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Home My WebLink About195-065Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~ -- 0(o~,-c~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~Vincent Nathan Lowell Date: ~'"~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ - ~a~~~ STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. WeN Class: ^ Development ^ Exploratory ®Sen+ice ~ ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Su p., or Aban~d~/~ 10/2112008 6~S~i 12. Permit to Drill Number 195-065 ~ 308-309 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 08/13/1995 13. API Number _ 50-029-20436-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 08/21/1995 14. Well Name and Number: PBU Y-05A - 1295 FNL, 4947 FEL, SEC. 34, T11 N, R13E, UM Top of Productive Horizon: 4525' FNL, 3775' FEL, SEC. 34, T11 N, R13E, UM 8. KB (ft above MSL): 88.22' Ground (ft MSL): 49.76' 15. Field /Pool(s): ; Prudhoe Bay Field / Prudhoe Bay Total Depth: 36' FNL, 4157' FEL, SEC. 03, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 11038' 9005' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 645146 y- 5948967 Zone- ASP4 10. Total Depth (MD+TVD) 11063' - 9006' ~ 16. Property Designation: ADL 047471 TPI: x- 646387 y_ 5945761 Zone- ASP4 Total Depth: x- 646023 y- 5944963 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi I r nic and rin inf rm i n er 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost tTVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, LWD, SBL, GR, CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED 0"x3" In I Cnu r urf 11 rface 11 12 dsAr i " 7 ' 7-1/ " r I /8" 47# L- 0 15' rf 7 1 -1/4" 1 1 u P rm fros 7" L-80 1 11043' 471' 9 - / " 7 I ' 23. Open to production or inject ion? ^ Yes ®No 24. Tuewc RECORD If Yes, list each i (MD+TVD of Top ~ Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 4-1/2", 12.6#, L-80 9848' 8007' & 9808' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. ~r.l~ } 3l`.~~, ~ ~~~~ i L ~ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ?' , ~'7y+: ~+ ~.~ 10972' Set Whipstock 10977' Pi3A w/ 2 Cement'obs 50 Bbls then 51 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Core s A wired? ^ Yes ®No tf Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25 `0.071. None ~~~~: ~~ .~I~ 4E ~ 2008 ~~~ . ,D ~~~ I Form 10-407 ReVISed 02 ~ CONTINUED ON REVERSE SIDE 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9845' 8862' None Shublik 9888' 8884' Sadlerochit 10182' 8961' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d ' t ~ ~/~~ ~ gne Title Drilling Technologist Date Terrie Hubble PBU Y-05A 195-065 308-309 Prepared ey NameMumber. Terrie Hubble, 564-4628 Well Number P rmi N . / A VIN Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 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 weN 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only li __ • Y-05A, Well History (Pre Rig Sidetrack) Date Summary 7/1/2008 T/I/0= 450/0/0 Temp=hot P1OGCC MIT IA PASSED to 4000 osi (AOGCC witnessed by C. Sheve) (CTD Screening) Pumped 10.6 bbls neat methanol down IA to reach test pressure. First 15 min. IA lost 80 psi, second 15 min. IA lost 0 psi, IA lost total of 80 psi in 30 min. Bled IAP down, bled back approx. 8 bbls. Casing valves tagged and left open, operator notified. FWHP's = 450/60/20 7/22/2008 T/I/O = 800NAC/9. Temp =Injecting water (Dewatering)., Swapped out 24-hour chart for 7-Day chart and wound chart recorder. 7-day chart was installed @ 11 O'Clock am. WV =Shut. Swab, SSV & MV =Open. IA & OA = OTG and Chart recorder. 7/25/2008 T/I/0= VACNAC/40. Temp= SI. Rigged down 3 pin recorder (DEWATERING). SV, WV, MV =SHUT SSV, IA, OA =OPEN 9/11/2008 MIRU, perform weekly BOP test. 9/12/2008 MU &RIH left hand motor with a 3.80" Parabolic Diamond bit. RIH w / 3.625" x 18.21' Dummy whipstock,, taq PBTD 11038'. POOH. Job complete. 9/23/2008 T/IA/OA= 3000/350/900 Temp=Hot PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre CTD) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite caps. Cycle and torque LDS "Standard" (1) LDS out C~ 12:00 all others move free with no bent pins. PPPOT-IC RU 2 HP bleed tools onto IC test void 50 psi, flushed void until clean returns achieved. Pressure void to 3500 psi for 30 minute test, 2000/ 15 minutes, 350/ 30 minutes. Bleed IC void to 0 psi. Cycle and torque LDS "Standard" (1) LDS out C~ 7:00 all others move free with no bent pins. 10/1/2008 T/I/0=10/0/0. Set 6" CIW J BPV. Pre Nordic 2. 10/12/2008 T-0 / IA-0 / OA-0. Pressure test swab to 4500 psi for 15 min, no pressure loss (pass).r Shell tested tree to 4500 osi for 15 min. No pressure loss, (pass). 10/18/2008 T/I/O = BPVNac/40 MIT OA PA ~ D to 2000 nci_, (Pre CTD) Pumped 2.4 bbls of crude into the OA to reach test pressure. MIT OA lost 60 psi in the 1st 15 min and 20 psi in the 2nd 15 min for a total loss of 80 psi in the 30 min test. Bled OAP back down. Final WHP's =BPV/-0/0 DSO notified of following upon departure. Wing, Swab = S/I Master, IA, OA =Open SSV found locked open upon arrival. 10/21/2008 T/I/O vac/0/0 Pulled 6' ciw J plug, used 4-5' and 1-2' tagged at 78' for Nordic 2. Page 1 of 1 BP EXPLORATION Page 1 of 23 Operations Summary Report Legal Well Name: Y-05 Common Well Name: Y-05 Spud Date: 5/4/1980 Event Name: 'REENTER+COMPLETE Start: 10/14/2008 End: 11/11/2008 Contractor Name:. NORDIC CALISTA Rig Release: 11 /11 /2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~ 10/21/2008 ~ 02:00 - 04:00 ~ 2.00 ~ RIGU ~ P ~ ~ PRE 04:00 - 10:00 6.00 I BOPSUF# P ~ PRE 10:00 - 14:30 4.501 BOPSUFjP 14:30 - 14:45 0.25 RIGU P 14:45 - 17:45 3.00 RIGU P PRE PRE PRE 17:45 - 18:20 0.58 RIGU P PRE 18:20 - 20:00 1.67 RIGU P PRE 20:00 - 21:00 1.00 RIGU P PRE 21:00 - 21:15 0.25 RIGU P PRE 21:15 - 22:50 1.58 RIGU P PRE 22:50 - 23:50 1.00 KILL P WEXIT 23:50 - 00:00 0.17 KILL P WEXIT 10/22/2008 00:00 - 04:45 4.75 KILL N WAIT WEXIT 04:45 - 05:15 0.501 WHIP P WEXIT 05:15 - 05:25 0.17 WHIP P WEXIT 05:25 - 06:25 1.00 WHIP P WEXIT 06:25-06:50 ~ 0.42~WHIP ~P ~ WEXIT 06:50 - 07:15 0.42 WHIP N SFAL WEXIT 07:15 - 07:55 0.67 WHIP N SFAL WEXIT 07:55 - 09:40 1.75 WHIP P WEXIT 09:40 - 10:20 0.67 WHIP P WEXIT 10:20 - 10:45 0.42 WHIP P WEXIT 10:45 - 11:35 0.83 WHIP P WEXIT Released from Y-09A. PJSM. Back off well. Move down pad to Y-05. PJSM. Spot Rig over well. SAFETY MEETING re: NU BOPE NU BOPE. Set cuttings box Test ROPE 250/3500. AOGCC waived witness DSM moved the uprights, tiger tank and RU hardline and PT Set welding shop. Filled pits and uprights w/ KCI Safety mtg re: pull CT to floor Pull CT to floor and stab. Replace packoff. Install CTC. Reverse fill CT w/ KCI. PT inner reel valve and packoff to 250/3500 Reverse slack back 3.7/3600 Pop off well. Cut coil to find wire - 9tt. Test wire. Install coil connector, pull test to 35k. Head up BHI UOC. Stand back injector & pump coil volume to complete a-line slack process. PJSM regarding pulling BPV. RU DSM lubricator & pulling tools. Stab lubricator onto well. P.T. to 1000psi. Leave 250psi & open master - 5psi on well, Pull 6" CIW BPV. LD DSM lubricator. Fluid pack well with 6bbls. Flow check - it flows ~ 0.1 bpm - 10psi. Bullhead 1.5 times tubing volume - 290bb1s 2% KCL ~ 6bpm. Initial injection rate of 6bpm ~ 1029psi, final injection rate of 6bpm ~ 765psi. Flow check well - it still flows ~ 0.1 bpm - 10psi. SI well & monitor pressure. Order & wait on 290bb1s, 9ppg KWF & a new reel swivel. Remove checks & blow back coil & swap out reel swivel. Build up rate in 1hr is 22psi. P.T. coil to 4300psi - no leaks. SI swab at tam & blow down kill line to prevent freezing. Open swab at 4am to monitor pressure -well is on a vac. Flow check well. PJSM regarding PU whipstock. MU BHI coil track tools & BOT 4-1/2"x7" WS. PU injector & stab onto tools. Stab onto well. Power up & test tools. Set counters. PVT 182 RIH w/ WS circ KCI 1.15/430 thru EDC w/full returns to 1800' and find that new CT packoff is wom out due to rusty CT (mfgd 8/2006) Safety mtg re: change packoff Re lace ackoff Resume RIH w/ WS circ thru EDC 1.2/480 PVT 237 Log GR tie-in down from 9860' CTD and are within 5' of being on depth 33k up wt Continue RIH 50'/min circ 1.53/780 and get some intermittent gas Log GR tie-in down from 10890' circ 1.54!730 25.5k dn. Corr +3'. RIH to set depth at 10989.5' rnntea: i uz~zuu° ~ ruz: ~g nm BP EXPLORATION Operations Summary Report Legal Well Name: Y-05 Common Well Name: Y-05 Event Name: REENTER+COMPLETE Start: 10/14/2008 Contractor Name: NORDIC CALISTA Rig Release; 11/11/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To I Hours Task Code NPT Phase Page 2 of 23 Spud Date: 5/4/1980 End: 11 /11 /2008 Description of Operations 10/22/2008 11:35 - 11:45 0.17 WHIP P WEXIT WS orientation is 178R. 26.5k hanging wt. Pressure CT to 3200 psi and see 6k wob before tool stroked and WS set. Stack 3k. PUH 41 k and left TOV11S ~ 10972' PVT 245 11:45 - 13:50 2.08 WHIP P WEXIT POH w/ setting assy circ thru tool 1.0/360. Take 35 bbls to cuttings box when retums were gassy and reeked of PW injection solids 13:50 - 15:00 1.17 WHIP P WEXIT LD WS setting BHA and remove checks from BHA. Tool string is covered w/ hea mun to to bottom. Have to wash exterior of tools w/diesel to cut it 15:00 - 16:00 1.00 STWHIP P WEXIT MU nozzle BHA w/ 6' pup Check packoff and was okay. Check screen in reelhouse and had a few minor solids. PT connection break to 4100 psi PVT 169 16:00 - 18:30 2.50 STWHIP P WEXIT RIH w/ BHA #2 circ thru nozzle 0.5/200 18:30 - 18:50 0.33 STWHIP P WEXIT PJSM regarding cement job. 18:50 - 20:10 1.33 STWHIP P WEXIT Begin mixing cement. RIH & tag WS. Taa WS at 10.980ft, corr -oft, up wt = 42k, flag pipe. Cement is at weight at 19:50, send sample to SLB lab. Pump 5bbls of bio w/ rig pump. Lost out MM for 20bbls. P.T. cement line, 250psV4000psi. 20:10 - 22:25 2.25 STWHIP P WEXIT Pump 50bbls of 15.8ppg class 'G' cement into the coil at 2bpm/2000psi with 2bpm returns (until 40bbls away) while slowly reciprocating coil. Slowly start closing the choke to get 1 for 1 displacement - 175psi WHP (8.34ppg out density). Close choke (built to 430psi) & SD pumps & clean up cement lines & pump truck. Swap to rig pumps & displace with bio lost retums & can't hold WHP let 2bbls come above EOP, lay in cement 1 for 1 at 2bpm/350psi, (26bbls achieve 1:1 with circ pressure climbed to 1000psi). Cement is out of nozzle at 10,150ft (40bbls on out MM). PUH to 9800ft. With 50psi on WHP, close choke, slowly PUH & wait 15min. Slowly bump up WHP, achieve 225psi WHP ~ ibpm. Wait for 15min, WHP fell to 100 si. Slowly bump up WHP, achieve 260psi WHP ~ 1bpm. 22:25 - 00:00 1.58 STWHIP P WEXIT Open choke, RIH at 50ft~min & contaminate to TOWS at_, ith 1.5bpm iNout. Lightly tag TOWS, PUH & have 50% losses. Slowly chase cement up hole while pumping 2.5bpm in/1 bpm out. At 10.560ft while PUH, lost all returns (all out of Bio too - 150bb1s pumped). PUH into the 4-1/2" tubing. At 9500ft, slowly gaining returns - 0.4bpm out with 2.5bpm in. (This is not fun anymore)- 10/23/2008 00;00 - 01:50 1.83 STWHIP P WEXIT Continue to POH while pumping at 2.5bpm in 0.3bpm out. Stop at 4600ft & divert cement retums to cuttings box - 50bbls of 10.5ppg. Hold 300psi WHP to get 1 for 1 retums. Inject at 2bpm ~ 400psi. SD pumps & let WHP bleed to Opsi. 01:50 - 03:00 1.17 STWHIP P WEXIT RIH pumping 2bpm with 1:1 retums. Occasionally take retums outside. Gently tao WS. 03:00 - 03:25 0.42 STWHIP P WEXIT Increase pump rate to ibpm/2600psi, slowly PUH to clean up 7" liner, 44k up wt. PUH to 9700ft while washing nipples & the packer. 03:25 - 03:45 0.33 STWHIP P WEXIT RIH to the WS at 10,970ft. 03:45 - 05:00 1.25 STWHIP P WEXIT PUH & clean up the 7" liner. 05:00 - 06:30 1.50 STWHIP P WEXIT Park ai 7000ft & slowly reciprocate coil with 1:1 returns while wo second batch of cement rnmea: nrz~zuuu 77:UZ:79 HM BP EXPLORATION Operations Summary Report Page 3 of 23 Legal Well Name: Y-05 Common Well Name: Y-05 Spud Date: 5/4/1980 Event Name: REENTER+COMPLETE Start: 10/14/2008 End: 11/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/11/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 110/23/2008 ~ 06:30 - 07:45 ~ 1.25 ~ STW H I P ~ P 07:45-08:20 0.58 STWHIPIP 08:20 - 08:45 0.42 STWHIP P 08:45 - 09:50 1.08 STWHIP P 09:50 - 10:30 I 0.671 STWHIPI P 10:30 - 11:20 I 0.831 STWHIP~ P 11:20 - 11:40 0.331 STWHIP P 11:40 - 12:20 I 0.671 STWHIP~ P 12:20 - 12:45 I 0.421 STWHIP~P 12:45 - 13:15 I 0.501 STWHIPP 13:15-13:30 ~ 0.25~STWHIP~P 13:30-13:55 ~ 0.42~STWHIP~P 13:55-14:40 ~ 0.75~STWHIP~P 14:40 - 15;30 I 0.831 STWHIP~P WEXIT RIH from 7000' 1.38/630 to tag at 10958' w/ a few wt loss spots in the 7"liner below the second set of perfs. PUH w/ 7k over. PUH thru liner area w/ a few 2-4k OP's WEXIT Circ 0.5/360 while PUH thru EOT and RBIH WEXIT Safety mtg re: cement WEXIT m nt w/ 4:04TT and 78cc FL Cement to wt at 0935 hrs. SWS take sample for UCA test IA 5, OA 463 PVT 280 WEXIT SWS PT 4000. Pump 5 bbls FW followed by 51.0 bbls 15.8 G cement at 1.8/1200-2600 psi at 69F. Swap to rig pump WEXIT PUH 5'/min from 10240' while WHP increased to 520 psi due to imbalance of cement in CT and KCI on BS. Displace cement w/ biozan 1.75/1580 w/ choke closed at initial 500 psi WHP. After 22 bbls out of nozzle the whp was at max of 800 psi, but took a drink and fell back to 740 psi. Continue displ cement 1.831970 unti135 bbls were displaced and whp=750 psi. Red rate to 1.0/300 w/ 13 bbls left and had 680 psi whp. Open choke w/ 6 bbls left and while POH to safety. Last bbl out of nozzle at EOT at 9850' WEXIT POH to 9000' w/ open choke and got over 5 bbls extra fluid back and determine well is continuing to breathe back at 0.2_ m. SI and had no press incr WEXIT Begin hesitation sqz and took 3.6 bbls to get 200 psi whp, which bled to 145 psi in three min and falling slowly. Repressure to 240 psi and bled back to 135 psi. Repressure and only get to 240 psi. Bled back to 172 psi in 5 min. Could not get whp to 300 psi and always bled back at least 100 psi in the first miri and then fell off slowl .After 10 bbls pumped start RIH 40'/min w/ choke closed and watch WHP hold at -300 psi WEXIT RIH from 8800' at 40'/min pumping occasionally and with choke closed. IOIP^t GT disolacement at 300-350 osi who, WEXIT RIH 40'/min thru EOT and bring rate up to 1.0/920. RIH w/ choke closed and dilute/displace cement w/ biozan at -450-500 psi whp. Perform occasional wt chks after wt loss spots. At 10900' 1.0/990 w/ 560 psi whp w/ choke closed. Tag at 10954'. PUH w/ 3k overpull WEXIT POOH to EOT 70'/min while rediluting cement 1.0/930 w/ 540 psi injection whp to the EOT WEXIT Park at 9870' w/ pump SD and monitor initial 505 psi whp 5 min 487 psi 10 min 472 psi 15 min 460 psi 20 min 454 psi PUH 100' to 9750' and whp was 447 psi WEXIT PUH 5'/min while bleed off whp to gauge pit and monitor on out MM. After 20 min had 17 bbls and was bleeding down at 1.0. b m rate w/ 150 psi whp. After 30 min had 25 bbls and still flowing back at 0.5 bpm w/ 70 psi whp. After 40 min had 28.5 bbls back and returns were 0.1 bpm w/open choke WEXIT Start cleanout by RIH 40'/min from 9600' jetting 2.1/1120 w/ open choke At 10000' 2.55/2.32/1580 and assume ECD's are charging up r• BP EXPLORATION Page 4 of 23 Operations Summary Report Legal We11 Name: Y-05 Common Well Name: Y-05 Spud Date: 5/4/1980 Event Name: REENTER+COMPLETE Start: 10/14/2008 End: 11/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 11/11/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/23/2008 14:40 - 15:30 0.83 STWHIP P WEXIT the formation again. After 50 bbls of returns, started getting cement up to 9.5 ppg back. Return rate gradually increased as density fell off and by 10600' 2.49/2.62/2000 while RIH 25'/min. Just before tag 2.5/2.83/1970 at 26'/min 15:30 - 16:00 0.50 STWHIP P WEXIT POH jetting liner 2.50/1950 at 40'/min. Return density 8.86#. Took 5 min for return rate to return back to normal 16:00 - 17:50 1.83 STWHIP P WEXIT POOH for millin assy. 17:50 - 20:00 2.17 STWHIP P WEXIT Pop off well. Remove blanks & install check valves. Inspect flow sub -remove cement sheath around wire. Test wire -bad on both tests. Stab onto well. Jet stack. Function test BOP's. Jet stack. Pop off well. 20:00 - 22:50 2.83 STW HIP N SFAL WEXIT Trouble shoot a-line. Moisture is evident in the wire at the anchor end & are able to burn it off with the meg tester. Test from inside of reel (disconnect wire) -bad on insulation lest. Test wire to MWD shack -fine. Retest wire -good ohms but continuity shows more moisture. Place injector over bung hole. Pump - 50ft of slack out of the reel. Test wire, ohms was ok, insulation test was bad. Pump 193ft more wire out. Test wire, ohms was ok, insulation test was bad. Remove wire from junction box, remove visible water inside juction box. Test wire from both ends & to MWD shack, both tests are ok. 22:50 - 00:00 1.17 STWHIP N SFAL WEXIT Cut off CTC. Terminate end of wire w/ protector. Stab onto well. Pump slack into reel. Pop off well & cut coil to find wire. 10/24/2008 00:00 - 03:40 3.67 STWHIP N SFAL WEXIT Cut 244ft to find wire. Test wire -good. Dress end of coil. Install CTC. Pull test to 35k -good. Test wire -good. Behead BHI. Test wire -bad insulation test. Troubleshoot again. Problem disappeared. Replace terminal strip inside junction box as a precaution. Test wire again -good. Swap out packoffs. 03:40 - 04:00 0.33 STWHIP P WEXIT Stab onto well. Test packoffs 250psi/3500psi -pass. 0 0 - 04:10 0.17 I P WEXIT PJSM regarding MU milling BHA. \I 1'~ 04:10 - 04:50 0.67 STWHIP P WEXIT MU milling BHA, mills were 3.8"go, 3.79"no-go. Stab coil onto tools. Stab onto well. Power up & test tools. Set counters. 04:50 - 06:40 1.83 STWHIP P WEXIT RIH w/ milling BHA Camp fire drill 06:40 - 06:50 0.17 STWHIP P WEXIT Set down at 9828' (assumed X nipple). Start pump 2.4/2030 and run thru w/minor MW. Did not see XN nipple 06:50 - 0$:00 1.17 STWHIP P WEXIT Precautionary ream thru 7" liner to WS at 20'/min and had MW/w[ loss at various spots. Go thru gas buster for 10 min. RIH last 20' at min rate and tag at 10975.3' CTD. PUH w/ no OP PVT 292 08:00 - 08:45 0.75 STWHIP P WEXIT Start motor 2.44/2.42!1630 w/ 9.05 ECD and ease in hole looking for pinch point and find it at 10977.8' Corr to 10976.6' and flag PVT 292 08:45 - 11:45 3.00 STWHIP P WEXIT Time mill window from 10976.6' 2.45/2.45/1550 w/ 8.94 ECD w/ 0-200 psi dill, 0-2.30k wob PVT 291 11:45 - 14:30 2.75 STWHIP P WEXIT Time mill window from 10980.0' 2.42/2.42/1580 w/ 8.94 ECD w/ 100-300 psi dill, 1.8-3.Ok wob PVT 291 14:30 - 22:00 7.50 STWHIP P WEXIT MW at 10981.7' was from stacked wt. Continue milling 2.38/2.38/1600 w/ 8.95 ECD w/ 100-250 psi dill, 2.5-3.2k wob. Exit window w/ 3 stalls at 10,985.5ft. Mill 10ft of formation. Ream & backream window three times, 45k up wt. 10% formation seen in sample from 10,995ft. Run through window dry -good. rnncea: i vc~cwo i i.vc. ~. r~.~ VELLf~EAD= FN ~~CTUATOR= AXELSC (B. ELEV = 83. 3F. ELEV = 49. ;OP = 280 Aax Angle = 95° @ 1289 )alum MD = 989 )atum TVD = 8800' Y -O 5 B WF~2E BELOW SECT ON WINDOW NOT@SHOWN OND DIAGRAM. DRLG DRAFT 20- 0~ 4-1/2" HES' X NIP, ID=3.813" 2574' IJ 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2673' 8007' ~ 9-5/8" x 4-1 /2" TNV HBBP-T PKR, ID = 3.919" TMJ 6' TIEBACK SLV, ID = 7.36" I 8215' Minimum ID = 2.27" @ 9829' DEPLOYMENT SLV PROFILE PERFORATION SUMMARY REF LOG: ANGLEATTOPPERP ~)i' =~' ' ;"70' Note: Refer to Production DB for historical pert data. SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 13200' - 13400' O 11110/08 9-5/8" CSG, 47#, L-80, BTRS, ID = 8.681" ~ 9617' 9823' TOP 3-3/16" x 2-7/8" LINER 4-1/2" TBG, 12.6#, L-80, 0.0152 by $223' ~ 9-5/8" X 7" TNV LT PKR, ID = 6.170" $22$' 9-5/8" X 7" TIW LNR HGR, ID = 6.109" 7" MILLOUT WINDOW (Y-05B) 10972' TO 16935' (OFF WHIPSTOCK) 9797' 4-1 /2" HES X NIP, ID = 3.813" 9808' 7" X 4-1/2" BKR SAB-L3 PKR, ID = 3.87; 9825' 4-1/2" HES X NIP, ID = 3.813" 9836' 4-1/2" HES XN NIP, ID milled to = 3.8i TOC ~ 9823' ~ f, ID = 3.958" 9848' 9848' 3-1/2" LNR, 9.2#, L-80, ID = 2.992" 9874' 3-1 /2" x 3-3/16" XO, ID = 2.786" 9874' 3-3/16" LNR, 6.2#, L-80, ID = 2.805" 11918' 3-3/16" x 2-7/8" XO, ID = 2.377" 11918' ~~4-1/2" WLEG, ID = 3.95 ELMD WHIPSTOCK 10972' PBTD I-~/ 1103E 2-7/8" LNR, 6.4#, L-80, ID = 2.441" I~ 13531' 7" LNR, 29#, NT-SOS, 0.0371 bpf, ID = 6.184" ~_f 11043' DATE REV BY COMMENTS DATE REV BY COMMENTS O6/03/80 ORIGINAL COMPLETION 08/30/95 KSB SIDETRACKCOMPLETION 11/11/08 Nordic 2 CTD SIDETRACK (Y-05B) PRUDHOE BAY UNfT WELL: Y-05B PERMfT No: 2081380 API No: 50-029-20436-02 Sec. 34, T11 N, R13E BP Exploration (Alaska) ALASSA OIL A1~TD GA,S COI~TSERQATIOPIT COMi~IISSIOrT SARAH PAUN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. ~~~~ SAP ~ `~ z~~$ PO Box 196612 ~ ~ CQ~7 Anchorage, AK 99519-6612 1 q Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-05A Sundry Number: 308-309 Dear Mr. McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. _ / ! Chair DATED this ~7d~"a~y September, 2008 Encl. .~.,~,,, C ! V I ~~ •~j' STATE OF ALASKA 'S-OJ'~ I A U G 2 q ~ ~ '° I3 ALASKA'OIL AND GAS CONSERVATION COMMISSI p~8 1~ ~ APPLICATION FOR SUNDRY APPROVAL ska ~'~ ~ ~~~ Cons. Cfln~l;;~~~;~•, 20 AAC 25.280 Anc#~~r~ 1. Type of Request: ®Abandon > ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ ARer Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: BP Ex loration (Alaska) Inc. 4. Current Well Class: ^ Development ^ Exploratory 5. Permit To Drill Number 195-065 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 ®Service ~ ^ Stratigraphic 6. API Number: 50-029-20436-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? ^ Yes ®No 8. Well Name and Number: PBU Y-05A - 9. Property Designation: ADL 047471 10. KB Elevation (ft): 88.22' 11. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): 11063' ~ Total Depth TVD {ft): 9006' Effective Depth MD (ft): 11038' Effective Depth TVD (ft): 9005' Plugs (measured): None Junk (measured): None M 7' 1 -/" 7' 7 Perforation Depth MD (ft): 10210' -11029' Perforation Depth TVD (ft): 8965' - 9004' Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Tubing MD (ft): 9848' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW'HBBP-Tpacker; 7" x 41/2" Baker'SABL-3' packer Packers and SSSV MD (ft): 8007'; 9808' 13. Attachments: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed O erations Pro ram 14. Well Class after proposed work: ^ Exploratory ^ Development ®Service 15. Estimated Date for Commencin O erations: October 1, 2008 16. Well Status after proposed work: ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: Commission Representative: ^ WAG ^ GINJ ^ WINJ ^ WDSPL 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean Mct_auahtin, 564387 Printed Name Sean McLau hlin Title CT Drilling Engineer Prepared By NameMUnber: Signature ~ Phone 564-4387 Date ~~tE e,8 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ` ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~~' `, ~S ~`~ ~~-~ Other: 43 S~7 Q Spy 1~0 ~ ~S~` Subsequent Fo equired: L~© APPROVED BY A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revis /2 06 S b it In Duplicate I SPA L ~ ~~ ~~P ~ ~ ~oo~ • • . To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission p From: Sean McLaughlin CTD Engineer Date: August 27, 2008 Re: Y-05A Sundry Approval Sundry approval is requested for Prudhoe well Y-05A. The original Y-05i well started injection in 1986 at 3000 bwpd and 350 psi but was suspected of HOT breakthrough in 1991 when rates shot up to 10,000 bwpd at 1200 psi. The Y-05Ai Rig ST was drilled to restore injection conformance, providing support for the surrounding Zone 4B producers, and to make the well competitive for MI injection. It was completed in August 1995 as a horizontal Zone 4 injector with a 7" cemented & perforated liner. Y-05Ai was put on WAG injection and has cumulative injection of 11.6 mmbw and 11.4 bcf MI to date. Y-05Ai was the first high angle (89 deg max hole angle at 10,862') injector in Prudhoe Bay or in any BP operated field. It was perforated in three sections (the heel, mid, toe) with the intent of creating three separate thermal fracture networks, each expected to have the rate of a conventional well. The initial target rate of 7000 bwpd was achieved with SWI. Two WAG cycles with SWI were completed then it was switched to PWI/MI service. The last MI cycle was in 2002. It has been on PWI service since. Five IPROFs have been run, the last in May 2007. The IPROFs have indicated that all three intervals take fluid somewhat uniformly (there is enough mung in the wellbore to make the interpretations fairly subjective). The current Y-05Ai pattern is not effective. The only active producer is Y-14B. It is a 100 bopd 80% WC well. The other producers are Y-34A (totally swept based on OH resistivity), Y-37A (lost during CTD operations with 2300' coil fish left in the hole), and Y-12 (SI for TxlxO communication since 1999). There are no remedial plans for any of these producers. REASON FOR SUNDRY: The current Y-05Ai injection support is largely ineffective and the pattern needs to be reconfigured. This CST will be a toe drill-out targeting a downthrown fault block to the south of Y-05Ai. It will be the first injector in the fault block and will provide sweep and support for the northern half of the Y-09A horizontal producer. Pre-CT Rig Work: (Start prep October 1, 2008) 1. F MIT-IA, -OA 2. W PPPOT-T. Torque LDS. 3. C Mill XN nipple to 3.8" (Use Left Hand motor and D331 4. C Run Dummy whipstock drift (3.7" x 17') to PBTD 5. W Set BPV 6. W PT MV, SV, WV 7. O Blind and bleed lines, remove well house, level pad DONE 07/01/08 mill) ~~~ ~ ~~Q~~~~ Rig Sidetrack Operations: (Scheduled to begin on November 20, 2008 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test, Pull BPV 3. RIH with a Baker TT 4-1/2 x 7" Thru Tubing whipstock. Set top at 10,972'. 4. Saueeze 45 bbl of cement to isolate parent well perforations 5. Mill 3.80" lowside window. 6. Drill 4.125" lateral section to 13,840' 7. Run and cement a 2-7/8" x ~16" L-80 liner string • 8. Make a cleanout run with mill and motor and MGR-CNL logging tool. 9. Perforate well. 10. FP well to 2000' 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = 6" CAMERO WELLHEAD= FMC ACTUATOR= AXELSON KB. ,F1EV = 83.2' BF. ELEV = 49.3' KOP = 2800' IMax Angle = 89 @ 10862' 'Datum MD = 9833' Datum TVD = 8800' SS Y-0 5A GO~RIZO AL @ 1046® LD WELBORE BELOW SECTION WINDOW NOT SHOWN ON DIAGRAM. 2004' 4-1/2" HES ' X NIP, ID = 3.813" 2574' IJ 9-5/8" DV PKR 13-3l8" CSG, 72#, L-80, ID = 12.347" I-{ 2673' 8007' U 9-5/8" x 4-1 /2" TM/ HBBRT PKR, ID = 3.919" ~ TNV 6' TIEBACK SLV, ID = 7.36" ~ Minimum ID = 3.725" @ 9836' 4-1/2" HES XN NIPPLE P~tFORATION SUMMARY REF LOG: GR/RES 08/22/95 A NGLE AT TOP PERF: 53 @ 9800' Note: Refer to Production DB for historical oerf data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9800' - 9802' S 08/26/95 3-3/8" 6 10210' -10230' O 08/28/95 3-3/8" 6 10250' -10330' O 08/28!95 3-3/8" 6 10570' -10590' O 08/28/95 3-3/8" 6 10610' -10690' O 08/28/95 3-3/8" 6 10970' -11029' O 08/22/95 9-5/8" CSG, 47#, L-80, BTRS, ID = 8.681" I-i 9617' 7" LNR 26, L80, 0.0383 bpf, ID = 6.276" I-I 10668' 8223' u 9-5/8" X 7" TNV LT PKR ID = 6.170" 8228' 9-5/8" X 7" TNV LNR HGR ID = 6.109" 9-5/8" MILLOUT SECTION WINDOW 8415' - 8465' 9797' 4-1/2" HES X NIP, ID = 3.813" 9808' 7" X 4-1/2" BKR SAB-L3 PKR, ID = 3.875" 9825' 4-1 /2" HES X NIP, ID = 3.813" 9836' 4-1/2" HES XN NIP, ID = 3.725" 984$' 4-1/2" WLEG, ID = 3.958" ELMD 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I-I 9848' PBTD 11038' 7" LNR 29#, NT-80S, 0.0371 bpf, ID = 6.184" ~j 11043' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/80 ORIGINAL COMPLETION 08/30/95 KSB SIDETRACK COMPLETION 03/04/01 SIS-QAA CONVERTED TO CANVAS 07/03/01 CWKAK CORRECTIONS PRUDHOE BAY UNff WELL: Y-05A PERMff No: 95-0650 API No: 50-029-20436-01 Sec. 34, T11 N, R13E BP Exploration (Alaska) I TREE = 6" CAMERON WELLHEAD; FMC ACTUATOR= AXELSON KB..EIEV = 83.2' BF. ELEV = 49.3' KOP = 2800' Max Angle = 89 @ 10862' Datum MD = 9833' Datum TV D = 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" I -O ~ ~' G~IR ONTAL @ 1046® LD W BORE BELOW Proposed CTD Sidetrack SECTION WINDOW NOT SHOWN ON DIAGRAM. 2004' 4-1/2" HES' X NIP, ID = 3.813" 2574' LJ s-5/a^ Dv PKR 9-5/8" x 4-1/2" TMJ HBBP-T PKR, ID = 3.919" I TNV 6' TIEBACK SLV, ID = 7.36" ~~ 821 Minimum ID = 3.725" @ 9836' 4-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: GR/RES 08/22/95 ANGLE AT TOP PERF: 53 @ 9800' Note' Refer fn Prnriurtinn f)R fnr hictnrical nerf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9800' - 9802' S 08/26/95 3-3/8" 6 10210' -10230' O 08/28/95 3-3l8" 6 10250' -10330' O 08/28/95 3-3/8" 6 10570'-10590' O 08/28/95 3-318" 6 10610' -10690' O 08/28/95 3-3/8" 6 10970' -11029' O 08/22/95 9-5/8" CSG, 47#, L-80, BTRS, ID = 8.681" ~ 9617' 9816' TOP 3-3/16" x 2-7/8" LINER 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" ~~ 9848' 13-3/16" x 2-7/8" L-80 Liner, Cemented 8 Perf'd 6223' u 9-5/8" X 7" TNV LT PKR ID = 6.170" 822$' 9-5/8" X 7" TNV LNR HGR, ID = 6.109" 9-5/8" MILLOUT SECTION WINDOW 8415' - 8465' 9797' 4-1/2" HES X NIP, ID = 3.813" 9808' 7" X 4-1/2" BKR SAB-L3 PKR, ID = 3.875" 9825' 4-1/2" HES X NIP, ID = 3.813" 9836' 4-1/2" HES XN NIP, ID rrmlled to = 3.80" /~ 9848~~2" W~ DID = 3.958" TOC I~ 9900' XO I~ 11770' I 7" LNR 29#, NT-80S, 0.0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/80 ORIGINAL COMPLETION 08/30/95 KSB SIDETRACK COMPLETION 03/04/01 SIS-QAA CONVERTEDTOCANVAS 07/03/01 CWKAK CORRECTIONS 07/31/08 MSE PROPOSED CTD SIDETRACK PRUDHOE BAY UNfT W~L: Y-OSBi PERMfr No: API No: 50-029-20436-02 Sec. 34, T11 N, R13E BP Exploration (Alaska) ~+ ® ~~~ • TO: ~ 7 P1mRpggisor ~~~C r(hl~C~'ft"". FROM: Chuck Scheve Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 02, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) NC Y-OSA PRUDHOE BAY UNIT Y-OSA Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv . ~'1 Comm Well Name• PRUDHOE BAY UNIT Y-OSA Insp Num• mitCS080702075802 Rel Insp Num: API Well Number: so-029-2oas6-ot-oo Permit Number 195-065-0 Inspector Name• Chuck Scheve Inspection Date• x/1/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-osA (Type Inj. `N TVD ~z9o - , IA o ~ aozo ~ 39ao s9ao p T I95o6so ' TypeTest SpT Test psi Iszzs OA o ' zo ! zo zo Interval 4YRTST p~F P / TUbing i 450 450 ~ 440 ~ 440 i Notes: ~~~ AUG ~~ ZD[~8 Wednesday, luly 02, 2008 Page I of 1 . . WELL LOG TRANSMITTAL "--- .--......-.-......---.....-----......,.--.--- ~----------' ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) 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 : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 2 5,.' 7\'07 ~~~e~est International Airport Roa~ JUN, .~ Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) EDE Disk Jewelry Log 26-May-07 26-May-07 EDE Disk Y - 05A Y - 05A Coil Flag UI..C- lq~-0~6- ~ J5<9"3S- 'tl I S-~3.b Signed: ~,1L-- ',"i 'i 'J 7qn1 (,,,,' .l ~!.ii..i 1 Date,~, NO O"'~7 '''Or'S ('0mmiS$ìçn c\k¡;:,~\Ci >.,,,.!h 0 ',-,."q ''oJ - ~ . Print Name: ð-t... r j';7i;,t1IA..Q... ¡11 o.1t IJi k..9 í.A PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDS¡~~;]CHOR:;GE(W¡\ilE:~7CR\...LOC:;.-;Ot'fì WEBStTE : 1f0lfql.N~ME:\;10[=t\;LOG.COi1/t D.\Master _Copy _00_ PDSANC·2OxxIZ _ Word\Distnòution\Tr.msmittal_ Sheets\Tr.msmit_ Original.doc ....,......,...." Schlumberger sCANNED JUN 2, 1 Z007 NO. 4306 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 - U Ie.... I qs- - 0fD '6 Field: Prudhoe Bay C CD Well Job# Loa Description Date BL olor L3·12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 1 Y -11 C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L 1 11686753 LDL OS/28/07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROF/IPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07 A 11626098 PRODUCTION PROFILE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF W/RST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z·29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Date Delivered: ,11 ¡¡",j ? ,n 10m Received by: ~ {J" "'...,f' ! 06/18/07 . . ...~ STATE OF ALASKA . ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 88.22 KB ( 8. Property Designation: ADLO-047471 ( 11. Present Well Condition Summary: Total Depth measured 11063 í feet true vertical 9005.73 feet Effective Depth measured 11033 feet true vertical 9004 feet Casing Length Size MD Conductor 110' 20"x30" Surface - 110' Surface 2673' 13-3/6" 72# L-80 Surface - 2673' Production 8415' 9-518" 47# L-80 Surface - 8415' Liner 2828' 7" 29# L-80 8215' - 11043' Perforation depth: Measured depth: 10970 - 11029 True Vertical depth: 9001.71 - 9004.23 11015 -11029 9003.62 - 9004.23 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) Stimulate 0 Exploratory Service ~ 9. Well Name and Number: PBU Y -OSA / 10. Field/Pool(s): Prudhoe Bay Fieldl Prudhoe Bay Pool " Plugs (measured) None Junk (measured) None TVD Surface - 110' Surface - 2673' Surface - 7646' 7471' - 9005' Collapse Burst 5380 6870 8160 2670 4760 7020 - ~jUN 112007 - L-80 Surface - 9848' 7"X4-1/2" BKR SAB-L3 9-5/8"X4-1/2" TIW HBBP-T PKR o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 1 0 o 4486 0 15. Well Class after oroposed work: Exploratory r Development 16. Well Status after proposed work: Oil Gas WAG 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations O¡/-Bbl o o x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble 9808' 8007' o o RBDMS 8Ft JUN 0 8 2007 Tubing pressure 2083 787 Service P-' WINJ~ WDSPL Title Data Management Engineer Signature Phone 564-4944 Ised 04/2006 LJ R t GIN A l Date 611/2007 Submit Original Only ~ ~ . .. Y -05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU #8 wi 1.75" OD i-coil. Memory 10g/perf/lPROF. MIRU CTU #8. MU and RIH POS GR/CCL logging assembly and 3.1" 00 JSN. RIH and tag TO at 11020' CTMO. Continued on WSR 05/27/07. 512712007 CTU #8 wi 1.75" 00 i-coil. Memory 10g/perf/lPROF. Continued from WSR Log up from 11020' to 10950'. Flag pipe at 10950' and log up to 9600'. POOH and confirm good data; calculate corrected PBTO at 11035' with reference Sperry Sun MWO OGR 22-Aug-95. MU and RIH with perforating assembly Gun #1 (20' - 2 7/8" PJ Omega). Tie-in to tailpipe jewelry with i-COIL and make initial correction to top shot of (-14'). Tagged TO and correlated good with corrected TO of previous run. Logged primary correlation off bottom with i-COIL. Made +2' correction. Positioned Gun #1 and perforated 10995' to 11015' (20'). PUH logging off. POOH. MU and RIH with Gun #2 (25' - 2 7/8" PJ Omega). Tie-in to tailpipe with i-COIL and make a correction to ccl of -22 ft. Position gun #2 and perforate 10970' to 10996' (25') with reference to Sperry Sun MWO-OGR 22-Aug- 95. Perforations are 2-7/8" PJ Omega, 6 spf, 60 degree phasing. Continued on 05/28/07. CTU #8 1.75" 00 i-coil. IPROF. Continued from after perforating assembly logging through jewelry. Pull to surface, confirm all shots fired. Have pad operator place well on injection. MU and RIH with POS STP logging assembly. Log interval 1 0150' to 11008' ctmd. Log up and down passes at 60 and 80 fpm. Make stop counts between all perf intervals. POOH. Tools clogged with heavy tar like Schmoo. No useful spinner data, spinners quit by 6000' in hole, sporadic data deeper, spinner non-functional due to Schmoo. Prep to perform SBG job. RIH with 3.0" JSN. Tag TO at 11026' ctmd. POOH jetting hot SBG, taking no returns. Let SBG soak while MU SLB STP logging assembly. Overdisplace SBG at high rate with 1 % KCL. Continued on WSR 05/29/07. #8 1.75" 00 i-coil. on injection and RIH with SLB STP logging assembly. RIH and perform stop counts between all perf intervals as per program. Perform dynamic upldown passes across logging interval at 40, 60, & 80 fpm. POOH and confirm good data. ROMO CTU #8. Left well on *** Job *** FLUIDS PUMPED BBLS 29 29 11% XS KCL TOTAL Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~} 01/25/2007 NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 () J: C. I ~5-- O~ $"'" Field: Prudhoe Bay . Well Job# Loa Description Date BL Color CD P2-37A 11491392 MEM PROD PROFILE 11115106 1 Y -23B 11418299 MEM PROD PROFILE 09106106 1 NK-07A 11588698 MEM GLS 12121106 1 07-01A 11555031 GAS ENTRY SURVEY 12119106 1 NK-08A 11485780 MEM GLS 12120106 1 NK-27 11588699 MEM GLS 12122106 1 NK-43 11513659 PRODUCTION PROFILE 12122106 1 DS 09-32 11555530 INJECTION PROFILE 12116106 1 P2-14 11539745 MEM PROD PROFILE 12107106 1 Y-05A 11539744 MEM INJECTION PROFILE 12106106 1 s-02A 11285936 MEM PROD PROFILE 08117106 1 12-32 11536184 USIT 12105106 1 MPS-10A 11486087 COMPOSITE WFLlLDL 12114106 1 Z-19A 11226013 SCMT 10128106 1 Y-30L 1 11588700 MEM PROD PROFILE 12123106 1 E-11 B 11434757 DSI 10124106 1 E-11 B 11434760 DSI 10129106 1 E-11 B 11434760 FMI 10129106 1 G-14A 11485777 MEM PROD PROFILE 11127106 1 G-14A 11485777 SCMT 11127106 1 0\ . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SCANNED JAN 3 0 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: MEMORANDUM State of Alaska TO: ~~ s~:~sor ~'t II/rt.ltk Alaska Oil and Gas Conservation Commission FROM: John Spaulding Petroleum Inspector DATE: Monday, November 08,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-05A PRUDHOE BAY UNIT Y -05A --<';i~^/D,ftl~ l,''f~' Src: Inspector Reviewed By: --<a.tl P.I. Suprv (j V- Comm Well Name: PRUDHOE BAY UNIT Y-05A Insp Num: mitJS041l06113521 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20436-01-00 Permit Number: 195-065-0 Inspector Name: John Spaulding Inspection Date: 11/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-05A Type Inj. F TVD 7290 IA 0 4000 3900 3980 P.T. 1950650 TypeTest SPT Test psi 1822.5 OA 0 20 40 40 Interval OTHER P/F P Tubing 460 480 480 480 Notes: 4 year test prior to swapping well to MI gas SCANNEr~~ NOV ~?, l;: 'lOOh Monday, November 08, 2004 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor (,~ Chairman THRU: Tom Maunder ~,-~A-- P.I. Supervisor/~' ! v ~' ~/-~ FROM: Chuck Scheve Petroleum Inspector DATE: July 24, 2002. SUBJECT: Mechanical Integrity Tests BPX Y Pad PBU Prudhoe Bay NON- CONFIDENTIAL Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D.I Notes: Y-05A 195-065 Y-18 183-029 Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj.I S I T.V.D. I 7290 I TubingJ 850 ] 850 J 850 I 850 I lntervall 4 TypetestI P ITestpsil 1823 ICasingI 0 I 23401 2320 I 23201 P/F I P J Type,nj.I S I T.V.D. 18~41 I~u~,,~l 1400 11400 I 1400 11400 Ilnterval[ 4' TypetestJ P ITestpsil 2110 I Casingl 690 I 23101 2300l 2300J P/F I P , J Type Inj. I I I I I I I I I lotervall Type testJI Test psi J I Casing I } I J I PIE I I Type Inj.} I T.V.D. I }Tubing I I } } }lntervall Type testI ITest psi l I CasingI I I I IP/F I IType Inj. I I T.V.D. I I Tubing I I I I I lntervall TypetestJ }TestpsiJ I Casing I I I I I PIE I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Y pad and witnessed the 4-Year MIT on wells Y-05A and Y-18. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T,'s performed: 2_ Attachments: Number of Failures: 0 Total Time during tests: 2 hours cc: MIT report form 5/12/00 L.G. MIT PBU Y Pad 7-24-02 CS.xls 7/31/2002 oN' oR c:t.o~t.~)°c 95.~. 065 95 ~' 06S 95-~065 95 065 95 .... 065 95 -- 085 Date~ 06/02/9'? RIIN F~AT~:i R m pV I 0 9 / 14/9 5 0 2 ,/- I 3 / .:,o 6 02/I s/96 '1 09 / 1 ~t/' 95 I 0..~/ lh/95 1 .... 3 08 / ''> '~ / 1 0 '--4.t 0 ? 4J,~ ""nH F' L E l I ON ....DATr:c ~/2- ~. /'-~p'"'=/' Ai'"e dr"y W a s !: I"~ ~:i,. .. , /i,., r" (;:; w e I I (:: 0 M H Fi.i N "F D A I I,. Y WELL OF,'S ~ ~t'01/~"7' TO //~o /%'--/ )a /M /"-Mi" -lf{ ~:i,a,,/-//o~_~ ~/.~,,~-,.,:; 'i es r'equ'i r'ed? ye::s ~ And r'ece'i ved'? yes :- Ana]ys'¥s & descr' '1' FI COlflp'i "~,FLti"l()e . . . :.[ n '¥ t: ~ ,s 'i 0 I::! I I__/I IM G S E I::!~/I I-- E S WELL LOG TRANSMITTAL To: State of Alaska August 21, 1996 Alaska Oil and Gas Conservation Comm. Attn.' Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 ~'~ t9 Co~ MWD Formation Evaluation Logs - Y-05A AK-MM-950838 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 ,. LDWG formatted LIS tape with verification listing. API#: 50-029-20436-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company D I::t I I_1_ I I~1 G S ~: F:t L/I C Elcl WELL LOG TRANSMITTAL To: State of Alaska February 9,1996 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant ~ 3001 Porcupine Dr. ~fi~f-) J Anchorage, Alaska 99501 MWD Formation Evaluation Logs - Y-05A, AK-MM950838 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs' 50-029-20436-01 1 Blueline 1 Rev Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs' 50-029-20436-01 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino, Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG ,, 1. Status of Well Classification ~f...,Service Well OIL [] 'GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Produce ~l~iector 2. Name of Operator 7. Permit Number 3. Address 8. P. O. Box 196612, Anchora~le, Alaska 99519-6612 36-01 4. Location of well at surface ?::.: .................... 9. Unit or Lease Name ' .... ~ ~ ~!'~:i'; ~ , ~ Prudhoe Bay Unit 1295'SNL, 4947' WEL, SEC. 34, T11N, R13E'~; N/A At Top Producing Interval -i ~~!!'_ i ~~/"~"~ :~ !:'?~i}i j~~i~,~,~,~. '~ 11.10' Well Number Y-O5A Field and Pool At Total Depth ........ ":_:; ·~ Prudhoe Bay Field/Prudhoe Bay Pool 37' SNL, 4148' WEL, SEC. 3, TION, R13E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 88.22 ADL 047471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 08/13/95 08/21/95 08/29/95I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11063'MD/8917' TVD 11033'MD/9002' TVD YES [] NO []I N/A feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, L WD, SBL, GR, CCL 23. CASING, LINER AND CEMENTING RECORD SE-FFING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 x 30 Insul. Cond. Surface 110' 36" 12 c.y. Arctic Set 13-3/8" 72# L-80 Surface 2673' 17-1/2" 3929 c.f. Permafrost II 9-5/8" 47# L-80 Surface 8415' 12-1/4" 1345 c.f. 'G', 130 c.f. Permafrost 7" 29# L-80 8215' 11043 8-1/2" 578 c.f. Class 'G' ., 24. Perforations open to Production (MD+TVD of Top and Bottom and ;~5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2" 9848' 8007'& 9808' MD TVD (Subsea) 9800'- 9802' 8748' - 8749' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10210' - 10230' 8877' - 8879' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10250' - 10330' 8881' - 8888' 8565' Kick Off Plu~l, 32 bbls 'G', Sqzd w/1800 ps/ 10570' - 10590' 8899' - 8900' 10610'- 10690' 8900'- 8904' Freeze Protected w/160 bbls Diesel 10970'- 11029' 8913'- 8916' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 5, 1995 Water Injector Injecting Date of Test Hours Tested PRODUCTION FOR ©IL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ORIGINAL ~ask8 Oil & Gcs Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -.. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea 8778' Top of Sag River 9853' 8799' Top of Shublik 9896' 8873' Top of Sadlerochit 10182' 31. LIST OF A'FI-ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-"~_~'/ (//"~ Title Senior Drillincl Enoineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ....... fr~.~ jection, Gas Injection, Shut-in, Other-explain. ~ ~.~ ~i V ~ L~ Item 28: If no cores taken, indicate "none". Form 10-407 OEO 1 2 1995 ,ask.~ 0it & G~s Co,s. C0mmissiorl Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: Y-05A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 08/01/95 (2) TD: 0 PB: 0 ANNUAL PLAINT. MW: 0.0 RIG MAINT. 08/02/95 (3) TD: 0 PB: 0 ANNUAL MAINT ANNUAL RIG MAINT. MW: 0.0 08/03/95 (4) TD: 0 PB: 0 RIG MAINTENANCE GENERAL RIG MAINTENANCE & REPAIR. MW: 0.0 08/04/95 (5) TD: 0 PB: 0 RIG MAINTENANCE ANNUAL RIG MAINTENANCE MW: 0.0 08/05/95 (6) TD: 0 PB: 0 ANNUAL MAINT. ANNUAL MAINT. MW: 0.0 08/06/95 (7) TD: 0 PB: 0 TURNKEY RIG MOVE PAD TO PAD ANNUAL MAINT. MW: 0.0 08/07/95 (8) TD: 0 PB: 0 TURNKEY RIG MOVE MW: 0.0 CONTINUE TURN KEY RIG MOVE F/G PAD TO Y PAD. 08/08/95 (9) TD: 0 PB: 0 TRUN KEY RIG MOVE CONTINUE RIG MOVE F/G PAD TO Y PAD MW: 0.0 WELL : Y-05A OPERATION: RIG : DOYON 14 PAGE: 2 08/09/95 (10) TD: 0 PB: 0 O8/lO/95 (11) TD: 0 PB: 0 08/11/95 (12) TD: 0 PB: 0 08/12/95 (13) TD: 0 PB: 0 08/13/95 (14) TD: 0 PB: 0 08/14/95 (15) TD: 8841' (8841) 08/15/95 (16) TD: 9515' ( 674) RIGGING UP OVER HOLE MW: 0.0 MOVE RIG ON Y PAD. REMOVE BOOSTER WHEELS, RAISE DERRICK. MOVE OVER WELL. CANTILEVER RIG OVER WELL HEAD. CONTINUE TO RIG UP. ACCEPT RIG ON 08/06/95 AT 1000 HOURS DUE TO MATTING OF BAD ROADS. TEST BOP'S MW: 0.0 RU FLOOR. PULL BPV, RU HOSES ON ANNULUS AND TUBING. DISPLACE DIESEL OUT AND CIRC TO SW, MONITOR FOR FLOW. SET TWC VALVE AND TEST TO 1000 PSI. ND TREE ASSEMBLY, NU BOP'S. RU AND TEST BOPE. RIH W/SECTION MILL MW: 0.0 TEST BOPE TO 500/5000 PSI. RU LUBRICATOR, PULL TWC VALVE, RD. RU TO PULL 4-1/2" TUBING, PULL HANGER. CBU. POOH AND LD 4-1/2" 12.6", N-80, AB MOD BTC TBG, SPOOL CONTROL LINE. TEST 9-5/8" PACK OFF TO 3500 PSI, TEST CSG TO 3500 PSI FOR 30 MIN. OK. TEST LOWER PIPE RAMS TO 500/5000 PSI, SET WEAR RING. MU MILLING ASSEMBLY AND RIH ON DP. MU KELLY HOSE, LOAD ADD DP IN SHED. CONT TO RIH. POOH W/MILLING ASSEMBLY MW: 0.0 RIH W/MILLING ASSEMBLY, TAG 4-1/2" TBG STUMP AT 9012'. SPOT 44 BBLS OF 17.1 PPG MUD. POOH TO 8550' DISPLACE WELLBORE TO 9.6 PPG MILLING FLUID (BIOZAN). POOH TO 8415', PU KELLY. CUT WINDOW IN 9-5/8" CASING F/8415' TO 8465'. CIRC HOLE CLEAN. POOH. RIH W/DRILLING ASSEMBLY MW: 0.0 POOH AND LD MILLING ASSEMBLY. RIH W/OEDP TO 8565'. CIRC HOLE CLEAN, PU TO 8465' CIRC, RIH TO 8565'. PUMP 5 BBLS H20, TEST LINES TO 3000, PUMP 15 BBLS H20, 32 BBLS CMT, 7 BBLS H20, DISPLACE W/130 BBLS MUD, CIP AT 1430 HRS. POOH 10 STDS. REVERSE CIRC (NO CMT RETURNS), APPLIED HESITATION SQUEEZE TO 1800 PSLEOR 1 HR. POOH, LD DP. FLUSH BOP STACK AND WORK ARMS. PULL WEAR BUSHING, MU BHA, INITIALIZE MWD. RIH. MU AND SET 9-5/8" RTTS. CHANGE 9-5/8" PACK OFF, TEST TO 5000 SPI. INSTALL WEAR BUSHING, RELEASE AND PULL RTTS. RIH. KICK OUT AND DRILL T/8841' MW: 0.0 VIS: 0 RIH TO 8173'. PU KELLY, WASH TO CEMENT AT 8258'. DRILL SOFT CEMENT TO 8310', DRILL FRIM CEMENT TO 8420' KICK OUT OF WINDOW AND DIRECTIONAL DRILL T/8841' DRILL T/9515' MW: 0.0 VIS: 0 DIRECTIONALLY DRILL FROM 8841' TO 9515' WELL : Y-05A OPERATION: RIG : DOYON 14 PAGE: 3 08/16/95 (17) TD: 9790' ( 275) 08/17/95 (18) TD:10123' ( 333) DIR DRILL T/9790' MW: 0.0 VIS: 0 DIRECTIONALLY DRILL FROM 9515' TO 9556'. CIRC HOLE CLEAN, PUMP PILL, CHECK FOR FLOW. POOH TO 9-5/8" CASING, CHECK FOR FLOW, POOH - HOLE IN GOOD COND. CHANGE BHA, LD MWD, PU NEW MWD/LWD, CHANGE BH ON MUD MOTOR TO 1.75 DEG, PU NEW BIT. RIH T/9556'. NO PROBLEMS, NO FILL. DIRECTIONALLY DRILL FROM 9556' TO 9790' DIR DRILL T/10123' MW: 0.0 VIS: 0 DIRECTIONALLY DRILL FROM 9515' TO 10123' 08/18/95 (19) TD:10155' ( 32) 08/19/95 (20) TD:10443' ( 288) 08/20/95 (21) TD:10730' ( 287) 08/21/95 (22) TD:10865' ( 135) 08/22/95 (23) TD:l1063' ( 198) 08/23/95 (24) TD:l1063' ( 0) DISPLACE MUD SYSTEM MW: 0.0 VIS: 0 DIRECTIONALLY DRILL F/10123' TO 10155'. CIRC HOLE CLEAN. CHECK FOR FLOW, POOH TO 9-5/8" (NO PROBLEMS), CHECK FOR FLOW, POOH. CHANGE OUT BHA. RIH, HIT BRIDGE AT 9777' HOLE PACKED OFF, WORK FREE W/ll5K OVERPULL. REAM F/9684' TO 9822'. HOLE PACKING OFF. PUMP 75 BBL HIGH VIS SPACER, CHANGE MUD SYSTEM TO NEW FLOPRO AND WEIGHT UP TO 9.8 PPG (HOLE CLEANING UP, NO EXCESS DRAG WHILE MOVING PIPE. DIR DRILLING @ 10443' MW: 0.0 VIS: 0 CBU TO 9.8PPG. REAM & WASH F/9777' T/ 10155'. DIRECTION DRILL F/10155' T/10443'. POOH (BHA @ RT) MW: 0.0 VIS: 0 DIRECTIONAL DRILL F/10443' T/10730'. CIRC HOLE CLEAN. FLOW CHECK. POOH FOR BIT CHANGE. TIGHT HOLE F/10240' T/10056'. WORK THRU TIGHT SPOTS @ 9900',9558',9216',8966',8720',8611', 8554' DIR DRILLING @ 10865' MW: 0.0 VIS: 0 DOWN LOAD MWD/LWD INFO. PULL WB. TEST BOPE TO 250/5000 PSI. INSTALL WB. MU BIT ~4, INITIATE MWD/LWD. RIH, CBU @ 4365' RIH T/8377'. CUT/SLIP DRILL LINE. RIH T/9818'. HOLE TIGHT. PU KELLY. WASH & REAM F/9808' T/9943'. RIH T/10555'. WASH & REAM F/10555' T/10730'. DIRECTIONAL DRILL F/10730' T/10865' POOH MW: 0.0 VIS: 0 DIRECTIONAL DRILL F/10865' T/11063' CIRCULATE HOLE CLEAN. CHECK FOR FLOW. POOH, TIGHT HOLE F/~962' T/9868'. CHECK FOR FLOW INSIDE 9-5/8", POOH. WASH & REAM T/10958' MW: 0.0 VIS: 0 POOH, L/D 22 JTS DP. L/D BHA, DOWNLOAD MWD/LWD, MU NEW BHA W/HO AND RR. RIH, BREAK CIRC AT 4728' AND 8367', RIH TO 9764'. PU KELLY AND REAM F/9764' TO 10212', REAM THROUGH TIGHT SPOT AT 9960'. RIH F/10212' TO 10481'. REAM F/10481' TO 10525'. RIH, L/D 4 SINGLES FROM DERRICK. REAM F/10525' TO 10958'. t.~S:S COns, Anchorage WELL : Y-05A OPERATION: RIG : DOYON 14 PAGE: 4 08/24/95 (25) TD: 0 PB: 0 08/25/95 (26) TD: 11063' ( 08/26/95 (27) TD:l1063' ( o) o) RUN 7" CSG MW: 0.0 CONT REAMING 8.5" HOLE F/10958' T/11063'. CBU. 10 MIN FLOW CHECK, SHORT TRIP TO 9-5/8" SHOE @ 8415'. TOH OK. TIH @ 9850'-9951',WORK THROUGH. CIRC AND CONDITION HOLE TO RUN 7" LINER. 10 MIN FLOW CHECK. POOH TO RUN 7" LINER (DROP 2.877" DRIFT). LD BHA & CLEAR FLOOR (139 BBLS TO FILL HOLE) RU TO RUN 7",29~ NT80S,NSCC CSG. RUN 68 JTS 7" CSG, W/ SHOE,FLOAT, PLUG CATCHER, TIW HANGER W/ LT PACKER. CIRC LINER VOLUME. RUN 2828' OF 7" LINER IN ON 5" DP @ 9-5/8" SHOE @ 0600 HRS. C/O 7" WIPER PLUG 10947' MW: 0.0 VIS: 0 M/U CMT HEAD WHILE CIRC DP AND 7" PIPE VOLUME AT 9-5/8" CASING SHOE AT 8415'. RUN 7" LINER THROUGH OPEN HOLE F/8415' TO 11043' TIGHT F/9800' TAKING 100,000# TO PUSH LINER IN HOLE. STUCK PIPE 20' OFF BOTTOM WHILE M/U CEMENT HEAD. CIRC AND CONDITION HOLE WHILE BATCH MIXING CEMENT. BROKE CIRC AT 5 BPM 1000 PSI AND INCREASED TO 9 BPM AT 1800 PSI AFTER CIRC BOTTOMS PAST LINE TOP PACKER. NO FLUID LOSS OR PACKING OFF. CMT PUMP 20 BBLS WATER TEST LINERS TO 4500 PSI, FOLLOWED BY 70 BBL MC-4 SPACER AT 11 PPG OVER MUD WEIGHT, FOLLOWED BY 494 SX (578 CU/FT) 105 BBLS CLASS 'G' CEMENT AT 15.7 PPG KICKED DART OUT W/5 BBLS WATER AND DISPLACED W/233 BBLS MUD W/RIG PUMPS, BUMP PLUG W/3000 PSI SET HANGER. SET LT PACKER W/4500 PSI. CIP 1255 HRS 08/24/95. RELEASE F/LINER HANGER AND REVERSE OUT W/SEAWATER, RECOVERED 40 BBLS SPACER, NO CEMENT. L/D CMT HEAD, L/D 60 JTS 5" DP, POOH L/D TIW LINER RUNNING TOOL. P/U 6" BIT, BIT SUB, 12-4 3/4" DC'S, 35-3 1/2" HWDP, 46-3 1/2" DP AND X/O. RIH ON 5" DP (SLM) TAG PLUG CATCHER AT 10947' DP MEASUREMENT. REVERSE OUT 100 BBLS MUD F/7" LINER W/SEAWATER. TEST 9-5/8" AND 7" LINER TO 3500 PSI, 30 MIN., OK. DRILL ON WIPER PLUG AT 10947' AT 0600 HRS. RIH W/7" RETAINER ON DP MW: 0.0 VIS: 0 CONTINUE DRILL UP WIPER PLUG @ 11594' C/O FLOAT COLLAR AND CMT TO 11038'. REVERSE CIRC CLEAN SEAWATER THROUGH SYSTEM. POOH LD 35,3-1/2" HWDP & 4-3/4" DC'S. RU ATLAS RUN SBL,GR, CCL F/9950' T/8600'. LD TOOL. NO CMT. EVALUATE LOGS. RUN 3-3/8" X 2' PERF GUN, 4 HPF & SHOOT @ 9800'-9802'. POOH RD. PU HOWCO 7",29# RETAINER & RIH ON 3-1/2" & 5" DP. WELL : Y-05A OPERATION: RIG : DOYON 14 PAGE: 5 08/27/95 (28) TD:l1063' ( 0) 08/28/95 (29) TD: 11063' ( 0) 08/29/95 (30) TD: 0 PB: 0 POOH TO PERF MW: 0.0 VIS: 0 CONTINUE RIH W/HOMCO 7" EZ-DRILL RETAINER & SET @ 98550' BELOW PERFS @ 9800' TO 9802' PRESSURE T/3500 PSI WITH 8.5 PPG SEAWATER. BLEED T/2600 PSI AFTER 30 MIN. HOLE TOOK ABOUT 6 BBLS OVER 1-1/2 HRS. BATCH MIXED 85 SX,100 CU/FT TOTAL OF 15 BBLS. PUMP 15 BBLS CMT,DROPPED WIPER PLUG & KICKED WITH 5 BBLS WATER. DISPLACE W/ RIG & SPOTTED CMT F/9850'. PULLED 5 STDS. PRESSURED UP & DOWN SQUEEZED. TOOK 8 BBLS T/3500 PSI. SQUEEZE 10 BBLS AWAY @ 3500 PSI OVER 35 MIN. HOLD PRESSURE 2 HRS & FINIAL PRESSURE 3000 PSI, BLEED OFF W/ 6 BBLS. TOTAL SQUEEZED AWAY 12 BBLS BEHIND PIPE. EST TOP CMT @ 9750'. CIP @ 1230 HRS,8/26/95. POOH LD PLUG CATCHER & HOWCO RUNNING TOOL. PU 6" BIT, 7" CSG SCRAPER, DC'S & 3-1/2" HWDP. RIH T/9724'. PU KELLY C/O CMT F/9740' T/9850' AND C/O CMT RETAINER @ 9850'. RIH TO BTM @ 11033' REVERSE IN CLEAN SEAWATER @ 6 BPM W/ 1350 PSI TILL HOLE CLEAN. POOH TO RUN DP CONVEYED ATLAS PERF GUNS. RIH W/ 7" SCRAPER MW: 0.0 VIS: 0 POOH LD 35,3-1/2" HWDP; 12,4-3/4" DC'S; CSG SCRAPER & BIT.PU 830',39 3-3/8" PERF GUNS W/ 6 SPF. SPACED OUT W/ BLANKS TO INTERVALS PER PROGRAM. 2035' 3-1/2" DP (FILL EVERY STD), HES SAFETY JT, 9-5/8" CHAMP PKR W/ UNDER BALANCE VALVE, FAS-FIL VALVE AND JARS 5" DP TO SURFACE, (CLOSE FAS-FIL FOR 500 PSI UNDER BALANCE APPROX 1580'). RU FLOW LINES, SET 9-5/8" PKR, TEST LINES TO 3000 PSI, PRESSURE UP ON ANNULUS TO FIRE GUNS (FIRED @ 2000 PSI). CONTINUE PRESS TO 2400 PSI. BLEED TO 500 PSI. BUBBLES IN BUCKET IN 1 MIN. OPEN BYPASS VALVE & FILL ANNULUS. REVERSE CIRC AND UNSET PACKER, FREE PIPE MOVEMENT. RD LINES & MANIFOLD. POOH TO PERF GUNS. STAND PIPE IN DERRICK, LD PKR AND FAS-FIL VALVE. (HOLE TAKING 15 BPH FLUID). LD FIRED PERF GUNS (ALL GUNS FIRED). NU TREE MW: 0.0 RIH WITH 6" BIT. CSG SCRAPER WITH 2 JUNE BASKETS T/10200' SLIP & CUT DRILLING LINE 59.5'. WHILE CIRCULATING. POOH LD ALL DP. DUE TO SOFT LOCATION. PULL WB. RU TO RUN 4.5" COMPLETION STRING. RUN 234 JTS,4.5" 12.6# L-80 NSCT TBG NEW WITH JEWERLY 7" BAKER PKR & 9-5/8" TIW STRADDLE PKR AND LANDING NIPPLE. WLEG @ 9848', XN 9837', 'X' NIPPLES @ 9825', , , IT , 9797 & 2004 . 7 PKR @ 9808 , 9-5/8 @ 8007'. NO SSSV RUN DUE TO WATER INJECTOR. LAND TBG. INSTALL 2 WAY CHECK. ND BOP'S AND & NU TREE. FLUID LOSS TO WELL 12 BPH. TOTAL LOSS TO HOLE 386 BBLS. WELL : Y-05A OPERATION: RIG : DOYON 14 PAGE: 6 08/30/95 (31) TD:l1063 PB: 0 RELEASE RIG 8/29/95 @ 2100 HRS MW: 0.0 CONTINUE N/D BOP'S, N/U ADAPTER FLANGE AND TEST TO 5000 PSI, HOLD 30 MIN., N/U TREE AND TEST TO 5000 PSI, HOLD 30 MIN., OK. R/U FIELD SERVICE LUBRICATOR, PULL TWO WAY CHECK, R/D SAME. PUMP 365 BBLS INHIBITED SEA WATER AT 3 BPM DOWN ANNULUS. TAKE RETURNS F/TUBING. PUMP 128 BBLS DIESEL DOWN ANNULUS. CLOSE IN CHANGE OVER TO TUBING AND INJECT 32 BBLS DOWN TUBING 1950 PSI AT 2 BPM. DROP SET BALL. PRESSURE UP ON TBG TO 4000 PSI AND HOLD 30 MIN., OK. R/U AND TEST 9-5/8" X 4-1/2" ANNULUS TO 4000 PSI. HOLD 30 MIN, OK. SET BPV, CLEAN PITS AND CELLAR. RELEASE RIG FOR WELL-TO-WELL TURN KEY MOVE AT 2100 HOURS 08/29/95. SIGNATURE: (drilling superintendent) DATE: ERRY-SLTN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING DBU/Y-05A 500292043601 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/25/95 DATE OF SURVEY: 082295 MWD SURVEY JOB NUMBER: AK-MM-950838 KELLY BUSHING ELEV. = 88.22 OPERATOR: BP EXPLORZTION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8404 7636.67 7548.45 8415 7645.97 7557.75 8420 7650.36 7562.14 8553 7769.06 7680.84 8651 7857.12 7768.90 COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDI'NACES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST~, SECT. 28 28 S 28.10 E .00 2258.06S 1532.96E b .. 28 30 S 27.99 E .53 2262.51S 1535.33E 2518/.~29 28 30 S 27.94 E .40 2264.62S 1536.45E 2520.58 26 15 S 5.15 E 8.00 2322.26S 1554.06E 2580.54 25 52 S 8.75 W 6.24 2364.98S 1552.75E 2622.19 8744 7939.57 7851.35 8821 8007.23 7919.01 8916 8090.59 8002.37 8992 8157.21 8068.99 9118 8268.95 8180.73 28 52 S 16.77 W 5.11 2406.48S 1543.20E 2661.03 29 4 S 17.08 W .32 2442.31S 1532.29E 2694.05 28 25 S 17.25 W .69 2486.00S 1518.80E 2734.27 28 16 S 17.74 W .36 2520.28S 1507.99E 2765.79 26 57 S 20.26 W 1.40 2575.56S 1488.99E 2816.31 9211 8351.13 8262.91 9304 8432.51 8344.29 9396 8512.64 8424.42 9488 8592.89 8504.67 9528 8627.71 8539.50 28 11 S 23.12 W 1.95 2615.42S 1473.11E 2852.31 29 55 S 22.52 W 1.89 2657.10S 1455.58E 2889.78 29 41 S 23.65 W .66 2699.34S 1437.58E 2927.70 28 59 S 20.87 W 1.66 2741.06S 1420.49E 2965.29 28 36 S 20.47 W 1.07 2758.98S 1413.73E 2981.55 9559 8654.93 8566.71 9590 8681.45 8593.23 9622 8707.62 8619.40 9654 8732.54 8644.32 9685 8756.56 8668.34 30 4 S 21.11 W 4.78 2773.28S 1408.30E 2994.51 33 9 S 23.17 W 10.51 2788.39S 1402.13E 3008.14 36 49 S 26.03 W 12.55 2805.03S 1394.49E 3022.97 39 37 S 28.64 W 10.22 2822.45S 1385.47E 3038.30 40 32 S 29.74 W 3.67 2840.10S 1375.61E 3053.69 9717 8779.94 8691.72 9747 8801.66 8713.44 9777 8821.66 8733.44 9808 8840.94 8752.72 9839 8858.98 8770.76 43 12 S 30.53 W 8.64 2858.22S 1365.09E 3069.41 46 25 S 31.91 W 10.98 2876.67S 1353.90E 3085.33 49 53 S 32.31 W 11.62 2895.58S 1342.03E 3101.57 53 11 S 32.20 W 10.65 2916.11S 1329.07E 3119.18 56 18 S 32.19 W 9.98 2937.72S 1315.47E 3137.72 9871 8875.87 8787.65 9900 8889.35 8801.13 9931 8902.80 8814.58 9963 8913.75 8825.54 9994 8922.19 8833.97 59 54 S 30.56 W 12.04 2960.88S 1301.35E 3157.69 62 48 S 28.91 W 11.55 2982.33S 1289.11E 3176.34 67 7 S 26.45 W 15.29 3007.82S 1275.75E 3198.74 72 6 S 24.64 W 16.72 3034.43S 1263.04E 3222.36 76 8 S 23.19 W 13.83 3061.55S 1251.02E 3246.61 10025 8929.34 8841.12 10057 8936.21 8847.99 10088 8942.84 8854.62 10117 8949.08 8860.87 10149 8955.35 8867.13 77 20 S 24.18 W 4.93 3089.34S 1238.82E 3271.51 77 44 S 23.06 W 3.66 3117.81S 1226.37E 3297.00 77 36 S 21.25 W 5.70 3145.93S 1214.93E 3322.35 77 55 S 23.04 W 6.03 3172.59S 1204.07E 3346.39 78 58 S 22.75 W 3.51 3200.82S 1192.15E 3371.75 EkRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Y-05A 500292043601 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/25/95 DATE OF SURVEY: 082295 MWD SURVEY JOB NUMBER: AK-MM-950838 KELLY BUSHING ELEV. = 88.22 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10179 8960.58 8872.36 81 24 S 23.78 W 8.57 3228.65S 1180.19E 10212 8964.83 8876.61 83 26 S 24.10 W 6.37 3257.87S 1167.21E 10243 8968.22 8880.00 84 5 S 23.69 W 2.49 3286.22S 1154.65E 10275 8971.46 8883.24 84 17 S 24.03 W 1.21 3315.36S 1141.76E 10307 8974.34 8886.13 85 20 S 23.75 W 3.40 3344.44S 1128.88E 3396.72 3422.85 3448.21 3474.28 3500.30 10338 8976.80 8888.58 85 43 S 23.89 W 1.32 3373.16S 1116.20E 10369 8978.84 8890.62 86 41 S 24.02 W 3.16 3401.41S 1103.65E 10399 8980.47 8892.25 87 1 S 23.71 W 1.50 3428.59S 1091.63E 10430 8981.83 8893.61 87 55 S 23.89 W 3.02 3456.68S 1079.24E 10461 8982.92 8894.70 88 0 S 23.85 W .26 3484.95S 1066.73E 3526.00 3551.26 3575.57 3600.71 3626.00 10492 8983.87 8895.65 88 34 S 24.15 W 2.06 3513.82S 1053.88E 10523 8984.85 8896.63 87 48 S 23.00 W 4.44 3542.47S 1041.38E 10554 8986.06 8897.84 87 44 S 22.88 W .43 3571.01S 1029.29E 10586 8987.23 8899.01 87 55 S 22.75 W .74 3599.61S 1017.26E 10617 8988.34 8900.13 88 0 S 22.62 W .47 3628.45S 1005.21E 3651.82 3677.48 3703.12 3728.83 3754.77 10648 8989.60 8901.38 87 20 S 22.32 W 2.31 3657.01S 993.40E 10678 8991.18 8902.96 86 37 S 21.83 W 2.88 3684.94S 982.07E 10708 8992.98 8904.76 86 37 S 22.09 W .85 3713.25S 970.65E 10739 8994.75 8906.53 86 49 S 23.06 W 3.20 3741.76S 958.80E 10770 8996.30 8908.08 87 24 S 24.22 W 4.20 3769.97S 946.45E 3780.48 3805.66 3831.21 3856.86 3882.13 10801 8997.41 8909.19 88 26 S 24.96 W 4.13 3798.02S 933.62E 10832 8998.09 8909.87 89 1 S 26.52 W 5.37 3825.92S 920.17E 10862 8998.48 8910.26 89 29 S 28.26 W 5.99 · 3852.57S 906.36E 10893 8999.09 8910.87 88 15 S 29.78 W 6.32 3879.62S 891.35E 10925 9000.01 8911.79 88 23 S 31.25 W 4.67 3906.80S 875.33E 3907.14 3931.88 3955.33 3978.94 4002.47 10956 9000.91 8912.69 88 19 S 32.39 W 3.63 3933.53S 858.74E 10986 9002.01 8913.79 87 28 S 34.27 W 6.90 3958.43S 842.37E 11063 9005.37 8917.15 87 28 S 34.27 W .00 4021.64S 799.30E 4025.46 4046.69 4100.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4100.30 FEET AT SOUTH 11 DEG. 14 MIN. EAST AT MD = 11063 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 168.76 DEG. TIED INTO SSDS GYRO SURVEY AT 8404.42' TOP OF WINDOW 8415' WINDOW POINT 8420' INTERPOLATED DEPTH 11063' ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/Y-05A 500292043601 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/25/95 DATE OF SURVEY: 082295 JOB NUMBER: AK-MM-950838 KELLY BUSHING ELEV. = 88.22 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8404 7636.67 7548.45 2258.06 S 1532.96 E 767.75 9404 8519.54 8431.32 2702.94 S 1436.00 E 884.88 117.13 10404 8980.73 8892.51 3433.19 S 1089.61 E 1423.69 538.81 11063 9005.37 8917.15 4021.64 S 799.30 E 2057.63 633.94 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~_ ERRY-SUN DRILLING SERVICES ANCHOR3tGE ALASKA PAGE SHARED SERVICES DRILLING PBU/Y-05A 500292043601 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/25/95 DATE OF SURVEY: 082295 JOB NUMBER: AK-MM-950838 KELLY BUSHING ELEV. = 88.22 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 8404 7636.67 7548.45 2258.06 S 1532.96 E 767.75 8462 7688.22 7600.00 2282.86 S 1544.76 E 774.62 8574 7788.22 7700.00 2331.64 S 1554.60 E 786.43 8685 7888.22 7800.00 2380.17 S 1549.96 E 797.75 6.87 11.81 11.32 8799 7988.22 7900.00 2432.21 S 1535.39 E 811.44 8913 8088.22 8000.00 2484.78 S 1519.18 E 825.57 9027 8188.22 8100.00 2536.18 S 1502.91 E 839.18 9139 8288.22 8200.00 2584.76 S 1485.59 E 851.70 9253 8388.22 8300.00 2633.80 S 1465.28 E 864.93 13.69 14.13 13.61 12.53 13.23 9368 8488.22 8400.00 2686.58 S 1443.17 E 880.15 9483 8588.22 8500.00 2738.65 S 1421.41 E 894.98 9598 8688.22 8600.00 2792.59 S 1400.27 E 910.61 9728 8788.22 8700.00 2865.11 S 1360.96 E 940.42 9897 8888.22 8800.00 2980.59 S 1290.12 E 1009.55 15.22 14.83 15.63 29.81 69.13 10613 8988.22 8900.00 3625.14 S 1006.59 E 1625.49 11063 9005.37 8917.15 4021.64 S 799.30 E 2057.63 615.94 432.14 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION W-31 (31-17-11-12) 1 LDWG TAPE+LIS I LDWG TAPE+LIS ECC No. Run ~ [ 5659.04 Run # i 6475.00 _ Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ Or F~o (907) 563-7803 Received by ~~~../~~ Date: _ RECEIVED SEP 1 4 1995 '~""~'" O;,~r~s-~o~s. Commission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, _ Enclosed, please find the data as described below: WELL ~ DESCRIPTION 'n / 0~ C-04 F-21 (12-35-12-13) Y-05A 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF I PLS FINAL BL+RF 1 SBT/GR FINAL BL+RF 1 PFC/PERF FINAL BL+RF Date: 29 August 1995 RE: Transmittal of Data Sent by: HAND CARRY Run # 1 Run ~ 1 Run ~ 1 Run ~ .1 Run ~ 1 ECC NO. 522.09 5811.07 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services ' 5600 B Street Suite 201 Anchorage, AK 99518 FAX to (907) 563-7803 Received by: ~_~/ ~Date: ~? ~, ~ ,,- u ~ C.-. ........................................ Anchora~e~"7~'-"~-'bUht,~;8$[oo ...... MEMORANDUM TO: THRU' State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzell, ~~ P. I. Supervisor -8~'~,q{~c- FROM: Bobby Foster,~~ SUBJECT: Petroleum Inspector(/ DATE: August 10, 1995 FILE NO: AIGIHJCD:doc BOPE Test- Doyon 14 BPX- PBU - Y-05A PTD # 95-0065 Prudhoe Bay Field Thursdy, August 10, 1995: I traveled this date~,BPX's Y-05A being drilled by Doyon rig 14 and witnessed the initial BOPE test. ~ As the attached AOGCC BOPE Test Report shows, them were no failures. The lower pipe rams could not be tested due to the crossover from the tubing hanger and the test joint was to long and the rams could not be closed with out damageing the rams. They will be tested after the tubing is pulled out of hole. The upper and lower kelly valve will be tested at the same time. The kelly was laidcEdown when the rig made a pad to pad move and the connections could not be tightened until the tubing is pulled. The location was clean and there was good access to all areas of the rig. The rig was clean and all equipment seemed to be in good working order. _ Summary:. I witnessed the BOPE test on Doyon rig 14 drilling BPX's Y-05A - test time - 2 hours - 0 failures. Note: I was notified by Todd Driskill, Doyon toolpusher, on 8/11/95 at 7:45PM that all the valves had been tested after the tubing had been pulled out of the hole. All the valves tested OK. Attachment: AIGIHJCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: DOYON Rig No. 14 PTD # BPX Rep.: Y-O5A Rig Rep.: Set @ 9,400' PBD Location: Sec. Weekly Other 95-0065 DATE: 8/10/95 Rig Ph.# 659-4510/11 JOHN RICHARDSON TODD DRISKILL 34 T. 11N R. 13E Meridian Um. TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 300/3,000 P 1 500/5,000 P NOTE 500/5,000 1 500/5,000 P 1 50O/5,00O P 2 500/5,000 P 1 500/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK YES Pit Level Indicators OK YES Flow Indicator OK YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Ouan. Upper Kelly / IBOP NOT~ InsideL°WerBall TypeBOpKelly / IBOP NiT1 Test Pressure 500/5,000 P/F 500/5,000 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves 16 No. Flanges 42 Manual Chokes '/ Hydraulic Chokes 1 Test Pressure P/F 500/5, 000 P 500/5,000 P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2150 3,200 I P 1,750 P 9 minutes 30 sec. minutes 46 sec. YES Remote: YES Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: NOTE: The bottom pipe rams will be tested after the tubing is pulled out of the hole. The crossover from the tubing hanger and the test joint was too long and the bottom rams could not be closed. The upper and lower kelly valves will be tested when the kelly is picked up and connections are tightened up. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24- HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AIGIHJCD.XLS ! ! 011, / CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 18, 1995 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .- Prudhoe Bay Unit Y-05A BP Exploration (Alaska) Inc. Permit No. 95-65 Sur. Loc. 1295'SNL, 4947'WEL, Sec. 34, TllN, R13E, UM Btmnhole Loc. 58'SNL, 4216'WEL, Sec. 3, T10N, R13E, UM Dear Mr. Jordan: 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 by 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. dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 fla. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 86.26 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47471 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1295' SNL, 4947' WEL, SEC. 34, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4467' SNL, 3708' WEL, SEC. 34, T11N, R 13E Y-O5A (14-3-10-13) 2S 100302630-277 At total depth 9. Approximate spud date Amount 58' SNL, 4216' WEL, SEC. 3, TION, R13E 7/15/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28287-58' feet No close approach feet 2560 11140' MD/8885' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8400 feet Maximum hole angle 9o o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 2890' 8250' 7500' 11140' 8885' 454 sx Class "G" RECEiV u 19. To be completed for Redrill, Re-entry, and Deepen Operations. MAY -9 1995 Present well condition summary Total depth: measured 10675 feet Plugs (measured) Alaska 0il & 6as Cons, CommJ$$Joll true vertical 9636 feet Arlchor~,,,:: Effective depth: measured 10471 feet Junk (measured) Fill @ 10471'MD(6/88) true vertical 9450 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20" x 30" 12 cu yds AS 140' 140' Surface 2643' 13-3/8" 3929 cuff PF II 2673' 2673' I nte rm e d i at e 9596' 9-5/8" 1345 cu ft "G" & 9626' 8692' Production 130 cuft PF Liner 1561' 7" 423 cuft "G" 9109'- 10670' 8250'-9632' Perforation depth: measured 9799;9821' (Sag R.) 9908;9936', 9946'-9996', 10006'-10021' (Ivishak) true vertical Subsea 8764:8783' (Sag R.) 8861;8962' (three Ivishak intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] ,/~¢h,e fore 'ng is true and correct to the best of my knowledge 21' I hereby certify that ~144¢ Signed . Title Drilling Engineer Supervisor Date ¢'-¢--~'~' Commission Use Only Permit Number APl number Appro__~_val/date~~ See cover letter ~',5'-~' ~ 50,o~?- ..'z c~ 9¢.~o~.- ~,/ .~//~/'7%~ .Ifor other requirements Conditior~s of approval Samples required [] Yes ~No Mud Icg required []Yes J~ No Hydrogen sulfide measures ,,~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; CI3M; [~t'5M; []10M; []15M; Other: Original Signeci By by order of~/~ Approved by David W, Johnston Commissioner tne commission Date.5 Form 10-401 Rev. 12-1-85 Submit licate I Well Name: I Y-05iA Redrill Plan Summary IType of Redrill (producer or injector): Injector of produced water Surface 1295 FNL, 4947 FEL Sec. 34 T11N/R13E Location: Target Location: 4467 FNL, 3708 FEL Sec 34 T11N/R13E Bottom Hole 58 FNL, 4216 FEL Sec 3 T10N/R13E Location: AFE Number: 4P0817 Estimated Start 7/15/95 Date: IRig: I DOYON RIG #14 Operating days to complete: I 1 '4o I TVD: 1888S I 17 IKBE: 186.26 I Well Design (conventional, slimhole, etc.): HORIZONTAL SIDETRACK I Objective: I SADLEROCHIT ABNORMAL PRESSURE Special design considerations NONE. NO ABNORMAL PRESSURE ANTICIPATED. RESERVOIR PRESSURE HIGHLY CONSISTENT IN "Y" PAD AREA AT 3800 PSI R£CF..IV£D ~'f - 9 1995 Gas Cons, Commission Anchors,.r Y-05iA Redrill Plan Summary Page 1 Mud Program: An 9.6-10.0 ppg mud will be used for the 8 1/2" production interval. Special design considerations Depth Densi PV YP INT 10MIN FL OIL SOLID (TVD) ty (CP) (#/FT GEL GEL cc/30 (%) S (PPG) ) min (%) KOP' 9.6 10 15 5 10 5 0 5 to to to to to to to to to 11140 10.0 18 30 15 30 7 0 10 Directional: I KOP: 1 400 Maximum Hole An~lle: Close Approach Well: 90° The above listed wells will be secured during the close approach. RECEIVED MAY - 9 1995 0il & Gas Cons. Commission Anchorz:,,~ Casin [;I/Tubing Program: Hole Csg/ -Wt/Ft -Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29.0 L-80 nscc 2890 8250/7500 11140/8885 Y-05iA Redrill Plan Summary Page 2 Cement Calculations: Liner 7" 29#, L-80,NSCC Size: Basis: 50% open hole excess, 80' shoe joint, 150' liner lap (9 5/8"), and 200' excess above liner top. Total Cement 94.5 454sxs of Class G Blend @ 1.17 ft3/sx Volume: Bbls I I I Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards and Contingencies This well is to be drilled with an 8 1/2" hole from the window to TD. With the mud weight having a potential of being 10.0 ppg there is the possibility of differential sticking. A contingency exists where a 7" drilling liner may have to be run if progress cannot be made in the event differential sticking is a factor. ~AI' -9 1995 Gas Cons. Commission Anchor~,:," Y-05iA Redrill Plan Summary Page 3 SUMMARY PROCEDURE 1. RU CTU, RIH to PBTD at 10627' and lay a cement plug across the perforations back to 9400', POOH, RIH with wireline and jet cut 4 1/2" tubing at _+9000' 2. Move in drilling rig. 3. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. 4. Install tree test plug. Remove the production tree. 5. Install BOP's and test to 5000 psi. Remove the test plug. 6. Pull and lay down the 4 1/2", 12.6#, L-80, AB MOD BUTT tubing. 7. PU 9 5/8" section mill, RIH to 9000', spot heavy mud to 8450', pull section mill to +8400'. 8. Displace well to FLO-PRO/milling fluid. Cut a 50' section in the 9 5/8" casing starting from about_+8400'-8450'MD. POOH 9. RIH with open ended drill pipe to 8550' and lay a cement plug back to 8200', POOH. 10. Run in with a 6 3/4" steerable drilling assembly and a 8 1/2" bit with gamma ray/directional MWD. Contact AOGCC to witness tag of cement for abandonment purposes. Dress the cement to 5' below the section top. Kickoff and if necessary displace well to clean FLO-PRO system. Continue to directionally drill to the 7" casing point at _+11140' at 87.4° (see attached directional plan). 11. Make a conditioning trip with an 8 1/2" hole-opener for the open hole section 12. Install a 7", 29#, L-80, STL Solid liner with 7" X 9-5/8" packer/hanger. Packer / hanger to be set at _+8250' md. 13. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement plus the 80' shoe volume, 9-5/8 X 7" lap volume, and 150' excess on top of the liner with drillpipe in the hole. Re-test BOP's as needed. Clean out cement to landing collar. RIH with drillpipe conveyed perforating assembly and perforate the well. POOH LDDP. Run the 4-1/2" L-80 completion string assembly using as much 4-1/2" used tubing and jewelry as possible. Space out and circulate with corrosion inhibitor. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Set packer. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Ai~sk~ Oil & Gas Cons. Commission AnchorE.:,'; Y-05iA Redrill Plan Summary Page 4 .,ared Servi¢ '~ Drilli.r~ .~a State Plane: Zone4 ~U · WOA: Y-Pad - ~m pl~ is for f~ibihw p~ ~ly Y-05A Y-05A Wp~ Preliminary Wetlplan CU~V£ ~ I ST~T g~ 8924 ~8.00' 1~8.00' B:OB ~49~ S ~554 ~! CU2VE ~ ' END G= 2URVE895~29.56' 20] ~B' B:~' 2501 S!551 El START mr 9646 ~9.56' 20!.28' B72B 2820S i427 Ej END D~ ~URVE !0~32 ~7.4~' ~i0.16' ~57~ 3:7~ S !~46 ~] ems 11140 87.44' 21g.16' 9D17 4042 S 740 E J j~oly;on 8997 3660 S6~6 E G45843 J , B97~ 3~7~S 1246 646453 594;8~D J 90~7 4042 S740 ~ 645964 594~940i 1 PROPOSED BHL .'!~ 9016.51 MD 11139.87 VS 4!09.56 N/S 4042.37 S E/W 740.06 E H, .~iBURTDN 4/18/95 1:55 pm HORIZONTAL VIEW (TRUE NORTH) SCALE 500 ft. / DWIS10N SURVEY REF: WELLHEAD 7 ~ Z3. ~ '::39 .Y3, 9316 TVS 500 ~l SOO --:500 ---2_00O ~--~580 VERTICAL VIEW ~CALE ~00 fL / DIVISION TVD REF: WELLHEAD ~RTICAL SECTION REF: WELLHE~ 75J0 -- 29.05' ~ S300 ~3 __6.3C' ~ 8 OC BOSe-- ~ ~6.67'~ 8809 ~',S 8108-- -- 273! ~ ~S.~* ~ 8~3z ~ ~TART 5: UURVE ~ !2.23'/!30 8~64--~ -- -- --2939-- -- ~ Top oF 7' Liner ~ 9118' KD ~.~°ne~ ,: , 9 5/8' 2sg. S~:e ~ 9517' 3031 ~ ~ 89.56' ~ 9646 K~ START D: CURVE ~e~ X 41.41' ~ ~7~5 ~D ~ 53.3B' ~ ,846 MD Y-O5A W~i 7 ;n DZ, ~ 11139 MD, 9516 TVD 8690-- 8728-- -- -- '~RI'iCAL ~,i0% PLANE: 169.63 R £CEIVED MAY ~ 9 1995 ~.~: ,s~a Uil & ~a~ Cons. Commission Anchor,'. ': I ii TREE: 6" MCEVOY WELLHEAD: ACTUATOR:OTIS Y-05i KB. ELEV = 81.1' BF. ELEV = 48,8' 9-5/8 D.V. PACKE., 25741 -- · , 3-3,8....~2#,,-,. 12673[ -- L-80, BTRS IKOP:2800' MAX ANGLE: 34° ~, 5000' 4-1/2", 12.6#/ft, L-80, IPC AB MOD BUTT TUBING TUBING IE~'i 3.958' CAPACITY: 0.0152 BBL/FT TOP OF 8 ] 19! 9-5/8", 47#/,'l, L-80, BTRS PERFORATIOI~I SUMMARY REF: LOG: BHCS 5/26/80 3 3/8 4 9799-9821 112 718 I 4 I 9908-9924 !13 118 I 4 I 9924-9936 1/3118 / 4 I 9946-9996 113 118 / 6 I 10006-10-321 OPEN/SQZ'D 4/89 OPEN 6/85 OPEN 9/80 OPEN 8/85 OPEN 8/85 OPEN PBTD ~ LANDING NIPPLE (3.813" ID) GAS LIFT MANDRELS fOTIS RL W/RA LATCH) N~ MDfBKB/ TVDss 5 I 3005 2923 4 I 5266 4909 3 I 7649 6899 S.D,NG SLEEVE (' MIN. ID) [ 8977' s ^,^ssY. 19044' 9.$/8' PACKER /~ ( GUIBERSON)(3.833"IDI u067' 12.6 #/ft, L-80 TAILPIPE "X" NIPPLE I ' (OTIS) (3.813"ID) , 91 09 4-1/2' 'XN' NIPPLE 19140' (OTIS)(3.725" ID) SHEAROUTSUB 19171' GUIBERSON MARKER JOINT [ 9806' CONFLICTING #'s DATE REV. BY 6-3-80 2/9/90 MMM 8/27/94 MANESS 0668'1 ~ ...... COMMENTS COMPLETION ORIGINAL MAC DIAGRAM UPDATE DA~A PRUDHOE BAY UNIT WELL: Y-05(34-11-13) APl NO' 50-029-20436 SEC 34; TN11;RGE13 BP Exploration (Alaska) RE£EIV .D MAY ~9 1995 Oil & Gas Cons. Commission Anchors STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend __ Operation Shutdown__ Re-enter suspended well Alter casing __ Repair well ~ Plugging X Time extension __ Stimulate ~ Change approved program __ Pull tubing __ Variance__ Perforate __ Other X __ Plugback for redrill 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1295' SNL, 333' EWL, SEC. 34, T11N, R13E At top of productive interval N/A At effective depth 788' NSL, 2164' EWL, SEC. 34, T11N, R13E At total depth 707' NSL, 2181' EWL, SEC. 34, T11N, R13E 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 8. z~'~ 10. 11. 6. Datum elevation (DF or KB) KBE = 81.16 feet 7. Unit or Property name Prudhoe Bay Unit Well number Y-05 (24-34-11-13) Permit number 80-8 APl number 50- 029-20436 Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical 10675 feet Plugs (measured) 9636 feet Effective depth: measured 10471 feet Junk (measured) true vertical 9450 feet Fill @ 104 71' MD (6/88) Casing Length Size Cemented Measured depth Structural Conductor 110' 20" x 30" 12 cu yds Arcticset 140' Surface 2643' 13-3/8" 3929 cuft PF II 2673' Intermediate 9596' 9-5/8" 1345 cuft "G" & 9626' Production 130 cuft Permafrost Liner 1561! 7" 423 cuft Class "G" 9109;10670' Perforation depth: measured 9799'-9821' (Sag R.) 9908'-9936~ 9946'-9996~ 10006L10021'~visha~ true vertical Subsea 8764'-8783' (Sag R.) 8861'-8962' (three Ivishak intervals) Tubing (size, grade, and measured depth) 4-1/2", L-80 to 9067' MD w/4-1/2" tailpipe to 9172' MD True verticql~d~pth "- - 2673' 8692' 8250'-9632' RECEIVED MAY - 9 199,5 Alaska 0il & Gas Cons. Commissior Anchorage Packers and SSSV (type and measured depth) 9-5/8" Guiberson packer @ 9067' MD; 4-1/2" BVN @ 2060' MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 7/15/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~";-~;;~, Title Drilling Engineer Supervisor\~: Signed /;~lr' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test __ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commissionq~ ~,-,~ ~' Form 10-403 Rev 06/15/88 Date i Appr°yal N°' ~ &'-~/~,,. ',~ ,q '-.:'-'~ ' '.:'-GommiSsioner Date ~//~ SUBMIT IN TRIPLICATE ,v LL PERMIT CHECKLIST COMPANY .J~ Y~ z~ 1-o2' WELL NAME GEOL AREA Y- 0 UNIT# PROGRAM: exp [] dev [] redrll ~ serv [] ADMINISTRATION 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 drlg 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 N N N N N N N N N N N N N 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. ~26. · 27. 2~. Conductor string provided ................ Y N Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg.. Y N CMT vol adequate to tie-in long string to surf csg . . . Y N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved. ~ N Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... .~Y----~/~--. Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ............ ..___ ........ %~; N BOPE press rating adequate; test tor~~~ psig. Y~ N Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~>' 31. Data presented on potential overpressure zones ..... Y/N/ ~,/ /'~ ~ /,~ 32. Seismic analysis 9f shallow gas zones .......... / N . . 33. Seabed condition survey (if off-shore) ........ / Y N 34. Contact name/phone for weekly progress reports . . ./~ . Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ C~mments/Instructions: "'~F-ORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ~ape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NIIMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 6594.00 M. GABEL RICHARDSON Y-05A 500292043601 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 16-AUG-96 MWD RUN 2 P. ROBERTS RICHARDSON MWD RUN 3 P. ROBERTS RICHARDSON MWD RUN 4 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: P. ROBERTS RICHARDSON WELL CASING RECORD 34 Date lin 13E 1295 4947 83.22 81.37 34.07 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 13.375 2673.0 9.675 8415.0 11063.0 MWD - EWR4/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. RUN 1, WHICH DRILLED OUT OF THE TOP OF THE CASING WINDOW AT 8415', WAS DIRECTIONAL WITH GAMMA RAY (DGR/SGRC). AFTER DRILLING OUT OF THE CASING WINDOW, THE MUD SYSTEM WAS CHANGED TO FLO-PRO. A 5 AAPI INCREASE IN GAMMA RAY READINGS WAS NOTED DUE TO THE MI/D CHANGE. RUNS 2 - 4 WERE DIRECTIONAL WITH GAMMA RAY (DGR/SGRC), & ELECTROMAGNETIC 4-PHASE WAVE RESISTIVITY (EWR4). ALL GAMMA RAY DATA WAS AQUIRED WITH GEIGER MUELLER TUBE DETECTORS (DGR/SGRC). FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8400.0 RP 9466.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 8620.5 8620.5 8774.5 8781.0 8878.5 8885.5 8923.5 8931.5 9090.5 9094.5 9143.5 9145.5 9293.5 9300.0 9313.0 9320.0 9323.0 9330.0 9343.0 9349.5 9354.0 9361.0 9360.5 9367.5 9385.0 9391.5 9611.0 9618.5 9857.0 9865.0 9904.'0 9911.5 9913.0 9920.0 11055.5 11063.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 11007.0 11000.0 (WALS, 25-AUG-95) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 8420.0 9556.0 2 9556.0 10155.0 3 10155.0 10733.0 4 10733.0 11063.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. / ? ? SHIFT. OUT $ CN : BP EXPLORATION WN : Y-05A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) (ALASKA) DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 172 Tape File Start Depth = 11063.000000 Tape File End Depth = 8400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42617 datums Tape Subfile: 2 284 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8400.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9505.0 15-AUG-95 ISC 2.02 CIM 3.94 MEMORY 9556.0 8420.0 9556.0 0 25.9 29.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P0391CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 8415.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: POLYMER 9.70 74.0 10.0 24000 5.6 .240 .120 .150 .300 72.0 149.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT BP EXPLORATION (ALASKA) Y-05A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 - Tape File Start Depth = 9565.000000 Tape File End Depth = 8390.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7054 datums Tape Subfile: 3 91 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9481.0 EWR4 9473.0 $ 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 AlqGLE: MAXIMUM ANGLE: STOP DEPTH 10116.0 10108.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ 17-AUG-95 ISC 2.02 CIM 3.94 MEMORY 10155.0 9556.0 10155.0 0 67.1 77.6 TOOL NUMBER P0401CRG6 P0401CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8415.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: POLYMER 9.70 70.0 10.0 23000 5.4 .220 .100 .-140 .280 70.0 157.3 70.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2. $ BP EXPLORATION (ALASKA) Y-05A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 45 Tape File Start Depth = 10160.000000 Tape File End Depth = 9470.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 53666 datums Tape Subfile: 4 110 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit ~run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10108.0 EWR4 10100.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10689.0 10681.0 20-AUG-95 ISC 2.02 CIM 3.94 MEMORY 10733.0 10155.0 10733.0 0 78.9 88.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ TOOL NUMBER P0401CRG6 P0401CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8415.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 9.90 71.0 9.0 34500 5.6 .140 .060 .100 .380 68.0 172.0 72.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3.- $ : BP EXPLORATION (ALASKA) : Y-05A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 42 Tape File Start Depth = 10740.000000 Tape File~End Depth = 10095.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17383 datums Tape Subfile: 5 107 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10688.0 EWR4 10679.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11015.0 11007.0 22-AUG-95 ISC 2.02 CIM 3.94 MEMORY 11063.0 10733.0 11063.0 0 86.6 89.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ TOOL NUMBER P0401CRG6 P0401CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8415.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 10.00 75.0 9.5 37000 4.4 .120 .050 .100 .330 71.0 193.0 71.0 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REFULRKS: CN WN FN COUN STAT MWD RUN 4.. : BP EXPLORATION (ALASKA) : Y-05A : PRUDHOE BAY : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 ' 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 26 Tape File Start Depth = 11064.000000 Tape File End Depth = 10675.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59899 datums Tape Subfile: 6 91 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 7 is type: LIS 96/ 8/16 01 **** REEL TRAILER **** 96/ 8/ 6 O1 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 16 AUG 96 2:52p Elapsed execution time = 1.86 seconds. SYSTEM RETURN CODE = 0 Y- 05A PRUDHOE BAY ~~ ~- Alaska 0il & Gas Cons. Commission -- Anchorage Run 1' 25 - August - 1995 GR Marked Line 8600 9932 WESTERN ATLAS Logging Services Tape Subfile' 2 i~ tyP LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS -ELL NAME: ~PI N~BER: ~PERATOR: ~OGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Y - 05A 500292043601 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 06-SEP-95 6475.00 J. DAHL D. WESTER 34 llN 13E 1295 4947 83.22 81.37 34.07 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 8420.0 PRODUCTION STRING 7.000 11043.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS SBT GRCH 1 1 25-AUG-95 WESTERN ATLAS LOGGING SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ Marked Line GR/SBT. EQUIVALENT UNSHIFTED DEPTH REMARKS: 47.00 29.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL. TOOL PARTIALLY COLLAPSING WHEN COMING OFF OF BOTTOM, MULTIPLE ATTEMPTS AT KEEPING TOOL FULL OPEN WERE MADE IGH ANGLE). RUBBER DEBRIS LODGED IN TOOL WHEN Bi<OUGHT OUT OF HOLE. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FiLE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8600.0 9918.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH - PASS 1 (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : Y - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 310 01 1 4 4 30 635 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 33 1014 BYTES * Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 9967.000000 8598.000000 0.500000 Tape File Depth ~ts = Feet **** FILE TRAILER **** LIS representation code decoding summary: %ep Code: 68 8218 datums i~ape Subfile: 2 128 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9750.0 9932.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 9758.0 9757.5 9782.5 9782.0 9792.5 9792.0 9795.0 9795.0 9798.0 9797.5 9804.0 9803.5 9816.5 9816.0 9829.0 9829.0 9838.5 9838.0 9841.0 9840.5 9844.5 9844.5 9850.5 9850.5 9885.0 9885.0 9895.5 9895.0 9903.5 9902.5 9909.0 9908.0 9913.5 9912.0 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. CN WN FN COUN STAT / ??MATCH. OUT $ : BP EXPLORATION (ALASKA) : Y - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 CUrves~ Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 8 * DATA RECORD (TYPE~ 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 9991.000000 Tape File End Depth = 9734.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1546 datums Tape Subfile: 3 56 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 '~W CURVES Curves and log header data for each pass in separate files; raw background pass in last file. ~ASS NLTMBER: 1 .3EPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9928.0 25-AUG-95 FSYS J1V2.0 UPDATE1 1842 25-AUG-95 10953.0 9980.0 8600.0 9932.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 11043.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELTNE COUNT TE NORMALIZATION IN OIL Z ~ TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : Y - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 CUrves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 131 Tape File Start Depth = 9967.000000 Tape File End Depth = 8598.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 41081 datums Tape Subfile: 4 207 records... Minimum record length: 62 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9742.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9952.0 25-AUG-95 FSYS J1V2.0 UPDATE1 1744 25-AUG-95 10953.0 9980.0 8600.0 9932.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2330XA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .O00 11043.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELiNE COUNT TE NORMALIZATION IN OIL Z TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : Y - 05A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 5 TTEN GR 68 GAPI F/MN LB LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 25 Tape File Start Depth = 9991.000000 Tape File End Depth = 9734.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7721 datums Tape Subfile: 5 101 records... Minimum record length: 62 bytes Tape Subfile 6 is type: LIS 95/ 9/06 01 **** REEL TRAILER **** 95/ 9/ 7 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 7 SEP 95 8:26a Elapsed execution time = 1.43 seconds. SYSTEM RETURN CODE = 0