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Home My WebLink About202-253STATE OF ALASKA ~_ ALAS~IL AND GAS CONSERVATION CO WELL COMPLETION OR RECOMPLETION REPORT 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Clas~nChOf~@ ®Development Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab g 4/29/2008 D 12. Permit to Drill Number 202-253 ~ 308-142 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 03/21/2003 13. API Number 50-029-21023-02-00 4a. Location of Well (Governmental Section): Surface: 19 2' FNL 118 ' FW 7. Date T.D. Reached 03/29/2003 14. Well Name and Number: PBU K-04B - 4 , 5 L, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 1849' FNL, 1726' FWL, SEC. 04, T11 N, R14E, UM 8. KB (ft above MSL): 52.59' ' Ground (ft MSL): 24.06' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2894' FNL, 1121' FWL, SEC. 04, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 10927' 8910' P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 671453 y- 5975278 Zone- ASP4 10. Total Depth (MD+TVD) 11012' - 8919' - 16. Property Designation: ADL 028303 TPI: x- 671991 y_ 5975384 Zone- ASP4 Total Depth: x- 671414 y- 5974325 Zone- ASP4 11. SSSV Depth (MD+TVD} N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic an 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, RES, PWD, DEN, NEU, ABI 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" x 30" Insulated onduc r urface 110' Surface 110' 36" 8 u ds Concrete 13-3/8" 72# L-80 39' 2691' 39' 2691' 17-1 /2" 3746 cu ft Permafrost 9-5/8" 47# L-80 36' 7217' 36' 7216' 12-1/4" 1822 cu ft Class'G' 132 cu ft PF'C' 7" 26# L-80 7056' 705 ' 8319' 8-1/2" 292 cu ft Class'G' 4-1/2" 12.6# L-80 8184' 11012' 8154' 8919' 6-1/8" 399 cu ft Class'G' 421 cu ft'G' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): .SIZE DEPTH SET MD PACKER .SET MD 4-1/2", 12.6#, L-80 8194' 8137' MD TVD MD TVD " 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ ' ~o+'~NNE®JUN ~ ~ 2008 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10400' - 10927' Ran SELRT Test Liner 9900' Cement Lower Perfs w/ 5.4 BBIs Class'G' 9611' 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 uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250_.071. i ~~ E t-~itl 4 None ( ?.~,d~~ ~ o~ AND LOG RECEIVE MAY 2 3 2008 Alaska Oil ~ Gas Cons. Commi ' n Form 10-407 Revised 02/2007 ONTINUED ON REVERSE SIDE ~~~ ~~~' ,iLif~l ~ 4S 1OQB ~(~ X5-056 ORIGINAL. 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RiceRS 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. Sag River 8363' 8324' None Shublik 8414' 8372' Sadlerochit 8470' 8425' CGL 8572' 8520' 23SB 8670' 8608' 22TS 8728' 8656' 21 TS 8786' 8700' Zone 1 B 8889' 8763' TDF 8948' 8791' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~~~ Signed Terrie Hubble Title Drilling Technologist Date 2 PBU K-04B 202-253 308-142 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A r val No. onuing Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNew-~: 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). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only Digital Well File • Page 1 of 1 • Well: K-04 Well History Well Date Summary K-04B 2/24/2008 T/I/0=2400/0/160 Load & Kill (WH & Tree Repair) Pumped 3 bbl neat meoh spear & 267 bbls crude down TBG. ***Casing valves open to gauges*** FWP=80/0/160 K-04B 2/24/2008 ****ACTUATOR CHANGEOUT**** T/I/O = SI/0/150 Removed McEvoy 6 x 7 actuated valve. Installed Cameron 6 x 7 actuated valve. Tested against master valve. Low pressure test to 500 psi for 5 minutes. Test passed. Tested tree to 5000 psi for 15 min. Test passed. Opened wing valve half way and tested wing valve x S-riser connection from manifold building to 900 psi. Test passed. *** Back Pressure valve is still in hole*** K-04B 2/24/2008 T=50. Set 6" CIW "J" BPV thru tree ~ 108". (SSV C/O) K-04B 2/26/2008 Pulled 6" CIW BPV #421 for SSV Swap. Tubing psi 5001b. K-04B 4/20/2008 CTU #6 w/1.75" CT. Daylight Coil. MIRU CTU, perform chain inspection, change packoffs, make up Baker MHA, pressure test surface lines to be ready in the A.M. for milling. '** Continued on 04/21/08 WSR *** K-04B 4/21/2008 CTU #6 w/1.75" CT. Daylight Coil. RIH with 3-1/8" left hand Baker MHA and 3.790" OD parabolic mill N at 8179.9' CTMD, pickup, got weight back at while killing well down backside with KCL. Dr toy X ~ 8177.5' and begin milling out the 3.725" O~nipp-"-Te.1fTa~`de a ~w passes up and down thru the nipple, made a dry pass and mill passes thru no problem. Continue RIH for dry tag. Tag hard at 9105', tried milling thru but over pulls were excessive. POOH to change BHA, mill, and add jars. Will continue in the A.M. when fluids are reloaded and we have a different BHA. Freeze protect wellbore to 2000' and roll tanks with 60/40 meth/water. *** Continued on 04/22/08 WSR *"* K-04B 4/22/2008 CTU #6 w/1.75" CT. Daylight coil. *** Interact Not publishing *** MU 2-1 /8" Baker MHA with 2.25" OD 3 blade metal muncher and RIH for drift. Drifted to 10. 741' CTMD with no oroblem. POOH with motor and mill. postpone caliper until A.M. *** Continued on 04/23/08 WSR *** K-046 4/23/2008 CTU #6 Caliper log. M/U PDS calioer tools.Log from 10700` to 8000` RIH w/ 3.80 D331 mill & 3.80 stream reamer. """""'Job in progress"""""" K-04B 4/24/2008. CTU #6 Mill obstruction ~ 9090 RIH w/ motor jars D313 mill 3.80 & stream reamer 3.80" Milled thru _.., . obstruction from 9089` to 9108` back ream thru four times until glean. Drift"tftir"u ry. ay o pro rom PBTD TD 8000` Bad spot is from 9089` to 9100` Mill & stream reamer are in gauge 3.79" """""Job complete""""" K-04B 4/25/2008 T/I/O =SSV/vac/120. Temp = SI. OA FL (pre MITOA, CTD). OA FL near surface. OA will need 3" integral flange. K-046 4/25/2008 T/I/0=0/0/0, Temp=Sl. PPPOT-T(PASS), PPPOT-IC (PASS). Pre CTD. PPPOT-T: Opened bleeder screw to verify 0 psi in test void. Removed internal check and installed external Alemite check. Pumped through void until clean fluid returns were achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Functioned LDS, all moved freely. PPPOT-IC: Opened bleeder screw to verify 0 psi in test void. Removed internal check and installed external Alemite check. Pumped through void until clean fluid returns were achieved. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Functioned LDS, all moved freely. K-046 4/26/2008 T/I/0=0/0/0; Set 6-3/8" CIW "J" BPV #403 thru tree for Nordic 1 Pre-rig; 1-2' ext. used, tagged ~ 108'; ***Complete*'~*~(May/Williams) K-04C 4/27/2008 T/I/0=0/0/0; Pulled 6-3/8" CIW "J" BPV thru stack for Nordic 1; 4-5' ext. used, tagged ~ 96" ***Complete'** (Bes ort am Print Date: 5/22/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 5/22/2008 • • BP EXPLORATION Page 1 of 20 Operations Summary Report Legal Well Name: K-04 Common Well Name: K-04 Spud Date: 10/21/1983 Event Name: REENTER+COMPLETE Start: 4/26/2008 End: 5/16/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/16/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/26/2008 12:00 - 18:00 6.00 MOB P PRE Attempt to repair move system. Isolate one drive motor. 18:00 - 00:00 6.00 MOB P PRE Move rig form DS 7 to K pad. 4/27/2008 00:00 - 05:30 5.50 MOB P PRE Continue move to K-04. Had some diffficulty climbing grade at Oxbow and West dock Rd. Spot over well at 0530. Accept rig 05:30 - 10:00 10:00 - 12:00 12:00 - 16:00 16:00 - 17:00 17:00 - 17:15 17:15 - 18:00 18:00 - 19:00 19:00 - 21:30 4.50 BOPSU P 2.00 BOPSU P 4.00 BOPSU P 1.00 BOPSU P 0.25 BOPSU P 0.75 BOPSU P 1.00 BOPSU P 2.50 RIGU P 21:30 - 22:00 0.50 -RIGU P 22:00 - 00:00 2.00 CASE P 4/28/2008 00:00 - 01:00 1.00 CASE P 01:00 - 02:45 1.75 CASE P PRE NU riser, BOP and lubricator. PRE Draw down test. Test BOP. Replace door seal O Rings. PRE .Test BOP. Test witnessed b Chuck Sheve of AOGCC. PRE Clear floor and load pipe shed with liner. PRE Well on vac thru BPV. Circulate across top. PRE t r nd ull BPV. LD lubricator and clear floor. PRE Circualte across top of well. RUNPRD MU CTC, fill coil, test CTC, test inner reel valve. Strap and drift liner and PH6 RUNPRD PJSM for liner RUNPRD PU liner and equipment. RUNPRD Continue PU liner and PH-6 RUNPRD Tag bottom at 10744' down 38300 up wieght at 10738' Re-tap to confirm numbers and pull up to 10724.5' for ball 02:45 - 04:45 I 2.001 CASE I P RUNPRD 2360 psi RIH to 10744', 10K WOB at 13690# indicated At 42 Bbls away drop rate to 0.9 BPM ~ 400 psi (wt. indicator at 15700#) Calculated 57.5 Bbls. to get ball on seat. 72 Bbls. away, surged pump and moved coil a couple of times. 80 Bbls. away, pump 6 Bbls. Bio sweep. 1.4 BPM ~ 780 psi. 146 Bbls. away, check hard line for ball. Recover? hau fr^^~ hardline. 04:45 - 07:10 2.42 CASE P RUNPRD Launch aluminum ball, confirmed ball is going around coil as we can hear the aluminum one. 2.25 BPM ~ 2300 psi 42 Bbls away drop rate to .9 BPM ~ 300 psi 60 Bbls away, surge pump and increase rate to 1.6 bpm 80 Bbls. away, check hardline again. No sign of the ball. Resume pumping, surging. YO-YO liner 100'. Pump 5 bbl hi vis sweep. displace one coil volume. 07:10 - 07:14 0.07 CASE N RUNPRD POH cir at 2 .5 bpm 212 psi.At 10200 saw pressure up to 480 pssi. 07:14 - 07:22 0.13 CASE N RUNPRD RIH back to bottom.10747. PU wt = 38K w/o pump. 07:22 - 07:30 0.13 CASE P RUNPRD Pressure to 3900 psi to shear seat._SD pump. PU wt=38K No 07:30 - 07:45 0.25 CASE P RUNPRD PJSM for cementing 07:45 - 09:05 1.33 CEMT P RUNPRD Flood lines to cementers. PT to 4000 psi. Mix and pump on the fly. Call volume on In MM density. Pump 5.4 bbl 15.8 ppg .Zero in MM. Displace with 30 bbl bio and KCL. Displace to 55.8 bbls(56.75 bbl CT+1 bbl PH6 - 2bb1 side exhaust). 2bpm ~ 1520 psi. PU wt 39K.to 10727.to open exhaust ports. Pump 5 bbl 2 cement 3 bio for contamination ~ 1.5 bpm with 890 psi. Sting back in and displace 2.9 bbls to land LW P. Open choke Printed: 5/22/2008 4:24:34 PM • • BP EXPLORATION Page 2 of 20 Operations Summary Report Legal Well Name: K-04 Common Well Name: K-04 Spud Date: 10/21/1983 Event Name: REENTER+COMPLETE Start: 4/26/2008 End: 5/16/2008 Contractor Name: NORDIC CALISTA Rig Release: 5/16/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours Task Code NPT ~ Phase Description of Operations 4/28/2008 07:45 - 09:05 1.33 CEMT P RUNPRD sting in 30K Dn. Set down 8K. Close choke. Shear LWP at 2400 psi. Pump 1.3 bpm ~ 868 psi land in collar at 64.4.bbls (on calculated vol) .Bleed to check floats. Floats held. Pressure to 500 psi. &unsting. Seen pressure fall off as we unsting from liner. 09:05 - 11:00 1.92 CEMT P RUNPRD POH. Circulate at 2.5 bpm ~ 1370 psi. 11:00 - 11:45 0.75 CEMT P RUNPRD PU injector. Recover 219' of wire from 255' of PH6. Standback PH6. LD Baker running tools. 11:45 - 12:15 0.50 CLEAN P WEXIT RU to pump slack. PJSM. Pump slac 12:15 - 13:00 0.75 CLEAN P WEXIT Cut off CTC. Stab onto well. Pump slack using 130E fresh water ~ 4.1 bpm ~ 3500 psi. three cycles of pumping. 13:00 - 13:25 0.42 CLEAN P WEXIT Cut coil back to find wire. Cut 281'.= 1.93 % slack.CT 14759'. E line 15043'. 13:25 - 15:30 2.08 CLEAN P WEXIT Meggar E line OK.MU CTC, Pull test CTC to 36K.MU MHA. PT to 4000 psi. 15:30 - 15:45 0.25 CLEAN P WEXIT Jet BOP stack. 15:45 - 17:00 1.25 CLEAN P WEXIT MU BHA. 17:00 - 18:45 1.75 CLEAN P WEXIT RIH. 18:45 - 19:35 0.83 CLEAN P WEXIT 9500, increased pump rate to 2.5 BPM ~ 2230 psi, attempted to do a tie-in log from 9570 down, Gamma failed, continue with cleanouUdriff. 9900', no motor work ar tags going down, PUH at 2.6 BPM X2200 psi 19:35 - 21:15 1.67 CLEAN P WEXIT POOH circulating at 2.6 BPM 21:15 - 21:30 0.25 CLEAN P WEXIT Lay down milling BHA 21:30 - 22:15 0.75 WHIP P WEXIT Change out DGS in coiltrak assembly, PU Weatherford 22:15 - 00:00 1.75 WHIP P WEXIT RIH, EDC open, pumping .2 BPM 4/29/2008 00:00 - 00:15 0.25 WHIP P WEXIT Continue RIH with AWeatherford anchor 00:15 - 01:40 1.42 WHIP P WEXIT Log down from 9370' for gamma tie-in Correct depth to 9569' (+ 30') Log up for CCL RIH to 9636', pull up hole to 9626' setting depth to put top of whipstock at 9610' Orient to 180 fora 30 L exit, close EDC Pressured up to 2500 psi to set anchor confirmed setting by stacking 2000# down 01:00 - 02:45 1.75 WHIP P WEXIT POOH 02:45 - 04:15 1.50 WHIP P WEXIT Lay down Setting tool, Reconfigure coiltrak tools, PU Whipstock, jars and coiltrak 04:15 - 06:00 1.75 WHIP P WEXIT RIH 06:00 - 06:15 0.25 WHIP P WEXIT Tle-in from 9500' down. Correction +31'. 06:15 - 06:20 0.08 WHIP P WEXIT RIH 37k up wt. Tag at 9624'. Stack 4K. PU & shear out at 47K. Up wt 36K. 06:20 - 07:50 1.50 WHIP P WEXIT POH. 07:50 - 09:15 1.42 WHIP P WEXIT LD WS setting tool. MU window mill/string mill BHA. 09:15 - 11:30 2.25 WHIP P WEXIT RIH tag at 9584 uncorrected. c , _ ` 11: - 5: 3.50 HIP WEXIT Time mill window from 9583.7'. 2.5/ 2.57 bpm (~ 1960 psi. ~T FS=1925 psi. K.~•t1G Milled highside window to 9586'. 15:00 - 18:00 3.00 STWHIP P WEXIT Mill high side window, 2.5 bpm, 2200-2300 psi, 1 fph, 2.5K wob, Milled to 9589.2'. 18:00 - 19:30 1.50 STWHIP P WEXIT Continue milling at 1 FPH, 2.56 BPM, 2250 psi, 2-3K WOB Printed: 5/22/2008 4:24:34 PM TREE _ ~ 6" MCEV OY WELLHEAD= MCEVOY ACTUATOR OTIS KB. ELEV = 52.59' BF. ELEV = 33.41' KOP = 7296' Ivtax Angle = 99 ~ 10041° Datum MD = 10329' Datum TVD = 8800' SS DRLG DRAFT 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" III NOTES: <~~ r ~,, 2200' 1~4-1/2" HES X NIP, ID = 3.813" 2( 609' u 2~ 691' ~ -Over 3-3/'16 2-7i8 diner CHAS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3699 3699 0 MMG-M DMY RK 0 12/13/07 3 5697 5697 2 MMG-M DMY RK 0 12/13/07 2 6997 6996 1 MMG-M DMY RK 0 04/04/03 1 8048 8026 19 KBG-2 DMY RK 0 04/04/03 7056' I-I 9-5/8" X 7" BKR ZXP LNR TOP PKR 9-5/8" CSG, 47#, L-80, ID = 8.681 " 8346' 7" LNR, 26#, L-80, .0383 bpf, 8097-8993, ID = 6.276" MILLOUT WINDOW 7217' - 724$' 8116' I-I 4-1/2" HES X NIP, ID = 3.813" 8137' I~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8161' -j 4-1/2" HES X NIP, ID = 3.813" 8181' 4-1/2" HES XN NIP, ID milled to = 3.80" 8184' 7" X 5" BKR ZXP LNR TOP PKR 8194' 4-1/2" WLEG, ID = 3.958" 4-1/2" TBG, 12.6", L-80, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 8193' I 8358' PERFORATION SUMMARY REF LOG: MWD ON 05112.108 ANGLE AT TOP PERF: 98 c~ 10000' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10040 - 10220 O 05(15!08 2" 6 10410 - 10710 O 05;16108 2" 6 10820 - 10860 O 05/17,'08 2" 6 10920 - 11100 O 05/18/08 2" 6 11160 - 11180 O 05;19,'08 2" 6 11320 - 11560 O 05120/08 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11012' 8217-20 I-i TBG PUNCHES, CMTD 2003 TOP OF CEMENT -,p~_,,,-... TO L @ 8, 719 8739' 3.5" XN Nipple -' ~' TOP OF 4 1,2°'HOLLOW WHIPSTOCK 9611' RA pip Tag 2' below TOWS ~~~~. ~~ -.. `°"" 9421' CROSSOVER 3-3(16" X 3-112„ ~ ~"" 9876' CROSSOVER 3 3!16° X 2 7/8" ~__ ' ~~ ~ •~ ~'~~ ~~~~~ 3-3116 x 2-718" LNRerr>td & perfd 11579 PBTD' 10400-927 SELRT TEST LNR DATE REV BY COMMENTS DATE REV BY COMMENTS 11/02/83 ORIGINAL COMPLETION 03/21/97 CTDSIDETRACK(K-04A) 04/08/03 DAV/KK RIGSIDETRACK(K-04B) 05116!08 NORDICI CTD SIDETRACK {K-04G} 05/18/08 /TLH CORRECTIONS 05/19/08 GJS/SV CORRECTIONS PRUDHOE BAY UNIT WELL: K-04B PERMIT No:`2022530 API No: 50-029-21023-02 SEC 4, T11N, R14E, 1942.42' FNL & 1184.88' FWL BP Exploration (Alaska) • ~ ~_ h ~ i ~ a f :-a ti`s ~ t ~ °s `' } ~ ~ r t j sb1 ~ ~~~ ~ ,~ ~ o ~ ~ ~ per` , c ~ i p ~ ~ i¢ a ~ S p ~ ~ ~ k., ~ s9 p ' € ~.~ x . _ t~ i ? j a f ,P" 1 f...~ ~~ { j{ ~ ~ i,._3 t.. t.., ~,.1~ CO1~T5ERQ~ ATIO 1T C ~ Ip~ Greg Sarber CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99519 d ~r ~,~.> Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K 04B Sundry Number:. 308-142 ~~!! APR ~. ~ 200 Dear Mr. Sarber: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this ~ day of April, 2008 Encl. ~~ ~E~II'VE. ' ~ STATE OF ALASKA •,~ ' ' / 1 ALA OIL AND GAS CONSERVATION COMMISSION ~°~~ ,~~~ ~~llly ASR ~ 5 2008 ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ii3Si(~' C1it l? C_~~ r,,.._ r._ __ 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensic~n6~QC~e ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Plu back for Sidetrack 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-253 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21023-02-00 - 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: PBU K-04B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028303 ~ ~ 52.59 ~• Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11012 8919 i 10927 8910 None None C in Len th ize MD TVD Burst CoNa se tructural nductor 110' 20" x 3 " 110' 110' Surface 2652' 13-3/8" 2691' 2691' 4930 2670 Int rmediate Production 7181' 9- / " 7217' 7216' 687 4760 Liner 1302' 7" 7056' - 8358' 7055' - 8319' 7240 5410 Liner 2828' 4-1/2" 8184' - 11012' 8154' - 8919' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9120' - 10760' 8839' - 8895' 4-1/2", 12.6# L-80 8194' Packers and SSSV Type: 7" x 4-1/2", BKR S-3 Packer Packers and SSSV MD (ft): 8137' 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: May 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 Greg Sarber, 564-4330 Printed Name g Sarber Title CT Drilling Engineer Prepared By NamelNumber: Signature Phone 564-4330 Date ~ - ~~ t? 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: "~ ~~ ~~ ~ ~~ ~ ~S Subsequent Form Required: 1~~~ APPROVED BY ~ - 8 A roved B COMMISSIONER THE COMMISSION Date Q Form 10-403 Revised 06%1006. Submit In Duplicate a, ~~~~~~a ~ 1 >~ ~Qt1 -M1 ~ • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: April 15, 2008 Re: K-04B Sundry Approval Sundry approval is requested to abandon perforations on well K-04B. by History - K-04B is a horizontal rotary side track well that was completed in April of 2004. The well was completed with 1,130' of Z1 A perforations. It came online producing 4,000 bopd and 10.8 mmscfpd (2.7k GOR). The well continued to decline and by mid-2004 it was making 1,000 bopd and 25 mmscfpd. In early 2005 K-04B became the permanent full time poor boy gas lift source for K-317B a Lisburne producer drilled off K-pad. As a result K-04B was choked back from between 1,100-1,700 psi. In early 2006 K-04B began producing over marginal GOR but remained online to support K-3178. Since that time the well has continued to produce full time at uncompetitive GORs. The wells oil production has continued to decline and become increasingly erratic at high back pressures. When flowed alone (without K-3178) at a lower back pressure the well flows right at or above marginal GOR. A step rate test was performed March 11th thru 13th 2008. The test showed an optimum choke setting of 60 degrees at a back pressure of 1,350 psi. Even at this choke setting the well produced at 61,300 GOR. REASON FOR SUNDRY: In order to achieve adequate isolation for the 2-7/8" liner cement job on the K-04C sidetrack, it will be necessary to abandon all the perforations in the existing parent well bore. . Pre-CT Rig Work: 1. F MIT-IA, MIT may need to be redone if rig arrives on location after June 13, 2008 (6 months time limit). 2. S Dummy off GLV's 3. C RIH with LH motor and mill. Mill XN nipple to 3.80". Run mill as a Drift to PBTD. 4. C Leave well with 150 kLSRV flowpro drilling mud from PBTD to 8,000'. 5. W AC-PPPOT-IC, T 6. W Install a BPV 7. O Bleed gas lift and production flowlines down to zero and blind flange. 8. O Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on June 15, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV, RIH with short liner section and SELRT tool. Conduct SELRT test. 5. Set Whipstock anchor with lug oriented to high side. 6. Set Weatherford Starburst whipstock tray into anchor with top at 9,625', oriented to 75 deg LOHS. 7. Mill 3.80" window at 9,625'. 8. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 9. Drill lateral section to 11,575'. 10. Run and cement a 3-3/16" x 2-718" L-80 liner stringy abandoning perfs in parent wellbore. 11. Make a cleanout run with mill and motor to PBTD in combination with a MCNL-GR-CCL tool. 12. Perforate well 13. Circulate well to KWF brine. FP well to 2000' with diesel. 14. Set BPV. ND 7-1/16" stack. Fee and PT tree cap to 3500 psi. • 15. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Greg Sarber CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble 7fiEEs s'h1Cev< YVaLH64Ds SOY ACTUATOR= 0715 KB.H.L/= 52.59' ~. REV = ~ . 33.4t' ~.._, KOP = . 7296' Arc Angle = Det{an h~D = ..~ . _ Oaturn IVD = 93 ~ 9281)' 10329' 8800' SS K -~ ~ B SAFETY N0T6: 2200' H4-112' 4•ES X NP, Ips 3:813' ras ~1Fr t~an~s ~ 9.518" W PKR f- j 2605 13.318` CSC. 72#, L-8D, [7 ~ 12.34r 289'(' ST A+D TVD DB/ TYPE VLV lATfli FORT OATE d 3699 3699 0 i~M1G-M DMY RK 0 12/13107 3 5897 5897 2 MMC3-M DfMfY faC 0 12H31D7 2 8997 6996 1 AAING-M ~ftf AK 0 Odi0dJ03 1 8048 8028 19 KBG-2 DMY AIC 0 04104/03 Minimum ID =3.725" @ 8181' 4-112" HES KN NiPPLE 1 C~ I r 112, 26J1, L-80, .0383 bpi, ~~ 6.278' {1 >_-7J8' LN2, 6.16IR, L-80, .D058 6pf, b m 2.441' P62R7RATION SUMMARY REF LOG: MVtrp ON 03122!03 ANGLEAT 7OP PEIiF: 85 ~ 9120' Note: Refer to Ifioductbn ~ fa tvstacicai erf daffi S¢E SPF N1TfftVAI. niS DATE 2-112 4 9120.9340 O 04/03/03 2-1l2 4 9580 - 9800 O 04/03!03 2-112 4 9850 - 9910 O 04J03J03 2--112 4 10100 - 103 O 04/03103 2-112 4 10430 - 10760 O 04/03103 DATE REV BY COtiMUBVTS DATE REV BY WMd9VT5 ttJ02J83 ORKiINALCOMPLETKNi 03121/97 CTD SIDETRACK K-04A 041~~3 DAV 1100 R!O SIDETRAC K (K-04~ 04110/03 JJfltAK GLV GY3 06104/03 G.LIOYTLP KB EtE1rATIDN CORRBCTICN 12117107 7fA/SV GLV CIO PRUDHDEBAY UNIT WBl: K-046 F92h1T No: X1022530 API No: 50.029.21023.02 T11N, RI4E, 1942.42' Fr18 1184.88'FWL BP Brpbratlon (Afaaka} 5$' f-j&5J8'X7'BKR2XPLN2T~DPP4lR ~ MLLOUt WWDDW 7217" - 7248' 8118' 4-1/2't-lESXNP',~s3.813' r~ 813T T X 4.112 8KR S-3 PIiR, ~ ~ 3.875' 81$9' 41 J2' 1£S X NP, ffl s 3.813' 8181' 4-112• ~ xw nw, ~ ~ 3.7zs 8184' r X5` BKR 7.JCPLNF2 TOPPKR d-112` TBG, 12.8', L-80, .0152 bpf, IDs 3.956' 7• L.PN~ 2~1, L-80, .0383 bpf, D s 8.278' H $358' s = 6' MCEVOY FEAD= MCEVOY acnwTOR = on s KB ELEV = _ _ ---52.59 BF.ELEV = 33.41' KOP = 7296" IIAax Angte = 93 ~ 9280' Datum MD = 10329' DstumTVD= 880Q' SS ~ K-04C moored C TD S iietrack 9-6/g DV PKR 26D8' 13-318" CSG, 72ar, L-80. D =12.34r 2691' Minimum ID =xxxx" ~ xxxx' SAFI=TY NOTES: IIQQ' -j4-ill' HES X NP, ID = 3 C,AS ! IFT 11M NfYiFi S ST AID ND OEV TV PE VLV LATCH PORT DOTE 4 3699 3699 0 MMI3-M OAM RK 0 12/13A7 3 5897 5897 2 A1/NCrM DAM RK 0 12113A7 2 6997 6996 1 MMGM DAM RK 0 04l04A0 1 8048 8026 19 KBG-2 DAM RK 0 04I04A3 x r aKRZxP 8-S/8' C80, 4Tf, L-1'10, 10 = 8.881' r LNR, 26N, L-80, .0383 hpf, gl ID = 8.276' L_ .0152 hpf, D = 3.958" PERFORATiDN SlA1NMRY REF LOG: AM10 ON 031'22103 A NGLE AT TOP PERF: 85 ®9120' Note: Refer to Production DB for historical peA data S2E SPF INTEIZVAL OpnlSgz DATE 2-'2" 4 9120 -9340 O 04A3103 2-'/2' 4 9560 -9800 O 04N3103 2-' 17' 4 9850 -9910 O 04+03103 2-' 17' 4 10100 - 10380 O OIA3103 2-'/7' 4 10430 - 10780 C 04/03103 AAILLOUT WINDOW 7217' - T248' 8118' 412" HES X NIP, ID = 3.813' 813T 7° X 4 t 2" BKR SJ PKR, D = 3.875" 8181' 412"HESXNP,D•3.813" ~ 8181' 412' HES XN NP, ID miffed to = 3.80" 8184' T X S' BKR ZXP L NR TOP PKR 8184' 412" WLC-G, ID = 3.968' BY 11AD2/83 ORIGINAL COMPLETION 03121197 CTDSIDETRACK(K-04A) 04!08103 DAVIKK RIGSIDETWICK(K-0~ 04/10/03 J,11KAK GLV Cl0 OBA4/03 CAAO/TL.P KB ELEVATION tX)RRf~TDN 12117/07 TFAISV GLV CIO x 4 L'2" 8KR KB LNR TOP PKR i TOL :N w dh RA MARKcR IOLLOW WFNPSTOCK 982b' pQ' CROSSOVER 3 3/18" X 2 7.8" 3-JJt6 x 2-718" 1.NR ~ntd s perid l 11575' PRUDHOE 3AY UNfi WELL: K-04B PERhfT No:'~'J22530 API No 50-029.2102302 J, R14E,1942.42' FNL 81184.88' F11YL 8P t3cpioraNon (Alaska • Rig Floor to Top of Well K-oac 2.2s 9.23 r ~y~~~ 7 1: 16" Amular z 5a0C psi 5.00 ~ - f--"V 7 1: ls' 5000 psi. RX-46 _ BP.rd slzaars 12.65 ~---- T ~'T 13.56 r-__~ z-, ~.iiV~~; 7 it 16' 5000 psi RX-~6 2 i.' 16' SC00 Fsi . R-24 4~ Mud Cross ~ a Gas 14.89 HCR M ~ HCR Choke Lane Kill Line ~ I 16.10 ~ 2 3 y' x 3 ir2' 2 li 16' 5000 psi . RX-24 'd. ~ R_m 16.66 ~- '-s:a• c.^-~: T7T 7 1;16" 5000 psi iRX-461 ~- 7 lr 16" X 3 1r8' FkuxJeti Adapter 20.04 ~ '~ ~.._~ _. ~' Swab Valve Tree Size ~. Fi~,~ -~, ~ Fk~r --~ 22.88 . _ SSV 24.86 ~ • `-T- .~ [-Master Valve h. ' - = a -- 26.68 ~• Lock Down Screws 31.00 -_~ Ground Level Questions on K-04B Sundry • • Maunder, Thomas E (DOA) Fage 1 of 1 From: Sarber, Greg J [SarberJG@BP.com] Sent: Wednesday, April 16, 2008 3:12 PM To: Maunder, Thomas E (DOA) _ Subject: Questions on K-04B Sundry ~~ p~ --~~ Tom, Here are the answers to your questions abou# the K-04B sundry application; 1 -The current source well for poor boy gas lift on well K-3178 is K-04B. The BP engineer responsible for managing that pad has chosen to switch to well K-03 as the source well for PBGL for K-317B. This will require some surface piping revisions. The work on K-03 is scheduled to be completed by May 20th. The sidetrack of K- 04C is currently scheduled to begin June 15th. The plan is to have the switch made to K-03 before the sidetrack operations begin on K-04. 2 -The SELRT is a new liner running tool that is going to be tested in the sump on K-04B prior to setting the whipstock and milling the window. This will no actually be how the perforations on K-04B are abandoned. The SELRT test finer wiN be a short dummy liner set at PBTD of 10,927'. While a full cemenfing operation will be conducted on this liner, the test liner will only be 500' long. The whipstock to begin the K-04C sidetrack wilt be set at 9,625'. There will be existing K-04B perforations above test liner and the whipstock up to 9,120'. All perforations in K-04B wellbore will be abandoned by the K-04C liner cement job. The planned tap of liner for K- 04C will be at 8,900'. I hope this information helps, and please contact me should you need additional information. Sincerely, Greg Sarber Ph: (907) 564-4330 Cell: {907) 242-8000 Email: sarberjg@bp.com 4/16!2008 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: C-23B, C-41A_PB1, D-27A, G-30B, J-27A, K-04B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 . .---.-'.......-..... C-23B: .963 -óCoO P I t...fLfLII Digital Log Images: 50-029-20775-02 1 CD Rom ~NED rES 0 1 2007 C-41A_PBl: .90i.1-1"ð~ tJ 1~t..ILI3 Digital Log Images: 50-029-22385-01,70 D-27 A: c9óS--l'ì3 'ti 1 L./LI'-I D Digital Log Images: 50-029-21543-00 1 CD Rom ^' _.r::- ..,,",,(tIo}4,~,~~t.;; 1 CD Rom ti G-30B: QöS--80'ð ILILI34 Digital Log Images: 50-029-21613-02 J-27 A: db d -dOO tt IL/LI3'D Digital Log Images: 50-029-21733-01 K-04B: ;;;ó9 - d S3 ~ ¡4¿/L/ d. Digital Log Images: 50-029- 21023-02 1 CD Rom 1 CD Rom 1 CD Rom -;:¡- e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 03,2003 r3L~ J ~ RE: MWD Formation Evaluation Logs: K-04B, AK-MW -2340063 K-04B: Digital Log Images 50-029-21023-02 :Jb~- /)53 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 -f Date¿/M/Ö&' ~C' .... <- m Signed: _'_ (CJ(ìrlJ:&~- . . ".' ) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 5/4/2005 Permit to Drill 2022530 MD Well Name/No. PRUDHOE BAY UNIT K-04B Jp ~ J.,/ I"~ h.~:J API No. 50-029-21023-02-00 Operator BP EXPLORATION (ALASKA) INC ./'" TVD 8919·r Completion Date 4/4/2003 / Completion Status 1-01L 11012 REQUIRED INFORMATION Samples No Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, PWD, GR, RES, ASI, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~Pf--- ED _ 0 ~ Rpt .ßEY/ 0 Rpt ,.E(5- 0 Log Log Run Scale Media No Directional Survey [,t171 0 'LI S Vt::, jfj~Miol'\ - Ú -{t... i ~.uJ y(.. '-\ i G ~ S (,. () ~ 1< G y? Directional Survey Directional Survey &A:rS"Verification Directional Survey Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? y@ Chips Received? -T'T)'\J" Current Status 1-01L UIC N Directional Survey ~ (data taken from Logs Portion of Master Well Data Maint) Interval OHI ~ Start Stop CH Received Comments 7191 11012 Open 4/29/2003 MWD 7112 10968 Open 5/13/2003 7191 11012 Open 4/29/2003 7191 11012 Open 4/29/2003 MWD 7112 1 0968 Open 5/13/2003 7191 11012 Open 4/29/2003 Sample Set Number Comments '~ Daily History Received? a/ N Formation Tops ®' N Analysis ~ Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/4/2005 Permit to Drill 2022530 Well Name/No. PRUDHOE BAY UNIT K-04B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21023-02-00 MD 11012 TVD 8919 C~tion Date 4/4/2003 Completion Status 1-01L Current Status 1-01L UIC N Date: . ~I ~ ~\'" Compliance Reviewed By: C,__" ~ ) ) J, aœ-ôl5.J /17/0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tl1 Avenue, Suite 100 ~chorage,Alaska May 07, 2003 RE: ,MWDFonnation Evaluation LogsK-04B, AK-MW-2340063 1 LDWG fonnattedDisc with verification listing. API#: 50-029-21023-02 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: Signed: ~Á~ RECEIVED - MAY 13 2003 AJasft~ or¡ & Gas Cons. CoI11l11Ìl!liOR And1tnge 23. CASING SIZE 20" X 30" 13-3/8" 9-518" 7" 4-1/2" WT. PER FT. Insulated 72# 47# 26# 12.6# ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 202-253 8. API Number 50- 029-21 023-02 9. Unit or Lease Name X = 671453, Y = 5975278 Prudhoe Bay Unit K-04B 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 22001 MD 19001 (Approx.) GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 1101 36" 39' 2691' 17-1/2" 36' 7217' 12-1/4" 7056' 8358' 8-1/2" 8184' 11012' 6-1/8" CEMENTING RECORD 8 cu yds Concrete 3746 cu ft Permafrost II 1822 cu ft Class 'GI, 132 cu ft PF IC' 292 cu ft Class 'G' , 399 cu ft Class IG' & 421 cu ft IG' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD MD TVD 9120' - 9340' 8839' - 8834' 9560' - 9800' 8833' - 8822' 9850' - 9910' 8822' - 8824' 10100' - 10380' 8832' - 8856' 10430' - 10760' 8858' - 8895' 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1942' SNL, 1185' EWL, SEC. 04, T11N, R14E, UM At top of productive interval 1849' SNL, 1726' EWL, SEC. 04, T11 N, R14E, UM X = 671991, Y = 5975384 10. Well Number At total depth 2894' SNL, 1121' EWL, SEC. 04, T11N, R14E, UM X = 671414, Y = 5974325 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 52.59' ADL 028303 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/21/2003 3/29/2003 4/412003 17 . Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 11012 8919 FT 10910 8908 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DEN, NEU, ABI Flow Tubing Casing Pressure CALCULATED Press. 174 24-HoUR RATE 28. CORE DATA CEGf::.IVED Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chipl.' 27. Date First Production April 16, 2003 Date of Test Hours Tested 4/22/2003 No core samples were taken. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BeL TEST PERIOD 2,910 OIL-BeL RBDMS BFL '. 1. ~~ ¡' ~,' ~ . " q.. ""'I;: ~~~~ .:-~~~=:_.... '..-... .",.... Form 10-407 Rev. 07-01-80 25. TUelNG RECORD DEPTH SET (MD) 8194' PACKER SET (MD) 8137' SIZE 4-1/2", 12.6#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8217' - 8220' Perf for 4-1/2" Casing Cement Squeeze 10910' Set EZSV; Squeeze 421 cu ft Class 'G' below retainer (also listed wI 4-1/2") Freeze Protected with 155 Bbls Diesel GAs-McF 8,364 GAs-McF WATER-BeL 110 WATER-BeL CHOKE SIZE 96° OIL GRAVITY-API (CORR) GAS-OIL RATIO 2,874 MAY 06 2003 Jr":''v ~." -"'("-'''\1''"'''' 1 LOCA, ".. -~~,~: ) VðU~ .~,: JSŒ~.'j",,~.., j~~~..~~.._'§..' "-, 1"-,' '... "" "",' ... ' .'~ 0 RIG I N A L Submit In Duplicate Alaska Œ'J & Gas Cons. Commi5Si0n Anchorege ) 29. Geologic Markers Marker Name Measured Depth Sag River 83631 Shublik 84141 Sadlerochit 84701 CGL 85721 23SB 86701 22TS 87281 21TS 8786' Zone 1 B 88891 TDF 8948' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8324' 8372' 8425' 85201 86081 86561 87001 87631 8791' Summary of Pre-Rig Work and Daily Drilling Reports, Surveys 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed Terrie Hubble ~ Title Technical Assistant K-04B Well Number Date ()Ç ---ria ,,03 202-253 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Michael Triolo, 564-5774 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 (OF, 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 Legal Name: Common Name: Test Date 3/20/2003 3/24/2003 FIT FIT K-04 K-048 Test Type Test Depth (TMD) 7,248.0 (ft) 8,379.0 (ft) BPE*PLORATION L.eak-Off,...ést,5ufl'll'l'lary Test Dépth(TVD) 7,247.0 (ft) 8,338.0 (ft) AMW 10.10 (ppg) 8.40 (ppg) SurfacePl'essure 650 (psi) 575 (psi) l.eak-·OffPTessÜre.·.(EtHP) 4,452 (psi) 4,213 (psi) EMW 11.83 (ppg) 9.73 (ppg) 1 ~. .,---, Printed: 4/8/2003 9:00:10 AM ) ) BPEXPLORA TION Operations .SurnmaryReport Page 1, of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 , Date From - To Hours Task Code NPT Phase Description of Operations 3/16/2003 04:00 - 19:00 15.00 MOB P PRE Turnkey rig move from DS 17-01 to K-04. Substructure left DS 17 09:00 hrs. Arrive K-pad at 19:00 hrs. 19:00 - 00:00 5.00 MOB P PRE Camp, pit module left DS 17 at 19:30 hrs. Arrive K-pad 23:45. 3/17/2003 00:00 - 05:00 5.00 MOB P PRE Move in and spot pit module, camp, shop, and cuttings tank. Berm all areas, connect lines, plug in power. ACCEPT Rig at 05:00 3/17/2003. 05:00 - 06:00 1.00 RIGU P DECOMP Pre spud meeting; safety and environmental meeting. 06:00 - 07:00 1.00 WHSUR P DECOMP Install secondary annulus valve. Bleed OA from 150 psi to 0 psi. 07:00 - 07:30 0.50 WHSUR P DECOMP R/U hoses. 07:30 - 08:30 1.00 WHSUR P DECOMP R/U DSM lubricator and pull BPV. 08:30 - 12:30 4.00 WHSUR P DECOMP Circulate out diesel, pump 50 bbl soap sweep, displace well bore with 120 degree KCI fluid @ 5 bpm and 280 psi. Blow down and RID circulating I,ines. 13:00 - 14:30 1.50 WHSUR P DECOMP Install TWC and test from below to 1,000 psi. 14:30 - 17:30 3.00 BOPSUR P DECOMP N/U BOPE 17:30 - 22:00 4.50 BOPSURP DECOMP Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by Chuck Schieve, of the AOGCC. 22:00 - 23:00 1.00 WHSUR P DECOMP R/U DSM and pull TWC with lubricator. 23:00 - 00:00 1.00 WHSUR P DECOMP M/U Baker spear, RIH and engage hanger, BOLDS. 3/18/2003 00:00 - 01 :00 1.00 WHSUR P DECOMP Straight pull to -170K before hanger pulled free. Continued pull to 180K with 5' - 6' of pipe movement. Tubing free at 180K. Hanging weight 142K. Calculated bouyed weight of -110K. 01 :00 - 01 :30 0.50 PULL P DECOMP Disconnect terminal ends of control lines. Break hanger and XO pup. LID Baker spear assembly. 01 :30 - 04:30 3.00 PULL P DECOMP POH with 51/2",17#, L-80 tubing and dual encapsulated control lines. Total of 48 joints 5 1/2" tubing to Camco Ball Valve. Recovered 25 control line clamps and 4 ss bands. 04:30 - 05:00 0.50 PULL P DECOMP RID Camco spooling unit. 05:00 - 08:00 3.00 PULL P DECOMP Continue POH LD 5 1/2",17#, L-80 tubing to 2,255 ft. (124 jts) 08:00 - 21 :30 13.50 PULL N RREP DECOMP Repair pipe skate. (Pad eye from elevator to hyd ram) 21 :30 - 23:30 2.00 PULL P DECOMP Continue POH LD 5 1/2",17#, L-80 tubing total 172 jts + 20.20 ft cut off jt. Smooth cut - OD @ cut 5.5", Recover 4 GLM assy & 1 SSSV assy. 25 CC clamps, 4 SS bands. 23:30 - 00:00 0.50 PULL P DECOMP RD 5 1/2" tbg handling equip. 3/19/2003 00:00 - 03:00 3.00 WHSUR P DECOMP MU retrieving tool for 9 5/8" pack off. Engage pack off. BOLDS on SOW. Pull 9 5/8" pack off wI 25k. MU new pack off, run & seat same. RILDS on SOW. Test pack off to 3000 psi. O-K. LD running tool. 03:00 - 03:30 0.50 BOPSUR P DECOMP PU test jt. Test lower pipe rams to BP & AOGCC regs. 250 psi low 13500 psi high. LD test jt. 03:30 - 04:00 0.50 WHSUR P DECOMP Install wear bushing. 04:00 - 06:30 2.50 TA P DECOMP RU Schl e-line unit. RIH wI 8.5" GR I JB - GR I CCL. Tag 5 1/2" tbg stump @ 7,344 ft e line measurement. POH wI GR I JB - GR/CCL. 06:30 - 09:00 2.50 TA P DECOMP MU & RIH wI 9 5/8" EZSV on e line. Set EZSV @ 7,258 ft e line measurement. POH wI setting tool. RD Schl e line unit. 09:00 - 10:00 1.00 T A P DECOMP Test 9 5/8" csg I EZSV 3500 psi I 30 mins. O-K. 10:00 - 13:00 3.00 STWHIP P WEXIT PU 9 5/8" whipstock assy BHA, orient UBHO & RIH to 1,037 ft. 13:00 - 19:00 6.00 STWHIP P WEXIT Con't RIH wI 9 5/8" whipstock assy on 4" DP from pipe shed to 7,225 ft. 19:00 - 00:00 5.00 STWHIP P WEXIT RU Schl e line. MU & RIH wI 'Gyro' Orient 9 5/8" whipstock to 64 degrees GTF. P/U Wt 180k, S/O Wt 180k. RIH tag 95/8" Printed: 4/8/2003 9:00:17 AM ) ') BP EXPLORATION Operations. Summary Report ' WEXIT EZSV @ 7,241 ft. Confirm orientation. Trip btm anchor wI 25k on 9 5/8" EZSV @ 7,241 ft (Drillers tally). Confirm orientation @ 64 degrees GTF. POH wI 'Gyro'. Shear off whipstock w/40k dn wt. TOW @ 7,217 ft. Displace well wI 40 bbl spacer & 10.1 ppg LSND mud. 546 GPM @ 2140 psi. Establish baseline parameters. SPR's wI both pumps. Mill window 7,217 ft to 7,248 ft. 532 GPM 1890 psi.11 0 RPM, TO 2-3 K. P/U Wt 165k, S/O Wt 160k Rot Wt 165k WOM 2 - 30k Ream window & circ Hi Vis sweep. 532 GPM, 1890 psi. 90 RPM, TO 2k. P/U Wt 165k, S/O Wt 160k, Rot Wt 165k. No sufficent increase in returns. Perform FIT to EMW 11.8 ppg as per BP regs. Hole depth 7,248 ft 7,247 ft TVD, 10.1 ppg LSND, 650 psi surface pressure. Pump dry job. POH to 7,165 ft. Blow down surface circ equip. Slip & cut drlg line. Service Top Drive. Observe well static. POH wI 8 1/2" mill assy to BHA @ 1,037 ft. Rack back HWDP & DC's. LD mill assy BHA. Inspect mills full gauge. Pull wear bushing. Function BOP rams. Flush stack. Install wear bushing. Clear rig floor. PU directional tools. PU & RIH wI 81/2" HTC HCM 605 PDC bit, MM, MWD, UBHO. Orient same. Up load MWD. Fin up load MWD. Con't RIH w/8 1/2" directional drilling BHA to 1,190 ft. Shallow test MWD O-K. Con't RIH wI 81/2" drilling BHA on 4" DP from pipe shed to 2,310 ft. Con't RIH wI 81/2" drilling BHA on 4" DP from derrick to 7,132 ft. RU Schl e line unit. MU SES. RIH wI Gyro on e line to 500 ft. Pack off SES, test O-K. Release pack off. Con't RIH wI Gyro on e line. Seat Gyro in UBHO sub. Confirm seat. Pack off SES. Orient string. Slide thru window @ 7,217 ft - 7,233 ft wI pumps off. Wash to btm @ 7,248 ft. Drill 8 1/2" hole 7 ,248 ft - 7,360 ft. P/U Wt 190k, S/O Wt 180k. 554 GPM, 3190 psi off btm, 3400 psi on btm. Lost communication wI Gyro. Slide 112 ft @ GTF 70 ROP 40 ft I hr AST= 2.8 hrs, ADT= 2.8 hrs POH wI 8 1/2" bit to 7,134 ft. Release pack off on SES. POH wI Gyro on e line. LD SES. RD Sch e line. RIH wI 81/2" bit to bottom @ 7,360 ft. Drill 8 1/2" hole 7 ,360 ft - 7,616 ft. P/U Wt 190k, S/O Wt 180k, Rot Wt 180k, TO on btm 6k, TO off btm 3k. 556 GPM, 2600 psi off btm, 2970 psi on btm. Slide 155 ft A VG TF 10 L Slide ROP 41 ft I hr Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To Hours Task Code NPT Phase 3/19/2003 19:00 - 00:00 5.00 STWHIP P 3/20/2003 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 11 :30 10.00 STWHIP P WEXIT 11 :30 - 13:00 1.50 STWHIP P WEXIT 13:00 - 13:30 0.50 EVAL P WEXIT 13:30 - 14:00 0.50 STWHIP P WEXIT 14:00 - 15:30 1.50 STWHIP P WEXIT 15:30 - 18:30 3.00 STWHIP P WEXIT 18:30 - 20:00 1.50 STWHIP P WEXIT 20:00 - 21 :00 1.00 CLEAN P WEXIT 21 :00 - 22:00 1.00 CLEAN P WEXIT 22:00 - 00:00 2.00 DRILL P INT1 3/21/2003 00:00 - 01 :30 1.50 DRILL P INT1 01 :30 - 02:30 1.00 DRILL P INT1 02:30 - 04:30 2.00 DRILL P INT1 04:30 - 09:00 4.50 DRILL P INT1 09:00 - 09:30 0.50 DRILL P INT1 09:30 - 13:30 4.00 DRILL P INT1 13:30 - 14:00 0.50 DRILL P INT1 14:00 - 16:00 2.00 DRILL P INT1 16:00 - 16:30 0.50 DRILL P INT1 16:30 - 00:00 7.50 DRILL P INT1 Page 2 of 9 Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Descri ption of Operations Printed: 4/8/2003 9:00: 17 AM ') ) BP EXPLORATION OperationsSurnmary' Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Date ' From - To Hours Task Code NPT Phase Description of Operations 3/21/2003 16:30 - 00:00 7.50 DRILL P INT1 Rotate 101 ft Rotate ROP 106 ft I hr AST= 3.76 hrs, ART= 0.95 hrs, ADT= 4.7 hrs. 3/22/2003 00:00 - 13:30 13.50 DRILL P INT1 Drill 8 1/2" hole 7,616 ft - 8,341 ft. Hole section TD. P/U Wt 195k, SIO Wt 180k, Rot Wt 190k, 90 RPM's, TO on btm 7k, TO off btm 4k. 556 GPM, 2870 psi off btm, 3200 psi on btm. Slide 274ft Avg TF 0 - 20 R Slide ROP 43 ft Ihr Rotate 451 ft Rotate ROP 150 ft I hr AST= 6.4 hrs, ART= 3 hrs, ADT= 9.40 hrs 13:30 - 14:00 0.50 DRILL P INT1 Circ btm hole sample as per Geologist 14:00 - 14:30 0.50 DRILL P INT1 Drill 8 1/2" hole 8,341 - 8,359 ft - Hole section TD. P/U Wt 195k, S/O Wt 180k, Rot Wt 190k, 90 RPM's, TO on btm 7k, TO off btm 4k. 556 GPM, 2870 psi off btm, 3200 psi on btm. Rotate 18 ft Rotate ROP 72 ft I hr. ART= 0.25 hrs, ADT= 0.25 hrs. 14:30 - 15:00 0.50 DRILL P INT1 Circ btm hole sample as per Geologist 15:00 - 16:00 1.00 DRILL P INT1 Flow check well static. POH wi 8 1/2" bit to 7,156 ft inside 7" csg. Hole in good shape. 16:00 - 16:30 0.50 DRILL P INT1 Service Top Drive 16:30 -17:00 0.50 DRILL P INT1 RIH w/8 1/2" bit to btm @ 8,359 ft. No fill. Hole in good shape. 17:00 - 18:00 1.00 DRILL P INT1 Circ Hi Vis sweep to surface. Flow check showing well static. Pump dry job. P/U Wt 195k, SIO Wt 180k, Rot Wt 190k. 90 RPM's, TO 4k 546 GPM, 2870 psi 18:00 - 21 :00 3.00 DRILL P INT1 POH w/8 1/2" bit to BHA @ 1,190 ft. Drop 21/4" rabbit @ 9 5/8" window. 21 :00 - 00:00 3.00 DRILL P INT1 LD 81/2' drilling BHA. Down load MWD. 3/23/2003 00:00 - 00:30 0.50 DRILL P INT1 Fin down load MWD. LD MWD, MM & bit. 00:30 - 01 :00 0.50 CASE P INT1 Clear rig floor. 01 :00 - 02:30 1.50 BOPSUR P INT1 Pull wear bushing. Install test plug. Change upper pipe rams to 7". PU 7" test jt. Test upper rams to BP & AOGCC regs 250 I 3500 psi. LD test jt. Pull test plug. Install wear bushing. 02:30 - 03:30 1.00 CASE P INT1 RU 7" casing handling equip. 03:30 - 05:30 2.00 CASE P INT1 PU & RIH wi 7" liner as follows; FS, 1 jt, FC, 1 jt, insert collar, 29 jts 7" 26#, L 80, BTC-M, Range 3 casing. Baker Lok all connections from jt #3 down. BOL 2000 pipe dope used on all other connections. Check floats O-K. Avg MU TO 8000. PU & MU Baker 9 5/8" 'HMC' liner hanger & 'ZXP' liner top packer. 05:30 - 06:00 0.50 CASE P INT1 Circ liner volume. 126 GPM @ 130 psi. P/U Wt 55k, S/O Wt 55k LD csg handling equip. PU DP handling equip. 06:00 - 08:30 2.50 CASE P INT1 RIH w/7" liner on 4" DP to 7,130 ft. 08:30 - 09:30 1.00 CASE P INT1 Circ bottoms up. 420 GPM @ 1100 psi. P/U Wt 150k, SIO Wt 145 09:30 - 10:00 0.50 CASE P INT1 Con't RIH wi 7" liner on 4" DP to 8,342 ft. Hole in good shape. Printed: 4/8/2003 9:00:17 AM ) ') EXPLORATION Operations Summary"Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2003 09:30 - 10:00 0.50 CASE P INT1 P/U Wt 170k, S/O Wt 155k 10:00 - 10:30 0.50 CASE P INT1 PU pre loaded cement head. Break circ, wash to bottom @ 8,359 ft. No fill. 10:30 - 12:00 1.50 CEMT P INT1 Circ & condition mud. RU surface cement lines. Pump 5 bbls H20. Test lines to 4000 psi. 12:00 - 14:00 2.00 CEMT P INT1 Mix & pump 45 bbls 11.1 ppg 'Mud Push', 50 bbls Class 'G' 15.8 ppg slurry Avg 3.8 BPM Max 700 psi. Drop dart. Flush lines thru tee on floor. Displace cmt wI rig pumps @ 263 GPM Avg 1700 psi. Total 118 bbls 10.1 ppg LSND mud. Seat dart in LC. Pressure to 3500 psi, set hanger. Bled off pressure check floats O-K. Unsting circ bottoms up 525 GPM @ 2390 psi. Mud push at surface on btms up. Set dn 70k to set 'ZXP' packer. Rotate on pkr wI good surface indication of pkr setting. CIP @ 1300 hrs. 14:00 - 15:00 1.00 CEMT P INT1 Pump dry job. LD cmt head. 15:00 - 18:00 3.00 CEMT P INT1 POH wI liner running tool. Choke manifold tested to BP & AOGCC regs 250 psi low 13500 psi high off critical path. 18:00 - 18:30 0.50 CEMT P INT1 LD & inspect liner running tool. O-K. 18:30 - 19:00 0.50 CEMT P INT1 Clear & clean rig floor. 19:00 - 19:30 0.50 BOPSURP PROD1 Pull wear bushing. Install test plug. 19:30 - 20:30 1.00 BOPSURP PROD1 Change upper pipe rams to 3 1/2" x 6". 20:30 - 22:00 1.50 BOPSUR P PROD1 PU test jt. Test BOPE to BP & AOGCC regs 250 psi low I 3500 psi high. LD test jt. Witness of test waived by John Crisp of the AOGCC. 22:00 - 22:30 0.50 BOPSURP PROD1 Pull test plug. Install wear bushing. 22:30 - 23:30 1.00 EVAL P PROD1 Test 7" x 9 5/8' csg & liner top to 3500 psi I 30 mins. 23:30 - 00:00 0.50 DRILL P PROD1 MU 6 1/8" XR 20 bit on 4 3/4" MM. Adjust MM to 1.83 deg bent housing. 3/24/2003 00:00 - 03:30 3.50 DRILL P PROD1 Con't PU & MU 6 1/8" drlg BHA to 423 ft. Surface test MWD. Install 'Nuke's'. 03:30 - 05:30 2.00 DRILL P PROD1 RIH w/6 1/8" drlg BHA on 4" DP from pipe shed to 3,783 ft. 05:30 - 06:30 1.00 DRILL P PROD1 Con't RIH w/6 1/8" drlg BHA on 4" DP from derrick to 7,052 ft. 06:30 - 07:30 1.00 DRILL P PROD1 Slip & cut drlg line. 07:30 - 08:00 0.50 DRILL P PROD1 Service Top Drive. 08:00 - 08:30 0.50 DRILL P PROD1 Con't RIH w/6 1/8" drlg BHA on 4" DP from derrick to 8,273 ft. 08:30 - 11 :00 2.50 DRILL P PROD1 Drill shoe track to within 1 ft of FS. Shoe track consisting of LC, cmt, FC, cmt. 11:00-12:00 1.00 DRILL P PROD1 Displace well wi 50 bbls Hi Vis spacer & 8.4 ppg 'Quick Drill' mud. 250 GPM @ 1850 psi. P/U Wt 164k, S/O Wt 158k, Rot Wt 163k. 30 RPM's, TQ 3k 12:00 - 13:00 1.00 DRILL P PROD1 Clean LSND mud & cuttings from under shakers & sand trap. 13:00 - 14:00 1.00 DRILL P PROD1 Drill FS & new formation to 8,379 ft. 250 GPM @ 1280 psi. P/U Wt 165k, S/O Wt 157k, Rot Wt 163k 30 RPM's, TQ 3k 14:00 - 14:30 0.50 DRILL P PROD1 Pull into 7" shoe. Perform FIT to EMW 9.7 ppg as per BP regs. Hole TD 8,379 ft MD, 8,338 ft TVD, surface pressure 575 psi wI 8.4 ppg mud. RIH to btm. 14:30 - 00:00 9.50 DRILL P PROD1 Drill 6 1/8" directional hole 8,379 ft to 8,549 ft. 250 GPM @ 1280 psi off btm, 1450 psi on btm. P/U Wt 175k, S/O Wt 165k, Rot Wt 160k, RPM's 30, TQ on btm 3-9k, TQ off btm 3k Slide 63 ft. Avg TF 60 R Printed: 4/8/2003 9:00: 17 AM 0) ) EXPLORATION Summary Report , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Date' From - To Hours Task Code NPT Phase Description of Operations 3/24/2003 14:30 - 00:00 9.50 DRILL P PROD1 Slide ROP= 33 ft I hr Rotate 1 07 ft Rotate ROP= 33 ft I hr AST= 1.92 hrs, ART= 3.22 hrs, ADT= 5.14 hrs. 3/25/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" directional hole 8,549 ft to 8,906 ft. 250 GPM @ 1555 psi off btm, 1710 psi on btm. P/U Wt 170k, S/O Wt 160k, Rot Wt 165k, RPM's 65, TO on btm 3-7k, TO off btm 3k Slide 331 ft. Avg TF 50 R Slide ROP= 28 ft I hr Rotate 26 ft Rotate ROP= 86 ft I hr AST= 11.9 hrs, ART= 0.3 hrs, ADT= 12.2 hrs. 3/26/2003 00:00 - 05:00 5.00 DRILL P PROD1 Drill 6 1/8" directional hole 8,906 ft to 8,951 ft. 250 GPM @ 1555 psi off btm, 1710 psi on btm. P/U Wt 170k, S/O Wt 160k, Rot Wt 165k, RPM's 65, TO on btm 3-7k, TO off btm 3k. Slide 38 ft. Avg TF 20 R Slide ROP= 23 ft I hr Rotate 7 ft Rotate ROP= 35 ft I hr AST= 1.6 hrs, ART= .2 hrs, ADT= 3.1 hrs. 05:00 - 05:30 0.50 DRILL P PROD1 POH w/6 1/8" drilling assy to inside 7" shoe @ 8,357 ft. Hole in good shape. 05:30 - 06:30 1.00 DRILL P PROD1 Drop opening dart for circ sub. Open circ sub, CBU. 550 GPM, 570 psi. P/U Wt 170k, S/O Wt 160k. Rot Wt 165k. 45 RPM's TO 3k. No significant increase in cuttings. 06:30 - 09:00 2.50 DRILL P PROD1 Con't POH wi 6 1/8" bit to BHA @ 423 ft. 09:00 - 11 :00 2.00 DRILL P PROD1 LD I download 'Nukes'. LD MM. 11 :00 - 13:30 2.50 DRILL P PROD1 MU I upload & RIH w/6 1/8" Sec FM 2643,5" 1.76 degree MM, MWD. Surface test MWD O-K. 13:30 - 17:00 3.50 DRILL P PROD1 Con't RIH w/6 1/8" drilling BHA to btm @ 8,951 ft. Precaution ream 8,796 ft to 8,951 ft. 17:00 - 00:00 7.00 DRILL P PROD1 Drill 6 1/8" directional hole 8,951 ft to 9,075 ft. 321 GPM @ 1700 psi off btm, 1910 psi on btm. P/U Wt 165k, S/O Wt 165k Slide 124 ft. Avg TF 10 R Slide ROP= 36 ft I hr AST= 3.48 hrs, ADT 3.48 hrs. 3/27/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" directional hole 9,075 ft to 9,548 ft. 343 GPM @ 2080 psi off btm, 2200 psi on btm. P/U Wt 167k, S/O Wt 160k, Rot Wt 167k. TO on btm 5k, off btm 3k Slide 460 ft. Avg TF 85 R Slide ROP= 40.3 ft I hr. Rotate 13 ft Rotate ROP= 130 ft I hr. AST= 11.4 hrs, ART= 0.10, ADT= 11.5 hrs 3/28/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" directional hole 9,548 ft to 10,075 ft. 343 GPM @ 2080 psi off btm, 2300 psi on btm. P/U Wt 167k, S/O Wt 155k, Rot Wt 160k, TQ off btm 3k Slide 527 ft. Avg TF 90 - 120 R Printed: 4/8/2003 9:00:17 AM ) ) Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Date From - To Hours Task Code NPT Phase Descri ptionofOperations 3/28/2003 00:00 - 00:00 24.00 DRILL P PROD1 Slide ROP=35 ft I hr AST= 15.14 hrs, ADT= 15.14 hrs. 3/29/2003 00:00 - 03:30 3.50 DRILL P PROD1 Dri1l61/8" directional hole 10,075 ft to 10,157 ft. Lost communication MWD. 331 GPM @ 2000 psi off btm, 2350 psi on btm. P/U Wt 165k, S/O Wt 150k, Rot Wt 160k, TO off btm 3k. Slide 82 ft. Avg TF 100 R Slide ROP= 39 ft I hr AST= 2.1 hrs, ADT= 2.1 hrs. 03:30 - 04:00 0.50 DRILL N DFAL PROD1 Trouble shoot MWD @ 10,157 ft. Rack back 1 stand, established communication wi MWD. Run to btm. 04:00 - 18:00 14.00 DRILL P PROD1 Drill 6 1/8" directional hole 1 0, 157 ft to 11,012 ft. TD 331 GPM @ 2000 psi off btm, 2350 psi on btm. P/U Wt 170k, S/O Wt 150k, Rot Wt 165k, TO on btm 5-6k, off btm 3-4k. Slide 311 ft. Avg TF 223 ft @ 130 R, 88 ft @ 20 L Slide ROP= 45 ft I hr Rotate 544 ft. Rotate ROP= 165 ft I hr AST= 6.9 hrs, ART= 3.3 hrs, ADT= 10.2hrs 18:00 - 19:00 1.00 DRILL P PROD1 Circ Hi Vis sweep surface to surface. Slight increase of cuttings at surface. 350 GPM @ 2225 psi P/U Wt 170k, S/O Wt 150k, Rot Wt 165k. TO 4k 19:00 - 20:30 1.50 DRILL P PROD1 POH wi 61/8" bit to inside 7" casing @ 8,328 ft. Flow checks & hole fill showing well static. Hole in good shape. 20:30 - 23:00 2.50 DRILL P PROD1 Clean rig floor. Slip & cut drlg line. Service Top Drive. 23:00 - 23:30 0.50 DRILL P PROD1 RIH wi 6 18" bit to btm @ 11,012 ft. No fill. Hole in good shape. 23:30 - 00:00 0.50 DRILL P PROD1 Circ & clean the hole @ 350 gpm, 2450 PSI. P/U Wt 170k, S/O Wt 150k, Rot Wt 165k. TO 4k. 3/30/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Circ & clean the hole @ 330 gpm, 2150 PSI. Spot 100 bblliner running pill. P/U Wt 170k, S/O Wt 150k, Rot Wt 160k. TO 4k. 01 :00 - 03:30 2.50 DRILL P PROD1 POH wi 6 1/8" bit to inside 7" csg @ 8,359 ft. SLM. LD excess DP. 03:30 - 04:30 1.00 DRILL P PROD1 Drop opening dart for circ sub. CBU @ 555 GPM 1700 psi. 04:30 - 05:00 0.50 DRILL P PROD1 Drop 2.25" drift wi wireline tail. Pump Dry job. Blow down Top Drive. 05:00 - 08:00 3.00 DRILL P PROD1 POH wi 61/8" bit to BHA @ 394 ft. SLM. No correction. 08:00 - 11 :00 3.00 DRILL P PROD1 LD BHA & download MWD. Clear rig floor. 11 :00 - 11 :30 0.50 CASE P COMP RU 4 1/2" casing handling equip. 11 :30 - 15:00 3.50 CASE P COMP PU & RIH wi 41/2" liner to 2,803 ft. Check floats O-K. FS, 1 jt 4 1/2" 12.6#, L 80 IBT csg, FC, 1 jt 41/2" 12.6#, L 80 IBTcsg, LC, 61 jts 41/2" 12.6#, L 80, IBT csg, 1 marker jt, 5 jts 4 1/2" 12.6#, L 80, IBT csg, XO bushing, Baker 5" x 7" 'HMC' liner hanger, Baker 5" x 7" Baker 'z)(P' liner top pkr. Avg MU TO 3400 fUlbs. All csg Rg 3. 15:00 - 15:30 0.50 CASE P COMP PU 1 std 4" DP. Circ one liner volume. P/U Wt 60k, S/O Wt 60k. 15:30 - 18:00 2.50 CASE P COMP Con't RIH wi 41/2" liner on 4" DP to 8,285 ft. 18:00 - 18:30 0.50 CASE P COMP Circ one pipe volume. 295 GPM @ 760 psi. Printed: 4/8/2003 9:00: 17 AM ) ) BP EXPLORATION Operations'SummaryReport Page 7 of 9 Legal Well Name: K-04 Common Well Name: K-04B Spud Date: 10/21/1983 Event Name: REENTER+COMPLETE Start: 3/14/2003 End: 4/4/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/4/2003 Rig Name: NABORS 2ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations 3/30/2003 18:00 ~ 18:30 0.50 CASE P COMP P/U Wt 140k, S/O Wt 140k. 18:30 ~ 20:00 1.50 CASE P COMP Con't RIH wI 4 1/2" liner on 4" DP to btm @ 11,012 ft. PU cmt head. Hole in good shape. 20:00 . 22:00 2.00 CASE P COMP Circ & cond mud. 295 GPM, 1100 psi. P/U Wt 155k, S/O Wt 155k. RU cementers. Batch mix cmt. 22:00 ~ 23:30 1.50 CEMT P COMP Test lines to 4500 psi wI cement unit. Pump 15 bbls CW 100, 31 bbls 10.5 ppg 'Mud Push', 73 bbls 15.8 ppg Class 'G' slurry. Wash lines up thru 'T' on floor. Drop plug. Displace wI 42 bbls 8.5 ppg 'Perf Pill', 84 bbls 8.5 ppg mud. Did not bump plug. Check floats not holding. Note: Latch plug @ 79 bbls away shear wI 3900 psi. 23:30 - 00:00 0.50 CEMT N DFAL COMP Attempt to release from hanger - No TO. Suspect hanger premature released. Unsting from hanger. CBU @ 555 GPM 3050 psi. P/U Wt 150k, S/O Wt 150k. Approx 70 bbls cement at surface. 3/31/2003 00:00 - 03:00 3.00 CEMT N DFAL COMP Circ & cond mud from cement contamination. Clean out flow line, shakers, sand trap & pits from cement. 03:00 - 03:30 0.50 CEMT N DFAL COMP RD surface circ lines & cmt head. 03:30 - 08:00 4.50 CEMT N DFAL COMP POH wI liner running tool. Test choke manifold to BP & AOGCC regs 250 psi low 13500 psi high off critical path. Inspect running tool. O-K. Clear floor. 08:00 - 08:30 0.50 BOPSUR P COMP Pull wear bushing. Function all LDS. 08:30 - 09:00 0.50 BOPSUR N DFAL COMP Function all rams, flush stack & HCR valves as precaution due to cement at surface. 13 BPM - 150 psi. 09:00 - 14:00 5.00 BOPSURP COMP PU 4" test jt. Set test plug. Test BOPE to BP & AOGCC regs 250 I 3500 psi. LD test jt. PU 2 7/8" test jt, test lower rams. LD test jt. Pull test plug. Install wear bushing. Jeff Jones of the AOGCC wavied witness of test. 14:00 - 19:00 5.00 CASE N DFAL COMP PU & RIH wI 3.83" mill, 27/8" MM on 2 7/8" 'PAC' DP from pipe shed to 3,034 ft. 19:00 - 20:30 1.50 CASE N DFAL COMP Con't RIH wI 3.83" mill on 4" DP from derrick to 8,184 ft. 20:30 - 21 :00 0.50 REMCM-N DFAL COMP Push liner wiper dart 8,184 ft to 8,551 ft. 21 :00 - 22:00 1.00 REMCM-N DFAL COMP Mill I push liner wiper dart 8,551 ft to 8,554 ft. 114 GPM, 1050 psi off btm, 1250 psi on btm. P/U Wt 130k, S/O Wt 130k, Rot Wt 130k, 25 RPM's TO 1.5k off btm, 3k on btm, WOM 3k. 22:00 - 00:00 2.00 REMCM-N DFAL COMP Push liner wiper dart 8,554 ft to 8,915 ft. 4/1/2003 00:00 - 02:00 2.00 REMCM-N DFAL COMP Push liner wiper dart 8,915 ft to LC @ 10,929 ft. Drillers tally. 02:00 - 02:30 0.50 REMCM-N DFAL COMP Attempt to test casing to 2000 psi. Broke over at 1890 psi. Abort test. 02:30 - 03:30 1.00 REMCM-N DFAL COMP Mill out remains of liner wiper dart, LC, FC, FS & 1 ft of new formation. 114 GPM, 1410 psi offbtm, 1650 psi on btm. P/U Wt 160k, S/O Wt 150k, Rot Wt 158k, 25 RPM's, TO 3k off btm, 5k on btm. WOM 3k. 03:30 - 04:30 1.00 REMCMIN DFAL COMP Circ 2 liner volumes. Rotate & reciprocate pipe. 115 GPM @ 1325 psi. Blow down Top Drive. 04:30 - 06:00 1.50 REMCM-N DFAL COMP POH wI 3.83" mill to 41/2" TOL @ 8,184 ft. Printed: 4/8/2003 9:00:17 AM ) ) BP EXPLORATION Operations Summary Report Drop opening ball & open circ sub wI 2500 psi. CBU. 348 GPM @ 3750 psi. Pump dry job. Blow down Top Drive. POH wI 3.83" mill to 3,034 ft. RU 2 7/8" handling equip. Con't POH racking back 27/8" DP to 23 ft. LD BHA. Clear rig floor. RU Schl e line. RIH & perf wI Tbg punch - HSD-WL-DP 1.56", 1606 PJ, HMX, 4 spf, 0.19" holes Perf interval 8,217 ft - 8,220 ft. Total 13 shots. RD Schl e line. RU 2 7/8" handling equip. MU 4 1/2" EZSV. 'YC' elevators slipped off stand of 2 7/8" 'PAC' DP. Incident investigation and remediation. RIH w/4 1/2" EZSV on 2 7/8" DP to 3,019 ft. RD 2 7/8" handling equip. Con't RIH w/4 1/2" EZSV on 4" DP to 9,929 ft. Con't RIH w/4 1/2" EZSV to 10,910 ft. P/U Wt 160k, S/O Wt 150k Set 41/2" EZSV @ 10,910 ft. Unsting from retainer. Est circ rate 190 GPM @ 1400 psi. Sting into retainer. Circ 2 open hole annular volumes @ 190 GPM I 1950 psi. Unsting from retainer. Circ 2 cased hole volumes @ 190 GPM I 1400 psi Sting into retainer. Est circ. RU Dowell, test lines. Pump 15 bbls CW 100, 30 bbls 10.5 ppg Mud Push, 75 bbls 15.8 ppg slurry, 5 bbls H20, 84 bbls 8.6 ppg mud. CIP @ 0330 hrs 4/2/2003 DFAL COMP Unsting from retainer. Circ excess cmt from well. Reciprocate pipe. 275 GPM @ 3000 psi. Est 20 bbls cmt @ surface. Spot 50 bbl seawater in 4 1/2" liner. 275 GPM @ 3100 psi POH wI setting tool to 8,230 ft. Displace well to clean seawater. 330 GPM @ 3700 psi. RIH wI setting tool to 41/2" EZSV @ 10,910 ft. Spot perf pill in 4 1/2" liner. POH wI setting tool to 7,034 ft. Slip & cut drlg line. Service Top Drive. POH wI setting tool to 2,982 ft. RU 2 7/8" handling equip. LD 2 7/8" 'PAC' DP & setting tool. Pressure test 4 1/2" x 7" x 9 5/8" casing to 2000 psi. O-K. PJSM on perf guns wI all personnel. PU & RIH wI toatal of 1640 ft of perf guns - 1130 ft loaded. Halliburton 2 1/2" 'Millennium' 60 deg phasing, 4 SPF, 26.5" penetration, 11gr HMX charges. Can't RIH wI perf guns to 2,786 ft on 2 7/8" DP from pipe shed. Can't RIH wI perf guns to 6,549 ft on 4" DP from derrick. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I Date From - To Hours Task Code NPT Phase 4/1/2003 06:00 - 07:30 1.50 REMCM-N DFAL COMP 07:30 - 10:00 2.50 REMCM-N DFAL COMP 10:00 - 10:30 0.50 REMCM-N DFAL COMP 10:30 -11:30 1.00 REMCM-N DFAL COMP 11 :30 - 13:00 1.50 REMCM-N DFAL COMP 13:00 - 15:00 2.00 REMCM-N DFAL COMP 15:00 - 16:00 1.00 REMCM-N DFAL COMP 16:00 - 18:00 2.00 REMCM-N DFAL caMP 18:00 - 21 :00 3.00 REMCM-N DFAL CaMP 21 :00 - 21 :30 0.50 REMCM-N DFAL caMP 21 :30 - 00:00 2.50 REMCM-N DFAL caMP 4/2/2003 00:00 - 01 :00 1.00 REMCM-N DFAL COMP 01 :00 - 01 :30 0.50 REMCM-N DFAL caMP 01 :30 - 02:00 0.50 REMCM-N DFAL COMP 02:00 - 02:30 0.50 REMCM-N DFAL COMP 02:30 - 03:30 1.00 REMCM-N DFAL caMP 03:30 - 05:00 1.50 REMCM-N 05:00 - 05:30 0.50 REMCM-N DFAL COMP 05:30 - 06:30 1.00 REMCM-N DFAL caMP 06:30 - 09:00 2.50 REMCM-P COMP 09:00 - 10:00 1.00 REMCM-N DFAL CaMP 10:00 - 11 :00 1.00 REMCM-N DFAL COMP 11 :00 - 12:30 1.50 REMCM-N DFAL caMP 12:30 - 13:30 1.00 REMCM-N DFAL caMP 13:30 - 14:00 0.50 REMCM-N DFAL COMP 14:00 - 15:30 1.50 REMCM-P caMP 15:30 - 16:00 0.50 REMCM-N DFAL caMP 16:00 - 19:00 3.00 REMCM-N DFAL CaMP 19:00 - 19:30 0.50 REMCM-P caMP 19:30 - 20:00 0.50 PERF P COMP 20:00 - 21 :30 1.50 PERF P COMP 21 :30 - 22:30 1.00 PERF P caMP 22:30 - 00:00 1.50 PERF P caMP Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Description of Operations Printed: 4/8/2003 9:00: 17 AM ) ) BP EXPLORATION OperéltionsSum maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-04 K-04B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/14/2003 Rig Release: 4/4/2003 Rig Number: Spud Date: 10/21/1983 End: 4/4/2003 Date From - To Hours Task Code NPT Phase Description ,of Operations 4/3/2003 00:00 ~ 02:00 2.00 PERF P COMP Con't RIH w/2 1/2" perf guns to 41/2" EZSV @ 10,906 ft Drill pipe measurement. 02:00 ~ 02:30 0.50 PERF P COMP Put guns on depth wi btm shot @ 10,760 ft. 02:30 ~ 03:00 0.50 PERF P COMP Hook up surface recorder. Pressure up to 2000 psi to fire guns. Good surface indication of guns firing. Loss 15 bbls. Perforated intervals as follows: 9120 ~ 9340 ft 9560 ~ 9800 ft 9850 ~ 9910 ft 10100 ~ 10380 ft 1 0430 ~ 1 0760 ft. Total of 1130 ft perforated. 03:00 - 04:00 1.00 PERF P COMP POH wi perf guns to 9,070 ft. (50 ft above top shot) Monitor well static. Pump dry job. 04:00 - 05:00 1.00 PERF P COMP POH wi perf guns LD 4" DP to 7,835 ft. 05:00 - 05:30 0.50 PERF P COMP Service Top Drive. Observe well @ 4 bbll hr static loss rate. 05:30 - 08:30 3.00 PERF P COMP POH wi perf guns LD 4" DP to 2,980 ft. 08:30 - 09:30 1.00 PERF P COMP RIH wi 4" DP from derrick to 4,940 ft. 09:30 - 11 :00 1.50 PERF P COMP POH wi perf guns LD 4" DP to 2,815 ft. 11:00 -11:30 0.50 PERF P CaMP RU 2 7/8" handling equip. 11 :30 - 12:30 1.00 PERF P COMP Con't POH wi perf guns. LD 2 7/8" DP to 1,640 ft. 12:30 - 13:00 0.50 PERF P COMP PU 2 1/2" perf gun handling equip. 13:00 - 16:00 3.00 PERF P COMP LD perf guns. Total 77 picks. All shots fired. 16:00 - 17:00 1.00 PERF P COMP RD perf gun handling equip. Clean rig floor. 17:00 - 17:30 0.50 RUNCOIVP COMP Pull wear bushing. RU for 41/2" L 80 IBT completion. 17:30 - 00:00 6.50 RUNCOIVP COMP M/U tailpipe and Baker S~3 packer. Baker Lock all connections below pkr. RIH with 41/2", 12.6#, L 80, IBT, Rg 3 completion to 8,100 ft. Average M/U torque 3800 ft-Ibs. P/U Wt 115k, S/O Wt 115k 4/4/2003 00:00 ~ 01 :30 1.50 RUNCOIVP COMP Fin RIH with 193 jts 41/2",12.6#, L 80, IBT, Rg 3 completion to 8,193 ft. Space out wi 3 pup jts. MU tbg hanger. Land completion wi WLEG @ 8,193 ft. 01 :30 ~ 02:00 0.50 RUNCOIVP COMP Cameron rep RILDS. 02:00 ~ 02:30 0.50 RUNCOrvP COMP Pressure test all surface circ lines. 02:30 ~ 05:30 3.00 RUNCOrvP COMP Reverse circ one tbg volume clean seawater followed wi inhibited seawater in annulus. 3 BPM 170 psi. 05:30 ~ 07:00 1.50 RUNCOIVP COMP Drop ball/rod. Pressure tubing to 3500 psi, set packer. Hold for 30 min tubing test, OK. Bleed tubing pressure to 1500 psi. Pressue annulus to 3500 psi for packer test, hold for 30 min, OK. Bleed off pressure and shear OCR valve. 07:00 - 07:30 0.50 WHSUR P COMP Set TWC. Test from below to 1000 psi. 07:30 - 09:30 2.00 WHSUR P COMP N/D BOP's. 09:30 ~ 11 :00 1.50 WHSUR P COMP N/U adaptor flange and tree. Test to 5000 psi. 11 :00 ~ 12:00 1.00 WHSUR P COMP RlU drill site maintenance lubricator. Pulled TWC. RID. 12:00 - 15:30 3.50 WHSUR P COMP RlU Little Red hot oil services. Test lines to 3500 psi. Pump 155 bbls diesel freeze protect. U-tube diesel. 15:30 - 16:00 0.50 WHSUR P COMP Installed BPV and tested to 1000 psi. 16:00 ~ 17:00 1.00 WHSUR P COMP Removed secondary annular valve from wellhead. Secured well. Rig released from K-04B at 1700 hrs 4/4/2003. Printed: 4/8/2003 9:00:17 AM ) / AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well k-04B Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,191.39' MD Window / Kickoff Survey: 7,217.00' MD (if applicable) Projected Survey: 11,012.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) c¥Dd~53 22-Apr-03 R i-: r ~: 1\',,1'1:: r1 ' t: 'v tt... ~ f=" [,=..' , APR 29 2003 PJaeks Œ1 & Gas COf¡S. C~Jmm~~T! A¡,,~ct10f~J Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA K Pad K-04B ~ Job No. AKZZ2340063. Surveyed: 30 March. 2003 Survey Report 17 April, 2003 Your Ref: APlS00292102302 Surface Coordinates: 5975278.00 N. 671453.00 E (70020' 17.9995" N. 148036' 31.4004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 975278.00 N, 171453.00 E (Grid) Surface Coordinates relative to Structure Reference: 2089.59 N, 1158.42 E (True) Kelly Bushing: 52. 59ft above Mean Sea Level Elevation relative to Project V Reference: 52.59ft Elevation relative to Structure Reference: 52. 59ft 5pe....,.....y-SUI'l DRILLING SERVices A Halliburton Company Survey Ref: svy4007 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B Your Ref: AP/SOO292102302 Job No. AKZZ2340063, Surveyed: 30 March, 2003 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) 7191.39 1.220 125.000 7137.78 7190.37 60.67 N 24.99 E 5975339.23 N 671476.59 E 65.61 Tie On Point AK-6 BP _IFR-AK 7217.00 1.240 127.290 7163.38 7215.97 60.35 N 25.43 E 5975338.91 N 671477.04 E 0.207 65.49 Window Point 7295.94 6.160 98.200 7242.14 7294.73 59.23 N 30.30 E 5975337.90 N 671481.94 E 6.4 76 66.34 7378.41 9.480 88.360 7323.84 7376.43 58.79 N 41.48 E 5975337.72 N 671493.12 E 4.326 70.28 7471.67 10.190 80.740 7415.73 7468.32 60.34 N 57.30 E 5975339.63 N 671508.90 E 1.588 77.84 ~ 7565.21 10.390 75.450 7507.77 7560.36 63.79 N 73.63 E 5975343.45 N 671525.15 E 1.032 87.36 7658.91 10.700 71.610 7599.88 7652.47 68.65 N 90.06 E 5975348.70 N 671541.47 E 0.820 98.22 7753.07 14.300 68.710 7691.80 7744.39 75.64 N 109.20 E 5975356.11 N 671560.44 E 3.880 112.09 7844.84 16.910 71.970 7780.18 7832.77 83.88 N 132.45 E 5975364.89 N 671583.50 E 2.999 128.71 7937.15 18.500 73.090 7868.11 7920.70 92.30 N 159.23 E 5975373.92 N 671610.08 E 1.761 146.86 8029.85 19. 1 30 72.750 7955.86 8008.45 101.08 N 187.81 E 5975383.35 N 671638.45 E 0.690 166.05 8123.44 19.310 69.670 8044.24 8096.83 111.01 N 216.97 E 5975393.94 N 671667.37 E 1.100 186.51 8218.18 19.020 71.610 8133.73 8186.32 121.32 N 246.30 E 5975404.92 N 671696.47 E 0.739 207.40 8292.46 18.170 71.020 8204.13 8256.72 128.90 N 268.74 E 5975413.01 N 671718.73 E 1.172 223.10 8405.22 17.520 74.370 8311.47 8364.06 139.20 N 301.71 E 5975424.06 N 671751.45 E 1.077 245.38 8497.76 20.850 76.790 8398.86 8451.45 146.71 N 331.17 E 5975432.25 N 671780.73 E 3.699 263.74 8530.88 21.540 79.250 8429.74 8482.33 149.19 N 342.88 E 5975435.00 N 671792.38 E 3.398 270.57 8562.21 22.360 80.800 8458.79 8511.38 151.22 N 354.42 E 5975437.28 N 671803.86 E 3.205 276.91 8591.79 23.560 84.440 8486.03 8538.62 152.69 N 365.85 E 5975439.02 N 671815.27 E 6.283 282.71 8622.80 25.970 91.830 8514.19 8566.78 153.08 N 378.81 E 5975439.70 N 671828.21 E 12.638 288.09 8653.83 28.160 99.820 8541.83 8594.42 151.61 N 392.83 E 5975438.55 N 671842.26 E 13.663 292.18 8683.89 31 .800 105.750 8567.87 8620.46 148.25 N 407.45 E 5975435.53 N 671856.95 E 15.602 294.76 8716.31 36.620 109.110 8594.68 8647.27 142.76 N 424.82 E 5975430.44 N 671874.44 E 15.964 296.44 -' 8747.38 39.880 110.760 8619.08 8671.67 136.19 N 442.89 E 5975424.29 N 671892.66 E 10.995 297.40 8777.54 42.420 112.450 8641.78 8694.37 128.88 N 461.34 E 5975417.40 N 671911.27 E 9.193 297.82 8812.02 47.990 113.880 8666.07 8718.66 119.25 N 483.82 E 5975408.28 N 671933.96 E 16.419 297.67 8843.12 53.220 113.950 8685.80 8738.39 109.51 N 505.78 E 5975399.04 N 671956.14 E 16.818 297.21 8869.78 57.560 114.660 8700.94 8753.53 100.47 N 525.77 E 5975390.47 N 671976.34 E 16.426 296.65 8904.96 61.000 116.930 8718.91 8771.50 87.31 N 552.99 E 5975377.93 N 672003.85 E 11.241 295.08 8938.40 63.170 119.090 8734.57 8787.16 73.43 N 579.07 E 5975364.65 N 672030.24 E 8.642 292.41 17 April, 2003 - 16:57 Page 20f5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B Your Ref: API 500292102302 Job No. AKZZ2340063, Surveyed: 30 March, 2003 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) 8973.08 66.300 120.910 8749.37 8801.96 57.74 N 606.22 E 5975349.59 N 672057.74 E 10.197 288.49 9001.03 69.170 122.170 8759.96 8812.55 44.21 N 628.26 E 5975336.57 N 672080.09 E 11.083 284.57 9033.46 73.220 122.390 8770.41 8823.00 27.82 N 654.21 E 5975320.77 N 672106.40 E 12.505 279.54 9066.39 77.680 123.330 8778.68 8831.27 10.53 N 680.98 E 5975304.10 N 672133.56 E 13.823 273.99 9096.86 82.510 124.040 8783.92 8836.51 6.12 S 705.95 E 5975288.03 N 672158.90 E 16.017 268.34 9123.55 85.800 124.150 8786.64 8839.23 21.00 S 727.93 E 5975273.65 N 672181.22 E 12.334 263.15 ~ 9159.31 90.120 127.930 8787.91 8840.50 42.02 S 756.81 E 5975253.30 N 672210.58 E 16.046 254.99 9190.58 91.670 132.120 8787.42 8840.01 62.12 S 780.75 E 5975233.75 N 672234.97 E 14.285 245.76 9214.41 91.850 136.460 8786.69 8839.28 78.75 S 797.80 E 5975217.52 N 672252.39 E 18.219 237.05 9251.04 92.220 139.700 8785.39 8837.98 105.98 S 822.25 E 5975190.85 N 672277.46 E 8.897 221.44 9280.34 93.330 141.850 8783.97 8836.56 128.65 S 840.76 E 5975168.61 N 672296.48 E 8.250 207.73 9310.76 92.410 143.520 8782.45 8835.04 152.81 S 859.17 E 5975144.87 N 672315.44 E 6.262 192.60 9343.40 90.800 144.200 8781.53 8834.12 179.16 S 878.41 E 5975118.97 N 672335.28 E 5.354 175.79 9377.74 88.200 144.230 8781.83 8834.42 207.01 S 898.49 E 5975091.58 N 672355.99 E 7.572 157.91 9405.88 87.040 145.520 8783.00 8835.59 230.01 S 914.67 E 5975068.96 N 672372.69 E 6.162 143.00 9439.64 88.460 150.280 8784.33 8836.92 258.58 S 932.59 E 5975040.81 N 672391.26 E 14.703 123.62 9470.99 91.230 153.490 8784.41 8837.00 286.22 S 947.36 E 5975013.51 N 672406.65 E 13.524 103.88 9499.21 92.660 156.060 8783.45 8836.04 311.73 S 959.38 E 5974988.28 N 672419.25 E 10.417 85.03 9531.72 93.150 160.440 8781.80 8834.39 341.88 S 971.40 E 5974958.42 N 672431.97 E 13.540 61.91 9563.25 92.960 163.920 8780.12 8832.71 371.85 S 981.04 E 5974928.68 N 672442.28 E 11.038 38.03 9589.28 93.210 167.850 8778.72 8831.31 397.06 S 987.38 E 5974903.63 N 672449.20 E 15.107 17.26 9624.70 93.270 172.390 8776.72 8829.31 431.88 S 993.44 E 5974868.94 N 672456.06 E 12.798 -12.48 9656.21 92.900 177.380 8775.02 8827.61 463.21 S 996.25 E 5974837.69 N 672459.58 E 15.857 -40.27 9684.00 92.470 180.950 8773.72 8826.31 490.97 S 996.65 E 5974809.95 N 672460.62 E 12.925 -65.69 ~ 9717.20 91.730 186.650 8772.50 8825.09 524.06 S 994.45 E 5974776.82 N 672459.17 E 17.301 -97.04 9749.66 92.4 70 190.060 8771.31 8823.90 556.15 S 989.74 E 5974744.63 N 672455.20 E 10.743 -128.44 9777.42 92.530 192.430 8770.10 8822.69 583.34 S 984.33 E 5974717.31 N 672450.41 E 8.532 -155.61 9811.89 90.620 196.300 8769.15 8821.74 616.72 S 975.78 E 5974683.76 N 672442.63 E 12.516 -189.68 9842.36 88.950 199.230 8769.27 8821.86 645.73 S 966.49 E 5974654.54 N 672434.00 E 11.068 -220.03 9869.76 88.150 202.040 8769.96 8822.55 671.36 S 956.84 E 5974628.69 N 672424.94 E 10.660 -247.40 9903.81 87.350 206.670 8771.30 8823.89 702.35 S 942.81 E 5974597.39 N 672411.62 E 13.789 -281.40 9934.55 86.910 209.850 8772.84 8825.43 729.39 S 928.28 E 5974570.03 N 672397.71 E 10.431 -311.96 9961.41 87.900 213.270 8774.05 8826.64 752.25 S 914.23 E 5974546.85 N 672384.20 E 13.243 -338.48 9998.15 89.750 217.030 8774.81 8827.40 782.27 S 893.09 E 5974516.35 N 672363.74 E 11 .403 -374.35 10029.08 88.030 220.400 8775.41 8828.00 806.40 S 873.75 E 5974491.79 N 672344.96 E 12.230 -404.09 17 April, 2003 - 16:57 Page 3 0'5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B Your Ref: API 500292102302 Job No. AKZZ2340063, Surveyed: 30 March, 2003 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10057.91 86.730 222.500 8776.73 8829.32 827.98 S 854.69 E 5974469.78 N 672326.40 E 10091.78 86.670 229.360 8778.68 8831.27 851.49 S 830.41 E 5974445.72 N 672302.66 E 10122.80 86.480 234.610 8780.53 8833.12 870.55 S 806.02 E 5974426.11 N 672278.72 E 10150.64 85.620 237.860 8782.45 8835.04 885.99 S 782.94 E 5974410.15 N 672255.99 E 10184.79 85.740 243.890 8785.03 8837.62 902.55 S 753.20 E 5974392.91 N 672226.64 E 10215.34 85.050 245.350 8787.48 8840.07 915.60 S 725.69 E 5974379.23 N 672199.44 E 10244.28 84.190 249.470 8790.19 8842.78 926.67 S 699.10 E 5974367.56 N 672173.10 E 10277.56 82.450 254.680 8794.07 8846.66 936.84 S 667.66 E 5974356.67 N 672141.91 E 10309.04 83.130 257.760 8798.02 8850.61 944.28 S 637.33 E 5974348.54 N 672111.76 E 10337.41 85.360 261.270 8800.86 8853.45 949.41 S 609.58 E 5974342.77 N 672084.13 E 10371.16 88.030 265.290 8802.81 8855.40 953.35 S 576.13 E 5974338.07 N 672050.78 E 10402.58 87.590 265.780 8804.01 8856.60 955.80 S 544.83 E 5974334.91 N 672019.54 E 10431.14 87.030 267.860 8805.35 8857.94 957.38 S 516.35 E 5974332.68 N 671991.10 E 10481.30 82.760 272.570 8809.82 8862.41 957.20 S 466.41 E 5974331.72 N 671941.18 E 10521.52 82.700 272.570 8814.91 8867.50 955.41 S 426.55 E 5974332.59 N 671901.29 E 10615.42 82.010 271.700 8827.40 8879.99 951.94 S 333.56 E 5974333.93 N 671808.23 E 10708.95 84.810 271.000 8838.13 8890.72 949.76 S 240.68 E 5974334.00 N 671715.33 E 10802.24 85.550 269.810 8845.97 8898.56 949.10 S 147.72 E 5974332.53 N 671622.39 E 10896.43 84.680 269.210 8853.99 8906.58 949.90 S 53.88 E 5974329.58 N 671528.59 E 10968.20 83.750 268.550 8861.22 8913.81 951.30 S 17.51 W 5974326.55 N 671457.25 E 11012.00 83.750 268.550 8865.99 8918.58 952.40 S 61.04 W 5974324.45 N 671413.76 E All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 22.836° (True). Magnetic Declination at Surface is 25.978°(20-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11012.00ft., The Bottom Hole Displacement is 954.35ft., in the Direction of 183.667° (True). 17 April, 2003 - 16:57 Page 4 of 5 BPXA Dogleg Vertical Rate Section Comment (°/1 DDft) 8.560 -431.38 20.221 -462.47 16.905 -489.50 12.049 -512.69 17.611 -539.50 5.272 -562.20 --- 14.482 -582.72 16.404 -604.30 9.944 -622.92 14.605 -638.42 14.282 -655.04 2.095 -669.44 7.534 -681.95 12.645 -701.16 0.149 -714.98 1.176 -747.88 3.085 -781.91 1 .498 -817.38 1.121 -854.54 1.586 -883.53 0.000 -901 .44 Projected Survey -- DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B Your Ref: API 500292102302 Job No. AKZZ2340063, Surveyed: 30 March, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7191.39 7217.00 11012.00 7190.37 7215.97 8918.58 60.67 N 60.35 N 952.40 S 24.99 E 25.43 E 61.04 W Tie On Point Window Point Projected Survey J - Survey tool program for K-04B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7191.39 0.00 7191.39 7190.37 11012.00 7190.37 BP High Accuracy Gyro (K-04) 8918.58 AK-6 BP _IFR-AK (K-04B) .~ 17 April, 2003 - 16:57 Page 50f5 Dril/Quest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well k-048 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,191.39' MD Window / Kickoff Survey: 7,217.00' MD (if applicable) Projected Survey: 11,012.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) ~d~d63 22-Apr-03 RECE\VED APR 2 9 2.003 Alasiœ or¡ & Gas Cons. eornmiMlion Andt0rag8 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA K Pad K-04B MWD ---- Job No. AKMW2340063, Surveyed: 30 March, 2003 Survey Report 17 April, 2003 Your Ref: API 500292102302 Surface Coordinates: 5975278.00 N, 671453.00 E (70° 20' 17.9995" N, 148036'31.4004" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 -" Surface Coordinates relative to Project H Reference: 975278.00 N, 171453.00 E (Grid) Surface Coordinates relative to Structure Reference: 2089.59 H, 1158.42 E (True) Kelly Bushing: 52. 59ft above Mean Sea Level Elevation relative to Project V Reference: 52. 59ft Elevation relative to Structure Reference: 52. 59ft sper-ar-ay-sul! DRILLING seRVIc:es A Halliburton Company Survey Ref: 5vy4008 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B MWD Your Ref: AP/S00292102302 Job No. AKMW2340063, Surveyed: 30 March, 2003 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) 7191.39 1.220 125.000 7137.78 7190.37 60.67 N 24.99 E 5975339.23 N 671476.59 E 65.61 Tie On Point MWD Magnetic 7217.00 1.240 127.290 7163.38 7215.97 60.35 N 25.43 E 5975338.91 N 671477.04 E 0.207 65.49 Window Point 7295.94 6.160 98.200 7242.14 7294.73 59.23 N 30.30 E 5975337.90 N 671481.94 E 6.476 66.34 7378.41 9.480 88.360 7323.84 7376.43 58.79 N 41.48 E 5975337.72 N 671493.12 E 4.326 70.28 7471.67 10.190 80.740 7415.73 7468.32 60.34 N 57.30 E 5975339.63 N 671508.90 E 1.588 77.84 ~ 7565.21 10.390 75.450 7507.77 7560.36 63.79 N 73.63 E 5975343.45 N 671525.15 E 1.032 87.36 7658.91 10.700 71.610 7599.88 7652.47 68.65 N 90.06 E 5975348.70 N 671541.47 E 0.820 98.22 7753.07 14.300 69.260 7691.80 7744.39 75.53 N 109.24 E 5975356.01 N 671560.48 E 3.860 112.01 7844.84 16.910 71.970 7780.18 7832.77 83.68 N 132.53 E 5975364.69 N 671583.58 E 2.952 128.55 7937.15 18.500 73.100 7868.11 7920.70 92.09 N 159.31 E 5975373.71 N 671610.16 E 1.762 146.70 8029.85 19. 1 30 72.510 7955.86 8008.45 100.93 N 187.87 E 5975383.20 N 671638.51 E 0.710 165.93 8123.44 19.310 69.830 8044.24 8096.83 110.88 N 217.02 E 5975393.81 N 671667.43 E 0.962 186.41 8218.18 19.020 71.540 8133.72 8186.31 121.17 N 246.37 E 5975404.77 N 671696.54 E 0.667 207.28 8292.46 18.170 71.430 8204.13 8256.72 128.69 N 268.83 E 5975412.80 N 671718.82 E 1.145 222.93 8405.22 17.520 74.370 8311.46 8364.05 138.86 N 301.84 E 5975423.72 N 671751.59 E 0.985 245.12 8497.76 20.850 76.830 8398.85 8451 .44 146.37 N 331.30 E 5975431.90 N 671780.87 E 3.702 263.47 8530.88 21.540 79.180 8429.73 8482.32 148.85 N 343.01 E 5975434.65 N 671792.52 E 3.304 270.30 8562.21 22.360 80.690 8458.79 8511.38 150.89 N 354.54 E 5975436.96 N 671804.00 E 3.177 276.66 8591.79 23.560 84.320 8486.03 8538.62 152.39 N 365.98 E 5975438.72 N 671815.40 E 6.273 282.48 8622.80 25.970 91.880 8514.19 8566.78 152.78 N 378.94 E 5975439.41 N 671828.34 E 12.819 287.87 8653.83 28.160 99.630 8541.83 8594.42 151.33 N 392.95 E 5975438.28 N 671842.39 E 13.364 291.97 8683.89 31.800 105.640 8567.87 8620.46 148.01 N 407.58 E 5975435.29 N 671857.09 E 15.686 294.59 8716.31 36.620 109.110 8594.68 8647.27 142.54 N 424.95 E 5975430.22 N 671874.58 E 16.034 296.29 -' 8747.38 39.880 110.850 8619.07 8671.66 135.96 N 443.02 E 5975424.05 N 671892.80 E 11.050 297.23 8777.54 42.420 112.640 8641.78 8694.37 128.60 N 461.45 E 5975417.11 N 671911.39 E 9.283 297.60 8812.02 47.990 113.930 8666.07 8718.66 118.92 N 483.91 E 5975407.95 N 671934.07 E 16.370 297.40 8843.12 53.220 113.550 8685.80 8738.39 109.25 N 505.91 E 5975398.79 N 671956.28 E 16.843 297.02 8869.78 57.560 114.950 8700.94 8753.53 100.23 N 525.90 E 5975390.23 N 671976.47 E 16.842 296.48 8904.96 61 .000 117.810 8718.91 8771.50 86.79 N 552.98 E 5975377.41 N 672003.85 E 12.018 294.59 8938.40 63.170 119.390 8734.56 8787.15 72.64 N 578.92 E 5975363.86 N 672030.11 E 7.716 291.62 17 April, 2003 - 17:10 Page 20f5 DrmQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for P8U _WOA K Pad - K-048 MWD Your Ref: AP/SOO292102302 Job No. AKMW2340063, Surveyed: 30 March, 2003 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) (O/100ft) 8973.08 66.300 120.080 8749.36 8801.95 57.08 N 606.15 E 5975348.93 N 672057.69 E 9.203 287.85 9001.03 69.170 127.100 8759.96 8812.55 42.77 N 627.67 E 5975335.11 N 672079.53 E 25.405 283.01 9033.46 73.220 128.060 8770.42 8823.01 24.05 N 651.99 E 5975316.95 N 672104.27 E 12.799 275.20 9066.39 77.680 123.960 8778.69 8831.28 5.33 N 677.77 E 5975298.83 N 672130.47 E 18.127 267.95 9096.86 82.510 124.670 8783.93 8836.52 11.59 S 702.55 E 5975282.48 N 672155.63 E 16.017 261.98 9123.55 85.800 127.460 8786.65 8839.24 27.22 S 724.01 E 5975267.35 N 672177.44 E 16.126 255.90 '--" 9159.31 90.120 130.150 8787.92 8840.51 49.60 S 751.85 E 5975245.60 N 672205.79 E 14.228 246.07 9190.58 91.670 144.840 8787.43 8840.02 72.59 S 772.91 E 5975223.10 N 672227.37 E 47.232 233.06 9214.41 91.850 136.460 8786.70 8839.29 90.99 S 788.00 E 5975205.05 N 672242.88 E 35.157 221.96 9251.04 92.220 139.280 8785.40 8837.99 118.14 S 812.56 E 5975178.47 N 672268.05 E 7.760 206.47 9280.34 93.330 141 . 190 8783.98 8836.57 140.63 S 831.28E 5975156.41 N 672287.27 E 7.533 193.00 9310.76 92.410 143.920 8782.45 8835.04 164.75 S 849.75 E 5975132.72 N 672306.29 E 9.459 177.94 9343.40 90.800 144.390 8781.54 8834.13 191.20 S 868.85 E 5975106.72 N 672326.00 E 5.138 160.98 9377.74 88.210 145.390 8781.84 8834.43 219.29 S 888.60 E 5975079.09 N 672346.38 E 8. 085 142.76 9405.88 87.040 144.570 8783.00 8835.59 242.31 S 904.73 E 5975056.44 N 672363.04 E 5.076 127.80 9439.64 88.460 149.720 8784.33 8836.92 270.64 S 923.03 E 5975028.54 N 672381.97 E 15.812 108.80 9470.99 91.230 152.590 8784.41 8837.00 298.09 S 938.15 E 5975001.43 N 672397.72 E 12.722 89.36 9499.21 92.660 157.820 8783.46 8836.05 323.69 S 949.97 E 5974976.12 N 672410.13 E 19.202 70.36 9531.72 93.150 160.820 8781.81 8834.40 354.06 S 961.44 E 5974946.02 N 672422.28 E 9.338 46.82 9563.25 92.960 163.550 8780.13 8832.72 384.03 S 971.07 E 5974916.27 N 672432.60 E 8.667 22.93 9589.28 93.210 167.410 8778.73 8831.32 409.19 S 977.59 E 5974891.27 N 672439.69 E 14.839 2.28 9624.70 93.270 172.120 8776.72 8829.31 443.98 S 983.87 E 5974856.63 N 672446.76 E 13.277 -27.35 9656.21 92.900 177.410 8775.03 8827.62 475.30 S 986.74 E 5974825.38 N 672450.35 E 16.805 -55.10 9684.00 92.470 180.850 8773.72 8826.31 503.06 S 987.16 E 5974797.65 N 672451.40 E 12.461 -80.51 ~ 9717.20 91.730 185.070 8772.51 8825.10 536.18 S 985.44 E 5974764.49 N 672450.45 E 12.896 -111.71 9749.66 92.470 190.990 8771.32 8823.91 568.29 S 980.92 E 5974732.29 N 672446.65 E 18.367 -143.06 9777.42 92.530 193.910 8770.10 8822.69 595.37 S 974.94 E 5974705.08 N 672441.30 E 10.511 -170.33 9811.89 90.620 197.010 8769.16 8821.75 628.57 S 965.75 E 5974671.68 N 672432.87 E 10.560 -204.50 9842.36 88.950 199.790 8769.27 8821.86 657.48 S 956.14 E 5974642.56 N 672423.92 E 10.643 -234.87 9869.76 88.150 202.510 8769.96 8822.55 683.02 S 946.26 E 5974616.79 N 672414.63 E 10.344 -262.25 9903.81 87.350 207.170 8771.30 8823.89 713.89 S 931.97 E 5974585.61 N 672401.05 E 13.875 -296.24 9934.55 86.910 210.090 8772.84 8825.43 740.83 S 917.26 E 5974558.33 N 672386.96 E 9.594 -326.78 9961.41 87.900 212.960 8774.06 8826.65 763.70 S 903.23 E 5974535.15 N 672373.46 E 11.292 -353.30 9998.15 89.750 217.350 8774.81 8827.40 793.73 S 882.09 E 5974504.65 N 672353.00 E 12.964 -389.18 10029.08 88.030 219.740 8775.41 8828.00 817.91 S 862.82 E 5974480.03 N 672334.29 E 9.519 -418.95 17 April, 2003 - 17:10 Page 3 0'5 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B MWD Your Ref: AP/S00292102302 Job No. AKMW2340063, Surveyed: 30 March, 2003 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10057.91 86.730 223.840 8776.73 8829.32 839.38 S 843.63 E 5974458.13 N 672315.60 E 10091.78 86.670 230.630 8778.68 8831.27 862.32 S 818.82 E 5974434.62 N 672291.32 E 10122.80 86.480 234.870 8780.54 8833.13 881.06 S 794.18 E 5974415.33 N 672267.12 E 10150.64 85.620 238.530 8782.45 8835.04 896.31 S 770.97 E 5974399.55 N 672244.26 E 10184.79 85.740 238.960 8785.03 8837.62 913.98 S 741.86 E 5974381.22 N 672215.56 E 10215.34 85.050 245.730 8787.48 8840.07 928.10 S 714.90 E 5974366.49 N 672188.94 E 10244.28 84.190 249.850 8790.20 8842.79 938.99 S 688.23 E 5974354.99 N 672162.52 E 10277.56 82.450 254.910 8794.07 8846.66 949.00 S 656.74 E 5974344.27 N 672131.27 E 10309.04 83.130 258.120 8798.02 8850.61 956.28 S 626.38 E 5974336.29 N 672101.08 E 10337.41 85.360 261.640 8800.87 8853.46 961.24 S 598.60 E 5974330.70 N 672073.42 E 10371.16 88.030 264.190 8802.81 8855.40 965.39 S 565.16 E 5974325.79 N 672040.09 E 10402.58 87.590 265.460 8804.01 8856.60 968.22 S 533.90 E 5974322.24 N 672008.90 E 10431.14 87.030 267.680 8805.35 8857.94 969.93 S 505.42 E 5974319.88 N 671980.47 E 10481.30 82.760 271.770 8809.82 8862.41 970.17 S 455.48 E 5974318.49 N 671930.55 E 10521.52 82.700 272.770 8814.91 8867.50 968.59 S 415.62 E 5974319.16 N 671890.66 E 10615.42 82.010 269.950 8827.40 8879.99 966.38 S 322.59 E 5974319.25 N 671797.60 E 10708.95 84.810 271.810 8838.14 8890.73 964.95 S 229.70 E 5974318.55 N 671704.71 E 10802.24 85.550 270.690 8845.98 8898.57 962.92 S 136.77 E 5974318.45 N 671611.75 E 10896.43 84.680 269.220 8854.00 8906.59 963.00 S 42.92 E 5974316.24 N 671517.93 E 10968.20 83.750 268.490 8861.23 8913.82 964.42 S 28.47 W 5974313.18 N 671446.59 E 11012.00 83.750 268.490 8866.00 8918.59 965.57 S 71.99 W 5974311.03 N 671403.10 E All data is in Feet (US Survey) 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 Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 22.836° (True). Magnetic Declination at Surface is 25.979°(19-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11012.000., The Bottom Hole Displacement is 968.25ft., in the Direction of 184.264° (True). 17 April, 2003 - 17:10 Page 4 0£5 BPXA Dogleg Vertical Rate Section Comment (o/100ft) 14.905 -446.18 20.015 -476.95 13.658 -503.79 13.474 -526.85 1.304 -554.43 22.204 -577.91 ~ 14.482 -598.29 15.980 -619.74 10.344 -638.23 14.634 -653.58 10.930 -670.38 4.275 -685.13 8.008 -697.75 11.764 -717.36 2.471 -731.38 3.066 -765.44 3.587 -800.17 1.435 -834.37 1.809 -870.86 1.644 -899.88 0.000 -917.83 Projected Survey ~ DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA K Pad - K-04B MWD Your Ref: API 500292102302 Job No. AKMW2340063, Surveyed: 30 March, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7191.39 7217.00 11012.00 7190.37 7215.97 8918.59 60.67 N 60.35 N 965.57 S 24.99 E 25.43 E 71.99 W Tie On Point Window Point Projected Survey ~ Survey toollJroQram for K-04B MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7191.39 0.00 7191.39 7190.37 11012.00 7190.37 BP High Accuracy Gyro (K-04) 8918.59 MWD Magnetic (K-04B MWD) J "- 17 April, 2003 - 17:10 Page 50f5 DrillQuest 3.03.02.005 ~1I~:~ ,1'l ,-~ 1 I "L ~ . ) !Æ~!Æ~J~!Æ ) jI AI1ASIiA. OIL AND GAS CONSERVATION COM:MISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit K-04B BP Exploration (Alaska), Inc. Pennit No: 202-253 Surface Location: 1942' SNL, 1185' EWL, Sec. 04, TIIN, RI4E, UM Bottomhole Location: 2934' SNL, 1129' EWL, Sec.,04, TIIN, RI4E, UM ' Dear Mr. Crane: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennìts 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 tenns and 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 7!!- day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section "..-' (, I\-· ¡ 1111 f} ~ Hole 8-1/2" 6-1/8" " STATE OF ALASKA-\ ALASKA.....l AND GAS CONSERVATION COMM¡,.A~ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory D Stratigraphic Test II Development Oil D Service D Development Gas D Single Zone D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 53.291 Prudhoe Bay Fjeld I Prudhoe 6. Property Designation Bay Pool /" ADL 028303 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / K-04B 9. Approximate spud dat~/ 01/15/03 ../ Amount $200,000.00 14. Number of acres in property 15. Proyosed depth (MD and TVD) 2560 108741 MD 189331 TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 92 Maximum surface 2490 psig, At total depth (TVD) 88001 I 3370 psig Setting Depth T ('IP Rotom enQth ~D TVD Mil ryn 12711 7100' 70991 8371' 83281 26531 82211 81711 108741 89331 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work D Drill II Redrill D Re-Entry D 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 1942' SNL, 11851 EWL, SEC. 04, T11N, R14E, UM At top of productive interval 20101 SNL, 19411 EWL, SEC. 04, T11N, R14E, UM At total depth 2934' SNL, 11291 EWL, SEC. 04, T11N, R14E, UM Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well / ADL 028304,11291 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 7250' MD Maximum Hole Angle 18. Casin9 Program Specifications Sl7e CasinÇl WeiQht Grade CouplinQ 7" 26# L-80 BTC-Mod 4-1/2" 12.6# L-80 IBT-M Ouantity of çement (j1clude ~taQ~ çt~aJ 248 sx Class IG' 315 sx Class 'G' RI:Cl:lv[n 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 Casing 9860 feet 8793 feet 9655 feet 8800 feet Length Plugs (measured) CIBP set at 9655' (O~ OEC 2 J 2002 - aslèaDiI & Gas Gons. CommlssJ Anchorage on Junk (measured) Size Cemented MD TVD 8 cu yds concrete 1101 1101 3746 cu ft Permafrost II 26911 2691' 1822 cu ft Class 'G', 132 cu ft PF lei 8348' 8347' 325 cu ft Class IG' 80921 - 8381' 80911 - 83801 90 cu ft Class IG' 81011 - 9858' 81001 - 8793' Structural Conductor Su rface Intermediate Production Liner Liner 110' 20" x 30" 2652' 13-3/8" 83121 9-5/8" 280' 7" 1757' 2-7/8" true vertical Open: 9421' - 9440', 9460' - 9480', 9500' - 9521', 9540' - 9560', 9580' - 9600'; Open Below Bridge Plug: 9680' - 9770', 9681' - 9770'; Sqzd: 9310'- 9370', 9420' - 9421', 9440' - 9460', 9480' - 9500', 9521' - 9540', 9560' - 9580', 9600' - 9630' Open: 8794' - 8795', 8795' - 8796', 8796' - 8797', 8798' - 8799', 8800' - 8800'; Open Below Bridge Plug: 8798' - 8791', 8798' - 8791'; Sqzd: 8792'- 8793', 8794' - 8796', 8795' - 8795', 8796' - 8796', 8797' - 8798', 8799' - 8800', 8800' - 8800' Perforation depth: measured 20. Attachments II Filing Fee D Property Plat D BOP Sketch D Diverter Sketch II Drilling Program II Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report D 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michael Triolo, 564-5774 Prepared By Name/Number: Sondra Stewman, 564-4750 ~.~~~ ~~;~ D~e 1~-J3~~ Permit Number API Number ~ApE!Q,val D,a~e See cover letter Zo ¿ - .z. 5" .3 50- 029-21023-02 'i / /tl :'.) for other reQuirements Conditions of Approval: Samples Required 0 Yes 181 No Mud LÓg Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required 181 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: Ti{"~ -t- E v PE j-fC '5S' c.?C f ~ ¡' . ORIGINAL SIGNED BY M L. Bill Cqmmissioner s'-' - t> Approved By Form 10-401 Rev. 12-01-85 by order of the commission Date ,\ I I J /7//1 ð Submit In Triplicate .......' ;. \ r "\ ~ t \1 i"--\ f ) Greater Prudhoe Bay K-04B Permit ) Well Summary I Well Name: I K-048 I Type of Well (producer or injector): Surface Location: K-04B Target Start: K-04B Target End: I AFE Number: I Ivishak Zone 1 A/1 B Horizontal Sidetrack ./ 1,9421 FNL 1,1851 FWL, Sec. 4, T11 N, R14E X = 671,453.00 Y = 5,975,278.00 2,0101 FNL 1,9411 FWL, Sec. 4, T11 N, R14E X = 672,211.00 " Y = 5,975,228.00 Z = 8,785' TVDss 2,9341 FNL, 1,1291 FWL, Sec. 4, T11 N, R14E X = 671,422.00 rY = 5,974,285.00 Z = 8,880' TVDss I PBD4P1791 I Rig: I Nabors 2ES / I Estimated Start Date: I Jan. 15m 2002 I Well MD I 10,874' Summary: I Operating days to complete: I 20.25 I I Well TVDrkb: TD I 8,933 I I Max Inc. I 92° I I KBE I 53.29' /' Decomplete motherbore and sidetrack out of existing 47#, 9-%" casing into the./ Colville formation, drill to top Sag, set and cement 7" 26# drilling liner, directionally drill 6-%" hole, land horizontally in the Ivishak Z1 A/B sands. Geosteer horizontally through the Z1A/B target sands to TD at 10,874' MD. Run, cmt and test a 4-%" ~ solid liner, perforate, and complete with a 4-%" L-80 gas lift completion. Target Estimates: Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserve -(,;'?mmbbl Production rate: ~;d Production rate: 1,300 bId Current Well Information General Well Name: Original Well API #: Sidetrack API #: Well Type: Current Status: Last H2S Sample: Cement: TD I PBTD: BHP: BHT: Is this well frac'd? K-04 50-029-21023-00 50-029-21807 -02 Ivishak Zone 1 A/B P Planned pre-rig eco ../ TOC: 'Z/,91 , 0 to isolate coil tubing ST, K-04A Tubing 'at ±7,300' MD o ppm /' Estimated top of cement on 9-%" casing @ 5,148' MD 7" casing cemented over liner top @ 8,092' MD. Pumped -56 bbls of 16.0 ppg Class G cement. Had ~rill up 211' of hard cement on top of liner top packer during cleanout trip. 7,910' MD TOC inside 5-%" tubing 3,370 psi @ 8,800' TVDss (7.4ppg EMW). Estimated 185°F@ 8,800' TVDss Estimated No Version #1, 12/22/2002 Mechanical Condition K-04 Wellhead: Base Flange height: Nabor 2ES: Tubing: Liner: Casing Casing Head: Casing Hanger: Tubing Spool: Tubing Head Adapter: Tbg. Hanger: Tree: Open Perfs: Casing Fluids: Materials Needed ') Greater Prudhoe Bay K-04B Permit ) 13-%" 5M McEvoy SSH with 9-%" mandrel hanger Above MSL = 24.79' KB I MSL = 53.29' 5-%",17.0#, L-80, BTC with planned tubing cut @ -7,300' MD. -With PBTD @ planned TOC: -7,910' MD 7" , 26# L-80 liner top @ 8,092' MD. Surface: 13-%",72#, L-80, BTRS to 2,691' MD Intermediate: 9-%", 47#, L-80, BTRS to 8,346' MD Production: 7", 26#, L-80, BTRS from 8,092 - 8,993' MD McEvoy 20" Slip on weld , 3,000 psi 9-%" McEvoy Mandrel Hanger with 9-%" packott McEvoy 13%", 5M Split Speed Head McEvoy 13%" X 6-%", 5M McEvoy 13%" x 7" with 7" TC4S thread top and btm (5 seal) 7", CIW type 'J' BPV McEvoy 5M,6-%" Currently from 9,310- MD to 9,600' MD (pl~ned to be abandoned at Pr-rig work) SW with diesel cap down to -2,200' TVD ïntermedïate Section: Amount 1,270' 2 each 1 assembly 1 each 1 each Production Liner: Amount 2,660' 65 each 1 each 1 assembly 2 each 1 each Completion: As Contingency Amount 8,200' 1 each 1 each 3 each 2 each 2 each 1 each 1 each Description 7" 26#, L-80, BTC-Mod Casing 7" Straight Blade Centralizers 4" DP X 7" Casing Baker plug assembly 9-%" x 7" ZXP liner top packer 9-%" Baker WindowMaster Whipstock Description 4 Y2", 12.6#, L-80, IBT-Mod Solid Liner 4 Y2" X 5 %" x 8" Straight Blade Centralizers 4- Y2" Halliburton float shoe Baker Liner Cementing Assembly 4 %", 12.6#, L-80, IBT-M; 10' Solid Short Joints 4-%" x 7" ZXP with HMC hanger Description 4 %" 12.6 Iblft, L-80, BTC-Mod tubing Baker S-3 Packer 7" X 4- Y2" Halliburton 4-%" XN-Nipple (3.725" ID) Halliburton 4-%" X-Nipple (3.813" ID) Camco 4-%" X 1-Y2" MMG Gas Lift Mandrels Camco 4-Y2" X 1" KBG-2 Gas Lift Mandrels 4-Y2" WLEG 6-%", 5m Cameron Tree 2 ) Surface and Anti-Collision Issues Greater Prudhoe Bay K-04B Permit , -) /'" Surface Shut-in Wells: Wells K-17 & K-14 are on either side of K-04. K-17 is -60' away and K-14 is -30' away. Therefore neither of the well houses needs to be removed for the rig move. No surface shut-in's are required. . Ensure the well house is removed from the K-04 well. Disconnect the S-riser and the knock-out spool prior to moving the rig over the well. Close Approach Wells: There are NO close approach wells associated with this profile. Well Name Current Status N/A Production Priority N/A N/A Well Control Precautions N/A Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum pot71ial surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- Maximum anticipated BHP: 3,370 psi @ 8,800' TV9ss - Ivishak Maximum surface pressure: 2,490 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · · · Planned BOP test pressure: · Planned completion fluid: 3,500 psi (the 9-%" & 7" casing will be tested to 3,500 psi) Estimated 8.6 ppg Seawater / 6.8 ppg Diesel , BOPE.Rating" 5,000 psi Working Pressure (entire stack and valves 'PJ . ed BOPE:TestPres. ~5 ¿' /250 psi Rams & Valves ( ~ 2,500/250 psi Annular Disposal · NO ANNULAR INJECTION ON THIS WELL. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Mud PrOQram 9-0/8" Window Milling Mud Properties: Density (ppg) Plastic vis 10.1 12 -15 8-¥2" Drilling Mud Properties: Density (ppg) Plastic vis 10.1 -./ 13 - 20 YP 25 - 35 YP 15 - 25 6 %" Production Hole Mud Properties: Density (ppg) Plastic vis YP 8.4 - 8.5 4 - 7 22 - 26 NOTE: See attached Baroid mud recommendation LCM Restrictions: Follow the attached LCM Decision Tree I LSND HTHP PH TauO Viscosity <10 9.0 - 9.5 6-9 55 - 70 LSND HTHP PH TauO Viscosity <8 9.0 - 9.5 3-7 45 - 55 I Low Density Quickdril LSRV pH MBT API FI <12,000 cp 8.5 - 9.0 <3 N/C 3 ") Great; Prudhoe Bay K-04B Permit Formation Markers Formation Tops 1t MD ft TVDss 1t TVD Pore psi EMW (ppg) Hydrocarbons KOP (CM2) 7,250 7,196 7,249 10. I Top HRZ 7,623 7,562 7,615 LCU 7,833 7,762 7,815 Top Kingak D 7,967 7,890 7,943 Top Sag River 8,371 8,275 8,328 3,169 7.4 Yes Top Shublik 8,424 8,325 8,378 3,188 7.4 Yes TSAD 8,481 8,379 8,432 3,208 7.4 Yes TCGL 8,594 8,485 8,538 3,249 7.4 Yes TZ1B 8,889 8,705 8,758 3,334 7.4 Yes TDF 9,008 8,757 8,810 3,354 7.4 Yes Land 9,175 8,785 8,838 3,364 7.4 Yes TD 10,874 8,880 8,933 3,401 7.4 Yes CasinglTubing Program :;ìt~~â ,. ... ", 8-Y2" 7" Casing 26.0# L-80 BTC-Mod 1,271' 7,100' 17,099' 8,371' I 8,328' ,.,/ 6%" 4 %" SoLid 12.6# L-80 IBT-M 2,653' 8,221' I 8,171' 10,874' 18,933' Tubing 4 Y2" GL 12.6# L-80 IBT-M 8,191' 29' I 29' 8,220' I 8,170' Cement Calculations Casine Size I 7" 26 Ib/ft L-80 BTC-M - Single Stage Basis I 30% excess - TOC: 6,900' MD Total Cement Volume: Wash None Spacer 30 bbls OfæC sified Spacer (Mudpush XL Des~~"'3V~ighted to 11.5 ppg Tail 51.3 bbls 24 sks) 15.8lb/gal Class G cementc.1§/6uftlsx with 0.3% D065, 0.04% D8 ,0.35% D167, 0.2% D046 ....." Temp I BHST::= 1650 F from SOR (use actual temps recorded by MWO @ TO) Casine Size 14-%" 12.6 Ib/tt L-80 IBT-M - Solid Liner Basis I 40% excess - TOC: 200' MD above the top of the Liner Top Packer Liner Top Packer: ::= 8,220' MD Total Cement Volume: Wash 15 bbls CW100 Spacer 30 bbls ~~sified Spacer (Mudpush XL Design) Weig~~~o 10.5 ppg ~~I__~~~~:~~~ Temp I BHST::= 1850 F from SOR (use actual temps recorded by MWO @ TO) 7" String Centralizer Placement a) Run a total of 2 solid straight blade centralizers. Run one on each shoe joint (Jts 1 and 2). The centralizer on joint 1 (bottom shoe joint) should be locked down 4 to 5' from the shoe, to allow the end of the casing to be picked up off the bottom of the hole. The other should be locked down in the middle of the joint.Do not run any centralizers on the rest of the liner. 4 V2" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. Do not put any centralizers in the 7" x 4-%" liner lap. . 4 ') Greater Prudhoe Bay K-04B Permit "") i Bit Recommendations /::·w~~~~,·:; ;i!.~~[~$~~¡'~W:~; .:{;'~~\~~~.~~'~J~:~~,.p-" Interm. 8-%" 7,250' - 8,371' Prod. 6 %" 8,371' - 1 0,874' ·:::~'ii:'0:'~~t·/~\~~~~~lg;~0,';~:'i:·'~'~:::;;:.::;!:_·~;::'~i;èt:,~.: ;'~};,~.~~:I~~:Xt·:. f;~~~.~~~.'~:, ,,::'~~~:~~i:~ TBD 8x12 TBD 6x10 Survey and Logging Program 8-%" Hole Section: While Drilling: Wireline Log in 6 Ye" Hole Sections: While Drilling: KOP in Colville, drill through HRZ I Kingak, drill to Top Sag MWD IGR I Res I PWD None Geosteer through Ivishak Zone 1 A and 1 B MWD I GR I PWD I Den I Neu I ABI (Den/Neu recorded only) Motors and Required Doglegs BHA# 1 . Motor SizEnind.Motor Required ..', .. -.. 7" Sperydrill 7/8, 6.0 stg, FTC Performance motor with adj bend housing @ 1.50 wI 8.25" concentric sleeve 4 3,A" Sperrydrill 4/5, 6.3 stg, performance motor wI 1.50 adj bend housing wI 5.75" concentric sleeve & ABI ." RPMs·. ,',' Required. Doølens". 80-100 Maximum build: 4.0°/100' 60-80 Maximum build: 14.0°/100' 3 .' Flow: Rate·; 450-550 gpm 250-275 gpm Scope of Work Planned Pre-Ria Work: 1. Rig up slickline, drift tubing and 2-%" tubing for upcoming P&A of existing perforations from 9,310' - 9,770' MD (CIBP set at -9,655' MD by CTU on 3/13/98). MU GR/JB and drift 2-%" tubing down as far as possible. (BP setting depth -9,270' MD). ",.- MU 2-%" Halliburton CIBP, RIH with CTU and set as close to the top of perfs as possible (± 9,270' MD). If hole conditions dictate it may be necessary to set the BP higher. The State has verbally OK'd this as long as the attempt to set lower was tried. Release from CIBP and POOH, LD setting tool. RIH with CTU to the CIBP and lay a 15.8 ppg class 'G' cement plug to fill the 2-%" liner from the top of the ~nd extend up into the 4-¥2" and 5-%" tubing -200'. Estimated minimum cement volume needed is 0.5 barrels. NOTE: The AOGCC has requested that the top of cement be brought up into the tubing . ""'100', therefore the minimum top of cement should be -8,000'. As outlined above, the job is planned to bring cement -200' into the tubing tail to help assure isolation is achieved. Top of cement may extend further up into the tubing as long as it doe~ot interfere with the upcoming tubing cutting operations (planned tubing cut :t7,300' MD). Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. Pull GL V out of GLM #2 @ 7,689' MD. Liquid pack both the tubing and 9-%" x 5%" annulus to surface. Test the integrity of the cement plug and 9-%" casing by simultaneously pressure testing both the tubing and 9-%" annulus to 3,000 psi for 30 minutes. NOTE: This step should be done prior to the tubing cut to allow additional trouble-shooting if either the cement plug or 9-%" casing is leaking. RU E-line. Cut the 5%" L-80 tubing at approximately 7,300' MD. The use of a jet or chemical cutter is at the discretion of the Wells Group Representative. This cut will not be fished, however is critical to the successful decompletion. Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2,200' MD with diesel. The well should not be left with methanol as a freeze protect fluid, diesel only. ./ 2. 3. t/"~ 4. ~/ 5. 6. 7. 8. 5 9. '\ Greater Prudhoe Bay K-04B Permit Test the FMC 9-%" mandrel palko!! and tubing hanger seals to 5,000 PSitOÎ30 minutes. Bleed tubing and annuli pressures to zero. 10. Set a BPV In the tubing hanger and test from below to 1,000 psi. Secure well. 11. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Nabors 2ES. Circulate out freeze prote~n and displace well to seawater. Set TWC. 2. Nipple down tree. Nipple up and test BOPE. 3. Pull and lay down 5-%" tubing from E-line cut and above. 4. MU clean-out BHA with 5" DP and flat bottom mill I String Mill I boot baskets I etc. RIH -50' below the 9-%" BP setting depth, -7,270' MD and circulate and condition wellbore as required. Pump hot oil to remove excess paraffin if needed. POOH ~ /' 5. RU Schlumberger E-line, make GR/JB run, GR/JB/GR/CCL run and set BP @ , ,,' ' MD. It may be necessary to run BP on DP depending on how clean the GR/JB's come back. ,"~' 6. Bleed down 13-%" X 9-%" annulus and ensure there is 0 pressure on the packoff. /" 7. If necessary change 13-%" x 9-%" packoff. Test the 9-%" casing to 3,500 psi for 30 minutes. Monitor the outer annulus for any increases in pressure on top of the normal increase due to ballooning effects. 8. PU 9-%" whipstock assembly. Set the whipsock on the BP such that the top of the whipstock is at -7,250'MD. Orient whipstock to 600 left of highsiçj.e,:""'Sþ1ear off of Whipstock and displace well over to 1 0.1 ppg LSND mud. /' Mill window in 9-%" casing. Perfo,r.m FIJ.-t6 11.8 ppg EMW. POOH 9. RIH with 8-Yi' drilling assembly ~'WD/GR/Res/PWD) to whipstock. Directionally drill to 8-%" TO. Planned TD is ~ MD I 8,336' TVD, top of Sag River formation. 10. Run and cement a 7",26# L-80 intermediate liner. Release from the liner. Circulate and condition well to clean /' up any cement above the liner top packer. POOH. 11. RIH with 6-%" drilling BHA with a 1.50 motor (with MWD/GR/ABI/PWD/Den/Neu) to 7" casing float collar. PU 4" DP as needed. Test the 9-%" casing and 7" liner from the landing collar to surface to 3,500 psi for 30 minutes. 12. Drill shoe track and displace .!]Jer to new 8.4 ppg Low D~E1Sity Flo-Pro fluid and drill 20' of new formation. Perform FIT to 9.7 ppg EMW. "",..,.'" .. ,) ~'f_ 13. Directionally drill ahead to TO geosteering through fone"!#,1"'B to TO at 1 O~D, 8,941' TVD (prognosed). 14. Perform wiper trip, circulate and condition mud and p01f"'Lay dow~xcess drillpipe. 15. MU and run 4-%" 12.6# L-80 BTC-M solid liner to TO and cement. Bump plug with perf pill. 16. PU off liner hanger and circulate and condition mud. Displace over to seawater. ./~., 17. POOH, LD liner running tools. Test liner top packer and wellbore above liner top to 3,500 psi for 30 minutes. 18. PU 2.5" Halliburton Millennium perforation assembly, perf -1,000' out of -2,500' of liner. POH, LD per guns. 19. MU 4-%" 12.6# L-80 completion assembly and RIH. See completion schematic for details. /' 20. Land tubing hanger and test hanger pack-off to 5,000 psi. 21. Reverse in seawater with Corexit to protect the annulus. 22. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 23. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 24. Pull two-way check. Freeze protect the well to 2,200' TVD. /" 25. Install BPV. Secure the well and rig down I move off Nabors 2ES. Post-Ri~ Work: 1. MIRU slickline. Pull the ball and rod I RHC plug. 2. Pull out DCK-1 shear valve, install GLV in all of the other mandrels as per the PE. 6 Greatt;tr Prudhoe Bay K-04B Permit ) Job 1: MIRU Hazards and Contingencies }> ~e wo adjacent Well~:K-1-\ and K-17) are both greater than 15' away from the K-04 wellhead. K-17 is -6 away and K-14 is -3 ' away. The well houses do not need to be removed from K-17 or K-14 prior to ,,' ,--rig move. Ensure· wellhouse is removed from the K-04 well. Disconnect the S-riser and the knock- out spool prior to moving the rig over the well. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re-attempted. }> K Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are in the 10 PPM range based on the last samples taken in 2000. Recent H2S data from the pad is as follows: K-04 less than 10 ppm Adjacent producers at Surface: K-14 0 ppm / K-17A 10 ppm Adjacent producers at TD: K-12A 10 ppm E-17 0 ppm The maximum recorded level of H2S on the pad was 10 ppm. }> The perforations and coil tubing liner will be abandoned with a CIBP and cement during the pre-rig. There will also be a tubing cut at -7,300' MD. Ensure an adequate handover from the wells group prior to conducting any operations on the well. Prior to moving over the well check the wellhead pressure to verify the well is dead. }> There is a potential for CTD to still be on K-317B when we go to move on K-04. /" :t.t¡;.,.,J>. _f__'_ _~.--'-X:'-:_'\"::.-_-X.."1"f'ltfí'( :-...-.-.-- --.----.-.-.-.--.-.-.-.---.---.-.---.--.-.-.-.-.-.-.-- - \;¡';"'."""..,"~:'-..\X'-'-'-'-'-'-'-~~~"- Job 2: Decomplete Well Hazards and Contingencies }> The tubing will be cut at -7,300' MD. The coil tubing sidetrack will be abandoned with cement, planned TOC: 7,910' MD. }> The 5-%" tubing was run back in 1983 so it is very possible that it is highly corroded and sections of the tubing may have high wall loss, with several possible penetrations. Limit over-pull on tubing string to 80% of tensile strength, and if tubing will not pull free on initial attempt, RU e-line to ma~.second cut. }> Wellhead: Cameron did an MIT test on 9/22/01 and had a few wellhead failures. The ring gasket in the flange between the tubing spool and the tubing head adapter would not test. They could not get a test on the 9-%" hanger void due to gas. They think that if they can get the gas out, that they could reenergize the Y -seal packoff with plastic and get a test. Stores has a condition B tubing head adaptor and a tubing hanger for this well head in stock. The tubing hanger is threaded a bit different then the one in the well. It has 7" NSCC top and TC4S bottom instead of both being TC4S. There should already be a XO to 5-¥2" BTC on the well, but not sure if we have a XO to 4-¥2" BTC for the new completion » NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies » Whipstock setting: Due to the low inclination of this well at the whipstock setting depth, a gyro will need to be utilized in order to ensure the correct orientation of the whipstock. The planned orientation of the whipstock is ±60° left of highside. This will allow for a better transition into the profile and allow for best chance at getting a full length window. Exact window depth to be based off of actual logs. Planned top of window is 7,250' MD. This window needs to exit the casing in the Colville CM2 formation. Use logs to ensure the whipstock is set over this interval from 7,275' MD -7,225' MD. 7 " Grea~~t Prudhoe Bay K-04B Permit ) j ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. ~ Equipment Measurements: Verify measurements of all assemblies prior to picking up ~ FIT: An FIT of 11.8 ppg EMW is required at the 9-%" window. This will cover the expected normal ECD range for this section. ' ~ ~ Kick Tolerance: The kick tolerance for the 8-%" open hole section would be arvrhfi~~. influx assuming a kick from the Sag at -8,371' MD. This is a worst case scenario based on an 7.9-p1 pore pressure gradient, a fracture gradient of 12.8 ppg at the 9-%" window (7,250' MD), and 10.1 ppg mud in the hole. ~ Hole Cleaning: Well inclination at the planned kick off point angle is about 1.4°. The wellbore above the KOP is essentially vertical, however we will be utilizing 4" DP. Good window milling and hole cleaning practices will be critical to ensure that metal and formation cuttings are removed from the well. .1fI:o";¡~,I¡.;.;""",\.,.,.;,....¡.m¡.m!};;.-mß,w;,a¡¡;!m,l,~I.w,:,M,,ilÁI~)"AI;';Þ'>,0"';',:¡';'Mm,~""';,;,,,.,,-m,-.-'-);';;';.-!MI,I.-;~,;¡';;,I};.¡¡,.M;,;»'-,~~...,;.m;,;,,;,,~-.-.-n.-;A-'A-,.w;.-.-mAA-,I,ImAAl~m"",I,I.;;.a;»mmm.a¡m,lmm.w,1»m,-mmmmmmmm,:,Iþ}m,mm,'Im'¡¡':J,\lmm.a,:,I»ml»N,I/J¡.;.;.mIAAl»mw~m¡Mij»,lmm.wm-,I;.,-r;m}'mm,:,I,Immmm¡,wmJAAOm¡¡!'¡m)N~ml-}m!mVlmmmmmm¡.;mwm¡'¡';'-!!!AWmm,I¡;mm.\I,W¡,:m,I,IßN¡')}!,!;,!,1J.: Job 4: Drill 8-%" Intermediate Hole Hazards and contingencies ~ KOP: The planned kick-off point is within the Colville CM2 interval. It was selected based upon historical success of exiting within this interval on the numerous sidetracks. Drilling in the Kingak has shown only minor hole problems on K Pad, however adhering to good Kingak drilling practices will be crucial to successfully drill and case this interval. ~ Wellbore Stability: Full sections of the Kingak shale will be drilled on this well. W Pad has a history of wellbore stability problems within the Kingak. Of the problems encountered, tight hole and packing off have been the main problems, however several stuck pipe incidents are noted on the pad data sheet. Most stuck pipe has been while running casing and or liners in the wells. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. ~ Lost Circulation: There are also several incidents of lost circulation seen when the Sag River formation was inadvertently penetrated. Extreme care should be taken when picking the 7" casing point. There have also been several occurrences of stuck pipe when intermediate casing was left off bottom. Ensure all of the Kingak is covered with pipe by setting the 7" shoe as close to bottom as possible. ~ Drilling Close Approach: Besides the parent wellbore, all wells pass BP Close Approach guidelines under Major Risk rules for this hole section. Note tolerance lines and allowable deviation from the planned K-04 well-path. ~ ECD/Hole cleaning: Flow rates ranging from 450 - 550 gpm should be used to avoid 'over-circulating' the hole, and preventing "charging" or eroding the shales. A flow rate of 525 gpm provides annular velocities of -208 fpm, and will effectively clean the well at the maximum ROP of 200 ft/hr (expected ROP < 100'/hr) within this interval. Minimize surging of the shales to prevent mechanical failure of the shale. While drilling through the Kingak, keep flowrates in the 500-525 GPM. Pipe rotation should be 80 rpm or more where possible. Maintain mud weight at 10.1 ppg through out the interval. ECD ceiling is 12.0 ppg. If ECD's are approaching 12.0 ppg, call ODE and talk through options. Minimize surging of the shales to prevent mechanical failure of the shale. » BHA: A single BHA with a Smith 'S86' PDC bit is planned for this hole section (see attached BHA Recommendation for details). The nozzle TFA specified below is designed to minimize pressure drop at the bit and nozzle exit velocities (-350 psi and -200 ft/sec at 550 gpm), as per recommended shale drilling practices, and still provide adequate HSI. » TD Criteria: The onsite geologist will be needed throughout the intermediate hole section for correlation of formation markers and selection of interval TD. LOCATING TOP OF SAG: The desired casing point is the thin siltstone at the base of Kingak. In order to prevent drilling into the Sag River and the risk of associated lost circulation, control drill at 5' intervals from 25' above the projected Sag top until the siltstone cap is identified. Each 5' interval will be circulated bottoms up for sample identification until the wellsite geologist is satisfied the cap has been located. 8 ) Greate! Prudhoe Bay K-04B Permit } ¡ä.,_.,;..'·....'·-u"'~'!;L."-A~I.u.;-~·,.\.r;,.\.-,..,.V\.~................'" w~;,:.;,.,;,;,;,;.;,;,~;..,;,;..,..;,.;;,;,¡,(O,..,;~,W\',r.-::,··fI-;,r,,, \ r::.--:.,-'-,~r';';"'-/lM"~;,w,;:-,,_\ Job 5: Install 7" Intermediate CasinQ Liner Hazards and Contingencies ~ Centralization: Run a total of 2 solid straight blade centralizers. Run one on each shoe joint (Jts 1 and 2). The centralizer on joint 1 (bottom shoe joint) should be locked down 4 to 5' from the shoe, to allow the end of the casing to be picked up off the bottom of the hole. The other should be locked down in the middle of the joint. ~ Cement Job: Break circulation to thin mud at 9-%" window. Break circulation slowly to minimize ECD; due to high surge and swab pressures, don't reciprocate unless necessary. Once on bottom, break circulation slowly and stage rate up to desired cementing rate of 6 to 8 bpm (to obtain desired AV of -265 to 354 fpm). Pipe should be left on bottom :(while circulating and cementing) unless movement is required for circulation / pack-off issues. It is very important that the shoe is on bottom and the Kingak shale is isolated behind pipe for upcoming drilling operations. Circulate a minimum of three liner annular volumes to condition hole for cement job (with a minimum of one annular volume at the desired cementing rate). UU:I;lm'lrlr:n~mlm:...mlw.:w- ., 1I1!ml:II;lmu...:mlmlllrmll I. --II---'--I-IIIIIIIII;mnl1:l;IIIIII11I1I1I11III1I1:- .1_1:-1:1:-11-:11. ---1--- ---I-IIILtIl'lllm:I'::IOlllm,;I::I__1 r-lT-----II----r-;ullll;;...;mk---r---.J\ ;-llmll-----Tmlllmma:11111111I Job 7: Drill 6- Va" Production Hole Hazards and Contingencies ~ Lost Circulation: Several wells of this kind have been drilled on K-pad recently with varying losses encountered, but on the whole, fairly minor from a risk standpoint. This well should be treated as any other Ivishak horizontal for LCM restrictions, etc. On K-pad the majority of lost circulation cases have been fault related and were all manageable either by pumping fiberous LCM pills and or them healing all on their own. Good drilling practices to limit ECD's and surge pressures should be a standard. To be prepared for potential lost circulation, a copy of the 'Lost Circulation Flow Chart' is included in this well plan binder in the mud section. ~ Faults: One fault crossing has been identified in this hole section and there is also one potential fault crossing. The estimated depth and throw of the faults are listed below for reference and planning. The risk of encountering losses at this faults is uncertain. Follow the LCM Decision tree if losses are encountered. Have LCM products on location to treat any losses. Fault #1: Uncertain' MD 8,831' TVD 10' Upthrown South Fault #2: 10,513' MD 8,895' TVD 30' Dow~thro West » Kick Tolerance: The kick tolerance for the 6- X" open hole section would be an nfi' influx assuming a kick from the Ivishak at -10,874' MD. This is a worst case scenario based on .4"Ppg pore pressure gradient, a fracture gradient of 9.7 ppg at the 7" shoe (8,371' MD), and 8.4+ ppg mud in the hole. Job 9: Install 4%" Production Liner Hazards and Contingencies » Centralization: Run one straight blade rigid centralizer per joint, floating along the full length of the joint. Do not put any cetralizers in the 7" x 4-%" liner lap. Centralizers are to help with the cement job. This centralizer placement proposal is subject to change depending on hole conditions and rig team recommendations. » Differential sticking could be a problem over this long horizontal section. Minimize the time the pipe is left stationary while running the liner. » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. 9 -.... ) Grea,ter Prudhoe Bay K-04B Permit ") ...... ;:::, " U' -- 'I:;,..·.:,;!...:..:;¡"~..'!.,,':....; ·.-..-..;.~.I.:..:",.'...¡;.,.. .., .~~~:,'~~.,;,;,¡,~ .'... _'-:1*'__\ _". .- ":"I,,¡¡,,~L,"',~;'¡,:";',~¡';'~;-M;A; ·11!';...'~'I'-.I¡,.;~"~~'1h :,~.~ '''-,'1,\''''.;.'11'''-__ . lA''';,:.!,'" ,;,:.;.,;;.., Job 10: DPC Perforate Well Hazards and Contingencies }> The well will be perforated ±550 psi over-balanced. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. }> It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Halliburton hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. }> Contact Halliburton to prepare for approximately 1,000' of 2-%" Millennium charge guns at 6 spf. Exact perforation depths will be provided after reviewing the LWD logs. }> Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Follow the LCM decision tree for "After Perforating". Position guns by tagging PBTD and picking up to the appropriate depth. 1:llm--.llml1...lam:1II11I1:1 :~!!lnlmmLI~:II:II:!I:I-lmmllll:I::lmlll:II:IIIIII:lm 111m. _III. _a~:I."l1lml..)';;WI:lllmm:lmlml-':IIIIllllllm:I'rmll:l:m:mlml---- .~mr_ .mnmm..1. .'111 . ;11111 ..... ---III:II-:":I--III:IIIIIIIIII11,mlll-:IIIII:' .11I11111-' Job 12: Run Completion Hazards and Contingencies }> Dirty Hole: It is critical to have a clean hole to run this completion in due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. }> Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. }> Thread Dope: Best-o-life (BOL) 2000 NM is the BP approved thread compound for Carbon API connections. BOL 2000 and BOL 2000 NM are compatible and can be mixed. }> Shear Valve: We will switch from an RP shear valve to a DCK-1 shear valve due to the RP shear valve failure on numerous wells. The DCK-1 shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. liLT. .1.1.":11I.111..1..1. ."u--m:n-:LIIL1TII:-_'- _I. 1I.n-:I_. 1UIII!:I:,TlIlI"lIlIlIr- -11;11I11I1111I111I-- _I. _mmm_ _1.1_11_1111_':'"11. _11I11: --n:n---,-:m;;.. ....;;11I-- --':1 11I_ _1.:'-_11_ _L'- _III. .1:-'---11I1--- -:In-nnrn:.,m 1I:1I11:11:lInl--- _111111111::II.,IIIIU---_1n Job 13: ND/NU/Release Rig Hazards and Contingencies }> See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. 10 DrillQuest~ PBU WOA K Pad K-048 WP12 K-04B WP12 Proposal Data Speï'í'Y-SU'1 North Slope Alaska CRIL.L.ING SERVlCJæs BPXA A H.mbunon ~.nv We We ft True North Degrees per 100 feet (US) 183.100° Well 0.00 N,O.oo E Azim. ~;~~~t~r~~7g:in : Measurement Units North Reference: Dogleg severity : Vertical Section Azimuth: Vertical Section Description: Vertical Section Origin: Incl J Dogleg Rate 12.000 4.000 0.000 12.000 12.000 0.000 14.000 10.000 0.000 Vertical Section -61.25 -6Ll5 -84.66 -189.64 26.30 37.57 90.79 690.54 841.01 993.48 Eastings ?~ ·'x E .'r. II E oJ11 ~ \ E ,\: ~,~ E "·~t. t.ri E 7..·· '\ E )\~:a-: "E XI'.J ~..) E ~~;, ,.) E " /IIW Northings 59.94 N 59.79 N 79.90 N 171.89 N 67.32 S 79.29 S 135.78 S 735.93 S 871.95 S 992.03 S Vertical Depth 7248.97 7268.95 7631.56 8441.30 8838.29 8837.99 8835.21 8843.29 8868.17 8933.29 130.035 89.995 69.236 69.236 133.000 133.756 133.756 228.000 258.725 258.725 1.275 3.232 17.767 17.767 90.000 91.951 91.951 87.000 83.947 83.947 Measured Depth 7250.00 7270.00 7639.70 8490.00 9175.40 9192.83 9274.57 9948.41 10256.15 10873.74 Begin 8-112" Hole ST Exit: 12.000·/100ft, 60.00· Left TF: 7250.00ftMD,7248.97ftTVD Begin Dlr @ 4.000·/10Oft : 7270.001t MD, 7268.95ft TVD ,/' End Dir, Start Sail @ 17.767° : 7639.70ftMD,7631.56ftTVD ~Fault #1 Crossing: 8504.83ft MD Begin 6-1/8" Hole ¿----- Begin Dir @ 12.0000/100ft : 8490.00ft MD, 8441.301t TVD ----·---K-04B T1 Geo Poly #1 K-04B Faul 300 ~ W Current Well Properties K-04B WP12 5975278.00 N, 671453.00 E 2089.59 N, 1158.42 E 70° 20' 17.9995" N, 148° 36' 31.4004" 53.29f 53.29f above Mean Sea Level above Structure Reference True North Feet (US) Well Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference : Ref. Geographical Coordinates RKB Elevation ~ 0' <>~ '.s1 ~7 ~ ~9 \ ~~ (i).9" <>-;. '.9.s-". (i) "9' .'.9): '0'fJ ~ -1: ~~ 0O;¡. ~<> North Reference .,~ 'd'<t» Units: ~9' 'oS!P '.s->. ~~ '7<~ ~ 'IS! C9~ ...,. ~ % K-04B T1 8838.29ft TVO 67.32 S. 756.66 E K-04B T2 8643.29ft TVD 735.93 S, ~19.39 E ~h K-048 Feul K-04B Faul K-041:J BI'IL 1:1933.:1.911 TV£) 99?.:~/ 53.70 W " ~ ...6' o -300 -600 -900 - ã) ~ ù) 0> c: :c t:: o Z Rate @ 10.0000/100ft : 9948.41ft MD, 8843.29ft TVD End Dlr, Start Sail @ 83.947° : 10256.15ftMD,8868.17ftTVD t3 Crossing: 10513.61ft MD Depth: 10873.74ftMD,8933.29ftTVD V I I 0 300 600 900 Scale: 1 inch = 300ft Eastings(Well) Reference is True North -1200 õ o C') II ~ C,,) .~ ..- Q) Cõ C,,) Cf) DrillQuest- PBU WOA K Pad K-048 WP12 spei'i'~-5UIl North Slope Alaska dRIL.L.ING seFtVtr;e-š BPXA A Halnbu<1on Company K-Q4B WP12 Proposal Data Dogleg seveñty : Degrees per 100 feet (US) Vertical Section Azimuth: 183.100° Vertical Section Descñption:Well Vertical Section Oñgin : 0.00 N,O.OO E Incl Azim. Wel Wel ft True North Vertical Oñgin : Hoñzontal Oñgin : Measurement Units North Reference : ,,~ - <Begin 8-1/2" Hole ___ ST ExIt: 12.000·/100ft, 60.00· Left TF: 7250.00ftMD,7248.97ftTVD .{300Å!i>-Begln Dir @ 4.000·/1000: 7270.0Oft MD, 7268.95ft TVD -='L 7200 - ~7~O~S!!.lY!L- _ _ Dogleg Rate 12.000 4.000 0.000 12.000 ]2.000 0.000 "'Í4.000 , 10.000 ~ 0.000 I Vertical Section -61.25 -61.15 -84.66 -189.64 26.30 37.57 90.79 690.54 841.01 993.48 Eastlngs 25.98 E 26.71 E 90.23 E 332.84 E 756.66 E 769.33 E 828.33 E 819.39 E 548.59 E 53.70 W Northlngs 59.94 N 59.79 N 79.90 N 171.89 N 67.32 S 79.29 S 135.78 S 735.93 S 871.95 S 992.03 S Vertical Depth 7248.97 7268.95 7631.56 8441.30 8838.29 8837.99 8835.21 8843.29 8868.17 8933.29 130.035 89.995 69.236 69.236 133.000 133.756 133.756 228.000 258.725 258.725 1,275 3.232 17.767 17.767 90.000 91.951 91.951 87.000 83.947 83.947 Measured Depth 7250.00 7270.00 7639.70 8490.00 9175.40 9]92.83 9274.57 9948.41 10256.15 10873.74 7639.7OOMD,7631.56ftTVD @ 17.767" ¡roo.oo :d:"~ ..::..-- End Dlr. Start Sai -2:11:..J~9191t TVD __ ~1~2~ _ _ ...!'!!Bf. 7500 ,[10000 Properties K-04B WP12 Wel Current -.:"'! Wel Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference : Ref. Geographical Coordinates RKB Elevation "900,00 --- ~.~ 7800 -. LCU. 1l!1519!1..:D!.º-.. _ _ ",!~..Q"J!1.i3.!9ft TVD __ 1 JC. 79~S1.9t~ 5975278.00 N, 671453.00 E 2089.59 N, 1158.42 E 70020'17.9995" N, 148036' 31.4004" W - --- ~' 53.29ft above Mean Sea Level 53.29ft above Structure Reference ~j!"A , ..' ;f'~~ -T . ." ~-5 ." WÕ~ ð· ~f. _l!JJf# '"::\ ~- ' ~~~:~ · ø~·~~~" True North Feet (US) North Reference Units .00 4 112" Uner 10873.74ft MD B933.29ft TVD ,.3100,00 ---...--- ~<) ~ ~ I ~ -r 00.., - 78"'06-118" "01, # .i' " # 8371.33ft MD I Begin Dlr @ 12.000·/1000: 8490.00ft MD, 8441.300 TVD A~ ~IÇ ~' .......~ 8328.29ft TVDJ Fault 11 Crossing: 8504.83ft MD ~Cf- -;: ~~ 9'J>' - - - ~<G> 4>":>'> ~~.... ~? ShUb"k,..ß~O~D_ - - - . . .__7- # ~~' OJ~ ':>~ ~<) 8400 .. ,g; ~~. §o.'. i>.... ~- - TSAO 8432.2911 1VO _ ...'.. ,,-t' ~'J' n';) , ^ n<!i ---'- - - - - - - - 00 OJ........ ~.".. .,>0: ...~.. ~...., (!)":>? .'. ~ f§>~ .', ...~ fbØ:. OJ"'" ~. ...t;;). OJ~ ...":>~ ~<)' OJ...· .tor::; @ fb":>' ...t;;)~ ....~ @ ~ ~ø ~ @ '. ,,:>, ,~ <:ì ~ ,i§ ",,~ð;, ~(j. ~-:r """. <)~ ~-:r" 4" ,,>0: G:J-.!J' ~ @ ø~ G:J-.!J' ûcP fi1.ò$' :,.,~, Q It>" ~, ~ <:f #" -~~ .~ <:;~ ~# ,~OO )- ,/ K-04~2 81M3. 29ft TVD 735.93 S. 819.39 E / / / / K-04B BHL 8933.29ft TVD 992.03 S. 53.70 W ~-'~~ --- .~ -:1 \ :~ \ !:::: \ l \ \ K-Q4'a T1 8838.29ft TVD 67.32 S, 756.66 E ~81151.9f!...IYL _ _ . 1218, 8..!.S~_2~ , TDF, S6..!.01.91t TVD_ _ _ ...L!V2.i3.~!..!.Y.L _ .~I:!!v~!, F~'{Q !!§'!: 2911 TVO 1CGL - Q) ~ ..c. ë.. 8100 Q) o (ij ü :e Q) > 8700 -1= o o ('I) II .c. () c :;:. 9000 å) Cõ () (f) 1500 1800 183,1000 (True North) 1200 Section Azimuth: 900 600 Vertical Section (Well) 300 o -300 inch = 300ft Scale: SpE!r"í'\I-SUI1 North Slope Alaska PBU_WOA K Pad Drillºuest~ ORLLNß_sèAVC&~ BPXA K-04B WP12 A H.IRWt1on Comp.lfty K-048 WP12 Target Data Measurement Units: ft Target Coordinate TVD Northings Eastings SSTVD Northings Eastings Target Name Point Type Well Well Well MSL ASPY ASP X Shape (ft) (ft) (ft) (ft) (ft) (ft) K-04B Fault # I Entry Point 8575.29 377 .95 N 137.68 E 8522.00 5975659.00 N 671582.00 E Polygon Boundary Point A 8575.29 377.95 N 137.68 E 8522.00 5975659.00 N 671582.00 E B 8575.29 60.78 N 447.51 E 8522.00 5975349.00 N 671899.00 E C 8575.29 377.95 N 137.68 E 8522.00 5975659.00 N 671582.00 E K-04B Fault #2 Entry Point 8833.29 255.94 S 519.28 E 8780.00 5975034.00 N 671978.00 E Polygon ~ Boundary Point A 8833.29 255.94 S 519.28 E 8780.00 5975034.00 N 671978.00 E B 8833.29 335.92 S 823.53 E 8780.00 5974961.00 N 672284.00 E C 8833.29 255.94 S 519.28 E 8780.00 5975034.00 N 671978.00 E K-04B T 1 DO Poly @ 95% Entry Point 8838.29 67.32 S 756.66 E 8785.00 5975228.00 N 672211.00 E Polygon Boundary Point A 8838.29 116.18 N 605.81 E 8785.00 5975408.00 N 672056.00 E B 8838.29 190.02 S 960.91 E 8785.00 5975110.00 N 672418.00 E C 8838.29 295.37 S 1018.51 E 8785.00 5975006.00 N 672478.00 E 0 8838.29 413.26 S 1099.84 E 8785.00 5974890.00 N 672562.00 E E 8838.29 671.38 S 970.90 E 8785.00 5974629.00 N 672439.00 E F 8838.29 921.09 S 693.12 E 8785.00 5974373.00 N 672167.00 E G 8838.29 1169.72 S 25.75 W 8785.00 5974108.00 N 671454.00 E H 8838.29 913.66 S 68.91 W 8785.00 5974363.00 N 671405.00 E I 8838.29 579.77 S 551.89 E 8785.00 5974711.00 N 672018.00 E J 8838.29 481.72 S 638.15 E 8785.00 5974811.00 N 672102.00 E K 8838.29 423.22 S 704.51 E 8785.00 5974871.00 N 672167.00 E L 8838.29 341.47 S 847.41 E 8785.00 5974956.00 N 672308.00 E M 8838.29 277 .50 S 805.87 E 8785.00 5975019.00 N 672265.00 E N 8838.29 3.03 S 526.07 E 8785.00 5975287.00 N 671979.00 E K-04B T I Gco Poly Entry Point 8838.29 67.32 S 756.66 E 8785.00 5975228.00 N 672211.00 E Polygon Boundary Point A 8838.29 142.75 N 580.92 E 8785.00 5975434.00 N 672030.50 E B 8838.29 88.23 S 927.63 E 8785.00 5975211.00N 672382.40 E . C 8838.29 407.47 S 1109.37 E 8785.00 5974896.00 N 672571.40 E ~ D 8838.29 868.44 S 883.87 E 8785.00 5974430.00 N 672356.50 E E 8838.29 1004.76 S 502.76 E 8785.00 5974285.00 N 671978.60 E f1t/~\ 4 F 8838.29 1233.25 S 47.11 W 8785.00 5974044.00 N 671434.10 E ~;~' .~ ",~'f~i G 8838.29 916.72 S 110.29 W 8785.00 5974359.00 N 671363.70 E ~:~ i~·~{:~1 H 8838.29 657.39 S 403.27 E 8785.00 5974630.00 N 671871.20 E .~ <, I 8838.29 333.97 S 825.68 E 8785.00 5974963.00 N 672286.10 E ~ . ~;: J 8838.29 55.57 N 456.59 E 8785.00 5975344.00 N 671908.20 E K-04B T2 Entry Point 8843.29 735.93 S 819.39 E 8790.00 5974561.00 N 672289.00 E Point ~~_k :c~.-?-4 y' 'if "<'';; K-04B Fault #3 Entry Point 8911.29 546.82 S 379.60 E 8858.00 5974740.00 N 671845.00 E Polygon Boundary Point A 8911.29 546.82 S 379.60 E 8858.00 5974740.00 N 671845.00 E B 8911.29 243.51 S 226.63 E 8858.00 5974040.00 N 671708.00 E C 8911.29 546.82 S 379.60 E 8858.00 5974740.00 N 671845.00 E K-04B BHL Entry Point 8933.29 992.03 S 53.70 W 8880.00 5974285.00 N 671422.00 E Point DrillQuest - 1 - 18 December, 2002 - 9:36 Sperl }-Sun Drilling Se. 'Vices Proposal Data - K-048 WPS - K-048 WP12 DDI = 5.5 DRAFT COpy Sperry-Sun Drilling Services North Slope A 8 PBl,¡j.tê~ W K-048 WPS - ~i Revised: 18 December, 2002 Proposal Report 18 December, 2002 Surface Coordinates: 5975278.00 N, 671453.00 E (70020'17.9995" N, 148036'31.4004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,-"," Surface Coordinates relative to Project H Reference: 975278.00 N, 171453.00 E (Grid) Surface Coordinates relative to Structure Reference: 2089.59 N, 1158.42 E (True) Kelly Bushing: 53.29ft above Mean Sea Level Elevation relative to Project V Reference: 53.29ft Elevation relative to Structure Reference: 53.29ft spe...........y-suf1 DR'ij:;'t.:;lNG<·'''s'e·R·\ii¿-es A Halliburton Company Proposal Ref: pr011400 DrillQuest 3.03.02.005 Page 2 of 12 18 December, 2002 - 9:39 Sperry-Sun Drilling Services Proposal Report for PBU_ WOA K Pad - K-04B WPS Revised: 18 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastinl Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) K-04 Reca ..:--;:?~.- 0.00 0.000 0.000 -53.29 0.00 0.00 E 5975278.00 Ntt;Jth671453.00 E 0.00 100.00 0.152 334.955 46.71 100.00 0.06W 5915278.13 N '#;"671452.94 E 0.152 -0.13 200.00 0.160 317.516 146.71 200.00 0.20W 5975278.38 N 671452.79 E 0.048 -0.37 300.00 0.373 216.849 246.71 300.00 0.52W 5975278.20 N 671452.48 E 0.432 -0.18 ~ 400.00 0.520 181.683 346.71 400.00 0.70W 5975277.47 N 671452.32 E 0.304 0.56 500.00 0.534 200.277 446.70 499.99 0.90W 5975276.56 N 671452.14 E 0.171 1.46 600.00 0.382 173.511 546.70 599.99 1.03W 5975275.80 N 671452.02 E 0.259 2.23 700.00 0.510 137.206 646.70 699.99 0.68W 5975275.15 N 671452.38 E 0.304 2.87 800.00 0.638 123.705 746.69 799.98' 0.11 E 5975274.53 N 671453.19 E 0.185 3.46 900.00 0.496 123.561 846.69 899.98 0.92 E 5975273.99 N 671454.01 E 0.143 3.97 1000.00 0.482 105.338 946.68 999.97 4.378 1.68 E 5975273.67 N 671454.78 E 0.155 4.27 1100.00 0.592 103.212 1046.68 1099.97 4.628 2.61 E 5975273.44 N 671455.72 E 0.112 4.47 1200.00 0.433 56.570 c1:t~ßf~~;; ::;¡'º:'199 :9~;> 4.528 3.39 E 5975273.56 N 671456.50 E 0.432 4.33 1300.00 0.829 53.176 :c1.246.64;\;~[~99 .96 3.888 4.31 E 5975274.22 N 671457.40 E 0.397 3.64 1400.00 0.935 37.942 1346.65;1399.94 2.77 8 5.41 E 5975275.36 N 671458.47 E 0.256 2.47 1500.00 0.545 34.581 1446.65 1499.94 1.77 8 6.17E 5975276.37 N 671459.21 E 0.393 1.44 1600.00 0.732 19.016 1546.64 1599.93 0.748 6.64E 5975277.41 N 671459.66 E 0.254 0.38 1700.00 0.508 25.938 1646.63 1699.92 0.26 N 7.06E 5975278.42 N 671460.05 E 0.236 -0.64 1800.00 0.327 357.443 1746.63 1799.92 0.91 N 7.21 E 5975279.07 N 671460.19 E 0.270 -1.29 1900.00 0.695 15.870 1846.63 1899.92 1.79 N 7.35E 5975279.96 N 671460.31 E 0.398 -2.19 2000.00 0.906 35.980 1946.62 1999.91 3.04N 8.00E 5975281.22 N 671460.93 E 0.348 -3.47 -....,,' 2100.00 0.754 45.707 2046.61 2099.90 4.08 N 8.99 E 5975282.29 N 671461 .90 E 0.207 -4.56 2200.00 1.041 352.883 2146.60 2199.89 5.48N 9.27 E 5975283.69 N 671462.14 E 0.839 -5.98 2300.00 1.000 17.671 2246.58 2299.87 7.24 N 9.45 E 5975285.45 N 671462.28 E 0.440 -7.74 2400.00 0.624 27.510 2346.57 2399.86 8.55 N 10.00 E 5975286.78 N 671462.81 E 0.400 -9.08 2500.00 0.272 310.102 2446.57 2499.86 9.19 N 10.04 E 5975287.42 N 671462.82 E 0.624 -9.72 2600.00 0.314 217.692 2546.57 2599.86 9.08 N 9.70 E 5975287.30 N 671462.49 E 0.424 -9.59 2700.00 0.384 269.094 2646.56 2699.85 8.87 N 9.17 E 5975287.07 N 671461 .97 E 0.309 -9.35 2800.00 0.250 312.983 2746.56 2799.85 9.00N 8.68 E 5975287.20 N 671461.47 E 0.267 -9.46 2900.00 0.395 2.951 2846.56 2899.85 9.52 N 8.54E 5975287.71 N 671461.32 E 0.302 -9.97 Sperry-Sun Drilling Services Proposal Report for PBU_ WOA K Pad· K-D4B WPS Revised: 18 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates .ä Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin. Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) <~lill~¡JJI {o/100ft} 3000.00 0.350 27.523 2946.56 2999.85 10.14 N 8.72 E 5975288.34N 671461:4¥Æ[i 0.164 -10.60 3100.00 0.144 357.109 3046.56 3099.85 10.51 N 8.86 E 5975288.71 N 671461.621¡Ë} 0.238 -10.98 3200.00 0.371 328.279 3146.56 3199.85 10.92N 8.66E 5975289.11N 671461.40E 0.255 -11.37 3300.00 0.418 359.127 3246.55 3299.84 11.59 N 8.48 E 5975289.78 N 671461.22 E 0.215 -12.03 3400.00 0.090 56.565 3346.55 3399.84 11.97 N 8.58 E 5975290.16 N 671461.30 E 0.377 -12.42 3500.00 0.343 286.640 3446.55 3499.84 8.32 E 5975290.28 N 671461.04 E 0.406 -12.52 ~ 3600.00 0.323 325.762 3546.55 3599.84 7.88 E 5975290.59 N 671460.59 E 0.223 -12.82 3700.00 0.388 355.264 3646.55 3699.84 7.71 ~,.,.,',.,.., 5975291.19 N 671460.41 E 0.192 -13.41 3800.00 0.190 276.650 3746.55 3799.84 7.54 E' 5975291.50 N 671460.23 E 0.397 -13.72 3900.00 0.678 290.245 3846.55 3899.84 6.78 E 5975291.70 N 671459.47 E 0.495 -13.90 4000.00 0.713 316.001 3946.54 3999.83 14.21 N 5.78 E 5975292.34 N 671458.46 E 0.312 -14.51 4100.00 0.668 336.301 4046.53 4099.82 15.22 N 5.14 E 5975293.33 N 671457.79 E 0.247 -15.47 4200.00 0.535 322.645 4146.53 4199.82 16.12 N 4.61 E 5975294.22 N 671457.24 E 0.195 -16.35 4300.00 0.356 310.662 4246.52 4299.81"'16.71 N 4.10 E 5975294.79 N 671456.72 E 0.201 -16.90 4400.00 0.350 257.323 4346.52 4399.81 16.82 N 3.56 E 5975294.90 N 671456.18 E 0.317 -16.99 4500.00 0.345 257.854 \~~99.81 16.70 N 2.96 E 5975294.76 N 671455.58 E 0.006 -16.83 4600.00 0.301 234.5494599.81 16.46 N 2.46 E 5975294.51 N 671455.08 E 0.137 -16.56 4700.00 0.216 303.317 4699.81 16.39 N 2.11 E 5975294.44 N 671454.73 E 0.300 -16.48 4800.00 0.770 329.073 4799.80 17.03N 1.58E 5975295.06N 671454.19E 0.583 -17.09 4900.00 1.724 350.299 4846.49 4899.78 19.16 N 0.99 E 5975297.18 N 671453.55 E 1.044 -19.19 5000.00 1.770 351.255 4946.44 4999.73 22.17 N 0.50 E 5975300.18 N 671452.99 E 0.054 -22.17 5100.00 1.778 351.626 5046.39 5099.68 25.22 N 0.01 E 5975303.22 N 671452.44 E 0.014 -25.19 5200.00 1.900 3.741 5146.34 5199.63 28.44 N 0.08 W 5975306.43 N 671452.27 E 0.407 -28.39 5300.00 1.670 4.514 5246.29 5299.58 31.53 N 0.14 E 5975309.53 N 671452.42 E 0.232 -31.49 ~ 5400.00 1.671 7.107 5346.25 5399.54 34.43 N 0.43 E 5975312.43 N 671452.65 E 0.076 -34.40 5500.00 1.691 11.693 5446.21 5499.50 37.32 N 0.87 E 5975315.33 N 671453.01 E 0.136 -37.31 5600.00 1.982 33.358 5546.16 5599.45 40.20N 2.18E 5975318.24N 671454.26E 0.747 -40.26 5700.00 2.016 28.176 5646.10 5699.39 43.21 N 3.95 E 5975321.29 N 671455.96 E 0.184 -43.36 5800.00 1.946 27.744 5746.03 5799.32 46.27 N 5.58 E 5975324.39 N 671457.52 E 0.071 -46.51 5900.00 1.658 25.747 5845.99 5899.28 49.07 N 6.99 E 5975327.22 N 671458.87 E 0.295 -49.38 6000.00 1.513 27.756 5945.95 5999.24 51.54 N 8.23 E 5975329.72 N 671460.05 E 0.156 -51.91 6100.00 1.425 31.067 6045.91 6099.20 53.78 N 9.49 E 5975331.98 N 671461.26 E 0.122 -54.21 6200.00 1.375 34.471 6145.88 6199.17 55.82 N 10.80 E 5975334.06 N 671462.53 E 0.097 -56.33 6300.00 1.430 37.540 6245.85 6299.14 57.80 N 12.25 E 5975336.07 N 671463.92 E 0.093 -58.38 6400.00 1.421 37.834 6345.82 6399.11 59.77 N 13.78 E 5975338.07 N 671465.41 E 0.011 -60.43 18 December, 2002 - 9:39 Page 3 of 12 DrillQuest 3.03.02.005 DrillQuest 3.03.02.005 Page 4 of 12 18 December, 2002 - 9:39 Sperry-Sun Drilling Services Proposal Report for PBU_ WOA K Pad - K-04B WPS Revised: 18 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6417.18 1 .402 37.689 6363.00 6416.29 _ 60.11 N 14.04 E 5975338.41 N 671465.66 f; 0.112 -60.78 CM3 6500.00 1.302 37.329 6445.80 6499.09 61.67 N 15.22 E 5975340.00 N 671466.81 è'\ 0.121 -62.40 6600.00 1.057 43.863 6545.77 6599.06 63.27 N 16.55 E 5975341.63 N . 671468.10 E 0.279 -64.07 6700.00 0.722 83.271 6645.76 6699.05 63.97 N 17 .82 E 5975342.36 N 671469.35 E 0.678 -64.84 6800.00 0.642 90.683 6745.76 6799.05 64.04 N 18.99 E 5975342.46 N 671470.52 E 0.119 -64.97 6900.00 0.825 104.342 6845.75 6899.04 20.25 E 5975342.33 N 671471.78 E 0.252 -64.88 ~ 7000.00 1.213 126.538 6945.73 6999.02 21.81 E 5975341.51 N 671473.36 E 0.546 -64.12 7100.00 1.137 126.748 7045.71 7099.00 23.451;"." 5975340.33 N 671475.03 E 0.076 -62.99 7200.00 1.227 125.721 7145.69 7198.98 25.12 E' 5975339.16 N 671476.73 E 0.092 -61.88 7219.32 1.244 127.427 7165.00 7218.29 25.45 E 5975338.92 N 671477.07 E 0.211 -61.65 CM2 7250.00 1.275 130.035 7195.68 25.98 E 5975338.51 N 671477.60 E 0.211 -61.25 ST Exit: 12.000°/1 OOft. 60.00° Left TF 7250.00ftMD,7248.97ftTVD K-048 WP12 7270.00 3.232 89.995 26.71 E 5975338.39 N 671478.34 E 12.000 -61.15 Begin Dir @ 4.000°/1000 : 7270.000 MD, 7268.95ft TVD 7300.00 4.348 83.273 'Z245.6(f 7298.89 59.93 N 28.69 E 5975338.57 N 671480.31 E 4.000 -61.39 7400.00 8.241 74.455 7~~;ggI;F 7398.27 62.29 N 39.36 E 5975341.18 N 671490.93 E 4.000 -64.33 7441.54 9.884 72.841 7386:ÖO 7439.29 64.14 N 45.64 E 5975343.17 N 671497.16 E 4.000 -66.52 CM1 7500.00 12.204 71 .302 7443.37 7496.66 67.60 N 56.28 E 5975346.87 N 671507.72 E 4.000 -70.55 7600.00 16.184 69.682 7540.30 7593.59 75.83 N 79.37 E 5975355.63 N 671530.62 E 4.000 -80.01 7622.65 17.087 69.417 7562.00 7615.29 78.10 N 85.45 E 5975358.03 N 671536.64 E 4.000 -82.61 THRZ 7639.70 17.767 69.236 7578.27 7631 .56 79.90 N 90.23 E 5975359.94 N 671541.38 E 4.000 -84.66 End Dir, Start Sail @ 17.767° : 7639.70ftMD,7631.56ftTVD -....' 7700.00 17.767 69.236 7635.69 7688.98 86.43 N 107.43 E 5975366.86 N 671558.43 E 0.000 -92.11 7800.00 17.767 69.236 7730.92 7784.21 97.24 N 135.96 E 5975378.33 N 671586.71 E 0.000 -1 04.45 7832.63 17.767 69.236 7762.00 7815.29 100.77 N 145.28 E 5975382.07 N 671595.93 E 0.000 -108.48 LCU 7900.00 17.767 69.236 7826.15 7879.44 108.06 N 164.50 E 5975389.79 N 671614.98 E 0.000 -116.80 7967.05 17.767 69.236 7890.00 7943.29 115.31 N 183.63 E 5975397.48 N 671633.94 E 0.000 -125.08 TJD 8000.00 17.767 69.236 7921.38 7974.67 118.88 N 193.03 E 5975401.26 N 671643.26 E 0.000 -129.14 8021.65 17.767 69.236 7942.00 7995.29 121.22 N 199.21 E 5975403.74 N 671649.38 E 0.000 -131.82 TJC DrillQuest 3.03.02.005 Page 5 of 12 18 December, 2002 - 9:39 Sperry-Sun Drilling Services Proposal Report for PBU_WOA K Pad· K-D4B WPS Revised: 18 December, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates ....w. Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastinll Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ¥(:¡'¡ e/100ft) 8100.00 17.767 69.236 8016.61 8069.90 129.70 N 221.56 E 5975412.73 N 671671.5IIE 0.000 -141.49 8179.16 17.767 ·69.236 8092.00 8145.29 138.26 N 244.15 E 5975421.81 N ß71693.9~1F;^ 0.000 -151.26 TJB 8200.00 17.767 69.236 8111.84 8165.13 140.52 N 250.09 E 5975424.20 N 671699.82 E 0.000 -153.83 8282.07 17.767 69.236 8190.00 8243.29 149.39 N 273.51 E 5975433.61 N 671723.02 E 0.000 -163.97 TJA 8300.00 17.767 69.236 8207.07 8260.36 151.33N 278.63E 5975435.66N 671728.09E 0.000 -166.18 8371.30 17.767 69.236 8274.97 8328.26 159.05 N 298.97 E 5975443.84 N 671748.26 E 0.000 -174.98 Begin 6-1/8" Hole ....J 8371.33 17.767 69.236 8275.00 8328.29 159.05 N 298.98 E 5975443.84 N 671748.26 E 0.000 -174.99 7" Casing 8ag River 8400.00 17.767 69.236 8302.31 8355.60 5975447.13 N 671756.37 E 0.000 -178.52 8423.83 17.767 69.236 8325.00 8378.29 5975449.87N 671763.11 E 0.000 -181.47 8hublik 8480.54 17.767 69.236 8379.00 8432.29 5975456.37 N 671779.14 E 0.000 -188.47 T8AD 8490.00 17.767 69.236 8388.01 8441 332.84 E 5975457.45 N 671781.82 E 0.000 -189.64 Begin Dir @ 12.0000/100ft: 8490.00t MD, 8441.300 TVD 8500.00 18.308 72.696 8397.52 8450.81"172.90 N 335.76 E 5975458.53 N 671784.72 E 12.000 -190.80 8504.83 18.590 74.295 8~Q2.10r.....~~55:.~.~.. 173.33N 337.23E 5975459.00N 671786.18E 12.000 -191.31 Fault #1 Crossing: 8504.83ftMD 8594.21 25.625 96.187 8485!00.'e'538:gn 175.11 N 370.26 E 5975461.53 N 671819.16 E 12.000 -194.88 TCGL 8600.00 26.163 97.1938490.21F¡:~~43.50 174.81 N 372.77 E 5975461.29 N 671821.67 E 12.000 -194.72 8700.00 36.247 109.919å~~§~~?; 8629.01 161.93 N 422.62 E 5975449.55 N 671871.80 E 12.000 -184.55 8800.00 47.144 117.534 8650:33 8703.62 134.82 N 483.14 E 5975423.83 N 671932.93 E 12.000 -160.75 8889.20 57.166 122.311 8705.00 8758.29 99.57 N 543.97 E 5975389.98 N 671994.56 E 12.000 -128.84 TZ1B 8900.00 58.391 122.812 8710.76 8764.05 94.65 N 551.68 E 5975385.24 N 672002.37 E 12.000 -124.35 9000.00 69.808 126.932 8754.38 8807.67 43.19 N 625.25 E 5975335.48 N 672077.09 E 12.000 -76.94 9007.74 70.696 127.222 8757.00 8810.29 38.80 N 631.06 E 5975331.22 N 672083.01 E 12.000 -72.87 TDF 9100.00 81.307 130.481 8779.29 8832.58 17.31 8 700.63 E 5975276.71 N 672153.84 E 12.000 -20.60 .~ 9175.40 90.000 133.000 8785.00 8838.29 67.328 756.66E 5975228.00N 672211.00E 12.000 26.30 Target-K-04BT1GeoPoly,Geologic¡ 9192.83 91.951 133.756 8784.70 8837.99 79.298 769.33E 5975216.32N 672223.94E 12.000 37.57 EndDir,8tart8ail@91.951°: 9192.83ftM D ,8837 .99ftTVD 9200.00 91.951 133.756 8784.46 8837.75 84.258 774.50 E 5975211.49 N 672229.23 E 0.000 42.24 9274.57 91.951 133.756 8781.92 8835.21 135.788 828.33 E 5975161.19 N 672284.22 E 0.000 90.79 Begin Dir @ 14.000°/1000: 9274.57t MD, 8835.21ft TVD 9300.00 91.769 137.314 8781.10 8834.39 153.928 846.13 E 5975143.46 N 672302.43 E 14.000 107.94 9400.00 90.997 151.297 8778.67 8831.96 234.91 S 904.32 E 5975063.83 N 672362.45 E 14.000 185.67 9500.00 90.165 165.273 8777.65 8830.94 327.58 S 941.22 E 5974972.03 N 672401.46 E 14.000 276.20 9600.00 89.324 179.248 8778.10 8831.39 426.42 S 954.65 E 5974873.52 N 672417.15 E 14.000 374.17 DrillQuest 3.03.02.005 .-" Total Depth: 10873.74ftMD,8933.2OOTVD 4 1/2" Liner Target - K-048 BHL, Drillers Fault #3 Crossing: 10513.61ft MD End Dir, Start Sail @ 83.947° : 1 0256.15ftM 0 ,8868 .17ftTVD -..".,/ Decrease in Dir Rate @ 10.000°/1000 9948.41ft MD, 8843.200 TVD Target - K-D4B T2, Drillers Comment BPXA 993.48 901.21 904.57 925.90 950.59 975.28 851 .83 876.52 782.46 824.51 841 .01 725.35 473.76 569.04 654.36 690.54 Vertical Section Page 6 of 12 18 December, 2002 - 9:39 The Along Hole Displacement is 2618.02ft, the Planned Tortuosity is 2.960°/1 OOft and the Directional Difficulty Index is 5.5. Based upon Minimum Curvature type calculations, at a Measured Depth of 10873.7 4ft., The Bottom Hole Displacement is 993.48ft., in the Direction of 183.098° (True). Magnetic Declination at Surface is 26.075°(17-Dec-02} The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 183.100° (True). All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. Sperry-Sun Drilling Services Proposal Report for PBU_WOA K Pad - K-04B WPS Revised: 18 December, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastin91 Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft) 9700.00 88.523 193.228 8779.99 8833.28 525.57 S 943.82 E 5974774.15N 672408·~Ji 14.000 9800.00 87.809 207.217 8783.20 8836.49 619.12 S 909.36 E 5974679.83 N 672376.28ŒiJ 14.000 9900.00 87.225 221.218 8787.56 8840.85 701.53 S 853.32 E 5974596.17 N,.§ .,.,. 672322.14 E 14.000 9948.41 87.000 228.000 8790.00 8843.29 735.93 S 819.39 E 5974561.00 NÙél;j,672289.00 E 14.000 10000.00 86.402 233.133 8792.97 8846.26 768.63 S 779.62 E 5974527.39 N 672249.99 E 10.000 10100.00 85.330 243.101 8800.20 8853.49 695.041;,.." 5974472.86 N 672166.64 E 10.000 10200.00 84.398 253.098 8809.17 8862.46 602.75 E 5974433.65 N 672075.22 E 10.000 10256.15 83.947 258.725 8814.88 8868.17 548.59 E 5974418.82 N 672021.38 E 10.000 10300.00 83.947 258.725 8819.50 505.83 E 5974409.32 N 671978.83 E 0.000 10400.00 83.947 258.725 8830.05 408.31 E 5974387.65 N 671881.78 E 0.000 10500.00 83.947 258.725 8840.59 8893.88 310.78 E 5974365.98 N 671784.72 E 0.000 10513.61 83.947 258.725 8842.03 ' 8895.32 297.51 E 5974363.03 N 671771.51 E 0.000 10600.00 83.947 258.725 ...ê904.4ß" 213.26 E 5974344.31 N 671687.67 E 0.000 10700.00 83.947 258.725 :i:flª14.97 115.74 E 5974322.65 N 671590.62 E 0.000 10800.00 83.947 258.725 8925.51 18.21 E 5974300.98 N 671493.56 E 0.000 10873.74 83.947 258.725 8933.29 992.03 S 53.70 W 5974285.00 N 671422.00 E 0.000 DriflQuest 3.03.02.005 Page 7 of 12 18 December, 2002 - 9:39 Formati on Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Up-Dip Depth Depth Depth Northings Eastings Formation Name , J (ft) Angle Dim. (ft) (ft) (ft) (ft) (ft) -- 6363.00 0.000 0.000 6417.18 6416.29 6363.00 60.11 N 14.04 E CM3 7165.00 0.000 0.000 7219.32 7218.29 7165.00 60.36 N 25.45 E CM2 7386.00 0.000 0.000 7441.54 7439.29 7386.00 64.14 N 45.64 E CM1 7562.00 0.000 0.000 7622.65 7615.29 7562.00 78.10 N 85.45 E THRZ 7762.00 0.000 0.000 7832.63 7815.29 7762.00 100.77 N 145.28 E LeU End Dir, Start Sail @ 83.947° : 10256.15ftMD,8868.17ftTVD Fault #3 Crossing: 10513.61ft MD Total Depth: 10873.74ftMD,8933.29ftTVD Begin Dir @\ql~pOoo/100ft: 8490.00ft MD, 8441.300 TVD Fault #1 Crosšîng : 8504.83ft MD End Dir, Start Sail @ 91.951 ° : 9192.83ftMD,8837.99ftTVD Begin Dir @ 14.0000/100ft: 9274.57ft MD, 8835.21ft TVD ,.Decrease in Dir Rate @ 10.000°/1 OOft : 9948.41 ft MD, 8843.29ft TVD .~ Begin 8-1/2" Hole ST Exit: 12.0000/100ft, £0.00° Left TF: 7250.00ftMD,7248.97ftTVD Begin Dir @ 4.000°/1000: 7270.00ft MD, 7268.95ft TVD End Dir, Start Sail @ 17.7£7° : 7639.70ftMD,7631.56ftTVD Beain6-1/8.::"J;:iole Comment BPXA Sperry-Sun Drilling Services Proposal Report for PBU_ WOA K Pad· K-04B WPS Revised: 18 December, 2002 25.98 E 25.98 E 26.71 E 90.23 E 298.97 E 59.94 N 59.94 N 59.79 N 79.90 N 159.05 N 8868.17 8895.32 8933.29 8441 .30 8455.39 8837.99 8835.21 8843.29 7248.97 7248.97 7268.95 7631.56 8328.26 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Formation Tops 10256.15 10513.61 10873.74 8490.00 8504.83 9192.83 9274.57 9948.41 7250.00 7250.00 7270.00 7639.70 8371.30 Measured Depth (ft) Comments North Slope Alaska Drit/Quest 3.03.02.005 . -....."I ~ 183.63 E TJD 199.21 E TJC 244.15 E TJB 273.51 E TJA 298.98 E Sag River 313.96 E Shublik 330.14 E TSAD 370.26 E TCGL 543.97 E TZ1B 631.06 E TDF Formation Name BPXA Page 8 of 12 7" Casing 4 1/2" Liner Casing Detail 8328.29 8933.29 18 December, 2002 - 9:39 <Surface> <Surface> 8371.33 <Surface> <Surface> 1-0873.74 To Measured Vertical Depth Depth (ft) (ft) Penetration Point Sub-Sea Depth (ft) Eastings (ft) Northings (ft) Sperry-Sun Drilling Services Proposal Report for PBU_ WOA K Pad - K-04B WPS Revised: 18 December, 2002 From Measured Vertical Depth Depth (ft) (ft) Casing details 7890.00 0.000 0.000 7967.05 7943.29 7942.00 0.000 0.000 8021.65 7995.29 8092.00 0.000 0.000 8179.16 8145.29 8190.00 0.000 0.000 8282.07 8243.29 8275.00 0.000 0.000 8371 .33 8328.29 8325.00 0.000 0.000 8379.00 0.000 0.000 8485.00 0.000 0.000 8705.00 0.000 0.000 8757.00 0.000 0.000 Profile Measured Vertical Depth Depth (ft) (ft) Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. Formation Tal's (Continued) North Slope Alaska "VEl1J'Arn DErAILS Phn K-04B K-I» 7250.00 Starting From TVD 0.00 -' Date: Dale: Dale: Darc. Target K-04B A ~ Plm: K-04B ..]>12 (K-I»/Plm K-I»B: Created By: Peach Holtzman 1211 Check<d: Rcvic\wd : Approv<d: 53.29' 53.29n Orign Orign +Ni-S +Fl-W 0.00 0.00 ŒGEND E-W (E-WB). Major Risk K-OI (K.ol), Major Risk K-02A (I(-02A), MajJr Ri;k K-02A (K.o2B), M.pr Ri;k K-02A (K-02C), Mapr Risk K-1I3A (K-1I3A), Mapr Ri;k K-03APBI (K-1I3APBI), Mapr Ris K-1I3APB2 (I(-03APB2), Mapr Ri;1 K·03 (K-1I3), Mapr Risk K-04 (1(-1»), tuERRORS K-04 (1(-001.0\), NOERRORS K-04 (I(-I»APBI), NOERRORS K-I» (K-I»APB2), NOERRORS K-I» (K-I»APB3), NOERRORS K-05A (I(-05A), Mapr Ri;k K-05 (K-05\, Mabr Risk K-07A (I(-ŒA), -Major Ri;k K·07APBI (K-07APBI), Mapr Ri;k K-07APB2 (I(-07APB2). Mapr Ri;k K-07B (K-O'IB), Mapr Ri;k K-07C (K-07C), MajJr Ri;k K-07 (1(-01), Mapr Risk K-12 (K-12~ Mabr Ri;k K-12 (I(-12A). Mapr Ri;k K· '2 (K-12APDI), Mapr Ri;k K-13 (1(-13), Mapr Risk K-14 (1(-14), Mapr Risk K-16(K-16). MaprRi;k K- 16 (I(-I6A). Mapr Risk K-16 (K-16ALl), Mapr Risk K-16(P1mJ5 K-16M2), Mapr Risk K-17(K-I7). Maj:>rRisk K-17 (1(-17 A). Map, Ri;k K-I7(K-I7APBI), Major Ri;k K-17 (K-I7APB2), Major Ri;k K-17 (K-I1PBI), Map, Ri;k K-17 (K-I7PB2). Map, Risk K-17 (1'_123 K-317B), Mapr Risl K-19A (K-19A), Map, Ri;k K-19(K-19), Mapr Ri;k K-:1O (K-20), Mapr Ri;k K-lO (K-lOA), Map, Ri;k K-20 (K-2OPBI), Mapr Ri;k K-lO(PbntI4 K-20B), Mapr Ri;k Pbn K-I»B K-04B ..]>12 VSec -61.21 -61.11 ·84.62 -1~:~1 37.63 90.95 690.61 841.07 99355 1Foœ 0.00 300-00 -25.16 0.00 64.86 21.68 0.00 92.86 96.80 0.00 Parent Welpath: YIConMD: Rig: Ref. DaIum: V.Seclion Anglo 183.111' D!..eg 0.00 ]2.00 4.00 0.00 12.00 ]2.00 0.00 ]4.00 10.00 0.00 - SECTION DErAILS +F/-W 26.00 26.73 90.27 332.81 756.71 71Ð.41 828.48 819.44 S48.6S -53.70 Tool MWI>+IFR+MS ToMD 7250 7500 7750 8000 8250 8500 8750 9000 9250 9500 9750 10000 10250 10500 10750 11000 SURVEY PROGRAM SurveylPlm Pbnn<d: K-04B "'P12 \'2 Jepth Fm Depth To 12..'iO.oo 11J173.85 COMPANY DErAILS BP ÅnD«' CalcuhIbn Method: M'llÏTIIm CUI",ature EmIr System: ISewSA Scan Method: Trav Cymder Nonb W~~W ~~eamg ANTI-COLLISION SETTINGS Interval: 50,00 To: 10873.85 Reference: Plan: K-04B wp12 Sku N/A LatÎl.ude u.ng}ude 1CI'2O'1H.OOON 148"3ô31.400W WEll. DETAn.s E&soog 611453.00 Nonloo8 5\115218,00 +Fl·W 158.16 Na",,, +Nt-S K·(} 2alI.04 +1'11-5 59.89 59.75 79.86 171.81 -õl.32 -79.33 -135.93 -735.98 -87l.oo -992.10 Colour TVD 7248.91 7268.95 7631.63 8441.30 8838.29 8837.99 8835.21 8843.29 8868.17 8933.29 From o 7250 7500 7150 8000 8250 8500 8750 9000 9250 9500 9750 1??oo 10250 10500 10750 A2i ]30.09 90.05 1Ð.23 1Ð.23 133.00 133.78 ]33.78 228.00 2S8.72 258.72 Inc 1.28 3.23 17.17 17.17 90.00 91.95 91.95 81.00 83.95 83.95 90 MD nso.OO 7270.00 7639.78 8490.01 9175.41 9]92.90 9Tl4.75 9948.45 0256.'9 003.85 Inlcrpolation Melhod:MD DeJIÙI Range From: 7250.00 Maximum Range: 1284.53 See I j 4 5 6 7 8 9 10 270 ~2§ -200 -100 -150 =!2§ -200 -175 -so -75 -125 -150 -100 -175 -125 -50 -25 -25 -75 -0 K-04B B K-04B C. [deg] vs Centre to Centre Separation [75ft/in] Azimuth (TFO+AZI) Travelling Cylinder ) Sperry-SUD Anticollision Report ) Company: BP Amoco .Field: Prudhoe Bay Reference Site: PB K Pad Reference Well: K-04 Reference Wellpath: Plan K-04B Date: 12/18/2002 Time: 13:03:55 Page: Co-ordinate(NE) Reference: Well: K-04, True North Vertical (TVO) Reference: 53.29' 53.3 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference· There are 1I8iJfj!1IUd1s in this t1ètð1cipaJ Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 7250.00 to 10873.85 ft Scan Method: Trav Cylinder North Maximum Radius: 1284.53 ft Error Surface: Ellipse + Casing Survey Program for Definitive Well path Date: 02/23/2001 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft ft 91.30 7250.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 7250.00 10873.85 Planned: K-04B wp12 V2 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 8370.50 8327.50 7.00 8.50 7" 10933.13 0.00 4.50 6.12 41/2" Sununary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB E Pad E-09 E-Q9B V5 8590.00 12713.28 789.16 872.69 660.20 Pass: Major Risk PB K Pad K-01 K-01 V1 Out of range PB K Pad K-02A K-02A V3 Out of range PB K Pad K-02A K-02B V1 Out of range PB K Pad K-02A K-Q2C V1 Out of range PB K Pad K-03A K-03A V3 9199.78 11277.22 953.10 219.00 737.05 Pass: Major Risk PB K Pad K-03APB1 K-03APB 1 V2 Out of range PB K Pad K-03APB2 K-03APB2 V2 Out of range PB K Pad K-03 K-03 V1 Out of range PB K Pad K-04 K-04 V1 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk ~ V- AiJ PB K Pad K-04 K-04A VO 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk PB K Pad K-04 K-04APB1 VO 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk V~t bo(¿' PB K Pad K-04 K-04APB2 VO 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk PB K Pad K-04 K-04APB3 VO 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk PB K Pad K-04 Plan K-04B cc V10 Plan 7250.00 7250.00 0.00 64.26 -62.50 FAIL: Major Risk PB K Pad K-04 Plan K-04BL 1 VO Plan: 8650.00 8650.00 0.00 80.31 -71.34 FAIL: Major Risk PB K Pad K-04 Plan K-04BL2 VO 8650.00 8650.00 0.00 80.31 -71.34 FAIL: Major Risk PB K Pad K-06A K-Q6A V4 Out of range PB K Pad K-06 K-Q6 V2 Plan: Undefine Out of range PB K Pad K-07A K-Q7A V1 Out of range PB K Pad K-07APB1 K-Q7APB1 V1 Out of range PB K Pad K-Q7 APB2 K-Q7APB2 V1 Out of range PB K Pad K-07B K-Q7B V1 Out of range PB K Pad K-07C K-Q7C V6 Out of range PB K Pad K-07 K-07 V1 Out of range PB K Pad K-12 K-12 V5 7259.99 7450.00 738.29 73.22 672.13 Pass: Major Risk PB K Pad K-12 K-12A V7 7259.99 7450.00 738.29 73.22 672.13 Pass: Major Risk PB K Pad K-12 K-12APB1 V3 7259.99 7450.00 738.29 73.22 672.13 Pass: Major Risk PB K Pad K-13 K-13 V1 Out of range PB K Pad K-14 K-14 V1 Out of range PB K Pad K-16 K-16 V2 Out of range PB K Pad K-16 K-16A V1 Out of range PB K Pad K-16 K-16AL1 V2 Out of range PB K Pad K-16 Plan#5 K-16AL2 V2 Plan Out of range PB K Pad K-17 K-17 V1 7282.77 7300.00 417.73 65.67 360.99 Pass: Major Risk PB K Pad K-17 K-17A V1 7282.77 7300.00 417.73 65.67 360.99 Pass: Major Risk PB K Pad K-17 K-17APB1 V1 7282.77 7300.00 417.73 65.67 360.99 Pass: Major Risk PB K Pad K-17 K-17APB2 V1 7282.77 7300.00 417.73 65.67 360.99 Pass: Major Risk PB K Pad K-17 K-17PB1 V1 7282.77 7300.00 417.73 65.59 361.01 Pass: Major Risk PB K Pad K-17 K-17PB2 V1 7282.77 7300.00 417.73 65.67 360.99 Pass: Major Risk PB K Pad K-17 Plan#123 K-317B V3 Pia 7282.77 7300.00 417.73 65.76 360.93 Pass: Major Risk PB K Pad K-19A K-19A V3 7256.94 7275.00 743.54 51.69 692.51 Pass: Major Risk PB K Pad K-19 K-19 V1 7256.94 7275.00 743.54 51.69 692.51 Pass: Major Risk ) Sperry-Sun ) Anticollision Report Company: BP Amoco Date: 12/18/2002 Time: 13:03:55 Page: 2 Field: Prudhoe Bay Reference Site: PB K Pad Co-ordinate(NE) Reference: Well: K-04. True North Reference Well: K-04 Vertical (TVD) Reference: 53.29' 53.3 Reference Wellpath: Plan K-04B Db: Oracle Summary <---------------------- Offset Well path ----------------------> Reference Offset Ctr-Ctr No-Go Allow.tble Site Well Well path MD MD Di<¡tance Area Deviation Warning ft ft ft ft ft PB K Pad K-20 K-20 V1 Out of range PB K Pad K-20 K-20A V1 Out of range PB K Pad K-20 K-20PB1 V3 Out of range PB K Pad K-20 Plan#14 K-20B VO Plan: Out of range Site: PB E Pad Well: E-09 Rule A'isigned: Major Risk Wellpath: E-09B V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset T.FO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 8525.00 8474.43 12125.00 8869.47 5.43 268.54 290.58 210.12 2.88 1266.06 862.70 1021.01 Pass ~ 8534.30 8483.15 12150.00 8869.23 5.42 268.90 290.91 207.88 2.88 1242.64 862.62 993.80 Pass 8536.70 8485.40 12175.00 8868.94 5.42 269.02 291.09 207.42 2.88 1219.18 863.74 968.07 Pass 8538.96 8487.52 12200.00 8868.11 5.42 269.13 291.23 206.96 2.88 1195.42 864.72 942.71 Pass 8541.20 8489.60 12225.00 8867.14 5.42 269.24 291.30 206.46 2.88 1171.52 865.59 917.94 Pass 8550.00 8497.79 12250.00 8866.23 5.41 269.52 291.44 204.41 2.88 1147.67 867.45 893.11 Pass 8550.00 8497.79 12275.00 8865.26 5.41 269.56 291.37 204.35 2.88 1123.73 867.72 870.01 Pass 8550.00 8497.79 12300.00 8864.02 5.41 269.60 291.24 204.22 2.88 1099.79 867.98 847.76 Pass 8550.00 8497.79 12325.00 8862.62 5.41 269.64 291.05 204.03 2.88 1075.93 868.24 826.37 Pass 8550.00 8497.79 12350.00 8861.33 5.41 269.68 290.81 203.78 2.88 1052.26 868.50 805.89 Pass 8550.00 8497.79 12375.00 8860.59 5.41 269.72 290.50 203.47 2.88 1028.95 868.76 786.61 Pass 8550.00 8497.79 12400.00 8860.41 5.41 269.76 290.10 203.08 2.88 1006.15 869.01 768.93 Pass 8559.65 8506.73 12425.00 8860.55 5.40 270.03 289.78 200.51 2.88 983.84 869.74 751.89 Pass 8562.25 8509.13 12450.00 8860.85 5.39 270.13 289.23 199.38 962.20 869.98 737.59 Pass 8564.96 8511.62 12475.00 8861.39 5.39 270.22 288.61 198. 16 941.09 870.07 724.75 Pass 8575.00 8520.84 12500.00 8862.23 5.38 270.43 288.00 195.46 920.95 869.08 713.62 Pass 8575.00 8520.84 12525.00 8863.39 5.38 270.47 287.11 194.56 901.77 869.31 705.50 Pass 8575.00 8520.84 12550.00 8864.92 5.38 270.50 286.12 193.57 883.65 869.53 699.38 Pass 8575.00 8520.84 12575.00 8867.09 5.38 270.53 285.03 192.49 866.74 869.74 695.05 Pass 8575.00 8520.84 12600.00 8869.12 5.38 270.56 283.87 191.32 850.60 869.94 691.51 Pass 8575.00 8520.84 12625.00 8870.42 5.38 270.59 282.62 190.07 835.17 870.14 688.19 Pass 8584.78 8529.75 12650.00 8870.95 5.36 270.75 281.44 186.99 820.63 871.44 683.69 Pass 8586.98 8531.74 12675.00 8871.12 5.36 270.80 280.03 185.17 807.41 871.99 677.87 Pass 8588.95 8533.53 12700.00 8870.87 5.36 270.84 278.54 183.31 795.29 872.46 667.85 Pass 8590.00 8534.47 12713.28 8870.69 5.36 270.86 277.72 182.30 789.16 872.69 660.20 Pass Site: PB K Pad Well: K-03A Rule Assigned: Major Risk Wellpath: K-03A V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9350.00 8833.01 10800.00 8708.46 6.80 34.11 59.98 275.68 1263.05 156.45 1106.70 Pass 9350.00 8833.01 10825.00 8709.19 6.80 34.11 60.06 275.76 1239.89 156.53 1083.43 Pass 9350.00 8833.01 10850.00 8709.71 6.80 34.12 60.15 275.85 1216.93 156.60 1060.34 Pass 9339.69 8833.26 10875.00 8709.99 6.80 36.76 58.79 275.93 1194.13 164.70 1029.45 Pass 9336.59 8833.34 10900.00 8710.10 6.80 37.57 58.46 276.04 1172.37 167.24 1005.12 Pass 9325.00 8833.66 10925.00 8710.46 6.80 40.60 56.91 276.10 1151.41 176.52 974.90 Pass 9325.00 8833.66 10950.00 8711.14 6.80 40.62 57.00 276.20 1130.85 176.67 954.13 Pass 9325.00 8833.66 10975.00 8711.59 6.80 40.64 57.11 276.31 1111.42 176.83 934.46 Pass 9325.00 8833.66 11000.00 8711.90 6.80 40.66 57.22 276.42 1093.61 177.02 916.38 Pass 9315.28 8833.93 11025.00 8712.17 6.80 43.25 55.94 276.49 1077.50 184.97 892.32 Pass 9309.64 8834.10 11050.00 8712.56 6.80 44.77 55.22 276.57 1063.15 189.70 873.20 Pass 9300.00 8834.39 11075.00 8713.30 6.80 47.36 53.91 276.60 1050.69 197.65 852.77 Pass 2 7/8"LlNER-TOP @ 8101' 27/8"6.16 #/FT L-80 ST-L ) TUBING SEAL ASSY. 10 = 2.441" wI "X" profile 3.813 CAPACITY = .0058 BBUFT 9 9-5/8" PACKER (B.O.T.) ~ ,Z - (103.958") ~ 41/2", 12.6#/ft, L-80 TAILPIPE 4 1/2" "X" NIPPLE (OTIS) j¡! \:1 (103.813") 4 1/2" "XN" NIPPLE (OTIS) (103.725") 41/2" TBG TAIL~ ( B.O.T )(3.958 1.0.) (ELMO) TREE: McEvoy 6" WELLHEAD: McEvoy ACTUATOR: OTIS 13-3/8", 72 #/ft, L-80, BTRS 12691' I I MAX ANGLE: 90· @ 9,360' I 5 1/2", 17.#/ft, L-80, TBG 10: 4.892 " I CAP: 0.0232 BPF ~\~,'r<\þ ~()OO' l'1þ TOP OF 7"LlNER I 8092' I 9-5/8", 47#/ft, L-80, BTRS I 8346' I ') Foe - . ~ PERFORATION SUMMARY REF: LOG: PDS Memory GRlCCL (9/6/97) SIZE SPF INTERVAL 9310 - 9370 9420 - 9421 1-11/16 4 9421 - 9440 9440 - 9460 1-11/16 4 9460-9480 9480 - 9500 1-11/16 4 9500-9521 9521 - 9540 1-11/16 4 9540 - 9560 9560 - 9580 1-11/16 4 9580 - 9600 9600 - 9630 1-11/16 4 9681 - 9770 OPEN/SQZ'D Squeezed Squeezed Open Squeezed Open Squeezed Open Squeezed Open Squeezed Open Squeezed Isolated Q.I~·' Or) ~ ß \' PBTD I 8953' I 7" ,26#/ft, l-80, BTRS 1 8993' I DATE 8/9/89 3/21/97 9/8/97 3/13198 REV. BY W.R.R. Hildreth PPA Engler K-04A ) KB. ELEV = 61.21' BF. ELEV = 24.79' (t SSSV LANDING NIPPLE I ' I (CAMCO )( 4.562" 10) 2037 FLAPPER I ~ GAS LIFT MANDRELS ( OTISWI RA LATCH) N° MD(BKB) TVDss 6 3172 3139 5 5136 5038 4 6603 6538 3 6747 6638 2 7689 7638 1 7841 7738 l ~."",,~,,'"I":'':':: I I SLIDING SLEEVE BAKER MOD. "L" (4.313" MIN. 10) 7950' 8012' 8036' 8083' ~ ... 8123 ' 8165' 8177' Horizontal I Window I /' 8381'to8387' ~ CIBP I 9655' I I c::J - ," I ,^. I w' '''''',~,,'''''. '-~ r-t . I J I, I I ;,'". . .:,.:"n":'~':';'1 I ·:'~,I ~ I:, :',:] ~ lOp of Whipstock I 8378' I -...... (ELMO) MARKER JOINT I 8540' 1 '1'*' Top of Cement (CTMD) I 8598' I ~~ , ;g. PBTD I 9796' I TO I 9858' I COMMENTS Put on mac CTO Sidetrack Revision Post squeeze perfs Set CIBP PRUDHOE SAY UNIT WELL:K-04AC12-04-11-14) API NO: 50-029-21023-1 SEC. 04: TN 11N: RGE 14E BP Exploration (Alaska) · TREE =. 6" MCEVOY WELLHEAD = MCEVOY AcTUA iÖR =,^,wmN'''õfìŠ KB.mï3j~\r ~ ",···W··""'NW iii'21, äF~"ËlË.V = _"~_m^,""N''''''''''24~79'' KOP ;MNmM"'W'W'W^'----a4oo' MäxAng'ìe ;;---'""95@-9692Î "ôãtum MD'; ,,"''''WM'W'''''_ DatüÍŸïiVÒ ';" 8800' SS ) K-04A - )ETY NOTES: Wß.L EXCEEDS 70° @ 8700' AND GOES HORIZONTAL @ 9360\ - 2037' 1---15-1/2" CAM SSSV LAND NIP, ID = 4.562" 1 GAS LIFT MANDRELS 1 9-5/8" DV PKR 1---1 2609' ~= - ST MD ìVD DEV TYÆ VLV LA TCH PORT DATE - 113-3/8" CSG, 72#, L-80, ID = 12.347" 1---1 2691' ~ ~ 6 3172 3139 0 OTIS DOME RA 16/24 08/26/97 5 5136 5038 2 OTIS SO RA 20/64 08/26/97 L 4 6603 6538 1 OTIS DV RA 0 08/26/97 1 PLANNED TUBING CUT 1---1 7,300' ~ 3 6747 6638 1 OTIS DV RA 0 08/26/97 2 7689 7638 1 OTIS DV RA 0 08/26/97 1 PLANNED Toe: 1---1 7,910' 1 ~ 1 7841 7738 1 OTIS DV RA 0 08/26/97 15-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1---1 8013' Minimum ID = 2.37" @ 8106" TOP OF 2-7/8" LNR 1 9-5/8" X 7" BKR LNR HGR I TIEBACK SL V 1---1 8092' I 3.75" BKR DEPLOY MENT SL V, ID = 3.00" 1---1 8101' I TOP OF 2-7/8" LINER, ID = 2.37" 1---1 8106' 14-1/2" TAILPIPE, 12.6#, L-80, .0152 bpf, ID = 3.958" 1---1 8165' ÆRFORA TION SUMMARY REF LOG: PDS MEMORY GRlCCL 09/06/97 ANGLE AT TOP PERF: 86 @ 9310' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 49310-9370 S 08/24/97 1-11/16" 4 9420 - 9630 S 08/24/97 1-11/16" 4 9680 - 9770 S 08/24/97 1-11/16" 4 9421 - 9440 0 09/08/97 1-11/16" 4 9460 - 9480 0 09/08/97 1-11/16" 4 9500 - 9521 0 09/08/97 1-11/16" 4 9540 - 9560 0 09/08/97 1-11/16" 4 9580 - 9600 0 09/08/97 1-11/16" 4 9681 - 9770 C 03/14/98 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1---1 8995' DATE 11/02183 03/21/97 02/23/01 03/03/01 07/29/01 REV BY COMMENTS ORIGINAL COMPLETION CTD SIDETRACK SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL CHIKA K CORRECTIONS 1 /'1 7950' 8013' I I ,. y~j:;";'t·:;, ~ I ':::<~c·::./:< !I ~ ' ': . ~ . . :.~: ,~ .'. '; ,y"," : . ~ . ~·~..··r ~~\ ''', ,:. g 8036' 8048' 8083' .i ',: 8123' 8166' 8177' ~ .. 8346' 1---19-5/8" CSG, 47#, L-80, ID = 8.681" I 1---15-1/2" BKR L SLIDING SLV,ID = 4.313" 1 I---1TBG SEAL ASSY W/ X PROFILE, ID = 3.813" 1---19-5/8" X 5-1/2" BOT PKR, ID = 3.958" 1 1---15-1/2" X 4-1/2" XO, ID = 3.958" I 1---14-1/2" OTIS X NIP, ID = 3.813" 1 1---14-1/2" OTIS XN NIP, ID = 3.725" I 1---14-1/2" TBG TAIL ID = 3.958" 1 1---1 ELMDTT LOG NOT AVAILABLE I 9,270' 1---1 Proposed BP I 7" MILLOUTWINDOW 8381' - 8387' WHIPSTOCK @ 8378' RA TAG @ 8387' x I x ( )( ~ ~~ - - 9655' 1---1 CIBP 03/14/98 1 ~ PBTD 1---1 9796' 12-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" 1---1 9858' DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: K-04A ÆRMIT No: 1970210 API No: 50-029-21023-01 SEC 4, T11 N, R14E 1942' SNL & 1185' EWL BP Exploration (Alaska) TREE: McEvoy 6" WELLHEAD: McEvoy K-04B Proposed Completion Base Flange Elevation = 24.79' Nabors 2ES RKB = 53.29' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' 13-3/8",72 #/ft, L80, BTC I 2691' I J ~ Window Milled from Whipstock Top of Window at +1-7,250' MD- u ~ -rOC ~ flot.:> I I +1-7100' I BAKER 7" x 9-518" lie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger .~ pRonUCTION TURING nFTAU S 4-1/2", 12.60 I bItt, L-80,IBT-M Coupling 00: 4.932" OriftllO: 3.833"/3.958" 1 2 3 4 GAS LIFT MANDRELS . ND Size Valve Type TBD 1-1/2" DCK-1 Shear TBD 1-1/2" DV TBD 1" DV TBD 1" DV I J 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-112" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.725" seal bore. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. 18092' I . I +1-8,221' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger -.; - I +/-8,371' 7",26 #/ft, L-80, BTC-Mod 4-1/2" 12.6 #/ft, L-80, BTC-Mod I +1-10,874' I Plug Back Depth I +1-10,794'1 Horizontal Sidetrack into Zone 1 Sands 9-5/8", 47 #/ft, L-80, BTC I 9.208' I Date 12/18/02 Rev By Comments Mik Triolo Proposed Completion GLI WELL: K-048 API NO: 50-029-21023-02 -------- ------- P054972 DATE ) INVOICE / CREDIT MEMO DESCRIPTION 1/18/02 INV# CKll1402M PERMIT TO DRILL FEE ~-DZ¡ß ë ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ,i , ANCHQAAGE;, AK99519-6612 PAY TO THE(' ORDER OF '¡,:: ;:::; ',::::::::'\ ';::":: ,,:.:?:: .'..,.,. '1!',.','.,..'., (lJ,.',..', ",.",.. ,.'" ,"'.~",',',', ,i:...,..'.',.,',~.','".~V,'~,.,','.,'.',','",'",.~.:",.',' " ~~, ",., tJ ,·.r, ...J.f~4f~, ' (m,1 """.' ::....':,.. ,,',:.;.'. . ',:,:.:::.' .,:.,:",:,.',',::; i ,i.'i,'.. ".i>" ..,:::'::::::" ::/:!:;:!: ' ,', :,,/::. ' "::\,: :::\::::.. ,":::":.:' ('. : ':;::,;;...: .', .'" ',:' ,c"',,.,'· ·}hL~~KAbi~ & GAS GO~~ER~AT±~N CO~IS!.:rq~ "",,',', ",,' 333,;W ?~~A~NUE SUI~E ;1Ø6 ANCHQRAC;.E, )\¡{ 99501 GROSS NATIONAL CITY BANK Ashland, Ohio >'DATE< DATE CHECK NO. ) 11/18/02 P054972 VENDOR DISCOUNT NET 56-389 4T2 No.P C6N$0I.JDÂTEP COMMERCIAL ACCOÚNT. 054972 AMOUNT NQvi8~' 20:02 i!**~$looL,oO**** NO~VALlbÁÞr-Ë·~120 ÚÄ,vs"> .,,'.::: ' : .,:':,,:"'.,: .,:.,'.:::.",',.' ;"'" '," ." ~¡¡<.:.;.:;::¡<::~S:::::~::j~r.:.~.~~;;.~~:y~~:;;\~J~ i ,.., ...... L~r"'"'' ....' ....' ..·..1 ;i:(ij~~~tJ {t;,~{;~f:~~;;~:ifÙDi~J III 0 5 l. ~ ? 2111 I: 0.... ~ 2 0 j a ~ 51: 0 ~ 2 ? a ~ b III .. ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "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. HOLE 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 ~nd logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance 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 A,fJ)( WELL NAME PA'û /:::"(57'.../1 PROGRAM: Exp _ Dev L Redrll X Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL ~ i cJ/.5 0 INIT CLASS /);aJ ¿ /-rv~') GEOL AREA )? ?' ð UNIT# / I ~.5' ð ON/OFF SHORE ..QL?) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. . . . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ¿p,/ '" .,¿ ~ J. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N PG /~CJ-v 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.. . . ., Ey , N , LJ (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y ,/t/, r¡ "- (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. N ENGINEERING 15. Conductor string provided. . .. . . . . . . . . . . . . . . . Y N . 16. Surface casing protects all known USDWs. . . .. . . . . . ¥ N· .' IA_ 17. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N /'l¡I'r 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . ~ 19. CMT will cover all known productive horizons. . . . . . . . . . é:f/ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . i' N ~' .-- 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N *- (J,-Ç, 7.. ~ .s 22. If a re-drill, has a 10-403 fo.r abandonment been approved. . . N; q / ~ '- . 23. Adequate wellbore separation proposed.. .'.. . . . . . . . . . N, 24. If diverter required, does "it meet regulations. ., . . . . . . . ~ f'ollllo· .. 25. Drilling fluid program schematic & equip list adequate. . . . . .~, ,N M~ n1 kl, ,0" 'I, r pC} . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ) , Ie:, , ~7.. BOPE press rating appropriate; test to 3500 psig. ' y'lIt S i 1-.y to r) S ¿ . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . , N 29. Work will occur without operation shutdown. . . . . . . . . . . .. N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . y.W) IA 31. Mechanical condition of wells within AOR verified. . . . . . . . .-¥--N- ¡oJ I" ;r )V. t9, APPR DATE vJt.1k j 1'/03 (Service Well Only) GEOLOGY APPR DATE ;//~ /~¥~ J' (Exploratory Only) ( 32. Permit can be issued w/o 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 name/phone for weekly progress reports. ...... ( . GEe;¡¿ PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP TEM JDH JBR COT () I JQ ~/05 DTS / MJW MLB 0'/D7/03 SFD WGA Rev: 10/15/02 - G:\geology\permits\checklist.doc ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ) ~Od--a 53 117/Q Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 07 08:45:57 200j Reel Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/05/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .03/05/07 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 PBU/WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA K-04B 500292102302 BP EXPLORATION Sperry Sun 07-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 K-MW-2340063 J. BOBBITT R. BORDES MWD RUN 2 K-MW-2340063 J. BOBBITT R. BORDES MWD RUN 3 K-MW-2340063 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 4 11N 14E 1942 1185 .00 52.59 24.79 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ) ) BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7100.0 6.125 7.000 8358.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL KICKED OFF FROM K-04 WITH TOP OF WHIPSTOCK SET AT 7217' MD, 7216' TVD. 4. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. MWD RUN 2 WAS DIRECTIONAL DGR¡ EWR-4¡ COMPENSATED THERMAL NEUTRON POROSITY (CTN) ¡ AND STABILIZED LITHO-DENSITY (SLD). 6. MWD RUN 3 WAS DIRECTIONAL WITH DGR¡ AND EWR-4. 7. MWD DATA WAS BLOCK SHIFTED 11' DOWN, PER THE 5/2/2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER AND RUN INFORMATION DATA RETAIN DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL K-04B WITH API # 50-029-21023-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11012' MD I 8919' TVD. SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SMOOTHED FORMATION EXPOSURE TIME. SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SROP SGRC SEXP SESP SEMP SEDP SFXE TNPS CTFA CTNA SBD2 SC02 SNP2 PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.12511 MUD WEIGHT: 8.4 PPG MUD SALINITY: 300-400 PPM CHLORIDES FORMATION WATER SALINITY: 10,100 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 ) ) Date of Generation..... ..03/05/07 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS RPD FET RPX RPM ROP FCNT NCNT NPHI PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7112.5 7214.0 7214.0 7214.0 7214.5 7214.5 7259.5 8279.5 8279.5 8311.5 8311.5 8324.0 8324.0 STOP DEPTH 10968.0 10974.5 10974.5 10974.5 10974.5 10974.5 11023.5 8870.5 8870.5 8870.5 8885.5 8885.5 8885.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 7112.5 8279.5 8897.0 MERGE BASE 8370.0 8962.0 11023.5 # 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 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 RPX MWD OHMM 4 1 68 12 4 ') ) RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/GM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7112.5 11023.5 9068 7823 7112.5 11023.5 ROP MWD FT/H 0.02 548.76 83.9492 7529 7259.5 11023.5 GR MWD API 12.36 380.81 89.8461 7712 7112.5 10968 RPX MWD OHMM 0.57 1887.18 25.8481 7521 7214.5 10974.5 RPS MWD OHMM 0.37 1973.55 32.003 7522 7214 10974.5 RPM MWD OHMM 0.09 2000 56.131 7521 7214.5 10974.5 RPD MWD OHMM 0.63 2000 53.591 7522 7214 10974.5 FET MWD HOUR 0.21 50.15 2.78272 7522 7214 10974.5 NPHI MWD PU-S 9.48 57.06 24.7836 1119 8311.5 8870.5 FCNT MWD CNTS 124.8 1983 638.757 1183 8279.5 8870.5 NCNT MWD CNTS 15508.9 44311.8 27422.5 1183 8279.5 8870.5 RHOB MWD G/CM 1.648 3.013 2.33128 1055 8324 8885.5 DRHO MWD G/GM -0.704 0.315 0.0377972 1055 8324 8885.5 PEF MWD BARN 1.57 16.16 3.51521 1149 8311.5 8885.5 First Reading For Entire File......... .7112.5 Last Reading For Entire File.......... .11023.5 File Trailer Service name............ .STSLIB.001 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 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...... .03/05/07 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX RPD FET ROP $ -) 1 .5000 START DEPTH 7112.5 7214.0 7214.0 7214.0 7214.0 7214.0 7259.5 STOP DEPTH 8332.5 8325.0 8325.0 8325.0 8325.0 8325.0 8370.0 # 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 VENDOR TOOL CODE DGR EWR4 $ # BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ) 22-MAR-03 Insite 6.02 Memory 8359.0 7110.0 8359.0 1.2 19.3 TOOL NUMBER 136696 121079 8.500 7100.0 LSND 10.10 65.0 9.1 400 4.8 3.200 1.740 5.000 5.000 74.0 141.8 74.0 74.0 ) ) 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . 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 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7112.5 8370 7741.25 2516 7112.5 8370 ROP MWD010 FT/H 0.5 277.54 102.652 2222 7259.5 8370 GR MWD010 API 40.92 356.01 145.561 2441 7112.5 8332.5 RPX MWD010 OHMM 0.57 1887.18 4.83862 2223 7214 8325 RPS MWD010 OHMM 0.37 1888.57 6.15751 2223 7214 8325 RPM MWD010 OHMM 0.09 2000 9.98413 2223 7214 8325 RPD MWD010 OHMM 0.63 2000 21.3886 2223 7214 8325 FET MWD010 HOUR 0.21 5.88 1.14343 2223 7214 8325 First Reading For Entire File......... .7112.5 Last Reading For Entire File.......... .8370 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 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...... .03/05/07 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: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF GR RPX RPS RPM RPD FET DRHO RHOB ROP $ ) 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 8279.5 8279.5 8279.5 8293.0 8306.0 8313.0 8313.0 8313.0 8313.0 8313.0 8324.0 8324.0 8370.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 8870.5 8870.5 8870.5 8885.5 8898.5 8905.5 8905.5 8905.5 8905.5 8905.5 8885.5 8885.5 8962.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 26-MAR-03 Insite 6.02 Memory 8951.0 8359.0 8951.0 17.5 61.0 TOOL NUMBER 151107 154267 153020 156401 6.125 8358.0 LSND 8.40 45.0 9.0 400 21.0 10.000 4.320 12.000 58.0 143.0 58.0 ) ) MUD CAKE AT MT: 9.500 58.0 # 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 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 RPX MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPM MWD020 OHMM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 FET MWD020 HOUR 4 1 68 24 7 NPHI MWD020 PU-S 4 1 68 28 8 FCNT MWD020 CNTS 4 1 68 32 9 NCNT MWD020 CNTS 4 1 68 36 10 RHOB MWD020 G/CM 4 1 68 40 11 DRHO MWD020 G/CM 4 1 68 44 12 PEF MWD020 BARN 4 1 68 48 13 GR MWD020 API 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8279.5 8962 8620.75 1366 8279.5 8962 ROP MWD020 FT/H 0.09 172.39 32.2692 1184 8370.5 8962 RPX MWD020 OHMM 0.84 1633.09 63.3122 1186 8313 8905.5 RPS MWD020 OHMM 1.13 1973.55 97.876 1186 8313 8905.5 RPM MWD020 OHMM 0.97 2000 277.962 1186 8313 8905.5 RPD MWD020 OHMM 0.82 1801.31 216.107 1186 8313 8905.5 FET MWD020 HOUR 1.98 50.15 8.37465 1186 8313 8905.5 NPHI MWD020 PU-S 9.48 57.06 26.1841 1183 8279.5 8870.5 FCNT MWD020 CNTS 124.8 1983 638.757 1183 8279.5 8870.5 NCNT MWD020 CNTS 15508.9 44311.8 27422.5 1183 8279.5 8870.5 RHOB MWD020 G/CM 1.648 3.013 2.33128 1055 8324 8885.5 DRHO MWD020 G/CM -0.704 0.315 0.0377972 1055 8324 8885.5 PEF MWD020 BARN 1.57 16.16 3.8197 1186 8293 8885.5 GR MWD020 API 12.36 380.81 57.0443 1186 8306 8898.5 First Reading For Entire File......... .8279.5 ') Last Reading For Entire File.......... .8962 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 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...... .03/05/07 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 ') header data for each bit run in separate files. 3 .5000 START DEPTH 8897.0 8903.5 8903.5 8903.5 8903.5 8903.5 8962.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 10968.0 10974.5 10974.5 10974.5 10974.5 10974.5 11023.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 29-MAR-03 Insite 6.02 Memory 11012.0 8951.0 11012.0 8938.0 93.3 TOOL NUMBER 151107 156401 ) ,I' $ # 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ~, 6.125 8358.0 Water 8.40 47.0 8.8 350 11.0 Based 2.000 .940 3.000 3.250 75.0 167.0 75.0 75.0 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 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8897 11023.5 9960.25 4254 8897 11023.5 ROP MWD030 FT/H 0.02 548.76 88.7107 4123 8962.5 11023.5 GR MWD030 API 24.42 151.13 66.1288 4143 8897 10968 RPX MWD030 OHMM 9.51 69.39 26.2688 4143 8903.5 10974.5 RPS MWD030 OHMM 9.45 72.75 27.0916 4143 8903.5 10974.5 RPM MWD030 OHMM 10.34 69.56 27.9485 4143 8903.5 10974.5 \ f \ RPD MWD030 OHMM FET MWD030 HOUR 11.27 0.23 73.49 18.72 29.6325 4143 2.36004 4143 8903.5 8903.5 10974.5 10974.5 First Reading For Entire File......... .8897 Last Reading For Entire File.......... .11023.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/07 Maximum Physical Record. .65535 File Type............ . . . .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/05/07 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 Date.................... .03/05/07 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