- LPR, 29M, L-80, .0371 hpf, D = 6.184' SAFETY NOTES: TBG x IA x OA COMM, TBG LEAK K-13 7150', TBG PARTIALLY COLLAPSED @29',CELLAR HAS PRODUCED IN THE PAST. "'CAUlION" 9P4T444Y47S4RRr RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PIT CAS I FT MANDRELS ST PERFORATION SUMMARY TVD REF LOG: BHCS ON 10/16/87 TYPE ANGLEATTOPPE7F: 43" @ 11907' Note: Refer to Production DB for hstucal perf data SIZE SFF INTERVAL OpNSqz DATE 2-1/8' 4 11907-11932 C 12/30/87 2-1/8' 4 11942-12024 C 12f60/87 2-1/8' 4 12047-12055 C 12/30/87 L-80, .0383 17- LPR, 29M, L-80, .0371 hpf, D = 6.184' SAFETY NOTES: TBG x IA x OA COMM, TBG LEAK K-13 7150', TBG PARTIALLY COLLAPSED @29',CELLAR HAS PRODUCED IN THE PAST. "'CAUlION" 9P4T444Y47S4RRr RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PIT CAS I FT MANDRELS ST &D TVD DEV TYPE VLV LATCH PORT DATE 4 3196 2934 48 1115 (WBd RA 10!60/18 KFMJMD 2 TBG PLI NCHES & SL TACO® 3 7170 5598 50 OTIS RA JTCtJAD CARD TBG. IAPERF HOLES & OA 2 10071 7458 47 OTIS RA 1 10702 7881 43 OTIS RA DATE I RB/ BY COWAE NTS DATE REV BY COMMENTS 12187 IOMML COMPLETION 06/19/19 JNUJMD ADDED BF E LE1/ 12/18!09 JKClSV PILA02/16/09) 06/19/19 JA/JMD FULL ABANDDMCBNT(05/27/19) 10/17/18 JL/JMD CNITDIA& 6/19/19 MWJMD ADD®DPZs 10!60/18 KFMJMD 2 TBG PLI NCHES & SL TACO® 06/20/19 JNUJMD ARNOFt CORRf�IDNS TO T LNR 02/07/19 IVJMD T�&PCPUNCHMi(Ot/31/19) 0325/19 JTCtJAD CARD TBG. IAPERF HOLES & OA FUPJOW ABOVEGLM#3 EQ RE IL' D = 2.75' F OF IMT BOTTOM OF DPZ3 1 PRUDHOE BAY UNIT VYLLL: K-13 PERMIT No: x1871010 AR No: 50-02921757-00 T11N. R14E 1803' FNL & 1142' FVVL BP Bcploration (Alaska) MEMORANDUM TO: Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: 5/24/2019 FROM: Bob Noble SUBJECT: Surface Abandonment Petroleum Inspector PBU K-13 BPXA - PTD 1871010; Sundry 318-171 5/24/2019: 1 traveled to BPXA's PBU K -pad, well 13 and met with BP representative Jon Arend. We inspected the marker plate and it was the proper diameter and 3/8" thick. It had the proper company name, PTD, well name, and API number welded onto it. The well is cut off 39 inches below tundra level and full of cement. A 5 -foot bar was used to determine that the cement was hard. I had them place the plate over the cut off and there was no overhang. I allowed them to proceed with welding the plate onto the cutoff casing and backfilling over the well. Attachments: Photos (3) 2019-0524—Surface—Abandon—PBU—K- I 3—bn.doex Page 1 of 3 Ik J 2019-0524_Surface_Abandon_PBU_K-13_bn.docx Page 3 of 3 OF T1,r • I y 8 THE STATE Alaska Oil and as ofA J\ S J A Conservation COmmissi n 333 West Seventh Ave ue " V ' GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 Main: 907.279.1433 OFA S Fax: 907.276. 542 www.aogcc.alaska. ov Michael Hibbert 1a JUN 7'202 Well Interventions Engineer SCA% BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU K-13 Permit to Drill Number: 187-101 Sundry Number: 318-171 Dear Mr. Hibbert: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French ` Chair T DATED this 51- day of June, 2018. RBDM$ JUN 0 6 2018 iii. 1 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 APR 1 7 2018 ,,�� 1. Type of Request: Abandon ID Plug Perforations o Fracture Stimulate 0 Repair Well 0 �Tiperat�n fs t'SY� Suspend ® • Perforate 0 Other Stimulate 0 Pull Tubing 0 CA 41• C g mC 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Othe A • lona uspend a 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number. 187-101 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p• 3. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21757-00-00- 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 1E1 PBU K-13 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028303&028304 PRUDHOE BAY,PRUDHOE OIL " II 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): 12150 9008 • 9210 6942 9210,10969 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-111 31-111 Surface 2775 13-3/8" 31-2806 31-2712 4930/6390 2670/2820 Intermediate 11171 9-5/8" 29-11200 29-8309 6870 4760 Production Liner 1194 7" 10956-12150 8126-9008 7240/8160 5410/7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11907-12055 8832-8939 3-1/2"9.3#x 2-7/8"6.5# L-80 27-11003 Packers and SSSV Type: 5-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 10892/8078 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 1Z1 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development p ' Service 0 14.Estimated Date for Commencing Operations: May 15,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended IEI 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions E • eer Authorized Signature: \ . �•\T. ��� Date: LI/i \lv,ww� 1D1 .� COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number 31 —011 Plug Integrity V BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: y / /` 1-70 71---0 d, G6-vnf",7 f" 4S /h oh 'cinfrG Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No I( Subsequent Form Required: E D - 4 L APPROVED BYTHE // d Approved by: COMMISSIONER COMMISSION Date: �O S I t VTI //// ' ,�� ORIGINAL 1 AV/tiler Or RBDM� JUN 062018 Y; , Submit Form a d Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Dupli e • • bp Well: K- 13 K-13 Suspend Well Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Laurie Derrick (907) 564-5952 History GPB Well K-13 was initially drilled & completed in December 1987. The initial completion was in Zone 1A/B. K-13 had consistent on-time until mid-1997. The well was shut-in for multiple integrity failures including an OA x surface casing leak into the cellar, tubing leaks and IA x OA. Multiple attempts were made to isolate the SC leak, but were unsuccessful. In December of 2009 a lower lateral cement plug was placed in the tubing and IA with roughly -950' of cement but the well still exhibits TxIAxOAxSC leaks during seasonal temperature fluctuations. - Well K-13 has no future utility and has been fully approved by co-owners for permanent abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a lateral surface cement plug in the well in addition to the lower lateral cement plug that was placed in the well in December 2009. Cut off tubulars below pad grade and install marker plate. The well will remain in suspended status until final removal of the casings and welding of marker plate 3' below original Tundra level. Procedural Steps Fullbore- Circ hydrocarbons out of tubing and IA 1. Circulate tubing and IA to 9.8 ppg brine. Circulation point will be the open pocket @ 3196'. 2. Fluid being circulated out will be diesel. 3. Have a vac truck on location ready to vac out any fuid that accumulates in the cellar. 4. The measured volume down to 3196' for tubing and IA is 224 bbls. 5. Pump 250 bbls of 9.8 ppg NaCI down the tubing taking returns from the IA. As Reference -Tubing and Annuli volumes: a. Tubing - 80 bbls down to TOC @ 9210' b. IA- 609 bbls down to est. TOC @ 9935' c. OA- 125 bbls down to est. TOC @ 2150' Slickline 6. D&T w/ 2" dummy gun. 7. D&T with 2.25" drift • Eline 8. Jet-cut tubing @ 1700' to establish circulation path down control line. 9. Hold 3500 psi on control line that does not have injectivity prior to jet-cutting. 10. Shoot 5' of perforations from 1600'-1605' Special Projects 11. Cement control and balance lines with 1.6 gallons each of Squeezecrete down to jet cut @ 1700' or treatment pressure of 5000 psi. a. Confirm injectivity prior to pumping cement. b. Control line is 1060ft/gallon. c. Follow Small Volume Cement Squeeze RP. Fullbore — Circ out hydrocarbons from IA and OA 12. Circulate tubing, IA, and OA to 9.8 ppg brine. Circulation point will be the perforation holes @ 1600'. 13. Fluid being circulated out will be diesel and crude. 14. Have a vac truck on location ready to vac out any fuid that accumulates in the cellar. 15. The measured volume down to 1600' for the tubing is 14 bbls, the IA is 99 bbls, and the OA is 93 bbls. 16. Pump 250 bbls of 9.8 ppg NaCl down the tubing taking returns as follows: a. Take 130 bbls of returns from the IA. b. Take 120 bbls of returns from the OA. j pia() ; eewearyi-- p I v7 Fullbore — Place Cement Plug #1 17. Pump 100 bbls of hot surfactant wash (160F FW + 2 gpt of F103 and 2 gpt of U067) a. Take the first 65 bbls of returns from the IA 18. Swap to taking returns from the OA and pump 15 bbl FW spacer 19. Swap to 15.8 ppb Class G Cement and continue taking returns from the OA 20. Pump roughly 120 bbls of cement and take returns from the OA until clean cement returns are seen at surface. a. Shut in OA. 21. Pump an additional 110 bbls of cement taking returns from the IA. a. Shut in tubing and IA. Cement Calculations — Surface Cement Plug Total cement to pump 230 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 Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 1 Safety 2 2 • • Minimum required thickening time: I 5 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:00 0 100 0 0:30 150 100 1315 1:00 230 100 1315 2:00 230 90 1315 3:00 230 80 1315 4:00 230 70 1315 5:00 230 60 1315 Special Projects 22. Notify AO_GCC Inspector of wellhead removal. (24-hour minimum notice) 23. Photo document all steps. 24. Cut off all casings and wellhead —1' below pad level. 25. Top off tubing and annuli with cement if needed. 26. Install marker cap on outermost casing string. The marker plate should have the following information bead welded onto it: a. BP Exploration Alaska b. Permit to Drill number- 1871010 c. Well Name—05-18 d. API Number—50-029-21757-00 Note: Final excavation, casing removal to 3' below tundra, and marker plate welding to occur at pad remediation. 3 • • Pre-Job Schematic 11-t.LL= 3MCEVOY WEI Li-ILA D= MOEN 0 Y SAFETY NOTES"TIBGx LAX OA COMM,TBG LEAK. AL 1 UA 1 0 R.= OTIS K-1 3 71 50'.TBG PARTIALLY COLLAPSED A,/29',CELLAR KB I-I P„,° . 541 HAS PRODUCED IN THE PAST. '"CAUTTON'"' 131 l-,I-V = 26 9" 1 RAPID FLUID OUTSIDE CONDUCTOR WI-EN OA PIT KLP= fl.i ix. Ai1gk2= 52 .i",9253 Da tum MD= 1 1 338' I 2000 HJ-1.,z O115 S S SV LAND NIP 10=2 75 Llituni TD= V 98-122 SS 0 GAS LIFT MA NI:12EL S ST MD rvo DEN 1 PE V LV LATCH PORT DATE I 1..i-JI9'CSG.72#,L-80,ID=12347" I—I 2 4 3196 2934 48 OTIS 805 I*1 i 4 Y 3 7170 5598 50 OTIS RA RA 2 10071 7458 47 OTC RA 1 10702 7881 43 OTC RA r Minimum ID = 2.313 @ 10936' 2-7/8" OTIS X NIPPLE . I 7150' H HOLE PI RP JOR41.4 BOW EDL14*3 I I 9210' H TEN3 TOC i 121161991 I ## # ••141 ,40•••• I 9935' HA TOC 0216009)I 't•101.1/ ..0CO' •4 V,0••••• S•• tip!, I 10a29* H 3-1"T OTIS XA SiDIPG SLV,ID=2.73L1 ITLA3ft PUNCH 0211669) H 10633%10853 .401/141.6 ill.. W h 4÷ /s-5 1-1:2 CO 1 9G.9 3*,L-8,/3 .ocia7 Ng,ID=2 992" 10873* .4.411•14**0 — I-)•••••••••6 po • I*.IF.. O.. i 4111•Ok 6. 10877" 113t3 SEAL A SSY 10892' H i_sy x 5-1.2"TW ng:t I 6•41.141•1 *10* 444444 I 10902* I-15-1 7 X 3-117 X0 I 1•1•1 111.0 •141 ,,.. I 10904' H3-1.2"x 2-7/0")a)I WV t4W 04 .1 ) lorne 2-71Ir OTIS X Me ID=2313" I t, i'lilr1 -... I 10969' 1-12-7,5 OTIS X PAP.ID=2.31,3*i I TOP OF r LNR H 10964' I 10969' TTP SET(12109.397) 2-7,8'TA LPPL,6.54.L-911 11003' I / i 905791wit.13=2 4,11' 1 ; ii:003: HH2-7/B.TBG TAL D=-2 441' I I-5.9'CMG VO,1-80,D=3.581' H 11196' I 1. PcP1-Of...4 1 K* S LtIMAI-i I 115e9 I—I444%AKER JOINT I REF LOG Bt-CS ON 10,1,6187 ANGLE AT TOP EtRF 43 @,1 1907' I Note Recta to ProkikEtion E tot Iii tot port:1t3 SIZE SFF INTERVAL OpritSq./ t...--L 2-118' 4 11907-11932 - 0 12230.,11" 2-118' 4 11942-12E124 ' 0 130i87 2-118 4 12047-12055 • o lama 7 I PBTD 1210T 1 011.1•0 44 411•••• • 1001* 4 1,41.1A.A.A. I 7'LIR.2154t.L-ao. 038.3 kg.o=6278' H 12150' DATE FEN'BY COPAN fl S DATE REV BY COMMENTS PRUDHOE BAY(fNT 12/87 ORIGIM41.COMPLETION 12/18109 JKC/SV RSA(121161)9) WELL K-13 03103101 56-MD F IpAL 1023110 JRA/SV DEPTH CORR PERIM No 9871010 08/14/01 RIWKAK CORRECTIONS API No 50-029-21757-00 02/17/03 RLItlh CORRECTION t TIP SET 19971 °J,EL 4, Ti 1N.P149.180. FNL&1142 FW L 08118/03 CPADMP MAX ANGLE COCRECRON 05129/26 CO/DTM TREE CORRECTION(6113/04) BP Exploration'Alaska) 4 • Loepp, Victoria T (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Tuesday, May 22, 2018 3:44 PM To: Loepp,Victoria T(DOA) Cc: Worthington,Aras J; Rixse, Melvin G (DOA);Schwartz, Guy L(DOA); Daniel, Ryan; Bronga,Jaime Subject: RE: PBU K-13(PTD 187-101, Sundry 318-171) P&A/Suspend Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, E'Yl.r.d t 4"cs" �� �� p I propose amending the original sundry by placing a lower cement plug in tubing and IA from "7,000' MD to 4,500' MD (175 bbls of Class G Cement—22 bbls in the tbg and 153 bbls in the IA).This will be followed by an MIT-T to 2,500 psi and a SL tag to confirm TOC. -Michael j �� � tea p7— ft 1 0 .--__ SAFETY NOTA:TEG 1IA x OACOt�A.TOGIEAIi ft, h _-' K-1 3 1150',TBG PARTW.Y CcLLAPSEDIT 29',CELLAR ai z- 5t 3U3/$"Casirg " HAS PRODUCECIN/REPAST •"CAUTION"' : Cemented to Surface RAPID R.UtDOUTSIDECO OUCDR 1MENOA P T e on •e_,Av.. s20:; , st Lateral Surface Plug in _-�1 i 2000' �'j • .. T,IA and OA-1500' 0_ or "' ko Ty0 cf. .::. T DATE OA Cemented from /'r or Surface Casing Shoe to MC -December'97 / r w 7150' -{ , ,: 1 ;- ,,, t. Tub irg and IA Cement s -700:T'ta45C0'MD *PAM' •.•��� 92to' - 1++jFjF+� - —__1 9-5/$"Casing Cemented to eaSa: 10828 -j • j 5,895'-414 bbl cement job 11.0. a 0t •i:•t•++.,• r 10877' IMM%O.- -{ 0.04`•x+ i + + 10902' {' - • - ....?O i •" 10904' '' x' eftAR ati 10936' -1 'x` C-2 i , 1 Wt Z -- 10969' -f .-,>,Nr r.�. } i 10966 T, ' 10969'-{ ! - I �_ a___ ,( 11007. ,...---- - ` // 11003' { �:.g0«2 At,) — 11000' 1-1' "` --t :. .., ,,; t 1 1 198' :_.. Al c.-RATKtti3N. ... 0 j 11569' j-j ..„.tq.04t I REF LOG ewCS{X4t3'.„. H ,'1 1210T rr�m�♦i oir j 12150' ----- '....�R x .u, , C+<i.'ALC OMPLET10% t - -, 1. .: _._ ;w.tTtu..x::-'010 x i1Nm :+0• h?2175740 '.•,t C'144 1.0 w161t42 FY+a. 1 UP Info(ahon to task at From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Tuesday, May 22, 2018 2:40 PM To: Hibbert, Michael <Michael.Hibbert@BP.com> Cc:Worthington, Aras J <Aras.Worthington@bp.com>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov>; Schwartz, i.uy L(DOA)<guy.schwartz@alaska.gov>; Daniel, Ryan <Ryan.Daniel@bp.com> Subject: PBU K-13(PTD 187-101, Sundry 318-171) P&A/Suspend This abandonment does not meet State regulations without a rig. While your proposal may meet BPs internal P&A criteria, it requires waiver(s)from State regulations for approval.We have reviewed this well with you and internally and require additional cement in the tubing and the IA above the existing lateral plug to consider approving. We may require lateral cement across the shoe. Please provide the top of the UG4 depth. 2 • • Victoria From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent:Tuesday, May 22, 2018 1:12 PM To: Loepp,Victoria T(DOA) <victoria.loepp@alaska.go' > Cc: Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>;Worthington, Aras J <Aras.Worthington@bp.com> Subject: RE: K-13 P&A Sundry Note Hi Victoria, Here is the TIO plot showing that we have had zero pressure on the tbg or any annulus over the last 4 years.We also have an OA integrity test from March of this year that the OA, IA and tbg held 1200 psi with only 36 psi lost over 15 m n. PC leaks almost always have high liquid leak rates at relatively low pressures as well as sustained surface pressures.T e only indication of IxO communication is @ the wellhead when pressure is applied. Placing an additional cement plug i the tbg and IA will not change our ability to pressure test prior to executing the surface plug because the only leak se ms to be at surface when pressure is applied. Can we have phone conversation to discuss so we can all get on the same page? Let me know when works for you. Thanks, Michael Updated Schematic showing all known cement in grey and proposed cement in red. 3 • • • . ,. K1 3 SAFETY NOTES:TEG x IA x OACOMK TKBGLEAg - 7150',TE3G PAR TULLY CCXLAPSEDg 29'.CS-LAR — --_ 13-3/8"Casing HAS PRODLICEC1N THE PAST, "*CAUT1Or‘'' Cemented to Surface 1 _ RAPID FLUID OUTSIDECONDUCDR WHENOA PiT- - 1193t Lateral Surface Plug in - 4 .. --...........e 2000' -I:--'....7'OTIS 8.5"S T, IA and OA-1600' '' / '.." C- _1 I- 28 AO 0- ,.. - 2 10071 7458 47 0' OA Cemented from i I1 TO702 7581 4a y' - R L. Surface Casing Shoe to . - 2150'-December 97 , III 7150' Ni N7AE,.....i.-_ 9-5/8"Casing . - 9210 H Cemented to 5,898'- T:' Kei9.1 414 bbl cement job we".r S .40***1,.. 9935' H A-.:,- . ' i ' 0 •.•"....•.,!,.! 1082811::.-'12' .,,T...; ''• II:.lige;4• N.4VVAsiv % L-8:.) 0.397PC4 .O=2 .::' H 10873* k41 ree4.4%.114i le 10877' -1-EkS STA..A ssv 10892' 1-1..-'_••.:', • '..-'1:'11WP*RI 444.4 044444 4.4%. 1 44** 10902'j-V- ...' .... *.,..' r Di 14441 $44* 441./ • 10904'j-f3-it2' x 2-7a...,-1 ro ••4 .. #44 .44 10936' -1_ '4i ... 4-- 10964' 10969' 11; - ' ;'.NF C': , r 10969' H :... 7.1211.)1' 7) I 0.1,7941 ID,L2 441. _jl 11003' r. [Moor 1-17- ---.E.,,':,'4,L 10=2441 - y, '2 11000' 1-1,_,,,_,-: L.,....,E.,-•I tet93 1 1777 '..1 47* ''... '.1 .,-.c.".-' 1 1-1-1198' 1 i 0 11569' Fft,-,,,,A.- REFLO3 8 HCS OHIO,' ANGLE AT TOP P9 43 ff '!.-.....-• '-',...,.••-•7--1 - -•-:: .-.-'-,SID'ZZ. '0,- " S.::.- - - '1 7•-•4''... Cr SZ . - . ' I PS"::= I-1 1210T r 4.0.444.4.• Ve41.41V41.11.44- I ..•;-. ..*-.... ...-to. .2:: :-* -,-`.-4..'...: H 12150' z ,_,..,-__ .._,.._, ,„,j,“.1.2 4-". _,4-t_ Rt.i.i i::, , •:,_....:•..i.L...."., .."4- 1217 ORIG4NAL.COMMAM*1 . . .,....# ..ofif.:C+: WELL *13 j.r.J.140. . ..1... i '1%-•_. ,. . ''., _RAJ:... -..;%.Prti COW', PERMIT No.1871010 08n4,3• ' •., :•,- 1.• ,: ...- t.v. A PilIo 534321321757-00 , SEC-4 T1'''i R14r.. *52.,..? oi.-4 1".12 , ..-..!- - ... .."-'71A'LR'i ;RE_ ', !I.-.3.4 IBP Exploration(A!Atka) TIO from 2014 until today 4 1 • • 1 UM rigs CBM star raa 4110 ormimm- 0161N ifts,14 SM:7V"H 'nom 0A.1, own* 6"•" tt 'llb""'> "F;fi'i Rows 'Siomi oou AMJM4 49 34 OG,* Wie41, WW1 ;4„:t'i! XIZif +oVit 14.4' :a'°Nr* A From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Tuesday, May 22, 2018 11:18 AM To: Hibbert, Michael<iVlichael.Hibbert@BP.com> Cc:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.Rov> Subject: RE: K-13 P&A Sundry Note Michael, We request the additional lower lateral plug with a substantial column of cement in the tubing and IA, at least 2500', if not more.That should be followed by an MITT. Before pumping the surface plug we would like to see pressure readings on T, IA, OA. At what depth is the IA/OA leak? 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(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 o you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeppuialaska.gov From: Hibbert, Michael [mailto:Michael.Hibbert@BP.corn] Sent: Monday, May 21, 2018 3:58 PM To: Loepp, Victoria T(DOA)<victoria.loepp@alaska.gov>;Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<meivin.rixse@alaska.gov> Cc: Worthington,Aras J <Aras.Worthington@bp.com> Subject: K-13 P&A Sundry Note Hi all, 5 After researching K-13 again to Ionto your request for an additional lowerrent plug across a potential PC leak, it was found that the lAxOA communication is near surface and no PC leak exists.The well does communicate from tubing to IA,to OA and weeps slightly at surface when pressure is applied , but no PC leak has been identified in this well. We recommend proceeding with the P&A as originally proposed. Sorry for the confusion on this point. Let us know if you'd like to sit down again to discuss this or if you are fine proceeding with the current sundry proposal. Thanks, Michael Hibbert BP Alaska—Intervention& Integrity Engineer (}4:ait!€LitaO'1 Email: Michael.Hibbert@bp.com 6 W \v/ c'\ - ) Post P&A Scem ic SAFETY NOM,TeG'OA x OACOM0A,TBGLE .. 1 K , 7150 , TSG PARTIAL"(COLtAPSED(4 29',ca.LAR 13-3/8"Casing , HAS PROD UCECIN THE PAST. •••CAUI 110*:*• BF EL& Cemented to Surface = (.• ' 1,, ' , I RAPID R.UIDOUTSIDECONDUCDR INHENOA PIT 1 ' KOP kt 20t., ---„„ I to •? 520925.t• ' - inat• Lateral Surface Plug in '... .. `-- I 2000' H3.1/7'OTIS SSSV LANO NF tO=2 75' ri ,...?'.- 74D'''' 881)a SL-• T.,IA and OA-1600' r/iise r $ GAS LiFT MAN DR:ES • . 1 4 3193 2934 4a OTIS RA I 13-205'"CSG 728,L80 0=12 S4- Hmr) Tv° DEv TYPE VI-V:A TCH "T 2A-- ---; — 2 10071 7438 V OTIS RA ...."- OA Cemented from — --- , rsei 63 oris PA/' Surface Casing Shoe to /ftPili ' ,illill: 2150'-December'9'7 / r--ii---5"07.-}{ .7,- PL 1,4 7A&J-V5G-ki ir3 9-5/8'Casing ' ' 9210 I: OC L12/18.091 A:6k,°\ I 1 Cerrented to 5,398'- .11111W, A..71111111rT0CO2/16,6S)I: 414 lath cernent;DO \ 0. . 7407.9 li; 444644 '4111.4404 OW 41 4'ity,•44•oi.• 111.`10 82 4 .-•t•-'2"":,\I'''S YA _ .S -5 I 4111.II it lk ii 6 Ai Or 1 .1•1*.t. .. 4414414410 I 444.0 4444414044414. 44 TBG,9 34 L-80. 0087 bpf 10=2 992' H 101173' Ai.1•Gi. 114 .4-I/Attt4 4 40, 4 VIOOW 07 * 1 •+.0 ir 10077 TEK3 SEAL A SSY .4 4. 4.4 14 -...- •••••• --,e, —40.....ig. loser 9-ste.x 5-112"TIWPKR .. ... 14*.444 410440 . ‘,444.44. 10902. 115-la X 3-112'XO I It*** sst, 10904' 1-17x2-7.e-xcl ti1 .444 41.# ... •114, *4 10936' I-12-74 ,..-, ^,f ( =. Ai ,v.girl ITCPCF 7" A OR 1 i... 7 w 9 .444 - .0110111 10%9' 1-412--,8 OTiS x NP tt,t 2 313 I I 1 Al ...,..,....p , 10969w H ,-. 1-02,03677, 1 2-71"TALPIPE a SW L40 1100 Ag 00575 I* ID=2 44tr. 1 Aiii1111111111 / 4 11003; 1 1,., Js*TEG TA L C=2 4411 I. 11 000' j 1 MO TT OGGED11,08.O3 1 I '..98"CSt3 47* L-bt) Z.,' =b 681"I 11198' PE:4FORA7 re/SAMAR., I 11569' I ISEElliZed: scoliaow 0 O V' --cal pe41 data -4z OArE 2 •12/30.18. I - 12/3057 6 Je-t 1-1 12107' 14.4441011 14441.444 14444444 I . D'96 2-6' H 12160' L.,....s......... PIRUOKI BAY Ufar 14 V 127 (V ',AL. ',11 L L t "J Atli K-13 0361 76"" PERMIT PloP1871010 08/14431 4 i 4..A.1{ .,-,_ ARM° 50-029-21757-00 0 ." 3RUlt 1 . I 7,iN R14F 1803.FNL 5 1142 ANL 08,i16133 L t,t - - •• - , - ' P t•E mpi+-fltinn YA lax k aP 5 • • N cc Thousand Cubic Feet of Gas ("MCF") per Month X a; N .-iO1 0 0 or Gas-Oil Ratio 0 R.o 0 0 o ccoo v 0 0 0 0 0 0 o O 0 0 0 o m - ei ani rl ei . i-1 ti ��� I( I ( Ocoe 2 F I '' `PP o 0 H - IIIlIIIIt111uII II 0o III J a �... IIIIIllhIIlIIIIIIIIII ■111111lliililllll•llllill _ sot, ~ •IIIII11111 I11II111111 1111 2 Z 111111111111111111111111111 0 IJIIIIIIIIJIIIIUIIHIIIII Il Q J iilii11111 111111l•111111l y 1111111/ s<,,r wi ■IIIIIIIIUIIII1111111IIIII1111IIIII11l I IIIN 0 0 •IIIIIIIIiiiiuui11111liliill 111111iill III g E E &‘: .._'.- IHIIIIIIIHIIIIIIIIIIIIHIIIUI0 i soot mi L IIIIlu11111. lI1ll 111 I I i 1111111111111111111111111111111111111 ' I • 11111111111111 11 I II. a } C 111111111111111111111 I.mL iV W :c. Z = C � IIIIIIIIF III 111111 11111 r ��04, � p Y c J 11 11 ri °. if o ° !!!""1211111101111111111111 aSII; � VIII ; IIIN °rviiiiiiUIIIIl1IIUa 4 Q , IVLIIIIII II ° es F3, IVA! � l IIIIfI�IISr • Z ,. MP,, MINIM 1G4iG IO 00 O - 111• P . do _. N 1111111111_ae o a a all ° II ' _ . _ r--- ° o o I ° 4« r 1� I(iI l 111111 s6roPQ 1 aa4 a I �%a 0. MO g 9 ° oVI � $a . ® v W II MUM a u 111111111111111111 ■111111 a 1 ii co s8s 8 8 0 0 o O O 8 .-i r 4Pr O O O o 4O O O .4 O O rl o .i c-1 ynuow Jad Ja;eM}o slaueg ao glum' Jad no to sla.ueg STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COION REPORT OF SUNDRY WELL OPENS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for RedriII 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Failed Conductor Top Job 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 187-101 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21757-00-00 7. Property Designation(Lease Number): ADL 028303&028304 8. Well Name and Number: PBU K-13 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12150 feet Plugs measured 9210,10969 feet true vertical 9008 feet Junk measured None feet Effective Depth: measured 9210 feet Packer measured 10892 feet true vertical 6942 feet Packer true vertical 8078 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"Conductor 31-111 31-111 Surface 2775 13-3/8" 31-2806 31-2712 4930/6390 2670/2820 Intermediate 11171 9-5/8" 29-11200 29-8309 6870 4760 Production Liner 1194 7" 10956-12150 8126-9008 7240/8160 5410/7020 Perforation Depth: Measured depth: 11907-12055 feet SCANNED . True vertical depth: 8832-8939 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#x 2-7/8"6.5#L-80 27-11003 27-8161 Packers and SSSV(type,measured and 5-1/2"TIW Packer 10894 8080 true vertical depth) 12.Stimulation or cement squeeze summary: RECEIVED Intervals treated(measured): 1 7 (�18p Treatment descriptions including volumes used and final pressure: APR / 20 13. Representative Daily Average Production or Injection D °G "'C Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-449 Authorized Name: Lastufka,Joseph N Contact Name: Worthington,Aras J Authorized Title: IM Speci ist Contact Email: Aras.Worthingtonabp.com Authorized Signature: 4-1 .7/)Date: 4/i1 jltb Contact Phone: +1 907 564 4102 Form 10-404 Revised 04/2017 ` 7 `` �D q 2018 Submit Original Only - /A`Ir c RBDM , ( L O • Daily Report of Well Operations K-13 ACTIVITYDATE SUMMARY T/I/0= SSV/0/0. Temp= SI. WHPs (Pre P&A). No AL or flowline. Installed heater in wellhouse, door left cracked open. TC x SSV void = 0 psi. 12/24/2017 SV, WV, SSV= C. MV= 0 IA, OA= OTG. 1110 hrs. T/I/0 = 160/0/0. Temp= SI. Assist SP w/Conductor steaming and cement. Steam on conductor for 3 hrs and found hard bottom @ 4" below flutes chipped at for several hours smashed samples to look like cement and sand mixture. Continued steaming and could not make anymore depth shut down and sort out non-hazardous confined space to continue with cleaning out flutes and conductor. Contacted AA and HSE working towards continuing 12/26/2017 in AM with new permit. ...suspend operation tell AM of next day... T/I/0 = 160/0/0. Temp= SI. Assist SP w/Conductor cleaning and cement. VAC fluid from cellar, remove floor grating, chip and remove cement from flutes to around 9" in eace flute. Pour-2 gallons of squeeze create into flutes covering the centralizer. Sample left in well house. Heater in well house and tree cap bled to 0 psi from MV up and door left open. SV, WV, MV= C. SSV= ?. IA, OA= OTG. 16;00 12/27/2017 TWO = 0/vac/0. Temp = SI. WHPs(eval conductor top job). Cement sample in well house not set up. There is oil seeping trough the flute in the 2 o,clock position (about the size of a silver dollar). Heater in well house, treecap bled to 0 psi from MV up. 12/28/2017 SV, WV, MV= C. SSV= ?. IA, OA= OTG. 16:00 T/I/0 = 0/vac/0. Temp= SI. WHPs(post cement). Cement sample in well house not set up. There is oil seeping trough the flute in the 2 o,clock position (-1/8 cup). Heater in well house, treecap bled to 0 psi from MV up. SV, WV, MV= C. SSV= ?. IA, OA= OTG. 12:00 12/29/2017 TWO = 0/0/0. Temp= SI. WHPs(post cement). Cement sample in well house is not set up. There is oil seeping through the flute at the 2 o'clock position (-1/8 cup). Heater in well house, treecap bled to 0 psi from SSV up. 12/30/2017 SV, WV, SSV, MV= C. IA, OA= OTG. 11:00 T/I/0 = SSV/0/0. Temp = SI. WHPs (Post cement). Cement sample in WH has not set up. There is a small pool of dark fluid in the conductor at the 2 o'clock position. No bubbling or LEL's. Heater in WH working properly. Tree cap pressure= 0 psi. 12/31/2017 SV, WV, SSV, MV= C. IA, OA= OTG. 09:30 T/I/0= SSV/0/0. Temp= SI. WHPs(post cement). Flowline&AL disconnected. Heater working properly. A small pool of dark fluid in the conductor at the 2 o'clock position. No bubbling or LEL's. Tree cap pressure= 0 psi. 1/2/2018 SV, WV, SSV, MV= C. IA, OA= OTG. 04:30 T/I/0 = SSV/0/0. Temp = SI. WHPs (post cement). Flowline&AL disconnected. Heater working properly. No fluid on top of cement. Wet area from the 1 o'cock to 5 o'clock positions on SH. Cement sample in well house is hard. No bubbling or LELs. Tree cap pressure= 0 psi. 1/2/2018 SV, WV, SSV, MV= C. IA, OA= OTG. 12:20 T/I/0= SSV/0/0. Temp= SI. WHPs(post cement). Flowline&AL disconnected. Heater working properly. No fluid on top of cement. Cement sample in well house is hard. No bubbling or LELs. Tree cap pressure= 0 psi. 1/3/2018 SV, WV, SSV, MV= C. IA, OA= OTG. 23:30 • Daily Report of Well Operations K-13 T/I/O =Vac/0/0. Temp= SI. WHPs (eval SC repair). No AL or flowline. Heater is installed and working properly. IA&OA FL's @ surface. Cement in conductor is discolored from the 11 to 3 o'clock position and is cracked at the 9 o'clock position. No fluid is visible in the conductor at this time. Cement sample is fully cured. 1/9/2018 SV, WV, SSV(partially) = C. MV= O. IA, OA= OTG. 14:30. T/I/O = SSV/8/7. Temp= SI. WHPs (eval SC repair). FL&AL disconnected. Heater installed working and installed in WH, Bled tree cap to 0 Psi. Cement sample and top of cement in conductor is hard. 1/12/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:00 T/I/O = SSV/5/5. Temp= SI. WHPs (eval SC repair). FL&AL disconnected. Heater installed working and installed in WH, Bled tree cap to 0 Psi. Cement sample and top of cement in conductor is hard. SV, WV, SSV= C. MV= O. IA, OA= OTG. 01:50 1/14/2018 TWO= 0/0/0. Temp SI. OA Integrity test to 1200 psi. OA FL= @ Surface. Used 3.25 BBLS of DSL to pressure OAP from 0 psi to 1198 psi. IAP &TP tracked the OAP while increasing to target pressure. At 100 psi an observable leak started coming from the lower starting head threads @ the 1-4 o'clock position, and at 500 psi a leak started in the conductor coming through the cement @ the 2 o'clock position. Monitored for 15 min after test pressure was reached, OAP lost 36 psi during monitor. Sucked —0.50 gallons of fluid total from the conductor. Bled WHPs through the OA to 0 psi in 15 min (3 BBLS). Hung tags. Final WHPs = 0/0/0. 3/30/2018 SV, WV= C. SSV, MV= O. IA, OA= OTG. 17:00 T/I/O = 30/30/30. Temp= SI. C & B line injectivity test `No Injectivity on Control line, Injectivity on Balance line*(Pre P&A). Pumped 1/4 gallon hydraulic fluid down control line (lower port)to pressure line to 3950 psi. Monitored for 15 min, control line lost 290 psi. Bled control line to 0 psi. Pumped 3 gallon hydraulic fluid down balance line @ 3000 psi. Balance line decreased to 0 psi when pumping stopped. 4/5/2018 SV, WV= C. SSV, MV= O. IA, OA= OTG. 16:30 J Fluids Summary Bbls Type —2 Gal Squeeze Crete TREE= . 3"MCEVOY yELLNOTES:TBG x IA x OA COMM, ACTUATAR= MCEVOY • K-1 3 X50',TBG PARTIALLYCOLLLAPSED@29',CELLAR ACTUATOR= OTIS 'KB.ELEV= 54.3' HAS PRODUCED IN THE PAST. ***CAUTION*** 'BF.ELEV= 26.9'' RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PIT KOP= 2000' Max Angle= DatUm MD= 52 @111938' 2000' —13-1/2"OTIS SSSV LAND NIP, ID=2.75"I Datum ND= 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT' DATE 13-3/8"CSG,72#,L-80, ID=12.347" -4 2806' 4 3196 2934 48 OTIS RA 3 7170 5598 50 OTIS RA 2 10071 7458 47 OTIS RA 1 10702 7881 43 OTIS RA Minimum ID =2.313 @ 10936' 2-7/8" OTIS X NIPPLE 7150' —IHOLEINPUP JOINT ABOVE GLM#3 1 111111 9210' I—I TBG TOC(12/16/09) 111111 111111 9935' I-1IA TOC(12/16/09) 'V.'11111111 Al h.1.1.W4141 1111' 1 11�'1�.11� 10828' —13-1/2"OTIS XA SLIDING SLV,ID=2.7 ITUBING PUNCH(12/16/09) 10833'-10853' 14 ••••••111 1't 11111111 14141�1111111111i X111 3-1/2"TBG,9.3#,L-80,.0087 bpf, ID=2.992" 10873' •-111111.1 11•1111111111111 ��;111111111111 �; 10877' —I TBG SEAL ASSY I ���11111111111►� 10892' I-19-5/8"X 5-1/2"TW PKR 111111 111111 d11111*, 10902' —15-1/2"X 3-1/2"XO 1111 f 1111; 410 10904' —13-1/2"X 2-7/8"XO 111114 '414 10936' -I2-7/8"OTIS X NIP,ID=2.313" •Wi 10969' —12-7/8"OTIS X NIP, ID=2.313" TOP OF 7"LNR — 10964' 10969' —I TTP SET(12/03/97) 2-7/8"TAILPIPE,6.5#,L-80, — 11003' I 11003' —12-7/8"TBG TAIL, ID=2.441" .00579 bpf,ID=2.441" 11000' —I ELMD TT LOGGED 11/06/93 I 9-5/8"CSG,47#,L-80,ID=8.681" — 11198' PERFORATION SUMMARY 11569' H MARKER JOINT REF LOG: BHCS ON 10/16/87 ANGLE AT TOP PERF: 43 @ 11907' I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 2-1/8" 4 11907-11932 0 12/30/87 2-1/8" 4 11942-12024 0 12/30/87 2-1/8" 4 12047-12055 0 12/30/87 I PBTD — 12107' I11111111 11111111111111111 7"LNR,26#,L-80,.0383 bpf,ID=6.276" -4 12150' 1...............1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ► 12/87 ORIGINAL COMPLETION 12/18/09 JKGSV P&A(12/16/09) WELL: K-13 03/03/01 SIS-MD FINAL 02/23/10 JRA/SV DEPTH CORR PERMIT No:51871010 08/14/01 RN/KAK CORRECTIONS API No: 50-029-21757-00 02/17/03 RL/tlh CORRECTION(TTP SET 1997) SEC 4,T11 N,R14E, 1803'FNL&1142'FWL 08/16/03 CMO/TLP MAX ANGLE CORRECTION 05/29/26 CO/DTM TREE CORRECTION(6/13/04) BP Exploration(Alaska) • OF Tit • IA THE STATE Alaska Oil and Gas tis�� OfLASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALA9XP' Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions & Integrity Engineer swop N Q V ( (viol? BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-13 Permit to Drill Number: 187-101 Sundry Number: 317-449 Dear Mr. Worthington: 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 L day of September, 2017. RDDMS -L- tj. f - 4 toll STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well H • Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Top Job H • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 187-101 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H 3. 8. API Number 50-029-21757-00-00 • 99519-6612 Stratigraphic 0 Service 0 7, If perforating. 8. Well Name and N ee What Regulation or Conservation Order governs well spacing in this pool? �� WII planned perforations require a spacing exception? Yes 0 No H PBU K-13 • • q ED 9. Property Designation(Lease Number): 10. Field/Pools: SEP 2 0 2017 ADL 0028304 ' PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY AOGGC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12150 • 9008 9210 6942 9210/10969 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 33-113 32-112 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 11171 9-5/8"47#L-80 30-11201 30-8310 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 10894, 8079.30 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development H Service 0 14.Estimated Date for Commencing Operations: 10/15/17 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended H i 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington,Aras J be deviated from without prior written approval. Contact Email: Aras.Worthington©bp.com Authorized Name: Worthington,Aras J Contact Phone: +1 907 564 4102 Authorized Title: Intervener• &Integrity Engineer J �1 Authorized Signature: �/ ' Date: /�i, �n 2 // COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number 3(-7-4/4( Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other `� Post Initial Injection MIT Req'd? Yes 0 No PJ1 Spacing Exception Required? Yes 0 No Q/ Subsequent Form Required: / t7 4b `rL APPROVED B Approved by: 4110.11COMMISSIONER COMMISSIONYTHE Date: 1 12-(1 %.1- r71.- .1-YTL 9/ZB/j9- C q C . 1 INIA 1 ,,, ,L c--c 0\-1 , „ . -,....„ , , , ,-5.-"' co- ' RE,,,,,,s ;,,,,,, ,,i,,,:s-t- _ f,,,, ,2:r-c,:i.77 , ' Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) September 20, 2017 To Whom it May Concern: Attached please find the Sundry Application for Conductor Top Job for Well K-13, PTD # 187-101. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 995196612 Attachment: Form 10-403 • • • K-13 Conductor Top Job Well Integrity Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Laurie Derrick (907) 564-5952 Estimated Start Date: October 15th 2017 History K-13 was reservoir abandoned on 12/16/09 because it did not have enough value to justify repair for TxIxOxSC communication. Cement was left at 9210' in the tubing and 9935' in the IA. Pressure testing after reservoir abandonment on 12/30/09 showed that the well still has TxIxO & the SH leaked at that time. During the test there were no fluid returns from the conductor but the SH leaked slightly. The tubing is partially collapsed from 28'slm to —2500'slm. Various drifts have made it through - generally the collapse appears to be ^•2.3" ID. The fluids in the well are a mixture of crude, 60/40 meth and 9.8ppg brine. Since the reservoir abandonment, operations has noted crude in the conductor flutes/cellar several times. Current Status The well is recommended for P&A, but we would like to perform a conductor top job in an attempt • to stop the conductor leaking crude while we wait for progression of the final P&A. Objective Perform a conductor top job to eliminate any leaking of fluid from the surface casing leak and into • the conductor/cellar. Procedural steps DHD/Special projects 1. Steam clean the Conductor x Surface Casing Annulus to top of good cement. 2. Circulate Cement or LockCem into the conductor from the top of existing cement to surface until clean cement returns are observed. • S III TREE= 3"MCEVOY WELLhEAD= MCEVOY SAFETY NOTES:MG x IA x OA COMM,TBG LEP1(4yi , . . ACTUATOR= OTIS K-13 7150%TBG PARTIALLY COLU‘PSED @ 29',CELLAR KB.ELEV= 54.3' HAS PRODUCED IN THE PAST. '"'CAUTIO/r" 'BF.Lb'= z6.9- RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PIT KOP= 2000" Max Angie= 52 @ 92531... . Datum MD= 11938' I 2000' H3-112-OTIS SS /LAM)HP.la-2.75' I Datum TV D=- woe ss • GAS LIFT MANDRELS I 13-3tEr CSG,7I,L-80,ID=12.34r I—I 2806' II ST MI) TV D DEV TY PE V LV LATCH FORT DATE 4 3/96 2934 48 OTIS RP, 3 7170 5598 56 OTIS 2 16071 7458 47 OTIS 1 10702 7881 43 OTIS RA RA RA IA nimum ID=2.313 ,../ 10936' 2-7/8" OTIS X NIPPLE -11 192170' JHHH°LETBG IOCIN PU:12131:16:17E GLM*3 I .0.00.1 Tiv.0.40:40.....00, 9935. H ke,/cfc 02q6,03? I 41 1...041 4,..,...•••44, 10828' 1-13-1- 7 OTIS XA SLIDING SLV,ID=2.75' I I TUBING PUNCH crzifidte) H 10633'401153' 4414 44.4/1$41 111.0.•••,,.. /411.101/0 11 MO.+ I II,4......3-1/2"TBG,9.34,L-80,.//,:,7 414,C t=2.992' H lora 4.14.01.0.0 v-t1...0. /400.111/. . 0.4 .1.44. .. war HTBG SEAL ASSY I 4'04 e misi'MNIC loggr H9-5/8"X 5-1/2"riv PKR I 0040441 ..../. 4.00 s111.0 I 1000Z —15-ter X 3-1,2"XO I 10011 440*, 10904' H3-112"X 2-7/' X0 I 0444114 4.0 411 I 10936' H2-7/8"OTIS X NP ID=2.313' I 44. •4 4 o 6411 —I I 10969' 2-7.V OTISH .ilz',I: 2_313"• 3=TOP OF 7"LNR H 10964' ...- II 2-718" TA!EWE_6.54,L-80. 11003' . 10969' rip SET(1.2.103,1') 11003' H2-7B'TBG TAL ID=2.441'1 .00579 bp4.ID=2.441' I 11000" Hawn.LoGGED1,06,s3 1 1 9-SW CSG,474,L-86.E)=8.681* H 11198' 1-41 61L PERFORATION SUMMARY I 1 1569* HIVIARKER Jaw I REF LOG: B-CS ON 1011647 ANGLE A T TOP PERF: 43 I", 1190?' Note.Refer to Roducttart DB for hostote.4 pen data SIZE SPF INTERVAL OpoiSqz DA TE 2-1/6" 4 11907- 11932 0 12/30/87 2-118" 4 11942- t2024 0 12130/87 2-1,1" 4 12047- 12055 0 1213687 I PBTD 12107' 6.1.0.01 1....10014 MAMAMA 0.1.1..14 I r LNR,2€0,L-81a,.0383 opt.ID=6.276 H 121W GATE Re/BY 00A4AENTS GATE REV BY COMMENTS PRUDHOE BAY UNIT 12/87 ORIGINIU_COI&NATION P1216109 JKCISV P&A(12/16109) WELL: K-13 03/03/01 S6--MCI FINAL 02123+10 JRAISV DEPTH CORR PERMIT No:r1871010 08 14.01 RNIKAK CORRECTIONS API No: 60-029-21757-00 02/17/63 R....* CORRECTION(TTP SET 1997) SEC 4, T11N,RI 4E.. 1803"FNL&1142 FWL 08116/03 CMDITLP MAX ANGLE CORRECTION 05129/26 CCYDTM TREE CCRRECTON(6113/04) Be Exploration(Alaska) . • 4111/0 Oo00o00 O N M O CO N 00 g? LO O C N N [F ul V r O O O O O O O M O) f� (p Z3 O co 0o N41 �— m O O e- 00 O O M 00000000 N el T Ns O I- CD CO e- M O) O O T- N 00 OD O) 00 00 0 I 1 1 1 1 I 1 1 F- 0 CO O) O 01r- 01ONI- e- O M M OD M v- O) N T- 00 OD 00 4.0 G� CO O) O N 0 (`7 MOO D 0 O) O T- 00 O N T- T- 00 O v N N N O V 0 03 Abo aT_ Te cMMOMoMONNO • M " c 0? o0 co 0o 0o C) U J J CO OD J J = d 73 N N 4# J J *k01 Ul *k .N N CO ,r 4t 4 O CO U 0`o -00aoNr o0 O M C? 0 N- r N- N CO AO M N .0 r J T- T- W Q CD= O W W 0 U W O 0 u_ U_ Of Of Of Z Z Z W W W 13-3 O D D Z Z D D 000U0ZJJF— H • • CD a1 l6 CO O CO co• CD N cri ai co a) p O CO 00 co 00 a0 co a co 0 r N N 00 a rM ❑ d M M -- M p coco — CO 0 2 w ❑ w z CI m w H Ha O a H 5 5 0-1 U o m N co .W_i U U w w w +L' CO MNL() J J J ¢ ¢ cn W aaorn < < < W OO a a D L R r Q Q Q = ❑ ❑ 0 - 0 0O '— N N O O O W AIa. W WI- QQI UUU Z ° Z WW a ❑ 2 2 2 O cr) (1) (1) N (1) 03 Q i 0. H • = t M I� N M p CO O O W d CO (3) (3) C CD O 2 ar cn - = - 0 ci) a2Om (r) mm (r) a) a 0 U a cnwcncn o a a a a dmmmm 0. O t m a ❑ w J D W 0 • 0 0 0 0 ❑ > O C N N N N W J J Z O � � � � Z 'l a a < W W ++ a) C) C) C) OJ N N a 0 a O D U0 W W W O `- m ❑ ce tx J J C7 O w w m m LL LL U U a m E m z M M M CO m a as 0 J U' 0 w a Y Y Y Y ¢ Q m m U LL cA co a C RLCEWWED STATE OF ALASKA - A... .3KA OIL AND GAS CONSERVATION COME, JION JUN 1 8 2ui.: REPORT OF SUNDRY WELL OPERATIONS OC;( 1 Operations Abandon U Plug Perforations L_l Fracture Stimulate LI Pull Tubing Li Operations shutdown ❑ Performed Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool El Repair Well ❑ Re-enter Susp Well ❑ Other Susp Well 5 Yr Inspect Rpt 0 2 Operator 4.Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 187-101 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21757-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028304 PBU K-13 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12150 feet Plugs measured See Attachment feet true vertical 9008 2 feet Junk measured None feet Effective Depth measured 9210 feet Packer measured 10891 97 feet true vertical 6941 59 feet true vertical 8078.15 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 29 97-109 97 29 97-109 97 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 11171 48 9-5/8"47#L-80 27 4-11198 88 27 4-8307 89 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10833-10853 feet 11907-11932 feet 11942-12024 feet 12047-12055 feet True Vertical depth 8034 16-8049 04 feet 8831 74-8849 93 feet 8857 2-8916 8 feet 8933 49-8939 29 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 5-1/2"TIW Packer 10891 97 8078 15 Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) SCANNED NNED i t Z IV 1 Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1627 10207 83 0 228 Subsequent to operation Suspended Well Shut-In 0 0 14 Attachments 15 Well Class after work Copies of Photo's and Plat 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 5 Year Susp Well Inspection Report 0 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ Daily Report of Well Operations 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP 0 SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catront BP.Com Printed Name Garry Catron Title PDC PE Signatured9JIMA„ C Phone 564-4424 Date 6/18/2015 VTi- 71q/1,5RBDM6 JUN 1 5 2015 Form 10-404 Revised 10/2012 Submit Original Only K-13 187-101 Plugs Attachement SW Name Date MD Description K-13 12/16/2009 9210 Cement Plug K-13 12/3/1997 10969 2-7/8" XX Plug a) a 0 0 0 0 0 co CO r N I� r — I� V O C) CO 0 t� N N U N 0 0 0 0 0 0 ca co O CO 3 co N O) co `- m CO 00 V O O O O) ON N O) CO O CO CO CT) CT) r CO Oj N O O CO O N M r CO 0) CO N- O r CJO CO CA r N CO CO H CO CA N in f� r CO CT N CA • O N V 6 N od N N o-i co 6 N N r O) N CO N CO CO r CO O) N ON C`') G) O O) COLO M 0 0) O b0 09 coO N N O r _ 0 CU r i I i I i i i i CO N N Q O U) M O) Cr) Cf) O CO N a) N N CO N a) vo r r r r r C C co � r L p O 0 O CO O 0 CO CA co co U J CO 00 J (n J C a) O J N M CSC • N C h *k Cl) (I)) O V CO 0) _ _ O (� O N N o0 a0 NCO c.--6 CO U O COti CO N h CO cO N- CO CC�0 r O r 00 CD a0 r y r r CT O J r r W CD I � Q O W W Q Q U (9 Upu_ u_ ZZ z W Z Z W m m C.) 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Suspended Well Site Inspection Form 5 year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: !PRUDHOE BAY UNIT K-13 Field/Pool: PRUDHOE BAY/ PRUDHOE OIL Permit#(PTD): 187-101 API Number: 50029217570000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 1/6/2010 Surface Location: Section: 4 Twsp: 11N Range: 14E Nearest active pad or road: K PAD Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, gravel Pad or location surface: Gravel pad, snow, snow melt Location cleanup needed: none Pits condition: snow packed Surrounding area condition: clean -snow melt Water/fluids on pad: snow melt Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition: good Photographs taken (#and description): yes, wellhouse, surrounding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: McEvoy 3"tree and McEvoy wellhead. IA and OA open to gauge. Swab valve stem grease fitting (alemite)weeping grease. Cellar description, condition, fluids: metal lined, ice and free melt water from snow and pad Rat Hole: None Wellhouse or protective barriers: Yes, intact Well identification sign: Yes, correct Tubing Pressure (or casing if no tubing): SSV closed Annulus pressures: IA= 0 psi OA= 0 psi Wellhead Photos taken (#and description): Yes, wellhead and tree Work Required: Vac out cellar as part of summer dewatering project. Will help prevent any current or future sheen and identify location. Will repair intermittenly weeping grease fitting. Operator Rep (name and signature): Whitney Pettus AOGCC Inspector: Johnnie Hill Other Observers: Ryan Hayes Inspection Date: 5/15/2015 AOGCC Notice Date: 5/14/2015 Time of arrival: 3:05 PM Time of Departure: 4:00 PM Site access method: Truck - , -. . , t • , . - 1 ... I 7 4 \„,,,, . 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' ' s � .x ii a�M ;*‘ ,:: , '' a 31k S-. 5 IF '1 .fir '� A<r: yy..,�t.. ��t s. inuiliiL loll I I 46 El agM^ a , J= 9 i $o o 1 ti i r `rr fit kAi. ' ' I '� 1 c A, ' V' i A ::: ir ,y r Ntilt 1 _m /4 ii ••.,,. /: • 6' a,..,,. . , ... , . .....„, ..:. (4.! 4 . 0 i. .,. 1 I . ., ... • .ilk 1 hii , , 1 P ' ' ' ( • ,,-. , ... , vi. • I t..,4,, ,-- , . i .. : 4 ,..e „ , . j . 1 * . . 1 ..- ... .. , .4 i l 1 .,..---,-,-..?:i„•,,,..,;-:- , ,,,, ..., r...,,,..„i 117: .,, .., t WELL NAME K-13 ,'.4 • m-o8-II-14, %4 OWEROPt 51,,Et.t.J.94 - Rp„1,X11,100 5j2„Let.00.t 1,M1t 1,,,WI(TM,,,k a ' I . . t , ----- . . , ' 1 ..'"' 4. .... . , , . ,.. . , . , , . .. . ' ( .. , Z , .!). ,,, ' .,:'-'''',C7...,,,,,,,I,;•:::',,:',,',„::,,,':,.'',, ''''' . -.s'441:7:,1;:, .,. ,, "•-• 1,'''. •,T,:. '.',+'.,:—.. .*,','1,'.''''t i'.'":—..:- t'''' - ...'. .• •.• . ' —, ,'''''' . ., .. •.. . . ...or:. . .. . , ' .. ', - • - ' - . .,... ,• . ." ' ' '. .• ,• • • "4. t • • •,•• .' • . 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I. 1 I .. . ...„ ... . . , „ , .. .,.. v . . .. ,....., V ,. 1 —... .... . • , -' . I .- . „ TREE=r 3"MCEVOY ACTUATOR WELLHEAD= MCEVOY K-1 3 SAI- 1Y NOTES:TBG x IA x OA COMM,TBG 5 O 0',TBG PARTIALLY COLLAPSED @ 29', EL ACTUATTORR= OTIS CELLAR KB.ELEV= 54.3' HAS PRODUCED IN THE PAST. ***CAUTION*** BF.ELEV= 26.9' RAPID FLUID OUTSIDE CONDUCTOR WHEN OA P/T KOP= 2000' Max Angle= 52 @ 9253' Datum MD= 11938' 2000' —3-1/2"OTIS SSSV LAND NIP, ID=2.75" Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3196 2934 48 OTIS RA 13-3/8"CSG,72#,L-80.ID=12.347" — 2806' 3 7170 5598 50 OTIS RA 2 10071 7458 47 OTIS RA 1-1 1 10702 7881 43 OTIS RA Minimum ID = 2.313 @ 10936' 2-7/8" OTIS X NIPPLE 7150' — HOLE IN PUP JOINT ABOVE GLM#3 111111 9210' —ITBG TOC( 12/16/09) 111111111111 9935' —I IA TOC(12/16/09) '11'11/111Cf 111;1.1.1.1.11,1�1 11. . ._ _ 10828' —13-1/2"OTIS XA SLIDING SLV. ID=2.75" TUBING PUNCH(12/16/09) 10833'-10853' 111111•�AA11a1111 E 4 1♦1♦1♦1♦1♦11111 4, 00000 14,41111111 3-1/2"TBG,9.3#,L-80, .0087 bpf; ID=2.992" — 10873' v1a1.1111/11111,111 -1..._4114,':'1 1_94 1,.. 1. 1 111111 1. 11 111111 ,♦ 10877' —TBG SEAL ASSY A 111111 . -.T1 j1111/1111j►� 10892' —I9-5/8"X 5-1/2"TIW PKR 111111 11111/1111. 11111 0 10902' —15-1/2"X 3-1/2"XO 11111111 10904' —3-1/2"X 2-7/8"XO 1111 10. �11� 10936' —12-7/8"OTIS X NIP, ID=2.313" I 1441 10969' —12-7/8"OTIS X NIP, ID=2.313" TOP OF 7"LNR —1 10964' 10969' —TTP SET(12/03/97) 2-7/8"TAILPIPE,6.5#,L-80, —1 11003' 00579 bpf. ID=2.441" 11003' —2-7/8"TBG TAIL,ID=2.441" 11000' —ELMD TT LOGGED 11/06/93 9-5/8"CSG,47#, L-80, ID=8.681" — 11198' I--A L PERFORATION SUMMARY 11569' —MARKER JOINT REF LOG: BHCS ON 10/16/87 ANGLE AT TOP PERF: 43 @ 11907' - I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11907- 11932 0 12/30/87 I 2-1/8" 4 11942- 12024 0 12/30/87 2-1/8" 4 12047- 12055 0 12/30/87 I PBTD — 12107' 1 11111111 1111111111111111. 7"LNR,26#,L-80. .0383 bpf,ID=6.276" —I 12150' 1.4.1./..A.A. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT r 12/87 ORIGINAL COMPLETION P12/18/09 JKC/SV P&A(12/16/09) WELL: K-13 03/03/01 SIS-MD FINAL 02/23/10 JRA/SV DEPTH CORR PERMIT No: 1871010 08/14/01 RN/KAK CORRECTIONS API No: 50-029-21757-00 02/17/03 RL/tlh CORRECTION(TTP SET 1997) SEC 4,T11 N. R14E. 1803'FNL&1142'FWL 08/16/03.CMO/TLP MAX ANGLE CORRECTION 05/29/26 CO/DTM TREE CORRECTION(6/13/04) BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 05/16/15 Inspector: Johnnie Hill Operator: BP Alaska Well Name: PBU K-13 Oper.Rep: Ryan Holt PTD No.: 1871010 Oper.Phone: 907-659-5766 Location Verified? Yes Oper.Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 01/06/10 Date AOGCC Notified: 05/12/15 Sundry No.: 309-397 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? No IA 0 OA 0 Condition of Wellhead: well head was good,had a little oil on it Condition of Surrounding Surface Location: good gravel around out side of well hose,inside had well house floor,there was some soil sheen in the cellar box Follow Up Actions Needed: find where oil was coming from on the tree and also Vac out cellar to make sure oil is not coming up subsurface;we could not tell Comments: SCANNED JUL 1 5 2015 Attachments: None REVIEWED BY: Insp.Supry 5g(2-- Comm Comm PLB 06/2014 2015-0516_Suspend_PBU_K-13jh.xlsx Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well HistoryFile Identifier Organization (done) RESCAN Color items: [] Grayscale items: Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: K Other items scannable by large scanner OVERSIZED (Non-Scannable) D Logs of various kinds Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ SCANNED BY; ~ BREN VINCENT SHERYL MARIA LOWELL RESCANNEDBY: BEVERLY BREN VlNCE~'~ SHERYL~,.~ARIA General Notes or Comments about this file: PAGES: LOWELL DATE: /S/ . J Quality Checked (done) RevlNOTScanned,wtxl • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU K -13 Oper. Rep: Jack Winslow PTD No.: 1871010 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 01/06/10 - Date AOGCC Notified: Sundry No.: 309 -397 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed Photos Taken? Yes IA 0+ by Operator OA 0+ Condition of Wellhead: Well house in place, full tree with closed SSV, flow line intact. - Condition of Surrounding Surface OK Location: Follow Up Actions none Needed: I) Attachments: None REVIEWED BY: Insp. Supry 107 /t( Comm PLB 08/2010 2010- 0911_Suspend_PBU K- 13_cs.xls STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMI ION R~c~~v~® JAN ~ ~ zeta WELL COMPLETION OR RECOMPLETION REPORT $.Clarritnisaio 1 a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned ®Suspended 2oAACZS.~os 2oAAC2s.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero 1 b. Well Clasp e~~~~~~ ry ®Develo m n lorato ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., us , or Aband.: 1/6/2010 .Permit to Drill Number: 187-101 309-397 ` 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 10/01/1987 13. API Number. 50-029-21757-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 10/17/1987 14. Well Name and Number: PBU K-13 ' 1803 FEL, SEC. 04, T11 N, R14E, UM FNL, 4137 Top of Productive Horizon: 1095' FNL, 3826' FEL, SEC. 08, T11 N, R14E, UM g. KB (ft above MSL): 54.3 GL (ft above MSL): 23.9' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1451' FNL, 4233' FEL, SEC. 08, T11N, R14E, UM 9. Plug Back Depth (MD+TVD): 9201' 6936' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 671407 y_ 5975416 Zone- ASP4 10. Total Depth (MD+TVD): 12150' 9008' 16. Property Designation: ADL 028303 8~ 028304 TPI: x- 666556 y- 5970734 Zone- ASP4 Total Depth: x- 666159 Y- 5970370 Zone- ASP4 11. SSSV Depth (MD+TVD): None 17. Land Use Permit: 18. Directional Survey: ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1951' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL /BRCS / CNL-Poro /Laser-Log / CCL / GR / CBT / VDL 22. Re-Drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FL GRADE TOP BOTTOM .TOP BOTTOM SIZE CEMENTING RECORD PULLED,.. 20" Surface 110' Surfa 110' 1 72# L-80 / S-95 2 1 7-1/ " Ar i II 9-5/8" 47# L-80 Surf ce 11200' Surf 8309' 12-1/4" 2325 cu lass'G' 7" 2 L- 0 1 4' 1215 ' 8132' 9008' 8-1/2" cu ft Class' ' 24. Open to production or injection? ^ Yes ®No 25. TueING RECORD If Yes, list each interval open (MD+TVD of To & Bottom Perforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD / TVD p ; 3-1/2", 9.3#, L-80 11003' 10892' / 8078' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC: _ ~ ~a ~~'(~, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED t~ a ,~~'~%` ~~~~` t yu 10833' - 10853' PerfTubing for Pumping Cement Plug ' .~ 9201' Secure well with 71.7 Bbls Class 'G' Cement , 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqu ired? ^ Yes ® No Sidewall Core(s) Acquired? ^ Yes ®No 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 250.071. None RBDMS JAN 2 2 ~p Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ~ Submit Original Only ZZ•!o ~4 i~f>o 29. GEOLOGIC MARKERS (List all formations and m encountered): 30. RMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 11202' 8310' None Shublik A 11259' 8353' Sadlerochit /Zone 4 11356' 8425' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Operations, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. O ~ / /~~ f~ Signed: Terrie Hubble - Title: Drilling Technologist Date: ( ~ V PBU K-13 187-101 309-397 Prepared By nlameAUumber. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Josh Allely, 564-5732 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation 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 13: 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 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 1212009 Submit Original Only • K-13, Well History (Ops to Suspend) Date Summary 12/12/2009 WELL SHUT IN ON ARRIVAL. DRIFT TO 10902' SLM W/ 2" DUMMY GUN, 2" LIB (IMPRESSION OF WHAT LOOKS LIKE FILL). ATTEMPED TO RUN 2.25" PUMP BAILER UNABLE TO GET PAST 6' SLM. RAN 10' x 1.75" PUMP BAILER TO 10904' SLM (RECOVERED FEW SMALL HARD PIECES OF CEMENT AND 1/2 GAL SOUPY CEMENT). CURRENTLY STANDING BY FOR COIL. 12/13/2009 MU and RIH with PDS logging tools for coil flag. Log from tag at 10943' to 10500' ctmd. Flag pipe at 10820' ctmd. POOH. Confirm data. TD corrected to 10935' corr. Log tied into 3 1/2" tubing talley dated 18 Oct 1987. 12/16/2009 T/I/0= 450/450/450. Temp= SI. Monitor cellar for TxIxOxSCxSurface communication (Assist CT w/ cement P&A). Bubbling/ fluid visible C~ 5:00 position on SH. C~ 500 psi, active fluid/ bubbling C~3 5:00, 7:00, 9:00 positions. Bubbling slows down C~3 100 psi, stops C~ 0 PSI. Job incomplete. SLB has control of valves. 12/16/2009 MIRU. MU and RIH w/ 20' 2" guns, 6 spf, 2006PF charges, 60 deg phasing. Correct depth to top shot and pull in to position at 10833' corr. Displace tubing with 9.8 ppg brine, then pump 200 bbls 9.8 brine into IA through open pocket in station #4. Drop ball and fire guns. Perforate 3 1/2" tubing from 10833' to 10853' corr. All shots verified at surface. Perforations correlated to 3 1/2" tubing talley dated 18 Oct 1987. MU and RIH with 1.75" BJN cementing BHA. Layed in 71.7 bbls 15.8 class "G" cement from 10935' corr with 1 to 1 returns. Estimated top of cement at 9853' corr. PUH to safety at 9100' drop ball ceanout down to 9850' never saw any signs of cement returns during cleanout. POOH chasing to surface freeze protect coil. 12/17/2009 Freeze protect IA & tubing to 3196' w/diesel. RDMO. Job Complete. 12/19/2009 WELL S/I ON ARRIVAL. DRIFT W/ 2.25" CENT, 1.50" S-BAILER TO TOP OF CEMENT C~ 9201' SLM (S-BAILER FULL OF CEMENT). DRIFT W/ 2.00" CENT, 1.50" S-BAILER TO TOP OF CEMENT C~ 9201' SLM (S-BAILER 1/2 FULL OF CEMENT). T/I/0= 50/0/0 WELL S/I ON DEPARTURE, DSO NOTIFIED. 12/30/09 T/I/0=100/vac/0 CMIT TxIA to 1000 psi/ FAILED. Circ Well w/DSL to FP TxIA (Secure Well). Pumped 5.35 bbls 60/40 meth down TBG to bring TxIAxOA to 400 psi. OA tracked w/T & IA. DHD noticed the lower Starting Head started leaking. Call PE. Bled TBG pressure. PE & Pad-Op notified upon departure. FWP=O/0/0 Tags hung. SV, WV & PV = S/I. SSV, MV, IA & OA =Open . 12/30/09 T/I/0=100/vac/0. Temp=Sl. Assist Fullbore with CMIT TxIA FAILED (secure well). TBG FL C~? 282' (2.4 bbls). IA FL near surface. Pressured tubing to 200 psi W/ 5.4 bbls of 60/40 methanol, TxIAxOA comm confirmed, no fluid returns from the conductor. Monitor for 30 mins, pressures were unchanged. Pressured TBG to 400 psi, IA & OA tracked with tubing pressure. Lower starting head started to leak diesel C~3 3 & 7 O'Clock positions with 400 psi on the OA, no fluid returns from the conductor. Monitor W HP's for 30 mins. T/I/O pressures unchanged C~ 400 psi. Bled off pressures due to lower starting head leak. Monitor for 30 mins, T/I/O unchanged. Left Katch Kan installed in cellar. Final W HP's=0/0/0. SV,WV =Closed. SSV, MV =Open. IA, OA = OTG. 12/31/09 T/I/O = Vac/Vac/Vac. Temp = SI. WHP's (secure). No AL. WHP's went on Vac overnight. No fresh leaks on SH. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/03/10 T/I/O=VacNacNac. Temp=Sl. WHPs (secure). No change in pressures, no leaks on lower starting head. SV, W V =Closed. SSV, MV =Open. IA, OA = OTG. 01/05/10 T/I/O = ONACNAC. Temp = SI. WHPs (post secure). SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 01/06/10 T/I/0= 0/0/0. Temp= SI. Remove Katch Kan. Rigged down KK out of cellar and returned it to junior J Pad. SV, WV =closed. SSV, MV =open. IA,OA =open to gauge. NOVP. Page 1 of 1 TREE=_ 3" MCEVOY WJ=ILHEAD = MCEVOY ACTUATOR = OTIS KB. F1EV = 54.3' BF. ELEV.- _. 26.9' KOP = 2000' Max Angle = 52 @ 9253' Datum MD = 11938' Datum TVD = 8800' SS SAFETY ~S: TBG x IA x OA COMM, TBG LEAK @ K-13 7150', TBG PARTIALLY COLLAPSED @ 29', CELLAR HAS PRODUCED IN THE PAST. ***CAUTION*** RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PR 2000' 3-1/2" OTIS SSSV LAND NIP, ID = 2.75" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" i~ 2806' Minimum ID = 2.313 @ 10936' 2-7/8" OTIS X NIPPLE (p~'h 71 tbls p~w,pc~ n ~ d a-s. S ~ cr ~ o~ 4 t o 1- (~ 5 . y 1b~s~ bacws:dG ctrwtx wr .S `1`135' M~ 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 10873' q5 ~ ' nbo~t Path c ~'" TOP OF 7" LNR 2-7/8" TAILPIPE, 6.5#, L-80, .00579 bpf, ID = 2.441" 9-5/8" CSG, 47#, L-80, ID = 8.681" I 11003' I PERFORATION SUMMARY REF LOG: BHCS ON 10/16/87 ANGLE AT TOP PERF: 43 @ 11907' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11907 - 11932 O 12/30/87 2-1/8" 4 11942 - 12024 O 12/30/87 2-1/8" 4 12047 - 12055 O 12/30/87 I PBTD I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" i-i 12150' ;r '':;~ :. ,1,3~ ~2. 2 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/87 ORIGINAL COMPLETION 03/03/01 SIS-MD FINAL 08/14/01 RWKAK CORRECTIONS 02/17/03 RL/tlh CORRECTION (TTP SET 1997) 08/16/03 CMO/TLP MAX ANGLE CORRECT~N 05/29/26 CO/DTM TREE CORRECTION (6/13/04) PRUDHOE BAY UNff WELL: K-13 PERMR No: 1871010 API No: 50-029-21757-00 SEC 4, T11 N, R14E, 1803' FNL & 1142' FWL BP 6cploration (Alaska) ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3196 2934 48 OTIS RA 3 7170 5598 50 OTIS RA 2 10071 7458 47 OTIS RA 1 10702 7881 43 OTIS RA 7150' HOLE IN PUP JOINT'"~'A--~~BOV E GLM #3 g 20 1 _ ~ ~~ Gc»v-~-+ ~v~Q 10828' 3-1/2" OTIS XA SLIDING SLV, ID = 2.75" P`~ 10877' TBG SEAL ASSYI 10892' 9-5/8" X 5-1/2" TNV PKR 10902' 5-1/2" X 3-1/2" XO 10904' 3-1/2" X 2-7/8" XO 10~ 936' I~ 2-7/8" OTIS X NIP, ID = 2.313 " 10969' 2-7/8" OTIS X NIP, ID = 2.313" 10969' TTP SET (12/03/97) 11003' 2-7/8" TBG TAIL, ID = 2.441" 11000' ELMD TT LOGGED 11/06/93 11569' I~ MARKER JOINT Nob b Sat !a if SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dan Kara Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 1101 Anchorage, AK 99519-6612 �ql "' 2 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K - Sundry Number: 309-397 Dear Mr. Kara: 2005 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 0 1 Daniel T. Seamount Chair 7 4 DATED this / 7 day of December, 2009 Encl. 9-' STATE OF ALASKA • E E1V E a?v- l2 A LAS •IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL NOV 20Q9 20 AAC 25.280 Alaska 9-1 6 1118 r- QU COMM' 1. Type of Request: Anchorage ❑ Abandon ® Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Specify: ❑ Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 187 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 21757 - 00 - 00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU K -13 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028303 & 028304 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12150'_ 9008' - 1 12107' 8977' 10969' None Casina Lenath Size MD TVD Burst Colla Structural Conductor 110 1 Surface 2 13 -3/8" 2712' 4930 2670 Intermediate 112 9-5/8" 11 9' 6870 4760 Production Liner 11 7" 10964'- 121 0' 1 8132' 9008' 7240 541 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11907' - 12055' 8832'- 8939' 3 -1/2 ", 9.3# x 2 -7/8" L-80 11003' Packers and SSSV Type: 9-5/8" x 5 -1/2" TIW packer Packers and SSSV 10892'/ 8078' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory 2i Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: w Commencing Operations: December 15, 2009 ❑ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Abandoned C �' 16. Verbal Approval: Date: P „ ❑ WINJ ❑ GINJ ❑WAG _ ®Plweser} SPLUG Commission Representative: I 5zts ,xn Y.r - 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Allel 564 -5732 Printed Name Dan Kra Title Engineering Team Leader r Prepared By NameN Signature _ _ Phone 564 -5667 Date 11 Z Terrie Hubble, 564 -4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ? fj 2 ,_,/ Sundry Number: ✓ ® Ld Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Val C.0^j;4_: ft•. P/ c c� �r�ss �. r � �'e s�' I / + Other. r Subsequent Form Required: jQ , Z14 7 APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date rr Submit In Duplicate jL -Z -a� �l c9 To: Tom Maunder Petroleum Engineer O bp Alaska Oil & Gas Conservation Commission From: Josh Allely Wells Group Engineer BP Alaska Date: November 25, 2009 Re: PBU K -13 Sundry Approval Sundry approval to suspend well K -13 is requested. K -13 is a well that is exhibiting TxIAxOA communication with a surface casing leak. It is currently secured with a plug in the tubing tail. The plug is holding and the well remains dead [figure 1]. It is our desire to secure the well with a more permanent cement plug. Due to the nature of the annular communication, removing the plug and potentially allowing gas to surface has been deemed too risky. The current plan is to punch holes above the packer and leave 500' MD (364' TVD) of cement in both the 3 -1/2" tubing and the 3 -1 /2 "x 9 -5/8" annulus above the packer [figure 2]. The production packer is 306' MD (229' TVD) above the top of hydrocarbon bearing sands (TSAG) and 1015' MD (754' TVD) above the top perf. The 9 -5/8" intermediate casing was top set in the Sag River formation. The daily drilling report detailing the cement job on the 9 -5/8" casing indicates that cement was circulated to approximately 6064' MD, 5134' MD above the shoe, assuming gauged hole volume plus 30 %. No losses were noted. We are requesting approval of a sundry to proceed with this work as we feel the planned action is sufficient to isolate the Ivishak formation, complies with AOGCC zonal isolation requirements, and offers the least amount of exposure. Well Information Status: Non Operable producer, secured with 2 -7/8" XX plug at 10969' and Typical Production Rate: 848 bfpd, 13.0 mmscfpd, 0% WC at 1541 psi whp and 95F wht. Max Deviation: 52deg at 9253' and Perf Deviation: 43 deg at 11907' md. Min. ID: Unknown. Obstruction near surface. Gauged out to 2.31" Last TD tag: 10/13/97: tag TD with 2" dmy gun at 12,048 slmd. Last Downhole Ops: 09/27/09: Troubleshoot restriction at 30'. SIBHP / SIBHT No survey since 1997. Assuming 3200 psi. Latest 1-12S level: Unknown Ann Comm Status: TxIAxOA x Surface Casing; Not Operable The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed cement plug is attached for reference. Planned Work: (scheduled to begin December 15, 2009) 1. CTU Punch holes in 3 -1/2" tubing above packer at 10865' MD.' 2. CTU Lay in 36 bbls of cement into the 3 -1/2" tubing and 3 -1 /2 "x 9 -5/8" annulus leaving top of cement at 10392' MD. 3. Slickline Drift and tag 3 -1/2" tubing and verify TOC. Josh Allely Wells Group Engineer 564 -5732 (w) 350 -7362 (c) Dan Kara Wells Group Engineering Team Lead 564 -5667 (w) 240 -8047 (c) CC: Well File Sondra Stewman/Terrie Hubble I TREE = 3' MCEV OY WELLHEAD = MCEV OY K 13 SAFETY NOTES: TBGx IA x OA COMM, TBG LEAK @ ACTUATOR= OTIS 7150',TBG PARTIALLY COLLAPSED 29 ',CELLAR KB. ELEV = 54.3' HAS PRODUCED IN THE PAST. "'CAUTION"" BF. ELEV = 26.9' RAPID FLUID OUTSIDE CONDUCTOR W HEN OA P/T KCP 2000' Max Angle = 52 @ 925Y Datum MD = 1'1938' 2000' 3 1/ OTLS SsSV LAND NIP, D = 2.75' Datum TVD = 8800' SS GAS LIFT MANDRELS ST RIO TV DEV TYPE 4 3196 2934 48 OTIS RA VLV LATCH PORT DATE 13.3 8' CSG, 72 #. L -80, D = 12.347' 28(16' 3 7170 5596 50 OTIS RA 2 10071 7458 47 OTIS RA 1 10702 7881 43 OTIS RA Minimum ID = 2.313 @ 10936' 1 1 1 1 2.7/8" OTIS X NIPPLE 7150 HOLENFUPJONTABOVEGLM#3 10828' 3.1 OTS XA SEE SEE D =2.75' 3-1/7 TBG. 9.3#. L- 80..0087 bpf, D = 2.992'H 10873 10877' TBG SEAL ASSY 10892 H9.57ir x 5-ur - 5w PKR 10902' H ur xo 10904' 3-1 x 2 -n8' xo 10936' 2 -7/8' OTIS X NIP, D = 2.313' TOPOF T LNR 10964' 10969' 2 -718' OTS X NIP, D = 2.313' 10969 TiP sEr (, 2/03197) 2.718' TAILPIPE 6.5#, L -80, 11003' 11003' 2.7/8' TBG TAL, D = 2.441• .00575 W, D = 2.441' 1100K HELMD TTLOGC� 11/06753 9518' CSG, 47 #, L• 80. D = 8.661' 11198' PERFORATION SUMMARY 11569' MARKERJONT REF LOG: BHCS ON 10/16/87 ANGLEAT TOP PERF_ 43 @ 1190T Note: Refer to Production DB for historical pert data SIZ A L 'Sqz DA 2 -118' 4 11907-11932 O 12/30187 2 -118' 4 11942-12024 O 12130/87 2 -178' 4 12047 - 12055 O 12/30/87 PBTD H 1210T T LNR. 26#. L- 80..0383 bpf, D = 6276' 12150' L1ATE REV BY COMMENTS DATE REV BY COMMENTS PR DHOE BAY UNIT ,2187 ORIGINAL COMPLETION WELL K -13 03»03101 S&MD FINAL PERMIT No : 08/14/01 K API No: 50-029-21757-00 02117103 RLMh CORRECTION (TTP SET 1997) SEC 4, T11 N. R14E 1803' FNL & 1142' FWL 08/16103 C:MOf" MAX ANGLE CORRECTION 29/ r (6113/04) I BP Exploration (Alaska) Figure 1: Current schematic for K -13 I KH = T MCEVO - V JELLHEA D - _ SAC E SAFETY NOTES: TBG x IA x OA COMM, TBG LEAK Q ACTUATOR = OTB K-13 7150', TBG PARTIALLY COLLAPSED g 29', CELLAR 4 3 ELEV = 54 .3' HAS PRODUCED IN THE PAST. '**CAUTION"' 3= H.EV - = - - 25 ' 9 , RAPID FLUID OUTSIDE CONDUCTOR WHEN OA PIT KUr- 7000' Max Angle = 52 a 92!3S L 'atum MD = _ 11938 O 2000' ORS SSSV I AND NP, IO = 2.75' N Datum D = 893 SS GAS _rT MANDRELS ST MD TVO DEVI TYPE VLV LATCH FX)RI Di 13 -1 CSG, 7214, L -83, ID = 12.341- 2806' 4 3196 2934 46 OTIS RA 3 7170 5596 50 OTIS RA 2 10071 7458 47 OTIS RA 1 10702 7881 43 OTIS RA Minimum ID = 2,313 @ 10936' 2 -7/8" OTIS X NIPPLE ` 7150' dHOLENP P.'OlNTABUVLULI-.14J TOP 10828' ., _t 2 U I ti XA iLr-)ING SLV. b = 2.75" ivWn' Pun c6 f'el't 3 -1;Z" TBG, '134 . -4n, .0087 bp? ID = 2.992• - 0 10877 TBG SLAL ASSY 10892' 9 -518 X o-v2 T'A' ?(R 10902 5 -112" X 3 -'r2° XO 10904' 10936 969' 2 -718" OTISS X NIP p - 2.313' roP OF 7' LNF2 10964' 10 10969 TTPS= {12:03x97) 1 z - 7x 3~ IAIL 6.5z L - 8 0. 11003' - 11003' z - ?xa" TaG TnIL, p = 2.441" . 00579 bo1. 0 = 2.441' 11000' EL PA) TT LOGGED 1 11(W93 9 -518' CSG, 47#, L -a0• ID - 9.ee 1 J 4 11198' F*RFORA PION SUMMARY 11569 M1�AFtKER JUIN� REF LOG. 31-CS UN 1x116181 A OGLE AT TOP -ERF. 43 (a* 11907' Note: Ref qr to RaJurtlon DB lo historical pert data SIZE SPF NTERVAL 3�'Wsgz DATE 2-1;M" 4 1190! - 11932 0 12130187 2 -1x8" 4 11942 - 12024 U 12130/87 2 -118" 4 17047" 12055 0 1213,^.xa7 TD 12107' r�B 7" LNR, 76it, L .0383 bat, [) = b'.276" 12150' DATE REV BY COWENTS DATE H =V BY COT I TEN 15 PRuDHOC BAY UNIT 121 77 ORIGINAL COMPLETION VJH 1: K -13 33/03101 SIS4,10 =tNA'_ -FRMIT No: P 187 1 010 38;14x01 RIwKAK CORRECTIONS APlq). SW23621757 -30 32117x03 RLltlh CORRECTION (T'P SET 1997; S=EC 4, ri 1 N. R14F 1803' =NL 31142' FWL 38/16103 CMOiTLP MAXANGLECORRL-CTK)N 3 CG1JIM I iFE CORRECTION (6/13x041 SP Exploration (Alaska) Figure 2: Proposed cement plug. STATE OF ALASKA ALAS"~'"'OIL AND GAS CONSERVATION COMMISSI¢-" ' REPORT C, SUNDRY WELL OPE,,ATION:S..,.. 1. Operations performed: Operation shutdown __ Stimulate Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service __ 4. Location of well at surface 1804'SNL, 4137' WEL, Sec. 4, T11N, R14E At top of productive interval 1095' SNL, 3814' WEL, Sec. 8, T11N, R14E At effective depth 1430' SNL, 4198' WEL, Sec. 8, T11N, R14E At total depth 1450' SNL, 4220' WEL, Sec. 8, T11N, R14E Other X 6. Datum elevation (DF or KB)" ~-: ,.~ KBE = 54.$O 7. Unit or Property name Prudhoe Bay Unit 8. Well number K-13(11-8-11-14) 9. Permit number/approval number 87-101 / 10. APl number 50- 029-71757 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 12150' feet 9007' feet Plugs (measured) Effective depth: measured 12107' feet Junk (measured) true vertical 8976 feet Casing Length Size Cemented Structural Conductor 80' 20" Surface 2771' 13-3/8" 3900 cu ft Arctic Set II Intermediate 11171' 9-5/8" 2325 cu ft Class G Production Liner 1186' 7" 365 cuft Class G Perforation depth: measured Measured depth 110' 2806' 11200' 12150' True vertical depth 110' 2700' 8308' 9OO7' true vertical Tubing (size, grade, and measured depth) 3-1/2"9.3# @ 10877'MD Packers and SSSV (type and measured depth) T. L W. 10892' MD 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure FEB 2 3 1996 Alas~,a Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1326 16903 9 0 1451 20080 35 0 Tubing Pressure 1225 651 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil Gas__ Suspended 17. I h~r-e~y c,~rtify that~the forgoing is tr~le ap, d correct to the best of my knowledge. Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE WELL K-13(11-8-11-14) _. Tubing Patch 2/17/9 5 r.i.h with slip stop & 3 1/2 k.o.t, locate # 3 glm at 7170' md, set slip stop 7' above glm. r.i.h with both lower and top pack off sections, set top slip stop 7152' md. the robing patch is to isolate the collar leak on the 10' pup joint above the glm. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: DESCRIPTION pFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF CCL FINAL BL+RF CCL FINAL BL+RF ECC No. Run ~ 1 4475.07 Run # 1 4588.03 Run # 1 5602.04 Run ~ 1 6079.04 Run # 1 6451.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~.~ Or. to (907) 563-7803 Received by: ~ ~_..--' Date: Please sign andreturn~o~ PetrotechnicalData Cente~ BP Exr!oration (Alaska) Ins 900 East BensonBoulevard Anchorage, Alaska 99508 Received by LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION i/ 0~~ B-14 (43-32-11-14) D-18 ~, K-13 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF I PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF ECC NO. Run # 1 1291.08 Run # 1 5073.05 Run # 1 5661.09 Run # 1 6079.03 Please sign and return to: Attn. Rodney D. Paulson ~tla~ 201 Anchorage, AK 99518 Or to (907) 563-7803 Received ECEIVED 2 8 1995 Anchorage LARRY GRANT ~ Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 31 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: K-13 1 PLS FINAL BL+RF ECC No. 3771.06 4475.04 Run # 1 6079.02 Please sign and retu ~ REC£1v£~ // ;,;,J,~~, ~ ~ ) AU~ o~ D a t e: anchorage' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL R-01 DESCRIPTION 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF 1 PLS FINAL BL + RF 1 PDK/GR FINAL BL + RF 1 PLS FINAL BL + RF ECC No. Please sign and return to: ~_tn. Rodney D. ~ At~s Wire l~j~e--~erv ice s Run # 1 2447.01 Run # 1 3096.02 Run # 1 3096.03 Run # 1 6079.01 Run # 1 1291.05 BP EXPLORATION BP Exl31orat~on (Alaska) Inc. 900 East Benson Boulevarcl P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: ARCO DATE: 06/22/90 EXXON T#: 81310 PHILLIPS STATE OF ALASKA ARCHIVES SYSTEM _Tape & Transmittal Only BP MAGNETIC LIS TAPE & LISTING Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. CASED HOLE: K-09 K-13 W-11 CH/CNL 04/JUN-90 SCH#73900 1600BP! CH/TDT-P 05/30/90 SCH#73899 1600BPI CH/TDT-P 06/09/90 SCH#73905 1600BP! #1 9243-9924 TAPE POS.#07109 ~'~"'~ AP1#50-029-21736 #1 11191-12096 TAPE POS.#07110 __ AP1#50-029-21757 #2 12995-13563 TAPE POS.#07111 AP!#50-029-21981 OPEN HOLE: W-16 DIL/BHC/CNL 05/24/90 SCH#73892 1600BPI ARCHIVES ONLY: W-16 DIL/CNL/FLD 05/24/90 SCH#73892 1600BP! Information Control Well Records LR 2-1 J. Dietz/S. McCurry #1 #1 7662-11466 TAPE POS.#07112 7 TAPE POS.#07113 AP!#50-029-21961 r~~ RECE JUN 2 7 1990 Alaska 0il & Gas Cons. C0m~[ss[0~ Anchorage BP EXPLORATION BP Ex01oration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :06/06/90 T#:81244 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FtNAES Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. h-08 Perf. 05/31/90 #1 8995-9320 Sch 5" K-13 TDToP 05/2090 #1 11200-12082 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ¢"'~S...TATE ARCHIVES Standard Alaska Production 900 Easl Ben,on Bou! P.O. Box 196612 Anchorocje. Alaska (907) 564-5 ] I I HOUSTON ARCO CHEVRON EXXON TEXACO TO: MO B IL PHILLIPS · GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS I NOEXED STANDARD ALASKA PRODUCTION Date: 01-17-89 T~: 79736 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and retu~nlng it to this office: A-09 PROD-F #1 01-12-89 9350-9915 Sch 5" A-09 PITS #i 01-13-89 9200-9800 Sch 5" E-05 COMP #1 01-08-89 9765-10045 Sch 5" E-05 GR/CCL #1 01-09~89 8356-10079 Sch 5" K-13 PROD-F #1 01-10-89 11800-12109 Sch 5" U-13 Tubing Caliper #1 01-14-89. 9950-11446 Sch 5" X-10 PERF #1 01-08-89 10500-10800 Sch 5" ~' Alaska Oil & uas Con:. Commission Rece i ved Date A umt al the o,,g;no& Standa,d O~1 Company Founded ;n Cleveland. C~o. ,, 1870. Shirley R. McCurry INFORMATION CONTROL Well Records LR2-1 INDEXED DALLAS ,woo STANDARD CHEVRON ALASKA PRODUCTION E,~ON Date: 03/09/88 TEXACO TO: TI: 78641 MOBIL PHILLIPS STATE OF ALASKA REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this offlce: ~ D-26 Static Gradient 02/19/88 Camc° ~ G-24 " " 02/20/88 Camco ,, ,, R-23 " " 03/05/88 Camco ~ X-16 " " 03/03/88 Camco ria Aldridge Date f j ........ ,,a ~sd~,U6~q$.~'~.~.: .... -- ell ecords LR2- '~" " "* -"'-'"' STATE OF ALASKA ALASKA LJlL AND GAS CONSERVATION COMMISSION WEll C( MP! ETLON OR RECOMPLETION REPORT AND LOG', 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 8 7-101 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21757 4. LOcation of well at surface 9. Unit or Lease Name 1804' SNL, 4137' WEL, Sec. 4, T11N, R14E Prudhoe Bay Unit At Top Producing Interval 10. Well Number K-13 (11-08-11-14) 1095' SNL, 3814' WEL, Sec. 8, T11N, R14E 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 1450' SNL, 4220' WEL, Sec. 8, T11N, R14E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 54.30' I ADL 28304 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10-1-87 10-17-87 12-30-87I N/A feet USE I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12,150'MD 9007'TVD 12,107'MD 8976'TVD YES [] NO []I 2000feet MD I 1951' 22. Type Electric or Other Logs Run DILl BHCS / CNL-poro / Laser-log / CCL/ GR / CBT/VDL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'n'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 13-3/8" 72# L-80 Surface 1838' 17-1/2" 13-3/8" 72# S-95 1838' 2806' 17-1/2# 3900 cu ft Arctic Set II 9-5/8" 47# L-80 NSCC Surface 5334' 12-1/4" 9-5/8" 47# L-80 Butt 5334' 11,200' 12-1/4" 2325 cu ft Class G 7" 26# L-80 1J4S 10,964' 12,150' 8-1/2" 356 cufl Class G 24. Perlorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET {MD) Perforations 2-1/8" Hyperdome @ 4 spf. 3-1/2" 9.3~ 10,877' T.I.W. 10892 MD BKB TVDss 11,907' - 11,932' 8777' - 8796' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11,942' - 12,024' 8803' - 8863' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12,047'- 12,055' 8879'- 8885' 13-3/8" X 9-5/8" Down squeeze 13-3/8" x 9-5/8" Annulus with 300 sx Arctic Set I fo/lowed by 125 bbls dry crude 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 12-30-87 IF/owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithoiogy, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MAFIKEFI~ '[- "' 30. ' 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 11,202' 8309' Shublik A 11,259' 8352' Zone 4 11,356' 8424' (Top Ivishak/ Sadlerochit) 31. LIST OF ATTACHMENTS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge Signed '%--~~/~ T i t l e pBU Drilling Fngin ooring SuDorvisor D at e '-'~//1/~"~'/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells· Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 INITIAL PERFORATING DATA - Well K-13 12/20/87 Pressure tested tubing and inner annulus. 12/30/87 Installed and tested lubricator to 3500 psi. Rigged up Schlumberger and perforated the following intervals for initial production using 2 1/8" Hyperdome guns at 4 spf: 11907' - 11932' MD BKB ( 11942' - 12024' MD BKB ( 12047' - 12055' MD BKB ( TVDss) TVDss) TVDss) Ref. BHCS/GR, 10/16/87. Put well on production. 02/02/88 Set and tested initial SSSV in ball valve nipple at 2000'. 02/17/88 Shut in well to prepare for static pressure survey. 02/19/88 Ran initial static pressure temperature survey at 8800' TVDss. jm(02/22/88) 0755Z Teleco Oilfield Sm Js of Alaska Inc. 61 16 Nielson Way Anchorage, AK 99502 (907) 562-2646 October 15, 1987 JOB #590 STANDARD ALASKA PRODUCTION CO. WELL: K-13 PRUDHOE BAY UNIT RIG: NABORS 1SE Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures A ,~¢~iili'r COMPANY TELECO OILFIELD SERVICES JOB 590 SURVEY CALCULATIONS **************************************** Date Page 10/13/87 Company: STANDARD ALASKA INC Well: K-13 Location: PRUDHOE BAY Rig: NABORS 1SE TELECO Job # 590 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 229.55 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE-IN TO SPERRY SUN GYRO 1392.00 1.8 284.0 N 76 00 W 1391.96 2.24 3.10S 0.30W 3.11 S 5.528W 0.000 TELECO MWD 1720.00 3.5 250.5 S 70 30 W 1719.33 13.44 1.86N 19.26W 19.35 N 84.469W 2.547 1814.00 5.4 224.5 S 44 30 W 1813.04 20.60 2.02S 25.35W 25.43 S 85.446W 2.900 1908.00 8.5 222.4 S 42 24 W 1906.34 31.91 10.27S 33.17W 34.73 S 72.792W 3.308 1629.00 3.5 289.2 N 70 48 W 1628.50 9.28 1.87N 13.80W 13.93 N 82.250W 1.124 1535.00 4.5 294.1 N 65 54 W 1534.73 6.22 0.53S 7.71W 7.73 S 86.005W 1.920 TELECO Job # 590 TAK 10/13/87 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' **************************************************************************************************** 2003.00 11.9 220.6 S 40 36 W 1999.82 48.56 22.87S 44.32W 49.87 S 62.704W 3.594 2097.00 15.2 222.4 S 42 24 W 2091.19 70.37 39.36S 58.91W 70.85 S 56.251W 3.539 2193.00 18.4 221.3 S 41 18 W 2183.08 97.86 60.03S 77.42W 97.97 S 52.212W 3.350 2287.00 21.5 221.3 S 41 18 W 2271.43 129.60 84.11S 98.60W 129.60 S 49.535W 3.298 2382.00 25.2 221.3 S 41 18 W 2358.64 166.86 112.37S 123.46W 166.95 S 47.691W 3.895 2477.00 28.3 220.3 S 40 18 W 2443.46 209.12 144.74S 151.40W 209.45 S 46.288W 3.297 2569.00 31.8 220.6 S 40 36 W 2523.08 254.60 179.79S 181.28W 255.32 S 45.237W 3.808 2662.00 35.5 221.0 S 41 00 W 2600.48 305.52 218.80S 214.95W 306.72 S 44.492W 3.986 2760.00 39.2 218.9 S 38 54 W 2678.38 364.13 264.36S 253.12W 366.00 S 43.755W 3.993 2919.00 43.1 222.1 S 42 06 W 2798.08 467.42 343.90S 321.05W 470.47 S 43.032W 2.787 3012.00 46.7 225.6 S 45 36 W 2863.94 532.73 391.22S 366.51W 536.09 S 43.132W 4.694 3286.00 47.4 227.7 S 47 42 W 3050.63 733.01 528.88S 512.34W 736.35 S 44.090W 0.616 3600.00 47.9 228.4 S 48 24 W 3262.16 964.99 684.01S 684.93W 967.99 S 45.038W 0.229 3916.00 48.9 229.4 S 49 24 W 3471.96 1201.27 839.35S 862.99W 1203.85 S 45.796W 0.395 4228.00 49.3 229.1 S 49 06 W 3676.24 1437.08 993.27S 1041.64W 1439.31 S 46.361W 0.147 4543.00 49.4 230.1 S 50 06 W 3881.43 1676.06 1148.16S 1223.63W 1677.96 S 46.822W 0.243 4923.00 48.1 232.9 S 52 54 W 4131.97 1961.56 1325.99S 1447.19W 1962.81 S 47.503W 0.651 TELECO Job # 590 TAK 10/13/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' 5215.00 47.2 224.9 S 44 54 W 4328.68 2177.17 1467.74S 1609.68W 2178.38 S 47.641W 2.047 5531.00 48.1 225.2 S 45 12 W 4541.55 2409.98 1632.72S 1774.95W 2411.69 S 47.390W 0.293 5848.00 47.4 226.6 S 46 36 W 4754.69 2644.15 1796.01S 1943.46W 2646.26 S 47.258W 0.394 6163.00 48.3 229.8 S 49 48 W 4966.08 2877.59 1951.65S 2117.53W 2879.74 S 47.334W 0.805 6480.00 49.9 234.0 S 54 00 W 5173.62 3116.93 2099.46S 2306.04W 3118.58 S 47.685W 1.121 6733.00 48.0 223.5 S 43 30 W 5339.77 3307.43 2225.08S 2449.28W 3309.07 S 47.746W 3.216 7046.00 49.9 225.2 S 45 12 W 5545.31 3542.49 2393.86S 2614.27W 3544.71 S 47.520W 0.732 7297.00 50.9 226.6 S 46 36 W 5705.30 3735.48 2528.44S 2753.15W 3738.03 S 47.436W 0.586 7479.00 51.2 227.7 S 47 42 W 5819.72 3876.90 2624.70S 2856.92W 3879.56 S 47.426W 0.498 7666.00 51.0 227.7 S 47 42 W 5937.15 4022.37 2722.60S 2964.61W 4025.11 S 47.437W 0.110 7856.00 51.1 227.3 S 47 18 W 6056.59 4170.04 2822.43S 3073.56W 4172.88 S 47.439W 0.173 8202.00 50.7 227.3 S 47 18 W 6274.81 4438.37 3004.43S 3270.99W 4441.40 S 47.432W 0.117 8518.00 49.1 227.3 S 47 18 W 6478.35 4679.90 3168.26S 3448.72W 4683.11 S 47.427W 0.507 8970.00 49.7 227.3 S 47 18 W 6772.49 5022.84 3400.88S 3701.05W 5026.31 S 47.420W 0.133 9190.00 51.8 227.3 S 47 18 W 6911.68 5193.08 3516.35S 3826.31W 5196.68 S 47.417W 0.955 9403.00 51.8 226.6 S 46 36 W 7043.40 5360.29 3630.62S 3948.63W 5364.06 S 47.403W 0.259 9623.00 50.5 227.3 S 47 18 W 7181.40 5531.44 3747.57S 4073.83W 5535.38 S 47.389W 0.641 TELECO Job # 590 TAK 10/13/87 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 9844.00 49.0 228.4 S 48 24 W 7324.19 5700.04 3860.76S 4198.88W 5704.05 S 47.402W 0.778 10065.00 47.7 227.0 S 47 00 W 7471.06 5865.08 3971.89S 4321.02W 5869.17 S 47.411W 0.755 10413.00 45.2 227.0 S 47 00 W 7710.81 6117.04 4143.80S 4505.55W 6121.37 S 47.395W 0.718 10635.00 43.5 227.7 S 47 42 W 7869.55 6272.10 4248.94S 10856.00 42.2 229.1 S 49 06 W 8031.57' 6422.36 4348.72S 11042.00 41.7 230.5 S 50 30 W 8169.91 6546.70 4428.97S 11136.00 41.5 229.8 S 49 48 W 8240.20 6609.10 4468.96S 4619.69W 6276.55 4732.08W 6426.81 4827.04W 6551.04 4874.95W 6613.38 S 47.394W 0.797 S 47.417W 0.729 S 47.463W 0.570 S 47.488W 0.539 TELECO 0 i ~ ? i e ~ d PLAN VIEW Smrvicms 9600 8000 6400 4800 B200 1600 0 I WEST (~t) 1600 i 600 3200 4eo~ k- 640Bo 8000 1 1200 12800 IcLECO Oil?ield Services VERTICAL PROJECTION 0 2000 4000 6000 8000 ~ 0000 12000 lO00 ,'-! i f 7. ] ...... ...... ,Y-T--T .... T- ..... -F-] ~ ..... ....... ? .... F-]-,'T--F-T-'~-'-I'--I-T"-T-' ~ ~ ~ , ~ ~ ~ : , ': · . . G ~ ~ ' ~ i ' ' ~ ' I -- t ~ ~S6oo~ ~?~~G ~~ ~~Ip~][r~OE~ ~),y~, 1~. 5000 ~ · i : / F'~--T I l-'= ~-~ I t ' '~ ? ' ~ 1 :"'~ "- l ~'"" ........... ~ ~' ..... ~ ........ '}' ~ ..... r"-~'~-?~4~ ''~ ...... "T-f ....... 40.~: --i .............. ~EG~ ..... + ..... 4--i ~ ....... 't' '~ .... ~: .... ~ .... ] J~ .... [ ': ~ ....~: F ..... ~ ...... l ......... f"'"%'-; ........ ~ ......... ~' ..... 1-% ....... ~ ..... ~'"-~ ...... ~ ........ r ..... ~ ..... r ..... ~ L , , ~ ' ' 95 8, 1, BEG' , . ' f i " ~ , ; ~ : . · ' ], ..... ' ...... ; ~ .........~ ..... ?' ............. ~ .................... ~ ;--~: ........ ' ~O~"-' ................ , ~-- ¢ ~ ..... v' h .... 1-'- ~ ....: ....... ~ .... r'-"~ ..... ~-] ....... $ .--~ ...... ~ ....... F ....... ~--. + -W : ............... ~ ........ ~":- .... ~ ............... ~ ..... 4-- '---~ ........ ~--~ ..... , ................. 4 .... ~ ................ * ..... ?--- '. i , , ' . ~ t : " ' ; .... , ......... r"--, ..... r ..... t , i : -: : ) i [ f I -- ; / t , ' ~ / ~.t. .... ~.. ~ ....... '. .... i. ,, . ~ ' , - ~ , i ~ ~ ; · 1BO00~ - ~ ~ .......... ' : ~ , , . i : , ' : I : ~ ' I i ' ; i ' ~ ~ / I5000~' ~ ~ ' ' ; ~ ~ ~ ',, ~ ~ :.' ; t : ) I ' · : ~ ~t ~ j .... ~ ~ ~' ~ ...... I ~ '"f ' ' - 1 , ' ' ~- - ~ ~ ~ : ,; ' ~ ........ ' .... ' ..... ;. ................... : ~: .:' ........ ~, . : .............. ~ ......... . . , ,r ............ t ...... ,.. ~ . ~ ...... ~ ' , -: : : i ' ~ ~ , ' .... t ;' ' t ~ i ' : i ' ' / ' ' I t ' ' / ~ : , ] , , . , ; , VERTICAL SECTION STANDARD ALASKA PRODUCTION CO. PAD K (~. 8. ~-~4) K-13 Controlled Drilling Consultants, Inc. LES HENDERSON 3334552 CONTN LLED'DRILLING CONSULTA&.$, INC. 4234 'KINGSTON .DR. Ancho,rage, Alaska 99504 (907) 333-1552 October 20, 1987 . Mr. B~ian Rose Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, AK 99502 RE: Magnetic,Single Shot Survey Job No. 0987-030 'Well K-13 (11-8-11-14) P~udhoe Bay Field N~rth Slope, Alaska Date.of Survey: 9-30-87' to 10-13-87 Dear Mr. Rose: Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the.above well. The method used in calculating this survey was Radius of Curvature. The depth of the survey was 481 to 11206. Thank you for giving us this opportunity to be of service. Yours very truly, · Contro!l~ Drill~,ng conSulta~ Terry V, Henderson Directional Supervisor Inc. SOHIO ALASKA PETROLEU~i iAGNETIC SINGLE SHOT SURVEY ~ADIU~ OF CURVATURE METHOD OF ~OMPLiT~TiON ~OMPUTED FOR CDC BY OCEANTECH --% JOB NO A-0987-030 YELL K-J3 KB ELE¥ 54.30 FT. SURVEY DATE 9/30/87 PROPOSED DIR S49-55Y RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D H ASSUMED VERTICAL TO 0 FT, 0 0 0 , O0 -54,30 N , OOE 481 0 I6 481,00 426,70 S62,00E 68i 0 i8 68i,00 62~,?0 S~6,00W 975 0 18 974,99 920,69 SSO, OOE iJ2J 0 29 ii20,99 ~066,69 936,00E i213 0 30 i2i2,98 i 158,68 SSO, OOW I303 i 0 i30A 98 I248,6~ N66,00W 1392 I 48 1391 1535 4 30 1534 1629 3 30 I628 1720 3 30 1719 1814 5 24 i813 1908 8 30 1906 2003 11 54 1999 2097 15 I2 2091 2193 18 24 2183 2287 21 30 2271 2382 25 12 2358 2477 28 iS 2443 2569 31 48 2523 95 1337,65 N76 , OOW 72 1480,42 N65,90W 49 1574, i9 NTO,80W 32 J 665,02 S70: 50W 03 1758,73 S44,5OW 33 1852,03 S42: 4OW 82 1945,52 940 60W I9 2036,89 S42 08 2128,78 S41 43 2217, i3 S41 63 2304,33 S41 45 23<99 , I 5 S40 07 2468.77 S40 2662 35 30 2600,48 2546,i8 S4i 4OW 30W 30W .00 i,38 2.54 3.05 3.62 3.38 2.67 ,ii 2.30 t 59 S 9 84 S 22 44 38 93 59 60 '-33 69 111 97 ~44 34 ~. 79 39 218,39 S ,00 W t,00 E i,36 E 2,08 E 2,9i E 2,62 E i,47 E .58 W 8.00 W i4,09 W t9.54 W 25,64 W 33,46 W 44.6i ~ 59,20 W 77,71 W 98,87 W ~23.72 W ~51 ,65 W !8i ,54 W 215,2i W .o0 S 90 i,i3 $ 62 O O E 1,94 S 44 3~, 34 E 3,28 S 3,9 23 58 E 4.2i S 43 36 ~2 E 4.47 ,S :3.5 52 S E 3.68 $ 23 34 8 E 2.73 $ 12 16 48 W :3.00 S 89 !3 55 W i4 28 N 80 4i 6 W 19 6~ N ~3 !7 45 I.~ 25 69 S 86 27 20 W 34 88 S 73 36 2i 49 93 S 63 17 33 W 70 85 S 97,93 S 52 30 45 W 129.54 S 4<:945 !1 W I66,87 S 47 5i 9 W 209,38 S 46 24 57 W 255,22 S 45 20 27 306.61 DOG LEG SEVERITY DEG/i0OFT .o0o · 056 .152 ,024 .556 ,899 . 064 547 298 5i3 335 298 3OHIO WELL K-13 ~EAS, DR!FT )EPTH ANGLE D H 2760 39 12 3012 46 36 3286 47 24 3600 47 54 3916 48 48 4228 49 ~8 4543 49 24 4923 48 6 5848 47 24 6163 48 lo ~480 49 54 B733 48 0 7046 49 54 7297 50 54 7479 5! i2 7666 5 t 0 7056 5 i B S202 50 42 8518 49 6 8970 49 42 9190 5~ 48 94 03 5 t 48 9623 50 30 9944 49 0 0065 47 42 TRUE VERTICAL DEPTH 3472,39 3882.08 4755,34 4966 73 5174 20 5340 42 5545 96 ~ 95 5020 36 5937.79 6057,24 B275,45 6478.99 6773,i3 69i2.32 7044,04 7182,04 7324,93 7471,70 SUB SEA 2624.07 2743,77 2809 2996,56 3208.09 3418, 3827,78 4078,32 4275.03 4487.90 4701 . 04 4912,43 5119,98 5206, J 2 5491 5651 , 65 5766,06 5883,49 6002,94 ¢:..~21, 6424,69 ~7i8,83 ~858.02 ~-.989,74 7i27,74 7270,53 74i7.40 SINGLE SHOT RECORD OF SURVEY DRIFT DIREC DE~, TOTAL 838.90W ~4~, 1 OW S45,GON 947,70B S48,40W S49,40W ~49, i OW ~5 O, i OW S52,SOW S44,90W 845,20W 846,60W S49,80W S54,0 OW ~43,50W ~45,20W S47,70W S47.70W S47,30W S47.3 OW 847.3 OW S47,3 OW S47.30W S46,60W S47,30B 940,40W ~47,0 OW · ~.43 49 528.3.3 ~, 46 3~, 67 992,49 i ~47.39 ~ :3~ ~ t 631.95 ~ 795,24 1950,88 2098,69 2224,3 i 2393, 09 2527,43 2623,50 272 ~ , 45 2~2 i, 27 3003,37 3167,28 3400 02 35I = .,55S 3629 81 3746 77 3:359 96 397 ~ 09 JOB NO A-0987-030 COMPUTER~ ~7 OCT 87 KB ELEV 54,70 FT. COORDINATES 32i,30 366,7g 5i2,44 685,02 862,95 1 041 ,47 i 223.47 ~ 447,03 ~609,52 1774,80 ~943,30 2tt7,37 2305,88 2449,I2 2614,11 ~ 22 2057,i6 2964,80 3073,74 .~z~!.O7 344S,70 ~700,92 3826,i2 3948.44 4073,64 4~90,6~ 4320.02 CLOSURE'* DISTANCE ANGLE DOG LEG SEVERITY DE6/1OOFT 365.89 $ 43 49 39 ~ 470,34 S 43 5 !6 W 535,9i 9 43 iO 52 ~ 736,02 $ 44 7 30 ~ 967,66 S 45 3 56 W 1203,35 S 45 49 2 W 1438,65 $ 46 22 45 W ~677,31 S 46 50 i~ ~ I962,i7 S 47 30 57 W 2i77,7~ S 47 39 ~O W 2411,05 S 47 24 3 W 2645,62 S 47 i6 4 W 2879.10 S 47 20 36 W 3117,94 $ 47 41 35 W 3308.43 $ 47 45 i4 3544,07 3737,39 3878,93 4024,46 4i72 4440 4682 5025 5i95 5363 5534 5703 5868 47 31 38 W 47 26 54 W 4¢ Ze 28 W 47 27 t W 22 S 47 27 8 W 73 S 47 26 35 B 44 S 47 26 8 W 63 S 47 25 35 W 98 S 47 25 20 W 37 S 47 24 27 W 69 $ 47 23 36 W 87I 256 20! i70 50'7 290 925 4i2 .685 553 ,i07' ,i38 ,ii6 .506 ,iS3 ,955 ,258 .~2~ 5:, ~ 47 24 '-' ,-.:4 W 48 S 47 24 54 W D"t $'T~'~:OE--- 46"7, 5~2 6-0-- 732'772'-- 964.7'0 ..... ~ 436, ! 675;' 43 -- ~ 9~-0 2409,36 ....... 3i i~ .~0 ...... S70~/'8i ~ 9 76 .~.,' - 402~ . 76 ...... 4i 69 4679,25 ..... 5022 .'i ..,~; 92,4'8 5359,62 ..... 5~30,77 - 5~64 SOHIO WELL SINGLE SHOT SURVEY JO8 NO A-0987-930 COMPUTER- KB ELEV ) 54,30 FT, REtORt OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DiREC D M DEG, TOTAL COORDINATES C L 0 S U R E¢ DISTANCE ANGLE D M 80u LE6 SEVER ! TY DEG/1 O OFT D t S T'¢i M CE- .... 10635 43 30 7870,19 78t5,89 $47,TOiil 4248,23 S 4619,40 10856 42 t2 8032,2I 7977,9i S49,tObJ 4348,0i $ 4731.79 ii042 4i 42 8i70,54 8Ii~,24 SSO,5OiJ 4428,26 $ 4826,76 6t2O,g? S 47 23 52 W 6275.85 S 47 23 48 N 6426.12 S 47 25 13 N 6550.35 S 47 27 55 W 66i2,69 @ 47 29 26 ~ ,654 .428 627i,.2 ...... 642i;6~ ..... 6546"~'J ...... ~60~;42 ....... THE FOLLOWI N6 IS EXTRAPOLATED TO TD 1206 41 ;30 829;t,26 8238.96 .S49,80W 4,498,19 S 49i0,10 I.,i 6659,04 $ 47 30 24 N .000 BOTTOM HOLE CLOSURE 6659,04 FEET AT S 47 30 24 W ~OHIO t.¢ELL K-I~ SIHGLE SHO'T SURVEY ~ER.URED DEPTH ANu OTHER DATA FOR EVERY EVEN i00 FEET OF 3UD SE~ DEPTH, TRUE · MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH. DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES i54 254 354 454 554 654 754 $54 954 J 854 1254 ~354 i454 I555 J655 t755 2059 2163 2269 2~77 2489 2606 2729 2868 2998 3J44 329i 3439 358~ 3738 3889 i54, 254, 354, 454, 554, 654, 754, e54. 954, ~054. 1i54, i254, J354. 1454, J554, 3654, 1754, I854, J954, 2054, 2154, 2254, 2354, 2454, 2554, 2654, 2754, 2854, 2954, 3854, 3t54, 3254, 3354, 3454, -54 300 500 600 700 JOOO 12~0 I3OO I~O0 1500 1600 1700 ~900 2000 2t00 2200 2300 2400 2500 2600 2700 2800 2900 3000 Sled 3200 3300 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 i 2 4 8 t4 22 35 5i 74 i05 i 43 i89 284 4.34 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 2 4 6 8 i6 23 3i .38 46 47 48 49 50 51 ,09 ,37 ,77 't, 24 2,23 2,5i 2,72 .3,32 7,58 2,98 J ,94 2,68 i 4,75 I5.73 31 .83 52,64 9! ,39 i28.22 J48.84 i94,50 249,08 3i3,58 38~,63 4.57,44 5,.7,0,86 604.11 75i. 17 825,23 S S S S S 9 S S N N f,! S S S S S S S S S S S S S S .9 ,00 ~ .07 E · ;'8 E ..6i E ,94 E i,26 E i ,3~ E ~c~ E 2,97 E ,4~ E 3,08 kl 9.o., 2i,69 ki 3~, 75 W 52~0 W ! 03, i-1 kl i34,~9 W i55,47 ~ i94,o~ w 24 i ,~i i.~l ¢94, SF: ~ 359,52 ~.~ 4~6,0 i ~J 5i5,22 Y 596,22 W 67~,~.~ Y 847,29 ~ SOHIO WELL K-J3 SINGLE SHOT SURVEY JO8 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN FEET MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SER DIFFERENCE VERTICAL CORRECTION 404 i 4347 4500 4654 4005 4955 5252 5400 5698 599.5 6i44 6296 6449 6603 ~754 ~905 7059 7215 ?374 75~3 7692 7851 801 0 8169 8326 8480 8633 8787 g941 9097 9258 3554, 3500 486 3654. 3600 539 3754, 3700 592 .3,954, 3800 3954, 3900 699 4054, 4000 750 4i54. 41 O0 80i 4254. 4200 849 4354, 4300 :897 4454, 4400 945 4554, 4500 994 4654, 4600 i 043 4754, 4700 i 092 4054, 4800 i t40 4954. 4900 i i 90 5054, 5000 i24i 5i54. 5i O0 i294 5254. 5200 i348 5354. 5.3300 i399 5454. 5400 i 450 5554, 5500 t504 5654. 5600 156I 5754, 5700 i619 5854, 5800 i678 5954, 5900 t737 6054, 6000 1797 6I 54, 61 O0 1855 6254, 6200 i914 6354, 6300 197i 6454 . 6400 2025 6554. 6500 6654 . 6600 2132 6754, 6700 ~'i86 6854. 6800 2242 e).~54. 6900 2303 52 5:3 53 54 53 5i 5i 48 48 48 49 49 49 48 50 5i 53 54 55 54 57 58 59 59 60 58 59 57 54 53 54 54 5~, 6i NO A OF SUB SEA DEPTH, COMPUTER- KB ELEY TOTfiL COORDINATES 899,85 S 975,33 S 1051,28 S ~b 59 S J200,62 S i27i,60 S i3.39,9i S i4i0,74 8 i486,09 ~ i563,29 $ i64i.44 8 i7i8,85 S ~794.46 S i868,69 $ i94i,96 9 20i3.89 S 2084:70 9 2156,9i S ~5 5i S 23i 7,02 S 2400, OG S 2wdJ,96 S 2568.i0 S ~6ol 88 S 27.35,19 S 2818,8~ S 2902~59 S 2985,83 $ 3067,98 8 3~47,89 S 3305,40 S 338~,97 8 3466,34 S 355~,80 8 i 02 i. 64 i i 09, i 198.66 i 288,06 i466, i5 i 628.59 i705.9i i784 36 igC3 43 i942 47 2 023 03 2I O~ 74 2i94 2286 ~79 99 2459 77 25~8 56 262 i i 5 2707 76 2796 2979 8~: bJ ~071 07 g252 07 3427 35i2.78 3598 3684.6 3772,79 .7865 54. -30 Fi', ._. SOHIO !~tELL K-13 ~ING:LE SHOT ..-.UR~E'¢ JO8 NO A 0987' 030 ~,OHPU.ER- t? OCT K9 ELEV 5<,30 OTHER DRTR FOR EVERY EVEN i00 FEET OF SUB SE~ DEPTH. 87 MEASURED DEP TH TRUE VERTICAL oU9 H[-TvC DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 9420 9579 9736 9889 10187 t 0331 J 075 0 I1020 1i154 ii2o6 7054, 7000 2365 7i54, 7i00 2424 7254. 7200 2484 7354, 7300 2534 7454. 7400 2584 7554, 7500 2632 7654, 7~00 2677 7754. 7700 27i9 7854. 7800 2758 7954, 7900 2796 ~054o 8000 283i 8154, 8i00 2865 8254, 8200 2899 62 763~,75 $ 59 3723,82 S 57 3805,i0 S 53 3882,42 $ 50 3958,03 S 48 397i,09 S 45 397i,09 $ 42 4i72,23 8 39 4238,05 S 38 4300,94 S 35 436i.08 S 34 44~9,03 $ 34 4475,94 $ i3 4498.I9 $ 3957,89 4048,82 4177,47 4223.8~ 4320,~2 4320,~2 4536,62 4609,22 4678,08 4746.93 4815.59 4883,77~ 49i0.~0 SOHIO WELL K-t3 SINGLE SHOT SURVEY dOB NO A-0987-0~0 COMPUTER- I7 KB ELEV 54.~0 87 ! NTERPOLATED VALUES FOR EVEN 1000 FEET OF HEASURE~ DEPTH MEASURED bEPTH 0 I O00 3000 4 000 5000 6000 ?000 8000 9000 JO000 TRUE VERTICAL DEPTH Ot I997. 2856, 4iB4, 4858, 6148, 6792, 8~39. 8293. -54, 946. I943. 280I, 3473, 4i~0. 4804. 5462, 6094, 6738. 7374, 8085. 8239. TOTAL COORDZNFtTES ,00 S .00 2,~? S 2.2~ 21,97 S 44,20 384,67 9 360,55 879,88 S 910,96 i360,56 S i492,0J iS7i,28 $ 2025,90 2368,28 S 2589,25 2897.i8 $ 3i56,00 34i5:57 S 37i7,77 3938.33 ~ 4285,44 44i0,4i S 4805,22 4498.~9 S 49JO,iO HORIZONTAL VIEW ~FANDARD ALAS~ PRODUCTION WELL K-'I3 (~-$-11-14) .... ' ....... RADIUS OF CURVATURE ! MAGNETIC SINGLE SHOT .. ' ' . } , SCALE:I"r I000' i , , --O~TOBER :t7,--t987 .! I ! .! i .. ! I ' · , COMPANY .. . i. · UB.$ URFA CE DIRECTIONAl. SURVEY ~UIDANCE r~ONTINUOUS r'~looL Company . STANDARD ALASKA PRODUCTION COMPANY Well Name K-13 (18p4' SNL~l143' EWL~SEC 4,TllN,R]4E) Field/Location PRUDHOE BAY, NORTH SLOPE. AL-ASKA , Job .Reference No. Oa..te 72475 19-0CT-87 Loc3ged By: Computed By; SALAZAR KRUWELL ? 0 R ST~',,f,)A~i') Ai~,~SK/~ PI~UDUCTION S:~(dc:¥ t.)aTH: 19-UCT-~7 Ct). D A T F.:: 2/5 - (J C'i' - ~ '7 ~EASUR D E P T t., D H D g P T d IN'¥ERPOLAT~':O VA. LUE:S F'{)R EVEri lO0 0 I 0 C 200 3o6; 400 5,.~0 600 7 O0 q 00 00 00 0 (> 0 G 0 00 : 0 t, ::.). 00 1. ();), 0 20 O, 300. 60 (). O 70 (') . 0 U 799.99 899.99 1000.0~ 1100,00 1200.00 1300.0o 1400 · O0 1500.00 1600,GO 1700 0 ,;: 1 @ 00: 00 1900~ 0t3 ::/99,99 1099 . 1 199.s~9 1299.99 [ 399,97 1499.8b 159q.64 I bg~ , 4.0 1799.21 1898.5'! - 5 q, 30 0 45.70 0 1 r,. '~ { 1 t ri -0.,,')3 145.70 '0 7 $ 17 22 245.7(~ 0 1.0 345.7~ 0 14 5 27 b9 r': 0.17 4q5,70 545,'I0 0 16 S 22 6 E 0.37 b q 5. '70 745,~9 0 17 8 27 7 h 0,63 2000 2100 2200 2300 2400 2500 2600 2700 2800 2quo :00 G 0 , O0 .0 0 .00 . 1997.0.[ 2094.10 22~3,25 2374.3n 24 b 2, ~i 254 B. 3 1 262'~,~5 270/. b2 27~2. t4 945,69 o 14 8 31 39 E 0,8! 1045.o9 0 15 8 34 9 F: 0.83 1145.o9 () o 5 ~8 3 g 0.82 12/t5.o'9 ~) 39 N 78 19 w 1.05 lq45,58 3 41 ~,,72 2~ ¢,; 4.4_~ 1~45..3q 3 49 :~ 71 2b u~ 7,99 1645.16 3 i4 ;¢ '7~) 5o '., 11.84 1744,~I $ t~ 8 52 1~ ~ 1.~{,oO 18q4.27 d !.3 5 4.t 19 :~ 29.t~2 3000. 3100 3200:00 3300,00 3400,0:'~ 3500.00 3600.0U 3700.00 3800 O0 3qo0~O0 2'.)21. 2987 3055,49 3123.2o 319k.04 3258. l 'I 332.~, 7 t 3390.75 :1451.21 194.2.71 1 2~,39.~0 j,~ 2t ;i 41. ih * 70.59 21.35..17 .14 hq 5 41 27 , 99.81 222~,9b 22 2'1 ~ -il 37 ;~ 1.34.62 24,..~d.b,'~ 2q 2'1 S q~.~ bi w 221.35 2,~9~.,)! 3 ~ 19 S 4C i ~: 272.64 25/b.b5 31 '1 5 3~ 31 v, 329.4~ 2653.22 q'.) 3% 5 3'~ 5~ ~. 391.59 272~;. 14 -:I'2 47 S ,tl ,t2 ,~, 457.02 27'49.2,, 4,5 213 b ~e, 8 ~ 526.90 2d~.~7. {;1 ,iV 41 29t3.07 ~; 4 S q7 27 ,', 674.85 3001.19 47 19 S 48 l'J i,,, 74~,59 3068,9o ~,1 2., ~, 48 b ,, d22.10 313(,.-1~ 4'1 2'7 3203.~7 /i'l 59 3270..',i 4d 42 S q7 ,i~ ~, 1.044.28 3336.'i5 48 20 5 48 20 ~', 1119.34 3402.91 48 35 $ q8 48 ~ 1194.06 0 0 (; L e: G DCG/100 DATE OF' SURVEY{ KEbLY BUSHING EbEVATION{ t~i EASI..I R ED OEP'tH gNGINEESI RECTAaiGULAR COORDINATES e~ORT'lt/SO!lTti EAST/WEST FEET FEET 0,00 0,00 N 0,00 E 0,09 0,01N 0,02 0.15 0,0o S 0,05 E; 0.07 0,3o S 0,15 E 0,12 0,64 S 0,32 E 0,03 l,Ol S 0,52 0.17 1.40 $ 0,71 E 0,06 1,80 S 0,89 E 0,31 2,2b S 1,11 E 0,12 2,6~ S 1,32 0,17 0,18 0,30 1,13 '1,1.0 3,15 0,72 2.33 2.51 4,02 3,81 3,71 3.30 3,65 3.23 3 61 3~7 4,1~ 1,75 3.08 4.31 0,55 1,48 0.27 0,40 1.12 0,49 0,94 0.98 0,47 3 07 S 1,55 3:39 S 1,81 3,5~ S 1,97 3,54 S 1,63 3,01 S 0,29 1.89 S 4,21 0,42 N 10,84 1,18 N 16,55 2.14 S 22,61 9,73 S 30,88 22.65 S 42,65 40,4~ S 58,16 62 62 S 77,77 88:95 S 101,07 119'78 S 128,37 154,7~ 8 158,94 194,32 S 192,53 238,b9 5 229,51 2B7.31 $ 269.70 337,50 S 312,89 388,25 S 351.47 438,07 S 415,55 488,49 S 470,44 538,01S 525,10 587 03 S 579,93 636~21 S 634,56 685~97 $ 689 51 736,13 S 744:79 786.44 S 800,53 835,77 S 856,66 HORIZ, DIST, FEET PAGE 1 19-0CT-87 54,30 FI S, SALAZAR DEPARTURE AZIMUTH DEG o,00 N 0 0 E 0,03 N 58 13 E 0.08 $ 36 12 E 0,33 $ 26 36 E 0,71 $ ~6 54 E 1,13 8 27 30 E 1,57 S 26 56 E 2,06 $ 25 28 E 2,52 $ 26 I E 2,99 $ 269 g ,43 ,84 4 09 3 90 3 O2 4 62 10 85 16 60 22 71 32 38 $ 26 43 $ 28 0 E $2851 S 24 42 E S 5 32 W S 65 5O N 87 47 W !~ 85 55W S 84 36 W S 72 30 W 48,29 S 62 I W 70,85 S 55 10 W 99,85 S 51 9 W 134,64 S 4~ 39 W 175 57 $ 46 58 W 221:85 $ 45 45 W 273i 52 S 44 45 W 331 13 S 43 52 W 394,06 S 43 11W 460,22 $ 42 50 W 530,46 S 42 57 ~ 603,81 $ 43 29 W 678,19 S 43 55 W 751,79 S 44 18 W 825,18 S 44 {9 W 898,58 $ 44 55 W 972,61 $ 45 8 W 1047,18 S 45 20 W 1122,20 S 45 30 W 1196,82 S 45 42 ~ PAGE 2 STANDARD ALASKA PR UDH .P, F, BAY NORTH SLOPE,A[jASKA DATE OF SURVEY{ 19'0CT'87 BUSHING EbEVATION{ 54,30 FT ENGiNEEN{ $, SALAZAR '[N?igRPO6AT~?.[) VAUUES };'OR i<V~;[~ lO0 FEET Of /qEASURED F)EPTH TRUE S [.i ~-,S EA COURSE MEASURED VER'CICA~, VE~,'['ICA[, DEVIATION AZI~UI'H DEPTH DEPTH DEPTH PEG MI~J DEG VTRTICaL i)OGLeiG RECTANGUbAR COORDINATES HC]RIZ, DEPARTURE SECTt[.)~'~ S~2VERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG H~N 4000 O0 J523.20 ~40~.90 48 46 100:00 358~.97 3534.67 48 55 200 O0 3654,~0 3600.30 49 3 4300 O0 ~'720,11 3665.8! ~8 54 4400~00 37~3.~9 3731.~)9 %8 52 4500i ()(~ 3851.53 3797.23 ~9 9 4600 00 ]91.7.14 3862.84 48 44 4700~00 39~3'7l 3~29.41 48 3 4800.00 405~). 6t~ 3996.3(~ 47 59 4900.00 4117.64 4U63,34 47 50 S 48 43 ~ 1269.1~ ~; ~8 35 ~ 1344.4g " 93 S 48 41 ~ 1.~95,48 S 49 3 ~ 1570,70 8 48 59 ~ 1~46.22 S b(~ 5 ~ 1721.o9 S 51 46 ~'~ 179e.27 S 52 17 ~ 1870,55 S 52 ~9 ~ 1944.65 0,41 0.17 0,i2 1'1~ 0.25 0.39 1,US 0,54 0,56 0.20 885 2U S 913,17 ~ 127~ 935~03 $. 969,72 ~ 134 984.99 $ 1026 27 ~ 1422 1035'08 $ 1082 84 W 1497 1084,43 S 1139 61 W 1573 1134,00 S 1196 60 W 1648 1183,15 $ 1253.86 W 1723 1230,01 $ 1311,93 ~ 1798 1275.75 $ 1370,53 ~ 1872 1320,84 $ 1429,46 W 1946 85 6 45 53 W 09 $ 46 2 w 47 $ 46 I0 W 98 S 46 17 W 58 $ 46 32 W , 95 $ 4639 W 35 $ 46 5O W 4O S 47 ~ W 27 $ 47 15 W 50uO O0 418q.73 4130.43 4B 13 5100~00 425'[. 39 ,~1 37,u9 4'1 33 5200.00 43~9ob~ 4265.2;! qb 48 5300 O0 43~7.67 4333.37 47 30 5400 O0 4454,9~ 4400.06 ~7 46 5500 O0 4522.22 q467.92 %1 4~ 5600 QO 4589.21 45{4.91 4~ 5 5700 O0 465~.27 4601,97 47 20 5800 O0 4724.3~ '%6'10,02 47 15 5900.00 4792.15 4'?~7.8~ 47 21 S 52 13 ~ 201~.71 $ 48 31 ~ 2093,2! S 44 24 W 21u6.17 $ 44 5 ~ 2239.0~ 5 44 6 ~ 2312.70 S 44 3R ~ 238~.40 S 4~ 3~ ~ 24b0,36 S 45 ~7 w 2534.30 5 45 45 ~ 2507.37 S 46 29 ~, 26S0.~9 1,26 5,23 0.86 0.63 0,40 0,44 0.32 1.56 1,34 0,59 1366,01 6 1488 26 ~ 2020 13 $ 47 27 W 1412,84 $ 1546 23 ~ 2094 51 S 47 34 W 1453,75 S 1598 71 ~ 2167 1516,28 S 1649 75 W 2240 71 1509,48 $ 1701 1622,30 $ 1752 1675,14 $ 1805 1727,71 5 1857 1779,12 S 1909 1829.88 $ 1962 15 w 2314 97 w 2388 12 ~ 2462 46 W 2536 67 ~ 2610 75 w 2683 59 $ 47 31 W $ 4724 W 55 $ 47 18 W 46 $ 47 13 W 63 S 47 8 W 76 S 47 4 W O0 $ 47! W 44 $ 47 0 W 60,')0 0(') 485'~J.56 ,i8o5.Z~) 41 5,i 6200.00 4993.2~ 4938.93 4~ 3 6300.0o 505q.93 5u05.~3 ~ 34 ~400.0{~ 512b.4~ 507] . t A 4':) 23 6500.00 519C',4~ 51..~b. t6 4'~ 13 6bO0.('O 5~56.~4 52{.}2, 34 47 19 6700,00 b324.0b 5209.76 47 .~5 6800.00 5391 .03 5!~.7~ ~7 55 6900, (,0 545'!.9~ 5403.o~ ~'~ 2~. 5 .io 1.5 , 2154.50 b 4~ 43 ~ 282~.gl. 5 4') ~,2 ..; 2903.23 S 51 13 ~'~ 2977.77 5 '42 ~5 , 3u53.21. 5 53 '3% ,~ 3129.07 S 49 '47 * i203,92 S 44 30 * 3277,64 ~ 43 42 ,'~ 3351.53 a 'i:, ~ ~ 3425,45 2.20 0.75 0.61 1.69 0,95 1,14 5.19 2,31 0,74 1.80 18HO 23 S 2016,83 W 2757,33 S 47 0 W 1928 73 $ 2073,13 ~ 2831,58 S 47 3 W 1976 90 S 2129,85 ~ 2905,93 $ 47 ~ W 2024 46 $ 2187,25 W 2980,35 S 47 12 W 2070 88 5 2246,81 , 3055,60 $ 47 ~9 W 2116 32 $ 2307,'15 W 3131,22 $ 47 28 W 2162,11 $ 2367,08 ~ 3205,89 S 47 35 W 2212,68 $ 2420,84 W 3279,70 $ 47 J4 W 2256,27 S 2472,25 W 3353 81 $ 47 ~9 W 2319,78 5 2523,78 W 3427:95 $ 47 Z4 W 7000,00 55.23.31 7100.00 5587 65 "~ '- _ . ~ .., .~ 3.3 ,'~ t, :} 2 7200.00 5652.u2 5597,72 7300.C0 5715.37 5561.07 50 45 7400.00 577~.47 75r)0. flu 5R41.bl 5737.21 50 42 7600,00 5904.91 5850.0[ 7700 O0 596~.41 b')14.l [ 5;~ 25 7800~00 0032,~5 59'17.75 50 33 7900.00 6095.61 6041.31 50 5 45 56 ~ )577.32 5 46 32 ~ 3653.72 5 47 ~ ~, 3731.00 5 47 !8 ~ 3808.51 5 47 11 ~ 3886.08 $ a7 lU ~ ~963.14 S 47 ~ a 4040.52 S 47 12 b ~i17.59 S .~7 4 a 4194.71 0,65 0,94 1,25 0,43 0,24 0,09 0,36 0'17 1,01 0,32 2373 04 S 2577,57 w 3503,60 5 47 21W 2426~35 5 2632,51 ~ 3580,12 $ 47 20 W 2479129 $ 2687,77 W 3656,64 $ 47 18 W 2532 19 $ 2744,23 w 3734,00 S 47 18 W 2584 80 S 2801,24 ~ 3811,58 S 47 ~8 W 2637,50 $ 2858,24 ~ 3889,21 S 47 18 W 2690,07 S 2914,95 w 3966,54 $ 47 17 W 2742 62 $ 2971,58 ~ 4043,79 $ 47 17 W 2795~05 $ 3028 16 ~ 4120,93 $ 47 17 W 2847,60 S 3084:71 w 4198,13 $ 47 17 W C~.ii~Pl~'.l:ATIi.~i,, [.)ATE; 26-OCT-B7 DATE OF SURVEY~ 19'0CT'87 KEbbY BUSitlNG EI~EVATION~ 54,~0 FI ENGINEERI $, SABAZAR Ii,~TERPOL, ATEO VALUES FOR P:V.ff:?~i 100 FEET OF ?iEASURED DEPTH V[:;R'['ICAL O(}GL, EG AgCTANGIJL, AR COORDINATES HORIZ, S~CTIOt.., SEVERI'I'Y NORI'H/SOUT~i EAST/WEST DI~T, FEEt DEG/IO0 FEET FEET FEET RO00,O0 6158.98 8100,00 6222.50 6108.29 50 27 S 40 53 t~ 434.9.08 8200 O0 6286.41 6232.11 50 B S 46 57 ~ 4425,98 8300 O0 ~35t),6~ 6296.]8 49 50 S 46 5~ , ,'1502,50 8400 0() 6415.32 6351.02 49 3~ 6-47 5 ~ ~5'18.73 8500 O0 6~8('},5~ 6420,23 49 1 ~600 O0 554n,55 0492.25 48 20 8700 OO 661.].35 6559,05 48 9 8800,00 6679,51 o625.21 q8 55 8900.00 5744,~ 6690.50 49 27 9000.00 o809.]1 .6755.0! 5o 19 9100.Oi) 6B72.5I a818.21 51 11 200, [.)O 6934.5I ~80.2't 52 7 ]00.00 ~995,59 0941,29 52 12 9400.00 7057,]~ '1003,~)6 51 3.~ 9600.Q0 7!83.{)] 712~.73 59 72 9700,00 7247.13 71':32, ~ ~ 49 57 9800'00 73]~.97 7257,67 t~ iu 9900.00 7377.7,$ 7323.-~4 48 28 10000,00 744~t. 5~3 '? 39 u, 2.,.~ ~'1 52 lOlO0.O0 7511.~0 7457 ...~ 10200 Oo 758(], t 1 '!525.Sl 4a 10400 O0 77itq,¢7 '/6~4.67 10500~00 7790,ol 7735. 7i 44 lObO0.O0 7~62.1b 7~'.37.U5 4 { 27 10700,00 7934.9~ 7~Slj,n~; 10800.00 8008.51 /954.2:t 11000,00 ~57.45 :~1~.~3, !b ~1 39 11100.00 3232,30 ri 17f4, t)~ gl 21. 11200.00 ~30'1.S2 ,-;253,22 11300.00 8]82,32 ~325,"2 '.1 37 11400.00 ~457.1 3 ,~,d2,63 ,~1 42 11500 0.~ ~531 .a3 6477.!3 11600~() ~605.33 ~-551.u3 q2 20 11700.00 8679,13 ~624.h3 ~i2 11800,00 8752,40 au98.i(~ 4t 4 11900.00 fi~25.33 S 47 14 ;~ 4654,47 8 47 2 V~ 4729,51. fi 46 54 ~ 4803,85 5 46 52 W q878.74 S q6 55 ~ 4954.41 S 47 2 v~ 5030.75 S q7 11 ~ 5108,17 S 47 15 ~ 51M6.55 S .~7 4 ~'~ 5265.~6 S 4~ 59 ~. 5..~44.23 5 'lO 43 v, 5~99,63 a 47 I ~-~ 557t,,28 S 47 3 ~ 5652.33 5 47 ~ ~ 5727.~0 S .[~ 55 ~. 5875.72 5 .ih 5o ~., ~948.84 S -ia 5~ ~ 6021.34 S 47 8 ,.. 6162.90 S ,t7 27 ,'~ 6232.08 b 47 50 ~ n300,58 S 4d 22 ,~ ~368.32 5 48 b'7 ~ ~43b,08 5 40 ~ - 6501,8f' S 49 19 v, o568,1r~ S 49 37 ~, 0634.0o $ ~19 19 , 0700.37 s q9 6 v. ~766.73 S 49 lb ~ o8t],65 & aR 54 ~ 6901.00 S q~ 38 ~ 6968,48 & ,~ 3! v: 7036.52 S a~ ]8 ~, 7104.95 DEPARTURE AZIMUTH PEG 0,35 0,55 0,23 0,46 0,40 o,53 0,88 o, 82 o,56 2900,26 S 3141,38 ~ 4275 2952.9'/ S 3197,74 h 4]52 3005,55 S 3253,96 ~ 4429 3057,8! 6 3309,97 h 4506 3109,78 $ 3365'85 ~ 4582 3161,3~ S ~421'39 W 4658 ~212,45 6 3476,47 ~ 4733 3263,22 S 3530,86 W 4807 3314,50 S 3585,57 W 4882 3366,28 $ 3640'86 49 S 47 17 W 65 $47 ~6 W $ 4716 W $ 47 16 W 54 $ 47 15 W $ 47 15 W $ 47 15 W 87 S 47 ~5 W 85 S 47 14 W 4958,60 S 47 ~4 W 1.15 1.04 1.04 0.70 0.36 0,50 0.75 0,60 0,72 1,24 3418,39 S 3696 75 W 5035,01 $ 47 14 W 3471,15 S 3753:52 ~ 5112,51 S 47 14 W 3524,41S 3811 12 W 5190,96 $ 47 14 N 3578,25 S 3859 17 ~ 5270 14 S 47 ~4 W 3631 85 S 3926 72 w 5348 78 $ 47 14 W 3685 16 S 3983 81 . 5426 89 $ 47 13 W 3738 17 S 4040 30 ~ 5504 36 $ 47 13 W 3790 68 S 4096 27 W 5581 lO $ 47 13 W 3842 52 S 4152,02 ~ 5657,23 $ 47 ~3 W 3893 80 S 4207,21 W 5.732,56 S 47 12 W 0,29 0,71 0 20 1~40 0,86 0.7b 0,73 0,48 0,77 1,21 3944 42 S 4261 72 W 5806,95 S 47 12 W 3994 81S 4315:75 W 5880,83 S 47 12 W 4044 77 S 4359,24 ~ 5954,02 S 47 12 W 4143 11S 4474,32 ~ 6097 94 S ~I 12 W 41.91 06 S 4525,83 W 6168:31 $~. 11W 4238,03 $ 4576,70 W 6237,55 S 47 12 W 42~4.1~ a 4627,42 ~ 6306,09 $ 47 12 W 4329.40 6 4677.83 ~ 6373.84 $ 47 12 W 437],47 S 4727,99 ~ 6440.58 $ 47 Il W 0,34 0,26 0,82 0,29 0,67 0,40 0,44 0,52 0,23 0,27 4417.18 S 4778 41 w 6507,28 S 47 14 W 4460 42 $ 4828:67 , 6573,54 S 47 16 W 4503 25 S 4878,75 , 6639,38 $ 47 17 W 4546 35 $ 4929,22 w 6705,71 $ 47 18 W 4589 71S 4979,46 ~ 6772 04 $ 47 19 W 4633 51S 5030,06 ~ 6838:93 S 47 20 W 4677 5b S 5081,02 W 6906,25 $ 47 22 W 4722,10 S 5131,71 ~ 6973,72 S 47 22 W 4767,11S 5182,76 W 7041,75 S 47 23 W 4812,38 S 5234,07 W 7110,17 S 47 24 W [)ATE OF ~URVE¥= 19-0CT-87 · HU$flll~G E~EVATIONI 54.30 FT ENGINgBR~ $, SALAZAR ' I!~TE;RPOLATk't) ~Al,~iJ~li; i;'(.',~l.t F'vSh lO0 FEET OF aEASURE}3 DEPTH VF;RTtCA!, [>(}G[,EG RECTANGULAR COORDINATES HORIZ, DEPARTURE 5EC']'!~'., ~:VE[~.ITY i~URTH/SOOTH ~:AST/~E6T DIST, AZIMUTH FI.'~:T okG/1 O0 FEET ~'EET FEET DEG MIN I 2(!00.00 ~j F 9 d.i.~4. 68~,3.75 43 28 1.2]00.00 897(~.5~ i~916.2~, 43 30 12150. (',(~ 900~,.,, ~5 8952.55 43 30 S 41~ 4.:i ~ 7242.4.1 O, O0 0 '. iii 0 4t~57,75 5 521~5 59 ~ 7178,80 S 47 24 W 4903,15 S,,.. 5337i33 ~ 7247.61 S ~ 25 W 4925,85 5 5363 20 ~ 7282.0~ S 26 W STAI',~bARD ALASKA PR(.i~i)I, iC~I'I!]i, CO, R'-13 t-,!ORT},,~ ,.%LOPE~ At,,A.,,SKA C(.t!'4Pt.iTr~'!'IL~',: [)ATE: 26-0CT-87 PAG£ 5 DATE OF ~URVEYI 19'0CT~87 KEbG¥ BUSHING EGEVAT~ON~ 54,30 FT ENGiNEERI $, SALAZAE ' IhTERPOLATEP V$~i,uES [,'(~R ffVgi',~ 1000 FEET OF MEASUREO DEPTH I";EASI.,~RED 'VERI'ICAL YERTI, CAL DEVIA'r,[(~i~ A2,1~tkiTH DEPTH DEPTH DEBTd DEG ~I~',i [)fg{; ~I~, 0 00 ¢} OO -,54.30 0 .1000: o(? 99~:.~ 945.09 0 !4 2000.00 1997.01 i942,71 i1 54 3000,o0 2653.5.-~ ~'/Q9.24 46 23 40(]0. O0 3523.2('~ 346~. 90 48 46 5000.0;) ~184.73 413i,;. 43 48 13 bO0().O0 4~5~1.5b 480b.2b 47 5q ~~TflOC'(O{' 5523,31 5.q6g.O~ 4g ~9 .00(;, .o b'lS~,gb bl.~'.)4,ob b0 40 ~flO00C, 66Uq 31 6'155 ~I 50 19 VER'i'tCAL [.~()G[.,k:G RECTANGUI..,AR CODROINATES HORIZ, DEPARTURE 5ECTI. I~ bEq~;RiTY ~ORTH/SOUTh EAS%'/~E~T DI~T, AZIMUTH FEtT DEG/IO0 FEET FEET FEET PEG ~ ~7 5 ~ 5~01,92 S q~ 43 ~ 7173.5N b 48 43 ~ 't27b,~2 0,00 0,17 3,81 4,31 O'gl 1,20 2,20 O,6b 0,35 1,15 0,00 N 0,00 E 0 O0 N 0 0 E 3,07 S 1,55 E 3:43 S 26 43 E 22"65 $ 42,65 ~ 48 29 $ 62 I W 885.28 $ 913,17 w 1271 85 1366,01 $ 1488,26 ~ 2020 13 S ) 18b0,23 $ 2016,83 W 2757 33 $ 47 0 W 2373.0q $ 2577,57 w 3503 60 $ 47 21W 2900,2~ $ 3141,38 ~ 4275 49 $ 47 17 W 3418,39 5 369~,75 ~ 5035 O1 $ 47 14 W 0.29 0.3q 0,44 0,00 3944,q2 5 4261,72 ~ 5806,95 S 47 12 W 4417,18 5 4778 ~1 ~ 6507,28 $ 47 14 W 4857'75 S 5285:59 w 7178,80 $ 47 24 W ~925,85 $ 5363'20 W 7282,03 $ 47 26 W 0. C (,', 0 54.30 54,3U 1,54.3U 254.3u 254,30 20 354. '3C, 454.30 454.3u 4u 554. ~() 554.3~ 50 654 3C 654,3C, (~0 754: 3(> 754.3u 7(.) 854.31 954.3! 9b<:i . 30 '90 1054 3t 1054.3~ 1. t;d 1 i 54 ~ 31 t 1254,31 125*.~t.~ 120 1354.32 i35.1.. 36 I30 1454.36 !554.5. a ] 654.77 1.754.95 1754. 3U 17U S [.,: ,.k C (; u r;' S f: V ~: i,< 'r I C ICAI.~ DgVl PTii BEG 195t.47 2058. ~(~ 2162,75 2268, B2 2254 2377.70 26o7 I9 2b5~.30 2730:79 2862.03 3001,] 1 2~54 3149.33 295:! 3298,2b 3O54 3445,89 3154 3594.23 325,, 3744.96 3354 3895.6u 3454 4047.2~ 3554 4199 54 3654 4351~8~ 4504,~4 3854 , ½ <, , 30 . .] 0 25 10 <, 51 qb 4 () 2~ 1 (). -t), {; . t) , O, (1 . (", . 0 , 0, 3. :5, bU. 123. le. 5. 216. 27(~. ~.'~1 . 627, 637. 747. ~55. 965. 1078. 1190. 1304. 1419. 1534. 1649. IOU t:'Ei!:T Of~ SUb-SEA DEPTH Al., [,:.,GL, r.:(; 0~, ~,gV E,~ IT Y: I' bEG/10U f'EET <)0 O.00 O,OU bi OL,' "),04 0 O0 N U.3 0.I3 /),00 N 05 o,nB (),19 S [2 0,o7 0,47 ~ 21 0.02 (),84 S ~1 0,03 1,21 S 50 O.OO 2,08 S 71 0.27 2,52 $ 76 0,20 2.88 M2 i:),99 3,24 a4 0.20 3,5q ~b O,dl 3.61 5~ 0.~1 3'32 41 0.65 (),62 ~t! 2.51 1.31 ~)9 2.61 0,13 14 3.2~ 5,74 b5 3,32 16.38 S 24 3.38 32 63 S 24 3.42 53~86 S 17 3.64 80,30 S 76 3,b8 112,47 S 51 3,5b 151,07 S 55 3.83 197.36 S U2 4.37 253 23 S 70 4.23 388,80 S 02 1,01 462,85 S 2q 0.29 537,16 S 8R 0,72 609.62 S 40 0.35 683.09 S i~ 0,76 758,90 S 71 0.50 833,5~ S 77 0,15 908.77 S 59 0.12 984.76 S 46 0,39 lO6Oe7O S 43 0,50 1136,11 S DATE OF SURVEY~ BUSHING EbEVATION: ENGINEER~ PAGE 6 19-0CT-87 54,30 rX $, 5ALAZAR ' CU(]~[)INATE$ HORIZ, DEPARTURE EAS1/WEST UlST, AZIMUTN FE~T FEET DEG MIN 0.00 E 0,00 0,00 E 0,00 0,03 E 0,03 0,09 E 0,21 0,24 E 0,53 0,43 E 0,94 0,63 E 1,37 0,81 E 1,84 1,00 E 1,22 E 2,80 1,44 E 3,22 1,68 E 3,65 1.90 E 4,02 1,95 E 4,10 0.75 E 3,40 1,99 ~ 3,24 7,89 W 7,91 14,09 ~ 14,15 19,70 w 19,70 26,81 ~ 27,41 4O 53 bO 83 88 35 123 17 165 89 216 97 277 57 349,92 434,75 531,27 37,08 51,34 70,03 93,39 121.94 155.74 195,18 241,49 296,08 362.05 442,57 W 640,39 524,14 W 750,51 605,06 W 858,92 6~6,34 W 968,34 7~9.86 W 108~,0~ 854.18 ~ 1193'52 939,91 W 1307,40 1026.01 ~ 1422,13 1112.23 ~ 1536,92 1199,02 W 1651,78 N 0 0 E N 75 57 E N 80 ~2 E S 26 7 E $ 26 44 E S27 14E S 27 20 E $ 26 0 E $ 25 39 E $ 25 47 E S 26 40 E $ 27 27 E S 28 18 E S 2ti 21 E S 57 W S 85 28 W N 84 41 W S 89 36 W S 77 54 W 866 9 W S 57 33 W S 52 26 W S 49 18 W S 47 18 W S 45 52 W S 44 40 W S 43 38 W S 42 55 w S 42 57 W $ 43 43 W S 44 17 W S 44 47 W S 45 8 W S 45 24 W S 45 41 W S 45 57 W 846 IOW S 46 21W S 46 32 W ~AG£ 7 STANDARD AL~F, KA PR[iDbCTIOF~ CFI, K-13 KEbLY BUSHING EbEVATION= 54,30 FT I?~TERPOL. ATEi) ~vALUES t/[;R ~Vi-i~ Io0 t"EET 0[": SUB-SEA DEPTH TR{iE 5Ut3-Sk:a COURSE b'iEAb'UP, 1P~D VP;F::'I'ICAi, VEkFICAL I)EVIATIOi'~ AZI~i. iTH DEPTH I')EPTq [~EPTH DEG ala bFG iql~,J VERTICAL bL.)GL~E(; R£CTANGULAR COORDINATES HORIZ, DEPARTURE SEC'J.'I{.~ SEVERITY NORTH/SOUTH EAST/WEST DIST, AZimUTH F~E:.[' D~':(;/1 O0 FEET FEET FEET DEG NIN S 51 12 ~ 1763.5] S 52 19 ~ 1879.6a 5 57 2~ ~ 19~'{5.01 $ 44 10 ~ 2203.09 5 44 6 ~ '~311.9a S 44 37 ~ 2421.7!. 5 45 15 ~ $ 48 3 ~ 2'74~,69 1..51 0,61 0,77 5,1~ 0,90 0.44 0.39 1,55 0.55 2,26 1209.65 S 1280.26 ~ 1705 1278~27 $ 1373,79 ~ 18 76 1345,40 $ 1461,56 W 1986 14~4,95 S 1548,6! ~ 2097 1490,33 5 1624,57 W 2204 1568,96 $ 1700,64 W 2313 16~7,52 $ 1777,87 ~ 2423 1726,20 5 1855,94 ~ ~534 1801,65 5 1933,05 ~ 2642 1876,34 S 2012,50 W 2751 71 S 46 45 W 50 S 4~ 3 W 52 $ 4 22 W 68 S 4734 W 61 $ 47 28 W 83 S 47 18 W 87 8 47 10 W 62 S 47 4 W 47 S 47 0 W 51 S 47 0 W 6141, bO 4954.3u ~ 900,00 .i a 5 6291 49 505.t..3O 5uVO,u9 4i~ 29 644.4])~ 5154'3v hl~:~O.O<', 4~ 29 6596 51 525~.3~.; 52C~(.).0C <t7 53 6894.45 5~54.,)t) 5400.0,~ 4~ 21 704R.15 5::54. lO 5b<)~,,O~O 40 h6 7361~62 575a. ~{~ 57<,~). 0~ 50 54 O. 39 1.63 0.91 5,10 1,73 0,22 1,18 O. 22 0,24 1948,7~ S 2096,79 W 2862,55 S 47 5 W 2020,4~ S 21~2 27 W 2973,99 S 47 12 W 2091.18 $ 2273175 ~ 3089,17 S 47 ~3 W 2160 46 5 2365,08 W 320~,30 S 4735 W 2236~75 $ 2444.02 ~ 331~,05 S 47 32 W 231~.82 $ 2520,86 ~ 3423,79 $ 47 24 W 2398.70 S 2604,01 W 3540,43 S 47 21 W 24~1,19 $ 2689.78 w 3659 40 S 47 18 W 2564.59 $ 2779,33 W 3781:77 S 47 18 W 2648,12 S 2869,71 W 3904,84 $ 47 17 W 0.06 u,36 0.85 0,27 0,73 0.54 0,61 0.85 0.50 2730.99 S 2959,06 ~ 4026 70 S 47 17 w 2813.41 $ 3047,95 ~ 4147:92 $ 47 17 W 2896,36 S 3137,21 ~ 4269 78 $ 47 17 W 2979,25 5 3225,84 W 4391 13 S 47 16 W 3060.73 S 3313 11 ~ 4510 52 S 47 16 W 31~0,79 $ 3399116 ~ 4628 05 $ 47 15 W .) 3218,38 S 3482,84 W 4762 17 $ 47 15 W 3294,82 ~ 3564 57 W 4854 07 $ 47 ~5 W 3373,85 $ 3648:95 W 4969,68 S 47 14 W 3455,84 $ 3737 00' W 5089,99 S 47 14 W 9232,3b 695:,. 3ti {,90,,, OC 5?. 21 9395,0_9. 7{154.30 7 t.; (; r~. 0 :", 51 t3 9554.8i) 7154.3.~ 71 u(),~):~ 59 43 9711,15 '125't..{u '/200.OL~ 4'~ 53 9864.48 736~.30 730u..,0 q~ q7 10014,50 7454. ~o '7400.~,(, ~i'l 49 10162.29 7551~. 30 75<~ ('.'. L,{~ ,lb 5V 10307.79 765.'.. 30 7~u(,. <)5> ,i5 53 10449.94 775q, ~0 770(,.~:0 .~4 4a 10589.19 7854,3(~ 780U.Ut: 43 31 '~ .7 It ,, 5212.12 b 4~ 59 ~ 5340.39 5 c'7 3 ~ 5584.82 g 47 7 ~ ~70u.93 ~ ~'7 4 ~ 5~1.2,6~ b ~6 58 ~ 5921,3~ 5 46 54 ~:, 6026.94 £ q7 3 ~ 6127.~h $ %7 23 v- 6224.66 0,50 0,42 0,82 0,85 0,57 0,35 1,36 1,05 0,87 3541,7a S 3829.91 W 5216 55 S 47 14 W 3629,23 $ 3923 91 ~ 5344 94 S 47 14 W 3714,27 S 4014:88 w 5469 47 S 47 ~3 W 3796,50 S 4102'53 w 5589 64 S 47 ~3 W 3875 64 S 4187,65 ~ 5705 87 S 47 ~2 W 3951:74 $ 4269,59 * 5817 70 S 47 12 W 4025,99 S 4349,13 ~ 5926 51 $ 47 12 W 4098,15 $ 4426,37 W 6032,2~ S 47 ~ W 4157,17 $ 4500,15 W 6133,24 S 47 1~ W 4233,00 S 4571,23 W 62~0,13 S 47 ~ W PAGE 8 DATE OF $1JRYEY{ 19-,0(~T-87 KE66~ BUSHING ELEVATION~ 54,30 FT rCEASU}'<F!'> VP'.RT[CA[~, ~}<RTICAL [)EVlAT[rJ~ AZIi'4I,'I'[I V!i;V,'I?ICAI.., i.)~;IGa&G RECTANGUI,AR COORDINATES HOR1Z, DEPARTURE 5~.:C'}'I(,:,: 5f,;VERIT¥ [~OR'i'H/SOUTH EAST/WEST DIST, AZIMUTH ~"~:'i' DEG/lOO FEET FEET FEET DEG 8IH 1.91 O, 37 0.44 0.45 0,54 O, 22 4~96,25 8 4640,88 ~ 6324,20 $ 47 12 w q356.69 8 4708,77 ~ 6415,08 S 47 13 W 4415.35 S 4776.30 ~ 6504,48 5 47 14 w 4588,0o 8 4977,55 W 6769~52 $.- 19 W 4647.07 8 5045,83 h 6859,72 $ 47 21W 4707.0! S 5114,60 w 6950,9! $ 47 Z~ W 4768,2~ 6 5184,08 ~ 704~,52 $ 47 ~ W 48~0,43 $ 5254,58 ~ 7157,48 $ 47~4 W 12077.55 h95a.3U ~ 90(~. ',,~ 43 30 12150.00 9t>(,6. ~5 c~952. Db 4,3 30 & 48 43 ,': 7220.96 8 48 43 .~: "1276.~ .0,00 4892 90 $ 5325,7! ~ 492b~Ub $ 5303,20 ~ 7232,17 $ 47 25 W 7282,03 S 47 26 W This is to acknowled~_ receipt of the following prints and negatives. COMPANY: STATE OF ALASKA ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA · Z-22 A SBT/GR;CCL 5" }Zq0ol__ ;~~ 0 1 , , SIGNED DATE Please return one copy of signed transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT/RTNCARD1 This is to acknowledge _'eceipt of the following L _nts and negatives. COMPANY: STATE OF ALASKA ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY .,, WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA /B-IS CN/GR ~£~ 5,~ ,000o-- 1~0~O~ 0 1 /B 10 PLS ~,, t910(.7-!~uo7 1 0 1 D-11 PAS %EAK DETECTIO~ 5" 1]0qoo- {°70~ 1 F-39 PFC/G% ~UBING PATCH) 1 1 ~ 5" U ~o -- 7~50 0 G-04 PFC/GR,~ACKER SET REC% 5" 1 J-10 PLS 5~, %t~o~O 1 0 ~ K- 13 GR/CCL Q~) 5'~ ~ O~5o ~; ~O 0 1 K- 13 PLS ~, 1 0 1 R-16 PLS 5" ~[Doo -([q~ 1 0 1 X-2! PLS 5" %0oo-q~lO 1 0 1 SIGNED ~~O_~ ~~(-'~_ DATE ' '"~'~ IgJJ ~ ?r~. ~g,.~. ~'~ Please return one copy of signed transmittal to each of th~owi~'~ Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT~RTNCA3JD1 INDEXED DALLAS ARCO CHEV~OX STANDARD ALASKA PRODUCTION E~'~CON TEXACO Date: 01/26/88 TO: MOBIL T#: 78486 PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing e copy of this letter end returning It to this office: A-12 A-13 B-3B D-3 D-18 D-18 F-8 F-19 H-9i J-28 K-12 K-14 Y-24 COL/Perf. I2/23/87 #1 8100-9230 GO 5" Caliper Tool(Muitifinger) 01/10/88 #2 100-8650 Sch 5" Spinner/Hydro/Temp. on coil tubing 12/17-18/87 #1 9500-11055 Production Profile Cont. Flow Survey Temp. Production Profile CCL/Perf. Injection Profile Production Profile Production Profile Production Profile CCL/Perf. PIT/Flowmeter 01/08/88 #1 10400-10660 Camco 12/27/87 #1 10900-11200 GO 5" 12/27/87 #1 10800-11200 GO 5" 01/16/88 #2 10950-11250 Camco 12/25/87 #1 12200-12830 GO 5" 01/10/88 #1 9500-10000 Camco 01/12/88 #1 10790-11030 Camco 01/08/88 #1 9150-9370 Camco 01/18/88 #1 11800-12100 Camco 12/22/87 #1-4 10950-11730 GO 01/09/88 #1 12828-13450 Camco 11 1) )! 5" 5" 5" 5" 5') GO 5"/2" Received C_"'~ ~'"g ~"""" Victoria /_ ,. ~V/ '"? . mldridge --/--//I _. ~ m~e OilS. ~[[~ttSSL ,~ '" I NFORMAT ION CONTROL A un') gl )he o,,g~l 5)ondo~d ~1 C°~n~ Founded ~n Cle~elo~. ~,o. ,~ 1870 INDEXED DALLAS ARCO CHEV~O~ STANDARD ALASKA PRODUCTION E XLXON TEXACO Oate: 01/06/88 ¥O: MOBIL TI: 78391 PHILLIPS STATE OF ALASKA GEOSC IENCES ~ B-13 ~ ¢-9 '~-~'"~ F-24 R-23 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipY by signing a copy of this letter and returning it ,o this office: CCL/Perf. 11/19/87 #1 10590-10750 GO 5" COL/Perf. 11/21/87 #1 9500-9800 GO 5" CNL/GR 12/28/87 #1 11830-12216 SCH 5" Spinner/TEMP/Hydro on coil tubing 11/21-22/87 #1 9750-10515 GO Plug setting & Tubing Puncher Record CCL/Perf. 11/29/87 Completion Record 12/29/87 X-Y CALIPER 11/26/87 CCL/Perf. 11/19/87 Squeeze Perf. Record 12/23/87 12/30/87 #1 3450-3734 Sch #1 9600-9832 GO 5" #1 10765-11972 Sch 5" #1 10400-11710 GO 5" #1 9500-9900 GO 5" #1 11192-12138 SCH 5" Rece i ved Date .. ~.~ JAN 1'2 !?;,'! ~" ^las~ Oil & ~as Cons. Commissio. Anchorage A un;t ot the o,,g;nol Stondo,d C~l Co,npony Founded ,n Cle-elond. 0~,o. ,n 1870 Victoria Aldridge I NFORHAT I ON CONTROL Wel I Records LR2-1 5" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ll. Type of Request:' Abandon I'1 Suspend [] Operation Shutdown Time extension Ci Change approved program r'l Plugging [] Stimulate 2. 'Name of Operator Standard Alaska Production Company · 'Address , Re-enter suspended well [] Alter casing [] Pull tubing [] Amend order [] Perforate [] Other I'1 P. O. Box 196612~ Anchorage~ Alaska 99519-6612 4. Location of well at surface 1804'SN1., 4137' WEL, Sec. 4, T11N, R14E At top of productive interval 1095' SNL, 3814' WEL, Sec. 8, T11N, RI4E At effective depth 1430' SNL, 4198' WEL, Sec. 8, T11N, R14E At total depth 1450' SNL, 4220' WEL, Sec. 8, T11N, R14E 1. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 2771' 11171' 1186' measured true vertical Tubing (size, grade and measured depth) 12150' feet 9007' feet 12107' feet 8976 feet Size Plugs (measured) Junk (measured) 20" 13-3/8" 9-5/8" 3900 cuft Arctic Set II 2325 cuft Class G 7" 365 cuft Class G 3-1/'2" 9.3tt @ 10877' MD Packers and SSSV (type and measured depth) T.I.W. 10892' MD SSSV @ 2000' MD 5. Datum elevation (DF or KB) KBE , 54.30 feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number K-13(11-8-11-14) 8. Permit number 87-101 9. APl number 5 0 - 029-71757 0. Pool Prudhoe 0il Pool Measured depth 110' 2806' 11200' 12150' True Vertical depth 110' 2700' 8308' 9007' RECEIVED NOV'2 :~ !.987 Alaska Oil & Gas Cons. Commisslo~ Anchorage 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 4th Quarter 1987 4. If proposal was verbally approved Name of approver Date approved 5. I her(jby ~certify p~,~tAhe ~gis true and correct to the best of my knowledge Signed:~<~ (~.~:~, ~-~-' Title D/vision Ddllincj En(]ineer Commission Use Only Notify commission so representative may witness IApproval [] Plug integrity [] BOP Test [] Location clearance I No. Conditions of approval Approved by ORIGINAL SIGNED BY LONNtE C. SMITH Approved Copy .Returned Commissioner by order of the commission Date Submit in tripli(~att Form 10-403 Rev 12-1-85 PBUWELL K-!3 Permit Numbers 87-101 Approval Dates 9/30/87 Well Status Well operations were shut down after running 3-1/2" tubing, nippling down BOPE, and installing the tree. A DIL/BHCS/CNL has been run in the 8-1/2" ho1% CCL/GR/CBT/VDL logs were run across the 7" llner, and a gyroscopic survey has been run from PBTD to surface. The 13-3/8" x 9-5/8" annulus has been downsqueezed with cement and filled with non-freezing fluid. ~emaining Drilling _Operations The well will be completed by perforating underbalanced with wlreline conveyed guns. Perforations to be consistent to current development strategy. Flow well for simple cleanup. Install sub surface safety valve in ball valve nipple. R£CEIVC,.I) NOV 2 Rlaska Oil & Gas Cons. Commissio, Anchom!]~ MAW/kb/2222D STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDHOE BAY October 1, 1987 at 0600 hfs AFE # 120595 Current Operation: ~ Depth: 510' Day: - 1 24-Hour Ftg: 420' Water Used: Drilling. Accepted rig at 2000 hfs on 9/30/87. Spud K-13 at 0230 hrs on 10/1/87. Drilling at 510'. Mud Type: Spud WT: 8.6 VIS: 280 PV: 16 YP: 55 FL: 14 Solids: 2 Temp: 40°F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDHOE BAY October 2, 1987 at 0600 hfs AFE # 120595 Current Operation: 0600 Depth: 1648' Day: 1 24-Hour Ftg: 1138' Water Used: Jetting and Drilling. Drilling 17-1/2" hole at 1648'. MudType: Spud WT: 8.6 VIS: 280 PV: 16 YP: 55 FL: 14 Solids: 2 Temp: 40°F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDII()E BAY October 3, 1987 at 0600 hfs AFE # 120595 Current Operation: 0600 Depth: 5143' Day: 4 72-Hour Ftg: 2833' Water Used: 4 I00 Dyna-Drilling. Drill to 2810'. Ran 13-3/8" casing and cemented with 4194 sks Arcticset II. Drilled 12-1/4" hole to 5028'. Dyna-Drilling at 5143'. Mud Type: Low WT: 9.2+ VIS: 34 Solids PV: 7 YP: 6 FL: 12.5 Solids: 6.5 Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDIlOE BAY October 6, 1987 at 0600 hfs AFE # 120595 Current Operation: 0600 Depth: 6555' Day: 5 24-Hour Ftg: 1412' Water Used: 1750 POH. Dyna-Drill 12-1/4" hole to 5207'. Drill to 6555'. Tripping. Mud Type: Low WT: 9.2+ VIS: 35 Solids PV: 7 YP: 8 FL: 14.5 Solids: 6.5 Temp: 74°F Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDItOE BAY October 7, 1987 at 0600 hfs AFE # 120595 STANDARD ALASKA PRODUCTION Current Operation: 0600 Depth: 714 8' Day: 6 24-Hour Ftg: 593' Water Used: 1225 Drilling. Dyna-Drill 12-1/4" hole to 6724'. Drilling to 7148'. Mud Type: Disp WT: 9.3 VIS: 35 PV: 6 YP: 6 FL: 10.6 Solids: 7 Temp: 7 I°F STANDARD ALASKA PRODUCTION Rig: Nabors 18t5 Well' K-13 Daily Drilling Report -- PRUDIIOE BAY October 8, 1987 at 0600 hfs AFE # 120595 Current Operation: 0600 Depth' 7945' Day: 7 24-Hour Ftg: 797' Water Used: 1225 POH. Drill 12-1/4" hole to 7945'. Mud Type: Gel WT: 9.3 VIS: 34 PV: 5 YP: 4 FL: 9 Solids: 7 Temp: 78°F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDIIOE BAY October 9, 1987 at 0600 hfs AFE # 120595 Current Operation: 0600 Depth: 8650' Day: 8 24-Hour Ftg' 705' Water Used: 1050' Drilling. Drill 12-1/4" hole to 8650'. Mud Type: Gel WT: 9.5 VIS: 35 PV: 6 YP: 6 FL: 7.2 Solids: 8.5 Temp: 81°F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDHOE BAY October 12, 1987 at 0600 hrs AFE # 120595 Current Operation: 0600 Depth: 10926' Day: 11 72-Hour Ftg: 2276' Water Used: 4550 POH. Drill 12-1/4" hole to 10926'. Mud Type: Gel WT: 9.7 VIS: 34 PV: 7 YP: 5 FL: 7.8 Solids: 9.5 Temp: 92°F Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDIIOE BAY October 13, 1987 at 0600 hrs AFE # 120595 STANDARD ALASKA PRODUCTION Current Operation: 0600 Depth: 11,207' Day: 12 24-Hour Ftg: 281' Water Used: 1225 Run 9-5/8" casing. Drill to 12-1/4" TD at 11,207'. Running 9-5/8" casing. Mud Type: Gel WT: 9.8 VIS: 36 PV: 8 YP: 7 FL: 7.4 Solids: 10 Temp: 93°F SURVEy ]VID 53 11136 ANGLE DIREqrFIQN TVD SECTION 41.5 S49.8W 8241 6610 COORDrNATE$ D~ S4479 W4875 0.54 Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDHOE BAY October 14, 1987 at 0600 hrs AFE # 120595 STANDARD ALASKA PRODUC-i-ION Current Operation: 0600 Depth: 11,207' Day: 13 24-Hour Ftg: ' Water Used: RIH with 8-1/2" BHA. Ran 9-5/8" casing and cement. RIH to clean out cement. Mud Type: Gel WT: 9.8 VIS: 35 PV: 8 YP: 7 FL: 7.6 Solids: 10 Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDHOE BAY October 15, 1987 at 0600 hrs AFE # 120595 Current Operation: 0600 Depth: 11,835' Day: 14 24-Hour Ftg: 628' Water Used: 1050 Drilling. Drill cement and float shoe. Drill 8-1/2" hole to 11,835'. Mud Type: Gel WT: 8.9+ VIS: 32 PV: 3 YP: 4 FL: 12.5 Solids: 4.5 Temp: 89°F Rig: Nabors 18E Well: K-13 Daily Drilling Report -- PRUDHOE BAY October 16, 1987 at 0600 hrs AFE # 120595 STANDARD ALASKA PRODUCTION 0600 Depth: 12,150' Day: 15 24-Hour Ftg: 315' Water Used: 1050 Current Operation: R/U for logs. Drill to TD of 12,150'. POH and RAJ for logs. Mud Type: LowSol WT: 8.9+ VIS: 33 PV: 3 YP: 4 FL: 13 Solids: 4.5 Temp: 92°F Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDItOE BAY October 19, 1987 at 0600 hfs AFE # 120595 STANDARD ALASKA PRODUCTION Current Operation: 0600 Depth: 12,107' PBTD Day: 18 72-Hour Ftg: ' Water Used: 2715 Logging. Clean out liner to 12,107'. Test liner, lap and 9-5/8" to 3000 psi. R/U to mn logs. Mud Type: NaC1 WT: 9.6 VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDHOE BAY October 20, 1987 at 0600 hrs AFE # 120595 Current Operation: 0600 Depth: 12,107' PBTD Day: 19 24-Hour Ftg: ' Water Used: 175 Install x-mas nee. Finish cased hole logs. Run 3-1/2" robing. Mud Type: NaC1 WT: 9.6 VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: K- 13 Daily Drilling Report -- PRUDHOE BAY October 21, 1987 at 0600 hrs AFE # 120595 Ctm'ent Operation: 0600 Depth: 12,107' PBTD Day: 20 24-Hour Ftg: ' Water Used: Released rig from well'@ 1200 hours on 10/20/87. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: °F I NDE XE [] DALLAS ARCO C}tEVRON EXXON TEXACO Fb\RATtION STANDARD /\l 1\" Dote: 10/30/87 78281 HOBIL PItlLLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC OPEN HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning It to thls office: DAL / UN IT / STAT E: K-13 DIL 10/16/87 #1 11201-12148 GO 5" & 2" K-13 BtICS 10/16/87 //1 11201-12118 GO 5" & 2" K-13 CNL-poro 10/16/87 //I 11201-12107 GO 5" & 2" K-13 Laserlog , 10/16/87 11199-12050 GO 5" STATE ONLY: DIRECTIONAI. SURVEYS Magnetic Single Shot Directional Survey Date: Gyroscopic Directional Survey Date' Job//: Job/J · Recelved Date Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 A un;! Of ~'he o*';g;nol ~,tondo,d 0~,1 Compony Founded ,. Cle,,elond. Ofl,o. ,n 1870 P~oductJon Compa~ 900 Eosl Ben,on Boulevu,d P.O Bo, 196612 Anchorage. AIo,,I,o 99519-66 {907l 564.5111 DALLAS ARCO CHEVRON E X_XON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES INDEXED STANDARD AL ASKA PRODIJC'I'ION Dote: 10/26/87 .TI: 78273 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng o copy of this letter and returning it to this office: ~E-28 ~ E-28 ~'--E-28 '"' J-2 -'~ K-13 CBT 10/17/87 #1 9000-12430 Sch 5" CET 10/17/87 #1 9000-12430 Sch 5" GR/CCL 10/19/87 #2 8840-10775 Sch 5" Perf. Record 10/18/87 #2 9100-10274 Sch 5" CBT 10/19/87 #1 10980-12096 Sch 5" Rece, ved .... Victoria' ~ ~C A]d~d~e Date Wel I Records LR2-1 Stondord P~oduchon 900 Eos* Benson BcI P O Bo,~ 196612 Ar',(ho~oge. Alosko 99.519.6612 (907! 564-51 ! I ARCO STANDARD AI_ASKA PR(~[)/JCl EXXON Date: 10/21/87 PHILLIPS IO: ~: 78248 STATE OF AK PDBY Systems (Transmittal Only) SYSTEMS (Transmittal & Tape) ARCHIVES SAPC MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: K-13 OH 10/16/87 Job J/373666 GO Tape Pos. J/05419 * EY~XON' An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. PA1 ea_s e_ Aldridge I/ Date ~lask~ 0ii & ~as uo · ~ell R~ords ~2-~ founded ,. Cle~elond. ~,o ,,, MEMORAN DdM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith .j~ DATE: October 21 1987 Commlsslo~er &~-- mUENO: D.ADA.39 TELEPHONE NO: T.RU: Michael T Minder ~../,z~/, SUBJECT: Sr Petroleum Engineer BOP Test SA_PC K-13 Permit No. 87-101 Prudhoe Oil Pool FROM: Doug Amos~ Petroleum Inspector SaturdaM, October 3, 1987: After witnessing the mechanical integrity ~est at '~co~ PBU' I-~'EA~led to Standard Alaska Production Company's K-13 well to witness the BOP test. The testing commenced at 10:00 p.m. and was concluded at 11:30 p.m. There were two failures. I filled out an AOGCC BOP test report which is attached. In summary, i witnessed the BOP test at SAPC K-13 well. Attachment 02-001A (Rev. 8/85) .5/84 ' -"~"~':': .... ! sr".,_ [o,.oo e ~ ' ..... STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COI~tlSSION B.O.P.E. Inspection Report Date t)~T", '~) I '~ ~ notation: Sec ~ ~ ~l~ i~ ~, ~' ]5~/~'~asinz Set a ~boG Drilling. Contractor ~A~~ Ri .~ ~ Representative ~. Location, General. ~ ~ell Sign(o~ ACC~ATOR SgST~ . General Housekeeping 0~ Rig ~ ' Full Charge Pressure ~OO pair Reserve Pi} 0 ~ Pressure After Closure ~ ~O ~ psig ,,, . . Mud Systems Visual Audio Pump incr. clos. pres. 200 psi& mi~ ~sec. Trip Tank ,~,~'~ ~ Full Charge Pressure Attained: ~ min ~.~ sec. Pit Gauge ~,, ~ N2 ~I. 9~;~OG/ ZZ~,~Z~ ~ psig ,.~ - ~ , , , ~ ~ Flo~ Honitor O ~, ~.~. Controls: Haster Gas Detectors _ 5~ ;~ Remote ~ B!inds switch cover Kelly and Floor Safety Valves so~ Sta,c~ ~est ~ressure uvver ~enr, ~ ~est ~ressur~ .... . ~nuiar Preventer ~{ ~) ~OO Lower Kelly I ~Test Pressure Pipe Rams ~ ~k~ 2 ~ )~ Ball Type ] ~ Test Pressure Blind Rams ~ ], ~I Inside BOP ~ --~Test' Pressure " Choke Line Valves ~Za ', Choke Manifold { ~est Pressure H.C.K. Valve W [ ~ No. Valves ~ , , . , Kill Line Valves ~ ~ No. flanges ~ Check Valve . ~. ~ Adjustable Chokes ~ Hvdrauicall, choke Test Results: Failures ~ Test T~e I hrs. Repair or Replacement of failed, equipment to be made within~ ~ days and Inspector/ Co~ission office notified. ~ ' , . ~ ' , ..... ,... Distribution orig. - AO&GCC cc - Operator '-~ (~.~_^nL cc - Supervisor Inspector, ~0\~~-~---~------- September 30, 1987 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit K- 13 Standard Alaska~ Production Company Permit No. 87-101 Sur. Loc. 1804'SNL, 4137'WEL, Sec. 4, TllN, R14E, Btmhole Loc. 845'SNL, 4525'WEL, Sec. 8, TllN, R14E, Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of'rthe Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours priQr to commencing equipment installation so that the Co~mmission may witness testing before drilling below the shoe of the conductor pipe. Ver~ truly ypurs, L. C. Smith Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI, JR~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ~ l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ~v Re-Entry [] DeepenF'II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company KBE = 56 feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 28304 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1804' SNL, 4137' TEL, Sec. 4, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 750' SNL, 4400' TEL, Sec. 8, T11N, R14E K-13 (11-08-11-14) KOO683449-G-14 At total depth 9. Approximate spud date Amount 845' SNL, 4525' TEL, Sec. 8, T11N, R14E October 1, 1987 $200,000. 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) 3roperty line ADL28303 ,/.,f. O0 feet SurfaceK2-A 35 feet 2469 11864'MD/8986'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) Kickott cleptl3 1200 feet Maximum hole an~lle45.9 o Maximum surface ,.~300 pslg At total depth (TVD) 8800 4390 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Conductor 80' Surface 110' 110' 8 cu. yds. concrete 17-1/2" 13-3/8" 72# L-80 Butt. 1985' Surface 2015' 2000' 17-1/2" 13-3/8" 72# S-95 Butt. 794' 2015' 2000' 2809' 2680' 3900 cu. ft. Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 5384' Surface 5414' 4500' 12-1/4" 9-5/8" 47# L-80 Butt. 5466' 5414' 4500' 10880' 8302' 2325 cu. fl. Class G 8-1/2" 7" 26# L-80 IJ4S 1234' 10630' 8128' 11864' 8986' 337cu. fl. 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~ ¢: p !:: ~~ertical depth Structural Conductor ' Surface SF-P 2 Intermediate Production ~as~ 0il & Gas Cons. C0mmissl01t L i ne r Anchorage Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drillin~l fluid pro~lram [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify that the foregoing is true and correct to the best of my knowledge Si~lned ~ - ~ ~ Title Division Orillinc~ En(Tineer Date e ? Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~-/-)~1 150-,¢,z,~-Z~7.57 I 09/30/87 Ifor other requirements Conditions of approval Samples required [] Yes El'No Mud Icg required [] Yes I~i--NO Hydrogen sulfide measures [] Yes l~"'No Directiona,~survey required I~l"Yes [] No Other:Required working pres~ BOPE//~ ~'/ ~ ~ ~ .,~I-13M; ,I~5M; I-I10M; I-I15M; by order of Approved by ~i ~ ~ -.,.,~..]~..,_..~_~v~ Commissioner the commission Date Form 10,401 Rev. l~t 4; Submit in [ PROPOSED DRILLING A~ COMPL~ION PROGRAM WELL K-13 [ 11- 8-11-14 ] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-9.7 ppg water base mud in the 12-1/4" hole and a 9.0 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 2809' and cement 13 3/8" L-80/S-95 Buttress casing to surface. ' ,, Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDSs. Directionally drill 12 1/4" hole to the 9-5/8" casing point ~ove the Sadlerochit Sandstone. Run 9 5/8" 47# [,-80 ~d. xed string of Buttress and NSCC to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreezing fluid. Directionall¥ drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaC1 completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production ~acker on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. The well will be perforated in accordance with normal practices. Tubing Size: 3 1/2", 9.3#, L-80, EUE 8RD MOD, IPC WITH 7 GLMS Tailpipe Size: 2 7/8", 6.5#, L-80, MOD 8RD, IPC Note: TOP OF SEABEE SAND: 7975' MD; POSSIBLE ACID STIMULATION ON PERFORATIONS RLB: Il-JUN-87 SEP 2 5 1987 A,l~sk~ 0ii 8, Ges Con~. comml~lolf Anchorage WELL K-13 Ill- 8-11-14~ PBU PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2015 ~,,'8" Casing Shoe 1/'2" Open Hole 2809 2814 3 1/2", 9.3i, L-80, EUE 8RD MOD, IPC WITH 7 GLMS 9 5/8" Packer 7" Tieback Assembly 1058O 10630 9 5/8" Casing Shoe 12 1/4" Hole 10875 10880 7" PBTD 11824 7" Liner Shoe 11864 8 1/2" Open Hole 11864 SEP 2 5 1SB-/ '~as~ Oit & Gas Cons. commissio" §.O.P. STACK CONFIGURATION 13-S/8 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING i ANNULAR PREVENTER ! i I I , PIPE RAMS I I 1 I BLIND RAMS ,1 I l 2 IN. KILL LINE L CHECK H AND H AND DRILLING SPOOL ! PIPE RAMS , I 4 IN. CHOKE LINE GATE GATE _$1$DUAIO' [DRANO13]KI3_CLOSAP_SHORT7~LIS~ i Closest 22-SEP-1987 Approach Analgsis Date- 22-SEP-87 Time' 14'06'35 Search Radius= 200 7 DEGREE LEAD LINE For proposed well' K-I3 [11- 8-11-14] Location = W-E S-N TVD(SBS) Top 671407.00 5975416.00 -56.00 Bottom 666583.13 5970388.12 8860.00 Note' All depths in Ceet Below Kellg Bushing (BKB) 14' 06 Page 1 WELL IDENT Closest Approach /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY\ TVD DEPART A029-2019700 E-5 6741.6 4721.5 7351.6 2538.2 3171.2 A029-2047000 E-17 6115.6 4074.8 6693.6 3825.8 2062.4 4485.3 2390.6 8812.7 5510.5 A029-2057100 E-19 8712.8 6757.8 8183.8 6029.8 928.4 A029-2057600 E-20 8480.4 8517.7 9079.5 3892.3 1713. 1 A029-2078400 E-I4 7316,4 5315.3 7591.4 5385. I 469, I 7100.4 5092.2 7953.8 5676.0 A029-2099800 K-i 1194.8 0.0 1199.9 10.0 176.6 A029-2101100 K-3 894.9 0.0 900.0 1.2 77.2 A029-2101400 K-2A 1485.7 18. I 1491.4 3.9 34. 5 A029-2102300 K-4 1737.6 64.5 1743.3 7.0 133,3 A029-2103800 K-6 2825.5 676.3 2828, I 17.0 195. 5 A029-2104500 K-7 2783.8 636. I 2788.6 3. I 302.2 A029-2140800 K-8 2680.7 542.8 2682.0 8.3 489.7 A0~.-~141800 K-5 3280.0 1145.5 3214.3 809,7 151.4 3180.6 1042.8 2836. S 605.0 VERTICAL DISTANCE 4323. 843. -344. SUMMARY The well which comes closest to the proposed well is' A029-2101400 K-2A Closest approach distance = KICK OFF ~or this run = 34.5 ~eet I200. 0 Ceet _$1$DU~iO: [DRANOI3]KI3_CLOSAP_SHORT. LIS; 1 Search Radius= 200 COURSE LINE For p~oposed well' K-13 [I1- 8-11-14] Location = W-E S-N TVD(SBS) Top 671407.00 5975416.00 -56.00 Bottom 666006.34 5971013.48 8860.00 Note' All depths in ~eet Below Kellg Bushing (BKB) 22-SEP-1987 --- Closest Approach Analgsis --- Date' 22-SEP-87 Time' 14'04'39 14' 05 P~ge Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE Vertical /PROPOSED\ TVD DEPART A029-2019700 E-5 6741.6 4721.5 7351.6 2538.2 2642.9 A029-2047000 E-17 5976.5 3931.1 6555.7 3681.3 1661.2 4527.5 2434.2 A029-2057100 E-19 8271.7 6302.2 7483.3 5390.7 1340.7 8761. 1 6807.7 A029-2057600 E-20 8480.4 6517.7 9079.5 3892.3 1163.9 A029-2078400 E-14 7114.8 5107.0 7175.7 5003.9 88.3 7067.5 5058. 1 A029-2099800 K-1 1194.8 0.0 1199.9 10.0 176.6 A029-2101100 ½-3 894.9 0.0 900.0 1.2 77.2 A029-2101400 K-2A 0.0 0.0 5.6 0.0 35. 1 A02~-2102300 K-4 1673.0 49.8 1679.0 6.9 140.2 A029-2103800 ½-6 2845. i 696. = ~ 2849.3 I7. I 111. 6 An~g-~i04500 K-7 2808.6 659.8 2805.8 3. 5 223.0 ~0=9-=140800 ½-8 2743.0 597.4 2743, 5 8.3 420.0 A029-2141800 E-5 3130.4 990.9 3013. I 700. 6 253. I 3059.4 917.6 Intersection /NEARBY\ TVD DEPART VERTICAL DISTANCE 8485.8 5235.2 3954.0 6623.8 4562.6 -2150.8 7230.0 5056.1 152.8 ~_46=. ~ 432.0 -597. 4 SUMMARY The well which comes closest to the A029-2101400 K-2A p~oposed well is' Closest approach distance = KICK OFF ~or this run = 35.1 ~eet 1200.0 ~eet Pt4. L TO $'rAMp TO pIT TRIP TANK 75' ~®L ~AND ' t/ I / "r'RAP / I,~0 88L MUO cLEA~JER I/,'~,C u U r l HUO ~E~ t,,, -- I~ EER ~ TRII~TION I~ITC / ..' / ..." /' ,' / - Choke Manifold - Poor Boy Degasser · - Brandt VacuumvType Degasser - Brandt Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge 1 - RecOrding drilling fluid: pit 'level indicat, or with both visual and audio warning devices at driller's console 1 - Trip Tank (75 BBL.) , 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp AgitatOrs 4O OI 02 04 OI I0 20 3,0 3,2 t""7. ~K-I~ i (~o~ed) I I I ! I K-9 ( Proposed ~~ I ~o 20 30 .4o. _~_ iD ~) .... (ProPg~ ' (Proposed) I .aoo'~ .-- K-8 I I (Propo$1d) J ! K-7 L.. 2250' (Proposed) J i '0 ~-6 (.P_r~p0sed) i1000' u - J ~ ~ILL ~ I~..WELL K4JAS,STA~ED) I t~ .L~: ~ LAT= 700 20,21.11 ,, I ~ LONG = 148° ~6 ~.i9 J , i~ ~:~ x= 6~,~0 !100 ~ Y=5,975, 5~2 J I (~sed~ I I I ~ I I. I 2200' _ I I I ~-~ ~1~5 Proposed) J I ! i I ~ K-14 i (PropoJed) O. oO4.11'14' PAD DETAIL SCALE: I"-- 500' to%PORT ION OF T. t~1 & 12 ,N,,.;.R. 14 E,,~U.M SCALE: I = I/2 MILE ~URVEYOR',S._ CERTIFICATE ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS ANO OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATION8 ARE FURNISHED BY OTHERS. REGISTERED LAI~ SURVEYOR ADD K-13 PROPOSED BHL ADD K-14 PROPOSED BHL ADD K-9 PROPOSED 8HL ADD K-5 PROPOSED BHL ADD K-8 PROPOSED BI41. ADD K-T PROPOSED BHL REVISE K-6 BHL. REVISE K-5 DELETED, ADD K~6 BHL REVISE K-5 ADDED BHL REVISE K-3 ADD REVISE K-4 ADDED BHL REVISE K-S ADD K-:~A REVISE K-3 ADDED BHL REVISE K-2 ADD PROPOSED BHL REVISE K- I SURFACE LOC. FROM PROPOSED TO AS-STAKED. REVISE K-I BHL. _ ~ , y L. McNeil PAD ~/e/e~ Located In NWl/4 PROTRACTED SEC. 4iT, IlN~R.14E.~UMIAT - -: , ........ z/is/as II /14/8S Surveyed for ~,o/~/.~ SOHIO ALASKA PET~~~CO. 9/~7/83 9/12/83 ..... 9 /l~/8~ Surveyed by ./~/.~ OCEAN TECHNOLOGY LTD. e/la/e3 LAND & HYDROGRAPHIC ~VEY~ e/ s/83 J 2502 West Northern (8) !3) (3.0 mm (14 ubzu 22) (6) ~~,~. ~'~F i "(29 cbru .31) GeolQ~y: rev: 01/28/87 6.011 fee ar=~ ~necl ~ 1. is uba po~: ..... - ..................................... , , 2. Is ~ ~o be locaued iu a ~ds_~_ned pool ............................. ~ .3. Is well locaued proper disum=ce from prop. ~ line .................. ~ ,, 4. Is well locaued p~ ~.~r~-nce 'L-zm other ~!!s .., ................. ~ 5 Is suffi~ undadica:ad a~-eage available in this pool ........... ~ 7. Is ope_~-ator tha only affec:ad parry ................................. ~ , 8. C~ ~~: be anorovad., before fir--caen-day ~-ail: ...................... ~ 9. Does ooerat~ hav~ a bond in force .................................. ~ 10. Is a conse_~za~_on order needed ...................................... dB 1! Is adminis~~v~ smorovml-needed ~ 12. IS the lease ~her aoorooria~a ..................................... ~ 13. Does the well have a uni.m~ ~-~ and ~_~ber .......................... z~ · · 14 IS condnznor string provided ~ 15. W~ ~~ ~~ ~~c~ ~esh ~c~ z~ ....................... ~ 16. ~ ~ c~U ~ed ~ ~ua ~ ~~r ~d ~~ce ......... ~ 17. ~1~ c~u ~e ~ ~ce ~d ~t~~te or p~~~ s~ ... ~ 18. W~ c~U ~ ~ ~ ~~~ ~~ ..................... ~ 19. ~ ~ ~~ ~ a~te s~e~ ~ ~~se, t~i~ ~ ~t.. ~ 20. ~ ~ ~ ~ be ~~ o~ ~ ~ ~~~~e ............ ~ ~. ~ old ~ore ~~: ~ce~a ~~d ~ 10-403 ............ '" ~. ~ a~a ~~~ s~a~ ~sed ............................ ~ For exoloraucry and Strz~hic w~lls: 29. Ar~ daua presented ~n pocenuial overp~~ zones? ................. ~___/Q ~ 30. Ara seis~c ~!ysis data presented on sh~]l~ gas zones .... , ....... ~ "' 31. If an offshore loc. ,, are survey results of seabed conditions presenuad~ : ,,i Addil::ional Rmmzks : k-IS I ~'0 ' , "/?/ore` K - , ~' ~ 9~J ,, ,,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , COMPANY NAME : BP EXPLORATION WELL NAME : K- 13 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292175700 REFERENCE NO : 98124 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/09/17 ORIGIN : FLIC REEL NAME : 98124 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, K-13 ,PRUDHOE BAY, API# 50-029-21757-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/09/17 ORIGIN : FLIC TAPE NAME : 98124 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : BP EXPLORATION, K-13 ,PRUDHOE BAY, API# 50-029-21757-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: K-13 API NUMBER: 500292175700 OPERATOR: BP Exploration LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 17-SEP-98 JOB NUMBER: 98124 LOGGING ENGINEER: H. KIRKBY OPERATOR WITNESS: A. COLEMAN SURFACE LOCATION SECTION: 4 TOWNSHIP: liN RANGE: 14E FNL: 1804 FSL: FEL: 4137 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 54.30 DERRICK FLOOR: 53.30 GROUND LEVEL: 23.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 12107.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEAS~ED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 16-0CT-87 LOGGING COMPANY: GEARHART BASELINE DEPTH 88888.0 12031.0 12020.0 12011.0 12010.0 12007.5 12007.0 12002.0 11998.0 11997.5 11990.0 11989.5 11985.5 11984.5 11982.5 11969.5 11968.5 11940.5 11939.5 11932.5 11932.0 11904.0 11887.5 11887.0 11867.0 11866.0 11827.5 11826.5 11821.5 11821.0 11812.0 11811.5 11766.5 11765.0 11725.5 11725.0 11708.5 11707.5 11696.0 11695 5 11691 5 11681 5 11667 5 11656 0 11599 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.5 88888.5 1201 O. 5 12007.5 12002.0 11997.0 11990.0 11985.0 11983.0 11969.5 11940.5 11933.0 11904.0 11888.0 11867.0 11827.5 11821.5 11812.0 11766.5 11726.0 11709.0 11696.0 12031.5 12020.5 12010.5 12007.5 12002.0 11998.5 11990.0 11985.0 11983.0 11969.5 11940.5 11933.0 11904.0 11888.0 11867.0 11827.5 11821.5 11812.0 11766.5 11726.0 11709.0 11696.0 11692.5 11681.0 11669.0 11657.0 11600.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 11564.0 11536.0 11535.5 11506.0 11504.5 11465 0 11464 0 11451 5 11450 5 11446 5 11436 0 11435 0 11419.0 11412.5 11411.5 11377.5 11376.5 11364.0 11362.5 11360.0 11358.5 11355.5 11354.0 11348.0 11333.5 11332.0 11331.0 11329.5 11320.5 11313.5 11304.0 11296.0 11269.5 11269.0 11260.0 11258.5 11238.5 11210.5 11209.5 11202.0 11193.5 100.0 $ REMARKS: 11536.0 11506.0 11465.5 11451.5 11436.0 11413 0 11377 5 11363 5 11360 5 11355 5 11348 0 11333.5 11330.5 11565.5 11536.0 11506.0 11465.5 11451.5 11448.0 11436.0 11419.5 11413.0 11377.5 11363.5 11360.5 11355.5 11348.0 11333.5 11330.5 11320.0 11320.0 11313.0 11313.0 11303.0 11303.0 11295.0 11295.0 11268.5 11259.0 11237.5 11210.5 11201.5 99.5 11268.5 11259.0 11237.5 11210.5 11194.5 101.0 CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON BP EXPLORATION WELL K-13 ON 22-0CT-97. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GA~4FIARAY PROVIDED BY THE CLIENT (GR.BCS); AND RST SIGMA-MODE PASS #1 SIGM R2P TO GR.BCS. ALL OTHER _ RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM R2P _ SHIFT. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~iARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12015.0 11152.0 RST 12034.0 11152.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: TYPE REPR CODE VALUE 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 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 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 BSAL RST PPK 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI R2P PU-S 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 CRRA RST 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1116936 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: DEPT. 12034.500 CCL.RST CIRN. FIL 0.361 CIRF. FIL IRAT. FIL 0.481 NBAC.RST SBNA.FIL 84.625 SBFA.FIL SFFC.RST 29.764 SIGM. R2P TPHI.R2P 35.399 CRRA.RST DEPT. 11151.500 CCL.RST CIRN. FIL -999.250 CIRF. FIL IRAT. FIL -999.250 NBAC.RST SBNA.FIL -999.250 SBFA.FIL SFFC.RST -999.250 SIGM. R2P TPHI.R2P -999.250 CRRA.RST 0 0 3023 72 28 2 -999 -999 -999 -999 -999 -999 000 TENS.RST 826 DSIG.RST 529 SFNA.FIL 203 SIBF.RST 922 SIBH.R2P 014 FBEF.RST .250 TENS.RST .250 DSIG.RST .250 SFNA.FIL .250 SIBF.RST .250 SIBH.R2P .250 FBEF.RST 1654. 000 BSAL.RST 1. 378 FBAC.RST 34.932 SFFA.FIL 1 O1. 032 SFNC. RST 127. 979 TRAT. FIL 55.926 GRCH. RST -999.250 BSAL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 SFNC.RST -999.250 TRAT. FIL -999.250 GRCH.RST 203.348 3689.687 31.927 31.956 0.922 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 53.763 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENIIMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMFLARY LDWG TOOL CODE START DEPTH GRCH 12015.0 RS~ 12034.0 $ STOP DEPTH 11197.0 11197.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12019.5 12009.0 12007.0 11998.5 11994.0 11993.0 11985.0 11971.5 11969.0 11961.0 11940.0 11931.0 11916.0 11915 5 11913 0 11903 5 11887 5 11886 5 11866 5 11865 5 11826 0 11821 0 11811 5 11807 5 11766.0 11765.0 11750.5 11724.5 11708.5 11707.5 11696.0 11695.0 11681.0 11670.0 11666.0 11663.5 11646.5 11634.0 11627.5 11607.0 11606.5 11579.5 11565.0 11560.5 11554.5 11535.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88889.5 88889.0 12020.5 12010.5 11998.5 11994.0 11985.0 11969.5 11961.0 11940.5 11917.0 11904.0 11888.0 11867.0 11821.5 11812.0 11766.0 11709.0 11696.0 11664.0 11608.0 11581.0 11565.5 11556.0 11536.0 12007.5 11994.0 11973.0 11932.5 11917.0 11913.5 11888.0 11867.0 11827.5 11808.5 11766.5 11752.5 11726.0 11709.5 11696.0 11681.5 11672.0 11667.5 11648.0 11635.5 11629.5 11609.0 11562.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 11534 5 11513 0 11511 5 11505 0 11504 0 11465 0 11464 0 11459.5 11435.5 11434.5 11413.0 11411.5 11377.0 11361.5 11358.0 11353.0 11350.5 11348.0 11346.5 11328.0 11316.5 11313.5 11303.5 11301.0 11295.5 11293.0 11272.0 11265.0 11259.5 11257.5 11237.5 11231 5 11225 0 11210 5 11209 5 11206 0 11198 0 100 0 $ 11511.5 11506.0 11466.0 11460.0 11436.0 11414.0 11377.5 11358.5 11348.0 11316.5 11303.0 11294.5 11271.0 11259.0 11238.0 11223.5 11210.5 100.0 11535.5 11514.5 11506.0 11466.0 11436.0 11413.0 11363.0 11360.5 11355.0 11352.0 11347.0 11329.5 11313.5 11300.5 11292.0 11265.0 11258.5 11231.5 11211.0 11207.0 11199.0 101.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #2 GRCH TO RST SIGMA- MODE PASS #1 GRCH; AND RST SIGMA-MODE PASS #2 SIGM R2P _ TO RST SIGMA-MODE PASS #1 SIGM R2P. ALL OTHER RST _ SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM R2P SHIFT. _ $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 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 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI R2P PU-S 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1116936 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 10 ** DATA ** DEPT. 12035 CIRN. FIL 0 IRAT. FIL 0 SBNA.FIL 82 SFFC.RST 29 TPHI.R2P 31 0 O0 CCL. RST 339 CIRF. FIL 481 NBAC. RST 627 SBFA. FIL 964 SIGM. R2P 963 CRRA. RST DEPT. 11197.000 CIRN. FIL -999.250 IRAT.FIL -999.250 SBNA.FIL -999.250 SFFC.RST -999.250 TPHI.R2P -999.250 CCL.RST CIRF. FIL NEAC.RST SBFA.FIL SIGM. R2P CRRA.RST O. 000 TENS.RST O. 825 DSIG. RST 3429. 554 SFNA. FIL 76. 471 SIBF.RST 29. 026 SIBH.R2P 2.046 FBEF. RST -999.250 TENS.RST -999.250 DSIG.RST -999.250 SFNA.FIL -999.250 SIBF. RST -999.250 SIBH.R2P -999.250 FBEF. RST 1607.000 BSAL.RST 2.766 FBAC.RST 36.316 SFFA.FIL 102.251 SFNC.RST 128.842 TRAT. FIL 57.644 GRCH. RST -999.250 BSAL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 SFNC. RST -999.250 TRAT. FIL -999.250 GRCH.RST 206.089 4225.490 31.930 33.238 0.871 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 61.353 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 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 SUBtLetY LDWG TOOL CODE START DEPTH GRCH 12015.0 RST 12034.0 STOP DEPTH 11199.0 11199.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 11 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12010.0 12009.5 12007.0 11997.5 11992.5 11989.5 11985.0 11984.0 11977.0 11975.0 11969.5 11961.5 11960.5 11940.0 11932.5 11931.5 11903.5 11900.0 11891.5 11887.0 11886.0 11866.5 11826.5 11826.0 11822 0 11811 5 11807 5 11797 5 11766 0 11765 0 11751 0 11726 0 11724 5 11718 0 11709 0 11707 5 11705 0 11696.5 11695.5 11687.5 11681.0 11675.5 11670.5 11649.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST 88888.0 88889.0 12010.0 12007.5 11989.5 11985.0 11978.0 11969.5 11962.5 11961.0 11940.5 11933.0 11904.0 11892.0 11888.0 11867.0 11827.5 11821.5 11812.0 11766.5 11726.5 11720.0 11709, 0 11705, 0 11696, 0 11677.0 11649, 0 12010.5 11998.5 11994.0 11984.5 11976.5 11933.0 11903.5 11900.5 11887.5 11827.5 11807.5 11798.5 11766.5 11752.5 11726.0 11709.5 11696.5 11688.5 11681.5 11672.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 12 11641.5 11643.0 11607.0 11609.0 11580.0 11581.5 11560.5 11562.0 11535.5 11536.0 11535.0 11535.5 11524.5 11524.5 11505.0 11506.0 11504.0 11506.0 11464.5 11465.5 11459.5 11460.5 11453.5 11455.5 11455.5 11435.5 11436.0 11434.5 11436.0 11412.5 11413.5 11411.5 11413.0 11398.0 11399.5 11397.5 11397.5 11377.0 11377.5 11369.5 11370.0 11361.5 11363.0 11358.0 11360.5 11355.5 11356.0 11353.5 11355.0 11352.0 11352.0 11346.5 11347.0 11330.5 11330.5 11327.5 11329.0 11313.5 11313.5 11303.5 11303.0 11301.0 11300.5 11291.0 11290.0 11265.0 11265.0 11259.5 11259.0 11257.5 11258.5 11210.5 11210.5 11209.5 11210.5 100.0 100.0 101.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPBDANDDEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #3 GRCH TO RST SIGMA- MODE PASS #1 GRCH; AND RST SIGMA-MODE PASS #3 SIGM R2P _ TO RST SIGMA-MODE PASS #1 SIGM R2P. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM R2P SHIFT. _ $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 13 ** 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 96 1 0.5 FT 10 0 FT 68 1 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 1116936 O0 000 O0 0 3 1 1 4 68 CCL RST V 1116936 O0 000 O0 0 3 1 1 4 68 TENS RST LB 1116936 O0 000 O0 0 3 1 1 4 68 BSAL RST PPK 1116936 O0 000 O0 0 3 1 1 4 68 CIRNFIL 1116936 O0 000 O0 0 3 t 1 4 68 CIRF FIL 1116936 O0 000 O0 0 3 1 1 4 68 DSIG RST CU 1116936 O0 000 O0 0 3 1 1 4 68 FBAC RST CPS 1116936 O0 000 O0 0 3 1 1 4 68 IRAT FIL 1116936 O0 000 O0 0 3 1 1 4 68 NBAC RST CPS 1116936 O0 000 O0 0 3 1 1 4 68 SFNA FIL CU 1116936 O0 000 O0 0 3 1 1 4 68 SFFA FIL CU 1116936 O0 000 O0 0 3 1 1 4 68 SBNA FIL CU 1116936 O0 000 O0 0 3 1 1 4 68 SBFA FIL CU 1116936 O0 000 O0 0 3 1 1 4 68 SIBF RST CU 1116936 O0 000 O0 0 3 1 1 4 68 SFNC RST CU 1116936 O0 000 O0 0 3 1 1 4 68 SFFC RST CU 1116936 O0 000 O0 0 3 1 1 4 68 SIGM R2P CU 1116936 O0 000 O0 0 3 1 1 4 68 SIBH R2P CU 1116936 O0 000 O0 0 3 1 1 4 68 TRAT FIL 1116936 O0 000 O0 0 3 1 1 4 68 TPHI R2P PU-S 1116936 O0 000 O0 0 3 1 1 4 68 CRRA RST 1116936 O0 000 O0 0 3 1 1 4 68 FBEF RST UA 1116936 O0 000 O0 0 3 1 1 4 68 GRCH RST GAPI 1116936 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 14 ** DATA ** DEPT. 12035.000 CCL.RST CIRN. FIL 0.356 CIRF. FIL IRAT. FIL 0.482 NBAC.RST SBNA.FIL 85.320 SBFA.FIL SFFC.RST 29.319 SIGM. R2P TPHI.R2P 34.926 CRRA.RST DEPT. 11199.000 CCL.RST CIRN. FIL -999.250 CIRF. FIL IRAT. FIL -999.250 NBAC.RST SBNA.FIL -999.250 SBFA.FIL SFFC.RST -999.250 SIGM. R2P TPHI.R2P -999.250 CRRA.RST 0.004 TENS.RST 0.826 DSIG.RST 3072.090 SFNA.FIL 73.483 SIBF.RST 28.399 SIBH.R2P 2.055 FBEF. RST -999.250 TENS.RST -999.250 DSIG.RST -999.250 SFNA.FIL -999.250 SIBF.RST -999.250 SIBH. R2P -999.250 FBEF.RST 1585.000 1.549 35.093 103.078 129.795 57.132 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 BSAL.RST FBAC. RST SFFA.FIL SFNC. RST TRAT. FIL GRCH. RST BSAL. RST FBAC. RST SFFA. FIL SFNC. RST TRAT. FIL GRCH. RST 207.943 3660.131 31.383 32.169 0.915 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 73.439 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 12015.0 RST 12034.0 STOP DEPTH 11195.0 11195.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 15 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12019.0 12010.0 12006.5 12006.0 11994.0 11990 0 11984 5 11983 5 11977 5 11974 5 11971 0 11969 5 11961.0 11954.0 11948.5 11945.0 11944.5 11941.0 11913.0 11905.0 11888.5 11887.0 11867.5 11866.0 11844.5 11828.5 11823.5 11822.5 11812.5 11808.0 11765.5 11727.0 11725.0 11708.0 11705.5 11697.5 11695.5 11690.5 11682.0 11671.0 11647.0 11614.0 11561.0 11537.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.0 88889.5 12010.0 12007.5 11994.0 11989.5 11985.5 11978.0 11969.5 11960.5 11948.5 11946.0 11940.5 11904.0 11888.0 11867.0 11828.0 11821.5 11812.0 11726.5 11705.0 11696.0 11689.0 11536.5 12020.5 12007.5 11985.0 11976.5 11972.5 11955.0 11946.0 11913.0 11888.0 11867.0 11845.5 11824.0 11808.0 11766.5 11726.0 11709.5 11696.0 11681.5 11672.0 11648.0 11615.5 11562.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 16 11535.5 11506.5 11504.5 11484.0 11461.0 11450.5 11436.5 11435.0 11421 0 11413 5 11412 0 11378 5 11376 5 11361 0 11359 0 11356.5 11349.5 11347.0 11333.5 11328.5 11321.0 11314.0 11305.5 11302.0 11296.5 11292.0 11289.0 11272.5 11267.5 11265.5 11260.5 11258.5 11232.0 11211.5 11208.5 11203.0 11202.0 100.0 $ 11505.5 11460.5 11436.0 11413.0 11377.5 11360.5 11356.0 11348.0 11333.5 11319.5 11303.5 11294.5 11290.0 11271.0 11265.0 11259.0 11210.5 11201.5 98.5 11536.0 11506.0 11485.5 11451.5 11436.0 11421.5 11413.0 11377.5 11360.5 11347.0 11329.5 11313.5 11300.5 11287.5 11265.0 11258.5 11231.5 11209.0 11203.0 101.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA-MODE PASS #4 GRCH TO RST SIGMA- MODE PASS #1 GRCH; AND RST SIGMA-MODE PASS #4 SIGM R2P _ TO RST SIGMA-MODE PASS #1 SIGM R2P. ALL OTHER RST _ SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM R2P SHIFT. _ $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 17 ** 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 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 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL RST PPK 1116936 O0 000 O0 0 4 1 i 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI R2P PU-S 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA RST 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1116936 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 18 ** DATA ** DEPT. 12035.500 CCL.RST CIRN. FIL 0.338 CIRF. FIL IRAT. FIL 0.493 NBAC.RST SBNA.FIL 88.076 SBFA.FIL SFFC.RST 31.329 SIGM. R2P TPHI.R2P 29.795 CRRA.RST DEPT. 11193.500 CCL.RST CIRN. FIL -999.250 CIRF. FIL IRAT. FIL -999.250 NBAC.RST SBNA.FIL -999.250 SBFA.FIL SFFC.RST -999.250 SIGM. R2P TPHI.R2P -999.250 CRRA.RST -0.002 TENS.RST 0.819 DSIG.RST 3691.228 SFNA.FIL 67.745 SIBF.RST 30.342 SIBH. R2P 2.008 FBEF.RST -999.250 TENS.RST -999.250 DSIG.RST -999.250 SFNA.FIL -999.250 SIBF.RST -999.250 SIBH. R2P -999.250 FBEF. RST 1626.000 BSAL.RST 2.787 FBAC.RST 36.839 SFFA.FIL 1.543 SFNC.RST 129.606 TRAT. FIL 55.574 GRCH.RST -999.250 BSAL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 SFNC. RST -999.250 TRAT.FIL -999.250 GRCH.RST 209.231 3615.044 33.225 33.715 0.835 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 72.007 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 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 RST 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 19 REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNRSAV 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 BSALRSAV PPK 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RSAV PU~S 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 20 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) DSIG RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH RSAV CU 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RSAV UA 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA RSAV 1116936 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12035.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 SIBH. RSAV -999.250 GRCH. RST -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 DEPT. 11151 500 NBAC. RST -999.250 FBAC.RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999 250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999 250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999 250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999 250 DSIG.RSAV -999.250 SIBH.RSAV -999.250 GRCH. RST 53.763 FBEF. RSAV -999 250 CRRA.RSAV -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE · 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 21 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~ULRY VENDOR TOOL CODE START DEPTH RST 12059.5 $ LOG HEADER DATA STOP DEPTH 11123.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 22-0CT-97 8B1-129 1227 22-0CT-97 12107.0 12046.0 11200.0 12045.0 1800.0 NO TOOL NUMBER CGRS-A RST-A 8.500 12107.0 SEA WA TER 8.40 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 22 TOP NORMALIZING WINDOW (FT) .. BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into SWS BHC Sonic log dated 10/16/87 Pumped 240 BBL seawater prior to logging capped w/methanol. 4 Passes made: 3 at 1800 fph, 1 at 3600 fph for comparison RST used to give TDT-P equivelent log. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #1 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 380 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 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 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS1 F/HR 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 23 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) NPHV PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS1 S 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PSl V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PSl 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RCAK PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FPHV PSl V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PSl V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS1 UA 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS1 MA 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1116936 O0 000 O0 0 6 1 t 4 68 0000000000 NBEF PS1 UA 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS1 UA 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PSl V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RXAK PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS1 PPK 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN FIL 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PSi CU 1116936 O0 000 O0 0 6 t 1 4 68 0000000000 FBAC PS1 CPS 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 24 NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NBAC PS1 CPS 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PSl CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1116936 O0 000 O0 0 6 i 1 4 68 0000000000 SFFA SIG CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 6 i 1 4 68 0000000000 TRAT PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 KHZ 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS1 KV 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PSI AMP 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PSl 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PSl 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PSi PU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI R2P PU 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1116936 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12059.500 CS. PS1 1656.696 TENS.PSI 917.000 NPHV. PS1 NPDE. PS1 1544.725 NSCE. PS1 2.540 CRRA.PS1 1.994 NSCR.PS1 AQTM. PS1 0.661 CHV. PS1 203.035 CPSV. PSl 5.040 CP2V. PS1 CM2V. PS1 -12.270 RCFR.PS1 0.000 RCLC.PS1 0.000 RCRC.PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1501.466 FPDE. PS1 1547.853 0.053 12.187 0.000 1488.572 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 25 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG TRAT.SIG CRFI.PS1 XTM. PS1 BUST. PSI TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CM2V. PSl RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG TRAT. SIG CRFI.PSl XTM. PS1 BUST. PSI TPHI.SIG 2.195 160.401 27.419 12.476 5.060 0.000 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 225 628 81 543 0 000 -999 250 11122 500 1546 365 1 102 -12 231 0 000 2 118 160 433 31 300 12 151 5 055 0 000 83 062 0 412 0.435 46.330 1.524 45.849 41.647 1.211 0.049 196.435 69.824 0.000 2.484 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 SIGM. R2P TRAT. FIL RDIX. PS1 TAV. PS1 BUSP. PSl TPHI.R2P CS.PS1 NSCE. PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR. PS1 BMCU. PS1 FBEF. PS1 BSPR. PS1 XP2 V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IR~T. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC.PS1 SIGM. R2P TRAT. FIL RDIX. PS1 TAV. PSl BUSP. PS1 TPHI.R2P -0.082 AQTF. PS1 31.640 GDCU. PS1 54.673 NPGF. PS1 1.123 MARC.PSi 12.056 X~2V. PS1 0.000 RXAK.PS1 -999.250 CIRN. PS1 -999.250 DSIG.PS1 -999.250 NBAC.PS1 -999.250 SBFA.PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 SIBH.R2P -999.250 GR.PS1 5472.000 RSCS.PS1 95.031 FICU. PS1 0.000 RSXS.PS1 -999.250 CCLC. PS1 1823.380 TENS.PSl 2.687 CRRA.PS1 202.066 CPSV. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.071 AQTF. PS1 34.902 GDCU. PS1 71.975 NPGF. PS1 1.244 MARC.PSI 12.070 X~2V. PS1 0.000 RXAK. PS1 2.796 CIRN. PS1 0.618 DSIG.PS1 0.436 NBAC.PS1 65.381 SBFA.PS1 3.982 SBFA.SIG 64.736 SBFA.FIL 41.898 SIGM. PS1 41.239 SIBH.R2P 1.543 GR.PS1 33320.000 RSCS.PS1 95.003 FICU. PS1 0.000 RSXS.PS1 55.775 CCLC.PS1 0.661 59.028 0.999 0.000 -12.270 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 74.023 8463.000 2.378 8878.000 0.010 1496.000 2.300 5.065 0.000 1486.817 1.102 59.575 0.996 0.000 -12.298 1.000 0.415 -0.554 2402.496 58.431 4.137 58.013 41.900 71.647 44.204 8463.000 2.391 8878.000 -999.250 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. PS1 CRNI.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PSl RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. PS1 CRNI. PS1 CTM. PS1 CACU. PS1 TPHI.PS1 152.888 4.734 0.999 201.096 0.000 38.373 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 449.900 81.543 2.554 -999.250 1550.294 0.072 12.180 0.000 1487.123 151.813 2.867 1.007 200.790 0.000 41.365 0.628 2983.889 42.178 1.418 44.019 52.010 1.055 1.533 451.710 70.068 2.565 54.105 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~fiVlARY VENDOR TOOL CODE START DEPTH RST 12059.5 $ LOG HEADER DATA STOP DEPTH 11168.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~94A RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 22-0CT-97 8B1-129 1227 22-0CT-97 12107.0 12046.0 11200.0 12045.0 1800.0 NO TOOL NUMBER CGRS-A RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 27 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 12107.0 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) : SEAWATER 8.40 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into SWS BHC Sonic log dated 10/16/87 Pumped 240 BBL seawater prior to logging capped w/me thanol . 4 Passes made: 3 at 1800 fph, 1 at 3600 fph for comparison. RST used to give TDT-P equivelent log. THIS FILE CONTAINS THE RAW RST SIGMA~MODE DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 380 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 28 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** 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 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS2 F/HR 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NPHV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS2 S 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS2 V 1116936 O0 000 O0 0 7 I 1 4 68 0000000000 CM2V PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FPHV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS2 S 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS2 PSIG 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS2 UA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS2 MA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS2 UA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS2 UA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS2 UA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 29 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) BSPR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS2 MA 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS2 CPS 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 KHZ 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 KHZ 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS2 DEGC 1116936 O0 000 O0 0 7 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 3O NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) XTM PS2 DEGC 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS2 KV 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 AMP 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS2 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1116936 O0 000 O0 0 7 i 1 4 68 0000000000 TPHI R2P PU 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1116936 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR. PS2 XP5 V. PS2 RXLC. PS2 BSAL. PS2 CIRN. FIL IRA T. PS2 SFFA. PS2 SFFA. SIG SFFA. FIL SFNC. PS2 SIGM. SIG TRAT. SIG CRFI. PS2 XTM. PS2 BUST. PS2 TPHI. SIG DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR. PS2 XP5 V. PS2 12059.000 1546.937 0.661 -12.250 1.000 2 162 160 401 28 344 12 878 5 060 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 228.267 75.684 0.000 -999.250 11168.000 1548.501 0.661 -12.231 0.000 2.122 160.610 30.852 11.861 5.061 CS. PS2 1800.000 TENS.PS2 873.000 NPHV. PS2 NSCE. PS2 2.707 CRRA.PS2 1.994 NSCR.PS2 CHV. PS2 202.066 CPSV. PS2 5.069 CP2V. PS2 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RTDF. PS2 0.000 FPHV. PS2 1501.466 FPDE. PS2 FSCR.PS2 0.180 AQTF. PS2 0.661 SF6P.PS2 BMCU. PS2 32.812 GDCU. PS2 58.700 EXCU. PS2 FBEF. PS2 56.524 NPGF. PS2 0.995 FPGF.PS2 BSPR.PS2 1.095 MARC.PS2 0.000 XHV. PS2 XP2V. PS2 12.056 X~2V. PS2 -12.289 RXFR.PS2 RXRC. PS2 0.000 RXAK. PS2 0.000 SHCU. PS2 BSAL.SIG -999.250 CIRN. PS2 -999.250 CIRF. PS2 CIRF. FIL -999.250 DSIG.PS2 -999.250 FBAC. PS2 IRAT. FIL -999.250 NBAC. PS2 -999.250 SFNA.PS2 SBNA.PS2 -999.250 SBFA.PS2 -999.250 SFNA.SIG SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS2 SFFC. PS2 -999.250 SIGM. PS2 -999.250 SIBF. SIG SIGM. R2P -999.250 SIBH.R2P -999.250 TRAT.PS2 TRAT. FIL -999.250 GR.PS2 363.383 CRNI.PS2 RDIX. PS2 41255.000 RSCS.PS2 8463.000 CTM. PS2 TAV. PS2 94.888 FICU. PS2 2.373 CACU. PS2 BUSP.PS2 0.000 RSXS.PS2 8878.000 TPHI.PS2 TPHI.R2P -999.250 CCLC. PS2 0.000 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 1863 650 2 695 202 308 0 000 0 000 -0 004 34 968 70 794 1 145 12076 TENS.PS2 1469.000 NPHV. PS2 CRR~.PS2 2.295 NSCR.PS2 CPSV. PS2 5.060 CP2V. PS2 RCLC. PS2 0.000 RCRC.PS2 FPHV. PS2 1496.583 FPDE. PS2 AQTF. PS2 0.661 SF6P. PS2 GDCU. PS2 60.269 EXCU. PS2 NPGF. PS2 0.998 FPGF. PS2 MARC.PS2 0.000 XHV. PS2 X~2V. PS2 -12.284 RXFR.PS2 1547 853 -0 202 12 231 0 000 1488 420 157 237 4 734 0 995 200 612 0 000 38 698 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 455.209 76.660 2.563 -999.250 1555.177 0.123 12.246 0.000 1488.839 155.483 3.184 1.017 201.166 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 31 RXLC. PS2 0.000 R3fRC. PS2 BSAL.PS2 65.097 BSAL.SIG CIRN. FIL 0.497 CIRF. FIL IRAT. PS2 0.447 IRAT.FIL SFFA.PS2 39.929 SBNA.PS2 SFFA.SIG 1.018 SBNA.SIG SFFA.FIL 39.674 SBNA.FIL SFNC. PS2 38.186 SFFC. PS2 SIGM. SIG 0.933 SIGM. R2P TRAT. SIG 0.036 TRAT. FIL CRFI.PS2 201.247 RDIX. PS2 XTM. PS2 71.638 TAV. PS2 BUST. PS2 0.000 BUSP. PS2 TPHI.SIG 1.693 TPHI.R2P 0.000 RXAK. PS2 2.780 CIRN. PS2 0.816 DSIG.PS2 0.447 NBAC.PS2 63.982 SBFA.PS2 2.921 SBFA.SIG 61.925 SBFA.FIL 36.623 SIGM. PS2 35.936 SIBH.R2P 1.350 GR.PS2 66832.000 RSCS.PS2 95.001 FICU. PS2 0.000 RSXS.PS2 50.168 CCLC. PS2 0.000 SHCU. PS2 0.500 CIRF. PS2 1.327 FBAC. PS2 2516.187 SFNA.PS2 52.904 SFNA.SIG 3.525 SFNA.FIL 52.658 SIBF. PS2 36.658 SIBF. SIG 63.859 TRAT. PS2 60.990 CRNI.PS2 8463.000 CTM. PS2 2.384 CACU. PS2 8878.000 TPHI.PS2 -999.250 41.323 0.809 3187.849 40.238 0.909 39. 668 45.3 O1 1. 027 1.347 461. 785 73. 731 2. 561 49. 738 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX 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: 3 DEPTH INCREMENT: O. 5000 FILE SUFmUh~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RST 12062.5 11170.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 32 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): 22-0CT-97 8B1-129 1227 22-0CT-97 12107.0 12046.0 11200.0 12045.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 12107.0 BOREHOLE CONDITIONS FLUID TYPE '. FLUID DENSITY (LB/G) : SURFACE TE~IPERATURE (DEGF) : BOTTOM HOLE TE~IPERATURE (DEGF) FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO CHOKE (DEG) : SEAWATER 8.40 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SAArDSTONE 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into SWS BHC Sonic log dated 10/16/87 Pumped 240 BBL seawater prior to logging capped w/me thanol . LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 33 4 Passes made: 3 at 1800 fph, 1 at 3600 fph for comparison. RST used to give TDT-P equivelent log. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 380 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** 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 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3 F/HR 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NPHV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 34 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) RCAK PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FPHV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS3 MA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 XM2V PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RXAK PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1116936 O0 000 O0 0 8 1 i 4 68 0000000000 BSAL SIG PPK 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 35 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dt. SS MOD NUMB Sg2.~IPEL.~I CODE (HE~) SIBF PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1116936 O0 000 O0 0 8 1 i 4 68 0000000000 SIBF SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 KHZ 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 KHZ 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS3 KV 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS3 AMP 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI R2P PU 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1116936 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS3 AQTM. PS3 CM2V. PS3 RCAK. PS3 FSCE. PS3 HVPV. PS3 NBEF. PS3 BSTR.PS3 XPSV. PS3 RXLC. PS3 BSAL.PS3 CIRN. FIL IRAT. PS3 SFFA.PS3 SFFA.SIG SFFA.FIL SFNC. PS3 12062.500 1548.120 0.661 -12.309 0.000 2.144 160.401 27.899 12.188 5.060 0.000 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 CS.PS3 NSCE. PS3 CHV. PS3 RCFR.PS3 RTDF. PS3 FSCR.PS3 BMCU. PS3 FBEF. PS3 BSPR.PS3 XP2V. PS3 RXRC. PS3 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS3 SBNA.SIG SBNA.FIL SFFC. PS3 1687 764 2 693 201 581 0 000 0 000 0 020 33 105 56 833 1 070 12 027 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TENS.PS3 800.000 NPHV. PS3 CRRA. PS3 2. 037 NSCR. PS3 CPSV. PS3 5. 060 CP2V. PS3 RCLC. PS3 O. 000 RCRC. PS3 FPHV. PS3 1494.142 FPDE. PS3 AQTF. PS3 0.661 SF6P.PS3 GDCU. PS3 60.668 EXCU. PS3 NPGF. PS3 1.004 FPGF. PS3 MARC. PS3 0.000 XHV. PS3 X~2V. PS3 -12.309 RXFR.PS3 R3fAK.PS3 0.000 SHCU. PS3 CIRN. PS3 -999.250 CIRF. PS3 DSIG.PS3 -999.250 FBAC. PS3 NBAC. PS3 -999.250 SFNA.PS3 SBFA.PS3 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS3 SIGM. PS3 -999.250 SIBF. SIG 1545.411 0.043 12.290 0.000 1489.411 157.749 4.340 1.010 200.854 0.000 38.373 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 36 SIGM. SIG -999.250 SIGM. R2P -999.250 SIBH. R2P TRAT. SIG -999.250 TRAT. FIL -999.250 GR.PS3 CRFI.PS3 226.458 RDIX. PS3 71287.000 RSCS.PS3 XTM. PS3 73.242 TAV. PS3 95.031 FICU. PS3 BUST. PS3 0.000 BUSP.PS3 0.000 RSXS.PS3 TPHI.SIG -999.250 TPHI.R2P -999.250 CCLC. PS3 DEPT. 11170.000 CS. PS3 NPDE. PS3 1547.853 NSCE. PS3 AQTM. PS3 1.322 CHV. PS3 CM2V. PS3 -12.231 RCFR.PS3 RCAK. PS3 0.000 RTDF. PS3 FSCE. PS3 2.130 FSCR.PS3 HVPV. PS3 160.628 BMCU. PS3 NBEF. PS3 30.732 FBEF. PS3 BSTR.PS3 11.992 BSPR.PS3 XPSV. PS3 5.057 XP2V. PS3 RXLC. PS3 0.000 RXRC. PS3 BSAL.PS3 67.441 BSAL.SIG CIRN. FIL 0.497 CIRF. FIL IRAT. PS3 0.448 IRAT. FIL SFFA.PS3 41.505 SBNA.PS3 SFFA.SIG 1.149 SBNA.SIG SFFA.FIL 42.567 SBNA.FIL SFNC. PS3 39.167 SFFC. PS3 SIGM. SIG 0.988 SIGM. R2P TRAT. SIG 0.042 TRAT. FIL CRFI.PS3 203.518 RDIX. PS3 XTM. PS3 72.917 TAV. PS3 BUST. PS3 0.000 BUSP. PS3 TPHI.SIG 1.956 TPHI.R2P 1872.623 TENS.PS3 2.670 CRRA.PS3 201.944 CPSV. PS3 0.000 RCLC. PS3 0.000 FPHV. PS3 -0.110 AQTF. PS3 35.039 GDCU. PS3 70.264 NPGF. PS3 1.185 MARC. PS3 12.080 XM2V. PS3 0.000 RXAK. PS3 2.807 CIRN. PS3 0.764 DSIG.PS3 0.446 NBAC. PS3 64.346 SBFA.PS3 3.783 SBFA.SIG 59.938 SBFA.FIL 39.496 SIGM. PS3 38.821 SIBH. R2P 1.440 GR.PS3 96915.000 RSCS.PS3 95.012 FICU. PS3 0.000 RSXS.PS3 52.338 CCLC.PS3 -999.250 195.150 8459.000 2.388 8878.000 0.000 1467.000 2.286 5.065 0.000 1505.128 1.322 59.815 1.003 0.000 -12.276 0.000 0.496 0.513 2487.443 57.325 3.848 55.323 39.418 64.811 57.282 8463.000 2.389 8878.OOO -999.250 TRAT. PS3 CRNI.PS3 CTM. PS3 CACU. PS3 TPHI.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. PS3 CRNI.PS3 CTM. PS3 CACU. PS3 TPHI.PS3 -999.250 461.316 73.731 2.554 -999.250 1547.853 0.050 12.246 0.000 1492.387 157.749 3.551 1.006 201.113 0.000 40.801 0.774 3318.608 41.773 1.214 40. 510 46.169 1. 040 1.448 465.315 73.486 2.566 51.662 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 37 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUN~VL~Y VENDOR TOOL CODE START DEPTH RST $ LOG HEADER DATA DATE LOGGED: 12063.5 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 11166.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~IA RAY RST RESEVOIR SATURATION $ 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) : 22-0CT-97 8B1-129 1227 22-0CT-97 12107.0 12046.0 11200.0 12045.0 3600.0 NO TOOL NUMBER CGRS-A RST-A 8.500 12107.0 SEAWATER 8.40 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 38 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: Tied into SWS BHC Sonic log dated 10/16/87 Pumped 240 BBL seawater prior to logging capped w/methanol. 4 Passes made: 3 at 1800 fph, 1 at 3600 fph for comparison. RST used to give TDT-P equivelent log. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 380 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 39 TYPE REPR CODE VALUE 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 C~SS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1116936 O0 000 O0 0 9 i 1 4 68 0000000000 CS PS4 F/HR 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NPHV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS4 S 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKPS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FPHV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS4 S 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS4 PSIG 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS4 UA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS4 MA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU PS4 UA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS4 UA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS4 UA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 MARC PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 XHV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 X~2V PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR PS4 1116936 O0 000 O0 0 9 I 1 4 68 0000000000 RXLC PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 40 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) SHCU PS4 MA 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL PS4 PPK 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNPS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS4 CPS 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS4 CPS 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS4 CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM R2P CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH R2P CU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS4 KHZ 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS4 KHZ 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS4 DEGC 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 XTM PS4 DEGC 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TAV PS4 KV 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS4 AMP 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS4 AMP 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 BUSP PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS4 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS4 PU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI R2P PU 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CCLC PS4 V 1116936 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 12063.500 CS.PS4 NPDE. PS4 1548.501 NSCE. PS4 AQTM. PS4 0.661 CHV. PS4 CM2V. PS4 -12.211 RCFR.PS4 RCAK. PS4 0.000 RTDF. PS4 FSCE. PS4 2.125 FSCR.PS4 HVPV. PS4 160.401 BMCU. PS4 NBEF. PS4 27.882 FBEF. PS4 BSTR.PS4 12.342 BSPR.PS4 XPSV. PS4 5.060 XP2V. PS4 RXLC. PS4 0.000 RXRC. PS4 BSAL.PS4 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS4 -999.250 IRAT. FIL SFFA.PS4 -999.250 SBNA. PS4 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS4 -999.250 SFFC. PS4 SIGM. SIG -999.250 SIGM. R2P TRAT. SIG -999.250 TRAT. FIL CRFI.PS4 230.256 RDIX. PS4 XTM. PS4 74.707 TAV. PS4 BUST. PS4 0.000 BUSP. PS4 TPHI.SIG -999.250 TPHI.R2P DEPT. 11166.000 CS.PS4 NPDE. PS4 1549.379 NSCE. PS4 AQTM. PS4 0.661 CHV. PS4 CM2V. PS4 -12.172 RCFR. PS4 RCAK. PS4 2. 000 RTDF. PS4 FSCE. PS4 2.103 FSCR. PS4 HVPV. PS4 160.767 BMCU. PS4 NBEF. PS4 31.409 FBEF. PS4 BSTR.PS4 11.342 BSPR.PS4 XPSV. PS4 5.060 XP2V. PS4 RXLC. PS4 0.000 RXRC. PS4 BSAL.PS4 75.793 BSAL.SIG CIRN. FIL 0.529 CIRF. FIL IRAT. PS4 0.461 IRAT. FIL SFFA.PS4 36.680 SBNA.PS4 SFFA.SIG 1.267 SBNA.SIG SFFA.FIL 38.526 SBNA.FIL SFNC. PS4 37.337 SFFC. PS4 SIGM. SIG 1.027 SIGM. R2P TRAT. SIG 0.042 TRAT. FIL 2950 820 2 689 201 823 0 000 0 000 0 018 32. 812 56.229 1.132 12.100 O. 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 102021. 000 94. 888 O. 000 -999.250 3609.957 2.686 202.308 0.000 0.000 0.050 35 376 69 797 1 231 12 085 0 000 3 325 0 887 0 459 64 762 4.418 63.023 35.076 34.374 1.287 TENS.PS4 1051.000 NPHV. PS4 CRRA.PS4 2.017 NSCR.PS4 CP5V. PS4 5.069 CP2V. PS4 RCLC. PS4 0.000 RCRC. PS4 FPHV. PS4 1501.466 FPDE. PS4 AQTF. PS4 0.661 SF6P.PS4 GDCU. PS4 61.323 EXCU. PS4 NPGF. PS4 1.004 FPGF. PS4 MARC. PS4 0.000 XHV. PS4 XM2V. PS4 -12.270 RXFR.PS4 RXAK. PS4 0.000 SHCU. PS4 CIRN. PS4 -999.250 CIRF. PS4 DSIG.PS4 -999.250 FBAC. PS4 NBAC. PS4 -999.250 SFNA.PS4 SBFA.PS4 -999.250 SFNA.SIG SBFA.SIG -999.250 SFNA.FIL SBFA.FIL -999.250 SIBF. PS4 SIGM. PS4 -999.250 SIBF. SIG SIBH. R2P -999.250 TRAT. PS4 GR.PS4 127.857 CRNI.PS4 RSCS.PS4 8463.000 CTM. PS4 FICU. PS4 2.368 CACU. PS4 RSXS.PS4 8878.000 TPHI.PS4 CCLC. PS4 0.010 TENS. PS4 1486.000 NPHV. PS4 CRRA.PS4 2.222 NSCR.PS4 CP5V. PS4 5.069 CP2V. PS4 RCLC. PS4 0.000 RCRC.PS4 FPHV. PS4 1501.466 FPDE. PS4 AQTF. PS4 0.661 SF6P.PS4 GDCU. PS4 60.381 EXCU. PS4 NPGF. PS4 1.000 FPGF. PS4 MARC. PS4 0.000 XHV. PS4 X~I2V. PS4 -12.279 RXFR.PS4 RXAK. PS4 0.000 SHCU. PS4 CIRN. PS4 0.530 CIRF. PS4 DSIG.PS4 1.047 FBAC.PS4 NBAC. PS4 2336.471 SFNA.PS4 SBFA. PS4 50.851 SFNA.SIG SBFA.SIG 4.850 SFNA.FIL SBFA.FIL 55.008 SIBF.PS4 SIGM. PS4 35.075 SIBF. SIG SIBH. R2P 68.663 TRAT.PS4 GR.PS4 44.562 CRNI.PS4 1547.853 -0.017 12.187 0.000 1492. 005 160.564 4.340 1.000 200.854 0.000 38.698 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 464.344 75.684 2.539 -999.250 1552.736 0.018 12.231 0.000 1493.226 159.380 2.762 1.000 201.278 0.000 40.081 0.910 2980.392 39.794 1.363 39.599 49.278 1.244 1.290 460.102 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-SEP-1998 06:57 PAGE: 42 CRFI.PS4 207.047 RDIX. PS4 115339.000 RSCS.PS4 XTM. PS4 74.707 TAV. PS4 94.978 FICU. PS4 BUST. PS4 0.000 BUSP.PS4 0.000 RSXS. PS4 TPHI.SIG 1.973 TPHI.R2P 49.047 CCLC. PS4 8463.000 2.377 8878.000 -999.250 CTM. PS4 CACU. PS4 TPHI. PS4 74.707 2.559 48.459 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/09/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/09/17 ORIGIN : FLIC TAPE NAME : 98124 CONTINUATION # : 1 PREVIOUS TAPE : CO~fENT : BP EXPLORATION, K-13 ,PRUDHOE BAY, API# 50-029-21757-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/09/17 ORIGIN : FLIC REEL NAME : 98124 CONTINUATION # : PREVIOUS REEL : COGENT · BP EXPLORATION, K-13 ,PRUDHOE BAY, API# 50-029-21757-00 DIRECT DIGITAL LOOOt~O ~O~PU l ~' TER PROCESSED ANALYSIS Compan.~,., STANDARD AL. ASKA PRODUCTIOH CO,' We!l K-t3 OZH API NUM: 5 0'- 029-2 ~ "757 Fimld PRUDHOE BAY DATE OF JOB: 10-16-87 Count NORTH SLOPE State ALASKA Country, USA CL I ENT FORMAT DATA TAPE LOG I NF ORMA 1' i ON o T AHD ARD FORMAT ( L .~ I , S , ) Name: i<-t3 O?:H APi NUM: 50-029-2~;757 i.~i~ i i No.: SAPC K- i .~ D~pt.h~: I 03D4.00 to 12t 77, O0 Field: PRUDHOE BRY D~TE OF JOB: 10-!6-87 · -"-- 20 OCT, . 'i9E~7' T i me: 3: S 1 F'kI TUE, L,I,S, T APE RECORDS HE~DER R E C 0 R D .., Dat~:~ ~7,"i8/20 Or-'igin: Reel F'r-mvious tap~: Da'tm: 87/10,."20 Or. igin: Tapm n..~me: ~7366¢-] Cont, inuation '.~: O'i File n.'.~me: &GSF0t ,00~ I'i~:,..:imum Iength: i 024 HEADER Vmr-sic, n ~ ~ File t. ppe: LO Pr. evious M N E M CN I.,.i N FN C: O U N S T A T CTRY SECT TOWN RANG ED F' EGL. PD LNF DHF RUN L C E: SON L U N FL L d L ENG l ~9i TN DD DL TLI TCS TL~E: MRT HT HFST MFSS RMC bleST t'iCSS I NFr]RMA Ti CiN REt'ORD.::,, CONTENTS U N I T T V P E ~ANDARD ALASKA PRODLICTiON CO ................. K-iS O,.':H APl NUM: 50-029-21757, ............... F'RUDHOE ~."' ~.,R¢ i0 iE. L~" ................ NORTH "'~ ALASKA USA 04 54,30'0 .................................................. FT 5'$, 3 O0 ................................................... FT~ i<B ...................................................... KB ......................................... ............. 3 0 ....................................................... 4', ¢ ..~ t~ ~:,t_-, NORTH :SLL P E .................................... NORTH SLOPE .................................... ROEnE~' CUNN ~NGHAM .................................... i2i50, OOO ............................................... FT ~215i ,OOO ............................................... FT i120i, OOO ............................................... FT i2!48, OOO ............................................... FT 2, OOO ................................................... HR 7, '450 ........................................ .......... HR 169, O0 O ................................................ DEGF ~ 69, OOO ................................................ DEGF DISPERSED L Z L]NO .................................... FLOWL i NE ................................... "~."~..,~., (I[lO , 0 ,'L'_, 2,870 ................................................... 6S, O00 .................................................. HEAS ............................................. 2.9~0 ................................................... 77, OOO .................................................. MERS ............................................. CP OHMM OHMM DEGF OHMM DEGF C A TG C 0" ~- :+::~- This LIS t~pe w..~ w~"itten b,,¢ ~ear. har't indua",+..~-ie~ i,~iir'.~line Ser. vice~. :~::~ :+::~ ~ii cur-ye arid too! mnemonic~ uzed ar.e thoze which most close!,p ma%ch m:~: :+~:~ ~ear-ha~t cu~ve and tool mnemonics, ~ ~E~RHART TO SCHLUMBERGER MHEM SERVICE UNIT MHEbi SER',?i CE UHIT [:'EPTH FEET DEPT FT T ¢.:-' f.-t MERGE LBS TEHS MERGE L~: ,:, GR MERGE GAPI GR MERGE C;RPI IL[:' i'"tERG E OHMM IL[> biERGE OHMM ILM MERGE OHMM iLM MERGE OHMH - ~ LL .:, i"tER GE O Ht'I M LL.¢t MER(';E OHMM DT MERGE US,"'F DT MERGE US,"F FC:NL MERGE CPS FCNL MERGE CPS t',iC:H L MERGE CPS HCHL MERGE CPS C ILi':, COMPUTED MI"tH O C: I LD COMPUT MMHO HPHS COI'4PUTED SSPU NPHi COMPUT PU RAT COMPUTED NRC~T COHPUT SP MERGE ¢~P i SP MERGE ¢:~P I B ARHART" DATA E N T R $:.t:~:$ ENTRY BLOCK LEGEND TYPE DESCR~PT iON 0 Ter'minator. ,:; no mor. e entr'i~s ) FORMAT SPEC I F i CAT i ONS TYPE S I ZE (::ODE 0 t 66 DATA FORHAT' :+~:~** DATLiH SPECiFiCATiON BLOCKS *:~-:~ SERVICE SERVICE AP1 MNEM ID ORDER ~ UNIT L. OG APi APl APt F!'~.E TYPE CLASS HOD ~ DEPT 3?3666 FT 0 0 TENS MERGE . ~73666 LBS 95 0 GR MERGE 3?3666 GAPi 95 54 iLD MERGE 373666 OHMH 95 i20 ILFi MERGE 37~6rS60HHH 95 i20 LLA MERGE 37~666 OHHM 95 220 [:,T HERGE 373666 US/F 95 8 FCNL MERGE S7S6E, 6 CPS 95 78 NCNL MERGE S73G66 CPS 95 78 CiLD C:OMPUT 37S666 MMHO 94 68 NPHi COMPLtT 373666 PiJ 94 NRAT COHPUT S736~,6 94 i 64 SP hiERGE 77366~ API 95 iO 0 0 0 0 0 0 i 0 0 46. 0 0 44 O 0 6 O O ,. ~. 0 0 ..S i 0 0 '30 0 0 46 0 0 3' 0 0 i 0 0 i 0 0 o P E =. .., A T' 1 O N PRC SiZE LVL. SMPL RC 4 O 1 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 i 68 '4 0 i 68 4 0 i 68 4. 0 i 68 4 0 1 68 4 0 i 68 4 0 I 68 4 0 i 68 PROCESS iNDiCATORS O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OHO000 0()0000 000000 000000 OOF~OOO O00000 OOOOOO 000000 000000 000000 [:, E P T N C i.i L ] -I:. h .=, C: !LD f,iP H i ILD fi R A T TA R C 0 R D ,."] I L i'i SP L. LA D T F C N L F' a g e t2i69,5£~0 O, i '206 ':), 58 O 96'-:~, 500 '278 ,SOO i i 869,50 O 295, i 00 i i76'9 = . . ,., O0 314,500 i i 669,5 0 O 569,500 .7,63,70 O i 146'"~, 5 O 0 :2:07,700 369,500 3i9,600 i i 269,500 ~62 OOO i76i . 000 i 000, 00 (.", 4860:000 '-' ~ .~ '~, 46 4718, OOO 34,356 4709,000 4'9,888 4660, 000 20,41 7 4718, 000 81 , 470 4621 , 000 92,47O 45Z= O00 ii ,143 47i8, OOO bu ...... O 4621. 000 82,224. O, 000 - I 06. 500 34. 070 80.700 ,.,,. 260 40, i O0 ',2'2,100 3I ,500 27,000 4i . i 30 16,800 ~8 t~4 23.')00 25,830 32,600 24 ~'PO 78,408 22,940 i . 00 0 -9'99, ;250 4,2 A 5 · '.'9 i 07 2,207 20, O45 2 ' 099 48 9 ',' ':) 2, 099 274 2,6i5 i 0.8t4 i, :399 74] ,802 i9,861 i,8i9 t'2, ! 62 i -"36 i , 000 0, 000 4, i02 75.7 00 23,388 45,5O0 i5,24i 73, ,SOO S0,269 60. 700 455 50 O 8,ilo 6 i , 700 44 1 S'"' 24,400 27,66'3 :$ '2,60 O i O. 399 8:.'.4,600 37 5O i 8 i2 89 iO 000 9 43 9.31 09:9 350 589 3i 325 85 lO0 94 iii i05 000 300 600 5OO 8 O0 900 8 00 600 608 200 i ';: i46 i 9.3 000 800 O00 2 00 6 O0 i 00 200 600 t00 60 ;) M.~ .... i mum t ength: I..,-_~]'~"i. TRAILER R E C 0 R [:.' S SeI:-vi ce name: Fiie t,..Jpe: LO N e x t ',/er.,_--, i or'; · i:' i i e: M a :,.'. i m u m i e n g t h: i 0 ;~ 4 'HEADER Dat. m: Fil~ t. up~:,.; LO Pr-mvious f'iia: Page I 0 M iq E H CN kIH · FN COLIN STAT CTRY SECT T 0 I.,.t N RANG EI<B EDF LHF DHF RUN LCC SOH LUN FL LUL ki ~ T N DD DL TL~ TCS TL~8 BHT HRT MT NSS HV~S RH RHF MFST NFSS RHC NCST HCSS ! NFORHA'T OH R E C 0 R D o C 0 N T E H T S TYPE STANDARD ALASKA PRODUCTION CO,' ................ K-i~ O,."H APi NUH: 50-029-2i,..,-", ............... PRUDHOE 8AY DATE OF JOB: i0-i6-S7 ................ NORTH '-" A~' .:,L _ I- E .................................... ALASKA .................................... USA i iN ' , ........ , ................ 't4E, . ~ , .... , , , , , . . , , . ~ , , , , , , . , , .... , , , , . , . , , . . , . , ....... o4, ,-'~ 00 ............................... FT ,~, ..*00 ................................................. F'T 23,900 ............................................ , ..... FT KB · 3 O ..................................................... 37F_,~666 ............................................... 76t '-' NORTH SLOPE .................................... NORTH SLOPE ................................... ROEDER ................................. C U N H i N G H. A M ................................. i2150, OOO ............................................ FT i2i5i , O00 ............................................ FT i120t,000 ........................................... FT i2i48,000 ........................................... FT 2,000 ............................................... HR 7,450 ............................................... HR 169,000 ................................................ DEGF i 69, OOO ................................................ DEGF DISPERSED LIGNO .................................... FLOWL i NE ...................... ............. 3~, OOO ................................................. 2,820 ............ '-' 870 ............................. 68, 0 0 0 .................................................. MEAS ............................................. 2,9~0 ................................................... 77, OOO .................................................. MEAS ............................................. CF OHHH OHHN DEGF OHNH DEGF CATG SiZE C: 0 [:, E 0 0 40 65 0 0 40 65 0 0 40 65; 0 0 2 Lq 65 0 0 20 65 O, 0 :'-lO 65 0 0 2 65 0 0 3 6,5 0 0 .?, 65 0 3 4 68 O ~ 4 68 0 .S 4 68 0 3 '2 ~5 0 ~ :2 65 0 ~ 5 "=' 0 O 2 79 0 0 '2 7 9 0 0 i 0 65 0 0 i 0 "=' tZ, .j 0 0 20 65 0 0 2 0 65 0 0 20 ~,.. 0 0 20 65 0 '~ 4 68 0 .S 4 68 0 .3 4. 68 0 --" o 4 6 O 2 4 68 0 4 4 68 0 I 4 E, 0 i 4 68 0 ',2 2O 65 0 2: 2 0 65 0 2 4 ' q 0 2 4 68 O 2 4 6 ;9 0 2 4 68 0 2 !2 65 0 2 4 ~'" 0 2 4 :68 0 '2 t 2 65 P a ge COMMENT REL. URD :, ms Thi:_-, L. iSi. apm wa~ written b~,~ G~ar. ha~"t Inducts-ires Elir-~lin~_ S~:rvice._~-., ~+~:+, Al! cur. vm and tool ~n~monics used arm thosm ~,hich ~ost closmip mmtch m, Gm~har~t curvm and tool mnmmonics, GEARHART TO SCHLUMBERGER t'i i-~ E i"i SERVICE UNiT MNEM SERVICE UNiT DEPTH FEET DEPT FT TEN2 FiERGE LBS TENS M~:RL~E LBS C;R2 MERGE GAP I GR MERGE GAPI i2 [) A T A ENTRY BLOC:KS ENTRY FORMAT !SA_. T i ON'--'',... TYPE S I ZE CODE 0 i 66 TYF'E DESCRIPTION 0 Ter. m i rtali:.oP ,:: ri,.:, mor.~ entl.", i e_~: ) DATA FORMAT' or'"r..C',~ F i CAT 1 ON~',,_. . c, ~.~:~-:.~:s DATUM SPECIFiCATiON 8LOCKS ~:~-'+~ S.F-,,, ot=.~ ,,, I C:E AP1 APl AP! APl FiLE r.;. !'-, ,,, iCE '-'-""" MNEM iD ORDER ~ UNiT LOG TYPE CLASS MOD ~4 DEPT .'3_,73666 FT 0 0 0 0 0 TENS MERGE 37$666 LBS 95 O 0 0 GR MERGE 373666 GAPi 95 54 i 0 i PRC ,~ SIZE LVL SMPL RC 4 0 i 68 4 O i 68 4 0 i 68 PROCESS iNDiCATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 · C, EP T T Et',IS 6R RECORDo i5 O. 000 4523 000 67.700 Il!sS_ .0£10 4a4a.~ . 't!055.000 4543 000 000 :60,50 O 0'955. 000 4543 000 69.800 i 0S55. 000 4465 000 (52, '200 10755,000 44!6 000 59,600 (1655, 000 4309 000 63,300 I ¢!.~55 000 4"':';:"4 65,800 i04= . ~5,000 a. I96 000 50.500 ~: :.,~ :~: :a FiLE 'TRAILER :~ :~. :+.' :.~ H..~ximum !~_ngth: ~ 024 T P, ~ Z L E E: R E C 0 R D © File typm: LEI ? .~ g ,E.': ST~q'E : ~,!,.,ASFA APl f~i.lf,"k~gt< : 50-029-21757 CEFEP~;r:CE ~',~r:~ : 73~99 ~B~Jotio~ ,. IS Tape Verification bisti, ne ch.lt!mberger ~hlasKa Comt.~ut.:ir~O t.';enter P AGE ,' ******************************************************************************* ******************************************************************************* ** ** ** '** ** ******************************************************************************* ******************************************************************************* IS Tar, e verlficati, on bistir~q chlumberaer Alaska Computinq Center 54.3 53,3 GL: ~3.9 T/X I L[:'IPE: ~.~ITI: $iZF 2: 8,5" 'TI;G-P-! 05 T ~,! C - P - X 2 ~TC-,C6- ! ! 52 Taa. T C*~,.i T}'~IS [.,IBCaF:Y TAPE ~hTC!'!ES THf' CIIRVE bCO! O!'J BLtJE!:!NE, t.,CC,! = TSP;!/T$C.W PAGE: ****************************************************************************** FIb!" - Eii>I r.()ol 50-02q-P 1757 , , * T 0 o L E' X T E N S l ('~.~ T 00 L *' T Y P E ~ 7.5 * TPT-P ,P'St THERMAL, hgC~Y ~)Ol, 12082' TO 11192' C N E p A P :! ~,: 50 - 5KC7 4 TO wt,: 1 I% C C U ~e :'~ 0 ~ T H $ 7 ~, ~ A L i $ K N~%'I lISA S('::': ~: 35007 P l)A T ~': S 1, F P [) F ? O, AVl) FT 54,3 E~t3 ~'T 54,3 E[:F FT 53,3 T ~ I) F 1 2 0 g 3 DEFI t;::X'.P!~ f] R. A T I Ot~ Compan~ Name DH. Og :::!.Y Field ,iame ] ~ell ~ame 029-2i757 APl Serial ~<~umber 4' FNL & 4137' FEi., Field Location Section Township Range County State or Province N~tion WitDess' Name Service Order Nt,~mber Permament datum Log ~leasured From Eli g'i' 12(,'~2, Bottom LOa Interval TI I FT 1 1 2oo. 'fop bo~ Interval TLA, 1-~:r,'.-, 30-~':,:Y '.:im.e.. ~o.o..~e.[." i: ,otto~ [) F: F I ....DKp,. ;- .... ,');;''';;;'~;''::'~'. tn n ! r,, ................................. sTG~' .SirJ,na (~..~eutror': Capture Cross SectioD) SIGt' Si. oma (,~eutror, Cat?ture cross Section) S ~ I")T Statt)5 of TP!~I T I"~T ~orositv Tape verificatior, !.~ist:Inq. chl. umberqer AlasKa Con;puting Center 20-jUN-1990 !512a 8iqma formation - far detector (TOTP) $I~n~a format, ior~ - near ~etector 81qrna boreho!e - far detector (TI')'I"P) SlO~a ~oreho!e - near detector (TDTP) Far "FDTr¢~ Count: '~'ate ~ear 'f'~.):I'~ Count Rote Amplitude for~'~ation -- far detector (TDTP) Ampli, tude boreho!e -- Far detector (TDTP) Amo!itude formation - near detector (TDTP) implit:ude [aoreho!e -- near detector (TDTP) ~ore:hole sigma (corrected) -- TbTP ~,~ini. tror'~ mo~l;e mopI. t. or ratlo(TDTP) S~andard ~eviation of Si. qma-iorr~"~atio~ ~:~ac.~.~round, Near Gates Far (-lack qround Total Counts analyzed - near detector (TDTP) Total. counts analyzed - far detector [TDTP) ~"otal counts - near detector (TDTP) Total counts - far detector (TDTP)' Selected qates co~]at, rate - near' detector (TDT'P) 8e!ec~ed gat. es count rate - far detector (TDTP) Inelast. ic cot.]nt:inq ~ate - near detect:or (TDTP) I. netastic count:.ing rate - far detector TDT-P Telemetry Error CotJnt ~ie8~ Vo],,t aoe Stat us of ~'aw ~¥ear 1st: (gate ~aw Near 2nd Gate ~:aw ~ear :ira Gate ~a~ *..?ear Zith Gate Raw ~'~ear' StP Gate ~a~ ~eaI' 6t:~ (;ate Paw ~;ear 7tl~ Gate P~,~: ~ear 9th Gate ~aw *,:ear loth Gate Raw ~,,ear l ltb Gate ~aw ~-,~'.:ear t_?th gate Paw ~ear 13th (]ate ~aw h~ear ~.4t~ Gate Raw ~:ear ~5%h Gate Raw ~iear ]6th (;ate riaw Far 1st e';ste Ra;~ F~r 3rd (;ate Raw Far 5th Gate Paw ~'ar 6th Cote Raw Far 7th Gate ~aw Far ~th Gate I.~ Tar;e verifl, cat ion !~ist. ir'~q chlumberg~r Al..aska Comp,]t.i..~(:~ Center 20-diJN-t99© t5,'2~ DEFI ';~";"'''~;''~' ~ . ar ~,''~;~h e ........ ' ....... '"'''''''''''''''''' ~"10 ~aw Far iOth Gate ~FII ~aw Par l!t,n Gate RF12 Paw Far !2th Gat~ PF13 Raw Far !3th Gate RF'I~ Raw ~ar 14th Gate ~"!s ~aw Far lSt~ Gate ~FI,~ Raw ~ar 16th Gate .1 [;, ~ICx' NLA CiJ 3500 GIGk PS1 Cli~ 350(} T F H l p S !. P IS ~I! PSi V 3%00 SFVr~ PSi SF ~ r~ PS1 CI~ ,, a~ Verificat.ion Listina chlt~mho-rger alaska Com~utinq Center 2o-JiJi, l,.!ogo i5:28 PAGE: F'TnT ps1 CD~ ,350071 51 0o() ~0 9 ... ~:,~ ~,~. ,.. ~,~ . . .~ .... NTDT PS! CPS 350071 51 000 ()0 0 ~-o 1 (, PS 35007 ! 51 39! O0 0 F~ t C P,,:, 350071 51 39 t. 00 .A~'ND PSi CPS 3fi0071 51 390 00 0 A [~ ~,! D PS! COtS 350071 51 390 O0 0 [.o ! ~ 35007 ! 51 4OO 01 b $!BH PSI CU 35n071. 51 4aO Ol 0 M~'OF' PSl 35007!. 5! 000 ('.)0 T~hT PSi 350071. 51 000 O0 0 ..... >] PS1 C[~ 350071 5t 000 on 0 E~CF PSI CPS 350071 5! 39C, i7 FPAC PS1 CPS 35007! 51 391 17 TCA.[, PSl 35007t. 5~ 000 O0 TCAF PS1 35007!, 5! 000 O0 0 T C ?,i [) P S 1. C' P 5 35007 !. 5 t 000 00 T C P D P '" ......... o 1 C;°S 35007 ;! 51 000 o0 0 TSCN pS! CPS 350071 5! 000 00 0 TSC'F pS1 CPS 35()t~7! ~1 000 00 0 I ~.~ ~) r'> p $ !. C P s ~ 5007 ! 5 i. 000 () 0 0 l' ~ 'FB P S ! C P 8 350 () 71 51. 0 i) 0 r) () 0 TT~;C PSi 35f) 07!. 51 390 00 HV PS 1 V 350o71 51 000 00 SlTC pc~ 3q0071 51 ()00 00 0 R ~.. l P $1 C P.F. 350071 51 3 o 0 (;, 1 0 P~' 2 PS 1 CPS 350t) 7 ! 5 ! 390 02 0 R~ 3 PS1 CPS 3~()07! S! 39(') 03 R~,~ 4 PS I CPS 35n071 51 390 04 0 RN 5 PS ! CPS 35('i071. 51 3q() 0 S 0 ~' ~ 6 P S ! C P $ 35 () () 71 5 ! 390 F? ~7 PS 1 CPS 3%0071 51 390 07 0 R~ ~ PS'l CPS 350()7 ! 5 ! 39o [~9 PS1 CPS 350071 5! 390 Oq ~t.~l(, PS! CP,S 35007! 51 3qL, I0 RN 11 PS1 cPS 3~ ......... ) 0 (; 7 ! 51 3 q O ~)I~ PS1 C9S 350071 51 3~0 .... .> 1 CPS 350071 51 39() R~!4 PS1 CPS 350071 51 390 14 0 ONt R PS! ~[,e .)qn071 51 300 . . k,. ~_} - . ..... -ol CPS 350071 bl 300 16 0 PF! PSI CPS 350071 51 3t?J 01 kF2 PS1 CPS .]5,~o7 I 51 3o! 02 ~V3 ~$!. 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PS RF1 J PS 1 CPS ~F!2 PSI CPS ~F13 PS! CPS RF!4 PSI CPS ~F! 5 PS1 CPS ~:' ! 6 PS1 CPS COb PS 1 V 350071 51 39! I0 0 ! ! 1 4 68 0000000000 35007] 51 39! It 0 I I. 1 i 68 0000000000 350071 5i 39! 12 0 I 1 1 4 6~ 00000()0000 350071 51 39! 13 0 I 1 t 4 6B 0000000000 350071 51 39! 14 0 i I I 4 68 0000000000 350071 51 39] 15 0 I ! i 4 6~ 0000000000 350071 5t 39]~ 16 0 t 1 1 4 68 0000000000 350071 51 310 O1 0 1 1 ! 4 68 0000000000 350071 51 635 21 0 l 1 I 4 68 0000000000 350071 51 150 01 0 i ! 1. 4 68 0000000000 [..,E .i:':,il.~:~B ~.. . SIZE ;~E.P~ 'PROCES,.~ DF:PT, 12096,500 $I'd~q i4!..¢.~ 28,1.0a SI(;:v, PSi -999,250 L~TD~'~,P81 T.P~I,PS! -999 25q I'SH[J' SP~.tF,PS1 -9C}q' ,PSI -999,250 SFFP'PSI. ~ -999,250 SF~D,PS1 .... ., 250 $ B }.~ ~' P S 'i - 999.250 F T D T ' :~, ......... ,Pol -999,250 NTD-T,P81 AFFP PS1 -909.999250 ~:i"~F13'!~81... -999:250'999 250 .~F~.~I:>, uS! -999250250 ..... ~ a , · ...... ,... ,~ .,. · SlgC,PS! 25n SIE}H, 5! M~OF,PSI -999 ~R!T' . ~ ... ,.,. . . .... .., . . , . ~ . S!) S l, [.': S ~!. -999 ,250 ~%ACK , PSi - 999,2S0.. FBIC, PS 1 -9991250 rC~N'Psl.Psi TChF,....._!Pg -999,251:~ TCN[),PSI -999,250 ~CFK:,PS1 -999250 TSCN,P81 TSCF',PS1 -999,250 I ?.~ ~.~:i), PS I -999,250 INFD,PS1 -999,250 TTEC,PSl ~v, PS 1. ~ ...... ,999, ~n_ .. SAT~_ . t., [::'$ ! -999,250. RN 1, PS ! -999, ~50 RN2, PS 1 R~:~3,PS1 999250 RN4,PS1 -ggq 250 ~Nb,PS1 999250 ~N7,PSI iggq' '' ' i 9' ., ,250 RNa,PS1 -999,250 PN9,PS! 99 ,250 RNIO,P81 PSI ,t.~q~ 25c) ~:~12 PS1. -999,250 R~I. 3,PS1 999.250 o! -999 P5(') ghi!6,Fol -999,250 PFI,PS1 99g 250 RF2,PS1 .. PS1 -999250 RFS,PS1 -999'250~ RF6,P81 R?'3, PS !.. : e '99~' 250~ ~F4' ~81. .. -999125n ~Fg, ~ S!"' -999250 RF1 O, PS1 [~F'7,F,>i -q99,25n PFa, ........... RFII,PS1. -<)992~n RF'I2,P51 -999,250 ~FI. 3,P81 999250 ~F"I4,PS1 .......... ,250 ~F16,PS1 -999,250 GR,PSI 99250 TENS,PS1 CCI ,PS1 -999,~50 [)FPT, 12(t0(:, 000 S I (:-'q, :-'i b a 17,4S4 $ I G.'"z, PS 1 17,592 STDT,PSI '!_'t:!.i I, P S .! 2.b,743 ISh:J,P8! 36,0(~0 SF'F.~, PS1 18.974 8FND,P,SI SFHF',PS1 37,0072 S F, [-t ~::. P ,e.,. !. 44.349 FTPT,PS1 !0,928 NTDT,P81 AFFP,P8! 102,972 AkFO,PS1 !36,054 ,~FNi), PS1 454,004 ABND,P$1 SI,aC,PS1 .! ,9f. 5 .SIB!-~, PS 1 46,.150 /'< ~OF, P,q I 1,223 TRAT,PSI SP$!,P,$! 0,5130 BAC~:,PS 1 74,404 Ft~AC,P81 16,393 TCttN,P$1 TCA~,PSI 27887,349 TCNI;. P~31 25278,863 TCFD.P8! 8274.908 TSCN.PS1 TSCF,PS! 26~7,~0'1 i ~.}[:D, I'S 1 ]342,353 I~IFg,PS! 427,957 TTKC,PSI liV,P81 234,625 5aTC,PS1. 1,0o0 RNI,PS1 719,866 RL2,PS! R?3,PS1 1084,449 ~ 4,PS! 1555,059 nNS,PS! 1.612,72~ RNfl,P8! PN7,PSi '1037,36~ a~.~a, PS! 734,747 RNg,PS1 1906 622 k~lO,PS1 ~"11 ,PS1 274:'), 396 P~"]. 2,P81 2823,6~0 ~'~13,Pal 2579~985 RNI4,PS]. ~N 1. K, PSi lOStq ,4OH ~ ~'J 1 g , PS1 455,729 ~F1 · P~lo 285494.. PF2 , PSI ~;F3,FS1 310,57! ~F'.4, F'S 1 414,738 ~FS,oS! 4S3l~la RF6,P81 PF7,pS1 324,074 ::¢F8, PS1 320,?1o PF(:), r~S l 675,154 RFIO,PSi PFII ,PS1 937,500 ~gl 2,["8J 989,583 PF13,PSt 931,713 RF14,PS1 PF'!B.PSI. 4nT,ag5 ~Fl~.[:'S1 1't7,4~'.9 (;~,P5! 26,375 TFNS,PS1 -ggg 250 -999 250 -999 250 -ggg 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999'250 66 000 21 653 29 639 490 138 2 376 66273,172 6221,115 0,000 63,640 1683,407 1949.405 1901,042 ~7 415 468:750 675,154 777,392 1070,000 IS Tape Verif. i. cation Listinc! chl. umberger AlasKa Computi. nn Center C C !,, ? S !,, 0,0 0 {'~ ! 190(),00o 1 ~7,605 1 32,93~i c~,~q pS!. ' PSi !. I ,599 :1. 0,265 t:~,aC<, ...... 1 3 2 4 8 4 2 ~ 9 T C N D, P S 1 1 3 0 59, ,:.. ! 734'625 8ATC'PS! P S 1 i i 045,3 B 7 R i:,~ 4, b q ! 1 1212,707 ~?i~, ,. 1 286 ~::~. 303 R ~',~ 12, !::' S i i 16'12,723 ! 26'2,3a6 RF4, PSi ' P q I 1. 943,287 afl 2, 1 640,432 RFI6, I 0' OOO DEPT. TPHI ,PS SBHP'PS AFFD,P5 S ! (; C, P S SPS I. PS TCaP,PS TSCF, PS HV, PS PN3,PS ~N7,PS PP3,PS ~'F'7, PS afl 1 ,PS ~FIS,PS CC[..PS t. 1800,000 S I. Givi, [{LA ! 22.42! 1 3!o941. 1 0 173 [~ACK.PSi 1. 45/-~49' j. ~ " ,6 f) 9 T C I 2.34'~50 s~~' '" . ,.. P 81 I 1032,366 !;'.NO, PSI. t !261,!61 ~'.aS, PS1 1 2901. ,7~5 RL~I. 2.PS1 ! 2297'247 R.N!O,P81 I 2~5,494 RF4, PSI ! 408.951 RF~. 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PSI !062,927 I ~.~t.~9, PS 1 1219,609 INFD,PS1 23:i,750 5A~'C.PS1 1,000 pN!.pS 1062,!28 R~:4.,PS! 1495,536 PaS,PS1 926.339 ~'N=,PSi 719.8i~6 F'.ti9, PS1 2431,!75 R~lP,PS1 2334.449 R~... 13, PS! 6~6,3~4 aql6,P81 51.5,253 RF! ,PS1 2~ 3. b65 RF4, t>S ! 374. 229 NFS, 201 .28! aF fl. r:,[; ! 3{)4,7~4 RF'9, PS1 !6,122 17,467 1.1,760 467,398 I 2!5 18 759 8553 691 404 090 680 803 1542 039 1867 559 3182 663 283 565 432 099 615 355 1141 975 17 359 12.639 i3,485 1.2,835 21.6 20.168 10207,693 395 675 723,586 1579,241 1.901.0~2 3603 050 27!:991 451 3~9 1398 534 12~977 29,1.8i 32.1.22 7.512 472.580 1 !71 27:327 5557.260 357,!.94 701.265 !538,318 1781,994 1895.4~1 262.346 435,957 580,633 8TDT, PS 1 oFND, NT[)T,PSI ABND,P8! TRAT,P81 TCAN,P81 TSCN,PS1 RN2,PS1 RM6,PS! RNIO,PS1 RNI4,PSI RF2,PSI RF6,PS1 RF14,P8! TENS,PSI 8TDT,PS1 SFND PS1 NTDT:PS1 ABND.PS1 TRAT,PS1 TCAN,PS1 TSCN,-ol '"C PS! TIE., RN2,P$1 RN6,PS! RNIO,PS1 RNI. 4,PS1 RF2.P$1 RF6,PS1 RFIO,P81 RFI4,P$1 TENS,PSI STDT, PS ! SFI4D,PSI ?~T[?T, P$1 ABNO,PS1 TRAI,P$1 TCAN,PS1 TSCN.PS1 TTEC.PS1 RN6,PS1. R~,IO,P$1 RN14,PSI RF2.PSI RF6,PS! RFIO,PS! 66,000 19;582 32'644 453'307 .2;476 80432,000 7576'554 0;0o0 86 000 1744 792 t940 !04 26~9 732 13 545 497 685 657 793 1008 873 1050 000 66,000 15,160 32.326 471,026 2,240 102269,469 9691,377 0,000 101,480 1780,134 1958,705 3454 241 9 675 540 123 690 586 1385,031 1000,000 66,000 35,052 22,899 448,054 2 793 56846:633 2969,153 0,000 137,600 1573,661 1750.372 !203,497 25,155 435,957 592,207 IS ;!::a~e Veri~ication LIst. iraq chlumberoer .h]..aska (?om~t, ut:inq Center F!5,PSI 1.89, ..43 ~F1. 6,PS1 ...... P S ! 0, (:~ 0 n CCI,, ........ . DEPq~, 11600,0o0 P S 1. 13,3 e 7 I ,s.H ~' o .... .... , ,PSi SIGC,PSI O, ~.~24 SIBH,PSI SDS!,PSI. 0,i47 !~ACK,PS1 '.C ... PSI 65164., 391~ 'tCND,PSi TSCV, P S 1 6223,7 a 2 i ;~l i'~ '0. P $ i H~.Pgl 235,000 $1TC PSI ~N7, PSI !4~!. ,692 R~lt,PS1 2932,009 PP3, PS1 300,9~6 RF4 ~F7, PS!. 516,975 RFt i,,PSl 1.157,407 R. 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PSI, 42 531 , ,PSi 46,~26 FTDT,PS1 !49.886 48,962 a~';OF,P51 149,442 FBA(i, PGI~ 30! 61,535 TCF[).PS1 12 o 4.318 I ~ F [;:,, P $ I 1 000 ~ ~1 · 1464, t~0 709,876 33 ,t 8,765 ~ ~.~ ! 3, P S 1 157~,937 RFI,PS1 462, q 6 ] r~ F 5, P 81 353.009 1.437,1t4 RV!3,PSi 958,719 GR,PS! 1!,383 SiG~!,PS1 41,2 !.9 8FFO, PSI 43,179 FTOT.PS! 143,971 43,759 MMOF,DSI 158,6~ 1 FBAC, PSi 29412,906 TCFU,PS1 i!97,422 INFi),PSi !.000 RNI.PS1 1491.815 R~5,PS1 .. PS 1 701,265 Phi9, 3255,20~ RN1.3,PG1 J 51,9,940 RF1 ,PS1 448.7I.~ RFS.PS1 350,561 !~6,218 RFlS,PS! 777.~4 613.426 44,250 10 690 11 282 15 450 562 134 1 169 13014,531 438.94,5 702. 160 1576,003 :1828,704 3875. 386 333 719 5OllS4 750. 386 1757,330 12,438 11,504 12,025 1.4,717 560.52~ 1 232 32 728 !2107 635 439 9~! 695 684 1568 080 1819 !96 3720 282!452 474 760 731,170 !.626.603 12.305 14,32~ SIG~!.PS1 14,444 40.78! 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PS! ~NIO.P$1 PN!4.PS1 PAGEI 385,802 1065,000 66,000 12,291 29,~18 453, 55 1,772 115448'516 i1026,375 0,000 ~47 O6O !817 130 1954 089 3863 812 23 220 605 710 754'244 1983,025 1050,000 66.000 12,640 29'239 451,280 °890 108936,000 !0513,801 0 000 154 800 1765 253 1912 202 3664 434 27 090 584 936 737.179 1788 862 10651000 66.000 16.771 32 768 4701276 1.~63 95772,234 8880,102 0,000 lSl,~90 18!0.345 1986.35t 3!50.144 34.100 cM]..tlm~,er<~r Alaska Computi,.~<~j' C'enter. SP!.tF, PS 1 ~ 2, ~FF'D,PS1 i23.7c"' P~ ICC,PS1 1,543 S!'B.H PSI DST,PSl o 77.'] !~aCK' 25. 293 Tci~:n ps1 TSCF,PSi ~46,700 laND,PS! P?o3,PSI ! J 28..!72 RF4,PSI ~NT,PSI !Ol(}.a02 Rk:l 5.Pi3I 7416,52~ R?'~!6,PS1 ~K3,PS1 297.619 ~F7. PS1 271. 577 RFS, PSi. RFII ,PS1 7~ifi, g30 ~'FI 2,PSI RFI. 5,P8! i 76,"111 CC!.:. PSI. O. o0o Ot'.P~'. I ! 200, OOO SiVa. TP~.iI , ................ .~'~P, PS1 92,642 $1GC.P81 1,396 STE. H,P81 SP5! .PS1 I .004 5~CK, D81 TCAF,PS1 9625,I25 TCt.~D,PSl TSCF. PS !. 45 !, 040 T~!:~O, PS ! ?v. pS 1 234. ~75 5.~TC, PS ! R~ 3. PS 1 1065, ~ 4~ ~S7. PS! 773.80° ~NS. PS1 R~}! I..PS1 1.9~4,747 R~015.PS1 6~4~, 52<4 ~F3, PS 1 277.77~.; ~F4. PF7. PS1 169. 753 PV!I .PS1 5!5.046 g'F!2.PS! ~F l 5, PS 1 ! 29,24.4 CCI.. PS 1 f'~. (;00 DEPT. Ili91 .50(! TFH t. PS 1 -999. 250 S~', PS1 -999.25n AFFP'. PS 1 -999,250 8lgC.PS1 -999.250 SIBu. PS1 gL'S! ,PSI -q99.25C 5ACK,P81 TC.~F. P51 -9qO. 2~C TSCF,PS1 -999. 250 I ~V.P81 -q~.2bO 5.~'rC, P8 ! ~'. ~: 3. PS J -~99. 250 PN4, PSI 20-.di.!N-!. 990 15128 ;35 84 ~ 46.265. FTDT,PSI . P $ i. !.27,620 51,!43 1.1~l .01,2 FattC, P81 20247,7()7 TCFD,P~ 1216,657 INPD,PS1 729, :167 2~99.6~1, 706,018 RFI,PSI ,4t6'667 ?FS,PSI 308,780 RF9,P81 706, ~45 ~.. ! 43,229 GR,PSI 44.250 sFVn. ,PS1 56,000 rTDT,PS! 94.247 AFND,PS! 73,363 185.4()5 FB~C.PS! !.5490,855 TCFD. PS1. 1211,982 !~:FD,P81 1..OiiO PN! ,PS1 !456.473 RaS,P81 7!4,286 ~.<Ng. PS1 17i3.1.~9 R~:~I 3,P8! 732,~7 RF! ,PS! 349 151 RFS,PSl 273:920 pF'q,nS1 44~,6(32 RF13,P8~ 1.42. 747 530 134 766 369 1579 241 !3 250 35.995 37.258 6 941 538 255 I. 308 39 930 5556 725 3~7 524 702 1.60 i643 518 1902,006 1861.,497 25!,!.16 450.149 56,622 , . 62.000 38.905 40'663 4.035 469.252 1.1~3 36 740 3667.810 336,187 697.545 480.655 579.6~7 126! 161 2521701 337 577 474 537 318.~87 42.188 -999.25t) -999.250 -909.250 -999.250 -g90.25o -999.250 -999 250 -999~250 -999.250 -999,250 -999.250 RF6,P$! RF!.O,PSt RF!4,PS1 TENS,PSI 8TDT,PS1 SFND,P81 ~TDT,P81 TROT TCAN: TSC~i,P81 TTKC.P81 RN2oP$1 RN6"P$1 RNIO,PS1 RN!4'PS! RF2,PS1 RF6'PS! ~:FIO,PS1 RFt4,PS1 TENS,PS1 STDT,P81 SFND,PS1 ~TUT,PS1 ABeD,PS1 TRgT,P8! TCAN,PS1 TSC}~.PSI TTEC.PS1 RN2.P81 R~6,PS! ~:lO.PS! ~N14.PS1 R~2,PS1 RF6,PSI RFIO,P81 TEt~S,PS1 STF:T,PS1 SF~D,PS1 NTDT,PS1 AB~:D.P81 TRhT,PS1 TCAN.PS1 TSCN.P$1 TTEC.P81 RN2.P8! RNIO.P8! PAGE: 10 641.74! 799,851 1558,~80 1035,000 66 000 38 988 23 044 498 995 3 173 54925 172 2686,347 0,000 178 020 172o: 79 120:56 40,635 444,568 606,399 321,80!. !030.000 66.000 41.688 14.847 421,345 3,589 36158 2~9 !.61 17o4 o'ooo 187,695 1374 628 803.571 30,960 3!2,500 424,383 190.972 1040,000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999:250 -999,~50 Tape Veriflcotlop l:istinq chlumber:~er A, lasKa Comptlt, inO (;'enter 20,-dli'N-! 990 15 :, 2b' ¸!1. '999,250 '999 250 '999 25O '999 250 -999 250 -999 250 RN13,P81 RFI.P$I. ~FS,P81 RFgP81 . RF13.P81 -999.250 ~NI4,P81 -999.250 RF2.P$! -999 250 RF6.P81 -999 250 RFIO'P8! -999 250 RF!4.PSI -999 250 TENS.PSI '999,250 '999,250 '999 250 '999 250 '999 250 '999 ~50 SERVJ:,CF, : FL!C D~TE' : 00106/20 ~X PEC SIZE : 1~24 FIL~; TYPE : LO t,~ST FILE : FIL~: - [CbI'!',O02 PRIII:~.~OE !3AY 50-r~29-? ! 7 b7 P~SS ~2 bOG 9AI~?~ f}lTr~ SA!,:[-'.[,EL'., ETVKRY -.5000 FEET ~!S ?ac, e Verification !,ist. i.r'~c~ ;chlum~err;~er Al~ska Co,:put, inq Center 990 1..5~28 , T U !:~! I V a b U D E F I C~; BP EXPLORATIOn.! F'~,. PI~UDHOE BAY WS~ K-I3 API~:I 50-029-2 ! 757 FI: t8()4' FNL & 4137' F'Eb S F C ~: 4 ~'~; ~ T J' USA W l ~ ~,~ C A B L F, L;O~ 35007! E'FD FT e., APD ~T 54,3 E~B FT 54,3 E~F FT 53,3 F~ G L V ? 23,9 T~D FT 12063, Company Name Field ~ame Well Name APl Serial Number Field Location Section Township Ranoe Cou6tv State or Province Nation Wit, bess' Name Service []rder Number Permament datum Loq ~!easured From . ¥Pi4 : CURV i')emth Channel ~;ame SirJma (~'4et.!tro~ Can. t~!re Cross Section) Stat. us of: T~.')~' TDT Pnrosjty 'FtPT shunt Current Siqma formatior, - ~ar detector 8},cdma ioru'~at]on - naar ,~etector Sioma ~ore~ole - far r~et:ector (TDtlD) Siqma borehole - near detector Far Ti')T~ Count ~ate ~,~ear '17DT~ Count Rate ~mmlltude formation -- far detector AmDlitume borenole -- Far detect, or Am~titud~ formation - near detector (TDrP) Amo!lt.:u~e Porehole -- near detector SlG~~ Correction ~I$ 7a~e Yerlficatio~ !..,istinq ;chlumberoer AlasKa Com[.~utinO Cente:r 2 O-dUi>i-!. 990 !5:28 PAGE: 1] ~ it:ton mode monitor ( NMDF I~ rat i DTP) TRAT TDT Patio SP~! Standard devJ. ati. on of Slqma-for~ation (TDTP) B~CK 8ackoround, Near Gates FBAC Far PacKqround TCAN Total. counts 8~al. yzed - near detector (TDTP) C~,F' Total cour~ts analyzed - far detector (TDTP) CND ~'otal counts - near detector (TDTP) TCFP Total counts - far detector TSC~e Selected Gates count rate - sear detector (TDTP) ~,,,CF oeleCt, ed ~ate~,~ cogent rate - far detector. ,. (TDTP).. ~N~';D l.r'~elastic count:irma rate - near °etector (TDTP) I~,':FD Inelastic counting rate - far detector (TDT'P) TTE'C TDT-P Telemetry Error Count HV ~4ead Voltaoe SATC Status of: .ATC RN~ Raw Near !st <;ate ~t~2 :~a:w ~,~ear 2nd Gat:e P~3 Raw r,<lear 3rd (;ate ~'74 [~aw ~;ear <~th <;ate RNa ~aw t.~'ear 5th Gate RN6 Raw ~Gear ~th Gat~ R~7 Raw Near 7t:.h Gate RNa ~(~w ~'.~ear fit~ date P~;9 Raw ~?ear 9tn Gate ~;],.O Raw ;~ear i. Ot, h Gate RNI. 1 gaw ~<~ear 1!th Gate RN!2 Raw ~,,]ear 12th Gate RN!3 ~aw ~,~ear 13th Gate p~!~ ~'aw Near ]4t.h <;ate F:f'~I5 ~aw t,~ear lSt~ Gate p~,~!6 ~aw ~ear !6th <:;ate R~ t ~a,~ Far 1st Gate RE"2 Raw ~'ar 2nd Gate RE".'] ~aw Far 3rd Gate [;:r~ ~aw Far 4th Gate R~5 Raw ~ar 5th Gate PF6 Raw Far 6th Gate ~F7 ~aw ~'ar 7th Gate RF8 Paw Far 8th (;ate PF9 Pa,' ~'ar 9t~ Gate ~'!o Raw ~'ar !.'~tr, Gate ~'~1 ~aw Far lite, (;ate FF'!2 Ra~: Far 12t~ Gate ~r13 ~aw Far 13th PF'! 4 Paw Far 1,4tn <;ate RF15 Raw Far 15th Gate ~V~: Paw Far l~th Gate GP Gamma FaY T E' ~,~ S 'r e n s I o r~ .,Ia Tape t/erification Listipq {chlun~berqer"A!aska ComF.;t.lt,.ir~o Center PAGE: 14 T~ CU 350071 5! 350(:'7 ! 51 P !J 350 c) 71 5 CU 350071 C~! 350071 5! CU 350(.,7 ~ C!; 35007~ 5! CPS 350071 CPS 350071 C°S 350071 CPC~ 350O71 CPS 350{~71 5! CPS .]50i)71 CU 35n071 C~i 350071 350071 350071 C~ 350071 CPS 350071 5! CPS 350<~7! 5! 350071 51 ~Snf~7! 4O0 O1 0 39O O0 0 890 O! 0 0 (') 0 00 0 40O 02 0 400 02 40 c 01 0 40O 0! 0 00 n 00 0 00 o o 0 O 391 00 0 39 ! 00 0 39{1 00 O 39 o C, 0 0 40 ~ o 1 0 00 O 0 a 0 000 0 C, u O 0 () () 0 0 390 17 0 39! O 00 () () 0 0 ('; 0 0 0 () 2 1 1 4 6a 0000000000 2 I I 4 68 0000000000 2 ! I 4 68 0000000000 2 1 1 4 68 O000oo0000 2 1 1 4 68 00o0000000 2 ! 1 4 68 0000000000 2 ! I 4 6S 0000000000 2 1. 1 4 68 0000000000 2 ! 1 4 68 0000000000 2 1 I 4 68 O0000000nO 2 ! 1 ~ 68 O0(~O000OO0 2 ! 1 4 6H 0000000000 2 1 I 4 68 0000000000 2 J 1 4 6~ 0000000000 2 I 1 4 68 oOOO0000~O 2 1 ! 4. 68 OOc)O000000 7 ~. 1 4 68 000()0()0000 2 1, 1 4 68 0000000000 P 1 i 4 6~ 00o0000000 2 ! ! 4 68 000o000000 2 1 ! 4 68 0000000000 2 !. 1 a 68 0000000000 2 ! 1 4 68 0000000000 chlUm~'ero, er &laske Comp~ti~(~ Cen2er 20-OUt, i-1990 I5:28 15 .......... [ A P I A P I A t::~ I TCFD PS7 CPS 35007! TSC~ PS~ CPS 35007:! TSCF P~S2 CD~ 35007! IN~tP PS2 CPS 35007! I~FD .PS2 CPS 350071 TTE:C PS2 350071 H V P S ~ :~ 350071 8~TC PS2 35007! RN! PS2 CPS 350071 ~: ~. 2 PS2 (~.PS 350071 p~4 PS2 CPS 350071 R~6 PS2 CPS 35()071 R~,'7 PS2 CPS 350071 RN g PS2 CPS 350()71 ~ I'<: 9 PS2 CPS 350071 ~.:'.I0 PS2 CPS 35007! R~)II P52 CPS 350071 ~ ~ I. 2 PS2 CPS 350(:,71 .~ ~; l, 3 PS2 CPS 35007~. ~;I~ ~S? CPS .350071 Rh~15 PS2 CPS 350071 [{[~ 16 PS2 CPS 350071 [~FI P~32 CPS 350071 RE2 PS2 CPS 350071 PF3 PS2 CPS 35007 t. ~F 4 I'.~S2 CPS 390071 RV5 'PS~ CPS 350071 tcF'i PS2 CPS 35007 ! PV8 P~2 CPS 350071 PFO PS2 C¢S 35007 ] ~F!f> PS2 CPS 350071 RE'I ! PS2 CPS 390o7 l PF!? PS2 CPS 35o{)7! avl3 PS9 CPS 3%O071 PFla P:32 C¢S 350071 RFI5 P82 CPS 350071 PFi6 PS2 CPS 350071 GP PS2 G~P! 350071. T~;~S PS2 !.,~ 35oo71 CCL uS2 V 350071 ~ b£JG irYPE CLASS ~(~!) a[iaB S ! 5 ! 0 () 0 0 C! 0 2 000 OO 0 ~ ~ ! ! 000 00 0 I 000 00 o 2 ! 0 o 0 · .,l, 0 o 0 0 I 390 00 0 2 1 51 000 O0 0 2 1 i 000 00 0 51 ~90 0i 0 2 5! 390 02 0 2 ! I 390 03 0 2 ! i 390 04 o 2 !. 5! 390 05 0 ~ 1 5! 390 O6 0 2 i 51 390 07 0 2 ! !. '390 0 ~; 0 2 ! 1. 390 () 9 0 2 ! 1 39 0 ! {::, 0 2 ! 51 390 ! 390 12 0 2 1 51 390 13 0 2 51 390 14 0 2 !. I 390 ! 390 16 0 2 l 5! 391 0!, o 2 1 1 391 02 n 2 5! 391 03 o 2 ! I. 391 04 (~ 2 1. 1 ;t91 05 () 2 1 .39 ! 06 0 2 ! 51 391 07 0 2 1 ~ 39 ! 0 ~ 0 2 1 I 3 9 J. 0 9 0 2 1 5! 391 !0 0 2 1 5! 391 11 0 2 1 i 3 ~ !. 12 o 2 l 51 391 13 0 2 51 391 !4 0 2 !. 51 .~Ol 15 0 2 1 Sj 39! !6 0 2 1 51 31o O1 6 2 1 51 635 2! 0 2 1 51 t 5 n 0 ! 0 2 ! 1 1 1 ! I1 1 ! 1 1 1 1 1 1 1. 1 UMB SIZE REPR PROCESS 4 8 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 OOOO000000 .4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ~ 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 68 0000000000 4 6H 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000000000 4 6R 0000000000 4 68 0000000000 4 68 000000O000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 go00000000 4 68 0000000000 4 6H 0000000000 4 69 0000000000 4 6H 0000000000 4 68 0000000000 4 6~ 0000000000 4 68 0000000000 4 6~ 0000000000 4 6~ 0000O00000 4 68 0OO0000000 4 68 OOO000000O 4 6~ O000000000 a 6~ O00000000O ** ~ATA .chlt.]~berqer g].aska Co~ot~ti. nq Center P?, 12096. 000 SfG?!,PS2 'iSHl.?, PS2 44,188 SFFO,PS2 ~'.'~ ~'{ ~ ,S 2 57 1732 F T D T A~ F'D, PS 2 9:0 ' Pq2 77 156 C~,PS2 I '~ I C. 52 P S 2 ..... :000 TC, PS2 I, 439 ~N4, o2 I5~i, .. PS2 705,,!92 R~a. P82 1.2, ............... ! 6, P,S. 2 7 ~ O, 227 RFI, PS2 ~F4. PS2 38 it, 5213 RFS.PS2 ~?'~, P82 340' 909 RFg,P82 RF'!2,P82 430,87! CF13.P55~ RFI. 6, PS2 151,51 5 GR,P82 PF:pT, !2000,000 PS2 39,906 8FFO PS2 [" ~"'S 2 1 45,32 '~ lSFp I.... , ~.~C~: .Pg2 1.69, ~135 Tc?jr,, P82 24830,4()2 TCFD,PS2 S~TC, PS'2 i, o0n RN 1., 082 Ri':;4' PS2 ! 526,442 R~5, PS2 ~!~, PS2 747. ! 95 PN9. PS2 RN! 2,.P82 2804,4~7 R~<i! 3,P52 p N ! e, PS 2 831., 330 ~RF !., PS2 ~F4, P82 437.88~ RF5, PS2 o2 347,222 ~F'q, PS2 RFI2.PS2 941.35~ PP13,PS2 ~F ! 5. PS2 235, ]39 GR, P82 ! SHU. P,L.52 40.53a4 A~FD.PS2 126.'!33 AF~D.P82 S I~H. PS2 44,400 ~:4~[)F, P52 ~ACF.PS2 179.771 Ft:~C.P82 TCHU,PS2 26136.59~ TCFO.PS2 I~qD,PS2 I 310,(>42 S~TC,P~2 ! .000 RL'I.PS? PN4.P52 ! 383,102 Rt.15. PS~2 ~I~. P82 734.954 ~Pg. P82 R~ 12. PS2 3 ! 34,645 R"~ 13, P82 PF4. PS2 38~. 62) RF5. PS2 ~F8, PS2 334. 535 RF' I, 2, PS2 1 ~)85,737 RF1 ~. PS2 t!~16.P32 318.510 20-00~.~-!, 990 1,5: 2~! 43,950 $ fL...!, ...... 45,1. 64. 8 F' ~.! ['>, P $ 2 3,2 o. 7 N T D T. 'pSp A ~2 I. , 204 T~AT, PS2 37.2.q:9 TCAN.PS2 3308, 3 TSC~'-.:,. o2 342' 9 TTEC,PS2 ~52,8~:il RN2.P82 1292,614 RN6,PS2 i 600.379 R ,'::; ! 0, P 82 ~9,356 ~F2.P82 6,705 ., F6,PS2 ' ~" 54:5 R~i o, P82 4>4, .... ]59,848 RFI4,PS2 ~6,4;38 :TENS, PS2 17.238 8TDT P82 .. 19 , !. 9 ! S F h' [) ,. P o ~' 2 10,794 t, JTDT.PS2 44.7,4i:~3 1,!97 T[~AT,P82 34,665 TCAr~',PS2 8:0a5 425 TSC~,~,P82 ,, .,.. ~ ..... 41.0.oo8 _T~..(,, 73!'!70 k/~2.P82 i626,60~ RNG,P82 ,, . ~' 18q7,035 2672.2'!5 R{q14,P82 293,210 RF2,P82 439,815 RF6, P:~i2 634,~5 RI'lO,P82 939.429 RF14,PS2 42'438 T~S,PS~ 66 43 12 4.1! 4 43420 !347 0 1!93 !420 416 740 ,000 TPHi,P$2 .950 SBHF.P$2 (}81 AFFD.PS2 ,903 $IGC,PS7 160 SDSI PS2 253 TCAF,PS2 397 TSCF,PS2 000 HV,PS2 600 RN3.PS2 182 RNT'PS7 454. RNil P$2 621 R~I5 PS2 12o RF3 PS2 826 RF7 PS2 667 RFll.PS2 212 RFI5,PS2 ,00o CCL,P$2 66,000 2!,459 29 120 .474i977 7 413 63.140,927 6167,698 0,000 164 475 1754:808 1963.141 2075,320 32 895 49J:898 652,006 835,762 !1.10.000 15.~43 8TDT.PS2 66,000 !7.5&1 ,:82 19,585 11o9q0 NTDT.~S? 37 580 453,86,4 A~!;'), 52~ 4471451 lbl. 7~AT.D82 2 447 3 1426 TCA~' PS2 77()(~5:6~6 ~591,408 TSCi.!,P82 7560 801 'J9~.510 ~TFT. C,PS2 C:O00 692 515 ~h2,PS~ 178.0~O 1514~275 [~6,P82 1790.123 1830 633 P~:10,P82 1961.805 32C)9:~76 R,..,14.PS2 2824.074 296.474 RF~.PS2 32,895 ~34,6~5 ~6, .... -, PS2 5n6.811 68~.090 RFIO,PS2 641,026 11~3,894 ~F!,!.P32 1065.705 31.964 %:E~S,PS7 l!10.nO0 TPHi,PS2 8B?IF,PS2 AFF'D,P82 $I'gCiPS2 SDSI,PS7 TCAF.PS2 TSCF,FS2 HV,PS2 RN3.PS2 R~7,P82 RNll.PS2 R~!.5,PS2 RF3,P$2 RF7.PS2 RFll..PS2 RF15,PS2 CCL,PS2 TPHI,PS7 SBMF.PS2 AFFD.PS2 SDSI.PS2 TCLF.FS2 TSCF,P82 HV,PS2 RN3.PS2 R~7.PS2 RNll.PS2 PN!5,PS2 RF3,PS2 PF7.PS2 ~FI!..PS2 RFIS.PS2 CCI,.PS2 PAGE: !6 76,971 54,838 92,646 o,0o0 0 909 10289 955 322 691 201 500 1306 818 658'144 162 053 ]36;174 19ii864 2 833 8 394 0,000 26,795 37,677 102,978 1,994 0 400 26171 051 2556 427 235 250 1103 766 1!55 849 7796 474 1356 170 30~ 784 354 938 906.636 513.1.17 0,000 27,510 34,590 108.795 1,783 0 310 314732133 3090,189 235,375 1037 809 1311:728 2939.~14 1855 710 2841455 392 628 909 599 711,138 0,000 IS ?:ape Verification !iistinq chlumberger ~iosKa Comput~.nc! Center IS}4UoPS2 40,344 ......... P a 2 45 001 F e ]'2~ PS~ 47,552 ~ ......~ ......... PS2 'I~4 652 BAC~, PS2 ~8227' . ,266 ~CF[:) Pq2 ............... , P ~ 2 '~:~'PS2 lz~06 250 RI?5 PS2 R~1.2 r~S2 324~,457 RN!3 o52 R~ J. 6, PS2 1346,450 RF1: PS2 RF4,PS2 394.63! RFS.PS2 ....... P S 2 334,535 RFC'ps2 ! 19.3,9~.0 f~F!.3,PS2 RF!6,..,'~z 5~4 824 (;~,PS2 20-dL~N-! 9. 90 !.5128 :1.2,875 !3,787 i2,5~2 5] 6.0 74 ..!., 14(3 33,483 9797 0!6 394 766 7!7 593 1568 2~7 3584 104 300,481 416,667 653,045 1366.1, b6 23.625 DEPT, I. 170(i,, 000 $ IG~--~., PS 2 29,138 STDT,PS2 isHt-~ PS2 35 1sa SFFO,PS2 32.1~8 SVNi").P52 $~:~H~ PS2 47 ~34 ~mD'r ps2 7,907 NTDT,{..-~2 ADF'U:, PS2 1i. 9.867 AFND,P82 484,772 S!~,PS2 54'703 ~t~40F, P82 !.~97 ~"RAT' PS2 BACF'.,PS2 18~,809 FBAC PS2 37,785 TCA~ PS2 7 C"D' 'R . TCt.:~D , PS2 i~8 3.730 T ~F ~.. ,P,. 2 5757,271. , PS2 ! ~';~'~D , PS2 1268,~:~91 IHFO,PS2 382,320 TTEC,PS2 S~TC,PS2 I ,C, 00 RNI,PS2 709'876 ~N2,PS2 .... ~qo 1.593'3~4 RN6,PS2 P?q~,P~'2 740,741 b~;~9 PS2 1~59 568 .RN10,os2 [) , ~ ,,, · ~ · .. R~:12,PS2 2.376 , 54 '.] R~.!I 3,P82 2(')I t). 031 Rt'.~I 4, PS2 , ...... * ... .. ~ .... R~:~1.6.P~9 725,30q PF1, ~2 2E7,423 PF2,PS2 PF"4. PS2 4.10,8~0 i:~F5,PS2 424,383 P[6,P82 RF'?.PS2 306,713 RFg,PS2 634'645 ~FIO,PS2 R~12,P.S'2 779 32! RF13,PS2 628 858 NFJ. 4,PS2 ........... t~' PS2 66 000 3:1. 277 442 467 95494 578 9369 014 0 000 fsi 890 17S@ 194 1@82 716 3393 132 35 383 514 824 65]; 042 1372 ~95 1~:10 0o0 66.000 34,491 23,661 451.792 2,793 5'1072,500 3!17,873 0 000 187,695 1635.802 1857,639 1342 593 29i025 437 886 S0,633 14,738 1~20,000 DEPT '! 16(~0, ()O0 SIGM,pS? !.0,543 STDT,PS2 66,000 , ISi!Ii,PS2 39,g06 8FFD,P$2 1j.,179 SFN[~,PS2 12,127 S~:.~, PS2 ~4,700 FTDT.PS2 15. 32(') N~'DT, P.S2 29,679 A~FP,PS2 149.4~1 AFNn. PS2 558.339 AR~), PS2 463,253 S~ t~.~, P52 46.~50 ~.~qOP. PS2 1 .212 ~'p~'r, ps2 1 bACv,PS2 1~9,'78a F'{~AC, P82 34,5!4 TCA~,~S2 112178~188 TC~D.PS2 30'~2l., 25~ TCFO.PS? 13109.3~3 TSC:.~, PS2 11122.771 lr ~r'~. PS2 12~.{~3I INFQ,PS~ 452.804 TTEC,PS2 0 0o0 SAq C, PS2 I. ('~() r) Ri'~l ,PS2 7('5.128 ~NP,PS2 193:500 P~,4.PS2 1426.2~2 P¢5,PS~ 15~0.529 RN6,PS2 1838,q42 P~ ~, P.S2 7~1, l~o RkO,PS2 1816,907 R~.,1. O. PS? 1923. C77 ~['!2.PS2 3~7q..}07 R:~:I 3.P52 3052,323 RN14,PS2 3978,365 pr~ 1. 6, PS2 1800, ~8 ! RP'i. PS2 3(>8.6~2 p~ 2. PS2 25,155 FP*4,PS2 472,60~ PFS.PS2 536,265 ~F~.OS2 621,142 ~F~,PS2 35~,7qf~ ~F'n, P~2 7~7,747 PF~IO,PS2 785.108 P~ !.P,PS2 !46<4. !20 P F' 1. ']. r:'S 2 186q,213 ~'! 4.PS~ 2o33,179 P~ !¢.PS2 9&0.54~ (;R, P82 2e,922 T[kS.PS2 1095.000 TPHt,PS2 $SHF,PS2 AFFD,PS2 $IGC.PS2 SDSt,PS2 TCAF,PS2 TSCF.PS2 HV P82 RN:3 PS2 RN~ o2 RNil PS2 RF3 RF?,P$2 RFtl.,PS2 RF15'PS2 CCL'PS2 TPHI,P$2 SB}iF,PS2 ~FFD,PS2 SIGC,PS2 SDSI,PS2 TCAF,PS2 TSCF,PS2 H¥,FS2 RN3,P$2 RN7,PS~ RNll,PS2 ~N15 FS2 'BF3:P82 RFJ,P$2 RFII.P$2 RF15.PS2 CCL,P$2 TP~I.PS2 SBHF,P82 AFFD.P$2 5IGC.PS2 SDSI,P$2 TCAF.PS2 TSCF,P$2 HV,PS2 ~3,P$2 Rh7.FS2 ~Nll.PS2 ~N15.P$2 RF'3.PS2 PFT.FS2 PFll..PS2 ~F1S.PS2 CCL,P$2 PAGE: 17 23,550 36,732 1~,245 0,928 0,1.97 42276,875 414.7,80] 235.375 1020,448 1325,231 2920,524 2528.935 280,449 422,676 1001.,603 1091.747 0,000 39,162 41,579 !l ~93. 0.589 1922~81.3 111 ~45'7 235,375 1064,815 974,151 2571 373 842 978 291 281 295 204,475 0,000 13,262 36.199 134.336 0.6!1 0.153 62815,820 6228.358 235.500 1045.~7] 1434,295 2934.695 3221,154 326.003 611,497 !~2,994 1~13,27i 0,000 cblum~erc:~er al, as~::a Computinq Cent. er ° 'PS2 46,438 SFFO, 42,528 FTDT.PS2 !44,97! AFN[),p . 203 11o F:F~C,PS2 2974 g ~ 32 ~ 'r .: ~:~, ......... !272,45~ IF~FD, PS2 1. 000 ~41. PS2 t. 44~, 901 RN5, P:S2 719,522 'R~'~'9,PS2 !626.:157 RF1,¢, 2 <~57, ! 76 ~'~FS, PS~ 366' 5 ! 2 RFg, P82 1396,605 Rffl3,PS2 'ISHt~,PS2 39.906 ~FFO,PS2 8BHN,PS2 46,083 FTDT,PS2 ABWD,P$2 147,5q0 ~.PNr), PS2 SISH,PS2 4ii, 93[~ g~4[)F, PS2 BACk,PS2 2!.0,790 FGAC.PS2 TC~':~D.PS2. 2P016,223 TCFD,PS2 ,.. ,. ~' ., p r,~' 4, p $ 2 153 ~h, 45 ~¢ ~ N 5. [:' 52 R~'~12,PS2 3253,348 R?,~!3,PS2 RN 1 ~;. PS2 1268, 02 4:~5,247 PFS.P52 '8, PS2 393,5 RF...2.PS2 ! ~q6. RF I 6. PS2 520, ~]3 ? (;[~.. P52 2 O"'d Li~'!- !990 15:28 11,27!. STDT,PS2 !!.,900 SFND,PS2 14, ~88 :NTDT,PS2 5813,217 ABNO,PS2 !. 209 T F~: h T, P 82 36,720 12337,19I TSC~:~, PS2 454,C~60 ~[EC,pS2 q'"~ "" ' PS2 717.593 1631.944 g~F~6. PS2 1836 420 R?~IO,PS2 3854 !~7 R~,~ 14. P82 318 287 ~F2,PS2 480 324 v~F'~,PS2 '!~' .... .096 RFIO. PS2 !.618,4.~:! ~F14,PS2 26'64:! TF;NS,PS2 1.3,899 S'I::!)T, P82 PS 14,8F19 SFN[),-, 2 1.5,4~t7 f~ITDT,PS2 512'617 ABND,P82 1,159 T~AT,_ ~2 3 ¢. 9 ! 4 T C A ~..~. P S 2 1436.9t~9 TSCi;, PS2 444,375 TTEC,PS2 708,705 PN2,... 82 1588,542 ftys6, 1927.083 R ~,,,: I o, P L; 2 34b;9,583 Rt~;14,P82 29~.997 aF2,P82 497,685 a:F6,P52 7e5,818 RFIO,PS2 1645,448 P~'14,~S2 29.875 T~:~S, 82 66,000 13 051 30 325 462 133 1. 857 1. Ii 0495. 594. ., 0560,584 0.000 192,640 I. 849,923 3734.568 29,025 6.883 1770.000 1.095, . 66,000 16,671 32,205 459,823 !,862 91904,594 2779,922 0 000 211 560 1~52 678 1973 586 3177 083 36 765 630i787 779 321 1630 015 1080: 000 [; [!;Vl., I 13f)o. (lr~') Sla:~,l. o2 35,14. i) S~ [.)T, t)S2 66,000 IS!411,PS2 40,7~1 SFF'),PS2 37,4. h2 SF Nt>.PS2 38.]!8 o[~.PS2 5(':~, lc'~4 FTDT.PS2 6,6~)2 ~ Dq", PS2 21,819 ~PFr:;,PS2 ['1%,1.4~ ~F'<[') P82 51.8.843 Af:~Nf),PS2 474 480 "I RP e ,., PS2 3 202 P,.,2 60,509 ~,~{')v PS2 1, o ....... ', .... 146 TRA'r, a~Ck*PS2 2! 1.2(')0 F'~AC, PS2 44,90~ TCA;.4, PS2 51928,586 TC~,~r:. PS~ !.q634.8~] 'rCFO. PS2 5258.5~3 TSEtse.PS2 258~,013 :! ~r' ps9 1270.436 T,'~F!), PS2 31)2.415 TT~.:C. PS2 0,000 ~' ' . "' '".. P82 723.[ea F'[;2.PS2 206.400 ~':P.PS2 721 ,726 R~.~ F'S2 l~bS,6'4q R~.I(~.PS2 1Rq5.461 R~¢!2,P.S2 23n~,'~07 R~.~ t 3, ~8'2 1a41,518 R~14,PS2 1~71,875 h'hlf,PS? 825,093 RFI,PS? 256,559 FF'2.P$2 48.375 ~F'~.PS2 -4n7.022 ;~F5 Pn2 4Ol.235 PF6 ~S2 445 602 .... - · .' *. ': -' F~P ['S2 2~'7.423 RFO P52 5~0 633 RFIO' . .......... - .PS2 592 20'1 P~ 1.2,PS2 6~2,~7¢ t-~Fl 1.P52 553,~26 ~F'! 4.PS2 312.500 = . . . . PS2 !OqO OO0 Fw!6 PS2 163.96~ (:;P t:'S2 70.125 T TPHI.P$2 ........ PS2 .~FFD.PS2 StGC,P82 8DSI,P$2 TCAF,P82 TSCF'!'ps2 EV,P82 R~3,PS2 R~7,P82 RNI!,P82 RN15,PS2 RF3,PS2 RF7,PS2 RFi I. P 82 RFi5,PS2 CCL,P82 TPH!,PS2 8BHF,P$2 AFFD.P82 SIGC.P52 SDSI,P82 TCAF,P82 TSCF,P$2 },iV,PS2 R~!3,PS2 RN7,PS2 RN!I,PS2 RN1.5 PS2 ~r~ls2p' ~F7 ~Fl!:P$2 RFI. S,PS2 CCL,P$2 TPHI'.PS2 SB~F.P$2 AFFD.PS2 SIGC.PS2 SOSI,PS2 TC~F,P82 TSCF.PS2 HV.P$2 R~3,P82 RN7.PS2 R~ll.PS2 RF3.PS2 RF7,PS2 RFII.P$2 CCL.PS~ 14,224 35,483 130,825 0 706 o !,75 59495 773 5686 291 235 125 1.072 531 1413 966 3018 904 2995 756 316 358 50~ 543 1163 194 156'8,287 0,000 15,300 35,397 129,733 1,123 0 248 49358 719 4715 387 235 000 1073 289 !3!3 006 3041 294 2230 282 320,216 511 188 1!76;698 1188,271 0,000 52,452 45.739 123.292 1,620 0.716 15657.234 8o8,263 235.000 1151 414 987~723 2565,104 ~07,292 293,210 277,778 777,392 167,824 0.0GO IS Tape veri..fication L.i, sti. ng cblumberqer AlasKo Compt!tir~a Center I 1200,000 SIG~4, P$2 46,43;9 SF'FO.PS2 sa,aa6 FTDT,PS~ 79,774 ~iaOV,PS2 2!4,244 Fi3AC,PS2 146i~9,965 TCF?~,P52 1,000 RF~I pc .... · ps 2 1 396,605 ~:~5,.. ,. 1651,234 a~'.}l 3,P82 765,81~ RF'I,PS2 329' 861 }..~FS.PS2 2~ 1.6]6 ~Fg, PS2 " POq RFI3 PS2 C.'. PS2 5~.250 .,~,. i)E'p't:, ! 1 t 96, ..... I. S ~'~ U, P S 2 45,5 63 [)F, 2 5f~ t77 A B ~' r.'~, P $ 2 92,294. Sl'laH, ¢82 73,629 P G 2 20 q 683 ~:3~C~, pS2 1543 i ' 738 T C ~? D, ..... , I ~ '~..~ P, P S 2 ! 295. 'l 35 S~TC.P...g2 I, 000 ~:~4 PS2 !410, 10[~ ~r,~a ['ps2 "744.599 R~ !. 2 PS2 1747.685 ~tc:, 16 [ PS2 729,167 ~:P4~ PS2 333,'! ! 9 ~F'~. PS2 277. 778 ~'!2'P52 .~97,685 ~F!6.P82 16n. 1 08 ** [~",Jt'7! ()F DATa ** 20-jUN-!990 !.5:28 38,247 STDT,PS2 39.9~:~o SFNb,P$2 3.809 NTDT,PS2 4 ~ ~1,026 l B ~..~ !:~, P S 2 1. 141 TRAT.PS2 4 I., O O 7 T C g ?~, P S 2 3503.853 TSC~, PS2 7 ,096 R~2, 1.398,534 RN6,PS2 i622,299 RNIO,PS2 1282,793 268 237 , 314,429 RF6,PS2 ~33l:790 RF!4,PS2 62.594 35,!74 STDT,PS2 3'1,023 SFbtD,PS2 4,519 NTDT, PS2 438,2~:9 ABN[),PS2 41'0 6g TRAT PS2 , 7B ~'CAN, PS2 38 S 9,294 TS C ~, P S 2 T ' PS2 346 , 17 ~ T_ 707,948 RN2,PS2 i408,~79 RP~,PS2 165~ ,~34 ~N10,PS2 1404.321 RN1.4,PS2 244,9~5 PF2,PS2 337.577 RFS,PS2 493,~27 ~F10.PS2 62,654 359,8! 3 66.000 41,938 13,871 396,383 3.472 33099,9}.4 Iso]. 9 0 000 222 525 1338 734 1529 707 837 191 36,765 324,074 387,731 ~04,475 1070o000 66.000 3~,883 15.408 406.932 3,247 36508.555 180t,003 0 000 2()7~045 137!.528 !568,287 875,772 34,830 331,790 4:30,170 244.985 !075,000 TP~I,PS2 SBuv PS2 .... -i~,~ AFFD,P$2 $ :I ('; C , PS2 ot).:. I ,PS2 TCAF'PS~ TSCF,PS2 H¥,P,.2 RN3,PS2 RNT,~S2 RNIS,ps2 RF7,P$2 RF~!,PS2 RFIS,PS2 COb,PS2 TPN!,P82 SB}..~F,PS2 S!GC,P82 SDSt,PS2 TCAF,P$2 TSCF,PS2 EV,P$2 RN?,P82 R~I1,P$2 g" PS2 .~15. RF3.PS2 RF7,P$~ RF!l.P$2 RF15,PS2 CCh,PS2 ~AGE~ 19 64 291 52 585 88 286 I 826 I 125 8886 854 432 986 235 125 1026 234 775 463 2035 108 71:3 734 266 204 173 6tl 499 614 I48,534 0,000 58,414 54,41~ 86.73 1'808 0.913 10559,998 554.705 35,125 1 78.318 60,031 2021,605 748,457 256,559 200,617 580.633 177.469 0o000 iS Tape YerIf:ication List. ir.~q chl~.~,m~er<Ter g~laska Cont?utin:~ Center **** FILE H E;A [)E;R **** SFRVICF,: : FglC DATF : 90/06/20 ~-~A.X REC SI:gE : 1()24 FILE TYPE : 1..,0 20-d ii i:'~-, !. 9~ (r.t !5:22 PAGE 20 , * F' 'I', L E .,. g !) .'I' T . 00 3 :* ~P EXPDORATIOi'~ * ~'-!3 * 50-029-2 t 757 , , , , , , , PRd[)[;O~] DAY Field Name K-!3 Well ,Name 50-029-21757 AP1 Serial Number 1804' ~:~L g 41~7' FEI~ Field bocation 4 Section ill TO~Dshjp ~LAS~:A State or Province {iSA Nat iOn C A ~l,.~: witness' ~ame IS Tape Verif.!lcati. or'~ Li. stinq chlumber'<:!er Alaska Co~'.puting Cent. er 990 15: 28 ?AG~: 21 T U ?,i ~ V A L t:i D E F i S~.:,. 5 Serv. ce Order Nu~.ber pD.A.T ~4 $ [.~ Permament datu~ E~D F'r 0, I..~<:F FB boq ~e~sureO From ~:PD FT 54,3 [~: ~: ~ FT 54,3 KCL ~'..' 23,9 T D r7 F T 12063, ........... ' .... [>~]['t''~''"''''''',~;;'''Channe l t:: ..... ' ....... ''''''''"'''''''' .. Sigma (:~.;eutror: Capture Cross section) Status of TOT TDT Porosity 'Ti3T 8hu~t Current StOma formation - far detector Siqme forr::atlor~ - nest det. ecto~ Si, oma borehole - f}:ar detector T Slqma borehole - near detector (TDTP) ;',{ear TDT~: Count;. Rate ~moltt. ude formatl, on --:far detector (~DTP) Amplitude t.~orehole -- Far detector (T[.)TP) Am~!itude format:ion - near detector .~?,~lltude ~orenole -- near detector ('rDTP) S ! C[,:~ Correction ~orehol. e sIqnt8 (corrected) -- *~in!tron :Code monitor ratio star, doral devfati, on of Siqma-formatton (TDTP) 8aCkqrOUnd, Near Gates Far RaCkgrot~nd Total cour~ts analyzed - near detactor (TDTP) Tots1 cOUnts analyzed - for detector (TD];P) ~'ot4.,! cour~ts - near detector q:'otol counts - far detector (TD~'P) Selected nates count rate - near oat. actor (TDTP) Selected ,cotes co~nt rate - far detector (TDTP) Inelastic countino rate - near detector Inelastic count:ina rate - far eetector (TDTP) TDT-P Telemetry Frror ~ead Voltaqe Status oi ~aw .~ear 1st Gate Raw ~,~ar 2n<~ C;at~, Po,~ r~ear -'!tn Gate IS Ta~e Verificatlor) t.,istin(~ c'blUm'her(~er ~laska Con".put.ir~O Center !5:28 ~:~6 Raw ~:~ear 6t.h (;ate RN7 aaw ~ear 7th (;ate RN9 Raw ~'4ear 9th (;ate R~I? qaw ~4ear !2th Gate ~¥ 1 3 Raw ~¢:',~ear i. ]t.h Gate RNI~ Raw Near 14t. h (;ate RN15 Raw Near iEth Gate ~NI. 6 Raw r.4ear' 1,6t~ Gate RF! Raw Far 1st (;ate ~F2 Raw Far 2nd (::ate RF3 aaw ~ar 3rd Gate RF4. Raw Far 4th Gate RF5 '~aw Far 5th Gate RF6 ~;~aw Far 6th (;ate ~F7 Raw Far 7th (;ate R~8 Raw Far 8th Gate RF9 Ra~~ Far 9th Gate ~FiO P~a,: Far loth Gate UFll Raw Far !Ith Gate RF12 Raw Far i2th Gate ~'F13 ~aw Far 13th Cate R~'14 ~'aw Far 14th Cate ~':15 Raw Far 15t. h 6ate ~'~a ~aw Far 16th Gate T~:NS Tension CCI., CC~., Am[~lltude 2~ DATa F(jR?,~,AT SPECIFI. CATIr~N PECO~{> ** SET TYPE I8 Torte verifi, eation bistinq ¢!'lU,~berger Alaska ComputinP Cer'~ter 20-Jt.; ~"~- ! 990 15:28 PAGE{ 23 I TPHI PS3 SF?~{> PS 3 S~ ~.~ F PS3 CU FTDT PS 3 CPS NTDT PS 3 CPS ~F'FI> PS3 CPS AB'FP PS3 CPS A F ~':~ F~ PS3 CPd ~ ~ ~P PS3 CPS GIGC PS3 SIEF PS3 Ct~ ~f'tF P8 3 T[~A!: PS 3 SDS! PS3 BACk.; P83 CPS F~C PS3 CPS TChN P83 U"C ~F PS 3 TC ~' Ps3 C'P8 TCFD P8 3 CPS TSC?~ PS3 CPS TSC~' ~83 CPS I~FF PS3 CPS ~ V P S 3 v 8BT~ P83 R~ 1 oS 3 CPs Pr,'2 PS3 CPS P~'3 PS3 CPS P~':4 PS3 C~'~8 ~N5 PS3 CoS ~:~6 PS3 CPS ~r~? PS3 CPS ** SET ~"'!PE '" CHA!~ ** RV :~,..IT ....... iC!.C ~ I API O ORDER ~ LOG TYPE " O0 1 0 0 ,, 0 350071 5!. 400 Ot 0 3 ! t 4 35007 ! 51 390 O0 0 3 !. 1 4 .,150071 51 ~90 Ol 0 3 ! 1 4 350071 5! 000 00 0 3 i I 4 350()71 5t 400 0:2 0 3 ! 1 4 350071. 5! 400 02 0 3 t ! 4 3 .~ ()07 I 51 4 o 0 01 0 3 ! 1 4 350071 51 40o 01 O 3 l 1 4 350071 51 00() 0() 0 3 1 1 4 350071 51 000 00 0 3 I ! 4 350071 51 391 00 (~ 3 1: 1 4 350071 51 391 O0 O 3 I ! 4 350071 51 39 (;, 00 0 3 t I 4 35007 I 51 390 O0 o 3 ! I 4 350o21 51 400 01 0 3 I I 4 350071 51 400 O! 0 3 ! I 4 35097 I 51 000 00 0 3 1 I 4 350071 51 O0o OO o 3 ! 1 4 350071. 51 000 OO 0 3 1 1 4 ] 50 () 7 ! 5 !. 39 (.) 17 0 3 1 I 4 35o07 ! 51 391 17 o 3 1 1 4 35007 ! 51 000 O0 0 3 ! 1 4 35007I. 5! 000 O0 0 3 i ! 4 ~5007 ! 5 ! 000 CO 0 3 ! I 4 35no71 51 000 O0 0 3 1 1 4 35007 ! 5 ! O()O OO o 3 I ! 4 3%007 ! 51 <}0o O0 0 3 l 1. 4 35007 '! 51 0()<) O0 0 3 1 I 4 35007 l 51 0 O0 OC) 0 3 ! 1 4 350071 5~ 390 O0 0 3 I 1 4 35o{;71 51 00o OO 0 3 1 1. 4 35 ,') (.~ 'l 151 0 t) 0 (; (, 0 3 i 1 4 35n071 51 390 Ol () 73 I 1 4 3b0071 5! ~'90 02 o 3 I 1 4 350(;71 51 390 03 9 3 1 1 -~ 35()o7! 5! 390 04 o 3 ! I a 3q007 ! 51. .~9~) 05 0 3 1 I 4 350071 5 ! 39~ 06 u 3 ! 1 4 350()71 51 390 07 0 3 1 1 4 REPR PROCESS ¢OD~::: {HEX) 68 0000000000 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 000000(>000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 O0000000OO 68 OOnO00OO00 68 00o0000000 68 0000()(}0o00 68 O00OOOO0OO 68 O000UO0000 0000000000 68 00o0000000 0000000000 0000000000 68 0000000000 68 0000000000 0000000000 68 OOO0000000 68 0000000000 6B 0000000000 0000000000 68 0000000000 68 0000000000 O00000oO00 I~ Ta~:e Verifi, catI, o~ bistinq chlumberqer Al. asKa C,-omputir'~ Center 2(}-j[JN-t99() ~5:28 PAGg: 4 [~ ~ 9 P ~, 3 C 'P 8 3500 ? 1 5 ! 390 09 O R~.: 1C I783 CPS 350071 51 390 RN!! PS3 CPS 350071 5! 390 1! R~,~12 PS3 CPS 350071 S1 390 !2 0 RN13 PS3 CPS 350071 5! 399 13 0 RNI~, PS3 CPS 350071 %1 390 14 0 PNI5 PS3 CPS 350071 51 390 15 O R~: ! 6 PS3 CPS 35(1071 5! 390 !6 0 RFI PS3 CPS 350071 5!~ 391 R~':2 PS3 CPS 350071. 5t 39! ()2 RF3 PS3 CPS 350071 51 39t 03 O RF4 PS3 CPS 350071 51 39l 04 O ~ F 5 P S 3 C P S .35007 ! 5 ! 39 ! 05 O RFa PS3 CPS 35C~071 51 391 06 RF7 PS3 CPS 350071 51 39! 07 0 RF~ PS3 C~S 350071 5! 39! 08 0 RF9 PS3 CPS 350071 51 :'t91 09 O RFIO PS3 CPS 350071 5! 391 ~0 0 RFll P83 CPS 350071 51 391 I1 0 RF1.2 PS3 CPS 350071 5i 39! !2 0 RFI3 FS3 CPS ~50071 51. 391 13 0 RFI~ P53 CPS 350071 51 39!. 14 0 RF15 PS3 CPS 350071 51 391 15 0 RF.I6 PS3 CPS 35n071 51 391 !6 0 G~ PS3 GAP! 350071 51 3!0 O1 0 T ~ i'<~ SPS3 I.,P. 350071 5!. 635 21 O CCL Pt53 V 350071 5! 1.50 01 0 l~:~i.!Ml5 Sh~4P ELE~4 CODE (HEX) ., 1, 1 4 000 O 3 I I 4 68 O000OO0000 3 i 1 4 68 0000000000 3 1 I 4 68 O00OOOO000 3 I 1 4 6~ 0000000000 3 1 I 4 6§ 0000000000 3 1 1 4 68 0000000000 3 1 I 4 68 0000000000 3 1 1 4 68 0000000000 3 I i ~ 6~ 0000000000 3 1 I 4 68 0000000000 3 1 i 4 68 O000000000 3 I 1 4 68 0000000000 3 i I 4 6~ 0000000000 3 1 1 4 68 0000000000 3 I 1 4 68 0000000000 3 I i 4 68 0000000000 3 1 1 4 68 0000000000 3 1 1 4 68 O00000©OOO 3 I ! 4 68 0000000000 3 1 1 4 68 i~ ! ! 4 68 0000000000 3 1 1 4 68 0000000000 3 1 I 4. 6~ 0000000000 3 1 ! 4 6~ 0000000000 3 1 1 4 6~ 0000000000 3 1 ! 4 6~ 0000000000 3 1 1 4 6B 0000000000 * * [> A ,,.r fi * * ~F:}4~,, PS 3 Sa, l 77 FTDT, t>53 ~ ¢ FF, PS 3 92,294 ,~F~.~7), PS 3 BACF. 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