The URL can be used to link to this page

Home My WebLink About199-076XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete 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: Beverly Mildred Daretha~owell Date: ¢~'/~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: ~si ) STATE OF ALASKA ) ALASKA 01L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission Anchorage ,'I No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged a Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 Memory Induction, GR, Temp CASING, LINER AND CEMENTING RECORD "~I "." ". ..,' ',. I,: "."":' ,',' :$~ltJr::tr:\eF!1""'MI¡¡' "SEJJlIN~,',n¡;f!;I1ij1'~p"" 'I' .i <I!j'" """"""". ",' ;,llli:'I::'I:' I,'::. 1'1 ::,,1,1; :'i!"I'!,,'I:,'lil'!" : 1,1;11 ~'II: 11,,' "~'~I':~,I,~,, :,1'~I:,:'~:, ., "~'II,"'," 11"..":.,,,' """i~':"1 ""I, !,:, ,I~I ':, ' 'II~'" :'~~',I ',',II,:." I." , ,I::~i i':':;:'::I:':I~:ø,~,e':,!: ':"!II~ !,:'I'i'!,'ßfØ:~~:",II·I', ,i,' i:" ::,:f:dRil,'!!i"I: :i:B:Qm;¡¡~:íM,I'li,:¡,:;'1;Ö~I:'I:;li:¡J j'B,Ø:¡;[OM,,'i '¡i,I::¡,'sI,lei,i',i,I', Conductor Surface 110' Surface 110' 36" 8 cu yds Concrete L-80 Surface 2685' Surface 2685' 17-1/2" 3746 cu ft Permafrost 'E' and II L-80 Surface 8889' Surface 8812' 12-1/4" 1740 cu ft Class 'G', 279 cu ft PF L-80 8381' 8922' 8343' 8843' 8-1/2" 271 cu ft Class 'G' L-80 8358' 10972' 8322' 9018' 3-3/4" 129 cu ft Class 'G' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 103' FSL, 1663' FEL, SEC. 18, T11N, R13E, UM Top of Productive Horizon: 569' FSL, 1485' FEL, SEC. 18, T11N, R13E, UM Total Depth: 643' FNL, 2538' FEL, SEC. 19, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 632339 y- 5960690 Zone- ASP4 TPI: x- 632507 y- 5961159 Zone- ASP4 Total Depth: x- 631480 y- 5959929 Zone- ASP4 18. Directional Survey 0 Yes a No 21. Logs Run: MWD, GR, ROP, 22. :,:: ,!:'I C~$:I,N~I:" ,I!': I: 'I. I<",',i :il,';; ::$~~,~,~I·~"'I;I ::~II!,:,' 'I::, 20" x 30" 13-3/8" 9-5/8" Insulated 72# 47# 26# 6.16# 7" 2-7/8" 23. Perforations ORen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD c"C' h.. !i\iiil.kE"'D 0!1 ,1 200h "~, t'·U~ P! ,,',)).J U L J.., ,~¡.: ._.. . ..J MD 26. Date First Production: Not on Production Date of Test Hours Tested Zero Other 5. Date Comp., Susp., or Aband. 4/23/2005 6. Date Spudded 07/29/1999 7. Date T.D. Reached 07/31/1999 8. KB Elevation (ft): 84.3' 9. Plug Back Depth (MD+ TVD) 10912 + 9014 10. Total Depth (MD+TVD) 10972 + 9018 11. Depth where SSSV set I N/A MD 19. Water depth, if offshore N/A MSL REC£:jVi!:O JUL 1 2 2005 1b. Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number ßPO /' 199-076 305-084 1·'S·O ~ 13. API Number 50-029-21117-01-00 14. Well Name and Number: PBU U-06A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028283 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ,:I:'A:MQP~ill:¡",\ ~:~~:'I! !"~'U~~réD:::: ;1:, SIZE 4-1/2", 12.6#, L-80 TVD 25~,I,1' DEPTH SET (MD) 3237' - 8413' PACKER SET (MD) 8323' · .,".' ,',::: .·.·1'" ';ÄbIIID;:FRÂ8TU,RE;CEM,ENT 's6bèEiE;' ETC, ,", ·.I.I'!,::; ,"'I"',' ,I', I, ,,' ", "" ",'" "" ""1"',,1,, 'I, ',', ,I ,,'" '","1","" 'I :1:::i;,':':I:,:;"'; I,: ;:;1," DEPTH INTERVAL (MD) 7296' 2980' AMOUNT & KIND OF MATERIAL USED P&A w/ 36 Bbls Class 'G' Set EZSV with Whipstock on Top PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL-BsL PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE 27. GAs-McF WATER-BSL CHOKE SIZE GAS-OIL RATIO GAs-McF WATER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBOMS . BFt JUL 1 3 Z005 None Form 10-407 Revised 12/2003 ORiGiNAL CONTINUED ON REVERSE SIDE (]f ) ) 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik A 8946' 8866' None Shublik B 8980' 8896' Shublik C 9015' 8925' Sadlerochit 9045' 8949' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~Q/1^Ù, fL~ ---- PBU U-06A 199-075 305-084 Well Number Title Technical Assistant Date b7.., &--05 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer : Terrie Hubble, 564-4628 Ken Allen, 564-4366 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 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ) \Nell: Field: API: Permit: U-06B Prudhoe Bay Unit 50-029-21117 -02-00 205-064 Accept: Spud: Release: Rig: 04/27/05 05/01/05 05/11/05 Nabors 7ES Accept: Spud: Release: Rig: OS/22/05 N/A 06/08/05 Nabors 2ES PRE-RIG WORK 04/12/05 DRIFTED WI 2' STEM, 2.25" CENT, SAMPLE BAILER TO 8996' SLM (30 DEGREE DOGLEG). SAMPLE BAILER CAME BACK EMPTY. 04/23/05 BLEED IA DOWN FLOWLINE, FREEZE PROTECT FL. KILL TUBING WI 224 BBLS 1% KCL DOWN TUBING. RIH WI 2" BDN. FOUND HARD CEMENT IN CHOKE ON SQUEEZE SHACK. STAND FOR NEW CHOKE & REVERSE MANIFOLDS TO REPLACE SQUEEZE SHACK. HAD LEAK FROM SQUEEZE MANIFOLD'S CONTAINMENT SUMP. AN ICE PLUG IN THE SUMP DRAIN MELTED +1- .5 GL ON GROUND DUE TO MISSING DRAIN CAP. REPORTED TO SRT. TAG TD AT 10956' CTM (RESET COUNTER TO 10912'). LAY IN 36 BBLS OF 15.8# CLASS G CEMENT FROM 10902' TO 6980' CTMD. CLEAN OUT TO 7290'. EST TOC = 7290' CTMD. FREEZE PROTECT TUBING FROM 2200' TO SURFACE. TRAP 480 PSI ON WHo JOB COMPLETE. 04/24/05 TAG HARD CEMENT PLUG TOP AT 7296' WLM W/3.25" CENT & SB. DRIFTED TO 3400' WI 3.72" CENT I TESTED TBG FOR SIDETRACK WORK. CUT TUBING AT 3237' (REF TBG TALLY) MID JOINT WITH 3.65" SCP JET CUTTER. ) ) BP EXPLORATION Qperations,·SummaryjReport Page 1 .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2005 00:00 - 04:00 4.00 MOB P PRE Move pits and position to install moving jeep, prepare sub for derrick down move, pull sub off well and position to lay down derrick, move satilite camp from P2-Pad to U-Pad. Lay down derrick and prepare Sub & Pits for move. 04:00 - 22:00 18.00 MOB P PRE Move Sub, Pits and remeainder of rig equipment from Pt. Mac 2 to U-Pad 22:00 - 00:00 2.00 RIGU P PRE Lay matting boards & herculite around cellar, spot sub over well U-06 @23:15 hrs, build berms, prepare to raise derrick. 4/27/2005 00:00 - 01 :00 1.00 RIGU P PRE Raise derrick, continue to rig-up on U-06a. (Pre-spud meeting at 23:30 hrs on 4/26/05 during pre-tour meeting.) 01 :00 - 02:00 1.00 RIGU P PRE Bridle down, bridle up top-drive. 02:00 - 04:00 2.00 RIGU P PRE Move in pits, hang bridle lines in derrick. 04:00 - 04:45 0.75 WHSUR P DECOMP Accept rig at 04:00 hrs, pull BPV w/lubricator (DSM), take on seawater in pits. 04:45 - 06:00 1.25 WHSUR P DECOMP RU to displace well, finish loading pits w/8.5 ppg seawater. 06:00 - 06:30 0.50 WHSUR P DECOMP Test gas alarms. 06:30 - 10:30 4.00 WHSUR P DECOMP Displace well with seawater, gas encountered (circ through choke), pump 380 bbls seawater, monitor well to ensure well is "dead", pressure test well to 3500 psi, test good. 10:30 - 12:00 1.50 WHSUR P DECOMP Function all LOS's on tubing and casing spools. 3 LOS on tubing spool frozen in locked position. Test 9 5/8" packoff - failed. Test Tubing Hanger - OK. 12:00 - 13:45 1.75 WHSUR P DECOMP Work on siezed tubing head LOS, set TWC & test to 1000 psi f/below, blow down lines. 13:45 - 14:45 1.00 WHSUR P DECOMP NO tree & adapter flange. 14:45 - 15:45 1.00 WHSUR P DECOMP Cut & grind down siezed tubing head LOS's. 15:45 - 18:00 2.25 BOPSUF P DECOMP NU BOPE. 18:00 - 18:30 0.50 BOPSUP P DECOMP RU to test BOPE, tighten leaking gland nuts. 18:30 - 23:30 5.00 BOPSUP P DECOMP Test BOPE & choke manifold 250/3500 psi (All tests witnessed by J. Rose - Wellsite Leader & C. Weaver NAD Tool Pusher I witness waived by AOGCC (John Spaulding). 23:30 - 00:00 0.50 BOPSUF P DECOMP RD testing equipment & blow-down linesrrD. 4/28/2005 00:00 - 00:30 0.50 PULL P DECOMP Pulled TWC (wllubricator - DSM). 00:30 - 01 :00 0.50 PULL P DECOMP MU landing joint to pull tubing. 01 :00 - 01 :30 0.50 PULL P DECOMP Back-out LOS's. 01 :30 - 02:30 1.00 PULL P DECOMP Pulled tubing free (80K Ibs), circulate well surface to surface plus wlpumping surfactant wash to clean well (well cleaned-up), 11 bpm, 200 psi. 02:30 - 03:00 0.50 PULL P DECOMP LD landing joint, disconnect control line, LD tubing hanger. 03:00 - 06:00 3.00 PULL P DECOMP POOH w/50 joints 4 1/2" tubing & control line (26 rubber protectors + 2 steel bands recovered from string). 06:00 - 06:30 0.50 PULL P DECOMP Cut control line from SSSV and RD spooling unit. 06:30 - 08:00 1.50 PULL P DECOMP POOH with total of 76 full joints of 4 1/2" tubing, clean rig floor. 08:00 - 09:00 1.00 DHB P DECOMP RU to run E-Line. 09:00-10:15 1.25 DHB P DECOMP RIH & POOH w!unk basket, 8 1/2" guage ring and gamma ray to 3175'. 10: 15 - 11 :30 1.25 DHB P DECOMP LD gauge ring and basket, change head on wireline unit, MU EZSV bridge plug. . 11 :30 - 13:30 2.00 DHB P DECOMP RIH wlCCL and set EZSV on wireline at 2980'. 13:30 - 14:30 1.00 DHB P DECOMP Pressure test casing t/3500 psi f/30 min (OK), blow down lines. Printed: 6/13/2005 11: 1 0:39 AM ') ) BP EXPLORATION Operations Summary Report Page 2 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 Date From- To Hours Task Code NPT Phase Description of Operations 4/28/2005 14:30 - 16:00 1.50 BOPSUP P DECOMP PU 42 joint of 5" drillpipe fl RTTS packer. 16:00 - 18:00 2.00 BOPSUP P DECOMP PU & M/U RTTS and set at @40', RU & test lower pipe rams 250 psi, pipe began to hydraulic out 2200 psi, Bleed pressure, pick up & check RTTS - OK. Reset RTTS at 40' and tested flabove to 1000 psi. 18:00 - 19:45 1.75 BOPSUPP DECaMP NO BOP stack. 19:45 - 21 :30 1.75 BOPSUP P DECaMP CO tubing spool and 9 5/8" pack-off & tested pack-off to 5000 psi. 21 :30 - 00:00 2.50 BOPSUP P DECaMP NU BOP stack. 4/29/2005 00:00 - 02:00 2.00 BOPSUr; P DECaMP Continue to NU BOP's. 02:00 - 03:00 1.00 DHB P DECOMP RU & test lower pipe rams and flanges to 250 low/3500 high (leaking gland nuts - required some tightening), RD testing equipment. 03:00 - 03:15 0.25 DHB P DECaMP Install wear bushing. 03:15 - 04:30 1.25 DHB P DECaMP Retrieve storm packer (no pressure below packer) and LD all equipment. 04:30 - 05:15 0.75 STWHIP P WEXIT POOH 14 stands 5" drillpipe. 05:15 - 12:30 7.25 STWHIP P WEXIT PU and rack-back 53 stands of 5" drillpipe. 12:30 - 15:00 2.50 STWHIP P WEXIT PU and RIH w/90 joints of 5" drillpipe. 15:00 - 16:30 1.50 STWHIP P WEXIT Cut 105' of drilling line. 16:30 - 18:15 1.75 STWHIP P WEXIT POOH and rack-back 30 stands of 5" drillpipe. 18:15 - 19:15 1.00 STWHIP P WEXIT PJSM, RU Gyro Data and Sperry E-Line. 19:15 - 22:00 2.75 STWHIP P WEXIT PU and rack-back 5 stands of HWDP and 9 drill collars. 22:00 - 00:00 2.00 STWHIP P WEXIT PJSM, PU whipstock mill assembly. (NOTE: Pre-Spud meeting at tour change for new crew at 23:30 hours.) 4/30/2005 00:00 - 03:00 3.00 STWHIP P WEXIT RIH wlwhipstock to 2944' (2 min/stand). 03:00 - 08:30 5.50 STWHIP P WEXIT At 36' above EZSV, oriented the whipstock to 328.5 degrees w/#1 gyro. The #2 gyro tool malfunctioned and could not confirm whipstock orientation and was pulled out of the hole f/service. While work on #2 gyro, PU single joint of drillpipe and a 10' pup and tagged the top of the EZSV at 2980'. Both gyro's were then run to confirm the final whipstock orientation at 321 degrees. 08:30 - 09:30 1.00 STWHIP P WEXIT Anchor whipstock and shear off, displaced from seawater to the 9.1 ppg milling fluid. 09:30 - 15:00 5.50 STWHIP P WEXIT Milled window f/2958' V2974' and drilled new hole to 2986' wlo problem (appeared to be some cement behind casing), 423 gpm, 480 psi, 100k rt wt, 110k up, 95k dn, 1-2k tq, 70 rpm. 15:00 - 16:30 1.50 STWHIP P WEXIT Circulate, rotate and reciprocate f/2986 V2958' 650 bbls @ 423 gpm, 480 psi, pump sweep and circulate clean. 16:30 - 17:30 1.00 STWHIP P WEXIT Pull V2950' and perform FIT to 11.7 ppg EMW (20' of hole f/mid-window at 2966 to 2986'). 17:30 - 19:00 1.50 STWHIP P WEXIT POOH to BHA. 19:00 - 21 :30 2.50 STWHIP P WEXIT LD BHA/milling assembly. 21 :30 - 23:00 1.50 STWHIP P WEXIT Pull wear ring & flush stack, set wear ring. 23:00 - 00:00 1.00 DRILL P INT1 PU BHA #2 to drill 8 1/2" hole. 5/1/2005 00:00 - 03:00 3.00 DRILL P INT1 Complete MU of BHA #2, RIH on 5" drill pipe (1x1 f/59 jts out of pipe shed) to 2900'. 03:00 - 04:30 1.50 DRILL P INT1 Obtain slow pump rates, PWD baseline, run gyro. NOTE: PWD base-line calculations as follows: Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ') Page 3 .. BP EXPLORATION OperatioMsSummary Report U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/1/2005 03:00 - 04:30 From - To Hours Task Code NPT Phase Description of Operations Date 04:30 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 10:00 10:00 - 11 :00 11 :00 - 13: 15 13:15 - 15:30 15:30 - 17:30 17:30 - 17:45 17:45 - 18:00 18:00 - 22:00 22:00 - 00:00 5/2/2005 00:00 - 10:00 10:00 - 00:00 5/3/2005 1.50 DRILL P INT1 0.50 DRILL P 1.50 DRILL P 1.50 DRILL P 2.00 DRILL P 1.00 DRILL P INT1 INT1 INT1 INT1 INT1 2.25 STKOH N DFAL INT1 2.25 STKOH N 2.00 STKOH N 0.25 STKOH N 0.25 STKOH N 4.00 STKOH N DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 DFAL INT1 2.00 STKOH N DFAL INT1 10.00 STKOH N P 4.50 DRILL P 0.50 DRILL P GPM 500 600 AVG Actual 9.56 ppg 9.58 ppg Model Differential 9.85 ppg .29 ppg 9.90 ppg .32 ppg .30 ppg RPM 100 100 Based upon the above data, .3 ppg will now be added to our "modeled" ECD values which will then represent our "clean-hole" ECD value. That "clean-hole" ECD value plus .6 ppg (per the well plan) now represent our PWD "hard-line" for path-forward 8 1/2" hole drilling operations. Ease through window to rat-hole TD at 2986' (no problems). Orient tool face w/gyro at 2986'. Drill f/2986' t/3193', 500 gpm, 1450 psi. Gyro survey(s) indicate well path 180 degrees off. Run #2 gyro to confirm directional problem (confirmed pr - decision made to sidetrack well). Pump dry job, begin TOOH to check BHA, POO BHA. Handle BHA/change out bit (picked up ne TIH t/2909'. Circulate 71 bbls @ 500 gpm, 137 si. Ease through window to 3004' 0 pump (ok). Gyro survey to confirm tool- ce orientation f/ sidetracking well - 4 good seats (330 de with same reading on first tool Lead tattle-tail confirmed at in UBHO. 2nd. tool gave same reading but on POH did t show mark on tattle-tail. Gyro Data h ä bumped 2nd tool on wind wall standing it back damagi gyro mechanism. Re-ran 1 st tool to comfirm read' . There is no other backup tool in Alaska. Ted ri II for sidetrack f/2986' t/2989', 400 gpm, 925 psi, 11 Ok up, 11 Ok dn. AST = 2.35 hrs ART = 0.30 hrs ADT = 2.65 hrs Control/time drilling for open-hole sidetrack f/2989 t/3193', 400-500 gpm, 945-1500 psi. INT1 (Note: Gyro surveys poviding good data). Drill ahead in new 8 1/2" hole f/3193' t/4608', 4-5k tq on, 4k tq off, 544 gpm, 1640 psi, 145k up, 125k dn, 130k rt, 80 rpm. Actual ECD's staying within 0.4 ppg of calculated. Pumped sweeps @ 3,758' & 4,512'. INT1 ART = 4.16 hrs AST = 8.69 hrs ADT = 12.85 hrs Drill ahead f/4608' t/4984', 15-20k wob, 1750 psi on, 1600 psi off, 4-5k tq on, 4k tq off, 145k up, 125k dn, 130k rt, 80 rpm, calc ECD - 9.9 ppg, act ECD - 10.1 ppg. Circulate and condition hole (pump 2+ X BU to include 25 bbl weighted sweep (11+ ppg)), 580 gpm, 2020 psi, 100 rpm, INT1 Printed: 6/13/2005 11: 1 0:39 AM ~.~ It:'~. rr:-~' '~'~ ' · ',: !~: f'ßi Î! I ! ~ ~ :1:.. ¡, ,\ I í : L-, r· 1'1'\ ,j II ¡j,~-" \ t i i F '_./ :w J.J ~, W b"":¡ ) ¡,mini, \, i'nE' mj~': r" ~ .¡'~,': \"., :CQ:n,'J ¡:"1,.n7'" , '~<,".\. I ¡ I ~ ' " ':1 ". 'I.· ~'(" i" l ~ f . . ;' r ~ \ í ~ ¡ / ¡ \,' ' ~, i : \ ," ~ ,n, :i¡ .ffl' ,\, :.\ ,,'1':. I : . : I . W. " . , _.'\, I ') .,U, t~ U Lf~ ~ .lr-u Q¿) J ü :' lyU ) A.1'1A.SKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 w. -,rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~q"f" f) ]10 Re: Prudhoe Bay U-06A Sundry Number: 305-084 Dear Mr. Isaacson: 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. Please provide at least twenty-four (24) hours 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. q)~ Daniel T. Seamount, Jr. Commissioner ~ DATED this ~ day of April, 2005 Encl. ~"i~'f,"kH"'Er', A PR 1 .41.DB5 l'\o;Pf'''t~1J~~-' ,- · 1. Type of Request: II Abandon /1 0 Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver o Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well "t..t (, /.\-. It /1 ( UJ 0 C;; ) STATE OF ALASKA ') CItJ- 4-7"()~ ALASKA OIL AND GAS CONSERVATION COMMISSION RECE/v'E APPLICATION FOR SUNDRY APPROVAL APR 0 20 AAC 25.280 - 6 2005 A/:itJca Oil & &, C Ions. COIl'h.. o Other Anchorage o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current ~II Class: IBI Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number ~~f)75· / C¡C¡ - 0 '7 ¿, W4A- 6. API Number: 50-029-21117-01-00/ 99519-6612 84.3" 9. Well Name and Number: PBU U-06A /' 8. Property Designation: 11. Total Depth MD (ft): 10972 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 9018 10912 9014 None Length Size MD TVD Burst Junk (measured): None Collapse ADL 028283 Liner 110' 20" x 30" 110' 110' 2685" 13-3/8" 2685' 2685' 4930 2670 8889" 9-5/8" 8889" 8812' 6870 4760 541' 7" 8381' - 8922' 8343' - 8843' 7240 5410 2614' 2-7/8" 8358" - 10972" 8322" - 9018' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9420' - 10190" 9047" - 8963' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker Perm Packer; 4-1/2" Otis DBE SSSV Nipple Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 8323" 2097' Tubing MD (ft): 8413" 12. Attachments: IBI Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: D Exploratory IBI Development D Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Signature l}:I\.... ~. \, Phone 564-5521 Date "115/ () 5 Commission Use Only April 15, 2005/ Date: 15. Well Status after proposed work: DOil DGas DWAG DGINJ / D Plugged IBI Abandoned D WINJ D WDSPL Contact Ken Allen, 564-4366 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3t:J5"' -p ef D Plug Integrity D BOP Test D Mechanical Integrity Test T-e~r- goPE ~ ·~SoC? pst. Other: ^ . Î · I I'~'e p }O lie J {-cJ I' ..V'- ì ~ - 4- 0 t r-t t ~f.A W d , (!) -- '\-oJ . D Location Clearance RBDMS 8Fl APR 0 7 2005 t r Ç,t' L( hr¿,~./( ¡µ..pi{ U. - 0 (p IS. COMMISSIONER APPROVED BY THE COMMISSION Date fJ-/ 7/.5 Submit In Duplicate OR\G\NAL ) ) , " To: Winton Aubert - AOGCC Date: April 4, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: U-06A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well U-06A. U-06 was drilled in 6/1984 and was sidetracked to U-06A in 8/1999. The U-06A location was found to be swept when drilled so the well did not produc~ for a significant time. U-06A has been shut in since 2/2000. The /' wellbore is providing no production or value to the field as it currently sits. U-06B targets Zone 4b in two fault blocks west of exploration well K24-11-12. The well will target between 40-80 feet of net LOC (tvdss) along its length. In the first fault block K24-11-12 cut 30' , of light oil in upper Zone 4. This fault block is structurally higher to the west away from K24-11- /' 12. The fault block is thought to contain 0.92 mmstb of remaining risked reserves. The second fault block to the west of the K24-11-12 block is estimated to hold additional reserves as no production has occurred in the block. Fault block isolation and fault baffling have prevented recovery of these target reserves. The second fault block is slightly lower structurally and is expected to have an average light oil column of 25'. This fault block is thought to contain 0.29 mmstb of remaining risked reserves that will not be captured by the West End development. The well is designed to cross-cut upper Zone 4 through an undulating profile with the toe-up at TD to assess the TSAD elevation. Based on recent offset drilling at W-08A and farther south at P-27, there is upside potential for an additional 10-15' of light oil to augment the reserves. A slotted 4- / 1/2" liner will be run throughout the production interval. The U-06B sidetrack is currently scheduled for Nabors 2ES beginning around 5/15/05, after completing the NK-65A sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Pre-Rir-l Work: 1. Rig up slickline, Drift 4-1/2" tubing to top of 2-7/8" liner at 8358' MD. Drift 2-7/8" to as deep as possible. 2. Fluid pack the tubing and inner annulus. 0 3. P&A perfs and 2-7/8" liner from the PBTD to -7,300' MD. RIH with coil to PBTD. Lay in~ bbls of cement to -7,300' MD. Obtain Squeeze with 5 additional bbls. POH with coil. a. Cement Calculations: · 2-7/8" liner = 10,912' - 8,358' or 2,554' (-15 BBLS) · 4-1/2" tubing = 8,358' - 7,300' or 1,058' (-16 BBLS) /- ,/ · Squeeze an additional 5 BBLS for a total cement volume of~~S 4. Rig up slickline, drift 4-1/2" tubing and tag TOC. L ~ 5. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 6. Chemical cut the 4-1/2",12.6#, L-80 tubing at - 3,200' MD. U-06A Application for Sundry ) ) 7. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to -2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to / 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to geawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. / 4. Pull 4-1/2" tubing from chemical cut at -3,200' MD. 4 '\ 5. RU e-line. Run GR/JB for 9-5/8", 47# casing with CCl to just above top of tubing stub at 3,200' MD. 6. RIH with CIBP on e-line. Set CIBP to avoid cutting a casing collar during window milling / operations. T~s ¡ 0" 40·~ (Â,;P PrHJt.!CK... (. 7. PU 9-5/8" Baker bottom trip whipstock assembl~. RIH, orient whipstock and set on CIBP. 8. Swap over to 9.0 ppg LSND milling and drilling fluid (Ugnu KOP). 9. Mill window in 9-5/8" casing at 3,000' MD (top of window) plus 20' past middle of window. Perform FIT. POOH. 10. MU 8-1/2" drilling assembly with Dir/GR/PWD on 5" DP and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 3-4°/100' to _50° hold angle. 11. Drill ahead to the top of the HRZ. Increase mud weight to 10.9 ppg for HRZ/Kingak drilling. 12. Drill ahead to casing point at Top Sag River to an estimated depth of 11,649' MD. 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing with 150' of overlap. Displace cement with muä POOH. 14. MU 6-1/8" BHA with Dir/GR/RES/ABI on 4" DP. RIH to the 7" landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. 16. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT. 17. Drill the 6-1/8" production interval building to horizontal, targeting Z4B Ivishak. Drill ahead to an estimated TD of 16,734' MD. 18. Run a 4-1/2" slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to place top of liner with 150' of overlap. 19. Release from liner, displace well to clean seawater. 20. Run the 3-1/2", 9.2#, 13Cr80 completion tying into the 4-1/2" liner top. 21. Set packer and test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 22. Set and test TWC. 23. ND BOPE. NU and test the tree to 5,000 psi. 24. Freeze protect the well to -2,200' and secure the well. 25. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-Rig Start: Estimated Spud Date: 4/15/05 5/15/05 Ken Allen Operations Drilling Engineer 907.564.4366 U-06A Application for Sundry TREE = WELLHEAD == · ACrUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD = 4"Cr# MCEVOY BA KER 84.30' 48.80' 7700' '102 @"9684' 8967 8800' SS ) I 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2680' ~ Minimum 10 = 2.441" @ 8331' TOP OF 2-7/8" LINER TOP OF 2-7/8" LNR 1-1 I TOP OF 7" LNR 1-1 8358' 8381' U-06A / Current - ~ L I I :8: :& . . , t J I \4-112" TBG 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 8413' 1 J \ I TOP OF CEMENT 1-1 8600' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 8889' r--4 ~ TOP OF WHIPSTOCK 1-1 8920' I RA TAG 1-1 8930' ÆRFORA TION SUMMARY REF LOG: MEMORY RESISTIVITY LOG ON 08/01/99 ANGLE AT TOP ÆRF: 98 @ 9420' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9420 - 9528 0 08/04/99 2" 4 9540 - 9576 0 08/04/99 2" 4 9664 - 9690 0 08/04/99 2" 4 9814 - 9842 0 08/04/99 2" 4 9902 - 9958 0 08/04/99 2" 4 9980 - 9988 0 08/04/99 2" 4 10154 - 10190 0 08/04/99 I PBTD 1-1 9280' 7" LNR 26#, L-80. 0.0383 bpf, ID = 6.276" 1-1 9325' SA } NOTES: 700 @ 9227' & 90° @ 9268' 2097' 1-14-1/2" OTIS DBESSSV NIP, ID = 3.813" 1 GAS LIFT MANDRELS ST MD lVD DEV 1YÆ VLV LATCH PORT DATE 5 2992 2908 0 CAM RK 4 5136 5050 7 CAM RK 3 6585 6497 2 CA M RK 2 7607 7518 4 CAM RK 1 8259 8146 21 CAM RK 8321 ' 8322' 8323' 8358' 8380' 1-14-1/2" PARKER SWS NIP, ID = 3.813" 1 1-1 K-22 TUBING ANCHOR 1 H9-5/8" X 4-1/2" BAKER PERM A<R, ID = 3.99" 1-1 DEPLOY MENT SLEEV E 1 H4-1/2" OTIS SWS NIP, ID = 3.813" 1 8401' H4-1/2" OTIS XN NIP, ID = 3.8"1 8413' 1-14-1/2" WLEG 1 8398' 1-1 ELMD IT LOGGED 11/22/90 1 MILLOUT WINDOW 8919' - 8929' PBTD 1-1 10912' 1 12-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.441" H 10972' 1 COMMENTS DA TE REV BY COMMENTS DA TE REV BY 06/28/84 ROBERTS ORIGINAL COMPLETION 08/04/99 WHITlOW CTD HORIZONTAL SIDETRACK 01/31/01 SIS-QAA CONVERTED TO CA NV AS 03/08/01 SIS-MD FINAL 03/30/02 RNlTP CORRECTIONS PRUDHOE BA Y UNIT WELL: U-06A ÆRMIT No: 199-0750 API No: 50-029-21117-01 SEC 18, T11N, R13E BP Exploration (Alaska) TR,* = ~ELLHEAD--' · ACTUATOR = KB. ELEV =" BF. ELEV = KOP= Max Angle = Datum MD = Datum NO = 4"CIW MCEVOY BAKER 84.30' 48.80' 7700' . " , . 102 @ 9684' 8967 880Ò' 58 ) U-06A Pre-Rig, ) 2097' ~14-1/2" OTIS DBE SSSV NIP, 10 = 3.813" 1 e I 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2680' ~ Minimum 10 = 2.441" @ 8331' TOP OF 2-7/8" LINER ~ ~ -3200' - Tubing Cut -7300' - Top of P&A Cmt /~ 8321' 1-14-1/2" PARKER SWS NIP, 10 = 3.813" I~ 8322' 1-1 K-22 TUBING ANCHOR 1 ITOP OF 2-7/8" LNR 1-1 I TOP OF 7" LNR 1-1 14-1/2" TBG 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 I TOP OF CEMENT 1-1 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 TOP OF WHIPSTOCK 1-1 I RA TAG 1-1 8358' 8381' 8413' 1 8600' 1 8889' r--.4 8920' 8930' ÆRFORA TION SUMMARY REF LOG: MEMORY RESISTIVITY LOG ON 08/01/99 ANGLE AT TOP ÆRF: 98 @ 9420' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9420 - 9528 0 08/04/99 2" 4 9540 - 9576 0 08/04/99 2" 4 9664 - 9690 0 08/04/99 2" 4 9814 - 9842 0 08/04/99 2" 4 9902 - 9958 0 08/04/99 2" 4 9980 - 9988 0 08/04/99 2" 4 10154 - 10190 0 08/04/99 I PBTD 1-1 9280' 7" LNR, 26#, L-80, 0.0383 bpf, 10 = 6.276" l-i 9325' 8323' 8358' 8380' ~19-5/8" X 4-1/2" BAKER PERM PKR, 10 = 3.99" 1-1 DEPLOYMENT SLEEVE 1 H4-1/2" OTIS SWS NIP, 10 = 3.813" 1 8401' ~14-1/2" OTIS XN NIP, 10 = 3.8" 1 8413' 1-14-1/2" WLEG 1 8398' 1-1 ELMO IT LOGGED 11/22/90 1 MILLOUT WINDOW 8919' - 8929' /~ PBTD l-i 10912' 1 12-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, 10 = 2.441" H 10972' 1 SAFETY NOTES: 70° @ 9227' & 90° @ 9268' DA TE REV BY COMMENTS DA TE REV BY 06/28/84 ROBERTS ORIGINAL COMPLETION 08/04/99 WHITLOW CTD HORIZONTAL SIDETRACK 01131/01 SIS-QAA CONVERTED TO CANV AS 03/08/01 SIS-MD FINAL 03/30/02 RNlTP CORRECTIONS COMMENTS PRUDHOE BA Y UNIT WELL: U-06A ÆRMIT No: 199-0750 API No: 50-029-21117 -01 SEC 18, T11N, R13E BP Exploration (Alaska) ~ ",' U-LJB Proposed Con .~Ietion / GI M nesign: #6 - 3000' MD - 3-1/2" X 1-1/2" DV #5 - 3800' MD - 3-1/2" X 1-1/2" SV #4 - 6135' MD - 3-1/2" X 1-1/2" DV #3 - 7540' MD - 3-1/2" X 1-1/2" DV #2 - 8393' MD - 3-1/2" X 1-1/2" DV #1 - 11430' MD - 3-1/2" X 1-1/2" DV 2680' ~ ~ 13-3/8", 72", L-80 2850' - 11\I' - 9-5/8" X 7" Baker Flex-Lock Liner Hanger with ZXP and C-2 running tool TREE = 4" CIW WELLHEAD = MCEVOY ·AcfOATOR·;--········-······.···-··..··....--S·ÃXER -RËf··ËIË·'r;;;-···---·..····..·-······-..······-..·-··-·····-S4:-3"Õ' ·BF:..-ËI1~'\T;·-··-·-····-··-·-·-···--·_··..-····-·····-'''''-4~r8Õï T«)p...;;;----·---·--....·-·.....-·..·-·-··--· 7700' -riAaxAngie;" 1Ö2@ 9684' Datum MD = -·---ã967· lYãtum-tVO·-;-------·....····..··-····..-·-·..··ãaë)"õ'·ss TOW -3000' - -- ---------- 3-1/2", 9.2#, 13Cr80, Vam Top -IES EZSV -3020' -3200' Note: #1 GLM installed right above X nipple ~ 11 ,443' - 7 X 4-1/2" Baker S-3 Packer 11,493' - 7" X 5" Baker Flex-Lock Liner Hanger with ZXP and HR running tool 11,649' - 7", 26#, L-80, BTC-M 7300' 8323' 8381' ~,"'~~i Cmt P&A Plug Packer Liner Top ~ .""'; '."'f¡"'" ..... I ~;': I \~f!). ,7i- 4-1/2",12.6#, L-80, IBT, Slotted _________4 8889' ~ 2-7/8", 6.16#, L-80 9325' Date 01-05-05 01-10-05 02-08-05 03-30-05 7", 26#, L-80 Rev By Comments RBT Proposed Completion - wp01 RBT Proposed Completion - wp01 RBT Proposed Completion - wp06 KWA Proposed Completion - wp07 PRUDHOE BAY UNIT WELL: U-06B API NO: Permit NO: GPB Rotary Drilling Tubing Tail: -10' Pup Joint -X Nipple (2.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (2.813") -20' Pup Joint -XN Nipple (2.75") -10' Pup Joint -WLEG --~ 16,734' 199-076-0 PRUDHOE BAY UNIT U-06A 50- 029-21117/2-01'i BP EXPLORATION (ALASKA) INC Roll #1: Start: Stop Roll #2: Start~ Stop MD 10972' TVD 09019~-'Completion Date: ~/4/99 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 9080 J- 1-3 SPERRY GR OH 12/7/99 12/9/99 D 9300 ,.--/' I PDS IL ~ ~.~4x~ ~.~ c o ~- OH 8/10/99 8/10/99 L ILL.,`/' FINAL 8680-10971 OH 8/10/99 8/10/99 L NGP-MD ~ F~ 8940-10971 OH 2/5 12/7/99 12/9/99 L NGP-TVD' F~ 8775-8934 OH 2/5 12/7/99 12/9/99 L SRVY LS~G ~ BHI 8800-10971. OH 8/12/99 8/12/99 L SRVY RPT ~-~- ' SPE~Y 8800-10971. OH 8/12/99 8/12/99 Wednesday, June 20, 2001 Page 1 of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 07, 1999 U-06A AK-MW-90141 1 LDWG formatted Disc with verification listing. API#: 50-029-21117-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G.. Ap~.~q~ch~a.~g~ ,~.~s ..ka~ 9,,5,18 · 55 9 i999 <%- --\ Date: Signed':."--3" ;x~a~a 0il e~ Gas COns. C0mm~.smn ~en0rage BP Exploration (Alaska) Inc. ._P. etro.-mchnical Data Centeg. MB3,3 900 E. Benson Blvd. ._Anchorage,. Alaska 99519,_6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company To,' WEI,I, LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs U-06A, December 7, 1999 AK-MW-90141 U-06A: 2" x 5" MD Gamma Ray Logs: 50-029-21117-01 2" x 5" TVD Gamma Ray Logs: 50-029-21117-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: '1' () ':'~ ]999 .~a~a 0il & Gas Cons. Commi~ion Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil i-q Gas I-] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. ~ 3. Address 8. APl Hum P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21117-02 .......................... ~~ 9. Unit or Lease Name :4. Location of well at surface ~ ¢.0~-r!~., ! ............... ' ~ ~l~tl!l~ Prudhoe Bay Unit 103' NSL, 1663' WEL, SEC. 18, T11N, R13E, UM ~ DATE/ I 10. Well Number At top of productive interval i ~,~'~'--~-' i~ U-06A 569' NSL, 1487' WEL, SEC. 18, T11N, R13E, UM ~ V~? i At total depth~~~--~ ~' .~ /.,,f~_--~ 11. Field and Pool 643' SNL, 2535' WEL, SEC. 19, T11N, R13E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 84.30'I ADL 028283 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 7/29/99 I 7/31/99 I 8/4/99 I N/A MSL] One 117. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey t20. Depth where SSSV set 121. Thickness of Permafrost 10972 9019 FTI 10912 9014 FTI []Yes F-INo t (Nipple) 2097' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, POP, Memory Induction, GR, Temp 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulated Conductor Surface 110' 36" !8 cu yds Concrete 13-3/8" 72# L-80 Surface 2685' 17-1/2" 3746 cuft Permafrost 'E' and II 9-5/8" 47# L-80 Surface 8889' 12-1/4" i1740 cuft Class 'G', 279 cuft PF 7" 26# L-80 8381' 8922' 8-1/2" ~71 cuft Class 'G' 2-7/8" 6.16# L-80 8358' 10972' 3-3/4" '129 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8413' 8323' MD TVD MD TVD 9420' - 9528' 9047' - 9035' 9540' - 9576' 9034' - 9030' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9664' - 9690' 9015' - 9010' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED 9814' - 9842' 8989' - 8986' 9902' - 9958' 8979' - 8974' 2000' Freeze Protect with 30 Bbls MeOH 9980' - 9988' 8972' - 8972' 10154' - 10190' 8963' - 8963' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 7, 1999I Gas Lift Date of Test Hours Tested IPRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (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. , ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Shublik 'A' 8946' 8865' Shublik 'B' 8980' 8895' Shublik 'C' 9015' 8925' Sadlerochit 9045' 8949' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e '"'~/~ ~ Title Technical Assistant III Date O~" Z/"/-9~ U-06A 99-075 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. iTEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. iTEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. iTEM 27': Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-ln, Other-explain. ITEM 28-' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: U-06A Accept: Field: Prudhoe Bay Spud: APl: 50-029-21117-02 Release: Permit: 99-075 CTD Unit: 07/26/99 07/29/99 08/04/99 Nordic #1 ...................................................... 07/27/99 1 Removed Boogie wheels from cellar area. Hung BOP stack. W/O AFE approval to move over well. NU BOPE. Rig accepted 19:00 hrs 7/26/99.Tested BOPE. Installed coil conn. Pumped dart through coil. Loaded well w/sea water. While doing pad inspection, Zane Montague w/Nordic noticed a hydraulic oil drip from moving system. Depressured system. Approximately ~ pint of oil went on ground. Notified Kent Engles (BPX spill Tech). He classified it as a non-reportable leak (< 1 gallon) and the rig crew shoveled the contaminated gravel into a oily waste bag. BPX Environmental will pick up the oily waste today (7/27/99). LCIR is being completed. 07/28/99 2 8923' RIH w/cementing nozzle. Tagged Whipstock @ 8919'. Spotted 28 bbls cement. Attempted to squeeze. Max pressure: 330 psi. POH to 7800'. Had 6 bbl gain. SD. Monitored flow for 30 minutes. No gain. POH. Proper hole fill. MU window milling assembly. WOC to develop Comp strength. Press test cement plug with 1500 psi. Good press test. RIH with 3.80" window milling BHA #2. Milled through XN nipple at 8386 ft. RIH and tagged firm cement at 8600 ft. Drilled cement at 40 - 80 FPH from 8600 - 8922 ft. Milled window from 8922 - 8923 ft. 07/29/99 3 9035' Finished milling 3.80" window f/8'923-29'. Overall window f/8922-29' (7' window). Drilled formation to 8940' at 16 fph. POH. RIH w/pilot DSM and 3.80" string reamer. Reamed cement pilot hole f/8600-8922'. Reamed window f/8922-29'. Reamed open hole to 8940 ft. Reamed window area three times. RIH with no pump to TD. Clean window. POOH. M/U Directional Building BHA #4. RIH with 2.65 deg bent motor. Run through window OK. Orient TF. Drilled build section from 8940 - 9035 ft. Orient TF. 07/30/99 4 9702' Drilled to 9329' while turning left and building angle. Tripped for horizontal assembly. C/O BHA. RIH w/1° bent motor assembly & new DS49 PDC bit. Tied-in with flag on CT [-4 ft CTD]. Orient TF in liner. MWD log with GR from 9000 - 8920 ft for geology correlation. RIH to TD. Drilled 96 - 98 deg Incl. hole from 9329 - 9540 ft. Short trip to window. Drilled 96 - 100 deg Incl. hole from 9540 - 9682 ft. First fault was projected at 9600 ft. No mud losses seen. Orient TF to right. Drilled to 9700 ft. Stacking wt after TF change. Short trip to window. Tied-in with MWD GR. Added 2 ft to CTD. RIH to TD. 07/31/99 5 10632' Drilled to 9766'. Differentially stuck. Worked free. Drilled to 8925'. Differentially stuck. Worked free. Displaced well to new mud while short tripping to window. Drilled to 10006'. Short tripped to window. Drilled to 10209'. Crossed fault - No mud loss. TF affected by fault. Drilled to 10300'. Short tripped to window. Tied-in with GR, added 6 ft to CTD. RIH. Drilled to 10,515 ft. Short tripped to window. RIH. Circulated up missing survey data. Oriented TF. Drilled to 10,632 ft. Pump pressure climbed quickly, indicating bit nozzles plugged, possibly from chunked motor stator rubber. POOH to change out motor. No mud loss. U-06A, Coil Tubing Drilling Page 2 08/01/99 6 10971' POH. Changed out failed motor & MWD probe. RIH w/BHA #6. Tight f/9810-990'. Drilled f/ 10632-10815'. Stacking problems f/10672-10750'. Wiper trip to window (Tight f/9915-9820'). Was also tight RIH (shale section). RIH to 10810'. Oriented TF to 90L. Drilled from 10815 - 10920 ft. Wiper trip to window. Tied-in with GR. Added 9.5 ft to CTD. RIH and reamed shale's at 9710 ft and 9860 ft. RIH and drilled from 10926 - 10971 ft. Started seeing mud losses of 0.6 BPM at 10960 ft. Mud losses healed to 0.2 BPM while circulating at 2.2 BPM. Geology decided to call TD at 10,971 ft. Reamed tight shales at 9850 and 9710 ft several times until no over pull or motor work was seen. POOH. Flagged CT at 8100 ft. POOH. Lay down drilling BHA. Pick up PDS Memory Induction/GR logging tools. 08/02/99 7 10972' RIH with PDS memory induction /GR log. Run in OH at 15-20 fpm. Took +/- 2500# weight at 9840' but went through - OK. Tag bottom at 10967' uncorrected CTD. Log out to 8700' at 30 fpm - no tight spots. POH with logging tool & LD same. PDS downloaded data. Good data. M/U drilling BHA #8. RIH. Shallow test MWD. Poor signal. POOH and replace MWD tools. RIH with drilling BHA. Shallow test MWD - OK. RIH. Tied-in with GR [ -5 ft CTD]. RIH and ream shales at 9710 and 9850 ft. Shales in better condition. RIH and tag TD at 10,972 ft. POOH. Full returns. Lay down drilling BHA. Held Safety Meeting. RIH with 2 7/8", STL Liner. 08/03/99 8 10972' Held Safety Meeting with day crew. Ran total of 84 joints of 2 7/8", 6.16#, L-80, STL Liner. M/U Baker CTLRT and running tools. RIH with liner on CT. Ran in open hole at 60 FPM. Tagged TD at 10981 ft CTD. Corrected TD was 10,972 ft. Pump ball and released running tool from liner. Sat down wt and displaced well to 2% KCL water. Held Safety meeting. Pumped 23 BBL of 15.8 PPG cement. Inserted CT wiper dart and displaced with rig pumps. Dart sheared liner wiper plug and cement was displaced at 3 BPM. The liner wiper plug landed on schedule. Circulated at liner top and POOH. L/O Baker tools and RIH with jetting nozzle on CSH work string. WOC for 3 hours at top of liner. RIH jetting liner to PBTD of 10,912 ft. POOH laying in new FIoPro in liner. POOH with CT. 08/04/99 9 10972' POH with CT to 2700'. Pressure test liner to 1500 psi. No test - pressure bled off to 250 psi. POH with 1 11/16" work string & rack back. Load tubing with KCI water. Shoot fluid level in tubing x casing annulus - 630'. P annulus - 550 psi. Pump 5 bbl fluid to tubing at 1 BPM. Max P tubing - 1190 psi. Fluid level rose to 540' (90'). P annulus rose to 650 psi. Repeat with 5 bbl to tubing. Max P tubing - 1400 psi. Fluid level in annulus rose to 450' (90'). P annulus rose to 750psi. Hook up line from annulus to flow line to bleed gas off annulus and liquid pack same. Make multiple attempts to pressure test tubing and annulus to 1500 psi. Finally got both to hold steady - confirmed communication from tubing to 9 5/8" casing but liner and cement appear OK. MU SWS 2" perf guns. RIH on 30 stands CSH work string. RIH on CT to PBD. Drop ball and displace to firing head. Perforated 9420-9528', 9540-9576', 9664-9690', 9814-9842', 9902- 9958', 9980-9988' and 10154-10190' with 4 spf. POOH with CT. Stand back CSH. LD perf guns. RIH with nozzle and freeze protect tubing to 2000'. Blow down CT with N2. U-06A, Coil Tubing Drilling Page 3 08/05/99 10 10972' Finished blow down of CT with N2. Bleed off CT press. N/D BOP stack and remove hydraulic hoses. Pick up stack and pull rig forward off well. Install tree cap and press test cap. Master, swab and wing valves are closed. Released rig at 10:00 Hrs, 08/04/99. Total time on well was 8 days, 15 hours. Installed booster wheels in cellar and move rig to E-28A. 1oeo 800 600 400 200 -.I-- '+- 0 200 400 600 800 IOO0 1200 B.P. ExploraLion (True) Structure: Pad U Field : Prudhoe Bay Well: U-O6A, 50-029-21 1 17-01 Location : North Slope, Alaska <- West (feet) 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 800 I I I I I I I I I I I I I I I I I I I I I I I I I I I Brij Potnls Dote plolt~l: t8-Aug-1999 P~ Reference I~ U-~ Projected to TD ~~:?; ;: :~; ~ ~ 8600 8800 8~00 .... .................. ...... .... - ¢~00 I I i i i i 900 1 BO0 1700 ~ 600 ~ 500 1400 1300 1200 11 O0 ~ 000 900 ~00 700 600 500 4~ 3~ 2~ 1 ~ 0 1 O0 200 300 Vortical Socfion (foot) -> Azimuth 42.02 with reference 569.96 N, 182,98 E from U-06 B.P. Exploration (True) Pad U U-06A U-06 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : U-06A Our ref : svy204 License : 50-029-21117-01 Date printed : 18-Aug-1999 Date created : 18-Aug-1999 Last revised : 18-Aug-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 634003.550,5960616.180,999.00000,N Slot location is n70 18 2.332,w148 55 41.241 Slot Grid coordinates are N 5960690.000, E 632339.000 Slot local coordinates are 103.50 N 1663.10 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad U,U-06A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 1 Your ref : U-06A Last revised : 18-Aug-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 8800.00 21.18 18.54 8644.82 369.96N 8919.00 20.26 20.19 8756.12 409.68N 8950.52 24.70 357.63 8785.29 421.41N 8968.65 29.39 346.73 8801.44 429.53N , 8996.25 32.29 333.69 8825.17 442.75N 182.98E 0.79 0.00 632515.34 5961063.13 196.93E 0.92 -38.84 632528.58 5961103.09 198.55E 30.53 -48.64 632529.98 5961114.85 197.37E 37.54 -53.89 632528.66 5961122.95 192.54E 26.34 -60.47 632523.60 5961136.08 9020.12 35.55 325.29 8844.98 9046.79 39.24 318.13 8866.18 9064.95 42.28 314.21 8879.93 9086.12 44.95 304.41 8895.28 9113.47 51.03 295.21 8913.59 454.18N 466.84N 475.38N 484.59N 494.60N 185.75E 23.89 -64.42 632516.61 5961147.38 175.70E 21.37 -67.10 632506.33 5961159.86 167.49E 21.88 -67.95 632497.97 5961168.26 156.20E 34.30 -67.23 632486.52 5961177.26 138.57E 33.41 -62.86 632468.72 5961186.95 9139.57 56.65 288.85 8929.00 9183.12 61.08 272.45 8951.62 9227.29 71.80 265.31 8969.27 9268.02 83.40 259.72 8978.01 9311.92 95.62 254.35 8978.38 502.45N 509.18N 508.29N 503.07N 493.24N 119.04E 29.15 -55.63 632449.06 5961194.45 82.59E 33.76 -36.22 632412.49 5961200..53 42.20E 28.42 -8.53 632372.13 5961198.92 2.85E 31.47 21.69 632332.88 5961193.00 39.83W 30.40 57.56 632290.38 5961182.41 9342.14 99.23 244.51 8974.47 9376.84 99.93 242.92 8968.70 9412.27 97.65 242.57 8963.28 9455.59 96.02 230.46 8958.11 9479.44 95.54 229.21 8955.71 482.74N 467.59N 451.55N 427.86N 412.55N 67.85W 34.42 84.12 632262.56 5961171.41 98.53W 4.95 115.91 632232.16 5961155.72 129.65W 6.51 148.66 632201.33 5961139.13 165.45W 28.01 190.22 632165.96 5961114.81 183.58W 5.59 213.73 632148.11 5961099.18 9499.57 95.10 226.40 8953.84 9529.69 96.24 222.18 8950.86 9567.12 97.21 217.44 8946.48 9601.99 98.44 214.45 8941.73 9644.14 100.81 209.53 8934.68 399.09N 377.64N 349.10N 321.14N 285.91N 198.43W 14.07 233.67 632133.50 5961085.46 219.35W 14.45 263.61 632112.96 5961063.64 243.15W 12.84 300.74 632089.69 5961034.68 263.42W 9.20 335.09 632069.91 5961006.36 285.43W 12.81 376.00 632048.54 5960970.75 9683.69 102.39 202.14 8926.71 9721.27 100.63 203.37 8919.21 9766.69 98.70 214.80 8911.56 9807.82 97.65 215.85 8905.72 9828.94 97.56 218.67 8902.92 251.07N 217.11N 178.06N 144.84N 128.18N 302.31W 18.73 413.18 632032.28 5960935.62 316.55W 5.68 447.94 632018.65 5960901.41 338.29W 25.17 491.50 631997.62 5960861.'98 361.83W 3.59 531.93 631974.67 5960828.36 374.50W 13.24 552.79 631962.30 5960811.47 9866.62 97.47 220.42 8897.99 9896.94 95.18 224.64 8894.65 9927.19 94.48 227.28 8892.10 9949.69 94.04 229.39 8890.43 10001.07 95.27 239.94 8886.25 99.38N 77.18N 56.23N 41.31N 11.73N 398.29W 4.61 590.11 631939.04 5960782.25 418.65W 15.76 620.24 631919.07 5960759.69 440.32W 9.00 650.31 631897.79 5960738.36 457.08W 9.55 672.61 631881.29 5960723.15 498.79W 20.60 722.50 631840.12 5960692.83 10057.94 93.43 237.47 8881.94 10113.29 91.49 232.73 8879.56 10156.17 90.97 225.87 8878.64 10181.29 90.61 221.83 8878.29 10220.79 90.00 224.29 8878.08 17.72S 49.35S 77.29S 95.40S 124.26S 547.24W 5.41 776.82 631792.21 5960662.52 592.58W 9.25 830.66 631747.44 5960630.09 625.06W 16.04 873.16 631715.47 5960601.58 642.45W 16.14 898.26 631698.40 5960583.16 669.42W 6.42 937.75 631671.95 5960553.83 10269.64 90.44 231.52 8877.89 10314.29 89.47 235.19 8877.93 10348.89 86.57 231.85 8879.12 10446.67 86.40 221.48 8885.13 10475.42 86.04 218.31 8887.03 156.99S 183.63S 204.19S 271.07S 293.08S 705.64W 14.83 986.31 631636.32 5960520.47 741.46W 8.50 1030.08 631600.99 5960493.19 769.26W 12.78 1063.96 631573.57 5960472.15 840.15W 10.59 1161.10 631503.89 5960404.01 858.55W 11.07 1189.77 631485.89 5960381.68 10512.57 88.68 215.33 8888.74 10579.07 86.92 207.94 8891.30 10607.27 86.75 197.75 8892.86 10642.20 84.81 192.47 8895.43 10676.79 81.47 191.07 8899.56 322.78S 379.32S 405.23S 438.85S 472.46S 880.78W 10.71 1226.72 631464.19 5960351.59 915.61W 11.42 1292.03 631430.37 5960294.45 926.53W 36.08 1318.59 631419.92 5960268.35 935.60W 16.06 1349.64 631411.44 5960234.57 942.61W 10.46 1379.30 631405.04 5960200.84 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from U-06 and SSTVD from R_KB - MSL = 84.3 ft. Bottom hole distance is 1146.99 on azimuth 229.50 degrees from wellhead. Vertical section is from tie at N 369.96 E 182.98 on azimuth 222.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad U,U-06A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : U-06A Last revised : 18-Aug-1999 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 00 R D I N A T E S Deg/100ft Sect Easting Northing 10715.67 79.36 186.15 8906.04 510.35S 948.35W 13.61 1411.30 631399.98 5960162.86 10768.79 78.98 176.50 8916.04 562.44S 949.56W 17.86 1450.80 631399.70 5960110.76 10803.69 83.76 168.74 8921.29 596.62S 945.12W 25.89 1473.22 631404.75 5960076.66 10831.00 84.46 163.47 8924.09. 622.99S 938.59W 19.37 1488.44 631411.74 5960050.43 10882.29 86.48 154.51 8928.15 '670.66S 920.27W 17.85 1511.60 631430.90 5960003.09 10918.19 88.33 146.77 8929.78 701.89S 902.70W 22.14 1523.04 631449.03 5959972.18 10939.14 85.25 144.13 8930.95 719.12S 890.84W 19.35 1527.90 631461.19 5959955.17 10971.00 85.25 144.13 8933.59 744.85S 872.24W 0.00 1534.56 631480.25 5959929.78 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from U-06 and SSTVD from RKB - MSL = 84.3 ft. Bottom hole distance is 1146.99 on azimuth 229.50 degrees from wellhead. Vertical section is from tie at N 369.96 E 182.98 on azimuth 222.02 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad U,U-06A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 3 Your ref : U-06A Last revised : 18-Aug-1999 MD SSTVD 8800.00 8644.82 10971.00 8933.59 Comments in wellpath Rectangular Coords. Comment 369.96N 182.98E Tie-in Point 744.85S 872.24W Projected to TD NO PROPOSAL Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA U Pad, Slot U-06 U-O6A Job No. AKMW90141, Surveyed: 31 July, 1999 ORIGINAL SURVEY REPORT 11 August, 1999 Your Reft 500292111701 Surface Coordinates: 5960690.00 N, 632339.00 E (70° 18' 02.3320" N, 148° 55' 41.2415" W) Kelly Bushing: 84.30ft above Mean Sea Level OR:II--LING SERVII~E!S Survey Ref: svy8703 COMPANY Sperry-Sun Drilling Services Survey Report for U-O6A Your Ref: 500292111701 Job No. AKMW90141, Surveyed: 31 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8800.00 21.180 18.557 8644.82 8729.12 8919.00 20.260 20.190 8756.12 8840.42 8950.52 24.700 357.630 8785.29 8869.59 8968.65 29.390 346.730 8801.44 8885.74 8996.25 32.290 333.690 8825.17 8909.47 9020.12 35.550 325.290 8844.98 8929.28 9046.79 39.240 318.130 8866,18 8950.48 9064.95 42.280 314.210 8879.93 8964.23 9086.12 44.950 304.410 8895.28 8979.58 9113.47 51.030 295.210 8913.59 8997.89 9139.57 56.650 288.850 8929.00 9013.30 9183.12 61.080 272.450 8951.62 9035.92 9227.29 71.800 265.310 8969.27 9053.57 9268.02 83.400 259.720 8978.01 9062.31 9311.92 95.620 254.350 8978.38 9062.68 9342.14 99.230 244.510 8974.47 9058.77 9376.84 99.930 242.920 8968.70 9053.00 9412.27 97.650 242.570 8963.28 9047.58 9455.59 96.020 230.460 8958.11 9042.41 9479.44 95.540 229.210 8955.71 9040.01 9499.57 95.100 226.400 8953.84 9038.14 9529.69 96.240 222.180 8950.86 9035.16 9567.12 97.210 217.440 8946.48 9030.78 9601.99 98.440 214.450 8941.73 9026.03 9644.14 100.810 209.530 8934.68 9018.98 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 369.90 N 183.09 E 5961063.07 N 632515.55 E 409.62 N 197.04 E 5961103.03 N 632528.80 E 421.35 N 198.66 E 5961114.78 N 632530.21 E 429.48 N 197.48 E 5961122.89 N 632528.88 E 442.69 N 192.65 E 5961136.02 N 632523.82 E 454.12 N 185.87 E 5961147.32 N 632516.84 E 466.79 N 175.82 E 5961159.81 N 632506.56 E 475.33 N 167.60 E 5961168.20 N 632498.20 E 484.53 N 156.31 E 5961177.21 N 632486.75 E 494.54 N 138.68 E 5961186.91 N 632468.95 E 502.40 N 119.16 E 5961194.42 N 632449.29 E 509.13 N 82.70 E 5961200.50 N 632412.72 E 508.23 N 42.32 E 5961198.90 N 632372.36 E 503.02 N 2.97 E 5961192.99 N 632333.11 E 493.19 N 39.72W 5961182.41N 632290.60 E 482.69 N 67.74W 5961171.42 N 632262.77 E 467.54 N 98.41W 5961155.73 N 632232.37 E 451.50 N 129.54W 5961139.15 N 632201.53 E 427.81 N 165.34W 5961114.83 N 632166.15 E 412.51N 183.47W 5961099.21N 632148.29 E 399.05 N 198.32W 5961085.49 N 632133.68 E 377.60 N 219.24W 5961063.67 N 632113.14 E 349.05 N 243.03W 5961034.72 N 632089.85 E 321.09 N 263.31W 5961006.40 N 632070.07 E 285.86 N 285.32W 5960970.79 N 632048.68 E Alaska State Plane Zone 4 PBU_WOA U Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.913 30.533 37.543 26.344 23.893 21.365 21.876 34.302 33.411 29.151 33.756 28.417 31.466 30.396 34.421 4.948 6.509 28,008 5.589 14.070 14.446 12.841 9.198 12.808 -379.46 -415.86 -424.71 -429.09 -434.00 -436.26 -436.85 -436.14 -433.54 -426.63 -416.89 -393.54 -362.25 -328.94 -290.10 -261.97 -228.81 -194.73 -152.12 -128.39 -108.36 -78.52 -41.89 -8.31 31.31 Tie-On Point Window Point Continued... 11 August, 1999 - 16:21 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for U-O6A Your Ref: 500292111701 Job No. AKMW90141, Surveyed: 31 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9683.69 102.390 202.140 8926.71 9011.01 9721.27 100.630 203.370 8919.21 9003.51 9766.69 98.700 214.800 8911.56 8995.86 9807.82 97,650 215.850 8905.72 8990.02 9828.94 97.560 218.670 8902.92 8987.22 9866.62 97.470 220.420 8897.99 8982.29 9896.94 95.180 224.640 8894.65 8978.95 9927.19 94.480 227.280 8892.10 8976.40 9949.69 94.040 229,390 8890.43 8974.73 10001.07 95.270 239,940 8886.25 8970.55 10057.94 93.430 237.470 8881.94 8966.24 10113.29 91.490 232.730 8879.56 8963.86 10156.17 90.970 225,870 8878.64 8962.94 10181.29 90.610 221.830 8878.29 8962.59 10220.79 90.000 224.290 8878.08 8962.38 10269.64 90.440 231.520 8877.89 8962.19 10314.29 89.470 235.190 8877.93 8962.23 10348.89 86.570 231.850 8879.12 8963.42 10446.67 86.400 221,480 8885.13 8969.43 10475.42 86.040 218.310 8887.03 8971.33 10512.57 88.680 215.330 8888.74 8973.04 10579.07 86.920 207.940 8891.30 8975.60 10607.27 86.750 197.750 8892.86 8977.16 10642.20 84.810 192.470 8895.43 8979.73 10676.79 81.470 191.070 8899.56 8983.86 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 251.02 N 302.20W 5960935.66 N 632032.42 E 217.07 N 316.44W 5960901.46 N 632018.78 E 178.01 N 338.18W 5960862.03 N 631997.73 E 144.80 N 361.72W 5960828.40 N 631974.78 E 128.14 N 374.39W 5960811.52 N 631962.41 E 99.33 N 398.18W 5960782.30 N 631939.13 E 77.13 N 418.54W 5960759.75 N 631919.16 E 56.18 N 440.21W 5960738.42 N 631897.87 E 41.27 N 456.97W 5960723.21N 631881.37 E 11.69 N 498.69W 5960692.90 N 631840.18 E 17.77 S 547.13W 5960662.60 N 631792.26 E 49.39 S 592.47W 5960630.18 N 631747.49 E 77.33 S 624.95W 5960601.67 N 631715.50 E 95.44 S 642.35W 5960583.26 N 631698.43 E 124.30 S 669.32W 5960553.93 N 631671.97 E 157.03 S 705.54W 5960520.57 N 631636.33 E 183.67 S 741.36W 5960493.30 N 631600.99 E 204.22 S 769.16W 5960472.26 N 631573.56 E 271.11 S 840.05W 5960404.14 N 631503.86 E 293.11S 858.44W 5960381.81N 631485.85 E 322.82 S 880.68W 5960351.72 N 631464.14 E 379.35 S 915.51W 5960294.58 N 631430.31E 405.27 S 926.43W 5960268.48 N 631419.85 E 438.88 S 935.51W 5960234.71N 631411.37 E 472.50 S 942.51W 5960200.98 N 631404.95 E Alaska State Plane Zone 4 PBU_WOA U Pad Dogleg Vertical Rate Section (°/100ft) (ft) Comment 18.733 66.77 5.676 99.65 25.167 141.55 3.592 181.02 13.242 201.47 4.611 238.27 15,760 268.17 8.999 298.25 9.554 320.68 20.605 371.61 5.406 427.58 9,246 482.60 16.040 525.44 16.145 550.43 6.416 589.68 14.828 638.48 8.502 683.02 12.779 717.50 10.587 814.85 11.073 843.13 10.710 879.33 11.415 942.53 36.085 967.66 16.065 996.40 10.459 1023.55 Continued... 11 August, 1999 - 16:21 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for U-O6A Your Ref: 500292111701 Job No. AKMW90141, Surveyed: 31 July, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10715.67 79.360 186.150 8906.04 8990.34 510.39 S 948.25 W 5960162.99 N 631399.88 E 10768.79 78.980 176.500 8916.04 9000.34 562.48 S 949.46 W 5960110.88 N 631399.59 E 10803.69 83.760 168.740 8921.29 9005.59 596.66 S 945.02 W 5960076.79 N 631404.63 E 10831.00 84.460 163.470 8924.09 9008.39 623.02 S 938.50 W 5960050.54 N 631411.62 E 10882.29 86.480 154.510 8928.15 9012.45 670.70 S 920.18 W 5960003.20 N 631430.77 E 10918.19 88.330 146.770 8929.78 9014.08 70'1.93 S 902.61 W 5959972.28 N 631448.89 E 10939.14 85.250 144.130 8930.95 9015.25 719.15 S 890.75 W 5959955.27 N 631461.05 E 10971.00 85.250 144.130 8933.59 9017.89 744.88 S 872.15 W 5959929.87 N 631480.11 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Alaska State Plane Zone 4 PBU_WOA U Pad Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 13.606 17.856 25.895 19.365 17.854 22.145 19.349 0.000 1052.53 1087.28 1106.10 1118.26 1135.29 1142.22 1144.38 1146.95 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 229.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10971.00ft., The Bottom Hole Displacement is 1146.95ft., in the Direction of 229.500° (True). Continued... 11 August, 1999 - 16:21 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for U-O6A Your Ref: 500292111701 Job No. AKMW90141, Surveyed: 31 July, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA U Pad Comments Measured Depth (ft) 8800.00 8919.00 10971.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8729.12 369.90 N 183.09 E 8840.42 409,62 N 197.04 E 9017.89 744,88 $ 872.15 W Comment Tie-On Point Window Point Projected Survey 11 August, 1999 - 16:21 - 5 - DrillQuest WE£L OG TFIANSM/ AL ProActive Diagnostic Services, inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL I MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT[S) U-06a 8-1-99 Open Hole I I I I Signed ' Print Name: ProActive Diagnostic Services, Date' .'-,Ub ~'J ]999 .h~as~,~) Oil & Gas Cons. Commission Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com Please Check When Transmittal Reports are Returned. Keep copy of this letter in the file for future use. C:LMy DocumentskExcel_Word_DocumentskDistribution_ForrnskBp_pb_form.doc TONY KNOWLE$, GOVEFINOFI ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Jul',' 26. 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Rc~ Prudhoe Bay Unit U-06A BP Exploration (Alaska) Inc. Permit No: 99J'~ 7~ Sur Loc: 103~SL, 1663~3/EL, Sec. 18. T11N, R13E. UM Btmhole Loc. 4509'NSL. 2606%VEL. Sec. 19. T11N. R13E. UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting 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 new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlfJEnclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS , OIL AND GAS CONSERVATION ~-~_~,MMISSlON PERMIT TO DRILL 2O AAC 25.005 la. Type of work f-] Drill [~Redrill Ilb. Typeofwell [-I Exploratory DStratigraphicTest I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator i5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE -- 84.30' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028283 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 103' NSL, 1663' WEL, SEC. 18, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 515' NSL, 1464' WEL, SEC. 18, T11N, R13E, UM U-06A At total depth 9. Approximate spud date Amount $200,000.00 4509' NSL, 2606' WEL, SEC. 19, T11 N, R13E, UM 08/18/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047451,3246'I No Close Approach 2560 11091' MD / 8947' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e) (2)} Kick Off Depth 8925' Maximum Hole Angle 96° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2741' 8350' 8230' 11091' 8947' =118 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' truemeasuredvertical 92149325 feetfeet Plugs (measured) 0 Effective depth: measured 9280 feet Junk (measured) true vertical 9173 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 8 cu yds concrete 110' 110' Surface 2649' 13-3/8" 3746 cuft Permafrost E & II 2685' 2685' Intermediate 8853' 9-5/8" 1740 cuft Class 'G', 279 cuft PF 8889' 8812' Production Liner 944' 7"' 271 cuft Class 'G' 8381' - 9325' 8342' - 9214' Perforation depth: measured 8920' - 8944' (Sag River) 9040' - 9082', 9096' - 9140' (Ivishak) true vertical subsea 8757' - 8780' (Sag River) 8868' - 8961' (two Ivishak intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,/~ Ted Stagg Title CT Drilling Engineer Date Commission Use Only Permit Number I APl Number Approval Date I See cover letter ~'- ,~ 50-029-21117-'~t. 0¢.3~ ~ ~' ~, ,, ¢~ for other requirements Conditions of Approval: Samples Required []Yes ~'No Mud Log Required l-lYes ~No Hydrogen Sulfide Measures [~]Yes []No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE []2K; [] 3K; ,J~4K; [] 5K; [] 10K; [] 15K Other: by order of :Approved By ORIGINAL SIGNED-BY Commissioner the commission Date ~ L L LI Al- i (obert N. Chdstenson Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX U-06a Sidetrack Summary of Operations: U-06 production performance has fallen off due high water cut. The sidetrack, U-06a, will target the lower Zone 4. This sidetrack will be conducted in two phases. Phase 1: Set whipstock: Planned for August 14, 1999. · A Tubing Integrity Test will be performed. · A Kinley caliper will be run over the tubing and liner. · A permanent whipstock will be set on E-Line at approximately 8,925' MD. Phase 2: Squeeze Perfs, Mill Window and Drill Directional Hole: Planned for August 18, 1999. Directional drilling coiled tubing equipment will be rigged up and utilized to squeeze perfs, mill the window and drill the directional hole as per attached plan to planned TD of 11,091' MD (8,947' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and all other Class II wastes will go to Grind & Inject for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,350' MD and cemented with approx. 21 bbls. cement to bring cement 200 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 8,925' MD (8,762' TVD ss) - TD: 11,091' MD (8,947' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction log will be run in open hole. TREE: 4" CIW WELLHEAD: McEVOY ACTUATOR: BAKER 13 3/8" 72# L-80 BTRS I 2680'1 ~ KOP: 4800' MAX ANGLE: 25° @ 9100' 4 1/2" 12.6# L-80 BTRS TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT Top liner approx. 8,390' Top perf @ 8,920' TOP OF LINER 9 5~8" 47# I 8889'I L-80 BTRS U-06a Proposed Completion OKB. ELEV-- 84.30' BF. ELEV = 48.80' CMT'd 4-1/2" SSSV LANDING NIPPLE ( OTIS )( 3.813" ID) 2097' GAS LIFT MANDRELS ~.AMC..(') WI RI 2gg2' 5136' 6585' 7607' 8259' AT~I-I/ T~/I'~ 2907' 5049' 6496' 7527' 8152' 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) K-22 TUBING ANCHOR ~9 5/8" PERM PACKER (BAKER) (3.99" ID) --4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2" "XN" NIPPLE (OTIS) (3.725" ID) 4 1/2" WLEG (ELMD) 8321' 8322' 8323' 8380' I S401' I 8413' J 8398' J Top Whipstock approx. 8,925' 2 7/8" liner cemented to 200 ft above window U-06 PERFORATION SUMMARY :{EF LOG: GEARHART-BHCS (RUN 2) 6-22-84 TIE IN LOG: SWS - CBL 6-26-84 IISIZE SPF F 1/8" 4 I 4 1/2" 8 41/2" 8 INTERVAL OPEN/SQZ'D 8920-8944' 9040-9082' 9096-9140' OPEN/5-10-88 O PEN/8-28-90 OPEN/8-28-90 Abandonment Cement 7"26# L-80 ~ U-06a Case 301 6/18/99 ~.X=631392 lY=5959800 -500 U-06 X distance from Sfc Loc 500 5[ -500 -1,000 IWell Name U-06 I CLOSURE Distance 1,283 ft Az 226 de~ NEW HOLE E/W (X) N/S (Y) Kick Off 190 415 TD -925 -889 State Plane 631,414 5,959,801 Surface Loc 632,339 5,960,690 DLS de~/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 35 -57 365 Curve 3 10 -90 290 Curve 4 10 90 229 Curve 5 10 -90 399 Curve 6 10 180 115 Curve 7 10 -90 239 Curve 8 10 90 499 2,166 Drawn: 7/20/99 7:34 Plan Name: Case 301 Section Path Distance (Feet) 500 1,0001,500 2,000 2,500 3,000 Angle @ K.O.= 20 deg MD:8925 U-06a Case 301 6/18/99 Marker Depths ~::)ri~l Wellbore TSGR I 8,7521ft TVD TSHU I 8,7821ff TVD Kick Off I 8,7621ft TVD 8,9251ft MD IDeprtr @KO 471 ft I MD KO Pt 8,925 MD New Hole 2166 Total MD 11,091 TVD TD 8,947 DLS de~l/1 O0 Tool Face Lencjth Curve 1 6 0 ~30 Curve 2 35 -57 365 Curve 3 10 -90 290 Curve 4 10 90 229 Curve 5 10 -90 399 Curve 6 10 180 115 Curve 7 10 -90 239 Curve 8 10 90 499 2,166 Drawn: 7/20/99 7:34 Plan Name: Case 301 U-06a CT Drilling & Completion BOP LU 36" 22.5" 2 3/8" CT ~1 I i i I 10,000 psi Pack-Off 7 1/16" Annular 71/16'5000psi I Blind/Shear 71/16" Pipe/Slip 2 3/8" I 7 1/16" Pipe ,~ -~ 2 3/8" SWAB OR MASTER VALVE STATE OF ALASKA ALA;~?,,A OIL AND GAS CONSERVATION'~OMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging J--JTime Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation ShutdoWn [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 103' NSL, 1663' WEL, SEC. 18, T11 N, R13E, UM At top of productive interval 515' NSL, 1464' WEL, SEC. 18, T11N, R13E, UM At effective depth 641' NSL, 1421' WEL, SEC. 18, T11N, R13E, UM At total depth 663' NSL, 1415' WEL, SEC. 18, T11N, R13E, UM 5. Type of well: ,~ Development [] Exploratory [] Stratigraphic I--] Service 6. Datum Elevation (DF or KB) KBE -- 84.3O' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number U-06 9. Permit Number 84-78 10. APl Number 50-029-21117 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9325 feet true vertical 9214 feet Effective depth: measured 9280 feet true vertical 9173 feet Casing Length Size Structural Conductor 110' 20"x 30" Surface 2649' 13-3/8" Intermediate 8853' 9-5/8" Production Liner 944' 7" Plugs (measured) Junk (measured) Cemented 8 cu yds concrete 3746 cuff Permafrost E & II 1740 cuft Class 'G', 279 cu ft PF 271 cu ft Class 'G' MD TVD 110' 110' 2685' 2685' 8889' 8812' 8381' - 9325' 8342' - 9214' Perforation depth: measured 8920' - 8944' (Sag River) 9040' - 9082', 9096' - 9140' (Ivishak) true vertical subsea 8757' - 8780' (Sag River) 8868' - 8961' (two Ivishak intervals) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8413' Packers and SSSV (type and measured depth) 9-5/8" Baker permanent packer at 8323'; 4-1/2" Otis SSSV Landing Nipple at 2097' 13. Attachments C~ Description summary of proposal I--] Detailed operations program E~ BOP sketch [14. Estimated date for commencing operation August 14, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved 15. Status of well classifications as: J~ Oil [] Gas J--1 Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17.1 hereby certify that the fore~ true and correct to the best of my knowledge Signed Ted Stagg Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test __ Subsequent form required 10- j Approval No. Approved by order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED BY .~.. ~r! N. Ghris~enson Commissioner Submit In Triplicate DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET / O~ 149g CKO& 14~c~C 100. OC 100. 0 HANDLING INST' S/I- TERRI HUBBLE X4&28 ,,,' THE AnACHED CHECK IS IN PAY=:~'."I' FOR ITEMS DESCRIBED ABOVE. mi[I]~I'L'N~ m 1 OO. O0 1 O0. OO PAY :'TO. The: ORDER ANCHDRAOE AK 99501-3120 ,'~.53. i, 0],,, ,:Oh~i~O:~ScIs,_' OO.O. hh&ci,, COMPANY _~,/~ WELL NAM~,,/ ~--/°~ PROGRAM: exp __ dev ~ redrll '~_ serv __ wellbore seg ann. disposal para req __ WELL PERMIT CHECKLIST FIELD & POOL ~/'"~:~,/'~, INIT CLASS GEOL AREA o~-. ,,--~ UNrr~, ,, N ON/OFF SHORE ADMINIS I I~ATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ~ psig 26. BOPE press rating appropriate; testto '7' ' 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N Permit can be issued w/o hydrogen sulfide measures ..... ~Y N Data presented on potential overpressure zones ...... /~Y NN Y_,/4q /,~/7~,,,//'') Seismic analysis of shallow gas zones .............. Seabed condition survey (if off-shore) ............. Y N Contact name/phone for weekly progress reports [exploratorzy'only] GEOLOGY 30. 31. 32. APPR ~ 33. ~ :34. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UlC/Annular RP _~_~ BEW WM JDH COMMISSION: co c~ ~/z~-h~ Comments/Instructions: '0 Z 0 ITl c:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Dec 02 12:49:10 1999 Reel Header Service name ............. LISTPE Date ..................... 99/12/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services ~ Tape Header Service name ............. LISTPE Date ..................... 99/12/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MW-90141 STEVE LATZ WHITLOW/HUPP RECEIVED :-~ 0 9 1999 · ~Jaska Oil & Gas Cons. Commissior~ U-06A Allohor~e 500292111701 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DR~LLING SERVICES 02-DEC-99 MWD RUN 2 AK-MW-90141 STEVE LATZ WHITLOW/HUPP MWD RUN 3 AK-MW-90141 MEL GABEL WHITLOW/HUPP 18 llN 13E 84.30 DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 82.30 48.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH {FT) 13.375 2680.0 9.625 8889.0 7.000 8919.0 3.750 10971.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS. 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 01/08/99 (PDS GR) WITH A KBE OF 84.3' AMSL. THIS WELL KICKS OFF FROM U-06 AT 8919'MD, 8756'SSTVD. 4. MWD RUNS 1-3 REPRESENT WELL U-06A WITH API#: 50-029-21117-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10971'MD, 8934'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8915.0 10945.5 ROP 8920 . 5 10975 . 0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 8919.0 8917.5 8923.5 8922.5 8931.0 8928.5 8934.0 8933.0 EQUIVALENT UNSHIFTED DEPTH 8942 0 8949 5 8951 0 8955 5 8958 0 8971 5 8977 5 8984 5 8989 5 8991 5 8993 0 8995 5 9006 0 9025 0 9036 0 9042 0 9062 5 9070 5 9077 0 9085 0 9086 5 9088 5 9100 0 9101 5 9102 5 9104 0 9108 0 9113 5 9126 5 9128 5 9156 0 9161 5 9176 0 9181 0 9186 5 9193 0 9196 5 9206 0 9227 5 9294 5 9356 5 9372 5 9529 5 9539 5 9551 0 9564 0 9579 0 9588 0 9625 5 9662 5 9673 0 9678 5 9680 0 9693 0 9717 0 9778 0 9783 0 8940 5 8948 0 8949 5 8954 0 8956 5 8970 0 8975 5 8982 0 8988 5 8990 0 8992 5 8994 5 9005 0 9023 0 9034 0 9040 0 9060 5 9068 5 9075 0 9083 0 9084 5 9086.5 9098.0 9099.5 9101.0 9102.0 9106.5 9111.5 9124.5 9127.0 9153.0 9159.0 9173.5 9178.5 9184.0 9190.5 9194.0 9204.5 9226.0 9292.5 9353.0 9368.0 9525.0 9535.0 9546.5 9558.5 9574.0 9583 5 9621 0 9658 0 9668 5 9675 5 9677 5 9691.0 9715.0 9773.0 9778.0 9788 9808 9810 9849 9921 9994 10001 10075 10095 10149 10174 10177 10201 10206 10213 10377 10462 10600 10633 10643 10661 10714 10716 10731 10754 10784 10786 10793 10813 10815 10829 10831 10839 10840 10890 10901 10925 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: 9783.0 9803.5 9805.5 9844.0 9916 5 9988 5 9995 5 10070 0 10089 5 10145 5 10171 0 10173 5 10197.5 10202.5 10209.5 10372.5 10457.0 10595.0 10631.0 10640.5 10658.0 10712.5 10715.5 10730.5 10753.0 10782.0 10784.0 10790.0 10810.0 10812.0 10825.5 10828.0 10834.5 10836.0 10886.5 10898.0' 10921.5 BIT RUN NO MERGE TOP MERGE BASE 1 8940.0 9329.0 2 9329.0 10632.0 3 10632.0 10971.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 8915 10975 9945 4121 GR 21.34 820.1 47.7648 4062 ROP 0.7 500.5 107.473 4110 First Last Reading Reading 8915 10975 8915 ~ 10945.5 8920.5 10975 First Reading For Entire File .......... 8915 Last Reading For Entire File ........... 10975 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8913.5 9297.0 ROP 8919.0 9326.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 29-JUL-99 INSITE 3.2up3, 4.02 7.74, 1.22 MEMORY 9329.0 8940.0 9329.0 20.3 83.4 TOOL NUMBER T-PCG 2 3.750 3.8 FLOPRO 8.80 65.0 9.3 21000 6.8 .000 .000 .000 .000 150.0 .3 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8913.5 9326 9119.75 826 8913.5 GR 23.98 820.1 90.618 768 8913.5 ROP 0.7 304.9 85.8667 815 8919 Last Reading 9326 9297 9326 First Reading For Entire File .......... 8913.5 Last Reading For Entire File ........... 9326 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9297.5 10602.0 ROP 9326.5 10632.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FTi: BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 31-JUL-99 INSITE 3.2up3, 4.02 7.74, 1.22 MEMORY 10632.0 9329.0 10632.0 86.0 102.4 TOOL NUMBER T-PCG 1 3.750 3.8 FLOPRO 8.70 65.0 9.3 19500 6.8 .000 .000 .000 .000 154.0 .3 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9297.5 10632 9964.75 2670 9297.5 GR 21.34 194.7 37.9382 2610 9297.5 ROP 38.8 500.5 111.081 2612 9326.5 First Reading For Entire File .......... 9297.5 Last Reading For Entire File ........... 10632 Last Reading 10632 10602 10632 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10606.0 10942.0 ROP 10632 . 5 10971.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY {LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 31-JUL-99 INSITE 3.2up3, 4.02 7.74, 1.22 MEMORY 10971.0 10632.0 10971.0 78.9 88.3 TOOL NUMBER T-PCG 2 3.750 3.8 FLOPRO 8.80 65.0 9.5 21000 6.8 .000 .000 .000 .000 175.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10606 10971.5 10788.8 732 10606 GR 23.26 154.46 37.8187 673 10606 ROP 25.1 360 119.753 679 10632.5 First Reading For Entire File .......... 10606 Last Reading For Entire File ........... 10971.5 Last Reading 10971.5 10942 10971.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/12/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/12/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 99/12/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File