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Home My WebLink About202-080 Imag€. )roject Well History File Cover J.. '-'«be XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. d.ö:J..- 020 'Well History File Identifier Organizing (dOIH~) RESCAN 0 Two-Sided 0 Rescan Needed 0 Color items: DIGITAL DATA / Diskettes, No. I OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 Grayscale items: 0 Other, NofType 0 0 Poor Quality Originals: Other: OVERSIZED (Non-Scannable) 0 0 Logs of various kinds BY: BEVERLY ROBIN VINCENT SHERY~INDY 0 Other DATE: 1f~ ~~/SI V1{;V ~ NOTES: BY: ~ ~ d. DATE:~~I m D J ~ _i X 30 = 3 () + 1 7 = TOTAL PAGES I i 7 ~ J ,j f '!ø BEVERLY ROBIN VINCENT SHERYL~INDY DATE:7'lJ- ðlf'sJ /IVt '/J < 4- q, ~JlA/ r)~ wl~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION:. ¿ YES - NO BEVERLY ROBIN VINCENT SHERY~WINDY DATE:<'?,:Jj::) 'Oif VV\. P BEVERLY ROBIN VINCENT SHERYL SWINDY Project Proofing Scanning Preparation I BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY . GRAYSCALE OR COLOR IMAGES) ReScanned (i}(fil'¡d{!;)/ pJq; 1!'./H~r.i,1/.lfT0IríoIJ .~c,)IniJlg compfe,'0d) RES CANNED Br: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 General Notes or Comments about this file: Quality Checked (rll)lI(~\ 12/1 O/02Rev3NOTScanned. wpd R····E'-C.·"., '" ,-,~ I\/E 10123106 Sclllulllupgep or"~ q\ ¡:;: '>006 <.,,1 ¿..» c J NO, 4009 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Alln: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, At< 99501 Alaska Oil &, G<\~ COI1~. Commis.~ Field: Borealis Well Job # log Description Date BL Color CD V-106A PB1 40011007 OH EDIT OF MWD/LWD 10115104 2 1 V-106A PB2 40011007 OH EDIT OF MWD/LWD 10119/04 2 1 V-106A PB3 40011007 OH EDIT OF MWD/LWD 10/22/04 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Sch/umberger-DCS 2525 Gambel! St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: Date Delivered' . SCA~·Nt;!} ~¡; i~ ¿;~ (, dOd -otò ~ Ii./ ¡C) t5 .;t:t 14{/ Cj C) ~ ILlfJóO e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE . F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc \ STATE OF ALASKA') ALASKAtl AND GAS CONSERVATION COMI\,..jÐION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1 a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: RES I AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, MWD, LWD, DIPOLE SONIC, DIR CASING, LINER AND CEMENTING RECORD ~rnl~$'t>i:~H~b:..S~rrN~PEfl1[HI"D ',H()'I;)~ ' ",',", ".'" "',',", '" """'" ',',' ,'" ",,' ','ToP::,'BeTTQM::llOP>"BOTTOMSIZEi:" , ,CEM~~TING ReCQRD' 29' 109' 29' 109' 42" 260 sx Arctic Set (Approx.) 329' 3099' 328' 2648' 9-7/8" 701 sx Arcticset Lite, 250 sx Class 'G' 820' 9583' 815' 6896' 6-3/4" 126 sx Lite Crete, 134 sx Class 'G' 25; 'ApIQ,fRACTUReCEMENTSQUeÈZe;ETC~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9106' P&A wI 20 Bbls Class 'G', Sqzd to 1000 psi 905' Set 5-1/2" EZSV 800' Set 7-5/8" EZSV, Sqz 20.5 Bbls cmt into annulus 80' Set Cmt Plug, 165 Bbls Cement PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL -BSL 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4870' NSL, 1649' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 5124' NSL, 5155' WEL, SEC. 01, T11N, R11E, UM Total Depth: 5176' NSL, 5139'WEL, SEC. 01, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590651 y- 5970119 Zone- ASP4 TPI: x- 592352 y- 5975673 Zone- ASP4 Total Depth: x- 592368 y- 5975726 Zone- ASP4 18. Directional Survey 0 Yes IBI No 22. . GRADE' H-40 L-80 L-80 CA$ING , $Ize Wl'~'PÊRFT, 34" x 20" 91.5# 7-5/8" 29.7# 5-1/2" x 3-1/2" 15.5# x 9.2# 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE Zero Other 5. Date Comp., Susp., or Aband. 9/29/2004 6. Date Spudded 05/01/2002 7. Date T.D. Reached 05/08/2002 8. KB Elevation (ft): 82.8' 9. Plug Back Depth (MD+ TVD) 109 + 109 10. Total Depth (MD+TVD) 9595 + 6907 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 202-080 304-353 13. API Number 50- 029-23083-00-00 14. Well Name and Number: PBU V-106 15. Field I Pool(s): Prudhoe Bay Field I Borealis Pool Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: SIZE 3-1/2",9.2#, L-80 TVD GAs-McF W A TER-BSL 20. Thickness of Permafrost 1900' (Approx.) , AMOUNT PULLED' GAs-McF W A TER-BSL , TúålNGRecORD DEPTH SET (MD) 7000' - 9111' PACKER SET (MD) None CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) 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 CC.'I.'iN5"'E-"1"'\ 0 L (" 1 ~) . C' C' r y ff",,~ L) '1_' J. t¡) 2 J J'J Form 10-407 Revised 12/2003 ORtGINAL CONTINUED ON REVERSE SIDE RBDMS BFl DEC 0 7 2004 0(: 28. GEOLOGIC MARKERS ') 29. .~ìRMA TION 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". Schrader Sluff M 5632' Schrader Bluff N 6033' Schrader Bluff 0 6314' Sase Schrader 1 Top Colville 6987' CM1 8371' Kalubik 9253' Kuparuk C 9330' Kuparuk B 9458' 4050' None 4275' 4431' 4804' 5767' 6573' 6648' 6773' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHUbble~- ~~ Tille Technical Assistant Date I \ '3ð/Ùl( PSU V-106 202-080 304-353 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 Permit NO.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ) ') Well: Field: API: Permit: V -1 06A Prudhoe Bay Unit 50-029-23083-01-00 204-185 Accept: Spud: Release: Rig: 10/01/04 10/08/04 10/30/04 Nabors 9ES PRE-RIG WORK 09/23/04 SET CATCHER SUB @ 9151 8LM. PULLED 8T#1 S/O 9001 SLM. 09/24/04 PULLED ST#2 @ 7762 SLM. PULLED ST #3 @ 4626 SLM. RAN STATION 3 WOULD NOT SET, LOST CHINA CAP OFF BOTTOM OF VALVE, RAN POCKET POKER TO# 3 8T A TION @ 4630 SLM. ALL CLEAR, SET 8T # 3 DUMMY VALVE @ 4626 SLM. SET ST# 2 DUMMY @ 7765 SLM. PUMP 130 BBLS DIESEL DOWN THE IA. SET ST#1 DGLV. START MIT- IA. 09/25/04 MIT FAILED. RAN LIB TO CATCHER @ 9150 SLM. CATCHER EMPTY. RAN 3 1/2 KlO W/ RUNNING TOOL, TAPPED DOWN ON ST# 2 @ 7762 SLM. RAN LIB WI KlO TO ST#3 @ 4628 SLM MARK OF VALVE, AND ST# 1 @ 9001 SLM. MARK OF VALVE, RAN 31/2 GS PULLED C.S. @ 9047. MAY HAVE COME UP HOLE, CHINA CAP IN CATCHER SUB. RAN 2.70 CENT, WI SB SAT DOWN @ 9330 SLM. 09/29/04 SERVICE SSV. LOAD/KILL WELL WITH 125 BBLS OF 1% KCL. RIH WITH 2.0" BON. PUMP 5 BBLS 15.8 PPG CLASS G CEMENT. LOST RETURNS AND WELL DRANK ALL 5 BBLS CEMENT. PUMPED SECOND BATCH OF 15.8 PPG CLASS G CEMENT, 15 BBLS, 2 BBLS WITH AGGREGATE. BUILT 1000 PSI SQUEEZE PRESSURE. CLEANED OUT TO 9125' CTMD W/ 60 BBLS BIOZAN. POOH CIRCULATING OUT CONTAMINATED CEMENT WITH GOOD 1 FOR 1 RETURNS WHILE HOLDING 500 PSIG WHP. FREEZE PROTECT WELL WITH DIESEL TO 2200'. SECURE WELL TRAPPING 500 PSIG WHP. 09/30/04 PULL PUMP-IN SUB OFF WELL, INSTALL TREE CAP. PREP FOR SLlCKLlNE TO TAG. RAN 2.50" CENTRALIZER AND SAMPLE BAILER. TAGGED CEMENT @ 9106' SLM. BAILER CAME BACK EMPTY. ) ') BP EXPLORATION Q.perationsS....mroäry Aeport Page 1 tII8Þ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1 0/1/2004 Rig Release: 10/30/2004 Rig Number: Spud Date: 1017/2004 End: 10/30/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/30/2004 12:00 - 00:00 12.00 MOB P PRE Wells group completing P&A on V-106. Perform service on #2 generator, inspect traction motor on drawworks, assemble spare drag chain, PM in pump room. Grease drawworks, choke manifold, mud manifold and BOP stack. Cleared SAA. General cleaning around rig. Pre-Move PJSM with all personnel. 10/1/2004 00:00 - 01 :30 1.50 MOB P PRE Move storage tanks and pit complex to allow heavy equipment to grade site around V-106. Move rig off V-120. 01 :30 - 03:00 1.50 MOB P PRE Heavy equipment grading site in preparation for rig to move on. 03:00 - 04:00 1.00 MOB P PRE PJSM. Lay mats and herculite. Spot V-1 06 well equipment in cellar. 04:00 - 06:00 2.00 MOB P PRE Spot rig over V -106. 06:00 - 07:00 1.00 MOB P PRE Spot pits and cuttings tank. Accept rig at @ 07:00 hrs. 07:00 - 08:00 1.00 RIGU P PRE Rig up circulating lines. Take on 9.7 ppg brine. 08:00 - 11 :00 3.00 WHSUR P DECaMP Rig up DSM. Pull BPV with lubricator. Tubing pressure 0, tubing on vacuum. Pressure on casing 350 psi, bleed off to 0 psi. Rig down DSM and install TWC. Bleed down all lines. 11 :00 - 12:00 1.00 WHSUR P DECOMP Nipple down tree and adaptor. Inspect tubing hanger threads and XO, OK. 12:00 - 12:30 0.50 WHSUR P DECOMP Secure diverter in cellar. 12:30 - 15:00 2.50 WHSUR P DECOMP Nipple up BOP's. 15:00 - 19:00 4.00 WHSUR P DECOMP Hold Pre-Job Safety Meeting - Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment- Witness Of BOP Test By AOGCC Inspector Chuck Scheve- Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Rig Down Testing Equipment 19:00 - 20:00 1.00 WHSUR P DECOMP Rig up DSM. Pull TWC. Rig down DSM. 20:00 - 21 :30 1.50 PULL P DECaMP Make up XO and drill pipe joint to hanger. Pull hanger to 7' above rig floor with 265K indicated weight. No further movement. Screw in TDS and pump 30 bbls 9.7 ppg brine at 105 gpm in an attempt to free tubing, no success. Had full returns during circulation. 21 :30 - 22:30 1.00 CLEAN P DECOMP Called out Schlumberger wire line to perform chemical cut on tubing. Began to displace freeze protection. Pumped 50 bbl 9.7 ppg soap sweep at 105 gpm. Tubing packed off with 1,200 psi. Shut down pumps. Pressure bled back to 800 psi in 15 minutes and held steady. Bled down lines to 0 psi. 22:30 - 00:00 1.50 PULL P DECOMP Break off tubing hanger and lay down same. 10/2/2004 00:00 - 03:00 3.00 PULL P DECOMP Monitor well. Prepare for Schlumberger wireline to arrive and chemical cut 3.5. tubing. 03:00 - 06:00 3.00 PULL P DECOMP PJSM. Spot and rig up Schlumberger equipment 06:00 - 07:30 1.50 PULL P DECOMP Make up chemical cutter and RIH to 7,000'. 07:30 - 08:30 1.00 PULL P DECOMP Cut tubing, had positive indication at surface of successful cut. POH with wireline. 08:30 - 09:30 1.00 PULL P DECOMP Rig down e-line and remove same from floor. 09:30 - 1 0:30 1.00 PULL P DECOMP Rig up and circulate 178 bbls down tubing at 6 bpm with returns through choke unti/9.7 ppg brine around. 10:30 - 11 :00 0.50 PULL P DECOMP Open annular and flush top of hole. Rig down circulating equipment and blow down choke. 11 :00 - 18:00 7.00 PULL P DECOMP Monitor well. Install stripping rubber. PJSM. POH laying down Printed: 11/1/2004 2:09:57 PM ) ') BP EXPLORATION Operations Summary Report Page 2 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1 0/1/2004 Rig Release: 10/30/2004 Rig Number: Spud Date: 10/7/2004 End: 10/30/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/2/2004 11 :00 - 18:00 7.00 PULL P DECOMP 3.5" tubing. Note: Recovered 227 joints tubing, 1 X-Nipple, 1 GLM and 1 cut off joint 3.5" tubing. Smooth cut noted on 20.86' cut off joint. 18:00 - 19:30 1.50 PULL P DECOMP Clear rig floor. Install test plug. Rig up and test lower rams, 250 psi Low - 3,500 psi High, OK. Pull test plug, install wear bushing. 19:30 - 20:30 1.00 PULL P DECOMP Pick up and rig up 2-7/8" DP handling tools. 20:30 - 22:30 2.00 ZONISO P DECOMP Make up 5.5" EZSV. Pick up 29 joints 2-7/8" PAC DP. Make up torque 4,000 Nibs. RIH to 905'. 45K up weight 40K down weight. 22:30 - 23:00 0.50 ZONISO P DECOMP Set EZSV as per Haliburton technicians procedure at 90S'. Release setting tool and set down 1 OK to test set. 23:00 - 00:00 1.00 ZONISO P DECOMP POH. Lay down 5 joints 2-7/8" Dp and stand back 8 stands. LD EZSV setting tool. 10/3/2004 00:00 - 01 :00 1.00 ZONISO P DECOMP Complete LD EZSV setting tool and clear rig floor. 01 :00 - 01 :30 0.50 DHB P DECOMP PJSM. Test 5.5" casing and EZSV plug to 3,000 psi for 10 minutes, OK. 01 :30 - 03:30 2.00 ZONISO P DECOMP Make up 5.5" casing cutting tools and RIH to 820'. Change out handling equipment. 03:30 - 04:30 1.00 PULL P DECOMP Rig up circulating system. Cut 5.5" casing at 820'. 04:30 - 05:00 0.50 PULL P DECOMP Circulate out and clean 7-5/8" X 5.5" annulus with heated hi vis sweep followed by 9.7 ppg mud. 05:00 - 07:00 2.00 PULL P DECOMP Monitor well. Blow down TDS. POH LD 2-7/8" PAC DP. 07:00 - 07:30 0.50 PULL P DECOMP Lay down cutting assembly. Change elevators and clear rig floor. 07:30 - 08:30 1.00 PULL P DECOMP PJSM. Pull wear bushing and 5.5" pack off. 08:30 - 09:00 0.50 PULL P DECOMP Make up 5.5" spear. Latch onto 5.5" casing and pull hanger to floor. 09:00 - 10:00 1.00 PULL P DECOMP Rig up casing tongs. Lay down hanger. Lay down fishing assembly. 10:00 - 12:00 2.00 PULL P DECOMP POH and lay down 19 full and 1 - 9.55' cut joint of 5.5" casing. 12:00 - 12:30 0.50 PULL P DECOMP Clear and clean rig floor. 12:30 - 13:30 1 .00 PULL P DECOMP Make up 7-5/8" EZSV and RIH to 800'. 50K up weight 50K down weight. 13:30 - 14:30 1.00 PULL P DECOMP Break circulation at 3 bpm, 125 psi. Set EZSV at 800'. Unsting and test to 1,000 psi. Sting back into EZSV and establish injection rate at 2 bpm, 1,180 psi (5 bbls away). 14:30 - 15:00 0.50 PULL P DECOMP Pressure test Schlumberger cement lines to 3,000 psi, OK. Squeeze 20.5 bbls, 15.8 cement into 7-5/8" x 5-1/2" annulus below EZSV. Chase with 9 mud water. Cement in place at 1500 hrs. 15:00 - 15:30 0.50 PULL P DECOMP Unsting from EZSV and CBU at 7 bpm. 350 psi. Rig down cement equipment. 15:30 - 16:00 0.50 PULL P DECOMP POH 16:00 - 16:30 0.50 PULL P DECOMP Lay down 7-5/8" EZSV running tool. Pick up storm packer. 16:30 - 18:00 1.50 PULL P DECOMP Pick up 9, 4-314" drill collars, storm packer and set at 35'. Test to 1,000 psi for 10 minutes, OK. 18:00 - 18:30 0.50 PULL P DECOMP Flush stack and well head with water and blow down lines. 18:30 - 21 :00 2.50 PULL P DECOMP Nipple down BOP and well head. 21:00 - 00:00 3.00 PULL P DECOMP Nipple up diverter system. 10/4/2004 00:00 - 02:00 2.00 PULL P DECOMP Complete NU diverter. Function test same. Witness of test Printed: 11/112004 2:09:57 PM ) ) BP EXPLORATION Operations Summary Report Page 3- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -106 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1 0/1 /2004 Rig Release: 10/30/2004 Rig Number: Spud Date: 10/7/2004 End: 10/30/2004 Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2004 00:00 - 02:00 2.00 PULL P DECOMP waived by AOGCC representative Chuck Schieve. 02:00 - 02:30 0.50 PULL P DECOMP RIH and release/retrieve storm packer. 02:30 - 03:30 1.00 PULL P DECOMP Lay down storm packer and 9 joints drill collars. 03:30 - 04:00 0.50 PULL P DECOMP Make up 7-5/8" cutting assembly 04:00 - 05:00 1.00 PULL P DECOMP RIH and cut 7-5/8" casing 5' below landing ring at 35'. Cut casing with 204 gpm, 925 psi, 78 rpm, 1.5K torque. POOH and lay down cutting tool. 05:00 - 06:30 1.50 PULL P DECOMP Pick up 7-5/8" spear and engage casing. Pull hanger and cut joint to floor and lay down same. Cut joint length 5.70', 06:30 - 08:30 2.00 PULL P DECOMP Pick up 3 drill collars, 1 joint wash pipe and shoe. RIH to 35'. 08:30 - 09:30 1.00 PULL P DECOMP Wash over 7-5/8" casing from 35' to 68'. CBU 250 gpm, 0 psi. 09:30 - 17:00 7.50 PULL P DECOMP Continue to wash over 7-5/8" casing from 68' to 181'. Pick up wash pipe each connection. 50K up weight, 48K down weight, 500 gpm, 105 psi, 70 rpm, 1,300 ft/lbs. 17:00 - 17:30 0.50 PULL P DECOMP Circulate hole clean. 12 bpm, 100 psi. 17:30 - 18:00 0.50 PULL P DECOMP POH and stand back wash pipe in derrick. 18:00 - 18:30 0.50 PULL P DECOMP Clean rig floor. Rig down 11-3/4" handling tools. 18:30 - 19:00 0.50 PULL P DECOMP Service TDS. 19:00 - 20:30 1.50 PULL P DECOMP Pick up 7-5/8" cutter assembly and RIH to 179'. Cut casing with 204 gpm, 925 psi, 78 rpm, 1.5K torque. POOH and lay down cutting tool. 20:30 - 21 :00 0.50 PULL P DECOMP Pick up 7-5/8" spear, RIH and engage casing at 35'. 21 :00 - 21 :30 0.50 PULL P DECOMP Displace hole to new 8.9 spud mud. 21 :30 - 22:30 1.00 PULL P DECOMP Set back stand. Rig up 7-5/8" handling tools. Back off cut off joint and lay down with grapple. Cut off joint length 35.99'. 22:30 - 00:00 1.50 PULL P DECOMP Pull and lay down 2 joints 7-58" casing (41.92' & 42.01'). Lay down cut off joint 24.48'. 10/5/2004 00:00 - 01 :00 1.00 PULL P DECOMP Laid down spear. Rigged up 11.75" handling tools. RIH wi wash pipe to 170', encountered fill. Washed down to 179'. 01 :00 - 09:30 8.50 PULL P DECOMP Wash over 7-5/8" casing from 179' to 336'. (Top drive should have bottomed out at 326') 09:30 - 11 :30 2.00 PULL P DECOMP Pulled out of hole with wash pipe. 11 :30 - 12:00 0.50 PULL P DECOMP Picked up casing cutter. 12:00 - 12:30 0.50 PULL P DECOMP Cleared floor. 12:30 - 14:30 2.00 PULL P DECOMP Ran in hole with 7 5/8" casing cutter and worked into stump at 179'. Tagged up at 201'. Picked back up 5' above stump. Ran in hole and tagged up at 314'. Picked up and retagged 6' higher at 308'. Pulled out of hole. Laid down cutter. 14:30 - 15:00 0.50 PULL P DECOMP Serviced top drive. 15:00 - 16:30 1.50 PULL P DECOMP Went thru pumps due to rocks. Cleaned out suction manifold and checked valves. Conditioned mud. 16:30 - 17:00 0.50 PULL P DECOMP Picked up BHA components to floor and cleared floor. 17:00 - 18:30 1.50 PULL P DECOMP Changed out wash over shoe on wash pipe. Found a solid 5' core of cement inside wash pipe. 18:30 - 19:00 0.50 PULL P DECOMP Cleared ice build up out of derrick. 19:00 - 20:30 1.50 PULL P DECOMP Made up 6118. bit with 81/2. stabilizer 14' above bit. 20:30 - 21 :00 0.50 PULL P DECOMP Ran in hole and tagged top of 7 5/8. casing stub at 179' with bit. Worked into top of fish and bottomed out with stabilizer at 193' (14' in). 21 :00 - 21 :30 0.50 PULL P DECOMP Circulated well clean. 21 :30 - 22:30 1.00 PULL P DECOMP Pulled out of hole. Stood back DCS and laid down bit and stabilizer. 22:30 - 00:00 1.50 PULL P DECOMP Made up 12 5/8. washover shoe on 60' of wash pipe. TIH to Printed: 11/1/2004 2:09:57 PM ') ) BP EXPLORATION Operations Summary Report Page 4 ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-106 V -1 06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 10/1/2004 Rig Release: 10/30/2004 Rig Number: Spud Date: 10/7/2004 End: 10/30/2004 Date Frorn..To COde NPT Phase Description of Operations 1 0/5/2004 22:30 - 00:00 1.50 PULL P DECOMP 179', 10/6/2004 00:00 - 00:30 0.50 PULL P DECOMP Washed 60' over 75/8" casing from 179' to 239'. Bottomed out on top sub to verify wash pipe was over casing. 00:30 - 01 :00 0.50 PULL P DECOMP Pulled out of hole with 60' wash pipe assembly. 01 :00 - 02:00 1.00 PULL P DECOMP Made up 147' wash pipe assembly. Tripped in hole. 02:00 - 04:00 2.00 PULL P DECOMP Worked over casing stub at 179'. Washed over casing to 326' and bottomed out on top sub. Had light to medium washing with cement returns and flocculated mud. 04:00 - 05:00 1.00 PULL P DECOMP Circulated well clean at 439 GPM and 68 psi. 05:00 - 06:00 1.00 PULL P DECOMP Pulled out of hole and stood back wash pipe. 06:00 - 07:00 1.00 PULL P DECOMP Picked up 7 5/8" cutter. Tripped in hole. Worked into top of casing stub at 179'. Cutter stopped at 183'. Pulled and laid down cutter. 07:00 - 08:00 1.00 PULL P DECOMP Picked and ran 63/4" tapered mill. Tagged fill inside 7 5/8" casing at 183'. 08:00 - 11 :00 3.00 PULL P DECOMP Washed and reamed bridges inside 7 5/8" casing from 183' to 800'. Tagged EZSV at 800'. 11 :00 - 11 :30 0.50 PULL P DECOMP Circulated well clean. 11 :30 - 12:30 1.00 PULL P DECOMP Pulled out of hole wI 6 3/4" tapered mill. 12:30 - 13:00 0.50 PULL P DECOMP Picked up 7 5/8" cutter and tripped in hole to 480'. 13:00 - 13:30 0.50 PULL P DECOMP Cut 7 5/8" casing at 480' with 60 RPM, 4 BPM and 475 psi. Torque was 700 to 900. 13:30 - 14:00 0.50 PULL P DECOMP Pulled up to 329' and cut 7 5/8" casing with 65 RPM, 4 BPM, 500 psi and 800 torque. 14:00 - 14:30 0.50 PULL P DECOMP Pulled out of hole and laid down cutter. 14:30 - 15:30 1.00 PULL P DECOMP Made up 7 5/8" casing spear and tripped in hole. 15:30 - 16:00 0.50 PULL P DECOMP Engaged 7 5/8" casing with spear and jarred free with 100k Ibs pull. Tripped out hole to spear. 16:00 - 18:00 2.00 PULL P DECOMP Laid down 150' of 7 5/8 casing. Top of 75/8" casing was sliced from the outside confirming that the initial wash over run had gone outside the casing. Top of 75/8" casing stub at 329'. 18:00 - 19:00 1.00 PULL P DECOMP Cleared floor of casing handling tools and miscellaneous. 19:00 - 20:30 1.50 PULL P DECOMP Made up 12 1/4" bit wI stabilizer. Tripped in hole. 20:30 - 21:00 0.50 PULL P DECOMP Washed down to 7 5/8 casing stub at 329'. 21 :00 - 21 :30 0.50 PULL P DECOMP Circulated and conditioned mud for cement plug @ 14-15 bpm while reciprocating. Lost +1- 2' of hole while working pipe. Unable to wash back to 329'. 21 :30 - 22:30 1.00 PULL P DECOMP Tripped out of hole with bit. 22:30 - 00:00 1.50 PULL P DECOMP Broke down spear and bumper sub. Ran in with wash over assembly and laid down same. 1017/2004 00:00 - 02:00 2.00 PULL P DECOMP Completed laying down wash pipe and all tools. Cleared floor. 02:00 - 03:00 1.00 STCTPL P DECOMP Rigged up 2 7/8 handling tools and power tongs. 03:00 - 04:00 1.00 STCTPL P DECOMP Picked up 2 7/8" PAC tubing. Tagged fill at 289'. Rigged up to circulate. 04:00 - 05:00 1.00 STCTPL P DECOMP Washed from 289' to 293'. (36' above stub) Unable to work deeper. 05:00 - 06:00 1.00 STCTPL P DECOMP RU OS to lay cement plug. 06:00 - 07:00 1.00 STCTPL P DECOMP Test lines T/2500psi, Pump 10 BBLS water, 165 BBLS 15.7 PPG CMT. 07:00 - 08:00 1.00 STCTPL P DECOMP POOH UD 2 7/8" PAC DP. 08:00 - 09:30 1.50 STCTPL P DECOMP PIU 16" Bit, XO, 61/4" DC, RIH washing F/15' Tf75'. 09:30 - 12:00 2.50 STCTPL P DECOMP Wait on Cement, Clean gravel out from under the rig floor. 12:00 - 13:00 1.00 STCTPL P DECOMP Wash down to BTM of conductor, encounter green CMT out of Printed: 11/112004 2:09:57 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ') Page 5 ... BP EXPLORATION Operations Summary Report V -1 06 V-106 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 10/7/2004 12:00 - 13:00 13:00 - 20:00 20:00 - 20:30 10/8/2004 20:30 - 21 :30 21 :30 - 00:00 00:00 - 00:30 00:30 - 04:30 04:30 - 06:00 06:00 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 16:30 16:30 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 21 :30 21 :30 - 00:00 10/9/2004 00:00 - 05:00 06:00 - 07:00 1.00 STCTPL P 7.00 STCTPL P DECOMP DECOMP 0.50 STCTPL P DECOMP 1.00 STCTPL P 2.50 STCTPL P 0.50 DRILL P 4.00 DRILL P DECOMP DECOMP SURF SURF 1.50 DRILL P 4.00 DRILL P SURF SURF 1.00 DRILL P 1.00 DRILL P SURF SURF 4.50 DRILL P SURF 1.00 DRILL P SURF 2.00 DRILL P SURF 0.50 DRILL P 1.50 DRILL P 2.50 DRILL P P SURF 1.00 DRILL P SURF 1.00 DRILL P SURF Start: 10/1/2004 Rig Release: 10/30/2004 Rig Number: Spud Date: 10/7/2004 End: 10/30/2004 Description of Operations conductor. Stand back clean out Assembly. While waiting on cement, P/U HWDP, P/U DC, and service top drive. P/U stand drill collars with 16" Bit, RIH and tag cement at 110' Set down 12K, Cement firm. POOH. Lay down BHA assembly. Held PJSM, P/U BHA #19. R/U wire line ç¡yro data tools, Run Gyro survey @ 117'. Rotate & Slide F/117'- T/357', Running Gyro surveys after each stand. Up wt 60k - Down 60k - Rotate 60k 170 GPM @ 504 PSI Trip out of hole to pick up Drilling Jars. TIH. Drill Rotate & Slide FI 357' - T/1 002'. 600 GPM @ 1927 PSI, 80 RPM. CBU, Run Gyro survey multi shot. Drill Rotate & Slide F/1002' - T/1096' Up wt 80k - Down 70k 660 GPM @ 1927 PSI AST 2.2 HRS ART 3.16 HRS Drill Rotate & Slide F/ 1 6' - T/1659' Survey @ 1600' MD 560' TVD INC 28.85 - AZ14.10 AST 2.8 HRS ART 1.12 HR Circ & Con ole 662 GP @ 2121 PSI. PO for Bit, Replace 12 1/4" MX-C1 Hughes with 12 1/4" 1 N Security Bit. rade Bit. Service Top Drive. RIH T/1644' tag fill- wash T/1659'. Drill Rotate & Slide F/1659' - T/1938' Survey @ 1880' MD - 1800' TVD INC 34.49 AZ13.78 DLS 3.25 AST 1.03 ART .18 Up wt 85k - Down 70k 670 GPM @ 2440 PSI WOB 30k Bit RPM 224 .p. Rate 348 Drill Rotate & Slide F/ 1938' - T/3061' MD - TVD 2617' AST 1.52 ART 1.88 Survey MD 3003' TVD 2617' INC 43.7 AZI 5.63 650 GPM @ 3400 PSI WOB 35 - 40k RPM 80 CBU for short trip. 650 GPM @ 3060 PSI oft bottom POOH F/3061' - T/1900', Up wt 109 - Down 78k, Pulled clean Printed: 11/1/2004 2:09:57 PM TREE = NJA (~;" WELLHEAD = 11" FMC . ., . , A CTUA TOR= NA KB. ELEV = 82,80' . .. '" .. . BF. ELEV = 54.30' . . ... .. ..... ... .. ... KOP = 300' ~xÄ ngle = "'S8@4Ö93" Datum MD = """""""""""""'-"""--"~'.,..".~ Datum TVD =, V-1(;J Abandonmen:) Top of 7-5/8" casing at 329' MD 7-5/8"_EZSV at 800' MD 5-112" EZSV at 905' MD Estimated BOC is 2000' MD 17-5/8" CSG, 29,7#, L-80, 10 = 6.875" 1-1 3099' Top of 3-/12" tbg at 7000' MD ~ I 5-1/~~:;'~::~~:~B:: ::::::: ~ ::::: ~ I ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.5" 6 9364-9385 Perf OS/26/02 2.5" 6 9337-9358 Perf OS/26/02 I W'Ford Rug 1-1 9512' 13-1/2" CSG, 9.2#, L-80, .0087 bpf, 10 = 2.992" 1-1 9583' DA TE REV BY 09/18/04 NM 10/11/04 NM COMMENTS A'oposed Abandomrent Actual Abandonment Estimated TOC is 80' MD Estimated BOC is 329' MD 5-1/2" production casing cut at 800' MD ~ Abandonment Data: A 165 bbl Class G 15.7 ppg cement plug will be placed on top of the 7-5/8" EZSV at 329'. This will isolate any freshwater strata to 80' A 7-5/8"EZSV will be set at 800'.20 bbls of 15.8 ppg G cement will be squeezed into the 7-5/8" x 5-1/2" annulus to provide 1200' annular cement fill. Estimated TOC from primary cement job is 5850' MD (Ugnu Ma at 5632' MD) GR/Porosity indicates sands above will not support commercial development. Kill weight brine, (9.7 ppg) will be left inside the 5-1/2" casing after cementing off the open perforations. \ r I 9087' 1-1 TOP OF BKR PBR, 10 = 4.00" 1 1 I 9103' Ij BTM OF 3-1/2" BKR SEAL ASSY, 10=2.990" 1 )/)/ x )/ t ~ ~ t ~ ~ I I I " ... .. x a r DA TE REV BY COMMENTS Production Zone Isolation Details Open perforations (9385'-9337') isolated with 3.2 bb115.8 ppg Class G cement plug placed via coil from 9512' to 9150' MD. Estimated TOC at 9150' MD. PRUDHOE BAY UNrr WELL: V-106 ÆRMrr No: 202-080 API No: 50-029-23083-00 SEC 11, T11 N, R11 E, 4870' NSL & 1649' WEL BP Exploration (Alaska) ~1f~1fŒ lill~ &\~ll~~[ß~ / FRANK H. MURKOWSK~ GOllëRNOR I / l AI,ASIiA OIL AND GAS ! CONSERVATION COltlMISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ctO~-ò?70 Re: Prudhoe Bay V-I 06 Sundry: 304-353 Dear Mr. Crane: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed fonn. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF THE COMMISSION DATED this Jd}day of September, 2004 Enc!. y..JLd+ '1 (lC'{t.OOq STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: / II Abandon [J Repair Well II Plug Perforations [J Stimulate [J Other [J Alter Casing [J Pull Tubing [J Perforate New Pool [J Waiver [J Time Extension [J Change Approved Program [J Operation Shutdown [J Perforate [J Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit Toynll Number BP Exploration (Alaska) Inc. IBI Development D Exploratory 202-080 3. Address: D Stratigraphic D Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23083-00-00 7. KB Elevation (ft): 82.8' 9. Well Name and Number: r' PBU V-106 8. Property Designation: 10. Field / Pool(s): ADL 028240 Prudhoe Bay Field / Borealis Pool 11. "", "~~~~~"",,<,' """"""}'}' ,.,"',."',""" i,' 'i, ... "', ," ..,. ' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9595 6907 9518 6832 None None CáSm!:l" . . '. }IMnth }, Sa' / 'M[ " rvD Burst ColIsO6e I 80' 34" X 20" 109' 109' - . 3070' 7-5/8" 3099' 2648' 6890 4790 Dr~' IM;"n 9557' 5-1/2" x 3-1/2" 9583' 6896' 7000 4990 LinAr Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 9337' - 9385 6655' - 6702' 3-1/2", 9.2# L-80 9111' Packers and SSSV Type: 3-1/2" HES 'X' Nipple Packers and SSSV MD (ft): 2370' 12. Attachments: 13. Well Class after proposed work: IBI Description Summary of Proposal D BOP Sketch D Exploratory IBI Development D Service D Detailed Operations Program 14. Estimated Date for Septemb¡;2.1004 15. Well Status after proposed work: / Commencing Operations: DOi! DGas D Plugged IBI Abandoned 16. Verbal Approval: Da~ DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Neil Magee, 564-5119 Printed Name L~ell Crane Title Senior Drilling Engineer Signature-:::::--1": ... Í /1 ff ~ ---~ Prepared By Name/Number: --. Phone 564-4089 DateC}-J6-D<.f Terrie Hubble. 564-4628 t/ " "'",, "" "',!, Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: .3oV-3S.3 D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance RECEIVED t-o . TeL.,t ßOI)E '~çoo f~' Other: A-p p tQ Lied r-ot'Vv\.. 10 --{O{ ~~'N?d ~y ç¿ J..R tv- O^-l ~ Vv<Þ/l 'g~ ~ W 2004 &œ~"~ F:ë/fi;° 7 Alaska Oil & Gas Cons. Commission Anchorage APPROVED BY 9/u Iðw v Approved By. J ~ ~ Â ./ COMMISSIONER THE COMMISSION Date Form 1 0-403 Re~6/~ ~ '--"""" ~mit JI Dupficate RBDMS BFL SEP 2 1 7004 ORIGINAL P G' RECEIVED SEP 2 02004 Alaska I.m ci!, ual Cons. Commission Anchorage To: Winton Aubert - AOGCC Date: September 18, 2004 From: Neil Magee - BPXA GPB Rotary Drilling Subject: V-106 Application for Sundry Approval- P&A for Sidetrack Operations (Revised 9/18/04) Approval is requested for the proposed P&A of PBU well V-106. This microbore Kuparuk producer was originally drilled and completed May 2002. Initial well production was disappointing at 346 BOPD, 387 BWPD. The last well test (6/21/04) indicated the well producing at 3 BOPD, 70 BWPD. There are indications that there may be tubing -annulus communication from the top GLM. The well was shut in June 1, 2004 for low production. It has been decided to re-drill this well as a horizontal producer eastward of the original well location. This well will receive waterflood support from proposed injector V-120 and existing injector V-105. The net estimated reserves are 1806 MSTBO with half being allocated to the injector well V-120. The V-106A sidetrack is currently scheduled for Nabors 9ES beginning around October 1st 2004. The pre- rig work for this sidetrack will be scheduled immediately after the Application for Sundry is approved. Scope Pre-ria ODerations: 1. Function test all tubing hanger and 5-1/2" casing pack-off and lockdown screws. 2. PPPOT-T to 5000 psi. 3. Fluid pack the tubing x 5-1/2" annulus with diesel from 2000' to surface. 4. R/U slick-line. Dummy off any live GLM. ~ 5. Pressure test outer annulus to 3000 psi 6. R/U coil unit and pump abandonment plug from 9512 to 9150' with.2 Is 15.8 ppg Class G cement. (Open perforations from 9337'-9385' yields 187' cement over up ost perforation.) Wash back to 9150' to assure tubing clear of cement above plug. 7. Pressure test casing against P&A plug to 3000 psi 8. Circulate the well with clean seawater through the tubing cut. Freeze protect tubing with diesel from 2,200' to surface. Bled casing and annulus pressure and record pressure. 9. Set a BPV. Secure the well. Remove the wellhouse. Level the pad as necessary. / RiQ ODerations: 1. MIRU Nabors 9ES. 2. RU lines and circulate out diesel freeze protect and displace the well to seawater. Pull BPV and install TWC. 3. Nipple down tree. Nipple up and test the BOPE to 3500 psi. Pull TWC. ,/ 4. RU and pull the 3-1/2" tubing from SBR and circulate wellbore to 9.7 ppg brine. POOH LD tubing. 5. RIH and set 5-1/2" EZSVat 900' MD. Pressure test to 3000 psi. V-106 Application for Sundry 6. MU 5-1/2" multistring casing cutting assembly and RIH to 800'. Displace inside of casing to 9.7 ppg mud. Cut casing at 800'. Circulate the annulus to 9.7 ppg mud. ~ 7. Remove wellhead pack-off and recover 5-1/2" casing. 8. RIH and set 7-5/8" EZSV 00 ion drillpipe. Pressure test to 1000 psi. Cement squeeze 7-5/8" x 5- 1/2" annulus below with 0 b 15.8 ppg cement. POOH. This provides 1200' of annular cement fill between 7-5/8" and 5-1 asing. 9. MU 7-5/8" casing cutter assembly and RIH. Circulate casing to 9.7 ppg mud. Cut 7-5/8" at 500' MD.. Make second cut at 250' MD. / 10. Set 7-5/8" RTTS 20' below wellhead and test to1000 psi. / 11. NO BOPE and remove wellhead. NU diverter spool and riser. Retrieve 7-5/8" RTTS. 12. MU 7-5/8" casing cutter assembly and RIH. Make cut just below the landing ring. MU 7-5/8" spear assembly and recover 7-5/8" support ring and pup.. 13. Make up Baker washpipe and washover 7-5/8" casing to 250'. PU casing spear and recover casing /' from 250' MD, continue washing ~ve , d recover casing from second cut at 500' MD. 14. RIH with cement stinger and lay i 61 I Class G 15.8 ppg cement plug from 800' to 300'. (Assumes 150% excess in open hole portio m 500' to 300'.) POOH 15. Prepare for V-106A sidetrack operations. ,/ V-106 Application for Sundry , TREE = ' 3-1/8" 5M CIVV WB..LHEAD = 11"FMC ACTUATOR- NA KB. B..EV = 82.80' BF. B..EV = 54.30' KOP= 300' Max Angle = 5S @ 4093' Datum MD = DatumTVD= V -1 06 7 -5/S" CSG, 29.7#, L-SO, ID = 6.875" I I 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" I I 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" I 14-3/4" X 3-1/2" CSG XO, ID = 3.000" H PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE None PBTD 9512' 3-112" CSG, 9.2#, L-80, .00S7 bpf, ID = 2.992" 9583' 2370' ST MD 3 4634 2 7765 1 9003 9060' 9084' 9087' 9103' 9158' 9173' 9283' 9461' I SAFETY NOTES: -l3-1/2" HES X NIP, D = 2.S13" I GAS LFT MANDRB...S TVD DEV TYÆ VLV LATCH PORT 3504 56 KBG2-9 rN BTM 3.5x1 5305 56 KBG2-9 rN BTM 3.5x1 6340 20 KBG2-9 RP BTM 3.5x1 DATE 05/11/02 05/11/02 05/11/02 -13-1/2" BKR CMD SLIDING SLV,ID = 2.813" I -lBKRLOCSEALASSY,ID=2.990" I -lTOPOFBKRPBR,ID=4.00" I j BTM OF 3-112" BKR SEAL ASSY, ID = 2.990" I 3-1/2" HES X NIP, ID = 2.813" -l3-1/2" HES X NIP, D = 2.813" I -l16'PUPJTW/RA TAG I -l16'PUPJTW/RA TAG I DATE REVBY COMMENTS DATE REVBY COMMENTS 05/13/02 CRM Original Corrplelion I-- -,!. -. " ... PRUDHOE BAY UNIT WB..L: V-106 ÆRMIT No: 202-080 API No: 50-029-23083-00 SEC 11, T11N, R11E, 4870' NSL & 1649' we.. BP Exploration (Alaska) TREE = NJA WELLHEAD = 11"FMC ACTUATOR;: NA KB~ELEV = 82.80' BF. ELEV = 54.30' KOP= 300' Max Angle = 5S @ 4093' Datum tvD = Datum TVD - , V-1 06 Abandonment Estimated TOe is 300' MD Top of 7-518" casing at 500' MD '7-5/8"_EZSVat 800' MD 5-112" EZSV at 900' MD Estimated BOe is 800' MD / 5-112" production casing cut at 800' MD Estimated BOe is 2000' MD 17-5/S" CSG, 29.7#, L-SO, D = 6.875" H 3099' Abandonment Data: A~elass G 15.8 ppg cement plug w~ìaced Q.!1-top of the 7-518" EZSV at 800' -'This will isolate any freshwater strata to 300' (Assumes 150% excess in open hole from 500' to 300'.) A 7-5/8"EZSV will be set at 800'.Æô7 bbls of 15.8 ppg G cement will ~ squeezed into the 7-518" x 5-112" annulus to provide 1200' annular cement fill. Estimated TOe from primary cement job is 5850' MD (Ugnu Ma at 5632' MD) GR/Porosity indicates sands above will not support commercial development. Kill weight brine (9.7 ppg) will be left inside the 5-1/2" casing after cementing off the open perforations. 5-112" CSG, 15.5#, L-SO, BTC, 10 = 4.950" 9106' ~ -lTOPOFBKRPBR, 10=4.00" I ~BTMOF3-1/2"BKRSEALASSy,ID=2.990" I 14-3/4" X 3-1/2" CSG XO, D = 3.000" H ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to A'oduction DB for historical perf data ql'50 Production Zone Isolation Details SIZE SPF MERVAL Opn/Sqz DATE 2.5" 6 9364-9385 Perf OS/26/02 2.5" 6 9337-9358 Perf OS/26/02 Open perforations (9385'-9337') will be isolated with 3.2 bb115.8 ppg elass G cement plug placed via coil from 9512' to 9150' MD. Estimated TOe at 9150' MD. 1 WFord Rug I 9512' 13-1/2" CSG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 9583' DATE REVBY COMMENTS DATE REVBY COMMENTS 09/18/04 NM A'oposed Abandonment ,--~~ PRUDHOE BAY UNIT WELL: V-106 PERMIT No: 202-080 AA No: 50-029-23083-00 see 11, T11N, R11E, 4870' NSL & 1649' WEL BP Exploration (Alaska) ?- -' Jo ;.--. i) \.: ~r~-ÕF- DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020800 Well Name/No. PRUDHOE BAY UN BORE V-106 Operator BP EXPLORATION (ALASKA) INC ~'f1IA.¿ J ~ ~ API No. 50-029-23083-00-00 MD 9595 .,.-- rvD 6907./ Completion Date 5/26/2002 ç'» Completion Status 1-01L Current Status 1-01L UIC N ------------ --------- ----------.--- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes c--- ---------- ---------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: RES/AIT, DT/BHC,CNL,LDL,GR,Caliper, SP,MRES,MWD,LWD,DIPOL (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Interval OHI ~ Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments If --- 1~og L2"ónic 25 BS 1 3000 9580 Open 6/11/2002 Triple Combo PlatfOrm ! Express and DSL T .;...ED C Vi 0890 Gamma Ray 110 9594 Open 6/11/2002 ! LOg ....-Neutron 25 BS 3000 9580 Open 6/11/2002 Platform Express ¿; ~ -- L50nic 25 BS 3000 9580 Open 6/11/2002 Triple Combo Platform Express and DSL T -~g tJõensity 25 BS 3000 9580 Open 6/11/2002 Platform Express ~g ~ic 25 BS 3000 9580 Open 6/11/2002 Borehole Compensated Sonic DSL T with Caliper .:..eD C 40-895 See Notes 2950 9588 Open 6/11/2002 PEX AIT BHC Data ; ! Log jOOt1ction/Resistivity! - 25 BS 3000 9580 i Open 6/1112002 Platform Express i ~Log LGamma -Ray 25 Blu 108 9540 Open 6/11/2002 ¡..keg -<3ammaRélY 25 Blu 108 9540 Open 6/11/2002 ~ c:.ßorosity 25 BS 3000 958.0 Open 6/11/2002 Platform Express -" .----- ---------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020800 MD 9595 Well Name/No. PRUDHOE BAY UN BORE V-106 Operator BP EXPLORATION (ALASKA) INC TVD 6907 Completion Date 5/26/2002 Completion Status 1-OIL Current Status 1-01L Well Cored? ADDITIONAL INFORMATION t.;'\ Y/~ Daily History Received? WN r-" (;)/ N Chips Received? .- Y IN Analysis Received? ---- ------- --- - - ---------~ ----- Comments: -- Formation Tops -Y I N - -.La Compliance Reviewed By: Date: API No. 50-029-23083-00-00 UIC N -' )J<J-~ DN~ - ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4., Location of well at surface r------ ," '., - 'iI i""~"iI:'~-1fi'.\'.)\6<f\::::! 4870' NSL, 1649' WEL, SEC. 11, T11 N, R11 E, UM ¡ GOMPLETlON ~ . 1:OCfÁ~!¡s. At top of productive interval 1 OA TE .. ~ -,j §. . ,"_.:.or 5124' NSL, 5155' WEL, SEC. 01, T11 N, R11 E, UM ,'!), 2t=>"()?~1 . " .... .. ,(: 10. Well Number 5~~~?~St~~39'WEL, SEÇ. 01, T11N, R11E, UM I. VÃÞA t~.,~J 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 82.8' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5-1-2002' 5-8-2002 5-26-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9595 6907 FT 9518 6832 FT 181 Yes 0 No 22. Type Electric or Other Logs Run RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, MWD , LWD , DIPOLE SONIC, DIR CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 29' 109' 42" 29' 3099' 9-7/8" 26' 9583' 6-3/4" Classification of Service Well 7. Permit Number 202-080 8. API Number 50- 029-23083-00 9. Unit or Lease Name Prudhoe Bay Unit V-106 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2378' MD 1900' (Approx.) 23. CASING SIZE 34" X 20" 7-5/8" 5-1/2" x3-1/2" WT. PER FT. 91.5# 29.7# 15.5# x 9.2# GRADE H-40 L-80 L-80 CEMENTING RECORD 260 sx Arctic Set (Approx.) 701 sx Articset Lite, 250 sx Class 'G' 126 sx Lite Crete, 134 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 SPF MD TVD 25. SIZE 3-1/2",9.2#, L-80 MD TVD J<ö¡? ~ ']¿bi ,I)/.> v'-iÍ''Þ AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 9111' PACKER SET (MD) None ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9337' - 9385' Frac'd, Placed 229,988#'s of Carbolite behind pipe Freeze Protected with Diesel, MeOH and Hot Crude Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA D ¡: r F! \l F t1 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ~ dRiPs: ,~,., '".., . 9337' - 9358' 6655' - 6676' 9364' - 9385' 6682' - 6702' 26. 27. Date First Production June 30, 2002 Date of Test Hours Tested 7/2/2002 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 1387 GAs-McF 672 WATER-BBl 852 Oll-BBl GAs-McF WATER-BBL No core samples were taken. CHOKE SIZE 70 Oil GRAVITY-API (CORR) GAS-OIL RATIO 485 JUL 1 9 2002 Alaska on & t:ias l:Ùns lAJ::I:¡I,')~;(ii Anchoraoe Form 10-407 Rev. 07-01-80 0 R ¡ GIN A L RBOMS 8FL SEP 2 3 20~bmilln Duplicate [. P ') 29. Geologic Markers Marker Name Measured Depth Schrader Bluff M 5632' Schrader Bluff N 6033' Schrader Bluff 0 6314' Base or Schrader Bluff Top of Colville 6987' CM1 8371' Top of Kalubik 9253' Top of Kuparuk C 9330' Top of Kuparuk B 9458' 31. List of Attachments: ') 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4050' 4275' 4431' 4804' 5767' 6573' 6648' 6773' R,E(:EI\/ED JUL "1 9 2002 Alasl<ô (W t) bi:ì:-'; ',("1):1 ,I 1::I.d 11::>:;:>101' A nchnl';1':)(- Summary of Daily Drilling Reports, Surveys, Post Rig Summary Report and a Leak-Off Integrity Summary. 32. I ~erebY certify that the fo~oin~ is true and correct to the best of my knowledge Signed Terrie Hubble ,....,-,p AM.t ~ ~ Title Technical Assistant V-106 .202-080 Well Number Permit No. / Approval No. Date ()7./R.o~ Prepared By Name/Number: Sandra Stewman, 564-4750 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 ~ \ ': l I \ ~ Lh Legal Name: V-106 Common Name: V-106 Test Date 5/5/2002 Test Type LOT Test Depth (TMD) 3,099.0 (ft) BPEXPLORATION Leak-Off TestSummary Test Depth (TVD) 2,648.0 (ft) AMW 9.30 (ppg) Surface Pressure Leak Off Pressure (BHP) 1,872 (psi) EMW 13.61 (ppg) 593 (psi) ._~ ~' Printed: 5/20/2002 3:13:20 PM BP EXPLORATION Operations Summary Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/30/2002 Rig Release: 5/13/2002 Rig Number: 9-ES Spud Date: 5/1/2002 End: 5/13/2002 4/30/2002 00:00 - 06:00 6.00 RIGU P PRE Move shop & camp. Jack pit complex. Pull pits forward. Jack up sub. Move sub off V-1 01 & spot on V-106. Spot pit complex, shop, & camp. Hook up all lines @ interconnect. 06:00 - 13:30 7.50 DIVRTR P SURF NU diverter & riser. Take on water & start building spud mud. Bring BHA to rig floor. Rig Accepted @ 0600 hrs 4/30/2002. 13:30 - 14:00 0.50 DIVRTR P SURF Function test diverter. Witnessing of test waived by John Spaulding--AOGCC Field Inspector. 14:00 - 14:30 0.50 DRILL P SURF Start to MU BHA. Phase 3 Pad & Access Road conditions called. 14:30 - 00:00 9.50 DRILL N WAIT SURF Phase 3 on Pads & Access Roads. Phase 2 on Spine Road. Clean rig. Do maintainance as appropriate. 5/1/2002 00:00 - 13:30 13.50 DRILL N WAIT SURF Continue to wait on weather. Hold Pre Spud Meeting with all hands. Lifted Phase 3 Pad and Access road restictions to V & W Pads @ 13:30 Hrs. 13:30 - 14:00 0.50 DRILL P SURF Fill hole & Riser. Check for leaks - OK. 14:00 - 15:30 1.50 DRILL P SURF M/U BHA # 1, Orient, Surface check MWD - OK. 15:30 - 17:30 2.00 DRILL P SURF Tag cement @ 106'. Drill 9 7/8" Hole to 357' '",",. 17:30 - 18:00 0.50 DRILL P SURF POH w/2 stands HWDP. M/U Jar stand & RIH. 18:00 - 00:00 6.00 DRILL P SURF Drill 9 7/8" Directional Hole from 357' to 1001' Up = 73K DN = 70K RT = 71 K 652 GPM @ 2000 psi. WOB = 5 - 35 K. ART = 3.3 Hrs. AST = 2.7 Hrs. 5/2/2002 00:00 - 06:30 6.50 DRILL P SURF Drill from 1001' to 1692'. 652 GPM @ 2210 psi. PU = 85K DN = 77K RT = 81 K. WOB = 30K AST = 2.8 Hrs. ART = 2.7 Hrs. 06:30 - 07:30 1.00 DRILL P SURF Circ. LO - HI Vis. sweep. 07:30 - 08:00 0.50 DRILL P SURF POH - Tight @ 1055' to 905',797' & 635' to 630'. Wiped all- OK 08:00 - 09:30 1.50 DRILL P SURF Stand back HWDP, Jars & DC's. C/O Bit & RIH wi Mtr & MWD. 09:30 - 10:00 0.50 DRILL P SURF Service Top Drive & Blocks. 10:00-11:00 1.00 DRILL P SURF RIH - Work through tight spot @ 760'. Pushing debris from 982' to 1652'. 11 :00 - 11 :30 0.50 DRILL P SURF Wash last stand to bottom @ 1692'. 11 :30 - 17:00 5.50 DRILL P SURF Drill from 1692' to 3113' - TD per Geologist. 652 GPM @ 3250 psi. PU = 100K DN = 70K Rt = 87K. TQ = 6500. WOB = 35K AST = 1.6 Hrs. ART = 2.42 Hrs. 17:00 - 18:00 1.00 DRILL P SURF Circ. LO - HI Vis Sweep. 18:00 - 18:30 0.50 DRILL P SURF POH to 2750'. Swabbing & pulling 15 to 45K over. 18:30 - 19:00 0.50 DRILL P SURF RIH to 2900' - Tight. Ream to bottom @ 3113'. 19:00 - 20:00 1.00 DRILL P SURF Circ. Weighted sweep. 20:00 - 00:00 4.00 DRILL P SURF Back ream out of Hole to 905'. 650 GPM & 100 RPM. Heavy cuttings over shakers throughout. 5/3/2002 00:00 - 01 :00 1.00 DRILL P SURF Cont. Backreaming out of hole to 264'. 650 GPM & 100 RPM. 01 :00 - 01 :30 0.50 DRILL P SURF Circ. bottoms up. 01 :30 - 03:00 1.50 DRILL P SURF POH & UD BHA. 03:00 - 05:00 2.00 CASE P SURF R/U Csg equip. Make dummy run wi Hanger & Ldg. Jt. 05:00 - 13:00 8.00 CASE P SURF Run 75/8" Csg. Had to wash down from 240' to 450'. Worked through tight spot from 915' to 930'. Smooth from 1100'. Land Hgr., B/O Franks tool & R/U Cmt. head & Lines. 13:00 - 15:30 2.50 CEMT P SURF C&C Mud for Cmt. Job. Unloading large amounts of cuttings & Printed: 5/20/2002 3:13:41 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/30/2002 Rig Release: 5/13/2002 Rig Number: 9-ES Spud Date: 5/1/2002 End: 5/13/2002 5/312002 13:00 - 15:30 2.50 CEMT P SURF gravel. Yield down to 12. 15:30 - 17:30 2.00 CEMT P SURF PJSM. Pump 5 bbls CW - 100, test lines to 4000 psi, pump 5 bbls. CW - 100. Pump 75 bbls. 10.2 ppg MUDPUSH XL. Drop btm plug & pump 313 bbls 10.7 ppg Arctic Lite Lead slurry followed by 52 bbls. 15.8 ppg Class "G" Tail slurry. Drop top plug and chase w/10 bbls water and 125 bbls mud. Bump plug wi 1500 psi. Floats ok. NO CEMENT TO SURFACE.. 17:30 - 18:30 1.00 CEMT P SURF RID Cement head, C/O bails, back off pup jt. on Landing Jt. 18:30 - 19:30 1.00 CEMT N CEMT SURF M/U TAM Combo tool. RIH to port collar. M/U pump-in sub & hose. 19:30 - 23:00 3.50 CEMT N CEMT SURF Open TAM port collar. Establish circ. 5 BPM @ 620 psi. Contaminated cement to surface after 60 bbls pumped. Large quantities of gravel over the shakers. Mud clabbered. 220 bbls. contaminated cmt & mud dumped. Finally cleaned up. 23:00 - 00:00 1.00 CEMT N CEMT SURF Cement: Pump 20 bbls water followed by 10.7 Lite cement. cement returns to surface after pumping 200 bbls. Total pumped - 221 bbls. Displace DP wi 5 bbls water and 10 bbls mud. Close Tam port collar & test to 1000 psi - OK. Bleed off pressure - no back-flow. 5/4/2002 00:00 - 01 :00 1.00 CEMT N CEMT SURF Pull Combo tool out of Tam Collar. Shear choke wi 1750 psi. Circ. clean. 01 :00 - 02:00 1.00 CEMT N CEMT SURF POH, LID Combo Tool. 02:00 - 03:00 1.00 CEMT P SURF M/U Csg Pup on Landing Jt. Break out Landing Jt. & LID. 03:00 - 06:30 3.50 DIVRTR P SURF NID Diverter System. C/O Boot to 16". 06:30 - 10:30 4.00 BOPSUR P PROD1 N/U Gen-5 Lower Split Unihead & 13 5/8" BOPE. Test metal to metal seal @ casing spool to 1000 psi. 10:30 - 15:00 4.50 BOPSUR P PROD1 Test BOPE to 250 14500 psi - Annular to 250 13500 psi. Witness of test waived by Chuck Sheve, AOGCC. 15:00 - 15:30 0.50 BOPSURP PROD1 RID test equip. Install Wear Bushing. 15:30 - 16:00 0.50 BOPSUR P PROD1 Service Top Drive. 16:00 - 23:00 7.00 BOPSUR P PROD1 P/U DP from shed & stand back in derrick. 23:00 - 00:00 1.00 BOPSUR P PROD1 Bring BHA # 3 to floor. 5/5/2002 00:00 - 02:30 2.50 DRILL P PROD1 P/U & M/U BHA # 3. 02:30 - 04:00 1.50 DRILL P PROD1 P/U 4" DP & RIH to 2845'. 04:00 - 05:00 1.00 DRILL P PROD1 Fill Pipe. Pressure test 7 5/8" Csg to 3500 psi. Chart for 30 minutes. 05:00 - 06:00 1.00 DRILL P PROD1 Hold "Trip" & "Stripping" Drills with Hunt's Crew. 06:00 - 07:30 1.50 DRILL P PROD1 Cut & slip 65' drilling line. Inspect & adjust brakes. 07:30 - 10:ob 2.50 DRILL P PROD1 Wash down to F/C. Drill plugs, FIC, Cement & Shoe. Clean out rat hole & drill 20' of new hole to 3133'. 10:00 - 10:30 0.50 DRILL P PROD1 Displace hole wi new 9.3 ppg. LSND Mud. 10:30 - 11 :00 0.50 DRILL P PROD1 Pull bit inside casing and perform LOT to 13.6 ppg. EMW. 11 :00 - 11 :30 0.50 DRILL P PROD1 Place bit just outside casing and take Benchmark ECD readings. ( see Remarks). 11 :30 - 18:00 6.50 DRILL P PROD1 Drill from 3133' to 4337'. WOB = 4 -15K 330 GPM @ 2340 psi. UP = 100K ON = 75K RT = 87K TQ = 3700 @ 60 RPM. AST = 0.7 Hrs. ART = 3 Hrs. 18:00 - 19:00 1.00 DRILL P PROD1 Circulate LO - HI Vis Sweep. ECD down to 11.47 ppg . Calculated ECD = 11.17 ppg. : 0.3 ppg over. 19:00 - 21 :30 2.50 DRILL P PROD1 POH - swabbing and pulling 10 to 30 Kover. Backream from 4056' up to shoe. No cuttings over shaker. No problems backreaming @ 110 RPM & 330 GPM. Printed: 5/20/2002 3: 13:41 PM ) ) Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/30/2002 Rig Release: 5/13/2002 Rig Number: 9-ES Spud Date: 5/1/2002 End: 5/13/2002 5/512002 21 :30 - 22:00 0.50 DRILL P PROD1 Service Top Drive. 22:00 - 22:30 0.50 DRILL P PROD1 RIH to 4244'. Hole slick. 22:30 - 00:00 1.50 DRILL P PROD1 Wash to bottom - no fiII.drill from 4337' to 4523' Same Parameters. ART = 0.4 Hrs. 5/6/2002 00:00 - 05:00 5.00 DRILL P PROD1 Drill from 4523' to 5365'. WOB = 5 to 15K TO = 5500 330 GPM @ 2550 psi. UP = 118K DN = 80K RT = 94K AST = 0.2 Hrs. ART = 2.5 Hrs. 05:00 - 06:00 1.00 DRILL P PROD1 Circulate tandem HI-LO Vis Sweeps. ECD down to 11.43 ppg. 06:00 - 09:30 3.50 DRILL P PROD1 POH dry to 4990'- 15 to 30K over pull. Unable to go back down to wipe @ 4990. Backream up to 4245'. Pull 1 stand into old hole - OK. RIH to 5084' - taking weight. Ream to 5365' 09:30 - 23:30 14.00 DRILL P PROD1 Drill from 5365' to 7139'. WOB = 5 to 15K TO = 7000 330 GPM @ 2950 psi. UP = 137K DN = 89K RT = 106K ART = 7.44 Hrs AST = 1 Hr. 23:30 - 00:00 0.50 DRILL P PROD1 Circulate LO-HI Vis. sweep - 110 RPM, 330 GPM up, 250 dn. 5/7/2002 00:00 - 00:30 0.50 DRILL P PROD1 COMPLETE PUMPING LO-HI VIS SWEEP. 330 GPM/11 0 RPM. CALCULATED ECD = 11.4 ACTUAL ECD = 11.5 00:30 - 05:00 4.50 DRILL P PROD1 WIPER TRIP - PULLED 50 TO 60K OVER @ 6040' - 6020' SWABBING. BACKREAM FROM 6020' TO 5365'. PULL 1 STAND DRY INTO OLD HOLE - NO PROBLEM. RIH TO 7050'. REAM LAST STAND TO BOTTOM @ 7139'. 05:00 - 15:00 10.00 DRILL P PROD1 DRILL FROM 7139' TO 8163'. WOB = 8 TO 16K TO = 8400 PU = 157K DN = 92K RT = 117K 330 GPM 3480 PSI, 80 RPM STARTED LOSING FLUID TO WELL ( 25 - 40 BBLS/HR) 2 8050' ADDED BAROFIBER & MONITOR WHILE DRILLING AHEAD. LOSSES AT 10 BBLS I HR BY 8163'. ECD @ 12.8 PPG. 15:00 - 16:00 1.00 DRILL P PROD1 CIRCULATE LO-HI VIS SWEEP. ECD DROPPED TO 11.9 PPG 16:00 - 00:00 8.00 DRILL P PROD1 CONTINUE DRILLING TO 8660' WOB = 8 TO 20K TO 7500 PU = 160K DN = 103K RT = 126K 330 GPM @ 3300 PSI MAINTAIN ECD 11.7 - 11.9 PPG AVG. SINCE 05:00 HRS: ART = 8.42 HRS. AST = 3.44 HRS WEIGHTED MUD UP TO 10.0 PPG WITH SPIKE FLUID WHILE DRILLING. 5/8/2002 00:00 - 03:00 3.00 DRILL P PROD1 CONTINUE DRILLING: FROM 8660' TO 8909'.80 RPM TO = 8K UP = 166K DN = 108K RT = 130K 330 GPM @ 3380 PSI ART = 1.6 HRS. AST = 0.7 HRS. 03:00 - 04:00 1.00 DRILL P PROD1 CIRCULATE HI-LO VIS SWEEP. 110 RPM & 330 GPM. CALCULATED ECD = 11.25 PPG ACTUAL ECD = 11.43 PPG 04:00 - 06:00 2.00 DRILL P PROD1 WIPE TO OLD HOLE @ 7046'. HOLE SLICK IN AND OUT. MAX 15K OVERPULL I DRAG. 06:00 - 15:30 9.50 DRILL P PROD1 DRILL FROM 8909' TO 9595'. TD PER GEOLOGIST. TO = 10.2K 330 GPM @ 3340 PSI. UP = 182K DN = 119K RT = 143K ART = 6.42 HRS. AST = 0.56 HRS. 15:30 - 17:30 2.00 DRILL P PROD1 CIRCULATE TANDEM LO-HI VIS SWEEPS. ECD= 11.6 PPG 17:30 - 23:00 5.50 DRILL P PROD1 POH FOR WIPER TRIP TO SHOE. PULL SMOOTH WI NO PROBLEMS TO 4200' PULLED 25K OVER & SWABBING. Printed: 5/20/2002 3:13:41 PM ') ) BP EXPLORATION Operations Summary Report Page 4 of 6 Legal Well Name: V -1 06 Common Well Name: V -1 06 Spud Date: 5/1/2002 Event Name: DRILL +COMPLETE Start: 4/30/2002 End: 5/13/2002 Contractor Name: NABORS Rig Release: 5/13/2002 Rig Name: NABORS 9ES Rig Number: 9-ES HOUrs ..Task Code NPT Dêscri ptiÖl'lbfOþeratiöns 5/8/2002 17:30 - 23:00 5.50 DRILL P PROD1 WORK PIPE TO 4050 - 50K OVER. MIU TOP DRIVE & WASH BACK DOWN TO 4250'. CIRCULATE LO - HI VIS SWEEP. POH DRY TO 3764' PULLED TIGHT WI 50K OVER. MIU TOP DRIVE. 23:00 - 00:00 1.00 DRILL P PROD1 START BACKREAMING TO SHOE. 5/9/2002 00:00 - 00:30 0.50 DRILL P PROD1 BACKREAM TO SHOE. PULL TIGHT @ 3200'. REAM TWICE -OK. 00:30 - 01 :00 0.50 DRILL P PROD1 PUMP LO-HI VIS SWEEP INSIDE SHOE TO CLEAN CASING. 01 :00 - 01 :30 0.50 DRILL P PROD1 SERVICE TOP DRIVE & CROWN. 01 :30 - 04:00 2.50 DRILL P PROD1 RIH TO 9500'. NOT A BOBBLE. 04:00 - 08:00 4.00 DRILL P PROD1 WASH TO BOTTOM @ 9595'. NO FILL. CIRCULATE TANDEM LO-HI VIS SWEEPS. SPOT LOGGING PILL. PUMP DRY JOB. DROP DP RABBIT. 08:00 - 11 :00 3.00 DRILL P PROD1 POH TO SHOE. NO EXCESS DRAG. HOLE SLICK. 11 :00 - 12:00 1.00 DRILL P PROD1 PUMP LO-HI VIS SWEEP TO ENSURE CASING CLEAN. 12:00 - 12:30 0.50 DRILL P PROD1 POH WI DP TO BHA. 12:30 - 14:30 2.00 DRILL P PROD1 STAND BACK HWDP & JAR STAND. LID DC's, LWD, MOTOR & BIT. CLEAR & CLEAN FLOOR. 14:30 - 23:00 8.50 EVAL P PROD1 PJSM WI SWS AND ALL HANDS. RIU SWS . RIH TO 9595'. LOG PEX I BHC SONIC THROUGH KUPARUK & SCHRADER AS PER PROGRAM. POH WI TOOLS. RID SWS. HOLE SEEPAGE = 2 BPH. 23:00 - 00:00 1.00 BOPSUR P PROD1 PULL WEAR BUSHING & INSTALL TEST PLUG & BEGIN BOP TEST. 5/10/2002 00:00 - 02:30 2.50 BOPSUR P PROD1 COMPLETE BOPE TESTING. TEST ALL TO 250 PSI 14500 PSI. ANNULAR TO 250 I 3500 PSI. TEST WITNESSED BY JOHN CRISP, AOGCC. 02:30 - 03:00 0.50 DRILL P PROD1 PULL TEST PLUG. INSTALL WEAR BUSHING. RID TEST EQUIP. 03:00 - 05:00 2.00 DRILL P PROD1 MIU 6 3/4" PORCUPINE HOLE OPENER AND RIH TO SHOE. 05:00 - 06:00 1.00 DRILL P PROD1 CUT & SLIP 80 DRILLING LINE. INSPECT BRAKES. SERVICE TOP DRIVE & CROWN. 06:00 - 09:30 3.50 DRILL P PROD1 RIH. BREAK CIRCULATION @ 5600', 7500' & 9500'. 09:30 - 12:00 2.50 DRILL P PROD1 WASH TO TO @ 9595' - NO FILL. PUMP TANDEM LO-HI VIS SWEEPS. SPOT CASING LUBE PILL FOR LOWER SECTION. 12:00 - 14:30 2.50 DRILL P PROD1 POH STAND BACK 25. LID DP TO 7000' 14:30 - 15:30 1.00 DRILL P PROD1 CIRCULATE & SPOT "STEEL SEAL" PILL FOR UPPER SECTION. 15:30 - 19:30 4.00 DRILL P PROD1 CONTINUE POH LID DP. 19:30 - 20:30 1.00 DRILL P PROD1 STAND BACK HWDP. LID JARS & H/O. 20:30 - 21 :00 0.50 CASE P PROD1 PULL WEAR BUSHING. P/U HANGER & LANDING JOINT & MAKE DUMMY RUN. 21 :00 - 22:00 1.00 CASE P COMP RIU TO RUN CASING. 22:00 - 23:30 1.50 CASE P COMP PJSM. M.U SHOE TRACK, LATCH 7 TEST FLOATS - OK. RUN ALL 3.5" WITH JEWELRY. 23:30 - 00:00 0.50 CASE P COMP CHANGE OVER TO 5.5" SPIDERS & RIU FRANKS TOOL. 5/11/2002 00:00 - 23:00 23.00 CASE P COMP CONTINUE RUNNING 5.5" CASING, CIRCULATING IN EVERY JOINT. CIRCULATE 1 1/2 TIMES BOTTOMS UP @ 3090',4200',6900'.100% DISPLACEMENT & RETURNS THROUGHOUT. Printed: 5/20/2002 3: 13:41 PM ) BP EXPLORATION Operations Summary Report Page 50f6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V -1 06 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/30/2002 Rig Release: 5/13/2002 Rig Number: 9-ES Spud Date: 5/1/2002 End: 5/13/2002 5/11/2002 23:00 - 23:30 0.50 CASE P COMP PIU CASING HANGER WITH LANDING JT. LAND CASING. MIU CEMENT HEAD. 23:30 - 00:00 0.50 CASE P COMP BREAK CIRCULATION, STAGE UP PUMPS TO 4 BPM/815 PSI. 100 % RETURNS. 5/12/2002 00:00 - 02:00 2.00 CEMT P COMP CIRCULATE & CONDITION MUD FOR CEMENT JOB - PV = 12 YP = 14 4 BPM @ 815 PSI-100% RETURNS. RECIPROCATING PIPE 02:00 - 04:30 2.50 CEMT P COMP SWITCH TO DOWELL. PUMP 5 BBLS. CW-100, TEST LINES TO 4000 PSI., PUMP 15 BBLS CW-100. PUMP 35 BBLS, 10.8 PPG. MUDPUSH XL SPACER PUMP 59 BBLS, 11.5 PPG, LiteCRETE LEAD SLURRY FOLLOWED BY 28 BBLS, 15.8 PPG, LATEX "G" TAIL SLURRY. ALL PUMPED @ 3.5 BPM. FLUSH LINES & DROP COMBO TOP & BOTTOM WIPER PLUGS. DISPLACE CEMENT WITH RIG PUMP. 220.5 BBLS SEAWATER BUMP PLUG WITH 2100 PSI. FLOATS - OK. RECIPROCATED UNTIL LEAD SLURRY AROUND SHOE - GOT STICKY. 100 % RETURNS THROUGHOUT JOB. 04:30 - 05:00 0.50 CEMT P COMP RID SWS CMT. HEAD. LID LANDING JT. 05:00 - 06:00 1.00 RUNCOIVP COMP INSTALL PACK-OFF RI.L.D.S., TEST TO 4000 PSI. 06:00 - 07:30 1.50 RUNCOIVP COMP RIU 3.5 TBG. EQUIP. MAKE DUMMY RUN WI HANGER 07:30 - 19:00 11.50 RUNCOIVP COMP RUN 3.5" PRODUCTION TUBING & JEWELRY AS PER PROGRAM. SPACE OUT SEAL ASSY. INTO PBR 19:00 - 20:00 1.00 RUNCOIVP COMP REVERSE CIRC TO SPOT CORROSION INHIBITED CLEAN SEAWATER 20:00 - 21 :00 1.00 RUNCOIVP COMP DRAIN BOP, LAND HANGER & RI.L.D.S. 21 :00 - 23:00 2.00 RUNCOIVP COMP TEST TUBING TO 4500 PSI FOR 30 MINUTES. BLEED PRESSURE TO 3000 PSI & PRESSURE UP ANNULUS. DEFINITE SHEAR OF RP VALVE AT 4300 PSI WITH TUBING PRESSURE AT 3100 PSI-INSTANT EQUALIZATION. PRESSURED UP ANNULUS & TUBING TO 4500 PSI AND HELD FOR 30 MINUTES FOR CASING TEST. BLED OFF TUBING & ANNULUS THROUGH TUBING. BROKE CIRC DOWN ANNULUS INTO TUBING TO CONFIRM SHEAR 3 BBLS I MIN @ 2400 PSI. 23:00 - 23:30 0.50 BOPSURP COMP SET TWC. TEST TO 2800 PSI. 23:30 - 00:00 0.50 BOPSUR P COMP NIPPLE DOWN BOPE. 5/13/2002 00:00 - 01 :00 1.00 BOPSURP COMP N/D BOPE 01 :00 - 03:00 2.00 WHSUR P COMP NIU ADAPTER FLANGE & TREE. TEST TO 5000 PSI. 03:00 - 03:30 0.50 WHSUR P COMP RlU DSM. PULL TWC. 03:30 - 05:30 2.00 CHEM P COMP RlU LITTLE RED. TEST LINES TO 3500 PSI. PUMP 107 BBLS DIESEL DOWN 5.5" X 3.5" ANNULUS. ALLOW TO U-TUBE. 05:30 - 07:00 1.50 EVAL P COMP CONTINUE TO ALLOW DIESEL TO U-TUBE. RIG UP ON 7.625" X 5.5" ANNULUS. PERFORM LOT = 12.46 EMW. INJECTION RATES: 1 BPM @350 PSI, 2BPM @ 500 PSI, 3BPM @ 850 PSI4 BPM @ 900 PSI, 5 BPM @ 975 PSI INJECT 55 BBLS. FINAL - 5BPM @ 810 PSI. PUMP 40 BBLS DIESEL TO FREEZE PROTECT. RID LITTLE RED. 07:00 - 07:30 0.50 WHSUR P COMP SET BPV. TEST TO 1000 PSI. 07:30 - 12:00 4.50 RIGD P POST RD DSM. BLOW DOWN & RD ALL LINES. CLEAN PITS. CHG Printed: 5/20/2002 3:13:41 PM ) ') BP EXPLORATION Operations Summary Report Page60f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 06 V-106 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/30/2002 Rig Release: 5/13/2002 Rig Number: 9-ES Spud Date: 5/1/2002 End: 5/13/2002 HoUrs COde NPT Phase Description of Operations 5/13/2002 07:30 - 12:00 4.50 RIGD P POST LINERS ON PUMPS TO 51/2". CHG VALVES, SEATS, SWABS. CLEAN RIG. SECURE WELL. RELEASE RIG FROM L-106 AT 12:00 HRS ON 5/13/02. Printed: 5/20/2002 3:13:41 PM ) ") Well: Field: API: Permit: V -1 06 Prudhoe Bay Field / Borealis Pool 50-029-23083-00 202-080 Rig Accept: 04-30-02 Rig Spud: 05-01-02 Rig Release: 05-13-02 Drilling Rig: Nabors 9-ES POST RIG WORK OS/26/02 PERFORATED 9364'-9385' AND 9337'-9358' IN THREE RUNS WITH 2.5" 2506 POWERFLOW BH 6 SPF ORIENTED +1- 10 DEGREES. CHARGE DATA: 0.66" EH, 4.8" PENE, 10.5 GMS. ALL SHOTS FIRED, WHP CHANGED FROM 0 TO 200 PSI. OS/27/02 INJECTIVITY TEST. 1 BPM-2310, 2 BPM- 2475 PSI, 3 BPM- 2700 PSI. 05/30/02 RAN PETREDAT GAUGES & PERFORMED SBHPS WITH STOPS AT 9467', 9365', 9262' & 9365' MD. ACQUIRED GOOD DATA. RAN 3 1/2" CATCHER. 05/31/02 SET CATCHER. PULL STA 1, RP SHEAR VLV. SET SIDE POCKET MEMORY GAUGE IN STA 1. PULL CATCHER. MIT IA TO 3020 PSI. TEST PASSED. LOST 40-PSIIN 30 MIN. BLEED IA DOWN TO 950 PSI. FOUND BOTTOM 2 3/4" OF SPMG LATCH IN CATCHER. RERUN CATCHER RERUN NEW SPMG STA#1 INTERGAL, PULL C-SUB 06/02102 FRACTURE TREAT KUPARUK "C" SANDS WITH 232487# OF CARBOLlTE (58080# WAS 12X18, REMAINDER WAS 16X20). FLUSHED TO COMPLETION WITH 229988# BEHIND PIPE. ESTIMATE 2500# OF 12X18 CARBOLlTE IN WELLBORE. 06/03/02 MIRU UNIT #8. RIH CIRCULATING SLICK KCL AT 2 B/M TO SUSPECTED SAND TOP AT 8858. CIRCULATE DOWN TO 8960 USING TWO 5 BBLS SWEEPS OF HEC. POH TO CHANGE OUT NOZZLES. 06/04/02 MADE COUPLE ATTEMPTS TO FISH TREE SAVER SEALS WITH NO LUCK DUE TO WELL GETTING SLUSHY, RDMO. CHANGE OUT BHA. RIH JETTING FILL FI 8892' TO 9287' DID NOT ENCOUNTER RUBBER CUPS. POOH CHANGE BHA,RIH REVERSE OUT FILL FI 8892' TO 9360' DID NOT ENCOUNTER RUBBER CUPS. GOOD RETURNS THROUGHOUT JOB. FP WELL TO 3000'. 06/05/02 PULLED DGLV'S FROM GLM'S #2 AND #3. SET 16/64" - 1789 # TRO LGLV IN GLM #2 AND A 16/64" - 1746# TRO LGLV IN GLM # 3 - ALL BOTTOM LATCH. PULLED CATCHER SUB. WE WERE UNABLE TO PULL THE SPMG IN GLM #1 DUE TO FRAC SAND IN THE WELLBORE. 06/17/02 UNABLE TO GET TOOLS PAST 92' SLM W/3 1/2" SLIP STOP CATCHER SUB, SUSPECT ICE PLUG-- PRESSURE UP TO 3000 PSI WI METH. (HOLDING PRESSURE @ 2875 PSI IN 10 MIN.) V-106, Post Rig Summary Page 2 ) ) 06/18/02 MIRU DS CTU #3. RIH W/2.25" DJN. TAG ICE AT 153' CTM. HB&R PUMPING 150 DEG DIESEL DOWN COIL. BREAK THROUGH ICE ON IA WHEN COIL WAS AT 830' CTMD. DRIFT DOWN TO 5500' CTMD. FP IA WI 48 BBLS NEAT METH. CIRC FP IN TBG WI 33 BBLS NEAT METH WHILE POOH. DID NOT FP FL. ASSIST CTU - PUMPED 145 BBLS HOT DIESEL TO JET ICE PLUG OUT. PUMPED UP IA WITH 1 BBL NEAT METHANOL TO 2500 PSI PRIOR TO PUMPING HOT DIESEL DWN COIL. PUMPED 48 BBLS NEAT DWN IA @ 1.4 BBLS/MIN. 06/24/02 PUMP HOT CRUDE DOWN IA AND UP TBG FOR APC TEST CREW PRE-FLOW. 06/25/02 HOT OIL I.A.; PUMPED 18 BBLS HOT CRUDE, WELL LOCKED UP 06/29/02 HEAT KCL WATER TO 170* F I PUMP 92 BBLS SLICK KCL WATER TO ASSIST COIL IN THAWING PLUG DOWN HOLE. MIRU CTU #3 WAIT ON LOADER TO PLACE RIG MATS. RIH W/2.25 JSN FOR CLEAN OUT, ICE BRIDGES AND PLUGS F/500'. 955'. HARD PLUG AT 1000'. POOH CHANGE TO DJN RBIH WASH F/1022- 1030'. 06/30/02 AWGRS I PUMP 269 BBLS HEATED KCL WATER DOWN COIL TO ASSIST WITH THAWING ICE PLUG. WASH F/1030' - 1225', BREAK THROUGH ICE - 650 PSI UNDER PLUG. CONTINUE RIH TO 5000' NO OBSTRUCTIONS. POOH, SWITCH TO JSN. RIH TO CLEAN OUT. CIRCULATE 160 DEG KCL IN TUBING TO WARM UP ANNULUS (I/A PRESSURE DROPPED FROM F/1950-1680 PSI AS WELL WARMED UP, END PRESSURE -1520 PSI), KICK OFF GAS LIFT. CLEAN OUT WELL FROM 7900' TO 9518' (PBTD) WITH HEC SWEEPS. CIRCULATE ON BOTTOM FOR 45 MIN. POOH WASHING GLM'S. ANADRILL SCHLUMBERGER Survey report Client...... ....... ... ...: BP Exploration (Alaska) Inc. Field... ..... ............: Prudhoe Bay / Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-106 API number.... ......... ..: 50-029-23083 Engineer..... ... ....... ..: Franco COUNTY:......... .........: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.. ...: Minimum curvature Method for DLS.. .........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum........ ..: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 54.30 ft KB above permanent..... ..: n/a DF above permanent.. .....: 82.80 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: 17.45 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 8-May-2002 19:28:48 Spud da t e. . . . . . . . . . . . . . . . : Last survey date..... ....: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 01-May-02 08-May-02 105 0.00 ft 9595.00 ft ~- ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date........ ....: 30-Apr-2002 Magnetic field strength..: 1149.52 HCNT Magnetic dec (+E/W-) .....: 26.06 degrees Magnetic dip.............: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H.............. : Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.52 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.06 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.06 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 .- ~ ANADRILL SCHLUMBERGER Survey Report 8-May-2002 19:28:48 Page 2 of 5 ===. -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 eft) (deg) (deg) eft) eft) eft) eft) eft) eft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 130.30 0.33 125.37 130.30 130.30 -0.12 -0.22 0.31 0.38 125.37 0.25 MWD_IFR_MSA 3 197.45 0.90 118.79 67.15 197.45 -0.28 -0.58 0.93 1.09 122.20 0.85 MWD_IFR_MSA 4 290.30 0.99 81.53 92.85 290.28 -0.07 -0.82 2.36 2.50 109.09 0.66 MWD_IFR_MSA 5 383.57 0.76 35.32 93.27 383.54 0.87 -0.19 3.51 3.52 93.14 0.77 MWD_IFR_MSA 6 474.80 1.25 339.69 91.23 474.76 2.23 1.23 3.52 3.73 70.67 1.13 MWD_IFR_MSA 7 567.81 2.53 335.91 93.01 567.72 4.57 4.06 2.33 4.68 29.82 1.38 MWD_IFR_MSA -- 8 660.62 3.70 334.72 92.81 660.39 8.30 8.64 0.21 8.64 1.41 1.26 MWD_IFR_MSA 9 754.72 5.52 341.59 94.10 754.18 14.20 15.68 -2.51 15.88 350.89 2.02 MWD_IFR_MSA 10 847.54 7.27 350.55 92.82 846.42 23.06 25.71 -4.89 26.17 349.23 2.16 MWD_IFR_MSA 11 941.07 7.89 353.24 93.53 939.14 34.19 37.92 -6.62 38.49 350.10 0.76 MWD_IFR_MSA 12 1034.35 9.67 358.21 93.28 1031.32 47.43 52.11 -7.61 52.66 351.69 2.07 MWD_IFR_MSA 13 1124.53 12.18 4.92 90.18 1119.86 63.87 69.16 -7.03 69.52 354.19 3.12 MWD_IFR_MSA 14 1216.33 15.45 9.97 91.80 1209.00 85.45 90.86 -4.09 90.95 357.43 3.79 MWD_IFR_MSA 15 1308.34 18.40 13.51 92.01 1297.02 112.10 117.06 1.43 117.07 0.70 3.39 MWD_IFR_MSA 16 1401.20 20.70 14.35 92.86 1384.52 143.11 147.21 8.92 147.48 3.47 2.50 MWD_IFR_MSA 17 1495.05 23.67 17.68 93.85 1471.41 178.52 181.24 18.76 182.21 5.91 3.44 MWD_IFR_MSA 18 1581.27 27.69 19.84 86.22 1549.10 215.86 216.59 30.82 218.77 8.10 4.79 MWD_IFR_MSA 19 1682.36 28.88 23.38 101.09 1638.13 263.61 261.09 48.48 265.56 10.52 2.03 MWD_IFR_MSA 20 1775.43 30.68 22.82 93.07 1718.90 309.61 303.61 66.61 310.83 12.37 1.96 MWD_IFR_MSA 21 1868.43 31.05 22.88 93.00 1798.73 357.11 347.58 85.13 357.85 13.76 0.40 MWD_IFR_MSA 22 1962.41 33.50 19.88 93.98 1878.19 407.16 394.31 103.38 407.64 14.69 3.11 MWD_IFR_MSA -' 23 2055.63 36.42 20.31 93.22 1954.58 460.52 444.46 121.74 460.83 15.32 3.14 MWD_IFR_MSA 24 2149.14 39.42 19.69 93.51 2028.34 517.92 498.46 141.38 518.13 15.84 3.23 MWD_IFR_MSA 25 2243.99 42.39 18.29 94.85 2100.02 580.00 557.19 161.57 580.14 16.17 3.28 MWD_IFR_MSA 26 2336.51 43.43 19.34 92.52 2167.78 642.97 616.81 181.89 643.07 16.43 1.36 MWD_IFR_MSA 27 2429.31 44.64 16.28 92.80 2234.51 707.45 678.21 201.59 707.54 16.55 2.64 MWD_IFR_MSA 28 2523.27 46.59 15.79 93.96 2300.23 774.58 742.75 220.14 774.68 16.51 2.11 MWD_IFR_MSA 29 2617.55 48.80 15.50 94.28 2363.68 844.27 809.89 238.94 844.40 16.44 2.36 MWÐ_IFR_MSA 30 2709.55 51.61 15.44 92.00 2422.56 914.90 878.01 257.79 915.07 16.36 3.05 MWD_IFR_MSA . ANADRILL SCHLUMBERGER Survey Report 8-May-2002 19:28:48 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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) eft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2802.90 52.94 16.45 93.35 2479.68 988.71 949.00 278.08 988.90 16.33 1.66 MWD_IFR_MSA 32 2895.75 55.49 16.09 92.85 2533.97 1064.01 1021.30 299.17 1064.22 16.33 2.76 MWD_IFR_MSA 33 2988.56 55.28 16.14 92.81 2586.69 1140.37 1094.68 320.37 1140.60 16.31 0.23 MWD_IFR_MSA 34 3051.91 56.69 16.78 63.35 2622.12 1192.87 1145.03 335.25 1193.10 16.32 2.38 MWD_IFR_MSA 35 3161.33 55.71 16.32 109.42 2682.99 1283.79 1232.19 361.16 1284.03 16.34 0.96 MWD_IFR_MSA 36 3255.12 55.42 16.10 93.79 2736.03 1361.12 1306.47 382.75 1361.38 16.33 0.36 MWD_IFR_MSA 37 3348.15 54.50 16.66 93.03 2789.44 1437.28 1379.55 404.23 1437.55 16.33 1.10 MWD_IFR_MSA - 38 3440.51 55.78 15.51 92.36 2842.23 1513.04 1452.36 425.22 1513.33 16.32 1.72 MWD_IFR_MSA 39 3534.03 56.94 15.84 93.52 2894.04 1590.86 1527.33 446.26 1591.18 16.29 1.27 MWD_IFR_MSA 40 3628.63 56.58 16.32 94.60 2945.89 1669.96 1603.35 468.17 1670.31 16.28 0.57 MWD_IFR_MSA 41 3721.37 55.73 16.73 92.74 2997.55 1746.97 1677.19 490.08 1747.33 16.29 0.99 MWD_IFR_MSA 42 3814.73 55.09 16.49 93.36 3050.55 1823.82 1750.84 512.05 1824.18 16.30 0.72 MWD_IFR_MSA 43 3907.68 56.31 16.07 92.95 3102.93 1900.59 1824.55 533.57 1900.97 16.30 1.36 MWD_IFR_MSA 44 4000.87 56.31 16.42 93.19 3154.62 1978.11 1898.99 555.26 1978.51 16.30 0.31 MWD_IFR_MSA 45 4093.21 58.08 15.49 92.34 3204.64 2055.69 1973.61 576.59 2056.11 16.29 2.10 MWD_IFR_MSA 46 4187.88 57.51 15.95 94.67 3255.10 2135.76 2050.72 598.29 2136.21 16.26 0.73 MWD_IFR_MSA 47 4283.91 56.89 15.77 96.03 3307.12 2216.45 2128.37 620.35 2216.93 16.25 0.66 MWD_IFR_MSA 48 4373.75 56.15 16.20 89.84 3356.68 2291.35 2200.40 640.99 2291.86 16.24 0.92 MWD_IFR_MSA 49 4466.56 55.92 15.54 92.81 3408.53 2368.30 2274.44 662.04 2368.84 16.23 0.64 MWD_IFR_MSA 50 4560.44 55.34 16.02 93.88 3461.53 2445.75 2349.01 683.11 2446.32 16.21 0.75 MWD_IFR_MSA 51 4652.60 56.70 16.90 92.16 3513.04 2522.16 2422.30 704.76 2522.74 16.22 1.67 MWD_IFR_MSA 52 4746.39 56.70 16.54 93.79 3564.53 2600.55 2497.37 727.32 2601.13 16.24 0.32 MWD_IFR_MSA .~ 53 4839.78 56.54 17.19 93.39 3615.91 2678.53 2572.00 749.94 2679.11 16.26 0.61 MWD_IFR_MSA 54 4934.54 55.91 17.37 94.76 3668.59 2757.29 2647.22 773.34 2757.86 16.28 0.68 MWD_IFR_MSA 55 5027.53 58.09 17.29 92.99 3719.24 2835.27 2721.66 796.57 2835.83 16.31 2.35 MWD_IFR_MSA 56 5121.08 57.97 16.90 93.55 3768.77 2914.63 2797.51 819.89 2915.19 16.33 0.38 MWD_IFR_MSA 57 5214.37 57.14 16.98 93.29 3818.82 2993.36 2872.83 842.83 2993.91 16.35 0.89 MWD_IFR_MSA 58 5308.87 56.82 16.68 94.50 3870.31 3072.59 2948.67 865.78 3073.14 16.36 0.43 MWD_IFR_MSA 59 5401.23 55.96 16.31 92.36 3921.44 3149.50 3022.42 887.62 3150.06 16.37 0.99 MWD_IFR_MSA 60 5495.98 56.19 16.36 94.75 3974.32 3228.10 3097.87 909.73 3228.68 16.37 0.25 MWD_IFR_MSA .. ANADRILL SCHLUMBERGER Survey Report 8-May-2002 19:28:48 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5589.76 56.45 15.88 93.78 4026.32 3306.12 3172.84 931.40 3306.72 16.36 0.51 MWD_IFR_MSA 62 5683.49 56.35 16.73 93.73 4078.19 3384.17 3247.77 953.31 3384.79 16.36 0.76 MWD_IFR_MSA 63 5776.86 56.77 16.09 93.37 4129.65 3462.07 3322.51 975.32 3462.70 16.36 0.73 MWD_IFR_MSA 64 5869.77 55.36 17.25 92.91 4181.51 3539.15 3396.35 997.43 3539.78 16.37 1.84 MWD_IFR_MSA 65 5963.57 55.11 17.56 93.80 4235.00 3616.20 3469.88 1020.48 3616.82 16.39 0.38 MWD_IFR_MSA 66 6056.74 54.95 17.85 93.17 4288.40 3692.55 3542.61 1043.70 3693.15 16.42 0.31 MWD_IFR_MSA 67 6149.94 55.44 19.17 93.20 4341.60 3769.06 3615.17 1067.99 3769.63 16.46 1.28 MWD_IFR_MSA 68 6243.17 57.60 20.42 93.23 4393.03 3846.75 3688.33 1094.33 3847.25 16.53 2.57 MWD_IFR_MSA - 69 6336.70 56.78 20.19 93.53 4443.71 3925.26 3762.05 1121.61 3925.69 16.60 0.90 MWD_IFR_MSA 70 6429.93 56.54 20.53 93.23 4494.95 4003.05 3835.07 1148.71 4003.41 16.67 0.40 MWD_IFR_MSA 71 6524.78 56.45 20.80 94.85 4547.30 4082.01 3909.07 1176.62 4082.31 16.75 0.26 MWD_IFR_MSA 72 6617.62 56.43 20.34 92.84 4598.63 4159.26 3981.51 1203.80 4159.51 16.82 0.41 MWD_IFR_MSA 73 6711.22 56.40 19.87 93.60 4650.41 4237.15 4054.73 1230.61 4237.36 16.88 0.42 MWD_IFR_MSA 74 6802.72 56.25 19.81 91.50 4701.14 4313.23 4126.35 1256.45 4313.41 16.94 0.17 MWD_IFR_MSA 75 6896.63 55.68 19.28 93.91 4753.70 4391.00 4199.69 1282.49 4391.15 16.98 0.77 MWD_IFR_MSA 76 6990.18 56.33 19.23 93.55 4806.01 4468.52 4272.91 1308.06 4468.65 17.02 0.70 MWD_IFR_MSA 77 7082.77 55.99 18.82 92.59 4857.57 4545.40 4345.62 1333.13 4545.51 17.05 0.52 MWD_IFR_MSA 78 7175.37 53.12 18.45 92.60 4911.26 4620.81 4417.09 1357.24 4620.91 17.08 3.12 MWD_IFR_MSA 79 7268.93 50.76 19.62 93.56 4968.94 4694.44 4486.73 1381.25 4694.53 17.11 2.71 MWD_IFR_MSA 80 7361.34 49.83 18.75 92.41 5027.97 4765.50 4553.87 1404.62 4765.57 17.14 1.24 MWD_IFR_MSA 81 7453.85 48.94 18.53 92.51 5088.19 4835.71 4620.41 1427.06 4835.77 17.16 0.98 MWD_IFR_MSA 82 7548.79 48.29 17.68 94.94 5150.96 4906.94 4688.11 1449.20 4906.99 17.18 0.96 MWD_IFR_MSA -- 83 7642.45 47.98 16.95 93.66 5213.47 4976.69 4754.70 1469.96 4976.74 17.18 0.67 MWD_IFR_MSA 84 7735.86 46.01 18.92 93.41 5277.18 5044.99 4819.69 1490.98 5045.04 17.19 2.61 MWD_IFR_MSA 85 7829.49 43.33 21.40 93.63 5343.77 5110.72 4881.48 1513.63 5110.76 17.23 3.41 MWD_IFR_MSA 86 7920.33 41.49 22.75 90.84 5410.83 5171.78 4938.25 1536.64 5171.80 17.28 2.26 MWD_IFR_MSA 87 8013.34 40.71 22.94 93.01 5480.92 5232.65 4994.60 1560.37 5232.66 17.35 0.85 MWD_IFR_MSA 88 8106.52 39.81 22.04 93.18 5552.03 5292.64 5050.23 1583.41 5292.64 17.41 1.15 MWD_IFR_MSA 89 8200.22 36.83 22.03 93.70 5625.54 5350.54 5104.08 1605.21 5350.54 17.46 3.18 MWD_IFR_MSA 90 8294.46 33.69 23.20 94.24 5702.48 5404.72 5154.30 1626.10 5404.72 17.51 3.41 MWD_IFR_MSA ~ANADRILL SCHLUMBERGER Survey Report 8-May-2002 19:28:48 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8387.16 31.64 22.78 92.70 5780.51 5454.51 5200.35 1645.65 5454.52 17.56 2.22 MWD_IFR_MSA 92 8480.83 29.09 22.83 93.67 5861.33 5501.65 5244.00 1664.00 5501.67 17.61 2.72 MWD_IFR_MSA 93 8574.03 28.26 22.82 93.20 5943.10 5546.18 5285.22 1681.35 5546.21 17.65 0.89 MWD_IFR_MSA 94 8666.12 26.67 22.05 92.09 6024.80 5588.49 5324.47 1697.56 5588.53 17.68 1.77 MWD_IFR_MSA 95 8758.90 26.62 20.16 92.78 6107.73 5630.01 5363.28 1712.54 5630.06 17.71 0.92 MWD_IFR_MSA 96 8853.30 23.45 19.15 94.40 6193.25 5669.92 5400.89 1726.00 5669.98 17.72 3.39 MWD_IFR_MSA 97 8946.75 20.44 17.21 93.45 6279.92 5704.83 5434.05 1736.93 5704.89 17.73 3.31 MWD_IFR_MSA -- 98 9040.94 16.91 15.23 94.19 6369.14 5734.97 5462.99 1745.39 5735.04 17.72 3.81 MWD_IFR_MSA 99 9133.84 16.06 19.66 92.90 6458.23 5761.32 5488.13 1753.27 5761.38 17.72 1.63 MWD_IFR_MSA 100 9227.42 14.14 20.25 93.58 6548.57 5785.67 5511.04 1761.58 5785.74 17.73 2.06 MWD_IFR_MSA 101 9321.16 12.73 19.00 93.74 6639.74 5807.43 5531.55 1768.91 5807.50 17.73 1.54 MWD_IFR_MSA 102 9414.69 12.68 17.11 93.53 6730.98 5828.00 5551.11 1775.28 5828.07 17.73 0.45 MWD_IFR_MSA 103 9507.93 11.88 16.30 93.24 6822.09 5847.83 5570.10 1780.98 5847.90 17.73 0.88 MWD_IFR_MSA 104 9538.70 11.49 16.75 30.77 6852.22 5854.06 5576.07 1782.76 5854.13 17.73 1.30 MWD_IFR_MSA 105 9595.00 10.78 17. 63 56.30 6907.46 5864.93 5586.46 1785.97 5865.00 17. 73 1.30 Projected to TD [(c)2002 Anadrill IDEAL ID6_1C_I0] ~' . O,bP .~.,. -, ~~- V-106 Survey Report - Geodetic Schlumberuer Report Date: 09-May-2002 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 17.730° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.00011 Structure / Slot: V-Pad IV-106 TVD Reference Datum: KB Well: V-106 TVD Reference Elevation: 82.800 ft relative to MSL Borehole: V-106 Sea Bed / Ground Level Elevation: 55.000 ft relative to MSL UWUAPI#: 50-029-23083-00 Magnetic Declination: +26.053° Survey Name / Date: V-106 5-7-2 I May 7,2002 Total Field Strength: 57475.514 nT Tort I AHD I DDI/ ERD ratio: 147.531° I 5881.53 ft I 6.081 10.851 Magnetic Dip: 80.756° -- Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Fee1 Declination Date: May 07, 2002 Location LatILong: N 70 1941.148, W 1491553.304 Magnetic Declination Model: BGGM 2001 Location Grid NlE YIX: N 5970118.610 ftUS, E 590651.190 ftUS North Reference: True North Grid Convergence Angle: +0.69228854° Total Corr Mag North -> True North: +26.053° Grid Scale Factor: 0.99990934 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec NI-S EJ-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970118.61 590651.19 N 701941.148 W 149 1553.304 130.30 0.33 125.37 130.30 -0.11 -0.22 0.31 0.25 5970118.40 590651.50 N 70 1941.146 W 149 1553.295 197.45 0.90 118.79 197.45 -0.27 -0.58 0.93 0.85 5970118.04 590652.12 N 70 19 41.142 W 149 1553.277 290.30 0.99 81.53 290.28 -0.06 -0.82 2.36 0.66 5970117.82 590653.56 N 70 1941.140 W 149 1553.235 383.57 0.76 35.32 383.54 0.89 -0.19 3.51 0.77 5970118.46 590654.70 N 70 1941.146 W 1491553.202 474.80 1.25 339.69 474.76 2.25 1.23 3.52 1.13 5970119.89 590654.69 N 70 1941.160 W 149 1553.202 567.81 2.53 335.91 567.72 4.58 4.06 2.33 1.38 5970122.70 590653.47 N 70 1941.188 W 149 1553.236 660.62 3.70 334.72 660.39 8.29 8.64 0.21 1.26 5970127.25 590651.30 N 70 1941.233 W 149 15 53.298~, 754.72 5.52 341.59 754.18 14.17 15.68 -2.51 2.02 5970134.26 590648.49 N 701941.302 W 149 1553.378 847.54 7.27 350.55 846.42 23.00 25.71 -4.89 2.16 5970144.25 590645.99 N701941.401 W1491553.447 941.07 7.89 353.24 939.14 34.11 37.92 -6.62 0.76 5970156.44 590644.12 N 701941.521 W 149 1553.497 1034.35 9.67 358.21 1031.32 47.32 52.11 -7.61 2.07 5970170.62 590642.95 N 70 19 41.660 W 149 1553.527 1124.53 12.18 4.92 1119.86 63.74 69.16 -7.03 3.12 5970187.68 590643.32 N 70 1941.828 W 149 1553.510 1216.33 15.45 9.97 1209.00 85.30 90.86 -4.09 3.79 5970209.41 590646.01 N 701942.041 W 1491553.424 1308.34 18.40 13.51 1297.02 111.93 117.06 1.43 3.39 5970235.67 590651 .20 N 70 19 42.299 W 149 15 53.263 1401.20 20.70 14.35 1384.52 142.94 147.21 8.92 2.50 5970265.90 590658.33 N 70 19 42.596 W 149 15 53.044 1495.05 23.67 17.68 1471.41 178.34 181.24 18.76 3.44 5970300.05 590667.75 N 70 1942.930 W 1491552.757 1581.27 27.69 19.84 1549.10 215.68 216.59 30.82 4.79 5970335.53 590679.39 N 70 19 43.278 W 149 15 52.405 V-106 ASP Final Survey. xis Page 1 of 4 5/13/2002-3:12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) lftUS) (ftUS) 1682.36 28.88 23.38 1638.13 263.45 261.09 48.48 2.03 5970380.25 590696.51 N 70 1943.716 W 1491551.889 1775.43 30.68 22.82 1718.90 309.48 303.61 66.61 1.96 5970422.98 590714.12 N 701944.134 W 1491551.360 1868.43 31.05 22.88 1798.73 357.00 347.58 85.13 0.40 5970467.16 590732.11 N 701944.566 W 149 1550.819 1962.41 33.50 19.88 1878.19 407.06 394.31 103.38 3.11 5970514.10 590749.79 N 70 19 45.026 W 149 15 50.286 2055.63 36.42 20.31 1954.58 460.43 444.46 121.74 3.14 5970564.47 590767.54 N 70 1945.519 W 149 1549.750 2149.14 39.42 19.69 2028.34 517.84 498.46 141.38 3.23 5970618.70 590786.53 N701946.050 W1491549.177 2243.99 42.39 18.29 2100.02 579.93 557.19 161.57 3.28 5970677.66 590806.00 N 70 19 46.628 W 149 15 48.587 2336.51 43.43 19.34 2167.78 642.90 616.81 181.89 1.36 5970737.52 590825.59 N 701947.214 W 1491547.994 2429.31 44.64 16.28 2234.51 707.39 678.21 201.59 2.64 5970799.15 590844.56 N 70 1947.818 W 1491547.419 2523.27 46.59 15.79 2300.23 774.51 742.75 220.14 2.11 5970863.89 590862.32 N 70 1948.453 W 149 1546.877 --' 2617.55 48.80 15.50 2363.68 844.18 809.89 238.94 2.36 5970931.25 590880.30 N 70 1949.113 W 1491546.328 2709.55 51.61 15.44 2422.56 914.81 878.01 257.79 3.05 5970999.59 590898.33 N 701949.783 W 149 1545.778 2802.90 52.94 16.45 2479.68 988.61 949.00 278.08 1.66 5971070.81 590917.75 N 70 1950.481 W 149 1545.185 2895.75 55.49 16.09 2533.97 1063.90 1021.30 299.17 2.76 5971143.35 590937.97 N 70 19 51.192 W 149 15 44.569 2988.56 55.28 16.14 2586.69 1140.25 1094.68 320.37 0.23 5971216.98 590958.29 N 701951.914 W 1491543.950 3051.91 56.69 16.78 2622.12 1192.74 1145.03 335.25 2.38 5971267.50 590972.55 N 701952.409 W 149 1543.516 3161.33 55.71 16.32 2682.99 1283.65 1232.19 361.16 0.96 5971354.96 590997.40 N 70 1953.266 W 149 1542.759 3255.12 55.42 16.10 2736.03 1360.98 1306.47 382.75 0.36 5971429.49 591018.09 N 70 1953.997 W 1491542.129 3348.15 54.50 16.66 2789.44 1437.12 1379.55 404.23 1.10 5971502.81 591038.68 N 70 19 54.715 W 1491541.502 3440.51 55.78 15.51 2842.23 1512.87 1452.36 425.22 1.72 5971575.87 591058.79 N 70 1955.432 W 149 1540.889 3534.03 56.94 15.84 2894.04 1590.68 1527.33 446.26 1.27 5971651.07 591078.92 N 70 1956.169 W 1491540.274 3628.63 56.58 16.32 2945.89 1669.77 1603.35 468.17 0.57 5971727.35 591099.91 N 701956.916 W 1491539.634 3721.37 55.73 16.73 2997.55 1746.78 1677.19 490.08 0.99 5971801.45 591120.92 N 70 1957.643 W 1491538.994 3814.73 55.09 16.49 3050.55 1823.62 1750.84 512.05 0.72 5971875.35 591142.00 N 70 19 58.367 W 149 15 38.353 3907.68 56.31 16.07 3102.92 1900.38 1824.55 533.57 1.36 5971949.30 591162.63 N 701959.092 W 1491537.724 4000.87 56.31 16.42 3154.62 1977.89 1898.99 555.26 0.31 5972024.00 591183.42 N 70 1959.824 W 1491537.091 -~ 4093.21 58.08 15.49 3204.64 2055.46 1973.61 576.59 2.10 5972098.86 591203.84 N 70 20 0.558 W 149 1536.468 4187.88 57.51 15.95 3255.1 0 2135.52 2050.72 598.29 0.73 5972176.22 591224.61 N 70 201.316 W 1491535.834 4283.91 56.89 15.77 3307.12 2216.19 2128.37 620.35 0.66 5972254.12 591245.73 N 70 20 2.080 W 1491535.189 4373.75 56.15 16.20 3356.68 2291.09 2200.40 640.99 0.92 5972326.39 591265.49 N 70 202.788 W 1491534.587 4466.56 55.92 15.54 3408.53 2368.02 2274.44 662.04 0.64 5972400.68 591285.64 N 70 20 3.516 W 1491533.972 4560.44 55.34 16.02 3461.53 2445.47 2349.01 683.11 0.75 5972475.49 591305.80 N 70 20 4.250 W 149 15 33.356 4652.60 56.70 16.90 3513.04 2521.87 2422.30 704.76 1.67 5972549.02 591326.57 N 70 204.971 W 149 1532.724 4746.39 56.70 16.54 3564.53 2600.25 2497.37 727.32 0.32 5972624.36 591348.21 N 70 20 5.709 W 1491532.065 4839.78 56.54 17.19 3615.91 2678.22 2572.00 749.94 0.61 5972699.25 591369.93 N 70 20 6.443 W 1491531.404 V-106 ASP Final Survey.xls Page 2 of 4 5/13/2002-3: 12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD vSec NI.S EI.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°'1000) (ftUS) (ftUS) 4934.54 55.91 17.37 3668.59 2756.99 2647.22 773.34 0.68 5972774.73 591392.42 N 70207.182 W 149 1530.720 5027.53 58.09 17.29 3719.24 2834.97 2721.66 796.57 2.35 5972849.44 591414.74 N 70207.915 W 1491530.042 5121.08 57.97 16.90 3768.77 2914.32 2797.51 819.89 0.38 5972925.57 591437.15 N 70 20 8.661 W 149 15 29.360 5214.37 57.14 16.98 3818.82 2993.04 2872.83 842.83 0.89 5973001.14 591459.18 N 7020 9.401 W 149 15 28.690 5308.87 56.82 16.68 3870.31 3072.27 2948.67 865.78 0.43 5973077.25 591481.20 N 70 2010.147 W 149 1528.020 5401.23 55.96 16.31 3921.44 3149.17 3022.42 887.62 0.99 5973151.25 591502.14 N 702010.872 W 149 1527.382 5495.98 56.19 16.36 3974.32 3227.77 3097.87 909.73 0.25 5973226.95 591523.34 N 702011.614 W 149 1526.736 5589.76 56.45 15.88 4026.32 3305.77 3172.84 931.39 0.51 5973302.17 591544.10 N 702012.352 W 149 1526.103 5683.49 56.35 16.73 4078.19 3383.82 3247.77 953.31 0.76 5973377.36 591565.11 N 70 20 13.089 W 149 15 25.46~ 5776.86 56.77 16.09 4129.65 3461.71 3322.51 975.32 0.73 5973452.35 591586.21 N 702013.824 W 149 15 24.819~ 5869.77 55.36 17.25 4181.51 3538.78 3396.35 997.43 1.84 5973526.45 591607.42 N 70 20 14.550 W 149 15 24.173 5963.57 55.11 17.56 4235.00 3615.83 3469.88 1020.48 0.38 5973600.24 591629.58 N 70 20 15.273 W 149 15 23.500 6056.74 54.95 17.85 4288.40 3692.18 3542.61 1043.70 0.31 5973673.24 591651.91 N 70 20 15.988 W 149 15 22.821 6149.94 55.44 19.17 4341.60 3768.70 3615.17 1067.99 1.28 5973746.09 591675.33 N 702016.702 W 149 1522.112 6243.17 57.60 20.42 4393.03 3846.40 3688.33 1094.33 2.57 5973819.55 591700.78 N 70 2017.421 W 1491521.342 6336.70 56.78 20.19 4443.71 3924.93 3762.05 1121.61 0.90 5973893.59 591727.17 N 70 2018.146 W 1491520.545 6429.93 56.54 20.53 4494.95 4002.73 3835.07 1148.71 0.40 5973966.93 591753.38 N 70 2018.864 W 149 15 19.753 6524.78 56.45 20.80 4547.30 4081.72 3909.07 1176.62 0.26 5974041.25 591780.39 N 702019.592 W 149 15 18.937 6617.62 56.43 20.34 4598.63 4158.99 3981.51 1203.80 0.41 5974114.00 591806.69 N 70 20 20.305 W 1491518.143 6711.22 56.40 19.87 4650.40 4236.90 4054.73 1230.61 0.42 5974187.53 591832.61 N 70 20 21.025 W 1491517.360 6802.72 56.25 19.81 4701.14 4312.99 4126.35 1256.45 0.17 5974259.46 591857.58 N 70 20 21.729 W 1491516.605 6896.63 55.68 19.28 4753.70 4390.77 4199.69 1282.49 0.77 5974333.10 591882.73 N 70 20 22.450 W 149 15 15.844 6990.18 56.33 19.23 4806.01 4468.31 4272.91 1308.06 0.70 5974406.62 591907.41 N 702023.170 W 149 15 15.096 7082.77 55.99 18.82 4857.57 4545.19 4345.62 1333.13 0.52 5974479.61 591931.60 N 70 20 23.885 W 149 15 14.36/ 7175.37 53.12 18.45 4911.26 4620.61 4417.09 1357.24 3.12 5974551.37 591954.84 N 70 20 24.588 W 149 15 13.659~ 7268.93 50.76 19.62 4968.94 4694.25 4486.73 1381.25 2.71 5974621.28 591978.01 N 70 20 25.273 W 149 15 12.957 7361.34 49.83 18.75 5027.97 4765.32 4553.87 1404.62 1.24 5974688.70 592000.56 N 70 20 25.933 W 149 15 12.275 7453.85 48.94 18.53 5088.19 4835.54 4620.41 1427.06 0.98 5974755.50 592022.20 N 702026.588 W 149 15 11.618 7548.79 48.29 17.68 5150.96 4906.77 4688.11 1449.20 0.96 5974823.45 592043.51 N 702027.253 W 149 15 10.971 7642.45 47.98 16.95 5213.47 4976.51 4754.70 1469.96 0.67 5974890.28 592063.47 N 702027.908 W 149 15 10.365 7735.86 46.01 18.92 5277.18 5044.81 4819.69 1490.98 2.61 5974955.51 592083.69 N 702028.547 W 149159.750 7829.49 43.33 21.40 5343.77 5110.56 4881.48 1513.63 3.41 5975017.56 592105.59 N 702029.155 W 149 159.088 7920.33 41.49 22.75 5410.83 5171.65 4938.25 1536.64 2.26 5975074.61 592127.91 N 702029.713 W 149 158.416 8013.34 40.71 22.94 5480.92 5232.55 4994.60 1560.37 0.85 5975131.23 592150.96 N 70 20 30.267 W 149 157.722 8106.52 39.81 22.04 5552.03 5292.56 5050.23 1583.41 1.15 5975187.13 592173.33 N 702030.815 W 149 157.049 V-106 ASP Final Survey. xis Page 3 of 4 5/13/2002-3: 12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (tt) (°) (°) (tt) (tt) (tt) (tt) (°/1 OOft) (ftUS) (ftUS) 8200.22 36.83 22.03 5625.53 5350.48 5104.08 1605.21 3.18 5975241.24 592194.47 N 70 20 31.344 W 149 156.412 8294.46 33.69 23.20 5702.48 5404.68 5154.30 1626.10 3.41 5975291.70 592214.75 N 70 20 31.838 W 149 155.801 8387.16 31.64 22.78 5780.51 5454.50 5200.35 1645.65 2.22 5975337.98 592233.74 N 7020 32.291 W 149155.230 8480.83 29.09 22.83 5861.33 5501.66 5244.00 1664.00 2.72 5975381.85 592251 .56 N 70 20 32.720 W 149 154.693 8574.03 28.26 22.82 5943.09 5546.21 5285.22 1681.35 0.89 5975423.27 592268.41 N 70 20 33.125 W 149154.186 8666.12 26.67 22.05 6024.80 5588.53 5324.47 1697.56 1.77 5975462.71 592284.14 N 70 20 33.511 W 149153.712 8758.90 26.62 20.16 6107.73 5630.06 5363.28 1712.54 0.92 5975501.70 592298.65 N 70 20 33.893 W 149 153.274 8853.30 23.45 19.15 6193.25 5669.98 5400.89 1726.00 3.39 5975539.46 592311.65 N 70 20 34.263 W 149 152.881 8946.75 20.44 17.21 6279.92 5704.90 5434.05 1736.93 3.31 5975572.75 592322.18 N 70 20 34.589 W 149 152.562 9040.94 16.91 15.23 6369.14 5735.04 5462.99 1745.39 3.81 5975601.78 592330.30 N 702034.874 W 149 152.314 9133.84 16.06 19.66 6458.22 5761 .38 5488.13 1753.27 1.63 5975627.01 592337.86 N 702035.121 -' W 149152.084 9227.42 14.14 20.25 6548.57 5785.74 5511.04 1761 .58 2.06 5975650.02 592345.90 N 70 20 35.346 W 149 151.841 9321.16 12.73 19.00 6639.74 5807.50 5531.55 1768.91 1.54 5975670.62 592352.97 N 70 20 35.548 W 149 15 1.627 9414.69 12.68 17.11 6730.98 5828.07 5551.11 1775.28 0.45 5975690.25 592359.11 N 70 20 35.740 W 149151.440 9507.93 11.88 16.30 6822.09 5847.90 5570.10 1780.98 0.88 5975709.30 592364.59 N 70 20 35.927 W 149 15 1.274 9538.70 11.49 16.75 6852.22 5854.13 5576.07 1782.76 1.30 5975715.30 592366.29 N 70 20 35.986 W 149 15 1.222 9595.00 11.49 16.75 6907.39 5865.34 5586.81 1785.99 0.00 5975726.07 592369.39 N 70 20 36.091 W 149 15 1 .127 --- V-106 ASP Final Survey.xls Page 4 of 4 5/13/2002-3: 12 PM SC-.-"gøP Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ,--- Well Job # Log Description V-106 ~ V-106 'V V-106 i V-106 0 V-106 7f V-106 22242 PEX AIT BHC (PDC) 22242 PEX AIT 22242 PEX DENINEUTRON 22242 PEX TRIPLE COMBO 22242 PEX TRIPLE COMBO SSTVD 22242 BHC ..- 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 AK 99508-4254 RECE'VED 1\ \hl 1 Î 2001) v~'1 . I t.. Date Delivered: AlASkaOü&GasCons.Co1nJnIåOn And\oœge Date 05/09/02 05/09/02 05/09/02 05/09/02 05/09/02 05/09/02 6/6/2002 NO. 2130 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color CD Sepia BL Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 AnN: Sherrie Recelved~' (. ~ I~' é7Pa.o~o ~ Sc~lInbl'gep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description V-106 V-106 V-106 22232 GR & ROP5 DATA 22232 MD IMPULSE-GR 22232 TVD IMPULSE-GR 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 AK 99508-4254 Date Delivered: RECEIVED 11 If\' 1 '1 "002 vvJ.¡ ¡ L: AJ~sblOi' & ~Cons. Commiad", AncITorage tØgNl f Date 05/08/02 05/08/02 05/08/02 6/6/2002 NO. 2130 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Sherrie Recelved~~ .) ) MWD/LWD Log Product Delivery Customer .J3P.Exploration.{Alaska) Inc. . Dispatched.To: . Lisa. Weepie Well No V-106 . DateJ)jspatched: . 13,May-02 I nstallation/Rig . Nabors 9.ES Dispatched By: .Nate.Rose Data No Of Prints No of Floppies Survey,S 2 1 é^CB,O[Q RECEIVED t..~ :\.'y' 1 :.~ 200( I . .ï. \j L ReceiVedBY:~,(" ~--..J Alaska Oi & Gas Cons.CoIImisston Anr.hnrage I Please sign and return to: AnadriU LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com . Fax~ 907-561-8417 L WD Log De1ivery V1.1, Dec '97 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (j)'< Chair ~ SUBJECT: Blowout Preventer Test THRU: Tom Maunder" ( Nabors 9ES P.I. Supervisorß \'o~ PBUV Pad ~'\ \ V-106 FROM: John Crisp 202-080 Petroleum Inspector PBU Borealis Field NON- CONFIDENTIAL Operator Rep.: Dick Maskell Contractor Rep.: Cris Clemmons Test Pressures Rams: 250/4500 MISC. INSPECTIONS: PIF Location Gen.: Good Housekeeping: Good PTD On Location Yes Standing Order: Yes BOP STACK: Quantity 1 1 P/F Sign: NIA Rig cond: OK Hazard: Yes Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Size 13 5/8" 3.5x6 2 7/8x5 13 5/8" 31/8 31/8 31/8 1 1 2 1 DATE: Op. phone: 659-4806 Rig phone: 659-4831 Op. E-Mail: Rig E-Mail: P/F P P Annular: 250/3500 Choke: 250/4500 TEST DATA FLOOR VALVES: Quantity PIF Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P P P P P CHOKE MANIFOLD: Quantity P/F No. Valves 15 P Man. Chokes 1 functioned Hyd. Chokes 1 functioned May 10,2002 MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual OK OK OK Tested Tested Alarm OK OK OK Tested Tested ACCUMULATOR SYSTEM: TimelPsi P/F System Pressure 3100 After Closure 1650 200 psi Attained 38 sec. Full Pressure 2 min. 35 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 6 @ 1950 psi. Testis Details I travelled to BP's Prudhoe Bay Unit, Borealis Field V Pad to witness the weekly BOP test on Nabors 9ES. I aalowed the Rig to test the individual choke anifold valves prior to my arrival on the Rig. I witnesses sed O/S choke valves & choke manifold body test. No failures were witnessed. Rig is clean & in excellent shape. Total Test Time: 5 hrs. Number of failures: cc: Q Attatchments: none BOP Test (for inspectors) BFL 11/20/00 BOP Nabors 9ES 05-10-02jc.xls ~~~~t ") : F !Æ~~~~~~ ) ALASIiA. OIL AlWD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit V-I 06 BP Exploration (Alaska), Inc. Pennit No.202-080 Sur Loc: 4870' NSL, 1649' WEL, Sec. 11, T11N, RIlE, UM Btmhole Loc. 5237' NSL, 5147' WEL, Sec. 01, T11N, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit V-106. . ,. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. 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, ~,~.~ c-ammy áechsli Taylor Chair BY ORDER OF THE COMMISSION DATED thislJ-~day of April, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA ~ STATE OF ALASKA 1 AND GAS CONSERVATION COMtv. '110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil , 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 84' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / V -1 06 9. Approximate spud date 04/21/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9757' MD / 7058' TVD 0 17. Anticipated pressure {~e 20 AAC 25.035 (e) (2)} 56 Maximum surface 2765 psig, At total depth (TVD) 6750' / 3440 psig Setting Depth T 9D Bottom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 3169' 2622' Surface Surface 9065' 6391' 9065' 6391' 9757' 7058' NGA if-18( 0 L 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4870' NSL, 1649' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 5111' NSL, 5187' WEL, SEC. 01, T11N, R11E, UM At total depth 5237' NSL, 5147' WEL, SEC. 01, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028238, 41' No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Hole Casing Weight Grade CouDlina 42" 34" x 20" 91.5# H-40 Weld 9-7/8" 7-5/8" 29.7# L-80 BTC 6-3/4" 5-1/2" 15.5# L-80 BTC-M 6-3/4" 3-1/2" 9.2# L-80 IBT-M 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Lenath 80' 2983' 9035' 692' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 341 sx Articset Lite, 221 sx Class 'G' 174 sx Lite Crete, 173 sx Class 'G' (5-1/2" x 3-1/2" CementinQ ProQram) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED Perforation depth: measured APR 3; 2002 Al8aOilIGl8Can1.Con8iI8ion ~ true vertical 20. Attachments II Filing Fee 0 Property Plat 0 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: Jame ranks, 564-4468 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that t,he fore ng is tru.Je~ ;¿?Ire.. '. ...c ... reo C..t..to.th.,e... b.....e....s_.t.. 0..... f.. m,Y. ..~.n.......o..w. I.~. ~g..,..e. ...-... . Signed Lowell Crane ~ I~ Title Senror Dnlhng Engineer , . , ','co.r.",i.jC)l1,'Q~..()"ly'-,,' ;, Date 4-;),- Od- Permit Number API Number .zo.?-o~o 50- 027- Z3CJ ð'3 Conditions of Approval: Samples Required 0 Yes £SI No Hydrogen Sulfide Measures 0 Yes -¡g) No Required Working Pressure for BOPE 0 2K 0 3K Origin~tSfó¡,~t- BoP E- to 4s 00 p~- ~ Approved By Cammy OechsliO R f C I N' A L Commissioner Form 10-401 Rev. 12-01-85 I ~., fApP~o~1 D~ See cover letter '--t - \~7\ () ~ for other requirements Mud Log Required 0 Yes ~ No Directional Survey Required ~ Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU ~qA- --4)y order of the commission 1\ \FJ r) Date '\ - {7\ ,0 ~. Submit In Triplicate ) ) I Well Name: IV-106 Drill and Complete Plan Summary x = 590,651.49' Y = 5,970,118.94' 4870'FSL, 1649'FEL,Sec. 11,T11N, R11E X = 592,320' Y = 5,975,660' 51111 FSL,5187' FEL, Sec.01,T11N, R11E X = 592,358.75' Y = 5,975,787.09' 5237'FSL,5147'FEL,Sec.01,T11N,R11E / I Rig: I Nabors 9ES / I Type of Well (service I producer I injector): Surface Location: As-Staked Target Location: Bottom Hole Location: I AFE Number: 1 5M-4052 1 Estimated Start Date: 1 04/21/2002 1 1 TVD: 1 7058' 1 I MD: 19757' I Well Design (conventional, slimhole, etc.): I Objective: Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-3169'): Initial below Permafrost interval TO Density (ppg) 8.5 - 8.6 9.3 - 9.5/ 9.6 max Viscosity (seconds) 300 200-250 200-250 I Producer 1 Operating days to complete: 1 BF/MS: 1 54.3' I Microbore (Iongstring) Yield Point (lb/10Ote) 50 - 70 45 - 60 45-60 APIFL (mis/30m in) 15 - 20 <10 <8 6 %" Intermediate I Production Hole (3169' - 9757'): Interval Density Tau 0 YP (ppg) 9.3-9.5 Upper Interval Top of HRZ 4-7 10.3 ./ 5-8 Hydraulics: Surface Hole: 9 7/8" (0-3169') Interval Pump Drill GPM Pipe 620 4" 17.5# AV (fpm) 190 0-3169' Production Hole: 6 %" (3169'-9757') Interval Pump Drill Pipe A V GPM Opm) 3169' -9757' 295 4" 17.5# 240 20-25 20-25 Pump PSI Pump PSI PV pH 8-12 8.5-9.5 1 0-18 8.5-9.5 2300 ECD ppg-emw 9.8 Motor Jet Nozzles ("/32) N/A TFA (in2) 18,18,18,12 .856 3300 ECD ppg-emw . 11.7 / Motor Jet Nozzles ("/32) N/A 5x12 TFA (in2) .552 API Filtrate 6-8 116.8 1 RKB: 184' Spud Mud PH 8.5 - 9.5 8.5-9.5 8.5-9.5 LSNO HTHP Filtrate 4-6 <10 by HRZ ) ) Directional: Ver. (Sperry) WP-03 KOP: 300' Slot NQ Maximum Hole Angle: Close Approach Wells: 56.48 degree~ at 2625'-7218' MD All wells pass major risk criteria. Logging Program: Surface Hole (0-3169' MD) Production Hole (3169'-9757' MD) Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Note: MWD/LWD (GR/Directional) Gas Detection None MWD/LWD (Dir/GR/RES) PEX, BHC Sonic, Gas Detection, Cuttings samples Logs to be run over Schrader and Kuparuk. Formation Markers: Formation Tops MDbkb TVDss Pore Press (EMW) Hydrocarbon bearing SV5 1676 1560 8.4 No SV4 1828 1695 8.4 No Base Permafrost 1833 1700 8.4 No SV3 2321 2100 No SV2 2572 2265 No SV1 2963 2485 No UG4A 3552 2815 8.4 Yes UG3 4151 3150 8.4 Yes UG1 5034 3645 8.4 Yes Ma 5552 3935 8.4 Yes N Sands 6016 4195 8.4 Yes 0 Sands 6311 4340 8.4 Yes Obf Base 6971 4730 No CM3 7292 4910 No CM2 7457 5010 No THRZ 8976 6225 No BHRZ 9177 6415 No K-1 9213 6450 No TKUP 9265 6500 10.0 Yes Kuparuk C 9270 6505 10.0 Yes LCU Kuparuk B 9405 6635 No Kuparuk A 9524 6750 10.0 Yes TML V (Miluveach) 9607 6830 No CasinglTubing Program: Hole Size Csg/ WtlFt Grade Conn Length Top 8tm Tbg O.D. MDITVD MDITVD bkb 42" 34 x 20" 91.5# H-40 WLD 80' GL 80'/80' 9-7/8" 7 5/8" 29.7# L-80 BTC 2983' GL 3169'/2622' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 9035' GL 9065'/6391' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 692' 9065'/6391' 9757'/7058' Tubing 3-1/2" 9.2# L-80 IBT-mod 9035' GL 9065'/6391' V-106 Program - Version 1 Page 2 ") ) Integrity Testing: Test Point Surface Casing Shoe Depth 20' min from surface shoe Test Type LOT EMW/ 12.6 ppg minimum target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader with 1000 psi compressive strength and covering the entire Kuparuk interval with 2000 psi compressive strength cement. If logs indicate the Schrader not to be oil bearing, the program will be amended to provide 2000 psi compressive strength cement above the top of the Kuparuk only. Casing Size 17-5/8" Surface I Basis: Lead: Based on 1833' of annulus in the permafrost @ 250% excess and 488' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface / Tail: Based on 500' TVD (848' MD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2228' MD ",/ Total Cement Volume: Lead 270 bbl 1 1515 ft;j 1 3~1 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 fe Isk. ./ 46 bbl 1258.1 ft;j 1 221 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 fe/sk../ Tail 5-1 12"x3-1 12" Production Longstring Basis: Lead: Based on TOC ~O' above top of Schrader formation & 30% excess + 80' shoe. Lead TOC: 50521 MD - ' Tail TOC: 500'MD above TKUP. Crossover @ +1- 9069' MD / Total Cement Volume: Lead 72 bbls 1 404 fe 1174""sks of Lite Crete at 12 ppg and 2.33 fe/sk/ Tail 36 bbls 1 202 fe 1 17J' sks of Dowell 'G' at 15.8 ppg and 1.17./ fe/sk. . Casing Size Well Control: Surface hole will be drilled with diverter. The production hole 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 the planned casing test for future frac considerations, the BOP equipment will be tested to 4500 psi. The diverter, BOPE and drilling fluid system schematics are on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: . Planned BOP test pressure: Planned completion fluid: 344095i @ 6750' TVD (sub-sea) - Kuparuk Sands 2765 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 4500 psi ,,/ 8.6 ppg filtered seawater or brine 1 6.8 ppg Diesel . Disposal: . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class 2 wastes to DS-04 for injection. Haul all Class 1 wastes to Pad 3 for disposal. Hydrogen Sulfide: . H2S has not been recorded on V-Pad wells. As a precaution, Standard Operating Procedures for H2S are followed at all times. V-106 Program - Version 1 Page 3 ) ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: _The twenty inch conductor. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugslwell shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES¡ (Slot NO). 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3169' ../ MD/2683' TVD. Surface hole TD will be +1-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. Depending on hole conditions, a port collar can be run in the casing to allow for secondary cementing at the Company Representative's discretion. /" 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4500 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/NEUT/DEN/RES and RIH to float collar. Test the 7 5/8" casing to 3500 psi for 30 minutes. / 7. Drill out float equipment and displace well to LSND drilling fluid. / 8. Drill new formation to 20' below 7-5/8" shoe and perform Leak Off Test. 9. Drill to :f:100' above the HRZ, ensure mud is condition to 10.3 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. 10. Drill ahead to -150' of rat hole into the Miluveach formation(TD - 9757' MD17058' TVD). / 11. Make wiper trip as required by hole conditions, circulate and condition hole for 10g~i_~~H r? 12. Perform open hole logging program. Run PEX/BHC Sonic logs. If logging time i( excessi~~ RIH with 6-3/4" cleanout assembly and condition hole for running the 5 Y2" x 3 Y2" casing. 'pgeHíaying down excess 4" DP. I 13. Run and cement the tapered production casing as required from TD to 500' above the Schrader. Displace the casing with heated seawater during cementing operations and freeze protect the 5 Y2" x 7 -5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 518" shoe. Record on chart and submit to town.) 14. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. 15. Sting seal assembly into tieback receptacle and test to 4500 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 16. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 17. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to lower GLM. 18. Rig down and move off. V-106 Program - Version 1 Page 4 ) ) V-106 Job/Operational Breakdown .p:}/I9¡I'¡¡:'-'--'-I/J~ml,,JJ.lI¡mJI'lþll~ml.ll.lffl~mml;.l--mm"'mullml'UCJIIJUlmll::;lm,lmmmm:m";'-~-¡Iß.I.II~I:lmllJ~¡_II~11ml~JJ,lmIJ.lIJAlI,I:llmmJmmmmml,1,U¡~llmm.lIIJII:'-,:1,I.ImmII.I,ImlIIIJI.lmmmlml,lU,lII:UU'¡IJ¡¡mm.-mm~II.I.IJ.I.lJIJI"IUlJl.Umllmm:IIJm.\W'~IJ,Imml¡lJml¡UmllIIIIII~'IÞN';þ¡I,IIJlIIJlmmmlCICIIJJlmmmllm.l.lI,l,l"."'JI.lI.IIIDI Job 1: MIRU Hazards and Contingencies / );> V-Pad is not designated as an H2S site. In the wells drilled to date on this pad there has been no report H2S as being present. As a pre-caution, follow at all times the Standard Operating Procedures for H2S. ~ The well does not require a surface shut-in. ~ Check landing ring height on V-106 conductor, the BOP stack may need to be run with a double flange on bottom (13-5/8" x 11") Reference RP's .:. IIDrilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~:I~I¡JlmJJmmlI,II':,IJIlm,a:mmmmumml.D"mml"'.III,:mIIJ:I,:I~IJ.m¡~CmlllC,m.IDI,¡IIIII:,lImmm,mmm,mll:.IIJ¡m~,III¡Io:¡:m,IJlammaIIJaJ¡J),m'II,~am'I:I,:!,r¡~ammmmIm:.II¡i;,IIJmmlJmal,:JJaaJ~lllma.l.llllmJIIIJ,mWIJIII¡I:,alaiJIIIIWWIIIJI;alm,aal/.,lllUß,I,a)l,IIJ,lIImmIJ¡¡im,:a,:III,I¡J:.WI¡J¡,:IWJI~)Jm.mmllalllUla,amllPmmUma¡IIIra"mll:mal.l::C Job 2: DrillinQ Surface Hole Hazards and Contingencies );> In this interval, a fault in the SV2 @ +/-2350' TVDss will be crossed. This fault has a 60' estimated throw to the west. Another fault that may be crossed is near TD of the well in the Miluveach Shale @ +/-6900' TVDss. This fault has a throw of 90' in the SSW direction. );> Drilling Close Approach: All wells pass BP Close Approach Guidelines. The nearest close approach well is V-100 (actual) which will have a center-center distance of 19~ 323' MD. All well pass under Major Risk Rules. );> There has been consistent observation of gas hydrates while drilling wells off this pad. Expect to encounter hydrates from the base of permafrost to the shoe setting depth. To combat the gas circulated out while drilling through the hydrates, appropriate mud products will be implemented at surface. Refer to Baroid mud recommendation. );> Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough jr;r'when aerated gas cut hydrate mud is circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situàtion.) Reference RP's .:. 'IPrudhoe Bay Directional Guidelines" .:. IIWell Control Operations Station Bill" .:. IISuccessfully Drilling Surface Hole. 'I:lU,UIIIIII;:UI:allallllII-"a,tIllIIUl,:!a,aama:I,U:¡-'U:Wlumllunl:II:¡l:IlUllalm_lIlJlall/llm:JI,lI'ltUlIIIIIII-:awmIJ;m,:v"'. .:lUlalllU:~VV1III1III,anIUIlU:IIWIIU::U:.WJlllllllUmlm¡:' 'j';" .al~llIlmm:IIIUU:UIIIIIUUIIJUI.IlIlIlIIIlal:lUmllllUwuall:-'IIII'Wn:11,laa.IUIlIAIJIIIJII,:lIlamllllmmIIIIIl/UI.UlUllllma:llm¡- .,II:IIII.IIIIIIIIII).IIlIIlaolllll.l. '¡:IIIJIIIII::lll.nl!lIUIIIIIC Job 3: Install Surface CasinQ Hazards and Contingencies );> It is critical that cement is circulated to surface for well integrity. Plan of 250% excess cement through the permafrost zone and 30% excess below the permafrost. A 7-5/8" port collar should be only used as per the TAM Port collar-running criteria. If used it should be positioned at ::t1 OOO'MD to allow a secondary circulation. );> "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. IICasing and Liner Running Procedure" .:. IISurface Casing and Cementing Guidelines" .:. IIDowell Cement Program" V-106 Program - Version 1 Page 5 ) ) .:. "Surface Casing Port Collar Procedure" 'v.; .LU ,......."""'^ ,. --\-- '-I~:-I-:-\ -.' -'111":::1111 VI' ;'IIIL:Wlllmn,,1111-.-'----llIm:I:lla,mll-lllll-nllllnmmnll1111:111::rlllllllllllllll -~"' --I-I--:I:::':II:I1-I-I:I1I1~III\'I-. 1.ILIIIWnIW' --'-In -:nw: :11-1:1111'ØI:,:Umll:I:I:I:n-IIIII-:I. --;ml-:'- .1 Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario of 10.0 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.6 ppg at the surface casing shoe, 10.3 ppg mud in the hole, kick tolerance is 25.1 bbls. An accurate LOT will be required as well as heighten~d awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.6 ppg. /" ~ Faults: The well trajectory is expected to intersect a fault at approximately TD of the well. The fault has an estimated throw of. 90'~ ÇOl1sult t~.e ~<:>st C;irculatiol1[)eci~i()~ . ,.r~e re~ardi~g.. Lc;.rv1 treatn-¡ents . ardpr?ced ~ ~~s.. ..... .1[h.iê.... ¡.sP()tc9n$id~rè9 ..~.hi~~. ri~K f9r 19êt¡ cirçuléiti9l1W~ ilE:)cJrilliI1Q; h()Y"~VE:)r,.19ê§~ê m?YþE:) .ßJ'lçOlJl1~erE:)cJwhênJlJn ning thE:)pr9qlJqti9nq~~il1gß~rir1g~ ~ V-Pad development wells have kick tolerances approaching 25 bbls. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HRZ" 11111/1111)1,11111/111)1111.1'11111111':11111/1111_111111111;1,:1111111,1111:11111111¡aIUIJIIIIIUII)lIlIIlIIi, -lml;mUIL -IIJl/lmil~mm-, ,;lIlmmIllIUllc "!IJUmIIUlm¡lImlI'lmll,IIIIIIIllIIlnIlUlmIßIIIIIII~,IUllml¡UIIIICI:U¡IIIIIIITU~llIlm¡I:IIIJl.lIII:,'¡lmlll,:aWI-;W~IIIIU;-''-III1L!IIII:IIUlI,m,'If\I'II,mlml¡lmUlII¡~IIClIIIII,n:mI/IW"IIII:II/Ilml11,_II.W.I:r:I;llIllu:-mllJlI¥II.IIIlmWm Job 8: LOQ Production Hole Hazards and Contingencies ~ Ensure the hole is in very good condition to avoid a stuck tool string ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 ¥2" x 3 ¥2" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" 'I\m;~.. ';11111111_111";1'1-;- -I' '\. .amlnm- ;1: -;111.1; :1111;1-' )I,'-I;;I-'I1)\;nn... I ;.....alll'ollmmmIlUmllmmllllll;;..,...lInl'llmlmlllllllllllmlllllnlmlllml:111 mmll--,IIIUlIIIIUIII',lIlIIlIIlIlIlr- --,- -:till; -;11;-;1.111:1-/1'-':'1'- .1.-1 1-- -I. ;r; X;lllaalmllllmlClilllmllllllllIIllIClm-- .'-.1- .ILILLLU Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 5-1/2" casing will be cemented to 500' MD above the Schrader Bluff. The top of the hydrocarbon interval should be verified with open hole logs. This is a deviation from the Production Casing and Cementing Guidelines RP. This decision is based on the Schrader Bluff targets being secondary and the belief that anything more than 500' MD may further jeopardize successful cement placement over the primary Kuparuk. ~ If losses are encountered while running the production casing, be prepared to treat with Barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. ~ Freeze protect the 5 ¥2" x 7-5/8" casing annulus to 3169' MD/2682' TVD (base of surface casing) with diesel. It is essential that freeze protection of the 7" annulus be performed only after the UCA / indicates 500 psi compressive strength is indicated. A second LOT will be required prior to displacing freeze protect. This would be to satisfy AOGCC for future annular pumping permits.) V-106 Program - Version 1 Page 6 ) ) ~ The well will be under-balanced after displacing the cement with heated sea-water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. ~ Ensure a minimum hydrostatic equivalent of 9.8 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off .-P8Šresulted from a reduction in hydrostatic pressure while pumping spacers and flushes. -hoNe... ~ The X-Nipples, with an I.D. of 2.813" is the tightest tolerance for the Weatherford Dual - Plug system, (tapered cement plugs to be used in the 5 Y2" X 3 Y2" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been modified for a maximum O.D. of 2.5". Caliper to confirm, prior to use. Reference RPs .:. "Production Casing and Cementing Guidelines" .:. "Dowell Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" 111:1111-- - '_'-'I!.'''m!nlm.II'.''LI. v .11__':II-IT:I:I!IIIIII:m 11II1II_.:-I1:III:I:I,.-,::u-.:IIIII'I'mlml-:'- .,- .'I"llIm. '~:_a- .'_I.'III::I\I:U-:UI:III:-Ilrml-':I- .IIIIta!'!' ,- .1. --;.:11:111111.'1'.11111.1.'_'. _a:I!I:I:-:n:m:-.~m!l--- ---'111'--'.'111:1:--- .,nll'- -~'II"ml:--- .'lnIDUI:li:I:W-:I:r'III:-H:I----IIIIU--- .lIIlIInt.'.'.'.'. --:1'-11:1:11;---:111 Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" ,1~lIIþll¡¡al,IUII:I,:IC¡lacWWm¡lc ,:1:1111'11:,:1,: -!r, -lIn¡,:II,~III,1 :II/IIU:,I,ID,lm;l,mm:nuaam,I,:m;m,l1,II!,-,r:r¡IU;JI,:U-J-.,IJ.IJ"'m,.,'lImll'l:a':,IIJ¡m¡ammIIJmla,U,:JJI-~I;I:-,_1 I:'CI'- -!"'I,"alOmm,mlaml¡I;H:llml:U'lm,:mla,I,I_I¡:III¡:II:':I~,,:,a;¡;aum;r:n,::m;I~ßII'~:.II,I~I,a,a~;UJ~'IIJI:lmmm'II'1~'U'JI:I'--III:Jc ::1:.I,:J.:-:IVI.,-~;tl-m¡IIJ",III,maalm;,:I!R,I:I¡¡:IWJIIJaIIUII:',1 Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Standard practices apply. .:. Freeze Protection of Inner Annulus l:cUlalm:mlI~IJI,'aI¡mllalJmJ~_IUII:II:L °\c -mIJWIIII::I~WW¡I¡¡¡IUIIII-¡:J)(I!,,:uaIJJ:' _1II'1I!,aIUlI'IIIII!la'ml~IJIn_:al.l:JIII-¡aJI~m111f'I1II1JIlII:mmmmlml:lllmln.IßlllaUlalllnumlIIaU::IIJ~a.III'-UlJIII-J:-¡-J:IJI.UI:JI,uaWIJa¡aIIlUl,mnm,:lmnlmllIIm¡:UIJ'JIJWII,I.u:~- -1II:ua.:ual:U:lm,mumIIUln'IIU::II'IIIIU:IIm~I;I'I:a¡~- --:nI'iNoIU~I,mIIUmlla. V-106 Program - Version 1 Page 7 d KBE KOP Bid 1/100 Base Gubik Cry 2/100 SV6 Bid 2.5/100 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: V-106 Proposed Well Profile - Geodetic Report March 26, 2002 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA (Drill Pads) t dy Vertical Section Origin: V-Pad /V-106 IIIIIIIt)' 5 W TVD Reference Datum: V-106 S _I b I I TVD Reference Elevation: V-106 Fea Sea Bed I Ground Level Elevation: 50029 Magnetic Declination: V-106 (P4) / March 26, 2002 Total Field Strength: 97.769° /5917.92 ft /5.903/ 0.83~ Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.32809751, W 149.2648043C Magnetic Declination Model: N 5970118.940 ftUS, E 590651.490 ftUS North Reference: -+D.6922908r Total Corr Mag North .> True North: 0.99990934 Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 17.450° N 0.000 ft, E 0.000 ft KB 82.8 ft relative to MSL 55.000 ft relative to MSL 26.045° 57475.837 nT 80.75r May 15, 2002 BGGM 2001 True North +26.045° Well Head --' Grid Coordinates Geographic Coordinates MD Incl Azim TVD I VSec I N/.S EI.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 5970118.94 590651.49 N 70.32809751 W 149.26480430 300.00 0.00 345.00 300.00 0.00 0.00 0.00 0.00 5970118.94 590651.49 N 70.32809751 W 149.26480430 322.80 0.23 345.00 322.80 0.04 0.04 -0.01 1.00 5970118.98 590651.48 N 70.32809762 W 149.26480438 400.00 1.00 345.00 399.99 0.74 0.84 -0.23 1.00 5970119.78 590651.25 N 70.32809980 W 149.26480616 500.00 2.00 345.00 499.96 2.95 3.37 -0.90 1.00 5970122.30 590650.55 N 70.32810671 W 149.26481159 600.00 3.00 345.00 599.86 6.63 7.58 -2.03 1.00 5970126.49 590649.37 N 70.32811821 W 149.26482076 700.00 4.00 345.00 699.68 11.78 13.48 -3.61 1.00 5970132.37 590647.72 N 70.32813433 W 149.26483357 800.00 5.57 0.11 799.33 19.35 21.70 -4.51 2.00 5970140.58 590646.72 N 70.32815679 W 149.26484087 900.00 7.35 8.28 898.69 30.30 32.89 -3.58 2.00 5970151.78 590647.51 N 70.32818736 W 149.26483333 979.91 8.84 12.39 977.80 41.47 43.94 -1.52 2.00 5970162.85 590649.44 N 70.32821755 W 149.26481662 ---....-.;J 1000.00 9.22 13.22 997.64 44.61 47.02 -0.82 2.00 5970165.94 590650.10 N 70.32822596 W 149.26481095 1100.00 11.14 16.49 1096.07 62.26 64.08 3.75 2.00 5970183.05 590654.47 N 70.32827257 W 149.26477389 1144.59 12.00 17.61 1139.75 71.20 72.63 6.38 2.00 5970191.64 590656.99 N 70.32829593 W 149.26475256 1200.00 13.39 17.61 1193.80 83.37 84.23 10.06 2.50 5970203.28 590660.53 N 70.32832762 W 149.26472272 1300.00 15.89 17.61 1290.55 108.64 108.31 17.70 2.50 5970227.45 590667.88 N 70.32839340 W 149.26466076 1400.00 18.39 17.61 1386.11 138.10 136.39 26.62 2.50 5970255.63 590676.46 N 70.32847011 W 149.26458843 1500.00 20.89 17.61 1480.28 171.70 168.42 36.78 2.50 5970287.78 590686.23 N 70.32855762 W 149.26450604 1600.00 23.39 17.61 1572.91 209.37 204.33 48.18 2.50 5970323.82 590697.19 N 70.32865572 W 149.26441359 Station ID V-106 (P4) report.xls Page 1 of 3 3/26/2002-11:14 AM Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD VSec NJ-S EI.W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) SV5 1676.72 25.30 17.61 1642.80 241.00 234.47 57.75 2.50 5970354.07 590706.40 N 70.32873806 W 149.26433598 1700.00 25.89 17.61 1663.80 251.05 244.06 60.79 2.50 5970363.69 590709.32 N 70.32876426 W 149.26431133 End Bid 1788.67 28.10 17.61 1742.80 291.30 282.41 72.96 2.50 5970402.18 590721.03 N 70.32886903 W 149.26421263 SV4 1828.35 28.10 17.61 1777.80 309.99 300.23 78.62 0.00 5970420.07 590726.47 N 70.32891771 W 149.26416673 Base Permafrost 1834.01 28.10 17.61 1782.80 312.66 302.77 79.43 0.00 5970422.62 590727.25 N 70.32892465 W 149.26416016 Bid 2/100 1879.36 28.10 17.61 1822.80 334.02 323.13 85.89 0.00 5970443.05 590733.46 N 70.32898027 W 149.26410777 1900.00 28.51 17.61 1840.97 343.80 332.46 88.85 2.00 5970452.42 590736.31 N 70.32900576 W 149.26408377 Bid 4/100 1979.36 30.10 17.61 1910.17 382.65 369.49 100.60 2.00 5970489.58 590747.61 N 70.32910692 W 149.26398848 2000.00 30.93 17.61 1927.95 393.13 379.48 103.77 4.00 5970499.61 590750.66 N 70.32913421 W 149.26396277 2100.00 34.93 17.61 2011.87 44 7.48 431.28 120.21 4.00 5970551.60 590766.47 N 70.32927572 W 149.26382944 '-' 2200.00 38.93 17.61 2091.80 507.55 488.53 138.39 4.00 5970609.06 590783.95 N 70.32943213 W 149.26368200 2300.00 42.93 17.61 2167.33 573.04 550.96 158.20 4.00 5970671.72 590803.01 N 70.32960268 W 149.26352134 SV3 2321.27 43.78 17.61 2182.80 587.64 564.87 162.62 4.00 5970685.68 590807.26 N 70.32964068 W 149.26348549 2400.00 46.93 17.61 2238.12 643.65 618.26 179.56 4.00 5970739.27 590823.55 N 70.32978653 W 149.26334810 2500.00 50.93 17.61 2303.81 719.02 690.10 202.36 4.00 5970811.37 590845.48 N 70.32998279 W 149.26316318 SV2 2572.06 53.81 17.61 2347.80 776.08 744.48 219.62 4.00 5970865.95 590862.08 N 70.33013135 W 149.26302319 2600.00 54.93 17.61 2364.08 798.79 766.13 226.49 4.00 5970887.68 590868.69 N 70.33019050 W 149.26296747 End Bid 2625.27 55.94 17.61 2378.42 819.60 785.97 232.78 4.00 5970907.59 590874.74 N 70.33024470 W 149.26291645 SV1 2963.41 55.94 17.61 2567.80 1099.72 1052.97 317 .52 0.00 5971175.57 590956.24 N 70.33097411 W 149.26222912 7 -5/8" Csg pt 3168.73 55.94 17.61 2682.80 1269.82 1215.10 368.97 0.00 5971338.30 591005.72 N 70.33141703 W 149.26181178 UG4A 3552.60 55.94 17.61 2897.80 1587.83 1518.21 465.17 0.00 5971642.52 591098.24 N 70.33224509 W 149.26103140 UG3 4150.72 55.94 17.61 3232.80 2083.34 1990.50 615.05 0.00 5972116.54 591242.39 N 70.33353531 W 149.25981545 UG1 5034.52 55.94 17.61 3727.80 2815.50 2688.37 836.53 0.00 5972816.97 591455.40 N 70.33544177 W 149.25801832 Ma 5552.30 55.94 17.61 4017.80 3244.44 3097.22 966.28 0.00 5973227.32 591580.19 N 70.33655867 W 149.25696536 WS2 6016.51 55.94 17.61 4277.80 3629.01 3463.77 1082.61 0.00 5973595.22 591692.07 N 70.33756001 W 149.25602120 WS1 6311 . 11 55.94 17.61 4442.80 3873.07 3696.40 1156.43 0.00 5973828.70 591763.07 N 70.33819550 W 149.25542202 .-.-' Obf Base 6971.72 55.94 17.61 4812.80 4420.34 4218.03 1321.98 0.00 5974352.24 591922.29 N 70.33962048 W 149.25407814 Drp 2/100 7218.42 55.94 17.61 4950.97 4624.71 4412.83 1383.80 0.00 5974547.76 591981.75 N 70.34015262 W 149.25357626 CM3 7291.72 54.47 17.61 4992.80 4684.91 4470.21 1402.01 2.00 5974605.35 591999.26 N 70.34030937 W 149.25342842 7300.00 54.31 17.61 4997.62 4691.64 4476.62 1404.04 2.00 5974611.78 592001.21 N 70.34032688 W 149.25341193 7400.00 52.31 17.61 5057.37 4771.82 4553.04 1428.29 2.00 5974688.48 592024.54 N 70.34053564 W 149.25321505 CM2 7457.21 51.16 17.61 5092.80 4816.74 4595.86 1441.88 2.00 5974731.46 592037.61 N 70.34065261 W 149.25310471 7500.00 50.31 17.61 5119.88 4849.86 4627.43 1451.90 2.00 5974763.14 592047.24 N 70.34073885 W 149.25302336 7600.00 48.31 17.61 5185.08 4925.68 4699.70 1474.84 2.00 5974835.68 592069.31 N 70.34093628 W 149.25283711 7700.00 46.31 17.61 5252.88 4999.17 4769.75 1497.07 2.00 5974905.99 592090.69 N 70.34112764 W 149.25265661 V-106 (P4) report. xis Page 2 of 3 3/26/2002-11 :14 AM Grid Coordinates Geographic Coordinates Station ID MD Incl I Azim TVD I VSec NI-S El-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7800.00 44.31 17.61 5323.21 5070.26 4837.51 1518.57 2.00 5974974.00 592111.36 N 70.34131274 W 149.25248205 7900.00 42.31 17.61 5395.98 5138.85 4902.88 1539.32 2.00 5975039.60 592131.32 N 70.34149131 W 149.25231356 8000.00 40.31 17.61 5471.09 5204.85 4965.79 1559.29 2.00 5975102.75 592150.53 N 70.34166316 W 149.25215141 8100.00 38.31 17.61 5548.46 5268.19 5026.17 1578.45 2.00 5975163.35 592168.96 N 70.34182811 W 149.25199583 8200.00 36.31 17.61 5628.00 5328.80 5083.94 1596.78 2.00 5975221.33 592186.58 N 70.34198592 W 149.25184699 8300.00 34.31 17.61 5709.60 5386.59 5139.02 1614.26 2.00 5975276.61 592203.40 N 70.34213638 W 149.25170505 8400.00 32.31 17.61 5793.17 5441.50 5191.36 1630.87 2.00 5975329.14 592219.37 N 70.34227936 W 149.25157017 8500.00 30.31 17.61 5878.61 5493.46 5240.88 1646.59 2.00 5975378.84 592234.49 N 70.34241463 W 149.25144252 8600.00 28.31 17.61 5965.80 5542.41 5287.53 1661.40 2.00 5975425.67 592248.73 N 70.34254207 W 149.25132226 8700.00 26.31 17.61 6054.66 5588.28 5331.26 1675.27 2.00 5975469.56 592262.07 N 70.34266153 W 149.25120963 '-' 8800.00 24.31 17.61 6145.05 5631.02 5372.00 1688.20 2.00 5975510.45 592274.51 N 70.34277282 W 149.25110462 8900.00 22.31 17.61 6236.89 5670.59 5409.71 1700.17 2.00 5975548.29 592286.02 N 70.34287583 W 149.25100742 Top HRZ 8976.24 20.78 17.61 6307.80 5698.58 5436.39 1708.64 2.00 5975575.07 592294.17 N 70.34294871 W 149.25093864 9000.00 20.31 17.61 6330.05 5706.92 5444.34 1711.16 2.00 5975583.05 592296.59 N 70.34297043 W 149.25091817 9100.00 18.31 17.61 6424.42 5739.98 5475.85 1721.17 2.00 5975614.68 592306.22 N 70.34305650 W 149.25083688 Base H RZ 9176.96 16.77 17.61 6497.80 5763.17 5497.95 1728.18 2.00 5975636.86 592312.96 N 70.34311688 W 149.25077995 9200.00 16.31 17.61 6519.89 5769.73 5504.21 1730.17 2.00 5975643.14 592314.88 N 70.34313398 W 149.25076379 K-1 9213.44 16.04 17.61 6532.80 5773.47 5507.77 1731.30 2.00 5975646.71 592315.96 N 70.34314370 W 149.25075462 Top Kuparuk 9265.32 15.00 17.61 6582.79 5787.35 5521.00 1735.50 2.00 5975659.99 592320.00 N 70.34317984 W 149.25072051 End Orp / Target 9265.34 15.00 17.61 6582.80 5787.36 5521.01 1735.50 2.00 5975660.00 592320.00 N 70.34317987 W 149.25072051 Kup C 9270.51 15.00 17.61 6587.80 5788.69 5522.28 1735.90 0.00 5975661.28 592320.39 N 70.34318334 W 149.25071726 LCU / Kup B 9405.10 15.00 17.61 6717.80 5823.53 5555.49 1746.44 0.00 5975694.61 592330.52 N 70.34327406 W 149.25063166 KupA 9524.15 15.00 17.61 6832.80 5854.34 5584.86 1755.76 0.00 5975724.09 592339.49 N 70.34335429 W 149.25055597 TMLV 9606.97 15.00 17.61 6912.79 5875.78 5605.28 1762.25 0.00 5975744.58 592345.73 N 70.34341007 W 149.25050327 TO /5-1/2" Csg Pt 9756.98 15.00 17.61 7057.69 5914.60 5642.29 1774.00 0.00 5975781.73 592357.03 N 70.34351117 W 149.25040784 ------ Le~al Description: Northin~ (Y) rftUSl EastinQ eX) rftUSl Surface: 4870 FSL 1649 FEL S11 T11N R11E UM 5970118.94 590651.49 Target: 5111 FSL 5188 FEL S1 T11N R11E UM 5975660.00 592320.00 BHL: 5233 FSL 5150 FEL S1 T11N R11E UM 5975781.73 592357.02 V-106 (P4) report. xis Page 3 of 3 3/26/2002-11 :14 AM ) ." ~ VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska V-106 (P4) Prudhoe Bay Unit - WOA Schlumbergor Structure: V-Pad Section At: 17.45 deg Date: March 26, 2002 -2000 -...........................-........................................... ............................................. ""'"'''''''''''''''''~''''''''''''''''''''''''''''''''''''''''''''''''''' '''''''''''''''''''d".,.,"""....."......",...........................................................",...................",,,.......,,....,,.....,........-. 0-........ KOP Bid 1/100~00 MD 300 TVD 28.10° 1r.61D az 334 departure ,,1 ) ,\~ ~L.. . (,\ ~ I. . Bid 4/1001979 MD 1910 TVD . 30.10'1 17.61' az 383 departure =: :: =: :: === ~~ :: =: ~:.~: .~= ~.....:::~..~~~~~~~~I~:~__~~;!~~~~;......~=._".......".~~~~.~~~; ~n=~::;~~;¡~-'~:'~:'~~~~;:.:~;::.."0.~:.~.i.~j::,,..!.7.~::.~:(~~=.._. ~- .....,.. .- ~.." T_. - +-' Q) - ~~ g~ 0 Q) N > II ..8 c: rn :;:.¡: _° ..c.~ +-'N c,CX) Q)- 0((1 -~ CO .. U- .- Q) ~I!: Q) > > Q)~ :::::sW ". ..... .... ..... ...... ..... ..... ..... ..... m.. ..m ..n. SV1 }'ii6:fK1o '2¡;(¡~"'I'v()"" ..... ..... ..... ".., ..... 0~\4,\'--:\,¡'\-;;:M(f-2'j¡¡;'\ TVÔ -..... ¡.m:" 'ij"lil¡"i;I()''3n:nvö''. ..... 7.". Hold Angle 55.940 " U(:'1 ~j¡)',~5 r~1Ï) !~i~t~ ''t\/o ... ... i ' 4000 _.......".......",....."'......_,......"".....,,,.......,,,,, 'f;i7"';i~;':i..¡:¡t)"';¡';)"1¡;":i'v\)'-"""""""'T"""'''''''''''''..",,,.....,"w. ~;in-!MI) 6:\'11./;11) -. ,ow, -. u'" --- ...-- ~-::'='~-::-~'~;~~~~2~;~-::-:~~:-;1 .. Ob'l'¡¡,;;j¡j 6'Ö';2 ¡;¡Ö 48':13 'i'VD .....! . ..... ..... ...... ...... . /. .---."..- "... ..... ..... ..... ..... ..... ..... ..... I ::::: 8~H m~ f~m *~:WrT~R-::::' -::::.: - ..... -.... ----- ----- ----- - ----- ..--. -... .-... .-.-. ---.- ---- ---- ----. I . ¡ ! I End Drp / Target I ~-~~f~~~~;i~~:~tü~~~;~:~~r~,:~,~~~,~-;~~~'~~ì ! H Id À I 15 000 ! TD/5-1/2"CsgPt [ 0 [ ng e. I 9757 MD 7058 TVD i , 15.00' 17.61' az 5915 departure 6000 -..-.--.-- "--'~-~~ ... . ----- 8000 ----..---.------.--------------.---.-------.+------"- I i I I ""_""_"._._o"'__'_-_"'....o~_.'¡'_....o...._o....~'-'O~"--'-----'-"""-"""~_"_M""_""'-"""..._..........._._--~.,¡._._.__.........._..._.__....._...-..-.-.... ! 10000 -- I ! i I I i I I I I I -2000 0 2000 4000 6000 8000 Vertical Section Departure at 17.45 deg from (0.0, 0.0). (1 in = 2000 feet) 6000 -....--........ ') PLAN VI:EW Client: BP Exploration Alaska Well: V-106 (P4) Field: Prudhoe Bay Unit - WOA Structure: V-Pad Schlumberger Scale: Date: 1 in = 1000 ft 26-Mar-2002 -1000 0 1000 2000 I 3000 I True North Mag Dee ( E 26.05° ) -....,....,'...,-......................... ---.----.-------------........-. """"""~fi/~16:¡'::7%~:'~D"""""'''''-''''''''''''''''''''''''''''' - 6000 15.00' 17.61' az 5642 N 1774 E ~¡ l~ .End Drp1 Targat 9265 MD 6583 TVD 15.00' 17.61' az 5521 N 1735 E 5000 -..........................................-.........-............. ........."..............."."'.................."..."...................................,........................."...........,.,......"............... - 5000 I~ ---- Qrp2/100 ^ 7218 MD 4951 TVD ~5.94' 17.61' az ^ 4000 _..............................................................................................................................................................................................................................................................~~.1.3.N....laB~.E...................................................................... - 4000 ^ I ~ 0:: 0 Z 0 ,.... Co ,....: ,.... S :;:, 3000 _.......................................... ...................................-................................... .........................................1::".................. ........................................................................... """"""""""""""""""""""""""""""'"''''''''r''''''''''''''''''''''''''''' - 3000 ~ I I I I I I I ~ 2000 -.........----------...---..-.-.-..-.----. -------------------...---...-.----.-......................... ........-..--..----.--..--..---.-.. ..-.---.....-......-. ".........................-.-.-.-----.--.---- ::> 0 en V V V 1000 0 i ! i ----.---..-.-...-.....-.............-.....---..--------....---.---..-..........t-.--.---.......-.....-.. - 2000 ! i I ¡ I I ! --BI6-411M--_---------__..___l__l.._t---~_---_!.:~-@::..ç~g-p.L_--------..----------------.----..--...-....--..--..-...L.............-..-.- - 1000 1979 MD 1910 TVD I. 3169 MD 2683 TVD ! 30.10' 17.61' az 55.94' 17.61' az i 369N 101 E ~ 1215N 369E i I End Bid : End Bid I 2625 MD 2378 TVD : 1789 ~D 17~3 TVD . 55.941 17.61' az ¡ 28.1?1 17.61 az ------- I 786 NI233 E I 282"1 73E ~ . i . Bid 2/100 Bid 2.5/1°0 1879 Md 1823 TVD 1145 Mq 1140 TVD 28 1a:Jz..61' '7 12.00' 17.61' az / 323 N fl6 E 73 N 6 ~ I I KOP Bid 1/100 I i, Crv 2/100 , 300 MD 300 TVD I' 700 MD 700 TVD 0.00' 345.00' az ~3~' :~.OO' az, 0 N 0 E 0 I -1000 I I 1000 2000 EAST »> I 3000 I 0 «< WEST ) Schlumberger Anticollision Report ) . . . .. . .. çQIDP~nY:BPArnocò . .. Fi~ld:.. ... . .PrU9t1Qe'êay.' . . Rêrêrence Sit~: . . 'PBVPàd ., . . .. Refèf~nceWen: . .... V'-1.06'. . ... . . .RerèrenceWcH~påth: :plan V~.t06 . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 9756.98 ft Maximum Radius: 2000.00 ft . D~te: . .3/2a/2002. . . Ti~e:'t1:51:59 .~ag~:,.. . i . .. .. . .. .. .. . . ... . . .. Çö;.ot4illåt~(NJj:) ~eferericë:. .. Well: \1-106; Tru e . North .. Vêrticål('i'YDr~~ference: . 'Vt1Q6.plahß2.8 .. , .. Db: 'Sýbäse . Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 9/13/2001 Validated: No Planned From To Survey ft ft 28.50 1000.00 1000.00 9756.98 Version: Toolcode 3 Tool Name Planned: Plan #4 V1 Planned: Plan #4 V1 CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station Casing Points .. MD TVD . . Diameter ft . ft. .~. 3168.73 2682.80 7.625 9756.98 7057.69 5.500 H()leSize . in. . 9.875 6.750 75/8" 5 1/2" x 3 1/2" Summary PB V Pad PB V Pad PB V Pad PB V Pad V-100 V-101 V-102 V-201 V-100 V7 Plan V-101 V4 Plan: V- Plan V-102 V2 Plan: PI V-201 V8 Rèference . MD. ft. 299.20 747.87 749.36 499.37 . Offset MD .ft 300.00 750.00 750.00 500.00 .. Ctr'-Ctr. No-Go. . Distance Area . . .. ft. ft 195.90 6.28 235.67 16.10 115.88 17.15 132.81 9.62 . AIJowable. ;OeviatiOi1 . . ft ' . . 189.62 Pass: Major Risk 219.57 Pass: Major Risk 98.73 Pass: Major Risk 123.20 Pass: Major Risk Attachmeot 9 -, ) Borealis V-106: Proposed Completion TREE: 3-1/8" - SM CIW L-80 WELLHEAD: 11" - SM FMC GS Cellar Elevation = 53.4' RKB - MSL = 84' 7-5/8",29.7 #Ift, L-80, BTC I 3169' MD Ij ~ 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS # Approx MD/TVD Size Valve Type 3 2 1 4628'/3500' 7767'/5300' 9029' /6357' 1" 1" 1" DV DV DV L ~ 3-1/2" 9.2# IBT Mod L-80, Tubing L 3-1/2" Baker CMD sleeve, wI 2.813 X profile in top, I 9059' MD 5-1/2", 15.5 lIft, L-80, BTC-Mod " ....- 3-1/2" Seal Asembly -~ 3-1/2" PBR /" 5-1/2"x3-1 12" XO placed at +1-150' above the Kuparuk Formation I 9065' MD Plug Back Depth I 9672' MD I J . 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID C 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID. . 3-1/2", 9.2 #/ft, L-80,IBT Mod I 9757' MDI Date 2/14/02 Rev By BWS Comments Boreal is WELL: V-106 API NO: 50-029-xxxxx-OO Proposed Seal Bore Completion - WP3 Microbore with 5-1 /2"x3-1 /2" tapered longstring 3/26/02 jdf BP Alaska GPB Satellites ") ) V-106 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in both NWE offset wells and all Borealis wells to date. These are expected to be encountered near the base of the Permafrost at 1833'MD and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. . A fault will be crossed at 2350' MD, but losses are not anticipated as this fault is not expected to be conductive. Production Hole Section: . A majority of the L-Pad and V-Pad development wells will have tight "kick tolerances". A . heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 pore pressure. Read the Shale Drilling Recommended Practice. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on L- Pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . V-106 will cross a fault near TD of the well. The estimated throw of the fault is approximately 90'. Loss circulation is considered to be a moderate risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies '-102 ) , Subject: V-I02 Date: Wed, 3 Apr 2002 19:24:25 -0600 From: "Odenthal, Robert S" <OdenthRS@BP.com> To: "'bob - crandall@admin.state.ak.us'" <bob - crandall@admin.state.ak.us> V-102 will be the well that will have the surface log suite run on them. Drilling operations on this well should start the end of April. Robert S. Odenthal BP Exploration Alaska Drilling Engineer Work #: 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com ,oò V-¡06el cl0Jw- úJ ( ¿c.5'~ ~r guo¿IJ #c ¿J~ uAl~fjl' Cú~ ¿( eva4/c/ 6&eý) 8.610 /~ ~ 1 of 1 4/4/20027:47 AM : H 206294 DATE INVOICE I CREDIT MEMO DESCRIPTION : 031202 CK031202D PYMT -:OMMENTS: HANDL-::NG INST: GROSS 100.00 Permit to Drill Fee S/H - Terrie Hubole X4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 , ANCHORAGE, ALASKA 99519.6612 :j. PAY VI \ OLR 100. on FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 """412 DATE 03/14/02 CHECK NO. 00206294 VENDOR DISCOUNT Ai ASK An I I .Å NET 00 iOO. 00 H RECEIVED APR 3 ZOOZ A18skaOü¡GaConl.COIRmluion A1t-, -.-' 100. 00 No. H 208294 CONSOLIDATED COMMERCIAL ACCOUNT 00206294 ONE HUNDRED & 00/100************************************* US DOLLAR ALASKA OIL A~p GAS . CONSERVATION --COMMISSION 333-WEST 7TH AVENUE SUITE- ,l{)P . ANCHORAGE To The ORDER Of AK 9950 1 118 2 0 b 2 ~ ~ 118 I: 0 ~ . 2 0 j 8 ~ 5 I: 008 ~ ~ . ~ 118 d ,'Of '1::- DATE 03/14/02 AMOUNT $100.00 NOT VALID AFTER 120 DAYS R~-~~ßß~LL.. ) ) TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN TRANSMIITAL LETTER WELL NAME 160' CHECK 1 STANDARD LEITER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) v DEVELOPMENT REDRILL PäOT HOLE (PH) , EXPLORATION ANNULAR DJSPOSAL . QLJ NO INJECTION WELL ANNULAR DISPOSAL <-J YES INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL' (/ -/C,ç;; "CLUE" The permit is for a new weUbore segment of existing weD ~ Permit No, ,API No. - ' Production should continue to be reported as a function of the original API number stated above. ' In accordance with 20 MC 25.005(1), aU records, data and logs acquired for' the pilot hole must be clearly , differentiated in both name (name on permit plus PH) and API number (SO -70/80) from , records, data and logs acquired for wel~(n~me on permit). Annular disposal bas ~ot been. requested. . . Annular Disposal, of drilling wastes wiU not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS <-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved .sùbJect to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to tbe spacing exception that may occur. /50~~ r-c-o/ls OW~~~ WELL PERMIT CHECKLIST COMPANY .ß/J Y WELL NAMEj'Aú V- /6.6 FIELD & POOL bL/(?I.~ INITCLAsS {)~J/ /-0// ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schemati~ & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . APPR DATE 26. BOPE press rating appropriate; test to 4500 psig. v.JGI&- , (.g J 0 ¿ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . '.' 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AgfR .Pl'yE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N~ r=¥o.? - 34. Contact name/phone for weekly progress reports [exploratory 0 ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a N pool; and (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: . UIC/Annular: COM RP~ SFD- '11R ~p~T~ /V~ ~.yc>7 ENGINEERING GEOLOGY APPR DATE //¿ ~)¿ (plQ./1. PROGRAM: Exp - Dev){ Redrll - Serv - Wellbore seg - Ann. disposal para req - GEOL AREA '?9 r".I UNIT# /)&t;~ ON/OFF SHORE ~,o N N N N N N &3~ @ N g 01 r'l D . ~~~ e¡:œ5S ìO ~ rJ~Iwr~ q~ç ~ AJ.jÆ , ~ ~ CLo y ~ "ffÝ"''''-lL ::: (fcP' @ ; B' 1"1/) . ~N N fYlsP ~ 1.. 7vS P Ç.-t' . .N N - yeP Y N Y (" ( Comments/Instructions: TEM WGA yJGk COT DTS 01/.1 G 1° f( JMH_- G :\geology\templates \checklist. doc