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Home My WebLink About201-206 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFichefile. Please insure that it remains as the first page in this file. ;J-° / ¿;-tJ Þ Well History File # Digital Data Added to LaserFiche File CD's - # Yes No DVD's - # Yes No Diskettes - # Yes No Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil D Gas D Plugged a Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC25.110 a Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 7/18/2004 201-206 304-255 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/13/2001 50-029-2141~02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/2912001 PBU K-O5B 1935' SNL, 441' EWL, SEC. 04, T11N, R14E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 5187' SNL, 786' WEL, SEC. 05, T11N, R14E, UM 55.03' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1864' SNL, 1279' WEL, SEC. 08, T11N, R14E, UM 11712 + 8917 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 670710 y- 5975268 Zone- ASP4 11752 + 8939 Ft ADL 028304 TPI: x- 669565 y- 5971989 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 669123 y- 5970023 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes aNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR, RES, DEN, NEU, Memory CNL, CCL 2. CASING, LINER AND CEMENTING RECORD CAsiNG -, MD' NO HoLE AMOUNT SIZE WT. PER FT. ,GRADE TOP '&;>VIIUM T Of' I BOTTOM SIze CEMENTING RECORD PULLED 20. x 30. Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2793' Surface 2701' 17-1/2" 3999 cu ft Permafrost 9-5/8" 47# L-80 Surface 7410' Surface 6683' 12-114" 1982 cu ft Class 'G' 7. 26# N-80 7266' 9141' 6559' 8297' ~1/2" 189 cu ft Class 'G' 4-1/2" 12.6# L-80 8979' 10899' 8144' 8843' 6-1/8" 98 cu ft Class 'G' 3-1/2" x 2-7/8" 8.81# 16.16# L-80 10798' 11749' 8837' 8937' 3-3/4" 16 cu ft Class 'G' 23. Perforations o?en to Production (MD + TVD of Top- and 2.,i~", ",,',,' ,T,,'~ " i':,"(,', ,', ' Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2, 12.6#, L-80 8989' 8928' MD TVD MD TVD ,": AciD. FRACTURE, CEMENT SQUEEZE. ETC. " DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9660' Set Whipstock Anchor Packer 9644' Set Whipstock 9644' P&A with 40 Bbls Class 'G' / 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production NIA Date of Test Hours Tested PRODUCTION FOR OIL-Bel GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED + OIL-Bel GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8Fl AU611 '004 ! "c~ Ii, - ~f/ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE UKlblNAL ~~y: \~.;.\o~ ~ ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 9662' 8742' None Base Sadlerochit 11680' 8903' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ 1ft. ." \ 1 /J L // Signed T erne Hubble ",""""117 AI \L.O tlu..xn. f\.P Title Technical Assistant PBU K-05B 201-206 304-255 Well Number Permit No.1 Approval No. INSTRUCTIONS Date 09 -{ I-()l.{ Prepared By NamelNumber: Drilling Engineer: Terrie Hubble, 564-4628 Thomas McCarty, 564-4378 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 8: ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only ~ ~ Well: Field: API: Permit: K-05C Prudhoe Bay Unit 50-029-21418-03-00 204-118 Accept: Spud: Release: Rig: 07/17/04 07/20/04 07/25/04 Nordic #1 ,~" "~,"'" '..""""""..,,""',...,,..,,----~---,-~._..... ""..".~~.......'._""" PRE-RIG WORK 04/30/04 ATTEMPT TO PULL RELEASEABLE SPEAR WI NO SUCCESS. CALIPER TBG. FROM 9344' SLM TO SURFACE. SWITCH TO 3" WT. BAR. JARRING DOWN ON SPEAR CORE AT END OF DAY. 05/01/04 ATTEMPT TO PULL RELEASEABLE SPEAR, SET WHIDDON STYLE CATCHER SUB @ 9326' SLM. 05/02104 PULLED STA # 3,4. CATCHER STILL IN HOLE 05/03/04 SET RK-DGLV IN STA #4 @ 4284' SLM. RIU LITTLE RED PUMPED 60 BBLS SHUT DOWN, PUMPING EQUIPMENT PROBLEMS. SET RK-DGLV IN STA #3 @ 6945' SLM. PULLED CATCHER FROM 9343' SLM (EMPTY). RIG DOWN. 07/09/04 DRIFTED TBG WI 20' X 3.70" DUMMY WHIPSTOCK, SAT DOWN @ 7456' SLM. (TARGET WAS 9375' MD). DRIFTED TO 9351' SLM (TARGET DEPTH) W/3.50" LIB. DRIFTED TBG WI 3.80" GAUGE RING TO 7800' SLM, NO TIGHT SPOTS ENCOUNTERED. DRIFTED WI 5' STEM, 3.70" CENT, 5' STEM, 3.70" CENT, 5' STEM, 3.80" GAUGE RING TO 9328' SLM. DRIFTED WI 5' STEM, 3.70" CENT, 5' STEM, 3.70" CENT, 5' STEM, 3.50" LIB TO 9338' SLM, CAME BACK WI PIC OF "G" FN. BEGINTO RIH WI WHIPSTOCK (19' X 3.65" 00). 07/10/04 DRIFTED W/19' X 3.65" WHIPSTOCK TO 9340' SLM. ~ ~ BP EXPLORATION Page 1 .. Operations Summary Report Legal Well Name: K-05 Common Well Name: K-05 Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 7/17/2004 End: 7/26/2004 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2004 02:00 - 02:45 0,75 MOB P PRE Prepare rig for move. Off Critical Path Operations: - Kill K-05 with HOT and VECO. 02:45 - 04:30 1,75 MOB P PRE PJSM. Place Herculite. Move Rig over K-05C, RIG ACCEPT: 04:30 hrs 7/17/2004 04:30 - 08:30 4.00 MOB P PRE ND Tree cap. NU BOPE. 08:30 - 17:30 9.00 BOPSUF P PRE PT BOP's as per AOGCC Drilling Permit # 204-118 BOP & Valving @ 400/3500 psi and 250/2500 psi on annular Witnessed John Crisp AOGCC Inspector 1 failure, valve # 12 rebuild 17:30 - 20:15 2,75 BOPSUF P PRE Open well. - Well on vacuum. - Fill hole at 1bpm. - Lost total of 194 bbls in 3 hours. Conduct PJSM. Position injector head. MU BOT CTC (pull test to 35k / pressure test to 3500 psi). Test reel valve to 400 psi low and 3500 psi high, 20:15 - 21:30 1,25 FISH P DECaMP PU fishing BHA. - Filling hole across the top at 1 bpm. - Rupture disk pinned to 5100 psi. - 7/8" ball for disconnect. - All equipment drifted to 1.186" 21 :30 - 23:30 2.00 FISH P DECaMP RIH with fishing BHA at 80 fpm, - Pumping at 1-2 bpm, filling hole, - No indication of hanging up at 7400' MD (slickline had difficulty there in the past). - SD Pumps, fill across the top. - At 9280' MD: PU at 44k; SO at 25k. 23:30 - 00:00 0.50 FISH P DECaMP Tag fish at 9365' MD. Begin jarring. - Jarring down at 35k down weight, 75 - 100 fpm, - Completed 25 jar licks. 7/18/2004 00:00 - 00:15 0,25 FISH P DECaMP Continue jarring. Fish free. Push fish to 9800' MD (at 75 fpm), - Jarring down at 35k down weight, 75 - 100 fpm, - Coil life at 30% in jarring area, - Completed 27 total jar licks, free on lick #27, 00:15 - 00:30 0.25 FISH P DECaMP Fish stopped at 9800' MD. Attempt 2 more jar licks down, Not successful. Bring rate up to 2 bpm, release from fish. 00:30 - 02:15 1,75 FISH P DECaMP POOH with fishing BHA #1. - 70 fpm; 2.4 bpm; 4000 psi. - Well on a vacuum. Losing fluid to formation at approximately 2bpm. 02:15 - 03:00 0.75 FISH P DECaMP LD BHA. 03:00 - 05:15 2,25 WHIP P WEXIT Spot E-line unit. Rig up tools, PJSM, RU sheaves in derrick. Bring tools to rig floor. 05:15 - 06:50 1.58 WHIP P WEXIT RIH with run #1 - 3.75" gauge ring, CCL, and GR to 9700' MD. POOH and pulled tight at 8960 ft, worked free, "X" nipple Printed: 7/2712004 10:46:13 AM ,~ ~ BP EXPLORATION Operations Summary Report Page 2'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-05 K-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/17/2004 Rig Release: 7/26/2004 Rig Number: N1 Spud Date: 11/4/2001 End: 7/26/2004 Date From~To Hours Task Code NPT Phase Description of Operations 7/18/2004 06:50 - 07:45 0,92 WHIP P WEXIT LD GA and Aehead eline for packer run 07:45 - 08:15 0,50 WHIP P WEXIT PSJM on packer running SOP and hazards 08:15 - 09:30 1,25 WHIP P WEXIT Set up SLB Eline orientation and attaching WFT running tools, Changed out shooting GRlCCL Well taking 3 bpm to maintain full. 2 trucks hauling to rig at present time 09:30-11:18 1.80 WHIP P WEXIT AIH with Packer to 9753 ft 11:18 -11:33 0.25 WHIP P WEXIT PUH tying in Corrected +13 ft (+2 ft for PDC log). Conducted tie-in pass Confirmed. Set top of packer at 9660 ft and 20,6 deg right. Logged off. 11 :33 - 12:20 0.78 WHIP P WEXIT POOH with setting tools 12:20 - 13:15 0.92 WHIP P WEXIT AD SLB Eline and load pipe shed with WS running tools, Confirmed shear values on both and lug setting 13:15 - 14:10 0,92 WHIP P WEXIT MU Weatherford's WS BHA 14:10 - 16:52 2.70 WHIP P WEXIT AIH with WS, filling across the top, lossing 2 bpm Wt check at 9500 ft 43k. Tagged 9674', cycled 4 times and sheared lugs. PUH and tagged. OK. Top of WS 9663' CTMD 16:52 - 17:38 0,77 WHIP P WEXIT Cir down CT and displace well bore with 1-1/2 ppp bio water. Lossing 2 bpm as before. seals failed on K-Latch or the colletts failed and we still have the WS. Having WFT build new WS assembly, 17:38 - 19:30 1,87 WHIP P WEXIT POOH, Filling hole across the top with seawater. 19:30 - 19:45 0,25 WHIP P WEXIT LD BHA, 19:45 - 21 :30 1,75 WHIP N WAIT WEXIT Discuss options of plan forward. - Will have SLB E-line perform an STP (spinner/temperature/pressure) log for leak detection. 21 :30 - 23:30 2.00 WHIP N WAIT WEXIT Wait on SLB personnel to mobilize tools and equipment. 23:30 - 00:00 0.50 LCA N DPAB WEXIT Aig up SLB E-line. 7/19/2004 00:00 - 00:45 0.75 LCA N DPAB WEXIT Aig up SLB E-line. Prepare tools for AIH. 00:45 - 01 :45 1.00 LCA N DPAB WEXIT AIH with SLB E-line STP (spinner, temperature, pressure) log. 01 :45 - 02:00 0.25 LCA N DPAB WEXIT Logged down to 9650, - Set tool down at 9660' ELM (TOWS), Logged up from 9650 to 9470' MD, WI! flow going through packer/whipstock assembly. 02:00 - 02:45 0.75 LCA N DPAB WEXIT POOH with SLB E-line STP, 02:45 - 03:45 1.00 LCA N DPAB WEXIT AD SLB. Aelased from location. 03:45 - 06:00 2.25 LCA N DPAB WEXIT Wait on SLB Cementing to prepare slurry to shut off losses. Cement plan: - 15.8 ppg, no bentonite. - 3.5 hrs TT - BHST = 180 deg; BHCT = 101 deg. - 40 bbls pumpable /' - 10 bbls neat cement .20 bbls aggregate - 10 bbls neat cement 06:00 - 09:00 3.00 LCA N DPAB WEXIT WO Cementers 09:00 - 10:00 1.00 LCA N DPAB WEXIT PU/MU Cement BHA, PT hardline 10:00 - 11:40 1.67 LCA N DPAB WEXIT AIH and tagged the WS at 9359.2', PUH and painted flag at 9649.2 ft 11 :40 - 11 :55 0.25 LCA N DPAB WEXIT POH to 9425' ft to conduct injectivity test. 2bpm up to 1850 psi SD pressure stabiliz at1820 si. Aeleased pressure, cirulating at 1:1 rati . Go fï.gur Printed: 7/27/2004 10:46:13 AM ~ .--.... Page 3 48 BP EXPLORATION Operations Summary Report: . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-05 K-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 7/19/2004 11 :55 - 12:35 0,67 LCR N DPRB WEXIT 12:35 - 14:30 1,92 STWHIP P WEXIT 14:30 - 14:45 0,25 STWHIP P WEXIT 14:45 - 16:40 1.92 STWHIP P WEXIT 16:40 - 22:00 5,33 STWHIP P WEXIT 22:00 - 00:00 2,00 STWHIP P WEXIT 7/20/2004 1,50 STWHIP P WEXIT 00:00 - 01 :30 01 :30 - 03:00 1,50 STWHIP P WEXIT 03:00 - 03:30 0.50 STWHIP P WEXIT 03:30 - 05:30 2.00 DRILL P PROD1 05:30 - 06:00 0,50 DRILL P 06:00 - 07:08 1,13 DRILL P 07:08 - 07:26 0,30 DRILL P 07:26 - 07:33 0.12 DRILL P 07:33 - 07:44 0.18 DRILL 07:44 - 08:51 1.12 DRILL 08:51 - 09:05 0.23 DRILL 09:05 - 10:23 1.30 DRILL 10:23 - 10:29 0.10 DRILL 10:29 - 11:20 0,85 DRILL 11:20-12:15 0.92 DRILL 2,00 DRILL N PROD1 PROD1 PROD1 PROD1 SFAL PROD1 Start: 7/17/2004 Rig Release: 7/26/2004 Rig Number: N1 Spud Date: 11/4/2001 End: 7/26/2004 Description of Operations Turn hole over to 1-1/2 ppb Bio water POOH to PU milling BHAPU WFT window PU/MU WFT Milling BHA RIH and tagged at 9662.2 ft Painted flag Q = 2,63 bpm 1910 psi off bottom Milling window as per WFT SOP's Vol pits = 260 bbl's - Adjusted depth -14.5' to reflect actual depth of TOWS at 9648.15' MD (top of plug at 9660 - 11.85' of whipstock). - RIH at 0.2-0.4 fpm, 2.5 bpm in / 2.5 bpm out, 1950 psi. - Top of Window at 9648' CTMD. - Bottom of Window at 9653.75' CTMD Drill 10' of new formation to 9664' MD, Dress window. - RIH at 0.2-0.4 fpm, 2.5 bpm in / 2.5 bpm out, 1720 psi. - Pit volume at 257 bbls. - Metal shavings back to surface. - Dress twice with pumps on. Dress window, - RIH at 0.2-0.4 fpm, 2.5 bpm in /2.5 bpm out, 1720 psi. - Pit volume at 257 bbls. - Metal shavings back to surface, - Dry tag, - Swap fluid to flo pro reconditioned mud, POOH. - Continue to swap to Flo Pro as POOH, - EOP flag at 9400' MD (orange). LD window milling BHA. - Window mill 3.8 go /3.79 nogo, - String mill 3.8 go /3,79 nogo. Pre-Spud on K-05C. PJSM. PU build BHA. MU coil connector. - Pressure test to 3500 psi. - Pull test to 35k. Change Packoff, RIH with Build BHA #5, Shallow hole test MWD and Orienter. Continue to RIH with Build assy BHA #5. Corrected to flag at 9400' EOP. Depth = 9462 ft Log down for Geo at 9610 ft Corrected +5.5 ft RIH and tagged btm at 9663 ft Drilling, TF 20R Q = 2.6/2,51. P = 3330/ Vp 314 bbl Started new hole at 9661 ft Orient TF around to 80 to 90 L Drilling, TF 90L Q = 2.6/ ,= 3330/ Vp 314 bbl Orient TF aro rop some angle Dr"' , 98L Q = 2.6/2.51, P = 3450/3575, Vp 307 bbl Orient TF to 45 L Drilling, TF 50LL Q = 2.4/2.51. P = 3450/3675, Vp 307 bbl Drilling ahead. Free spin 3500 psi at 2.63 psi. Drilling at 2.65/2.7/3850 psi. Pit vol=305 bbls. IAP=6oo psi, OAP=160 psi. Blew a seal on an upper traction cylinder on the injector. Pull Printed: 7/27/2004 10:46:13 AM W6A- -7/ &jl.-CC4 ( STATE OF ALASKA ( F:',:\'~':::'~ ¡;-:~~ ~'; ,:"'~', ALASKA OIL AND GAS CONSERVATION COMMISSION ø J~O ~~~<)L- APPLICATION FOR SUNDRY APPROVAL- t 20 MC 25.280 ,,. ;"", ' ' 1. Type of Request: / iii Abandon D Repair Well iii Plug Perforations D Stimulate D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Change Approved Program D Operation Shutdown D Perforate D Re-Enter Suspended Well 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESI;NTWE;L~CQNPITIQN:$tJMMAI1,(", ': ' Effective Dep,t, h, ,M, D" (ft" ),:, lEffe"c, tive Depth TVD (ft): Plugs (measured): 11712 8917 9375 .' .'," ,"MÐ ',"", 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 55.03' 8. Property Designation: ADL 028304 11; , Total Depth MD (ft): 11752 Structural Conductor Surface Intermediate Production Liner 110' 2793' 7410' 20" X 30" 13-3/8" 9-5/8" 1875' 1920' 951' 7" 4-1/2" 3-1/2" x 2-7/8" Liner Liner D Other D Time Extension 4. Curre9t Well Class: 1m Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 201-206 / 6. API Number: / 50- 029-21418-02-00 9. Well Name and Number: PBU K-05B Junk (measured): None " COllapse' 110' 2793' 7410' 110' 2701' 5380 2670 6683' 6870 4760 6559' - 8297' 7240 5410 8144' - 8843' 8430 7500 8837' - 8937' 7266' - 9141' 8979' - 10899' 10798' -11749' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 10130'-11700' 8813'- 8912' 4-1/2",12.6# Packers and SSSV Type' 4-1/2" Baker 'KB' packer; 7" x 4-1/2" Baker 'ZXP' packer; 7" x 4-1/2" Baker'S-3' packer; . 9-5/S" x 7" Baker 'ZXP' packer; 4-1/2" HES 'X' Nipple Tubing Grade: Tubing MD (ft): L-80 8989' Packers and SSSV MD (ft): 9375'; 89801; 8932'; 7266'; 2116' 12. Attachments: 1m Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Com mission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Thomas McCarty .{, Title CT Drilling Engineer ,~i~.~~~~~~..Ii"c"...".".........,...11/;..(~....~""',,' .,:,:\"""..""":.::,0',"':""""':"""':"','.:,,',,,,,,"o"~'~~~~"'.('" """'.""'~~~~'~~~""'O:'i."",, , , .:(.""'::",.,'. ':"'".,.,'.'.'.' ,,::"".'.:.':, '..'::'..:..'::,':".,: '.' .":.',,':. "".,...::.:":,(,~::,..,,, : ":"""""':"":':"/",""""".'.:". 1::i'i.:':,':C.'o, . m. . .wUislðh"<!.Ø...:..únl~':<'...":.:i:',":":':, ' ':::':: '.: ': :(':-' '! I:' ::,;'. ' ,:' .' ,:,,: ~:' ,': I ,.., ,: ,,;-,"":,' ,':"" '" ,"',:' ',",-' ': ,,:, :.:::":"" I, : i ':" ',,': :.,::: I.," ." .,'i I"~, I ::.: ", :: i::' : ,', ::."'::' :'-;', ':", i: ;,..I',:'~':' ,', ,,' "I,:""":.',,,'.': ;,1:,':':,.:,,' ,\' ',": -",': '.::' ,', ':: '::: ,-,,' .',' i" :,'.':"" '. . -,"" ,'"',''' ' '. I~:'~'~;' ":" ' : "', -'" ,~,':~" ""Y~' , ,,'::'." "" ',",." I' ~,~:':,': "",'" I:' -<::".1" ::,,, 'i:" :,'., 1m BOP Sketch July 15, 2004 I Date: 13. Well Class after proposed work: I D Exploratory 1m Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ / D Plugged 1m Abandoned D WINJ D WDSPL Contact Thomas McCarty, 564-4378 Date , I. r ~ Prepared By Name/Number: .~~Z/;q~,:t:\ Terrie Hubble, 564-4628 I Sundry Number: 3of-;)-~Ç D Plug Integrity D BOP Test Conditions of approval: Notify Commission so that a representative may witness D Location Clearance D Mechanical Integrity Test Other: ~ f yO\{ e d Fe ý "'^- IC'~ 40 ( 'r€b l-'v\ N: d ~ý 01dYlM'iL u<.( II i-os (. Bft JUt () 8 100~ Daœ ~tt: COMMISSIONER APPROVED BY THE COMMISSION ORIGINAL (' ( ( bp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Thomas McCarty Drilling Engineer Date: July 7, 2004 Re: Well K-05B prep for a CTD sidetrack (/ Well K-05B is scheduled for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. The sidetrack, K-05C, will exit out of the existing 4-1/2" liner from a thru tubing whipstock and target Zone 1 / reserves. The whipstock anchor will be run with the rig on location and will isolate the existing perfs. The following describes work planned for the sidetrack and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. CTD Pre- Rie Summary 1) Service CT - Attempt to fish KB packer unsuccessful, Oct-Nov 2003 2) Slick liner - Caliper tubing, tubing in good condition, May 2004 3) Slick line - Attempt to fish KB packer unsuccessful, May 2004 , 4) Slick line -Dummy gas lift valves, Pressure test IA to 3000 psi, good test, May 2004./ Å CTD Sidetrack Summary 1) MIRV CTD rig. 2) Attempt to push KB packer to 3.7" liner top at approx. 10797' 3) Set whipstock anchor to position top of whipstock at approx. 9330' , 4) - Run whipstock tray. -ks 101(55) Mill 3.8" window off of whipstock. 1'\', I 6) Drill4-l/4" x 3.75" open hole sidetrack to)1669' planned TD with MWD/gamma ray. frY~; ie...., , 7) Run 3-3/16" x 2-7/8" liner completion~/ifop of liner (TOL) will be at approx 8960' md (8071 'TVDss) in 4 Y2" tubing tail. Cem~nt liner with approi 25~,þls of 15.8 ppg cement, plan to bring cement top to TOL 8) Run MCNL, Perforate. '''---:,;c/' 9) RDMO. .' The pre CTD work has begun but the drilling rig will perform most of the prep work. The drilling rig will arrive on location on appro x July 17th. Thomas McCarty CTD Drilling Engineer 564-4378, 748-2598 CC: Well File Terrie Hubble TREE = 4-1/16" CIW, 5K WELLHEAD = tv'CEVOY . ... ..... .. "... ",...n......... ACTIJl\ TOR = AXELSON KB. ELEV = 55.03' BF. ELEV = 28.22' KOP ='" , " 1450' Max Ange = . "99' @10062' Datum MO = 9981' Datum TvO = 880Ò'SS' 113-318" CSG, 72#, L-80, [) = 12.347" H 2793' rJI 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" I Minimum ID = 2.377" @ 10837' 3-1/2" X 2-7/8" LNR XO PERFORA 1l0N SUMrvIA RY REF LOG: MEfv10RY GRlCNL ON 12/31/01 ANGLE AT TOP PERF: 90° @ 10130' Note: Refer to Production DB for historical perf data SIZ E SPF INTERV AL Opn/Sqz DATE 2-7/8" 4 10130 - 10700 0 01/07/02 2" 6 11620-11700 0 12/31/01 19-5/8" X 7" TW LNR TOP PKR l-t 19-5/8" X 7" llW LNR HGR 1-1 I 9-518" CSG, 47# L-80, 10 = 8.681" 1-1 7452' 7465' 7578' MILLOur WINOOW 7578' - 7628' W/ 9-5/8" SECllON MILL (K-05A) 17" LNR, 29#, NT-80, 10 = 6.184" 1-1 10159' DATE 11/18/85 01/03194 11/26/01 01/07/02 02/03/02 08/18/02 COMMENTS ORIGINAL COMPLETION SIDETRAC K COM Pl eriON CH/KAK RIG SIDErRACK(K-05B) CTO WELL EXTENSION CHffP CORRECTIONS JM/KAK SET BP REV BY C' ( K-058 SAÆTYNOTES: PRE-SDTRKWELLBORENOT SHOWN ON DIAGRAM Sa.OW 9-518" eSG SECTION MILLED WINDOW @ 7578' (K-05A). WELL ANGLE> 70° @ 9780' & > 90° @ 9969', 2116' H4-1/2" I-ESX NIP, 10 =3.813" ~ GAS LIFT MA NORELS DEV lYÆ VLV LATa; FQRT 27 MMG DOME RK 16 33 MMG SlO RK 20 19 KBG-2 rN BK 0 21 KBG-2 rN BK 0 DATE 01/15/02 01/15/02 01/15/02 01/15/02 L ST MD TVO 4 4308 3977 3 6970 6253 2 8003 7174 1 8842 7959 l 1 . . J f 7266' 1-19-5/8" X 7" BKR ZXP PKR, 10 = 6.276" I 7279' 1-19-518" X 7" BKR Hfv1C HGR, 10 = 6.305" I 9-5/8" MILLOur WINOOW 741 0' - 7426' ~ TOPOFWHIPSTOCK@7410' 8911' H4-1/2" HESX NIP, ()=3.813" I Y I 8932' H7" X 4-1/2" BKR 5-3 A<R, ID = 3.875" 8955' 1-14-112" HESX NIP, [) =3.813" 1 8976' 1-14-1/2" HES X NIP, 10 = 3.813" I 8980' 1-17" X 4-1/2" BKR ZXP PKR, 10 = 4.938" I 8993' H 7" X 4-1/2" BKR HfvC HGR, 10 = 4.938" I 9375' 11BKR KB A<RW/RElEASEABlE/ SPEAR (10/06/03) I 10797' 11BKRKB PKRSEAL I LOC, 10 = 2.39" 10798' 113.70" BKR DEPLOY I SLV, 10 = 3.00" 14-1/2" WLEG 1-1 17" LNR, 26#, N-80, 10 = 6.276" 1-1 / I 4-1/2" LNR SHOE 1-1 10900' 1 13-1/2" LNR, 9.3#, L-80, .0087 bpf, [) = 2.972" I~ 10837 1 10837' 113-1/2" X 2-718" LNR I XO, 10 = 2.377" 12-718" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.377" 1-1 11749' DATE 08/04/03 08/13/03 09/12/03 10/06/03 REV BY . COMMENTS CMO/TLP KB 8.EV A 1l0N CORRECllON KEY/TLH FULL IBP / SET KB PKR OA C'TLP BKR KB PKR fv10VED RMHlKAK SET R8.EASEABLE SPEAR PRUDHOE BA Y UNIf W8.L: K-05B ÆRMlT No: 2012060 API No: 50-029-21418-02 SEC 4, T11 N, R14E, 1935' SNL & 441' EWL BP Exploration (Alaska) . TREE = 4-1/16" C~, 5K 'WËLLHÈAO = MCEVOY ACTUA TOR = AXELSON KB. ELEV = 55.03' BF. ELEV = 28.22' KOP = 1450' Max Angle = 99 @ 10062' Datum MO = 9981' Datum NO = 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2793' ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1 9-5/8" MILL OUT WINDOW 7410' - 7426' TOP OF WHIPSTOCK @ 7410' 19-5/8" X 7" T~ LNR TOP A<R 1-1 7452' 19-5/8" X 7" TIW LNR HGR 1-1 7465' 1 , MILLOUT WINDOW 7578' - 7628' WI 9-5/8" SECTION MILL (K-05A) 17" LNR, 29#, NT-80, 10=6.184" 1-1 10159' 1 , 19-5/8" CSG, 47# L-80, 10 = 8.681" 1-1 7578' 1 14-1/2" WLEG 1-1 17" LNR, 26#, N-80, 10 = 6.276" l-i I Mechanical whipstock -I ,( \ K-05C SAFETY (' $: PRE-SDTRK WELLBORE NOT SHOWN ON DIAGRAM BELOW 9-5/8" CSGSECTlON MILLED WINDOW @ 7578' (K-05A). WELL ANGLE> 70° @ 9780' & > 90° @ 9969'. Proposed CTD Sidetrack I .. 2116' 1-14-1/2" HES X NIP, 10 = 3.813" 1 ~ GAS LIFT MANORELS OEV 1YÆ VLV LATCH 27 MMG DOME RK 33 MMG SIO RK 19 KBG-2 OV BK 21 KBG-2 OV BK PORT OA TE 16 01/15/02 20 01/15/02 0 01/15/02 0 01/15/02 L ST MO NO 4 4308 3977 3 6970 6253 2 8003 7174 1 8842 7959 l ~ ~ 1\ J f 7266' 1-19-5/8" X 7" BKR ZXP A<R, 10 = 6.276" 1 7279' 1-19-5/8" X 7" BKR HMC HGR, 10 = 6.305" 1 ~ 8911' 1-14-1/2" HES X NIP, 10 = 3.813" 1 8932' 1-17" X 4-1/2" BKR S-3 A<R, 10 = 3.875" 1 8955' 1-14-1/2" HES X NIP, 10 = 3.813" 1 8960' 1-1 Liner Top Packer 1 8965' -i Top of Cement I 8965' -I Top of 3-1/2" Liner 8976' 1-14-1/2" HES X NIP, 10 = 3.813" 1 8980' l-i 7" X 4-1/2" BKR ZXP A<R, 10 = 4.938" I 8993' -17" X 4-1/2" BKR HMC HGR, 10 = 4.938" 1 ÆRFORA TION SUMMARY REF LOG: MEMORY GRlCNL ON 12/31/01 ANGLEATTOPÆRF: 90° @ 10130' Note: Refer to Production OB for historical perf data ~~-3/16" X 2-718" cmt'ed and perfedl-l 11669' 1 SIZE SPF INTERV AL Opn/Sqz OA TE 2-7/8" 4 10130 - 10700 isolated prOPosed) 9346' - BKRKB A<RW/ RELEASEABLE SPEAR (10/06/03) 2" 6 11620 - 11700 isolated proposed 10797' - BKR KB A<R SEAL LOC, 10 = 2.39" I 10798' - 3.70" BKR OEPLOY SLV, 10 = 3.00" 4-1/2" LNR SHOE 1-1 10900' 1 10837' 1-13-112" X 2-7/8" LNRXO 10 = 2.377" 1 13-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.972" 1-1 10837' 1 ' 12-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.377" 1-1 11749' 1 ~ I PBTD 1-1 11712' 1 OATE 11/18/85 01/03/94 11/26/01 01/07/02 02/03/02 08/18/02 COMMENTS ORIGINAL COM PLETION SIDETRACK COM PLETION CHlKAK RIG SIDETRACK (K-05B) CTO WELL EXTENSION CH/TP CORRECTIONS JMKAK SET IBP REV BY OA TE REV BY COMMENTS 08/04/03 CMOffiP KB ELEVATION CORRECTION 08/13/03 KEY ITLH PULL IBP I SET KB A<R 09/12/03 OAClTLP BKR KB A<R MOVED 10/06/03 RMHlKAK SET RELEASEABLE SÆAR PRUOHOE BAY UNIT WELL: K-05B ÆRMrT No: 2012060 API No: 50-029-21418-02 SEC 4, T11 N, R14E, 1935' SNL & 441' EWL BP Exploration (Alaska) Permit to Drill MD 7 Pel, ~ C} ~ L{ DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 2012060 Well Name/No. PRUDHOE BAY UNIT K-05B 11752 NO Completion Date 1/7/2002 Operator BP EXPLORATION (ALASKA) INC -----------,-----.-----'- ----'---- Completion Status 8939 API No. 50-029-21418-02-00 1-01L UIC N Current Status 1-01L ...----------------- -------'--- ----,-- --------- ------'----- ---"'-'-------- REQUIRED INFORMATION ---------.--.---- Mud Log No Samples No -------.-...---. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt 0 C C C C C Log Log Log 0 Log Log Log Electr Dataset Number Name V"'(1242~~9trþb,~ <i ,~~tjf¡p~t,iÒd'..'" ,"""',,",.""" """"",'""',,..,.,"'" ,.~Mp~r~~Hf~. "" ' ',~,","'" '96#¡I~rÎ?q~tQ( -¡#ij~{~~.~~¥ ' ~06 'Ñ~Ù~'~9Q,': ,"'..,,',,','" "',"..",,',',' .PttjdUi::tiÒlÎr 8r~$$Úf$'," a-f1564$~~'.@(~t~~. . - 0707~~Try,~~~~¥,; .. ' ',""'" ",' '"',,, "," /Í0708R~~,m~;.~~x, ,'" ",', ",,",', "," "",', 'N~Útrph.,;..'i,'~, """"" , '.. '" ""',, ,," "',",'" d' """,, , .§Eimrn;~~~y'.';, , ," ,', '" c./t1 039~1~\I~dfiÇ~~j9tt '~p¡,rp,~(:'; ,', ' , " "'"',, ",", """"""',,,',,,', '" """ ..~~.mp~r~tyt~'.'.'..' "" """" ," "" ", "",",,', ,"""""""","", " :Þt~~$Ûtè.. " ",,' ..-- ------------ Well Cores/Samples Information: Name Interval Start Stop Log Log Run Scale Media No 1 1 2 2 Blu Blu 2 2 Blu Blu 2 2 2 Blu Blu Blu 2 2 Blu Blu 2 Blu -'----'----- Sent Directional Survey No .---------------- ----- ------ --,----- ------_.- (data taken from Logs Portion of Master Well Data Maint) 1 1 (' Interval OH/ Start Stop CH Received Comments ------------------ ---"" 9095 11703 Case 1 0/25/2002 7408 1 0860 Open 9/13/2002 PB1 9950 11710 Case 1 0/25/2002 9950 11710 Case 7/26/2002 7399 10900 Open 12/28/2001 8826 11638 Case 3/15/2002 9950 11710 Case 7/26/2002 9950 11710 Case 7/26/2002 7403 10900 Case 1/31/2003 Digital Well Logging Data 10800 11752 Open 3/15/2002 10884 11350 Open 3/15/2002 ( 9950 11710 Case 1 0/25/2002 9950 11710 Case 7/26/2002 9950 11710 Case 1 0/25/2002 7408 10860 Open 9/13/2002 PB1 9950 11710 Case 7/26/2002 9950 11710 Case 7/26/2002 9950 11710 Case 1 0/25/2002 1 1 1 1 1 1 1 1 1 1 1 1 1 1 --------- Received Sample Set Number Comments Permit to Drill 2012060 MD 11752 - DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Well Name/No. PRUDHOE BAY UNIT K-05B Operator BP EXPLORATION (ALASKA) INC NO 8939 ,.-- Completion Date 1/7/2002- ADDITIONAL INFORMATION Well Cored? Y / fb Chips Received? Analysis Received? -------.-- ... -----------.----. Comments: ~ ~ Completion Status 1-01L Current Status 1-01L Daily History Received? {Y)/N &)/N Formation Tops ----- ----------- ----------- - ..... ------'-'-- ,--- Date: '------, Compliance Reviewed By: - ~ s~ L 1 IJ Nor LtNt l API No. 50-029-21418-02-00 UIC N ------ -----------------"'-- (' ------- ----------- --------------- ~..l r ~-W..~ ( (' (. ( aol ~dtJf.t; llS(o~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 30, 2003 RE: MMD Formation Evaluation Logs: K-O5B pal, AK-MM-11182 K-O5B PBl: Digital Log Images 50-029-21418.. 70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signe : RECEIVE.[) JAN ~=S 1 2003 ^".10IrA OiII9.l""'~ ("1\1',\(0 {"" . " . ru(._"",:,. v. :ru" ."" .'~I. j)m!n!t1!~!!f;n ~.....J¡. i'!f"""~"~ {,~: n..H,..'. \T',~;~ " ' Scblumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well L2-21 I ~ 'Fi,.::Jï 5 NK-38 J~ /../, 1"'10 D-24 I '-,,-~ c ~ F-34A Ie. ~ -I ()q R-04 J 7C 4'0 ~S? D.S.5-19 I c ~q"'D7 D.S.5-40 " -J5~ D.S.15-19A ~y-( ¡qq D.S.18-16B Il í~c;fl1 D.S.18-21A qT" ;:¡-q-il K-05B ~....~ Job# SBHP SURVEY STATIC SURVEY LDL LDL LDL LDL LDL LDL SBHP SURVEY SBHP SURVEY 22336 MCNL Log Description Date 10/01/02 09/12102 09/10/02 09/30/02 09/29/02 09/28/02 10/03/02 10/03/02 09/30/02 09/30/02 07/12/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E- Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECE'V'E[) QtT 2 r "e^f} , "I '"J i.I",I- Alalkt\ Œ'J & (,î:r~ GQ~¡ß. (;Qmmi8$ion ÀA,d!'V'l&M,i t'U í<"ïUI.l'U1~t:.... Blueline 10/15/02 NO. 2484 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints c- CD 1 1 1 1 1 1 1 1 1 1 1 1 { Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ReœiV~ ~ (, \1: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska aD/-dO/p IIO3c¡ September 11, 2002 RE: MWD Foffi1ation Evaluation Logs K-05B PBI, AK-MM-III82 1 LDWG foffi1atted Disc with verification listing. API#: 50-029-21418-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. J\nchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical ,Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~ ~ RECEIVED SEP 1 3 .2002 Alaska Ot, & Gas Cons. Comminion Anchorage 07/25/02 Schlumberger NO. 2259 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ( Well Job# Log Description Date Blueline Sepia Color Prints CD ( K-05B af)I-~nl^ MEM PROD PROFILE 07/12/02 1 P1-04 (REDO) ICl 3.. o~ 3 PROD PROFILE/DEFT 07/10/02 1 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECE\VEO JUL 2. 6 ZOOl Oä & Gas Cons. CommissiOn ,Alaska Anch0t89Ð Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Recei~ ~J 03/06/02 Scblulllbellger NO. 1872 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AlTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: LIsa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay t~- Well Job # Log Description Date Blueline Sepia Color Prints CD ( K-05B ,::Jnl-d Ole 22023 MCNL 12/31/01 1 1 1 K-05B 22092 GR ROP5 DATA 12/29/01 1 K-05B 22092 MD SLIMPULSE-GR 12/29/01 1 1 K-05B 22092 TVD SLIMPULSE-GR 12/29/01 1 1 K-05B PB1 22093 GR ROP5 DATA 12/24-26/01 1 K-05B PB1 22093 MD SLIMPULSE-GR 12/24-26/01 1 1 K-05B PB1 \ / 22093 TVD SLIMPULSE-GR 12/24-26/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2- 1 900 E. Benson Blvd, Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AITN: Sherrie r..1" Q _I' :-: "002 .i"t'~ .J L A&äæ & Gas Cons. Commissio Anchorage n Recelve~ ~ LJJoo fA.. / Date Delivered: I ~ ( STATE OF ALASKA I("! ALASKA OIL AND GAS CONSERVATION COMMt..vION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-206 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21418-02 4. Location of well at surface t."';;~u~';TÊ::;¡J~r:, - 9. Unit or Lease Name 1 , ~I ""~,.\:, -- - ¡ ì 1935 SNL, 441 EWL, SEC. 04, T11 N, R14E, UM t f1~\Tç; ¡ '-..i - . Prudhoe Bay Unit At top of produ?tive interval} ./.-7'(;"':-;" \ J ~r,...,: ". \' "';' - . 5187 SNL,786 WEL, SEC. 05, T11 N, R14E, UM.\IF-'~:;::'~: ~,tn-."...... ~ 10. Well Number At total depth ~ "-d,, -,-".} ,",. , 18631 SNL 1278' WEL SEC. 08 T11 N R14E UM ~ ._.lb------: 1 ""_"""-"""-~-'~':-:4I K-05B , , , , , -""",-,'" '--" ",,"", .. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 55.031 ADL 028304 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 11/13/2001 12/29/2001 1/7/2002 N/A MSL One 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+ NO) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11752 8939 FT 11712 8917 FT 1m Yes ONo (Nipple) 2154' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, Memory CNL, CCI 23. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" x 3011 Insulated Conductor Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2793' 17-1/2" 3999 cu ft Permafrost 9-5/811 47# L-80 Surface 7410' 12-1/4" 1982 cu ft Class 'G' 711 26# N-80 7266' 9141' 8-1/2" 189 cu ft Class 'G' 4-1/2" 12.6# L-80 8979' 10899' 6-1/8" 298 cu ft Class 'G' 3-1/2" x 2-7/8" 8.81# / 6.16# L-80 10798' 117491 3-3/4" 56 cu ft Class IG' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 2" Gun Diameter, 6 spf 4-1/211, 12.6#, L-80 8989' 8928' MD TVD MD TVD 10130' - 10700' 88131 - 8834' 11620' - 11700' 8884' - 8912' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 30 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 20, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/24/2002 4 TEST PERIOD 2596 17964 280 54.51 6921 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 26.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RECEiVED FES 2 7 2002 ...- Alaska Oil & Gas Coos. Commission ., . .. ~ . . (J ~ \\ \ ~ ~ \ \\\!\ Jj, t ... Form 10-407 Rev. 07-01-80 i-i' :1 """- ~ "!'-", RBDMS 8Fl ' Submit In Duplicate \ ~.,) u~' ~ ,.- ¡~AR 5 2002 c,F (' (' 29. Zone 1 Geologic Markers Marker Name Measured True Vertical Depth Depth 96621 87421 116801 89031 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Base Sadlerochit 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date OA.. ~ '7. D K-05B Well Number 201-206 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 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: K-O58 Common Name: K-O58 Test Date 11/12/2001 11/19/2001 FIT FIT Test Type BP EXPLORATION - : Lf!ak;.Off 'TestS u m ma ry Page 1 of 1 Test Dåpth(TMD) , Test Depth(TVD) "AMW SuñacePreSsure Leak Off Pressure (BHP) EMW 7,440.0 (ft) 6,696.0 (ft) 10.00 (ppg) 700 (psi) 4,178 (psi) 12.01 (ppg) 9,161.0 (ft) 8,297.0 (ft) 8.50 (ppg) 475 (psi) 4,139 (psi) 9.60 (ppg) Printed: 11/27/2001 4:14:59 PM (' (" - BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/4/2001 14:30 - 00:00 9.50 MOB P PRE MOVE CAMP AND PITS TO LOCATION. BEGIN MOVING RIG TO LOCATION. 11/5/2001 00:00 - 09:30 9.50 MOB P PRE MOVE RIG TO K-PAD. ONE TIRE HAD SLOW LEAK AROUND BEAD SEAL, AND HAD TO BE PUMPED BACK UP EVERY HOUR. 09:30 - 13:30 4.00 MOB P PRE LAY MATS AROUND WELL AND HERCULlTE UNDER SUB. SPOT RIG OVER K-5 WELL. CONT. MAINT. WORK ON LIGHTS AND CAMERAS IN DERRICK. 13:30 - 15:00 1.50 MOB P PRE SPOT AND HOOK UP PITS AND CAMP. 15:00 - 17:30 2.50 MOB P PRE CLOSE CELLAR DOORS. INSPECT DERRICK. RAISE DERRICK. 17:30 - 19:30 2.00 MOB P PRE INSTALL CATTLE CHUTE WITH CRANE. 19:30 - 00:00 4.50 MOB P PRE RU FLOOR. START TO BRIDLE DOWN. CLEAN RIG AND PREP FOR ACCEPTANCE. 11/6/2001 00:00 - 06:00 6.00 MOB P PRE FIN CLEAN RIG. MAKE FINAL INSPECTION. ACCEPT RIG AT 0600 HRS. 06:00 - 12:00 6.00 RIGU P PRE RIU RIG WHILE WAIT ON VAC TRUCKS(NO VAC'S TRKS WERE AVAILABLE) TO BRING SW TO RIG. CONT. TO R/U AND CLEAN RIG. 12:00 - 15:30 3.50 RIGU P PRE R/U TO DISPLACE SW, CALIBRATE H2S SENSORS, BLOW DOWN FLARE LINE 15:30 - 16:30 1.00 RIGU N WAIT PRE WAIT ON DSM, NO PERSONNEL AVAILABLE, HAD 2 HOUR NOTICE PRIOR TO CALL OUT 16:30 - 18:00 1.50 RIGU P PRE RU DSM LUBRICATOR, PULL BPV, RD DSM 18:00 - 18:30 0.50 RIGU P PRE RU HARD LINES TO WING VALVE 18:30 - 19:00 0.50 RIGU P PRE PJSM ON DISPLACEMENT JOB W/ ALL INVOLVED PERSONNEL 19:00 - 00:00 5.00 RIGU P PRE TEST LINES TO 1000 PSI, CIRC OUT DIESEL F/ WELLBORE W/ SW, CIRC 20 BBL DIRT MAGNET SWEEP AROUND AT 3 BPM, 280-350 PSI, R/D LINES 11/7/2001 00:00 - 02:30 2.50 WHSUR P DECOMP PTSM, PJSM. INSTALL TWC AND TEST TO 1200 PSI - OKAY. 02:30 - 05:00 2.50 WHSUR P DECOMP ND TREE 05:00 - 09:00 4.00 BOPSUR P DECOMP NU BOPE 09:00 - 16:00 7.00 BOPSUR P DECOMP CHANGE OUT VARIBLE RAMS AND BLIND RAMS. CENTER THE STACK. PTSM, PJSM. HOOK UP KILL LINE, SET FLOW RISER, CLEAN UP TOOLS AND CELLAR. 16:00 - 17:30 1.50 BOPSUR P DECOMP MAKE UP 3-1/2" TEST JOINT. 17:30 - 00:00 6.50 BOPSUR P DECOMP TEST RAMS TO 250 / 5,000 PSI - OKAY. TEST ANNULAR 250/3,500 PSI- OKAY. BODY OF SUPER CHK LEAKING. TEST WITNESSED BY JOHN CRISP OF AOGCC. 11/8/2001 00:00 - 06:30 6.50 BOPSUR N SFAL DECOMP PTSM. CONT. TESTING CHOKE MANIFOLD. BODY TEST OF SUPER CHOKE LEAKING. DISASSEMBLED, REDRESSED, REASSEM., TEST TO 3,500 OKAY. 06:30 - 07:30 1.00 BOPSUR N SFAL DECOMP CONT. TESTING CHK MAN. AT 250/3,500 PSI - NO TEST. 07:30 - 10:30 3.00 BOPSUR N SFAL DECOMP CHANGE OUT CHOKE VALVES #3 AND #12 WITH NEW VALVES, WHILE TESTING THE UPPER, LOWER, MANUAL KELLY VALVES AND FLOOR SAFETY VALVE TO 5,000 PSI. - OKAY. 10:30 - 14:00 3.50 BOPSUR N SFAL DECOMP PICK UP TBG HANDLING EQUIP. CONT. INSTALL OF VALVES #3 AND #12. 14:00 - 15:00 1.00 BOPSUR N SFAL DECOMP RU DSM AND PULL TWC. Printed: 11/27/2001 4:15:06 PM - - BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/8/2001 15:00 - 23:00 8.00 BOPSUF N SFAL DECOMP RU TO PULL TBG AND CONTROL LINES. CONTINUE TESTING CHK MANIFOLD 250 /3,500 PSI - OKAY. FUNCTION TEST SUPER CHK AND MANUAL CHK - OKAY. (WITNESSED BY JEFF JONES - AOGCC). 23:00 - 23:30 0.50 BOPSUF P DECOMP BLOW DOWN SURFACE EQUIPMENT. PJSM. 23:30 - 00:00 0.50 BOPSUF P DECOMP BACK OUT LOCK DWN SCREWS. PULL TBG HNGR W/ 140K. 11/9/2001 00:00 - 00:30 0.50 WHSUR P DECOMP PJSM. BREAK OUT TBG HNGR. 00:30 - 01 :30 1.00 PULL P DECOMP RU EQUIPMENT TO PULL AND SPOOL SS CONTROL LINES. 01 :30 - 07:00 5.50 PULL P DECOMP POOH W/3-1/2" NSCT TGB TO SSCV. RECOVERED 68 BANDS OF 71 TOTAL. 07:00 - 07:30 0.50 PULL P DECOMP RD/LD SPOOLING EQUIP. 07:30 - 08:00 0.50 PULL P DECOMP CALIBRATE RIG MONITORING EQUIP - BLOCK HEIGHT, RPMS. 08:00 - 15:00 7.00 PULL P DECOMP CO NT. PULING 3-1/2" TBG STRING. TOTAL OF 237 JTS PULLED, 1 SSSV, 2 GLM AND 15.2' CUT JT. 15:00 - 16:00 1.00 PULL P DECOMP LD ALL TBG EQUIP, AND CHG TO 5" ELEVATORS. CLEAN RIG FLOOR. 16:00 - 22:30 6.50 WHSUR P INT1 MU AND SET TEST PLUG AND TEST RAMS W/ 4" DP 250 / 5000 PSI- OKAY. TEST #14 VALVE (BACKSIDE), MUD CROSS TO 250/3500 - OKAY. 22:30 - 00:00 1.50 WHSUR P INT1 RD TEST JT, PU STORM PKR, SSCV. CLEAN FLOOR. 11/10/2001 00:00 - 00:30 0.50 BOPSUF P INT1 LD TEST JT. 00:30 - 01 :30 1.00 WHSUR P INT1 RU HANDLING EQUIP FOR BHA AND DC. 01 :30 - 03:00 1.50 WHSUR P INT1 MU BHAAND RIH TO 276'. 03:00 - 04:00 1.00 WHSUR P INT1 MU STORM PKR & SSCV. RIH AND SET STORM PKR AT 35'. 04:00 - 04:30 0.50 WHSUR P INT1 PRESSURE TEST PKR TO 500 PSI - OKAY. PJSM. 04:30 - 07:30 3.00 WHSUR P INT1 C/O 9-5/8" PACKOFF SEAL AND TEST TO 5,000 PSI - OKAY. 07:30 - 09:30 2.00 WHSUR P INT1 RIH, PULL STORM PKR, POOH, LD. CLEAN FLOOR. 09:30 - 10:00 0.50 WHSUR P INT1 STAND BACK BHA TO SET WEAR RING. 10:00 - 10:30 0.50 WHSUR P INT1 SET WEAR RING. 10:30 - 16:30 6.00 WHSUR P INT1 MU BHA, C/O ELEVATORS. 16:30 - 00:00 7.50 WHSUR P INT1 PU AND RABBIT 4" DP. RIH TO 7,078. 11/11/2001 00:00 - 02:00 2.00 STWHIP P INT1 CONT. RIH AND TAG LINER TOP AT 7452'. UP 180K, DOWN 155K. 02:00 - 04:30 2.50 STWHIP P INT1 DISPLACE WELL TO 10 PPG MILLING FLUID. PUMP SLUG. 04:30 - 06:00 1.50 STWHIP P INT1 POOH TO 5,132'. 06:00 - 07:00 1.00 STWHIP P INT1 SERVICE TOP DRIVE W/ MINOR ADJUSTMENT ON LINK TILT AND KELLY HOSE-STD PIPE. 07:00 - 12:00 5.00 STWHIP P INT1 CONTINUE TO POOH. 12:00 - 13:00 1.00 STWHIP P INT1 LD BHA. 13:00 - 16:00 3.00 STWHIP P INT1 PJSM. RU WIRELlNE, RIH AND SET 9-5/8 CIBP AT 7,424'. 16:00 - 17:00 1.00 STWHIP P INT1 POOHW/ WIRELlNE, AND RD. 17:00 - 18:00 1.00 STWHIP P INT1 TEST 9-5/8", 47#/FT CSG TO 3,500 PSI FOR 30 MN - OKAY. 18:00 - 20:30 2.50 STWHIP P INT1 PJSM. PU/MU BHA #2. 20:30 - 21 :30 1.00 STWHIP P INT1 ORIENT MWD. 21 :30 - 22:00 0.50 STWHIP P INT1 MU WHIPSTOCK & RIH. 22:00 - 00:00 2.00 STWHIP P INT1 MU BHA #2 & RIH TO 682. 11/12/2001 00:00 - 00:30 0.50 STWHIP P INT1 PTSM. CHK CROWN-O-MATIC. FINISH RIH W/BHA #2. RD TONGS. ( (' Printed: 11/27/2001 4:15:06 PM ~ BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/12/2001 00:30 - 01 :30 1.00 STWHIP P INT1 CHK STROKE COUNTERS - OKAY. ST MWD. 01 :30 - 03:30 2.00 STWHIP P INT1 RIH WITH 4" DP TO 3,763', FILLING EVERY 15 STDS. 03:30 - 04:30 1.00 STWHIP P INT1 SERVICE TOP DRIVE. TIGHTEN HYD FITTING, ADJUST BRAKES. 04:30 - 06:30 2.00 STWHIP P INT1 CONT. RIH TO 7,356'. (90 SEC/STD). 06:30 - 07:30 1.00 STWHIP P INT1 ORIENT WHIP TO 81 DEG RIGHT OF HS. TAG CIBP @ 7,434' DPM. SHEARED PIN AT 45K AND SET WHIP. TOP OF WHIPSTOCK @ 7,410'. 07:30 - 14:30 7.00 STWHIP P INn MILL WINDOW IN 9-5/8" CSG. TOW-7,410', BOW-7,426'. PUMP SWEEPS DURING MILLING. RECOVERED 240 LB OF METAL (5X5 GAL BUCKETS). 14:30 - 17:30 3.00 STWHIP P INT1 DRILL FORMATION TO 7,440'.8-1/2" HOLE 7,426' -7,432' 8.0" HOLE 7,432 - 7,440'. 17:30 - 19:00 1.50 STWHIP P INT1 SWEEP HOLE CLEAN. SHUT DWN PUMPS, WORK THRU WINDOW OKAY. PULL ABOVE WHIP. 19:00 - 20:00 1.00 STWHIP P INT1 PERFORM FIT WITH 10 PPG MUD, TO 12 PPG EMW. 20:00 - 20:30 0.50 STWHIP P INT1 POOH 5 STDS, MONITOR WELL - OKAY. 20:30 - 21 :00 0.50 STWHIP P INT1 PUMP SLUG. REMOVE BLOWER HOSE. 21 :00 - 00:00 3.00 STWHIP P INT1 CONT. POOH. (PULLING A WET STRING). TO 2,803'. 11/13/2001 00:00 - 01 :00 1.00 DRILL P INT1 POOH. (PULLING A WET STRING). FROM 2,803' TO 2,145'. 01 :00 - 03:00 2.00 DRILL N RREP INT1 REPAIR FUEL PUMP ON GENERATORS 03:00 - 05:00 2.00 DRILL P INT1 POOH. (PULLING A WET STRING). FROM 2145' TO 104'. 05:00 - 06:00 1.00 DRILL P INT1 LAY DOWN MILLING BHA. CLEAR RIG FLOOR. 06:00 - 07:00 1.00 DRILL P INT1 WASH OUT BOP WITH JETTING TOOL. PULL AND INSPECT WEAR RING. 07:00 - 10:30 3.50 DRILL P INT1 PJSM. MAKE UP BHA #3 WITH REBUILT 8 1/2" PDC BIT 10:30 -11:00 0.50 DRILL P INT1 SURFACE TEST MWD. OK. 11 :00 - 13:30 2.50 DRILL P INT1 RIH PICKING UP 4" DRILL PIPE IN SINGLES FROM PIPE SHED. 13:30 - 14:30 1.00 DRILL P INT1 CUT AND SLIP 83' OF 1 1/4" DRILLING LINE. 14:30 - 15:00 0.50 DRILL N RREP INT1 REPAIR TOP DRIVE. REPLACE "0" RING ON HYDRAULIC HOSE 15:00 - 16:00 1.00 DRILL P INT1 SERVICE TOP DRIVE 16:00 - 19:00 3.00 DRILL P INT1 RIH FOM 2787' TO 7355' WITH DRILLING BHA. 19:00 - 21 :00 2.00 DRILL N SFAL INT1 ATTEMPT TO ORIENT TOOL FACE. NO SIGNAL FROM MWD. REPLACE SENSOR ON SURFACE MUD LINE. 21 :00 - 21 :30 0.50 DRILL P INT1 ORIENT TOOL FACE 50' ABOVE CASING WINDOW AT 81 DEG TO RIGHT OF HIGH SIDE. PASS BHS THROUGH WINDOW WITH NO PROBLEMS. 21 :30 - 00:00 2.50 DRILL P INT1 WASH FROM 7432' TO 7440'. DIRECTIONAL DRILL FROM 7440' TO 7478' W/1.25 DEG MOTOR AND SURVEY WITH GR/RES/MWD 39', 46' AND 62' FROM THE BIT. SLIDING TO START KICK OFF WITH 8-10 WOB. 11/14/2001 00:00 - 00:30 0.50 DRILL N SFAL INT1 REPLACE SPERRY SUN MWD SENSOR ON SURFACE MUD LINE 00:30 - 09:00 8.50 DRILL P INT1 DIRECTIONAL DRILL FROM 7478' TO 7823' W/1.25 DEG MOTOR AND SURVEY WITH GR/RES/MWD 39',46' AND 62' FROM THE BIT. ROTATING TIME 1.5. SLIDING TIME 4.5. 09:00 - 11 :00 2.00 DRILL N SFAL INT1 REPAIR EPOCH RIG WATCH SYSTEM, NOT TRACKING CRITICAL RIG OPERATIONS. 11 :00 - 19:00 8.00 DRILL P INT1 DIRECTIONAL DRILL FROM 7823' TO 8287' W/1.25 DEG MOTOR. ROTATING TIME 3.5. SLIDING TIME 2. 19:00 - 20:30 1.50 DRILL P INT1 CIRCULATE AROUND 30 BBL HIGH VIS WEIGHTED ( I" t Printed: 11/27/2001 4:15:06 PM ( (' - BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/14/2001 19:00 - 20:30 1.50 DRILL P INT1 SWEEP. CIRCULATE AND CONDITION MUD PRIOR TO TRIP. 20:30 - 21 :00 0.50 DRILL N DFAL INT1 ATTEMPT TO TAKE SURVEY. NO SIGNAL FROM DOWN HOLE MWD TOOL. MAKE SEVERAL ATTEMPTS. 21 :00 - 22:00 1_00 DRILL N DFAL INT1 POH FROM 8290' TO 7542'. ATTEMPT TO TAKE SURVEY WITH NO SUCCESS. 22:00 - 00:00 2.00 DRILL N DLAF INT1 PUMP DRY JOB AND POH FROM 7542' TO 6046' 11/15/2001 00:00 - 03:30 3.50 DRILL N DFAL INT1 POH FROM 6047' TO 912' 03:30 - 06:00 2.50 DRILL N DFAL INT1 STAND BACK BHA. CHECK BIT. DOWN LOAD MWD AND RUN DIAGNOSTICS. DISCOVER DIRECTIONAL PULSAR SENDING LOW VOLTAGE SIGNALS. CHANGE OUT MWD. 06:00 - 07:30 1.50 DRILL N DFAL INT1 RIH WITH BHA AND NEW MWD DIRECTIONAL PROBE. 07:30 - 08:00 0.50 DRILL N DFAL INT1 RIH TO 1380'. SHALLOW TEST MWD. OK. 08:00 - 11 :30 3.50 DRILL N DFAL INT1 RIH TO 7262'. ORIENT TOOL 81 DEG TO HIGH SIDE. 11:30-12:00 0.50 DRILL N DFAL INT1 MAD PASS FROM 7320' TO 7357' AT 150 FPH. 12:00 -13:00 1.00 DRILL N DFAL INT1 RIH TO 8011'. CHECK MWD. OK. 13:00 -14:00 1.00 DRILL N DFAL INT1 RIH TO 8287'. WASH AND REAM FROM 8230' TO 8287' AS PRECAUTION. 14:00 - 00:00 10.00 DRILL P INT1 DIRECTIONAL DRILL FROM 8287' TO 8909' WI 1.25 DEG MOTOR AND SURVEY WITH GR/RESIMWD 39', 46' AND 62' FROM THE BIT. ROTATING TIME 7. SLIDING TIME 1. 11/16/2001 00:00 - 04:00 4.00 DRILL P INT1 DIRECTIONAL DRILL FROM 8909' TO 9141' WI 1.25 DEG MOTOR AND SURVEY WITH GR/RESIMWD 39', 46' AND 62' FROM THE BIT. ROTATING TIME 2. SLIDING TIME O. 04:00 - 06:00 2.00 DRILL P INT1 CIRCULATE. PUMP 30 BBL HIGH VIS SWEEP. CIRCULATE AND CONDITION MUD. 06:00 - 08:00 2.00 DRILL P INT1 WIPER TRIP TO 9 5/8" CASING WINDOW. NO EXCESSIVE DRAG. 08:00 - 10:00 2.00 DRILL P INT1 CIRCULATE. SPOT 100 BBL LINER PILL IN THE OPEN HOLE. 10:00 - 13:30 3.50 DRILL P INT1 POH, SLM TO 9 5/8" WINDOW. NO EXCESSIVE DRAG. 13:30 - 14:30 1.00 DRILL P INT1 PUMP DRY JOB. MONITOR WELL. SERVICE TOP DRIVE. 14:30 - 15:30 1.00 DRILL P INT1 INSPECT TOP DRIVE, CROWN BLOCKS AND TRAVELING BLOCKS. 15:30 - 19:30 4_00 DRILL P INT1 POH, SLM TO BHA. 19:30 - 22:00 2.50 DRILL P INT1 POH. LAY DOWN BHA. DOWN LOAD MWD IN PIPE SHED. 22:00 - 23:00 1.00 DRILL P INT1 CLEAR RIG FLOOR. RIG UP TO RUN 7" LINER. 23:00 - 00:00 1.00 DRILL P INT1 RUN 7" FLOAT SHOE AND COLLAR JOINTS- 11/17/2001 00:00 - 03:30 3.50 DRILL P INT1 RUN 7" LINER. CHECK FLOATS. RUN 45 JTS 7" 26# L-80 BTC-MOD CASING. 03:30 - 04:00 0.50 DRILL P INT1 MAKE UP BAKER 9 5/8" X 7" HMC HYDRAULIC LINER HANGER. 04:00 - 04:30 0.50 DRILL P INT1 CHANGE OUT HANDLING TOOL TO DRILL PIPE TOOLS. 04:30 - 05:00 0.50 DRILL P INT1 CIRCULATE LINER VOLUME. 05:00 - 09:30 4.50 DRILL P INT1 RUN 7" LINER ON 4" DRILL PIPE TO 9 5/8" CASING WINDOW. 09:30 - 11 :30 2.00 DRILL P INT1 CIRCULATE DRILL PIPE AND LINER VOLUME. MAKE UP CEMENTING HEAD AND STAND IN DERRICK. 11 :30 - 13:00 1.50 DRILL P INT1 RUN 7" LINER ON 4" DRILL PIPE TO 9141'. NO PROBLEMS. 13:00 -13:30 0.50 DRILL P INT1 RIG UP CEMENT HEAD AND LINES WITH FLOW METER. 13:30 -15:30 2.00 DRILL P INT1 CIRCULATE. INCREASE PUMP RATE SLOWLY TO 6.5 BPM AT 1200 PSI. 15:30 - 18:30 3.00 DRILL P INT1 PUMP 5 BBL WATER. TEST LINES TO 4000 PSI. PUMP 50 Printed: 11/27/2001 4: 15:06 PM - BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/17/2001 15:30 - 18:30 3.00 DRILL P INT1 BBL 11 PPG ALPHA SPACER FOLLOWED BY 33.6 BBL (165 SX) 15.8 PPG PREMIUM CLASS CEMENT WITH 0.35% HALARD-344, 0.5% UCS AND 0.08% HR-5. DROP PLUG, GOOD SURFACE INDICATION. PUMP 5 BBL FRESH WATER. CHANGE TO RIG PUMPS AND DISPLACE CEMENT WITH 135 BBL 10.0 PPG MUD AT 6.5 BPM. FULL RETURNS. BUMP PLUG WITH 1500 PSI. CEMENT IN PLACE AT 18:10 HRS. PRESSURE UP TO 3000 PSI. RELEASE PRESSURE, FLOATS HELD. SET DOWN WEIGHT TO CONFIRM LINER HANGER SET. ROTATE 15 TURNS, PRESSURE UP DRILL PIPE TO 700 PSI, PICK UP AND RELEASE FROM HANGER. PICK UP TO RELEASE DOGS FROM TIE BACK SLEEVE, SET DOWN AND SET ZXP LINER TOP PACKER. REPEAT PROCEDURE. GOOD INDICATION OF DOGS AND PACKER SETTING. TOP OF 7" LINER AT 7265', FLOAT SHOE AT 9141' 18:30 - 19:30 1.00 DRILL P INT1 CIRCULATE BOTTOMS UP. NO CEMENT RETURNS. 19:30 - 20:30 1.00 DRILL P INT1 RIG DOWN CEMENT HEAD AND LINES. 20:30 - 21 :30 1.00 DRILL P INT1 CUT AND SLIP 1 1/4" DRILLING LINE. 21 :30 - 00:00 2.50 DRILL P INT1 POH 4 " DRILL PIPE WITH LINER RUNNING TOOL. 11/18/2001 00:00 - 01 :30 1.50 DRILL P INT1 POH 4 " DRILL PIPE WITH LINER RUNNING TOOL AND LAY DOWN SAME. 01 :30 - 02:00 0.50 DRILL P INT1 CLEAR RIG FLOOR OF DRILL PIPE HANDLING TOOLS. 02:00 - 03:00 1.00 DRILL P INT1 PULL WEAR BUSHING. RIG UP TEST JOINT AND TOOLS PRIOR TO BOP TEST. 03:00 - 10:30 7.50 DRILL P INT1 TEST CHOKE MANIFOLD TO 250 PSI LOW AND 5000 PSI HIGH. TEST BOP AND RELATED VALVES 250 PSI LOW AMND 3500 PSI HIGH. NOTE: AOGCC REP' CHUCK SCHEVE WAIVED WITNESSING TEST. 10:30 - 11 :00 0.50 DRILL P INT1 RIG DOWN TEST JOINT AND EQUIPMENT AND INSTALL WEAR BUSHING. 11 :00 - 16:00 5.00 DRILL P INT1 MAKE UP BHA #5 WITH 6 1/8" TRICONE BIT. TEST MWD. 16:00 - 16:30 0.50 DRILL P INT1 TEST CASING, LINER AND LINER TOP PACKER TO 3500 PSI FOR 10 MINUTES. 16:30 -18:30 2_00 DRILL P INT1 RIH. PICK UP 4" DRILL PIPE IN SINGLES FROM PIPE SHED. 18:30 - 19:00 0.50 DRILL P INT1 RIH TO 3370'. 19:00 - 19:30 0.50 DRILL P INT1 TEST MWD. OK. 19:30 - 20:30 1.00 DRILL P INT1 RIH TO 6170'. 20:30 - 21 :00 0.50 DRILL P INT1 SERVICE TOP DRIVE. 21 :00 - 23:00 2.00 DRILL P INT1 RIH TO 9020'. TAG UP ON CEMENT STRINGER. 23:00 - 00:00 1.00 DRILL P INT1 WASH AND ROTATE CEMENT STRINGER TO TOP OF LANDING COLLAR AT 9055' 11/19/2001 00:00 - 00:30 0.50 DRILL P INT1 CIRCULATE AT TOP OF LANDING COLLAR AT 9055' 00:30 - 01 :30 1.00 DRILL P INT1 PRESSURE TEST CASING, LINER AND LINER TOP PACKER TO 3500 PSI FOR 30 MINUTES. OK. 01 :30 - 05:00 3.50 DRILL P INT1 DRILL 7" LANDING COLLAR, CEMENT, FLOAT COLLAR, CEMENT AND FLOAT SHOE FROM 9055' TO 9141'. 05:00 - 07:00 2.00 DRILL P INT1 DISPLACE 10 PPG LSND MUD WITH QUICKDRIL-N 8.4 PPG MUD. 07:00 - 08:00 1.00 DRILL P INT1 DIRECTIONAL DRILL FROM 9141' TO 9161' WITH 1.83 DEG BENT HOUSING MOTOR WITH ABI16', RES 49', GR 56', ,f " (" Printed: 11/27/2001 4:15:06 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/19/2001 11/20/2001 11/21/2001 11/22/2001 11/23/2001 ( ~' BP EXPLORATION Operations Summary Report K-05B K-05B REENTER+COMPLETE NABORS NABORS 2ES 07:00 - 08:00 From - To Hours Activity Code NPT 08:00 - 09:00 09:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 18:00 18:00 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 07:30 07:30 - 13:00 13:00 -15:30 15:30 - 16:00 16:00 - 00:00 00:00 - 00:00 00:00 - 06:00 1.00 DRILL 1.00 DRILL 14.50 DRILL 0.50 DRILL 0.50 DRILL 17.50 DRILL 2.50 DRILL 0.50 DRILL 0.50 DRILL 2.50 DRILL 2.00 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 5.50 DRILL 2.50 DRILL 0.50 DRILL 8.00 DRILL 24.00 DRILL 6.00 DRILL P P P N N p P P P P P P P P P P P P P P P INT1 INT1 INT1 RREP INT1 RREP INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Page 6 of 8 Start: 10/31/2001 Rig Release: Rig Number: Spud Date: 11/4/2001 End: Phase Description of Operations DIRECTION 68' AND DEN 92' FROM THE BIT. ROTATING TIME .75. SLIDING TIME O. PERFORM FIT WITH 8.5 PPG MUD, 475 PSI WITH AN EMW OF 9.6 PPG. DIRECTIONAL DRILL FROM 9161' TO 9627' ROTATING TIME 4.25. SLIDING TIME 6_25- RIG REPAIRS. REPLACE '0' RING ON TOP DRIVE LINK TILT HYDRAULIC SYSTEM. RIG REPAIRS. REPLACE '0' RING ON TOP DRIVE LINK TILT HYDRAULIC SYSTEM. DIRECTIONAL DRILL FROM 9327' TO 9943 WITH 1.83 DEG BENT HOUSING MOTOR WITH ABI16', RES 49', GR 56', DIRECTION 68' AND DEN 92' FROM THE BIT. ROTATING TIME 4. SLIDING TIME 10.25. PUMP 30 BBL HIGH VIS SWEEP. CIRCULATE AND CONDITION MUD AND CLEAN HOLE. POH TO 7" LINER SHOE. NO EXCESSIVE DRAG. MONITOR WELL. PUMP DRY JOB. BLOW DOWN TOP DRIVE POH FOR BIT AND BHA CHANGE. POH TO BHA. MONITOR WELL. STAND BACK HWDP AND FLEX COLLARS- PJSM. REMOVE RA SOURCES. POH WITH BHA. LAY DOWN MOTOR AND MWD- CLEAR RIG FLOOR. INSTALL MOUSE HOLE TO FACILITATE LOADING AND UNLOADING OF MWD. MAKE UP NEW 61/8" PDC BIT, MOTOR WITH 1.5 DEG BENT HOUSING AND MWD. SHALOW TEST MWD. OK. RIH TO 9630'. RUN SURVEY CHECK SHOTS AT 9336' AND 9491'. OK. HELD UP ON TIGHT SPOT AT 9630'. WASH AND REAM FROM 9630' TO 9943'. CIRCULATE AS PRECAUTION TO REMOVE ANY JUNK LEFT ON BOTTOM FROM LAST BIT. DRILL FROM 9943' TO 10,125' WITH NEW PDC BIT AND MUD MOTOR WITH 1.5 DEG BENT HOUSING WITH RES AT 41', GR AT 48' AND DIRECTOINAL SURVEY AT 60' FROM THE BIT. ROTATING TIME 2.57- SLIDING TIME 2.5. DRILL FROM 10,125' TO 10,768' WITH PDC BIT AND MUD MOTOR WITH 1.5 DEG BENT HOUSING WITH RES AT 41', GR AT 48' AND DIRECTOINAL SURVEY AT 60' FROM THE BIT. ROTATING TIME 7.5. SLIDING TIME 7.25. DRILL FROM 10,768' TO 10,900' WITH PDC BIT AND MUD MOTOR WITH 1.5 DEG BENT HOUSING WITH RES AT 41', GR AT 48' AND DIRECTOINAL SURVEY AT 60' FROM THE BIT. ROTATING TIME 2.25. SLIDING TIME 0.75. NOTE: GRADUAL INCREASE OF MUD LOSES TO THE HOLE. LOST 60 BBL IN LAST HOUR OF DRILING. TOTAL LOST WHILE DRILLING 175 BBL. Printed: 11/27/2001 4:15:06 PM .. BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/23/2001 06:00 - 06:30 0.50 DRILL P INT1 SPOT 25 BBL LCM 30 LBS/BBL PILL ON BOTTOM. OBSERVE WELL. LOSING 6 BBUHR WITH THE WELL STATIC. 06:30 - 08:00 1.50 DRILL P INT1 CIRCULATE BOTTOMS UP. LOST 90 BBL MUD. 08:00 - 09:30 1.50 DRILL P INT1 POH TO 7" LINER SHOE. NO EXCESSIVE DRAG. MONITOR WELL. 09:30 - 10:30 1.00 DRILL P INT1 CUT AND SLIP 1 1/4" DRILLING LINE. 10:30 -11:30 1.00 DRILL P INT1 SERVICE TOP DRIVE. 11 :30 - 12:30 1.00 DRILL P INT1 RIH TO 10,900' TO. NO EXCESSIVE DRAG. 12:30 - 16:30 4.00 DRILL P INT1 CIRCULATE HIGH VIS LCM PILL. CIRCULATE BOTTOMS UP. SPOT 50 BBL LINER RUNNING PILL IN OPEN HOLE. 16:30 - 21 :00 4.50 DRILL P INT1 POH FROM 10,900' TO 2216' SLM, DROP DRILL PIPE DRIFT. MONITOR WELL AT 7" LINER SHOE. 21 :00 - 23:00 2.00 DRILL P INT1 POH TO 539'. LAY DOWN 4" DRILL PIPE IN SINGLES. 23:00 - 00:00 1.00 DRILL P INT1 POH. LAY DOWN BHA HOLE TAKING 8 BBL OF MUD PER HOUR. 11/24/2001 00:00 - 02:00 2.00 DRILL P INT1 POH. LAY DOWN BHA DOWN LOAD MWD. 02:00 - 03:00 1.00 DRILL P INT1 CLEAR RIG FLOOR. PJSM. RIG UP TO RUN 4 1/2" LINER. 03:00 - 06:30 3.50 DRILL P INT1 RUN 47 JTS 41/2" L-80, 12.6# IBT-M LINER. 06:30 - 07:30 1.00 DRILL P INT1 PICK UP BAKER 41/2" X 7" HMC LINER HANGER WITH ZXP LINER TOP PACKER 07:30 - 08:30 1.00 DRILL P INT1 CIRCULATE LINER VOLUME AT 3 BPM WITH 150 PSI. CONFIRM LINER WEIGHT. 08:30 - 14:30 6.00 DRILL P INT1 RIH WITH 41/2" LINER ON 4" DRILL PIPE TO 7" LINER SHOE. 14:30 - 15:00 0.50 DRILL P INT1 MAKE UP 'TO' CEMENTING HEAD AND STAND BACK. 15:00 -15:30 0.50 DRILL P INT1 CIRCULATE DRILL PIPE AND LINER VOLUMES. CONFIRM STRING WEIGHT. 15:30 - 17:00 1.50 DRILL P INT1 RIH WITH 4 1/2" LINER ON 4" DRILL PIPE TO 10,900' 17:00 - 20:00 3.00 DRILL P INT1 CIRCULATE AND CONDITION MUD AT 7 BPM WITH 1300 PSI. RECIPROCATE PIPE. PJSM WITH RIG CREWS, HALLIBURTON CEMENTERS AND TRUCK DRIVERS. 20:00 - 21 :30 1.50 DRILL P INT1 PUMP 5 BBL WATER, TEST LINES TO 4000 PSI. PUMP 40 BBL 9.8 PPG ALPHA SPACER FOLLOWED BY 53 BBL (250 SX) 15.6 PPG PREMIUM CLASS CEMENT WITH 1.0% BENTONITE, 0.35% CFR2, 2.0% LATEX-2000 AND 3.0% D-AIR 3 AT 5 BPM. DROP PLUG AND DISPLACE WITH 30 BBL PERF PILL PLUS 87.5 BBL MUD USING HALLIBURTON CEMENTING UNIT. AFTER PUMPING 90 BBL LATCHED INTO LINER WIPER PLUG, SHEAR OUT AT 2100 PSI. BUMP PLUG WITH 117.5 BBL DISPLACED. PRESSUER UP TO 3200 PSI. BLEAD PRESSURE OFF, FLOATS HELD. RECIPROCATED PIPE, FULL RETURNS. CEMENT IN PLACE AT 21 :20 21 :30 - 22:00 0.50 DRILL P INT1 SET BAKER HMC LINER HANGER AND CONFIRM WITH DOWN WEIGHT. ROTATE AND RELEASE FROM HANGER. PRESSURE UP DRILL PIPE WITH 1000 PSI, PICK UP TO PRESSURE DROP AND CIRCULATE CEMENT FROM LINER TOP. ROTATE AND SET DOWN TO SET ZXP LINER TOP PACKER. 22:00 - 22:30 0.50 DRILL P INT1 CIRCULATE. CEMENT CONTAMINATED MUD RETURNS 22:30 - 00:00 1.50 DRILL P INT1 CIRCULATE AND DISPLACE 8.5 PPG MUD WITH SEA WATER. ( ( Printed: 11/27/2001 4:15:06 PM BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 10/31/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/25/2001 00:00 - 01 :00 1.00 DRILL P INT1 CIRCULATE AND DISPLACE 8.5 PPG MUD WITH SEA WATER. 01 :00 - 02:00 1.00 DRILL P INT1 RIG DOWN CEMENT HEAD AND LINES. CLEAR RIG FLOOR. 02:00 - 09:00 7.00 DRILL P INT1 POH. LAY DOWN 4" DRILL PIPE. LAY DOWN LINER RUNNING TOOL. 09:00 - 09:30 0.50 DRILL P INT1 TEST LINER TO 3500 PSI FOR 30 MINUTES. 09:30 - 10:30 1.00 DRILL P INT1 PULL WEAR BUSHING. 10:30 - 12:00 1.50 DRILL P INT1 RIG UP TO RUN 41/2" TUBING. PJSM WITH CREW. 12:00 - 22:30 10.50 DRILL P INT1 RIH WITH COMPLETION. 41/2" 12.6#, L-80, IBT-M TUBING. TOTAL OF 208 JTS RUN 22:30 - 00:00 1.50 DRILL P INT1 SPACE OUT TO LAND TUBING. PICK P PUP JOINTS. 11/26/2001 00:00 - 00:30 0.50 DRILL P INT1 SPACE OUT TO LAND 4 1/2" TUBING COMPLETION. 00:30 - 01 :00 0.50 DRILL P INT1 RIG UP LINES TO REVERSE CIRCULATE. 01 :00 - 05:00 4.00 DRILL P INT1 REVERSE CIRCULATE TUBING VOLUME WITH CLEAN SEA WATER. DISPLACE WELL WITH CLEAN SEA WATER TREATED WITH CORROSION INHIBITOR. 05:00 - 06:30 1.50 DRILL P INT1 DROP 1 7/8" BALL AND ROD. SET BAKER S-3 PACKER AT 8932'. TEST TUBING TO 3500 PSI FOR 30 MINUTES. TEST TUBING X CASING ANNULUS TO 3500 PSI FOR 30 MINUTES. SHEAR 'RP' PORT IN MLG AT 4307' BLEED OFF PRESSURE. 06:30 - 07:00 0.50 DRILL P INT1 LAY DOWN LANDING JOINT AND XO. BLOW DOWN TOP DRIVE. 07:00 - 08:00 1.00 DRILL N SFAL INT1 SET TWO WAY CHECK VALVE. UNABLE TO OBTAIN TEST. 08:00 - 10:30 2.50 DRILL P INT1 RIG DOWN TUBING RUNNING TOOLS AND CLEAR RIG FLOR. 10:30 - 13:00 2.50 DRILL P INT1 RIG UP DRILL SITE MAINTENANCE LUBRICATOR, PULL TWO WAY CHECK. REPLACE TWC AND OBTAIN GOOD TEST AFTER TWO ATTEMPTS. RIG DOWN LUBRICATOR. 13:00 - 19:00 6.00 DRILL P INT1 NIPPLE DOWN BOP. INSTALL TREE. 19:00 - 20:00 1.00 DRILL P INT1 PRESSURE TEST TREE AND ADAPTOR TO 5000 PSI. OK. 20:00 - 20:30 0.50 DRILL P INT1 RIG UP LUBRICATOR, PULL TWO WAY CHECK, RIG DOWN LUBRICATOR. 20:30 - 23:00 2.50 DRILL P INT1 RIG UP LINES FROM HOT OIL UNIT TO WELL. FREEZE PROTECT WELL WITH 155 BBL DIESEL AT 75 DEG AT 2 BPM WITH 500 PSI DOWN ANNULUS. 23:00 - 00:00 1.00 DRILL P INT1 FREEZE PROTECT DIESEL 'U' TUBE ACROSS TOP OF WELL. 11/27/2001 00:00 - 03:00 3.00 WHSUR P COMP U-tube freeze protect diesel. Installed BPV, tested to 2500 psi. RID annular valve and released rig. Note: Rig released at 0300 hrs 11/27/01. .( ('''I Printed: 11/27/2001 4:15:06 PM { BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12122/2001 00:00 - 04:00 4.00 RIGU P PRE Accept rig at 04:00 hrs. 04:00 - 11: 15 7.25 BOPSUF P DECOMP Nipple up BOP. Back Dowell CTU #4 into position and begin rig-up. 11:15-17:00 5.75 BOPSUR P DECOMP Test BOP. Jeff Jones of the AOGCC waived witnessing the test. 17:00 -18:30 1.50 BOPSUR P DECOMP Pull TWC with lubricator. 18:30 -19:15 0.75 CLEAN P DECOMP PJSM prior to picking up BHA and initial entry into well. 19:15 - 22:45 3.50 CLEAN P DECOMP Re-head coil, MU MHA, Pressure and pull test new coil connector, test inner reel valve, Circulate out FP from coil, and make up cleanout BHA for drilling out liner shoe. Will run weatherford motor with cleanout BHA. 22:45 - 00:00 1.25 CLEAN P DECOMP RIH with coil while displacing the diesel FP to tiger tank. 12/23/2001 00:00 - 01 :00 1.00 CLEAN P DECOMP Continue to RIH with coil. 01 :00 - 01 :05 0.08 CLEAN P DECOMP Tag the landing collar at 10,815'. (Made a -3' correction to the coil depth). 01 :05 - 02:20 1.25 CLEAN P DECOMP Flag the pipe at 10,815'. Roll the hole to 3% KCI water containing 1.5 PPB of Biozan. 02:20 - 05:00 2.67 CLEAN P DECOMP Drill about 2' and started having a lot of rubber chunks coming back in our returns. Bit started stalling at very frequent intervals and different locations between the bottom and about a foot up the hole. Quit making progress. 05:00 - 07:15 2.25 CLEAN P DECOMP POOH with BHA. 07:15 - 07:30 0.25 CLEAN P DECOMP Set back injector and LD motor. 07:30 - 09:15 1.75 CLEAN N WAIT DECOMP Wait on arrival of replacement mule shoe for junk basket. Original had a belled box. 09:15 - 09:25 0.17 CLEAN P DECOMP MU half mule shoe and junk basket. 09:25 -11:10 1.75 CLEAN P DECOMP RIH with venturi basket. 11: 10 - 11 :30 0.33 CLEAN P DECOMP Circulate down to top of junk 11 :30 - 13:40 2.17 CLEAN P DECOMP POH LD junk basket. 13:40 - 14:05 0.42 CLEAN P DECOMP Junk basket had a pint of aluminum cuttings and the nose off the wiper dart which was about the size of an egg. This piece had obviously been rolling around under the bit. Continued milling would have put a lot of cycles on the coil which could have been detrimental to future work. 14:05 - 14:15 0.17 CLEAN P DECOMP PU PDC and motor 14:15 -14:25 0.17 CLEAN P DECOMP Stab onto well 14:25 - 16:25 2.00 CLEAN P DECOMP RIH to 10,815' and tag landing collar. 16:25 -18:30 2.08 CLEAN P DECOMP Drill landing collar and small amount of cement to the float collar at 10,857'. Very small amount of cement observed. 18:30 - 18:45 0.25 CLEAN P DECOMP Drill through the float collar. After drilling through the float shoe we picked up on the coil and noticed about 10-12k of overpull. Also saw motor work and some stalls when pulling up. Apparently some debries from the float collar is just above the bit. Pull up hole slowly to 10,657' with continuous over pull and frequent stalls. At about 10,657' the debries apparently came dislodged. Start back to bottom with bit. No cement observed between the bottom of the float collar and the top of the guide shoe at 10,898' 18:45 - 22:35 3.83 CLEAN P DECOMP Time drill through the guide shoe. 22:35 - 22:45 0.17 CLEAN P DECOMP Finish drilling out of the shoe at 10,901.7' at 22:35 hrs. Drill ahead to 10,912' at a rate of +1- 70 BPH with full returns. Mostly cement observed at the shakers after bottoms up at ( Printed: 1/14/2002 10:16:10 AM BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations ,,' " 12123/2001 22:35 - 22:45 0.17 CLEAN P DECOMP 10,912'. 22:45 - 00:00 1.25 CLEAN P DECOMP Circulate the hole bottoms up while emptying out the pits and starting flo-pro mud down the coil. Worked bit through the shoe, float collar, and landing collar several times at full rate and did not see any motor work. Getting full returns to surface. 12/24/2001 00:00 - 00:10 0.17 CLEAN P DECOMP Continue to circulate flo-pro mud down to the bit. 00:10 - 02:30 2.33 CLEAN P DECOMP POOH with BHA while circulating the hole full of new flo-pro mud. 02:30 - 03:00 0.50 CLEAN P DECOMP PJSM prior to laying down BHA 03:00 - 03:35 0.58 CLEAN P DECOMP Lay down BHA Return line to pit plugged. 03:35 - 03:45 0.17 CLEAN N SFAL DECOMP PJSM to determine strategy to locate plug. 03:45 - 05:00 1.25 CLEAN N SFAL DECOMP Pulled hose from HCR and found junk from float equipment. Removed plastic and aluminum junk. Need to consider locating annular pressure sensor some place closer to the well. 05:00 - 05:40 0.67 DRILL P PROD1 MU BHA #4. 05:40 - 05:45 0.08 DRILL P PROD1 Stab onto well. 05:45 - 08:25 2.67 DRILL P PROD1 RIH tie in at 9610 -4' correction. 08:25 - 09:00 0.58 DRILL P PROD1 RIH to 10,912 09:00 - 10:00 1.00 DRILL P PROD1 Drill at 2.6 bpm 2950 psi 2800 psi FS initially drilling with full returns 1 OOftlhr at 10930' drill to 10,981 10:00 - 11 :35 1.58 DRILL P PROD1 Drilling ahead at 11,015' at 11 :35 AM at 40 FPH, 2.6 I 2,900 with full returns. 11:35 -13:00 1.42 DRILL P PROD1 Drilling ahead from 11,015' to 11,031'. Drilling with some indication of differential sticking. Drilling slow. Lots of pyrite(+I- 10%) in cuttings. Probably near fault #1. 13:00 - 13:20 0.33 DRILL P PROD1 Short trip to the shoe. Still getting full returns. 13:20 -14:05 0.75 DRILL P PROD1 Drill ahead from 11,031' to 11,044'. Hole is sticky and weight transfer a challenge. 14:05 - 15:30 1.42 DRILL P PROD1 Wiper trip to 9400'. Tag TD 8' high at 11,036' on the return to bottom. 15:30 - 16:30 1.00 DRILL P PROD1 Drilling extremely slow to 11,060'. Appears we are drilling in a shale. Weight transfer still a challenge. 16:30 - 19:25 2.92 DRILL P PROD1 Drill ahead from 11,060' to 11,100'. 19:25 - 22:00 2.58 DRILL P PROD1 Drill ahead from 11,100' to 11,187' with full returns. 22:00 - 23:00 1.00 DRILL P PROD1 Lost 100% of returns when the bit hit a depth of 11,187'. Drill ahead with no returns to see if fault zone heals. 23:00 - 00:00 1.00 DRILL P PROD1 Still no returns. Swap over to 3% KCL water for drilling fluid. Drilling at 11,240' at 11 :59 PM on 12/24/2001. 12/25/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Wiper trip from 11,240' to the liner shoe. No motor work or tight spots observed. 01 :00 - 02:30 1.50 DRILL P PROD1 Drill ahead from 11,240' to 11,300'. 02:30 - 04:30 2.00 DRILL N STUC PROD1 Start short trip to the casing shoe. Pull up hole to 11,251' and could not pull any higher. Pipe moved down, but not up. Pull at different speeds with pumps both on and off. Pull up to 75K. Consult with engineering team. Order out crude. While waiting for crude the pipe was worked again and became stuck at 11,268'. Could not move pipe up or down. 04:30 - 05:00 0.50 DRILL N STUC PROD1 PJSM prior to pumping crude. 05:00 - 06:45 1.75 DRILL N STUC PROD1 Pump 60 bbls of crude down the coil with approx. 16k pushing down from the injector at surface. Let crude soak for approx 20 min and then cycle pumps with crude on bottom. Pick up to neutral weight and let crude soak another 20 minutes. Pull up 20k over string weight (total of 65k Ibs up) and cycle pump. (' ( Printed: 1/14/2002 10:16:10 AM BP EXPLORATION Pag~ 3 of 14 Operations Summary Report Legal Well Name: K-O5B Common Well Name: K-O5B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: Date From- To Hours Activity Code NPT Phase Description of Operations 12/25/2001 05:00 - 06:45 1.75 DRILL N STUC PROD1 Stack weight down again. No movement observed in coil. 06:45 - 09:35 2.83 DRILL N STUC PROD1 Pump 90 barrels of crude down the coil with approx. 16k pushing down from the injector. Work pipe. No movement. 09:35 - 11 :25 1.83 DRILL N STUC PROD1 Pump 100 barrels of crude down the coil at 2.7 BPM. while stacking 21.5k down on the coil. Cycle pumps every 20 minutes. No pipe movement. 11:25 -13:40 2.25 DRILL N STUC PROD1 Rig up and pump 120 barrels of crude oil down the coil x production tubing annulus at +1- 3 BPM while stacking 23k Ibs down on the coil (Annulus volume of +1- 110 bbls). Once the crude was spotted, shut down the pumps for 10 minutes and let crude soak with 23k Ibs force down. After 10 minutes, brought pumps on line and picked up 70k on the coil. Held for 10 min and then shut down the pumps and stacked 23k Ibs down on the coil for 10 minutes. After 10 minutes brought the pumps on line for about 3 minutes when we noticed the injector head took weight. Moved the coil down hole 10' and then picked back up to the stuck point at 11,268'. Pulled 60k at the stuck point. Drop back to bottom. Line up and pump crude down tubing. Pull up again and saw an overpull of about 5k when the bit reached the stuck point (no motor work observed on the way up through the open hole). Pull the BHA into the liner at 9150'. 13:40 - 15:00 1.33 DRILL N STUC PROD1 Bulhead the crude oil in the coil and the coil x tubing annulus away. 15:00 - 16:15 1.25 DRILL N SFAL PROD1 Fix hydraulic leak in ops cab. Mix pill. 16:15 - 17:15 1.00 DRILL N STUC PROD1 RIH slow to 10700', washing 2.7 BPM; 2600 psi, no returns. Saw no motor work in liner. 17:15 -18:30 1.25 DRILL N DPRB PROD1 Pump 30 bbls of 25 ppb OM seal medium 2.7 BPM; 2600 psi. SI backside with pill at bit. Pressure climbed and broke repeatedly with pill passing thru BHA. Saw as much as 4800 psi CTP at 0.25 BPM. Displace to fault. Saw 40 psi WHP response with 25 of 30 bbls away in fault. Open BS and check returns, reduce rate. Slight flow then lost it all. Back to 2.7 BPM; 2600 psi, no returns. 18:30 -19:00 0.50 DRILL P PROD1 Safety meeting. Verify with Anchorage on continued drilling. 19:00 -19:45 0.75 DRILL P PROD1 RIH. Clean to 11275'. Sat down here, worked thru. Tag TD 11297'. 19:45 - 20:45 1.00 DRILL P PROD1 Drill to 11350'. 20:45 - 21 :00 0.25 DRILL P PROD1 Wiper to shoe. Pulled heavy wlo MW and stuck at 11215'. 21 :00 - 00:00 3.00 DRILL N STUC PROD1 Work pipe in downward direction. Call for crude. 12/26/2001 00:00 - 00:30 0.50 DRILL N STUC PROD1 Crude tanker here. RU. Bottle test. 00:30 - 01 :05 0.58 DRILL N STUC PROD1 Stuck at 11 ,228'. Pump crude down coil and spot 10 bbls outside of coil. PU to neutral weight and shut-down pumps. Set 17k down on the coil and cycle pumps. No pipe movement. 01 :05 - 01 :45 0.67 DRILL N STUC PROD1 Rig up and pump crude down the annulus. Pump 20 barrels of crude and catch WHP. After pumping 30 bbls of fluid the coil took weight. Move the coil down and then picked back up past the stuck point. Only saw a slight, if any, overpull at the stuck point. Pull BHA up into the liner. 01:45 - 02:15 0.50 DRILL N STUC PROD1 Bull head the crude from the coil with 3% KCL water. Then, bullhead the crude from the annulus with 220 barrels of 3% KCL water. 02:15 - 04:00 1.75 STKOH N DPRB PROD1 POOH with BHA. 04:00 - 04:10 0.17 STKOH N DPRB PROD1 PJSM prior to pulling BHA. (' (' Printed: 1/14/2002 10:16:10 AM BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations .. 12/26/2001 04: 1 0 - 04:40 0.50 STKOH N DPRB PROD1 Lay down drilling BHA and down-load TORC and MWD data. 04:40 - 05:00 0.33 STKOH N DPRB PROD1 MU cementing BHA. 05:00 - 05:15 0.25 STKOH N DPRB PROD1 Pressure test BHA. ok. 05: 15 - 07:30 2.25 STKOH N DPRB PROD1 RIH with cementing BHA to 10000'. 07:30 - 09:45 2.25 STKOH N DPRB PROD1 WO cementers. RU cementers 09:45 -10:15 0.50 STKOH N DPRB PROD1 Safety meeting. 10:15 -13:15 3.00 STKOH N DPRB PROD1 Mix cement. Cement at wt 10:45. Line-up on backside and fill hole. Position nozzle at 10775'. Load 15.8 ppg cement in coil: 10 bbls neat, 25 bbls with 15 ppb PerfectSeal, 5 bbls neat. Displace to nozzle. SI injection into backside. Bullhead cement 2.7 BPM; 2300 psi CTP. Saw WHP response with 18 bbls cement into fault. Open BS, and lay in remaining 17 bbls 1: 1. Full returns while laying in the cement. Pull to safety 9500'. Circulate. Full returns at 2.3 BPM. Choke returns. At fixed choke, 2.3/1.9 BPM, 350 psi WHP intial. Built to 2.3/2.3 BPM, 670 psi. Choke back a little more. WHP rose to 750 psi, broke back a couple times, built to 700 psi, then lost it all to 100 psi with 10 bbls of cement remaining in wellbore (highside water channel?). Attempt to get squeeze back without success. Cement gone. 13:15 -15:15 2.00 STKOH N DPRB PROD1 Circulate liner clean to 10,900' with 1.5 ppb bio water. Chase cement contaminate OOH at 2.7/1.5 BPM. 15:15 -18:00 2.75 STKOH N DPRB PROD1 Mix another 40 bbl batch of cement: 5 bbls neat, 25 bbls with 18 ppb PerfectSeal, 10 bbls neat. 16:00 cement at weight. Load cement in coil. Circulate cement to nozzle (10800') 2.7/1.5. SI backside. Squeeze cement away 2.0 BPM 500 psi WHP. WHP increased to 1000 psi with 4 bbls cement into fault. Bleed off WHP and lay in remaining 31 bbls cement 1 :1. Pull to safety 8500'. SI backside and pressure well to 1000 psi. Put another 3 bbls away. Final squeeze 1000 psi, bled to 800 psi in 20 minutes. 18:00 -19:15 1.25 STKOH N DPRB PROD1 Drop 11/16" ball. Circulate to nozzle with 1.5 ppb bio water 2.3 BPM holding 500 psi WHP. Circulate excess cement from well to 10920' CTM. On the way down to 10,920' CTM, the nozzle tagged something hard at 10,882' CTM. Pecked at the hard spot several times and then was able to wash past 10,882' CTM. Washed to 10,920' CTM. 19:15 - 22:00 2.75 STKOH N DPRB PROD1 POOH with cementing nozzle. Wash gas lift mandrels and other tubing jewelery with 1.5 ppb of bio water on the way up the hole. 22:00 - 22:15 0.25 STKOH N DPRB PROD1 PJSM prior to laying down cementing nozzle. 22: 15 - 23:00 0.75 STKOH N DPRB PROD1 Pull nozzle up into stack and flush stack, choke lines, etc. 23:00 - 23: 15 0.25 STKOH N DPRB PROD1 Lay down cementing nozzle. 23: 15 - 00:00 0.75 STKOH N DPRB PROD1 Pick up drilling BHA and test MHA. 12/27/2001 00:00 - 02:30 2.50 STKOH N DPRB PROD1 RIH with drilling BHA. Shallow hole test at 1500'. Ok. RIH to tie-in point at 9610'. 02:30 - 03:10 0.67 STKOH N DPRB PROD1 Tie-in at 9610'. Subtract 6' from coil depth. 03:10 - 03:35 0.42 STKOH N DPRB PROD1 Continue to RIH. 03:35 - 06:30 2.92 STKOH N SFAL PROD1 Attempt to run Gamma Ray log across the hole section from 10,640' to 10,920' at the request of the onsite geologist. MWD pulser not functioning well...worked fine for tie-in, but not getting consistently good signals to surface now. Slow logging speed to 60 FPH and got better data, but not perfect by any ( ( Printed: 1/14/2002 10:16:10 AM i' { ( BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations " """,' 12127/2001 03:35 - 06:30 2.92 STKOH N SFAL PROD1 means. Shorten logged section to 10,785'-10,920'. Telemetry problems fixed. Will need to relog GR gap across shoe. Calling this two hours downtime. 06:30 - 07:30 1.00 STKOH N DPRB PROD1 Tag and stall 10905' with highside TF. Orient. Tag at minimum rate same depth at low left TF. Orient to 100L. 07:30 - 09:15 1.75 STKOH N DPRB PROD1 Attempt drilling off of 10905' tag depth. Repeated stalls. Time drill into it. Must have been a stringer, never saw it again. Wash in hole and stall 1 0,923' then nothing. RIH clean to 10930'. SO pumps and RIH dry. Tag hard 10933'. UCA at 09:00 shows 1600 psi. 09:15 -11:00 1.75 STKOH N DPRB PROD1 PUH and finish logging GR gap at shoe while WOC. 11:00 -12:00 1.00 STKOH N DPRB PROD1 RIH with pumps looking for hard cement. No noticeable motor work by 10945'. Will perform open hole sidctrack. 12:00 -13:00 1.00 STKOH N DPRB PROD1 Cut trough down 10915' -10945' at 30 FPH. Stall at 10934'. TF shifted to low right. 13:00 -14:00 1.00 STKOH N DPRB PROD1 Orient. Torc lost itself. Send several commands to get back to 150L. 14:00 - 16:15 2.25 STKOH N DPRB PROD1 Cut trough down 10915' - 10945' at 30 FPH, slowing down at 10934'. Stall at 10938'. TF shifted again. Adjust back to 150L and continue with trough. Flag pipe 10945'. Back cut 100 FPH. 16:15 - 17:45 1.50 STKOH N DPRB PROD1 Perform second pass down, as above. No stalls, no motor work. Returns are still 1 :1. Back cut 100 FPH. 17:45 -18:45 1.00 STKOH N DPRB PROD1 Perform third pass down. Also, held crew change safety meeting. 18:45 -19:45 1.00 STKOH N DPRB PROD1 Time drill from 10,945' to 10,948' at 3 FPH. 19:45-21:10 1.42 STKOH N DPRB PROD1 Time drill from 10948' to 10,954' at 6 FPH. 21:10-22:25 1.25 STKOH N DPRB PROD1 Start drilling ahead in new hole at 10,954'. Drill at 13 FPH, 165L. 22:25 - 23:40 1.25 DRILL N DPRB PROD1 Turned tool face up to 76L at a depth of 10,970'. Drill ahead. 23:40 - 00:00 0.33 DRILL N DPRB PROD1 Drilling ahead at 10,990' at midnight. KCI drilling fluid with full returns. 12/28/2001 00:00 - 01 :30 1.50 DRILL N DPRB PROD1 Drilling ahead at 1 :30 AM at 11,018', 50L. Swap hole over to flo-pro mud. Full returns. 01 :30 - 02:20 0.83 DRILL N DPRB PROD1 Drill ahead from 11,018' to 11,050'. 02:20 - 03:40 1.33 DRILL N DPRB PROD1 Wiper trip to 9400'. 03:40 - 05:00 1.33 DRILL N DPRB PROD1 Drill ahead from 11,050' to 11,115'. TF at 140L. Having a hard time keeping the bit from building hole angle. 05:00 - 05:30 0.50 DRILL N DPRB PROD1 Drill ahead to 11,125'. 05:30 - 06:15 0.75 DRILL N DPRB PROD1 Discuss status with Anch geo. Will point it straight down to hit fault at 8808' SSND. Project 80 deg inc at this point. Then we'll correct back to horizontal. Should not come close to Kavik doing this. 06:15 - 07:30 1.25 DRILL N DPRB PROD1 Drill to 11178' 07:30 - 08:30 1.00 DRILL N DPRB PROD1 Pump up survey. 81 deg project at bit. Orient. 08:30 - 09:20 0.83 DRILL N DPRB PROD1 Drill to 11225'. Rattier drilling at about 11211', but no losses. 09:20 - 09:45 0.42 DRILL N DPRB PROD1 Wiper trip to 10970'. 09:45 - 10:45 1.00 DRILL N DPRB PROD1 Drill to 11262'. Seeing losses here. 2.7/1.4 initial. 10:45 - 11 :45 1.00 DRILL N DPRB PROD1 Continue drilling. Order KCL water. Losses increased to 2.7/0.2 by 11280', Then at 11290', we saw a 700 psi drop in CTP and lost all returns. Drill to 11293'. Pull slowly to 11260' while orienting. Clean -- no overpulls. Drill to 11310'. 11 :45 - 12:30 0.75 DRILL N DPRB PROD1 Wiper to 10970' clean. Out of mud. Switch to KCL water. Printed: 1/14/2002 10:16:10 AM BP EXPLORATION Page6of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations " 12128/2001 12:30 - 13:30 1.00 DRILL N DPRB PROD1 Drill to 11360'. Back on productive time. 13:30 - 14:00 0.50 DRILL P PROD1 Wiper to shoe clean. RIH clean thru junction with 100L TF. 14:00 - 15:00 1.00 DRILL P PROD1 Drill to 11394'. Switch back to pits. Wiper to fault. 15:00 - 15:30 0.50 DRILL P PROD1 Pump up survey. Move TF from 90R to 90L. 15:30 -16:00 0.50 DRILL P PROD1 Drill to 11453'. 16:00 - 16:45 0.75 DRILL P PROD1 Wiper to shoe. Slight overpull wlo MW at 11350' (CTC 11274'). 16:45 - 18:15 1.50 DRILL P PROD1 Drill and survey to 11555'. Pump up survey. 18:15 - 19:30 1.25 DRILL P PROD1 Wiper to shoe. 19:30 - 20:25 0.92 DRILL P PROD1 Drill to 11,600'. TF straight down. Hole getting a little bit sticky towards 11,600' and saw some weight stacking while drilling. 20:25 - 20:50 0.42 DRILL P PROD1 Wiper to 11,280'. 20:50 - 21 :50 1.00 DRILL P PROD1 Drill ahead from 11,600' to 11,626' with tool face straight down. Hole very sticky and frequent motor stalls. 21 :50 - 22:35 0.75 DRILL P PROD1 Drill ahead from 11,626' to 11,654' with tool face straight down. 22:35 - 23:00 0.42 DRILL P PROD1 Drill ahead to 11,663' with tool face down. 23:00 - 23:15 0.25 DRILL P PROD1 Wiper trip to the fault. 23:15 - 23:55 0.67 DRILL N STUC PROD1 Pick up to 11,350' and could not pull any higher. Drop down and pick back up into the same spot several times. (Top of coil connector at 11,274', fault where we lost returns at 11,260'). Pick up and stuck pipe at 11,360'. Work pipe without success. Stack 17k down on the coil and rig up mud pump to the tubing x coil annulus. Start pumping 3% KCI water down the annulus at 4 BPM. After pumping 2 barrels, and before we caught pressure, the pipe came free. Drop down and pick back up with the coil. Got stuck again at 11,345'. Pumped several barrels of 3% KCI water down the annulus again at 350 psi WHP and pipe came free. 23:55 - 00:00 0.08 DRILL P PROD1 Continue with wiper trip to 11,850', 12/29/2001 00:00 - 00:45 0.75 DRILL P PROD1 Finish wiper trip. 00:45 - 02:35 1.83 DRILL P PROD1 Drill ahead from 11,663' to 11,694' with tool face straight down. Drilling very slowly. Frequent motor stalls. 02:35 - 03:50 1.25 DRILL P PROD1 Drill ahead from 11,694' to 11,720' with tool face straight down. 03:50 - 04:55 1.08 DRILL P PROD1 Wiper trip to the casing shoe. Only 2-3k of overpull noted in the area of 11,260'. 04:55 - 05:45 0.83 DRILL P PROD1 Drill ahead from 11,720' to 11,729'. Hole was extremely sticky. Picked up and drop back down to 11,720' and became bit stuck. Work pipe and pick up to 11,710' and became bit stuck again. 05:45 - 07:00 1.25 DRILL P PROD1 Wiper to 9600'. 07:00 - 08:30 1.50 DRILL P PROD1 Log tie-in at 9610' GR. Correct depth (+35'). 08:30 - 09:30 1.00 DRILL P PROD1 RIH. Tag with motor work 10315'. Fell thru. RIH. Sticky bottom 30'. Tag TD 11752' corrected. Repeat twice. 09:30 - 12:00 2.50 DRILL P PROD1 POOH, laying in 30 bbls Flo-Vis pill with 1 drum Lubetex and 1/2 drum Kla-Gard. Slight overpulls in fault area at 1.0 BPM. Flag pipe 9800' EOP. 12:00 -12:30 0.50 DRILL P PROD1 LD drilling BHA. 12:30 - 13:00 0.50 CASE P COMP RU liner running equipment. 13:00 -13:30 0.50 CASE P COMP Safety meeting. 13:30 -15:30 2.00 CASE P COMP MU 28 jts of 2-7/8" STL and 1 jt of 3-1/2" STL liner (putting 0.75 BPM water in hole). ( ( Printed: 1/14/2002 10:16:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/29/2001 12/30/2001 ( « BP EXPLORATION Operations Summary Report K-05B K-05B REENTER+COMPLETE NABORS NABORS 3S From- To Hours Activity Code NPT " 15:30 - 16:15 16:15 - 17:30 17:30 - 19:20 19:20 - 20:30 20:30 - 21 :20 21 :20 - 23:30 23:30 - 23:40 23:40 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 05:45 05:45 - 07:30 07:30 - 08:00 08:00 - 09:45 09:45 - 11 :45 11:45-12:15 0.75 CASE 1.25 CASE 1.83 CASE 1.17 CASE 0.83 CASE 2.17 CASE 0.17 CASE 0.33 CASE 0.50 CASE 1.50 CASE 1.00 CASE 0.50 CASE 2.25 CASE 1.75 CASE 0.50 CEMT 1.75 CEMT 2.00 CASE 0.50 CASE P P P p N N N N N N N N N N P P P P Phase COMP COMP COMP COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP COMP COMP COMP COMP Page 7 of 14 Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Spud Date: 11/4/2001 End: Description of Operations MU CTLRT, pull test. Bring inj to floor. Rehead CTC. Pull and PT. Stab coil. RIH. Make a -17' correction to coil depth at flag (10,760'). RIH to the fault at +1- 11,260' and saw some stacking of weight when the float shoe passed through. Tag TO at 11,752'. Drop 5/8" liner setting ball. Pump (plastic) ball to the coil tubing liner running tool. With approx 20 bbls of 3% KCI water pumped the pressure in the coil spiked to 500 psi and then back to 0 psi. Then, with 40 barrels of 3% KCL water pumped, the pressure on the coil increased to 700 psi, then quickly fell to 0 psi. Pick up on the coil and pick-up weight was 60,000 Ibs. prior to dropping the ball PU weight was 56,000 Ibs. Attempt to release the CTLRT by pumping at high rate in order to get a 2850 psi differential across the CTLRT, or to pick up the ball and seat it. Pumped 50 barrels at rates of up to 3 BPM and pressures as high as 3600 psi. Pick up on the liner. Took 80k Ibs to pick up liner. Decided to POOH while we could still move the liner. POOH with coil and CTLRT to trouble shoot problem. PJSM prior to laying down the CTLRT. Finish pulling out of hole with CTLRT. Lay down CTLRT. Found that the shear pins that hold the seat in place in the wiper plug were sheared and the ball was in the ball catcher in the nose of the wiper plug. The Baker hand says that the only thing he could think of that could have caused this is the ball slamming into the seat so hard that it sheared the pins before adequate pressure built up to release the tool. Suggestion for next run is to trickle fluid in behind ball at a rate slower than before (last try was at 0.8 BPM). Prepare the CTLRT for another run in the hole. Change out the wiper plug and re-pin the ball seat into the top of the wiper. Pump dart through coil. Coil volume of 48.8 barrels. Make up CTLRT to coil. RIH with coil. Tie-in to flag at 10,760' (-18' correction). RIH to TO at 11,752'. Launch 5/8" setting ball. Displace ball. Strange 1000 psi pressure fluctuations with 9 bbls gone. At 25 bbls, SD pump and choke block valve to 0.4 BPM suck. Bumped ball at 35 bbls gone. Pressure to 2500 psi to shear ball seat. PUH a couple feet to verify free of liner. Yes (10k less). Stack back down on liner. Safety meeting with cementers. Mix cement. Cement at wt 08: 15. PT lines. Cementers load 10 bbls 15.8 Class G cement into coil. Load dart while flushing lines. Launch dart, check, gone (MM zero at dart). Displace cement with KCL water 2.7 BPM; 2100 psi. At 49.0 bbls, coil dart picked-up LWP and sheared at 2900 psi. Displace to latch collar 1.6 BPM; 2900 psi. Bump plug. SO pumps. Holding pressure at 3200 psi. Unsting CTLRT. Note: No returns thru entire cement job. No cement above fault at 11290'. POOH. LD CTLRT. Printed: 1/14/2002 10:16:10 AM i BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of.Operations " 12130/2001 12:15 -12:30 0.25 CASE P COMP Set TWC. 12:30 - 18:00 5.50 CASE P COMP RU and perform weekly BOP test. Witness waived by AOGCC's Chuck Scheve. 18:00 - 18:30 0.50 CASE P COMP RU BPV lubricator. Pull TWC. 18:30 -19:30 1.00 CASE P COMP Monitor well. No gas pressure at surface. Rig up and pump one tubing volume of 3% KCL water down the tubing. Hold tour handover safety meeting. 19:30 - 20:45 1.25 CASE P COMP Circulate FP methanol out of coil and lift logging tools up to the rig floor. 20:45 - 21:15 0.50 CASE P COMP PJSM prior to PU of CNL tools. 21 :15 - 23:45 2.50 CASE P COMP PU CNL logging tools and CSH. 23:45 - 00:00 0.25 CASE P COMP RIH with CNL logging tools. 12/31/2001 00:00 - 01:15 1.25 CASE P COMP Continue to RIH with CNL log. The tie-in log will be the Sperry Sun MWD Dual Gamma Ray/Stabilized Litho Density/Comp Thermal Neutron run 11/12/2001 -11/23/2001 and recorded on 1112512001. 01:15-03:10 1.92 CASE P COMP Start logging at 30 FPM at 8850' in order to catch all of the tubing jewelery. Log to PBTD at 11,653' (CTM). Tried pumping at 2.5 BPM at PBTD and stacked +1- 3k on the tool, but could not push through obstruction. 03:10 - 04:50 1.67 CASE P COMP Log from PBTD to 8850'. 04:50 - 06:30 1.67 CASE P COMP POOH with logging tool. 06:30 - 06:45 0.25 CASE P COMP Safety meeting. 06:45 - 09:00 2.25 CASE P COMP Standback injector. Standback 16 std CSH. Safety meeting. LD CNL tool. 09:00 - 10:30 1.50 CASE N DPRB CaMP MU motor and mill, MU CSH. Stab coil. 10:30 - 13:00 2.50 CASE N DPRB COMP RIH. 13:00 -14:15 1.25 CASE N DPRB COMP Tag stringer wi motor work 11649' and 11652'. Skipped thru. Wash wlo MW to PBTD 11719' CTM. Stall here. Repeated tags and stalls at same depth. RIH dry -- took weight starting 11675', then SD at 11690'. Ream area with high vis pill 10640' to TO. RIH dry -- clean to TO. 14:15 -16:30 2.25 CASE N DPRB COMP POOH leaving 10 bbl hi vis Flo-Pro pill in liner. Drop 5/8" ball once above 2-7/8" liner top to open circ sub. Never saw ball land and pressure up, but did see a 500 psi step drop in CTP. 16:30 - 18:00 1.50 CASE N DPRB COMP SB inj. Fill hole thru coil and kill line. SB 16 stds CSH. LD motor and mill. 18:00 - 19:00 1.00 PERF P COMP Crew change safety meeting. Perf safety meeting. 19:00 - 21:00 2.00 PERF P COMP Pick up 2" perforating guns. Guns are loaded with Schlumberger 2" Powerjet, 6 spf, 60 degree phasing guns loaded to perforate from 11,620'-11,700'. 21 :00 - 23:00 2.00 PERF P COMP RIH with guns. Tag PBTD at 11 718' CTM going down. Correct coil depth back to 11,712' at PBTD (-6' correction). 23:00 - 23:50 0.83 PERF P COMP Pick up hole to 11,650' and then drop back down with the bottom nose of the guns to 11,700.7' and launch the 5/8" steel ball. Pumped 42 barrels of 3% KCI water down the coil when the ball landed on the seat. Pressured the coil up to 2850 psi when the guns fired. 23:50 - 00:00 0.17 PERF P COMP Start out of hole with 2" perforating guns. 1/1/2002 00:00 - 02:20 2.33 PERF P COMP Flag coil at 10,299.5' and continue to POOH with coil. 02:20 - 02:35 0.25 PERF P COMP PJSM prior to POOH with perf guns. 02:35 - 03:45 1.17 PERF P COMP Noticed some well head pressure and gas at surface prior to breaking off lubricator. Bullhead 180 barrels of 3% KCL water ( (' Printed: 1/14/2002 10:16:10 AM ( ,f BP EXPLORATION Operations Summary Report Page 9 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-05B K-05B REENTER+COMPLETE NABORS NABORS 3S Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Spud Date: 11/4/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/1/2002 02:35 - 03:45 1.17 PERF P COMP down the coil x tubing annulus at 2.7+ BPM. 03:45 - 05:30 1.75 PERF P COMP Lay down 1-1/4" CSH and spent perf guns. All shots fired on the perf guns. 05:30 - 08:00 2.50 RUNCO COMP Make up KB packer BHA. Change packoff. Stab pipe. 08:00 -10:15 2.25 RUNCO COMP RIH. Correct depth at flag. RIH. Tag 10797'. Corrected liner top should be at this depth, but we should skip past this depth with the seal unit and locate at 10804'. 10:15 -12:00 1.75 RUNCO COMP Attempt to work past 10797'. Unable to work deeper dry. Try with charge pump feeding coil at 0.7 BPM. No go. Catch fluid level in coil and RIH at 1.5 BPM. Saw 300 psi bump in CTP at same time we tag at 10797', then flat line 1.5 BPM; 500 psi CTP. Well still on suck. (Perfs in communication with fault?). PUH no pressure CTP loss. 12:00 - 14:30 2.50 RUNCO DFAL COMP POH to inspect KB Packer assembly. Packer was not there! 14:30 - 15:20 0.83 RUNCO DFAL COMP M/U fishing BHA. 15:20 - 17:00 1.67 RUNCO DFAL COMP RIH. Realized the GS Hyd spear we have in the BHA may release with the continuous loss circulation. 17:00 -18:00 1.00 RUNCO DFAL COMP TOH 18:00 -18:30 0.50 RUNCO DFAL COMP MIU BHA with CTLRT with 4" GS profile to retrieve KB packer. 18:30 - 20:45 2.25 RUNCO DFAL COMP RIH with KB Pkr fishing BHA to 10362'. -7' correction @ flag. Reflag EOP. Check up wt. @ 10752' = 56k. Continue RIH & tag TOF @ 10792'. 20:45 - 21 :00 0.25 RUNCO DFAL COMP Work GS profile into KB Pkr top and P/U @ 56k. Slack off 5k twice into fish to ensure engangement. Looks like KB pkr seals pushed into the liner top deployment sleeve. PIU with 57k. 21 :00 - 23:45 DFAL COMP POOH fishing assy @ 67fpm, pumping 0.6bpm thru CT & across the wellhead to fill hole. Losing fluid @ 2.0bpm. At 6500' start getting 0.5bpm returns & losing @ 1.5bpm. 23:45 - 00:00 DFAL COMP OOH. Recovered & LID KB Pkr & seal assy. LID CTLRT & fishing assy. Line-up and fill hole by pumping across the wellhead. 1/2/2002 00:00 - 01 :00 DFAL COMP MIU new seal assembly & KB packer on 1 jt of PH-6 & MHA. Connect coil & test MHA to 3000 psi - OK. Fill hole via CT & annulus with 1 Obbls. 01 :00 - 03:30 DFAL COMP RIH KB Pkr assy @ 80fpm filling hole via CT & annulus. -10' correction at flag. Continue RIH to 10770' Check up wt @ 56k. RIH & see seals going-in @ 10793' to 10799.5'. Slack off 10k & P/U to 1.5' above up wt. Repeat sting-in & tag at same depth. PIU 15' to ball drop position. 03:30 - 06:45 3.25 RUNCO COMP Drop 5/8" ball & pump 5 bbls KCL water @ 2.5bpm/522psi to to fill hole. Pump additional 15 bbls KCL water & allow ball to gravitate. Stab-in seals & chase ball at minimum rate of 0.4bpm/680psi. Ball on seat @ 37 bbls away. Pressure-up CT to 2300psi & slack off 10k. Isolate CT pressure & fill annulus with 12 bbls. Pltest pkr elements via annulus to 2000 psi. Observe CTlannulus communication @ 2000 psi (looks like running tool shifted). Bled off annulus/CT. Pump via CT & observe 1 for 1 returns. Attempt to PIU running tool. Unable to pull free with 70k pull. Pull to 1 OOk without success. 06:45 - 09:30 2.75 RUNCO DFAL COMP Discuss options with Baker IT in Deadhorse. Its possible that the running tool failed to shift. Loaded and pumped 3/4". This will land on the upper seat and shift the running tool if it isn't already shifted. First 3/4" ball appears to either not have made Printed: 1/14/2002 10:16:10AM (' BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-05B K-05B REENTER+COMPLETE NABORS NABORS 38 Page 10 of 14 Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Spud Date: 11/4/2001 End: Date From - To Hours Activity Code NPT Phase Description of Operations 1/2/2002 06:45 - 09:30 2.75 RUNCO it over the CT gooseneck on has landed. Dropped another followed with 10 bbls mud. Only noticed a small increase in pump presssure as mud exited out of ciculation ports (or someother area). Running tool appears to have shifted at the intial drop of the 5/8" ball. Discussing options with town and Baker. Could possibly be differentially stuck at the seal area of the running tool. Ordered crude truck with anticipation of displacing annulus and lightening the hydrostatic pressure 09:30 - 10:45 1.25 RUNCO DFAL COMP Wait on crude. 10:45 -12:25 1.67 RUNCO DFAL COMP Displace coil and annulus to crude. 12:25 -12:45 0.33 RUNCO DFAL COMP Nabors crew change. PJSM with crews discuss past & present operations. 12:45 -14:15 1.50 RUNCO DFAL COMP With the less hydrostatic pressures from oil, pull to 100k in attempt to pull out of packer with running tool. Same results, no movement. Discuss options with town. Decice to drop 7/8" disconnect ball. 14:15 - 15:00 0.75 RUNCO DFAL COMP Drop 7/8" ball and follow with 110 bbls KCL water (twice displ. volume) Unable to get ball on seat. Appears to be some sort of leak above disconnect or balls not getting to seats. Ball maybe hung up within CT or laying in horizontal sections. 15:00 -15:45 DFAL COMP Make-up and launch foam pig with 12 bbls hi-vis mud behind then KCL at 2.7 bpm 1850 psi. Pressure increased to 2300 psi after 49.5 bbl total away. Pumped another 20 bbls with no increase in pressure. 15:45 -17:00 DFAL COMP Displace remainder of crude from wellbore. 17:00 -18:00 DFAL COMP Discuss further options with town crew. Leaning toward cutting CT. 18:00 -18:30 DFAL COMP Nabors and Schlumberger crew change. PJSM discuss CT cutting and last option to try prior to cutting pipe. Making arrangements for cutting/fishing tools. 18:30 -19:30 DFAL COMP Line up both Dowell and Nabors pumps to CT. Pump at maximum rates obtainable +1- 4.9 bpm at +1- 4600 psi in attempt to put any ball on seat. Attempt to pull free with 98k - still no luck. Freeze protect CT. 19:30 - 20:00 DFAL COMP Town crew okays further pressuring CT with a cement truck to @ 6000psi to see whether any ball will seat & disconnectlshear/release. Mobilise DS cement truck. 20:00 - 21 :30 DFAL COMP W.O DS cement truck. Meanwhile line-up tools chemical cutting CT. BTT will need to machine X/O from CTC to 3-1/2" IF box for connecting to SWS pump in sub. Also call for lifting wire rope slings from Peak. 21 :30 - 22:40 DFAL COMP Cement truck arrives. RIU lines. Reposition inlet MM & P/test sunction line against inner reel valve to 4000 psi - OK. 22:40 - 23:00 0.33 RUNCO DFAL COMP PJSM with cement crew. Discuss HP pumping operations. 23:00 - 23:30 0.50 RUNCO DFAL COMP Flush and Pltest hard lines to 7000 psi - OK. 23:30 - 00:00 0.50 RUNCO DFAL COMP Line up both Unit #4 & cement pumps to CT. Pump several times at maximum rates of @ 5.0 bpm at +1- 5950 psi. Unable to pull free with 90k. 1/3/2002 00:00 - 01 :30 DFAL COMP MIU & launch foam pig with KCL at 3.0bpm/2500 psi. Ramp up to 5.0bpm/5950psi after 51 bbls away. Continue pumping but observe no increase in pressure. Still unable to pull free. 01 :30 - 03:00 DFAL COMP RID cement truck & lines. Put back inlet MM in line & Pltest same-OK. Printed: 1/14/2002 10:16:10AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( t BP EXPLORATION Operations Summary Report K-05B K-05B REENTER+COMPLETE NABORS NABORS 3S 1/3/2002 03:00 - 04:30 From - To Hours Activity Code NPT DFAL COMP 04:30 - 05:00 05:00 - 05:15 05:15 - 06:20 06:20 - 06:50 06:50 - 07:20 07:20 - 08:15 08:15 - 09:00 09:00 - 09:30 09:30 - 11 :30 11:30 -12:00 12:00 -15:25 15:25 -16:30 16:30 - 16:55 16:55 - 17:30 17:30 -19:15 19:15-21:00 21 :00 - 21 :30 21:30-22:15 22:15 - 23:00 23:00 - 23:30 23:30 - 23:45 Phase DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP 1.08 RUNCO 0.42 RUNCO 0.58 RUNCO DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP 0.75 RUNCO 0.50 RUNCO 0.25 RUNCO DFAL COMP DFAL COMP DFAL COMP 23:45 - 00:00 DFAL COMP 1/4/2002 00:00 - 00:30 0.50 RUNCO DFAL COMP 00:30 - 00:40 0.17 RUNCO DFAL COMP 00:40 - 00:45 0.08 RUNCO DFAL COMP 00:45 - 03:30 2.75 RUNCO DFAL COMP Page 11of 14 Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Spud Date: 11/4/2001 End: Description of Operations SWS unit arrive. FP CT & R/U to surface cut CT. Check tools 00/10 combatibility - OK. Set 2-3/8" Combi pipe/slips. Pushlpull test and confirm slips are holding. Close manual lock on BOP. PJSM on coil cutting operations. Strip injector up off well. Install false table, dog collar & C-plate. Apply chain tension on injector. Install hot-tap. Hot-tap & drain coil. R/U hydraulic cutter. Crew change out PJSM covering steps leading up to SWS tool installation point. Continue draining coil from hot tapping. Continue to drain coil. Cut coil and dress both ends. Make up CTC both ends. Install BIT XO's and TIW valve, SWS pump-in sub. (-10'KB) Install valve on reel side circ 5 bbls methanol through coil. Set injector on deck. Wait on scaffolding crew. RIU slings and elevators. Set up 6' scaffolding. PJSM covering mlu of SWS surface equipment and handling the cutting tool. M/U SWS surface equipment. PIU chemical cutter stab into CT. Notice Baker TIW leaking through valve stem. Change out TIW valve PIU SWS chemical cutter. Install flow tube assembly. P/U to 25K. Open manual locks on pipe/slips rams and open rams, open annular. PIU to 62K (5K over string wt) and put CT in tension. Correct log depth. RIH with chemical cutter. Estimate top of CTC +1- 10751'. Pump down starting at 9800' at 1.3 bpm @ 780 psi Tagged up at CTC 10750' PP up to 1800 psi. Shutdown pumps. PIU l' secure drill floor. Fire cutter. Lost +1- 10k on weight indicator. Appears to be good cut. Unable to PIU on cutter, dogs appear to be still engaged. Working e-line tryed pumping down CT at 1-1.5 bpm, no success. PIU to 10682' with 3500 Ibs max pull. PIU CT by 2' to see if anchors would retract - no luck. Review options with town & decide to pump crude into CT to reduce drag & possibly pull out chem cutter or snap eline socket. Line-up to pump crude down CT. Pump 42 bbls of crude down CT. Work eline to 3500 Ibs max pull, no success. Line-up to reverse circulate out crude from CT. Maintain eline in tension with 22001bs. Dump 800psi CT pressure & observe eline pull free. POOH eline with chemical cutter taking U-tubed returns to the tigger tank. Continue POOH eline with chemical cutter to 200'. Reverse circulate and swap CT to KCL water. PJSM on LID chemical cutter. Set 2-3/8" Combi pipe/slips. Pushlpull test OK. Close manual lock on BOP. Set dog collar on CT. Break off flow tube assembly and LID chemical cutter - Observe anchor dogs fully retracted with nothing amiss. RID SWS sheaves, flow tube, pump in sub & X/Os. Suspend CT on blocks. RID slings & clear Printed: 1/14/2002 10:16:10AM ( ,f BP EXPLORATION Operations Summary Report Page 12 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-05B K-05B REENTER+COMPLETE NABORS NABORS 3S Spud Date: 11/4/2001 End: Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Date From-To Hours Activity Code NPT Phase Description of Operations 1/4/2002 00:45 - 03:30 03:30 - 05:00 DFAL COMP RREP COMP floor. Observe well - static. Observe 2-3/8" Combi pipelslips not holding. Close VBR & change out 2-3/8" Combi pipe/slips. Pltest Combi pipe/slips to 500 psi. RIU floor for spooling cut CT. PIU injector onto floor. Crew change. PJSM review operational plans for attachment of CT spoolable connector. Alert Peak and Schl. of upcoming plans for changing out CT spools on location. Dress CT on reel-side fl CTC. ( Swedged back to 2.375", CT was slightly egged) PJSM again to review installation procedure. Start CTC into CT then setdown with injector weight to fully slip connector into CT. Dress well-side CT. PJSM. Stab spoolable CTC onto well-side. Make-up 2 rds clockwise. Pull test 3600 Ibs (max allowable with total trolly weight). Retorque CTC 1/4 rd. Flag CTC. Remove scaffolding from rig floor. Slowly lower injector allowing CTC to engage with injector chains. Remove dog collar, slips, etc. Stab injector onto well. Take up tension on CT prior to opening pipelslip rams. Hydraulic hose parted on injector. Stop and inspect injector. Leak on middle skate hyd cylinder. Locked in upper middle and lower hyd cylinders. Will observe while POH. Reapply tension to string 47k. Unlock manuals on pipelslip rams. Notify and clear all personnel from coil area. Open combi rams. Start spooling on CTC..no problems, continue POH to 200'. Tryed pumping methanol to coil while POH but ambient air temp is so cold, water from the well was freezing on coil causing a dangerous condition with coil brakes. Switch to water while POH. Called AOGCC gave notice of BOP test within 4-6 hrs. Witnessing wavied by Lou Grimaldi. Will test while swicthing out coil reels. Freeze protect coil at 200'. Continue POH checking for EOP each 15' at master valve. Rig up to blowdown coil w/N2. Pressure test N2 lines to 3500 psi. Purge coil with N2. RID N2 unit. Crew change. PJSM. Review operational plans for changing out CT spools on location and BOP testing. RIB injector & T-bar up. Unstab pipe. Prep for reel swap. Meanwhile install TWCV & grease valves in readiness for BOP testing. PJSM on use of cranes with ambient temp of @-33F, 13mph wind & +1-70F WC. PIU reel out of coil cab & install into spare trailer. Meanwhile BOP testing. PIU new reel & install into coil cab. Meanwhile BOP testing. VBR & 2-3/8" Combi pipelslips leaking. Continue testing other BOPE components. Will openup bonnets to inspectlchangeout rams & retest later. RIU hoses & hardlines to new CT reel. Continue BOP testing. 05:00 - 05:30 05:30 - 06:00 06:00 - 06:45 0.50 RUNCO 0.50 RUNCO 0.75 RUNCO DFAL COMP DFAL COMP DFAL COMP 06:45 - 08:00 DFAL COMP 08:00 - 08:15 DFAL COMP 08:15 - 09:15 09:15 -10:45 DFAL COMP DFAL COMP 10:45 - 11 :05 0.33 RUNCO DFAL COMP 11:05-15:15 4.17 RUNCO DFAL COMP 15:15 - 15:45 15:45 -16:10 16:10 - 18:30 0.50 RUNCO 0.42 RUNCO 2.33 RUNCO DFAL COMP DFAL COMP DFAL COMP 18:30 -19:00 DFAL COMP 19:00 - 22:40 DFAL COMP 22:40 - 23:00 DFAL COMP 23:00 - 00:00 DFAL COMP 1/5/2002 00:00 - 01 :45 DFAL COMP 01 :45 - 04:00 DFAL COMP Printed: 1/14/2002 10:16:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date (II BP EXPLORATION Operations Summary Report K-05B K-05B REENTER+COMPLETE NABORS NABORS 3S 1/5/2002 04:00 - 06:00 From - To Hours Activity Code NPT DFAL COMP 06:00 - 06:45 06:45 - 11 :00 11 :00 - 11 :30 11 :30 - 12:00 12:00 -18:30 18:30 -19:00 19:00 - 22:30 22:30 - 00:00 2.00 RUNCO Phase DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL caMP DFAL COMP 1/6/2002 00:00 - 00:20 0.33 RUNCO DFAL COMP 00:20 - 01:15 0.92 RUNCO DFAL COMP 01:15 - 02:00 0.75 RUNCO DFAL COMP 02:00 - 03:30 1.50 RUNCO DFAL COMP 03:30 - 05:15 DFAL COMP 05:15 - 06:00 06:00 - 08:05 08:05 - 09:25 09:25 - 12:15 12:15 - 13:00 0.75 RUNCO 4.25 RUNCO 0.50 RUNCO 0.50 RUNCO 6.50 RUNCO 2.83 RUNCO 0.75 RUNCO DFAL COMP DFAL COMP DFAL COMP DFAL COMP DFAL COMP Page 13 of 14 Start: 12/22/2001 Rig Release: 1/7/2002 Rig Number: Spud Date: 11/4/2001 End: Description of Operations Continue testing BOPE. Open up Combi bonnet-wrong size rams. Crew change out. PJSM cold weather working. Review testing still required on BOP stack and work to be done on CT reel. Current weather conditions at location: -35* with 5-10 mph winds. All major outside work basically shutdown due to weather Continue testing BOPE. Opening VBR bonnets, inspect-repair and retest. Watching weather. Make repairs to coil units level wind system. Pull TWC. PJSM. Prepare to stab coil to injector. Weather concerns. Make attempt to stab pipe to injector. Lifting frame hydraulic cylinders starting to drip hydraulic fluid. Tarped the injector to warm up with Tioga heater. Temps still-37 with 5-10 mph winds. WOO Crew change safety meeting concerning weather and stabbing coil to injector. Present conditions at camp: -36F winds 5-12 mph winds slightly higher at injector area. Warm-up injector & stab-in pipe ensuring personnel catch some warmth every 15 minutes. Changeout stripper packoff & MIU stripper to injector. M/U Baker slip-on CTC & pull test - OK. M/U XIO (ball catcher). Drill bleed hole in CT. Remove 5" lubricator. Stab onto well. Inspect injector chains - OK. Prep to pump ball thru CT. DS pump too cold. Warm-up pump. Pump 3 bbls methanol ahead. Drop 1-318" ball & chase with 55.9bbls methanol thru CT. Cut off CTC & MIU new Baker slip-on CTC. Pull test to 35k & Pltest to 3500psi - OK. MIU fishing BHA with packoff overshot dressed with 2-3/8" basket grapple. Displace out FP MeOH to tigger tank. Frozen backside lines. RIH. Same time crew change. PJSM. Unthawing backside lines. Fish-in-hole bottom to top: CTLRT, XO, 1 jt PH-6, xo, Hyd Disc, Swivel, CTC, CT stub Weight check at 10620' 44k up 19k down. RIH tagged at 10746' setdown and plu 50k confirm latch with overshot. Start jarring down. This to release running tool. Jar 36 times without success. Jar up increasing plu to 30k over and came free. Appears KB packer is moving, still some drag. Jar down once more then up and came free again. this time no drag. Set down again then plu no drag or overpull. TOH LID fish. Retrieved: CT stub, CTC, 1/2 of Hyd Disconnect, 1- 3/4" and 1- 7/8" ball. Appears that at some point prior to dropping the 7/8" ball, the disconnect plunger had shifted down expossing the circulation ports. This prevented a seal on the 7/8" seat. The seat and ball had severe fluid errosion. Further proof that no fluid went past the disconnect was the 3/4" ball. We found it setting on some o-ring debris inside the plunger. Another oilfield mystery with the 3/4" ball. Printed: 1/14/2002 10:16:10 AM , BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: K-05B Common Well Name: K-05B Spud Date: 11/4/2001 Event Name: REENTER+COMPLETE Start: 12/22/2001 End: Contractor Name: NABORS Rig Release: 1/7/2002 Rig Name: NABORS 3S Rig Number: ..., Date From - To Hours Activity Code NPT Phase Pe$cription. of Operations " 1/6/2002 13:00 - 14:30 1.50 RUNCO~ /J.J DFAL COMP Discuss options. Running with GH. Should be able to latch on and pressure up CTLRT to release. 14:30 - 16:30 2.00 RUNCO~ N DFAL COMP TIH wi BHA #14 16:30 - 16:45 0.25 RUNCO~ N DFAL COMP Check plu wt at 10652' 44k run-in 19k. RIH tag-up at 10746' setdown 5k. PIU to to 50k confirm latch-in. Pump up to 3700 psi and release CTLRT. P/U to 49k and slacked off to 44k. Appears we have the CTLRT. 16:45 - 17:00 0.25 RUNCO~ N DFAL COMP Circulate at 2bpm/2000psi no returns. 17:00 -19:45 2.75 RUNCO~ P COMP TOH pumping 1 bpm down CT and across top. 19:45 - 20:45 1.00 RUNCO~ P COMP OOH with BHA & fish (1/2 of Hyd Disconnect, X/O, PH6 Tbg, X/O & Rltool w/3/4" & 518" balls). Close MV, put-on tree cap & circ CT. UD fish. 20:45 - 22:00 1.25 RUNCO~ P COMP Clear floor & prep to RIH perf guns. As well is on vacuum, weld-on non-sealable 3-3/8" OD no-90s on btm bullnose of 2-7/8" gun assy to prevent suck-wedging into the KB pkr top. 22:00 - 23:00 1.00 RUNCOI\ P COMP Open MV & fill-up hole with 106 bbls KCL water. Hole sucking @ 1.5bpm. SIB injector. Freeze protect CT. Keep hole full by pumping across the wellhead. 23:00 - 23:15 0.25 PERF P COMP Pre-job safety meeting with SWS. Review perf job. 23:15 - 00:00 0.75 PERF P COMP RIU handling tools & start PIU SWS 2-7/8" powerjet, 4spf, 60 degs phasing guns. Meanwhile fill-up hole by pumping across the wellhead. 1/7/2002 00:00 - 01 :30 1.50 PERF P COMP Continue PIU 28 jts of SWS 2-7/8" powerjet, 4spf, 60 degs phasing perforating guns for perforating from 10130'-10700'. M/U 1 jt 2-3/8" DC. 01 :30 - 02:00 0.50 PERF P COMP Set 2-3/8" Combi pipe/slips. Rack out injector. MU & P/test MHA to 3500 psi - OK. 02:00 - 03:30 1.50 PERF P COMP Displace out FP MeOH with KCL water to tigger tank & further circulate CT till out temp of 60 degs. M/U CT to gun assy. 03:30 - 05:30 2.00 PERF P COMP RIH with perf guns. Check up checks @ 5400'/30k; 9000'/47k; 10500'/48k; 10784'/48k. Tag KB Pkr top @ 10788'. P/U free wt & correct depth to 1 0792'. 05:30 - 06:00 0.50 PERF P COMP PUH & position for btm shot @ 10700'. Launch & chase 5/8" steel ball with KCL water. Ball on seat after 44bbls away & gun~ fired @ 1850 psi with good indications. Continue displacing to CT vol of 54bbls to confirm guns firing. Guns are 2 7/8" Powerjet, 4SPF, 60 deg phasing. Perf interval 10130' - 10700' 06:00 - 08:30 2.50 PERF P COMP POOH with 2-7/8" perforating guns. (Crew change PJSM review plans for today.) TOH to 970'. 08:30 - 09:30 1.00 PERF P COMP Freeze protect coil. 09:30 - 09:45 0.25 PERF P COMP TOH to BHA. 09:45-10:15 0.50 PERF P COMP Set back injector to deck. 10:15 -12:30 2.25 PERF P COMP UD 2 7/8" perf guns. All shots fired. 12:30 -13:10 0.67 PERF P COMP Bullhead 30 bbls neet methanol in wellbore. Well on vacuum. 13:10 - 13:40 0.50 PERF P COMP Set BPV. 13:40 - 18:00 4.33 DEMOB P COMP Rig down CTU #4, knock down and vacuum out backside lines. Clear floor of Baker handling tools. (Sent all bck in for inspection). 18:00 - 20:30 2.50 DEMOB P COMP NID BOPE. Empty rig & outside tanks. RID hardlines. Install tree cap & test to 4000psi. Nabors 3S released at 20:30 hrs on 1-7-2002. Last report! ( -..... :,- Printed: 1/14/2002 10:16:10 AM Client. """".". ......: BP Exploration Inc. Field....................: Prudhoe Bay Well.....................: K-05b API number... ............: 50-029-21418-02 Engineer.................: E. ROUX RIG:.....................: Nabors 3S STATE:...................: ALASKA ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: GR Tie-in @ 9610 ft GL above permanent.......: 0.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: ANADRILL SCHLUMBERGER Survey report 184.66 degrees [(c)2001 Anadrill IDEAL ID6_1C_10J 29-Dec-200115:19:05 Spud date................: Last survey date.. .......: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 2 26-DEC-01 29-Dec-01 21 10837.25 ft 11752.00 ft (...._- ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2000 Magnetic date............: 26-Dec-2001 Magnetic field strength..: 1149.80 HCNT Magnetic dec (+E/W-).....: 26.55 degrees Magnetic dip.............: 80.82 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H.............. : Dip. . . . . . . . . . . . : of G........... : of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.80 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ( ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.54 degrees (Total az carr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 29-Dec-2001 15:19:05 Page 2 of 2 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 10837.25 86.56 195.20 0.00 8784.47 4449.97 -4332.62 -1619.66 4625.46 200.50 0.00 TIP 2 10904.54 85.95 195.47 67.29 8788.87 4515.96 -4397.38 -1637.41 4692.34 200.42 0.99 SP 3 10944.57 81.98 192.09 40.03 8793:08 4555.25 -4436.03 -1646.89 4731.87 200.37 13.00 SP 4 10983.50 80.98 186.57 38.93 8798.85 4593.60 -4474.00 -1653.13 4769.65 200.28 14.25 MWD 5 11014.71 86.75 184.94 31.21 8802.19 4624.62 -4504.86 -1656.24 4799.68 200.19 19.20 SP 6 11047.50 92.26 173.64 32.79 8802.47 4657.19 -4537.58 -1655.83 4830.26 200.05 38.33 MWD {---- .. 7 11084.26 96.05 168.31 36.76 8799.81 4692.80 -4573.77 -1650.09 4862.32 199.84 17.76 SP 8 11139.51 88.85 158.54 55.25 8797.44 4744.15 -4626.57 -1634.36 4906.76 199.46 21.94 SP 9 11194.58 80.43 164.04 55.07 8802.58 4794.41 -4678.43 -1616.78 4949.92 199.06 18.23 SP 10 11254.00 85.88 173.58 59.42 8809.68 4851.08 -4736.22 -1605.37 5000.90 198.72 18.39 MWD 11 11314.59 92.38 189.82 60.59 8810.61 4911.34 -4796.54 -1607.17 5058.64 198.52 28.84 SP 12 11379.66 86.43 198.79 65.07 8811.28 4975.40 -4859.50 -1623.21 5123.44 198.47 16.55 SP 13 11434.71 86.70 195.19 55.05 8814.58 5029.07 -4912.05 -1639.27 5178.36 198.46 6.55 SP 14 11474.69 88.25 188.42 39.98 8816.35 5068.68 -4951.12 -1647.43 5218.01 198.40 17.38 SP 15 11524.95 88.13 190.49 50.26 8817.93 5118.74 -5000.67 -1655.67 5267.63 198.32 4.14 SP 16 11554.00 87.02 190.68 29.05 8819.16 5147.61 -5029.20 -1661.01 5296.40 198.28 3.88 MWD 17 11584.73 81.08 193.19 30.73 8822.35 5177.91 -5059.09 -1667.32 5326.76 198.24 21.00 SP 18 11625.23 75.45 193.82 40.50 8830.59 5217.08 -5097.63 -1676.57 5366.26 198.21 13.96 SP 19 11664.83 68.91 192.59 39.60 8842.70 5254.34 -5134.31 -1685.18 5403.80 198.17 16.77 SP 6-axis 20 11684.36 65.63 193.89 19.53 8850.25 5272.15 -5151.84 -1689.30 5421.74 198.15 17.93 SP 21 11752.00 54.52 198.82 67.64 8883.96 5329.46 -5208.02 -1705.64 5480.21 198.13 17.58 Projected to TD ( [(c)2001 Anadrill IDEAL ID6_1C_10J Client. . . . . . . . . . . . . . . . . . .: BP Exploration Inc. Field....................: Prudhoe Bay Well.....................: K-05b PB-1 API number............. ..: 50-029-21418-02 Engineer...... ........ ...: E. Roux RIG:.....................: Nabors 3S STATE:.............. .....: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS........ ...: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference..........: GR Tie-in @ 9610 ft GL above permanent.......: 0.00 ft KB above permanent.. .....: -50000.00 ft DF above permanent..... ..: -50000.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft ANADRILL SCHLUMBERGER Survey report Azimuth from rotary table to target: 184.664 degrees [(c)2001 Anadrill IDEAL ID6_1C_10] 26-Dec-200116:24:37 Page 1 of 2 Spud date.... ..... .......: 23-Dec-01 Last survey date....... ..: 26-Dec-01 Total accepted surveys...: 11 MD of first survey.......: 10837.25 ft MD of last survey........: 11350.00 ft (~----- ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2000 Magnetic date............: 22-Dec-2001 Magnetic field strength..: 1149.80 HCNT Magnetic dec (+E/W-) .....: 26.53 degrees Magnetic dip.............: 80.82 degrees ----- MWD survey Reference Reference G.... .... ......: Reference H... ...... .....: Reference Dip.. ..........: Tolerance of G...........: Tolerance of H........ ...: Tolerance of Dip... ......: Criteria --------- 1002.68 mGal 1149.80 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.53 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 26.53 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ( ANADRILL SCHLUMBERGER Survey Report 26-Dec-2001 16:24:37 Page 2 of 2 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Az im (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 10837.25 86.56 195.20 0.00 8784.47 4449.88 -4332.62 -1619.66 4625.46 200.50 0.00 TIP 2 10942.30 90.13 193.06 105.05 8787.50 4553.44 -4434.43 -1645.28 4729.81 200.36 3.97 SP 3 10983.83 91.20 190.02 41.53 8787.02 4594.66 -4475.11 -1653.58 4770.85 200.28 7.74 MWD 5-axis 4 11022.52 87.75 187.26 38.69 8787.38 4633.25 -4513.35 -1659.39 4808.73 200.19 11.42 SP 5 11076.00 86.81 185.27 53.48 8789.91 4686.64 -4566.45 -1665.22 4860.60 200.04 4.11 MWD 6 11113.00 86.32 187.91 37.00 8792.13 4723.55 -4603.14 -1669.46 4896.52 199.93 7.24 MWD Ç..---- 7 11175.42 86.85 186.96 62.42 8795.85 4785.79 -4664.92 -1677.52 4957.37 199.78 1.74 SP 8 11215.00 87.39 186.01 39.58 8797.84 4825.29 -4704.20 -1681.99 4995.85 199.67 2.76 MWD 9 11271.50 88.63 181.66 56.50 8799.80 4881.74 -4760.52 -1685.76 5050.18 199.50 8.00 MWD 10 11319.95 87.43 178.91 48.45 8801.47 4930.01 -4808.94 -1686.00 5095.93 199.32 6.19 SP 11 11350.00 88.33 177.35 30.05 8802.58 4959.85 -4838.95 -1685.02 5123.94 199.20 5.99 MWD Projected [(c)2001 Anadrill IDEAL ID6_1C_l0] ( ( ( ~~ ~.. ."Ô""'r:Q"""'" ' ", " ",',,' Pi', ", , ,', ,,'",' ""1,"..",;"",,,;,,1<; .,-', ' ",", -",'- -I'^"'i',""'ë '..,-,:)",,'~i 'I'; ,è:~" ':\1',' ' _:- ,,' " 17 -Jan-O2 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Surveys for the sperry sun section of K-O5B PB 1 Re: Distribution of Survey Data for Well K-058 P81 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,399.36' MD Window / Kickoff Survey 7,410.00' MD Projected Survey: 10,900.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED JAN 2 i: 2002 William T. Allen Survey Manager Alaska Oil & Gas Cons. Commission Anchorage Attachment(s) 4M ú. old / cl~(! Ie cI i'~ /(- (J.f ß f/'{' J I c/ Jf ¡f J aM. c¿ r is) ID [,'11 ( North Slope Alaska Alaska Drilling & Wells PBU- WOA K Pad, Slot K-O5 K-O5BPB 1 Sperry Section Job No. AKMM11182, Surveyed: 23 November, 2001 SURVEY REPORT 18 January, 2002 \ Your Ref: API 500292141870 Surface Coordinates: 5975268.00 N, 670710.00 E (70020' 18.0679" N, 148036' 53.1040" W) Surface Coordinates relative to Project H Reference: 975268.00 N, 170710.00 E (Grid) Surface Coordinates relative to Structure Reference: 2096.62 N, 415.18 E (True) Kelly Bushing: 55.03ft above Mean Sea Level spa"""""y-5Ui1 DFI.L,;;L.~~ A Halliburton Company Survey Ref: svy11O40 Sperry-Sun Drilling Services . Survey Report for K-05BPB1 Sperry Section Your Ref: AP/500292141870 Job No. AKMM11182, Surveyed: 23 November, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7399,36 30.800 191.830 6618.49 6673.52 2813.92 S 496.33 W 5972443.51 N 670277.86 E 2814.23 Tie On Point MWD Magnetic 7410.00 30.720 191.890 6627.63 6682.66 2819.24 S 497.45 W 5972438.16 N 670276.87 E 0.805 2819.62 Window Point 7477.13 28.800 201.560 6685.94 6740.97 2851.08 S 506.93 W 5972406.12 N 670268.11 E 7.692 2852.78 ( 7541.70 24,340 213.150 6743.71 6798.74 2876.72 S 519.93 W 5972380.19 N 670255.69 E 10.563 2881.32 7570.61 23.670 219.080 6770.13 6825.16 2886.21 S 526.85 W 5972370.54 N 670248.99 E 8.657 2892.60 7635.12 22.210 233.570 6829.58 6884.61 2903.52 S 544.84 W 5972352.83 N 670231 .40 E 9.019 2915.01 7663.94 21.780 242.000 6856.31 6911.34 2909.27 S 553.95 W 5972346.88 N 670222.43 E 11.047 2923.53 7698.31 21 .190 250.810 6888.30 6943.33 2914.30 S 565.45 W 5972341.58 N 670211.05 E 9.535 2932.19 7729.22 20.880 256.380 6917.15 6972.18 2917.44 S 576.08 W 5972338.20 N 670200.49 E 6.543 2938.76 7757.91 20.750 254.940 6943.97 6999.00 2919.96 S 585.95 W 5972335.46 N 670190.68 E 1.840 2944.51 7850.73 20.280 256.060 7030.90 7085.93 2928.11 S 617.44 W 5972326.59 N 670159.38 E 0.660 2962.92 7945.42 19.110 257.570 7120.05 7175.08 2935.40 S 648.51 W 5972318.60 N 670128.49 E 1.347 2980.38 8037.92 17.760 253.900 7207.81 7262.84 2942.57 S 676.85 W 597231 0.78 N 670100.32 E 1.924 2996.80 8130.41 19.100 245.160 7295.57 7350.60 2952.84 S 704.14 W 5972299.89 N 670073.26 E 3.316 3015.78 8224.52 19.590 244.150 7384.37 7439.40 2966.19 S 732.31 W 5972285.91 N 670045.40 E 0.630 3037.94 8319.54 21.630 245.560 7473.30 7528.33 2980.38 S 762.60 W 5972271.03 N 670015.45 E 2.209 3061.62 8412.93 21.100 245.450 7560.27 7615.30 2994.49 S 793.56 W 5972256.22 N 669984.82 E 0.569 3085.46 8505.78 20,040 245,050 7647.20 7702.23 3008.14 S 823.18 W 5972241.90 N 669955.51 E 1.152 3108.41 8595.36 22.000 246.940 7730.82 7785.85 3021.19 S 852.54 W 5972228.18 N 669926.46 E 2.315 3130.70 -' 8691.59 22.060 247.440 7820.02 7875.05 3035.18 S 885.81 W 5972213.44 N 669893.52 E 0.205 3155.21 \ 8786.05 21 .160 247.630 7907.84 7962.87 3048.48 S 917.96 W 5972199.41 N 669861.68 E 0.956 3178.69 8880.18 20.270 246.880 7995.89 8050.92 3061.35 S 948.67 W 5972185.85 N 669831.27 E 0.987 3201.27 8973.35 19.630 245.770 8083.46 8138.49 3074.11 S 977.78 W 5972172.43 N 669802.46 E 0.798 3223.21 9067.06 19.210 246.710 8171.84 8226.87 3086.66 S 1006.30 W 5972159.23 N 669774.23 E 0.559 3244.75 9124,00 18.950 245.640 8225.65 8280.68 3094.18 S 1023.32 W 5972151.32 N 669757.38 E 0.765 3257.63 9181.51 18.710 244.550 8280.09 8335.12 3102.00 S 1040.16 W 5972143.13 N 669740.73 E 0.741 3270.72 9275.21 17.570 245.340 8369.13 8424.16 3114.35 S 1066.58 W 5972130.17 N 669714.59 E 1.245 3291.36 9340.31 18.650 240.450 8431.01 8486.04 3123.59 S 1084.57 W 5972120.53 N 669696.82 E 2.863 3306.18 9369.07 22.640 234.590 8457.92 8512.95 3129.07 S 1093.09 W 5972114.86 N 669688.43 E 15.607 3314.24 9403.34 26.260 234.470 8489.11 8544.14 3137.30 S 1104.64 W 5972106.37 N 669677.07 E 10.564 3325.92 , --'- .....-..-,' ..--".,- .--..""-"'--"'--"" -----.-...........--,.." ,-_.., , ""-...." --""'--"""'-"""'-"""""""'-'--""----'-....,....-- 18 January, 2002 -- 1:55 Page 2 of 5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for K-05BPB1 Sperry Section Your Ref: AP/500292141870 Job No. AKMM11182, Surveyed: 23 November, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9434.48 30.050 232.030 8516.56 8571.59 3146.108 1116.39 W 5972097.30 N 669665.52 E 12.718 3338.21 9463_29 31.830 230.880 8541 .27 8596.30 3155.338 1127.97 W 5972087.80 N 669654.15 E 6.510 3350.84 9496.79 35,920 228.770 8569.08 8624.11 3167.398 1142.22 W 5972075.43 N 669640.18 E 12.702 3367.04 9528.29 37.670 226.590 8594.30 8649.33 3180.098 1156.17 W 5972062.41 N 669626.53 E 6.931 3383.74 f 9557.46 39.440 226.490 8617.11 8672.14 3192.608 1169.36 W 5972049.61 N 669613.62 E 6.072 3400.00 9591.11 44.560 220.270 8642.12 8697.15 3208.98 S 1184.76 W 5972032.87 N 669598.60 E 19.594 3420.66 9622.64 50.240 219.250 8663.46 8718.49 3226.82 S 1199.59 W 5972014.70 N 669584.18 E 18.171 3442.50 9651.62 54.370 216.070 8681.18 8736.21 3244.98 S 1213.58 W 5971996.23 N 669570.61 E 16.685 3464.34 9684.92 57.570 210.730 8699.82 8754.85 3268.02 8 1228.74 W 5971972.86 N 669555.97 E 16.396 3491.17 9715.97 61.780 208.040 8715.49 8770.52 3291.37 S 1241.88 W 5971949.21 N 669543.37 E 15.483 3517.60 9743,09 65.260 206.390 8727.58 8782.61 3312.958 1252.97 W 5971927.38 N 669532.77 E 13.939 3541.68 9776,62 68.720 204.360 8740.69 8795.72 3340.84 8 1266.19 W 5971899.20 N 669520.20 E 11.727 3572.40 9808.06 '12.940 204.800 8751.01 8806.04 3367.83 8 1278.54 W 5971871.93 N 669508.46 E 13.487 3601.99 9835.5"7 74.390 204.810 8758.75 8813.78 3391.80 S 1289.62 W 5971847.72 N 669497.94 E 5.271 3628.29 9870.05 78.030 203.640 8766.97 8822.00 3422.33 S 1303.35 W 5971816.88 N 669484.90 E 11.059 3661.68 9904.34 83.410 204.710 8772.49 8827.52 3453.19 S 1317.21W 5971785.72 N 669471.75 E 15.989 3695.42 9941.94 89.080 204.010 8774.96 8829.99 3487.36 S 1332.68 W 5971751.21 N 669457.06 E 15.194 3732.81 9968.60 90.250 203.020 8775.11 8830.14 3511.80S 1343.31 W 5971726.53 N 669446.99 E 5.749 3759.42 9997.33 93_950 202.750 8774.06 8829.09 3538.25 8 1354.48 W 5971699.83 N 669436.43 E 12.913 3788.09 10030.33 97.280 201.910 8770.83 8825.86 3568.62 8 1366.95 W 5971669.18 N 669424.65 E 10.404 3820.90 ~ 10061.95 98,520 201.480 8766.48 8821.51 3597.728 1378.53 W 5971639.83 N 669413.73 E 4.146 3852.20 10090.40 97.100 201.010 8762.62 8817.65 3623.998 1388.74 W 5971613.33 N 669404.12 E 5.253 3880.38 10123.52 96,780 199.640 8758.62 8813.65 3654.82 8 1400.16 W 5971582.25 N 669393.41 E 4.218 3913.26 10155.18 93.440 198.600 8755.80 8810.83 3684.61 8 1410.49 W 5971552.23 N 669383.76 E 11.045 3944.78 10183.99 91.660 198.290 8754.52 8809.55 3711.91 8 1419.59 W 5971524.73 N 669375.28 E 6.271 3973.55 1 021"1.:m B9.260 199.940 8754.25 8809.28 3743.478 1430.53 W 5971492.94 N 669365.06 E 8.720 4006.94 10276.52 87 -530 199.480 8755.90 8810.93 3799.11 8 1450.46 W 5971436.85 N 669346.40 E 3.027 4066.05 10369.88 84.770 198.920 8762.17 8817.20 3887.07 S 1481.10W 5971348.22 N 669317.78 E 3.016 4159.18 10414.19 84.700 198.670 8766.24 8821.27 3928.84 8 1495.31 W 5971306.14 N 669304.52 E 0.584 4203.29 10463.28 85.000 198.020 8770.64 8825.67 3975.24 8 1510.70 W 5971259.39 N 669290.19 E 1.453 4252.17 '" """,,-.._-,...----_.. --------...,----....-.-.........-"-....-..",.",,---....,, ""-"""-"'-"--'----"-"""""-"----"""""""'-"""'-""""""'---,...-..""-'--"-,,---,, 18 January, 2002 - 1:55 Page 3 of 5 DrillQuest 2.00.09.003 North Slope Alaska Measured Depth (ft) f 10555.24 10602.42 10651.01 10697.41 10744.64 10779.43 10837.25 10900.00 Incl. 88.280 88.460 88.830 89.200 89,020 87,050 86.560 86.560 Azim. 196.290 196.690 197.390 197.890 197.050 196.810 195.200 195.200 Sub-Sea Depth (ft) 8776.03 8777.38 8778.52 8779.32 8780.06 8781.25 8784.4 7 8788.24 Vertical Depth (ft) 8831.06 8832.41 8833.55 8834.35 8835.09 8836.28 8839.50 8843.27 Sperry-Sun Drilling Services Survey Report for K-05BPB1 Sperry Section Your Ref: AP/500292141870 Job No. AKMM11182, Surveyed: 23 November, 2001 Local Coordinates Northlngs Eastlngs (ft) (ft) 4062.95 S 4108.17 S 4154.61 S 4198.82 S 4243.87 S 4277.13 S 4332.62 S 4393.07 S 1537.77 W 1551.16 W 1565.39 W 1579.45 W 1593.63 W 1603.75 W 1619.67 W 1636.09 W All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.573° (1 0-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 199.970° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10900.00ft., The Bottom Hole Displacement is 4687.84f1., in the Direction of 200.427° (True). \ 18 January, 2002 - 1:55 n' ." ""--'----"'-""--.....--- Global Coordinates Northlngs Eastings (ft) (ft) 5971171.10 N 5971125.58 N 5971078.83 N 5971034.31 N 5970988.95 N 5970955.47 N 5970899.63 N 5970838.82 N Page 4 of 5 669265.13 E 669252.77 E 669239.60 E 669226.55 E 669213.40 E 669204.04 E 669189.39 E 669174.35 E Dogleg Rate (a/100ft) 4.031 0.929 1.629 1.340 1.819 5.704 2.906 0.000 Vertical Section 4343.84 4390.91 4439.43 4485.78 4532.96 4567.68 4625.27 4687.69 .., ,~ Alaska Drilling & Wells PBU_WOA K Pad Comment Projected Survey for the sperry SUI section of PB 1 Anadrill Drilled the rest of PB 1 '----"---'-"""-"'--'--"'-""""'-""--" .... --...--..... . ----"".....,......."...., --"-"'---"""---'----..-.....-...-"-'-"-"-""",-,- DrillQuest 2.00.09.003 ," , ' . North Slope Alaska Comments Measured Depth (ft) f- - 7399,36 7410.00 10900.00 Sperry-Sun Drilling Services Survey Report for K-05BPB1 Sperry Section Your Ref: API 500292141870 Job No. AKMM11182, Surveyed: 23 November, 2001 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 6673.52 6682.66 8843.27 2813.92 S 2819.24 S 4393.07 S Survey tool program for K-05BPB1 Sperry Section Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 7399.36 \ 18 January, 2002 - 1:55 0.00 6673.52 To Measured Vertical Depth Depth (ft) (ft) 7399.36 10900.00 6673.52 8843.27 Comment 496.33 W 497.45 W 1636.09 W Tie On Point Window Point Projected Survey for the sperry sun section of PB 1 Anadrill Drilled the rest of PB 1 Survey Tool Description AK-1 BP _HG - BP High Accuracy Gyro (K-05) MWD Magnetic (K-05BPB1 Sperry Section) ,." ,....., ,..--...-....-,......-.--.."---- ---,--,----.-..-....-"...-".., ....._".....,. Page 5 of 5 . Alaska Drilling & Wells PBU_WOA K Pad ...-. "",..--'" .....---..........,.....-...--....,..,....,.. DrillQuest 2.00.09.003 ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Reshipment of Disks Re: Distribution of Survey Data for Well K-05& 6 ./" Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,399.36' MD Window / Kickoff Survey 7,410.00' MD Projected Survey: 10,900.00' MD (if applicable) ( Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ aO J--;)Olp 18-Dec-01 RE(~EIVED DEe 2 8 2001 Alaska OH & Gas Cons, {;OmmISSlfJ¡ ,AncÞorag€' ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well K-058 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,399.36' MD Window / Kickoff Survey 7,410.00' MD Projected Survey: 10,900.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns, Regards, Carl Ulrich Survey Manager Attachment(s) a\":','/'1)t.,L"8l" oto : "i',' ,I :,\,;.;;1"""" ,:'. ,"", ,', , ",;,..1" """"";""":",!,"" ,",', 1,1: ~, 11-Dec-01 R.ECEIVED [J[:C '1 ,.~ 2001 Aiaska Oil 8: Gas Cons. Commission AncÞr.orage DEFINITIVE , \.._- North Slope Alaska Alaska Drilling & Wells PBU_WOA K Pad, Slot K-O5 K-O5B Job No. AKMM11182, Surveyed: 23 November, 2001 (- SURVEY REPORT 10 December, 2001 Your Ref: AP/500292141802 Surface Coordinates: 5975268.00 N, 670710.00 E (70° 20' 18.0679" N, 148036' 53.1040" W) Kelly Bushing: 55.03ft above Mean Sea Level "- "'- ( E5p.""':J-!5U" DAIL-LIN,G SERVIc:es A Halliburton Company Survey Ref: svy11040 Sperry-Sun Drilling Services . Survey Report for K-O5B Your Ref: AP/500292141802 DEFINITIVE Job No. AKMM11182, Surveyed: 23 November, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs ' Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7399.36 30.800 191.830 6618.49 6673.52 2813.92 S 496.33 W 5972443.51 N 670277.86 E 2814.23 Tie On Point MWD Magnetic (' 7410.00 30.720 191.890 6627.63 6682.66 2819.24 S 497.45 W 5972438.16 N 670276.87 E 0.805 2819.62 Window Point 7477.13 28.800 201.560 6685.94 6740.97 2851.08 S 506.93 W 5972406.12 N 670268.11 E 7.692 2852.78 7541.70 24.340 213.150 6743.71 6798.74 2876.72 S 519.93 W 5972380.19 N 670255.69 E 10.563 2881.32 7570.61 23.670 219.080 6770.13 6825.16 2886.21 S 526.85 W 5972370.54 N 670248.99 E 8.657 2892.60 7635.12 22.210 233.570 6829.58 6884.61 2903.52 S 544.84 W 5972352.83 N 670231.40 E 9.019 2915.01 7663.94 21.780 242.000 6856.31 6911.34 2909.27 S 553.95 W 5972346.88 N 670222.43 E 11.047 2923.53 7698.31 21.190 250.810 6888.30 6943.33 2914.30 S 565.45 W 5972341.58 N 670211.05 E 9.535 2932.19 7729.22 20.880 256.380 6917.15 6972.18 2917.44 S 576.08 W 5972338.20 N 670200.49 E 6.543 2938.76 7757.91 20.750 254.940 6943.97 6999.00 2919.96 S 585.95 W 5972335.46 N 670190.68 E 1.840 2944.51 7850.73 20.280 256.060 7030.90 7085.93 2928.11 S 617.44 W 5972326.59 N 670159.38 E 0.660 2962.92 7945.42 19.110 257.570 7120.05 7175.08 2935.40 S 648.51 W 5972318.60 N 670128.49 E 1.347 2980.38 8037.92 17.760 253.900 7207.81 7262.84 2942.57 S 676.85 W 5972310.78 N 670100.32 E 1.924 2996.80 8130.41 19. 1 00 245.160 7295.57 7350.60 2952.84 S 704.14 W 5972299.89 N 670073.26 E 3.316 3015.78 8224.52 19.590 244.150 7384.37 7439.40 2966.19 S 732.31 W 5972285.91 N 670045.40 E 0.630 3037.94 8319.54 21.630 245.560 7473.30 7528.33 2980.38 S 762.60 W 5972271.03 N 670015.45 E 2.209 3061.62 8412.93 21.100 245.450 7560.27 7615.30 2994.49 S 793.56 W 5972256.22 N 669984.82 E 0.569 3085.46 8505.78 20.040 245.050 7647.20 7702.23 3008.14 S 823.18 W 5972241.90 N 669955.51 E 1.152 3108.41 ( 8595.36 22.000 246.940 7730.82 7785.85 3021.19 S 852.54 W 5972228.18 N 669926.46 E 2.315 3130.70 8691.59 22.060 247.440 7820.02 7875.05 3035.18 S 885.81 W 5972213.44 N 669893.52 E 0.205 3155.21 8786.05 21.160 247.630 7907.84 7962.87 3048.48 S 917.96 W 5972199.41 N 669861.68 E 0.956 3178.69 8880.18 20.270 246.880 7995.89 8050.92 3061.35 S 948.67 W 5972185.85 N 669831.27 E 0.987 3201.27 8973.35 19.630 245.770 8083.46 8138.49 3074.11 S 977.78 W 5972172.43 N 669802.46 E 0.798 3223.21 9067.06 19.210 246.710 8171.84 8226.87 3086.66 S 1006.30 W 5972159.23 N 669774.23 E 0.559 3244.75 9124.00 18.950 245.640 8225.65 8280.68 3094.18 S 1023.32 W 5972151.32 N 669757.38 E 0.765 3257.63 9181.51 18.710 244.550 8280.09 8335.12 3102.00 S 1040.16W 5972143.13 N 669740.73 E 0.741 3270.72 9275.21 17.570 245.340 8369.13 8424.16 3114.35 S 1066.58 W 5972130.17 N 669714.59 E 1.245 3291.36 9340.31 18.650 240.450 8431.01 8486.04 3123.59 S 1084.57 W 5972120.53 N 669696.82 E 2.863 3306.18 9369.07 22.640 234.590 8457.92 8512.95 3129.07 S 1093.09 W 5972114.86 N 669688.43 E 15.607 3314.24 9403.34 26.260 234.470 8489.11 8544.14 3137.30 S 1104.64 W 5972106.37 N 669677.07 E 10.564 3325.92 """""'...",....-....""'" ..-..------.. -'--"'---'-'-"""""'", 10 December, 2001 - 15:55 Page 2 of 5 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for K-05B Your Ref: API 500292141802 Job No. AKMM11182, Surveyed: 23 November, 2001 . Alaska Drilling & Wells North Slope Alaska PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9434.48 30.050 232.030 8516.56 8571.59 3146.10 S 1116.39 W 5972097.30 N 669665.52 E 12.718 3338.21 (_.. , 9463.29 31.830 230.880 8541.27 8596.30 3155.33 S 1127.97 W 5972087.80 N 669654.15 E 6.510 3350.84 '- 9496.79 35.920 228.770 8569.08 8624.11 3167.39 S 1142.22 W 5972075.43 N 669640.18 E 12.702 3367.04 9528.29 37.670 226.590 8594.30 8649.33 3180.09 S 1156.17 W 5972062.41 N 669626.53 E 6.931 3383.74 9557.46 39.440 226.490 8617.11 8672.14 3192.60 S 1169.36 W 5972049.61 N 669613.62 E 6.072 3400.00 9591.11 44.560 220.270 8642.12 8697.15 3208.98 S 1184.76W 5972032.87 N 669598.60 E 19.594 3420.66 9622.64 50.240 219.250 8663.46 8718.49 3226.82 S 1199.59 W 5972014.70 N 669584.18 E 18.171 3442.50 9651.62 54.370 216.070 8681.18 8736.21 3244.98 S 1213.58 W 5971996.23 N 669570.61 E 16.685 3464.34 9684.92 57.570 210.730 8699.82 8754.85 3268.02 S 1228.74 W 5971972.86 N 669555.97 E 16.396 3491.17 9715.97 61.780 208.040 8715.49 8770.52 3291.37 S 1241.88 W 5971949.21 N 669543.37 E 15.483 3517.60 9743.09 65.260 206.390 8727.58 8782.61 3312.95 S 1252.97 W 5971927.38 N 669532.77 E 13.939 3541.68 9776.62 68.720 204.360 8740.69 8795.72 3340.84 S 1266.19W 5971899.20 N 669520.20 E 11.727 3572.40 9808.06 72.940 204.800 8751.01 8806.04 3367.83 S 1278.54 W 5971871.93 N 669508.46 E 13.487 3601.99 9835.57 74.390 204.810 8758.75 8813.78 3391.80 S 1289.62 W 5971847.72 N 669497.94 E 5.271 3628.29 9870.05 78.030 203.640 8766.97 8822.00 3422.33 S 1303.35 W 5971816.88 N 669484.90 E 11.059 3661.68 9904.34 83.410 204.710 8772.49 8827.52 3453.19 S 1317.21 W 5971785.72 N 669471.75 E 15.989 3695.42 9941.94 89.080 204.010 8774.96 8829.99 3487.36 S 1332.68 W 5971751.21 N 669457.06 E 15.194 3732.81 9968.60 90.250 203.020 8775.11 8830.14 3511.80 S 1343.31 W 5971726.53 N 669446.99 E 5.749 3759.42 9997.33 93.950 202.750 8774.06 8829.09 3538.25 S 1354.48 W 5971699.83 N 669436.43 E 12.913 3788.09 ( 10030.33 97.280 201.910 8770.83 8825.86 3568.62 S 1366.95 W 5971669.18 N 669424.65 E 10.404 3820.90 10061.95 98.520 201.480 8766.48 8821.51 3597.72 S 1378.53 W 5971639.83 N 669413.73 E 4.146 3852.20 10090.40 97.100 201.010 8762.62 8817.65 3623.99 S 1388.74 W 5971613.33 N 669404.12 E 5.253 3880.38 101.23.52 96.780 199.640 8758.62 8813.65 3654.82 S 1400.16 W 5971582.25 N 669393.41 E 4.218 3913.26 10155.18 93.440 198.600 8755.80 8810.83 3684.61 S 1410.49 W 5971552.23 N 669383.76 E 11.045 3944.78 10183.99 91.660 198.290 8754.52 8809.55 3711.91 S 1419.59 W 5971524.73 N 669375.28 E 6.271 3973.55 10217.39 89.260 199.940 8754.25 8809.28 3743.47 S 1430.53 W 5971492.94 N 669365.06 E 8.720 4006.94 10276.52 87.530 199.480 8755.90 8810.93 3799.11 S 1450.46 W 5971436.85 N 669346.40 E 3.027 4066.05 10369.88 84.770 198.920 8762.17 8817.20 3887.07 S 1481.10 W 5971348.22 N 669317.78 E 3.016 4159.18 10414.19 84.700 198.670 8766.24 8821.27 3928.84 S 1495.31 W 5971306.14 N 669304.52 E 0.584 4203.29 10463.28 85.000 198.020 8770.64 8825.67 3975.24 S 1510.70 W 5971259.39 N 669290.19 E 1.453 4252.17 """---.--..----..-......",,--.....,.....""" ........ .........."....,...-.-,,---,-. -...... .."..,- -""-"""""'---"-"-""""-"--" ----.----.-..-,... ....... .. 10 December, 2001 - 15:55 Page 3 of 5 DrillQlJest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for K-05B Your Ref: AP/500292141802 Job No. AKMM11182, Surveyed: 23 November, 2001 . Alaska Drilling & Wells North Slope Alaska PBU_WOA K Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10555.24 88.280 196.290 8776.03 8831.06 4062.95 5 1537.77 W 5971171.10 N 669265.13 E 4.031 4343.84 10602.42 88.460 196.690 8777.38 8832.41 4108.175 1551.16W 5971125.58 N 669252.77 E 0.929 4390.91, f '-.' 10651.01 88.830 197.390 8778.52 8833.55 4154.61 5 1565.39 W 5971078.83 N 669239.60 E 1.629 4439.43 10697.41 89.200 197.890 8779.32 8834.35 4198.82 S 1579.45 W 5971034.31 N 669226.55 E 1.340 4485.78 10744.64 89.020 197.050 8780.06 8835.09 4243.87 5 1593.63 W 5970988.95 N 669213.40 E 1.819 4532.96 10779.43 87.050 196.810 8781.25 8836.28 4277.135 1603.75 W 5970955.4 7 N 669204.04 E 5.704 4567.68 10837.25 86.560 195.200 8784.47 8839.50 4332.62 5 1619.67 W 5970899.63 N 669189.39 E 2.906 4625.27 10900.00 86.560 195.200 8788.24 8843.27 4393.07 5 1636.09 W 5970838.82 N 669174.35 E 0.000 4687.69 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.573° (1 0-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 199.970° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10900.00ft., The Bottom Hole Displacement is 4687.84ft., in the Direction of 200.427° (True). ( m_'--"-""""""""'""",---"" ..-.........., ..,..-........-...-.--,.."-.,,.....,........-.."""""""""-"--'--"---- ---.--.."..".."" '----'"., 10 December, 2001 - 15:55 Page 4 of 5 DrillQuest 2.00.08.005 North Slope Alaska Comments i '- Measured Depth (ft) 7399.36 7410.00 10900.00 Sperry-Sun Drilling Services Survey Report for K-O5B Your Ref: API 500292141802 Job No. AKMM11182, Surveyed: 23 November, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6673.52 6682.66 8843.27 2813.92 S 2819.24 S 4393.07 S Survey tool program for K-05B Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 7399.36 , , , '- ...... ........ ...... 0.00 6673.52 10 December, 2001 - 15:55 To Measured Vertical Depth Depth (ft) (ft) Comment 496.33 W 497.45 W 1636.09 W Tie On Point Window Point Projected Survey Survey Tool Description 7399.36 10900.00 6673.52 AK-1 BP _HG - BP High Accuracy Gyro (K-05) 8843.27 MWD Magnetic (K-05B) ..,'.",..,..."..,.'-_...._._--,------,--- Page 5 of 5 . Alaska Drilling & Wells PBU - WOA K Pad (" (- '-""""'--"'-"-""---"- DrillQuest 2.00.08.005 ( ~1f~1fŒ ffi)~ ~~~~~~ ( ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡nt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson . Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit K-05B BP Exploration (Alaska), Inc. Permit No: 201-206 Sur Loc: 1935' SNL, 441' EWL, Sec. 04, T11N, R14E, UM Btmhole Loc. 1845' SNL, 1268' WEL, Sec. 08, TIIN, R14E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other govenunental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay UnitK-05B. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (ß~/~r C~~~ ~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 23rd day of October 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA - AND GAS CONSERVATION COMrv( PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill II Redrill 1 b. Type of well 0 Exploratory Dßtratigraphic Test III Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas IÐ Sin~~ Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) í-O. Field and Pool BP Exploration (Alaska) Inc. Plan AKB = 55.53' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 6283t.'-3"ð-: ADL 028304 ~ 4. Location of well at surface 7. Unit or Property Name 1935' SNL, 441' EWL, SEC. 04, T11N, A14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 5031' SNL, 572' WEL, SEC. 05, T11N, A14E, UM ",:~1i~1 At total depth 9. Approximate spud date 1845' SNL, 1268' WEL, SEC. 08, T11N, R14E, UM 10/25/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number 6faåes in property 15. Proposed depth (MD and TVD) ADL 028303, 1268' MD "e;,~,j~¡;is,.8!1'~4Laway"at,885Q'""""",;, 2560 11770' MD / 8906' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 7400' MD Maximum Hole Angle 900 Maximum"surface ~:Kttota' depth (ND) 8800'/3300 psig 18. CaSi~&~rogram Specifications TonSetting Depth Bottom Ouantitv of Cement Hole Casino Weiaht Grade Couolinn Lenath MD TVD MD TVD finclude staae data) 8-1/2" 7" 26# L-80 BTC-M 1860' 7250' 6546' 9110' 8272' 184 cu ft Class 'G' 6-1/8" 4-1/2" 12.6# L-80 BTC-M 1989' 8960' 8130' 10949' 8850' 97 cu ft Class 'G' 3-3/4" 2-7/8" 6.16# L-80 ST-L 870' 10900' 8793' 11770' 8906' 6 cu ft Class 'G' ,J¿ 1 ALASKA( jlON Äo/ Ii) 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Casing Structural Conductor Surface Intermediate Production Liner Liner 11172 feet 8829 feet 11147 feet 8828 feet Length Plugs (measured) -:&. \Jon;: .., - '!lIt..¡ L( HOle;: TO l!:i€ð.Q..tlte1) ß'1 "...;. ~ Cc~c..¡;C> '\'Vßi':.ac:. A..er - ~~ .s\-(c:M.t ~ ~ t.~.", """,~v .5 €A-' lS'Ia.. ~ t... 19. To be completed for Aedrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Junk (measured) Size Cemented MD TVD 110' 2793' 7578' 20" X 30" 13-3/8" 9-5/8" 8 cu yds Concrete 3999 cu ft Permafrost 1982 cu ft Class 'G' 110' 2793' 7578' 110' 2701' 6828' 2707' 1148' 7" 4-1/2" 541 cu ft Class 'G' Uncemented Slotted Liner 7452' - 10159' 6719' - 8826' 1 OORECE l'fIE [19' Perforation depth: measured OCT 1 1 í' I ¡ 20. Attachments 9780' - 9800', 9830' - 9850', 9890' - 9910' Slotted Section: 10156' - 11146' true vertical 8757' - 8764', 8775' - 8782', 8794' - 8799' Alaska Oil & Gas Cons. Commission Slotted Section: 8826' - 8828' . II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Walter Quay, 564-4178 ThomasJJ¡;f;arty, 564-~§9lf" Prepared By Name/Number: Terrie Hubble, 564-4628 21. I ~erebY certify that the foregoing .~, true and rrect to the bes(of.mY~ÓWI~áge . r - I. . / Signed Brian Robertson 1-)~ Title Semor Dniling Engineer Date /0/ III '01 "", '.:' ,..",',:.,',,:\:,::,:':,.,.)..'.¥,',,/:,.:::,' ,"," ',';'Cø~m~s$iori'lJse()níyiY,::: ",>i::..',:",('::,:",;,,::,p, :".«:,':....:,:¡',:,';'", permi~~i~ 2D~ :~10~~~~:~8-02 APPn'~~~\~) ~~:~~:re;~~~~:ments Conditions of Approval: Samples Required 0 Yes IJ No Mud Log RequiTed 0 Yes IiINo Hydrogen Sulfide Measures ~Yes 0 No Directional Survey Required (iJ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~.5K psi for CTU Other: ~ ~ £~ Original Signed By by order of .... r' ,. Commissioner the commission 0 ,~~lG1r~/~\ L Approved By Form 1 0-401 Rev. 12-01-85 Date lO:iAf)) Subm t In Triplicate f I Well Name: (, I K -058 Drill and Complete Summary I Type of Redrill (producer or injector): I Producer Surface Location: x = 670,710/ Y = 5,975,268 1935' SNL 441' EWL S04 T11N R14E Umiat Target Start Location: x = 669,775 / Y = 5,972,150 5031' FNL, 572' FEL, Sec. 05, T11N, R14E Umiat Target Intermediate x = 669,454/ Y = 5,971,770 Location: 124' SNL, 903' WEL, Sec. 08, T11 N, R14E, Umiat Rotary X = 669,200/ Y = 5,970,800 Bottom Hole Location: 1088' SNL, 1181' WEL, Sec. 08, T11 N, R14E, Umiat Coil X = 669,132.59/ Y = 5,970,041.71 Bottom Hole Location: 1845' SNL, 1268' WEL, Sec. 08, T11 N, R14E, Umiat I AFE Number: 14P1667 I Estimated Start Date: 110/25/01 lB.!9=J Nabors 2ES 1 [Qperatin~s to complete: 117.75 (Rotary) 1 Rotary 10,949' MD: Coil 11 ,770' MD: (AMSL) Rotary 8850' TVD: Coil 8906' TVD: (AMSL) Cellar Elevation: 26.53' I AKa: 155053 I 1 Well DesiQ!!jconventional, slim hole, etc.>.J Conventional Big Bore - 9-5/8" Sidetrack ~ective: I Complete well as Zone 1 Producer. K-05B Well Plan 10/11/2001 Page 1 f ( Formation Markers Formation Tops (wp8) MD TVD Comments UG4AfTop Ugnu 4701 WS1 6156 WS2ITop West Sak CM3/K101Top Colville Mdstn 6326 7400 6674 KICK OFF Point CM2 7924 7156 CM1 8083 7306 THRZ 8328 7536 BHRZ 7724 LCU 8620 7811 Kingak E 8620 7811 T JDlTop Kingak D 8705 7891 T JClTop Kingak C 8758 7941 T JBlTop Kingak B 8918 8091 T JAfTop Kinaak A 9019 8186 ~ t'-\,I Saa River Ss 9110 8272 c:-~ Gas @ 7.2 ppg EMW Shublik 9162 8321 Gas @ 7.2 ppg EMW Top SadierochitITZ4B 8242 8396 Gas @ 7.2 DD~ EMW TZ3 9372 8518 Gas @ 7.2 DD~ EMW TZ2 9440 8581 Gas @ 7.2 DD~ EMW TZ1B 9672 8756 Oil @ 7.2 ppg EMW TZ1A 9778 8806 Oil @ 7.2 ppg EMW BSAD 10141 8836 TD Criteria: TD of the rotary portion of the sidetrack should be within the first target polygon to keep the TD of the well +/-200' from the Graben Fault. K-05B Well Plan 10/8/2001 Page 2 (' (' c IT b" p aslngJ u Ing rogram Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. M DITVD M DITVD 8-1/2" 7" 26# L-80 BTC-Mod -1860' 7250' / 6546' 9110'/8272' 6-1/8" 4-1/2" 12.6# L-80 BTC-Mod -1989' 8960' / 8130' 10,949' /8850' Tubing 4-1/2" 12.6# L-80 BTC-Mod -8960' GL 8960'/8130' Directional KOP: 17400' MD Maximum Hole Angle: -330 In original wellbore at 6100' MD -900 In tangent interval and through Reservoir section Close Approach Well: All wells except E-14 pass BP Close Approach guidelines pass under Major Risk rules. E-14 passes Minor Risk(1/200) at the 8850' TVD Close A,pproac.h iS~U~ irs;.,~~e;r~Q'B1~:';I~ll!,~n,(~.~~I,~þ,~,~~~låfJh:~~s~,.re differential/risk, ' . é""'o e'rae" '0 Is1Ön'" "0(' sheëtA, ~"S ~!,"',., Survey Program: Standard MWD Surveys from kick-off to TD. LSND PV 15-19 Whipstock Window in 9-5/8" Yield Point tauO H 25 - 35 3 - 8 9.0 - 9.5 HTHP ee's/3D min <9 Intermediate Mud Pro erties: LSND Densit Viscosit PV 1 0 45 - 55 15 - 1 9 8-1/2" hole section Yield Point tauO 20 - 25 3 - 7 HTHP ee's/3D min <9 Production Mud Pro erties: Ouickdril-N Densit Viscosit PV 8.4 - 8.5+ 45 - 60 5 - 8 6-1/8" hole section YP tauO 20 - 25 5 - 8 MBT <3 H 8.5 - 9.0 API FI N/C Lo 8 %" Intermediate: Drilling: MWD IGR IRes - Realtime over entire interval. Sam Ie catchers as er on-site Geolo ist. No 0 en hole 10 s are lanned. No cased hole 10 s are lanned. Open Hole: Cased Hole: 6-1/8" Production: Drilling: Open Hole: Cased Hole: K-05B Well Plan 1 0/8/2001 Page 3 (' (' c tp emen ro~ ram Casina Size 7" Drilling Liner I Basis: Lead: None T ail: Based on 1000' of open hole with 30% excess and 82' of 7" shoe track. Tail TOG: -8100' MD 7321' TVD) Fluid Sequence & Volumes: Pre None Flush Spacer 50 bbls Alpha Spacer weighted to 1 ppg above MW Tail 33 bbl I 184 fe 1160 sks of 'G' at 15.8 ppg and 1.15 dIsk, BHST 1950 I BHGT 1350 (use actual circulating temps recorded by MWO at TO), TT = Batch Mix + 4 to 4.5 hrs Casina Size 14-1/2" Production Liner 1 Basis: Lead: None Tail: Based on 82' of 4-112" shoe track, 1840' of open hole with 50% excess, 150' of 7" x 4Y2" liner lap, and 250' of 7" x 4" DP annulus volume. Tail TOG: -8960' /' MD (8130TVD).- Liner toP. Fluid Sequence & Volumes: Pre 5 Bbls Walter Flush Spacer 40 bbls Alpha Spacer at 9.8 ppg Lead None Tail 53 bbl I 297 fe I 250 sks of Halliburton 'G' at 15.6 ppg and 1.19 dIsk, BHST 2150 I BHGT 1400 (use actual circulating temps recorded bv MWO at TO), TT = Batch Mix + 4 to 4.5 hrs K-05B Well Plan 1 0/8/2001 Page 4 ( .( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3281 psi @ 8750' TVDss - Ivishak . Maximum surface pressure: 2406 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel . Disposal . 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 OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . K-05B Well Plan 10/8/2001 Page 5 ( ( Sidetrack and Complete Procedure Summary Pre-Ria Work: ~ 'ð ~ 2. IV) 3. * Notify the field AOGCC representative with intent to plug and abandon * 1. Rig up CTU. RIH to top of 4%" slotted liner or to top of IBP fish in liner (inflatable bridge plug and setting assembly was left in hole at -10,150' MD, on 1/9/95). Perform a cement P&A using 15.8 ppg class 'G' cement, by bullheading cement down into the 4-1/2" slotted liner and laying in cement up into the 3-1/2" tubing tail. Bullhead adequate cement volume to fill the 4%" slotted liner and squeeze -15 to 20 bbls to the formation and then lay-in adequate volume to fill the 7" liner and extend up into the tubing tail a minimum of 100'. Estimated minimum cement volume required is 45 barrels. Use aggregate as required to aid in plugging the formation. NOTE: The AOGCC has requested on prior sidetracks exiting above the reservoir that the top of cement be brought up into the tubing tail -100', therefore the minimum top of cement should be 9,597'. Top of cement may extend further up into the tubing as long as it does not interfere with the upcoming tubing cutting operations. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. Liquid pack the 9-5/8" x 3-1/2" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3500 psi for 30 minutes. 4. Rig up E-line. RIH with tubing cutter and cut the 3%" L-80 tubing at -7600' MD (cut tubing in the center of full joint). This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. 5. 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 2200' MD with diesel. 6. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 7. Set a BPV in the tubing hanger. Secure well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree. Nipple up and test BOPE to 250 /3500 psi. 4. Pull and lay down 3%" tubing from E-line cut and above. 5. Only if necessary to change out 9-5/8" pack-off: Bleed any pressure from 13-3/8" x 9-5/8" annulus. Change out 9-5/8" pack-off through BOP stack. Test pack-off to 5000 psi to verify integrity. 6. MU 9-5/8" whipstock window milling assembly and RIH to top of 7" liner at 7452' MD. POOH. 7. RU E-line and set BP at -7424' MD (set as needed to avoid cutting casing collar). Test 9-5/8" casing to 3500 psi for 30 minutes. 8. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. 9rien,t.W.hipstock and set on BP. Mill window in 9-5/8" casing at -7400' MD. Prior to POH, perform~ FIT...~t:Q~\-1~2~~þ;~'eEMW::'~; 9. RIH with 8%" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag @ :t911 0' MD (8272' TVD). 10. Run and cement 7", 26# intermediate drilling liner to -150' back into window. POH. 11. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU) to the 7" liner landing collar. 12. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3500 psi for 30 minutes. 13. Drill shoe track and 20' of new formation. Conduct PI~~~QQ~~ 14. Drill 6-1/8" production section as per directional plan to ärï' estm,åted TO of 10,949' MD (8851' TVD). 15. Run and cement a 4%", 12.6# L-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean seawater above liner top. POOH LD DP. 16. Test the 4Y2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. 17. Run a 4%" L-80 completion tying into the 4-1/2" liner top. 18. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 20. Freeze protect the well to -2200' and secure the well. 21. Rig down and move off. K-05B Well Plan 10/8/2001 Page 6 ( (" Post-Ria Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the production packer. 2. Dummy off the GLM with the RP shear valve. CTU Operations: 1. MIRU Coil drilling unit. Drill 3-3/4" extension down in to Graben target with TD at -11,768' MD. 2. Run and cement 2-7/8" liner back into 4-1/2" liner. 3. Perforate -200' in the Graben and -700' in the horizontal section. 4. Rig down and move off. Post-CTU Work: 1. MIRU slickline. Install gas lift design as required. 2. Rig up flowline. K-05B Well Plan 10/8/2001 Page 7 ( (' Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to K-05. The two adjacent wells, K-11 and K-10 are approximately 35' and 75' from the K-05 wellhead respectively. Establish a minimum distance of 5' from the K-11 and K-10 well houses. 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. Recent H2S data from the pad is as follows: Adjacent producers at Surface: K-10A 10 ppm Aug 19,00 15-21 A 10 ppm Mar 3, 01 The maximum recorded level of H2S on the pad was 10 ppm. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ..- . ,n""""_,...",,,. , , ^ ,.., .--.."'-"'..."'..,..""'.-."...""'.,.'"....."" ... '" ".."_.",, ,..". , Job 2: Decomplete Well Hazards and Contingencies ~ The perforations and bottom section of this well should be isolated by 2 barriers (the cement plug and the seawater). \The plug will be tested in the Pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. -""""""""""""""""""""'i"""""""""""""""""""""'"...."""'.""",.",,, , """"',"" "..,....".""""", """"""':._",,"'.,"'-""""""""""""',""""",,"'".....""'","'..."""..""""",.."",...","..."""",."""",,,.,, ."'...- Job 3: Run Whipstock Hazards and Contingencies ~ 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. Job 5: Drill 8Y2" Intermediate Hole Hazards and Contingencies. .."', c',,, '.'. ," ,", ' ~ On prior K Pad wells, 1ç:>$f:ci'réÙíåtìori-"ïrnhe ¡'Ate'rm'èdfate section ,has been a ,plinor problem experienced while drilling shallow sandstone intervals and when crossing faults in the' Kingak shales'.' ' No fault crossings are planned in the drilling of K-05B. The original well was drilled to Top Sag with 9.9 ppg(with 30° inc.) and no losses reported. Several incidents of lost circulation have been seen when the Sag River formation was inadvertently penetrated. Extreme care should be taken when picking the 7" casing point. ~ The well will kick-off in the Colville (CM3) Mudstone drill through the HRl, into the Kingak shale with the intermediate shoe in the Sag River formation. K Pad has a limited history of wellbore stability problems within the Kingak shales and of the problems encountered, minor incidents of tight hole and packing off have been the main problems. Most K Pad wells drilled the Kingak with 9.7 or 10.1 ppg. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. ~ The kick tolerance for the 8%" open hole section would be infinite bbls assuming a kick from the Sag River at -9110' MD. This is a worst case scenario based on an 8.5 ppg pore pressure gradient, a fracture gradient greater than 11.0 ppg at the 9-5/8" window, and 9.6 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines in this intelVe!,kj!;"IIJ'.he,"~nrea~e§,t~,,¡,çl,ose approach well in,.t~!'~"j.~~¡¡Ç!tj9;Qi,¡,.i.s\'~"~iê~r,wJaJ~t1m,i§.'ì¡~aMeln~~1b200¡'i!fwel,l:::to:,w§JI at 9110' MD - within the majO'r'tì$lt tolerance. "I""r¡¡¡¡,:"lh>1""'" """""""'!,"',«"",""!!JI.,!""!,!!",,!,,!,,,,,"!""",,, """!,,",,!,,!I,',I,,,', ,.,!!,!, ,!""","",!",,!,!,! ,I, ,!!",""""'!"!"!!,",""",',',I", " !!, ,II , , """'!,,'! ,,! ...., ! ,,! "!"I"""",'",""",,,, , ","'""O.,""""I,I,"'!!" Job 6: Install ¡"Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. K-05B Well Plan 10/8/2001 Page 8 ( ( þ;> 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. Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies þ;> No fault crossings are planned in the drilling of K-05B, however there is a Graben Fault +/-200' from the wellpath near its planned TD. þ;> K Pad has a history of lost circulation events while drilling in the reservoir section. Losses have generally been minor. All cases of losses are believed to be fault related. As no fault crossings are planned in the drilling of K-05B, lost circulation is not thought to be a significant risk, however be prepared for losses by establishing a contingency plan(pumping fibrous LCM pills, sufficient drilling fluid volume). þ;> The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at ~10949' MD. This is a worst case scenario based on an 7.8 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" shoe, and 8.5 ppg mud in the hole. ~ Drilling Close Approach: All wells except E-14 pass BP Close Approach guidelines. ~ B~1'~~j¡1§~~I"Jr~~'~,~I;'l~~~~~~~~"i~:~!~r~¡I'~$;;W1Þ])~~"will pass whe~ r:ninor risked at a 1 in 2~0 Tolerable Collision Risk. The risk are IS minor, as the problem approach area IS In the plugged Qtt~:S£ØIf(\\JfI!1I~\~~~~eíi~rJ;Ï!c¡11~,~¡qè of the this rotary section, with both the wells in the reservoir interval(little or no differences in pressure). 'The nearest approach well is E-14 which is ~814' well-to-well at 10,949' MD and passes under Major Risk rules. ,",",' .."",..~.,,.... ~....' """""""""""""",""""" ..",..,. ...""',,'"",..,..."",, m.", m,.",.".., "....""....,-, m ,"""""",",~, '" "..", , "". ,"a ",.."""""m ' "'"""""""""" ..",.". ",... ","', ".. ""'",, "",.""'",...,, "....." """OM"" "" Job 9: Install 4Y2" Production Liner Hazards and Contingencies þ;> Differential sticking could be a problem. The 8.5 ppg Quickdril will be ~600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. þ;> 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. " ','",.".I,..U\""W ,." . , ,', ,..""", """ ,U"LU, ""."" , " ,\!,\!",.J,,"," ",u,,", Job 12: Run Completion Hazards and Contingencies þ;> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 1000 F. WL ," , ., ,,"L,II!, U""", u, ",,¡U,"\;,\!'", ,'""""'W\!,,,,',.' , ,. ,"'",1,,' ",',",\!,,¡ , ',1, W",",',\;,"",',U,\4 ;¡"""""","','"¡,;,"",,,;, ,',"'"\;"",'""IU"L,"", ,U) Job 13: ND/NU/Release Ria Hazards and Contingencies þ;> 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. K-05B Well Plan 1 0/8/2001 Page 9 CXJMPANY DET AlI.S BP Amoco Calculatioo Method: Minimum arn-ature Enor System: ISCWSA SC3n Melhod: Tray C)1inder North Enor Surfuce: Ðlip!icaI + Casing WamÌII!! Method: Rules Based REFERENCE INFORMATION Co-mliœte (NiE) Iœference: Well Ceo"": K-OS, Trœ North Vertical (IVD) Iœlerence: Plan K-O5B 5553 Sec'ion (VS) Referenœ: Slot - (O.OON,O.OOE) Measured Depth Iœference: Plan K-O5B 5553 Calculation Melhod: Minimum Curvature FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 7155.53 7924.00 CM2 2 7305.53 8083.45 CMI 3 7535.53 8327.95 THRZ 4 7810.53 8620.28 LCUrrop Kingak 5 7890.53 8705.32 TJD 6 7940.53 8758.47 TJC 7 8090.53 8917.92 Till 8 8185.53 9018.91 TJA 9 8271.53 9110.33 Top Sag 10 8320.53 9162.42 Shublik II 8395.53 9242.15 Top Sad. 12 8517.53 9371.83 Zone 3 13 8580.53 9440.12 Zone 2 14 8755.53 9671.99 Zone IB 15 8805.53 9778.03 Zone IA 16 8835.53 10141.05 Base Sad. \\ Slarl )jiT2°1l00':7400"MD, 6674.14'TVD \. SI¡¡¡1 DiI:7°fIO0':7420'MD, 6691.29'TVD 700 :s 4: <:> <:> ~ ..c Õ. OJ 0 õj .g ~ > OJ ::I ... E-o 900 950 , \, ~\'.'End'Ðir :-7765036'MD, 7006.29' TVD - TIIR/. \.- l.('Ufl(J,P Kill~ak ~.... '1'.11> . '1'1(' SURVEY PROGRAM Depth Fro Depth To Sur\'eyiPlan Plan: K-O5B wp08 (K-O511'Ian K-O5B) Tool Dale: 7/2612001 Created By: Ken Allen Checked: 7400.00 10949.41 PIanœd: K-05B wp08 VI MWD Dale: Reyiewed: Date: WELL DETAILS Name +N'.S +FJ-W Latitudo Longin.¡" Sk,' Northing 5975268.00 Easting 670710.00 70"20'18'()68N 148°36'53.I04W N/A K-05 2097.91 4]5.68 TARGET DETAILS Name K-O5B Polygoo6.\ K-05B Sag TI K-O5BIDTI K -05 B Land T2 lVD +FJ-W l;.sting Shape 669350.18 Polygon 669775.18 Point 669200.25 Point 669454.23 Point +N/-S Northing 5971999.92 5972149.95 5970799.91 5971769.68 883553 -3236.49 -1433.96 827]53 -3096.17 -1005.64 885053 -4432.85 -1611.19 883553 -3469.06 -1335.\8 SECTION DETAILS ec MD Inc Azi TVD +N/-S +Fl-W Dug TFace VSec Target 7400.00 30.80 191.83 6674.14 -2813.96 -496.29 0.00 0.00 2814.23 ~ .~..., 7420.00 31.09 196.46 6691.29 -2823.93 -498.81 12.00 85.00 2824.45 7765.36 19.83 248.92 7006.29 -2932.12 -579.94 7.00 138.95 2953.85 911 0.33 19.83 248.92 8271.53 -3096.17 -1005.64 0.00 0.00 3253.45 K-05B Sag TI 5 9130.33 19.83 248.92 8290.34 -3098.61 -1011.97 0.00 0.00 3257.90 6 9379.13 19.83 248.92 8524.39 -3128.96 -1090.71 0.00 0.00 3313.32 7 9941.05 90.00 205.00 8835.53 -3469.06 -1335.18 13.50 -45.68 3716.47 K-05B Land T2 8 10141.05 90.00 205.00 8835.53 -3650.32 -1419.70 0.00 0.00 3915.71 9 10505.61 88.63 190.48 8839.91 -3996.59 -1530.49 4.00 -95.45 4278.99 10 10949.41 88.63 190.48 8850.53 -4432.85 -1611.19 0.00 0.00 4716.58 K-05BTDT3 . CASING DETAILS No, TVD MD Name Size 1 8271.53 9110.33 7" 7.000 2 8850.53 10949.40 4-1/2" 4.500 All TVD depths are ssTVD plus 55.53' for RKBE. ~ -... TJI! IJ{)()(~... T.IA , \ ¿~\"- To}Sag "'" 7\ \." ~1~lIhli~ : ." \ '.- 1 op s¡IIL . \ . Slart l>ir'U,5"/I{)O': 1)\7'J.1 \' \1P, XS24.vrrVI> '\. ~~Hl~ .~ ' . \'<:'ue:2 "" . ..' : Zìilt"-.I!... >...' Zuìiì:!-i-.~ : . ¡ '. .....,.. .... ---',-+:---:"---::-::::::-:':'-:-;-- , ¡base Sad. I, í i I (JOUO ! ¡ EI1lIDir:<J'J41.05'MI>.XXY¡;SVTVI>". I ! : ; StartDir4"/IOO': 10141.0S' MI>, XX.\S.53'TVI> " / End I>ir : 1O505.hl' MI>. XX.~iJ.')' TVI> I 3000 -., . . Total Depth :' 10949.41' MD, 8850.53' TVD 'I. m .m m .... ,. ,.;.. . .. . . -. . . .m__.___m...m--_C..... _'.._m__"""-..m_'" .... .... " ..¡¡ \ 4-1/2" : ___m_._~~~ ¡ 3500 ¡ 4000 4500 5000 Vertical Section at 199.97° [500ft/in] ...--...---.---..-..-....-. . 5500 7000 7500 6000 6500 COMPANY DETAII.S REFERENCE INFORMATION BP Amoco Co-ordinate (NiE) Reference: Well Centre: K-05, T"", Nonh Veruc.J (IVD) Referenœ: Plan K-O5B 55.53 Section (VS) Referenœ: Slot - (O.ooN,O.ooE) Measured Dep1h Reference: Plan K-05B 55.53 Calculation Method: Minimum Cun'alUre Calculation MeIhod: Minimum Cun'atore ErrorSptero: ISCWSA S<:an Method: T lõIy C)iindet- North Error Surlàce: EIIipticaI + Casing Wanrlrnz MeIhod: Rules Based -200 -250 -300 E ~ 0 0 ~ +' :<: t: 0 ~ :<: ;:; 0 en -350 -400 -450 -500 I -2000 v/~t~~~ir 12°/100': 7400' MD, 6674.14'TVD Siart Dir 7°/100' : 7420' MD, 6691.29'TVD ,'7500 ~~~~j~ K-O5B SagTl +--- , . ! . .IF -~;,. ",/ ----(þ I " . ...//~ f ;' u! . f .,. . --f- Fnl! nir: W505,61'MD,8839.91'TVD .. t. ....-.........-.....-. '-""""'?-""""""--'--"--"'-~---'~"'~-" 'TVD" ,D ! i j f K-05B 'I'D T~ UO" " Total I?e)Jt~:lp?~9,41 'r-1P' 8~50.53' TvD , '~OO -1000 -500 0 SURVEY PROGRAM Dep1h Fro Dep1h To SurveyiPlan Plan: K-O5B wpO8 (K-O5/Plan K-O5B) Tool Dale' 7/26/2001 Created By: Ken Allen Checked, 7400.00 10949.41 Planned: K-O5B wpOS VI MWD Dale: Reyiewed: Dale: Name .¡.N<-S WELL DETAILS fasting Latitude Longitude Slot +FJ-W Northing 5975268.00 670710.00 70"20'18JJ68N 148°36'53.104W NJA K-05 2097.91 415.68 TARGET DETAILS Name lVD +FJ.W Easting Shape (>69350.18 PoIY8on 669n5.18 I'oinl 669200.25 Point 669454.23 Poinl +NJ-S Northing 5971999.92 5972149.95 5970799.91 5971769.68 K-05B Polygon6.1 K-O5B Sag T1 K-O5BTDD K -05 B Land T2 8835.53 -3236.49 -1433,96 8271.53 .3096.17 -1005.64 8850.53 -4432.85 -1611.19 8835.53 -3469.06 -1335.18 SECTION DETAILS See MD Ine Azi TVD +N/-S +FJ-W DLeg TFaee VSee Target 7400.00 30.80 191.83 6674.14 -2813.96 -496.29 0.00 0.00 2814.23 7420.00 31.09 196.46 6691.29 -2823.93 -498.81 12.00 85.00 2824.45 7765.36 19.83 248.92 7006.29 -2932.12 -579.94 7.00 138.95 2953.85 9IlO.33 19.83 248.92 8271.53 -3096.17 -1005.64 0.00 0.00 3253.45 K-05B SagTI 9130.33 19.83 248.92 8290.34 -3098.61 -1011.97 0.00 0.00 3257.90 9379.13 19.83 248.92 8524.39 -3128.96 -1090.71 0.00 0.00 3313.32 9941.05 90.00 205.00 8835.53 -3469.06 -1335.18 13.50 -45.68 3716.47 K-05B Land T2 8 10141.05 90.00 205.00 8835.53 -3650.32 -1419.70 0.00 0.00 3915.71 9 10505.61 88.63 190.48 8839.91 -3996.59 -1530.49 4.00 -95.45 4278.99 10 10949.41 88.63 190.48 8850.53 -4432.85 -1611.19 0.00 0.00 4716.58 K-05B TD T3 . CASING DETAILS No. TVD MD Size Name I 2 8271.53 8850.53 7.000 4.500 9110.33 7" 10949.40 4-1/2" FORMA nON TOP DETAILS No. TVDPath MDPath Fonnation I 7155.53 7924.00 CM2 2 7305.53 8083.45 CMI 3 7535.53 8327.95 THRZ 4 7810.53 8620.28 LCUffop Kingak 5 7890.53 8705.32 Till 6 7940.53 8758.47 TJC 7 8090.53 8917.92 TJB 8 8185.53 9018.91 TJA 9 8271.53 9110.33 Top Sag 10 8320.53 9162.42 Shublik II 8395.53 9242.15 Top Sad. 12 8517.53 9371.83 Zone 3 13 8580.53 9440.12 Zone 2 14 8755.53 9671.99 Zone IB 15 8805.53 9778.03 Zone IA 16 8835.53 10141.05 Base Sad. All TVD depths are ssTVD plus 55.53' for RKBE. 500 1500 2000 2500 1000 West(-)Œast(+) [500ft/in] (' BP Amoco ( Planning Report - Geographic I ~i:~~any~-~~~~~ci~~ --.---.------ " ~:~~di:~:e~~~leferen:~:i~~~-:~~~~~3e NO~:-----'p~ge: ....~_.- ~ ~ ~ ~ - - - - ~ ~: ~::J ~ ~ . 9 ~ - -- , Field: Prudhoe Bay . - -----------, North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 l ~;~~~~~::: ~~~~~~~~~k:er66) ----------_._._-----_._---~::~;;~i~~;::~:I~_____~~~ ~~~~I______---------- - .--. .-_____..1 --------..-------- PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5973161.33 ft 670342.10 ft ---..----------...------------------ ---"'-- Latitude: 70 19 57.435 N Longitude: 148 37 5.245 W North Reference: True Grid Convergence: 1.30 deg ,- -.. --- --- - --------.---- .--. ---- -- - ------------ .--- ------- ---.- ..--- - ---- -- --..-...----- ------ - - ,--_.... ---... ------.---- --- _._---,- -- - -.----- ------.. - -..--..--,-- - ----- '----.---------,-------.---. --..---- Well: K-05 K-05 Surface Position: +N/-S 2097.91 ft +E/-W 415.68 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 2097.91 ft +E/-W 415.68 ft Northing: Easting : 5975268.00 ft 670710.00 ft Northing: 5975268.00 ft Easting : 670710.00 ft Measured Depth: 29.00 ft Vertical Depth: 29.00 ft Slot Name: Latitude: Longitude: 70 20 18.068 N 148 36 53.104 W Latitude: Longitude: Inclination: Azimuth: 70 20 18.068 N 148 36 53.104 W 0.00 deg 0.00 deg ._-- --....-,.--,--.-.-- - ---'-" '--'---'- - -....--...-..-.-..-.........-..- ,-----..---- -- - -------- ,--_. ---.--.-- ..,.......- --. --"'.--"-----"'- - --._------ .--- ---, -.-,-----.., .--...., ..,-..--.-----. ".- -...-----..------.,- .--..,--.-.-.,-...----....-. ...---..-.. ,--.,- -....- --,-,.__.._- --.- -----. - .... ----.-,------.----.....-..-.-,-. - '----"'-'-'---""'--"-'----"'---"-------------------'--.-.--------.---,-------- -_.... ",. -.--,------.. ----- '---.....--.-,,-, --------.- ------ .-- -..---..-----.-.-.. Wellpath: Plan K-05B 500292141802 Current Datum: Plan K-05B Magnetic Data: 9/22/2000 Field Strength: 57490 nT Vertical Section: Depth From (TVD) +N/-S ft ft "-""-"-'-"-'-'---------"""--',-,---- -.--...------------.-....-- 0.00 0.00 55.53 ft Height Drilled From: K-05 Tie-on Depth: 7400.00 ft Above System Datum: Mean Sea Level Declination: 26.96 deg Mag Dip Angle: 80.81 deg +E/-W Direction ft deg --------..--.,--....-.- 0.00 199.97 ,-, .-.., -...--.....,..--, -------_...-..- --..,--.,..-...,--.......----,.. ....----.-.--.---....-,.---- ---,-----.-.--..----,..----- -.,-.-----....",------.--.-..,--,- ...-..-.-,-,.....,..,-- -----... """"".-"'-'-'---------..,--. ....- ,..._-_.._._--,--------_...._--, -."-----------..-. ---. .----.---.---..-.--,----..---............,.-.- ,-------_.,.... 6. ~ ~ ~ ~ ~ -== ~ ==- -=- ~ ~: = = b : ~ ~ ~ ~ == =- -= = ~ Plan Section Information 7400.00 30.80 191.83 6674.14 -2813.96 -496.29 0.00 0.00 0.00 0.00 7420.00 31.09 196.46 6691.29 -2823.93 -498.81 12.00 1.46 23.17 85.00 7765.36 19.83 248.92 7006.29 -2932.12 -579.94 7.00 -3.26 15.19 138.95 9110.33 19.83 248.92 8271.53 -3096.17 -1005.64 0.00 0.00 0.00 0.00 K-05B Sag T1 9130.33 19.83 248.92 8290.34 -3098.61 -1011.97 0.00 0.00 0.00 0.00 9379.13 19.83 248.92 8524.39 -3128.96 -1090.71 0.00 0,00 0.00 0.00 9941.05 90,00 205.00 8835.53 -3469.06 -1335.18 13.50 12.49 -7.82 -45.68 K-05B Land T2 10141.05 90.00 205.00 8835.53 -3650.32 -1419.70 0.00 0.00 0.00 0.00 10505.61 88.63 190.48 8839.91 -3996.59 -1530.49 4.00 -0.38 -3.98 -95.45 10949.41 88.63 190.48 8850.53 -4432.85 -1611.19 0.00 0.00 0.00 0.00 K-05B TD T3 ..--,-----------..------. --..---..-.---...-----.-. .--..- ._, -.--.......----..-..,-----.-------- ---. .----...-.-----------. --- .--..,-.,---- "..---.--,-----,..... -.. .--...,.----,-,-.---....,....-,....,....- ..-... --- -----.---... ...--- ..----..., "-,...._-,-""---- -- , Section 1: Start [----~D -"----~~~-"---'-"""--~:t';"'--'~'--'- 'T~D--""-'--~+Njf--"'-"'-+Et~w"---'----~r---'-"-~~~~'~~-d~~~~dOOft:'1~TI~~ft ,-~-TJ:~----' , ',' ..' --;-l [~~~]LJHC=TfU[J~ti[~['-::~~1t~C~~_=][~LJ ~==-[[=[:_~~[-j Section 2: Start ------------_..._--_._.._-~-_._--------_..._---------------------------.-----.------.--.....-------...-------.-.--...--'----...-----..--------.---.---- , ,.. , " , , , , MD Incl Aliin TVD+.N/-S +E/-W VS ,DLS" Build, Turn, TFO -'.'. -_._..,.,_!~------,-------~.~~-_._--,---_._--~:~-,-,-,,----- --'.""-'_!~---"'---~'--'_.'~--"---'_!~---~--'-"----'------~-".__.__._--,-- ----'--_!~-----'-'."'---'--'~:_~_~_~h9~~,_9..~_~~!9_9!~-_~~~~~99!!.___...__9_~~___,.....,_. ,'. ._-"'._----'-""--h"_~-- -.---"---' 7450.00 29.54 199.26 6717.19 -2838.34 -503.44 2839.58 7.00 -5.18 9.33 138.95 7500.00 27.09 204.55 6761.21 -2860.34 -512.24 2863.26 7.00 -4.89 10.58 136.53 7550.00 24.88 210.75 6806.16 -2879.74 -522.35 2884.95 7.00 -4.42 12.40 131.87 ----------....-------.---..- ----------------..---..-.-.-,..-,-.--,.,--, ,,-..-----.-.-. --.. ----.--....----.....--.-- .._-..- '--'------------"-------.'-"- . '....--------- ----.------.-.-------,--..-,---- -------_.._---.,--,_.. - --,-.--.--,.. -"'--'-----' -,----_..- , Tolerable COI(u;ion Risk Worksheet Generic name of scenario: (for input on DEAP) DS K-05B Rev. 6 - 14 Mar 97 Description (Be specific. Include all factors which affect either the cost of collision or the cost of reducing the risk) Using conventional anti-collision rules, the K-OS8 sidetrack will violate close approach guidelines with the P & A section of well E-14. Well K-O58 MD in E-14 11,767' Planned Separation 814' (well-to-well) Use this sheet to describe a well interference scenario where ORA may be applicable. Check first that the scenario really is different from those described on existing worksheets. Ref. BPX Anti-Collision Recommended Practices Prepared by: Walter Quay Authorised by: List all the consequences of collision and the necessary remedial action 1. Penetrate subject well (E-14). Close approach point is in the horizontal portion in the Ivishak Zone 10f K-O5B and E-14 and will be under the same BHP as current drilled formation, therefore, there should be no risk of an influx / kick. 2. Could lose the drilled portion of this hole, requiring the plug back and open hole sidetrack, if unable to proceed/stuck. 3. Violated well will not require rig workover as it is the P&As tail portion of E-14. How could the probability of collision risk or the severity of the consequences be reduced? How might this impact the drilling operation? Estimate the tot I cost of collision C = $400 M The following are ways to reduce the collision probability: 1) Decrease the allowable minimum well separation by Running a gryo in E-14B to KOP from E-14 well bore and reducing the size of the uncertainty ellipses. Estimate the NPV planned well Estimate the total cost of substantially reducing the risk Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you prepared to tolerate (guideline = 0.05) F = 0.05 v= $40M Given the uncertainty in the above estimates, by how many times must the savings made from not reducing the risk outweigh the risk itself? (guideline = 20) VF Tolerable Collision Risk - - C = 0.39 M= 20 1 F = M = 0.05 VF - > 1 : close approach tolerances need not be set C v:; < 1 : CoTI~~~~~b~~Sk = 1 in ~ = 11 in 200 H.williamson, SPA Well Design 192 180 150 120 0 120 150 180 192 N:uIIU WELL DETAILS IE/-W NorthinB 1"'tinB L"titudu LonBillklu Slot 415,~R 59752~R,OO ~70710,00 70"20'IR,O~RN 14R"J(,'5J,104W N/A ('"Iunl,,'ion Mullk.l: MiuimwII ('lIrv'Jlu", Errnr Systum: ISCWSA S"'II MUlh,"¡: TmY C'ylindurNorth Emil Surl.,u: Ellipllual I C"sing W:u1ling Mu\h"¡, Rul", lJ"su~ ANTI-COLLISION SETTINGS COMPANY DETAILS IN/.S BI'Amo,o Interpolation Method:MD Depth Range From: 7400,00 Maximum Range: 1292,04 Interval: 25,00 To: 10949.41 Reference: Plan: K-05B wp08 K.05 2097,91 0 Colour , ..~ ..~, -~-~,,~ ..-- 0 270 SURVEY PROGRAM Duplh I'm Depth Tn SurvUy/PIIUI Tool 7400,00 10949.41 PI:uuII,,1:K.051JW10RVI MWD ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4500 5500 WELLPA111 DETAILS PWn K-O51J 500292t41R02 P""-'~:'~~IM~: K-O5 7400.00 lUg: Nabn'" 22E Ru[ D,tum: Plan K.05B 55.s31t V,S.'Ctinn Origin ~¡¡;~ ~~~nfVD AIIgl.: 'IN/.S 199.97" 0,00 0.00 0,00 LEGEND - ..............' -, -, .. -, f " -, _. " -, -, 90 - ".'VI""V""'.""""'. K-l0 K-IOA), M~iorRisk K.IO K-IOAPB~' M'jor Risk K-IO K-IOAPB2 , M'\i'" Risk K-IO K-IOAPBJ,M'jorRisk K-lIa(K.lla), ajorRisk K-II(K-IIJ,M,,orRlsk K.13(K.13),Ma)orRlsk - K.I~A(K-I6AJ,M~("Risk K.19A(K.19AJ,MainrRisk K.19(K-19J,MajurRlsk Plan K.05B -- K.05B W10R ( SECTION DETAILS Sue MD Ine Azi TVD -IN/.S "E/-W DLeg TFucu VSeu Turgut I 7400,(x) 30,HO 191.H3 ~~74,14 .2H13,% -49~,29 0,00 0,00 2H14.23 2 7420,00 31.09 l%o4~ ~~91.29 .2H23,93 -49R.H1 12,00 H5,OO 2R24o45 3 77~5.36 19,R3 24R,92 7006.29 .2932,12 -579,94 7,00 13H.95 2953,R5 4 9110.33 19,R3 24R.92 R271.53 -3096,17 -IOO5,~4 0,00 0,00 3253045 K-O5B Sag TI 5 9130.33 19.H3 24R,92 R290.34 .309R,~1 -1011.97 0,00 0,00 3257,90 6 9379,13 19,H3 24R.92 H524.39 .312R,% -1090,71 0,00 0,00 Hl3.32 7 9941.05 90,00 205,00 8H35,53 .3469,O~ -1335,18 13,50 -45.~8 J716,47 K-O5B Lund T2 H 10141.05 90,00 205,00 8H35,53 .3~511.32 -1419,70 0,00 0,00 3915,71 9 10505.61 88,63 190o4H H839,91 -3996,59 .1530049 4,00 .95,45 427H,99 \() 10949.41 88,63 190048 HH50,53 .4432,85 .I~I 1.19 0,00 0,00 471~,58 K-O5B 11) T3 Naill" WELL DETAILS IE/oW NorthillB Ea"illB Lalilll"" LolIBillkl" Slot 415,68 5975268.00 670710,00 70"20'18,O68N 148"JI,'51,I04W N/A COMPANY DETAILS ANTI-COLLISION SETTINGS liP Amllco IN/.S Interpolation Method:MD Depth Range From: 7400.00 Maximum Range: 1292.04 Interval: 25,00 To: 10949.41 Reference: Plan: K-05B wp08 ClIlCllllition Mull>.I: Minimum CurvIIIIIN M~:; ~~¡~~: ~~~~W~~"lcr Nonh Em" Snrface: Ellipticol' C",<inB W¡U11inB M"U>K1: Rul,,< 1111."'-" K.O5 2097,91 192 180 Colour ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4500 5500 150 120 ""_~'^_M.W, 0 0 30 0 30 0 0 SURVEY PROGRAM D"plh 1'111 Deplh Tn Survey/I'IM TIIIII 7400,00 10949.41 I'huu,"": K-O511 wpON VI MWD WELLI'A TII DETAILS Plan K-O5R 500292141802 p""-'ì\~~~Iç:;~: K'()5 7400.00 RiB: Nabllrs22E ReC Dalum: I'lan K.OSB 55.531t V$"ctilln Origin .~~~ ~~,~'1vD Angle .N/.S 199,97" 0,00 0.00 0.00 LEGEND - "'" "... . .., .. . .. '~':k - , _. -, -, ( -. _. - , -, ,. - , -, - , '",",", , -', -, -~ , , ~~"~ K.O5l1 wpOg ( SECTION DETAILS Suo MD In" A,¡ 'IVD +N/.S +E/-W DLug TFu"u VS"C TurRul I 74(){J.OO 30,80 191.83 (,(,74.14 -2811,% -4%,29 0,00 O,()O 2814,21 2 7420.00 n09 196.4(, (,(,91.29 -2821.91 -498.81 12,00 85,00 2824.45 3 77(,5.3(, 19,83 248,92 7()0(,,29 -2912,12 -579,94 7,00 138,95 2953.85 4 9110.31 19,83 248.92 8271.51 -1()%.17 -1005,(,4 0,00 0,00 3253.45 K-O5B Slig TI 5 9110.31 19,83 248,92 8290.34 -1098.(,1 ,.1011.97 0,00 0,00 3257,90 (, 9179,11 19,83 248,92 8524.39 -1128.% .1O9().?1 (),OO 0,00 1313.32 7 9941.05 90,00 205,00 8815.53 .14(,9,0(, -1135.18 13,50 -45,(,8 1716.47 K-05B I.IIndT2 8 IO141.()5 90,00 205.00 8815,53 .1(,50.32 -1419,70 0,00 0,00 3915,71 9 10505,(,1 88,(,3 190.48 8819.91 -19%.59 -1510,49 4,00 .95,45 4278.99 10 10949,41 88,(,3 190.48 8850.51 -4412,85 -1(,11.19 0,00 0,00 471(,58 K-05B TO T1 180 192 , ~11ing ylind. SAFEfY NOTES: PRE-SDTRK WELLBORE NOT SHOWN K c. --A C U rre n t Stat U S ( ìlAGRAM BELOW 9 5/8" CSG SECTION MILLED - ) .JOW @ 7578' (KO PI"). WELL> 70 deg @ 9840' AND GOES HORIZONTAL @ 10174'. SEE CAUTION BOX BELOW CONCERNING FISH IN HOLE TREE = 4" CrN, 5K WELLHEA D= MCEV OY .. ,.....,.....,..,.........................",...."..,..,.........",..,..,'...........,.,.........,... A CTUA TOR= AXELSON ",,""""'.""',"'."..W',"""',"".,",",'..','",""........'"."w""...",,"""","",... KB. ELEV = 56.03' ...............,......,..............".... ,.............,.,........., BF. ELEV = 28.22' "'"""W""'."""""'.""""""".',......"".."_W,,,""',,,.....'",.."..,..., KOP = 1450' ....."..,.....~.........",."...,......",.....,.....,.....",.."."""""""'.'.".""""'.' Max Angle = 93 @ 10519' -----..----------.--.- Datum MD = 10145' 1---",,---.--.---- Datum 1V D= 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2793' Minimum ID = 2.635" @ 9685' 3-1/2" PKR SWN NIPPLE 9-5/8"CSG,47# L-80,ID=8.681" l-i 7578' CAUTION:" FISH IN HOLE" 1 0/29/94 - TWO 6" L x 2" W BULL NOSE GUIDES FROM STRIP GUNS LEFT IN HOLE DURING ÆRF. OPS. DEPTH UNKNOWN. 1/9195 - CT LEFT IBP AND SETTING ASSY IN HOLE. DEPTH UNKNOWN. LENGTH OF FISH = 13.64' I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 9697' ÆRFORATION SUMMARY REF LOG: A WS PDK-1 00 GR/CCL 02/05/94 ANGLE AT TOP ÆRF: 68 @ 9780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-1/8" 4 9890 - 9910 0 10/29/94 2-118" 4 9830 - 9850 0 10/29/94 2-1/8" 4 9780 .. 9800 0 10/29/94 4-1/2" SLTD 10156 - 11147 0 01/03/94 8> 2125' ST 2 1 MD 4540 7369 7452' 7465' -13-112" OTIS SSSV LAND. NIP, ID = 2.750" I GAS LIFT MANDRELS 1VD DEV TYÆ VLV LATCH PORT DATE 4182 28 MMG- 7 DOME RK 16/64 10/22/97 6591 31 MMG-7 S/O RK 20/64 10/22/97 -i 9-5/8"x 7" TrN LNR TOP PKR 1 -i 9-5/8"x 7" TrN LNR HANGER 1 MILL OUT WINDOW 7578' - 7628' WI 9-5/8" SECTION MILL 9591' 9632' 9664' 9685' 9697' 9706' 1 TrN OIS SEAL ASSY WI COIL TBG GUIDE, ID = 3.920" 17" LNR, 29#, NT80, .0371 bpf, ID = 6.184" I -i 3-1/2" A<R SWS NIP, ID = 2.750" 1 -iT' x 3-1/2" BKR SABL-3 PKR, ID = 3.910" 1 -13-1/2" PKRSWS NIP,ID=2.750" I -i 3-1/2" A<R SWN NIP, ID = 2.635" I -i3-1/2" WLEG, ID = 2.870" I l-i ELMD ...... ...... ...... ...... ,"""""" ...... ...... """...... ,"""""" ...... ...... ...... ...... ...... ...... ...... ...... ...... ~ 1 PBTD l-i 11147' 14-1/2" SLOTIED LNR,12.6#, L-80, .0152 bpf, ID = 3.958" 1 11171' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/18/85 ORIGINAL COMPLETION 01103/94 SIDETRACK COMPLETION 02/22/01 SIS-SL T CONV ERTED TO CA NV A S 03/03/01 SIS-MD FINAL 07/26/01 CH/tlh CORRECTIONS PRUDHOE BA Y UNIT WELL: K-05A ÆRMrT No: 93-1560 API No: 50-029-21418-01 1935' SNL & 441' EWL, SecA, T11N, R14E BP Exploration (Alaska) TREE = 4" CrN, 5K WELLHEAD= MCEVOY , """""""""""""""""""""""""""""""'--"""""""""""""""""'" A CTUA TOR= AXELSON """""""""""""""""""""""""""""""""""""'M"""""""""""" KB. ELEV = 56.03' ...........""....."....,...".....",.... """""""""""'...." BF. ELEV = 28.22' """"~"""""""-'^""""""".'-""""',,""'-""""""""""'.," KOP = 1450' .m.m""""""','"",",-","""""""""""""""""""""""""",,,...,..".... ~.~-~-~"~~:"~"",,,,,,~~...@_~~519~. Datum MD == 10145' ---'----"------- Datum lV D= 8800' SS K-f jA Proposed Pre-Rlj 113-3/8" CSG, 72#, L-80, ID == 12.347" I 2793' Minimum ID = 2.635" @ 9685' 3-1/2" PKR SWN NIPPLE 19-5/8" CSG, 47# L-80, ID = 8.681" 1-1 7578' Tubing Cut at --7600' MD 1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 1 ÆRFORA TION SUMMARY REF LOG: A WS PDK-1 00 GR/CCL 02/05/94 ANGLE AT TOP ÆRF: 68 @ 9780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-1/8" 4 9890 - 9910 0 10/29/94 2-118" 4 9830 - 9850 0 10/29/94 2-1/8" 4 9780 - 9800 0 1 0/29/94 4-1/2" SLTD 10156 - 11147 0 01/03/94 9697' 8) 2125' ST 2 1 MD 4540 7369 7452' 7465' -l3-1/2" OTISSSSV LAND. NIP, ID=2.750" I GAS LIFT MANDRELS lVD DEV ìYÆ VLV LATCH PORT DATE 4182 28 MMG- 7 DOME RK 16/64 10/22/97 6591 31 MMG-7 S/O RK 20/64 10/22/97 -l 9-5/8"x 7" TrN LNR TOP PKR I -I 9-5/8"x 7" TrN LNR HANGER 1 MILLOUT WINDOW 7578' - 7628' WI 9-5/8" SECTION MILL 9591' 9632' 9664' 9685' 9697' 9706' 1 TrN OIS SEAL ASSY WI COIL TBG GUIDE, ID = 3.920" 17" LNR, 29#, NT80, .0371 bpf, ID = 6.184" 1 -l3-1/2" PKRSWS NIP, ID = 2.750" I -l7" x 3-1/2" BKR SABL-3 PKR, ID = 3.910" I -13-1/2" PKR SWS NIP, ID = 2.750" I -13-1/2" PKR SWN NIP, ID = 2.635" I -l3-1/2" WLEG, ID = 2.870" I l-l ELMD ,...... . ...... , " .."............ ......"',' """"""'...... ....... ...... """...... ,"""""" ...... ,...... ...... ...... ...... . " ...... . ...... ...... ~ ""I" 1 PBTD l-l 11147' 14-1/2" SLOTTEDLNR,12.6#, L-80, .0152 bpf, ID=3.958" I 11171' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/18/85 ORIGINAL COMPLETION 01103/94 SIDETRACK COMPLETION 02/22/01 SIS-SL T CONV ERTED TO CA NV AS 03/03/01 SIS-MD FINAL 08/17/01 WSI Proposed Pre-Rig PRUDHOE BA Y UNIT WELL: K-05A PERMIT No: 93-1560 API No: 50-029-21418-01 1935' SNL & 441' EWL, Sec.4, T11N, R14E BP Exploration (Alaska) TREE: 4-1/16" - 5M CIW L-80 WELLHEAD: 135/8" - 5M McEvoy SSH 13-3/8", 72 # lit , L80, BTC I 2793' Window Milled from Whipstock Top of Window at +/-7400' MD Bridge Plug set at +/-7424' MD 17452'1 7" x 9-5/8" Liner Top 110159'1 7",29 #1It, NT-80 111,171' I 4-1/2",12.6 #/ft, L-80 9-5/8", 47 #/ft, L-80, BTC I 9.208' I K-O5B Proposed Completion Cellar Elevation = 26.53' Nabors 2ES RKB = 55.53' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' +/-7250' I BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger GAS LIFT MANDRELS TVD Siz e TBD 1-1/2" TBD 1-1/2" TBD 1" TBD 1" Valve Type RP Shear DV DV DV 4-1/2" 12.6# L-80, BTC-Mod Tubing with GLM's 1 2 3 4 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +/-8,960' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" 12.6 #/ft, L-80, BTC-Mod I +/-10,950' I Plug Back Depth I +/-10,865' I I +/-9,110' 7", 26 #/ft, L-80, BTC-Mod Horizontal Sidetrack into Zone 1 Sands Cemont Date Rev By Comments PRUDHOE BAY UNIT 08/13/01 WSI Proposed Completion WELL: K-05B 10/05/01 WDO Proposed Completion API NO: 50-029-21418-02 Alaska Drilling & Wells ( BPX K-05B CTD Sidetrack (' Summarv of Operations: A combined Rotary/CTO horizontal sidetrack of well K-05A is proposed. Rotary operations, (Phase 1) and Coil drilling (Phase 2) operations are summarized below. Additional details on the rotary operation are included on a separate document. Phase 1: Rotary sidetrack. Planned for October 25, 2001 . Rotary sidetrack (see operational details enclosed on separate document) Phase 2: Drill and Complete CTD horizontal Sidetrack: Planned for January 01, 2002 2%" coil will be used to drill a 33,4" open hole sidetrack, out the toe of the 4-1/2" liner to be run by rotary, approx. 830' feet. (as per attached plan) A solid, cemented 2-7/8" liner completion will be run. The well will be perforated. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular disposal on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 2-7/8" solid liner run from approx 10,900' (8,793'TVOss) to planned td of 11,770. The liner will be cemented in place with approximately 10bbls of 15.8ppg cement and then perforated. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . MWO Gamma Ray will be run over the open hole section. . Memory CNL will be run in the cased hole after reaching TO. Hazards . H2S is not expected on K-Pad. . 3 fault crossings are prognosed, as the target is located in a graben. Lost circulation is expected. Reservoir Pressure . Reservoir pressure is estimated to be 3,300 psi (7.2ppg) at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,244 psi. ~ { K-O5B PROPOSED CompletionLJiagram Nabors 9ES RKB 55.5 est'd GL 26.53 OKB 56.03 TREE: 4" CIW 5K carbon WH: McEvoy 13 3/8" 5K Orig KOP 600' Orig Side-track 7600' Casing: 13 3/8" 72# L80 BTC 2793' 7" x 9 5/8" LH/PKR 7050 MD' CIBP/Whipstock Window 7195'MD 7" x 9 5/8" LH/PKR 7452' . Window 7578'-7628 Cement 7481 ' CIBP 7910' Casing: 9 5/8" 9208' DATE REV. BY 3-08-01 3-12-01 Schmitz McCarty COMMENTS Proposed Pre-Rig Mod itied tor CTD 4 1/2", 12.6#, L80 BTC X SSSV @2200' GLMs 4 1/2" x 7" Packer X nipple WLEG @ 9126' 7 " 26# Liner 9126' MD @TSGR 8275 TVD / 2-7/8" Prod. Liner to 11 ,768'MD / . . . . . "'J' . . 4 1/2" 12.6# Prod Liner 8975-11000' MD 21 B 8850' TVD . . . . . . -~&- . . . . . . I 4 1/2" liner 10021-11171 Slotted 10156-11147 PBTD 7 " 29#, 10159 "Liner Perfs 9780-9910' ~ f¡;::::}lei~ ¡¡:::;:"".w";<"",M""""""""'%"¡I';;"~",,,,,, § PI;, M""""""",!I,¡",."".'¡, ¡ gml¡ gff m¡¡ ""ELLPATH DETM" ".;o...,\~;~\~~,. P"."W."p"" TI,.. MO, PI.. K~'. 10900,00 "" .."Dolom' V's..H.. A.,I. Sunl., ',"mTVD On,l. 'N;.1, D"". ,".w REFEf<ENCE INFORMATION «eTODN omo" .".W .c., TO,," mmmm ¡¡~ ,ri~ mm ANNOTATIONS MD A......,.. 8793.80""0,CO <DP ,m." "'80.DO 1 '007." 11010.00 , "OS." 1176'.87 TD 8300 8400 .... .5 8500 = <::I 8550 III .... .c 8600 .... ~ 08650 Q ¡¡¡ 8700 (J :e 8750 Go! :> 8800 C!I 28850 ¡... 8900 8350 8450 8950 9000 9050 .3900 -4000 -4100 .4200 -4300 ....-4400 C ~ -4500 <::I ~ -4600 .... +' -4700 :c 1:: -4800 0 Z -4900 ;;.::;.. ..:.. .c -5000 .... :::$ 0 -5100 <Ø) .5200 -5300 -5400 .5500 -5600 T to True North North: 26.60' Magnetic Field Strength: 57503nT Dip Angte: 80.83" Date: 1011012001 Model: BGGM2001 Plan Plan #8 (K.O5IPlen#8 (GTO) K.058) Created By Bri, Pot"is Date 1011112001 com -2900.2800-2700-2600-2500-2400-2300-2200-2100-2000-1900-1800-1700-1600-1500-1400-1300-1200-1100-1000 -900 -800 -700 -600 -500 -400 -300 West(-)/East(+) [100ft/in] K-058 Fault6 3 4000 4050 4100 4150 4200 42.50 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 Vertical Section at 198.10' 10/11/2001 10:20 AM ObP (' BP Amoco ( Baker Hughes INTEQ Planning Report ...... ... ... (NT EQ '-Co~p~-~-;:--BP A~o~;--"-----'--------------------- Date; 10/11/2001 Time: 10:21 :23 .---- pa~~~------;--"l Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-05,True North I Site: PB K Pad Vertical (I'VD) Reference: System: Mean Sea Level i Well: K-05 Section (VS) Reference: Well (O.OON,O.OOE, 198.1 OAzi) i i Wellpath: Plan#8 (CTD) K-05B Survey Calculation Method: Minimum Curvature Db: Oracle I .-- - .-- -....- -....- -- - - _._on_--------. --'-'-.------- ._--.. ------.- - .--.-.----- -------.-.--...--.--.-- .------------.-.-----.---------- _.---,- --. ---------,-.--. -----, -"'----'--'-----'-- J . n_.'_"'-,--. ---n.._""""_--,---"",'------'---"'--'- ------ ,-,.-" .- "-------------,,,,-,------,----,-,"'---'-----'----'-'--------'----"'-"'--'--"--"""--'-----'----'---'-'--"---'..-..--....--..---- '------""------, ~: ~~~ I North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 \ Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ,I Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2001 . __n......___..-...-.--..--...--',,----... '_n__........""" .. """""--"""'-"-"-"""""--"-'----'---'-"----"---"---..._-----_..__..._...._-,..------_....__--_n"""""_---_'--~"n....."-" Site: . '-"-------"-'--- -- -,_,-.."-m",- -- no_. --.........-- ',--, -,-.....-... ,-,.."'-'--...-, "_n"-' _h__- ,,-...._-----------... .--.'--- ,--,-",--,--,-"--'--"------------------"-------"-"'--'"-..--.. "-'-----"'----""-"--""'---"'------"--"'-'"] I I PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5973161.33 ft 670342.1 0 ft Latitude: 70 19 57.435 N Longitude: 148 37 5.245 W North Reference: True Grid Convergence: 1.30 deg ... ..."...........-,...-.... -.""'-"-- ..,...-...--.-..-.-. .........--....-......-..-........,..,--...-.-,-....----"'------..--------_..._-,-----. ""----'-----"'--"---"'-"-"--""-""'--""'-"""-'-"-'---.....-.. ....-.-.-...-.--...-"-----.-.-----,,..--...-. ....,..--.....""""""-_.....-m"- . .,-----,.......... -.. .....---, -,........-.................... ,.--"., --. "".-"-"""'--'---'- ..............-............-.......-------..--,--.-... .......-...._...."m___..__----.... ...--------.--..---.-..--......--....--.---....-....-----..--..-...-...-...----.-..-.""-----..--."-' Well: K-05 K-05 Well Position: +N/-S 2097.91 ft Northing: +E/-W 415.68 ft Easting: Position Uncertainty: 0.00 ft Slot Name: 5975268.00 ft 670710.00 ft Latitude: Longitude: 70 20 18.068 N 148 36 53.104 W ".....-............---..---... .....-. ....-.".---- .-......-."....................---....--.--..-'-.....-........._____m-...'-....-..........-... .m................,..---. ...-....--...........-...-.................. .. '-........--..... ..., --.. -,...-.-.............-...-... ....."..,.,.""-,,,-"""""'-......-,............. --...-----.-...--------.-,...-----,---.----....---.,............""'-"-""'-'--'-""..--.....----.."".-""'-"--""-.---".....-.....--.......---'--"----".---- """'--""'."--"--'-- "",-"""",,-,.,-"-""'__.n'_...._----'" Wellpath: Plan#8 (CTD) K-05B 500292141802 Current Datum: Plan K-05B Magnetic Data: 10/10/2001 Field Strength: 57503 n1' Vertical Section: Depth From (TVD) ft 0.00 Drilled From: Plan K-05B Tie-on Depth: 10900.00 ft Height 55.53 ft Above System Datum: Mean Sea Level Declination: 26.60 deg Mag Dip Angle: 80.83 deg +N/-S +E/-W Direction ft ft deg .-.- ,... '-"""."""."""'-'---..-........"""".'.""""-"'---.......'- """"""""-,,-,,,,--"'---.....-...."'-'--"---""'-"--"'-"-----"-,-----......,...--"--....-.--.-.-..-"" 0.00 0.00 198.10 . -""'--""""'-"'---"".'-'--"'--'-"-"'-'-"-" -...-,.,-....".--.. "--"---""'----'-""-..-..-'--' "-""",-"""",-"-------,-""""-,,,,,,,'.""""'.""'-'----"-._--'. .... .-..-. -..-.....-.-.-, -----...--...,..... --......,......,........-. - ......,.",... .,.....".........-"'" " . .. - .....-..--... '-"" . ...., .... Plan: Plan #8 . Tied to Rotary Plan #8 Principal: Yes Date Composed: Version: Tied.to: 10/11/2001 1 From: Definitive Path Targets , , ,', ..'..' ':'.Qescriptio~ ", .'¡ ""',,TvD. ,.'" .", .'+N/-$. " .',;~/~W,',"',i.'.' ."i~ottlj¡l1g"" .'" ',:..,'~å~tin~'..Jj~gJV[in~'Sec..~"':J)èg'M¡~'Seç'"~...,....,i,"" .. ..".",. ,.:,., ,. ..- ~_.-. ........-..'.._...1: _::~.;:.L",..'"l;E.,._...:.".--:.. .,.,L...c....c:'-_c. ~,~..:~LI!..i_~::L..._;L~_&L;_~~:,:~j:2:...l" ~..':~_L.:..."_..,, ":,,L::~...~.~.KL ":~...u..'_L.tt:f~~i:~;:lŒ:~.'...":_".:~.!..:,,,.i.!:,lL;.:..:::..,,:;.L....i:~~,._,._.i.:,._..U_.,¡.j¡~j~-,--...~J:.': ,....i,ii...._.,., K-05B Fault6.1 0.00 -4682.83 -1967.98 5970541.89 668849.27 70 19 32.010 N 148 37 50.548 W -Polygon 1 0.00 -4682.83 -1967.98 5970541.89 668849.27 70 19 32.010 N 148 37 50.548 W -Polygon 2 0.00 -4600.96 -1785.06 5970627.90 669030.26 70 19 32.816 N 148 37 45.209 W -Polygon 3 0.00 -4621.84 -1658.49 5970609.91 669157.27 70 19 32.611 N 148 37 41.514 W -Polygon 4 0.00 -4775.56 -1452.92 5970460.92 669366.27 70 19 31.099 N 148 37 35.513 W -Polygon 5 0.00 -4621.84 -1658.49 5970609.91 669157.27 70 19 32.611 N 1483741.514W -Polygon 6 0.00 -4600.96 -1785.06 5970627.90 669030.26 70 19 32.816 N 148 37 45.209 W K-05B Fault6.2 0.00 -5565.32 -2047.05 5969657.89 668790.32 70 19 23.331 N 148 37 52.849 W -Polygon 1 0.00 -5565.32 -2047.05 5969657.89 668790.32 70 19 23.331 N 148 37 52.849 W -Polygon 2 0.00 -5434.18 -1831.00 5969793.91 669003.31 70 19 24.621 N 148 37 46.544 W -Polygon 3 0.00 -5399.14 -1744.18 5969830.91 669089.30 70 19 24.966 N 148 37 44.010 W -Polygon 4 0.00 -5424.93 -1621.72 5969807.92 669212.31 70 19 24.712 N 148 37 40.436 W -Polygon 5 0.00 -5317.93 -1356.21 5969920.93 669475.30 70 19 25.765 N 148 37 32.687 W -Polygon 6 0.00 -5424.93 -1621.72 5969807.92 669212.31 70 19 24.712 N 148 37 40.436 W -Polygon 7 0.00 -5399.14 -1744.18 5969830.91 669089.30 70 19 24.966 N 148 37 44.010 W -Polygon 8 0.00 -5434.18 -1831.00 5969793.91 669003.31 70 19 24.621 N 148 37 46.544 W K-05B Fault6.3 0.00 -4979.57 -1763.65 5970249.91 669060.28 70 19 29.092 N 148 37 44.582 W -Polygon 1 0.00 -4979.57 -1763.65 5970249.91 669060.28 70 19 29.092 N 148 37 44.582 W -Polygon 2 0.00 -4887.31 -1421.44 5970349.93 669400.28 70 19 30.000 N 148 37 34.594 W K-05B Polygon 6.2 0.00 -4829.37 -1770.25 5970399.91 669050.27 70 19 30.569 N 148 37 44.775 W -Polygon 1 0.00 -4829.37 -1770.25 5970399.91 669050.27 70 19 30.569 N 148 3744.775 W -Polygon 2 0.00 -4933.89 -1572.56 5970299.92 669250.28 70 19 29.542 N 148 37 39.004 W -Polygon 3 0.00 -5231.56 -1679.35 5969999.92 669150.30 70 19 26.614 N 148 3742.119 W -Polygon 4 0.00 -5179.30 -1778.20 5970049.91 669050.29 70 19 27.128 N 148 37 45.005 W , .._,_.., ..... -"'" ""."""","--"---'-""'-'-'--,----.-.-..."""""--"--"'--..-,-.-....-...--......-.-,.. . "'-",-..-.-....-...-.-'....__m..... . ",,-,,'--"."----"""'" ......---.-..,.....,...-"---....---.......---...-..--.,,.......-...--,.-......_"..,.... ---""""""""'......'--'--""-' .. ....,..-..-...""....-....--.-.......---....'" ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report .J&'. lUG... INTEQ r Company: BP Amoco - ------- Date: 10/11/2001 Tim;'--10;21';3------- Page~--2---1 I Field: Prudhoe Bay Co-ordinate(NE) R, eference: Well: K-05. True North !I Site: PB K Pad Vertical (TVD) Reference: System: Mean Sea Level Well: K-05 Section (VS) Reference: Well (0.00N.0.00E.198.1 OAzi) I Wellpath: Plan#8 (CTD) K-05B Survey Calculation Method: Minimum Curvature Db: Oracle ¡ l- ----. --- ----,'------ --'----'-- ----------------- ---------,--- ---. ----..-------- ---'--------.-----------------------.----.---...---.---------.-------,-.---------- '--'----------'-'--.---.-----" Targets r--~:~~-------.:seri~~::-'-----; -----:~/: ----:ii~---~~~.g -~~~g --~ ~mfitn~ ;-~ ~~~ ~¡ 1-- --, -'- -"-'--_h'_"'__'_'___h"'__--"".._h'- _---____h_,____--,,-- -- -'-____-,h__'_- "'___h__'_h____--'-"_h_-""--'---'--'---------------"---'------------'--'------------'_,,- ----------------"-,-----,----______h'. -______h,'____-'-----__,_._h_, , K-05B Polygon6.1 8780.00 -3236.49 -1433.96 5971999.92 669350.18 70 1946.236 N 148 37 34.968 W -Polygon 1 8780.00 -3236.49 -1433.96 5971999.92 669350.18 70 1946.236 N 148 37 34.968 W -Polygon 2 8780.00 -3295.57 -1035.17 5971949.94 669750.19 70 19 45.656 N 148 37 23.326 W -Polygon 3 8780.00 -3887.50 -1398.73 5971349.93 669400.22 70 19 39.833 N 148 37 33.936 W -Polygon 4 8780.00 -4485.12 -1512.34 5970749.92 669300.25 70 19 33.956 N 148 37 37.249 W -Polygon 5 8780.00 -4429.45 -1761.16 5970799.90 669050.25 70 19 34.503 N 148 3744.513 W -Polygon 6 8780.00 -3584.15 -1541.89 5971649.92 669250.20 70 19 42.817 N 148 37 38.117 W K-05B T6.1 8795.00 -5156.58 -1677.65 5970074.91 669150.29 70 19 27.352 N 148 37 42.070 W '-"'-_0----',--'-,---,-,-----------,-,------,,--,--,-,.,h'_h____,_---'-------,--.- '----""--'-'- Annotation - "-'--'-"'------------------"--"~--"""'-'C""'-"" ,-----_._-,-.-.----'-- --------'----,--""--' '-~---'~---_____"h___"'_'""._-, --..,,-----.--."'--- --C-'------'__--_-_h_____'----'..,--- '--"';~-'_h_,_'_----"-----""---'-------------;;-'-----'--"----~.-----'--_..__..,-~- -"---"" , MD - TVD ft "- ft, 10900.00 8793.80 11160.00 8799.80 11570.00 8807.88 11769.87 8905.93 KOP 1 2 TD ..- ". ,-,- --"" -"'-"'-h..-__.."----,--."""..,--"..,,,-,-, "",--",-..""""--"-,,..._,------,-,,-_._.._--_...._----,,.,,--_."-.-------"..--.___h...___h_,,_,,_,,...--,,-------..---------------..-----...---.------..-----------------..---------------------------- Plan Section Information ,n .,,1 "d,e9,11""I"I",II""lld!:l9,,""', ':"'"":",ft".""."',,,,,, ",,,',," ',',ft""",'."'.",,,","-~' "",-"..I,.I".ft""II,'III-:'_",..II",'d~gt~O()ft",'~eQl,11"P"O"I,~d~g_"POO,ff:'dØ$;J"I.', """",,,' I I I I I ,..c_,...._,.., """,-,,-- ..,-..""-'_..".,,.., h-,..",___...L_.., """----"'" ,.._1_, "-~.."---""_...."",....."--""-.....L,__,,..,-,,..,,_..,,,,,,---,,-,~_..,,,""'-""" """,_"""""_"""----,-""""_""""._-"",~""",,-,,,,,.,",,-~-"'.",,"-""-"",-~,,..__..,~._.,,.,,_.._., ""'-""--h'" "".._.."""1_""..""",..-"".."--,,,, ........-... "",..,.,"-"" .C,_I_",~ ,.,;: -: ",--,,'.. ",-",-------" .-"," 10900.00 88.63 190.48 8793.80 -4384.37 -1602.18 0.00 0.00 0.00 0.00 11160.00 88.77 164.47 8799.80 -4641.82 -1590.84 10.00 0.05 -10.00 -90.00 11570.00 89.07 205.48 8807.88 -5041.54 -1625.65 10.00 0.07 10.00 90.00 11769.87 29.11 205.48 8905.93 -5189.37 -1696.10 30.00 -30.00 0.00 180.00 --'--"----------------------""'--"--___"h"'__"------"""---,,,..-......"-..--,-..---"..-..-----......,,,,---.. ""--"'---"h"-"--"-------"'-""---"'-"---'-----"""-'h----..---..---"--'-"'-"""---"---""""'------"'----"""""""----""'--'-----.-.-"'....- _h"""h_.._..--_-"-".,-"--"-""""'__"'h""""_,-",,',,,.-----..,--,-, ..., Survey ,'"'"",,.ff" ,'1"I"",I',""""""dil"""","id"""..""",II",t1'",,.'":",""',.iJf"'ft',,',,.,,, : ",',',' ">-,ft""".,, " ,""'I""I"I"'"""'.,'"I."",,"..',,ft,:"~~d""/~OÐftff..'"'.','"II.:,"',,".,"d'I'I',,""',,,,",:,""".,,",I."':,'"'.,,' ,. -- ----- ,,¿:- :. :-...... è, ,- _L: ~".i:~9:L~';;L~.~;~&:,. ..ecL:.. ,: ~~~---~:, ¿ ::,~ ," L~: i: "-,,:L,,, ,: ~~i:L- J_. ~f~L_;:.:: _,~:.L ~L:;:., -~~;&,~ i¿~:--- ,-.':ê_cL_l ~:, ~,~ L:1 ;_L:~:~~:,;,_:; -~,;,".~, ...,~ :_:~-",~~~--,,:,,~,,: ::"" L~,~:~:_:,-' :~: :~_:~-~CU,,--~, 10900.00 88.63 190.48 8793.80 -4384.37 -1602.18 5970848.59 669208.15 0.00 4665.17 0.00 KOP 10925.00 88.63 187.98 8794.39 -4409.04 -1606.19 5970823.84 669204.71 10.00 4689.86 270.00 MWD 10950.00 88.64 185.48 8794.99 -4433.86 -1609.12 5970798.96 669202.34 10.00 4714.36 270.06 MWD 10975.00 88.64 182.98 8795.58 -4458.78 -1610.96 5970774.00 669201.07 10.00 4738.62 270.12 MWD 11000.00 88.65 180.48 8796.18 -4483.76 -1611.71 5970749.01 669200.88 10.00 4762.60 270.18 MWD 11025.00 88.66 177.98 8796.76 -4508.75 -1611.38 5970724.04 669201.79 10.00 4786.25 270.24 MWD 11050.00 88.68 175.48 8797.34 -4533.70 -1609.95 5970699.13 669203.79 10.00 4809.52 270.30 MWD 11075.00 88.69 172.98 8797.92 -4558.56 -1607.44 5970674.33 669206.86 10.00 4832.38 270.35 MWD 11100.00 88.71 170.47 8798.48 -4583.29 -1603.84 5970649.69 669211.02 10.00 4854.77 270.41 MWD 11125.00 88.73 167.97 8799.04 -4607.84 -1599.17 5970625.25 669216.25 10.00 4876.65 270.47 MWD 11150.00 88.76 165.47 8799.59 -4632.17 -1593.43 5970601.07 669222.54 10.00 4897.99 270.52 MWD 11160.00 88.77 164.47 8799.80 -4641.82 -1590.84 5970591.48 669225.35 10.04 4906.36 270.65 1 11175.00 88.77 165.97 8800.12 -4656.32 -1587.01 5970577.07 669229.51 10.02 4918.96 90.05 MWD 11200.00 88.77 168.47 8800.66 -4680.70 -1581.48 5970552.83 669235.59 10.00 4940.41 89.97 MWD 11225.00 88.78 170.98 8801.20 -4705.29 -1577.03 5970528.34 669240.61 10.00 4962.40 89.91 MWD 11250.00 88.78 173.48 8801.73 -4730.05 -1573.64 5970503.67 669244.55 10.00 4984.88 89.86 MWD 11275.00 88.79 175.98 8802.26 -4754.94 -1571.35 5970478.84 669247.41 10.00 5007.82 89.81 MWD 11300.00 88.81 178.48 8802.78 -4779.90 -1570.14 5970453.91 669249.19 10.00 5031.18 89.75 MWD 11325.00 88.82 180.98 8803.30 -4804.89 -1570.02 5970428.93 669249.88 10.00 5054.90 89.70 MWD 11350.00 88.84 183.48 8803.81 -4829.87 -1570.99 5970403.94 669249.47 10.00 5078.94 89.65 MWD 11375.00 88.85 185.98 8804.31 -4854.78 -1573.05 5970379.00 669247.98 10.00 5103.25 89.60 MWD 11400.00 88.88 188.48 8804.81 -4879.57 -1576.20 5970354.14 669245.40 10.00 5127.80 89.55 MWD 11425.00 88.90 190.98 8805.30 -4904.20 -1580.42 5970329.42 669241.74 10.00 5152.52 89.50 MWD I 11450,00 88.92 193.48 8805.77 -4928.63 -1585.71 5970304.88 669237.01 10.00 5177.38 89.45 MWD 11475.00 88.95 195.98 8806.23 -4952.80 -1592.07 5970280.57 669231.20 10.00 5202.34 89.40 MWD ----,-.--,..-.-....-..-.....-.... , ..-....--.. "--"""'---""""""-""-""--'-"""----"""----""----'-"-----'"'---""---""""-----""",h'".."..--.. ----,..,..-....,----.." "'---"--""""-"'-'-----------"-"--"---'---""""-""-""----""-'-""",----""'-----'-""---,..""'- ",..-"-,..-....--.,,....--..-"'----""--""""" ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report B.8 .... INTEQ 1- --.. -- ._-- . Company: BP Amoco Date: 10/11/2001 Time: 10:21:23 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-05, True North Site: PB K Pad Vertical (TVD) Reference: System: Mean Sea Level -. ;;;:~~~~:._-~~~~~- ~~~~tK-o~~._---_._----_.__._._---------__~~;~f:u~;;~;!~!~~~~~~~O~~~~~~~ 98'_:~_~;b: -___~~~Ie -----_J Survey r----MO---'--- Incl----A~¡;;----SST-Vï>-'-Nìš------- EJW .. MapN MapE DLS -----V-S-----'---TFO --'-T~I ---1 I'~T ~~]g--":: :--~~~-- ::Hf" i~~:- -:~~-~~ ~g~~: ~f :~~:: ¡~ .. ~~l~~:~-- ;~~f~ær .1 I 11550.00 89.04 203.48 8807.55 -5023.34 -1617.36 5970209.48 669207.52 10.00 5277.24 89.27 MWD I 11570.00 89.07 205.48 8807.88 -5041.54 -1625.65 5970191.10 669199.65 10.00 5297.11 89.25 2 I 11575.00 87.57 205.48 8808.03 -5046.05 -1627.80 5970186.54 669197.60 29.99 5302.07 180.00 MWD " Page: 3 11600.00 80.07 205.48 8810.71 -5068.47 -1638.48 5970163.88 669187.43 30.00 5326.70 180.00 MWD 11625.00 72.57 205.48 8816.62 -5090.38 -1648.93 5970141.74 669177.49 30.00 5350.77 180.00 MWD 11650.00 65.07 205.48 8825.65 -5111.41 -1658.95 5970120.49 669167.95 30.00 5373.87 180.00 MWD 11675.00 57.57 205.48 8837.64 -5131.20 -1668.38 5970100.50 669158.98 30.00 5395.61 180.00 MWD 11700.00 50.07 205.48 8852.39 -5149.40 -1677.05 5970082.10 669150.72 30.00 5415.61 180.00 MWD 11725.00 42.57 205.48 8869.64 -5165.71 -1684.83 5970065.62 669143.32 30.00 5433.53 180.00 MWD 11750.00 35.07 205.48 8889.10 -5179.85 -1691.56 5970051.33 669136.91 30.00 5449.06 180.00 MWD 11769.87 29.11 205.48 8905.93 -5189.37 -1696.10 5970041.71 669132.59 30.00 5459.52 180.00 TO - .. ..-.... """""_..0'-0-_.'_'-"'" ""'" -"-""'-""---,,,-,----",","..-..-__..._m--._....-"'-"""""-""""--...--..-...--..------.--....----'--.......-----'....... ..,-. --... ,...-.,,-,-......-..._____.0._____...,-----------..,,-,--_._0"'_,_-,--"",--,-",--"-,--,-,,,-,-,,---,,-,,--,-------""-""-'-"'.--'...'..'-'--"'" ( 38 CTD BOP Detail ( Methanol Injection 8tis 7" WLA Quick onnect - 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold 8 0 7-1/16" ID, 5000 psi worKing pressure Ram Type Dual Gate BOP~ TOT Manual over Hydraulic MOJ 5/21/01 XO Spool as necessary Single Manual Master Valve (optional depending on RU) - CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold I 27/8" Combi Pipe/Slip I 23/8" Combi Pipe/Slip 2 flanged gate valves 7" Annulus o~ 9 5/8" Annulus I I ./ ,/ ( ( H 194725 ~ ~ECK NO I 94725 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 072701 CK072701P PYMT OMMENTS: HANDL NG I N8T : 100.00 Per it To Drill ee 8tH - Terrie Hub Ie X4628 ~.Œß TOTAL ~ E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 194725 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 """"'4'12 00194725 PAY , ' , ' ONE HUNDRED & OO/100~**it****************:***************** US DOLLAR "DATE 07/31/01 l'::'"..l ' .:. . AMOUNT .. ~100'0()1 To The ORDER Of ALAE!~A OILANQ 'G~S . c;ON$ERV~T I Q~çOM~n aSIaN :333 WEST 7"tHþ.VEI'I\.lE SUITE 100 ." .' ANCHORAGE NO:rVALlPAF[ER1~Ö DAYS AK 99501 " , . . ,,' n'~,',..,. '9;,...'.,',..:,:,...:1).'.,.,:,...,.,,t~,'".,::..,",~ t:"."".. \ <- ,". .,.,",.,~~ -,..~<,_w:,,:' 1\1 . 9 ~ 7 2 5 III I: 0 ~ . 2 0 ~ B 9 5 I: 00 B ~ ~ . 9 1\1 ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER tJ$J. // 1/ /\ Ct<. WELL NAME. . lA... ""'L/\~ CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS OPTIONS MULTI LA TERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT RED RILL / PILOT HOLE (PH) EXPLORA TION INJECTION WELL ANNULAR DISPOSAL <-> YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL. "CLUE" The permit is for a new wellbore segment of existing well . . Permit No, . API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(£), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logS acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <-> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. 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) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY PROGRAM: exp - dev ~ redrll FIELD & POOL . U " INIT CLASS GEOL AREA !3 'j() ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2 L as moo t ~ N ..$¿;:ý ..¡ t:..c.?- Ú'-' . ~ . e enu rappropriae;;-r:................. 3. Uniquewellnameandnumber.................. 'N t'~,/,i..d .¡;Õ. t"", ,-1VL 02.f):3t:;.)c/' 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . 0-- ~ N 6. Well located proper distance from other wells.. . . . . . - . . ' N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . "\N, 8. If deviated. is wellbóre plat included.. . . . . . . . . . . . . . iN ) 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . 'j) N 11. Permit can be issued without conservation order. . . . . . . . ~ N 12. Permit can.be issued without administrative approval.. . . . . )N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N : ¡: ~~~:;;~~~ES~':t~~'~~~~~~ i ~~rl"~g: ": ": ": ": . ~ ~1- ~ ',~n ~ L ~~ ~ (;vdt¡ ~ A 17. GMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y ~) ~'òt: ~ ~,,"\"'.:>~"'~~ '-".s£ \ 18. CMT will cover all known productive horizons. . . . . '. . . .. 'N ' 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Cð.\~~\~~ ~ ~ ~ 1 ~~~(è~ ~\..\. 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~a \ - ~ ':;) ~ \ - ~ \ ~. '" 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N <.-\ö~Q.. ~~~~D.~~~ "'\.~t\...~~~\@.~.Y 23. If diverter required, does it meet regulations. . . . . . . . . . ...¥ N ~ ~ 24. Drilling ,fluid program schematic & equip list adequate. . . . . N £?TE ~~: ~g~~spr~~~:~=~;;~:~~;nt~sit¿ . . . 2,;~ . ¿slg: ~~Þ..<;'V ~>t @ ;p.\C)Co Ç>~\, ~SoD\~ ~~~ ~~ ~~ ~ ci>1\ ,~ . 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . . . N.. .;::) ~ 28. Work will occur without operation shutdown. . . . . . . . . . . N """-. ~ ~ . ~ ~ ~ ~ '.. ~ ~~ 29. IspresenceofH2Sgasprobable................. Y <tD \-,,~.. ~~~\ ~~c::..""-' !(" ~ Ot'\.'t\'3~ ,~,,~~\\\~ \:W1'S;.'(.~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . '. Y úD. ,5" ¿,~ , , ' $'~ .~&?f. Irzt h~ /~.'- ~ "'a.." . 31. Da~a ~resented. on potential overpressure zones. . . . . . . Y N ð )~ . r /;>';2../ /() ~//L-- z;) ~~'k Mt:t..{c:.A ~ ;£t.'"ðl, 32. SeIsmIc analysIs of shallow gas zones. . . . . . . . . . . . . Y N V V -r, E 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N 't:>¡ 34. Contact name/phone for weekly progress reports [exploratory only] Y N S POSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; " " (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL GY: ENGINEERING:' UIC nular COMMISSION: ~þ W WM E \0 serv well bore seg _ann. disposal para req - UNIT# 0//652'....) ON/OFF SHORE On ~u (/:>1-c APIpfi. D ~/c ANNU R c 0 Z 0 -f ~ ::0 - -f m - z -f J: 7 - CJ) » ::0 m » ~ GEOLOGY { APPR DATE Y N Y N Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) (' ( Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronoiogicaUy organize this category of information. ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 09 11:56:33 2002 Reel Header Service name. ""'" .... .LISTPE Date.....................02/09/09 Origin...................STS Reel Name.... .......... ..UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name............ .LISTPE Date.....................02/09/09 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11182 P. ROGER R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MM-1l182 P. ROGER J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Writing Library. K-05BPB1 Upper 500292141870 BP Exploration Sperry Sun 09-SEP-02 MWD RUN 3 AK-MM-11182 P. ROGER R.BORDES 4 llN 14E 1935 441 .00 55.03 26.53 I(, Scientific Technical Services Scientific Technical Services Sect. (Alaska), Inc. MWD RUN 4 AK-MM-1l182 P. ROGER R. BORDES 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7410.0 8.500 7.000 9141.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE ¿}yo /-~Olp / I 039 ( ( STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL CASING AND IS NOT PRESENTED. 3. MWD RUNS 2, 3, & 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD). 5. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 7403' MD, 6677' TVD TO 7410' MD, 6683' TVD. 6. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 9104' MD, 8262' TVD TO 9141' MD, 8297' TVD. BEHIND CASING FROM 9097' MD, 8255' TVD TO 9141' MD, 8297' TVD. RESISTIVITY DATA LOGGED 7. THE MWD SERVICES IN THE UPPER SECTION OF THIS WELL ARE PERFORMED BY SPERRY-SUN DRILLING SERVICES. THE FINAL SECTION OF THIS WELL ARE PERFORMED BY ANADRILL. THE MWD SERVICES IN 8. DIGITAL DATA AND LOG DATA IS DEPTH CORRECTED TO THE PDC GR LOG OF 12/31/01 WITH KBE = 55.03' A.M.S.L.. THIS WELL KICKS OFF FROM K-05 AT 7410' MD, 6683' TVD (TOP OF WHIPSTOCK). ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1 - 5 REPRESENT THE UPPER SECTION OF WELL K-05BPB1 WITH API # 50-029-21418-70. THE UPPER SECTION OF THIS WELL REACHED A TOTAL DEPTH OF 10900' MD, 8843' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED SBD2 = SMOOTHED SCO2 = SMOOTHED BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR FORMATION EXPOSURE TIME BULK DENSITY (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE ii.'i , ( ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: MUD FILTRATE SALINITY: CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: GICC MATRIX DENSITY: GICC LITHOLOGY: SANDSTONE $ HOLE SIZE: 6.125" MUD WEIGHT: PPG 8.4 400 - 900 PPM 11,500 PPM CHLORIDES 1. 00 2.65 File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/09/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPX RPS RPM RPD GR ROP NPHI FCNT NCNT PEF DRHO RHOB $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 7405.0 7405.0 7405.0 7405.0 7405.0 7408.0 7445.0 9131.0 9131.0 9131.0 9144.0 9144.0 9144.0 STOP DEPTH 10867.5 10867.5 10867.5 10867.5 10867.5 10860.5 10909.0 9849.0 9849.0 9849.0 9864.0 9864.0 9864.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 7408.0 8831. 0 8837.0 8843.5 8846.0 8850.0 8856.0 8860.5 8889.5 8896.5 8900.0 8906.5 8909.5 8914.5 8924.5 8928.5 8932.0 8947.0 8950.0 8956.0 8956.5 DEPTH GR 7403.0 8826.0 8831.0 8838.0 8839.5 8841. 5 8847.0 8853.0 8883.0 8888.5 8895.5 8901.0 8904.0 8912.0 8919.5 8923.5 8927.5 8945.0 8949.0 8955.0 8956.5 'I ~( ( 8963.5 8976.0 8984.0 8985.0 8991.5 8995.0 8998.5 9006.0 9008.5 9009.5 9013.0 9022.0 9030.0 9041.0 9043.0 9048.0 9052.5 9054.5 9056.5 9065.5 9069.5 9087.5 9092.0 9101.0 9103.0 9131.0 9139.5 9142.0 9150.5 9156.0 9160.5 9174.0 9184.0 9198.0 9202.0 9217.5 9223.0 9227.5 9229.5 9234.5 9246.5 9247.5 9254.5 9266.5 9276.0 9285.5 9292.5 9304.5 9321.0 9339.5 9344.5 9370.5 9380.5 9400.0 9407.5 9422.5 9439.5 9456.0 9470.5 9474.5 9479.0 9482.0 9483.5 9492.0 9514.5 9520.5 9524.0 9529.5 9533.0 9537.5 9569.5 9572.5 9583.5 9589.5 9593.5 9611.5 8962.0 8973.5 8981. 0 8983.0 8986.0 8993.5 8998.0 9004.5 9006.0 9008.0 9011.5 9019.0 9027.0 9038.0 9041.5 9046.0 9050.0 9052.0 9053.0 9063.5 9070.0 9088.0 9092.5 9098.0 9101.5 9131.0 9140.5 9144.5 9152.5 9158.0 9163.0 9178.0 9185.0 9199.0 9203.0 9220.0 9225.0 9229.5 9231. 5 9236.5 9247.5 9249.0 9255.5 9268.0 9277.0 9291.5 9297.0 9309.0 9323.0 9340.5 9344.0 9372.0 9381.5 9402.0 9412.0 9425.0 9442.0 9457.0 9471.0 9475.5 9479.0 9481.0 9483.0 9491.5 9515.5 9522.5 9525.0 9529.5 9533.5 9537.5 9569.0 9573.0 9584.5 9592.0 9595.0 9610.5 (' \( 9617 . 0 9621.0 9627.5 9632.5 9654.5 9668.5 9672.0 9673.5 9685.0 9691.5 9698.5 9703.5 9717.5 9727.0 9733.0 9743.5 9756.0 9768.5 978 0.5 9794.0 9801.5 9815.0 9821.0 9824.5 9864.0 9885.0 9889.5 9905.0 9923.0 9929.0 9935.5 9945.5 9962.5 9966.0 9970.0 9976.5 9988.5 9994.0 10001. 0 10011. 0 10042.5 10056.5 10066.0 10069.5 10076.5 10083.5 10091. 5 10104.0 10106.5 10123.0 10155.5 10161. 5 10172.5 10181. 0 10190.0 10197.5 10208.5 10223.5 10243.5 10259.0 10279.5 10286.5 10308.0 10310.0 10319.5 10324.5 10332.5 10339.0 10350.5 10361. 5 10367.0 10374.5 10379.0 10387.5 10388.5 10398.5 9616.0 9619.5 9625.5 9629.5 9652.0 9666.5 9670.0 9671. 5 9682.5 9690.0 9698.0 9703.5 9716.0 9725.5 9732.5 9741.5 9754.0 9765.5 9778.0 9792.0 9802.5 9815.0 9819.5 9824.0 9864.5 9887.0 9891.5 9904.5 9920.5 9925.5 9934.0 9945.0 9960.5 9963.5 9968.5 9974.5 9985.5 9991.0 9998.5 10009.0 10039.5 10050.5 10062.0 10067.0 10074.0 10082.0 10093.0 10102.0 10105.5 10120.0 10154.5 10160.0 10170.0 10181. 0 10187.5 10195.0 10206.5 10221.5 10240.5 10255.5 10277.5 10284.5 10304.0 10307.5 10316.0 10320.0 10328.0 10336.0 10346.0 10357.5 10362.0 10369.0 10373.5 10382.0 10384.5 10393.5 ~' ( 10399.5 10414.5 10418.0 10433.5 10446.0 10457.5 10478.5 10485.0 10508.5 10519.0 10527.5 10541. 0 10570.0 10573.0 10578.5 10581. 5 10586.5 10593.5 10595.5 10601.5 10604.5 10608.5 10613.0 10618.0 10619.5 10622.0 10632.5 10640.0 10650.0 10653.0 10656.0 10664.5 10674.5 10681. 5 10698.5 10714.5 10730.0 10735.0 10740.5 10752.5 10757.0 10761. 0 10781. 5 10807.5 10812.5 10821. 0 10831. 0 10836.5 10843.0 10852.5 10854.0 10909.0 $ 10395.0 10410.0 10413.0 10430.5 10441.5 10452.0 10474.0 10479.5 10502.5 10513.5 10522.5 10534.0 10564.0 10567.5 10572.0 10574.5 10580.5 10587.0 10589.5 10594.5 10599.0 10602.5 10606.5 10610.5 10612.5 10616.0 10627.0 10635.5 10644.0 10647.5 10649.5 10657.0 10667.0 10674.0 10690.5 10708.0 10723.5 10727.0 10732.5 10744.0 10749.5 10753.0 10772.5 10800.5 10804.5 10813.5 10823.0 10828.0 10834.5 10844.0 10845.0 10900.0 # MERGED DATA PBU TOOL MWD MWD MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 2 7400.0 3 8290.5 4 9141.5 5 9943.0 MERGE BASE 8290.0 9141.0 9942.5 10900.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ... """"" ...Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O I( ( 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 HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7405 10909 9157 7009 7405 10909 ROP MWD FT/H 0.07 219.32 73.0756 6929 7445 10909 GR MWD API 11.42 581.23 99.8121 6906 7408 10860.5 RPX MWD OHMM 0.43 1570.8 19.4265 6926 7405 10867.5 RPS MWD OHMM 0.5 1825.53 23.4207 6926 7405 10867.5 RPM MWD OHMM 0.62 2000 37.4389 6926 7405 10867.5 RPD MWD OHMM 0.62 2000 54.4337 6926 7405 10867.5 FET MWD HR 0.28 78.11 3.32877 6926 7405 10867.5 NPHI MWD PU-S 4.34 58.96 20.8312 1437 9131 9849 FCNT MWD CP30 104.84 2611. 87 727.302 1437 9131 9849 NCNT MWD CP30 12972.6 45557 27591. 6 1437 9131 9849 RHOB MWD G/CM 2.1 2.96 2.34835 1441 9144 9864 DRHO MWD G/CM -0.16 0.53 0.0750937 1441 9144 9864 PEF MWD B/E 1. 21 7.88 2.51448 1441 9144 9864 First Reading For Entire File......... .7405 Last Reading For Entire File....... ... .10909 File Trailer Service name............ .STSLIB.OOI Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/09 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...... .02/09/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOI Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log B IT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS RPM 2 header data for each bit run in separate files. 2 .5000 START DEPTH 7400.0 7400.0 7400.0 STOP DEPTH 8245.5 8245.5 8245.5 ( RPD FET GR ROP $ 7400.0 7400.0 7403.0 7440.0 8245.5 8245.5 8253.5 8290.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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. 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: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ..... ....0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record.. ... ...... ..Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O ( 14-NOV-01 Insite 4.05.5 66.16 Memory 8290.0 17.8 30.7 TOOL NUMBER PB02274HRG6 PB02274HRG6 8.500 LSND 10.00 58.0 8.8 800 3.5 2.250 1.448 2.000 1. 500 74.0 118.7 70.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 ~' \t ( First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7400 8290 7845 1781 7400 8290 ROP MWD020 FT/H 0.72 219.32 93.4986 1701 7440 8290 GR MWD020 API 48.18 293.23 142.848 1702 7403 8253.5 RPX MWD020 OHMM 1. 52 1570.8 6.96557 1692 7400 8245.5 RPS MWD020 OHMM 1. 95 1825.53 7.28316 1692 7400 8245.5 RPM MWD020 OHMM 1. 97 2000 15.0068 1692 7400 8245.5 RPD MWD020 OHMM 2.19 2000 27.0443 1692 7400 8245.5 FET MWD020 HR 0.28 40.35 2.90819 1692 7400 8245.5 First Reading For Entire File.... ... ...7400 Last Reading For Entire File........ ...8290 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/09 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. ..... .02/09/09 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 RPS RPX FET RPD RPM GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 8246.0 8246.0 8246.0 8246.0 8246.0 8254.0 8290.5 STOP DEPTH 9096.5 9096.5 9096.5 9096.5 9096.5 9104.0 9141.0 # 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: 16-NOV-Ol Insite 4.05.5 66.16 Memory 9141.0 19.0 22.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY TOOL NUMBER PB02272HRG6 ~\ EWR4 $ ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ""'" ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units......... ..Feet Data Reference Point...... ""'" .Undefined Frame Spacing............ ....... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ( PB02272HRG6 8.500 9141.0 LSND 10.00 47.0 9.6 1300 3.5 1. 650 .789 1. 300 1. 950 66.0 145.4 66.0 66.0 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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8246 9141 8693.5 1791 8246 9141 ROP MWD030 FT/H 4.26 166.83 96.0207 1702 8290.5 9141 GR MWD030 API 70.59 413.13 163.155 1701 8254 9104 RPX MWD030 OHMM 0.64 8.41 2 . 46762 1702 8246 9096.5 RPS MWD030 OHMM 0.69 8.12 2.42874 1702 8246 9096.5 RPM MWD030 OHMM 0.62 7.88 2.3936 1702 8246 9096.5 RPD MWD030 OHMM 0.62 8.51 2.50949 1702 8246 9096.5 FET MWD030 HR 0.29 19.89 1. 7456 1702 8246 9096.5 First Reading For Entire File......... .8246 Last Reading For Entire File.......... .9141 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/09/09 ( 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...... .02/09/09 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 RPX . RPS RPM RPD FET GR NCNT FCNT NPHI ROP RHOB DRHO PEF $ 4 ( header data for each bit run in separate files. 4 .5000 START DEPTH 9097.0 9097.0 9097.0 9097.0 9097.0 9104.5 9131.0 9131.0 9131.0 9141.5 9146.5 9146.5 9146.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO 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 CTN SLD $ STOP DEPTH 9893.5 9893.5 9893.5 9893.5 9893.5 9886.5 9849.0 9849.0 9849.0 9942.5 9864.5 9864.5 9864.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN # 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) 20-NOV-01 Insite 4.05.5 66.16 Memory 9943.0 17.8 78.0 TOOL NUMBER PB02254HAGR4 PB02254HAGR4 PB02249NL4 PB02249NL4 6.125 QUIKDRIL-N 8.40 45.0 9.2 750 12.0 ( ,( MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 3.500 1.702 4.000 3.200 76.0 163.4 76.0 76.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..... .... .... ... ..0 Data Specification Block Type... ..0 Logging Direction.. ... .... ...... ..Down Optical log depth units.......... .Feet Data Reference Point.. "" ....... .Undefined Frame Spacing......... ........... .60 .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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CP30 4 1 68 36 10 NCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9097 9942.5 9519.75 1692 9097 9942.5 ROP MWD040 FT/H 1. 65 297.95 44.4971 1603 9141.5 9942.5 GR MWD040 API 11. 42 581.23 58.695 1565 9104.5 9886.5 RPX MWD040 OHMM 0.43 481.42 36.514 1594 9097 9893.5 RPS MWD040 OHMM 0.5 1471.98 50.351 1594 9097 9893.5 RPM MWD040 OHMM 0.73 2000 106.835 1594 9097 9893.5 RPD MWD040 OHMM 0.72 2000 163.51 ,1594 9097 9893.5 FET MWD040 HR 0.52 78.11 6.37898 1594 9097 9893.5 NPHI MWD040 PU-S 4.34 59.08 20.9359 1437 9131 9849 FCNT MWD040 CP30 104.84 2611. 87 726.844 1437 9131 9849 NCNT MWD040 CP30 12972.6 45557 27584.5 1437 9131 9849 RHOB MWD040 G/CM 2.1 2.96 2.34859 1437 9146.5 9864.5 DRHO MWD040 G/CM -0.16 0.53 0.0761099 1437 9146.5 9864.5 PEF MWD040 B/E 1. 21 7.88 2.50186 1437 9146.5 9864.5 First Reading For Entire File...... ....9097 Last Reading For Entire File...... ;....9942.5 File Trailer Service name......... ... .STSLIB.004 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .02/09/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 ( Physical EOF File Header Service name...... ...... .STSLIB.005 Service Sub Level Name... Version Number... ... .... .1.0.0 Date of Generation...... .02/09/09 Maximum Physical Record. .65535 File Type....... ... ..... .LO Previous File Name...... .STSLIB.004 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 $ 5 ( header data for each bit run in separate files. 5 .5000 START DEPTH 9887.0 9894.0 9894.0 9894.0 9894.0 9894.0 9943.0 # 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 $ STOP DEPTH 10851.5 10858.5 10858.5 10858.5 10858.5 10858.5 10900.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY 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: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 23-NOV-01 Insite 4.05.5 66.16 Memory 10900.0 84.7 98.5 TOOL NUMBER PB02254HAGR4 PB02254HAGR4 6.125 QUIKDRIL-N 8.40 48.0 8.9 800 12.0 3.300 1. 698 2.900 4.000 77.0 156.0 77.0 77.0 f , ( EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ .... ..0 Data Specification Block Type... ..0 Logging Direction.... .... ........ . Down Optical log depth units...... .... .Feet Data Reference Point........ .... ..Undefined Frame Spacing.................... .60 .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 MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9887 10900 10393.5 2027 9887 10900 ROP MWD050 FT/H 0.07 126.31 58.6147 1915 9943 10900 GR MWD050 API 19.24 136.52 39.8504 1930 9887 10851.5 RPX MWD050 OHMM 2.24 65.36 30.8423 1930 9894 10858.5 RPS MWD050 OHMM 2.39 69.41 34.1772 1930 9894 10858.5 RPM MWD050 OHMM 2.78 65.06 35.6845 1930 9894 10858.5 RPD MWD050 OHMM 3.71 74.01 41. 7499 1930 9894 10858.5 FET MWD050 HR 0.38 24.64 2.79756 1930 9894 10858.5 First Reading For Entire File... .... ...9887 Last Reading For Entire File.... .... ...10900 File Trailer Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/09/09 Maximum Physical Record..65535 File Type............. ...LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name... ..... .... .LISTPE Date.....................02/09/09 Origin...................STS Tape Name............. ...UNKNOWN Continuation Number..... .01 Next Tape Name....... ... . UNKNOWN Comments................ .STS LIS wri ting Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date.....................02/09/09 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 (' (