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181-017
STATE OF ALASKA ALASKA~ AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ~ Abandoned ^ Suspended zonnc zs.,os Zoanc zs.,~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ~ Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.,,f _ 6!8/2009 ,, I~~ 12. Permit to Drill Number 181-017 - 309-127 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 04/24/1981 13. API Number 50-029-20559-00-00 ~ 4a. Location of Well (Govemmental Section): Surface: ' ' 7. Date T.D. Reached 05/09/1981 14. Well Name and Number: PBU H-13 ~ 1652 FNL, 1264 FEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 1194' FNL, 814' FWL, SEC. 22, T11 N, R13E, UM 8. KB (ft above MSL): 82.6 ` Ground (ft MSL): 45.35 15. Field / Pool(s): Prudhoe Bay Field / I~rudhoe Bay Total Depth: 1212' FNL, 1128' FWL, SEC. 22, T11 N, R13E, UM 9. Plug Back Depth (MD+ND) 9759 ~ 9287 Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 2~: Surface: x- 643332 y- 5959136 Zone- ASP4 10. Total Depth (MD+ND) 9805 ~ 9329 - 16. Property Designation: ADL 028284 - TPI: x- 645400 y- 5959634 Zone- ASP4 Total Depth: x- 645715 y- 5959622 Zone- ASP4 11. SSSV Depth (MD+ND) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ~ No Submit electroni n rint inform tion r 2 AA 2. 50 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (fVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL, BHCS, SP, GR, FDC, CNL, CAL, HDT, CBL, VDL, CCL, Gyroscopic 22• CASING, LINER AND CEMENTING RECORD CASING SETfING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FL GRADE TOP BOTfOM TOP BOTfOM SIZE CEMENTtNG RECORD PULLED 20" x 30" In ula ondu or SurFace 110' Su 110' 36" 8 u ds Concret /" 7# L-8 rf 2 5' 1-/2" 7 II 9- /8" 47# L-80 rfa 8906' SurFa 89 ' 12-1/4" 1208 cu ft'G', 130 cu ft Permafrost'C' 7" 29# L-80 11' 8 9324' -1/2" 38 Class'G' 23. Open to production or inject ion? ^ Yes ~ No 24. Tuewc RecoRo tf Yes; tisteach i (MQ+ND of Top & Bottom; Pe nterval open-- rforation Size and Number): S~ DEPTH SET MD PACKER SET MD None 5-1/2", 17# x 4-1/2", 12.61~, L-80 8466' 8335' MD ND MD ND ZrJ. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , ! : ,~ ~,• DEPTH INTERVAL MD AMOUNT Hc KINDAF MATERIAL USED • { ~ ~;,,~~,~-"~~ ,,i ~,.1 E b' ~ ~ ~ J ~ 9080' Set Whipstock P&A with 31.1 b Z6. PRODUCTION TEST ~ l.dCl~ Date First Production: Not On Production Method of Operation (Flowing, Gas Lift, et ~~Ska ~i1 ~ Ga~ Can~. ~omr~° . N/A Date of Test: Hours Tested: PROOUCr~or, FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHO ,. P~a~' GAS-OIL RATIO: Ftow Tubing Pf@SS. Casing Press: Ca~cuwre~ Z4-HOUR RATE~ OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s A uired? ^ 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. s ~Of~PLEI'10t~ ~~ None ~ ~l~ ,~~t. ~ 9 2D09 ~ a~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~~~~ ~~~ ~~~~ ~ ZS. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AND RS ENCOUNTERED~: 29. FORMATION TESTS ~ NAME MD TVD Well Tested? Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River SST 8979' 8578' None Shublik 8990' 8588' Ivishak 9058' 8651' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diag~am 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra S a Title Drilling Technologist Date~ ~'~~~ PBU H-13 781-077 309-127 PrepaiedeyName/-vumber. SondraStewman, 564-4750 Well Number Permi No. / A r v I N. Drit/ing Engineer: Sean MCLaughlin, 564-4387 INSTRUCTIONS GeNewu: This form is designed for submitting a complete and corred 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. I~M 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injedion, Observation, or Other. Multiple completion is defined as a well producing ftom more than one pool with production from each pool completely segregated. Each segregated pool is a completion. I~M 4b: TPI (Top of Producing Interval). Ire~a 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Ir~M 23: 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). I~~a 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed descnption and analytical laboratory information required by 20 AAC 25.071. ITeM 29: 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 02/2007 Submit Original Only ~ • H-13 Pre Rig Work Date Summary 2/22/2009 RAN 3-1/2" CENT TEL & S-BAILER TO SUSPECTED COLLAPSED LINER Q 9434' ELM...NO SAM~F RECOVERED. RUNNING 5-1/2" SS-CATCHER SUB IN PROGRESS. 2/23/2009 SET 5-1/2" SLIP STOP-CATCHER SUB C~ 5090' SLM. PULLED STA# 11 S/O GLV C~ 4915' SLM/ 4938' MD. PULLED STA# 12 LGLV C~ 2981' SLM/ 3006' MD. SET DGLV'S IN STA'S #12 . LRS MIT-IA TO 3000 PSI...PASSED. MADE 2 RUNS W/ 3" P-BAILER TO CATCHER SUB C~J 5085' SLM...RECOVERED -2 GALLONS OF PC-TBG. CURRENTLY RUNNING IN W/ 5-1/2" GR TO PULL C- SUB IN PROGRESS. 2/23/2009 T/I/0=1325/1350/0 Temp= SI Assist Slickline, MIT-IA PASSED to 3000 psi (CTD Screening) Loaded IA with 5 bbls 60/40 MW, 240 bbls crude. Slickline set DGLV. Pressured up IA to 3000 psi with 6 bbls crude for MITIA. IA lost 120 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 160 psi in 30 min test. Bled IA (9 bbls). Final W HP's=1900/500/0. Slickline in control of well at time of departure. IA open to gauge and tagged. 2/24/2009 PULLED 5-1/2" SLIP STOP CATCHFf~3 C~3 5090' SLM. RAN PDS 40 ARM CALIPER FROM 9410' SLM, TO SURFACE RECEIVED GOOD DATA. LEFT (1) ROLLER WHEEL &(1) CENTRALIZER ARM (9" LONG) FROM PDS CALIPER TOOLS. DRIFTED TUBING TO 9420' SLM W/ 3.65" CENTRALIZER. 3/2/2009 T/I/0= 1950/200/0 Temp= SI MIT OA to 2000 psi (CTD Screen) Arrive on location, MIRU, PJSM 3/3/2009 ""'WSR Continued from 03-02-09~`* Temp= SI Assist Slickline pump as directed- (CTD Screen) MIT QA PASSFD to 2000 osi on 2nd attemot MIT T to 3000 psi PASSED 1 st attempt, Pumped 6.1 bbls 50" crude down OA to reach test pressure. OA lost 40 psi in 1 st 15 min and 0 psi in 2nd 15 min for a total loss of 40 psi in 30 min test. Bleed back --1 bbl. Pumped 2 bbls neat, 200 bbis crude to load TBG. MIT T Pumped 14.1 bbls 50" crude down TBG to reach test pressure, TBG lost 100 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 120 psi in 30 min test, Bleed TBG pressure, Bled back ~ 5 bbls, Final WHP's 320/120/160 "Valve position on departure- Swab, SSV, Wing= SI / Master, IA & OA- Open" 3/3/2009 LRS PERFORMED SUCCESSFUL MIT-OA TO 2000 PSI (bled down to 0 psi) TAGGED XN NIPPLE @ 8.372' SLM (8.431' MDl W/ 3.805" G-RING (aooears hiahl LOCATED TT @ 8,401' SLM W/ 3.50" CENT, T.E.L., S-BLR (no sample) SET 4 1/2" XXN PLUG BODY W/ 22" FILL ~XT. C«3 8431' MD. LRS PERFORMED SUCCESSFUL MIT-T TO 3000 PSI (see loq for details.) 3/7/2009 T/I/0=1200/170/60. Temp=Sl. Bleed TP & IAP to 0 psi. (Pre-PPPOT). TBG FL Q Surface. IA FL C~ Surface. Bled IAP fro 170 psi to 0 psi in 20 minutes. Bled TP from 1200 psi to 400 psi in 1 hour. Flowline pressure dropping with TP bleed, called for grease crew to service wing valve. Rig down to monitor BUR's. No change in TP during 45 min. monitor. IAP increased 3 psi during TP bleed & momnitor. OAP decreased 30 psi during bleeds and monitor. Final WHP's=400/3/30. SV & WV=CLOSED. MV & SSV=OPEN. IA OA=OTG. NOVP. 3/10/2009 T/I/O/= 550/60/30. Temp= Sf. Bleed TBG & IA to 0 psi (pre PPPOT). TBG, IA & OA FL C~? surface. Bled TP from 550 to 400 psi, during bleed FL pressure dropped with TP. Pad operator will install heater on WV for possible hydrates, called grease crew to service WV valve. Bled IAP from 60 psi to 0 psi in 10 min, bled OAP from 30 psi to 0 psi in 2 min. Monitored for 30 min, with no change in pressures. Final WHPs= 450/0/0. SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. Page 1 of 4 ~ H-13 Pre Rig Work Date Summary • 3/14/2009 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) (Pre CTD) PPPOT-T Opened SBS verified 0 psi in void, removed 1" NPT plug, removed internal check, installed Alemite fitting. RU HP BT onto THA flushed void until clean returns achieved. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD all test equipment. Cycle and torque LDS "Standard" all were in good working and visual condition. 3/25/2009 SET 5-1/2" SLIP STOP C-SUB ~ 5,005' SLM. PULLED RK-DGLV FROM ST #11 (4,938' MD) & RK- DGLV FROM ST #12 (3,006' MD). SET RK-LGLV AT ST #12 (3,006' MD). CURRENTLY RIH W/ 5-1/2" OM-1 (ST), RK-OGLV TO ST #11 (4,938' MD) 3/26/2009 SET RK-OGLV AT ST #11 (4,938' MD). PULLED M/T 5-1/2" SS C-SUB FROM 5,005' SLM. BAILED -3- 1/2 GALLONS OF PCT FROM 8 381' TO 8,383' SLM W/ 2.25"_ PUMP-BAILER. EQUALIZED & PULLED 4-1/2" XXN PLUG BODY (intact) FROM 8,431' MD. 4/14/2009 RIG UP SLICKLINE UNIT TO SET DGLV'S 4/15/2009 SET 5 1/2" SLIP STOP C-SUB C«~ 5007' SLM PULLED RK OGLV FROM STA # 11 Q 4922' SLM (4938' MD) PULLED RK- LGLV FROM STA # 12 C«3 2983' SLM (3006' MD) SET RK-DGLV'S IN STA # 12 & STA# 11 DRIFTED W/ 20' x 3.70" DUMMY WHIPSTOCK PAST TARGET DEPTH OF 9150' MD W/ NO PROBLEMS - TAGGED TD C~ 9406' SLM 4/16/2009 T/I/O=SSV/1660/100. Temp=Sl. IA FL (CTD prep). AL has a poor boy that is SI. AL is also blinded. Unable to shoot FL through port on blind. IA does not have a companion valve. SV,SSV, Wv=closed. MV=open.lA,0A=0TG.NOVP. 4/28/2009 T/I/O = SSV/1680/270. Temp = SI. Bleed IAP to 500 psi (pre CTD). PBGL rigged up to IA & SI. IA FL C~3 4938' (sta # 11 dmy, 217 bbls). Bled IAP from 1680 psi to 480 psi in 2.5 hour (to UR 009, all gas). During bleed OAP went on Vac. IA FL unchanged. Monitor for 30 min. IAP increased 10 psi to 490 psi. FWHP's SSV/490Nac. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 4/29/2009 T/I/O = SSV/490/40. Temp = SI. Bleed IAP to 0 psi (CTD prep). IA has poor boy. IAP unchanged, OAP increased 40 psi overnight. IA FL @ 4938' Sta #11, DGLV (217 bbl). Bled IAP from 490 psi to 5 psi in 4 hours 55 min into UR. During IA bleed OAP decreased to 20 psi. Monitored pressures for 30 min. IAP, OAP unchanged. Final WHPs = SSV/5/20. WV, SV, SSV = closed. MV = open. IA, OA = OTG. 4/30/2009 T/IA/OA= 1700/0/0 Temp=cold PPPOT-IC (PASS) (W/H repair) PPPOT-IC: DHD bled tA x OA to 0 psi. Remove 1" NPT removed Internal check, installed 1" ALEMITE. RU 1 HP BT onto IC test void, flushed void until clean returns achieved. Attempted to pressure up void would not go above 100 psi. RU elephant onto packing port, attempted to flushed void of "chemola" RU x-over nipple 7/8" - 9UNC x 1/2" NPT ( SBS to 1/2" Alemite) to flush void through back side. RD x-over nipple, RU 1" Alemite onto packing port flushed void of old packing. re installed elephant gun packing (2.5) J-sticks until air free plastic achieved, pressured to 6200 psi. (2nd test) Pressure for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, RD all test equipment. Cycle and torque LDS "Standard" all were in good working and visual condition. 4/30/2009 T/I/0=1700/8/25. Temp=Sl. Monitor WHP's, bleed IAP to 0 psi (CTD prep). IAP increased 3 psi, OAP increased 5 psi overnight. IA FL C~ 4938' (DGLV C«2 Sta #11. Maintained a open bleed on IA while Cameron performed IC PPPOT. Monitor during rig down, pressures unchanged. Final WHP's=1700/0+/25. V, WV=Closed. MV, SSV=Open. IA, OA=OTG. NOVP. Page 2 of 4 • • H-13 Pre Rig Work Date Summary 5/3/2009 "`INITIAL T/I/O = 0/0/0'`** RIG UP TO SET 3.65" BAKER WHIPSTOCK WITH WPPT. LUBRICATOR FAILED PRESSURE TEST. LEAKING FROM HEAD CATCHER SUB. BLEED DOWN WHE. RIG DOWN TOOLS AND WHE TO CHECK FOR LEAK. FOUND COLLAR BACKED OFF OF HEAD CATCHER. RIG DOWN EQUIPMENT FOR THE NIGHT TO RETURN IN MORNING. 5/3/2009 T/I/0=1750/0/0 temp=Sl MIT IA "*PASS"* to 3000 psi (CTD Prep) Loaded IA with 2 bbls neat, followed by 235 bbls of 90* crude to reach test pressure. 15 min IA Iost 120 psi. 30 min IA lost 40 psi. Total IA loss 160 psi. Bled back 7 bbls. Pad op notified of tree valve positions as follows: SV,WV = closed. SSV,Master = open. IA and OA open to gauges. Pad op also notified of job status. Final WHP- 1750/40/0 5/4/2009 INITIAL T/I/O = 1650/0/0 SET TOP OF BAKER TTWS (4-1/2"_x_ 7°~ WHIPSTOCK AT 9.084'. OAL=17.53' BOTTOM OF WHIPSTOCK AT 9,097.53'. CCL TO TOP OF WHIPSTOCK = 12.6', CCL STOP DEPTH = 9067.4', ORIENTATION = 14.3 DEG TO RIGHT OF HIGHSIDE NO R/A PIP TAGS WERE INSTALLED IN WHIPSTOCK AS PER REQUEST IN PROCEDURE. WELL LEFT WITH MASTER OPEN, CASING VALVES OPEN, SWAB CLOSED, WING CLOSED & TAGGED, SSV OPEN DSO NOTIFIED OF VALVE POSITIONS BEFORE DEPARTURE FINAL T/I/O = 1650/0/0 5/11/2009 CTU #8 w/1.75" OD coil. Job scope - P&A, Mill XN. MIRU CTU. InterAct is publishing. Perform BOPE test as per sundry. MU & RIH w/ 2.25" D BDJ tapere nozz e. 5/12/2009 CTU #8 w/1.75" OD coil. Job scope - Cement squeeze, Mill XN. Kill wellbore with 321 bbls 1% KCL. Cap well with 210 bbls diesel to underbalance. Pump 31.1 bbls 15.8 ppg cement. Achieve 500 psi bump with 0.5 bbls cement behind pipe. Lav-in remaininq cement 1:1, losing an additional 2.5 bbls cement behind pipe. Build additional 1000 psi squeeze pressure above initial pressure bump with no additional cement behind pipe. Drop ball and RBIH jetting biozan to contaminate. Engage cement with 34 minutes of thickening time remaining. Work through hard tag at 8527' MD. RIH jetting biozan through sticky cement down to hard taq at 8667' MD. Unable to let throuqh cement. Pull to surface chasing contaminated cement to surface, leaving hard TOC at 8667' MD. Reciprocate through all jewlery. Washed through wellhead and BOP's. MU Baker 3.80" OD Mud motor /Mill assy. 5/13/2009 CTU #8 w/ 1.75" OD coil. Job scope - Mill XN nipple, mill cmt. RIH w/ Baker 2-7/8" Drilex left-handed motor with 3.80" OD parabolic diamond speed mill and 3.80" OD diamond string reamer. Tag TOC at 8661' MD. Mill ahead through cement to 8915' ctmd with average ROP of 0.4 fpm with frequent gel~ sweeps. Milling ahead. 5/14/2009 CTU # 8 w/1.75" OD coil. Job Scope - Mill cement. «< InterACT publishing »> Job continued from WSR 5/13/2009. Milling w/Baker 2-7/8" Drilex left-handed motor with 3.80" OD parabolic diamond speed mill and 3.80" OD diamond string reamer. Tag TOC at 8661' MD. Mill ahead through cement with average ROP of 0.4 fpm with frequent gel sweeps. Milled down to 9065' ELM. Pumped 20 bbl Geovisc pill. POOH C«3 80 %. Freeze protected from 2000' w/50/50 methanol water. Mill and reamer gauged @ 3.80" OD, 3.79" OD would not pass over mill or reamer. RDMO. Job complete. 5/19/2009 T/I/0=0/20/0 Temp=Sl MIT-T PASSED to 1000 psi (CTD prep) Pressured Tbg to 1000 psi with 3.1 bbls of ineth.T lost 60 psi in 1st 15 mins and 10 psi in 2nd 15 mins for a total loss of 70 psi in 30 mins. Bled TP. Final WHP's = 0/20/0. Wing is closed, Swab is closed, SSV is closed, Master is open, IA and OA are open to gauges. 5/21/2009 T/I/O - 100/0/0 , PRE NORDIC 2# PRESSURE TEST , pt down on swab 4500 psi for 5min pass , shell test tree 4500 psi fror 5min pass & service tree Page 3 of 4 • • H-13 Pre Rig Work Date Summary 5/25/2009 T/I/O = 5NACNAC. Temp = SI. Bleed WHPs to 0 psi (CTD prep). No AL, no F/L, no wellhouse, scaffolding removed excepting swab platform & ladder (swab platform has no railings). SV, WV, MV=Shut. SSV=Open. IA&OA=OTG. NOVP. Page 4 of 4 ~ • BP EXPLQR~4TION Page 1 at 9 Operations Sumrnary Repart Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: ' Date From - To Hours Task Code NPT P'hase ' Deseription af Operations 6/6/2009 09:00 - 11:00 2.00 MOB P PRE Set rig down on R Pad. PU mats and clean up around R-21 Post Pad Inspection w/ DSO Tool Service continuing to lay rig mats on R Pad access road Use 75T crane to set 13-5/8" stack on transport skid 11:00 - 15:00 4.00 MOB P PRE WO Tool Service to lay mats on R Pad access road. Original plan was to use plywood on one side, but a TS THA determined that the sheets weighed too much and it was too windy to safely use them Move new shaker into place SWS replace worn gripper blocks and service injector 15:00 - 20:00 5.00 MOB P PRE Move office trailer to H Pad w/ Security escort Move rig off R Pad and onto access road. Move rig over one mile of rig mats to the Spine Road stopping one time to back up on double mats. 20:00 - 22:30 2.50 MOB P PRE Turn onto Spine & the onto GC2 Access road. Tool Service laying rig mats over GC2 pipeline. Move rig onto H pad. 22:30 - 00:00 1.50 MOB P PRE RD tree cap. Move tree scaffolding away from well. ND XO on bottom of BOP's. 6/7/2009 00:00 - 02:00 2.00 MOB P PRE Spot cellar plywood. Spot Herculite liner. Spot T mats. Spot rig mats. 02:00 - 03:00 1.00 MOB P PRE Spot rig over well. Rig accept at 3am. 03:00 - 08:00 5.00 BOPSU P PRE RU Handy berm. NU BOP's. Spot cuttings box. Spot office trailer. Take on rig water. RU lubricator. Continue installation of new shaker. Install electrical to shaker 08:00 - 10:00 2.00 RIGU P PRE Prep injector/gooseneck. Pull CT to floor and stab into injector 10:00 - 15:15 5.25 BOPSU P PRE BOPE test. The States right to witness was waived by Chuck Scheve Continue installation of new shaker 15:15 - 16:45 1.50 RIGU P PRE PU injector, seal end of wire. Adjust wt cell Finish installation of new shaker. Reinstall railings and wall 16:45 - 18:00 1.25 RIGU P PRE Fluid pack CT. Pump slack back. PT packoff and inner reel valve as part of BOPE test MI Swaco install screens on shaker and adjust Welder instali piperack beam 18:00 - 18:30 0.50 STMILL P WEXIT Crew chg/safety mtg 18:30 - 22:30 4.00 STMILL P WEXIT Blow back coil. Pop off well. RU coil cutter. Cut coil - 70ft to find wire. RD coil cutter. Test wire. Dress coil. Install SLB CTC & pull test to 40k. Rehead BHI. Pressure test CTC & BHI UQC to 4k. Open well, Opsi. Flow check. 22:30 - 23:00 0.50 STMILL P WEXIT MU window milling BHA per program. Window mill was 3.80" no-go. 23:00 - 00:00 1.00 STMILL P WEXIT RIH, cir 0.4bpm/240psi, taking returns to Tiger tank, mostly diesel & minor amounts gas. 6/8/2009 00:00 - 00:45 0.75 STMILL P WEXIT Continue to RIH. Wt ck at 8600', 36k up, 27k down. Increase rate to 2.5bpm/2100psi. 00:45 - 01:30 0.75 STMILL P WEXIT Log down for tie-in from 9000' (-18ft corr). 01:30 - 04:10 2.67 STMILL P WEXIT Mill cement from 9066ft to 9084ft using 2.5bpm/2500psi w/ 1.5-2.5K Ibs WOB. 04:10 - 08:00 3.83 STMILL P WEXIT Mill window from 9084ft using 2.5bpm/2500psi w/ 1-2klbs WOB. Mill O.ift every 6min. 08:00 - 09:10 1.17 STWHIP P WEXIT Mill from 9087.0' 2.42/2400 w/ 0-100 psi diff, 1.5-2.5k wob w/ 9.55 ECD Printed: 6/22/2009 2:11:05 PM ~ • BP EXPLORATION Page 2' of 9 Operations Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Qate Frorn - To Hours Task Code NPT Phase Description vf Operations 6/8/2009 09:10 - 09:55 0.75 STWHIP P WEXIT Mill from 9088.0' 2.41/2330 w/0-100 psi diff, 1.5-2.Ok wob w/ 9.54 ECD Mill to 9088.75'. PUH clean to chk freespin. Ream back down 09:55 - 11:00 1.08 STWHIP P WEXIT Mill from 9088.75' w/ 2.40/2020 w/ 100-300 psi diff, -2.Ok wob w/ 9.54 ECD 11:00 - 12:00 1.00 STWHIP P WEXIT Mill from 9090.0' w/ 2.4/2020 w/ 200 psi diff, 1.6-2.3k wob w/ 9.54 ECD 12:00 - 12:45 0.75 STWHIP P WEXIT Mill from 9091.0' at increased penetration rate and appear to have exited window by 9093' 12:45 - 13:50 1.08 STWHIP P WEXIT Drill from 9095.0' 2.40/2020 w/ 250 psi diff, 2.0-3.Ok wob w/ 9.55 ECD Drill to 9103' 13:50 - 14:45 0.92 STWHIP P WEXIT Backream and ream. Dry tag was clean 14:45 - 16:15 1.50 STWHIP P WEXIT POOH circ thru mill 2.47/2220 16:15 - 17:15 1.00 STWHIP P WEXIT LD milling BHA 17:15 - 18:00 0.75 DRILL P PROD1 MU build BHA w/ used bi bit, 3.2 de motor w/ res tool , ,_ : - : . PROD1 RIH w/ BHA #2 circ thru EDC ` ~'~T 19:45 - 19:55 0.17 DRILL P PROD1 Log down for tie-in from 9010ft (-18ft corr). ~,,'3 ~ 19:55 - 20:05 0.17 DRILL P PROD1 Continue to RIH w/ build section BHA. Run through window - clean. 20:05 - 20:50 0.75 DRILL P PROD1 Drill build section from 9105ft. varies due to vibrations/2200/0 TF w/ 200 - 500 psi MW ECD=9.50 ppg 1-3k Ibs DHWOB ROP's=15 to 40 FPH PVT = 99 (conducting mud swap to new Geovis) Drill to 9,112 ft. 20:50 - 22:50 2.00 DRILL N DFAL PROD1 POH for tool failure. 22:50 - 23:00 0.17 DRILL N DFAL PROD1 Tag up. Flow check. Close EDC. Pop off. Blow BHA. LD BHA. Inspect motor & bit - ok, milk motor - ok. Test line - ok. 23:00 - 23:50 0.83 DRILL N DFAL PROD1 MU new BHI coil track tools & same 3.2AK0 motor & Hycalog bit. 23:50 - 00:00 0.17 DRILL N DFAL PROD1 RIH w/ BHA #3. 6/9/2009 00:00 - 01:35 1.58 DRILL N DFAL PROD1 Continue to RIH w/ BHA #3. 01:35 - 01:50 0.25 DRILL N DFAL PROD1 Log down for tie-in from 9010ft (-19ft corr). 01:50 - 02:00 0.17 DRILL N DFAL PROD1 Continue to RIH. Close EDC. Slight bobble through window. 02:00 - 05:25 3.42 DRILL P PROD1 Drill build section from 9113ft. 2.4/2125/0-100 R w/ 200 - 300 psi MW ECD=9.11 ppg 1-3k Ibs DHWOB ROP's=15 to 75 FPH PVT = 349 Drill to 9246ft 05:25 - 05:35 0.17 DRILL P PROD1 Wiper to the window & to TD - clean. 05:35 - 06:30 0.92 DRILL P PROD1 Drill build section from 9246ft. 2.5/2200/75-900 R w/ 200 - 300 psi MW ECD=9.22 ppg 1-3k Ibs DHWOB ROP's=45 to 150 FPH PVT = 350 Dtill to 9300' 06:30 - 10:30 4.00 DRILL P PRODi Slower drilling from 9300' w/ numerous stalls, high vibs, having to survey off bottom Drill w/ 2.47/2530/90L w/ 100-300 psi diff, 0.5-2.5k wob w/ 9.22 Printed: 6/22/2009 2:11:05 PM I TREE _ • 6-3/8" MCEVOY WEL~HEAD = MCEVOY A~TUATOR = Ol1S KB. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2695~ [~l[ U ~ = ~.~ " ~~~~a Insicie deplayment Sleeve {TC}L) 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8355~ TOP OF 4-1/2" TBG 8355~ `f~P 3-112" X 3-3f16" X 2-7I8'° LNR $~'~~' TOP OF 7" LNR 8412~ ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-{ $466~ 9-5/8" CSG, 47#, L-80, ID = 8.681" w hipstock 8907' ~ 3t~$~° PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 90° @ 10120' Note: Refer to Roduction DB for historical perf data SIZE SPF IMERVAL Opn/Sqz DATE 2" 6 10120-1-320 Open 06/17/09 _ PBTD 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800~ ST MD ND DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 $276~ ~5-1/2" SLIDING SLV, ID = 4.562" ~ 8315~ TBG SEAL ASSY 8335~ 9-5/8" x 5-1/2" TNV PKR, ID = 4.75" 8355~ 5-1 /2" X 4-1 /2" XO 8399~ 4-1/2" X NIP, ID = 3.813" -~ 8431' ~-j 4-1 /2" XN NIP, ID (tkIL1,ED TC} = 3.80" 8466~ 4-1/2" TBG TAIL ID = 3.958" 8428~ ELMD TT LOGGED 07/02/97 847b' ToC 1~288' I-I~-3116 x 2-7F& X-ouer 3-3!16" x 2-7i8" cmt'd and perf'd ~-~ 1i~39d' 9398~ ~FISH: TBG END IOCATORARM I I 9420~ FISH: CENTARM/ROLLER WHEEL (02/24/09) DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SETXXN PLUG (03/03/09) 02/16/01 SIS-SLT CONVERTED TO CANVAS 06/16i09 Nordic 2 Sidetracked for more oii.,.. 03/01/01 SIS-LG FINAL 09/26/01 RWTP CORRECTIONS 05/29/06 CO/DTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV C/O (02/23/09) PFtUDHOE BAY UNff WELL: H-13A PERMff No: API No: 50-029-20559-01 Sea 21, T11 N, R13E BP F~cploration (Alaska) 0 ~~ ALASFiA OII. A1~TD GAS COI~TSERQA'I'IO1~T CO1~II-IISSIOI~T Mr. John McMullen Engineering Team Leader BP Exploration Alaska, Inc , ~ ~~ ~,~~ `~ ~ 00~ P.O. Box 196612 ';'`"~"~'~~ ~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-13 Sundry Number: 309-168 Dear Mr. McMullen: ~~ ~ 1 ~~ The Commission DENIES the enclosed Application for Sundry Approval relating to the above-referenced well. The reason for this denial is that milling the window and exiting the casing, for regulatory purposes, is drilling. The well control requirements for drilling (20 AAC 25.036] are more comprehensive than the applicable requirements for workovers/wellwork [20 AAC 25.286]. No information was provided validating that the equipment on the Service Coil rig meets the drilling regulation requirements or requesting a variance to the requirements per 20 AAC 25.036 (fl. This denial is without prejudice to your right. to submit a new application including appropriate information to validate that the Service Coil meets the applicable standards for drilling under the Commission's regulations. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel . Seamount, Jr. Q' Chair DATED this o day of May, 2009 SARAH PAUN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enc. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMt>~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25280 ECEIVE[~ s-~ ~1AY 0 '~ 2iiiJ~ 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ~ ime ensi n Ot1S. OR1C111SSIOII :~fiChO( ~~Well ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter uspen ® hange Approved Program _ ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) ®Development - ^ Exploratory 181-017 (309-127) - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, laska 99519-6612 50-029-20559-00-00 7. If perforating, closest approach i ool(s) o e is operation to nearest 8. Well Name and Number: property line where ownership or I down trip~chan s: PBU H-13 Spacing Exception Required? ^ s No 9. Property Designation: B Elevation (ft): 11. Field /Pool(s): ADL 028284 ~ 82.6 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• R ENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effe ive pth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9805 9329 9 9 9287 8431' 9420' & 9398' C i Len. h i MD TV B r II tructu al n 11 11 ' rf 2 1 - 269 ' 2695' 493 7 Int rmediate P i /' Lin r 1 7" 1' 0' 048' - 9324' 16 7 2 Perforation Depth MD (ft): Perforation Depth TVD (ft): Bing Size: Tubing Grade: Tubing MD (ft): 9350' - 9462' 8919' - 9020' 5- 1' ', 12.6# L-80 8466 Packers and SSSV Type: 9-5/8" x 5-1/2" TIW Packer Packers and SSSV MD (ft): 8335' 13. Attachments: 14. Well Clas after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status a r proposed work: Commencin O erations: May 7, 2009 ^ Oil' ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name J n 01 le _ Title Engineering Team Leader \, ,.~~~~ Prepared By NameMumbec 564-4628 Terrie Hubble , Signature Phone 564-4711 Da Commission Use Onl undry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06!2006 f -, - ~ f !~ p~+~~p++fi ~y ~{" a~/(} /l~{ Submit In Duplicate 4 M N!e A.. trl~l~ ;~ fl.. .C~JQV ~O i~0~ ~~~~ To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission by From: Sean McLaughlin CTD Engineer Date: 06 May 2009 Re: H-13 Sundry Approval -Revision 1 Sundry approval is requested for well H-13. Initial perforations were just above the 25N shale. Current open perforations are still within this same interval. H-13 remained at low WC and GOR into the late `80's. WC increased to about 10% when perforations were added below the 25N shale in 1987, and GOR started increasing in late 1988. In 1994, a cement squeeze was performed to shut off high gas production from above the 25N shale. Post squeeze perfs were added below the 25N shale in an effort to hold off the gas. However, post squeeze production below the shale was in excess of 90% WC. Competitive production was not re- established until perforations were added above 25N in 1997. There were substantial variations in NOR, WC and GOR in H-13 during 1997. These may be partially in response to high rate injection in Y-18 at the time. In 1998, a second cement squeeze was performed to shut off high gas production coming from the upper set of leaking squeezed perforations located above the 25N shale and an attempt to shut off the water from below. A Borax log in 2001 confirmed that the second squeeze was still holding. Improved offtake at the end of 2002 may be a response to a temporary return of Y-18i to injection. In 2007, the H-13's production continued to decline and GORs reached over 50,000. A subsequent production log showed that the uppermost perforations were again leaking and contributing 100% of the wells production. For lack of a reliable gas shut off option, the well was shut in. REASON FOR SIDETRACK H-13 is currently SI as a low value producer with high GOR and no on time. Wellwork options to shutoff the gas have been exhausted given the two previous squeezes and the geological structure for the area. Future utilization of this wellbore has been determined to be a sidetrack. Northeast of H-21 the cross section drops down into the Zone 2 GDWFI area. H-13 is an ideal candidate to sidetrack into an area of thick GLOC in GDWFI Zone 2 between the current H-13 and H- 23. The proposed plan for H-13A is to drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around May, 20 2009. The existing perforations will be isolated by a cement downsqueeze after setting the whipstock, as well as the primary cement job. The sidetrack, H-13A, will exit the existing 7" liner and kick off in Zone 4 and target Zone 2C reserves. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. ~„t~a~l~rp.r PieH~f~ c~-O~pr/ v-~ /*~~rc~pp~'l~f „law l~vq~/ ~1` ~7 /lot /'~es~ 6 ~~~~ S~~ Pre-Rig Work: (scheduled to beg~April 20, 2009) 1. OMIT-lA - 3000 psi Pass 2/23/09 2. S DGLV's 3. S Drift for 4-1/2" X 7" Thru tubing whipstock to 9150' MD 4. E Set whipstock at 9080'MD. 5. C Down squeeze 27 bbl of 15.8 ppg cmt past whipstock to abandon existing perforations. 6. C Mill. XN nipple at 8431' MD to 3.80" with left hand motor and mill. 7. C Mi113.8" window at 9080' and 10' of rathole. 8. OMIT-Tubing 2000 psi 9. O AC-LDS; AC-PPPOT- T 10. O PT tree (MV,SV,WV), 11. O Bleed gas lift and production flowlines down to zero and blind flange 12. O Remove S-Riser, Remove wellhouse, level pad Rig Work:. (scheduled to begin on May 15, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Drill Build: 4.125" OH, 620' (35 deg/100 planned) 3. Drill Lateral: 4.125" OH, 1227' (15 deg/100 planned) with resistivity 4. Run 3-3/16" x 2-7/8" solid L-80 liner leaving TOL at 8412' 5. Pump primary cement leaving TOC at 8780', 28 bbls of 15.8 ppg liner cmt planned 6. Cleanout liner and MCNL/GR/CCL log 7. Test liner lap to 2000 psi. 8. Perforate liner per asset instructions 0700') 9. Freeze protect well, RDMO Post-Rig Work:. 1. Re-install wellhouse and FL's. 2. Generic GLV's Sean Mclaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = 6-3/8" MCEVOY WELLHEAD = MCEVOY ACTUATOR = OT1S KB. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @9600' Datum MD = 9310' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2695' Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ~ = 4.892" I 8355' TOP OF 4-1 /2" TBG --8355' TOP OF 7" LNR H $412' ~ i 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I--i $466' 9-5/8" CSG, 47#, 1-80, ID = 8.681" I-~ 8907' PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 3-1/8" 4 9350-9370 S 02/12/98 2-7/8" 6 9375-9400 C 03/03/98 3-3/8" 4 9380-9400 C 02!20/98 3-3/8" 6 9424-9430 S 06/02/94 3-3/8" 6 9442-9462 S 06/02/94 PBTD ~--( 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800' LE COLLAPSED LNR FROM ~ ~ H -13 3.70 9424' 1~433 ', ID 2001' 5-1/2" CAM SSSV LAND NIP, ID = 4.562" • GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02123/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8276' ~ 5-1/2" SLIDING SLV, ID = 4.562" I 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1/2" TNV PKR, ~ = 4.75" $$55' 5-112" X 4-112" XO $399' 4-1/2" X NIP, ~ = 3.813" 8431' 4-1/2" X>aV PLUG (03/03/09) 8431' 4-1/2" )aV NIP, ID = 3.725" 8466' 4-1/2" TBG TAIL ID = 3.958" $42$' ELMD TT LOGGED 07/02/97 9262' H MARKER ,io~lr 9420' J-FISH: CENTARM/ROLLER WHEEL (02/24/09) 9398' FISH: TBG END LOCATOR ARM DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SETX>aV PLUG (03/03/09) 02/16!01 SIS-SLT CONVERTED TO CANVAS 03/01/01 SIS-LG FINAL 09/26/01 RNITP CORRECTIONS 05/29/06 CO/DTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV GO (02/23/09) PRUDHOE BAY UNff WELL: H-13 PERMIT No: 81-0170 API No: 50-029-20559-00 Sec. 21, T11N, R13E BP Exploration (Alaska) I TREE = 6-3/8" MCEVOY WELLHEFtD = MCEVOY ACTUATOR = OT1S KB. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" • H-13 Proposed CTD Si e Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS I IFT MANnRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8276' ~ 5-1/2" SLIDING SLV, ID = 4.562" 8315' TBG SEAL ASSY 5-1/2" TBG, 17#, L-80, .0. TOP 3-1 /2" ~pf, ID = 4.892" H 8355' ' OF 4-1 /2" TBG 8355' 3/16" X 2-7/8" LNR 8412' TOP OF 7" LNR ~ 12' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I--I $466' 9-5/8" CSG, 47#, L-80, ID = 8.681" whipstock PERFORAl10N SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical p ert data SIZE SP F INTERVAL OpNSgz DATE 3-1/8" 4 9350-9370 S 02/12/98 2-7/8" 6 9375-9400 C 03/03/98 3-318" 4 9380-9400 C 02/20/98 3-3/8" 6 9424-9430 S 06/02/94 3-3l8" 6 9442-9462 S 06/02/94 PBTD H 9759' 7" LNR 29#, L-80, .0371 bpf, ID = 6.184" 9800' 8335' I~ 9-5/8" x 5-1 /2" TNV PKR ID = 4.75" 8355' -~ 5-1 /2" X 4-1 /2" XO 8399' 4-1/2" X NIP, ID = 3.813" 8431' --~4-1/2" XN NIP, ID MILLED TO = 3.80" 8466' 4-1/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 8790' TOC 10300' 13-3/16 x 2-7/8 X-over 3-3/16" x 2-7/8" crrrt'd and perf'd I 9398' FISH: TBG END LOCATOR ARM 9420' FISH: CENT ARM/ROLLER WHEEL (02/24/09) DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XXN PLUG (03/03109) 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/10/09 MSE PROPOSED CTD SIDETRACK 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORRECTIONS 05/29/06 COlDTM PERF CORRECTIONS (6/13/04) 03/03/09 T~, A;~~~ 'S~ "'L`/ ~ ~ ~ :'~ ,~ PRUDI-IOE BAY UNfr WELL: H-13A PERMfr No: API No: 50-029-20559-01 Sec. 21, T11 N, R13E BP Exploration (Alaska) 9080' - 0 22 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 07, 2009 4:15 PM To: 'McLaughlin, Sean M'; McMullen, John C Cc: Regg, James B (DOA); Seamount, Dan T (DOA); Foerster, Catherine P (DOA); Norman, John K (DOA) Subject: PBU H-13 (181-017) Importance: High Sean and John, Review has been completed on your recently submitted sundry (309-168) to change the operational program previously approved by sundry 309-127. You submitted the sundry per my request in a series of emails regarding milling the casing window with the service coil. Due to the late hour, Commissioner Seamount has asked me to communicate the decision via email. Your request to change the approved program authorized by sundry 309-127 is DENIED without prejudice. Sundry Approval 309-127 remains effective as does PTD 209-044 for H-13A. Tom Maunder, PE AOGCC 5/7/2009 Application for Sundry Approval 181-071 ... PBU H-13 ... 309-168 BP has submitted a Sundry Application to change the program originally approved for work on this well authorized by 309-127. The proposed change involves milling the casing exit and about 10' of new hole using the service coil rig rather than one of the CT Drilling Rigs. This document examines the request and considers two decision possibilities; deny BP's application without prejudice or approve it conditionally to assess SC technical performance and regulatory compliance. I recommend denying BP's application without prejudice. HISTORY BP originally made contact regarding using the service coil (SC) rather than the drilling coil (DC) on April 17. They stated that since better milling tools were available than when this was attempted in 1999, the work could be asc`omplished more economically and it was their opinion that the small amount of newly drilled hole resembled a perforation. Further messages were exchanged through~rri121 in an attempt to determine if some correspondence was exchanged when such work was attempted previously, but no documents were found. No further messages were exchanged until Apri129. In an exchange beginning Apri129, BP was requested to submit a sundry notice to change the approved program. A copy of the revised "short" program normally filed with the sundry was provided as well as a more detailed procedure that is rarely provided. In further exchanges ending mid day Apri130, BP was clearly informed to submit a sundry notice requesting a "change of program". Shortly thereafter, the BP engineer communicated his desire to "backup" and debate the need of a sundry and where it was specified in the regulations. No further messages were exchanged until May 5 and 6 when again, the sundry need was reiterated and it was pointed out that the original need for a sundry had been determined over a week prior. The BP engineer followed with a message questioning if I had any intention to approve the sundry and requesting a "verbal" approval since the preparation work needed to begin May 7 (today). DISCUSSION Two methods have been employed to prepare (P&A) a candidate well and re-drill a new penetration. All work can be accomplished using the DC rig or the preparation work can be performed by SC and the drilling including casing exit can be performed by the DC. BP desires to use SC to drill the window to save time and expense. Windows had been problematically milled using SC around 1999, but this process had been abandoned due to difl"xculties milling out. BP states that milling technology has advanced sufficiently so SC can drill the window. I agree with BP's statement regarding the milling technology. Although problem windows do occur, such occurrences are not frequent. From a technical point of view, it should be possible to successfully employ the milling BHAs on SC and mill a window. Well control equipment requirements for SC are regulated by 20 AAC 25.286 while well control equipment requirements for DC are regulated by 20 AAC 25.036. The drilling regulations aze more comprehensive than the well work regulations. I forwazded BP's initial message on their proposal to the Inspectors seeking their comments. Responses from Inspectors Grimaldi and Crisp highlight their concerns regarding the abilities of SC crews and the BOP equipment. BP's appears to also have concerns as highlighted in the detailed procedure provided April 29. In addition to well control requirements, 20 AAC 25.033 specifies the requirements for drilling fluids and the drilling fluids system. Much less specific requirements for primary well control for workover operations are found at 20 AAC 25.280 (5) and (6). Here-to-fore, having casing exits only performed by DC rigs has insured that the most comprehensive set of equipment, both BOP and fluid handling, is employed on operations where open hole will be present. Rig inspections and BOP test witnesses are regulazly conducted on the DC rigs. Inspections and test witnesses are not as frequently done on SC rigs due to availability of Inspectors and that SC rigs only operate "within pipe". RECOMMENDATIONS Two recommendations aze considered. Recommendation 1: Approve BP's application with the stipulation that the BOP test prior to beginning be witnessed. The Commission regulazly witnesses BOP tests where new hole is going to be drilled. As noted, Inspectors Grimaldi and Crisp have expressed concerns regazding the SC crews and their equipment. Witnessing the BOP test and inspecting the rig will likely identify deficiencies which is the reason tests aze witnessed. Recommendation 2: Deny BP's application without prejudice. Their application is not complete. While a significant amount of information was communicated via email, aside from listing the milling step in the pre-rig work section, no other information is offered to allow consideration of the request. It appears that they believe sufficient record has been established via the emails. I believe there is a clear distinction between cased hole operations and open hole operations. Our regulations are more comprehensive when open hole operations are considered. I recommend denying BP's application without prejudice. `` ~ i ~~ ,~/(~ J ~ n /~;~-~-~~ 1. Tom Maunder, PE ~~`l ~aO~~ i__ ~oyc~r, Th~.~~ Q~a~osy/ , ~ ~n /o es c~~, /l `~,.~ hpw / ~'n yCG orolaP~r~P G~ j `~S ~h~ ~ll,~g ~~ /~l~r tee,-ko~,.- re,3-~, ~o~ -~~? Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 06, 2009 3:40 PM To: 'McLaughlin, Sean M' Cc: Regg, James B (DOA); Hubble, Terrie L; McMullen, John C Subject: RE: Request to revise H-13 (181-017) sundry #309-127 Sean, The challenge is not just paperwork. What you are proposing may be technically feasible due to better equipment, but physically exiting the casing starts the drilling process and crosses the regulatory line between well work [20 AAC 25.286, 20 AAC 25.112] and drilling [20 AAC 25.036]. The BOP requirements for drilling at 20 AAC 25.036 are stricter than the BOP requirements for workovers at 20 AAC 25.286. It may be appropriate to cross that line, but documentation more complete than our series of emails is needed. That is why the need for a new sundry notice was communicated in one email on April 29 and the need to attach your documentation to it in another message the same day. Here we are a week later still debating that need even though John indicated that you would submit the sundry then. It is not appropriate for me to indicate that I would or would not endorse your request; and please note that I have no approval authority regarding work requests made to the Commission. Any authority to approve is with the Commissioners. Based on the impending start of well work tomorrow, I doubt it possible to secure a approval regarding your proposal. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Wednesday, May 06, 2009 1:36 PM To: Maunder, Thomas E (DOA); McMullen, John C Cc: Regg, James B (DOA); Hubble, Terrie L Subject: RE: Request to revise H-13 (181-017) sundry #309-127 Tom, If a "change approve program" Sundry is submitted is your intention to approved it? You have already seen the supporting documentation in earlier correspondence. Are there technical or safety issues you are concerned about that would hold up the change of approved program? If so, could you tell me what they are? The prep work can't be delayed on H-13 any longer. A coil unit will head to H-13 tomorrow to P&A the well and mill the XN nipple. If a change is submitted this afternoon could it be approved (at least verbally) by tomorrow afternoon? I'm unclear if the challenge is just paperwork or are there some other issues that need to be documented and addressed. Regards, Sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 06, 2009 12:54 PM To: McLaughlin, Sean M; McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 (181-017) sundry #309-127 Sean, Sorry I have been delayed in getting back to you. Sundry 309-127 was issued for the plugging of H-13. Permit 209-044 was issued for the drilling of H-13A. When I reviewed the documents, I marked the procedures with a line indicating the work covered by the sundry approval and the permit to drill. 5/7/2009 Page 2 of 3 Window milling is not considered well work and is not covered by the Matrix. It remains my opinion that a new sundry covering to "change the approved program" for the plugging and desired exiting of the casing be submitted. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Tuesday, May 05, 2009 10:16 AM To: Maunder, Thomas E (DOA); McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 sundry #309-127 Tom, Do you have any additional information for us? Nordic 2 is continuing to make progress and we need to finalize the prep work on H-13A. Regards, Sean From: McLaughlin, Sean M Sent: Thursday, April 30, 2009 1:00 PM To: 'Maunder, Thomas E (DOA)'; McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 sundry #309-127 Tom, Thanks for your patience with all the a-mails as we learn how to best approach this I think we need to backup a few steps and look at the specific regulation or 10-403 requirement that relates to milling a hole in the casing within the reservoir. I've reviewed the regs a few times during our a-mail correspondence and cannot find this requirement. Would you please point to the regs that suggest a 10-403 is needed for milling a window? The closest similar operation I can find is "perforate new intervals within a pool". In this case a 10-403 is not required. So, where would window milling fall under the matrix for Well Work Operations for Development (Production) Wells? The proposed window milling job occurs within the reservoir, and many times our windows are below or within perforated intervals. As such, from a well control standpoint, we do not introduce any additional risk to our service coil operations. I have not found any previous documentation between the commission and BP regarding window milling with service coil. Regards, Sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 29, 2009 12:58 PM To: McLaughlin, Sean M; McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 sundry #309-127 5/7/2009 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, April 30, 2009 9:22 AM To: 'McLaughlin, Sean M' Cc: Regg, James B (DOA); McMullen, John C Subject: RE: Request to revise H-13 sundry #309-127 Sean, That is correct that it is my interpretation that a new sundry is needed. That is the program that you are proposing to change. I agree that a BOP test prior to beginning any work is standard practice. Your message does point out the difference in the BOP tests for service coils versus drilling coils. While you have made the argument/statement that the proposed casing exit result is no different than a perforation, I believe there are some differences. In the more detailed procedure you have included, there are various advisory statements urging caution as the work is attempted/accomplished. As we had messaged earlier, have you been able to find any document between the Commission and BP regarding window drilling with service coil? I have not found any documents in the limited search I have conducted. I suspect we will exchange further messages. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Wednesday, April 29, 2009 5:24 PM To: Maunder, Thomas E (DOA); McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 sundry #309-127 Tom, Perhaps I misunderstood your request. Do you want us to submit for a new Sundry or can we revise the one we currently have? We don't usually specify a BOP test in the the pre-rig procedures. It is already understood. Service coil will body test the BOPS every rig up and perform a full test every 7th day. Regards, Sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 29, 2009 12:58 PM To: McLaughlin, Sean M; McMullen, John C Cc: Regg, James B (DOA) Subject: RE: Request to revise H-13 sundry #309-127 Sean and John, Thank you for both messages. I presume these documents will be attached to the sundry? In the initial coil procedure I don't see anything mentioned about the CT BOP test. Tom 5/7/2009 • Page 2 of 2 From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Wednesday, April 29, 2009 11:39 AM To: McMullen, John C; Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: Request to revise H-13 sundry #309-127 Tom, A revision to the H-13 Sundry (309-127) is requested to include milling a window in the liner as part of the pre rig work. A revised version of the Sundry verbiage is attached as well as the pre-rig procedure for milling a window. Regards, Sean From: McMullen, John C Sent: Wednesday, April 29, 2009 10:44 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); McLaughlin, Sean M Subject: RE: Drilling Windows with Service Coil We do not intend to proceed without your endorsement. That's why Icalled - to discuss how to get the endorsement. For starters, we'll proceed as you suggested with a sundry notice to "change approved plan". Sean will submit the paperwork. Thanks, John From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 29, 2009 10:21 AM To: McMullen, John C Cc: Regg, James B (DOA) Subject: Drilling Windows with Service Coil Importance: High John, I am sorry, but I am not going to be available to discuss this matter this morning. While it may seem that milling a window is essentially the same as plug milling or cleanout activities performed by service coil units, the fundamental difference is that the casing is exited in the window case. Possible differences in available rig equipment need to be reconciled. A read of the procedures provided with the sundry to P&A H-13 (181-017 - 309-127) and the permit for H-13A (209-044) does not provide any information as to what "coil rig" would be employed. At a minimum, a sundry notice will be required to "change approved plan". Also, be advised that I do not agree with your stated intent to "proceed as you plan". That may ultimately ultimately happen, however I don't believe that sufficient information has been provided to support my endorsement of the changed plans. I look forward to talking with you later this afternoon. Tom Maunder, PE AOGCC 5/7/2009 by To: Clark Olsen /Jerry Bixby GPB Well Ops Team Leaders From: Sean McLaughlin 564-4387 O / 223-6784 C Subject: H-13A Pre CTD Sidetrack Prep AFE#: PBD 4P2936 Sundry#: 309-127 Date: April 14, 2009 Revision: 1 The anticipated spud date for Nordic 2 to drill a CTD horizontal sidetrack from well H-13A is May, 20 2009. Objectives: Prep well for CTD rig Pre-Rig Work Summary: 1. OMIT-IA - 3000 psi Pass 2/23/09 2. S DGLV's 3. S Drift for 4-1/2" X 7" Thru tubing whipstock to 9150' MD 4. E Set whipstock at 9080'MD. 5. C Down squeeze 27 bbl of 15.8 ppg cmt past whipstock to abandon existing perforations. 6. C Mi11 XN nipple at 8431' MD to 3.80" with left hand motor and mill. 7. C Mill 3.8" window at 9080' and 10' of rathole. 8. O AC-LDS; AC-PPPOT- T 9. OPT tree (MV,SV,WV) 10. O Set BPV 11. O Bleed gas lift and production flowlines down to zero and blind flange 12. O Remove S-Riser, Remove wellhouse, level pad Post Rig: 1. Re-install wellhouse and FL's. 2. Generic GLV's Notes: o Reference Log: Schlumberger CBL 05/14/81 o Minimum ID: 3.725" at XN nipple (8431') o Max hole angle above the WS set depth is ~22 deg o Max DLS is 3.9 deg/100ft at 3400'. o Open perforations: Top perf at 9375'. o Reservoir pressure -BHP is expected to be 3209 psi (7.0 ppg) @ 8800'ss. Maximum surface pressure with gas (0.10 psi/ft) to surface is 2329 psi. The 8.6 ppg milling/drilling fluid will provide a 730 psi static overbalance. •I-13A Pre-CTD Procedure i E-line -Set the Whipstock top (a~ 9080' with 10 deg Right of highside orientation The Baker TTWS (4-1/2" x 7") whipstock will be set 10 deg ROHS at 9080'. The Schlumberger WPP tool has had a difficult time rotating the heavy 4-1/2" x 7" WS at higher angles. The inclination at the set depth is 22 degrees. Please give Baker and SLB at least 48 hrs notice prior to the job. 1. Rig up Eline 2. MU the following toolstring o Wireline head swivel o WPP Tool o Baker E-4 #10 setting tool o Adapter setting sleeve o Baker 4-1/2" x 7" TTWS - NO RA Tags needed in the WS, there is sufficient GR character in this area Set the TOWS at 9080' at 10 Right of highside orientation. - +/- 15 deg of plan is acceptable. Call town engineer if outside but close to the limits. - 7" collars located at 9071' and 9108'. - The inclination at the setting depth is 22 degrees. - If it is difficult to obtain highside orientation attempt to jog the assembly and use the torque in the cable to roll the whipstock. Coil- squeeze cement to isolate perfs above the whipstock 1. Ensure the IA is fluid packed. MU slick cement nozzle BHA 2. Lightly tag whipstock, (1-2klbs) with BHA & correct to e-line setting depth, PU 10' & flag pipe. o The top open perforation is at 9375'. o SBHP is 7.0 ppg EMW 3. Pull up to 9070' (10' above TOWS). Perform injectivity test. There is not a current injectivity test to reference. Two GSO's have been pumped on the well. The last (2/12/98) had a pre acid injectivity of 5 bpm at 100 psi. There was an estimated 3-4 bbls of cmt placed behind pipe. The cement volumes can be changed based on the injectivity test. 4. RU cementers. Monitor WHP while mixing cement. Prepare to pump cement in the following sequence: a. 5 bbls water spacer b. 27 bbls 15.8ppg Squeeze cement (70-90 ml fluid loss) c. 5 bbls water spacer d. l lh# biozan for cement contamination & cleanout Notes: - Cement volume is based on 12 bbls across the perfs 5 bbls squeezed into perfs, and 10 bbls of excess. The volume or recipe may need to be adjusted after an injectivity test. - BHST = 216 deg F - The pumping of aggregate has not been defined, but should be considered in dealing with high reservoir injectivity. 2 of 7 •I-13A Pre-CTD Procedure 5. Bullhead cement past whipstock in to perforations. 6. When a 500 psi pressure bump, (over baseline injection WHP) is observed, open choke to take returns & begin pulling up, laying in remaining cement 1:1. 7. Position nozzle at cement top just as last barrel of cement reaches nozzle. Pull up hole to safety 300' above estimated TOC. 8. With coil at safety, close choke, and slowly walk squeeze pressure up to a target of 1000 psi. Holding squeeze pressure while circulating for 30 min while closely monitoring in and out volumes. If 1000 psi squeeze pressure cannot be reached after delayed hesitation, stop down squeezing cement when TOC is at the top of whipstock. Reduce WHP to SOOpsi over baseline and POOH while circulating. 9. After 30 minutes at squeeze pressure, slowly bleed wellhead pressure down to 500 psi above the baseline. Minimize pressure surges while bleeding down WHP and during clean out. 10. Swap to 1'/z# biozan then RIH at 1:1 jetting at max CT pressure down to the whipstock tray. Make 2 passes at 80%. 11. Jet up hole at 80% running speed and max CT pressure, washing the nipples, packer, and GLV's thoroughly. Wash BOP stack. RDMO. Coil- Mill XN at 8431' to 3.8"- use LH motor and mill 1. MU 3.80" HC D331 parabolic DSM ,left hand motor and mill, and MHA 2. RIH taking returns to the tiger tank and circulating at minimum rate. Closely monitor volumes in the tiger tank, avoid misting the pad, and keep the pressure at the tank less than 150 psi. 3. Tag the XN nipple dry @ 8431'. PU 10' and bring the pumps up. Gently mill through the XN with ~ 1-2klbs WOB. Back ream and dress until no motor work is observed. Coil- Mi113.8" window at 9080' and 10' of rathole. The window will be a 4'/2" x 7" single string exit off of a Baker TTWS. The planned TOWS depth is at 9080' with a 10 deg ROHS tray face. Refer to the CTD RP, "Window Milling: Through Tubing Mechanical Whipstock" for additional information. Issues and Potential Hazards • Give BOT 24 hr notice prior to the job. A BOT service hand will be on the unit for the window milling. • Use a 2# Bio system for milling to help clean the metal shavings out of the well. • Slow patient milling will be the key to a successful window. There is nothing to be gained trying to speed up the window. • The recirculation system will be used. Review spill risks. • Ensure the window is dressed and smooth. Operations 3 of 7 ~I-13A Pre-CTD Procedure • L Rig up the recirculation system including a weir tank, transfer pump, and filter pod. The weir tank is used to trap the metal shavings. 2. Fill upright tank with 2ppb Biozan 2% KCL milling fluid. 3. Make up the following BHA to mill through the liner: o Hughes Christensen 3.80" diamond window mill (P/N E0378) o Hughes Christensen diamond reamer 3.80"go/3.79"nogo 0 2'/g" Baker X-treme straight motor 0 2-3/8 PH6 pup joint (no weight bars) o Circ sub, Disconnect, DFCV o CTC back to 1.75" CT o Record gage go/nogo on both mill & reamer. o The mills will be made up to the motor at the BOT shop. 2. RIH displacing the well to 2ppb Biozan milling fluid, shut down pump, & lightly tag 01000# WOB) the pinch point dry (planned TOWS @ 9080'). The pinch point on this 4-1/2" x 7" WS is 4.6' from the TOWS. 3. PU 10+', bring pump to full rate (~2.5 by@, &RIH slowly. Note RIH weight & free spin pressure. Be prepared to tag 1'-2' above dry tag when pumping at full rate. 4. Tag TOWS as indicated by a 250-300 psi increase in pump pressure & flag pipe. If motor stalls, PU & time drill down at 1'/hr. Monitor motor work & limit to a 300 psi increase for the 1St one foot below the TOWS. Monitor & record WOB. Slowly increase motor work after milling 1' using 500 psi as a maximum. Expect ROP less than 1'/hr until mill cuts through the liner wall. Afterwards expect 2-3k# WOB & 1'-3'/hr ROP. 6. The mill-off could be as much as 8.9' down from TOWS. But, will likely occur ~7' down from the TOWS based on past windows. If mill off does not occur before the theoretical Bottom of the window, control mill at 1'/hr until the mill has reached 9' below TOWS. Mill-off will be indicated by an abrupt decrease in WOB & increased ROP. Record this depth as the bottom of the window. 7. Drill a minimum of 10' in the formation. Sand over the shakers is usually a good indication the window exit is successful. If there is any doubt catch a fluid sample and take it to the geologist on either Nordic 1 or 2. Ream up & down from the WS face to 2' below the window bottom several times at 1'/min. 8. Swap wellbore to seawater while POOH. Leave a 2000' freeze protect cap. 9. If window quality is in doubt run a crayola mill to clean up the window. 4 of 7 5 of 7 ,I-13A Pre-CTD Procedure • -13A Pre-CTD Procedure TREE = 6-318" MCEVOY WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angie = 26° ~ 9600' Datum MD= 9310' Datum ND = 8800' SS 72#, L-80, D = 12.347" ~ 26yj' Minimum ID = 3.70" ~ 9424' POSSIBLE COLLAPSED LINER ~ 5-1/2" TBG, 17#, L-80, .0232 bpi, ID = 4.892" H 8355' TOP OF 7" LNR H 8412' ~ 4112" TBG, 12.6#, L-80, .0152 bpi, D = 3.958" ~ $4g6' 9-5/8" CSG, 47#, L-80, ID= 8.681" ~-{ $907' PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° ~ 9375' Note: Refer to Production DB for historical peridata SIZE SPF INTERVAL O /S DATE 31/8" 4 9350.9370 S 02/12198 2-7/8" 6 9375-9400 C 03/03/98 3318" 4 9380-9400 C 02/20/98 3318" 6 94249430 S 06/02/94 3318" 6 9442-9462 S 06/02/94 7" LNR, 29#, L-80, .0371 bpf, D= 6.184" H-13 SAFETY NOTES: POSSBLECOLLAPSEDLNRFROM 9424' TO 9433', ID = 3.70". 2001' 5-112" CAM SSSV LAND NIP, D= 4.562" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO [MAY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK D 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 $~27~-15-1/2" SLIDING SLV, D = 4.562" 8315 TBG SEAL ASSYI 8335' 9-518" x 5-112" TNV PKR, ID= 4.75" 8355 5-112' X 4-1/2" XO 8399' 4112" X NIP, ID = 3.813" 8431' 41/2" X>QJ PLUG (03103/09) 8431' 41/2" ~ NIP, ID = 3.725" $466' 41/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 9262' I~ MARKER JO1Ni 9420' -FISH: CENT ARM/ROLLER WHEEL {02/24/09} 9$g$' FISH: TBG END LOCATOR ARM DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XXN PLUG 03/03/09 02/16/01 SIS-SLT COM/ERTED TO CANVAS 03/01/01 SIS-LG FINAL 09!26!01 RN1TP CORRECTbNS 05/29106 COlDTM PERF CORRECTIONS 6N3/04 03/03/09 TFA/SV FISH ! GLV GO (02/23/09) PRUDHOE BAY UNIT WELL H-13 PERMR No; 81-0170 API No: 50-029-20559-OD Sec. 21, Ti1N, R13E BP Exploretion {Alaska} 6of7 ~i-13A Pre-CTD Procedure TREE = 63!8" MCEVOY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 82,55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26` ~ 9600' Datum MD= 9310' Datum TVD = 88017 SS 13318" CSG, 72#, L-80, D = 12.347" Minimum ID = 3.70" ~ 9424' POSSIBLE COLLAPSED LINER ~ 5-12" TBG, TOP OF 412" TBG ~~ 8355 TOP 3-1/2" X 33116" X 2-7/8" LNR 841 TOP OF 7" LNR $412' 4-1l2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" $466' SG, 47#, L-80, ID = 8.681" w h ip slot k H -13 A SAFETY NOTES: POSSIBLE COLLAPSED LNR FROM Proposed CTD Sidetrack 9424'T09433',ID=3.70". ~~' 5-12" CAM SSSV LAND NIP, ID= 4.562" O GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 0223!09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8315' ~TBGSEALASSY $335' 9-5/8" x 5-1/2" TAN PKR, D = 4.75" $355' S-1/2" X 412" XO 8399' 4-12" X NIP. ID = 3.813" I4-112" XN NIP, ID MILLED TO = 3.80" i 4-1/2' TBG TAIL ID = 3.958" ELMD TT LOGGED 07/02/97 PERFORATION SUMMARY REF LOG: SBL ON 05!14/81 ANGLE AT TOP PERF: 25° ~ 9375' Note: Refer to Production DB for historical pe rt data SIZE SPF INTERVAL OpNSgz DATE 31/8" 4 93549370 S 02/12/98 2-718" 6 9375.9400 C 03/03/98 33/8" 4 93849400 C 02/20/'98 3-3/8" 6 94249430 S 06/02/94 33/8" 6 9442-9462 S 06/02/94 PBTD 9759' 7" LNR, 29#, L-8Q .0371 bpt, ID= 6.184" 9800' 13-3/16 x 2-7/8 X-over ~ ~33/16" x 2-7/8" cmt'd and pert'd ~ 22 IFISH: CENT ARM/ROLLER WHEEL(0224J09) ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 0422/82 ORIGRJAL COMPLETION 03/06!09 DTRISV SET XXN PLUG {03/03/09) 02/16/01 SIS-SLT CONVERTEDTOG4NVAS 03/10/09 MSE PROPOSEDCTDSIDEfRACK 03/01/01 SIS-LG FMAL 0926/01 RN/TP CORRECTIONS 0529/06 OO/DTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV C/O (02/23/09) PRUDHOEBAY UNR WELL: H-13A PERMR No: API No: 50-029-20559-01 Sec. 21, T7iN, R13E BP Exploration (Alaska) 7 of 7 Service Coil BOPE requiremeor milling a window • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 21, 2009 1:56 PM To: 'McLaughlin, Sean M' Cc: McMullen, John C; Regg, James B (DOA); Harry Engel; Mike Bill Subject: RE: Service Coil BOPE requirements for milling a window Sean, Thanks for the well identifications. I have looked at the files and it is unclear from the procedures included with the permit applications that the intent was to P&A and drill the window using service coil, secure the well and move in the drilling coil. The operation reports indicate that multiple rigs were employed in each case with a lot of fishing being conducted on DS 05-17A/DS 05-17B (198-104). The operations for DS 07-29/DS 07-29A (198-227) did not encounter as significant difficulties. Dave's recollection of no state involvement is likely accurate as it is quite possible that the intent to separately employ a service coil FOLLOWED by a drilling coil was not realized when the permit was reviewed. During 1998, a total of 263 permits were approved with only 1 petroleum engineer being employed at that time by the Commission. You are correct that "things" have changed in a number of areas in 11 years. Specifically regarding that the BOP stack is now flanged, there weren't specific coil BOP regulations in effect until the regulations were updated effective November 17, 1999. With regard to milling a window and perforating being "similar", I do not agree, but this is not the forum to debate the differences. Suffice it to say, it is my opinion that exiting the wellbore is drilling and the necessary sundry and permit to drill need to be in place. I am hopeful that some sort of documentation can be located from the 1998 - 1999 time frame that can help us. If you have additional wells that you have identified, please let me know. If there is no prior documentation, then some sort of record/documentation will need to be established. I am sure we will exchange more messages on this. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Tuesday, April 21, 2009 9:47 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; Regg, James B (DOA) Subject: RE: Service Coil BOPE requirements for milling a window Tom, 05-17A and 07-29A are two wells to look at. I spoke to Dave Reem who was supervising coil unit #5 at that time. He was on the coil unit for rig up and milling the windows. The standard kit was used. He doesn't recall any state involvement or permits required. Although that part could have happened at the town level. History is interesting but we should be able to look at the current regs and make a decision point forward. There have probably been some regulation changes in the last 11 years and I know there have been some changes to the service coil operations. For example, in 1998 the BOPE was threaded onto the tree now the BOP stack is flanged up. I'd like to discuss how milling a window is different than any number of coil jobs that are done on a routine basis. More often than not when the coil rig gets to and leaves location the reservoir is exposed. Milling plugs and add perfs are great examples. If there are no issues with a coil rig adding perforations to a well then milling a window should be straight forward. There is no reason it shouldn't be treated as a prerig operation. Regards, Sean 5/7/2009 Service Coil BOPS requiremei~for milling a window • Page 2 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 21, 2009 8:43 AM To: McLaughlin, Sean M Cc: McMullen, John C; Regg, James B (DOA) Subject: RE: Service Coil BOPE requirements for milling a window Sean, Sorry I could not get back to you yesterday as I had a series of meetings. Could you please provide me with some well names where the service coil milling was employed? I looked at some of the CT redrills in the 1998/1999 time frame but was unable to identify any wells. Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, April 20, 2009 11:47 AM To: 'McLaughlin, Sean M' Cc: McMullen, John C; Regg, James B (DOA) Subject: RE: Service Coil BOPE requirements for milling a window Sean, et al, I don't know that proceeding with this process change is appropriate within the short time frame that you plan. One issue that may need to be examined is with regards to possible BOP equipment and testing protocols for work coil versus drilling coil rigs. Can you provide the well names where you examined reports? If this process change is implemented, it will be necessary to provide an updated procedure. Exiting the casing and then moving off likely has implications for securing the well in the interim between work coil and drill coil. Thanks in advance, Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Monday, April 20, 2009 10:36 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C Subject: RE: Service Coil BOPE requirements for milling a window Yep, Windows were milled with service coil in 1998 and 1999. I'll pulled a few old daily reports just to double check and the service coil operation seemed straight forward with the standard setup. We stopped milling the windows pre rig because the carbide mills used at that time would leave a rough exit and would need to be dressed by the rig. The diamond speed mills we use now drill a very clean exit. Some of the old players are still around and they agree it was a straight forward operation. It sounds reasonable a permit should be in place for the exit. We would like to give it a try on H-13B in about 2 weeks. The permit and sundry is already approved. Regards, Sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 17, 2009 4:24 PM To: McLaughlin, Sean M Cc: McMullen, John C Subject: RE: Service Coil BOPE requirements for milling a window Sean, et al, I believe this has been practiced previously. It would be my opinion that a new permit to drill should be in place. 5/7/2009 Service Coil BOPE requireme~for milling a window . Page 3 of 3 Further discussion on this may be necessary. I think we both should check with our colleagues who might have been involved with this before us. When are you planning such work and what well? Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Friday, April 17, 2009 4:20 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C Subject: Service Coil BOPE requirements for milling a window Tom, BP would like to use a service coiled tubing unit to mill a window as part of the pre rig work. The advantage to BP is that it saves Rig time. I looked in the regs and couldn't find a reason this would not be acceptable. I wanted to double check with you to make sure. I consider the operation much the same as perforating. We would be exiting in the Ivishak and drill about 10' of rathole after milling the window. Our whipstock ramp is 4 degrees so I figure the departure from the parent would be about 0.7 feet. This is less than many pert guns! The window milling BHA would be completely lubricated. The standard BOP set up for service coil is pipe/slip; pipe/slip; shear; blind; packoff. Would we need a approved permit to drill prior to milling the window? Regards, Sean Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 5/7/2009 Service Coil BOPE requiremei~for milling a window ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Grimaldi, Louis R (DOA) Sent: Wednesday, April 22, 2009 6:40 AM To: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Service Coil BOPE requirements for milling a window My view on the coil tubing situation is that the evolution of technology has surpassed the regulations and RP's. At this point I don't see much difference in the operations. I do agree with John that due to less oversight the service rigs may tend to be more "forgiving" of themselves on test procedure and performance. Every time I have tested one there have been instances of "Oh, we never test that" or "How much leakage is allowed?". This will be a sticky situation that will no doubt reveal some gaps in regulatory oversight. I wonder if they will do their leak-off test after drilling out, that's if they even know how to do one. guess if they get in trouble they can always just "Cut The Pipe!!!" From: Maunder, Thomas E (DOA) Sent: Tue 4/21/2009 2:18 PM To: DOA AOGCC Prudhoe Bay Subject: FW: Service Coil BOPE requirements for milling a window Here is the response that John sent in reply to my question. John raises some good points. Chuck or Lou, do you remember anything specific? The BP engineer did provide me some well names where the service coil did the P&A and drilled out. I looked at the permit applications and it is not possible to tell that a service coil would be employed to mill the window, that rig released and the CT drilling rig then moved on. Thanks in advance, Tom From: Crisp, John H (DOA) Sent: Saturday, April 18, 2009 5:47 AM To: Maunder, Thomas E (DOA) Subject: RE: Service Coil BOPE requirements for milling a window I don't know Tom. I can't remember the circumstances surrounding all the service coil work. The service coil Rig's have not been a priority for us to witness BOP tests because they test once a week & when they move on to a new well just test the flange breaks. I have witnessed BOP tests on these service Rigs & they don't usually get straight lines for 5 & 5. With Drilling could they be getting into areas such as compliance with choke manifold reg's. & gas detector reg's? Their next question will be why do we have to do a full BOP test & notify Inspectors if or Operation is just like perforating. Why can't we just dull or mill to 100'? Why can't we make just one trip & dull out one bit that will get us to more forgiving formation? After all we peforate in production zones & this will only put us 3' into production zone. From: Maunder, Thomas E (DOA) Sent: Friday, April 17, 2009 4:26 PM To: DOA AOGCC Prudhoe Bay Subject: FW: Service Coil BOPE requirements for milling a window All, I seem to remember reading something about using service coils to drill the windows. Do any of the Inspectors have recollection of this? From a technical stand point I don't know of any reason why it wouldn't work. It is my opinion that a PTD should 5/7/2009 Service Coil BOPE requireme~for milling a window ~ Page 2 of 2 be in place. Thanks for the help. Tom From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Friday, April 17, 2009 4:20 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C Subject: Service Coil BOPE requirements for milling a window Tom, BP would like to use a service coiled tubing unit to mill a window as part of the pre rig work. The advantage to BP is that it saves Rig time. I looked in the regs and couldn't find a reason this would not be acceptable. I wanted to double check with you to make sure. I consider the operation much the same as perforating. We would be exiting in the Ivishak and drill about 10' of rathole after milling the window. Our whipstock ramp is 4 degrees so I figure the departure from the parent would be about 0.7 feet. This is less than many pert guns! The window milling BHA would be completely lubricated. The standard BOP set up for service coil is pipe/slip; pipe/slip; shear; blind; packoff. Would we need a approved permit to drill prior to milling the window? Regards, Sean Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 5/7/2009 • ~- ~)~ I~ .rq ~ -.-.~~ i_.. 1J ~.....1 ~..' ~,.1 ~~ L.,t 1.,~ ALASSA OII, AlYD GA5 C01~5ERRATI011T COl~II~IISSIOrT John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 ,l~'. ~ ~ .~P~ ~.~ 20v~~ SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE t00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-13 Sundry Number: 309-127 Dear Mr. McMullen: 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, Cathy . Foerster Commissioner ,~ DATED this //3 day of April, 2009 • Encl. STATE OF ALASKA ~f~ ~~ ALA OIL AND GAS CONSERVATION CO~SION i APPLICATION FOR SUNDRY APPROVAL ~ `.APR ~ ~ ?Q1~~a_ t` 20 AAC 25.280 Alaska Oll ~ ~~. ~, ~{ I ~ < ~, >>Ss 1. Type of Request: ®Abandon • ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensioattC~~, ~(t8 ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. , ®Development ^ Exploratory 181-017 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20559-00-00 - 7. !f 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 H-13 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028284 • 82.6. Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9805 - 9329 ~ 9759 9287 8431' 9420' & 9398' in Le i TVD B r t Ila S ru r I n 11 11 1 ' urFa 2695' 13-3/8" 269 ' 2 5' 4 3 2 70 Intermediate Pr - / " 47 Liner 1389' 7" 411' - 980 ' 804 ' - 9324' 1 0 7 20 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9350' -9462' 8919' - 9020' 5-1/2", 17# x 4-1/2", 12.6# L-80 8466 Packers and SSSV Type: 9-5/8" x 5-1/2" TIW Packer Packers and SSSV MD (ft): 8335' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: , Commencin O erations: April 20, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 56a-4387 Printed Name J Mc UI Title Engineering Team Leader { ^ Prepared By NameMumber Signature Phone 564-4711 Datey c/~ ~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: a Conditions of approval: Notify Commission so that a representative may witness S~ ,, '~~~~~~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ location Clearance Other: ~5~~ pc,`~ ~'r'~-5~ ~ ~~~pS°i1`ti`~1~-:~~1 C3.'hl~J`~-C~~~ Subsequent Form Required: ~~~ APPROVED BY ,/ ~t'~ ` t9 / A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2~b06 Submit In Duplicate jg% k_rt L~ To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: 08 April 2009 ~ ill `~ Re: H-13~Sundry Approval • by Sundry approval is requested for well H-13. Initial perforations were just above the 25N shale. Current open perforations are still within this same interval. H-13 remained at low WC and GOR into the late `80's. WC increased to about 10% when perforations were added below the 25N shale in 1987, and GOR started increasing in late 1988. In 1994, a cement squeeze was performed to shut off high gas production from above the 25N shale. Post squeeze perfs were added below the 25N shale in an effort to hold off the gas. However, post squeeze production below the shale was in excess of 90% WC. Competitive production was not re- established until perforations were added above 25N in 1997. There were substantial variations in NOR, WC and GOR in H-13 during 1997. These may be partially in response to high rate injection in Y-18 at the time. In 1998, a second cement squeeze was performed to shut off high gas production coming from the upper set of leaking squeezed perforations located above the 25N shale and an attempt to shut off the water from below. A Borax log in 2001 confirmed that the second squeeze was still holding. Improved offtake at the end of 2002 may be a response to a temporary return of Y-18i to injection. In 2007, the H-13's production continued to decline and GORs reached over 50,000. A subsequent production log showed that the uppermost perforations were again leaking and contributing 100% of the wells production. For lack of a reliable gas shut off option, the well was shut in. REASON FOR SIDETRACK H-13 is currently SI as a low value producer with high GOR and no on time. Wellwork options to shutoff the gas have been exhausted given the two previous squeezes and the geological structure for the area. Future utilization of this wellbore has been determined to be a sidetrack. Northeast of H-21 the cross section drops down into the Zone 2 GDWFI area. H-13 is an ideal candidate to sidetrack into an area of thick GLOC in GDWFI Zone 2 between the current H-13 and H- 23. The proposed plan for H-13A is to drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around May. 15 2009. The existing perforations will be isolated by a cement downsqueeze after setting the whipstock, as well as the primary cement job. The sidetrack, H-13A, will exit the existing 7" liner and kick off in Z4 and target Zone 2C reserves. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (scheduled to l~n April 20, 2009) • 1. O MIT-IA - 3000 psi Pass 2/23/09 2. S DGLV's 3. S Drift for 4-1/2" X 7" Thru tubing whipstock to 9150' MD 4. E Set whipstock at 9080'MD. 5. C Mill XN nipple at 8431' MD to 3.80" with left hand motor and mill. 6. C Down squeeze 40 bbl of 15.8 ppg cmt past whipstock to abandon existing perforations. 7. OMIT-Tubing 2000 psi 8. O AC-LDS; AC-PPPOT- T 9. O PT tree (MV,SV,WV), 10. O Bleed gas lift and production flowlines down to zero and blind flange 11. O Remove S-Riser, Remove wellhouse, level pad ~t5 ~~~~~ ~'\ ~. Rig Work: (scheduled to begin on May 15, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 2. Mill 3.8" window at 9080' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 620' (35 deg/100 planned) 4. Drill Lateral: 4.125" OH, 1227' (15 deg/100 planned) with resistivity 5. Run 3-3/16" x 2-7/8" solid L-801iner leaving TOL at 8412' 6. Pump primary cement leaving TOC at 8780', 28 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/CCL log ~ , 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (700') 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Sean Mclaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE _~ 6-318" MCEVOY WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV - 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2695' Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8355' TOP OF 4-1 /2" TBG $355' TOP OF 7" LNR ~--~ 8412' 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" LE COLLAPSED LNR FROM 0 E S ~ ~ H -13 94 33 ' ID 3.70" 94 2001' S-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8276' ~ 5-1/2" SLIDING SLV, ID = 4.562" 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1 /2" TMJ PKR, ID = 4.75" 8355' 5-1 /2" X 4-1 /2" XO 8399 4-1/2" X NIP, ID = 3.813" 8431' 4-1/2" XWV PLUG (03/03/09) 8431' 4-1/2" ~V NIP, ID = 3.725" 8466' 4-1/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-) 8907' PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-1/8" 4 9350-9370 S 02/12/98 2-7/8" 6 9375-9400 C 03/03/98 3-3/8" 4 9380-9400 C 02/20/98 3-318" 6 9424-9430 S 06/02/94 3-3/8" 6 9442-9462 S 06/02/94 9398' ~~FISH: TBG END LOCATOR ARM PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XMV PLUG (03/03/09) 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORRECTIONS 05/29/O6 CO/DTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV GO (02/23/09) PRUDHOE BAY UNIT WELL: H-13 PERMIT No: 81-0170 API No: 50-029-20559-00 Sec. 21, T11N, R13E BP Exploration (Alaska) MARKER JOINT 9420' I-I FISH: CENT ARM/ROLLER WHEEL TREE _. 6-3/8" MCEVOY WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum TVD = -- --- 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ H-13 Proposed CTD S O Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8355' TOP OF 4-1 /2" TBG 8355' TOP 3-1/2" X 3-3/16" X 2-7/8" LNR 8412' TOP OF 7" LNR ~- 2001' -15-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8276' ~ 5-1/2" SLIDING SLV, ID = 4.562" 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1/2" TNV PKR, ID = 4.75" 8355' S-v2° x 4-v2° xo 8399' I-i 4-1 /2" X NIP, ID = 3.813" I 8431' ~4-1/2" XN NIP, ID MILLED TO = 3.80" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8466' 8466' 4-1/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 9-5/8" CSG, 47#, L-80, ID = 8.681" whipstock 8907' 8790' Toc 9080' 10300' 3-3/16 x 2-7/8 X-over PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical p ert data SIZE SPF INTERVAL OpNSgz DATE 3-1/8" 4 9350-9370 S 02/12!98 2-7/8" 6 9375-9400 C 03/03/98 3-3/8" 4 9380-9400 C 02/20/98 3-3/8" 6 9424-9430 S 06/02/94 3-3/8" 6 9442-9462 S 06/02/94 PBTD 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800' 0 22 13-3/16" x 2-7/8" cmt'd and oerf'd I 10927' I 9398' FISH: TBG END LOCATOR ARM 942 FISH: CENT ARM/ROLLER WHEEL DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XXN PLUG (03/03/09) 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/10/09 MSE PROPOSED CTD SIDETRACK 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORRECTIONS 05/29/06 CO/DTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV Cl0 (J2123/OE)'. ~ I ~-- PRUDHOE BAY UNfr WELL: H-13A PERMfr No: API No: 50-029-20559-01 Sec. 21, T11 N, R13E BP Exploration (Alaska) e 0 og escrlPtlon ae o or H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21 B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22/07 1 J-25A 11767130 MEM PROD PROFILE 06/18/07 1 Z-08A 11630483 GLSIPROD LOG 06122/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02-30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37 A 11594506 PPROFIIPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13/07 1 Z-13A 11649962 MEM PROD PROF (REVISED) 04/21/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 US IT (CEMENT) 06/24/07 1 12-05 11676951 USIT (CORROSION) 06/24/07 1 B-15 11626097 USIT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 ScblumblPger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WII J b# RECEIVED JUL 0 3 Z007 J~æka Oil & Gas Coos. CommIssion AndIorage L D 06/29/07 NO. 4324 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D t BL CI CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. SCANNED JUL 0 5 2007 Petrotechnical Data Center LR2-1 . 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /~ 1- 01'1- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, .._~r,~'~, ~ ~: ~,-~ - DATE: April 22, 2001 Commissioner ;fi ~-~ ~' ~ Tom Maunder, ~~~ P. I. Supervisor ~ (3~" ~ \ FROM: Lou Gdmaldi, SUBJECT: Petroleum Inspector SVS Misc. tests BPX H pad Prudhoe Bay Field Sunday. April 22. 2001; ! witnessed the first of the one-month retests of the SVS systems on BPX H pad wells in the GC-2 area of the Prudhoe Bay Field. Merv Liddelow (BP Rep.) performed the SVS tests today. All components functioned properly and held their pressure tests. The new style pilot boxes were installed on most'of the wells, which combined with the reliability of the electronic pilots helped to produce these great results. The well. houses were all dean with pilot valves in proper position. SUMMARY: I witnessed the SVS test on twenty BPX H pad wells in the Prudhoe . Bay Field. 20 wells, 40 components, No failures. Wellhouse Inspections; 33 wellhouses, No problems noted. Attachments: SVS PBU H-pad 4-22-01 LG.XLS NON,-CONEIDEN,,T, IAL, SVS PBU H-pad 4-22-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Ung/Pad: Prudhoe Bay field, H-pad Separator psi: LPS 157 HPS 22-Apr 650 WeH Permit Separ Set L/P Test Test Test Date OikWAG, GINJ, Number Number PSI PSI Tdp Code Code Code Passed GASorCYCLE H-01A 1951100 H-02 1710160 H-04 1710220 H-05 1710240 650 550 550 P P OIL H-06 1770020 157 125 125 P P OIL H-07A · 2001280 H-08 1770230 H-11' 1800680: 157 125 1001 P P 0IL , .Hr~2 1800670 !~!~!~'~I~''~''~1810170 650 550 525' v v ' OIL H-14A 1980680 H-15 1810610 157 125 125 P P OIL , H-16B 2000650 . H-17A 1971520 650 550 510 P P OIL H-18 1822100 H-19B 19809401 650 550 540 P P ' .. oIL , H-20 1830070 H,21 1860710 650.: 550 525 P P ' OIL H-22A 1970480 157 125 i25! P' P OIL , H-23A 1950850 650 550 550 P P OIL! , H-24 1853050 157 125 115 P P OIL H-25 1852680 650 550~ 550 P P OIL H-26 1852770 157 125 95 P P OIL H-27 1852360 , H-28 188044G H-29A 1980380 650 550 530 P P OIL H-30 1880350 650 550 525 P P OIL H-31 1940140 H-32 1940250 157! 125 100 P P oIL H,33 1940380 650 550 515 P P OIL H-34 1971640 157 ' 125 125 P P. OIL H-35 '1951490 650 550 515 P P. ' OIL H-36A 2000250 H-37 1971020 157 125 125: P P OIL , ,, , W~' 1/16/0! 20 Components: p~_~el~a~!lu~es: 0 Well Permit Separ Number Number PSI Set PSI L/P Trip Test Code Date on, WAG, GINJ, Passed GAS or CYCLE Remarks: Great test, no failures. RJF 1/16/01 Page 2 o£2 SVS PBU H pad 4-22-01 LG STATE OF ALASKA ALA~"' OIL AND GAS CONSERVATION COMMIS~~ ' REPORT SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exl)loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 1652'SNL, 1264' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 1180' SNL, 814' EWL, SEC. 22, T11N, R13E, UPM At effective depth 1198' SNL, 1108' EWL, SEC. 22, T11N, R13E, UPM At total depth 1200' SNL, 1128' EWL, SEC. 22, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 9805 true vertical 9328 Effective depth: measured 9759 true vertical 9287 Casing Length Size Structural -- Conductor 61' 20" x Surface 2646' 13 3/8" Intermediate 8857' 9 5/8" Production -- Liner 1389' 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=82.55 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number H-13(11-22-11-13) 9. Permit number/approval number 81-17 / 10. APl number 50-029-20559 11. Field/Pool I Prudhoe Oil Pool feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth BKB 8 cu. yds. 110' 110' 3720 c.f. 2695' 2695' 1338 c.f. 8906' 8509' 7" 380 c.f. 8411 '-9800' Perforation depth: measured 9380'- 9395'; 9395'-9400'; 9424'-9430'; 9442'-9462' Rna'd: .q.qRo:.q.q70: true vertical~ubsea 8864'- 8877'; 8877'-8882'; 8903'-8909'; 8920"-8938' Sazd: 8837'-8855' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8335' with 4 1/2" tailpipe to 8466' 8048 '-9323' ORIGINAL Packers and SSSV (type and measured depth) 9 5/8" PBR/packer at 8335'; 5 1/2" SSSV at 2001' 13. Stimulation or cement squeeze summar~ee attachment Intervals treated (measured) Treatment des. cription including volumes used and final pressure 14. Representative Daily Average Production or Injection Data RECEIVED ,JUL ]4 11tll as. Cons. c, ommi Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 905 7387 60 0 1002 1846 1173 1670 2244 281 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil× Gas Suspended Service 17. I hereby certify that the fo)~going is true ,~)'td ~correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE H-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/12/98 A GSO Cement Squeeze was performed using the following fluids: SUMMARY Bullhead killed well with 375 bbls of water. Rig in hole with 3.0" combo nozzle. Tagged TD at 9494'. PUH flagged pipe and cooled sump with 280 bbls of water. Pre-acid injectivity was 5 bpm at 100 psig, Laid in 15 bbls of DAD acid. Post acid injectivity was same, Over displaced acid with 55 bbls of water, Pumped 20 bbls of cement while pumping 2.4 bpm down backside. Laid in 10 bbls of cement with chokes closed. Laid remaining cement in while ramping pressure to 3000 psig. Held 3000 psig for 1 hr. Squeeze had a slow leak about 5 psi/min. lAP came up 130 psig during this time. Bleed WHP down to 500 psig, dropped ball and began jetting biozan. C/O cement to a depth of 9490'. Jetted liner to WCTOC and back. Laid in 14 bbls of TEA and Pull out of holed jetting liner and jewelry. FP tubing to 2000'. Final PT was JFT at 550 psig. Estimate 3-4 bbls cement behind C/O to 9490' CTMD Fluids Pumped BBLS. Description 705 2% KCL 470 2% KCL with FR 15 Fresh Water 20 Cement .. 95 Methanol 37 Biozane 14 TEA 1356 TOTAL BBLS ADDPERF 02/20198 SUMMARY The following additional interval were perforated using 2 7/8" guns, 6 SPF, random orientation and 60° phasing. 9380'- 9400' MD REPERF 03102/98 SUMMARY The following interval were reperforated using 2 7/8" guns, 6 SPF, random orientation and 60° phasing. 9375'-9400' MD STATE OF ALASKA R OIL AND GAS CONSERVATION COMMISS~ . REPO 'SUNDRY WELL OPB, ,ATIONS 1. Operations performed: Operation shutdown . Stimulate Plugging__ Perforate Pull tubing__ Alter casing ..... Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoraae, Alaska 99519-6612 4. Location of well at surface 1652'SNL, 1264' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 1180' SNL, 814' EWL, SEC. 22, T11N, R13E, UPM At effective depth 1198'SNL, 1108' EWL, SEC. 22, T11N, R13E, UPM At total depth 1200' SNL, 1128' EWL, SEC. 22, T11N, R13E, UPM 5. Type of Well: Development ExploratonJ Stratigraphic Service , 6. Datum elevation (DF or KB) KBE=82.55 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number H- 13(11-22-11-13) 9. Permit number/approval number 81-17 / 10. APl number 50-029-20559 11. Field/Pool Prudhoe Oil Pool.,, ,, i ~ ~'~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9805 feet Plugs (measured) 9328 feet 9759 feet Junk (measured) 9287 feet Casing Length Size Cemented Measured depth Structural -- Conductor 61' 20" x 8 cu. yds. 110' Surface 2646' 13 3/8" 3720 c.f. 2695' Intermediate 8857' 9 5/8" 1338 c.f. 8906' Production -- Liner 1389' 7" 380 c.f. 8411'-9800' Perforation depth: measured 9380'- 9395,; 9395'-9400'; 9424'-9430,; 9442'-9462' true vertica§ubsea 8864'- 8877,; 887758882,; 8903'-8909,; 8920"-8938' Sozd: 8837'-8855' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8335' with 4 1/2" tailpipe to 8466' Packers and SSSV (type and measured depth)9 5/8" PBR/packer at 8335,; 5 1/2" SSSV at 2001' True ve~ical depth BKB 110' 2695' 8509' 8048'-9323' 13. Stimulation or cement squeeze summar~ee attachment Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 905 7387 60 0 1002 1846 1173 1670 Tubing Pressure 2244 281 15. Attachments 16. Status of well classification as: \Copies of Logs and Surveys run.. Daily Report of Well Opej~tions Oilx Gas Suspended /17. I here?.¥ ce~ify t~h~t th~)/f,~regoing"~ is true,~nd,,.correct to the best of my knowledge. ¢ . ~igned~"~/~~ / ~~,,~__~ Title Technica/Assistantlll I m10-404 bev 06/15/88 ' Service Date ~/~___~/F~:~' SUBMIT IN DUPLICATE H-13 DESCRIPTION OF WORK COMPLETED REPERF O7/O2/97 SUMMARY The following interval were reperforated using 3 3/8" guns, 4 SPF, random orientation and 60/120° phasing. 9380'- 9400' MD HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 May 1996 RE: Transmittal of Data Sen~ by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: Run ~' 1 Run # 1 Run # 1 ECC No. 2452.06 5665.11 6090.05 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ..... O (907) 563-7803 :~ -~. 'k-~ ~'~ Received by: Date: ~! I ' ' ' '~ '~'" ? LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE .~NCHORAGE AK, 99501. Date: 9 May 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION '~i-;lZ G-16~44-11-11-13) i PLS FINAL BL+RF ECC No. i PLS FINAL BL+RF 1 CN FINAL BL+RF 1 PLS FINAL BL+RF 1 CN FINAL BL+RF Run # 1 1130.08 Run # 1 2413.02 Run # 1 2452.06 Run # 1 3385.03 Run # 1 4112.05 1 PFC/PERF FINAL BL+RF Run ~ i 1 PLS FINAL BL+RF Run # 1 Run # 1 1 PLS FINAL BL+RF Run # i 1 CN FINAL BL+RF Run # I 1 CN FINAL BL+RF Run # 1 1PLS FINAL BL+RF Run # I 1 PLS FINAL BL+RF Run # 1 I PLS FINAL BL+RF cont/ i PFC/PERF FINAL BL+RF Run # i 1 GR/CCL FINAL BL+RF Run ~ 1 4468.06 5609.04 5627.13 5665.11 6090.05 6103.05 5234.05 6624.03 6667'00 6670.00 Please sign and return to: Attn. Rodney D. Paulson _~,~ Western Atlas Logging Service~!~ 'i'~i.'I'I 5600 B Street Suite 201 ., ' .... . I Anchorage, ~ g9518 Received by: Date: Aiaska Oil & G~ Cons. Commiss',m STATE OF ALASKA REPOR co.sE.v^ ,o, couu o. OF SUNDRY WELL OPE. RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging__ Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigmphic Sewice 4. Location of well at surface 1652'SNL, 1264' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 1180' SNL, 814' EWL, SEC. 22, T11N, R13E, UPM At effective depth 1198'SNL, 1108' EWL, SEC. 22, T11N, R13E, UPM At total depth 1200' SNL, 1128' EWL, SEC. 22, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 9805 feet Plugs (measured) 9328 feet 6. Datum elevation (DF or KB) KBE=82.55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-13(11-22-11-13) 9. Permit number/approval number 81-17 / 10. APl number 50- 029-20559 11. Field/Pool Prudhoe 0il Pool Effective depth: measured true vertical 9759 feet Junk (measured) 9287 feet Casing Length Structural -- Conductor 61' Surface 2646' Intermediate 8857' Production -- Liner 1389' Perforation depth: measured Size Cemented 8 cu. yds. 3720 c.f. 1338 c.f. ?O" x 30" '3 3/8" 9 5/8" 7" 380 c.f. 9350' - 9462' (four intervals) Measured depth 110' 2695' 8906' 8411~9800' True ve~icaldepth BKB 110' 2695' 8509' 8048'-9323' true vertical subsea 8837'-8938' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8335' with 4 1/2" tailpipe to 8466' Packers and SSSV (type and measUred depth) 9 5/8" PBR/packer at 8335'; 5 1/2" SSSV at 2001' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 905 7387 60 0 2244 Subsequent to operation 1002 1846 1173 1670 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the forecm~ng, i~ ~ue and correct to the best of my knowledge. Signed(~~~ ~J~&~ Title SeniorTechnicalAssistantl, Form 10-406 Rev 06/15/88 / 281 Service Date SUBMIT IN DUPLICATE WELL H-13(11-22-11-13) NRWO/Reperf Operations 6/02/94 A NRWO GSO Squeeze was performed using the following fluids: SUMMARY WELL FLOWING ON ARRIVAL. LP WELL W/423 BBLS 100 DEG SW AT 5.5 BPM @ 50 PSI FINAL INJ RATE WHILE RIH W/3.5" CMT NOZ. COOL SUMP THEN MAKE JET PASS TO WCTOC. NOTICED PERFS STARTING TO PLUG AT BEGINNING OF DOWN PASS. LET WHP INCR TO 700 PSI AND STILL BUILDING. SD, MONIITOR. LOST 500 PSI IN 3 MIN. ORDER ACID, DUMP CEMENT. PUMP 35 BBLS 15% HCL W/25% XYLENE. LAID IN 19 BBLS OF CEMENT (68 CC/30 MIN FL IN FIELD). BUILD TO 3000 PSI SQUEEZE PRESSURE OVER NEXT 70 MINUTES. SD. BLEED OFF FROM 3000 TO 2900 PSI OVER 7 MINUTES. LIVE CELL FLUID LOSS OF 71 CC. BEGIN LIVE REVERSE OUT. FINISH LIVE CELL WHEN PERFS UNCOVERED AT 115 CC FL. REVERSE DOWN TO 9569' CTMD. SET DOWN ON HARD BOTTOM. CIRC BOTTOMS UP. BEGIN JETTING. UNABLE TO USE BALL BECAUSE OF BALL CATCHER PROBLEMS. MAKE UP PASS TO 8900' AND JET DOWN TO 9569'. REVERSE 130 BBLS SW. 14 BBLS CEMENT RETURNED. SD. HELD 2000 WHP FOR 8 MINUTES. REVERSE IN 46 BBLS OF N2. POOH. LEAVE WELL SI. FLUIDS 423 BBLS SW TO LOAD WELL 126 BBLS SW 35 BBLS ACID ** BBLS SW 12 BBLS FW (PREFLUSH) 20 BBLS CEMENT 6 BBLS FW (SPACER) 26 BBLS SW 26 BBLS DUO POLYMER (CONTAMINANT) 12 BBLS SW (DISPLACEMENT) 465 BBLS SW (REVERSE OUT) 80 BBLS SW (JET PASS) 130 BBLS SW (FINAL REVERSE OUT) 45 BBLS RECOVERED (N2 DISPLACEMENT) ** BBLS MEOH (FREEZE PROTECTION CT) ** BBLS MEOH (FREEZE PROTECTION WELL) v*. BBLS MEOH (FREEZE PROTECTION FLOWLINE) WELL CLEANED OUT TO 9569' 14. BBLS CEMENT RECOVERED (DOES NOT INCLUDE CEMENT NOT PUMPED) ACID (B.J. SERVICES) 15% HCL/25% XLYENE CONTAINING 5 GAL NE-41 5 GAL AC1274 9 GAL S-500 30 LB FERROTROL 210 CEMENT (B..I. SERVICES) 15.8 PPG CLASS "G" CMT CONTAINING 0.42% FL-33 0.1% CD-32 0.4% R-11 0.2% GEL 0.2%S-400 1.0 GAL PER SK FP-6L PAGE 2 WELL H-13(11-22-11-13) 6/07/94 7/14/94 8/15/94 The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9442' - 9462' MD The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9424' - 9430' MD The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9395' - 9400' MD LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE . AK, 99501. Date: 11 October 1994 Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION - · i PLS FINAL RF SEPIA Run # 1 H-16 i PLS FINAL BLUELINE Run # 1 1 PLS FINAL RF SEPIA Run # 1 H-16 1.PLS/STP FINAL BL Run # 1 I PLS/STP FNL.RF SEPIA Run # 1 1 PL/STP FINL.RF SEPIA Run # 1 ,~%H-17 (34-15-11-13) I PL/STP FINAL BL Run , 1 I PL/STP FINL.RF SEPIA Run # 1 ~/ ',(~F-42 (22-35-12-13) 1 PL/PROFILE FINAL BL Run # 1 I PL/PROFILE RF SEPIA Run ~ 1 1 PLS FINAL RF SEPIA Run ~ 1 H-13 (22-11-13) i PL/STP FINAL BL Run ~ 1 I PL/STP FINL.RF SEPIA Run ~ 1 -25 (33-7-11-13) 1 PL/PROFILE FINAL BL Run ~ 1 1 PL/PROFILE RF SEPIA Run $ I ECC No. 926.04' 2452.04 2452.03 5608.04 5665.08 5953.06 6047.02 6090.04 6238.05 At%as w'{~l{ -'"~600 B Street Attn. Rodne~~ulson Or F~ to (907 - ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 18 August 1994 RE: '~ Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL Y-02 (22-27-11-13) ~____~~ H-13 (22-11-13) DESCRIPTION 1 PL/SPNR FINAL BL 1 PL/SPNR RF SEPIA 1 PDK/BORAX FINAL BL 1 PDK/BORAX RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA ECC No. Run ~ 1 5786.04 Run # 1 Run ~ 1 6069.01 Run # 1 Run # 1 6090.03 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Received b~.w ~n~pauls°nDate~/O$&O~~ ~ ~ ~9~ D Please sign and return Petr0technical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99~08 Received by Please sign and return to: Petrotechnical Data C~ ~er BP Exploration (Alaska £nc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by . m+-o~S~LASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 20 July 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Dear. Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. R-16 (24-28-12-13) H-iS (22-11-13) 1 GR/JEWL. FINAL BL /La STP FINAL BL /~ OR/JEWL. RF SEPIA ~'~ PLS STP RF SEPIA /~CL/PERF FINAL BL 1 ~CL/PERF RF SEPIA l~~PL S LEAKDET FINAL BL S LEAKDET RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1' Run # Run # 1 3889.05 6090.02 Run # 1 5780.05 Run ~0~ W-08 (11-26-11-12) ~PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 4117.05 Run # 1 ~Sq x-01 (14-5-10-14) ~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 PLa LEAKDET FINAL BL 1 PLS LEAK. RF SEPIA Run # 1 4529.02 Run # 1 Run # 1 3986.02 Run # 1 t ECEIV£D Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: ,/(IL 2 ? 1994 Alaska Oil & 6as Cons. Anchorage c°mmissiorl Date: RECEIVED( JUN 2_ ?r 1994 Alaska 0il & Gas Cons. Cornmissior~ Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Date: 15 June 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Enclosed, please find the data as described below: WELL # DESCRIPTION R-10 F-34 (44-35-12-13) /! PLS PRESURE FINAL BL 1 PLS.PRESURE RF SEPIA PLS PRESURE FINAL BL 1 PLS PRESURE RF SEPIA ECC No. Run # 1 5823.01 Run # 1 Run # Run # 1 61~1.02 H-13 /1 PFC/GR/PERF' FINAL BL 1 PFC/GR/PERF RF SEPIA Run # 1 6090.01 Run # C-30 /~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run ~ 1 3983.01 Run # H-25 /1 PFC/GR/PERF FINAL BL 1 PFC/GR/PERF RF SEPIA Run # 1 5666.02 Run # 1 H-19 (22-15-11-13) ~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 3448.01 Run # 1 R-27 //1 PFC/PERF FINAL BL ! PFC/PERF RF SEPIA Run # 1 5670.03 Run # 1 P-23 (41-32-11-13) 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 6043.03 Run # 1 H-32 (42-20-1!-13) /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 6170.04 Run # 1 H-31 /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 6158.04 Run # N-21 /1 DTEMP/GR FINAL BL 1 DTEMP/GR RF SEPIA Run # 1 5630.01 Run ~ 1 C-ll /1 DTEMP FINAL BL 1 DTEMP FINAL RF SEPIA Run # 1 5942.01 Run # 1 Cont/ ALASKA oIL ~ GAS cONSERuATION COMMIssION Attn. LARRY GRANT 3001 poRCUPINE DR. ANCHORAGE AK, 99501- USA Date: RE: ECC #: Data: 6 December 1993 Transmittal of Data 6090 · 00 CN/~R Dear sir/Madam, BP Reference: H-13 PRUDHOE BAY ~,'~'. NORTH sLOPE, AK Enclosed, P19ase find the data as described below: Tapes/D iskettes: 1 sent by U.S. MAIL Please sign and return to: Atlas wireline Services petrophysical Services 5600 B street suite 201 Anchorage, AK99518 Attn. Rodney D. paulson Received by: ~ Date: cN/GR LDWG TAPE+LIST Run # i RECEIVED DEC 0 7 199,~ Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 24 November 1993 RE: Transmittal of Data ECC #: 6090.00 Data: CN/GR Dear Sir~Madam, Reference: BP H-13 NORTH SLOPE, . AK Enclosed, ple~e find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL CN/GR FINAL BLUELINE Run # 1 CN_~/GR RF. SEPIA Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services ~ ' 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by:__~~~~~~~ Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 /9 DATE: 05/27/92 T# 83529 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. D-07~;tf'>~ CCL 04/29/92 D-18~l'/Oe8 PFC ..- 05/23/92 D---~ ~Z--~ CCL/PERF F 05/25/92 $-31~-/~ TDT-P BO~X F 05/09/92 F-45~/--~ PROD-F F 05/05/92 G-02 ~,~0 TDT-P BO~X F 04/10/92 8-13 ~;~PROD-F ~ 05/10/92 M-26A~ ~ CNA / 05/20/92 M-31~Z')~ CCL/ 05/22/92 P-15~O-/~GAS LIFT SU~VEYF05/04/92 P-16~e'/~.GAS LIFT SU~VE~ 04/29/92 W-3~'~ CCL/PE~F, 05/14/92 x-o z-J9 ~-%3 PELF/ ]~[~5 " ~5 " 05/21/92 #1 05/15/92 #2 04/2~/92 #1 11500.00-12372.00 CAMCO 5 " 10900.00-11150.00 ATLAS 5 " 10080.00-10369.00 ATLAS 5 " 8750.00- 9482.00 SCH 5 " 9000.00- 9330.00 CAMCO 5 " 9500.00-10231.00 SCH 5 " 9250.00- 9500.00 CAMCO 5 " 9100.00-11770.00 SCH 2/5" 8800.00- 9861.00 SCH 5 " 2100.00-11900.00 CAMCO 2/5" 365.00-10200.00 CAMCO 2/5" 11300.00-11820.00 ATLAS 5 " 9690.00- 9881.00 SCH 5 " 13450.00-14350.00 SCH 5 " 12100.00-12372.00 CAMCO 05/09/92 #1 05/09/92 #1 100.00- 8900.00 SCH 100.00- 8900.00 SCH Information Control Well Records Adrian J. Martin / C£1VED JUN 1 1 199 . Alaska Oil & Gas Cons. Commission Anchorage Stondo~d A|oska P~oduction Company 900 EO$! Befl$on Boule~ P.O. Bo, 196612 1~7~ 564-511 I DALLAS INDEXED ARCO CHEVRON EXXON TEXACO Dote: 03/31/87' TO: MOBIL TI: 77804 PHiLLiPS ' STANDARD ALASKA PRODUCTION STATE OF ALASKA GEOSC IENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge recelptby signing a copy of this letter and returning:It to this Offlce: ' B-7 C-38 D-3 G-1 G-19 H-13 H-17 J-2 J-5 K-5 M-14 Q-5 S'13 Y-22 Y-24 Y-24 Perf. Record Production Profile WOPITS Flowmeter/Temp. Fullbore Spinner Production Profile Production Profile Completion Record Perf. Record Perf.' Record 03/17/87 #1 11500-11848 Sch' 03/12/87 #1 10825-11137 Camco 03/03/87 #1 10300-10660 Camco 03/18/87 #1 9750-10079 Camco 03/15/87 ~1 11250~11500 Sch 03/15/87 #1 9200-9520 Camco 03/11/87 #1 10250-10600 Camco 03/12/87 #2 10000-10283 Sch 11/16/86 #1 9990-10360 Sch 10/03/86 #1 8800-9740 Sch 03/21/87 #1 10200-10750 Camco #2 10000-10333 Sch 5" #1 10800-11201 Camco 5" #1 10500-11374 Sch 5" #1 13150-13531 Camco 5" #1 12700-13462 Sch 5" Step Rate/Injection Profile Perf. Record 10/01/86 Production Profile 02/25/87 Perf. Record 09/06/86 WOPITS 03/14/87 Perf. Record 10/28/86 5~! 5" 5" 5" 5" 5II ~ec~ived Date A un~l OI the O~,g~nol Slondo,d Founded ,n Cle-elond, Oh;o. ~ Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska P,oduc,ion Company ¢ 900 East Benson Boule~ P.O. Box 196612 An¢horoge. Alod~o 99.519-66 1907! .564-5 1 I ! DALLAS INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date: 02/20/87 TO: MOBIL TI: 77727_ · · PHILLIPS / sTATE OF 'ALAS~~ GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: B-23 F-17 F-17 H-13 H-26 J-1 N-3 N-3 N-8 S-18 T-7 Y-7 Y-13 Completion Record MWP-Measurement While Perf. Perf. Record 02/05/87 Completion Record 01/31/87 Completion Record 09/13/86 Junk Basket 09/30/85 Tubing Puncher 09/28/86 Collar Record 10/11/86 EPL 07/10/86 Completion Record 09/26/86 Completion Record 09/25/86 Completion Record 05/14/86 Completion Record 09/14/86 09/23/86 #2 8340-9966 Sch 5" 02/05/87 #1 10800-11374 Sch #1 10800-11374 Sch 5" #1 9200-9651 Sch 5" #1 9462-9989 Sch 5" #1 8900-9128 Sch 5" #1 9145-9600 Sch 5" #1 8172-9331 Sch 5" #1 9595-9970 Sch 5" #1 11200-12003 Sch 5" #2 8900-9600 Sch 5" #1 8450-9845 Sch 5" #1 9590-10620 Sch 5" Dres 5'" Y-24 Prod. Logging 02/02/87 #1 3100-13416 Anchor,,ne 511 Rece i ved ~ Date A unit o! Se o,ig;nol Slondo,d C~I Company Founded in Cleveland. bio. in 1870 Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 Standard Alaska Production CornW- 900 East Benson E~, ,ard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 4, 1987 STANDARD ALASKA PRODUC-q-fON Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well H-13 (11-22-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. PFB:JAM~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 H-13 Well File Yours very truly, Po ~. Barth, Supervisor Reservoir/Production Surveillance Unit i RECEIVED,, 0 6 g87 Alaska Oil & ga; Cons. Commission Anchorage A unit of the onginol Stondord Oil Compony Founded in Cle~efond Ohio in 1870. ALASi~,~ . STATE OF ALASKA L AND GAS CONSERVATION COMI~~'~" 3N REPORT OF SUNDRY WELL OPEI'{ATIONS 1. Operations performed: Operation shutdown © Stimulate ,'~ Plugging Z Perforate g~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 82.55 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1652' SNL, 1264' WEL, Sec. 21, T11N, R13E, UPM At top of productive interval 1180' SNL, 814' EWL, Sec. 22, T11N, R13E, UPM At effective depth 1198' SNL, 1108' EWL, Sec. 22, T11N, R13E, UPM At total depth 1200' SNL, 1128' EWL, Sec. 22, T11N, 'R13E, UPM 7. Well number H-13 (11-22-11-13) PBU 8. Approval number 7-38 g. APl number 50-- 029-20559 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9805 9328 Effective depth: measured 9759 true vertical 9287 Casing Length Size Structural -- Conductor 61 ' 20"x30" Surface 2646' 13 3/8" Intermediate 8857 ' 9 5/8" Production -- Liner 1389 ' 7" Perforation depth: measured 9350' - 9462' feet Plugs (measured) feetBKB feet Junk (measured) feet BKB Cemented 8 cu. yds. 3720 c.f. 1338 c.f. 380 c.f. (four intervals) true vertical (subsea) 8837' - 8938' Tubing (size, grade and measured depth) 5 1/2" L-80 to 8335' with 4 1/2" tailpipe to 8466' Packers and SSSV (type and measured depth) 9 5/8" PBR/packer at 8335'; 5 1/2" SSSV at 2001' 12. Stimulation or cement squeeze summary Measured depth 110' 2695 ' 8906 ' 8411 ' -9800 ' True Vertical depth BKB 110' 2695' 8509 ' 8048 '-9323 ' RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure aaa C0r~, Commission Anoh0rage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1310 2836 12 0 2320 5280 0 0 ~bing Pressure 1879 633 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ / Signed ~-' Title Supvr. Res/Prod. Surveillance I Date Form 10-404 Rev. 12-1-85 Submit in Duplicate Well H-13 (11-22-11-13) PBU ADDITIONAL PERFORATING OPERATIONS The following additional intervals were perforated January 31, 1987 using Schlumberger 2 7/8" carrier guns at 4 spf: 9424' - 9430' MD BKB (8903' - 8909' TVDss) 9442' - 9462' MD BKB (8920' - 8938' TVDss) Ail depths are referenced to BHCS/GR, 5/10/81. A lubricator was in- stalled and.tested to 3500 psi for all well work. Following perforating operations, the well was returned to production and tested. RE£EIVED ~-~ B 0 6 1987 Naska 011 & Gas Cons. Commission Anchorage jm 2/3/87 Standard Alaska Production 900 East Benson Bou~ .d P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) §61-5111 January 15, 1987 5'rANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: M.r.C.V.C.ha.t.%erton Well H-13 (11-22-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. PFB: JAM ~ Enclosures (9) cc: J. L. Haas (MB12-1) H-13 Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I JAN 2 o ] 87 Alaska Oil & Gas Cons. A unit of the omginol Standard Oil Company Founded h'~ Cleveland Ohio in 1870. ALA ,,~ OIL AND GAS CONSERVATION CO SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~- Operation Shutdown ~ Re-enter suspended well ~ Alter casing - Time extension - Change approved program ~ Plugging ~ Stimulate .% Pull tubing -- Amend order ~ Perforate X' Other 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1652' SNL, 1264' WEL, Sec. 21, T11N, R13E, UPM At top of productive interval (top Ivishak/Sadlerochit) 1180' SNL, 814' EWL, Sec. 22, T11N, R13E, UPM At effective depth 1198' SNL, 1108' EWL, Sec. 22, T11N, R13E, UPM At total depth 1200' SNL, 1128' EWL, Sec. 22, T11N, R13E, UPM 11. Present well condition summary Total depth: measured true vertical 9805 feet Plugs (measured) 9328 feet BKB 5. Datum elevation (DF or KB) KBE = 82.55 6. Unit or Property name Prudhoe Bay Unit 7. Well number H-13 (:11-22-11-13) PBU 8. Permit number 81-17 9. APl number 50-- 029-20559 10. Pool 'Prudhoe Oil Po°l feet Effective depth: measured true vertical Casing Length Structural . -.- Conductor. 61 ' ' Surface '2646' Intermediate 8857 ' Production -- Liner 1389 ' Perforation depth: measured 9350' - 9400' 9759 feet Junk (measured) 9287 feet BKB , Size Cemented Measured depth 20'x30" 8 cu. Yds. 110' 13 3/8" ' 3720 c.f. 2695' 9 5/8" 1338 c.f. 8906 ' 11 (two interVals) 380 c.f. 8411 '-9800 ' true vertical (subsea) 8837 ' - 8882 ' Tubing (size, grade and measured depth) 5 1/2" L-80 to 8335' with 4 1/2" tailpipe to 8466' Packers and SSSV (type and measured depth) 9 5/8" PBR/packer at 8335'; 5 1/2" Otis SSSV at 2001 ~ueVerticaldepth BKB 110' 2695' 8509' 8048'-9323' RECEIVED JAN 2 0 1987 0il & Gas Cons. C0mm[ssio~ Anchoraga 1:2.AttachmentS Description summary of proposal ~ Detailed operations program .~ BOP sketch 13. Estimated date for commencing operation Januar. y/February 1987 14. If proposal was verbally approved N'J~rr e of approver Date approved 15. I hereby c~ify that the for,cjtloing is true and correct to the best of my knowledge Sig'J~ed. F,.,~~ TitleSupvr. Res/Prod. Surveillance I Commission Use Only Conditions of approval Approved by Notify commission so representative may witness _m Plug integrity ~m BOP Test [] Location clearance ~{,~proveCl Cc~p~ ~eturrmd Commissioner I Approval No. ,..,~ ,,.. J ~1~ by order of the commission Date/-~ Form 10-403 Rev 12-1-85 Submit in triplicate Well H-13 (11-22-11-13) PBU ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following additional intervals during December 1986/January 1987 at 4 spf: 9424' - 9430' MD BKB (8903' - 8909' TVDss) 9442' - 9462' MD BKB (8920' - 8938' TVDss) All depths are referenced to BHCS/GR, 5/10/81. A lubricator will be installed and tested to 3500 psi for all well work. jm 12/3/86 JAN 2 0 1987 Alaska Oil & Gas Cons. BOWEN PACKOFF FLOW TUBES & PACKOFF J-~-- HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE ~J VALVE GREASE LINE GREASE MANIFOLD ' ~,~~~ PUMP RISER ...-GREASE RESERVOIR BOP [ ECE[VED JAN 2 0 !987 Alsska 0il & Gas Cons. Anshor~ SOHIO ALASKA PETROLEUM COMPANY SY0 ARCO CHEVRON EXXON TO: SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS ~.'.i. STATE "OF AK BPAE 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 9950:2 Date: 8-14-85 76382 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being sUbmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- C-15 H-4 H-8 H-13 N-21 CNL 5-25-85 8850-9734 #2 Sch 5" CNL 4-28-85 11000-11836 #2 Sch 5" CNL 4-28-85 8750-9423 #3 Sch 5" CNL 5-27-85 8900-9697 #2 Sch 5" CNL 5-28-85 9980-11383 #1 Sch 5" RECEIVED DATE , Technical Documentation :i.:S C;c~rlS. Fj,DF, lrDiSSIOD Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To: SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907l 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 6-26-85 T#: 76270 REFERENCE: ~$8~0 CASED HOLE FINAL LOGS ~,/The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- 5-30-85 Spinner 9100-9500 Camco 5" RECEIVED DAT[ Cathy Perkins LR 2-1 OH&Ga~Co~.-~ bTechnical Documentation ~Cho~ Co~1~i$$~ Records Management INDEXED SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON ,o:SFO/UNIT/STATE: TEXACO (-Mara t hon) MOB IL PHILLIPS BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: T#: 6-21-85 76261 REFERENCE: SOHIO 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 office:-- C--9 ~ D-15 ~/ F-14%/ H-13/ R-1 '~ X-24V APZ# 3660 5/12-14/85 Flowing Gradient & BHPD Camco 461 5-23-85 PBU & BHPD GO 440 5-11-85 PBU & BHPD GO 559 5/30-31/85 Flowing Gradient Camco 5-09-85 Static GO 1098 5-25-85 PBU & BHPD GO RECEIVED DATE Cathy PErkins LR 2-1 - '~'J~-'-0-~j' &"Gss c0rls. ~T{~l Documentation ............................................................ 19 Anchors. ge Records Management SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA SFO TELEPHONE 1907! 265-0000 ARCO MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 , EXXON TO: PHILLIPS Date: 6/11/85 T#: 76232 STATE OF AK SOHIO ~GNETIC LIS T~ES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a _~ ~1'c,7- o~",.~ z7"..' F-PP¥ of thi~_ letter and returning it to this office: Q ~'- * A-35' O.H. 4/25/$5 (/1 Sch (/70408 · D-15. CH-CNL 5/19/85 (/2 Sch (/70450 ~* C-18, CH-CNL 5/23/85 (/1 Sch (/70467 ~ * E-10. CH-CNL 5/20/85 ~/1 Sch (/70451 ~* G-10, CH-CNL 5/22/85 (/2 Sch (/70466 ~ * C-15, CH-CNL 5/25/85 (/2 Sch (/70464 ~- * B-15, CH-CNL 5/23/85 (~1 Sch (/70465 · E-17, CH-CNL 5/21/85 (/1 Sch (/70460 · ~ ~,~ * H-4, CH-CNL 4/28/85 (/2 Sch ~/70407 CH-CNL 5/27/85 (/2 Sch (/70478 '--* D-9, CH-CI~L 5/18/85 ~/1 Sch (/70449 --- * H-14, CH-CNL 5/26/85 (/2 Sch (/70477 · - ~-:. A-D4A O.'l. 5/28/85 ~I Sch ~70474 Q* A-34, O.H. 5/16/85 (/1 Sah (/70434 · H-8, CH-CNL LIS 4/28/85 (/3 Sch (/70406 Tape Pos. ~/03383 Tape Pos. (.~0338A Tape Pos. (/03385 Tape Pos. ~/03386 Tape Pos.t/03387 Tape Pos. (/03388 Tape Pos. !/03389 Tape Pos. I/03390 Tape Pos. (/03391 Tape Pos.t/03392 · Tape Pos.(/03393 Tape Pos. (/03394 T ~-p-e~ o s. ~7 Tape Pos. f/03381 Tape Pos. ~/03380 7-J : An Asterisk ( ) n~t to a [~st~ng above means you should have received the ~ap~(s) and L~st~ng(s) d~r~ct[y from the r~spect~v~ se~ce company. ~[eas~ conf~rm th~s. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 January 31, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well H-13 (ll-22-11-13)PBU Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our subsequent report of performing a scale inhibitor squeeze treatment on this well. rict Petroleum Engineer GJP/~H/pjw Enclosures cc: J. D. Hartz Geology Well File ~17 RECEIVED FEB - 1. 984 STATE OF ALASKA {( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorag. e, AK 99502 4. Location of Well At Sur face: 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 82.55' AMd. I 6 . Lease Designation and Serial No. - ~nT_. ~-a284 ~ 7. Permit No. 81-17 8. APl Number Perforate Stimulate Repair Well Pull Tubing 50-029-20559 9. Unit or Lease Name Pruahoe _P~_y Unit 10. Well Number ~-!3 ( !!-22-!!-!3)PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing I~ Perforations [] Altering Casing [] Abandon I-I Stimulation [~ Abandonment I-I Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing (-] (Note:.Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, inclu.ding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). , A 12 Barrel scale inhibitor squeeze treatment was performed over the following intervals January 30, 1984. The well was shut-in for 24 hours after the treat, ment. The SSSV was removed prior to stimulation and reset after the job at 2001'. 9350'-9370' BKB (Ref. BHCS/GR,05-10-81) 9380'-9400' BKB ( " ) RECEIVED FEB- 1 I984 1!~1. I hereb ti is true and correct to the best of my knowledge. Distri~t'~ ~Petr oleum Engineer Signed ~ Title ' ' ' The sp~e_below for/Cor~mission use Conditions of Appro~e~ff any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 January 11, 1984 Alaska Oil & Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chattertcn Gentl~: Wells G-1 ,~r3.~' H-l~3, R-7 PBU Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These~ccntain our proposals to perform scale inhibitor squeeze treatments/on %hes~ wells. ~ ' _G'..J~.3.~i_sga ~-- Distr'~ct 'Petroleum Engineer GJP~/pjw Enclcsures cc: J. D. Hartz Geolcgy Well File #17 ALASK/~JOIL AND GAS CONSERVATION ,v, MISSION }Z SU_N__DR_Y- N__O_TI_CE S A__ND REPORTS ON WELLS OTHER .c ~.c. 23~ U] 2. Name of OperandiO Alaska Petroleum Company Address Pouch 6-612, Anchorage, AK 4. Location of V~% Surface: 1652' SNL, 126'~' WEL, Sec. 21, TllN, R13E, UPM Elevation in fe indica ~: etc.) 12. Check Appropriate 8ox lo Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] A~ter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) -- 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proPosed work, for Abandonment see 20 AAC 25.105-170). A 12 Bbl. scale inhibitor squeeze treatment will be performed over the following intervals February/March, 1984. The well will be shut-in for 24 hours after the treatment. The SSSV will be removed prior to stimulation and reset after the job at 2001'. 9350'- 9370' BKB (Ref. BHCS/GR, 5-10-81) 9380'- 9400' BKB ( . ) /' '~ned' ~'/"~l~ 3 t.,t._~,'~..,.~ Title District Petroleum Engineer ~j~'~c~j be~w f~r.-~-~om~_missio_n u(~ ~onditions of Approval, if any: RECEIVED Approved Copy . Retur~Ct L_Approved by_ BY' LUN~i[ C. SidlTH By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 ~" Rev. 7-1-80 and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON 3111 "C" 5TREE1 ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 EXXON GETTY ~o: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmittal Only) Date: 8/10/82 Trans. #: 2510 CC#: 55510 REFERENCE: T-"~--_ following herewith. Please acknowledge receipt by signing a material is being submitted copy of this letter and returning it to this office:-- ~ EPL Sch 6/4/82 #1 5" J-2 EPL Sch 6/29/82 #1 5" E-2 CNL Sch 5/23/82 #10 5" 4/82) RECEIVED DATE _ EIV A,..~o nil ~ Gas Cons. C0mmis~'[0n .......... '"""~ ....e Victoria Aldridg. e · ~eveiopment Ge61ogy ~9 Well Records SOHIO ALASKA PETROLEUM COMPANY SF0 A~C0 CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 EXXON GETTY To: SFO/UNIT/STATE: (-Mar a tho n) MOBIL, PHILLIPS BPAE (Transmittal Only) CENTRAL FILES(CC#' s-Transmittal Only) Date: 8/3/82' Trans.#: 1788 CC#: 49788 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/liN IT / STATE: Q-2 CNL. N-6 CNL J-5 CNL H-7 CNL N-1 CNL CNL TDT-M Sch 6/10/82 #5 8600-9470 Sch' 6/11/82 #5 10250-11052 Sch 6/11/82 #5 9400-10364 Sch 6/11/82 #5 9900-10961 Sch 6/12/82 #1 8450-8959 Sch 6/10/82 #2 8750-9425 Sch 6/8/82 #1 8800-9743 11 5" 5" 5" 5" 5~t 5" /82) Karen Mestas / va Development Geology Well Records SOHIO ALASI;A PETROLEUM CO;':".PANY 10: SFO ARCO EXXON PHILLIPS CENTRAL FILES (CC//' s-Transmittal On17 · .. 311 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 7-12-82 Trans.#: 1718 cc#: 49718 REFERENCE: : SOHIO MAGNETIC LIS TAPES & LISTINGS wing material is being submitted herewith;',Please acknowledge receipt by signing a ,, copy of this letter and returning it to this office:-- , M-10w/ * M-12J , C_19%-/ Sch #1 6-8-82 CH TDT-M ACC-65223 Sch #6 5-18-82 CH CNL ACC-65146 Sch #1 6-28-82 CH TDT ACC-65264 S. ch #1 6-28-82 CH TDT ACC-65265 Sch #1&2 6-9-82 OH/DIL,BHC, ACC-65231 FDC,CNL/GR Replacement Tape: * S-3 u/ Sch #1,2,3 2-22-82 OH/DEL, BHC, FDC, CN~ / OR (Tape Pos. 01827~, (" " 01826', (" " 01830', (" " 01831', (" " 01834', ACC-62605 (" " 018321 ( S~o/~IT oN?.Y: , * ~-13 Sch #1 * M-lC Sch #1 6-8-82 ANSWER ACC,-65223 (" " 01828 ( " " 01829 * M-12 Sch ................... #I ........ 6-28-82 ANSWER ACC-65264 ( " " 01833 *SFO & EXXON: An A'sterisk:(*) next to a listing above means you should have received the Tape(s) and Listing(s) dire~tly from the respective service comPany. Piease conf irs this. ~ E~E~-v-~ Karen Mestas R~,~VEO L I_ Development Geology D A Tr Ar Ar Ar Ar Ar Ar Ar Ar~~ ~'v~' -'~ /~.~,~ ---'~L-~ ~1~ Well Records Alaska 0il'& Gas Cons Commission Anchorag'~ ' f - _ SOHIO ALASKA PFTF{OLEUM COMPANY SF0 ARCO CHEVRON EXXON 3111 "C" SIF-:[ET A?gCHOt~AGI~. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY ~o~ SFO/UNIT/STATE: (-Marathon) MOBIL BPAE (Transmittal Only) , CENTRAL FILES (CC#'s - Transmittal Only) Date: Trans.#:/~4~ ~x,._ REFERENCE: , I~~O FINAL DATA - PRESSURE SURVEY DATA~ he submitted herewith. Please acknowledge receipt by signing a following material is being copy of this letter and returning it to this office:-- ,/82) SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 May 19, 1982 Alaska Oil & Gas Conservation Coamission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Gentlemen: Mr. C. V. Chatterton Well }{-13 (11-22-11-13) Enclosed, in duplicate, are the following forms for the above-named 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. · ~r s 3 ly, / 'G. J..~P._.l~sga ~__,. Distrz~t Field Engineer J. D. Hartz Well File #17 CC #48,765 well. RECEIVED MAY 2 1982 Alaska Oil & Gas Cons. Commission Anchorage ( STATE Of ALASKA ( (~~..~' ALASKA OiL AND GAS CONSERVATION CO,,,i,,,SSlON · WELL COMPLETION 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 Sohio Alaska Petroleum Ccmpany R]-17 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502' 50-029-20559 4. Location of well at surface 9. Unit or Lease Name 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM ~- _ ' Prudhoe Bay Unit. At Top Producing 'Interval , LOCATIONS 10. Well Number VERIFIED 1180' SNL, 785' EWL, Sec. 22, TllN, R13E, ~ H-13.-(11-22-11-13) At Total Depth Surf. E 11. Field and Pool 1200' SNL, 1128' EWL, Sec. 22 TllN, R13E, f~ .B.H. ~-- Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil ~ool KBE = 82.55' AMSL ADL 28284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 4/24/81 5/9/81 5/16/8,~'~ feet MSLI one ' 7. Total Depth (MD+TVD) 9805'MD, 9328'~[i~ 18. Plug Back Depth (MD+TVD)19. Directional Survey 9759'[vD, 9287'~gD YES ]~ NO [] I20' Depth where sssv set2001 feet MD I21' Thickness °f PermafrOst1977' 22. Type Electric or Other Logs Run DIL/]~CS/SP/GR, FDC/CNL/GR/Cal, HDT, CBL/VDL/GR/CCL, g,'yroscopic survey , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEi WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 2fi" ~ qd" Tn.~u]at~r] Conduct.or S~rfa~:e ]]~' .~6" 8 cu. vds. concrete !~ 3/R'. 79.~ L-80 Surface 2695' 17 1/2" 3720 c~. ft. Perm.almost II q 5/R" &7~ f~-Rfl Surface .8906' ]2 ]/4" 2208 cu. ft. C~]ass G.: . ]qO cu. ft. Permafrost C 7" 299 L-80 3' ];:'84'11' 9800' ?8 1/2" 380 cu. ft. Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD [nterval, size and number) .MD r~/~D SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool Top: . 9350' 8919' 5 1/2" 8463' 8335' Bottom: 9400 ' 9045 ' ~)350' - 9370' BKB (8919' -8937' ~V'D) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~)38~" - 9400' B~ (8946' -9045' -~v'D) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date~First Product on ..... . I Method .of Operation (Flowing, .gas lift, etc.) .~pril 22, 1982I Flowi~ .. Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO ' TEST PERIOD e Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL . OIL GRAVITY-APl (corr) Press. ", .: 24.HOUR:RATE I~' ' . .. ' 28. CORE DATA Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. , RECEIVED · ' MAY 2 1982 Alaska Oil & Gas Cons. Comrrlissiorl h m',hnran,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS .NAME Include interval tested, I~ressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea ,, iSag River SST 8979' 8495' Shubl ik 8990 ' 8505 ' Ivishak 9058 ' 8569 ' ..,. ~?... i(.," · . ., . . 31. LIST OF ATTAC~ENTS . · Sig.~/ ~ ~'-"--..~ 3 ~c'~ Tm. District Field En~ 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 com'Rletion), so state in item 16, and in-item 24 show the producint~ intervals for only. the interval reported in item 27. Submit a separate form for each additional interval to be separately prOduced, showing the data pertinent to such interval. item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23:, Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 O(, STATE OF ALASKA ALASKA ~ ID GAS CONSERVATION CG(' .~SION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-17 3. Address 8. APl Number Pouch 6-&12, Anchorage, Alaska 99502 50-029-20559 4. Location of Well At Surface: 1652' 8NL, 1264' WEb, SOC. 21, TllN, R13E, ~ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 82.55' AMSL I ADL 28284 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number H-13 (11~22-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate r~ Alter Casing [] - Perforations ~ Altering Casing [] Stimulate [] Abandon ' [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals ~P.r~e perforated April 22, 1982, using Dresser Atlas 3 1/2" carrier .guns at 4 s.p.f. A lubricator Was installed and tested to 3500 psi for all well work. 9350 ' - 9370 ' BKB (Ref. BHCS/GR, 5/10/81) 9380' - 9400' BKB (Ref. BHCS/GR, 5/10/81) An SSSVwas set and tested in the ball valve nipple ca. 2000'. 14. I hereby certi at t/( r going rue and correct to the best of my knowledge° Signed Title District Field Engineer The space belo~.for__ Co.m~miss~0n_.~ ~;e BG. ~. Plisga Conditions of Approval, ~¢-a?iy: Gas Cons. O0mmissi Anchorage By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( STATE OF ALASKA ir" '; ALASKA 0IL AND GAS CONSERVATION CO¥,,,v,,SSlON ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS! / 2. Name of operator Sohio Alaska :Petroleum C~¥ 7. Permit No. 81-17 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20559 4. Location of Well at surface 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE- 82.55' AMSL ADL 28284 9. Unit or Lease Name Prudhoe Ba_v Unit 10. Well No. H-13 (11-22-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of . May 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur3 tests 1'4. Coring resume and brief description 15 Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED See Attachment~ MAY 2 1982 Alaska 0il & Gas Cons. C0mn]ission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. cie, NEm ('k ~ TITLE District Field Engineer DATE _~ ~ ~ ~ ~ ~ ~ ~- ~ i~,, , , -- , , ,, ..... NOTE--~por, on ~s~orm is required~or each calenda~ month, regardless of ~'he status of operations, and m~s~ be fi{~ in/du~H~a~e wi~h the Alaska Oil and ~ Conservat]Sn Commission-~--~ - ' ' by ~he lath of the succe~ing men,h, unless o~herwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 PERFORATING DATA - Well H-13 (11-22-11-13) April 20, 1982: Pressure tested tubing and inner annulus. April 22, 1982" Rigged up Dresser Atlas and perforated the following intervals using 3 1/2" carrier guns at '4 spf: 9350' - 9370' BKB (Ref. BHCS/~, 5/10/81) 9380' - 9400' BKB (Ref. BHCS/GR, 5/10/81) Put well on production May 2, 1982: Shut well in to prepare for static pressure survey. May 5, 1982: Ran static pressure/temperature survey at 8800' TVDss. May 10, 1982: Set and tested SSSV in ball valve nipple ca. 2000'. Well on production. Oil & Gas Cons. ~chorag~ SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON GETTY TO: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAZ (Transmittal Only) CENTRAL FILES (CC#'s - Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: Trans.#: cc#: h~~foNCE: SOHI,O FINAL DATA - PRESSURE SURVEY DATA . Ilowing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- /82) DATE 19 A!~c,~a 0ii & Gas Cons. Co~nmJssJol-~ Anchorag~ Well Records , SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 March 30, 1982 CONFIDENTIAL Alaska Oil & Gas Conservation Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Subject: Well H-13 (11-22-11-13) Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to perforate the well. Distr i~J Field Engineer GJP:JLH:syr Enclosures cc: J. D. Hartz Geology Well File #17 RECEIVED APR 0 11987 0il & Gas Cons. Commi~sion Anchorage ( ~ STATE OF ALASKA ALASKA O . 4D GAS CONSERVATION CO(~ SSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well At surface: 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, ~ 5. Elevation in feet (indicate KB, DF, etc.) KBE.'= 82.55' AMSL 6. Lease Designation and Serial No. ADL 28284 7. Permit No. 81-17 8. APl Number 50~329-20559 9. Unit or Lease Name Prudhoe Bay Un~t 10. Well Number H-13 (11-22-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~[ Alter Casing [] . Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment I-'] Repair Well [] Change Plans I--I Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during April, 1982, using Dresser Atlas 3 1/8" carrier guns at 4 spf: 9350' - 9370' BKB (Ref. BHCS/GR 5/10/81) 9380' - 9400' BKB (Ref. BHCS/GR . 5/10/81) An SSSV will be set and tested in the ball valve nipple ca 2000'. I ECEI YED ~. -, "Vo~ [[¢;2°~'~ .. _. ,,,,,/~, ~ ~'~'~~ APR 0 i ]982 AI~ 0il & Gas ~ns ~ChorM~ 14. I h~r th o f i~ tru~ and corr~t to th~ Signed ~/~~~"~ ¢? Title District Field m~ineer The spac~s,ow~or C0m~ission use G. J" ~. Plisga Conditions of Approval,~an~: Approved Returned ~ By Order of Approved by ~¥ ~" ~!~[ ~'° S~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" irt Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAI L: POUCH 6-612 ANCHORAG E, ALASKA 99502 June 9, 1981 Alaska Oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well H-13 (11__/22-11-13) Enclosed, in duplicate' is Form 10-407, completion Report, for the above-namsd well together with the Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. yours very truly, R. H. Reile¥ District Drilling Engineer RHR:ja Enclosures cc: Well File 917 Geology RECEIVED JUN-9 1981 Al~sk~ Oil & G~s Cons. Commission Anchorage ~: 'L STATE OF ALASKA ALASKA~,~L.~ O GAS CONSERVATION Ct., ~.~'~;SION WELL COMPLETION OR RECOMPLETION REPORT AND LoG 1. Status of Well Classification of Service Well .. OIL'[~ GAS[] SUSPENDED []" ABANDONED [] SERVICE [] . . 2. N:ame of Operator ' 7. permit'Number Sohio Alaska Petroleum Company 81-17 3. Address 8. APl Number Pouch 6-612, Anchoraqe, Alaska 99502 50-029-20559 4. LOcation of well at surface 9. Unit or Lease Name 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1180' SNL, 785' EWL, Sec. 22, TllN, R13E, UPM H-13 (11-22-11-13) At Total Depth 11. Field and Pool 1200' SNL, 1128' EWL, Sec. 22,, TllN, R13E, UPM . Prudhoe Bay .5. Elevation in feet (indicate KB;'DF, etc.) I 6. Lease Des gnation and Serial No. Prudhoe Oil Pool ~33E ".=~. 82.55' AMS ~I ADL 28284 12. Date ~p'Ucld~d- ?,' i~% 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions- 4/24/81 5/9/81 5/16/81I feet MSL one · 17. TotalDepth(MD+TVD) 18,PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost ~9805'tVD 9328'~V-D 9759'MD 9287'~V'D YES [~_ NO [] 2001 feetMD ~19~7''i~, 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, FDC/CNL/GR/Cal, HDT, CBL/VDL/GR/CCL, gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD ~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2~"×30'' rnsulated CondUctoz SurfaCe 110 ' 36" 8 cu~yds' concrete 1~ ~/R,, 72~ L-80 Surface 2695' 17 1/2" 3720 cu.ft. Permafrost II . ,,,' .. 1 4" 95~8 47# L-80 Surface 8906' 12 / 1208 cu.ft. Class G; 130 cu. ft. ' P~rmafro3t C 7" 29# L-80 8411' 9800' 8 1/2" 380 cu.ft. Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number.) SiZE ' · ' DEPTH SET (MD) BACKER SET (MD) 5 1/2" ' 8463' 8335' None . 26.' ~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , . ;. : : · ,: . ,. { , . 27. ' PRoDucTION TEST: Date. First Production , I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCI~ , W~TER-BBL CHOKE SIZE IGAs'OILRATIO .~ TEST PERIOD. I~ I Flow ~Tubing' ' Casing PreSsure CALCULATED OiL-BBL GAS-MCF WATER-~3BL OIL GRAVITY-APl (corr) Pres~. - . 24*HOUR RATE I~ , 28. " ' CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED . - JUN - 9 1981 ~aska 0il & Gas Cons. ComrnJssion .... Anchorage · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... GEOLO~Ic MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 8979' 8495' Shublik 8990' 8505 ' Ivishak 9058 ' -8569 ' .. 31. L~ST OF ATTACHMSNTS Well History, Well Logs, Directional Surveys .................... 32. ~ hereby certify that the foregoing is true and correct to the best of my know~ed§e Signed Tit,eDiStrict Drilling Date ~-" 3 ~ '-~ Engineer .... 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 i:n item 24 show the Producing intervals fo¢b'nly 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, etCo). Item 23: Attached supplemental recor(~S'for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. 28: If no cores taken, indicate "none". Well H-13 (11-22-11-13) WELL HISTORY Spudded well at 0300 hours, April 24, 1981. Drilled 17 1/2" hole to 2700'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2695'. Cemented with 3720 cu.ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2652', tested casing to 3000 psi, okay. Drilled out to 2730', ran leak-off test to 0.89 psi/ft. gradient. Directionally drilled 12 1/4" hole to 8917'. Ran 233 jts. 9 5/8" 47# L-80 Buttress casing to 8906'. Cemented in two stages: First stage with 1208 cu.ft. Class G cement; second stage through D.V. packer at 2589' with 130 cu.ft. Permafrost C cement preceded by Arctic Pack. Cleaned out to 8865', tested casing to 3000 psi, okay. Drilled out to 8936', performed formation competency test to 0.7 psi/ft, gradient. Directionally drilled 8 1/2" hole to 9805'. Ran open hole logs. Ran 35 jts. 7" 29~ L-80 Buttress liner to 9800'. Cemented with 380 cu.ft. Class G cement. Cleaned out to 9759', tested casing to 3000 psi, okay. Changed well over to NaC1. Ran CBL, dropped sonic tool to bottom. Fished and recovered entire fish. .Ran 204 jts. 5 1/2" 17# IJ4S IPC tubing to 8463'. Landed tubing with ball valve at 2001'. Installed and tested tree. Displaced tubing to diesel, set packer at 8335'. Tested tubing to 3500 psi, okay. Released rig at 0600 hrs., May 16, 1981. May 21, 1981 Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. Boss-16804 Well No. H-13 (SEC21TllN R13E) Prudhoe Bay Field North Slope, Alaska Survey Date: May 19, 1981 Operator: Blaine Baertsch Dear Mr. Plisga: Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscopic Multishot Directional.· Survey on the above well. '~. Thank you for giving us this opportunity to be of service. Yours very truly, KA/pr SPERRY-SUN, INC. Kirk Afflerbach Enclosures JUN - 91q.981 ~Jaska 0il & ~as Co~$. Commission SOHIO ALASKA PETROLEUM COMANY - ' 19, 1981 ' ,--'-~ ~'L-L--N'O-.--'H-;'"i"5-S'~'d'~'f'~Y-fN"'e"~-i-~ cuMP'uTA~rTO%~-D~A:T-E ..... ' ...................... " ...... B'O'S~~~O'S'~O-~~'E Y PRUDHOE BAY HAY 21, ~981 dOB NUMBER BOSS-1680q ALASKA KELLY BUSHING ELEV. = 82.55 Fi. .. TRUE: ::: .'SuB':SEA coURsE 'couRsE·.' TOTAL ::';::;::..: · ~--~:-~so ~%----v ~R.T~ c~A- C~Wr~TrC'A-L---~ N"C'c-~ ~A T': 0 N~O'rR' ~'C~O~~E: ~' Z'T~: ::~'<~'c'~ A~'~L-A'R~-O~~A'~ ~'s ..... .......... ~C'A'C DEPTH DEPTH DEPTH DE6 NIH DEGREES DE6/iO0 NORTH/SOUTH EAST/~EST SECTION { 1oo I .... 200 '300 4~00 399.98 500 499,97 { ~' 600':' i::.': ~599,95-- { 100.00 17.45 200.00 117.45 2'99~,"99 ........... :--2'i~'",hq 317,43 ~17.~2 800 799.91 900 899,90 1000 999.88 1100 1099.88 1200 .,: ~1199.87 1300 1299.87 1400 1399.86 -- i 5'oo i'4 c)9-j8'6 1600 1599.85 1,70 1.3~ ,32 -,13 817.55 917,33 ~ 0 52 S 26,6-0 E ,15 3,62 S ,13 E 1017,33 0 3¢ S 34,19 E ,32 z~.72 S .75 E fi-~?~2~ 0--,3 3'-----'S--~'~.-gTB~E i~:'.~. :i~;~:~ g;:::~:~..::,?~::::;.,: 1~.' : ~, ~~:' :.,~:.: :.:,: ":... :..:: ;:::, z~ s 7 ?.::~ :~:.: .~:;: .:, .. '3"2 ?~.:~.,;¢~;. ~.'0 2~ S 2 ~ :'"19~::¢:-E~?~ ';2'3' :;:~;:: ~": ;:~": 6' 12:; :?::1--8 : 1517.30 0 58 S 18. 0 E .09 8.73 S 2.63 E -,55 -.14 . t4---": .69 ,83 .'89 .96 · 1700 1699,85 1617.30 0 37 .. S 10,50 E ,09 9,80 S 2,90 E 1.03 ' i-8-0'0------l'7"99;'8'~;' 'f~?'1-7~'~9 ;~ :;~0%]5'6---S--iXr;'~O~~;:;.!i:.i:!~!:!..::::;;:i::i.::,O'7: ::;:.:.::: .. '1-0-;-8-4--S :.:i::?:: :..:i':::.:i:::;i::,',"l-6'¢:':,E:.':i::... '" ' ' £'-70 1900 1899.8 ~+ '? ~ :~ i':8'17'.,29.~~ 30 s i'1.7 9: : 1. z 5 2000 1999.83 '" O::!:i;''!:''33 S:i ": ":i 12. 1.18 2200 2199.83 2117.28 0 30 S 61. 0 E .14 13.63 S A..69 E 2.08 · 2300 2299,82 2217,27 0 34 S 85,39 E ,24 13,89 S 5,59 E 2,91 2500 : ' ~. :: 0:57 ' S 73. ::9~:~::~E:~:~ 68 ~::E'..: :" ~.89 2600' ':.: 2599'8:::::::::::::::::::::17:.26' . "0 :::: 18 S :::::8'~3":"E:/::::':::'. 5.58 2800 2799,80 2717.25 0 26 S 58, 0 E .07 15,~3 S 9,69 E 6,66 2900 2899,80 2817,25 0 27 S 59,30 E ,02 15,84 S 10,36 g 7~2~ i . . : .. ./· : WELL NO. H-1`5 SEC219TlZN~R13E PRUDHOE BAY ALASKA MEASURED DEPTH sp~RR~'LSUN W ELL:/'SU~ ANCHORAGE:~iiiA& COMPUTATION DATE MAY 21e 1981 VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG MIN BOSS GYROSCOPIC SURVEY JOB NUMBER BOSS-16804 KELLY BUSHING ELEV, = OPERATOR-B. BAERTSCH · . 82.55 FT. DIRECTION SEVERITY VERTICAL DEGREES DEG/IO0 SECTION TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST i- 36. 1 E 30 .'5300 3~'0~'0- 3396.56 $314.01 12 28 N 87.59 E 3.91 26.66 S 54,58 E 48 3500 3~93.~0 3410.85 16 18 N 8~.30 E 3.93 2~.81 S 79.35 ~ 73 3600 ~ 37 75 .97 .68 .36 .28 '; 8'i .52 .'5700 3800 .5900 4000 4'100 .5588.80 3506.25 18 :57 N 74.69 E .5.69 19.20 S 3.08.74 E 1 "" '-'""'"F''''~ ~~ "?'~ ~ · ;-.U :.'?.~-· ' ........ 4 ~" '2ii 5'1 · N 3.0,9. S ,:' 1 3775.15 i;3692. 601'~i : 22 46 ?'iNi;6 i: :' S 1 3959,51 .'5876,96 22 35 N 69, 9 E ,36 26.88 N 251.29 E 251.91 4051,85 .'.5969,28 22 37 N 69,59 E .19 40oZ~3 N 287,25 E 289,77 4.200 ~.1~.4,18 ~061,6.3 22 29 N 70, 0 E ,20 55.68 N ..%23.25 E 327.60 42'3'6';-57 '+ 154. ' ' 66,79 N ~.'.i: :':.'::':~!:i;~::7359,19:~';.Ei:i:::::: :' 365,35 4421,46 : .i '4 5.'38'9 2 15 N 70'":~'07': E:i~:'!'ii! i!i:.i'::2'81:i~i ?":!':~ii:'; 2,84' N' ;i'; ::?!::i!?: ;i::i 430, 86 ':i: 440, 61 4600 '+51~..08 ~.4;.'51,53 22 `5 N 70,90 E ,27 105,3~ N 466.4~. 5 477,89 4700 4606.87 452~+,.'52 21 ~2 N 71' 9 E ..'36 117,~8 N 501,68 E 514,77 4.800 4699,75 4617,20 21 ~8 N 72, 0 E ,.'55 129,21 N 5.'56,85 E 551.50 4900 .: 2s :, 4.0 588-.-0~~"~'-- 5000 ~ 4885.90 ~i.:i':.~ ,:i i: 4. 8:0:'~'." 8 ~ 50. 0 :i' 624.12 o o.7 o. 15; ......... .', · ..... 695.50 4.300 4.400 ~ 4500 5200 5072.60 4.990.05 21 8 N 73.50 E .27 171.26 N 675.~5 E 5300 5165.8~ 5083.29 21 15 N 73.80 E .13 181.41 N 710.13 E 5~00 5258.97 5176.42 21 28 N 73.69 E .26 191.60 N 745,08 E 5.~.0 O 5800 731.46 767.70 804.36 841.03 877.31 5631.14 5548.59 21 27 N 73.19 E .19 233.45 N 885.57 E 9 5900 5724.08 5641.53 21 52 N 72.80 E .45 244.24 N 920.87 E 9 6000 5816,77 573~,22 22 1~ N 71.80 E ,51 255.65 N 956.62 E 9 6100 2i~'59 N 5909,.:42.75826'87 : 13.52 50.20 87,~6 2q.77 SOHIO ALASKA PETROLEUM COMANY WELL NO. H-i$ SEC21eTllN,R13E PRUDHOE BAY ALASKA · , '('] ~!' .': , '. :! .' <~ ~ i':.';i' '."' ~:'~"~i:.~]:i::~'~ ]. ' ".; ' /': L_ ·" TRUE TOTAL ' ] :'' '. DEPTH ' DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION · · --~~.-..~--....', oFYs'URvEy MAY '19, 1981 ' MAY 21, 1981 dOB NUMBER BOSS-1680~ KELLY BUSHING ELEV. = 82.55 FT. 6200 ].:..:"! 6002,08 "6300 609~.83 6~+00 : 6187.81 6500 6600 6700 6800 6900 . .7ooo 6280,-85 637;5.78 6~66,70 655-9-.-67 6652.51 67/+5.10 6 6929.77 7022.55 6291.25 21 51 6384.15 21 51 --'6~ :7 7:: °: 12:~?' .;~: 21 ~ 0 666:2'.55'i:::i-- ': 22 2~ 7~00 675~.83 22 5~ 7200 68~7.22 , 22 5 7300 69~0.00 21 ~3 N 72,59 E .36 322.79 N 1169.28 E 1208.88 N 72.80 E .35 335.78 N 120~.57 E 12~5.60 ~--7'~79'0~~'6-2'::':'?'':~ ........ :'~::"~37"5%'8%--N ..... :~:';'[5'4-8%8~ ..... E ............. N 76.59 E i.o~ ~85.26 N i~85.9o E i~33.~ N 77.q0 E ,48 ~93.66 N 1~22.25 ~ 1~70,62 7500 7208.69' .... · 2t :: 10 : N :78-' z~08.40 N 1'~93.89 E~;;!::'::;' ''''~:' 15~+3.75 7600 730i.9i : 2i. i7 ' 1579.96 7700 739 ~. 83 73' i-~-2~~'22 ~ ~ :N--7~9~8:'0'~:~''''':':' ........... :~,'-'~':~:'-",i-5~5-.::7-[--E ...... ~'; ~'~ .... 7800 7487.31 740~.76 22 ~9 N 80.59 S .66 428.¢8 N 1605.26 S 165~.9~ 7900 7579.50 7~96.75 25 50 N 82.50 E 1.15 ~54.25 N 16~2.0~ E 169~.1~ 8i00 7762'02:::;;' : 7 6,7:9 ':.9 7: :~ : z5 56 qS,~. 1722.,8 1775,~8 8200 : '7853' ~ ':23 t7 ~7,16~'' 6 2:': 71. "E~(. :(: '.: 1815.08 8 ~ 0 d 79~45"; 5':~ '~~'~%-2-,'9'~' ' 2 ;' '~ 2' ...... ~'5-[;~'8--N':~' ":'"'-~:"'~8~;~'-['"E~''': ': ''': 8~00 8037.68 7955.Zm 22 ~0 N 8~.~9 E .7O ~55.~7 N Z8~0.57 ~ '~8~.Z2 8500 8130.21 8047.66 22 ~ N 83.69 E .~2 ~59.53 N Z878.27 E ~930.94 8 600 ),: 8223 ,. i2 ::::::::::::::::::::::: 81 ~'0~-57' 21 18 %N~8-¢;15-O~E ;; 4-6~-;~'4--N ;'.;: ::...: ?:7:1 ~0-4 %L.. : 1~~~' 87.00 "8516'40 5 20 56 85':'"5 66,4 50'95 ~:E.> 2005,65 ............8 800 8 ~ 09 ' 8'0~ ~::~.~.~: ~:~ ~8527' 25 20 56 ::': N ~(;~8 6' 6 9,0 ~' N.:~/~] ;~ :::1:986 '59/E ~. 20 ~ 9,1 ~ 8~00 ~505. ~ 7 8~ 20.22 ~0 2' ~ '8~?~E'''' ......... ...... ~'~'f'-o'~'''''~'' ..... 2'0'2~?~-~ .............. zo~v85' sooo 85~7.zz 85z~.56 2z z s 8~.8~ E z.~e ~7z.8~ N 2056.5~ ~ ............ : ................... : ......... . , : , ............. . ,,, .... L_SOHIO ALASKA:PETROLEUM. COMA:NY :: WELL NO. H-15 SEC21,T11N,R13E COMPUTATION DATE PRUDHOE,BAY MAY 219 1981 i:DATE:OF SURVEY MAY 199 PAGE 1981 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16804 ALASKA KELLY BUSHING ELEV. : 82.55 MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERT DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SEC FT. ICAL TION F 22.51 05,7. · 88 461.92 N 2302.~2 E 2348.15 1.15 457.51 N 23~6.29 E 2390.44 0,00 452.00 N 2391,83 E 2434,16 :':MI N. E A S T. :'iA:T:i:i M:D ~:: :='::<:ii: 9 8 0 5 '::; i:: 9600 9144.04 9061,49 26 26 S 85.39 E 9700 9233,79 9151,24 25 53 S 83. 9 E 9805 9328.24 9245.69 25 53 S 83. 9 E : HORIZONTAL' DISPLACEMENT' i NO THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. I~ :' :i : : ' i--/ ANCHORAGE":i'ALASKAii~.iii'ii!i'?:ii:i:ii'iii'i:~::'I: iii ~'i~' i:::ii:'~' ' L SOHIO ALASKA PETROLEuM COMANY :: : : : :~:.i ~i :i.:: .' :DATE iOF SURVEY MAY 19, , -W"_F'.-'~.'[~--N'O-'--H'Jj.-3--S-~"C-2*~"¥T-~"j.-N¥'R-i-'3'E ........................ CO-M-pUT-AT~O-N~ATE":"'"'":': .......... . PRUDHOE BAY MAY 21~ 1981 dOB NUMBER BOSS-~6806 KELLY BUSHING ELEV. = INTERPOLATED` vALuES~:~FoR EvEN: 000 FEET OF;~SE:ASURED:::DEPTH P'A-6-E'-- 5 ..... 1981 82,55 FT, TRUE SUB -SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 1000 9'99';8-8 ............9'1-?~.35 ....... '3';62 S 2000 1999.8~ 1917.28 12.67 S 3.60 E .17 .05 ~000 2999.79 2917.2~ 16.~5 S 11.21 5 .21 .04 400 O-- .... 3%5 91'51 : 5876 · 96 :. : 2' 6'i~'8" 'N----~-5-i~~.:::':~?:~/'~;~i~:~:;~:~ ~.4-01~9 '. ~ ::' :.Y.': '>:~:~.:~ 8000 7670.7~ 7588.19 , ~58.9q N 1682,26 E 529.26 7~.56 9000 8597,11 851~,56 ~71,85 N 2056,58 E ~02,89 75,62 THE CALCULATION 'BASED ON THE:. i .~ ' . · i~ :/ ... : i:'.:i i.i NCHORAGE'~I/:AL i: ': ' ':. [ SOH I 0 ALAS. K_A, iiP--E--T-~-O-iLE_U~-~Oi['J=A-N~z- i .-. J:: '~.: .:~::': :,;;iS~:. ii SUR VEY.~:.,MA ¥.:..,.~ 9s 1981 ,--WEL"L--~"O';--R"213 SEC21,TllN,R13E uum~ut t PRUDHOE BAY ALASKA r' HAY 21, 1.981 dOB NUMBER BOSS-16804 KELLY BUSHING ELEV. = 82.55 - -':~ - ~ : - .. :.::.~:':. :!::~!i~.~.;::',:~::-,::.~: ...,.:: .;::~.-,~,~;..:,.: OPE R A T 0 R B .- B A ERT S C, ,~, :.. , iNTERPOLATED "3.00 FEET OF:::SUB'SEA;:;DEPTH':: ' :L: ,; .. ; :: , L,:,:] .... ' Fl, MEASURED TRUE VER TI CAL MD-TVD VERT I CAL · o R ~ EC T I o' 9.., 0 o 82 82,55 182 182.55 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH- ~ :' NO"R~T~t/SOUTH -82'55 0.00 9.92 N .09 W 100.00 9.43 N .36 W 282 282,55 382 .'.'.,:i~$82,55 ': 482 . :, '::': ~ 82 ' 55 582 ': 582.55 682 682,55 .00 ,00 .00 o00 'W .01 .01 300' 00 : ': :':::~' :;:, 7-:. 16 .,N '..: ,:~.:.;::::<.'::;-:..':.-."';;:~.:~:- :': v.:,,:.. ::;: ::',' :.: 03:::~:':'': ')" ..' ,:~: .0 : ' 600.00 1.63 N 1.09 W .07 .02 782 782,55 700,00 882 882,55 800,00 982 '9~82· 55:.:.. 1082 i08.2'55 :'..: 1.000'00 1182. '~1182-'55' :::i 1282 1282,55 12.00,00 1382 1382.55 130O.O0 1482.55 1~00.00 ' 1582 · 55 :: 3. 5 O 0':' 0 ~:~. 1682 55 ~: ~ .lr:'.o 0-:00 178'2'55 , :!., 170'O:'OQ.:",. ,08 .02 · 10 · 0 1 ,00 · 15 .00 · 1~ .00 1482 1582 1682 1782 ,17 S 1,01 W 1.85 S .62 W 6.01 S 1.81 E 6.68 S 2.09 E LSOHIO ALASKA PETROLEUM COMANY i :: .'i :i :SURVEY M&Y.. 19, 1981 PRUDHOE BAY HAY 21, 198~ UOB NUNBER BOSS-I~80~ ALASKA KELLY BUSHING ELEV, : 82,55 ' TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH .:' .: ,: DEPTH D'~'P'T-Hi ~ ~82 ~2. ss ~ ~o o. o o is ................................i982 1982.55-- ................... 1900.00 ' ..... ' .... 'i-2%"5'0-"S' 2082 2082.55 2000,00 15,23 S 3.91 E MO-TVD VERTICAL "::~'~:' 'i: ': o · 17 .00 2182 2182.55 2100.00 13.55 S q.56 E .17 .00 228 2 ~'8"2'-.-5~5----~-"---220' 0"~,00 : :'::. ~iT~'~'8' 7"i"S :. ~: . :. ~5-~~i~::;i:i?~ii:~i::;:?i:;:~i:?'. :i ::..I18 · ': .. :./:~:~:i:. ::: ~:~:::~:..~' ~,'::~0 ~.::::~ :.::. 2 5~ 2 2 5'8~'~';'5"5'--'"2'5'o'0.'o'o ~ i"4 ;'~'5'~s--'--~'~'5~:' ~':: ~':'?'~:~ ~' ........... ~-[~ ....... '' ........... :~ ..... -'~':,"o'o':'~ .............. 2682 2682.55 2600.00 ~ 1~.88 S 8.90 E .19 .00 2782 2782,55 2700.00 15.~6 S 9.58 E .20 .00 ~i"~'~ ~i-8'Z;%~--~'i'o~o~;~oo~~z~'~'~'9'-s'~ ........ ~"~2'~""?'E"? .......... ' ............ ;'~ ...... ~ ...... ~' ' ';~-s ............. ~' 3286 ~282.55 3200.00 26.09 S ~3.78 E 1.55 .88 ~585 ~82.55 359.5 3582,55 3699 .:: 3682, 55': WELL NO. PRUDHOE ALASKA L_SOHIO ALASKA PETROLEUM cOMANY -'" H-IS SEC21~TllN~R13E BAY TRUE MEASURED VERTICAL DEPTH ~ DEPTH DEPTH NORTH/SOUTH__ COMPUTATION DATE MAY 21, 1981 P-A-G'E ..... 8- SURVEY .MAY ]19, 1981 dOB NUMBER BOSS-1680~ KELLY BUSHING ELEV, = ~ ' '. ~ ' : i ::i.]' ii' :.:;'i]':i:i~':i'i:ii!~)TP-~'R~A'T-~-R.' B · B AE:R.T.:S,C H .,i . iNTERpOLATED VALUES FOR :E:VEN:IO0- SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 2 21 · 15 :: 4'.:o 1~:~I,:: ii~. " ::::. .:',': ~i.~~ :~:: 8 · 5 3 ~ .i' --260.24 E 42.40 8.39 299.25 E 50.73 8.33 3782.55 38~2.55 3982.55 4082.55 3700.i00 :: .73 N 3 :/_.,_IA,~ 4 .... N 3900.00 3o.$o N 4000.00 44.89 N 82.55 FT. 4024 4133 42~1 4182.55 4100.00 59.11 N 338.18 E 58..98 8.25 ~'4"9 ............ ~"2'82.'55'---~7~'2-0"0-;:~0 : ::i~ ~.'::. 7'3."34'~N ..: 4673 4582.55 4500.00 114.34 N 492.52 E 91.27 7.84 4781 4682.55 ~600.00 ~ 127.08 N 530.30 E 98.93 4889 4782.55 4~,~.~.00 139.19 N 568.13 E 106.53 7.60 . ~996 . "4882.55 . · 4800-00.;.;;~::'/. . . , 5103 4982.55 ~ 4900.'00 ~ - : .: .:.: ·; 5210 . 5082.55' ::. 5000.00'-:.: 5517 5182.55 5100.00 185.22 N 7~6.56 E 155.58 7.25 5~25 5282~55 5200.00 19q.20 N 755.98 E 1,2.79 7.~1 5552 5582.55 5500.00 205.~2 N 792.1~ E 150.~0 7.62 i " : · . ,'. . : A N C H 0 R A GEg.:;.A L ::::::::::::::::::::::::::::::::::::::::::::::::::: ;. : ~ · · L__SONIO ALASKA pETROLEUM cOMANy :: :t: :'::: C TE oF 'SURVEY MAY.199 1981 PRUDHOE BAY MAY 21, 1981 dOB NUMBER BOSS-16804 - ALASKA KELLY BUSHING ELEV. = 82.55 FT. TRUE SUB-SEA HEASURED VERTICAL VERTICAL DEPTH :.::..:: : DEPTH i-- _5855 5682.55 ........................ ~ ..... ~ .............. 5963 5782.55 5700,00 251,28 N 6071 5882.55 5800,00 263.99 N 6178 5982.55 5900.00 276.50 N VAgUES FOR .:.EVEN ~10 TOTAL RECTANGULAR COORDINATES N MD-TVD VERTICAL 982.07 E 188.47 7.99 1020.58 E 196.36 7.89 6286 6501 6609 6717 682/+ 6q82.55 6400.00 : 335.63 N 1210.54 E 254.~9 7.59 6582.55 6500.00 3¢7.17 N '~2~8.~8 E 2~2.07 7.58 7364 7471 7579 7686 779~ 7082.55 7000.00 598.75 N 16~5.55 E 282,01 7.62 7182.55 7100,00 406.45 N 1485.96 E 289.41 7,41 728'~-'"~5-----¥'2"0-b~0~0 ': ~ :i~"~8~6--N~1'-5-;~-~,?.~O'4--E'.i~ ii'i i:'.:-!F: .<~: 2~9-6%-6~.?":'~h~..: :. l J~6 '::.. :..:.:,: ..... .,: : :: 738 2.55 ", ~:~ :~7 ~0 0-00.~' ~-~' ~ 2 i' i ~:'~ 156-0:87( E"~ :.';.~: '~..~':' ' 3 0 ~ ~ 0:.?~:? :::' ..~: ~,t_..~L..~:~=~.; t~ .. ,~:~ ~_~~ : ~.:L~ .- ('tL :~..:..... ,~ ._:~... _=;. L .... ........ ;,:.... hr... ,Lt.:. ::~. :;: .gL': .: .? [; '.: [,. ' .... :.: :,..L: ':._ :t: ,j'.:t: :... L.;, ........ ,,,, WELL NO. H-15 SEC21,~TllNgR13E COMPUTATION DATE PRUDHOE BAY MAY 2:1.~ 1981 ALASKA ATE' OF .SURVEY MAY 19, P-AGE 10 1981 dOB NUMBER BOSS-16804 KELLY BUSHING ELEV, = 82,55 FT, TRUE SUB-SEA VERTICAL VERTICAL MEASURED DEPTH. '~ :' DE"~'¥"~--T77 ..... -'~' DEPTH, ?.:'::::NORTH/SOUTH,': 8012 7682.55 7600.00 439.49 N 1687.54 8122 7782.55 7700.00 444.08 N 1731.92 82~1 7882.55 7800.00 4~8.37 N TOTAL RECTANGULAR COORDINATES E E 1775.09 E MD-TVD VERTICAL :.:E R EN:C E S:.:, :~ C 0 R R E C T I 0 N' 8 70 330.41 9.41 ~9.91 9.50 348.92 9.01 . o 8556 i 8182,55 8100'00 'N 8663 8282,55 8200.00 465.46 N 1938.0~ E 381.21 7.31 8770 8582,55 8500,00 ,. 468,35 N 1976.19 E 588.28 7,07 8877 8482,55 8400.00 470.70 N 2013.91 E 595,19 6.91 8984 · 85~8~'J5~'~-'8500~'U'O ........... ---'S--~'¥i'-,~84 N ~ 6,66 '. : ..'. 909Z' , 8682.55.: 8600.00 A7Z.GZ .. 9200' :' 8782,55 ......................... ~~.j .............. ~ , ~ ...4.., .~ ........ .~. ~ ...... :,.. ;,~, ' · ~.~,Ff!;,..'.:-::~;:::':,~'?F. :- ,:- ~.. ~ ,.,~.~ "' · ~. ...... : ...... .......... 9509 8882.55 8800.00 ~69.~5 N 2177.26 E ~27.~ 9.6~ 9~20 8982.55 8900.00 ~67.27 N 222~.~8 E ~58.01 10.57 9551 9082.55 9000.00 ~6~.25 N 2272.25 E ~8.91 10.90 9754 9282.55 92'00:'00': ..A5A.67 N THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 0 Eastman Whipstock A PETROLANE REPORT of ~SUB-SURFACE DIRECTIONAL SURVEY SOHIO PETROLEUM CO. COMPANY PAD H.f NO. 13 WELL NAME PRUDHOE BAY , ALASKA LOCATION JOB NUMBER A481D0326 TYPE OF SURVEY~ E [ -~ ~ V ~ D Directional Shot singljuNe. _ 9 198i Oil & Gas Cons. Commission Ap. chorag~ DATE 6/9/81 SURVEY BY George Wainscoat OFFICE ALASKA Eastman Whipstock P. O. Box 4-1970/Anchorage, Alas)<a 99509/(907) 34.,~4617 TWX 910-881-5066/Cable: EASTCO June 9, 1981 Sohio ~etroleum Company Pouch 6-612 Anchorage, Alaska 99502 Well Number: Pad H, Well No. 13 Location: Prudhoe Bay, North Slope, Alaska Type°of Survey: Directional Single Shot Date: 6/9/81 Method of Computation: Radius of Curvature Driller: George Wainscoat Job Number: A481D0326 Gentlemen®. I am enclosing.the original and five copies of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. erely, District Directional Drilling Supervisor Alaska District enclosure LK/kp Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide .. SOHIO'F'ETROLEUM-:"COo F'AD H, WELL NO; 12 DSS JOB NO~ PRUDHOE, BAY,NORTH SLOF'E ALASKA DSS,--O-9OO2-HDF-DR'tLLER;--G-WAt'NSCOA~ A481DO32& RECORD-OF-.SURVE¥ RAf-;IUS OF CURVATURE METHOD ~OHIO F'ETROLEUH CO, PAD'~H~ ....WELC"'NO:'13' DSS ............. PRUDHOE BAY,NORTH SLOF'E ALASEA 7]08-' NO':-A481 [;0326 COMPUTATION 'TIME ....... [;ATE ....... 08:25:00 09-JUN-81 PAGE NO, ............................................... TRUE .................................. MEASURED [;RIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G LJ L DEF'TH ANGLE DIRECTION L. ENGTH DEF'TH SECTION TVD C 0 0 R D I N A T FEET' D M D H FEET ...... FEET ....... -"FEET ................ FEET FEET O. 0 0 0 0 : O. 0.00 0.00 -77.00 0.00 0.00 ''2695. '0 0 0" 0 ......... 2695'~ ........ 2695T00 ....... 0'~00 .......... 2618'00 0.00 0.00 2942. '0 30 N 76 0 E 247. 2942.00 1.08 2865.00 0.26 N 1.05 3150, 3 45 S 66 0 E 208. 3149.83 8.07 3072.83 0.40 S 8.59 3284. ' 7 0 S 89 O' E .....134. ........ 3283'~'22 ........... 18~'87 ..... ~206~22 3.10 S 20.76 AR CLOSURE E S DISTANCE DIRECTION ' FEET' D M E E E' 0.00 0 0 0,00 .... 0 0 1.08 N 76 0 E 8.60 S 87 20 E -20,-99 ...... S---81 31 E DOGLE(; SEVERI1 DG/100F 0.00 0.00 0.20 1.62 2.86 3400. 11 30 N 81 30 E' 116. 3397.68 36.95 3320.68 1.88 S 39.34 . ........ oo ..... 3411-,38' ' 1.15 N 59.64 3493 14 0 N 81 30 E 9'3~ ...... 3488~8 ...........57~ 3583. 17 0 N 71 0 E 90. 3575.10 81.19 ~498.10 6.86 N 82.96 3681. 19 45 N 71 30 E 98. 3668.09 112.07 3591.09 i6.79 N 112.21 3753. 22 45 N 70 30 E ...... 72~ ......... 3735'w1~ ...... 1~38¥15 ...... 3658.19 25.29 N 136.89- 4000. 23 0 N 67 0 E 4459.--'23 .... 0'N'67 O-E 4950. 22 0 N 71 0 E 5253. 21 45 N 71 0 E 5620. .......... 22---0 N 72- 0 E 6009. 22 45 N 6330, ..... 22 .... ON 6989. 22 45 N 7432. 22 0 N '~745¥ .... 22-45-"'~N- 8054. 24 30 N 8437-.-"--23--0. N-. 8856. 21 0 N 9002. 21 15 N 226.35 E 391.44 E 566.82 E ,.673.56 E !'80'3.22 E 789. 5820. ~7 997.56 574~. ~7 ~25.21 N E 39.38 S 87 16 E E .... 59-~65 .... N-88 53 E E 83.25 N 85 16 E E 113.46 N 81 29 E E'- 1~9-.20-- N-.79 32 E ,,~08 4.55 2.81 4.20 234.19 N 75 8 E 0.56 412..51-- N--71-36 E 0.00 600.24 N 70 48 E 0.37 713.12 N 70 50 E 0.08 84~.-84---N--.70 56~E ..... 0.12 70 30 E .943.44 E 997.92 N 70 59 E 70-"30---E ..... :--321-~ ........ 6kt'7-~20---1-ti9-,69 .... 6040.20 .... 366,00-.N-.1058,62..-E.--1120..11 ...... N-70---56-E 71 30 E 659. '6726,58 1370.46 6649.58 447.67 N 1295.81 E 1370.96 N 70 56 E 0.24 0.23 0.13 0.42 E 1539.38 N 71 15 E E. 1657-.-96----N-71-40---E ....... 0.34 E 1780.38 N 72 16 E u.86 E---1932.26 .... N.-73-- 6 E ..... 0.40 E 2086.70 N 73 54 E 0.53 E 2157.93 N 74 14 E 1.12 oo 494.85 N 1457.67 76 0 E '443. 7136.22 1539.01 7059.~ 78 ...... O""E .... ~'15'i-~7'425T6~1"657'~9-~7348,-65- 52 ~, 65 -N -' 15730~6' . 1695.85 1848.87 2004.87 2057.42 83 0 E 309. '7708.74 1780.37 7631.74 542.08 N 82-30---E ...... 383. .....8059.-70 =-.1932.-16 ...... 7-982..30 .......561.54-N 85 0 E 419. 8447.77 2086.08 8370.77 578.63 N 89 30 E 146. 8583.96 2136.96 8506.96 581.15 N FINAL CLOSURE -'DIRECTION: N 74 DEGS 13 MINS 36 SECS E .......................................................... DISTANCE: ........... 2137-,.93---FEET ~ . z~,,/7 ,¢~,~ ¢¢ / S'URVEYS FOR THIS ASSY. DRILLWITH ? Bit type .,,_¢z%¢' _~:7~-~/ 3-// .... & Knozzle Size Hours on Bit' SURVEYS FOR THIS ASSY. DRILLWITH / R PM .~ & Knozzle -Size Hours on Bit ~ ~ ~.~'- , / ? / SURVEYS FOR THIS ASSY. k?'"::'"'" - ;':t:-:' , *. · " l · . ', ~. & Knozzle Size ." Hours on Bit- COMPANY' Purpos'e of Assy;z~/o/~W/.~w/~- SURVEYS FOR THIS ASSY. DRILLWITH WE,C~H','_ ~./~'~ / / & Knozzle Size Hours on Bit~3~ ~-//-/-/~ · ~UD! ,NO L~ 1 ":'-:-~' :' ': ' ' i'--:-'-'~"'i'-t ~-'~'-'~'~'i 1 ~ · ~ .1 ...... ~__~ ...... ~- F - ~--- b-'f"-~'l' '-: ':-'~ '?-'Ft~'~-k' t T '. ' ~-:--~. b':--:-~ ~ L ,',.--~ : ~- ~ ....... ~ .... ~ -;' j ' : - '~ ..... : ' SOHI61 'PETROL ':: :N.:~ PAD 'H;/NEI2L"'iNa '"-:'j'" ?. RUDHOE '-BRY,":NORTH --HOR · C:i -'-'200-~ ..~..DE .P..TH_. [ND I I:RTOR ...... .~"~'-m -.-+--!-4 +..! , ....... ~"';"F , -~--'--,-''~" -T't-t:' ' : ........ : .... ~ ..... ~-': .... : :'"F, ...... "-: ~:..~_~ .................. , .. ' ' ..:__~ .... ......... - --',.-.~ .......... ......... ....... :- ..~:., .... ~-!~-~-+-i--~.-i-'- ...... ............. :`. ""1. .... ~ . ', ' ...... ..... ~'~ ....... '~ .... -'~ ..... ..... I,. ~....~.~ _j.~ ..... .-'- ~ - "~ .... :'":"~ ....... ~Fr-~-: .... : · , ; ~ ' · ~ ; , ~ -~ ..... '-~ ' - .' '~t "'": "l .... ~ ; , . .: ..... .. ~ ......... , ..... ~ ....... :..:...~..L_.~. -~.-: .... ,-: '~ .... ~ .... ~ .......... t, -~---:--:-, :~-._ ...t-;._ ."..'.~.::;_.L.:~'~L:2::ZZ'~: .... ........... ~ ........... ~ .... ~--~ ....... t-:-'~,~ ..... ~ '- ~ ~ ..... ~ ............. r ...... ;-'F':"i'*-. ........ ~ q_~ .... ~, =__~.~ .... : ~..L..;.~_L..~.-:..-.~.-4-~-~ · , - · ;-. - , ...... :-~-~1~-~--t-~-i---,-~r .... t ....... T ..... : ~"~'~" ....... : .... ~"' ~":' F . ~...~.: .... L.~.; .... : .... ' .. · :-..i 4.,.-i.,~-~-~-: ;-'~ ..... ...... , ...... t, , ,, ~ ,.: : ,. ......... ' ' , ~ L , ' , , ;..: ..., ................ , ........... ,-- -~--t '%-',-, ~-~ ................ ' f , · ' ' ; ~ ~ ', I ,~.~.,.~ ~,~-~ ~~ ............. , '~ ..... ~'t~ ~ ~ ~ '' ' ' ' ~ ' ~ I ' ' ' - ~--~ ' "~" ~--' '~ .... ~ ...... ' ' ' ' · ' :- ; - ~ .... ~-q.=-4-'-~ ........ ~?t ....... t .............. I-'F'~ ............... , ............r-~ ...... :"T -'~( ' : : ~: ~ '. ' ~ ' · ~.' ~-~ '- ~--~.~ , i . , . ' ' ~ ' ~ j ' ; . ' ~ ' ' ~ ~-~-~-~--~t--'~-. .... " ' c .... ~" -' '--~ ~ ~ ! t ; · . . · t ' ~ - -' - - i --' - : 4. ~. ; L_; .. ~ ............. ~ ...... ~ · ....~ '-, *'~ ...... J "~"~ .... · , ' ' , ' , : '. J · ' ' "' ' .... ~" - .... r ........ ,-': ......... ~l"-:":~-~'-t ~ ~, ~ ,.· , · L ~ ' ,: ., ~ . ,: ~ ~ .... , ,_~._,,._=.~.. :__....~ .............. ,-, ......... i ............ '"J' : ' '" ' ' '" ......... ~ ...... ~ ..... : .... 1 .........: 1--1-~--f-~--1 ..... r ..... !'I':"I ...... ~ ............... ; ~ ..... ~ : ~'~ ....... ~'] ..... t,'C'--,-.-m~ ~ I. ~ ~; , ,_' .;, I ; .... ~ : .L L ..... ~-l-~ ....... I ............ ...................................... , ~ ~ , , . , · , . t , . . , ~.- ........ ~ ...... , ..... .~ ................ ~-- .~ ...... ~ ........ ~ ........ i ..... : .... i --: ---~ -..' ~-· : '. ....' ...... ~, ....... ~ .... :-'-i ........ ~-L7 .... ~"I':'-: .... :'! .... : .... I ................ FINRL STRTIgN~": ....:i.' .... , . . . , . . , . · : ~ . . .................. , .............. =--:~ .... - ....... , .... ~ ...................... ,-~ ...... ~ ..... DEPTH-900~.,HD.--8583, .. ~, :., ............... ~ ....... :--~ .... : .... r---:--:--: .~--: ...... ;-~-'," ', ','' '.. , ~....,:.~:,. '.,.,.,._~,_:..:..' :._, ....... , ..... ! .. NgRTH 58~,[5.ERST.~057 ,..: .... ~ ... : , '~ ..... !---~ .... ~- .......... ~-:.:-~ ...... ).~ -~-r-,'~' '-~" .-",--: ' ~ ..... :-,:. :-: ~ .... : .... ~-'~-, .... ,--~ r': ~--~-?~--?t-i,~ ',.-~-~, L~_,.~.:=.:..~. c~oSURE~ ~S~.~,.N I ..... , ...... ~... , .......... , ................ 4--, ....... ~ ....... ~--~ .... :-,.-~- ~ t . , I , .............. . ............... . .................... , ......... .,. ,.. ..... , ......... ' ' ' ' ' ' . ' ' ~ ' ~ ~-' -- . ~ ........ ~ ~ - - ' .-- ~ · - ~ - i ...... .- -. ....... ....... : ......., .......... ~ ' ' :'" : ......... ~"';";"*", ...... : ~ : ~ i '~ . { t ~ , ; ~ ~ : .[ . ' . ... j t ._'.._: ..... ., ....... , ..... ', ....... : . . t ',; , : .'. .... .', ............... Check Form for timely compliance with our regulations. r, Name and Number Completion Report Reports and Materials to he received by: Wel 1 History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Required ! Date Received Yes Yes Date Remarks SOHIO ALASKA PETROLEUM COMPANY SOH I 0 COl'IF I DENT IAL 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 To: STATE OF ALASKA Date: 6/9/81 ~ 842 H-13 H-13 H-13 H-13 H-.'13 H-13 REFERENCE:' SOHIO FINAL DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ~~'iL/SFL (Sch) 5/10/81 #1 ~/~/~HCS 5/10/81 #1 /,"~"~'~DC 5/10/81 #1 ~×'~/?/~D C / CNA 5 / 10 / 81 # 1 2" & 5" 2" & 5" "2" & 5" 2" & 5" "~/~agnetic Single Shot Survey ~///~Yroscopic Survey computed 6/9/81 5/19/81 Job~481D0326 Jdb#16804 RECEIVED DATE _ AnChoraga Carol Krieker Development GeologY Well Records, HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 June 3, 1981 CONFIDENTIAl Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen- Well H-13 (11-22-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of May, 1981. RHR:ja Enclosures cc: Well File #17 Yours very truly,. District Drilling Engineer ' /*' STATE OF ALASKA [ .... . ALASKA{,,_ AND GAS CONSERVATION C(~x ,IISSION ' MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-17 3. Address 8. APl Number :Pouch 6-612, Anchorage, Alaska 99502 50-029-20559 4. Location of Well at surface 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 82.55' AMSL ADL 28284 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. H-13 (11-22-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of May ,19 81 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month end: 9759' PBTD Footage drilled: 4125 ' 13. Casing or liner run and quantities of cement, results of pressure tests See Well History attached. ,'14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHCS/SP/GR @ 8895' FDC/CNL/GR/Cal @ 8895' HDT @ 8895' CBL/VDL/GR/CCL @ 9743' G~roscopic survey @ 9746' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVFD JUN lg81 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~lgtl~lfmliji "SIGNED TITLE District Drilling Enginee~ATE ~'' ~ 0 '~I NOTE--R~'p~ is required for each~alendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 SOHIO ALASKA PETROLEUM COMPANY ARCO 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH.6-612 ANCHORAGE, ALASKA 99502 EXXON Date: 5/29/81 # 827 PHILLIPS SFO SOHIO MAGNETIC LIS TAPES & Listings /he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- MAGNETIC LIS TAPES & LISTINGS FOR WELLS LISTED BELOW: E-2 CH CNL ~ (Shh) 5/7/81 # #61621 F-4 " 2/1/81 #5 #61371 J-6 " 5/8/81 #1 #61613 J-11 DNLL (DreS) 5/7/81 -- ~ -- R-4 (Sch) 5/7/81 #2 #61630 X-10 " 3/8/81 #1 #61465 MM (11).33-11-12 " .... #61557 *A-9 *B-5 *F-3 *G-2 .... ~G-3 *G B *N-Ii RECEIVED DATE _ (Sch) 4/23/81 #2 , ~ " 5/9/81 #3 " 5/7/81 # " 4/30/81 #5 "- 5/1/81 #1 ~ " 5/,10/81 #1 " 5/2/81 #2 ~' " 5/5/81, #2 CH CNL #61572 #61642 #61614 #61610 1/61613 #61635 #61634 #61607 #61636 Carol Krie~er Development Geology Well Records HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY May 8, 1981 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well H-13 (11-22-11-13) Enclosed, in duplicate, .is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of April, 1981. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer . STATE OF ALASKA ALASK/~r""'~L AND GAS CONSERVATION C('~ 1MISSION i ONTHLY REPORT F DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation [] .~. Name of operator Sohio Alaska Petroleum Company Address Pouch 6-612, Anchorage, Alaska 99502 :4. Location of Well at surface 1652' SNL, 1264' WEL, Sec. 21, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 82.55' AMSL ADL 28284 7. Permit No. 81-17 -~. APl Number 50_029-20559 9. Unit or Lease Name Prudhoe Bay unit 10. Well No. H-13 (11-22-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of April ,19_81 Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month-end: 5680' Footage drilled: 5680' Spudded well at 0300 hrs., 4/24/81 13. Casing or liner run and quantities of cement, results of pressur9 tests Ran 69 its. 13 3/8" 72~ L-80 Buttress casing to 2695'. Cemented with 3720 cu.ft. Permafrost II cement. Tested casing at 2652' to 3000 psi, okay. Performed leak-off test at 2730' to 0.89 psi/ft, gradient, · 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED MAY 1 5 198i Alaska Oil & Gas Cons. C0mmJssJ0n Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE District Drilling Enginee~AmE .-~'- - -- . ~his form is requ~red~for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate Form 10-404 Rev. 7-1-80 ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto~ Chairman Thru: Lonnie C. Smith' - '~~" · Commissioner Do ug Arno s ~ Petroleum Inspector April 29, 1981 Witness B .0. P.E. test on Sohio's H-13 Well, Sec. 21, T.1IN., R.13 E, Permit ~81-17 on Van Guard Rig #3 Sunday April 26, 1981: I departed my residence at 3:30 p.m. for a 5'i00 p.m.' depart'ute on wien Flight ~75, arriving Deadhorse at 8:00 p.m. MondaY April 27, 1981: . The B.O.P.E. test commenced at 3530 a.m. -~ : :: : :- ,, u and was concluded at 5:30 a.m., there were no failures, I filled out an A.O.G.C.C. B,O.P.E, test report which is attached. In summary, I witnessed the B.O.P.E. test on Sob:o's H-13 well on VanGuard Rig t3, there 'were no failures, I filled out an A,O,G,C.C.B.O.P,E. test report which is attached. DA ~df O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION C(]v~AqSION B .O. P .E. Inspection Report Inspector Date I~P, PlL. 27;19~/ Well /-/ -/3 Operator Well Location: Sec ~1 T II/J R tS~ M ~7/, ./go Pril ling Contractor ~&n ~PPD Rig # 'g Representative Permit # ~/' /7 /$ ~asing Set @ ~~' ft. Representative ~7!~4 Lg~'~A/~ Location, C~nera] Well Sign. ~A' Ceneral Housekeeping Peserve pit Rig BOPE Stack I Annular Preventer t . Pipe Rams Blind Rams / Choke Line Valves H.C.R. Valve Kil 1 Line Valves 7, / Check Valve Test Pres sure ACCL%~UIATO______RR SYSTE____MM IFull Charge Pressure-- ~Od) .psig 1Pressure After Closure /~D~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master Remote gP~f Blinds switch cover ~'~ min ~Z sec. min 1~ sec. Kelly and Floor Safety Valves- Upper Kelly I .Test Pressure Lo~er Kelly ! Test Pres sure Ball Typ~ ? Test Pressure Ins ide BOP ! Test Pres sure Choke Manifold i No. Valves.__ NO. flanges_, ~ ~dj ustab le Chokes, Hydrauically operated choke Test Pressure Test Results: Failures ,J~D/J~ Test Time.', / Repair or Replacement of failed equipment to be made within.. Inspector/Ccmmission office notified. Remarks: days and Distribut ion orig. - AO&CCC cc - Operator cc - Supervisor Inspector February 20, 1981 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re= Prudhoe Bay Unit H-13 Sohio Alaska Petroleum Company Permit NO. 81-17 Sur. Loc.= 1264'WEL, 1652'SNL, Sec 21, TllN, R13E, UPM. BottomhoIe Loc.~ 1120'EWL, 900'SNL, Sec 22, T11N, R13E, UPM. Dear Mr. Reiley .- Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to comr~encing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ArtiCle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. H. Reiley Prudhoe Bay Unit H-13 -2- February 20, 1981 commencing operations of the Department of contacted by a representative Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of ~he issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notify£ng this office within 48 hours af~e'r the well is spudded. We would also like to be notified so that a repre- sentative of the commission may .be present to witness of blowout preventer equipment before surface casing shoe drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness, present. Very truly yours, Hoyle' ~. Hamilton Chairman of ~ ~a ~ ~'~'- ~ ..... ~ ........ Alash Oil i ~.s Consemtion Co~ission Enclosure cc.- Department of Fish & Ga~e, Habitat Section w/o encl. Department of Environmental Conservation w/o/eno1. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 ,~ MAIL: POUCH 6-612 ANCHORAG E, ALASKA 99502 February 10, 1981 Alaska Oil & Gas Conservation Con~ission 3001 Porcupine Drive Anchorage, Alaska 99510 Attn: Mr. H. H. Hamilton Gentlemen: WELL H-13 (11-22-11-13) In accordance with the Prudhoe Bay Field Rules and Sohio's policy for drilling the first well on a new pad and/or new area, a 20" Hydril and diverter system was used when drilling the surface hole on H-9 (24-21-11- i3). We did not experience any surface gas during the drilling of the 17 1/2" hole on Well H-9 andbelieve it unnecessary to continue the use of the 20" Hydril and diverter system on Pad H. We, therefore, request that Rule 4(b) of Conservation Order No. 145 be waived for the remainder of H-Padwells. Yours very truly, SOHIO ALASKAPETROLEUMCOMPANY District Drilling Engineer cc: H-Pad/Well File K. W. Kolthoff SOHIO ALASKA PETROLEUM COMPANY February 5, 1981 3111 '°C" STREET ANCHORAGE, ALASKA TE LEPHON E (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENTIAL Alaska Oil & Gas Conservation Co~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well H-13 (11-22-11-13) Enclosed, in triplicate, are the following documents along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Equipment Diagram, 4. Surveyor's plat showing well location, 5. Directional plan. Yours very truly, District Drilling RHR: ja Enclosures cc: Well File ~17 PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~] SINGLEZONE;I~[] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum ~y ............ 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 9. Unit or lease name 1264' WEL, 1652' SNL, Sec. 21, TllN, R13E, UPM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 930' EWL, 960' SNL, Sec. 22, TllN, R13E, UPM H-13 (11-22-11-13) At total depth 11. Field and pool 1120' EWL, 900' SNL, Sec. 22, TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe Oil Pool Est. KBE = 77' .AMSLI ADL 28284 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number SafecO Ins. 2975387 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse 10 miles ADL 28285 4350feet well H-1 480 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9840lMD 9340'TVD feet 2560 April 20, 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3330 psig@ Surface KICK OFF POINT 3000 feet. MAXIMUM HOLE ANGLE 23 oI (see 20 AAC 25.035 (c) (2) 4390 ~ psig@_ 8800 ft. ~ (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20x30 Insulat.ed Conductor 110 Sur~ace 110 ~: 110 8 cu.yds. 17 1/2 13 3/8 729 L-80 Butt. .2680 Surface 2680 I 2680 3720 cu,ft. Permafrost 12 1/4 9 5/8 47~ L-80 Butt. 8860 Surface 8860 I 8440 1200 cu. ft. Class G;.. ~ I 130 cu. ft. Permafrost :8 1/2~ 7 29~ L-80 Butt. 1480 8360 ~, 7980 9840 I1 9340 270 cu. ft. Class :G 22. Describe proposed program: w/lB% salt See attached proposed drilling program outline. 23. I hereby~ ~e best of my knowledge ~1~ SIGNED TITLEDistrict Drilling Enginee~ATE The space below for Commission use CONDITIONS OF APPROVAL ,, ,, ,, :Samples required I Mud Icg required Directional Survey required I APl number []YES [~N,OI []YES ~NO /[~Y E S []NO Permit number Approval date I~/-I ~ 02/20/81 J SEE COVER LETTER FOR OTHER REQUIREMENTS --. APPROVED BY ~,~, ~ ,COMMISSIONER DATE F~H~-~m~,'~r 9fl_ 1 QRI' by order of the Commission II I Form 10401 Submit in triplicate Rev. 7-1;80 PROPOSED DRILLING AND CEMPLETION PROGRAM WELL H-13 (11-22-11-13) Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3720 cu. ft. Permafrost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil coluxm to 8800' TVD. Directionally drill 12 1/4" hole to 8445'+ ~"AzD. Run 9 5/8" 479 L-80 Buttress casing to 8440' TVD and cement first stage with 1200 cu. ft. cement. Cement second stage through D.V. packer collar at 2600'+ with 130 cu. ft. ~Permafrost I cement. 9_ 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9345'+ TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 270 cu. ft. Class G cement with 18% salt. Run 5 1/2" IJ4S tubing with 6 gas-lift mandrels and a production packer assembly at 7930'+ TVD. A subsurface safety valve with dual control lines will be placed at 2000'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. perforations to be suk~itted on Sundry Notice to follow. Details of proposed 2/3/81 B.O.P., STACK CONFIGURATIO_~N 5/8 TRIPLE RAM STACt~ ,5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS KILL LINE CHECK GATE GATE DRILLING SPOOL PIPE RAMS 4" CHOKE LINE H-3 H-13 5255' T 4760' TvD' '~ H-3~ 4330" "iV, 3670' ~'H-13 4 3694~ ~ H-13 4245', TVD , H:~ 4944' TVD ... : - :.sT-..j :--_--- .... ~ ~ :i ...... ~ ....... : .... : ~'-------!. +------'--a -. _--'7/_-. r :'l:: ;'::: :-L'i ...... ,.~ -~F_--! '.-'J i .--_-~--_--'_' i'-_ ! ! :. '-_". ! !'.: i i !.:. E!}!!l !.:!!~!!-:! *_--_; ,,- .'1.: '-1 :;.-7'. 'lC.ii:: l:l ;-' I0 s~O :50 01 t5 LAT. "tO° 1T'40.74" LON(L 14B050'~- I. 5?" ... .X =.. ------ . --- ~~ ,. · I I I ! 1 i ! , PAD DETAIL SCALE i"= 300' I~pORTION'- -~ T. II N.,R. ISE. SCALE i"'"!/2rMILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to' Practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision and all dimensions and other details are correct' Bottom hole lOcations are, furnished by others. EXTEN:S.IO,N ':' ;;/:: Surveyed for. SOHIO' AL AS KA PETROLEUN 2- ;5 -81 D.'H;Q (8800' SUBSEA) 6~- I Z-80 LA.B, F.M. LINDS'EY "~. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West'Northern Lights Boul'evord Box:,4L CHECK LIST FOR NEW WE.T,L PERMITS Item Approve Date (1) Fee /~r"- 'w~/.,,,.~. (2) Loc. (3) k~nin.I ~ Cclnpany Yes ( 4 ) '~~ ( 5 ) BOPE 1. Is the permit fee attached .......................................... 2. Is ~ell to be located in a defined pool ............................ 3. Is a registered survey plat attached ................................ 4. Is well located proper distance frcm property line .................. 5. Is well located proper distance frcm other w~lls .................... 6. Is sufficient undedicated acreage available in this pool 7. Is well to be deviated ............................................. o 8 Is operator the only affected party . ' ..... 9. Can permit be approved before ten-day wai~ ................. 10. Does operator have a bond in force ............... ~- 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Ts conductor string ...................................... 14. Is enough cement used to circulate on conductor and surface ....... 15. Will c~nent tie in surface and. intermediate or production Strings . ~.. 16. WLll cermnt cover all kno~m productive horizons .................... __ 17,. Will surface casing protect fresh water zones ...................... 18. Will all casing give adequate safety in collapse, tension and burst~ 19. Does BOPE have sufficient pressure rating - Test to ~-o~ psig~~. ~ ~' Approval P,.c::~2~ded: _ Additional Requirements: No Lease & Well No. ~ ~' Remarks Geology: / Engineering: rev: 03/05/80 Well Histow File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. · o · 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 APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. H- 13 *~c~/v PRUD H O E BAY~ °;~ ~~ ~ ~ *~ 18 - November - 1993 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD H - 13 500292055900 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 02-DEC-93 6090.00 W. BARKER J. BENNETT 21 11N 13E 1652 1264 82.55 0.00 45.35 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 8907.0 47.00 7.000 9800.0 29.00 5.500 8335.0 17.00 4.500 8466.0 12.60 BASELINE DEPTH 8862.0 8893.0 8904.0 8912.0 8937.0 8940.0 8945.5 8957.5 8959.5 8964.5 8969.0 8973.0 8992.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 8862.0 8893.5 8904.0 8912.5 8937.5 8940.0 8946.0 8958.0 8959.5 8964.0 8968.5 8973.5 8993.0 BHCS GR 2 1 24 -APR- 81 SWS 8994.0 8994.5 9002.0 9003.5 9004.5 9007.0 9008.0 9008.5 9020.0 9022.0 9024.5 9025.5 9026.0 9053.0 9053.5 9063.5 9073.5 9096.0 9097.0 9139.0 9153.5 9158.0 9225.5 9226.0 9227.5 9253.0 9263.5 9264.5 9398.0 9402.5 9403.5 9405.5 9419.5 9443.5 9444.5 9495.5 9501.5 9502.5 9510.0 9510.5 9512.5 9527.0 9578.0 9590.5 9591.5 9594.5 9602.5 9612.0 9621.0 9655.0 $ REMARKS: 8994.5 8995.5 9003.5 9005.0 9005.5 9008.0 9008.5 9009.0 9021.5 9023.5 9025.0 9026.0 9027.0 9054.0 9055.0 9065.0 9074.0 9097.0 9097.5 9139.5 9154.0 9159.0 9226.5 9227.5 9229.0 9254.0 9264.5 9265.0 9399.5 9404.0 9404.5 9406.5 9421.5 9445.5 9446.0 9499.0 9505.0 9505.5 9513.0 9514.0 9516.0 9530.5 9579.5 9592.0 9592.5 9595.5 9604.0 9613.5 9622.0 9655.0 CN/GR Cased Hole. LOG TIED TO BHCS DATED 10-MAY-81. NEUTRON LOG PARAMETRS: SANDSTONE MATRIX, CHISM FILTERING OFF, CALIPER CORRECTIONS OFF, NO CASING OR SALINITY CORRECTIONS APPLIED. WELL WAS LOGGED SHUT-IN AFTER PUMPING 210 BBLS OF SEAWATER. OPEN HOLE GAMMA RAY DOWNLOADED FROM THE BP EXPLORATION UPS/CSS SYSTEM 29-NOV-93. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT= 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: i START DEPTH STOP DEPTH 8886.0 9631.0 8899.0 9639.0 BASELINE DEPTH 8862.0 8904.0 8910.0 8912.0 8924.5 8937.0 8940.0 8945.5 8957.5 8960.5 8964.5 8968.5 8972.0 8973.0 8985.0 8989.0 8996.0 9004.0 9009.5 9013.5 9016.5 9020.0 9022.0 9024.5 9025.5 9026.0 9037.0 9052.0 9057.0 9061.0 9074.0 9102.0 9141.0 9146.0 9153.5 9182.5 9194.0 9211.0 9221.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... NPHI 8862.0 8904.0 8910.5 8912.0 8925.0 8937.5 8940.0 8946.0 8958.0 8959.5 8964.5 8968.5 8972.5 8973.5 8985.5 8989.0 8997.5 9005.0 9009.5 9014.5 9018.0 9021.5 9023.5 9025.0 9026.0 9027.0 9038.0 9052.0 9057.0 9061.5 9074.0 9102.0 9140.5 9146.0 9154.0 9183.5 9193.5 9210.0 9221.5 9227.5 9233.0 9236.5 9253.0 9258.5 9265.0 9398.0 9405.5 9411.0 9416.0 9419.5 9433.0 9443.5 9444.5 9495.0 9497.5 9505.5 9527.0 9578.0 9584.0 9596.5 9603.0 9605.0 9608.0 9610.5 9621.0 9655.0 $ REMARKS.' 9228.0 9233.5 9236.5 9254.0 9258.0 9265.0 9399.5 9407.0 9413.0 9417.0 9421.5 9435.0 9445.5 9446.0 9497.5 9500.0 9507.5 9530.5 9579.5 9586.0 9597.5 9603.0 9605.5 9609.0 9611.5 9622.0 9655.0 PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCHWAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH5. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FOB~4AT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units GRCH 2418 68 i GAPI NPHI 2418 68 I PU-S FUCT 2418 68 i CPS NUCT 2418 68 I CPS TENS 2418 68 i LB API API API API Log Crv Crv Size Length Typ Typ els Mod 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 * DATA RECORD (TYPES 0) Total Data Records: 38 1014 BYTES * Tape File Start Depth = 9655.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9523 datums Tape Subfile: 2 277 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: i START DEPTH STOP DEPTH 8870.0 9631.0 8882.0 9639.0 BASELINE DEPTH 8862.0 8906.5 8910.0 8913.5 8922.0 8940.0 8946.0 8956.0 8960.5 8964.0 8964.5 8967.5 8972.5 8979.0 8990.5 8992.5 8993.0 8993.5 8994.5 8995.0 9001.0 9002.0 9002.5 9003.5 9004.0 9004.5 9005.0 9008.0 9018.5 9019 · 0 9020.0 9021.0 9022.5 9024.5 9025.5 9026.5 9031.5 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH NPHI 8862.0 8862.0 8901.0 8906.5 8910.0 8918.0 8939.0 8945.0 8962.0 8965.5 8972.0 8994.5 9002.5 9003.0 9003.5 9004.0 9022.0 9024.5 9025.5 9026.0 8954.0 8958.5 8962.5 8978.0 8989.5 8992.0 8992.5 8993.5 8994.5 9000.5 9003.5 9004.0 9007.0 9019.5 9020.0 9020.5 9021.0 9031.5 9032.5 9035.0 9035.5 9036.5 9037.5 9038.5 9047.5 9048.0 9049.5 9050.5 9059.0 9059.5 9063.0 9064.0 9068.0 9070.0 9078.5 9096.0 9117.0 9133.0 9135.5 9137.0 9145.5 9146.5 9147.0 9151.0 9153.5 9156.5 9158.0 9158.5 9168.0 9168.5 9169.5 9170.5 9171.5 9174.5 9176.0 9181.5 9183.0 9184.0 9187.0 9188.0 9204.5 9205.5 9211.0 9216.5 9220.0 9221.5 9224.5 9225.0 9245.5 9248.5 9249.0 9252.0 9254.0 9255.0 9256.0 9263.0 9263.5 9264.0 9034.5 9035.5 9036.5 9037.0 9047.0 9048.0 9064.0 9069.0 9146.0 9150.0 9152.5 9156.0 9157.5 9159.0 9175.5 9219.5 9221.5 9225.0 9245.0 9248.0 9256.0 9264.0 9032.0 9038.0 9048.5 9049.0 9057.5 9058.5 9062.0 9066.0 9076.5 9094.5 9115.5 9131.0 9133.5 9135.5 9144.0 9144.5 9145.0 9168.0 9168.5 9169.0 9170.0 9170.5 9173.5 9181.0 9182.5 9183.0 9186.0 9186.5 9203.0 9203.5 9209.0 9215.0 9223.0 9224.0 9248.0 9250.5 9252.5 9253.0 9261.0 9262.0 9263.0 9265.0 9265.5 9266.0 9276.0 9276.5 9284.5 9307.5 9308.5 9309.0 9309.5 9313.0 9334.0 9334.5 9346.0 9346.5 9347.0 9347.5 9350.0 9352.5 9372.0 9372.5 9387.5 9389.0 9398.5 9399.0 9399.5 9400.0 9400.5 9402.0 9402.5 9407.0 9409.0 9415.0 9417.5 9418.5 9419.0 9420.0 9421.0 9424.0 9428.0 9428.5 9444.5 9447.5 9475.5 9484.5 9485.0 9489.0 9489.5 9498.5 9499.0 9499.5 9500.0 9501.0 9501.5 9502.0 9510.0 9511.0 9511.5 9512.5 9524.0 9307.5 9308.0 9333.5 9334.0 9372.5 9373.0 9388.5 9390.0 9398.5 9399.0 9399.5 9401.5 9402.5 9409.0 9415.5 9445.0 9485.5 9486.0 9490.5 9491.5 9500.5 9501.0 9501.5 9503.0 9503.5 9511.5 9512.0 9512.5 9513.0 9526.0 9264.0 9265.0 9265.5 9274.0 9275.0 9283.0 9306.5 9307.5 9308.0 9311.5 9345.5 9346.5 9347.5 9348.0 9348.5 9351.0 9399.5 9400.5 9403.5 9408.5 9417.5 9418.5 9419.5 9420.5 9421.0 9424.0 9429.5 9430.0 9447.0 9475.0 9501.5 9502.0 9502.5 9503.0 9511.5 9527.0 9584.0 9589.5 9590.5 9591.5 9595.0 9596.0 9603.0 9605.5 9608.5 9610.5 9612.5 9624.5 9633.0 9655.0 $ 9529.0 9584.0 9589.5 9590.5 9591.0 9595.0 9595.5 9603.0 9602.0 9605.0 9608.0 9610.0 9612.5 9625.5 9633.5 9655.0 9655.0 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH2. OUT / ??MATCH6. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 i PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 i CPS 5 TENS 2418 68 I LB * DATA RECORD (TYPES 0) Total Data Records: 38 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 .4 86 720 65 6 4 4 86720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 2O 1014 BYTES * Tape File Start Depth = 9655.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code~ 68 9523 datums Tape Subfile: 3 244 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8886.0 9631.0 2418 8898.0 9639.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: i BASELINE DEPTH 8862.0 8890.5 8895.5 8897.0 8901.5 8904.0 8910.0 8911.5 8914.0 8919.5 8925.0 8927.0 8943.0 8945.0 8951.0 8961.0 8972.0 8972.5 8973.5 8975.0 8977.5 8978.0 8978-5 8979.0 8989.5 9001.5 9002.0 9003.0 9004.0 9005.5 9006.5 9009.5 9010.0 9018.0 9018.5 9020.0 9022.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH NPHI 8862.0 8862.0 8890.5 8895.0 8897.5 8901.5 8903.5 8909.0 8911.0 8911.0 8915.0 8920.0 8926.0 8927.5 8944.0 8945.0 8951.0 8960.0 8972.5 8973.0 8973.5 8974.0 8975.0 8977.5 8978.0 8979.0 8978.5 8989.0 9002.0 9003.0 9002.0 9004.0 9004.5 9006.0 9005.5 9006.5 9006.0 9009.5 9009.5 9019.0 9020.0 9021.5 9022.5 9022.5 9023.0 9023.5 9024.5 9024.5 9025.5 9025.5 9026.0 9026.0 9026.0 9031.5 9032.0 9043.5 9044.0 9044.5 9044.5 9046.5 9046.5 9049.5 9049.0 9050.0 9049.5 9051.0 9050.0 9051.5 9052.0 9050.5 9052.0 9053.0 9051.5 9065.5 9066.5 9078.0 9078.5 9077.5 9079.0 9078.0 9079.5 9078.5 9090.0 9090.5 9095.0 9094.5 9095.5 9095.5 9107.5 9107.5 9108.0 9107.5 9110.5 9109.5 9116.5 9115.5 9122.0 9121.5 9129.5 9127.5 9135.0 9134.5 9137.0 9136.5 9137.5 9137.5 9140.0 9139.0 9146.5 9146.0 9159.0 9159.0 9167.0 9167.5 9168.5 9169.0 9169.5 9169.5 9170.0 9170.5 9170.5 9171.0 9171.5 9171.5 9173.0 9173.0 9173.5 9174.0 9176.0 9176.5 9176.5 9181.0 9181.0 9187.0 9187.5 9187.0 9188.0 9188,0 9187'5 9190.0 9190.0 9191.5 9191.0 9192.5 9191.5 9198.0 9198.5 9198.5 9199.0 9219.0 9219.0 9220.0 9220.0 9220.5 9219.5 9222.0 9221.5 9226.0 9225.5 9226.5 9226.5 9228.5 9228.5 9229.5 9229.0 9245.0 9246.0 9245.5 9246.5 9252.5 9253.5 9254.5 9263.5 9264.0 9276.5 9286.5 9287.5 9307.5 9308.5 9332.5 9346.0 9346.5 9347.5 9348.0 9350.5 9351.5 9393.5 9394.5 9398.5 9399.0 9399.5 9400.0 9401.0 9405.5 9406.5 9409.0 9410.5 9411.5 9413.0 9417.0 9420.0 9421.0 9422.0 9427.5 9428.0 9431.5 9432.0 9437.0 9444.5 9447.5 9448.0 9473.0 9480.5 9485.5 9488.0 9489.0 9490.5 9499.5 9500.5 9501.5 9509.5 9510.0 9510.5 9511.0 9513.5 9521.0 9531.0 9578.0 9579.5 9253.0 9264.5 9287.5 9399.5 9400.0 9407.0 9411.5 9414 · 0 9421.5 9429.5 9432.5 9438.5 9446.0 9492.0 9503.5 9504.0 9512.0 9512.5 9513.0 9515.5 9524.0 9534.0 9578.5 9580.0 9253.0 9253.5 9262.5 9276.0 9287.0 9308.0 9309.0 9332.5 9347.5 9348.0 9348.5 9349.0 9349.5 9350.5 9394.5 9395.5 9400.5 9401.5 9402.0 9406.5 9411.5 9413.5 9417.5 9421.5 9422.0 9428.5 9433.5 9447.0 9447.5 9473.5 9480.5 9487.5 9490.0 9490.5 9492.0 9502.0 9503.0 9503.5 9511.5 9512.0 9512.5 9580.0 9582.0 9586.0 9587.0 9593.5 9594.0 9596.5 9598.0 9602.5 9605.0 9608.5 9611.0 9612.5 9613.5 9621.0 9624.5 9630.0 9655.0 $ REMARKS: 9581.0 9583.0 9587.0 9588.0 9594.0 9595.0 9596.5 9598.0 9603.0 9606.0 9609.0 9611.5 9613.5 9614.0 9622.0 9625.5 9630.5 9655.0 9655.0 PASS 3. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH3. OUT / ? ?MATCH7. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units i GRCH 2418 68 i GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 i CPS 4 NUCT 2418 68 i CPS 5 TENS 2418 68 I LB * DATA RECORD (TYPE# 0) Total Data Records: 38 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86'720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 2O 1014 BYTES * Tape File Start Depth = 9655.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19046 datums Tape Subfile: 4 247 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8886.0 9631.0 2418 8898.0 9639.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: i ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH NPHI 8862.0 8862.0 8862.0 8895.0 8896.0 8896.0 8896.5 8903.5 8902.5 8907.0 8907.5 8914.5 8913.5 8925.5 8926.0 8937.0 8937.0 8951.5 8952.5 8952.5 8953.5 8953.5 8954.0 8956.5 8957.0 8960.0 8960.0 8964.5 8964.5 8965.0 8964.0 8973.5 8975.5 8979.0 8979.5 8979.5 8980.0 8980.0 8981.0 9004.0 9005.0 9005.0 9005.5 9005.5 9006.0 9006.5 9006.5 9009.5 9010.0 9010.5 9010.5 9016.5 9018.0 9020.5 9021.5 9021.5 9022.5 9022.5 9023.5 9023.5 9025.0 9024.5 9026.0 9025.5 9026.5 9044.5 9045.5 9046.5 9047.0 9047.5 9048.0 9049.0 9049.0 9051.5 9052.5 9052. 9061. 9061. 9063. 9067. 9068. 9069. 9070. 9071. 9072. 9073. 9094. 9095. 9105. 9105. 9106. 9107. 9108. 9113. 9116. 9131. 9135. 9136. 9136. 9138. 9138 · 9141. 9149. 9159. 9159. 9166. 9172. 9173. 9174. 9176. 9181. 9182. 9183. 9185 · 9186. 9190 · 9191. 9199. 9200. 9201. 9204. 9204. 9205. 9211. 9217. 9217. 9218. 9219. 9219. 9220. 9222 · 9223. 9224. 9225 · 9225. 9053.5 9065.0 9069.0 9109.0 9135.5 9138.0 9139.0 9159.5 9177.0 9186.5 9187.0 9218.5 9219.0 9220.0 9220.5 9226.0 9226.5 9061.0 9062.0 9064.0 9067.0 9069.5 9070.0 9071.0 9072.0 9072.5 9094.0 9095.5 9105.0 9106.0 9107.0 9107.5 9112.5 9115.5 9130.0 9134.5 9135.5 9140.0 9149.0 9159.5 9167.0 9173.0 9174.0 9175.5 9182.0 9182 ..5 9183.0 9190.0 9190.5 9198.5 9199.0 9199.5 9203.5 9204.0 9204.5 9210.5 9216.5 9217.5 9222.5 9223.0 9224.0 9237.5 9252.5 9253.5 9254.0 9254.5 9264.0 9264.5 9284.5 9289.5 9309.5 9334.0 9396.5 9398.5 9400.5 9401.0 9405.5 9406.5 9409.0 9411.0 9412.5 9416.0 9419.0 9421.5 9443.5 9444.5 9454.5 9455.0 9458.0 9460.5 9489.0 9502.0 9509.0 9510.0 9512.0 9512.5 9513.0 9513.5 9514.0 9515.0 9517.0 9521.5 9525.0 9531.0 9578.0 9582.5 9585.5 9588.5 9593.5 9602.5 9605.0 9608.5 9611.0 9613.0 9633.0 9655.0 $ REMARKS: 9237.5 9253.0 9254.0 9255.0 9253.0 9254.0 9265.0 9263.5 9264.5 9284.5 9290.0 9310.0 9334.5 9397.0 9399.5 9402.0 9402.5 9407.0 9407.5 9411.0 9412.5 9415.5 9417.5 9421.0 9423.5 9445.5 9446.0 9456.0 9456.5 9460.0 9462.5 9492.0 9504.5 9512.0 9512.5 9514.5 9515.0 9515.5 9515.0 9515.5 9516.0 9518.0 9525.0 9528.0 9534.0 9579.5 9584.0 9587.0 9590.0 9594.0 9604.0 9607.0 9609.5 9612.0 9614.5 9633.5 9655.0 9655.0 PASS 4. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH4. OUT / ??MATCH8. OUT $ CN : BP EXPLORATION WN : H- 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 2O * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 38 Tape File Start Depth = 9655.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19046 datums Tape Subfile: 5 224 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background 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 GRCH 2418 $ REMARKS: 1, 2, 3, 4 1, 2, 3, 4 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 4 PASSES $ CN : BP EXPLORATION WN : H- 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log CrV Crv Size Length Typ Typ Cls Mod i GRCH CNAV 68 i GAPI 2 NPHI CNAV 68 i PU-S 3 FUCT CNAV 68 i CPS 4 NUCT CNAV 68 I CPS 4 4 4 4 4 4 4 4 16 35 725 65 1 35 725 65 1 35 725 65 1 35 725 65 1 * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 32 Tape File Start Depth = 9655.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26982 datums Tape Subfile= 6 54 records... Minimum record length= 62 bytes Maximum record length= 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8886.0 2418 8894.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9639.0 9648.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): 18-NOV-93 FSYS REV. J001 VER. 1.1 1226 18-NOV-93 9759.0 9644.0 8900.0 9643.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9800.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : H- 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units i GR 2418 68 1 GAPI 2 CNC 2418 68 i PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 i CPS 5 SSN 2418 68 I CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/MN 8 TTEN 2418 68 i LB 9 TEN 2418 68 i LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPES 0) Total Data Records: 125 1006 BYTES * Tape File Start Depth = 9655.000000 Tape File End Depth = 8879.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 50097 datums Tape Subfile: 7 Minimum record length: Maximum record length: 200 records... 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE UMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8870.0 2418 8878.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9638.0 9647.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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 (EPITHERMALOR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 18-NOV-93 FSYS REV. J001 VER. 1.1 1301 18-NOV-93 9759.0 9644.0 8900.0 9643.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9800.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR 2418 68 I GAPI 2 CNC 2418 68 i PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 i CPS 5 SSN 2418 68 I CPS 6 CCL 2418 68 1 7 SPD 2418 68 i F/MN 8 TTEN 2418 68 i LB 9 TEN 2418 68 i LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 127 Tape File Start Depth = 9654.000000 Tape File End Depth = 8862.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 58673 datums Tape Subfile: 8 Minimum record length: Maximum record length: 202 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8886.0 2418 8894.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM GR CN CCL $ PULSE CODE MOD. GAMMA RAY COMPENSATED NEUTRON CASING COLLAR LOC. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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): STOP DEPTH 9639.0 9648.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 18-NOV-93 FSYS REV. J001 VER. 1.1 1336 18-NOV-93 9759.0 9644.0 8900.0 9643.0 1500.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9800.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 I GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 i PU-L 4 LSN 2418 68 I CPS 5 SSN 2418 68 I CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 i LB 9 TEN 2418 68 i LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 mmmmmmm 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 125 Tape File Start Depth = 9655.000000 Tape File End Depth = 8879.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 81148 datums Tape Subfile: 9 Minimum record length= Maximum record length~ 200 records... 62 bytes 1006 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: -- 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR -- 8886.0 2418 8894.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: .. TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER'S 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): 18-NOV-93 FSYS REV. J001 VER. 1.1 1411 18-NOV-93 9759.0 9644.0 8900.0 9643.0 1500.0 YES THERMAL SANDSTONE 0.00 0.000 0.000 9800.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE STOP DEPTH 9639.0 9648.0 TOOL NUMBER 3507XA 1310XA 2418XA 2323NA TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 4. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR 2418 68 i GAPI 2 CNC 2418 68 i PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 i CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 mmmmmmm 36 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 125 Tape File Start Depth = 9655.000000 Tape File End Depth = 8879.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 89724 datums Tape Subfile: 10 Minimum record length: Maximum record length: 200 records... 62 bytes 1006 bytes Tape Subfile 11 is type: LIS 93/12/o2 01 **** REEL TRAILER **** 93/12/ 4 Ol Tape Subfile: 11 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sat 4 DEC 93 12:28p Elapsed execution time = 42.84 seconds. SYSTEM RETURN CODE = 0 ¢/'7 H- 13 PRUDHOE BAY Run 1: 06- May - 1996 CNIGR Cased Hole 8950 9394 1A~S'I'ElU~ RECEIVED Logging Services Al~a 0~! & 6~ 6ons. 6o~mi~on Anchorsge Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY lINIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING H - 13 500292055900 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 24-MAY-96 6090.05 J. DAHL S. WHIPP 21 liN 13E 1652 1264 82.55 .00 45.35 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 8907.0 47.00 7.000 9800.0 29.00 5.500 8335.0 17.00 4.500 8466.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 i 24 -APR- 81 SWS BASELINE DEPTH 8957.0 8965.0 8972.0 8978.5 8982.0 8986.0 8992.0 9001.0 9011.0 9013.0 9016.0 9020 ..5 9025.0 GRCH 8956.5 8964.5 8971.5 8978.5 8982.0 8986.0 8992.5 9002.0 9012.0 9013.5 9017.0 9021.5 9026.0 EQUIVALENT UNSHIFTED DEPTH 9027.0 9036.5 9049.5 9052.0 9054.5 9060.5 9062.5 9074.0 9102.5 9122.5 9140.5 9146.0 9154.0 9183.5 9195.0 9210.5 9224.0 9233.5 9243.5 9258.5 $ REMARKS: 9027.5 9037.5 9050.0 9052.5 9055.0 9061.0 9063.0 9074.0 9102.5 9122.5 9140.5 9146.0 9154.0 9183.5 9195.0 9211.0 9224.0 9233.0 9243.5 9258.5 CN/GR Cased Hole. TD TAGGED AT 9396'. WELL TEST DATA TEST DATE ELAPSED TIME GROSS FLUID RATE NET OIL RATE NEW WATER RATE FORMATION GAS RATE LIFT GAS RATE CASING PRESSURE TGOR TGLR CHOKE OPENING MANIFOLD pRESSURE MANIFOLD TEMPERATURE WATER CUT 24-APR-96 HOURS 4.0 MBPD 2.19 MBOPD 2.13 MBWPD 0.06 MMSCFD 28.68 SCF/STB 13485 MMSCFD 0.00 PSIG 0 SCF/STB 13485 SCF/BBL 13106 90.0 PSIG 1150 DEGF 143 PCNT 2.8 LOGGED AFTER PUMPING 215 BBLS OF SEAWATER. WELL SHUT-IN AT 20:00 05-MAY-96. FIRST NEUTRON TOOL HAD FAILURE DURING THIRD PASS. PASS NO. 3 LOGGED WITH ANOTHER NEUTRON TOOL (60812). NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER & CASING CORRECTED, SALINITY = 0 PPM. HIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 1 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - .5000 START DEPTH STOP DEPTH 8950.0 9385.0 8950.0 9394.0 PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 (MEASURED DEPTH) BASELINE DEPTH NPHI 8957.0 8956.5 8965.0 8964.5 8972.0 8971.5 8978.5 8978.5 8982.0 8982.0 8986.0 8986.0 8990.0 8989.0 8997.0 8997.0 9001.0 9002.0 9011.0 9012.0 9013.0 9013.5 9015.0 9015.5 9018.5 9018.5 9020.5 9021.5 9024.0 9026.0 9027.5 9028.5 9036.5 9038.0 9040.0 9040.5 9045.5 9045.5 9049.5 9050.0 9052.5 9052.5 9054.5 9055.0 9060.5 9061.0 9062.5 9063.0 9074.0 9074.0 9102.5 9102.5 9122.5 9122.5 9141.0 9140.0 9143.0 9142.5 9146.0 9146.0 9154.0 9154.0 9183.5 9182.5 9188.0 9187.5 9194.5 9193.5 9217.0 9216.0 9224.0 9224.0 9233.5 9233.0 9243.0 9242.5 9259.0 9258.5 in separate files. EQUIVALENT UNSHIFTED DEPTH 9280.5 9315.0 $ REMARKS: 9281.0 9315.0 PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB * DATA RECORD (TYPE# 0 ) Total Data Records: 24 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 4 4 42 995 99 1 20 1014 BYTES * Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5875 datums Tape Subfile: 2 222 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8950.0 2418 8950.0 $ CURVESHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 8955.0 8954.5 8973.0 8973.0 8976.0 8979.0 8980.0 8981.0 8982.0 8982.5 8984.5 8985.5 8986.0 8988.0 8992.5 8992.5 8993.0 8993.5 8994.0 8995.0 8995.5 9001.5 9002.5 9003.5 9004.5 9004.0 9004.5 9005.0 9006.0 9006.5 9006.5 9007.5 9020.0 9021.0 9024.5 9025.0 9031.5 9032.0 9033.5 9034.0 9034.0 9035.0 9038.0 9039.0 9040.0 9040.0 9040.5 9041.0 9047.0 9048.0 9053.0 9053.5 9062.0 for each pass in separate files. STOP DEPTH 9385.0 9394.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8954.5 8976.0 8978.5 8980.0 8981.0 8981.5 8982.5 8984.5 8985.0 8985.5 8987.0 8993.0 9004.5 9032.0 9033.0 9039.0 9041.5 9047.5 9048.0 9053.0 9054.0 9062.5 9063.0 9065.0 9069.0 9092.0 9092.5 9096.0 9107.0 9138.5 9139.5 9140.0 9144.5 9174.0 9175.0 9177.0 9178.0 9185.0 9186.0 9186.5 9188.5 9208.0 9222.5 9223.0 9226.5 9227.5 9264.0 9276.0 9345.5 $ REMARKS: 9063.0 9065.5 9069.0 9092.5 9093.0 9096.0 9107.0 9138.5 9139.0 9139.5 9144.5 9144.0 9173.5 9174.0 9177.0 9176.0 9177.5 9185.0 9185.5 9186.5 9187.5 9207.0 9222.5 9223.5 9226.5 9227.0 9263.5 9276.5 9345.5 PASS 2. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 1 CPS TENS 2418 68 1 LB Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 24 1014 BYTES * 20 Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacin9 = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5875 datums Tape Subfile: 3 122 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8950.0 9383.0 8950.0 9392.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 8955.0 8954.5 8958.0 8958.0 8965.0 8965.0 8974.0 8974.0 8982.5 8982.5 8984.0 8984.0 8984.5 8985.0 8986.5 8986.5 8988.0 8987.5 8991.5 8991.0 8992.0 8992.0 8994.0 8994.0 8995.0 8995.5 9002.5 9003.5 9003.0 9004.0 9008.5 9009.0 9016.0 9017.0 9018.0 9018.5 9020.0 9021.0 9020.5 9022.5 9024.0 9027.0 9027.5 9036.5 9037.5 9037.0 9038.5 9041.5 9042.0 9047.5 9048.5 9048.5 9049.0 9050.5 9051.0 9051.5 9051.5 9052.0 9052.5 9062.0 9062.5 9066.0 9066.5 9069.5 9069.5 9096.0 9096.0 9107.0 9107.0 9171.5 9171.0 9190.5 9190.0 9192.5 9191.5 EQUIVALENT UNSHIFTED DEPTH NPHI 8954.5 9198.5 9210.0 9224.0 9225.0 9226.5 9229.5 9232.0 9253.0 9255.5 9256.0 9260.0 9261.0 9263.5 9264.0 9276.0 9276.5 9280.0 9296.0 9297.0 9318.5 9332.5 9350.0 9354.0 9361.5 93 74.0 $ REMARKS: 9225.0 9252.5 9255.0 9256.0 9263.5 9318.5 9361.5 9197.5 9209.0 9224.5 9226.5 9229.5 9231.5 9259.5 9260.0 9263.5 9276.0 9277.0 9280.5 9296.0 9297.0 9332.5 9351.5 9355.5 9374.5 PASS 3. FUCT, N-OCT, & TENS WERE SHIFTED WITH NPHI~ / ? ?MATCH3A. OUT / ? ?MATCH3 B. OUT $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS N-OCT 2418 68 1 CPS TENS 2418 68 1 LB Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 4 42 995 99 1 20 * DATA RECORD (TYPE# 0) Total Data Records: 24 1014 BYTES * Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacin9 = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decodin9 summary: Rep Code: 68 11750 datums Tape Subfile: 4 120 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log CrV Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 1 PU-S 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 1 CPS 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 4 4 38 995 99 1 16 * DATA RECORD (TYPE# 0 ) 1006 BYTES * Total Data Records: 20 Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10771 datums Tape Subfile: 5 43 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NI3MBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 8945.0 2418 8947.0 $ LOG HEADER DATA STOP DEPTH 9401.0 9405.0 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 SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE COND IT IONS 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): 06-MAY-96 ECLIPSE 2.2 1531 06-MAY-96 9759.0 9396.0 8950.0 9394.0 1500.0 YES TOOL NUMBER 3913XA 3946XA 8250EA/8248EA 8262XA 2418XA .000 9800.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 .000 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): 12 FAR COUNT RATE HIGH SCALE (CPS): 1612 NEAR COUNT RATE LOW SCALE (CPS): 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN): .0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPE# 0 ) 1006 BYTES * Total Data Records: 79 Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacing = 0.250000 Tape File,Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31321 datums Tape Subfile: 6 Minimum record length: Maximum record length: 155 records... 62 bytes 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 8945.0 2418 8945.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9401.0 9405.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER' S 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): 06-MAY-96 ECLIPSE 2.2 1553 06-MAY-96 9759.0 9396.0 8950.0 9394.0 1500.0 YES TOOL NUMBER 3913XA 3946XA 8250EA/8248EA 8262XA 2418XA .000 9800.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 12 FAR COUNT RATE HIGH SCALE (CPS): 1612 NEAR COUNT RATE LOW SCALE (CPS): 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN): .0 REMARKS: PASS 2. $ CN : BP EXPLORATION WN : H- 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 79 Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 30342 datums Tape Subfile: 7 Minimum record length: Maximum record length: 155 records... 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 8945.0 2418 8945.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SBAR PCM GR CN $ SWIVEL SUB SINKER BAR PULSE CODE MODULATOR GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER' S CAS ING DEPTH (FT): BOREHOLE COND IT IONS 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 DENS I TY: HOLE CORRECTION (IN): STOP DEPTH 9401.0 9405.0 · 06-MAY- 96 ECLIPSE 2.2 1759 06-MAY- 96 9759.0 9396.0 8950.0 9394.0 1500.0 YES TOOL NUMBER 3913XA 3946XA 8250EA/8248EA 8262XA 2418XA ..000 9800.0 .0 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 THERMAL SANDSTONE .00 .000 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): 12 FAR COUNT RATE HIGH SCALE (CPS): 1612 NEAR COUNT RATE LOW SCALE (CPS) : 800 NEAR COUNT RATE HIGH SCALE (CPS): 16800 TOOL STANDOFF (IN): .0 REMARKS: PASS 3. $ CN : BP EXPLORATION WN : H - 13 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 42 310 01 1 4 4 42 995 99 1 4 4 42 890 01 1 4 4 42 334 31 1 4 4 42 334 30 1 4 4 42 150 01 1 4 4 42 636 99 1 4 4 42 635 99 1 4 4 42 635 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 79 Tape File Start Depth = 9413.000000 Tape File End Depth = 8924.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 50892 datums Tape Subfile: 8 Minimum record length: Maximum record length: 155 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS 96/ 5/24 01 **** REEL TRAILER **** 96/ 5/28 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 28 MAY 96 2:0la Elapsed execution time = 2.80 seconds. SYSTEM RETURN CODE = 0 ~mmmmmmmmmmmmmmm~mmmm~ , .... SCHLUMBERGER .... . LiS LVP 009.;k02 V£BI~'~¢A'I'iON DIST~BG Pi~<E ~, REEL HEADER #~ SERVICE NAME :SERVIC DATE :81/05/15 ORIGIN : REEL NAME :REEL ID CONTINUATION # PREVIOUS REEL : COMMENTS :REEL COMMENTS ~ TAPE HEADER SERVICE NAME :SERVIC DATE :81105115 TAPE NAME CONTINUatION # :01 PREVIOUS TA~ : COMMENTS :I%PE ~D~MENTS ** FILE HEADER ** f" I LE NAME .'SERVIG.O£ 1 SERVICE N AM '~] : VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FI[Jr ** INFORMATION RECORDS ** .MNEM CONTENTS CN : SOfI[ ALASKA ~ETROLE WN : FN ': PRUDFOE BAY R~NG: R~N~E TOWN: TOWNSHIP SECT: SECTION COUN: NOR~ S~[PE 6TAT: ALASKA CTRY: USA MNEM CONTENTS P {E~': CNbFDCF RECO}D T~PE 047 *~ RECORD TYPE 047 #* UNIT TYPE CATE SIZE CODE 000 000 020 065 000 000 005 065 000 000 015 065 000 000 005 065 000 000 008 065 000 000 007 065 000 000 015 065 000 000 010 065 000 000 005 065 UNIT IYPE CATE SIZE CODE 000 000 007 065 LVP 009,H02 VERIFICATION LISTING RECORD TYPE 047 *~ ** COMMENTS *# DIL RUN # 1, LOGGED 05-MAY-81 CASING DRILLER 9,625 IN. @ 8905 FT. CASING LOGGER = .... 8896 FF. BiT SIZE [.'LUID IN THfi HOL, E :: XC POLYMER DENS : 9.60 VISC : 38.00 EH : 9.0 FLUID bOGS : 5.8 ML RM @ MEAS TEMP. : 4,47 @ 56 F. RMF " " : 5,24 ~ 56 F. RMC " " : 3,35 ~ 56 F. RM @ BHT : 1.39 @ 206 F. POROSITY MATRIX : LI~ESTONf PAGE ~* DATA FORMAl RECORD ~ ENTRY BLOCKS TYPf SIZE REPR CODE ENTRY 4 I 66 1 8 4 73 6 9 4 65 iNCH 0 1 66 0 DATUM S~RC. If!ICA~.ON .BLOCKS MNEM SERVICE SERVICE UNIT AP1, AP1 .~Pi API FILE SIZE PROCESS SAMPLE: REPR iD ORDER # LOG ~%PE CLASf MOD NO. 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DEPT 8900,000 GR ILD 1,448 CALk 17,000 RHOB NCNb 1703,000 NRA~ 84 -2 2 3 DEPT 8800,000 GR ILD -999,250 SP CALl -999,250 RHOB NCNL -999,250 NRA2 t.~5 -999 -999 -999 DEPT 87(0.000 GR ILD -999,250 SP CALl -999,250 RHOB NCNb -999,250 NRA~ -999 -999 -999 DEPT 86(0.000 GR ILD -999,250 SP CALl -999,250 RHOB NCNb -999,250 NRA% -999 -999 -999 DEPT 8500,000 GR 1LO -999,250 SP CALl -999,250 RHOB NCNL -999.250 NRA2 -999 -999 -999 DEPT 8400,000 GR ILD -999,250 SP CAbI -999,250 RHOB NCNb -999,250 NRA2 {47 -999 -999 -999 D~PT 83(0,000 GR iLD -999,250 SP CALl -999,250 RHOB NCNb -999,250 NRA3 -999 -999 -999 DEPT 82(0,000 GR £LD -999,250 SP CAbI -999,250 RHOB NCNb -999,250 NRA~ -999 -999 -999 ,141 .688 .312 ,471 .406 .155 .219 .395 .063 .719 .561 .853 .250 .719 ,3~5 ,995 ,063 .250 .250 .938 ,250 .350 ,250 .969 ,250 .250 .500 .250 ,250 .375 .250 .3fO .250 .438 .250 ,250 ,875 .250 ,:350 ,250 SFLU GR DRHO NPHI SFLU G~ DRHO NPHI .$FLU DRHO NPHI SfLU GB DRHO NPMI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI $P'LU GR DRHO NPHI SFLU GR DRHO NPHI $FLU GR DRBO NPH! SFLU DRHO NPHI 49.406 20.891 0.030 21.045 32.656 27.328 0.003 19.678 15,172 51,563 0.035 10.352 3.5~5 81,188 3 648 -999,250 -999.250 -999,350 -999,250 -999,250 -999,250 -999.2~0 -999'250 -999,250 -999,250 -999,3~0 -99~.250 -999,250 -999,250 -9~9,250 -999,250 -999,250 -999 250 -999.250 ~999,250 999.250 -999,350 -999,250 -999,250 -999,250 -999.350 -999.250 ~IL~ DT FCNL GR ILM DT FCNL GR DT f'CNL GR ILM DT FCNL GR ILM DT FCNL GR DT FCNL GR DT FCNL GR DT FCNL GR ILM DT FCNL GR DT FCNL GR ILM DT FCNL GR PAGE 29,688 89,750 1340.000 26.984 22.094 96,000 13~3.000 22,578 15.5~3 71.188 2228.000 65,00O 1.260 I09,563 3~6.750 81,938 20C0,0(0 -999.250 -9c. 9,250 -999,250 20C0.0(0 -999.250 -9~9.250 -999.250 20¢0-0(0 -999.250 -9~9.250 -999.250 20C0.0(0 -999,250 -9c. 9.250 -999.250 ~OC~,O(O 99 ,250 -9~9.250 -999.250 20C0.0(0 -999 250 -9~9;250 -999.250 .20C0.0C0 999,250 -9S9,250 -999.250 bVP 009.M02 VERifICATION LISTING PAGE 5 OEPT 8100,000 GR 3 lbo -999.250 SP -99 CALl -999,250 RHOB -99 NCNb -999,250 NRAT -99 DbPC 8000,000 GR. 4 ILO -999,250 SP -99 CALl -999.250 RHOB -99 NCNb -999,250 NRA~ -99 OEPT 7900,000 GR 5 iLO -999,250 SP -99 CALl -999,250 RHOB -99 NCNb -999,250 NR~I -99 O~PT 7800,900 GR 6 lbo -999,250 SP -99 CALf -999,250 RHGB -99 NCNb -999,250 NRAI -99 OEPr 7700,000 GR. 5 lbo -999,250 SP -99 CALl -999,250 RHOS -99 NCNb -999,250 NRA~ -99 OEPT 7600,000 GR 5 ILD -999,250 8P -99 CALl -999,250 RHOB -99 NCNb -999,250 NR~ -99 DEPT 7500,000 GR 7 IbD -999,250 SP -99 CALl -999,250 RHOB -99 NCNb -999,250 NRAT -99 DEFt 7400,000 GR 10 ibD -999,250 $P -99 CALl -999,250 RH08 -99 NCNb -999,250 NRA~ -99 DEPT 7300,000 GR 7 ILD -999,250 $P -99 CALl -999,250 RHOB -99 NCNb -999,250 NR~ -99 DEPT 7~00.000 GR 7 IbD -999,250 $~ -99 CaLl -999,250 RHO8 -99 N'CNL -999,250 NR~ -99 D~PT 7100.000 GR 9 ILD -999.250 SP -99 CALl -999.250 RHOB -99 NCNb -999,250 NR~I -99 9,563 9,250 9.25O 9,250 6.250 9.250 9.250 9.250 8,375 9.25O 9.250 9,~50 9.063 9.250 9.250 9.250 6.938 9.250 9.250' 9.250 7.46~ 9.250 9.250 9.350 9.$88 9.250 9.250 9.250 0,250 9,250 9.250 9.250 1.B13 9.2~0 9.250 9.250 5 375 9.250 9,250 6,375 9.350 9.250 9,250 SFLU GR DRHO NPHi GR DBHO NPHI 6FLU GR DRHO NPHI SFLU GR DRHO NPHI GR DRHO NPHI SFLU GR DRMO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPH1 GR DRHO NPHI MFLU GR DRHO NPH1 -999,250 -999 250 -999~250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99).250 -9~j9. 250 -999.250 -999,250 -999 250 -999:250 -999.250 2999 250 -999.250 -999.250 -999 250 -959.250 ~999.250 999 250 -999~250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -99~ 250 -9c. 9.250 2999,250 -99 50 -9c~9.250 -999,250 -9§9,250 -99~.250 -9~9.250 ILM DT FCNL GR IbM DT FCNL GR ILM ET F2NL IbM DT FCNL GR IbM DT FCNL GR ET F2NL GR IbM DT FCNL GR ILM DT FCNL G~ ILM ~T FCNL fir ILM FCNL ILM ET IFCNL GR 2000.000 -999.250 -999.250 -999.25O ~000.000 999'250 -999,250 -999.250 2000.000 -9~9.250 -~99,250 -9~9.250 2000.000 -999.250 -999.250 -999.250 2000.000 -999.250 -999,250 -999,250 2000.000 -9c.~,250 -~)9 , 250 -9~. 9.250 000.000 999.250 -999.250 -999.250 2000.000 -999.250 -999.250 -999.250 2000.000 -9S9.250 -999.250 -9S9.250 2000 O00 -9~9!250 -999 250 -9~9,250 300 000 -~)99.250 -9(.9.25O LVP DLPT CALl NCNL DEPT ILD CALl NCNL DEPT ILD CALl NCNL DEPT ILD CAbI NCNL DEPT ILD CALl NCNL DEPT ILD CALl NCNL DEPT ILD CALl NCNL DEPT iLD CALl NCNL DEPT ILD CALl NCNL DEPT 1LD CALl NCNL DEPT ILD CALl NCNL 009.H02 VER IflCATION 7000.000 GR -999,~50 SPI -999, 50 RHOB -999,250 NRAI 6900.000 GR -999.250 SP -999.250 RHOB -999.250 NRA~ ,~800.000 GR -999.250 -999.250 RHOB -999.250 NRA2 6700.000 GR -999.250 SP -999.250 RHOB -999.250 NRA2 6600.000 GR -999.250 SP -999.250 RHUB -999.250 NRAT ,~500.000 GR -999.250 SP -999.250 RHOB -999.250 NRAI 64(0.0(0 GR -999.250 SP -999.250 RHO8 -999.250 NRA2 6300.000 GR -999.250 SP -999.250 RHOB -999.250 NRA~ 6200.000 GR -999.250 SP -999.250 RHOB -999.250 NRA~ 6100.000 GR -999.250 SP -999.250 RHO8 -999.250 NRAI 6000.000 GR -999.250 SP -999.250 RHOB -999.250 NRA2 LI6TINS 92. -999. -999. -999. -999. -999, -999. -999. -999. -999. 34. -999. -999. -999. '.999 999; '999. 4}. -999. ,999. -999. .73. -999. -999. -999. t-~7. -999. 999. i999. {40. -999. -999. -999. t.~5. -999. -999. -999. t<5. -999. -999. -999. 625 250 25O 250 750 250 250 250 9{6 250 250 250 312 25O 25O 250 125 25O 25O 969 25O 2~0 25O 375 250 250 469 25O 2EO 25O 250 250 250 25O 50O 25O 25O 4C6 25O 250 250 SFLU GR DRBO NPHI SFLU GP DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GP DRHO NPHI SFLU GR D~HO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI GR DRHO NPHI SFLU GR DRHO NFHI -9S9.250 :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 -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 -999.250 -999.250 :~99,250 99,250 -999.250 -999.250 -.999 250 -999.250 -999 250 -999:250 -999.250 -999.250 -999.250 -999,250 -999.250 ~IL~, Dr fCNL GR ILM DT FCNL GR IL~ DT FCNL GR DT FCNL GR DT FCNL GR ILM DT FCNL GR ILM DT FCNL GR DT FCNL GR DT -FCNL GR ILM DT FCNL GR ILM DT FCNL GR PAGE 2000.000 -999.250 -9~9.250 -999.250 20£0.0(0 -999.250 -9~9.250 -999.250 20(0.000 -999.250 -9c. 9.250 -999.250 20C0.0(0 -999.250 -9c. 9.250 -999.250 20C0.0( 0 -999.250 -9c. 9.250 -999.250 ~0(0.000 c. 9.250 -999.250 2000.0C0 -999.250 -9~9.250 -999.250 20C0.0(0 -999 250 -919i250 -999 250 20(10.0(0 -999,250 -9(.~.250 -99 .250 20C0.0(0 -99 -~99.250 20C0.0¢0 -999.250 -9~.9.250 -999.250 LVP 009.;k02 VI~FIFI, CATION IJ]$T]~AG PA'(£ 7 DEPr, 5900.000 GR ILD -999.350 SP CALl -999.250 RHOB NCNb -999.250 NRAI DEPT 5800.000 GR ILD -999.250 SP CALl -999.250 RHOB NCNb -999.250 NRAI DEPT 5700.000 GR ILD -999.250 CALl -999.250 NCNb -999.250 DEPT 5500.000 GR ILD -999.250 CALl -999.250 RHOB NCNb -999.250 DEPT 5500.000 GR ILD -999.250 SP CALl -999.250 RHOB NCNb -999.250 NR~I DEPT 5300.000 GR ILD -999.250 SP CALl -999.250 RHOB NCNb -999,250 NRgT DEPT 5300.000 GR LLD -999.250 SP CALl -999.250 RHOB NCNb -999.250 NR~ DEPT 5200.000 GR ILD -999.250 SP CALl -999.250 RH00 NCNb -999.250 NR~2 DEPT 5100.000 GR ILD -999.250 SP CALI -999.250 RHOB NCNb -999.250 DEPT 5000.000 GR ILD -999.250 CALl -999.250 RHOB NCNb -999.250 NR~T DEPT 4900.000 GR ILD -999.250 SP CALl -999.250 RH00 ~05b -999.250 I~RAI 35.750 -999.250 -999.250 -999.250 25.484 -999.~50 -999.250 -999.250 43.750 -999.350 -999.250 -999.250 35.813 -999,350 -999.250 -999.250 30.750 -999.350 -999.250 -999.250 34.281 -999.350 -999.250 -999.250 26 3.56 -999.250 -999.250 35.375 -999.250 -999.250 -999.250 33.625 -999 350 -999:250 -999.250 52 688 -999:350 -999.250 -999.250 46,.375 -999.350 -999.250 -999.250 SFLU GR NPBI SFLU DRHO NPHI SFLU GR D~HO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DBHO NPHI SFLU G~ DRHO NPHI S~'LU GR DBHO NPHI SFLU GR D~HO NPHI SFLU DRHO NPHI $FLU GR DRHO NPH! -999.250 99.250 99.250 -99) 50 -999.250 -999.250 -99~.250 -999.250 -99~.250 -9§9.250 -999.250 -999.250 -99~.250 -9S9.250 -999.250 -999.250 -999.250 -9S9.250 -999.~50 -999. 50 -99~.250 -9S9.250 -999 50 -99;). 250 -9c. 9.250 -999.250 -999.250 -99~.250 -9S9.250 '999.250 -999.250 -99~.250 -9S9.250 ~999.250 .'999'250 959.250 -999.250 -999.250 -99~.250 -999.250 DT FCNL G~ ET FCNL GR ET F;NL IbM F."NL DT FCNL GR ILM F".NL GR ET FCNL GR FCNL FCNL GR ILM ET F-"NL DT FCNL GR 2000.000 -999.250 -999.250 -999.250 2000 000 -9~9;250 -999.250 -999.250 2000.000 -9~9.250 -~99.250 -9~9.250 2300.000 -9~9.250 -)99.250 -9(.9.250 2000.000 29S9.250 ~)99.250 -9~9.250 2000.000 -9~9.250 -)99.250 -9~9.250 2000.000 9(.9.25O 2000.003 ~99.250 -9(. 9. 250 2000.000 9(.9.250 -'999.250 -9(. 9.250 2000.000 -9~9.250 -~)99.250 -9(.9.250 2000.2000 -9S 9, 50 -g99.250 -999.250 L~P DEPT IbD CALl NCNb DEPT lbD CALI NCNb ILD CAbI NCNb DEPT ILD CALI NCNb DEPT ILD CALl NCNb DEPT CALl NCNb DEPT CAb1 NCNb DEPT ILO CALI NCNb DEPT ILO CALI NCNb DEPT CAb1 NCNb DEPT CAbI 'NCNb 009.H02 VERIFICATION 4B(O.O(O GR -999.250 SP -999.250 RHOB -999.250 NRA~ .4700.000 GR -999.250 SP -999.250 RHOB -999.250 NRA1 4600.000 GR -999.250 -999.250 RHOB -999.250 NRA~ 4500.000 GR -999.250 -999,250 RHOB -999,250 NRA~' 4400.000 GR -999.250 -999.250 RHOB -999.250 NRAI 4300.000 GR -999.250 SP -999.250 RHOB -999.250 NRAI 4200.000 GR -999.250 SP -999.250 RHOB -999.250 NRAI 4100.000 GR -999.250 SP -999,250 RHOB =999.250 NRA~ 4000.000 GR -999.250 -999,250 RHO8 -999.250 NRA~ ~3900.000 GR -999.250 SP -999.250 RHOB -999.250 NRA~ !3800.000 GR -999,250 $P -999.250 RHOB -999.250 NRA~ LI$3'ING ;44. -999. -999. -999. 28. -999. -999. -999. [59. -999. -999. -999. 38. -999. 999 35. 99. 999. ~99. -999. -999. -999. 18. -999. -999. -999. 38. -999. -999. -999. -999 -999. ~. 1-. -999. -999. -999. 48. -999. -999. -999. 219 250 250 250 875 25O 250 25O 719 25O 250 250 656 25O 3."O 250 063 25O 250 25O 969 25O 250 422 25O 250 344 25O 250 719 25O 250 875 25O 250 625 25O 250 250 SFLU GR DRBO NPMI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFL{3 GR DRHO NPf~I SFLU GR DRBO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU GR D'RHU NPH! SFLU GR DRHO NPHI -999.250 -999.250 -999.250 -999.250 999, 2'~ 0 -99},250 -999,250 -99).250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 99,250 9~,250 -999.250 -999 250 -99{).250 -999 250 -9991250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.25O -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 DT f'CNL GR IL~ DT fCNI, GR IL~ DT FCNL GR ILM DT FCNL GR DT FCNL GM DT F'CNL GR IbM DT FCNL GR ILM DT FCNL GR ILM DT FCNL GR DT FCNL GR IbM DT fCNL GR PAGE 2000.000 .250 -999.250 20(0,000 -999 250 -~99.250 20C0,0(0 -999,250 -9~9.250 -~99,250 20C0,0(0 -999.250 29;9.250 999,250 20(0,0(0 -999,250 -9~9,250 -999.250 20C0,0(0 -999 250 -999.250 20C0,0(0 -999,250 -9c. 9,250 -999.250 20C0.0(0 -999.250 ~,9S9.250 999~250 20C0.0(0 -999,250 -9~.9 50 20C0,0(0 -999,250 -9S9,250 -999,250 20(:0.0(0 -999'250 -9.c9.250 -999.250 LVP 00S.H02 VER~ICATION LISTING PAGE 9 D~PT 3700.000 GR iLL -999.250 SP CALl -999.250 RHOB NCNb -999.250 NRAI DEPT ]600.000 GR ILL -999.250 SP CALl -999.250 RHOB NCNb -999.250 NR~T DEPT 3500.000 GR IbD -999,250 SP CALl -999.250 RHOB NCNb -999.250 NB~T D~PT 3400.~00 GR ILL -999.250 CALl -999.250 RHUB NCNb -999,250 NR~T DEPT 3~00.000 GR ILL -999.250 BP CALl -999.250 RHOB NCNb -999.250 NR~T DEPT 3200.000 GR ILD -999.250 SP CALl -999.250 RHOB NCNb -999.250 DEPT 3[00.000 GR IbD -999.250 SP CALl -999.250 RHOB NCNb -999.250 NR~T DEPT 3000.000 GR ILD -999.250 SP CALl -999,250 RHOB NCNb -999.250 NB~T OEPT 2900.000 GR ILO -999.250 SP CALl -999.250 RHOB NCNb -999,250 NB~T DEPT 2800.000 GR ILL -999.250 SP CALl -999,250 RHOB NCNb -999,250 NR~T D~PT 2700.000 GR iLL -999,250 SP CALl -999.250 RH00 NCNL -999.250 NR~T 34.656 -999.250 -999.250 -999.250 42.000 -999,250 -999.250 -999.250 39.i25 -999.2~0 -999,250 -999.250 31.094 -999.250 -999,250 -999,250 34.i25 -999.250 -999,250 -999.250 51 063 -999.'27.0 -999.250 -999.250 40,625 -999.2~0 -999.250 -999.250 43.406 -999.2~0 -999.250 -999.250 51.094 -999.2~0 -999.250 -999.250 32.500 -999.250 -999.250 -999.250 23.625 -999,250 -999.250 -999.25O SFLU G~ DRHO NPHI SFLU GR DRHO NPHI SFLU GR D~HO NP~I SFLU GR DRHO NPHI SFLU GR DBHO NPBI $FLU GR DRHO NPHI SFLU GB DBHO NPHI SFLU GR DRHO NPHI SFLU GR DRHO NPHI SFLU DRHO NPHI SFLU DBHO NPHI -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 -999 250 -9~9~250 -999.250 ,-999, 5 999,22500 -9~9.250 -999.250 -999.250 -999 250 -999,250 2999,250 999,250 -9c39. 250 -999.250 -999.250 -999.250 -9~9.250 -999 ,250 -999~250 -999,250 -9§9.250 29991250 999 250 -99'9 250 -9~9 250 -999. 250 .-9cj9o250 999,250 -9~9o250 2999.250 999.250 -999.250 -9~9.250 -999.250 -999,250 -999.250 -9~9.250 DT FCNL GR ILN ET F2NL ET F2NL DT FCNL F2NL ET F~NL "L C-R FCNL ET F2NL fir FCNL ILM DT FCNL 2000.000 -999 250 -999~250 -999.250 000.000 9~9.250 -999.250 -9~9.250 2300.000 -9(. 9.250 -999.250 -9(. 9.250 2000.000 -999.250 -999.250 -9~9.250 2000. 000 -9c. 9.250 -999,250 -9c. 9.250 2000.000 -9~9,250 -999.250 -9~9.250 2000.000 -9~9.250 -999.250 -9c. 9.250 2000.000 -9c. 9.250 -999.250 -9(. 9.250 2000.000 -9~9.250 -999.250 -9~9.250 2000.000 -9c. 9.250 -999.250 -9(~9.250 2000.000 -9c. 9.250 -999.250 -9(. 9.250 L-VP 009,N02 VERIFICATION LISTINg,' DEFT 2600.000 GR 1LD -999.250 SP CALl -999.250 RHOB NCNB -999.250 NRA2 DEPT 2500.000 GR ILD -999.250 SP CALl -999.250 RHOB NCNL -999.250 NRA~ DEPT 2498.0(0 GR IBD -999.250 CALl -999.250 NCNB -999.250 NRAI 19.859 -999.250 -999.250 -999,250 23 219 -999~250 -999.2~0 -999.250 .~0.703 -999.25O -999.2.~0 -999.250 :~FLU GR DRRO NPBI SFLU GR DRHO NP~I DRHO NPHI ~"I LE NAME :$ERVlC.O01 ~ERV1CE NAME V '~RSION # : DATE : M~';KIMUM LEN3~'H : 1024 FILE TYPE NEXT F'IBE N.~ME : ## TAPE TRAiBER SERVICE NAME :SERVIC DATE :81/05/1-5 TAPE NAME CONTINUATION ~ 501 NEXT T~PE NA~E COMMENTS :T~P~ ~D~MENTS ** REEL TRILLER SERVI2E NAMgl :SERV1C DATE :81/Q5/15 OR1GIN : REEL NAME :REEL CONTINUATION # :01 NEXT REEL NA~E : COMMENTS :R~EL ~DMMENTS -999.250 0 999. z 5O -999.250 ~9~9.250 99B.250 -999.250 -99~.250 -999.250 -999.250 -999.250 -99).250 ILM DT FCNL GR DT FCNL GR DT ~CNL PAGE 10 2000.000 -999.250 -999.250 -999.250 ~000 000 )99 250 9~9 250 -)99.250 2000.000 -999.250 -9~9.250 -B99.250 DATE :~2/06/29 REEL ~,A~E :PEEL ID P~Ev I[~13S RE~'I, ** TAPE HEAO_~:~, ** DATE :82/06/29 O~JG~' :1070 TAPE ~; A ~,~ E] : PR~SV!ObS 'r,6PE : ** FILE ~EAD~R ** FILE ~: A ~E :SERVIC.O01 SERVICE NA~E : DATE : ~XI~I~-' bF~,:~T~-~ : lO2~ FILE T~'PE : Rf<CORDS ** Ca~ : SO}-!] 0 ALASK~ w?,~ : H-1 3 F~ : PPUDHOE BAY R~NG: i3~7 TO~ ~ · 1 1 SECT: 2l COU~,~: MOPTH SL(.~PE STAT: ALASKA CTRY: {~.S,A . ~ ~.', E ~..~,. CO~ PFTROLEU~ LVP Ot.O.H01 YERI~'ICATIO~'~ LIST~tN~ WELL FIELD STATF ~.~:. _ . 8 O O 0 F ~, ' .... 1 ~ 3/a I~. 0 FT. ' ~'r[~ :~'~ :"2680 F~. ~:._:,.~::.:: .._.:~.:-c:::..,~ .:.,..._:.~ ::. ,: ~:: . 7 IN 8411 5,5 la. 0 FT. FULL . .::' BOTTO~ QEPTH TOP DEPTH CAS!~'~ CA$Zkg LINEr Tt36I~G FLUID TYPE FLUID jrJP~ Y:U~.,R.E? aT ACC: ~0707,65223 RUN al, DATF LOGO ~ JUN a9 ** DATA DATU~ SPEC~ FICATION ~.~E,v, SFRVTCF SEDVICE DJ:PT fT SIGf< 601 Cd T~AT ~01 G? ~01 GAPI 8~C~ &O1 CPS NTDT ~', 01 CPS FTDT [~ 0 J C~S ~SF SOl SIG}.' $02 CU FSIG So2 T~T GR ~02 GAPi B~C~~ ~02 CPS FBAC ~02 CPS NT~T 202 CPS FTb~' &02 CPS S I G ~'~ S 03 Cd FSI~ f O] TRA~ GR Ch3 G~PI BACh f:,o3 CPS F~AC 5a3 CPS NT!jT ~)3 CPS FTDT 503 CPS GSF SIG~ S04 CU FSIG 504 TDAT GR BO4 GAPI B~CK ~:o4 CPS F8AC ~04 CPS NTDT S04 FTDT 804 CPS I 6~ I 68 1 68 OE.P:.f 9779,5000 ~-SIGa : ~g.99,~2:500 -FSIG .-99:9.250.0. ~AT G~- '9o9; 2SOe ~:~ aC~ ~999 :PSO0 P"~'A C a9'99 ;250'0 NTDT F~AC -099,2509 ~,~TDi' .999,2500 FTDT .-999.2500 .GaF ~AC~. ~99,2500 F~AC -999,250{~ ~TD!::: --9:99,2bg0. FTDT GAP -999~'250o Slav -gq~; ?"Soo PSIs7' ~ ~g9;2500 TRAT 2, 5,.. .'9 :3).~ ~..)9 .... B~A'-~;. ...... 4~,~99 .:5:(~( f::.~A~ C - . .:-:.-0.t, ~2,-.:.)-:5.~ f~;~.D F~:aC 0;00~;0 ?~TDT c', O~Oc ~-TDT 199.90'O'n GSF _. $1(;~~ 29,4336 F~IG 22 ~Bg2O_ ~ ~.RAI' 2,:3692 GR:: 61 ~5 ~'~ ' / ~q ,r,~ ~, ,, {:,~,,~ -<~r,' ~ OOO~ B~DT 199 ,.,e~t F * .,, ........) B .... , ..................... ~ , ....... · Gg 58. t953~ [*~C~: 4'09; 7"~;00 F~'AC -'0-.'0~69 ~:TDT 0. -999.2500 -999.2500 -999.2500 -999.2500 999.2500 999.2500 999. 500 999,2500 ~99.2500 -999.2500 14-26 0000 9687 0042 1055 7500 0020 9687 9000 8506 0000 G~ ?5.~OOO F~AC~t 409,7S6~} P?AC -0,125o S~TDT F?[~T 199~900.0 68F fi~O.o-20 · a:!.G~,s 18,4800 ESlG 1.80oo O,0000 9250 :oooo 1g,3516 409~6975 ' a ~''" :I ' ~' ~' ~ . ~ ..... /' ~ ~'' : ~'" ~ c ~ "-' "~ q . , r- . ~ ~, ~r~ ~ '.'4:- -" A 'f~'~ r, ~'~ "~a:~ - ~"~ l~/'~ ,< D~:~'T¢~ - ' -~ ',.~ ) - · . ,* . . bVP OIO,HO] VERIFICA~iO~ FTU'T I99.o000 TRAT 2.8689 GR FSIG 16.~100 TRAY F~AC O. OOaO MTDT SIG,, 17 ~900 FSIG B~CM 4q9.7500 FBAC GSF ~,0020 SIG~ GR 4_. 7500 FTD1 ~1 c~9. 9000 GSF OEPT 9000 00O0 SIGn GP 74~6000 FTOT 199,9000 GSa' NTDT 0,0000 F$IG 18,940o F~AC 0.0000 NTDT SIG~ 1~.~36Q FSIC BACK 499,7095 FBAC GSF 4.0010 GR 3~ 6191, BACK FTDT 199:900o DCPT 0300.0000 SIC~ GR 17.4004 BACK FTDT 199,90o0 GSF TRA~ 2.3977 GR NTPT 0.0254 FTDT FSIG 14,0667 TRA1 FBAC -0.0952 MTDT SIG~ 16.0225 FSIG B~Cw 499.7500 FgAC GSF 4,0o19 SIGM GR 36,6500 B~CW FTDI 1q9.9000 GSF DEPT 9200.0000 SIG~ G~ 21.3000 8~C~ FTDT 199.9000 GSF TRA. T ?.~I51 GP NTDT 0 000o FTDT FSIC 15~2666 TP~T FBAC -0.1250 NTDT STG~ 1~.]04S FSIG BACK 499.75o0 F~AC GS~ 4.0010 SICe G~ 30.8145 BACK FTDT 199.q0~0 GSF DMPT 9100.0000 SIOM G~ 61.3000 BACK FTDT 19Q.9000 GSF TRA~ 4,6300 GR ;ilO, B 831 - !,~C::K:". ~ ~ ~ ~ 96 0¢~:~'~' 203:8 GR .... .: ~: :.~:49:~'>,-~:: · } ~. ~. ,~ -;- ~ ,: ~'., ,: ~ -~ _ _ .:.... , -_ 4q9 . 7500 ' F~AC ~:~: O.O000 """NTDT' 0.0OO~ 4,00~-~~ :. 4, :: ::.: -:' -, ,.y: .::'::~ -~.4< ->:?"~. :--- hi _ : _::.::.~: .- :h-'. 499: 750:0 ' 4. 0020 . 199-9o0o :¢SE: ~.9~1:9 ':T~ ' -0 1250 -aTQT ...... _. 0020 -' :: ~'':::'~'~"'~:':~:":'=:::'<? ........ "': '':': 7 500 49 "65'in ~ ~ 9 ] 9 oo:'~ 0. 1~, 0344..- .::TR-A.T:.:> , - ~- i ~' ~ _::.: ,:TD~:.~::. 49 9 .~ SOO ,_- :P-~"~C:'" ::'?"~::t~ :'~:;:: .:~:_.:.: <.:::-_ :..: 0,:;..OffO?0 25-32' 00.60 <- ~ i'9':'~< 0000--. 750-~,: 0 4 ~ 75 NTDT 0.0000 FTOT FSIG 20.2864 TRAi' F8~C 0.0000 MTDT SIG~ 24 2227 FSIG B~CF 499~7500 Mgic GSF 4,0019 $IG~ GR 75.093~ BACk FTi)T 199.9000 GSF DEPT 9000.0000 FTD~r 199 9000 GSF T~AT 3~0~19 NTOT ~.O000 FTDT FSIG ~2.140o F~AC 0 0000 NTDT SIG~ 25~8232 BACK 499,7500 FBAC .,nF 4.0013 $IG~ G~ 53,6992 BACK FTDT 199.9000 D~PT 89o0.0000 GR 52 90oo BACK ~TDT 199~0'50 TRA~~ 4.M~34 GR NTD~ 0.0000 FTDT F$IG 38.8650 T~AT FBAC 0.0000 MTDT SIG~ 37.5906 FSIG BAC~ 499.5610 FBAC FTDT 199,9000 DEPT 8800 0000 $IG~ G~ ' 47:25n0 BACK FTD~ 199,9000 GSF FSIG 3 350o TROT FBAC 3~. OOOO NTDT SIG~~ ~5450 FSIG BAC~ 499 6250 FBAC G~ -99~:2500 BACg. DMPT 8798.0000 SIG~ LISTING lgq.9 ~ ' ' 0 c~ ':'T ~' '< ':' '~' ~?'::-'" ..... "-: ": ::0:~ ~: .~..,0 F,.~,T 1~.9 ~,, C~.F ~. 020 : ~' ~ -*' ~ ' 0 " 180 ~ O0 O0 '~TDT .......... 99::*~90"0~ '?"' - =:: '<:- ':~ ~: - ' 4 ~9.7 5'O-C :' :~C:'::' :::: ~::~ :~:': ...... ..... O:,~fO0~O':' ......:~' ' ' ': 499.7~o 'F~:C::':' ': :':~:':: :'~?' ~'=~'2::5:O'~:~:'":'~T'DT':~ :: ...... :~Q~O0:':O'O~- - ..... -' 19~. 9000- :~5:~ -:~::== ..:::: :::-"<~:~::0 :::~:::.:fi 9'~75 -:G~: ~:'':~:-:--:::' .... ': ::-~::<-'~-': ': ~:: ':' 21 ,'98~ : :T~:~T::<':~: >::' :~: ...... '3~OT:I:7:::'~'~GP:: ?::~-~ :¥'' ':: ........ ~:< 5'6::::: 5~5:9": .... ~, 0'437. ::.:~'i~ : :::. :% ?:'::.~::,:O.:O~O:::~:~::~T :.:~?~: .-.'.':: ::1 900:0 ::<::~ ::.-:: :': :.~.:: :::-:: :- 37,20 9. 19 9: ~ 60~: 3: ?~ "'<~ '::: . ~, 0 .... ~f~.:::r~.~ ':: :""'~FTDT~ ':"~'<:- :- :'~ I ~ 9. ~ OYO':':'=' <~':' "'cF':= :'':' :<'':~' :. G~, ~:::':. 0 0"~ O: '~ ~ ...... ..... - ":" _ , 0:~ 0-~ {~:~UT'':' :~:~' ~':: ~-~: :~:~ ": "~:'"<::'" ~:::~:~'"~ 4 37 620-0-:-, , :::::::::::::::::;:::::?40: :::~:6:~:,9:.:::.: :::::: ::::::::::::: ::: : : ::::::: :::::::::::::' :::::::: :: ::::::: : ::: : : :::: :::::::::::: ::: =.... ::- '::- ::. 4 0 9.6' ~:5:0: ::'~ ~::C:':'< ~': ':¥O": ~:::~ ::N ..... ':'<:':: ::.:: =================== <= :===?======? 1959.90'0:0-:. :::, ::.:' - - 999.2.50:{: :-:: :F: :AC:::::::: :: ::-:::~999: : :::.+: ::- <:~ ::~:: ::::-::::: ': : -999' 2500 ~;~ ':'::" '999,2500.' BA:C~; : :.. <:-, - :'":": : - -~ 99.2505 S~:P "::' "~ -::': '-:':~9:99~:: "<<::S"~G:':~<''' : :':;:': :' ~"g:~:'"25~0'~?:':: '':`:' : ';": '::' :::: :.:::.::.: :: :. ::::::::::::::::::::::::::::::::: ::::'7- :::::::::::::::::::::::::::::::::::::: SIG~ -999.250u FSIG B~C~ -gqg.25QO FPAC G~' -q~o.25c~n FTDT -999.2500 GSF :~DZT · ~-~ TAPE HEADER ~ .SERVICE NAME :EDIT 2ATE :85/05/ ~ O : R~GIN TAPE NAME :0~78 gONTIN~ATI3N ~ :01 PREVIOJS T~PE : gOMM~NTS : ** INF3RMATION R~COROS MNEM ~,ONT~NTS CN : SOHIO ALAS.~A ~N : H-L3 FN : PR LtDHOE BAY RANG: 13=~ OWN: . ECT: Z1 ~.OUN: N.,SLOPE STAT: ALASKA gTRY: USA MNEM CONTfNTS PETROLEUM COMPANY .... O O 0 0 O 0 O 04 O :~'5 PRES: ** COMMENT ALASKA 3I¥ISI~N COMPUTING CENTER ~=---=,~=====----,==.-~=r.~ =:==,r. gOMPAN¥ = SOHIO ALASKA wELL = H-13 FIEL2 = PRUOH2E DAY gOUNTY = N.$L~PE STATE = ALASK SECT[gN = 2I TOWNSHIP = 1LN AANGE = LiE DATE LOG~E2 3-27-~5 3G'T'TDM L3G INTERVAL TOP LOG INTERVAL SA 'SI NG-L a~, ,,,E ~ ,~IT SIZE TYP~ H3LE FLUI3 ~ENSITY VI,SCDS[TI LOG: CHCN, ~697 FT. 8900 FT. 0 000 ~'' . ~.N. @ 0 O. 000 IN. CRUD~ O. O0 ; .. : · .. · : · : · . 0 F ~-, DATA FORMAT RECDRO ~, ENTRY BLOC KS DATUM SP~ MNEM SERV OEP T SR NP~I PS 1 NRAT PSI RNRA PS1 NCNL PS/ FCNL PSI CCh PSi GR PS2 NP~i PS2 NRAT PSZ RNRA PS2 NCNL PSZ ~CNL PS2 C£~ PS Z ~R PS3 NPflI PS3 NRAT PS3 RNRA PS3 NCNL PS3 FCNL PS3 CCc PS3 GR TYPE Z 9 1.6 0 CiFICATiON ~LOCKS ICE SERVICE ONIT ORDER m LOG FT O0 ~A~I O0 PO O0 O0 O0 CPS CPS O0 O0 GAPI O0 PU O0 O0 O0 CPS OC ~PS O0 O0 ~API O0 PU O0 O0 CPS O0 CPS O0 SAPI 00 TYPE CLASS 4OD NO. CODE (OCTAL) .310 01 0 0 ~ I -6'8 0000000000000-0 890. ~20 O1 0 0 ~ 1 58 00000000000000 000 31 0 0 ~ I OB 00000000000000 150 Ol 0 0 ~ 1 ,58 00000000000000 310 Ol-~ ~. '0 :r-: O;.. ~:~ :.: '/:~ L_ ~'~'~8 ~ ~ 890 O0 0 '0 a i '68 000000000'0000~ , . ~ -. ~-~ : : . _. , 000 O0 0 0 ~ ' ~ 68 '000000000~000] 30 31 O::'-r ~_.':: ..:1:.:~ ~:8'::~0:00 00:0000~ 30 .'30 0 0 4 i' ~S 0000000000000~ 310 Oi 0 O ~ 1 '~8 00000000'00000~ 890 O0 :::O: ~:~. :~t: .6~?:0000'0~0::0:0000~~: ~20 Ol 0 - 0 ~ I 0000'000000000~ 000 . O0- 0 :: 0 :~ ~' ' 1 ~:b~8.~O0~ 330 B1 ~ 0 '~ ' ~ ~ O000OO000OO000 -~ _ ~ : , .. . ~ ~. ~ - ~ ~ 3~) 0 - 30 0 '~. ::.~: ~ ,~:. t..-~ 150 Ol 0 0 ~ 1 .68' 00000000000000 MR'AT ~S~ O0 ~20 Oi 0 ' 0 ~ i ~8 ~000000000000~ 000000000 NCNL PS:~ CPS O0 330 Jl 0 0 ~ 1 .6S 00000000000002 :. ~ ~..~ ~ . -:~ ~. >~ ~ :,= . _ ~ . _ CC~ pS:~ 150 O! o o ~ i ~8' oooooooooooooo : ~. :9~1::,.:~ ~R:'- :: - '. 6;5,0.000 .;.~~ ~P:~t~.: :.'.: '~x .:?.:~:8~.~;~'1< RN.RA . Z'gO-hZ NC~L i80~.0000 ' ~Cr~L 622,0000' CCL 0.0879 --999.2500 NgAL -}99. Z590 FC~ -999.A5~0 ~CL 0.0879 .5~ CC~ O.08~g DEPT 9~00.0000 GR 61. ~37.5 NPml i~.5523 NRAT GR 78.5625 NPHi i~. :~437 ;qRAT Z.~lSO RNRA Z.560~ 53. ~6~ B NPHI 12.6953 NRAT 2.2695 -~NR~ Z. 3105 .NCN.L 1~8~.0000 NRAT Z..i777 ~NRA 2. Z.34~ NC'~L 1-~.~2. 0000 F'CNL T 2.: 3535 RN2A Z. ~9~'0 NC~L i~65.0000 FCNL &-6~. ~000 CC~ 0.0106 _,,:~ . , ~ ? ,,~, .~ . ~ - ~, ~ ~ . , . ~ -., _ NCNL 155Z, 0'0~0 ~CNL ~95,~000 CCL O;'OlOa GR Z~.5406 FCNL 59Z*0000 CCL 0,0106 SR 2~"2500 NP~I 0:,0i06 - : . : : . ~ . . ~ ..~ _ ..~ :: -- - :.-A~ ~:~5~:: NC:~Ng'-- ::' f~7:5 00> L ~:C:"~:~ ~ - ~: ;~5-00.0:,~ CCL 0.,B1ZZ ~R 49' Z'~87 -NPh~ 17:23~3 '~'R AT ' Z~ 576Z RNRA 3.0137 .":.;~;:N'~- -: :. -1 ~A~O':O00: ~C]'NL :": :: . ; ~'.'0;:0~0. ~;C.~L_~ ' "::; :O'~*::O~A2 -GR: 46. 5625 NPhI 13' 8['8~ NRAT 2.3~57 ~N~A 2:'7070 ~CNL 1~27.0000 NRAT Z.3379 RNRA 2.7969 NCNL l~08.O00O FCNL 5-82. 000O · .~.:~. · . - _ ~N~A 3'I~Z6 NCNg 2 ~0 O* 0"0'00 FC~L 763;5000 CCL -0.055~ · _~R:~. ~_ 2~'0156: NP~i g-O:':3~ZS. NRAT : 2,-7;;-695 RNRA 3.18t6 NC':~L 2~90'O000 F'CNL 7-82'5'000 CCL -'.=O ;':0:5~6 GR Z2. bSb3 ~: N::.R:AT :' 2-~637 RNA A 3-,:1~65' NC::~L:: ~ ~A6~',I,2,0000: FC,NL 766, 5 0 O0 C CL -0; 0 5.8 6' : : .... ' . ,-:--- _ , : - : 9300.0000 ,~ 1~. 3~.3~ NP i.~L 9. 568u NR.AT -~ · , .~ ~ · ~ ~ ~ ~ . ~ ~ ~ - .- ~ :. ~NRA ~'-~3-~9 :~C NL ~9~ ~-.O:OOO nC ~¢.L 1377-0000 '~C~ ~R 20:'00~0 NPmi 9.51:9i NRAT 2.0430 RNRA ' NPHi 1~.~863 NRAT ' .Z.!455 ~'N~A : 2:Z6~6 NCNL · RNRA Z,'7255 -NCNL 260 O.~OOO FC,~L ~SZ. 5000 CCL NPHI E-CNL DEPT 9!00.0000 GR 7.9102 NRAT ;~R 19.67'i'~ NPHi 7.5125 ~RAT i.9033 RNRA ' - i,~ ~., : ' ~ '~ :. ~ , - ,' - ~-'.~ . :~- -' ~ NRAT 1.90!4 RNRA Z.0195 NC~L 3020.0000 FCNL ' ~C~ 0~,, t .,~6 --~RA T' 2 - 09.38 RNR A ~.. 326Z NC ~k 32.88.. 0000 FCNL CC;. RNRA :~. 3~ ? 7 f~CNL 1 ~03;- gOOO FCN~ 3,4~-.~000 ~C- =R 53. ~u~3 ~PHI 4,~. t6~i NRaT ~.O0~u RNA NRA'T 3.9883 RNRA ~.2109 .NC '4L 1~7:5. OOOO FCN~ CC~ O. 2498 · Z. 04::t8 Z. ~. 9 92. 19. ~3'75 3104. OOOO 9.8633 1365.0000 £. 5664 0.0415 Z.7930 2516.0000 I~.89~5 968. 0000 I. 9ii.i O.i~16 g. 12 50 21.953i 3926.0000 7.7637 i~9~. 0000 2.02.73 0.14.51 43. ~O~b3 3380.0000 10.2539 1~13. 0000 4.Z773 0.Z498 · 4. 3008 55.t875 1521.0000 42.9199 350.2:500 -999.2500 -'999.2500 -999.2500 -999.2500 -999. 2500 48. 532.5 331. ~000 GONTINJATiS]N ~ :01
