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Home My WebLink About202-22407/10/08 ~~. ,r d~r'Il~~~~~ih~~i~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh !k 1 nn rln M:n N0.4772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n~ae nl r..l... rn K-04C 12083398 MCNL - ..~(p~ 05/14/08 1 1 14-33 11982433 RST 05/28/08 1 K-20B 12021160 MCNL aU a ^ a ~ / °~ 05/24/08 1 1 15-25B 12005210 MCNL ~ L( 04/13/08 1 1 , ~~r~~ac env rv ~v ~~cc/vc nGV Gr l D ~ JIVI\II'IV NIYY nG l unrvllYl71 VIVC \.VI-T CX\.n I V: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 i ;~,`~ ATTN: Beth ~ i~ ~' I' Received by: r~'~'~~--.___ STATE OF ALASKA ~ ~-~~ ALASI~IL AND GAS CONSERVATION CO~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned' ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: '' ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 6/3/2008 12. Permit to Drill Number 202-224 - 308-106 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/04/2002 13. API Number 50-029-22555-02-00 4a. Location of Well (Governmental Section): Surface: 3251' FSL 4070' FEL SEC 04 7. Date T.D. Reached 12/07/2002 14. Well Name and Number: PBU K-20B - , , . , T11N, R14E, UM Top of Productive Horizon: 116' FNL, 4643' FEL, SEC. 09, T11 N, R14E, UM 8. KB (ft above MSL): 52.13' °. Ground (ft MSL): 24.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 901' FNL, 2904` FEL, SEC. 09, T11 N, R14E, UM 9. Plug Back Depth (MD+ND) 12971' , 8707'_ Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 671480 y- 5975192 Zone- ASP4 10. Total Depth (MD+TVD) 13004' ~ 870T - 16. Property Designation: ADL 028303' TPI: x- 670993 y- 5971813 Zone- ASP4 Total Depth: x- 672752 y- 5971069 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, ROP, 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 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set A rox. 10-3/4" 45.5# NT-80 35' 3716' 35' 3712' 13-1/2" 1045 sx PF 'E' 735 sx Class 'G' 7-518" 29.7# L-80 32' 9098' 32' 8259' 9-7/8" 264 sx Class 'G' 4-1/2" 12.6# L-80 8936' 11504' 813 ' 8789' 6" 460 sx Class 'G' 3-1/2" x 3-3/16" 8.81# / 6.2# I L-80 9910' 13004' 8668' 8707' 3-3/4" 135 sx Class 'G' x 2-7/8" 6.16# 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 4-1/2", 12.6#, L-80 8936' 8878' MD ND MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. n ~~~~~ JUL ~ ~ ~~"~ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11516' Set Cement Retainer 11516' P&A w/ 8.8 Bbls Cement 11475' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST 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 Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None a ) ~ ~T~~ Form 10-407 Revised 02/2007 /~ ~ ~ ~ ~ ~~ /GO~ITINUED ON REVERSE SIDE 6,8 6d~pr JUL ~ ~ ~Q08 ~~~G ~- 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ 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. Zone 1 10061' 8711' None (Kicked off in Zone 1, drilled entire sidetrack in same zone) 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 for~eg ing is true and correct to the best of my knowledge. ~ O ~ Signed Terrie Hubble f Title Drilling Technologist Date ~~ PBU K-20B 202-224 308-106 Prepared ByNameMumber.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: John McMullen, 564-4711 INSTRUCTIONS GeweRaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • K-20B -Well History Date Summary • 4/3/2008 T/I/0=2250/1360/40. Temp= SI. IA & OA FL (CTD prep). No A/L. IA FL C~ 5502' (above sta # 3, s/o) (145 bbls). 4/9/2008 WELL S/I ON ARRIVAL. SET 4 1/2" SS C-SUB @ 5840' SLM. PULLED BK-OGLV FROM STA #3 ~ 5725' SLM. PULLED BK-LGLV FROM STA #4 C~ 3250' SLM. SET BK-DMY GLV IN STA #4 @ 3250' SLM. SET BK-DMY GLb IN STA #3 @ 5725' SLM. PULLED 4 1/2" SS C-SUB FROM 5840' SLM. WELL LEFT S/I ON DEPARTURE. NOTE : IA PRESSURE @ 2200# ON DEPARTURE, DSO NOTIFIED. 4/15/2008 T/I/0=2180/2150/40. Temp=Sl. Bleed IAP & OAP < 500 psi (CTD screening). IA FL C~3 3745' (above sta # 3) (98 bbl). Bled IAP to production of K-317 from 2150 psi to 230 psi in 1 hr 45 min. 30 min monitor, IAP increased 10 psi Final WHPs=2180/240/40. 4/17/2008 T/I/0= 2180/220/40. WHP's post-bleed (CTD screening). Retaped needle valve on tree cap (leaking gas). In 2 days IAP decreased 20 psi & OAP remained unchanged. 4/17/2008 T/I/0=2220/220/100 Temp=S/I -MIT IA PASSED to 3500 psi, MIT OA PASSED to 2000 o~i.(CTD prep) Spear in to IA W/6 bbls of meth followed by 143 bbls of 110* crude to reach 3500 psi. IA lost 200 psi in 1st 15 min and 60 psi in 2nd 15 min for a total loss of 260 psi in 30 min test. Let IA stablize. (2nd test) Pressured up IA to 3500 psi w/5.7 bbls 110* crude. IA lost 100 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 140 psi in 30 min test Bled IAP to 500 psi, got back apex. 4 bbls fluid. MIT OA -Pressured up OA to 2000 psi w/2.5 bbls 110* crude. O~ lost 40 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 60 psi in 30 min test. Bled OA to starting pressure, bled back apex. 2 bbls fluid. FWP's = 2260/560/40. Casing valves open to gauges, tags hung, DSO notified of well status. 4/22/2008 T/I/0=2260/550/50, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre CTD. PPPOT-T: Stung into test port to check void pressure, bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS (ET style), all moved freely no problems. PPPOT-IC: Stung into test port to check void pressure, bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Functioned LDS {ET style), all moved freely no problems. 5/23/2008 Pull Liner packer, M/GR/CCUCNL, Set CMT Retainer, Squeeze CMT. Run Drift, MIRU CTU #9. Test BOP's. RIH w /baker 4" GS and jars. 5/24/2008 Pull Baker KB packer CNL GR CCL log. I ?t h oa ker and n III .d fP~o_jar #E;. Call Tool Service to come and check packer for NORM. NORM checks out OK. M/U logging tools. PJSM w / SLB loggers & crew. RIH w/ CCL GR CNL log 2 up passes from 11278 to 9100 @ 60fpm. Good Log. RIH w/CMT Retainer. Correct to flag and middle of element 11426.3, set retainer at 11516'. 5/25/2008 Set cement retainer & P&A. Sting into retainer pump 8.8 bbls of cement. Pressure up to 3000 psi ~ 1.5 bbls into perfs - lay in remaining cement 2.4 bbls worth. Contaminate cmt holding 500 well head pressure. RIH w/whipstock drift to 11538. UD BHA. MIT-T to 2000psi. Test Failed. RD CTU. 5/27/2008 T/I/O=SSV/0/100 temp=s/i MIT IA 2000 psi. **PASSED** (2nd Attempt) [Pre CTD] Pumped 2.5 bbls crude down IA to reach test pressure. First 15 min IA lost 60 psi, second 15 min IA lost 40 psi for a total loss of 100 psi in 30 min. Repressured IA with .1 bbls crude First 15 min IA lost 0 psi, second 15 min IA lost 0 psi for a total of 0 psi in 30 min. Bleed IA to 0 psi, bled back approx. 3 bbls. FWHP's 0/0/30 **Annulus valves open to gauges & tagged** 6/1/2008 T/I/0=0/0/0. Set 4" CIW H BPV. Nordic 1 to move on. 6/1/2008 T/I/O = 0/0/0 Pull 4 1/16" CIW H BPV post BOPE test. BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours ~ Task Code NPT Phase Description of Operations 6/1/2008 03:00 - 04:00 1.00 MOB P PRE Prep for rig move 04:00 - 07:00 3.00 MOB P PRE PJSM on rig move operations, Turnkey Rig move from G-15 to K-Pad 07:00 - 10:00 3.00 MOB P PRE Spot rig mats and layout herculite liner at well, PJSM on backing over well, move in and spot rig over well Accept rig at 10:OOHrs on 6/1/08 10:00 - 13:00 3.00 BOPSU P PRE NU BOP's, changing out gripper blocks in injector for 2" coil. 13:00 - 15:00 2.00 BOPSU P PRE Adjust accumulator pressure switch 15:00 - 22:30 7.50 BOPSU P PRE Perform accumulator draw down test Testin BOP's, Upper Combi failed, changed out upper 2" combi and 2 3/8" combi, continued with BOP test of all rams, valves and lines to 250 -3500 psi, annular to 250 - 2500psi, 5 minutes per test, as per AOGCC and BP regulations Jeff Jones with AOGCC waived witnessing BOP test. Send BOP Test report to AOGCC. 22:30 - 22:45 0.25 BOPSU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for R/U BPV lubricator and pulling BPV. 22:45 - 23:45 1.00 BOPSU P PRE Pull BPV. Well on slight vacuum. 23:45 - 00:00 0.25 RIGU P PRE Rig up injector head to pull coil stub from reel to injector. 6/2/2008 00:00 - 01:00 1.00 RIGU P PRE R/U internal grapple and tugger to pull coil across. 01:00 - 01:15 0.25 RIGU P PRE SAFETY MEETING discussing hazards, mitigations, and job assignments to pull CT to injector. 01:15 - 04:30 3.25 RIGU P PRE Pull test internal grapple. Remove crossbar on reel. Pull coil across to injector. Coil became stuck in injector, back out and pull through again. 04:30 - 05:00 0.50 RIGU P PRE Change out CT injector packoff to 2". 05:00 - 06:45 1.75 RIGU N SFAL PRE Replaced the hydraulic pump for the CT packoff in operations cab. 06:45 - 07:30 0.75 RIGU P PRE Stabbed through packoff and took out a chunk of the seal. Install new CT injector packoff and reboot a-line. 07:30 - 09:00 1.50 RIGU P PRE CT a-line slack management, boot a-line, reverse circ with 50 bbls of 2% double slick KCL, 25bbls of FW, cut 50' of CT and 5' of a-line cable, test cable, ok 09:00 - 11:30 2.50 EVAL P WEXIT MU Kindall CTC, Pull test to 35k. MU UOC. PT UOC to 4000psi, Test and chart inner reel valve 250-4000psi, 11:30 - 12:00 0.50 EVAL P WEXIT MU Baker Seal Assy BHA #1 with seal assy, locator, X-O's, 2 Jts of 2 3/8" PH6, X-O's, blind sub, DPS, EDC, powercomms, wear sub, LOC 12:00 - 14:25 2.42 EVAL P WEXIT , 1.43bpm, 1121 psi, Up wt 40.7k at 9800', Dn wt at 19.5k Ta ed and stun in de I m n v ,pump pressure started to increase when seals were engaged, shut down pump, open Baker choke, stacked 10k down 2 RA Tags installed in Whipstock 5.35' below TOWS 14:25 - 14:40 0.25 EVAL P WEXIT Pressure test cement retainer down CT to 2000 si, monitor for 10 mins, lost 50psi in 5 min, held tight next 5 mins, good test, bled pressure off to 0 psi 14:40 - 16:00 1.33 EVAL P WEXIT POH to BHA #1, std bk inj 16:00 - 16:35 0.58 EVAL P WEXIT POH with BHA #1, LD coil trak tools and Baker seal assy 16:35 - 17:35 1.00 EVAL P WEXIT Adjust and center Traveling Block over well while installing and Printed: 6/30/2008 9:31:49 AM ~~ BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 ~ Phase Description of Operations Date From - To Hours Task Code NPT 6/2/2008 16:35 - 17:35 1.00 EVAL P WEXIT surface test DGS and HOT tools 17:35 - 17:45 0.17 WHIP P WEXIT MU 3 3/16" monobore WS BHA #2 with coil trak tools, found two lines on DGS tool, questioned scribe line used 17:45 - 18:00 0.25 WHIP P WEXIT LD and confirmed correct scribe line used 18:00 - 18:15 0.25 WHIP P WEXIT MU 3 3/16" monobore WS BHA #2 with coil trak tools, CTC, stab Injector 18:15 - 21:10 2.92 WHIP P WEXIT RIH with BHA #2 with BTT 3-3/16" Gen II Whipstock on CoilTrak. BHA OAL = 66.68'. Circ at 0.25 bpm, 70 psi thru open EDC. 21:10 - 22:10 1.00 WHIP P WEXIT Log down with GR from 11,056' at 100 fph to tie-in with mother well bore. correct -16' CTD. 22:10 - 22:30 0.33 WHIP P WEXIT RIH and ositioned to of BTT 3-3/16" Gen II Monobore whi stock o t 11 Tray set at lowside tool face 180 de ROHS. ose ressure up an Setting tool sheared at 3600 psi. Stacked 2K down on whi stock. It is in lace. Pick up clean off top of whipstock. 22:30 - 23:00 0.50 WHIP P WEXIT Circ well to 2# Biozan / 2% KCL water. 2.0 bpm, 2400 psi. 23:00 - 00:00 1.00 WHIP P WEXIT POH with CoilTrak and BTT running tools while circ. 2.0 bpm, 2800 psi. 6/3/2008 00:00 - 01:30 1.50 WHIP P WEXIT POH to surface. 01:30 - 01:45 0.25 WHIP P WEXIT SAFETY MEETING discussing hazards, mitigations, and procedures to L/D whipstock BHA. 01:45 - 02:30 0.75 WHIP P WEXIT L/D Whipstock setting BHA#2. Found part of Whipstock deployment key was left in hole, metal 2" by 3/4" bar broke off while setting whipstock. It should wedge between the tray on the highside of the hole and the 3-3/16" liner. 02:30 - 03:40 1.17 STWHIP P WEXIT PU window millin BHA #3 with 2.74" HCC window and string mill, 2-1/8" BOT Xtreme motor, 2 jts 2-1/16" CSH and CoilTrak tools. BHA OAL = 99.81' 03:40 - 06:00 2.33 STWHIP P WEXIT RIH with BHA #3. Circ at 0.3 bpm, 1100 psi. RIH the last 500' with no pump to push key below whipstock to wedge it into place while milling. Stop pump and dry tag top of whipstock at 11,496', correct de th -21' CTD to 11475'. ~~ 06:00 - 08:00 2.00 STWHIP P WEXIT Mill 2.74" Lowside Dual exit window from 11475 to 11475.6 , K,~~~ 1.5 bpm, 2942psi, 2842psi free spin, 400# WOB 08:00 - 09:00 1.00 STWHIP P WEXIT Mill window from 11475.6 to 11476', 1.49/1.49 bpm, 2975psi, 1.Ok WOB 09:00 - 10:00 1.00 STWHIP P WEXIT Mill window from 11476 to 11476.3', 1.49/1.49 bpm, 3054psi, 1.28k W OB 10:00 - 11:00 1.00 STWHIP P WEXIT Mill window from 11476.3 to 11476.7', 1.49/1.49 bpm, 3000psi, 1.4 - 2k WOB 11:00 - 13:30 2.50 STWHIP P WEXIT Mill window from 11476.7 to 11478', 1.48/1.48 bpm, 2944psi, 2k WOB 13:30 - 15:30 2.00 STWHIP P WEXIT Mill window, 1.5 bpm, 2990 psi, 2.6 k WOB, 0.5 fph, Milled to 11479'. 15:30 - 21:00 5.50 STWHIP P WEXIT Mill window, 1.5 bpm, 3000 psi, 2.7 k WOB, 0.5 fph, Milled to Printed: 6/30/2008 9:31:49 AM TREE= 4-1/16" CM/ WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 52.13' BF. ELEV = 24.2' KOP = 4350' Max Angle = 98 @ 12033' Datum MD = NA Datum TV D = 8800' SS K-20C DRLG DRAFT 10-314" CSG, 45.5#, NT-80 BTC, ID = 9.950" Minimum ID =1.995" @ 11465' -r ~ : ,-~ a e r ~-+ 14-1 /2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 16 06!16/08 3 5739 5599 38 TMPDX SO BK 20 06/16/08 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 08/20/01 8868' i~4-1/2" HES X NIP, ID = 3.813" 8878' ~-~ 7-5/8" X 4-112" TM/ HBBP-T PKR, ID = 3.912" 8903' i~ 4-112" HES X NIP, ID = 3.813" I BKR TIEBACK SLEEV E. ID =? 4-1/2" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 9 7-5/8" CSG, 29.7#, NT-95HS NSCC, O = 6.875" ~O 8924' ~ 4-1/2" HES X NIP, MILLED ID = 3.8" 8936' 4-1/2" WLEG w /MULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-5/8" X 4-1 /2" BKR ZXP PKR, ID = 5.50" 8950' 7-5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" 9910' -j 4-112" KB LNR TOP PACKER. ID = 2.36" 9917' 3.7" BKR DEPLOY SLV, ID = 3.0" 9935' ~ 3-1/2" HOWCO XN NIP, ID = 2.750" 99~36~ 3-1/2" X 3-3/16" XO, ID = 2.786" TOC 3 3/16" LINER PER SCMT ~~ 10304' 11462' 2 318" TOP OF SOLID LINER (1jt lap) 11477' ~ TOP 3 3116" WHIPSTOCK RA Tag @ 11,482' 4-1/2" LNR. 12.6#. L-80 NSCT. 13108' .0152 bpf. ID = 3.958" ~ ~ 5Q`~ REF LOG: MWD ON 06/06:08 tJO ANGLE AT TOP PERF: 88" @ 11040' ~ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11080 - 11440 O 06110/08 PRE DRILLED LNR 1 1727 - 1269ti O 06I09i08 2-7/8" LNR, 6.16#, L-80 STL, I 13004' .0058 bpf, ID = 2.441" ( 1 11528' 2 3/8" TOP OF Pre-Drilled LINER 3-3/16" LNR 6.2#, L-80, 11568' ~ ' ~ , TCII..0076 bpf, ID = 2.80" 12662' PBrD ~ K-20C 2 3-8" Pre-Drilled LNR. 4.7#. L-80 STL. ID=1.995" 12696' K-20B DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03195 D-9 ORIGINAL COMPLETION 06/11/08 NORDICI CTD SIDETRACK (K•206) 08/28/98 D-16 SIDETRACK (K-20A) 06/12/08 /TLH CORRECTIONS 12/09/02 JLM/KK CTD SIDETRACK (K-206) 06/14/08 /TLH CORRECTIONS 08/17/07 JMG PJC SET KP PKR (07/27/07) 06/25/08 KDGSV GLV GO (06/16/08) 09/15/07 PJC WBS CORRECTIONS 09/15/07 JLJ/PJC GLV GO PRUDHOE BAY UNff WELL: K-206 PERMff No: 2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL 8~ 4070' WEL BP Exploration (Alaska) • • "t ~ i ~ SARAH PALIN, GOVERNOR a~irt~-7a~t~ OIIt ~ ~7 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOrT CObII~II5SIOIQ / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-7433 FAX (907) 276-7542 Abby Higbie CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~, a a,b Re: Prudhoe Bay, Frudhoe Bay Pool, K-20B ~~,~I~NE~ APR 0 3 2008 Sundry Number: 308-106 Dear Mr. Higbie: 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 2nd day of April, 2008 Encl. U ~ ,~~ STATE OF ALASKA ~ ~ "' ~~ ~ti ALASKA OIL AND GAS CONSERVATION COM~ION ~~ a ~,~~ ~~aa 2 0 ~ APPLICATION FOR SUNDRY APPROVAL ~ ' 20 AAC 25.280 ~1! Gas GCt15. CQmtl7ist 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extens'(olilC~i01.8~E ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-224 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22555-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A PBU K-20B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Poot(s): ADL 028303 - 52.13 ~ Prudhoe Bay Field / Prudhoe Bay Pool t2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13004 8707 - 12971 - 8707 12260 & 12680 12740 Casin L n th Size MD TVD Burst Colla se Structural Conductor 110' 20" 110' 110' 14 0 470 Surface 3681' 10-3/4" 3716' 3712' 5210 2480 Intermediate Pr u tion 906 ' 7-5/8" 9 9' 8259' 8160 7 2 Liner 2568' 4-1/2" 8936' - 11504' 8133' - 8789' 8430 7500 Liner 3094' 3-1/2" x 3-3/16" x 2-7/8" 9910' - 13004' 8668' - 8707' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12015' - 12960' 8755' - 8707' 4-1/2", 12.6# L-80 8936' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW HBBP-T Packer, 7-5/8" x 4-1/2" BKR Packers and SSSV MD (ft): 8878', 8936' and 9900' ZXP Packer and a 45 HYD K8 Packer with 4" GS Profile 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 1, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Abby Higbie, 564-5480 Printed Name Abby Higbie Title CT Drilling Engineer Prepared By Name/Number: Signature `~ ~ ~ Phone 564-5480 Date Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ('~~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ' ~ `~ Other. Subsequent Form Required: ~~ APPROVED BY A roved B ~ COMMISSIONER THE COMMIS ON Date Form 10-403 Revi ed 06/2006 ~ ~ 0~~~/Jn ~ `~[ Zt mit In uplicate ORIGINAL `~ 91 ( ( '~, • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission ~.J From: Abby Higbie (564-5480) ICJ CTD Engineer Date: March 21, 2008 Re: K-20B Sundry request CC: Well File Sondra Stewman/Terrie Hubble Sundry approval is requested for Prudhoe well K-20B. K-20B is a CTD ST drilled 12-2002 that was completed with 605' of Z1A. After pumping the CTD liner cmt job it failed the LNR lap pressure test. A LTP was then run to isolate the well from 4 sets of parent well perfs behind pipe. Once on production the well went to gas quickly reaching MGOR within two months. APPROF was run in December of 03. The production profile indicated that the majority of production was coming from the top set of perfs. A slight temp drop was observed in the toe of the well but according to the spinner data very little was entering the wellbore in this toe section. On 3/28/04 coil made an attempt to go in and set a CIBP for gas shut off in the toe but was unable to get into the liner top. The decision was made to pull the LTP and live with any gas produced behind pipe. After initial problems pulling the LTP (stuck and cut coil) it was successfully removed in December of 2004. In 2005 two CIBP were set in the well. The first plug was set at 12,680' and the subsequently plug was set at 12,260'. Both plugs did little to shut off gas production. In a last attempt to cut gas production a new LTP was set in July 2007. After setting the new LTP little to no cut in gas rate was seen. Currently the well is SI for high GOR. REASON FOR SIDETRACK: K-20B is currently SI for high GOR. Since initial production in 2002, K-20B has had high gas rates at uncompetitive GORs. Several attempts have been made with CIBPs and LTPs to shut off gas without success. The previous K-20A parent perforations that remain un-perfed will be able to be accessed from the new K-20C wellbore. The well currently has low remaining value Pre-Rig Work: The pre CTD work is slated to begin on April 1, 2008. 1. F MIT-IA, -OA 2. S Dummy GLV's #3 and #4 3. C Pull 4.5" HYD KB packer w/ 4" GS Profile (ID = 2.56") 4. C Set Cement Retainer at 11,500' 5. C Pump cement job, 3.5 bbl ~--••~ ~`~t ~.,~~ ~,,..~ ~ '~ ~'~ 6. C Whipstock Drift down to 11,500' `~ ~ ( 0.~ w ~\ 7. W PPPOT-IC, -T; LDS P 8. W PT MV, SV, WV 9. O Blind and bleed lines, remove well house, level pad Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high 2. Set Baker 3-3/16"x 4-1/2" TT whipstock lowside at 11,472' 3. Mi112.74" window at 11,472 and 10' of openhole. Swap the well to Flo-Pro. 4. Drill Build: 3" OH, 710' (15 deg/100 planned) 5. Drill Lateral: 3" OH, 858' horizontal (12 deg/100 planned) 6. Run 2 3/8" slotted liner leaving TOL 1 joint inside the window at 11,442' 7. Perforate the old 3-3/16" liner above the new slotted liner at 11,080-11,370' 8. Freeze protect well, Set BPV, RDMO Post-Rig Work 1. Install GLV, Set Baker patch 2. Install well house. Hook up flow line. Ktt 4- , ti LIW WELLHEAD = _ FMC ACTUATOR = BAKER KB. ELEV = 52.13' BF. ELEV = 24.2' KOP = 4350' Max Angle = 97 @ 11965' Datum MD = NA ', Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80 BTC, ID = 9.950" • K-zoe 2222' -14-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS Minimum ID = 2.440" @ 11568' 3-3/16" X 2-7/8" XO ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 1/4" 09/15/07 3 5739 5599 38 TMPDX SO BK 5/16" 09/15/07 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 08/20/01 8868' H 4-1 /2" HES X NIP, ID = 3.813" 8878' -17-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.912" 8903' 4-1 /2" HES X NIP, ID = 3.813" 8924' ~~4-1/2" HES X NIP, MILLED ID = 3.8" BKR TIEBACK SLEEVE, ID =? 4-1/2" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, NT-95HS I NSCC, ID = 6.875" TOP OF WHIPSTOCK ~ 11500' BKR TORQUE MASTER PKR 11514' 4-1/2" BKR CIBP (08/19/00) 12030' PERFORATION SUMMARY REF LOG: MWD ON 12/07/02 ANGLE AT TOP PERF: 97° @ 12015' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12015 - 12175 O 12/08/02 2" 4 12330 - 12365 C 12/08/02 2" 4 12390 - 12410 C 12/08/02 2" 4 12440 - 12490 C 12/08/02 2" 4 12530 - 12550 C 12/08/02 2" 4 12590 - 12660 C 12/08/02 2" 4 12695 - 12715 C 12/08/02 2" 4 12730 - 12960 C 12/08/02 4-1/2" LNR 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" 8936' 4-1/2" WLEG w/MULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" $950' 7-5/8" X 4-1/2" BKR HMC HGR ID = 4.875" 9900' 45 HYD KB PKR w / 4" GS PROFILE (07/27/07) 9917' 3.7" BKR DEPLOY SLV, ID = 3.0" 9935' 3-1/2" HOWCO XN NIP, ID = 2.750" 9936' 3-1/2" X 3-3/16" XO, ID = 2.786" 11504' 11510' DO - MILLOUT WIN W (K-20B) 11568' H 3-3/16" X 2-7/8" XO, ID = 2.440" 2-7/8" CIBP (8/7/05) 26$0' 2-7/8" CIBP (3/18/05) 1r27~ FISH -CIBP 3-3/16" LNR, 6.2#, L-80, TCII, .0076 bpf, ID = 2.80" ~ PBTD ~--i 12971' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, tD = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/OS/95 D-9 ORIGINAL COMPLETION 09/08/07 JPK/PJC GLV TVD CORRECTIONS 08/28/98 D-16 SIDETRACK (K-20A) 09/15/07 PJC WBS CORRECTIONS 12/09/02 JLM/KK CTD SIDETRACK (K-20B) 09/15/07 JLJ/PJC GLV GO 05/31/06 CO/DTM TREE CORRECTION (6/13/04) 03!29/07 SPF/PJC GLV GO 08/17/07 JMG PJC SET KP PKR (07/27!07) PRUDHOE BAY UNIT WELL: K-206 PERMff No: F2022240 API Nb: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL 8~ 4070' WEL BP Exploration (Alaska) TREE= 4-1/16" CNV WE~" ''.HEAD = dC"BATOR= FMC BAKER KB. ELEV = 52.13' BF. ELEV = 24.2' KOP = 4350' Max Angle = 97 @ 11965' Datum MD = NA Datum TV D = 8800' SS 110-3/4" CSG, 45.5#, NT-80 BTC, ID = 9.950" ) Minimum ID =XXX" @XXX' XXX 14-1 /2" HES X NIP, ID = 3.813" I BKR TIEBACK SLEEVE, ID =? 4-1/2" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 6950' I~ 7-5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" 7-5/8" CSG, 29.7#, NT-95HS I NSCC, ID = 6.875" ~` ~O 45 HYD KB PKR w / 4" GS PROFILE (07/27/07) ID=2.56" TO BE PULLED 9917' 3.7" BKR DEPLOY SLV, ID = 3.0" 9935' 3-1/2" HOWCO XN NIP, ID = 2.750" 9936' 3-1/2" X 3-3/16" XO, ID = 2.786" • K-20C Proposed CTD Sidetrack GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 1/4" 09/15/07 3 5739 5599 38 TMPDX SO BK 5/16" 09/15/07 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 08/20/01 $$s$' 4-1/2" HES X NIP, ID = 3.813" 8878' 7-518" X 4-1/2" TNV HBBP-T PKR, ID = 3.912" 6924' I--14-1/2" HES X NIP, MILLED ID = 3.8" 6936' 4-1/2" WLEG w /MULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" 14-1/2" HES X NIP, ID = 3.813" I ~TOC 3 3/16" LINER PER SCMT I Cement Retainer I 11500' 1 PERFS 4-1/2" LNR, 12.6#, L-80 NSCT, ~ .0152 bpf, ID = 3.958" 13108' 11504 abbv PERFORATION SUMMARY REF LOG: MWD ON 12/07/02 ANGLE AT TOP PERF: 97° @ 12015' Note: Refer to Production DB for historical p~ IIZE SPF INTERVAL Opn/Sqz 2" 4 12015 - 12175 O 2" 4 12330 - 12960 C 10290-11430 S? 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" U 11442' -L3/8" TOP OF LINER (1jt lap) 1 11472' TOP 3 3/16" WHIPSTOCK 3-3/16" LNR, 6.2#, L-80, 11568' ~'w TCII, .0076 bpf, ID = 2.80" K-20C 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 13040' K-20B ~~ ~O f data DATE 12/08/02 I K-20A 13004' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/95 D-9 ORIGINAL COMPLETION 09/08/07 JPK/PJC GLV TVD CORRECTIONS 08/28/98 D-16 SIDETRACK (K-20A) 09/15/07 PJC WBS CORRECTIONS 12/09/02 JLM/KK CTD SIDETRACK (K-206) 09/15/07 JLJ/PJC GLV GO 05/31/06 CO/DTM TREE CORRECTION (6/13/04) 03/29/07 SPF/PJC GLV GO 08/17/07 JMG PJC SET KP PKR (07/27/07) PRUDHOE BAY UNfr WELL: K-20B PERMfT No: 82022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL 8 4070' WEL BP Exploration (Alaska) . . Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 28, 2007 3:41 PM To: 'Preble, Gary B (SAIC)' Subject: RE: PBU K-20B (202-224) Thanks Gary. No need to redo the 404. Remember to make the correction on your copy. Tom Maunder, PE AOGCC From: Preble, Gary B (SAle) [mailto:Gary.Preble@bp.com] Sent: Tuesday, August 28,20071:40 PM To: Maunder, Thomas E (DOA) SUbject: RE: PBU K-20B (202-224) Tom, After talking with the drilling department the Job Scope (operations) Block 1 should be "Liner top packer". If that is the case is a 10-404 still required? Gary Preble Petroleum Data Management Engineer SAIC 907-564-4944 preblegb@bp. com sCANNED AU G 2 9 2007 -~-------- ~------_._--------- From: Maunder, Thomas E (DCA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 15, 2007 11:59 AM To: Preble, Gary B (SAle) Cc: Arthur C Saltmarsh; Stephen F Davies Subject: PBU K-20B (202-224) Gary, As you can see, I am reviewing several 404s that you recently submitted. I have a couple of questions on this well. On this 404 you have "Bridge Plug" listed in block 1 and have checked "Repair Well". Reading the operations report it appears that a liner top packer is what was run. It does have a profile for a plug, but the statement "Notify PO/PCC well ready to POP" [put on production] would indicated to me that no plug was set in the hole. Also, the listing of the perforations in the well is confusing. It appears that the depths (md and tvd) are mixed. Without researching the file in detail, I would guess that the gross measured perforated interval is 12015- 12960'. Associating what I would interpret to be the tvds leads me to believe that those numbers might be out of order unless that portion of the well bore is inverted. Please have a look at these observations and respond. It may be necessary to resubmit the 404. Call or message with any questions. Tom Maunder, PE AOGCC 8/28/2007 I: ~ . STATE OF ALASKA . ~ß~¡J AUG 0 3 ALASKA OIL AND GAS CONSERVATION COM ION Alaska [)iI p REPORT OF SUNDRY WELL OPERATIONS . to (ti o D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 202-2240 - 1. Operations Abandon D Repair Well 12] Performed: Alter Casing D Pull TubingD Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Exploratory Service 6. API Number: 50-029-22555-02-00 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 9. Well Name and Number: 52.13 KB- PBU K-20B - 8. Property Designation: ADLO-028303 ~ 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth measured true vertical 13004 / feet 8707.47 ~ feet Plugs (measured) Junk (measured) 12680,12260 12740 Effective Depth measured 12971 / feet true vertical 8707.24 - feet 5CANNED AUG 2 9 Z007 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28 - 1 08 1490 470 Surface 3679 10-3/4" 45.5# NT-80 28 - 3707 28 - 3703 5210 2480 Production 9071 7-5/8" 29.7# L-80 27 - 9098 27 - 8259.1 6890 4790 Liner 19 3-1/2" 9.3# L-80 9917 9936 8669.76 - 8675.59 10160 10530 Liner 2570 4-1/2" 12.6# L-80 8934 - 11504 8131.78 - 8788.99 8430 7500 Liner 1632 3-3/16" 6.2# L-80 9936 11568 8675.59 - 8783.35 Perforation depth: Measured depth: 12015 - 8755 - - - - True Vertical depth: 12960 - 8707 - - - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 25 - 8940 Packers and SSSV (type and measured depth) 4-1/2" TIW HBBP-T Packer 4-1/2" Baker ZXP Packer o o 8882 8941 o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 23903 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 394 SHUT-IN Tubing pressure 1732 o 13. Service x Contact Gary Preble WINJ WDSPL Sundry Number or N/A if C.O. Exempt: N/A Title Data Management Engineer Signature Phone 564-4944 Date 7/31/2007 Form 10-404 Revised 04/2006 ORIGII~AL BFL AUG 2 9 2007 Submit Original Only . . , K-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/22/2007 ***WELL SII ON ARRIVAL *** BRUSHED POLISH BORE OF BKR DEPLOYMENT SLV. @ 9887' SLM 19917' MD. ( RING ON 3.80 SWEDGE) ***LEFT WELL S/I*** "w '~.... ~~,..,_.. 7/ st Place Holder - Liner Top Packer - machining to cut threads on spaceout pup. ,,_. __ "w~nw~.·..._______W~'~" ___, 7/26/2007 Set L TP. CTU #9. MIRU. Start well kill with 1 % KCL. ***Continued on 7/27/07 i WSR*** ¡ iT¿71¿ÒÒiiSetLTP: CTÜ #9: ***(5ontin uedfromil¿6TÕ7WSR***~Completewell"killandRIH 'with 2.5" 00 JSN. Jet polished bore in deployment sleeve and 4-1/2" liner above Ithe deployment sleeve. POOH. MU and RIH and set BOT 45 hyd "KB" liner too i packer with 4" GS Profile at 9917' ctm with top of pkr at 9900.57' ctm. PT pkr 1950 I psi 120 min. POH - RDMO **** Notify POIPCC well ready to POP **** Job I I Complete **** f rm_____m~ ~m c"cm~~__·A·_·_____.·,._C.~^ FLUIDS PUMPED BBLS 259 1 % KCL 76 50/50 METH 335 TOTAL . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Malker.doc Schlumbergep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth RECEIVED DEC 2 1 Z005 ~ Oil & Gas ConS. Ccfì1rdsÚ::n .Anchorag-e Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE WIDEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE W/DEFT 07/16/05 1 D.S 18-038 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 10/25105 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B ~Oa -;/24--' 11057076 S8HP SURVEY 12/06/05 1 M-188 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/Q-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 5CAj~NEC jAN 2 5 2006 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Received bY~n 11/28/05 Schlumberger ,..... r f~.~ ~ $'-'<,~ ~.~ rõ'1.!f~~ '''"'' :,,,,,,,,,'" NO. 3613 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '2 (; 20f] 5 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ,,,. C0mm\~~1¡1 µJ1f,;;'10íage Field: Prudhoe Bay, Milne PI. WI! J b # L D Of D t BL CI CD , e 0 og escnpllon ae o or PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009685 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 USIT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 10928633 SCMT 05/15/05 1 09-20 10889215 SCMT 02/18/05 1 D.S.09-31C N/A SCMT 11/05/05 1 P·06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT éJ.C 07/04/05 1 D.S. 06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 ~."............_w_·"'- ..,-,-,...-..,.. I BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 5(;f\NNED DEC 1 92.005 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received b~E' Q ~)~ - ~ '-- Date Delivered: \\1.0::' \05 ) ~ECEIVED OCT 2 6 Z005 ,8¡ G,~s Cons. Commission ~~l1Jct,mn~ge WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: K-20B, AK.-MW-22192 K-20B: #- /333 7 Digital Log Images 50-029-22555-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~ ~ ~~~, LO/~ Signed: 0~ -Rù {J ~~ED OC1 3 1 21\1.\5 --.- .____~... ì.......--- í\,~,}."!~ ~~~;,~ r:-;lc '\ STATE OF ALASKA '\ AlA~. u.{ Oil AND GAS CONSERVATION COMM,...,ŠION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 52.13 KB 8. Property Designation: ADL-028303 11. Present Well Condition Summary: Total Depth measured 13004 true vertical 8707.47 Effective Depth measured 12971 true vertical 8707.24 Casing Conductor Surface Production Liner Liner Liner Length 80 3679 9071 19 2570 1632 Size 20" 91.5# H-40 10-3/4" 45.5# NT-80 7-5/8" 29.7# L-80 3-1/2" 9.3# L-80 4-1/2" 12.6# L-80 3-3/16" 6.2# L-80 Perforation depth: Measured depth: 12015 - 12175 12590 - 12660 True Vertical depth: 8755.06 - 8743.31 8709.09 - 8706.64 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 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 Oil-Bbl o 901 x Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development P Stratigraphic L' feet feet feet feet MD 28 - 108 28 - 3707 27 - 9098 9917 - 9936 8934 - 11504 9936 - 11568 12330 - 12365 12695 - 12715 8733.58 - 8729.56 8706.06 - 8706.02 4-1/2" 12.6# 4-1/2" TIW HBBP-T Packer 4-1/2" Baker ZXP Packer SEP 1 t~ Z005 Stimulate D ~"'j:.¡¡)tI;¡Ar:;~II¡·'í'\I'II\'('C' .~. ¡Y,e:·l'1"I¡ 'li!.1.iJ ;;¡:"H ,.::,'), Waiver D Time Extension r;l I \lLlJ I j I II ',I Re-enter Suspended w'elu¡'D 5. Permit to Drill Number: Exploratory Lc 202-2240 Service 6. API Number: 50-029-22555-02-00 9. Well Name and Number: K-20B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) 12680, 12260 12740 TVD 28 - 1 08 28 - 3703 27 - 8259.1 8669.76 - 8675.59 8131.78 - 8788.99 8675.59 - 8783.35 12390 -12410 12730 - 12960 8726.6 - 8724.19 8706.12 - 8707.16 Burst 1490 5210 6890 10160 8430 12440 - 12490 8720.67 - 8715.49 L-80 25 - 8940 8882 8941 ,T~,)Çl~NNtJ\ ,SE;P ? ~~ {OC~"i Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 000 31881 9 200 15. Well Class after proposed work: Exploratory r Development;¡ 16. Well Status after proposed work: Oil '¡;¡ Gas r WAGL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal. / Signat~~-;?tfid Form 10-404 Revised 04/2004 GINJL WINJ L Collapse 470 2480 4790 10530 7500 12530 - 12550 8712.17 - 8710.89 Tubing pressure o 1126 Service r WDSPLr Sundry Number or N/A if C.O. Exempt: N/A RBDMS BFL SEP 162005 Title Data Mgmt Engr Phone 564-4424 r~O'G!NAL Date 9/14/2005 Submit Original Only ~:,. ) ) K-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE I SUMMARY 8/6/2005 MIRU CTU #5 - Set CIBP (GSO): T/l/O=010/200. WHP still zero from past pump jobs. RIH wI 2.25" JSN for drift run. Note: WHP builds while RIH (tight perfs 1 fluid packed well). Drift good to 12450' CTM. Job continued on 8/7/05 WSR. 8/7/2005 Continued from 8/6/05 WSR. RIH wI 2-7/8" Weatherford CIBP. Park at 12,260' CTM (target depth). Unable to see ball on seat. Set down on CIBP (will not move down). PU 3 klbs over wt to 12,205' CTM. Appears plug is partially set and dragging up hole. Park and order out Flo-Pro to assist ball seating. Pump steel ball wI flo-pro. No change, cannot RIH and pull 3Klbs heavy OOH. No plug on tools at surface and setting rod in correct position. Circ flo-pro out of CT to tanks. Run 2.25" JSN and find plug at original setting depth of 12,260' CTM. Stack weight on plug (holding good). Well will require PBGL to flow (Operator and WOE notified). ***** Job Complete***** FLUIDS PUMPED BBLS 84 Methanol 58 2% KCL 25 FloPro 167 TOTAL ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONSiAY 06 Z005 1. Operations Performed: Abandon D Alter CasingD Change Approved Program 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] Exploratory 0 Stimulate []Alaska Oil &. Gas lQ)n«[Cbmmission waiverD TimAlI6iÐrigøD Re-enter Suspended WellD 5. Permit to Drill Number: 202-2240 6. API Number 50-029-22555-02-00 Repair Well 0 PluQ Perforations[K] Pull Tubing D Perforate New PoolD Operation Shutdown D Perforate 0 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic 0 ServiceD 9. Well Name and Number: K-20B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 52.13 8. Property Designation: ADL-028303 11. Present Well Condition Summary: Total Depth measured 13004 feet true vertical 8707.5 feet Effective Depth measured 12680 feet true vertical 8706.2 feet Plugs (measured) Junk (measured) 12680 4337,12740 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 108 28.0 108.0 1490 470 Liner 2570 4-1/2" 12.6# L-80 8934 - 11504 8131.8 - 8789.0 8430 7500 Liner 19 3-1/2" 9.3# L-80 9917 - 9936 8669.8 - 8675.6 10160 10530 Liner 1632 3-3/16" 6.2# L-80 9936 - 11568 8675.6 - 8783.4 Liner 1436 2-7/8" 6.16# L-80 11568 - 13004 8783.4 - 8707.5 13450 13890 Production 9071 7-5/8" 29.7# L-80 27 - 9098 27.0 - 8259.1 6890 4790 Surface 3679 10-314" 45.5# NT-80 28 - 3707 28.0 - 3703.0 5210 2480 Perforation depth: Measured depth: 12015 -12175,12330 -12365,12390 -12410, 12440 -12490, 12530 -12550, 12590 - 12660 True vertical depth: 8755.06 - 8743.31, 8733.58 - 8729.56,8726.6 - 8724.19,8720.67 - 8715.49,8712.17 - 8710.89,8709.09 - 8706.64 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 64.9ANNED MAY 11 2005 Packers & SSSV (type & measured depth): 4-1/2" Baker ZXP Packer 4-1/2" TIW HBBP-T Packer @ 8941 @ 8882 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: kBOMS t:JFL NIA.Y ] 0 2005 13 Prior to well operation: Subsequent to operation: Oil-Bbl 805 784 Representative Dailv Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 31.7 20 700 31.1 24 700 Tubing Pressure 1675 1675 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil Œ] Gas D Development ŒJ ServiceD Signature Garry Catron Garry Catron i\~ r~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 5/5/05 Form 10-404 Revised 4/2004 OR¡C::; I f; L ~\ ( r ro,\ ) ) K-20B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/16/05 CTU #4 PUSH CIBP: MIRU. MU/RIH W/ MEM GR/CCL IN CARRIER, 2.25" JSN ON BTM. DRIFT/PUSH CIBP FISH TO 12740' W/O PROBLEMS. LOG FROM 127401 - 123001. PAINT FLAG @ 12600'. POOH. LOG SHOWS +61 CORRECTION. ***CONTINUED ON 3/17/05 WSR*** 03/18/05 SET CIBP @ 126801 FLUIDS PUMPED BBLS 115 60/40 Methonal/Water 115 TOTAL Page 1 ·.TREE = ,~ WELLHEAD = A CTUA TOR = KB. ELEV = ,,,,,,,. '"'''''''''' " '''''' ""'"'' BF. ELEV = KOP= Max .A~~I~~ Datum MD = Datum TVD = 4-1/16" CrN FMC BA KER 52.13' 24.2' 4350' ·.···97·T~~'1~65" ) 8800' SS 110-3/4" CSG, 45.5#, NT-80, ID = 9.950" l-i 3716' Min imum ID = 2.440" @ 11568' 3-3/16" X 2-7/8" XO I TOP OF BKR TIEBACK SLEEVE l-i 17-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" l-i 17-5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" l-i 8934' 8941' 8950' I 7-5/8" CSG, 29.7#, L-80, ID = 6.875" l-i 10212' 1 I BKR TORQUE MASTER PKR l-i 11514' 14-1/2" BKR CIBP (08/19/00) l-i 12030' PERFORA TION SUMMARY REF LOG: MWD ON 12/07/02 ANGLEATTOPPERF: 97 @ 12015' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DA TE 2" 4 12015 - 12175 0 12/08/02 2" 4 12330 - 12365 0 12/08/02 2" 4 12390 - 12410 0 12/08/02 2" 4 12440 - 12490 0 12/08/02 2" 4 12530 - 12550 0 12/08/02 2" 4 12590 - 12660 0 12/08/02 2" 4 12695 - 12715 C 12/08/02 2" 4 12730 - 12960 C 12/08/02 K-20B ~ ~ SAFr~OTES: 2222' 1-{4-1/2" HES X NIP, ID = 3.813" 1 ~ ~ ST MD TVD 4 3265 3200 3 5739 5539 2 7634 7039 1 8801 7967 GAS LIFT MANDRELS DEV TY PE V LV LATCH PORT 2 TMPDX DOME BK 16 38 TMPDX S/O BK 20 38 TMPDX DV BK 0 38 TMPDX DV BK 0 DATE 01/27/03 01/27/03 08/20/01 08/20/01 L I :8: 8868' 1-i4-1/2" HES X NIP, ID = 3.813" 8878' 1-i7-5/8" X 4-1/2" TrN HBBP-T PKR, ID = 3.912" 8903' 1-i4-1/2" HES X NIP, ID = 3.813" 1 8924' 1-i4-1/2" HES X NIP, MILLED ID = 3.8" . Z t ~ ~ ~h+ ',¡'.,:. ',,' ~ ;8:.'.".'.'.'. 1--- 8935' 8936' 1-14-1/2" TBG,12.6#, L-80,.0152 bpf, ID = 3.958" 1 1-i4-1/2" WLEG, ID = 3.958" 1 l-i ELMD TT NOT LOGGED 1 /' MILLOUTWINDOW 11504' - 11510' (TOP OF WHIPSTOCK @ 11500') 9917' 9935' 9936' l-i 3.7" BKR DEPLOYMENT SLY, ID = 3.0" 1 l-i 3-1/2" HES XN NIP, ID = 2.750" 1 l-i 3-1/2" X 3-3/16" XO, ID = 2.880" 1 11568' l-i 3-3/16" X 2-7/8" XO, ID = 2.440" 1 12680'1-i2-7/8" CIBP(3/18/05) 1 12740'1-i2-7/8" UNSETCIBPFISH (3/18/051 I 12971' 1-1 PBTD I 3-3/16" LNR, 6.2#, L-BO, -i 11568' 1 .0076 bpf, ID = 2.800" 2-7/8"LNR,6.16#,L-80,.0058bpf,ID=2.441" l-i 13004' I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 13108' ~ DATE 06/03/95 08/27/98 12/09/02 01/27/03 03/28/03 08/16/03 REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK (K-20A) JLM/KK CTD SIDETRACK (K-20B) ?ITP C/O GL VS DRSITLH MILLED WINDOW CORRECT CMO/TLP KB ELEVATION & MAX ANGLE DATE 02/04/04 04/06/04 03/04/05 03/18/05 REV BY COMMENTS CMO/TLP PERF CORRECTION SRB/KA K FISH; SA FETY NOTE RAClTLH FISH; SAFETY NOTE (2/6/05) MCnLlPJC SET CIBP / PUSH CIBP FISH PRUDHOE BA Y UNIT WELL: K-20B PERMIT No: 2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL & 4070' WEL BP Exploration (Alaska) q J~ ~ ~, DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022240 Well Name/No. PRUDHOE BAY UNIT K-20B Operator BP EXPLORATION (ALASKA) INC )' f1I1LL é.-I ~ 4~ :J- API No. 50-029-22555-02-00 MD 13004 ___" TVD 8707 /' Completion Date 12/9/2002 _/ Completion Status 1-01L Current Status 1-01L UIC N ~-~------_._---.--- --_.~----~--- -~---~------_._--------~_..~----.-._~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~_.' ----------~--- ----.------------._~~-----. DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, CCL (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr ~. Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ----------_._---_._~-------~- 1 11470 13004 Open 1/9/2003 Rpt Directional Survey Rpt LIS Verification 11 031 12977 Open 4/17/2003 ~ D vf1692 LIS Verification 11 031 12977 Open 4/17/2003 ~ ~ectional Survey 11470 13004 Open 1/9/2003 "1:D D Las f12354 Production 9600 12910 Case 1/20/2004 Production and Injection Profile ED D Las 12354 Spinner 9600 12910 Case 1/20/2004 Production and Injection Profile / Temperature 9600 12910 Case 1/20/2004 Production and Injection rI ED D Las 12354 Profile ED D Las 12354 Casing collar locator 9600 12910 Case 1/20/2004 Production and Injection Profile ~. ED D Las 12354 Pressure 9600 12910 Case 1/20/2004 Production and Injection Profile LED D Las '"'12354 I njection Profile 1 9600 12910 Case 1/20/2004 Production and Injection Profile Log Injection Profile 25 BM 9600 12910 Case 1/20/2004 Production and Injection Profile Log Production 25 BM 9600 12910 Case 1/20/2004 Production and Injection Profile Log Spinner 25 BM 9600 12910 Case 1/20/2004 Production and Injection Profile Log Temperature 25 8M 9600 12910 Case 1/20/2004 Production and Injection Profile DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022240 Well Name/No. PRUDHOE BAY UNIT K-20B MD 13004 TVD 8707 Completion Date 12/9/2002 -~---_.~-~._--_._------- Log Casing collar locator Log Pressure (D C Pdf ..12423 Rate of Penetration t/ ED C Lis --12423 Rate of Penetration -- - - -------~---_._--~.__._-_._- Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Y@ Well Cored? Chips Received? "'-Ÿ / N Analysis Received? ~-- ~-~-~._~----~------~--- _.._._._----_._----~_.- Comments: --~-----.------~~_._-- )~ .__._----~_._---~--~+~-~---- Compliance Reviewed By: Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22555-02-00 Completion Status 1-01L Current Status 1-01L UIC N 25 BM 9600 12910 Case 1/20/2004 Production and Injection Profile 25 BM 9600 12910 Case 1/20/2004 Production and Injection Profile 25 1-3 11501 13004 Open 2/26/2004 ROP, DGR - Horizontal Presentation - MWD 1-3 11501 13004 Open 2/26/2004 ROP, DGR - Horizontal Presentation - MWD ~ Sample Set Sent Received Number Comments Daily History Received? ~N dIN Formation Tops Date: ~- ¡;(~ J~_;uHö- ) ) ¿)ð(} -cYé) Lf WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIn. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: K-20B, AK-MW-22192 K-20B: Digital Log Images 50-029-22555-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed~~\~~~,G ~ RECEIVED r:~~r) ? 6 ?OO4 I -_.u '- ....;., \.I :~jaska Oil & Gas Cons, Commission Anchorage ~~~\\\~ ) aoa-~r9Ý / Ilpq~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 08, 2003 RE: MWD Formation Evaluation Logs K-20B, AK-MW-22192 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22555-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED APR 1 7 2003 A1æka Qrj & Gas Cons. CommlMion Anctlorage Sc~lull~epgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 04/02/03 NO. 2725 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott,Milne Pt. Color ............ Well Job# Log Description Date Blueline Prints CD ~911 ó1~da~ 23081 CH EDIT MGR 12/08/02 1 ~. 9-35A\ '- ~ \ 23050 RST 01/08/03 1 / ¿J.(') T ~ 05.S. 9-28A ,q ~ 'e') L\ -=s 22515 RST 11/10/02 1 I~ð~~ ~ 18-05 \~ .'o<¡.<;n 22411 MCNL 08/19/02 1 ) Of ~-14A ~ 'O?~ 23100 SCMT 03/05/03 2 ~-30f90~-~,-~l ç 23078 SCMT 02/13/03 2 .31 A) 23087 OH EDIT ARC & IMPULSE (PDC) 11/03/02 1 J f.)O 75 ¥31A t)O'd. '- \~~ 23087 MD VISION RESISTIVITY 11/03/02 1 ~-31A 23087 TVD VISION RESISTIVITY 11/03/02 1 vR-31 A 23087 MD VISION RESISTIVITY (BHP) 11/03/02 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED ~e~'-~f'tf\l~~\ ~~ Alaska Of~ & Gas Coos. Commis8ion Anchorage ~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth yJ '" 1\ ReœiveG~p-_- 23. CASING SIZE 20" 10-3/4" 7-5/8" 4-1/2" WT. PER FT. 91.5# 45.5# 29.7# 12.6# 8.81# / 6.2# / 6.16# ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BsL TEST PERIOD 2,045 OIL-BsL GRADE H-40 NT -80 L-80 L-80 L-80 K-20B 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2222' MO 1900' (Approx.) f~~ /(SD2. '",.2> ;/ Ao S789'~ CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 30" 35' 3716' 13-1/2" 32' 9098' 9-7/8" 8936' 11504' 6" 9910' 13004' 3-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 1045 sx PF 'E', 735 sx Class 'G' 264 sx Class 'G' 460 sx Class 'G' 135 sx Class 'G' AMOUNT PULLED 3-1/2" x 3-3/16" x 2-7/8' 1. Status of Well Classification of Service Well 2. :~; of o~e~;:r 0 Suspended 0 Abandonef.;:.~::.9.:~~rvice ~'. '}J~'i '~!\oj .. 7. Permit Number BP E I t' (AI k) I ," a 'f".' . . 202-224 xp ora Ion as a nc. 17 q(. n'2ii 'j!.~ ". ... WIt;"; , . 3. Address '~'''_~_~'<~''B 1 ~,~~-....;--~___~_M?:;~'.~,.:_,,-.._'.j 8. API Number , V:';~:'H~: Ž '- ~~.~.;:' ,~- P.O. Box 196612, Anchorage, Alaska 99519-6612~ ,,,'~" 50-029-22555-02 4. Location of well at surface . 9. Unit or Lease Name 3251' NSL, 4070' WEL, SEC. 04, T11 N, R14E, UM X = 671480, Y = 5975192 Prudhoe Bay Unit At top of productive interval " 116' SNL, 4643' WEL, SEC. 09, T11N, R14E, UM X = 670993, Y = 5971813 10. Well Number At total depth 901' SNL, 2904' WEL, SEC. 09, T11 N, R14E, UM X = 672752, Y = 5971069 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 52.13' ADL 028303 12. Date Spudded 13. Date_~. Reached 14. Date Comp., Susp., or Aband. 12/4/2002 I 12þ7/2002 j;Þ 12/9/2002 . 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 13004 8707 FT 12971 8707 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, CCL 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 12015' -12175' 8755' - 8743' 12330' - 12365' 8734' - 8730' 12390' -12410' 8727' - 8724' 12440' - 12491' 8721' - 8716' 12530' - 12550' 8712' - 8711' 12590' - 12660' 8709' - 8707' 12695' - 12715' 8706' - 8706' 12730' - 12960' 8706' - 8707' 27. Date First Production February 1, 2003 Date of Test Hours Tested 3/3/2003 8 Flow Tubing Casing Pressure CALCULATED Press. 735 24-HoUR RATE 25. TUSING RECORD DEPTH SET (MD) 8936' PACKER SET (MD) 8878' SIZE 4-1/2", 12.6#, L-80 MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH GAs-McF 29,198 GAs-McF WATER-BsL 51 WATER-BsL CHOKE SIZE 55.210 OIL GRAVITY-API (CORR) GAS-OIL RATIO 14,281 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. Form 10-407 Rev. 07-01-80 mRR oS 7Jjg l r... lil~' RBDMS SF t MAR I 2 Submit In Duplicate ) ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 10061' 8711' (Kicked off in Zone 1, drilled entire sidetrack in same zone.) 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby ceriify that the for,oing ,is true and correct to the best of my knowledge Signed Terrie Hubble /'(OAJ\J..Q - ~ Title Technical Assistant Date D3 'CJ./ .O.~ K-20B 202-224 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Mark Johnson, 564-5666 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ') ) Page 1 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date Fronr;.To HOUrs Task Code NPT Phašë 12/1/2002 05:00 - 06:00 1.00 MOB P PRE 06:00 - 10:00 4.00 MOB P PRE 10:00 - 11 :00 1.00 MOB P PRE 11 :00 - 11 :30 0.50 MOB N WAIT PRE 11 :30 - 13:30 2.00 MOB N PRE 13:30 - 14:00 0.50 MOB N PRE 14:00 - 18:00 4.00 MOB N WAIT PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 22:45 4.25 MOB P PRE 22:45 - 00:00 1.25 MOB P PRE 12/2/2002 00:00 - 01 :30 1.50 MOB P PRE 01 :30 - 14:30 13.00 MOB N WAIT PRE 14:30 - 14:45 0.25 MOB N PRE 14:45 - 17:45 3.00 MOB P PRE 17:45 - 18:00 0.25 MOB P PRE 18:00 - 19:45 1.75 MOB P PRE 19:45 - 20:30 0.75 BOPSUR P DECOMP 20:30 - 21 :30 1.00 MOB P PRE 21 :30 - 00:00 2.50 MOB P PRE 12/3/2002 00:00 - 00:30 0.50 MOB P PRE 00:30 - 06:00 5.50 BOPSUR P DECOMP 06:00 - 07:15 1.25 BOPSURN RREP DECOMP 07:15 - 08:00 0.75 BOPSUR P DECOMP 08:00 - 09:15 1.25 STWHIP P WEXIT 09:15 - 10:15 1.00 STWHIP P WEXIT 10:15 - 10:45 0.50 STWHIP P WEXIT 10:45 - 11 :30 0.75 STWHIP P WEXIT 11 :30 - 14:00 2.50 STWHIP P WEXIT 14:00 - 14:50 0.83 STWHIP P WEXIT 14:50 - 16:45 1.92 STWHIP P WEXIT Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N1 Spud Date: 4/22/1995 End: [)~sþriþ~iøh ofOþer~ti()r1s Rig Released from 14-08AL 1 @ 05:00 on 12/1/02. PJSM. Prep to move rig to K-20. Roll-up tarps. Load trailers. Warm moving system & tyres. P/U rig & move 3'. Hang BOPs. N/U & test 14-08AL 1 tree cap. PJSM. Move rig off well & R/U to LID windwalls. Standby. W.O. wind speed to fall below 20mph. PJSM. R/U & LID windwalls. Scope down derrick. Jack up rig and move down the pad. Standby. W.O. Nabors 4ES to move from J-pad to Oxbow enroute to DS#1. Safety mtg re: rig move on Spine/K-Pad access Move off DS 14 onto Spine Turn off Spine onto K-Pad access Fin move from 14-08. Move onto K-Pad and set down in position to RU Standby. WO wind to get below 20 mph Unload trailers and spot misc equipment. K-20 wellhead is approx 50' from edge of Pad on drillers side. Will have to load/unload vac trucks from off drillers side. Meanwhile monitor pressures on K-20A -lA, OA & WHP = Opsi. Winds down to 18mph. Held PJSM on P/U derrick & windwalls. Raise derrick & windwalls. PJSM on move over well. Move rig over tree. Remove tree cap. Install XO spool. Set down. There's even less room than we thought! NU BOPE Stow derrick jacks. Crew change (late flight), safety mtg Accept rig 2130 hrs 12/2/02 Pull injector out of box. Install gooseneck. Stab CT Fin stab CT, set inj off to side Test BOPE. Witness waived by AOGCC Blind/shears failed. Remove and replace inserts. Retest - OK. Fin BOPE test. Cut off 126' CTC. Install Baker CTC. Pull test to 35k - OK. Install dart catcher. Load wiper dart. Launch & chase with 2% KCL. Dart hit @ 56.3bbls. Press test inner reel valve & CTC to 3500psi - OK. Open up well & observe Opsi WHP. Held pre-spud safety meeting. Reviewed well plan & considerations for operating with unbermed cuttings tank. Reviewed procedure, hazards & mitigation for M/U window pilot mill BHA#1. M/U window pilot mill BHA#1 with BKR 3.81" starting mill, 2-7/8" extreme motor, MHA, 2 jts PH6, XO & CTC. BHA OAL = 84.94'. RIH with BHA#1 circulating 1/2# biozan KCL-water at min rate - observe frozen spot into hardline. Thaw out spot & continue RIH circ 0.3bpm/80psi taking wellbore returns to the tigger tank. Wt check @11400" - Up wt = 42k & Dwn wt = 21.5K. Tag whipstock @ 11529' CTD. Correct depth to 11500". Ease-into milling with 2.5bpm, 1300/1520psi. Mill from 11500' to 11500.8'. P/U clean & dress again. Stall 1 x @ 11500.6'. Ease back in & mill to 11501.5' POOH for Torquemaster mill Printed: 12/16/2002 10:38:45 AM ) ') BPEXPLORAl:"ION Qp~réltiØI'l$SLlmr11é1rýl~pø.-:t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N1 Spud Date: 4/22/1995 End: Elate From- To Houts Task Code NPT [)~sçriþtiQn"Þf()Þ$råti()ns 12/3/2002 16:45 -17:10 0.42 STWHIP P WEXIT 17:10 - 18:50 18:50 - 19:10 1.67 STWHIP P 0.33 STWHIP P WEXIT WEXIT 19:10 - 20:00 0.83 STWHIP P WEXIT 20:00 - 21 :00 1.00 STWHIP P WEXIT 21 :00 - 22:00 1.00 STWHIP P WEXIT 22:00 - 22:50 0.83 STWHIP P WEXIT 22:50 - 23:03 0.22 STWHIP P WEXIT 23:03 - 00:00 0.95 STWHIP P WEXIT 12/4/2002 00:00 - 00:10 0.17 STWHIP P WEXIT 00:10 - 00:17 0.12 STWHIP P WEXIT 00:17 - 01 :20 1.05 STWHIP P WEXIT 01 :20 - 02:40 1.33 STWHIP P WEXIT 02:40 - 03:10 0.50 STWHIP P WEXIT 03:10 - 05:10 2.00 STWHIP P WEXIT 05:10 - 06:00 0.83 STWHIP P WEXIT 06:00 - 06:20 0.33 DRILL P WEXIT 06:20 - 07: 15 0.92 DRILL P PROD1 07:15 - 09:10 1.92 DRILL P PROD1 09:10 - 09:30 0.33 DRILL P PROD1 09:30 - 10:15 0.75 DRILL P PROD1 10: 15 - 11: 1 0 0.92 DRILL P PROD1 11: 1 0 - 12:00 0.83 DRILL P PROD1 12:00 - 12:20 0.33 DRILL P PROD1 12:20 - 14:00 1.67 DRILL P PROD1 LD pilot mill (shows proper wear). MU 3.80" TM mill and 3.80" SR RIH w/ BHA #2 10250', Continue RIH. IAP=100 psi, OAP=45 psi. Returns are clean KCL and 1 for 1. Dry tag top of whipstock at 11527'. PU at 40klbs. Kick on pumps. Free spin 2.5 bpm, 1520 psi. Tag at 11526.6'. Make -25.1' correction to 11501.5'. Begin milling window. 2.5/2.5/1730 psi. 11502.0', Slow getting started. Having to establish a cutting pattern. 2.5/2.5/1630 psi. 11502.6', Milling ahead. 2.5/2.5/1845 11506.2', Milling ahead. 2.5/2.5/1714 psi. Good ROP. Pit vol=308 bbls. 11508.3', Pump 10 bbl sweep of 2# biozan. 11509.0', Stall, sticky pickup, stall again several times. Resume milling. Continue milling window from 11510.0'. 2.5/2.5/1560 psi. Free spin=1450 psi. Pit vol=306 bbls. OAP=60 psi, IAP=160 psi. 11510.9', pump 10 bbl sweep of 2# biozan. Probably exited the window. Attempt to drill formation. Able to make hole at 35 fph with window mill. Driller reports significant metal on ditch magnets. Window depth 10500'-10510'. Drill formation rathole to 11516', then could not mill further. Suspect mill has lost cutting structure in sand. Geo caught bottoms up sample, and reports 30% formation sand, metal cuttings and cement in sample. Backream window. Dry tag at 11514.6', pump 20 bbls sweep of 2# biozan. Circulate sweep to TD, Paint flag at 11385' bit depth, 11300' EOP. POH chasing the sweep. Tag up at surface, lay down BHA #2, window milling BHA. Mill recovered at 3.78" with the face polished off. The string reamer was recovered at 3.80". Shut down for crew change. PU BHA#3, First Open hole BHA for turn section. Smith Geodiamond M09, and 2.8 deg BHI motor. RIH with BHA # 3 shallow test MWD. Start mud swap @ min rate. Tie in @ flag 11398', correct to 11365' bit depth. RIH to tag. Tag @ 11510', PUH to get toolface. Toolface 87L, orient to 51 L, RIH tag same spot. Retag same. PU weight start pump, 2.7bpm @ 3100 psi. RIH tag @ 11507, see motor work @ 3250 psi. Correct bit depth to 11514' Start drilling build section, 2.6 bpm @ 3250 psi. Toolface @ 87L. Orient II Drilling ahead 11532': 2.5 bpm, 3800 psi, 45 fph, 80L toolface, 1400# wob. Start keeping returns @ 180 bbls away. Stall @ 11557', PU free spin 3520 psi. T oolface 125L Losing prime on c-pump, PUH standby. IA 388 psi, OA 88 psi Drilling ahead 11580'.3450 psi freespin, 50 fph, 3000# wob, Printed: 12/16/2002 10:38:45 AM ) ) BPE~PLQRATION . Qp~~~ti()n$pl.lrn~êiryReÞôr-t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N 1 Spud Date: 4122/1995 End: rJate Ftom~T() Hours Task COde NPT D~sÞtiþtÎ()hof Oþer$tiöhS 12/4/2002 12:20 - 14:00 1.67 DRILL P PROD1 87L. 14:00 - 15:00 1.00 DRILL P PROD1 Drilling ahead 11635'.2.5 bpm, 3550 psi, 4000# wob, 40 fph, 119L toolface. Drill to 11662' 15:00 - 15:30 0.50 DRILL P PROD1 Orient (go to window to get clicks) 15:30 - 16:00 0.50 DRILL P PROD1 Drill from 11662-690' 2.6/3600/43L w/ no losses and complete end of turn. PVT 270 16:00 - 18:05 2.08 DRILL P PROD1 Wiper to window. POOH for lateral assy 18:05 - 18:40 0.58 DRILL P PROD1 Adjust motor to 1.37 deg, change bit 18:40 - 20:40 2.00 DRILL P PROD1 RIH with BHA #4 to drill lateral section. IAP=173 psi, OAP=29 psi. Pit vol=201 bbls. 20:40 - 22:05 1.42 DRILL P PROD1 Log tie in pass accross gamma profile at 11100'. Ref log used was the PDC log from town Geo's. Make a -27' correction. 22:05 - 22:20 0.25 DRILL P PROD1 RIH to tie into RA tag in whipstock. 22:20 - 22:40 0.33 DRILL P PROD1 Log tie in pass accross RA tag in whipstock. 22:40 - 22:50 0.17 DRILL P PROD1 Orient 2 clicks. 22:50 - 23:50 1.00 DRILL P PROD1 11690', Begin drilling lateral section of open hole. TF=80L. Free spin 3570 psi @ 2.6 bpm. Pit vol=270 bbls. Returns 100%. IAP=388 psi, OAP=29 psi. 23:50 - 00:00 0.17 DRILL P PROD1 11734', orient around to 1 OOL. 12/5/2002 00:00 - 00:20 0.33 DRILL P PROD1 11734', orient around to 1 OOL. 00:20 - 01 :45 1.42 DRILL P PROD1 Resume drilling. Pit volume=270 bbls. IAP=420,OAP=65. 01 :45 - 02:10 0.42 DRILL P PROD1 11797', Starting to stack a little bit, make wiper trip to shoe. PU off bottom a little sticky (5klbs over normal PU). 02: 1 0 - 04:05 1.92 DRILL P PROD1 Resume drilling. Free spin 3450 psi at 2.5 bpm. Drilling at 4000 psi, ROP=60 fph. Pit vol=268 bbls. 04:05 - 05:25 1.33 DRILL P PROD1 11883', Wiper trip to "vertical" pipe at 9400'. (60 degrees deviation). 05:25 - 06: 1 0 0.75 DRILL P PROD1 Orient to 60L. 06:10 - 07:00 0.83 DRILL P PROD1 Resume drilling. TF=60L, Pit volume=262 bbls. 2.5/3600/90-20L. Drill to 11924' in ratty drilling area at 95 deg looking for sand 07:00 - 07:30 0.50 DRILL P PROD1 Orient around 07:30 - 09: 15 1.75 DRILL P PROD1 Drilling 2.4/3500/60L. Drill to 11948'. 150' wiper. Drill to 11974' and at 98 deg 09:15 - 09:55 0.67 DRILL P PROD1 Swap to pump #2 due to washed out liner. Drill from 11974-12000' 2.5/3500/104L Sperry MWD is intermittent 09:55 - 10:20 0.42 DRILL P PROD1 Wiper to window 10:20 - 10:50 0.50 DRILL P PROD1 Orient around to right and Sperry still intermittent 10:50 - 11 :05 0.25 DRILL P PROD1 Drill from 12000-12018' and may have got into sand at 12010'. MWD too intermittent PVT 250 11 :05 - 11 :25 0.33 DRILL N DFAL PROD1 Wiper to window, 5k overpulls 11800-900' 11 :25 -13:15 1.83 DRILL N PROD1 POOH for MWD 13:15 -14:35 1.33 DRILL N PROD1 Adjust motor to 1.04, change MWD probe. WO SS spacer 14:35 - 16:30 1.92 DRILL N PROD1 RIH w/ BHA #5 16:30 - 16:50 0.33 DRILL N PROD1 Precautionary ream to TD, clean PVT 248 16:50 - 17:05 0.25 DRILL N PROD1 Orient 17:05 - 17:30 0.42 DRILL P PROD1 Drill from 12018' in sand at 97 deg 2.4/3450/90L. Drill to 12060' 17:30 - 17:45 0.25 DRILL P PROD1 Orient 17:45 - 18:45 1.00 DRILL P PROD1 Drill from 12060' to hold 92 deg 2.4/3470/170R. Hit a hard spot at 12070' 18:45 - 18:55 0.17 DRILL P PROD1 12088', Pick up to get 5 clicks. Difficult to work back to bottom. Setting down at 12048'. Had to work several times up and Printed: 12/16/2002 10:38:45 AM -) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N 1 Spud Date: 4/22/1995 End: Datë From '-To HOurs Task Code NPT 12/5/2002 18:45 - 18:55 0.17 DRILL P PROD1 18:55 - 19:40 0.75 DRILL P PROD1 19:40 - 20:05 0.42 DRILL P PROD1 20:05 - 20:25 0.33 DRILL P PROD1 20:25 - 22:30 2.08 DRILL P PROD1 22:30 - 23:15 0.75 DRILL P PROD1 23: 15 - 23:50 0.58 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 12/6/2002 00:00 - 01:15 1.25 DRILL P PROD1 01:15-02:35 1.33 DRILL P PROD1 02:35 - 02:45 0.17 DRILL P PROD1 02:45 - 03: 15 0.50 DRILL P PROD1 03:15 - 03:35 0.33 DRILL P PROD1 03:35 - 04:40 1.08 DRILL P PROD1 04:40 - 05:15 0.58 DRILL P PROD1 05: 15 - 05:55 0.67 DRILL P PROD1 05:55 - 06:20 0.42 DRILL P PROD1 06:20 - 07:20 1.00 DRILL P PROD1 07:20 - 08:25 1.08 DRILL P PROD1 08:25 - 08:55 0.50 DRILL P PROD1 08:55 - 09:30 0.58 DRILL P PROD1 09:30 - 10:25 0.92 DRILL N WAIT PROD1 10:25 - 11 :20 0.92 DRILL P PROD1 11:20-12:15 0.92 DRILL P PROD1 12:15 - 13:00 0.75 DRILL P PROD1 13:00 - 14:25 1.42 DRILL P PROD1 14:25 - 14:50 0.42 DRILL P PROD1 14:50 - 15:00 0.17 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:05 0.58 DRILL P PROD1 16:05 - 16:30 0.42 DRILL P PROD1 16:30 - 17:35 1.08 DRILL P PROD1 17:35 - 18:30 0.92 DRILL P PROD1 18:30 - 20:15 1.75 DRILL P PROD1 down to get thru it. OAP=133, IAP=540, Pit volume=245 bbls. Resume drilling. Free spin = 3450 psi at 2.5 bpm. 2.5/2.5/3830 psi. 12109', Continuing to drill. Pumping 10 bbl sweep of high vis flopro to aide in hole cleaning. Plan to pump 1 sweep per hour. 12121', Orient Resume drilling. 12197', Wiper trip. Clean PU off bottom. Overpulls at 12060-12020' . Stacked out at 12030' when RIH. Backream up from 12100' to clean up interval. Add 4 more drums of Klagard to get concentration up to 12#/bbl. Lost 20 bbls of mud to formation since 18:00. PVT=225 bbls. Call for 100 bbls of new mud at 14#/bbl Klaygard. Sticky area cleaned up from reaming. Continue wiper trip back to bottom. 12197', Resume drilling. Pit vol=235 bbls, Free spin=3650 psi at 2.5 bpm. Drilling at 2.5/2.5/3840 psi, 45 fph. 12230', pump another 10 bbl sweep. Continue drilling. 12262', PU and orient 3 clicks. New pit volume = 325 bbls after adding 100 new to system. Drill ahead. 12282', PU to orient. Clean PU at 40 klbs. Resume drilling. 2.6/2.6/4000 psi. 12305', Wiper trip to window. Clean PU off bottom at 39 klbs. 5k overpulls 12045-12020'. Log tie in pass over RA tag in whipstock. Make +11' correction. Continue wiper trip back in hole. Some weight losses at 12048', but better than last wiper trip. Tag TD at 12313' Drill from 12313' 2.4/3550/70R. Drilling w/ neg wt to 12380'. Lots of shale drilled Wiper before mud swap to 10400'. Minor overpulls 12025', 11800-900' RBIH, start new mud Drill from 12380' 2.3/3200/140R. Drill to 12428' PUH, circ min rate while WO pit cleaning (truck shortage/dirty vac late arrival). RBIH Resume drilling 2.5/3260/93R. Drill to 12538' Wiper to window. Fin mud swap Orient around. PVT 287 Drill from 12538' 2.5/3240/79R in mostly sand at 92-95 deg to 12700' Wiper to window Log tie-in up from 11550' 2.3/3150/29R. Add 7.0' Wiper to TD tagged at 12705' Drill from 12705' 2.4/3200/84R in 40-70 api sand. Drill to 12763' Orient around Drill from 12763' w/ neg wt 2.5/3240/67R holding 90 deg Wiper to 9400' Continue wiper up from 10650', lifting cuttings to vertical section of well (60deg). IAP=550 psi, OAP=167 psi. Printed: 12/16/2002 10:38:45 AM ') ) BPEXPLGFR:AmION 9perQtiol1~..$u01'rn.ãl¥.~~Rort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N1 Spud Date: 4/22/1995 End: !Date FrbmiTo . Hôurs Task Code NPT 12/6/2002 0.25 DRILL P 3.50 DRILL P PROD1 PROD1 20:15 - 20:30 20:30 - 00:00 12/7/2002 00:00 - 00:50 0.83 DRILL P PROD1 00:50 - 01 :15 0.42 DRILL P PROD1 01:15 - 02:10 0.92 DRILL P PROD1 02: 1 0 - 04:45 2.58 DRILL P PROD1 04:45 - 05:25 0.67 DRILL P PROD1 05:25 - 07:00 1.58 DRILL P PROD1 07:00 - 07: 15 0.25 CASE P COMP 07:15 - 11 :45 4.50 CASE P COMP 11:45 -13:05 1.33 CASE P COMP 13:05 - 14:40 1.58 CASE P COMP 14:40 - 15:00 0.33 CASE P COMP 15:00 - 16:30 1.50 CASE N RREP COMP 16:30 - 17:10 0.67 CASE P COMP 17:10 - 18:45 1.58 CASE P COMP 18:45 - 19:30 0.75 CASE P COMP 19:30 - 20:00 0.50 CEMT P COMP 20:00 - 20:50 20:50 - 20:55 0.83 CEMT P 0.08 CEMT P COMP COMP 20:55 - 22:15 1.33 CEMT P COMP Tag up, PU clean at 39 klbs, orient to 45R. 12850', Resume drilling. Free spin 3300 psi at 2.5 bpm. Pit volume=270 bbls. 2.6/2.6/3650 psi. Very difficult to drill. Near coil lockup. Having to pound our head against the wall to make a foot at a time. Depth at midnight=13,OOO'. Wiper trip to shoe. Clean off bottom at 40klbs. No overpulls or motor work observed in previously bad interval at 12000-12050' . 11550', Make logging pass accross RA marker for depth correction. Make +8.2' correction. Run back to bottom for final tag. Tag at 13004'. POOH to pick up liner. Clean PU off bottom. Real smooth in open hole. No shale problems at 12000'. Painted flags at 9800' and 6700' EOP. Tag up at surface. Stand back injector. Lay down drilling BHA. Bit recovered in gauge, graded 1,3, BT, with 1 chipped gauge cutter and 2 chipped backreaming cutters. Cut coil connector, change packoff, attach new coil connector. PT 35k, 3500 psi Safety mtg re: liner MU 48 jts 2-7/8" 6.16# L-80 STL liner w/ float eq, cementralizers and pup. Safety/info mtg re: snow removal MU 52 jts 3-3/16" 6.2# L-80 TC11 liner MU XO's, XN, pups and CTLRT RIH w/ liner on CT 11450' 46k, 15.6k RIH, clean while losing push all the way to tag at 13027' CTD. Final RIH wt -4k. Did not recip. TOL at 9917', BOL @ 13004' Begin circ at min rate w/ wounded pump #1 while fin replace packing in pump #2. Pump 5 bbls to check pump #2 Load 5/8" phenolic ball. Circ to seat 2.6/2.5/3200, sheared at 4350 psi. PUH 35k and released from liner. MIRU DS cementers Displace mud w/ 2% KCI 2.5/2.5/3030 initial then take returns to flowback tank. 2.4/2.2/2460 at end Continue circulating KCL, Cleaning pits. IAP=315 psi, OAP=120 psi. Safety meeting prior to cementing. Rig crews, SWS cementers, Peak vac truck driver, Baker, BP in attendance. Special attention paid to unique rig up with Nordic 1 at edge of K pad. Batch mix cement. Pit vol=190 bbls. Cementers come on line with water to warm lines. Pump 5 bbls to warm lines. PT lines to 3000 psi. All ok. On line with cement. Pumping Class G cement @ 15.8 ppg, as proceedure. 1.9 in/1. 7 out. Pumping at 1500 psi CTP. Pump 27.5 bbls of cement. (Calculated annular vol=21.5 bbls) SD pumps, isolate coil, suck back lines, drop dart. Pressure up behind dart to 700 psi. Launch dart. Pump 0.2 bbls bio. SD, check for dart. Confirmed dart away. Chase with bio at 2.7 bpm, 1420 psi. Returns 1.7 bpm. Caught fluid at 16 bbls away. In rate 2.6 bpm at 1560 psi, out rate = 2.3 bpm. Printed: 12/16/2002 10:38:45 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N1 Spud Date: 4/22/1995 End: Date Fron'l~ To Hours Task Code NPT 12/7/2002 20:55 - 22: 15 1.33 CEMT P COMP 22:15 - 22:20 0.08 CEMT P COMP 22:20 - 00:00 1.67 CEMT P COMP 12/8/2002 00:00 - 00:10 0.17 CEMT P COMP 00:10 - 00:40 0.50 CEMT P COMP 00:40 - 01 :00 0.33 EVAL P COMP 01 :00 - 03:45 2.75 EVAL P COMP 03:45 - 04:00 0.25 EVAL P COMP 04:00 - 05:10 1 .17 EV AL P COMP 05:10 - 06:20 1.17 EVAL P COMP 06:20 - 07:15 0.92 EVAL P COMP 07:15 - 08:30 1.25 EVAL P COMP 08:30 - 09:45 1.25 EVAL P COMP 09:45 - 10:00 0.25 EVAL P COMP 10:00 - 12:00 2.00 EVAL P COMP 12:00 - 12:30 0.50 EVAL P COMP 12:30 - 14:15 1.75 PERF P COMP 14:15 -16:00 1.75 PERF P COMP 16:00 - 17:35 1.58 PERF P COMP 17:35 - 18:30 0.92 PERF P COMP 18:30 - 19:30 1.00 PERF P COMP 19:30 - 20:40 1.17 PERF P COMP Cement at the shoe, IN=2.7, Out=2.1, Landed dart at 58.7 bbls away (Coil vol=56.3). Displace cement at 1.5 bpm. Returns 1.3 bpm. Landed liner wiper plug at 20.3 bbls, (Liner vol=20.68 bbls). Bump plug to 2000 psi. Check floats, held ok. Unsting, pump 10 bbls of biozan. Lost 2 bbls cement to formation during cement job. Pumped 6 bbls excess, so have cement over top of liner. Unsting from CTLRT seals, W/O pulling out of liner deployment sleeve. Cement in place at 22: 15 PM. Pump excess 10 bbls of bio out of coil and CTLRT to wash top of liner, and to chase cement OOH. POOH, chasing contaminated cemenUBio. Pumping at 1.8 bpm, getting 1 for 1 returns. Continue POOH Tag up at surface, Stand back injector. Rig down Baker eq. All parts of CTLRT recovered. Safety meeting prior to rigging up clean out BHA and logging carrier. Make up Baker mill and motor for cleanout. Attach SWS carrier for GR/CCL log. Make up 102 jts of Nordic 1-1/4" CSH work string. Picking up singles from pipe rack and dropping drift thru each one. Make up injector. RIH with logging tools/Mill and motor on CSH and coil. Log memory logging pass down from 8800' at 60 fpm. Tag TD at 12974' CTM. Circulate perf pill to the bit at 0.5 bpm. (Limit of SWS logging tool.) POOH logging up at 60'/min while leaving fresh hi LSRV mud in liner. Log to 8800' POOH w/ CT Safety mtg re: CSH Standback CSH LD GRlCCL and motor/mill. Cement comp str 2000 psi RU and PT wellbore to 1950 psi. Started injecting at 1850 psi. SD pump w/4 bbls pumped. ISIP 1500, 5 min 800,15 min 650 psi, 60 min 545 psi. No change to IA Load perf guns in pipe shed. Safety mtg re: perf guns MU 45 SWS 2" HSD Powerjet guns and blanks RIH w/ 35 stds CSH RIH wi CT Continue RIH. IAP=107, OAP=50 psi. Electronic OAP readout not working. Having to take manual readings. Installed 2 mechanical gauges to be sure of readings. Tag bottom at 12967' on up weight. Set depth to 12969' which is ELM PBTD. Pull up to firing depth of 12961.1'. Pressure test liner lap again. Failed PT. Took fluid at 1 bpm, 1400 psi injection pressure at surface. Bleed off pressure, normalize valves pump 15 bbls flovis perf pill. Drop 5/8" ball to fire guns. Pump remainder of perf pill. Chase with KCL. Ball on seat at 55.5 bbls away (Coil + CSH vol=58.4). Good indication of fire at 3000 psi. Printed: 12/16/2002 10:38:45 AM ') ) BP.Expu..ORAwrON ()¡p~ri:t~iØ~$. .$;Yf"l)'l11"I~rYRe!ì>()rt Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 12/1/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 12/9/2002 Rig Name: NORDIC 1 Rig Number: N1 Houts Task Code 'NPT Phase D~$þriptiohøfqþèration$ 12/8/2002 20:40 - 22:45 2.08 PERF P COMP POOH replacing voidage. 22:45 - 23:00 0.25 PERF P COMP Tag up at surface. Stand back injector. 23:00 - 23:20 0.33 PERF P COMP Safety meeting prior to standing back CSH and laying down perf guns. 23:20 - 00:00 0.67 PERF P COMP Stand back CS hydrill work string. 12/9/2002 00:00 - 00:15 0.25 PERF P COMP Continue to stand back CS hydril. 00:15 - 03:20 3.08 PERF P COMP lay down SWS perf guns. Intervals perforated: 12015-12175 12330-12365 12390-12410 12440-12490 12530-12550 12590-12660 12695-12715 12730-12960 03:20 - 03:45 0.42 PERF P COMP All guns out of the hole. All guns fired, all shots fired. Finish rig down of SWS perforating eq, and pickup the Baker liner top packer. 03:45 - 03:55 0.17 CASE P COMP Safety meeting prior to picking up liner top packer. 03:55 - 04:30 0.58 CASE P COMP Make up Baker liner top packer. 04:30 - 06:55 2.42 CASE P COMP RIH with Baker liner top packer. 06:55 - 07: 15 0.33 CASE P COMP 38k, 24k @ 9850' 0.5/160 psi. RIH and sting in at 9936' CTO. Set 8k to 9942'. Line up to BS and check lap for leak. Inject at 0.5 bpm @ 1380 psi. No change to IA. Bleed off press. Unsting at 44k (seals dragging) and PUH 38k to ball drop at 9912' 07:15 - 08:00 0.75 CASE P COMP load 5/8" aluminum ball. Circ to seat with KCI1.9/1.8/725, 0.6/0.6/165 08:00 - 08:30 0.50 CASE P COMP RIH wi ball on seat and sting back in (took a few tries-setting down on TOl). PUH to get string wt back at 9937.0'. Then PUH additional 1.5' at 9935.5'. Press up to 2500 psi and set l TP. PUH to 45k and verify set. Stack wt to verify, then get back to neutral wt. Bleed off CTP. Stack wt to 9942.1 '. Pull back to neutral at 9939.7'. Press up on BS to 2000 psi and monitor 5 min w/50 psi loss (to coil, leaking isolation valve). No change to IA. Bleed off press. Pressure up CT to shear ball seat at 3600 psi. PUH 38k and released. Top of l TP @ 9909.7' 08:30 - 10:05 1.58 CASE P COMP POOH wi l TP setting assy. Freeze protect from 2000' while POOH 10:05 - 10:30 0.42 CASE P COMP lO BHA. SI swab 10:30 - 12:00 1.50 RIGO P COMP RU nozzle assy. PT OS N2 @ 3000 psi. Blow down CT w/ N2 and bleed off 12:00 - 14:00 2.00 RIGO P COMP Breakdown hard line in reel house. Unstab CT and spool back to reel 14:00 - 15:00 1.00 RIGO P COMP NO BOPE. NU tree cap and PT 15:00 - 16:00 1.00 RIGO P POST Rig released at 1500 hrs 12/9/02 Fin RO and prep to move 16:00 - 16:30 0.50 RIGO P POST Move off well to end of Pad 16:30 - 17:15 0.75 RIGO P POST Hang BOP's for transport while RU Peak crane. Remove gooseneck and set on floor to change out chains on injector during rig move 17:15 -17:30 0.25 RIGO P POST Safety mtg: reel swap Printed: 12/16/2002 10:38:45 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-20 K-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 12/1/2002 Rig Release: 12/9/2002 Rig Number: N1 Spud Date: 4/22/1995 End: Date Fröm:~T() . Hours Task Code NPT Phase Desdriþtî()nÖfQþë~atipps 12/9/2002 17:30 - 18:45 1.25 RIGD P POST 18:45 - 19:30 0.75 RIGD P POST 19:30 - 20:00 0.50 RIGD P POST 20:00 - 00:00 4.00 RIGD P POST Pick used reel with 713k RF and set on ground. DS install new bushings on reel drive. Pick new reel of 0.204" wall CT and set in reel house Prep to head down the road. WO Security escort Safety mtg re: rig move Leave K Pad and head to F Pad Printed: 12/16/2002 10:38:45 AM ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well K-20B Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,470.19' MD Window / Kickoff Survey 11,475.00' MD (if applicable) Projected Survey: 13,004.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) ') a~_~ y 07 -Jan-03 RECEIVED JAN 0 9 2003 AIaiœ œ & Gas Cons {'.I\mnoo:-! ~ ~ -V""'1A58IOfJ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA K Pad K-20B ~ Job No. AKMW22192, Surveyed: 6 December, 2002 Survey Report 6 January, 2003 Your Ref: 500292255502 Surface Coordinates: 5975192.46 N, 671480.22 E (70020' 17.1523" N, 148036'30.6626" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 975192.46 N, 171480.22 E (Grid) Surface Coordinates relative to Structure Reference: 2003.44 N, 1183.69 E (True) Kelly Bushing: 52. 13ft above Mean Sea Level Elevation relative to Project V Reference: 52. 13ft Elevation relative to Structure Reference: 52. 13ft spe,-,'-'y-55UI! DRIL.L.ING seRVices A Halliburton Company Survey Ref: 5vy11420 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-20B Your Ref: 500292255502 Job No. AKMW22192, Surveyed: 6 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11470.19 91.700 146.560 8737.88 8790.01 4662.96 S 84.37 W 5970528.79 N 671502.50 E -1597.89 Tie On Point MWD Magnetic 11475.00 91.690 145.810 8737.74 8789.87 4666.96 S 81.70 W 5970524.86 N 671505.27 E 15.587 -1596.66 Window Point .. - 11500.00 91.660 141.960 8737.01 8789.14 4687.14 S 66.97 W 5970505.02 N 671520.45 E 15.394 -1589.31 115=30.-11 D5. G90 '132.050 8735.08 8787.21 4709.47 S 46.48 W 5970483.15 N 671541.45 E 32.264 -1577.20 11560.23 96.120 123.860 8732.03 8784.16 4727.88 S 23.26 W 5970465.28 N 671565.09 E 30.375 -1561.24 ~ 111)97.86 9-1.2 í)() 112.5JO 8728.61 8780.74 4745.56 S 9.72 E 5970448.37 N 671598.46 E 30.379 -1535.81 1162/.28 94.270 104.330 8726.42 8778.55 4754.82 S 37.53 E 5970439.74 N 671626.47 E 27.795 -1 51 2.54 11 660 21 89.600 95.170 8725.30 8777.43 4760.38 S 69.92 E 5970434.92 N 671658.98 E 31.202 -1483.72 11689.39 92.330 87.240 8724.80 8776.93 4761.01 S 99.56 E 5970434.97 N 671688.63 E 28.251 -'1455.90 11720.54 94.630 83.540 8722.94 8775.07 4758.55 S 130.05 E 5970438.13 N 671719.06 E 14.194 -1426.27 11753.3:2 ~)O.l\,I() 7(i.GOO 8721.37 8773.50 4752.92 S 162.28 E 5970444.49 N 671751.15 E 23.938 -1393.96 1 1 nn .f)Ç) 91.100 72.430 8720.69 8772.82 4742.20 S 201.08 E 5970456.10 N 671789.69 E 10.522 -1353.79 11821.3D 930:!O G~).mo 8719.62 8771.75 4732.60 S 229.27 E 5970466.34 N 671817.65 E 10.509 -1324.01 118:)137 ~nO'!O 61. ~j 1 0 3717.81 8769.94 4718.67 S 260.17 E 5970480.97 N 671848.23 E 24.8G:2 -'1290.:25 11898.82 93.040 5G.050 8715.61 8767.74 4697.23 S 295.56 E 5970503.22 N 671883.12 E 13.154 -1249.81 11930.64 9G.G50 51.290 8712.92 8765.05 4678.45 S 321.09 E 5970522.57 N 671908.22 E 18.730 -1219.56 11964.72 97.270 47.060 8708.79 8760.92 4656.34 S 346.68 E 5970545.26 N 671933.30 E 12.454 -1188.16 11993.17 96.300 43.180 8705.43 8757.56 4636.41 S 366.70 E 5970565.65 N 671952.85 E 13.965 -1162.75 12038.42 97.270 43.540 8700.08 8752.21 4603.74 S 397.55 E 5970599.01 N 671982.94 E 2.285 -1122.94 12076.67 93.740 41 .250 8696.41 8748.54 4575.63 S 423.21 E 5970627.70 N 672007.96 E 10.985 -1089.53 12110.04 93.830 40.190 8694.21 8746.34 4550.40 S 444.93 E 5970653.43 N 672029.10 E 3.181 -1060.77 12151.22 92.070 39.840 8692.09 8744.22 4518.90 S 471.37 E 5970685.52 N 672054.81 E 4.357 -1025.52 ~; 12185.52 92.330 35.610 8690.77 8742.90 4491.80 S 492.34 E 5970713.10 N 672075.15 E 12.347 -996.87 12215.22 91.540 33.320 8689.77 8741.90 4467.32 S 509.14 E 5970737.95 N 672091.39 E 8.152 -973.02 12253.17 93.300 33.670 8688.17 8740.30 4435.71 S 530.06 E 5970770.04 N 672111 .58 E 4.728 -942.94 12284.42 94.71 0 34.550 8685.99 8738.12 4409.90 S 547.54 E 5970796.24 N 672128.47 E 5.315 -918.01 12319.69 96.300 36.310 8682.60 8734.73 4381.29 S 567.89 E 5970825.30 N 672148.16 E 6.708 -889.46 12352.82 96.650 39.130 8678.87 8731.00 4355.26 S 588.03 E 5970851.79 N 672167.69 E 8.523 -861.94 12383.37 96.830 44.240 8675.28 8727.41 4332.61 S 608.20 E 5970874.90 N 672187.34 E 16.621 -835.50 12412.57 97.000 45.4 70 8671.76 8723.89 4312.06 S 628.64 E 5970895.91 N 672207.31 E 4.222 -809.47 ~--- 6 January, 2003 - 15:58 Page 20f4 OrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-20B Your Ref: 500292255502 Job No. AKMW22192, Surveyed: 6 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12449.84 96.210 51.640 8667.4 7 8719.60 4287.56 S 656.38 E 5970921.03 N 672234.48 E 16.581 -775.27 1/4ß1.2D 9S.GßO S2.:150 8604.21 8716.34 4268.30 S 681.03 E 5970940.85 N 672258.68 E 2.807 -745.70 1 ~~S~~;¿.l9 ~)t1. 0 10 GO.450 ü659.36 ü711.99 4239.94 S 723.74 E 5970970.18 N 672300.73 E 1 G.003 -G9G.On 12SG1.G4 D2.G~)0 62.210 8658.17 8710.30 4226.12 S 749.01 E 5970984.57 N 672325.67 E 7.617 -667.69 1 >'~/U.,1~! ~J;'.O /() (jt .r;UO ßGSG.nG n708.98 4211.89 S 777.47 E 5970999.45 N 672353.30 E 7.939 -G36.'1 G 12626.67 92.250 67.150 8655.60 8707.73 4198.36 S 807.74 E 5971013.67 N 672383.76 E 7.459 -603.12 ~i PSG5 72 91.G.1Q 68.560 8654.64 8706.77 4187.42 S 834.63 E 5971025.22 N 672410.39 E 5.432 -574.13 1 ;_)G8ß.4 7 DO.GGO 69.970 8654.01 8706.14 4175.83 S 865.25 E 5971037.51 N 672440.74 E 5.074 -541 .4 1 1::721.09 89.600 73.670 8653.93 8706.06 4165.65 S 896.24 E 5971048.39 N 672471.48 E 11.799 -508.110 121:::)7J2 89.2S0 78.430 8654.30 3706.43 4156.82 S 931.77 E 5971058.03 N 672506.81 E 13.029 -472.32 12793.27 90.220 82.130 8654.47 8706.60 4150.82 S 966.81 E 5971064.83 N 672541.70 E 10.759 -437.24 12821.79 89.780 83.71 0 8654.4 7 3706.60 4147.31 S 995.11 E 5971068.99 N 672569.91 E 5.751 -409.34 12855.27 89.4:10 86.000 8654.70 8706.83 4144.31 S 1028.45 E 5971072.76 N 672603.17 E 6.919 -376.84 1 ~')WJ2r)t 90.220 87.S90 8654.81 8706.94 4142.22 S 1065.76 E 5971075.70 N 672640.43 E 4.751 -340.88 1 /()/~)./.') ßLU/JO 93.030 8654.84 n706.97 4142.66 S 1099.32 E 5971076.02 N 672673.99 E 18.946 -309.29 12961.67 89.600 97.810 8655.06 8707.19 4146.29 S 1134.58 E 5971073.20 N 672709.32 E 10.948 -277.14 13004 00 89.000 97.810 8655.35 8707.48 4152.04 S 1176.51 E 5971068.41 N 672751.38 E 0.000 -239.36 Projected Survey All data is in Feel (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 71.0000 (True). ~ Magnetic Declination at Surface is 26.091 0(02-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13004.00ft., The Bottom Hole Displacement is 4315.51ft., in the Direction of 164.180° (True). -- 6 January, 2003 - 15:58 Page 3 of4 DrillQuest 3.03.02.004 North Slope A/aska Comments Measured Depth (ft) 11470.19 11475.00 13004.00 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-20B Your Ref: 500292255502 Job No. AKMW22192, Surveyed: 6 December, 2002 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8790.01 8789.87 8707.48 4662.96 S 4666.96 S 4152.04 S Survey tool program for K-20B Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 11t170. Hi 6 January, 2003 - 15:58 0.00 n nH) () 1 To Measured Vertical Depth Depth (ft) (ft) 11470.19 13001.00 Comment 84.37 W 81.70 W 1176.51 E Tie On Point Window Point Projected Survey ~ Survey Tool Description 8790.01 AK-3 BP _HM - BP High Accuracy Magnetic(K-20PB1) 8707.48 MWD Magnetic(K-20B) ~; Page 4 0(4 DrillQuest 3.03.02.004 ) ~1f~1fŒ lID~ ~~ ~L«~ TONY KNOWLES, GOVERNOR AT1ASKA OIL AND GAS CONSERVATION COMMISSION 333 w. -¡rn AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P. O.Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit K-20B BP Exploration (Alaska) Inc. Permit No: 202-224 Surface Location: 3251' NSL, 4070' WEL, SEC. 04, TIIN, TI4E, UM Bottomhole Location: 973' SNL, 2924' WEL, SEC. 09, TIIN, TI4E, UM Dear Mr. Johnson, Enclosed is the approved application for pennit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tennsand conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ~(/'''' day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ') ) Obp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mark O. Johnson em Engineer Date: November 25,2002 /' 1A?L- 'L 1- 'f Request for accelerated approval ofPBU K-20A Sundry and K-20B Permit to Drill Re: , ,".~-'\ We respectfully request that AOGCC approve the K-20A form 10-403 and K-20B permit to drill by (í/2'. Í/;ûdto enable the Nordic I CTD sidetrack rig to move over the well by 12/01/02. '-;::::?' This accelerated approval request is being made due to complications with well availability. Nord.ie..~-l-~S originally planning to move to the PI-08A sidetrack on 12/01/02 (instead ~K-20B), b~'sea ice.!!Ü~s to the East of the PM-l pad is not forecast to reach the required 18" by 12/1/02. A full 18" thickrlesSÍs required before drilling operations can commence. Warmer than usual weather on the North Slope and a layer of snow over the; sea ice has delayed achievement of the 18" at the East location. Based on borehole data, 18" to the East is now / expected by '" 12/7 . As such, we would like to move the rig to K-20A by ~12/1 and request the accelerated approval of permits. Thank you. ;2 ~O. ~, Mark O. Johnson 4 CTD Drilling E . ~eer 564-5666,240-8034 CC: Well File Sandra StewmanfT errie Hubble RECEIVED NOV 2 2 2002 Alaska Oil & Gas Cons. Commission Anchorage ~GA- IqlL){Ol.- 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3251' NSL, 4070' WEL, SEC. 04, T11N, R14E, UM At top of productive interval 116' SNL, 4635' WEL, SEC. 09, T11N, R14E, UM At total depth 973' SNL, 2924' WEL, SEC. 09, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028304, 2356' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11500' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina WeiQht Grade CouDlina 3-3/4" 3-3/16" x 2-7/8" 6.2#/6.16# L-80 ST-L ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 52.13' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028303 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / K-20B 9. Approximate spud date 12/01/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12900' MD 18717' TVD 17. Anticipated pres29u ee 20 AAC 25.035 (e) (2)} 97 0 Maxi~um surface 24~ psig, At total depth (TVD) 8800' / 3311 psig Setting Depth 0" Top Botom Quantity of Cement Lenath MD TVD MD TVD lincludeßtaae data) 3000' 9900' 8665' 12900 8717' 98 sx Class 'G' ./ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Rt€EIVED Casing Structural Conductor Surface Intermediate Production Liner 13108 feet 8764 feet 13020 feet 8764 feet Length Plugs (measured) 4-1/2" CIBP at 12030' (08/00) 2002 NOV 22 Alastœ Oll& Gas Cons. Commission . An9JJßI'8ae TVD Junk (measured) Size Cemented 110' 20" 260 sx Arcticset (Approx.) 110' 110' 3681' 10-3/4" 1045 sx PF 'E', 735 sx Class 'G' 3716' 3712' 9066' 7-5/8" 264 sx Class 'G' 9098' 8259' 4172' 4-1/2" 460 sx Class 'G' 8936' - 13108' 8133' - 8764' Open: 10290'-10340',10650' -10740',10810'-11000',11080' -11480',11620' - 11760', Below CIBP: 12060' - 12140' , 12570' - 12650' ,12730' - 13000' true vertical Open: 8763' - 8773' , 8781' - 8777' , 8776' - 8776' , 8779' - 8790' Below CIBP: 8774' - 8765' , 8756' - 8758' , 8762' - 8764' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Mark Johnson, 564-5666 Prepared By NameINumber: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true n correct to the best of my knowledge ./ Signed MarkJohnson ~ 0. ~ Title CT Drilling Engineer Date I'/ZSj,°2- Permit Numberi< F':PI'~~~X'1':("<:Çb;~"~~¡¡¡i0'\)¡';~~~¡'6~;: ." se~ coverleÌt~r ~ 2.0.2.-22.7' 50-029: 2555-02 I ilri.loJrw. for other reQuirements Conditions of Approval: Samples Required 0 Yes B1 No Mud Log RJquired 0 Yes ~ No Hydrogen Sulfide Measures S Yes 0 No Directional Survey Required EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: 'T ~s t ßç r £ f-cP ~ ç Dc..? r ç i' . ORIGINAL SIGNEDA~Î~~i6ner M L. tsJa \. \< ; Perforation depth: measured 20. Attachments Approved By Form 10-401 Rev. 12-01-85 by order of the commission Date 1/1 d. ~I n;J. ~ubmit In Triplicate ) ) BP K-20B Sidetrack Summary of Operations: Well K-20A is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, K-20B, will exit out of the existing horizontal 4 yz" liner from a whipstock at 11500'md and target Zone lA/IB reserves to a TD of 12900' md. A schematic diagram of the proposed sidetrack is / attached for reference. The well will be completed with a cemented and perforated 3 3/16"x 2 7/8"~Iid liner. The existing 4 yz" liner perfs are gassed out and will be abandoned during the primary cement jo~f the new sidetrack liner (form 10-403 has been submitted). Pre CTD Summary I) SIickIine -Drift tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. Pressure test OA to 2000 psi. 2) Service Coil - Drift tubing and liner to 11600' with dummy whipstock. Cleanout as necessary. Set whipstock at 11500' md. CTD Sidetrack and P&A ofK-20A Summary 1) MIRU CTD rig. 2) Mill window out of 4 yz" liner from whipstock at 11500'. /' 3) Drill 3.75" openhole sidetrack to ~12900' TD with MWD and gamma ray. ..¿'-:.'~'~~~.] 4) Run ~ 3/16" x 2 7/8" liner completion. T~p o~liner will be at 9900': Cement witIr'~ ce~ent.. Run Imer top packer as necessary. At thIS pomt the new cemented Imer covers aI1...op.eR"perforatlOns III the 4 yz" parent wellbore from 10290-11760'. P&A of the parent wellbore perforations is complete. 5) RDMO Mud Program: . Phase 1: 8.4 ppg seawater /' . Phase 2: 8.5 ppg used Flo Pro for milling, new Flo Pro for drilling. Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: J.' . A 3 3/16" x 27/8" solid cemented liner completion from 9900' to TD at 12900'. The liner cement volume is planned to be ~20 bbls of 15.8 ppg class G. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / . The annular preventer will be tested to 400 psi and 2500 psi. ) ') Directional . See attached directional plan. Max. planned hole angle is 97 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be ron. /' Logging . MWD Gamma Ray log will be ron over all of the open hole section. . A CNL/GRlCCL cased hole log is optional after the liner has been run and cemented. Hazards . The highest IDS recorded to date on K~Pad was/rÕ pppr.'/K pad is not an H2S pad. K-20A H2S is 10 ppm on 8/17/00. :::;?,/ . No fault crossing are anticipated so lost circulation risk is considered low. .".--" ,." ~ ."\ "",-"\ Reservoir Pressure 6 ) Res. press. is estimated ~o be 3311 psi at 8800' (7.2'»þg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2431 psi. /' ~-:: MOl 11/22/02 H1~'~ '\ TREE=, 4-1/16" CIW WELLHEAO = FMC 'ÃCtÜÄrorf;""",,,,,waÃKËå "KËCËlE\r;m#'m""u"'''45~.iV ï3fr~L'Bíu;mM'M....mm'24~2" 'KOp;_m........w.,..w..m"'43SÓí :.~.~.~~:'~~~~.'~::.':~~,!~:'~f~~~,~.~~~~ DatumMD= ~""-'-'-'-'~'~'.'-'-'-'-'''''.'-'-'''''''''''''''-'''''-''''''''-'-'-'''.'-''''"".'.'__-'.'0'''''''''-_''''.''''.'.'. DatumTVO= SSOO'SS ) s,þ (fo~' 110-3/4" CSG, 45.5#, NT-SO, 10= 9.950" l-i 3716' Minimum ID = 3.725" @ 8924" 4-1/2" HES XN NIPPLE TOPOF BKR TIEBACK SLEEVE 1-1 8934' 17 -5/S" X 4-1/2" BKR ZXP PKR, ID = 5.50" l-i 8941' 17-5/S" x 4-112" BKR HMC HGR, ID= 4.S75" l-i 8950' 17-5/S" CSG, 29.7#, L-80, 10= 6.875" l-f 10212' I PERFORATION SUMMARY REF LOG: MWD ON OS/04/98 ANGLEAT TOP PERF: 7S @ 10290' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL' Opn/Sqz DATE 2-7/8" 4 10290-10340 isolated proposed 2-7/S" 4 10650-10740 isolated proposed 2-7/8" 4 1 OS1 0-11000 isolated proposed 2-3/4" 4 11080-11480 isolated proposed 2-7/8" 4 11620-11760 isolated proposed 2-3/4" 4 12060-12140 C 08/19/00 2-3/4" 4 12570-12650 C 08/19/00 2-3/4" 4 12730-13000 C 08/19/00 f4-1/2" BKR CIBP08/19/00 K-20B / SAFr)oTES: Wa.L ANGLE> 70° @ 9859' & > 90° @ 1Ck } PRE-SIDETRACK WELLBORE NOT SHOWN BELOW M ILLOUT WINDOW. Proposed CTD Sidetrack ~ ~ 2222' 1-14-1/2" HES x NIP, ID = 3.813" 1 ~ ~ GAS LIFT MANORELS OEV TY PE VL V LATCH FORT 2 TMPDX rN BK 0 38 TMPDX rN BK 0 38 TMPDX rN BK 0 38 TMPDX rN BK 0 OATE 08/20/01 08/20/01 08/20/01 08/20/01 L ST MO TVO 4 3265 3200 3 5739 5539 2 7634 7039 1 SS01 7967 . I L 8868' 1-14-1/2" HES x NIP, 10 = 3.813" I 8 ~ 1 8878' 1-17-5/s" x 4-1/2" TIW HBBP- T PKR, 10 = 3.912" 1 t ~ 1 8903' 1-14-1/2" HES x NIP, 10 = 3.813" I 1 8924' 1-14-1/2" HES XN NIP, 10 = 3.S" 1 1 8935' 1-14-1/2" TBG,12.6#, L-SO,.0152 bpf, 10 = 3.958" 1 ~ ~ I 8936' .1-14-1/2" WLEG, 10 = 3.958" 1 ~ r' 1-1 ELMO TT NOT LOGGED 1 7-5/8" CSG MILLOUTWINDOW 909S' - 9111' (TOP OF WHIPSTOCK @ 9097') /' / 9900' 1--1 Top of 3-3/16" 6ner I 9910' 1-1 3-1/2" XN Nipple, 10= 2.75" I ~~J~Ma I" ,-, ~ I 115.50' H 3-3/16 X 2-7/8 crossover I ~~n, ,', I I I '>:~~'/......wuu....."y.~';~""~~~';~~~''''''''':''';';':'-'':'''::::;''':~~~«':-"'':::::-:;;'-::::-:;;"~"~~~'>:~~~~''';~';':'':::'~~'''.'l",;:;::::::;~'kj / ' '.. .. onmm.'m..... ;o""'<';~';'~;:;~;:;~~':«';''';''' ...",.:<~~.:;;:~~.~;.:;;~:;:;:;,;'~;;;.;::::::;;:;èi.;;~:;'~.~;~~:;~.,;..~u i'" 13-3/16 x 2-7/S crrted and perfed liner 1--1 12900' 1 11500' 1--1 Mechanical Whipstock .. I PBTO 1-1 13020' I 1-1 13108' -~ 14-1/2" LNR, 12.6#, LBO, .0152 bpf, 10=3.958. I ~ OATE 06103/95 08/27/98 02124/01 03/03/01 01/07/02 COMMENTS ORIGINAL COMPLETION RIG SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-MO FINAL CH/TP CORRECTIONS REV BY DA TE REV BY COMMENTS PRUOHOE BAY UNIT WELL: K-20A PERMIT No: 198-1500 API No: 50-029-22555-01 SEC4, T11N, R14E3251' NSL & 4070' WEL BP Exploration (Alaska) I TREE=' 4-1I16"Crw WELLHEAD = FMC 'AêTÜÄTÕFf;""""""'sÃKÊR -'_J"'-'''''''",~,...-....,-_.....,.'''-'''J...'''-'-,".'-'.'''-'''.'-''''''-'''''-'.'''''''''''''...",,,,,,,-,, KB. ELEV = 45.4' ....,...",.,,,,J..."''''''''',,,.',,,,,,........,,,,-,-,...,,,",-,.........'''''''''''--'''''''''''''''''.'''-''''''-''''''''''''. BF. ELEV = 24.2' "KÕP~"",--,--",--",w"""--435Ô; '~.~.~~~~~~~!~~~::.":.'~.t~~.X~.~~~~ Datum MD = '5ãiüñí'n/õ";''''''''''SSÔÔõ'SS' ") '1\\".~ 110-3/4" CSG,45.5#, NT-80, ID = 9.950" 1-1 3716' Minimum ID = 3.725" @ 8924" 4-1/2" HES XN NIPPLE rTOPOF BKR TIEBACK SLEEVE 1-1 8934' \7-5/8" X 4-1/2" BKRZXPPKR, ID= 5.50" 1-1 8941' 17-5/8" x 4-1/2" BKR HMC HGR, ID = 4,875" l-f 8950' ÆRFORA TION SUMMARY REF Loo: MVVD ON 08/04/98 ANGLE AT TOP PERF: 78 @ 10290' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10290-10340 0 02/23/01 2-7/8" 4 10650-10740 0 02/23/01 2-7/8" 4 10810-11000 0 02/23/01 2-3/4" 4 11080-11480 0 08/27/98 2-7/8" 4 11620-11760 0 02/23/01 2-3/4" 4 12060-12140 C 08/19/00 2-314" 4 12570-12650 C 08/19/00 2-3/4" 4 12730-13000 C 08/19/00 17-5/8" CSG, 29.7#, L-80, D = 6.875" 1-1 10212' ~ K-20A/ ~ ~ L I X I ~ t ~ ~ ~ ~ ~ ill- , !.. ..x . - SAFr"~OTES: WELL ANGLE> 70° @ 9859' & > 90° @ 10 } PRE-SIDETRACK WEL L BORE NOT SHOWN BB.OW M ILLOUT WINDOW. 2222' 1-14-1/2" HES X NIP, ID = 3.813" 1 ~ GAS LIFT MANDRELS DEV TYPE VLV LATCH RJRT 2 TMPDX rN BK 0 38 TMPDX DV BK 0 38 TMPDX rN BK 0 38 TMPDX DV BK 0 DATE 08/20/01 08/20/01 08/20/01 08/20/01 ST MD TVD 4 3265 3200 3 5739 5539 2 7634 7039 1 8801 7967 8868' 8878' 1-14-1/2" HES X NIP, ID = 3.813" I 1-17-5/8" x 4-1/2" Trw HBSP. T PKR, ID= 3.912" I 1-14-1/2" HES X NIP, ID = 3.813" 1 1-I4-1/2~' HES XN NIP, ID = 3.725" I 8903' 8924' 8935' 1-14-1/2" TBG,12.6#, L-80,.0152 bpf, ID = 3.958" I 8936' 1-14-1/2" WLEG, ID = 3.958" I 1-1 ELMD TT NOT LooGED 1 7-5/8" CSG MILLOUT WINOOW 9098' - 9111' (TOP OF WHIPSTOCK @ 9097') rl 12030' 1-1 4-1/2" BKR CIBP 08/19/00 I 13020' I 14-1/2" LNR, 12.6#, L80, .0152 bpf, ID=3.958" l-i 13108' I RBI BY DA TE REV BY COMMENTS DATE 06103/95 08/27/98 02/24/01 03/03/01 01/07/02 COMMENTS ORIGINAL COMPLETION RIG SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL CHITP CORRECTIONS PRUDHOE BAY UNIT WELL: K-20A PERMIT No: 198-1500 API No: 50-029-22555-01 SEe 4, T11 N, R14E 3251' NSL & 4070' WEI.. BP Exploration (Alaska) R.. BtlLS INTEQ -----.---------, Plan: Plan #14 (K-20/Plan#14 K-20B) . Date 11/19/2002 T ^M ¿ LEGEND - K-16 (K-16) - K-20 (K-20) K-20 (K-20A) - K-20(K.20P81) - Plan#14 K-208 - Plan #14 /.-:~-........ ~,V_j.' .q1n ~.. ¿Z::;..Oo ~ý f _¿$";;E .",-<.....' '_1 W--". Tie .. MDI 1118' ~. oa...... Ko28A 11470_11 Azimuths to True North Magnetic North: 26.10. Created By Bnj Patnis Stre~at~~~~<¡J¿~~ Contaçt In!mrnation Dip 20gle: 80-85. Dlfect (907,267.6613 Date: 11/1912002 E .ma,l' brij patnis@inteQ çom Model: BGGM2002 Baker Hughes INTEG. (907) 267-ô600 BP Amoco ObP -~--., WlLL'ATH D8TAlLS ''''''4 IWtGa 80028221"02 1(.20A 12.UII v_- ....... 71.00' ~ ~~= J::~ .... _..l--~-~-+-- -t-~------ -36~=~.__- -3700 =------1-.- i- -1m -3800 ~. ¡ . -3000-1--~-~~~- -L...---_.....;. .... 0." . ¡n___¡- REFERENCE INFORMATION Co-ordlnate ~¡ Reference: Wen Centre: K-20, True North v=~ (Vg ~:¡:~=: ~~~% Toe~~~)el Measured Depth Reference: K-20A 52.13 CalCUlatlon Method: Minimum Curvature Art t U.ø&lI ...,. ...... I U""OO ..,... ...." : ::m:: :t~ ~:::: . U...... "'It 80.8' . tt,..... fl." It." , t...... -.... ...a . 'aM.OI 81." ,1.8, . '''''''''''aU ..... n :=:::::: ::;: Ift'nON .IT~ - - "1'7." ......., ...... IT." "",.U ...... 11'_1I..c?01.7t -M,.u 1721." .....,-.11 -17.71 87D.11 047P." 71.417 *'1"" """'" ....t) ".......... .10.02 ::::::: ::::~ :::= ,,70.2'7 ...ue2." 10"'85 """2 ...tIUA' 1111.21 0.00 0.00 -t187'" .... ...17 -."'.28 ..00 211.00 -1882'" u..oo 211.00 -t ....., '8.00 ...00 -1~.2I iiã :4Ë :itä ;:::: 17-::: :::: """",--._-+---....--~_._- -.--~ .+------.. ---~ ; ; I I ..... nee. Y'88c T8r88t i :: rF~~ ~ . r~~F {!~~T~Fr~FfF+-J=f~Jn-l~ccr=r~E1r~mC-T: ~ -; I . I. ,. 1- .!, -, .I!e ..I -- -..I" r ! . I' -I i. 1 i' . . I is 1 i', ! 1 : ii, ' I K-208 T13.2,l...! i ; ¡ ! ! ¡ ! :~~- ;-~~~~ ~~:~~~~I~~~~=~-~~~!~Î.~.;j.'~I~lf~.H .n7.80811&7'.18n, K.JOIITt" _00""'''''''''''''' +.... Y. 1 ¡ IK.2oéT\á1i . I .. . ¡ .. , , :m::m:::: ~OI' --«oo-.:r-:-- .u, ---:---.- . ~'-I I. " ---' . I' '....' .. ..~ --.--1 , ! ! ;-+ :~u:nmr.::: J .c: -' .....--- I '1- ,-- --I .E!!L6 . .".., -. .--., - 1 ¡. .1. +! jl 1f18A1 U7"'" 4 1:: ~. I. 1 .. .. !. , . '. , '. ;., . 1788'" 11_'" . -4 . --. - . . -'-- ., ----'------L--...-.---- '_"111"'''' . 0 .-.... '__'n__... I.. o. . '.T .... 1 . ¡ !iWi!!æ !. i--:-':I-~ :m~'-c-! . . .~'=cJ_m_-:~jl!~1 :::; I 1 1 I I 1 I I 1 I ::I -4700 - KOP 1 I ! : I , -- '. .! i :. . ' . ' . i .1. I...! 0 ::; ...~~. ,.. "- ... l' ! -I . ì' . "1' - 81~-+-.-t---t-----t--:~'r--+-~ I en -4800 l~' . --'-:'-::--C'" ..1--=:, - . .1 : 1- ----:--~- .- . .. . ,... '. i 1----, Î K-20B P Iygo 131. ------------ --- .. f . ----- ~~m~__===-1~-~r:l= :f=~~~=f::~~~n .~~C~:~I:= : I+~~! ..... ~#tr~~t --4 I 1--1 --4c---~+- .5100l~----~-:---c--rrT~I-CC----:frl-C--cfr-ll-J-tn:Ätl~~1~14 t:L m' ~j-..::c '1:lm:t_i~:.:i . .~ :: ~~==C~:-~m~-~~4-~=~.. .~~:-.-:-..~~. ~~~~.::l_=~;:--::ê~i~::_~==~=~1'.:b' .., õ -j I I ¡:1-t. . ."" "" "" "" "" .,,, "",'''.1'''' "" '" "" '" ,," '" ""I ,,',", '" ,Pi, "I"'" ",'''I, "r,,;;j-. ,. ¡¡¡ -'.'p' . .t . 'I..J . . I . ..t .. I .., .1.. ~. -. -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 Q,845<r-+ - - --I~r--F-- I-r--r ~-- .. ::' .i ! ! I" I! 1 I West(-)/East(+) [100ft/In] a 8500 -, , .- - .. ... . . .:.-.-:.~---L- - :;j--'-- "-=Þuf-4+-=h=t-"---1---r'':'~--::Y I l---t---+ I I ---l. I I-'----i-I ---+--+--+--1'----F.-+----f-----+--+---+---1 38500--~-L-_.:J.-_L__,~ 'w-_.L_L- i ~.~l__L~~;..I--_d'l .+1. - !--____L.:.:..::..-.:..~.: .....:.!-=-.- .---. jl._I-1:~! i .L--1----J-_J_--_..L_.-J - ='t---T-- f --l----I----i---¡-~'--r--=r=~--.t---~i'------¡--~-¡--r-¡---:-¡----- r- t-------I ,--t-----¡-----!--¡'--r'ln_-i-----t--- -r, --t.. 1:: -, , I 1 1 II! Y ¡ I ' ! II! 1 1 " 1 I 1 1 1 I ' 1 , i i ¡ ! ; .. 8600----1,--J.---î'. -t----..j---'---'r-.t I ,. - ¡----+- II! I 1 - I~- I-~I PIan#14~_20é ! ¡ ! -+-----+---1- .-1 > :1 ! : I I I ¡ I ! ¡ I ¡ I II i ! !. I. I I .. 1.1 i ¡., [ ¡ i ! I i .8650.:.L-L----+-- '--.:..1..- . - . :"'._1-n_~j_--+--.:.- . . I ._~.:' . ~_I . '. ... . I !. ..,... . . . I.' . í '. .. I I 8 . ._1 . 19 -...L---l-! - -L.--L_! ë ~_.+---t-- -l .-¡-.=b--I-. --- '-l---.t---i==t-,--+----,--t--+ I I--t-------t---~----I--'--+-P-:- I ~----i~-t- ~~---.---¡---+-__-t-_nr---~ .. 8700--::J....t~.~::i~~-=:r~~.~t==~-+->-=f~-=:-~t~--::!...=k--~.~~d 4 -~.=~~ ~~~*-$~~=i=--=-+.i . n --~---~~~~ d:~t -=~~4-~~ ............-- - ti~:~h~=~~f.=-+'-~~~-1~~_:nj=~--j.:_-=-~~. ' I 1 I! ,- -- -, .\ - -I J ! , ¡ I ! + I " I I ! I I I I I K 20 (K 20A») Ii' : I ¡ : 8750-i------+-- --- . ~. 2 ---.L~i~- K-20 (K-20PB1d---+ +- I I. I-~ I I I. I I - .t-':-- ,. -+-------+-----+----+-~---; : I ¡ 1(20 (;20)1 1 TIP .L ! ¡ ii' 1 i ,.!. I. I I! i I ¡ I i ¡ , I ; : 1 ! ! :~I~J:~rrrrOP¡...t-r~'!~1-::J....t:t1~~.--tt-rJ~~:t-~::t-~~=l~m.~rt=tt.i~Lt~I.r:f ...,.... .. .1900-1850-1800-1750-1700-1650-1600-1550-1500-1450-1400-1350-13OO-1250-1200-1150-1100-1050-1ÒOO -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 .350 -3bo -250 -200 -150 -100 -50 0 50 Vertical Section at 71.00. [50ft/In] l- 11/19/2002 -10:33 AM- ~ ~ ObP ) ) Bil8 8AKI8 ....... IN'TEQ BP Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Prudhoe Bay Site: PB K Pad Well: K-20 Wellpath: Plan#14 K-20B Date: 11/19/2002 Time: 10:33:27 Co-ordinate(NE) Reference: Well: K~20. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.00E.71.ooAzi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: -'------ ---- Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5973161.33 ft 670342.10 ft Latitude: Longitude: North Reference: Grid Convergence: 70 19 57.435 N 148 37 5.245 W True 1.30 deg Well: K-20 K-20 Well Position: Slot Name: 20 +N/-S 2004.90 ft Northing: 5975192.46 ft +EI-W 1184.03 ft Easting: 671480.21 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 20 17.152 N 148 36 30.663 W Wellpath: Plan#14 K-20B 500292255502 Current Datum: K-20A Magnetic Data: 11/19/2002 Field Strength: 57542 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 K-20A 11470.15 ft Mean Sea Level 26.10 deg 80.85 deg Direction deg 71.00 Height 52.13 ft Targets Map Map <- Latitude --:> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft K-20B Polygon13.1 0.00 -4818.09 -85.42 5970374.00 671505.00 70 19 29.767 N 148 36 33.156 W .Polygon 1 0.00 -4818.09 -85.42 5970374.00 671505.00 70 19 29.767 N 148 36 33.156 W -Polygon 2 0.00 -4814.59 198.75 5970383.99 671789.00 70 19 29.801 N 148 3624.861 W -Polygon 3 0.00 -4578.87 564.26 5970628.00 672149.00 70 19 32.119 N 148 36 14.192 W -Polygon 4 0.00 -4358.45 1423.59 5970867.99 673003.00 70 19 34.286 N 148 35 49.108 W .Polygon 5 0.00 -3883.75 1050.32 5971334.00 672619.00 70 19 38.955 N 148 36 0.002 W .Polygon 6 0.00 -4212.16 538.64 5970994.00 672115.00 70 19 35.726 N 148 36 14.939 W .Polygon 7 0.00 -4570.24 12.28 5970624.00 671597.00 70 19 32.204 N 148 36 30.304 W K-20B T13.2 8665.00 -4206.42 1161.98 5971014.00 672738.00 70 19 35.782 N 148 35 56.744 W K-20B T13.1 8695.00 -4455.70 646.11 5970753.00 672228.00 70 19 33.331 N 148 36 11.803 W Annotation MD TVD ft ft 11470.15 8737.84 TIP 11500.00 8736.96 KOP 11520.00 8736.16 1 11570.00 8731.69 2 11665.00 8723.11 3 ,11740.00 8719.45 4 12040.00 8705.88 5 12290.00 8696.55 6 12540.00 8684.56 7 12790.00 8670.27 8 12900.00 8664.62 TO ObP ) BP ) III.. .... Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 11/19/2002 Time: 10:33:27 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVO) Reference: System: Mean Sea Level Well: K-20 Section (VS) Reference: Well (O.OON,O.OOE, 71.ooAzi) Well path: Plan#14 K-20B Survey Calculation Method: Minimum Curvature Db: Oracle 1------- -.--.-.---- Plan: Plan #14 Date Composed: 11/8/2002 Identical to Lamar's Plan #13 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information ----- MD loci Azim TVD +N/-S +E/-W DLS Build Tum TFO Target ft deg deg ft ft ft deg/10Oft deg/100ft deg/10Oft deg --.-.--- ,11470.15 91.70 146.56 8737.84 -4662.97 -84.36 0.00 0.00 0.00 0.00 11500.00 91.66 141.96 8736.96 -4687.18 -66.94 15.40 -0.13 -15.41 269.57 11520.00 92.93 140.69 8736.16 -4702.78 -54.45 9.00 6.36 -6.37 315.00 11570.00 97.27 123.66 8731.69 -4736.10 -17.71 35.00 8.67 -34.05 285.00 11665.00 92.81 90.57 8723.11 -4763.46 71.47 35.00 -4.70 -34.83 264.00 11740.00 92.77 81.56 8719.45 -4758.33 146.13 12.00 -0.05 -12.01 270.00 12040.00 92.24 45.53 8705.88 -4626.98 410.02 12.00 -0.18 -12.01 270.00 12290.00 91.94 75.55 8696.55 -4505.51 625.06 12.00 -0.12 12.01 90.00 12540.00 93.43 45.55 8684.56 -4384.16 840.04 12.00 0.60 -12.00 273.50 12790.00 92.97 75.59 8670.27 -4262.94 1054.95 12.00 -0.18 12.02 90.00 ¡ 12900.00 92.89 62.38 8664.62 -4223.63 1157.27 12.00 -0.07 -12.02 270.00 Survey MD Incl Azim SSTVD NIS E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 11470.15 91.70 146.56 8737.84 -4662.97 -84.36 5970529.09 671502.51 -1597.88 0.00 0.00 TIP 11475.00 91.69 145.81 8737.70 -4667.00 -81.67 5970525.13 671505.30 -1596.64 15.40 269.57 MWD 11500.00 91.66 141.96 8736.96 -4687.18 -66.94 5970505.29 671520.48 -1589.29 15.40 269.55 KOP 11520.00 92.93 140.69 8736.16 -4702.78 -54.45 5970489.98 671533.32 -1582.56 9.00 315.00 1 ~Q~J 11525.00 93.38 138.99 8735.89 -4706.60 -51.23 5970486.24 671536.62 -1580.76 ~5.00 285.00 MWD 11550.00 95.59 130.50 8733.93 -4724.13 -33.55 5970469.12 671554.70 -1569.75 35.00 284.91 MWD J;it 11570.00 97.27 123.66 8731.69 -4736.10 -17.71 5970457.51 671570.81 -1558.67 35.00 284.24 2 'tv(YI 11575.00 97.08 121.91 8731.06 -4738.79 -13.54 5970454.92 671575.05 -1555.60 35.00 264.00 MWD 11600.00 96.06 113.16 8728.20 -4750.25 8.47 5970443.96 671597.30 -1538.53 35.00 263.78 MWD 11625.00 94.89 104.45 8725.81 -4758.27 32.00 5970436.49 671621.01 -1518.88 35.00 262.78 MWD 11650.00 93.61 95.77 8723.95 -4762.63 56.52 5970432.68 671645.62 -1497.12 35.00 261.95 MWD 11665.00 92.81 90.57 8723.11 -4763.46 71.47 5970432.20 671660.59 -1483.26 35.00 261.30 3 11675.00 92.81 89.37 8722.62 -4763.46 81.46 5970432.43 671670.57 -1473.81 12.00 270.00 MWD 11700.00 92.80 86.37 8721.40 -4762.53 106.41 5970433.93 671695.49 -1449.92 12.00 269.94 MWD 11725.00 92.78 83.36 8720.18 -4760.29 131.27 5970436.73 671720.30 -1425.68 12.00 269.79 MWD 11740.00 92.77 81.56 8719.45 -4758.33 146.13 5970439.04 671735.10 -1410.99 12.00 269.65 4 11750.00 92.77 80.36 8718.97 -4756.76 155.99 5970440.83 671744.93 -1401.16 12.00 270.00 MWD 11775.00 92.76 77.35 8717.76 -4751.93 180.49 5970446.22 671769.31 -1376.42 12.00 269.94 MWD 11800.00 92.75 74.35 8716.56 -4745.83 204.70 5970452.87 671793.37 -1351.54 12.00 269.80 MWD 11825.00 92.73 71.35 8715.37 -4738.46 228.56 5970460.78 671817.05 -1326.59 12.00 269.65 MWD 11850.00 92.70 68.34 8714.18 -4729.86 252.00 5970469.91 671840.29 -1301.62 12.00 269.51 MWD 11875.00 92.66 65.34 8713.01 -4720.04 274.96 5970480.26 671863.01 -1276.72 12.00 269.37 MWD 11900.00 92.62 62.34 8711.86 -4709.03 297.37 5970491.77 671885.17 -1251.94 12.00 269.23 MWD 11925.00 92.57 59.34 8710.73 -4696.86 319.17 5970504.44 671906.69 -1227.36 12.00 269.09 MWD 11950.00 92.51 56.33 8709.62 -4683.57 340.31 5970518.21 671927.52 -1203.05 12.00 268.95 MWD 11975.00 92.44 53.33 8708.54 -4669.19 360.73 5970533.06 671947.60 -1179.06 12.00 268.82 MWD 12000.00 92.37 50.33 8707.50 -4653.75 380.36 5970548.94 671966.87 -1155.47 12.00 268.69 MWD 12025.00 92.29 47.33 8706.48 -4637.31 399.17 5970565.80 671985.29 -1132.34 12.00 268.56 MWD 12040.00 92.24 45.53 8705.88 -4626.98 410.02 5970576.38 671995.91 -1118.71 12.00 268.44 5 12050.00 92.24 46.73 8705.49 -4620.05 417.23 5970583.46 672002.95 -1109.65 12.00 90.00 MWD 12075.00 92.24 49.73 8704.52 -4603.41 435.86 5970600.52 672021.19 -1086.62 12.00 90.05 MWD 12100.00 92.22 52.73 8703.54 -4587.77 455.33 5970616.61 672040.31 -1063.11 12.00 90.16 MWD 12125.00 92.21 55.74 8702.58 -4573.18 475.60 5970631.66 672060.23 -1039.19 12.00 90.28 MWD 12150.00 92.18 58.74 8701.62 -4559.66 496.60 5970645.66 672080.92 -1014.93 12.00 90.40 MWD 12175.00 92.15 61.74 8700.67 -4547.26 518.29 5970658.55 672102.32 -990.39 12.00 90.51 MWD 12200.00 92.12 64.74 8699.74 -4536.01 540.59 5970670.30 672124.36 -965.64 12.00 90.63 MWD ') BP ) iii.. ObP / .... Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 11/1912002 Time: 10:33:27 Page: 3 Field: Prudhoe Bay C(H)rdinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (fVD) Reference: System: Mean Sea Level Well: K-20 Section (VS) Reference: Well (O.OON,O.OOE, 71.ooAzi) Wellpath: Plan#14 K-20B Survey Cakulation Method: Minimum Curvature Db: Oracle Survey r-- Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool I MD ft deg deg ft ft ft ft ft ft deg/100ft deg -------- 12225.00 92.08 67.74 8698.83 -4525.95 563.46 5970680.89 672146.98 -940.75 12.00 90.74 MWD 12250.00 92.03 70.74 8697.93 -4517.09 586.82 5970690.27 672170.13 -915.78 12.00 90.85 MWD 12275.00 91.98 73.75 8697.06 -4509.48 610.61 5970698.43 672193.74 -890.80 12.00 90.95 MWD 12290.00 91.94 75.55 8696.55 -4505.51 625.06 5970702.73 672208.10 -875.84 12.00 91.06 6 12300.00 92.01 74.35 8696.20 -4502.91 634.71 5970705.54 672217.69 -865.87 12.00 273.50 MWD 12325.00 92.19 71.35 8695.28 -4495.54 658.58 5970713.45 672241.38 -840.90 12.00 273.46 MWD 12350.00 92.36 68.35 8694.29 -4486.94 682.03 5970722.59 672264.63 -815.93 12.00 273.35 MWD 12375.00 92.53 65.36 8693.22 -4477.12 705.00 5970732.93 672287.36 -791.02 12.00 273.23 MWD 12400.00 92.69 62.36 8692.08 -4466.12 727.41 5970744.44 672309.52 -766.24 12.00 273.10 MWD 12425.00 92.84 59.36 8690.88 -4453.96 749.22 5970757.09 672331.04 -741.67 12.00 272.96 MWD 12450.00 92.98 56.36 8689.61 -4440.68 770.36 5970770.85 672351.87 -717.35 12.00 272.82 MWD 12475.00 93.12 53.36 8688.28 -4426.31 790.77 5970785.69 672371.94 -693.38 12.00 272.67 MWD 12500.00 93.25 50.35 8686.89 -4410.90 810.40 5970801.54 672391.21 -669.80 12.00 272.51 MWD 12525.00 93.36 47.35 8685.45 -4394.48 829.19 5970818.39 672409.62 -646.69 12.00 272.34 MWD 12540.00 93.43 45.55 8684.56 -4384.16 840.04 5970828.95 672420.24 -633.07 12.00 272.17 7 12550.00 93.43 46.75 8683.96 -4377.24 847.24 5970836.03 672427.27 -624.01 12.00 90.00 MWD 12575.00 93.42 49.76 8682.46 -4360.63 865.86 5970853.06 672445.50 -601.00 12.00 90.07 MWD 12600.00 93.40 52.76 8680.98 -4345.01 885.32 5970869.12 672464.60 -577.51 12.00 90.25 MWD 12625.00 93.38 55.77 8679.50 -4330.44 905.58 5970884.15 672484.52 -553.61 12.00 90.43 MWD 12650.00 93.34 58.77 8678.03 -4316.95 926.57 5970898.12 672505.20 -529.37 12.00 90.61 MWD 12675.00 93.29 61.78 8676.59 -4304.57 948.24 5970910.98 672526.58 -504.85 12.00 90.78 MWD 12700.00 93.24 64.78 8675.16 -4293.35 970.53 5970922.71 672548.60 -480.12 12.00 90.96 MWD 12725.00 93.18 67.78 8673.76 -4283.31 993.38 5970933.27 672571.22 -455.25 12.00 91.13 MWD 12750.00 93.10 70.79 8672.39 -4274.49 1016.73 5970942.63 672594.35 -430.30 12.00 91.30 MWD 12775.00 93.02 73.79 8671.06 -4266.89 1040.51 5970950.76 672617.95 -405.35 12.00 91.46 MWD 12790.00 92.97 75.59 8670.27 -4262.94 1054.95 5970955.05 672632.30 -390.40 12.00 91.62 8 12800.00 92.97 74.39 8669.75 -4260.35 1064.60 5970957.85 672641.89 -380.44 12.00 270.00 MWD 12825.00 92.96 71.39 8668.46 -4253.01 1088.46 5970965.74 672665.57 -355.49 12.00 269.94 MWD 12850.00 92.95 68.38 8667.17 -4244.42 1111.90 5970974.86 672688.81 -330.53. 12.00 269.78 MWD 12875.00 92.92 65.38 8665.89 -4234.62 1134.86 5970985.18 672711.54 -305.63 12.00 269.63 MWD 12900.00 92.89 62.38 8664.62 -4223.63 1157.27 5970996.68 672733.69 -280.85 12.00 269.47 TD t 5~ 1'~$ óqf TOLERABLE COLLISION RISK WORKSHEET I~:. Tolerable Collision Risk Worksheet Rev. 6 - 14 Mar 97 Standard Operating PrO<.. ).. Anti-Collision Management Use this sheet to describe a well interference scenario where QRA may be applicable. Check first that the scenario really is different from those described on existing worksheets. Ref. BPX Anti-Collision Recommended Practices Prepared by: L ð. ""° r c; 4 '" ++ Authorised by: ~"--~ ~ ) Page 21 of 12 Generic name of scenario: (for input on DE:AP) 1< - 20 13 (Be specifIC. Include all factors which affect either the cost of collision or the cost of reducing the risk) IhL Pf"')fO:><¡J.. ""ft) oç l"Z.tt/)ò ì ~ +~ ¡<-2-D! i5 w ¡.It-\!, i\ toD ft ~".I t;c,\ t1t II Y "" ~ t{, f.r . .TV b ~f th~ d,lDttk.tD-\ €,J. I(-If. ()..Id/hove, I . I . ~t~+".1ttlf~('-~('y +1..e.- {~~/" .í~ l°e-.a.tU ft\ ~ 0" c , A- a ~J: «. '2. þ '"8 (» i II be 0'\ t-D1\t.. 173 t Description no , Ust all the consequences of collision and the necessary remedial action /s~ Use Conventional ~leris~aJ~. rule - Major 7~ C ot\'5e1 v..e I\~ 6.ç Co H (~ìc.1\ ~ f(\¡t\0í"~' ~~e k.~o ð l~;1\ b~ How could the probability of collision or the severity of the consequences be reduced ? How might this impact the drilling operation? ~ Estimate the total .c- cost of substantially V = , reducing the risk Given the uncertainty In the above estimates, by how many times must the savings made from not reducing the risk outweigh the risk itself ? (guideline = 20) M= .... F=~= M Tbte~~. ~ Estimate the total cost of collision C = J 60 tI\~ Estimate the NPV of the planned well V= 1.)/Y\(nß + Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you prepared to , tolerate (guideUne = 0.05) F = IDS- Tolerable Collision Risk = VF = C 15öo(.ð5) =_1C -, 00 VF ~ c > 1 : close approach tolerances need not be set VF < 1 .. Tolerable 1 Ie 1 i I 3 Collision Risk = n - = n J . C VF Control Tier: 3 - ADW Revision Date: 08110198 Document Number: UPS-US-AK-ADW-ALL-HSE-D0C-00038-3 Print Date: 02/12/02 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLlED VERSION OF THIS DOCUMENT C~ BE FOUND AT þttp://alaska.boweb.bo.comIems ) Nordic CTD BOP Detail/' o~ -- CT Injector Head I 1 -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure /UI , I ~ f Methanol Injection ~ I Otis 7" WLA Quick I Connect - . I 7-1/16" 10,5000 pSI working pressure i- Ram Type Dual Gate BOPE - 7" Riser I I I I "\ Annular BOP (Hydril),7-1/16" 10 ~ 5000 psi working pressure Manual over Hydraulic \.. ~ I I I I TOT ~ 'CJ=t r Blind/Shear I" rc= ~o 2 318 .. Combi PipelSli~ ,,/ Fire resistant Kelly Hose to HCR ~. I Flange by Ham~er up 1/4 Tur~ -@- Kill line check valve Valve on DS Hardlme to StandpipE l 0 _rn }IßmfBj II -¥AÒ-: / manifold I l 7-1/16" 10, 5000 psi working pressure ~ 2"Sídeoutlets F = I 2 3/8" X 3 1/2" VBRs Ram Type Dual Gate BOPE I TOT II:: ~= I ' ~ ~ 23/8" Combi Pipe/Slip Manual over Hydraulic c:: I I I I XO Spool as necessary \ / 2 flanged gate valves I I @ , I @) I I II THA I L ~-_fÕì_- ~ Inner Annulus Tubing ~ r Spool ~ I I -@ - ~ Outer Annulus Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I~-' 1/" Full production christmas tree MOJ 9/15/02 H 207131 DATE INVOICE I CREDIT MEMO ~" 9/20/02 INV# CK091602C I j' ... ...¡.. .". ~ <"."""."T) r"-." _.. '¡ r' \ ,~~_l..,/ """~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ B.. P...... t';.' fI"" "HIi 1".111, . "" . ""'1 .,,¡,... f f ) t .I L" '..., ,. to -- .:A.., t, 'nßi qH~ 'P!;'1 TO THE ALASKA OIL & GAS CONSERVATION COMMISSIÒN ORDER 333 W. 7th AVE. STE. 100 OF ANCHORAGE, AK 99501 DATE '9/20/02 CHECK NO: H207131 GROSS VENDOR DISCOUNT NET H RECE1VED NOv 2.2, 2002 A1aska OU& Gas Cons. commission " ,... Anchorage FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 207131 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ---¡:j2 DATE SEPT. 20, 2002 AMOUNT ****$100.00**** II' 2 0 7 ~ :l ~ II' I: 0... ~ 2 0 ~ B g 5 I: 0 0 a 1. 1. ~ q II' ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 1¿?fK-2ðE PTD# 2o::J - 2-7 ¿.! CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE " The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuânce of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ß/' X WELL NAMEI".ð'0 k-20! PROGRAM: Exp - Dev ~ Redrll Á Re-Enter - Serv - We II bore seg- FIELD & POOL Cc.¡¿;,/.5t::> INITCLASS lJ~v /'-0/1 GEOLAREA 971""\ UNIT# /JC<')A ON/OFFSHORE~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . I Y . N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. .. . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N /j/ . / 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ,,,(/9 ~,,¿. 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . .. . . . . Y N 11. Permit can be issued without conservation order. . . . . . .. . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N 11 (Service Well Only) 13. Well located wlin area & strata authorized by injection .order #~. '! )(. IV, n ... (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . ., ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . .. . . . . . . . . 1:) N 16. Surface casing protects all known USDWs. . . . . . . . . . . ($, N . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . '¥-N- /'JIlt- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ 19. CMT will cover all know. n productive horizons. . . . . . . . . . æ,NfN 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N CT t) tÁ.. 22. If a re-drill, has a 10-403 for abandonment been approved. .. i- h N ~ pw;; 4?s.~ . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . c¿ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥:.:::-N"""?í[Æ-, ¡/JA J D 25. Drilling fluid program schematic & equip list adequate. . . . . N ~ ,,~(; 1, ç I;JF~ ' 26. BOPEs, do they meet regulation. . . . '.' . . . . . . . . . . N. . .' I APPR DATE 27. BOPE press rating appropriate; test to 3£" 00 psig. N ms (? '2- é./ ~ I p!-t . A~ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \}J~~ it 11..s[ 02. 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . . N fO.~ r ~ . 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N N./r YLM R N./1, APPR DATE (Service Well Only) GEOLOGY APPR DATE Æ tJ&~~ (ExPlorafu; Only) , )' 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMI~IONER: Comments/Instructions: RPrIf¡7¿ TEM JDH JBR COT (IU/o)- DTS ./ MJW MLB "'/ ¿¿,/ç¿ SFD- WGA Rev: 10/15/02 G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special' effort has been made to chronologically . . organize this category of information. ) '\ ~09~~LI / /foC¡~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 08 09:23:01 2003 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 0 8 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . .'. . . . . . . 03/ 04/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA K-20B 500292255502 BP Exploration Sperry Sun 08-APR-03 (Alaska) Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22192 M. ALLEN EGBEJIMBA MWDRUN 2 AK-MW-22192 M. ALLEN SARBER MWDRUN 3 AK-MW-22192 M. ALLEN SARBER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 4 11N 14E 3251 4070 MSL 0) 52.13 .00 .00 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 11501.0 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ) ') 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. WELL KICKED OFF FROM K-20A WITH TOP OF WHIPSTOCK SET AT ABOUT 11501' MD / 8737' TVDSS. 4. MWD RUNS 1 - 3 WERE DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. DIGITAL DATA ONLY WAS DEPTH SHIFTED TO THE SCHLUMBERGER MEMORY CNL OF 08-DEC-2002, PER THE 07-APR-2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 3 REPRESENT WELL K-20B WITH API # 50-029-22555-02.. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13004' MD / 8655' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) $ File Header Service name............ .STSLIB.OOl Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11031.0 11523.5 STOP DEPTH 12977.5 13005.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 11031.0 11038.0 11046.5 11054.5 11059.0 11064.0 11067.5 11075.5 11077.5 11088.5 11507.5 DEPTH GR 11031.5 11038.5 11047.5 11055.5 11059.5 11064.0 11066.5 11076.0 11078.0 11089.5 11500.0 ) ) 11521.0 11513.5 11538.0 11529.5 11558.5 11551.0 11581.5 11573.0 11591.0 11581.0 11614.5 11604.5 11639.0 11628.0 11685.5 11680.0 11705.5 11699.5 11788.0 11781.5 11804.5 11797.5 11809.0 11802.0 11812.5 11804.5 11823.0 11814.0 11850.0 11842.5 11876.0 11866.5 11883.5 11874.0 11889.5 11880.5 11892.0 11883.0 11899.5 11890.0 11919.0 11909.5 11926.0 11916.0 11930.5 11921.0 11953.5 11943.5 11966.5 11957.5 11987.0 11980.5 11997.5 11989.5 12006.5 11994.0 12040.5 12029.5 12055.5 12041.0 12068.0 12055.0 12075.0 12061.5 12096.0 12081.0 12222.5 12210.5 12240.0 12229.5 12262.0 12254.5 12273.0 12266.0 12283.0 12275.5 12302.0 12299.0 12318.0 12314.5 12332.5 12330.5 12358.0 12355.0 12369.5 12364.5 12377.0 12369.5 12423.5 12417.0 12432.0 12425.0 12445.5 12439.0 12464.5 12458.5 12480.5 12474.5 12496.5 12493.5 12505.5 12502.0 12509.0 12504.5 12515.0 12510.0 12519.0 12513.5 12523.0 12516.0 12530.0 12522.5 12563.0 12556.5 12656.0 12653.5 12667.0 12664.0 12688.5 12685.0 12721.0 12717.0 12729.5 12726.5 12773.5 12770.0 12777.0 12773.5 .'J ) 12814.0 12823.5 12839.5 12855.0 12864.5 12926.5 13005.5 $ 12810.0 12817.5 12834.0 12850.5 12860.0 12925.0 13004.0 # MERGED PEU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 11031.5 2 11660.5 3 11990.5 MERGE BASE 11689.0 12018.0 13004.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value....... .............. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11031 13005.5 12018.3 3950 11031 13005.5 ROP MWD FT/H 0.1 2289.52 81.5358 2965 11523.5 13005.5 GR MWD API 27.14 236.88 73.5471 3100 11031 12977.5 First Reading For Entire File........ ..11031 Last Reading For Entire File......... ..13005.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation. ..... .03/04/08 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name...... ...... .STSLIB.002 ') Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..03/04/08 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 11031.5 11516.0 STOP DEPTH 11660.0 11689.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 04-DEC-02 Insite 4.3 Memory 11688.0 11031.0 11688.0 89.6 96.1 TOOL NUMBER 82758 3.750 11501.0 Flo Pro 8.60 65.0 9.5 22000 .0 .000 .000 .000 .000 .0 141.5 .0 .0 ') ) # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11031.5 11689 11360.3 1316 11031.5 11689 ROP MWD010 FT/H 0.1 202.72 36.8396 347 11516 11689 GR MWD010 API 32.95 186.79 78.1116 480 11031.5 11660 First Reading For Entire File........ ..11031.5 Last Reading For Entire File......... ..11689 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name...... ...... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 2 .5000 ') FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 11660.5 11689.5 STOP DEPTH 11990.0 12018.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing............... .... ..60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 05-DEC-02 Insite 4.3 Memory 12018.0 11688.0 12018.0 90.8 97.3 TOOL NUMBER 82758 3.750 11501.0 Flo Pro 8.60 65.0 9.5 22000 .0 .000 .000 .000 .000 .0 145.0 .0 .0 ) ) ? Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11660.5 12018 11839.3 716 11660.5 12018 ROP MWD020 FT/H 4.55 624.67 56.2705 658 11689.5 12018 GR MWD020 API 56.28 151.39 89.7621 660 11660.5 11990 First Reading For Entire File........ ..11660.5 Last Reading For Entire File......... ..12018 File Trailer Service name............ .STSLIB.003 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type......... ...... .LO Next File Name.... ...... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 11990.5 12018.5 STOP DEPTH 12976.0 13004.0 # 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): 07-DEC-02 Insite 4.3 Memory 13004.0 12018.0 13004.0 ) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point.... ..... ... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 89.3 97.3 TOOL NUMBER 74165 3.750 11501.0 Flo Pro 8.70 65.0 9.0 22000 1.0 .000 .000 .000 .000 .0 159.1 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11990.5 13004 12497.3 2028 11990.5 13004 ROP MWD030 FT/H 0.56 2289.52 98.7414 1972 12018.5 13004 GR MWD030 API 27.14 236.88 66.8763 1972 11990.5 12976 ) ) First Reading For Entire File........ ..11990.5 Last Reading For Entire File......... ..13004 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/08 Maximum Physical Record. .65535 File Type......... """ .LO Next File Name. .... .,... .STSLIB.005 Physical EOF Tape Trailer Service name...... ...... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.... ...... . UNKNOWN Comments....... .... ..... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name...... ...... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File