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Home My WebLink About195-023Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~~ -'0~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~incent Nathan Lowell Date: ~L~ ....~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy .Dianna Vincent Nathan Lowell Date: Is~ ~ ~' ;l STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG -'~~~ ~` ~~(•~. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned~ ^ Suspended 20AAC 25.105 zoAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/31/2008 ~ 12. Permit to Drill Number 195-023 - 308-361 3. Address: P.O. Sox 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 05/11/1995 13. API Number 50-029-20217-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 05/22/1995 14. Well Name and Number: PBU G-02A 2163 FNL, 1974 FEL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 1284' FNL, 1238' FWL, SEC. 07, T11N, R14E, UM 8. KB (ft above MSC): 74' ~ Ground (ft MSC): 34.97' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 196' FNL, 2921' FWL, SEC. 07, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11635' 8974' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 658243 y- 5969486 Zone- ASP4 10. Total Depth (MD+TVD) 11725' - 8976' - 16. Property Designation: ADL 028304 ' TPI: x- 661437 y_ 5970434 Zone- ASP4 Total Depth: x- 663096 y- 5971558 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi el o ' n rint inf rm i n r 20 AA 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): RLL, CNL, MWD 22. CiASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED " Insltd Coductr rf 1 Srf 110' 3 c nr ' 17-1 P I . - / " 47# N- 311' rf 8 18' 1 -1 /4" ,420 w ft Howco Lite, 289 w ft'G', 135 w ft PF'C' 7" 2 L-80 1' 1 42 ' -1/2" 0 u la ' " L- 1 1' 1 1 7' I ' 23. Open to production or inject ion? ^ Yes ®No 24. TueING RECORD If Yes, list each i (MD+ND of lop & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER .SET MD 4-1/2", 12.6#, L-SO 10128' 9957' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ~eyf~,~s~~,~ ~~~ ~, `, ~~~~ 10278' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N!A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIQD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+T~/D 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. JD~ 8.~ None ~ .~~~: corm ~v-4v~ Revlsea oZ/ZOO~ CONTINUED UN REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN 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 9396' 8391' None Shublik 9445' 8433' Sadlerochit 9532' 8506' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the forego' g is true and correct to the best of my knowledge. t~ Si d /~% ~ gne Title Drilling Technologist Date Terrie Hubble PBU G-02A 195-023 308-361 Prepared ey NameMumber. Terrie Hubble, 564-4628 Well Number P i N A r v I N Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 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). IreM 28: 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 description and analytical laboratory information required by 20 AAC 25.07E IreM 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 • G-02A, Well History (Pre Rig Sidetrack) Date Summary 10/15/2008 RU, PT surface lines to 3500 PSI, Standby for heater. 10/16/2008 T/I/0= Vac/0/140 Temp=S1 MIT IA PASSED to 3000 psi. MIT OA PASSED to 2000 psi (CTD prep) Pumped 7.5 bbls 60° crude down IA to achieve test pressure. IA lost 100 psi 1st 15 mins and 40 psi 2nd 15 mins for a total loss of 140 psi in 30 mins. Bled (- 7 bbls). MIT OA. Pumped 0.9 bbls 60° crude down OA to achieve test pressure. OA lost 140 psi 1st 15 mins and 30 pis 2nd 15 mins for a total loss of 170 psi in 30 mins. Bled back (- 1 bbl) Final WHP's= Vac/0/0 DSO notified of following valve positions upon departure -Swab, Wing, SSV = S/I, Master, IA, OA = Open. 10/25/2008 RU, Drift CT with 1.25" ball, Perform weekly BOP Test. MU and RIH with 2-7/8" Inteq left-handed motor and 3.80" OD parabolic diamond speed mill. Tag XN nipple at 9975' ctmd. Mill through XN nipple._ Perform three reciprocations while milling to dress nipple. Dry drift cleanly through XN nipple to 10351' ctmd. Pull to surface. MU and RIH with 16.95' x 3.70" OD WFD dummy whipstock assembly. Drift cleanly to 10355' ctmd. Pull to surface. RDMO. Job complete. 10/26/2008 T/I/O = 650/110/150. Temp = SI. Monitor WHP (pre CTD). AL is connected & SI at casing valve,.ALP C~ 0 psi. TBG fluid level C~ 1722'. IA fluid C~3 surface. SV =closed. WV, SSV, MV =open. IA, OA = OTG. NOVP. 10/27/2008 T/I/O = VAC/280/650. Temp = SI. Bleed IAP & OAP to 0 psi (CTD Prep). AL connected, SI at casing valve. ALP = 0 psi. IA FL ~ surface. Bled IAP from 280 psi to 0 psi in 30 mins to BT. During IAP bleed, OAP decreased to 540 psi. Monitored for 30 mins, no changes. OA FL C~ surface, bled OAP from 540 psi to 0 psi to BT in 1 hr. Held open bleed on OA for Cameron while doing PPPOT & LDS. Monitored for 30 mins, no changes. Final WHPs =VAC/0/0. SV, WV, AL shut. SSV, MV open. IA & OA otg. NOVP. 10/27/2008 T/I/0=650/100/140 Temp = SI Load tbg pre pack off test (CTD) Pumped 3 bbls meoh followed by 189 bbls 1% kcl down tbg capped w/ 60 bbls crude for freeze protect FWHP's=0/500/840 (swab closed, wing closed, ssv open, master open, annulus valves open to gauges operator notified of high OA pressure and well status). 10/27/2008 Tree test Pre-CTD "*"PASSED"" 10/27/2008 T/IA/OA=O/0/0 Temp=cold PPPOT-T (PASS) PPPOT- IC (PASS) (Pre CTD) PPPOT-T Pressure bled through slotted bleed screw verified 0 psi. Removed 1 " NPT plug, removed internal check, installed 1"Alemite. Cycle all LDS "Standard" all moved and were in good visual condition. RU HP bleed tool onto THA flushed void until clean returns achieved. Pressured void to 5000 psi for 30 min, 4900/ 15 mins, 4900/ 30 mins. Bleed THA void to 0 psi, RD test equipment, re-installed Alemite cap. PPPOT-IC Pressure bled through slotted bleed screw verified 0 psi. Removed 1" NPT plug, removed internal check, installed 1 "Alemite. Cycle all LDS "Standards" all moved and were in good visual condition. RU HP bleed tool onto IC test void pressured to 3500 psi for 30 min, 3500/ 15 mins, 3450/ 30 mins. Bleed IC void to 0 psi, RD test equipment re-installed Alemite cap. *"* INTERNAL CHECKS REMOVED'"' '"' Starting head out of timing from reserve pit ~ 11:00, tubing spool is 2 bolt holes over back C«3 12:00 to reserve pit & F/L *"` 10/28/2008 T/I/0=0/0/100. Set 6" CIW J BPV. Pre Nordic 1. Page 1 of 1 BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: G-02 Common Well Name: G-02 Spud Date: 8/22/1976 Event Name: REENTER+COMPLETE Start: 10/29/2008 End: 11/7/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/7/2008 Rig Name: NORDIC 1 Rig Number: N1 bate From - To Hours Task Code NPT Phase Description of Operations 10/30/2008 00:00 - 10:00 10.00 MOB P PRE Move off pad and move rig from 18-06B to G-026. Route of travel is from 18-066 onto West Dock road to K-pad access road to G pad. 10:00 - 15:00 5.00 BOPSU P PRE I AT 10: NU BOP. Install sump. grease tree. 15:00 - 20:00 5.00 BOPSU P PRE T.'est BOP. AOGCC 's Chuck Sheeve waived witnessing the BOP test. Test annular, blind shears, 2-3/8" combi, 3-1/2" x 2-3/8" VBR, 2-3/8" combi, HCR, Kill line valves. Test stabbing valves also. 20:00 - 21:00 1.00 RIGU P PRE Cut off CT connector and inspect cable boot, looks ok. M/U CT to riser, line up to fill reel in reverse. Pump 40 bbls fresh water then displace with 2% KCL 2# biozan. 21;00 - 21:30 0.50 RIGU P PRE Break off CT riser, rig up hydraulic cutter. Cut 190 ft of CT to find cable. 21:30 - 22:10 0.67 RIGU P PRE Install SLB CT connector. Pull test to 35 Klbs, good. 22:10 - 23:00 0.83 RIGU P PRE Install BHI cable head. PT and electric test, good. 23:00 - 23:40 0.67 BOPSU P PRE Line up to PT inner reel valve and CT connector. Test and chart to 250 / 3,500 psi, good. 23:40 - 00:00 0.33 BOPSU P PRE Load BPV tools to rig floor. 10/31/2008 00:00 - 00:45 0.75 RIGU P PRE PJSM then ull BPV. Well is on vac. Fill well with 14 bbls. 00:45 - 01:00 0.25 MOB P WEXIT Load WFT tools to rig floor. 01:00 - 01:15 0.25 WHIP P WEXIT SAFETY MEETING. PJSM for picking up WFT whipstock anchor. Crew positions and overhead loads were discussed. 01:15 - 02:10 0.92 WHIP P WEXIT 'M/U BHA #1 - WFT Packer and settin ada for for 4-1/2, 2-3/4 Fury setting tool, 3" CoilTrak with HOT, DGS, and DPS. RA tags installed in whipstock while picking up BHA. 02:10 - 05:10 3.00 WHIP P WEXIT RIH BHA #1. Circ 0.2 bpm through open EDC. Log GR down from 8,940 ft, then from 9,540 ft. Correct +5 ft. Continue RIH to log CCL. 05:10 - 06:00 0.83 WHIP P WEXIT Log CCL up from 10,350 ft. Up wt is 46 Klbs. Stop at 9,900 ft and print out logs. 06:00 - 06:25 0.42 WHIP P WEXIT RIH to 10296.6 (10280 TOWS) Pu Wt 45K. Close EDC. Pressure shear at 3000. Stack 5K. OK. 06:25 - 08:25 2.00 WHIP P WEXIT POH Filling agrocc the ton of th hol .. Stati Ioac rate 8 hom . 08:25 - 09:40 1.25 WHIP P WEXIT LD anchor running tools . PU WS ,running tool and jars 09:40 - 11:20 1.67 WHIP P WEXIT RIH with hollow tray WS. 11:20 - 11:35 0.25 WHIP P WEXIT Tie -in +6 correction. 11:35 - 11:55 0.33 WHIP P WEXIT RIH 10000' . PU Wt 41 K. RIH DN Wt 16K, tag at 10291. Set 10K dn. PU 47K. set 10K down. PU to 52K shear off. 11:55 - 13:45 1.83 WHIP P WEXIT POH swapping well to milling fluid. 13:45 - 14:45 1.00 WHIP P WEXIT LD WS setting tools. PU milling assembly. c ~ ~ ' 14:45 - 17:00 2.25 STWHIP P WEXIT IH to 9580 J ~~ ` C o2~ 17:00 - 17:15 0.25 STWHIP P WEXIT Replace valve on power pack. ' 7- 17:15 - 17:40 0.42 STWHIP P WEXIT Log tie-in. Correction +5 . 17:40 - 18:00 0.33 STWHIP P WEXIT Tag at 10,279 ft at min rate. 18:00 - 21:00 3.00 STWHIP P WEXIT Pick up 39 Klbs and bring pump rate to 2.57 bpm ~ 2,300 psi off bottom. Ease back down to 10,278 ft, Mart time milling from there 1 fUhr. -_ Printed: 11/25/2008 11:02:53 AM VELLHEAD = 13-5/8" 5M McEVOY ~CTUA~TOR = OTIS :8. ELEV = 74.0' 3F. ELEV = 35.17' :OP = 3513' Aax Angle = 97° @ 12130' )alum MD = 10045' )alum TVD = 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2684' TOP OF 7" LNR ~~ 8261' Minimum ID = 2.37" @ 10,713' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 9311' 45 Hyd. "KB" Liner Top Packer 10070' Top 3-3/16 X 2-718 liner 10089' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10128' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 10265' SAFF~Y NOTES: I ' 2171' ~~ 4-1/2" SSSV HES HXO LAND NIP, ID = 3.813' 2683' 9-5/8" DV PKR GAS LIFT MANDRELS ~T MD TVD DEV TYPE VLV LATCH PORT DATE 2 4223 4176 29 CAMCO DOM RA 16 11/09/08 1 8228 7395 41 CAMCO SO RA 20 11/09/08 MILLOUT WINDOW (G-026) 10278' - 10284' 9946' ~ 4-1/2" HES X NIP, ID = 3.813" gg80' 4-1/2" HES X NIP, ID = 3.813" gggl' 4-1/2" HES XN NIP, ID =milled to 3.80" gg$7' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10128' 4-1/2" TTL WLEG, ID = 3.95" 10130' ELMD TT LOGGED 02/01 /96 10278' -~ 4-1/2" WFD HOLLOW WHIPSTOCK 10713' 3-3116" x 2-7J8" crossover, ID = 2.37" 3-3/16" X 2-7/8", 6.16#, L-80, STL solid cemented LNR ~~ 12171' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.953" 11725' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/05/76 ORIGINAL COMPLETION WELL: G-02B 05/29/95 SIDETRACKCOMPLETION PERMIT No: 208-158 11/06/08 Nordic 1 CTD SIDETRACK (G-02B) API No: 50-029-20217-02 11/10/08 GJF/SV GLV C/O (11/09/08) SEC 12, T11N, R13E, 2163' SNL & 1974' WEL RP FYnlnratinn /Alackal PERFORATION SUMMARY REF LOG: Baker Hughes MWD/GR/ROP 11/03/2008 ANGLE AT TOP PERF: 95° @ 10390' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SOZ DATE 2 6 10390 - 10440 O 11 /05/08 2 6 10480 - 10530 O 11/05,'08 2 6 10730 - 10770 O 11 /05.08 2 6 10810 - 10920 O 11 /05.08 2 6 11000- 11070 O 11/05!08 2 6 11120- 11180 O 11/05,'08 2 6 11200 - 11300 O 11/05/08 2 6 11430 - 11510 O 11/05/08 2 6 11530 - 11680 O 11105/08 2 6 11730 - 11900 O 11/05/08 2 6 11970 - 12020 O 11/05/08 G-02B • ~~ •~ ~ ` ~ -~~ ~ ~ ~ Lis ._J ALASKA. OIL A1~D GrAS CObT5ER~A7`IO11T CO11i1~II551O.1~ John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 .,,,~ f ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-OZA Sundry Number: 308-361 Dear Mr. McMullen: ~A~ q 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 folly win da or weekends lA person may not appeal day if the 23rd day falls on y a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair . l3~ DATED tYus ____ day of October, 2008 Encl. STATE OF ALASKA ' ~~~ AKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~O~' A ~~ 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ 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 195-023 _ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20217-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G-02A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028304' 74' ~ Prudhoe Bay Field / Prudhoe Bay 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): 11725' 8976' - 11635' 8974' None None in i TVD r t u ural r 1 "x 11 ' rf 2684' 1 -3/ " 4' 4930 2 7 In rm i 9311' - / " 11' 1 7 476 Pr i n Liner 2 7" 74 4' - 81 7 in r 1 4-1/2" 1 1 1' - 117 7' 84 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10380' - 11625' 8984' - 8974' 4-1/2", 12.6# L-80 10128' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 9957' 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: October 15, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the f regoing is tru and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name John ~ I Title En ineerin Team Leader / ~ Prepared By Name/Number J~ ~ Signature Phone 564-4711 Date / //`/'J Terrie Hubble, 564-4628 Commission Use Onl ' Sundry Number: ~ 8'_ ~ Conditions o proval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~~ ~rcC ~~ other: 3SOC'~ PS c ~O ~ ~S ~. °a +-~ a-~` ~ ~-~ (~c~ Subsequent Form Required: APPROVED BY ~~~ ~~ A roved B : COMMISSIONER THE COMMISSION Date V Form 10-403 Revised 06/2006 r ; r . -ti , r, s /~~ ~'~ ~F~. 0 CT ~ `A 2008 Submit In Duplicate • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission ~.J From: Ron Phillips ~J CTD Engineer Date: October 3, 2008 Re: G-02A sundry request Sundry approval is requested for Prudhoe well G-02A. G-02A was sidetracked in May 1995. The G-02 parent well straddled Zone 2 and fractured Zone 1. Unfortunately they thought it fractured up into Zone 2 and that gassed out the well. G-02A was designed as ZonelB horizontal but ended up being a Zone lA/1B horizontal. HOT was not encountered. The well came on line at 1000 BOPD and 5000 GOR. Production remained stable and the GOR did not rise above 10,000 for nearly 3 years. A SBHP Survey in 1996 showed a low pressure for Z1A and since then this well has been labeled as in the LPA. The GOR continued a slow climb and began to cycle in 2003 when a channel to gas broke down. Borax / PPROF logs run in 2004 show signs of a channel connecting the top perfs to gas. The PGOC from a 2008 RST log is around 10,130' MD. A channel squeeze was discussed but was found to have little IOR, therefore we are moving ahead with a CST package. Mechanically the well is in sound condition. It passed it's pressure testing (MITIA and MITOA) and had a caliper run May 31, 2008. The caliper showed the tubing to be in very good condition with no significant areas of wall penetration or cross-sectional loss noted REASON FOR SIDETRACK G-02A is being sidetracked because of low productivity and high GOR due in part to the gas channel. There are no further end-of-life adperfs also because of this channel. 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: 1. MIT-IA, and OA. 2. Dummy drift for WFD Hollow WS to 10,320' (74 deg incl) 3. PDS Caliper Log 4. Mill XN at 9,991' to 3.80" with left handed motor, mill. 5. Set BPV. 6. AC-LDS; AC-PPPOT- T 7. Test MV, SV, WV 8. Bleed gas lift and production flowlines down to zero and blind flange 9. Remove wellhouse, level pad The pre CTD work is slated to begin on October 1, 2008. ~ ~ ~ S 0. ~ ~cov~. ~ Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high, Pull BPV 2. Set 4-1/2" hollow whi stock @ 10280'. 3. Mill 3.80" window at 10280' and 10' of openhole. Swap the well to Flo-Pro. 4. Drill build/turn section with 3-3/4 x 4-1/8" bicenter bit, and land well. 40 deg/100 (plan #5) 5. Drill lateral section with 3-3/4 x 4-1/8" bicenter bit to TD at 12200'. 12 deg/100 (plan #5) 6. Run 3-3/16" solid/ cemented liner by 2-7/8" slotted liner leaving TOL at 10100' and transition form slotted to solid, 100' beyond landing point at 10660'. 7. Pump primary cement job from slotted liner to TOL, 6.8 bbl of 15.8 ppg cmt planned. 8. Run CO assembly 9. Test liner lap to 2000 psi. 10. Freeze protect well, Set Bf~DMO Post-Rig Work: 2. Pull BPV 3. Re-install wellhouse and FL's. 4. Generic GLV design. Flow well to portable test separator. Ron Phillips CTD Drilling Engineer 564-5913 • CC: Well File Sondra Stewman/Terrie Hubble TREE = 6" -5M -CNV WELLHEAD = 13-5/8" 5M McEVOY ACTUATOR = OTIS KB. ELEV = 74.0' BF. ELEV = 35.1 T KOP - 3513' Max Angle = 94 @ 10935' Datum MD = 10045' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2684' I TOP OF 7" LNR I Minimum ID = 3.725" @ 9991' 4-1 /2" HES X NIPPLE tL, 2171' I~ 4-1/2" SSSV HES HXO LAND NIP, ID = 3.813" I ~ 26~~ 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4223 8228 4176 7395 29 41 CAMCO CAMCO DMY DMY RA RA 07/04/03 07/04/03 SIDETRACK WINDOW - 8400' -8450' 9946' I~ 4-1/2" HES X NIP, ID = 3.813" 9957' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9980' 4-1 /2" HES X NIP, ID = 3.813" 9991' 4-1/2" HES XN NIP, ID = 3.725" 10128' 4-1/2" TTL WLEG, ID = 3.95" 10130' ELMD TT LOGGED 02/01/96 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9311' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10128' TOPOF4-1/2" LNR 10128' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 102' 7" X 4-1 /2" BKR HPLPO PKR, ID = 3.875" W/ BAKER G2 TIEBACK SLV, ID = 4.5" I- PERFORATION SUMMARY REF LOG: SPERRY/SUN MWD ON 05/95 ANGLE AT TOP PERF: 87 @ 10380' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPN/SCZ DATE 2-3/4" 4 10380 - 10500 O 05/26/95 2-3/4" 4 10600 - 10730 O 05/26/95 2-3/4" 4 10850 - 11130 O 05/26/95 2-3/4" 4 11270 - 11625 O 05/26/95 I 10131' PBTD 11635' -- 4-1/2" LNR 12.6#, L-80, .0152 bpf, ID = 3.953" 11725' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/05/76 ORIGINAL COMPLETION 07/13/03 CMO/TLP KB ELEVATION, MAX ANGLE 05/29/95 SIDEfRACKCOMPLETION 02/15/01 SIS-Isl CONVERTEDTOCANVAS 03/01/01 SIS-MD FINAL 09/20/01 RN/TP CORRECTIONS 07/04!03 JJ/TLP GLV GO PRUDHOE BAY UNIT WELL: G-02A PERMIT No: 1950230 API No: 50-029-20217-01 SEC 12, T11 N, R13E, 2163' SNL & 1974' WEL BP Exploration (Alaska) • TREE = 6" -5M -CM/ WELLHEAD = 13-5/8" 5M McEVOY AOTUATOR = OTIS KB. ELEV = 74.0' BF. ELEV = 35.17' KOP = 3513' Max Angle = 94 @ 10935' Datum MD = 10045' Datum TVD = 8800' SS ~0 ~ ~ S~ NOTES: Proposed CTD Sidetrack 0 2171' 4-1/2" SSSV HES HXO LAND NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2684' TOP OF 7" LNR (--( $261' Minimum ID = 3.725" @ 9991' 4-1 /2" HES X NIPPLE 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~~ 9311' 9-5/8" DV PKR I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4223 8228 4176 7395 29 41 CAMCO CAMCO DMY DMY RA RA 07/04!03 07/04/03 SIDETRACK WINDOW - 8400' -8450' 9946' -i 4-1/2" HES X NIP, ID = 3.813" 9957' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9980' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10128' 9991 ~ 4-1/2" HES XN NIP, ID = mlled to 3.80" TOP OF 4-1/2" LNR 10128' ' " " 10128 TTL WLEG, ID = 3.95 4-1/2 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" 10265' ~ 10130' ELMD TT LOGGED 02/01/96 PERFORATION SUMMARY REF LOG: SPERRY/SUN MWD ON 05/95 ANGLE AT TOP PERF: 87 @ 10380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SOZ DATE 2-3/4" 4 10380 - 10500 O 05/26/95 2-3/4" 4 10600 - 10730 O 05/26/95 2-3/4" 4 10850 - 11130 O 05/26/95 2-3/4" 4 11270 - 11625 O 05/26/95 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 11725' 10280' 1 4-1/2" WFD HOLLOW WHIPSTOCK 10700' 3-3/16" x 2-7/8" crossover ~I- ------- --- ---I 3-3/16" X 2-7/8" L-80 BONSAI 12200' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/05/76 ORIGINAL COMPLETION 07/13/03 CMO/TLP KB ELEVATION, MAX ANGLE 05/29/95 SIDETRACK COM PLETION 09/04/08 MSE PROPOSED CTD SIDETRACK 02/15/01 SIS-Isl CONVERTED TO CANVAS 03/01!01 SIS-MD FINAL 09/20/01 RN/TP CORRECTIONS 07/04/03 JJ/TLP GLV GO PRUDHOE BAY UNfT WELL: G-026 PERMIT No: API No: 50-029-20217-02 SEC 12, T11 N, R13E, 2163' SNL 8~ 1974' WEL BP Exploration (Alaska) 08/25/08 \~ 3 ~:, ._ ~~ O ~A5>a ~,~~ Sch[pmberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Joh # ~A~J~If~ S~~' ~ ~ 2D08 Lna nescrintinn N0.4826 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 nArA HI rnlnr rn A-02 12086677 RST ~ - ( 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 1 A-13 12086676 RST ~(~ ~f 07/23!08 1 1 G-02A 11968945 RST $= ~ 06/08/08 1 1 B-f9A 12017500 RST - ~ Q 06/14/08 1 1 15-18A 12005216 MCNL - ~ (~ - 06/24/08 1 1 C-02 11982437 RST / ~ 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - G ~ 04/21/08 1 1 B-37 12034907 CH EDIT PDC-GR 06/10/08 1 V-207 11999031 MDT aO 07/23/08 1 1 V-207 11999031 MDT QUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /(p 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) ~ Q 07/28/08 1 1 B-18 11978471 USIT _~ /(p ~ ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 ^ 07/21/08 1 1 13-29L1 11962614 LDL Q -(}(o ' 07/30/08 1 1 13-29L1 11966271 USIT - f (p 08/05/08 1 1 H-11 12017507 USIT - 08/04/08 1 1 ~- w ~ -at r~cN~c f\l.nrvvvvl.CVUC r1C\.Clr ~ Di .ll\arvIP1U HIVU r{tl Ut{IVIIVIa VIVO GVYT CAGH 1 V: BP Exploration (Alaska) Inc. q ~„ ~,.,,.. ~, Petrotechnical Data Center LR2-1 ~ s „' 900 E. Benson Blvd. ~-. Anchorage, Alaska 99508 Date Delivered: ~~~~ {~ ~ ~(~(}~~ ,•I~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth /~, Received by: /l/..~~ ~~ ;~ Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well /i~ -- /7G C-29A /J'l.·I:J¡ E-25 ~q3IC2:J. G-02A 'J.iJf; l"flf W-27 A ~~ot* D-25A (---.. ,'tfLf-Of~~ DS 15-25A' ~ ~.Ø~E-39A '\ 02-168 f c¡,~ {; l! C-25A '20'f~¡.o1 E-17A ·(DL/.- i¿g~ C-41A j ~.-t'¡,{)- DS 07-30A '11~'DS15-38A i.1;1-ili1 02-28A 15- {~J ~ D-11A ~{:t{-2./'6 DS 05-24A Job# 10715422 10715423 10715424 10670031 10854314 10715428 10715430 10928597 10928598 10928602 10928606 10715445 10715446 10928607 10928608 10928609 (Prints--, only-Job not complete) MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL SCANNED JUN ~ t 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: ¿:¿;3h:r I I /fj-~&2 ~ 01/24/05 NO, 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 ~ -~' Alaska Data & Consulting Services 2525 Gambell Street, Suit)Y400 í' AnChora.ge. AK~950 ~38 ....1., . ~J ATINCe ~.. / 1 , Iv \ /...., I / ~ Rece \!~d by: ,j f', :/i C VI / 1/ V MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~ DATE: Commissioner Tom Maunder, ~~ P. !. Supervisor THRU: March 26, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit BPX / G Pad March .26, 2.001: I traveled to BPX's Prudhoe Bay Field, G Pad, to witness Surface Safety Valve System tests and perform well house inspections. Merv Liddelow was the BPX representative in charge of testing and he performed the tests in a safe and proficient manner. Fifteen wells were tested with-nine failures witnessed. The pilots on wells G-02A, G-1 lA, G-14A and G- 21A failed to operate properly. The SSV's on wells G-01A, G-02A, G-03A, G-09 and G-13 failed to close or failed to hold D/P. Wells G-03 and G-09 were shut in pending repairs. Mr. Liddelow indicated to me that all other failures had been repaired and passed a retest within 24 hours. Fifteen well houses were inspected and slight crude oil leaks were noted on wells G-14 and G-16. Mr. Liddelow and his crew repaired these leaks immediately. The ^OGCC test reports are attached for reference. SUMMARY: I witnessed SVS tests on 15 oil producing wells on BPX's G Pad in the Prudhoe Bay Field. 15 wells, 30 components tested. 9 failures: 30% failure rate. 15 well house inspections Attachments: SVS PBU G Pad 3-26-01 JJ NON .- .C, ONFIDENTIA..L SVS PBU G Pad 3-26-01 JJ Alaska Oil and Gas Conservation CommissiOn Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/U~ad: PBF/PBU/G-Pad Separator psi: LPS 152 Date: 3/26/01 HPS 649 '~i~':! "~ i~:$$~ ' $$$ R,etes,,t, Well'Typ " ~2~?~ ~:~ff~! :~ :.~?~:3¥~--~:?"~5 ~3 f':-._~'::~-:~'- -~;~_~V,.~.- ~":'-::~:.'~:~.:d~:~-~?~:~q-':~.:q~5/~':~ Well Pemit Separ Set L~ T~t Test Test Date ~, waG, G~J, Number Number PSI PSI Trip Code Code Code Pass~ GAS or ~CLE ~,o~A ~9317~0 ~9 5~0 56~ P ~ om ~.02A ~ ~'~r950230~'~2 ~25 14~ 1" G-03A 1970700 152 125 115 P 5 OIL G-04A 1951630 G-05 1780970 ~9 550 555 P P &o~ ~7901~0 ' ~-07 ~7901~0 152 '~5' ~5 P P ' " om G-08 1810480 ~-09A'~ ~98~30 ~49 ~50 ~60 e 4 "' OI~ ~.10A ~950390 ~-~A ~93f606 - ~49 ~0 ~0 3 P 0~ G-12A ~9~050 ~-~3 '~8~07~0 152 1~5 120 ' ~ 4 " OI~ G-14A 1980530 649 550 0 2 P OIL ~-~SA ~98~340 ~49 5~0 ' ~30 P e " Om G-~6 18~12~0649 550 ~40 P G- 17 181094O ~-~8A' 19903e0' ~49 '550 ~5~ ~-~9A 199~030 ~-~i "195~540 ~9 SS0 0 2' e ' OI~ G-23A 1960200 G-24 1861830 G-25 1861620 G-26A 1981510 ~_e~'" 186~o G-29 1861600 ~-3o~" 19~o760'" ~-3~A' ~9~0540 ~9 550 ~0 e P ' ~ Om G-32A 1970010 152 125 140~ P P OIL Wells: 15 Components: 30 Fa#ures: 9 Failure Rate: 30.00o/~[~] 90 Day Remarks: G-3, G-9 are shut in for repair. Operator report,s, ,,all, o,,ther failures repaired & passed RJF 1/16/01 Page 1 of 2 SVS PBU G Pad 3-26-01 JJ1 : :' ~:~ :~:::~ ~ ' I~1 I ' ' ' :' Well Pemit Separ Set L~ Test Test T~t Date ~!, WAG, G~J, Number Number ,PS~ , psI , Tr~p Code Code Code Passed GASorCVCLE RJF 1/16/01 Page 2 of 2 SVS PBU G Pad 3-26-01 JJ1 oN-oR BEF ORE PERMIT DATA Wel 1 Inventory Page: 1 Date: 03/19/97 RUN DATE .... RECVD 95---023 DGR/CNO ~ ....7528-8975 TVD ,--.6 00/20/.,ss 95'-023 DGR/CNO DL~' 8~00-11727 MD 1-,6 o0/2s/95 95--023 95'-023 NGP/DGR/EWR/~ NGP/DGR/EWR/~ 10-~07 1 .... 6 08/20/95 1--6 08/28/95 DAILY WELL OPS c.. -/z,, 3' '% '7 - it '7,z ? Ar'e dry d~tch samples required? Was the well cored? yes yes ,o~And r'ece-ived? '~'a '1 y s 'i s Are we'll test.:s r'equ~red? yes Well ~s 'in compliance ,~ I n '~ 't '¥ a l CCMM ENTS & descr'~pt~on r'eceived? ....... yes ..... h,o-- o~,.Rece'i ved? yes - ~-t-o---- 01:! 111__1N G S I:: !::! ~ I r" ~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Larry Grant 3001 Porcupine Dr. Anchor~e, Alaska 99501 MWD Formation Evaluation Logs - G-02A AK-RB-950522 January 08, The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Yan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~Cj, Anchorage, AK 99518 G~02A: 1 LDWG formatted LIS tape with verification listing. API#: 50-029-20217-01 RECEIVED dAN 0 8 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Pern~ l~um. ber BP Exploration 95-23/ 3. Address B. APl Nur~ber~.~7~ [/ / [ /it.~[..// P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o - 029-2,.._ , '--,,,~ 4. Location of well at surface ~~. 9. Unit or Lease Name 3117'NSL, 1974' WEL, SEC. 12, T11N, R13E f?T~,~;, ?V;7.~ '".~, ,..~t~,,~T~' Prudhoe Bay Unit AtTop Producing Interval ~ //,'",' "' E // i ~i~j lO. WellNumber i 'V~Fj~i) ! 11. Field and Pool At Total Depth --~.".~- ~-4'__. ........ ' Prudhoe Bay Field/Prudhoe Bay Pool 5086' NSL, 1983' WEL, SEC. 7, T11N, R14E ,5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE-- 74' ADL 028304 1 05/12' Date1/95Spudded 13.05/22/95Date T.D. Reached 14.05/29/95Date Comp., Susp. or Aband. 15. Water Depth,N/AiffeetOffshoreMSL 16.oneNO. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11725'MD/8975'TVD 11635'MD/8974' TVD YES [] NO []I 2171 feet MD 1900'(Approx.) 22. Type Electric or Other Logs Run RLL, CNL, MWD 23. CASING, LINER AND CEMENTING RECORD SE'I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"X30" 27' 137' 36" 8 Cu. Yds. 13-3/8" 72# N-80 27' 2684' 17-1/2" 5471 Cu. Ft. 9-5/8" 47# N-80 27' 9311' 12-1/4" 1844 Cu. Ft. 7" 29# L-80 8261' 10265' 8-1/2" 466 Cu. Ft. 4-1/2" 12.6# L-80 10131' 11725' 6" 213 Cu. Ft. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter: 2-3/4", 4 spf 4-1/2" 11725' 9957' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10380'- 10500' 8910'- 8914' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10600'- 10730' 8913'- 8909' Freeze Prot. w/150 bbl Diesel 10850'- 11130' 8906'- 8898' 11270'- 11625' 8896' - 8900' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 7, 1995 Gas Lift Date of Test Hours Tested =REDUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO ~'EST PERIOD I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. · .'., · Form 10-407 ,~.r~ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9396' 8319' Shublik 9445' 8361' Top Sadlerochit 9532' 8434' 31. LIST OF A'FrACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ 1 (~ f~)~-~ Title Senior Drilling Engineer D at e INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- . jection, Gas Injection, Shut-in, Other-explain. - '"t, Item 28: If no cores taken, indicate "none". ~(' ~' "~. Form 10-407 ,,,x ~\\ ~ ~'~¢~~-~ _ /AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: G-02A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/07/95 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 05/08/95 ( 1) TD:10350 PB: 8742 05/09/95 (2) TD:10350 PB: 8742 05/10/95 (3) TD: 8450 PB: 8742 LD 4.5" TDS TBG MW: 0.0 MIRU ON G PAD. ACCEPT RIG @10:00 HRS ON 5/7/95. TAKE ON SEAWATER/HOSES T/CHOKE LINE. RU FIELD SERV. LUBRICATOR & PULL BPV. OPEN ACTUWATER VALVE. DISPLACE DIESEL F/WELL. PUMP DOWN ANNULUS & RECOVER DIESEL F/TBG. CHANGE LINES, PUMP DOWN TBG & RECOVER DIESEL F/ANNULUS. TOTAL OF 140 BBLS. CBU, NO GAS OFF BTTM. SET 2-WAY CHECK. ND TREE. NU BOP;S. TEST BOP & MANIFOLD--TESTS WAIVED BY AOGCC REP JERRY HERRING. MU LDG JT. BOLDS. PULL TBG T/RIG FLOOR 115,000~, LD HNGR. CBU. RU OTIS SPOOLING UNIT & TBG EQUIP. PULL & LD 4.5" 12.6#, L-80 TDS TBG. RECOVERED 27 CL RUBBER & 4 STEEL BANDS, RD OTIS. CONT. T/PULL 4.5" TBG. CUT 9-5/8" SECTION @8425 MW: 0.0 CON'T T/PULL & LD 4.5" 12.6# L-80 TDS TBG TOTAL OF 215 JTS. 5 GLM'S, 1 BVM & HNGR W/SPACE OUT PUPS. NORM CHECK OK. CLEAR PIPE HOUSE & LOAD BHA. MU SERVICO 7200 MILLMASTER ASSY. 6) 6-3/4" DC'S JARS, 21) 5" HWDP & PU & RIH 254 JT'S OF 5" DP OFF RACK. TAG TBG CUT @8746 DPM. DISPLACE SEAWATER W/MILLING FLUID 1000 BBLS RECEIVED F/MUD PLANT & 24 BBLS OF 18 PPG PILL F/8740 T/8400. TEST CASG T/3000PSI. OK. PU & LD 12 JT'S OF 5" DP T/8400 W/SECTION MILL KNIVES @8400' MADE CUT IN 9-5/8" CASG & CUT SECTION T/8425 @6:00. IRON RECOVERY = 95%. AVERAGE 4 FPH. LAY K/O PLUG IN WINDOW MW: 0.0 LARGE AMOUNTS OF SHALE COMING OVER THE SHAKER, PUMP HI/VIS PILL. RECIPROCATE & ROTATE T/CLEAN HOLE. UNABLE T/PULL BACK IN STUB @8400'. JAR TOOL BACK INSIDE, MADE CONNECTION & ATTEMPT T/REOPEN TOOL. KNIVES MAY BE BENT. FLOW CHECK & POOH. CHANGE OUT 7200 MILLMASTER. --KNIVES WERE BENT. RIH. FILL PIPE @ 4600' PU KELLY & WASH T/STUMP @8425. CONTINUE 9-5/8" SECTION F/8425 T/8450. WINDOW CUT IS SENDING SHALE OVER THE SHAKER & IRON RECOVERY IS @95%. TRQ F/10500 T/12300 FT/LB. CIRC HOLE CLEAN. CHECK F/FLOW. POOH. LD DC'S & SECTION MILL. RIH W/MULE SHOE ON 5" DP. PU 32 JTS OF 5" DP. START LAYING THE K/O PLUG. : G-02A OPERATION: RIG : DOYON 14 PAGE: 2 05/11/95 ( 4) TD: 8400'( 0) 05/12/95 ( 5) TD: 8720' ( 320) 05/13/95 ( 6) TD: 9390' ( 670) 05/14/95 ( 7) TD: 9551' ( 161) RIH W/KO ASSY MW: 0.0 VIS: 0 REV. CIRC @8450. 9-5/8" WINDOW F/8400 T/8450. RIH T/8550. CIRC WHILE BATCH MIXING CMT. PREJOB SFTY MTG & CMT: 5 BBLS H20. TEST LINES T/3000PSI. OK. FOLLOW W/32 BBLS OF 17 PPG CMT SLURRY; 7 BBLS WATER & DISPLACE W/RIG PUMP T/BALANCE 123 BBLS OF MUD (1220 STKS 96% PUMP EFF) POOH W/10 SNDS T/7600. CIRC PIPE VOL. @ 10 BPM. HAD GAS CUT MUD @ BU F/CMT JOB. CIRC CLEAN. SQZ DOWN ON CMT T/1500PSI W/FLUID LOSS. CHECK F/FLOW. POOH & LD 50 JTS OF 5" DP & MULE SHOE. PU KELLY & WASHING TOOL. CLEAN OUT IRON CUTTING F/BOP'S. RIH W/10 STNDS OF 5" DP UNDER 9-5/8" HOWCO STORM PKR & SET @ 50' ND BOP'S & TBG SPOOL, CHANGE 9-5/8" PACKOFF & TBG SPOOL. REDRESS STUMP, UN TBG SPOOL & TEST T/2000PSI. EMERGENCY SLIPS. NU BOP'S. TEST BOP'S & MANIFOLD T/250-5000. SET WEAR RING. PULL 9-5/8" HOWCO STORM PKR & 10 STNDS OF 5" DP. PU & MU STEERABLE K/O BHA#1. RIH SHALLOW TEST MWD & BREAK CIRC EVERY 10 STNDS RUNNING IN HOLE. EST. TOP OF CMT @ 8175. DIRECTIONAL DRLG MW: 0.0 ViS: 0 SLIP & CUT DL 59.5'. CONTINUE RIH W/STEERABLE 1-1/4 DEGREE, BHA #1 T/8088. PU KELLY. START LOOKING F/CMT. TAGGED FIRM CMT @ 8416. 16' INSIDE WINDOW. TIME DRILL ATTEMPT T/ST WELL. DRILL @ 1-3 FPH, 130 DEGREE T/LEFT OF HIGH SIDE. F/8416 T/8435 & 3-5 FPH F/8435 T/8450. PAST THE STUB @ 22:30 HRS. DRILL & SURVEY 8-1/2" HOLE F/8450 T/3720. SS IS STILL SHOWING MAGNETIC INTERFERANCE ON THE DIRECTIONAL. DROPPED ANGLE F/40DEGREE T/31 DEGREE & SHOWING DIRECTION OF 69 DEGREES. DRILLING MW: 0.0 VIS: 0 DIRECTIONAL DRILLING THE 8.5" HOLE & SURVEY F/8720 T/9390. DRILLING MW: 0.0 VIS: 0 CON'T. DIRECTIONAL DRILL 8.5" HOLE & SURV F/9390 T/9511 W/BHA %1. CBU. CHECK F/FLOW. POOH. CHECK FLOW & BHA & SHOE/8400. LD BH MOTOR & DOWNLOAD MWD TOOL. PU SS RLL ON MWD TOOL. PRE-JOB SFTY MTG, LOAD SS CNL SOURCE. RIH. SHALLOW TEST MWD-RLL. FILL PIPE @ 5749 & 8386. SURVEY CHECK SHOT @ 8902. TIGHT SPOTS @9049 & 9329. BOTH 60' SLIDES, WORK THROUGH & WIPE OUT. MADE MAD PASS F/9440 T/9481. REAM T/BTTM @9511. CON'T. MAD PASS F/9481 T/9511 & SURVEY @ 9469 & 9409. DIRECTIONAL DRILL 8-1/2" HOLE F/9511 T/9551. ,ELL : G-02A OPERATION: RIG : DOYON 14 PAGE: 3 05/15/95 ( 8) TD: 9840' ( 289) 05/16/95 ( 9) TD: 9935' ( 95) 05/17/95 (10) TD:10265' ( 330) 05/18/95 (11) TD:10265' ( 0) RIH W/BHA #3 MW: 0.0 VIS: 0 ROTARY DRILLING & SURVEYING THE 8-1/2" HOLE F/9551 T/9840/THROUGH ZONE 3. CBU. CHECK F/FLOW. POOH T/9-5/8" SHOE. CHECK F/FLOW. POOH. PULL SOURCE, BRAKE BIT & DOWN LOAD MWD & RLL. PU SS 1.75 DEGREE BH MOTOR W/INCLINATION @ BIT. CHANGE STAB, MU BIT & RIH. RIH W/BIT #4 MW: 0.0 VIS: 0 CONTINUE INSTALLING SOURCE IN SS MWD-RLL & RIH T/484. SHALLOW TEST OK. RIH T/4461. FILL PIPE & TEST TOOLS. OK. CIRC AIR OUT OF MUD @4461. CONTINUE RIH T/9-5/8" SHOE @8400. SLIP & CUT DL 59.5'. WORK ON SS COMPUTER PROGRAM F/ABI( AT BIT INCLINATION ) . ABI IS NOT WORKING RIGHT W/RLL TOOLS. ALL SURFACE PROBLEMS. RIH T/9840. CHECK SHOT W/ABI @8873. OK. PU DELLY DIRECTIONS DRLG F/9840 T/9935. SLIDE F/BUILD AND TURN. ABI FAILED. COMPUTER PROBLEMS. BIT HANGING UP. CBU & CHECK F/FLOW. POOH FLOW CHECK @ SHOE & BHA TOP. PULL SOURCE & CHANGE BIT. DOWN LOAD MWD RLL TOOL. LD MOTOR & REMOVE ABI TOOL TRANSMITTER. PU MOTOR & RERUN. LOAD SOURCE & MWD PROBE. RIH & SHALLOW TEST MWD. TRIP F/BIT MW: 0.0 VIS: 0 CONTINUE RIH W/BHA #4. FILL PIPE @ 5772 & SHOE @8400. SURVEY CHECK SHOT @9493. PU KELLY & WASH F/9875 T/9935. DIRECTIONAL DRILL THE 8.5" HOLE F/9935 T/10265. TOOH F/NEW BIT. CBU. CHECK F/FLOW. PUMP DRY JOB & POOH. CIRC STRING CAPACITY MW: 0.0 VIS: 0 POOH T/4350. CHK F/FLOW. RIH T/10265. FILLPIPE @6020 & 8400. CIRC HOLE CLEAN. CHK F/FLOW. & PUMP PILL @10265. POOH T/RUN 7" LINER. SLM. LD 27 JTS. 5" DP. CHECK F/FLOW. POOH TIGHT @8790. WORKED TIGHT SPOT CLEAN. POOH T/SHOE. CHK F/FLOW. FINISH POOH. LD HWDP. NM HWDP & JARS. DOWNLOAD RLL TOOL. REMOVE SOURCE F/MWD. RU CASG EQUIP. RUN 48 JTS. OF 7" L-80 NSCC LINER. BAKER HNGR & PACKER & 5" DP T/SHOE @8400. CIRC CAPACITY OF DP & 7" LINER. ,~ELL : G-02A OPERATION: RIG · DOYON 14 PAGE: 4 05/19/95 (12) TD:10265' ( 0) 05/20/95 (13) TD:10544' ( 279) 05/21/95 (14) TD:11385' ( 841) 05/22/95 (15) TD:11725' ( 340) 05/23/95 (16) TD: 11725' ( 0) POOH PLUGGED BIT MW: 0.0 VIS: 0 RIH W/7" LINER F/8400 T/10265. TIGHT @ 8750. CIRC & WORK PIPE--ATTEMPT T/FREE UP W/350000#. STUCK ON BTTM. PUMP 20 BBLS. H20-TEST LINES T/4000%. PUMP 70 BBLS. 11# SPACER. 83 BBLS. 15.7%, CMT-5 BBL. WATER & DISPLACE W/MU. BUMP PLUG W/3500#. SET HANGER & PACKER. REVERSE OUT 30 BBLS OF EXCESS CMT. POOH & LD 71 JTS OF 5" DP & RUNNING TOOL. TEST ALL BOPE. SET WEAR RING. TEST T/250/5000#. PU NEW BHA. RIH PU 3.5" PIPE OFF RACK T/3400. TEST MWD. PLUGGED BIT. POOH T/UNPLUG THE BIT. BOPE TEST WAIVED BY BOBBY FOSTER. DRLG & SURVEYS MW: 0.0 VIS: 0 MWD PLUGGED UP W/A CUPFULL OF CMT CUTTINGS. MU BIT. INSTALL MUD PROBE, CHECK RLL TOOL. SURFACE TEST. RIH RATTLE 3.5 DP T/CLEAN OUT CMT. CIRC FULL PIPE VOL. EVERY 10 STNDS. PU 15 JTS OF 3.5" DP. CIRC VOL. OF DP & TEST MWD. RIH & BREAK CIRC EVERY 30 STNDS. SLIP & CUT DL. RIH T/10097. MAD PASS T/10110, TAG TOP OF CMT. DRLG CMT & LNDG COLLAR @ 10175. TEST CSG & LINER LAP T/3500# OK. DRLG CMT-FLT COLLAR-SHOE & 5' OF NEW HOLE T/10270. CIRC & DISPLACE THE WELL W/FLOPRO MUD. DRLG & SURVEYING F/10270 T/10544. DRILLING & SURVEYS MW: 0.0 VIS: 0 DIRECTIONAL DRILG & SURVEYS F/10544 T/11385. CBU F/SAMPLES MW: 0.0 VIS: 0 CIRC HOLE CLEAN & 10 MIN. FLOW CHK. POOH T/SHOE. CHECK F/FLOW. POOH F/BIT. CHECK F/FLOW @ BHA. STAND BACK BHA. BREAK OFF BIT. CHANGE OUT PROBE IN MWD. RETRIEVE DATA F/RLL. CHK FLT. CHANGE MUD MOTOR F/1.83 DEG. T/1.25 DEG. & ORIENT. RIH. SURFACE TEST MWD-MM & RLL. FILL PIPE @ 4095. RIH FILL PIPE @ 7" LINER TOP @ 8261 & SHOE @ 10265. DIRECTIONAL DRILLING & SURVEYS F/11285 T/11725. CBU F/SAMPLES. POOH T/CHECK FISH TOOLS MW: 0.0 VIS: 0 CIRC HOLE CLEAN & CHK F/FLOW. POOH & LD 43 JTS. 5" DP. POOH T/BHA --FLOW CHK. STAND BACK 3.5" DP--HWDP & JARS. DOWN LOAD RLL. MU NEW BHA & RIH. CUT DL. REAM F/10265 T/10382. CHK F/FLOW. POOH. LOST 1586' BHA. BOX SPLIT ON CASG SCRAPER. MU 5-7/8" O'SHOT DRESSED W/4-5/8" BASKET GRAPPLE. ENGAGE FISH @ 9796 & JAR -- CHASE FISH T/8810, GRAPPLE IS SLIPPING. CHK F/FLOW & POOH T/CHK FISHING TOOLS. ,~ELL : G-02A OPERATION: RIG : DOYON 14 PAGE: 5 05/24/95 (17) TD:11725' ( 0) 05/25/95 (18) TD:11725' ( 0) 05/26/95 (19) TD:11725 PB:l1650 05/27/95 (20) TD:11725' ( 0) OPENING THE HOLE MW: 0.0 VIS: 0 POOH W/O'SHOT & 4-5/8" BASKET GRAPPLE. CHANGE OUT O'SHOT & GRAPPLE T/4-3/4. RIH T/8819 @ TOF. ENGAGE, JAR WHILE CIRC. 9.8 BPM, JARRING 100000 OVER STRING WT. UP & 25000 DOWN. FISH WAS LOOSE @ 1600 HRS. POOH T/SHOE. INSPECT DERRICK AFTER HEAVY JARRING, INSPECT DL. POOH & INSPECT ALL CONNECTIONS ON FISH WHILE TRIPPING OUT. LD BHA & RIH T/10265. SLIP & CUT 60' DL.PU KELLY, WASH & REAM T/10530. RIH W/4.5" LINER MW: 0.0 VIS: 0 REAM W/HOLE OPENER F/10530 T/11725. CIRC HOLE CLEAN. CHK F/FLOW & POOH T/9988. DISPLACE HOLE T/SEAWATER. PUMP 40 BBLS OF HI VIS SWEEP. CHK F/FLOW DROP 2.25" DRIFT. POOH. CHECK F/FLOW @ BHA. LD 12 SINGLES. BHA & HWDP. RU & PU 38 JTS. OF 4.5" LINER & BAKER HANGER & PACKER. RIH W/LINER ON DP. FILL PIPE EVERY 1300' RIH T/CLEAN OUT MW: 0.0 RUN 4.5" LINER ON 5" DP T/SHOE @ 10265. CIRC CAPACITY OF DP & LINER. RUN LINER T/TD @ 11725. PUMP 5 BBLS DCL SPACER TEST LINES T/4000. PUMP 15 BBLS SPACER & 38 BBLS CMT. DISPLACE & BUMP PLUG W/SEAWATER T/3000#. SET PACKER & HANGER @ 4000. REVERSE OUT 10 BBLS CMT & CIRC. POOH W/RUNNING TOOOL. PULL WEAR RING. & TEST BOPE T/250/5000. RUN WEAR RING. PU 2-7/8" BHA. FOUND BAKER FLT T/BE UPSIDE DOWN IN FLOAT SUB. C/O. PU BHA -- BREAK CIRC @ 700-1100-1500. RIH & FILL @ 4100. POH TO CHECK PACKER MW: 0.0 VIS: 0 RIH W/ 2 7/8" DRILEX MUD MOTOR, TAG CEMENT @ 11490' DRILL OUT CEMENT F/ 11490 - 11635' CIRC CUTTINGS ABOVE LINER TOP AND TEST LINER, OK. DISPLACE HOLE W/ CELAN SEAWATER. POH LAY DOWN 27 JTS PAC 2 7/8" DP. PU 59 2.75 PERF GUNS AND BLANKS. RIH 7 STANDS PAC 2 7/8" DP. FILL EVERY STAND W/ WATER. MAKE UP HES PACKER, SAFETY JT AND FAS-FILL VALVE RIH W/ 3.5" AND 5". CUT DRLG LINE. RIH W. PACKER @ 7" LINER TOP @ 8261' COULD NOT GET PACKER IN 7" LINER. MADE SEVERAL ATTEMPTS. ,~ELL : G-02A OPERATION: RIG : DOYON 14 PAGE: 6 05/28/95 (21) TD:11725 PB:l1640 05/29/95 (22) TD:11725 PB:11635 05/30/95 (23) TD:11725 PB:11635 PICKING UP 8.5" POLISH MILL MW: 0.0 POH TO 2 7/8" PAC LAY DOWN 7" CHAMP PACKER, FAS FILL VALVE, JARS AND SAFETY JT. RIH W/ 16 STDS 3.5" DP AMD MAKE UP SAFETY JT. WAIT ON HES FOR 9 5/8" CHAMP PACKER AND REBUILD FAS FILL VALVE. MAKE UP 9 5/8" PACKER, FAS FILL VALVE AND JARS, TAG UP LANDING COLLAR AND SPACE OUT TO PERF. MAKE UP MANIFOLD, SET PACKER @ 8201'. CLOSE ANNULAR PREVENTER AND FIRE GUNS W/ 2100#, GOOD BLOW, BLEED PRESSURE TO 400# AND OPEN BYPASS, REVERSE OUT, NO OIL OR GAS. POH, HOLE TAKING 90 BPH FLUID. REPAIR BROKEN BRAKE BAND. LAY DOWN 48 JTS 3.5" DP AND 21 JTS 2 7/8" PAD. LAY DOWN PERF GUNS. CLEAR FLOOR AND MAKE UP BAKER 8.5" POLISH MILL AND BOOT BASKER. NIPPLE DOWN BOPE MW: 0.0 RIH W/ 7" POLISH MILL AND BOOT BASKET. DRESS 7" LINER TOP W/ POLISH. POH 50 STANDS 5" DP. LAY DOWN REMAINING 5" AND 3.5" AND POLISH TOOLS. PULL WEAR RING, RIG UP AND RUN 240 JTS 4.5" 12.6# L-80 NSCT TBG. SPACE OUT, MAKE UP HANGER. TEST CONTROL LINES. REVERSE CIRC W/ CORROSION INHIBITOR. LAND TBG. RUN IN LDS, DROP PACKER SETTING BALL, PRESSURE UP ON TBG 4000#. SET PACKER AND TEST SAME. BLEED BACK TO 1500#. TEST ANNULUS TO 3500#, OK. BACK OUT LANDING JT. SET 2 WAY CHECK AND TEST TO 1000#. NIPPLE DOWN BOPE. RELEASE RIG MW: 0.0 NIPPLE DOWN BOPE AND NIPPLE UP ADAPTER FLANGE. TEST, OK. NIPPLE UP TREE AND TEST, OK. TEST CONTROL LINE, OK. RIG UP DSM LUBRICATOR, PULL 2 WAY CHECK, RIG DOWN LUBRICATOR. RIG UP HOT OIL SERVICE, SHEAR RP VALVE @ 2900# AND PUMP 150 BBL. DIESEL DOWN 4.5 X 9 5/8" ANNULUS. U-TUBE DIESEL BACK TO 4.5" TBG. CLEAN MUD TANKS, SECURE CELLAR AND TREE. RELEASE RIG @ 1500 ON 05/29/95. SIGNATURE: (drilling superintendent) DATE: · ~RRY-SUN DRILLING SERVICES SHARED SERVICES DRILLING PBU/G-02A 5oo292o217o1 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/28/9 ANCHO~GE ALAS~ I ~ ~ PAGE DATE OF SURVEY: ~~ MWD SURVEY ~~/~ JOB ~MBER: AK-MW-~O'J4~//t//7! KELLY BUSHING ELEV. = 7it ~~. OPE~TOR: BP EXPLO~TION ~ TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 8307 7458.10 7387.07 8400 7527.89 7456.86 8405 7531.71 7460.68 8581 7674.42 7603.39 8612 7700.49 7629.46 41 7 N 82.12 E .00 705.50N 2613.90E 2692.72 40 16 N 82.60 E .99 713.48N 2673.40E 2751.11 40 13 N 82.60 E .88 713.90N 2676.60E 2754.25 32 7 N 69.70 E 6.27 737.62N 2777.57E 2857.00 30 58 N 71.80 E 5.22 742.90N 2792.68E 2872.99 8642 7726.43 7655.40 8733 7805.92 7734.89 8828 7891.11 7820.08 8921 7975.63 7904.60 9015 8059.58 7988.55 30 36 N 70.80 E 2.09 747.86N 2807.31E 2888.43 27 0 N 70.60 E 3.97 762.30N 2848.56E 2932.11 25 12 N 74.00 E 2.47 775.02N 2888.29E 2973.76 25 30 N 70.90 E 1.45 787.09N 2926.45E 3013.71 27 38 N 69.70 E 2.36 801.27N 2965.98E 3055.69 9108 8140.99 8069.96 9201 8221.99 8150.96 9295 8303.57 8232.54 9387 8383.15 8312.12 9418 8409.21 8338.18 30 19 N 70.20 E 2.88 816.72N 3008.35E 3100.78 29 10 N 73.50 E 2.14 831.16N 3052.31E 3146.99 29 28 N 72.90 E .45 844.41N 3096.20E 3192.70 31 35 N 74.03 E 2.37 857.75N 3141.20E 3239.50 31 39 N 74.25 E .44 862.14N 3156.63E 3255.47 9433 8422.40 8351.37 9471 8454.67 8383.64 9553 8523.10 8452.07 9647 8599.22 8528.19 9710 8648.87 8577.84 31 34 N 74.75 E 1.77 864.31N 3164.46E 3263.56 32 19 N 73.02 E 3.10 869.89N 3183.79E 3283.60 34 23 N 69.06 E 3.67 884.56N 3226.35E 3328.59 37 12 N 69.30 E 3.00 904.07N 3277.66E 3383.48 39 0 N 67.53 E 3.35 918.40N 3313.86E 3422.41 9741 8672.77 8601.74 9802 8719.06 8648.03 9814 8727.76 8656.73 9844 8749.58 8678.55 9867 8765.73 8694.70 39 45 N 68.20 E 2.79 925.79N 3332.03E 3442.03 41 36 N 67.32 E 3.17 940.86N 3368.86E 3481.81 42 5 N 65.60 E 10.68 943.97N 3376.01E 3489.60 43 54 N 67.10 E 6.94 952.13N 3394.65E 3509.93 45 47 N 64.00 E 12.71 958.79N 3409.26E 3525.96 9885 8778.20 8707.17 9900 8788.58 8717.55 9932 8808.83 8737.80 9963 8827.67 8756.64 9995 8845.92 8774.89 47 24 N 62.00 E 11.91 964.77N 3421.01E 3539.08 48 26 N 57.91 E 20.73 970.53N 3430.95E 3550.42 52 4 N 55.36 E 13.05 983.93N 3451.28E 3574.21 53 35 N 55.48 E 4.85 998.04N 3471.74E 3598.38 55 40 N 56.18 E 6.87 1012.47N 3493.01E 3623.42 10026 8863.22 8792.19 10056 8878.73 8807.70 10087 8894.06 8823.03 10120 8909.34 8838.31 10150 8922.00 8850.96 57 10 N 56.18 E 4.79 1026.98N 3514.67E 3648.84 59 35 N 56.52 E 8.23 1040.95N 3535.65E 3673.44 61 30 N 56.72 E 6.12 1055.88N 3558.32E 3699.97 63 51 N 58.97 E 9.29 1071.62N 3583.36E 3728.99 65 42 N 56.64 E 9.44 1085.94N 3606.10E 3755.36 MICi OFILME JRRY-SUN DRILLING SERVICES ANCHORAGE ALAS KA PAGE SHARED SERVICES DRILLING PBU/G-02A 500292021701 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/28/9 DATE OF SURVEY: 052295 MWD SURVEY JOB NUMBER: AK-MW-50041 KELLY BUSHING ELEV. = 71.03 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10179 8933.68 8862.65 10212 8945.44 8874.41 10254 8959.12 8888.09 10283 8967.52 8896.49 10315 8974.73 8903.70 67 38 N 56.20 E 6.68 1100.93N 3628.68E 69 37 N 57.03 E 6.62 1117.46N 3653.77E 72 26 N 57.00 E 6.67 1139.14N 3687.17E 74 45 N 57.00 E 7.79 1154.69N 3711.12E 78 30 N 57.73 E 12.22 1171.03N 3736.64E 3781.82 3811.18 3850.14 3878.08 3907.77 10346 8979.98 8908.95 10378 8982.96 8911.93 10408 8984.04 8913.01 10440 8984.33 8913.30 10471 8984.72 8913.69 82 28 N 57.53 E 12.50 86 33 N 57.76 E 13.12 89 24 N 57.02 E 9.69 89 30 N 55.61 E 4.46 89 4 N 55.26 E 1.76 1187.83N 3763.13E 3938.52 1204.41N 3789.31E 3968.92 1220.83N 3814.97E 3998.76 1238.39N 3841.32E 4029.67 1256.25N 3867.24E 4060.28 10502 8985.19 8914.16 10533 8985.21 8914.18 10565 8984.82 8913.79 10595 8984.48 8913.45 10626 8984.12 8913.09 89 10 N 55.75 E 1.61 90 46 N 54.99 E 5.74 90 37 N 54.66 E 1.12 90 40 N 54.06 E 1.98 90 37 N 54.29 E .77 1273.73N 3892.68E 4090.31 1291.28N 3918.09E 4120.32 1309.82N 3944.40E 4151.54 1327.53N 3969.10E 4180.95 1345.65N 3994.20E 4210.89 10657 8983.75 8912.72 10688 8983.29 8912.26 10719 8982.52 8911.49 10750 8981.64 8910.61 10781 8981.07 8910.04 90 46 N 53.51 E 2.56 90 56 N 54.42 E 3.06 91 54 N 55.46 E 4.56 91 20 N 54.84 E 2.69 90 46 N 54.48 E 2.22 1363.94N 4019.28E 4240.88 1381.75N 4043.76E 4270.12 1399.56N 4069.14E 4300.21 1417.29N 4094.61E 4330.35 1435.07N 4119.68E 4360.14 10811 8980.33 8909.30 10842 8979.35 8908.32 10873 8978.42 8907.39 10905 8976.96 8905.93 10935 8974.94 8903.91 91 58 N 55.33 E 4.76 91 38 N 55.77 E 1.78 91 50 N 55.53 E 1.04 93 26 N 57.07 E 7.03 94 11 N 57.70 E 3.20 1452.82N 4144.94E 4390.10 1470.34N 4170.48E 4420.23 1487.55N 4195.66E 4449.92 1505.04N 4221.89E 4480.67 1521.36N 4247.39E 4510.34 10966 8972.99 8901.96 10997 8972.10 8901.07 11028 8972.45 8901.42 11060 8973.25 8902.22 11091 8973.11 8902.08 93 4 N 57.11 E 4.08 90 13 N 57.09 E 9.21 88 29 N 57.14 E 5.49 88 38 N 55.07 E 6.49 91 52 N 55.52 E 10.64 1537.91N 4273.27E 4540.44 1554.78N 4299.34E 4570.84 1571.90N 4325.83E 4601.71 1589.71N 4352.33E 4632.84 1607.21N 4377.60E 4662.71 11123 8971.70 8900.67 11153 8970.00 8898.97 11185 8969.15 8898.12 11217 8969.15 8898.12 11248 8969.15 8898.12 93 14 N 56.21 E 4.82 93 4 N 56.20 E .52 90 0 N 55.77 E 9.84 90 0 N 55.76 E .00 90 0 N 55.39 E 1.17 1624.95N 4403.77E 4693.51 1642.07N 4429.35E 4723.54 1659.75N 4455.54E 4754.33 1677.55N 4481.70E 4785.14 1695.37N 4507.71E 4815.82 °tRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/G-02A 500292021701 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/28/95 DATE OF SURVEY: 052295 MWD SURVEY JOB NUMBER: AK-MW-50041 KELLY BUSHING ELEV. = 71.03 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/NEST VERT. SECT. 11280 8968.96 8897.93 90 40 N 54.80 E 2.86 1713.37N 4533.50E 11311 8968.91 8897.88 89 30 N 55.38 E 4.13 1731.47N 4559.43E 11342 8969.04 8898.01 90 1 N 55.00 E 2.07 1749.23N 4584.99E 11373 8968.83 8897.80 90 44 N 56.12 E 4.29 1766.73N 4610.50E 11402 8968.74 8897.71 89 35 N 55.59 E 4.41 1782.72N 4634.08E 4846.36 4877.07 4907.30 4937.40 4965.15 11436 8969.06 8898.03 89 19 N 55.54 E .84 1801.99N 4662.18E 11467 8969.50 8898.46 89 4 N 55.21 E 1.32 1819.51N 4687.57E 11498 8970.00 8898.97 89 3 N 54.87 E 1.09 1837.40N 4713.14E 11529 8970.43 8899.40 89 20 N 55.13 E 1.29 1855.05N 4738.36E 11560 8970.96 8899.93 88 42 N 54.44 E 3.04 1872.91N 4763.66E 4998.31 5028.30 5058.59 5088.48 5118.50 11591 8971.68 8900.65 88 37 N 54.74 E 1.01 1890.82N 4788.85E 11620 8972.55 8901.52 88 0 N 54.14 E 2.91 1908.02N 4812.91E 11652 8973.50 8902.47 88 34 N 54.47 E 2.11 1926.51N 4838.65E 11683 8974.20 8903.17 88 48 N 53.86 E 2.11 1944.51N 4863.58E 11727 8975.12 8904.09 88 48 N 53.86 E .00 1970.33N 4898.93E 5148.45 5177.09 5207.75 5237.49 5279.76 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5280.32 FEET AT NORTH 68 DEG. 5 MIN. EAST AT MD = 11727 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 68.92 DEG. S~ ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/G-02A 500292021701 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/28/95 DATE OF SURVEY: 052295 JOB NUMBER: AK-MW-50041 KELLY BUSHING ELEV. = 71.03 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8307 7458.10 7387.07 9307 8314.45 8243.42 10307 8973.25 8902.22 11307 8968.88 8897.85 11727 8975.12 8904.09 705.50 N 2613.90 E 849.84 846.21 N 3102.07 E 993.49 143.65 1167.31 N 3730.75 E 1334.69 341.19 1729.28 N 4556.27 E 2339.06 1004.38 1970.33 N 4898.93 E 2751.88 412.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. .IRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/G-02A 500292021701 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/28/95 DATE OF SURVEY: 052295 JOB NUMBER: AK-MW-50041 KELLY BUSHING ELEV. = 71.03 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8307 7458.10 7387.07 705.50 N 2613.90 E 849.84 8325 7471.03 7400.00 707.05 N 2625.08 E 854.08 4.24 8455 7571.03 7500.00 718.88 N 2707.99 E 884.54 30.46 8577 7671.03 7600.00 736.91 N 2775.52 E 906.64 22.10 8693 7771.03 7700.00 756.20 N 2831.19 E 922.73 16.09 8805 7871.03 7800.00 772.41 N 2879.21 E 934.86 12.14 8916 7971.03 7900.00 786.38 N 2924.38 E 945.49 10.62 9028 8071.03 8000.00 803.36 N 2971.66 E 957.41 11.93 9143 8171.03 8100.00 822.67 N 3024.88 E 972.34 14.93 9258 8271.03 8200.00 839.00 N 3078.61 E 987.04 14.70 9373 8371.03 8300.00 855.70 N 3134.03 E 1002.60 15.56 9491 8471.03 8400.00 873.05 N 3193.76 E 1020.37 17.77 9612 8571.03 8500.00 896.64 N 3258.05 E 1041.59 21.22 9739 8671.03 8600.00 925.26 N 3330.69 E 1068.49 26.90 9874 8771.03 8700.00 961.34 N 3414.26 E 1103.83 35.33 10041 8871.03 8800.00 1033.90 N 3525.03 E 1170.13 66.31 10298 8971.03 8900.00 1162.33 N 3722.99 E 1327.42 157.29 10327 8977.12 8906.09 1177.80 N 3747.33 E 1350.82 23.40 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL To: State of Alaska August 26, 1995 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive ~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs G~02A, AK-MW-50041 REi The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Neutron and Gamma Ray Logs: 50-029-20217-01 1 Blueline 1 Rev Folded Sepia 2" x 5" TVD Neutron and Gamma Ray Logs' 50-029-20217-01 1 Blueline 1 Rev Folded Sepia 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20217-01 1 Blueline 1 Rev Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs' 50-029-20217-01 1 Blueline 1 Rev Folded Sepia ~,~j~~Aiaska 01t & Gat; Cons. Commission Anchora9.o 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ALASKA OIL ~ GAS CONSERV~XTION COM~HSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 6, 1995 Terry Jordon, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit G-02A BP Exploration (Alaska) Inc 95-23 2163'SNL, 1974'WEL, Sec 12, T11N, R13E, UM 387'SNL, 2275'WEL, Sec 7, T11N, R14E, UM Dear Mr Jordon: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the Nodh Slope pager at 659-3607. Yours t[uly, .~..~. - .. ---_.... ~, ~...,, ~ ~, David W. Jbhnston Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ..... ~' STATE OF ALASKA ALASK,, ~,.,~,L AND GAS CONSERVATION C~,~,..,,IlSSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratoryi-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163'SNL, 1974' WEL, SEC. 12, T11N, R13E At top of productive interval IO05'SNL, 3101' WEL, SEC. 7, T11N, R14E At total depth 387' SNL, 2275' WEL, SEC. 7, T11N, R14E 12. Distance to nearest property line ADL 28303-2275' feet 13. Distance to nearest well No close approach feet 6. To be completed for deviated wells Kickoff depth 8500 feet Maximum hole angle 5. Datum Elevation (DF or KB) KBE = 74' feet 6. Property Designation ADL 28304 7. Unit or property Name Prudhoe Bay Unit 8. Well number G-O2A 9. Approximate spud date 4/18/95 14. Number of acres in property 2560 10. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 11. Type Bond(see 20 AAC 25.025) :18. Casing program size Hole Casing 8-1/2" 7" 6" 4-1/2" Specifications Weight I Grade Coupling 29# I L-80 NSCC 1216# IL-80 NSCT ILength Number 2S 100302630-277 Amount $200,000.00 5. Proposed depth (MD and TVD) 11339' MD/8892' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ° I Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig Quantity of cement M D TVD (include stage data) 10431' 8982' 494 cuft Class "G" 11420' 8960' 191 cuft Class "G" REC'E:iV'£D FEB 2 2 1995 Alaska 0ii & Gas Cons. Commission Anchora ~ Fill @ 10230' (7/86) Setting Depth Bottom True Vertical depth Top MD I TVD 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10350 feet Plugs (measured) true vertical 9099 feet Effective depth: measured 10230 feet Junk (measured) true vertical 8994 feet Length Size Cemented Measured depth 110' 20" x 30" 8 cu yds 137' 137' 2657' 13-3/8" 5471 cuft 2684' 2684' 9284' 9-5/8" 1844 cuft 9311' 8242' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 1556' 7" 540 cuft 8794'- 10350' 7832;9099' measured 10123'-10130'; 10140'-10160'; I0172'-10192'; 10212'-10220'; 10228'-10234' Squeezed: 10038'-10073'; 10088'-10100' true vertical (subsea) 8851'-8947' (five measured intervals) 8779'-8832' (two squeezed intervals) '20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-1 20 AAC 25.050 requirementsl-] 21. I hereby certi,,~ that ~thtp%foreg~oing is trUe and correct to the best of my knowledge Signed '~/_~,/,&//~~'~- Title Drilling En~tineerSupervisor --~ Commission Use Only Permit Number --APl number Approval date Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes l~ No Hydrogen sulfide measures [] Yes .l~ No Directional survey required [] Yes [] NO Required working pressure foD~¢~~ S[~j~Y~d; t~1~, 3M: ~;LSM' []10M: []15M; Other: David W. Johnston by order of Approved by Commissioner tne commission See cover letter for other requirements Date Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: I G-02A Redrili Plan Summary IType of Redrill (producer or injector)' PRODUCER Surface 2163' FNL & 1975' FEL Sec. 12 T11N R13E Location: Target Location: 1005' FNL & 3101' FEL Sec. 7 T11N R14E Bottom Hole 387' FNL & 2275' FEL Sec 7 T11N R14E Location: AFE Number: 4P0659 Estimated Start 4/18/95 Date: lIVID: 111420' I IRig: I DOYON RIG #14 Operating days to complete: 22 I TVD: 18960' I KBE 174 Well Design (conventional, slimhole, etc.): HORIZONTAL SIDETRACK I Objective: I SADLEROCHIT ABNORMAL PRESSURE Special design considerations 3492 psi @8800' TVD,8.6 ppg EMW Mud Pr°g'ram: An 9.0 ppg mud will be used. Special design considerations hErE G-02A Redrill Plan Summary RECEIVED FEB 2 2 1995 Oil & Gas Cons. Commission Anchora ¢ Page 1 Depth Densi PV YP INT 10MIN FL OIL SOLID (TVD) ty (CP) (#/FT GEL GEL cc/30 (%) S (PPG) ) min (%) KOP' 10.0 10 15 5 10 5 0 5 to to to to to to to to to 10431 10.2 18 30 15 30 7 0 10 10431' 9.0 10 45 5 10 5 0 5 to to to to to to to to to 11420' 9.0 15 50 15 30 7 0 10 Directional: I KOP- i 500' Maximum Hole Angle: Close Approach Well: 90° The above listed wells will be secured during the close approach. Casing/Tubing Program: Hole Csg/ WtJFt Grade Conn Length Top Btm Size Tb9 O.D. MD/TVD MD/TVD 8 1/2" 7" 29.0 L-80 NSeC 2081 8350/7488 10431/8982 6" 4 1/2" 12.6 L-80 NSCT 2049' 10281/8972 11420/8960 N/A 4 1/2" 12.6 L-80 NSCT 8300 0/0 8300/7450 G-02A Redrill plan Summary RECEIVED FEB 2 2 i995 A~ska 0il & Gas Cons. Commission Anchora "- Page 2 Cement Calculations: Basis: Liner 17", Size: 29#, L-80, NSCC 50% open hole excess, 80' shoe joint, 150' liner lap (7"), and 200' excess above liner top. Total Cement Volume: i Bbls 88 Liner 4 1/2", 12.6#, L-80, NSCT Size: Basis' 50% open hole excess, 80' shoe joint, 150' liner lap (7"), and 200' excess above liner top. Total Cement ! I Volume: Bbls 34 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AC)GCC. Hazards and Contingencies Mud weights should be kept to a minimum while drilling through the horizontal section (_+9.0 ppg) to prevent differential sticking. With 9.0 ppg the hydrostatic is 4118 psi which is well over the 3492 psi formation pressure. RECEIVED FEB 2 2 1995 Oil & Gas Cons. Commission Anchor~. ,: G-02A Redrill Plan Summary Page 3 SUM . , 3. 4. 5. 6. 7. . 10. 11. 12. 13, 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. MARY PROCEDURE Pre-rig work. Bullhead down well to ensure that it is dead. Verify that sliding sleeve at 10,146' is open, RU wireline and shoot a 2' gun (4 spf) @ 10125', RU coiled tubing and lay a cement plug from _+10,304' to _+8800'. Squeeze away cement to push the cement top down to _+10000 Then jet cut tubing at _+8730' just below the 'SWS' nipple at 8723' and above the 9 5/8" packer at 8735'. Circulate well over to seawater. Freeze protect well with diesel to 2000' and set a BPV. (See well diagram) Move in drilling rig. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and tree test plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 4 1/2", 12.6#, L-80, TDS tubing. PU 9 5/8" section mill and RIH to _+8730 and spot 13 bbls of 17 ppg mud from 8730' to 8550', pull mill to 8550' and displace well to FLO-PRO/milling fluid. Pull section mill to _+8500 and cut a 50' section in the 7'-- casing starting from +8500' to 8550'MD. POOH RIH with openended drill pipe and lay a plug back/kickoff plug from 8650' to 8300' Run in with a 6 3/4" steerable drilling assembly and a 8 1/2" bit with gamma ray/directional MWD. Contact AOGCC to witness tag of cement for abandonment purposes. Dress the cement to 5' below the section top. Kickoff and if necessary displace well to clean FL©-PRO system. Continue to directionally drill to the 7" casing point at 10431' MD_+ at 91.3° (see attached directional plan). Make a conditiOning trip with an 8 1/2" hole-opener for the open hole section and with a 7" casing scraper spaced to clean the casing. Install a 7_" 29#, L-80, NSCC SOLID liner with 9 5/8" X 7" packer/hanger. Space packer / hanger to be set at +8350' md. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the 80' shoe volume, 7"X 9 5/8" lap volume, and 150' excess on top of the liner with drillpipe in the hole. PU 4 3/4" directional drilling assembly and drill horizontal section to 11420' MDTD. Install 4 1/2",12.6#,L-80,NSCT liner and cement in place. PU cleanout assembly and clean out 4 1/2" liner to landing collar. Test casing to 3500 psi, RIH with drillpipe conveyed perforating assembly and perforate the well. POOH LDDP. Run the 4-1/2", 12.6#, L-80, NSCT completion string assembly using as much 4-1/2" used tubing and jewelry as possible. Space out and circulate with corrosion inhibitor. Install a BPV and test plug. Remove BOP's. .Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Set packer. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production. RECEIVED FEB 2 2 1995 A!~ska. 0il & Gas Cons. Commission Anchor~.- -. G-02A Redrill Plan Summary Page 4 FEB 22 1995 .0ii & Gas Cons. Commission , ~. chore~:".'~ '~X-Sho, r-,ed Ser"vices Dr'"ittlng o. sl<o. S't:o.-t:e PLo. ne: Zone4 t~tJ: WOA: G-Pod ...n~^ (f""r')'% .............. L.~....; ? IIALLI~JRtLIN FrRtZEINT~L VIEW (TRt£ I~TRTH) SC/~_E 250 rt. / DIVISI[~I SLRVEY REF: 14ELLI £AD '-'L)2A ~dp ! ............ I/26/95 1 O: 34 , . V(~IIC~ S~ll~ k~r: WELLICAD t'-~N 30.33 ~ 85~ MD Km/ TIE IN / INTER~ATED ~INT / . , i ........................ ~,% (~..,? ~eco.~g..,,, I '~:.:,,~ ........... ~' '"':~ :"'~ '~"~ ' .... ~ ~ ) -~ .... J ..... u:'~---~'~59~ ~ 005.1 HI) END ~ CL~V[ , ~ I ~ ~ ~ ~ ~ ~ . ' ................ ox ~ b' I I 0 ............... ' .......... ~ ....................................... ~-~ L t'.~--i.,:~.,'w ~,., I'~~ I ~ga7~q- ,Z gl.~ ~ ~1~ HD To~t Pont vFRI IC~. SECTI~ l't~:: 60 ~ -~ ~ 4~ --1550 STATE Of ALASKA A!-~-q,~,A OIL AND GAS CONSERVATION COMMI, APPLIC,.. FOR SUNDRY ALS 1. Type of Request: Abandon x . Suspend Alter casing Repair well Change approved program . Operation Shutdown . . Re-enter suspended well ~ Plugging ..z__ 'Time extension _ Slimulale ~ Pull tubing, Vadance . Pi]dorate X Olher ~ . Pluf~back for redrill 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2163' SNL, 1974' WEL, SEC. 12, T11N, R13E, UPM At top of productive interval 1457' SNL, 1455' EWL, SEC. 07, Tl 1N, R14E, UPM At effective depth 1592' SNL, 1753' EWL, SEC. 07, Tl 1N, R14E, UPM At total depth 1618'SNL, 1807'EWL, SEC. 07, T11N, R14E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED FEB 2 2 1995 Alaska 0ii & 8as Cons. C0mmlsslon Anchore -", 6. Datum elevation (DF or KB) KBE = 61.60 AMSL 7. Unit or Property name Prudhoe Bay Unit 8. Well number G-02 (22°07-11-14) PBU 9. Permit number 76-50 10. APl number 50- 029-20217 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured true vedical Effective depth: measured true vertical Casing Length Structural -- Conductor 110' Surface 2657' Intermediate 9284' Production -- Liner 1556' Perforation depth: 10350 feet Plugs (measured) 9099 feet BKB 10230 feet Junk (measured) 8994 feet BKB Size Cemented 20"x 30" 8 cu yds 13-3/8" 5471 cuft 9-5/8" 1844 cuft fill at 10230' (07/86) Measured depth 137' 2684' 9311' 7" 540 cu ft 8794'- 10350' measured 10123'-10130~ 10140'-10160'; 10172'-10192~ 10212'-10220'; 10228'-10234' Squeezed: 10038'- 10073'; 10088'- 10100' true vertical (subsea) 8851;8947' (five measured intervals) 8779;8832' (two squeezed intervals) Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 10180' True vertical depth BKB 137' 2684' 8242' 7832L9099' Packers and SSSV (type and measured depth) 7" TIW HBBP PKR @ 10171'; 7" TIW HBBP-R PKR @ 10135'; 9 5/8" TIW HBBP-R PKR @ 8736'; 4 1/2" SSSV @ 2120' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 3/15/95 .... 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that thel~orego, ing is true and correct to the best of my knowledge. Signed ¢¢~/ /~ Title DrillingEngineerSupervisor FOR COMMISSION USE ONLY Date / I' Conditions of approval: Notify Commission.,.Sc--represen_~ti Plug integrity ~ Mechanical Inte~[ . ~ ~_ FAoP Pr~nr~e. d40b; I~ redve~ ~lt~/% 8C ° m m is s i° ~--.-K'~~ '~,,,,,~ioner ~ Ill , i ii, IApproval No.~,, Cb ~L~ .L PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev [] redrll~ serv [] /'/~JO ON/OFF SHORE ~/tJ 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ENGINEERING APPR Conductor string provided ................ Y Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf csg.. Y CMT vol adequate to tie-in long string to surf csg . . . Y 14. N 15. 16. 17. N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ............. _~. ....... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... .-~~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis 9f shallow gas zones .......... y N 33. Seabed condition survey (if off-shore) ....... /Y N 34. Contact name/phone for weekly progress reports . . ./% . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: ~,W/jo - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ubfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 6543.00 T. MCGUIRE D. WESTER G-02A 500292021701 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 19-DEC-95 MWD RUN 3 T. MCGUIRE D. WESTER MWD RUN 4 T. MCGUIRE D. WESTER MWD RUN 5 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 REMARKS: T. MCGUIRE D. HEIM MWD RUN 6 T. MCGUIRE D. HEIM 12 liN 13E 2163 1974 71.03 69.53 35.17 JAN 0 8 1996 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2693.0 9.625 8400.0 8.500 7.000 10265.0 6.000 11727.0 MWD - DGR/CNP/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. AV/CV CALCULATED USING THE POWER LAW. MWD RUN I WAS DGWD DIRECTIONAL ONLY. I IC OFILME MWD RUNS 2 - 4 WERE DGWD DIRECTIONAL WITH DUAL GAMMA RAY (DGR) & COMPENSATED NEUTRON POROSITY (CNP). MWD RUNS 5 & 6 WERE DGWD DIRECTIONAL WITH DUAL GAMMA RAY (DGR) & SLIM PHASE 4 RESISTIVITY (EWR4). CNP PROCESSING PARAMETERS: SANDSTONE MATRIX, 8.5" BOREHOLE SIZE, 11~500 PPM Cl FORM SALINITY NO DEPTH SHIFTS WERE DONE AS THIS IS THE DEPTH REFERENCE FOR THIS WELL. THERE ARE TWO TYPES OF GR CURVES. MWD RUNS 2, 3, 4, 5, & 6 HAVE THE FE/DGR RECORDED TOOL. MWD RUN 6 ALSO HAS A GAMMA RAY FROM THE DGWD/NGP REAL TIME TOOL. THE GR FROM THE DGR IS PREFERRED IF IT IS AVAILABLE. THE MERGED GR CURVE WAS SPLICED USING: 9379 - 11648' --> DGR (MWD RUNS 2 - 6) 11648 - 11678' --> NGP (MWD RUN 6). ,.~E HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR NPHI $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9379.0 11678.0 10240.0 11656.0 9372.0 10176.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 9511.0 9840.0 3 9840.0 9936.0 4 9936.0 10265.0 5 10265.0 11385.0 6 11385.0 11727.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHM~ NPHI MWD 68 1 PU-S FCNT MWD 68 i CPS NCNT MWD 68 i CPS 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 4 90 334 31 1 4 90 334 30 1 9 ROP MWD 68 1 FPHR 4 10 FET MWD 68 1 HR 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 206 4 90 810 01 4 90 180 01 4O Tape File Start Depth = 11730.000000 Tape File End Depth = 9370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51932 datums Tape Subfile: 2 312 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes ope Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 9379.0 CNP 9372.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9779.0 9772.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15-MAY-95 MSC 1.32 / ADAC 2.19A NGP 5.741 / CIM 3.94 MEMORY 9840.0 9511.0 9840.0 0 25.2 67.6 TOOL NUMBER P0371CRNG6 P0371CRNG6 8.500 8400.0 BIOPOLY 10.10 74.0 9.8 12100 4.4 .000 .000 .000 .000 .0 154.0 .0 .0 SANDSTONE .00 8.500 .0 0 RRMAi~S: CN WN FN COUN STAT MWD RUN 2. $ : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 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 GR MWD 68 1 AAPI 4 2 NPHI MWD 68 1 PU-S 4 3 FCNTMWD 68 1 CPS 4 4 NCNT MWD 68 1 CPS 4 5 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 810 O1 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 9845.000000 Tape File End Depth = 9370.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5707 datums Tape Subfile: 3 88 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes .pe Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 9764.0 CNP 9756.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9859.0 9851.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS ~_ MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLF. CORRF. CTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 16-MAY-95 MSC 1.32 / ADAC 2.19A NGP 5.741 / CIM 3.94 MEMORY 9936.0 9840.0 9936.0 0 43.9 52.1 TOOL NUMBER P0371CRNG6 P0371CRNG6 8.500 8400.0 BIOPOLY 10.10 78.0 9.0 13750 11.0 .000 .000 .000 .000 .0 141.6 .0 .0 SANDSTONE .00 8.500 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 NPHI MWD 68 1 PU-S 3 FCNT MWD 68 1 CPS 4 NCNT MWD 68 1 CPS 5 ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: 10 1014 BYTES * API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 890 01 1 4 4 90 334 31 1 4 4 90 334 30 1 4 4 90 810 01 1 20 Tape File Start Depth = 9940.000000 Tape File End Depth = 9750.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54219 datums Tape Subfile: 4 75 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~pe Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 9850.0 CNP 9850.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10184.0 10176.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 17-MAY-95 MSC 1.32 / ADAC 2.19A NGP 5.741 / CIM 3.94 MEMORY 10265.0 9936.0 10265.0 0 53.6 69.6 TOOL NUMBER P0371CRNG6 P0371CRNG6 8.500 8400.0 BIOPOLY 10.10 78.0 9.0 10500 21.0 .000 .000 .000 .000 .0 160.0 .0 .0 SANDSTONE .00 8.500 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 4. $ : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE .' ALASKA * FORMAT RECORD (TYPE# 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 GR MWD 68 1 AAPI 4 2 NPHI MWD 68 1 PU-S 4 3 FCNT MWD 68 1 CPS 4 4 NCNT MWD 68 1 CPS 4 5 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 810 01 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 21 Tape File Start Depth = 10270.000000 Tape File End Depth = 9845.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10814 datums Tape Subfile: 5 86 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~pe Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 10018.0 EWR4 10025.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11305.0 11312.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 21-MAY-95 MSC 1.32 / ADAC 2.19A NGP 5.741 / CIM 3.94 MEMORY 11385.0 10265.0 11385.0 0 74.8 90.0 TOOL NUMBER P0002SP4 P0002SP4 6.000 10265.0 BIOPOLY 10.40 105.0 9.8 28250 62.0 .150 .076 · 140 .220 86.0 176.0 86.0 86.0 .00 .000 .0 0 REMk¥~KS: CN WN FN COUN STAT MWD RUN 5. $ : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR 7 FET MWD 68 1 HR 4 4 90 310 01 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 810 01 1 4 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 89 Tape File Start Depth = 11390.000000 Tape File End Depth = 10015.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 76228 datums Tape Subfile: 6 154 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Ape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH DGR 11305.0 EWR4 11312.0 NGP 11336.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11649.0 11656.0 11678.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 22-MAY-95 MSC 1.32 / ADAC 2.19A NGP 5.741 / CIM 3.94 MEMORY 11727.0 11385.0 11727.0 0 88.0 90.7 TOOL NUMBER P0002SP4 P0002SP4 6.000 10265.0 BIOPOLY 10.60 70.0 8.8 30100 97.0 .140 .077 .120 .200 94.0 176.0 94.0 94.0 .00 .000 TOOL STANDOFF (IN) : .0 FREQUENCY (HZ): REMARKS: CN WN FN COUN STAT MWD RUN 6. THE CURVE "GRD" IS THE GAMMA RAY FROM THE NGP TOOL. $ : BP EXPLORATION (ALASKA) : G-02A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR 7 FET MWD 68 1 HR 8 GRD MWD 68 I AAPI 4 4 90 310 01 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 810 01 1 4 4 90 180 01 1 4 4 90 310 01 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 31 Tape File Start Depth = 11730.000000 Tape File End Depth = 11300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18564 datums Tape Subfile: 7 98 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes .pe Subfile 8 is type: LIS 95/12/18 01 **** REEL TRAILER **** 95/12/19 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 19 DEC 95 1:57p Elapsed execution time = 2.14 seconds. SYSTEM RETURN CODE = 0