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Home My WebLink About204-011 XHVZE e e Image Project Well History File Cover Page 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. Q..Q 4- - OJ L Well History File Identifier D Two-sided 1111111111111111111 Organizing (done) D Rescan Needed III II 1111111111111I RES CAN ~or Items: D Greyscale Items: DI~AL DATA "r Diskettes, No. , D Other, Norrype: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Date a/M/ó6 D Other:: Project Proofing BY: C Mari~ Date ~/d.E)þh --L X 30 = mP ,~IIIIIIIIIIIIIIIII rY]4J + ~D = TOTAL PAGES 50 (Count does not include cover sheet) 151 151 Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: --LL.. YES BY: ~ Date: Ó/J-oj 0(, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 1111I NO 151 mP NO BY: Maria Date: 151 III 11111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned III II 111111I11 11111 BY: Maria Date: 151 Comments about this file: Quality Checked "' 111/1/11I 1111111 10/6/2005 Well History File Cover Page.doc • • ~,_ _:~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .. .: , ~, F:~L,aserFiche\CvrPgs_Inserts~Microfilm Marker.doc STATE OF ALASKA .i.:a>.¡ RECEIVED ALASKA OIL AND GAS CONSERVATION COMNrrdSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,\~ MAR 0, 9 2007 Alaska Oil & Gas Cons. Commissj " 1 b. Well Class: Anch.o.raoe ~ Development U Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-011 . 307-034 13. API Number 50-029-20596-01-00 / 14. Well Name and Number: PBU 17-07A ~ 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 1 a. Well Status: 0 Oil 0 Gas 0 Plugged ~ Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2242' SNL, 930' EWL, SEC. 22, T10N, R15E, UM Top of Productive Horizon: 2651' NSL, 2059' EWL, SEC. 15, T10N, R15E, UM Total Depth: 3150' NSL, 329' EWL, SEC. 15, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 709176 y- 5928401 Zone- ASP4 TPI: x- 710159 y- 5933323 Zone- ASP4 Total Depth: x- 708415 y- 5933773 Zone- ASP4 18. Directional Survey 0 Yes ~ No 21. Logs Run: Zero Other 5. Date Comp., Susp., or J\Q~lJdß1 2/12/2007 fJIð'l/ 6. Date Spudded i7 21712004 7. Date 1.0. Reached 2/17/2004 8. KB Elevation (ft): 65' ;' 9. Plug Back Depth (MD+ TVD) 12969/' + 8731 ~ 10. Total Depth (MD+ TVD) 12969 / + 8731 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NIA MSL Ft Ft 16. Property Designation: ADL 028331 ~ 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE 20" 13-3/8" 9-518" 7" 4-1/2" CASING, LINER AND CEMENTING RECORD SETTING DEPTHMD - >, .~ < <'<~~~t! " ,.> ....... '><x <'A ",,0". '~I::J III"'" > ·,;..;.'······'·····«0;2-,...¡:.,.,.... Wr. PER FT. GRADE Top BorroM TöÞ 'Pû(~t:Ò' ..... LlVI 'VIVI' ,.'0', '...... ,;0'.... .'''' 94# H-40 Surface 80' Surface 80' 32" 232 sx Arcticset II 72# N-80 Surface 2687' Surface 2687' 17-1/2" 3000 sx Fondu 850 sx PF II 47# L-80 I 500-95 Surface 7475' Surface 8739' 12-1/4" 500 sx Class 'G' 26# L-80 7317' 10884' 6642' 8741' 8-1/2" 211 sx Class 'G' 184 sx Class 'G' 12.6# L-80 10740' 12967' 8681' 8731' 6-1/8" Uncemented Slotted Liner 22. 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED MAR 1 4 200J 24. . . .' . - .' - . . SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2",9.3#, L-80 10736' 10682' TVD ')J:::' '. ·"A '. - '... ,.' ,,_. '. -'. . . '. '. '-'-I.f"'\\"IU, _ vl::MI::NT ETC.,. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11064' Set Whipstock 11064' P&A wI 37.6 Bbls Class 'G' 26. . Date First Production: Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA PRODUCTION FOR OIL -BSL TEST PERIOD + Flow Tubing Casing Pressure CALCULATED OIL-BsL Press. 24-HoUR RATE+ 27. GAs-McF WATER-BsL CHOKE S,ZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 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 GAs-McF WATER-BsL .-.. ~ ,'"'' Form 10-407 Revised 12/2003, '. ." CONTINUED ON REVERSE SID~"A¡US SF l J ¡..~ I r:; I '" A , nauM l MAR 1 4 2007 ,28. GEOLOGIC MARKER~~ 29. ìRMA TION TESTS Include and briefl~marize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD CM2 8378' 7368' None CM1 9607' 8100' Top HRZ 10109' 8405' Base HRZ 10685' 8659' LCU 10775' 8695' Sag River 10903' 8748' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fÓAfÙ..g H J Mf!¡¿ Title Technical Assistant Date 03/7)7/07 PBU 17-07A Well Number Prepared By Name/Number: Drilling Engineer: Teffie Hubble, 564-4628 Mel Rixse, 564-5620 204-011 307-034 Permit No. I Aooroval 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 Digital Wellfile rage 1 or 1 '~' Well Events for SurfaceWell - 17-07 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS2 -> 17 -> 17-07 Date Range: 21/Jan/2007 to 08/Feb/2007 Data Source(s): AWGRS Events Source Well Date AWGRS 17-07A 02/08/2007 AWGRS 17-07B 02/08/2007 AYY.GRS 17-07 A 02/06/2007 AWGRS 17-07A 02/05/2007 AYY.GB,S 17-07A 01/30/2007 AWGRS 17-07A 01/29/2007 AWGRS 17-07A 01/27/2007 AWGRS 17-07A 01/26/2007 AW_GBS 17-07A 01/26/2007 AWGR~ 17-07A 01/25/2007 AWGRS 17-07A 01/24/2007 AWGRS 17-07A 01/23/2007 A WGRS 17-07A 01/22/2007 AwGRS 17-07A 01/21/2007 Description T/I/O= 100/0/300. Temp= S1. A/L line is disconnected. Bleed WHP's to 0 psi (pre BPV, pre rig). All FL's near surface. As of 02/06/07 TP increased 100 psi. lAP & OAP no change. Start TBG bleed to slop trailer from 100 psi to 0 psi in 40 min, gas only no fluids. During TBG bleed there were no changes in FL's or WHP's. Start OA bleed from 300 psi to 0 psi in 1 hour and 45 min, gas only no fluids. During OA bleed IA went on a Vac. Monitored pressures for 30 min. After 30 min. monitor, Final WHP's= 0+/Vac/l0. SET BPV PRE RIG API VALVE SHOP TIO= 1200/ 2200/ 2000 temp S/I **** WSR continued from 02-05 -07***** ( CTD Prep) Load and Kill Tubing MIT OA ( PASS) @ 2000 psi with 4 bbls crude ...Lost 120 psi in 1st 15 minutes ( PASS) and lost 50 psi in 2nd 15 minutes ( PASS) For total loss of 170 psi ,..Bleed back 18 bbls from IA,..Bleed back 2 bbls from OA,...Load & Kill Tubing, Pump 5 bbl methanol spear followed by 180 bbls 2 % KCL followed by 22 bbls 60/40 methanol/water FWHP's= vac/0/300 T/I/0=1250 /400/ 540 temp= S/I Load & Kill Tubing (CTD Prep) MIT IA @ 3500 psi ( PASS) Load IA with 5 bbl methanol spear followed by 485 bbls Crude, Lost 200 psi in 1st 15 minutes and lost 80 psi in 2nd 15 minutes for total loss of 280 psi, Load OA with 4 bbls Crude ***** WSR continued on 02-06-07 ****** T/I/O= 1270/1930/500. Temp= S1. Bleed lAP < 500 psi (pre-MITIA, pre-rig). SI lateral valve on A/L line. IA FL @ 7275' (446 bbls) between sta# 1& 2. Bled A/L line to DHD UR tank from 1930 psi to 0 in 30 minutes. Bled lAP from 1930 psi to 380 psi in 4.5 hours. During bleed tubing pressure decreased 20 psi and OAP decreased 20 psi. Monitored for 30 minutes. IA FL @ 7275'. OA FL @ 66'. No change in pressures. Final WHP's= 1250/380/480. ****** JOB POSTPONED******* ( AL riser was not removed on IA yet to load and MIT IA ) T/I/O = 1020/1900/480. Temp= S1. AL= Yes. IA & OA FL pre-LDS Drillout (Install heater if available). No heater available. IA FL @ 9441'. OA FL @ 66'. CTU #8, Drift/Log; Co nt' from WSR 1/25/07 ... Perform weekly BOP test. RIH w/ Dummy WS drift and CCL/ GR in memory carrier to 11000' ctm. (Note: Proposed WS setting depth is 10940' md). Log out of hole. OOH. Good Data. RDMO. *** Job Complete *** T/I/0=?/1800/450, PPPOT-T (PASS), PPPOT-IC (PASS), Function LDS (Pre-CTD). FMC BP Gen 2. Starting head: 13 3/8" x 20" 2m. Casing head: 20" 2m x 13 5/8" 5m w/ 1 FMC model 75 OA valve. Tubing head: 13 5/8" 5m x 13 5/8" 5m w/ 1 FMC model 75 IA valve. Tubing head adapter: 13 5/8" 5m x 5 1/2" 5m. Tree: FMC 6" w/ model 75 valves. PPPOT-T: Stung into TBG hanger test void to check pressure (2000 psi), bled pressure to 0 psi (gas/fluid). Pumped through test void untill clean returns were achieved, pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min, (PASS). Bled void to 0 psi. Functioned all LDS, no sign of bent or broken LDS. PPPOT -IC: Stung into IC hanger test void to check pressure (1800 psi), bled pressure to 0 psi (gas). Pumped through test void until! clean returns were achieved, pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 50 psi in second 15 min, (PASS). Bled void to 0 psi. 12 of 28 LDS very tight/stuck started twisting flats CTU #8, Drift/Log; Road to location. Spot unit. Found 3 stud bolts on PIS to be too short, call for replacements. Begin RU. Cont' on WSR 1/26/07 ... T/I/O = SSV/1700/450. S1. AL line. IA & OA FL's pre-FB (CTD prep). Pump-in-sub installed on swab with 2" hardline run to tiger tank. IA FL @ 7302' (461 bbls), between Sta # 2 & Sta # 3, OA FL @ 84'. *** CONT WSR FROM 1-22-07 *** ( pre ctd ) RIG DOWN SLICKLINE UNIT *** LEFT WELL SHUT IN , TURNED OVER TO DSO *** *** CONT WSR FROM 1-21-07 *** ( pre cte ) GOOD DATA ON CALIPER, SET WHIDDON @ 10718' SLM SET WHIDDON @ 10718'SLM PULLED S/O FROM STA. #1 @ 9444' SLM, PULLED LGLV FROM STA. #2 @ 7019' SLM, PULLED LGLV FROM STA. #4 @ 4134'SLM SET DGLV IN SA # 4,2 , & 1 PULL WHIDDON *** CONT WSR ON 1-23-07 *** ***WELL SHUT IN ON ARRIVAL*** (pre ctd) RAN 2.70" CENT., 1 1/4" x 10' WB, 2.70" CENT., DRIFT TO 10,914' SLM + 34' CORRECTION (KB ELEV - BF ELEV)= 10,948' MD. TOOLS STOP FALLING DUE TO HIGH DEVIATON OF WELL RAN 2.70" CENT., DUAL PETRADAT GAUGES, MADE STATIC STOPS PER PROGRAM. SEE DATA SECTION FOR DETAILS. RAN CALIPER FROM 10900' SLM TO SURFACE, ( GOOD DATA) *** CONT WSR ON 1-22-07 *** http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 3/7/2007 '---- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -07 17-07 ~ REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/9/2007 Rig Release: 2/19/2007 Rig Number: Spud Date: 5/17/1981 End: 2/19/2007 2/8/2007 10:30 - 15:00 4.50 MOB P PRE Load out equipment from 22 pad to DS 17. Clean up area around well head and Pad to prep for inspection. Complete pad inspection with DSO. 15:00 - 17:15 2.25 MOB P PRE Leave pad and head towards GPB on Spine Road 17:15 - 19:00 1.75 MOB P PRE Park at 1 A Pad turnoff for Kuparuk Field changeout 19:00 - 00:00 5.00 MOB P PRE Move from 1A Pad to past MPU turnoff by midnite 2/9/2007 00:00 - 05:00 5.00 MOB P PRE Continue move from 22-13 Move on Spine Road from east of MPU turnoff to S Pad by 0500 hrs 05:00 - 10:00 5.00 MOB P PRE Continue move after crew change and rig at J-Pad at 1000 hrs. - 10:00 - 18:30 8.50 MOB P PRE Continue move. Arrive on DS 17 and set rig down on Pad out of the way 18:30 - 00:00 5.50 MOB P PRE Standby while wo FL removal Had planned to move camp trailers from 22, but Security is busy wI N2ES and N1 moves. Shoot grade and find additional location prep is required. 2/10/2007 00:00 - 06:30 6.50 MOB P PRE Rig on standby. Finish shooting location. Wait on heavy equipment. Grade pad around and in front of wellhead. Re-shoot grade. Looks. good. 06:30 - 10:00 3.50 RIGU P PRE Rig off standby. Lay down herculite. Spot rig mats around wellhead. Move rig over well. Make up handi-berm around cellar. Spot cuttings box. Accept rig at 10:00 hrs on 2/10107. 10:00 - 15:00 5.00 RIGU P PRE Finish cellar prep. Hold PJSM. NU BOPs. Camps on location at 1100 hrs. Spot three camps. Establish comms and switch to rig power. Call for utilities and order KCL water. 15:00 - 22:15 7.25 BOPSU P PRE Test BOP equipment. Witness waived by AOGCC rep. C. Scheve. 22: 15 - 22:30 0.25 WHSUR P WHDTRE Safety mtg re: pull BPV 22:30 - 23:30 1.00 WHSUR P WHDTRE RU DSM HP lubricator and pull 5-1/2" BPV. WHP 95 psi, IA 0, OA O. RDMO DSM tools 23:30 - 23:45 0.25 RIGU P WEXIT Safety mtg re: Pull CT and stab 23:45 - 00:00 0.25 RIGU P WEXIT RU injector 2/11/2007 00:00 - 01 :15 1.25 RIGU P WEXIT Fin RU injector. Remove holding devices on reel and pull over pipeshed thru injector 01:15 - 04:15 3.00 RIGU P WEXIT Cut off internal grapple and prep end of CT. Install CTC and PT @ 35k. Install BHI UQC. Meg test. Found short in flow sub and replace 04:15 - 05:40 1.42 RIGU P WEXIT Move injector over bung hole and fill CT wI 2% KC11.5 bpm. PT CTC and inner reel valve at 3500 psi. Move injector over bung hole 05:40 - 07:00 1.33 KILL P WEXIT Line up to circ CT while bullhead. Kill wI 250 bbls 2% KCI at 3.3 bpm. WHP stabilized at 75 psi at 3.3 bpm. 07:00 - 08:30 1.50 STWHIP P WEXIT MU Baker 3-1/2" x 4-1/2" IT whipstock on Inteq MWD. Add RA tags in pipe shed. Stab coil. Test tools. Get on well. 08:30 - 10:30 2.00 STWHIP P WEXIT Run in hole with whipstock BHA. 10:30 - 11 :00 0.50 STWHIP P WEXIT Log GR tie in to CCUGR log. Subtract 11' correction. 11 :00 - 12:00 1.00 STWHIP P WEXIT Wait on WSL to finish up Incident Review meeting and verify GR tie in. 12:00 - 12:30 0.50 STWHIP P WEXIT RIH to 11,000'. 35k# up, 22k# dn wt. RIH to 11,087'. PU to- neutral weight. Close EDC. Fill coil and pressure up to 3600 psi. Baker setting tool activated and sheared. Set 5k# dn on ws. Looks good. Pick up. Free from whipstock. Top of whipstock is at 11,074'. TF: 190R. Printed: 2/26/2007 1 :52:32 PM "-'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17-07 fÃ 17-07 ~ REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/9/2007 Rig Release: 2/19/2007 Rig Number: Spud Date: 5/17/1981 End: 2/19/2007 Date Frorn ..To WEXIT Pull out of hole. Fill hole down coil at 0.4 bpm. WEXIT PJSM. Tag up. Get off well. Unstab coil. LD Inteq and Baker tools. Continue to pump 5 bbls KCL into well every 30 minutes, WEXIT PJSM. Prep floor to run 1-1/4" CSH. Dress elevators. MU 20 jts CSH wI 2.25" large hole nozzle. Stab coil. Get on well. WEXIT Stab coil. Get on well. Run in hole with cementing BHA pumping min rate thru nozzle wi choke 51 and well sucking fluid from CT. RIH to 11011', corr -11'. 39.8k# up wt. Open choke and circ 1.0/200 wlo returns WEXIT Start 34 bbls 120K Flopro pill down CT 1.75/350 wlo returns. Displace mud with 1% KCL water. After 10 bbls out of nozzle, shut in choke. No WHP response. Fill hole down CT annulus wI 4 bbls. Continue to circulate 1.0/210 with no rtns. MI RU SLB cementers. Hold PJSM with crews in ops cab (29 souls, an ops cab record ?) Pump 50 bbl 130K flovis pill down CT 1.0/230 wI choke 51 .Af while wo DS to get ready. Cementers batch up and begin 6r' pumping cement Cementers load CT 1.5/1400 with 37.6 bbls 15.8 ppg Class G plug cement wI 3:35 thickening time and 90 cc fluid loss. Displace cement wI 5 bbls fresh water then 32 bbls biozan followed by kcl water at 1.5 bpm wI choke closed. With cmt at nozzle at 11,000', 1.47/1850/15 begin to PUH at 5' per min at 43.5k#. After 20 bbls out nozzle and at 10940', reduce rate to 1.25/200/66. Open choke with 12 bbls left at 10,925' and WHP at 110 psi. PUH laying in remaining cement and out-ran rtns. PUH past calc WCTOC at 10,300'. Continue to PUH to 9,900'. rom 9900' at 3' per min while circ at 0.34110 wlo returns while letting cement settle and set. CTP gradually increa indicating that fluid is filling backside. Left cemeter . ged up and released personnel for rest while bulk truc Iver headed back for more cement. (if needed). WEXIT Continue to circ 0.34/280 psi wlo rt " nc rate to 1.0 bpm at 700 psi and got full rtns. 51 c e and pressure up well to 100 psi. Bled off to 0 psi in In. Repeat "squeeze" three times.. WEXIT RIH at 1.0 bpm/70 si wI choke closed. Well pressured up to 500 psi. Let' eed to 0 in 15 minutes. Begin c out. RIH fl 9930' at 30'/min 1.5/1550 holding 300 p . P to 10,780' cleanout depth which is in the 4-1/2" solid mer and had nearly full rtns. PUH, bleed off WHP and had 1.5 in/1.35 out/1335 psi. Call this good enough for now. irculate out of hole at 1.5 bpm at 1330 psi. Wash each GLM whl OH. Dump diesel cont rtns to cuttings box. Treat minimal rtns wI retarder. Also got back formation sand from the Sag . r WEXIT Tag up at surface. WEXIT Unstab coil. Found appro' ately 300 ft e-line below coil connector. Get off well. LD C WEXIT Reverse circulate to push slack into r Cut 304' of coil to find wire. Coil length is now 13,680' in len WEXIT Test e-line (good). MU e-coil head. Test same. W EXIT MU window milling BHA (HCC one step mill wI diamo 2/11/2007 12:30 - 14:45 14:45 - 16:00 2.25 STWHIP P 1.25 STWHIP P 16:00 - 17:30 1.50 STWHIP P 17:30 - 20:10 2.67 STWHIP P 20:10 - 22:10 2.00 STWHIP P 22:10 - 22:30 0.33 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 2/12/2007 00:00 - 00:35 0.58 STWHIP P WEXIT 02:30 - 02:45 02:45 - 03:45 03:45 - 05:30 1.75 STWHIP P 05:30 - 06:30 06:30 - 07:00 STWHIP P 2.00 STWHIP P 0.75 STWHIP P Printed: 2/26/2007 1 :52:32 PM . . SARAH PALIN, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 1 7 -07 A J I Sundry Number: 307 -034 ~'i)JJ tf; Ð Dear Mr. Rixse: SCANNED JAN 232007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this .f-3day of January, 2007 Encl. f) 7::! / /2-tf-./7 ~ RECEIVED I STATEOFALASAA/ I /"'~~~ ' ALAS OILANDGASCONSERVATIONCOMMI ION JAN 2 3 2007 APPLICATION FOR SUNDRY APPROVAL . ll-:>,\.'" .. ..... 20 AAC 25.28041aSka O¡l & Ga~ Cons. Cammission 1. Type of Request: 181 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension ¡Ulctmrage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 204-011 ,/ 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20596-01-00 ,/ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 17-07A ý" Spacing Exception Required? DYes ~No 9. Property Designation: J 110. KB Elevation (ft): j 11. Field / Pool(s): ADL 028331 65' Prudhoe Bay Field / Prudhoe Bay Pool ¡ 122 »ii<i iii>.. ..........i "iC · ·····i.i.iC····· ii.·. ·...i···.··i.i.iii···.>i·..·i·ii··.·ii..iiiii.······i...... ·i.i. "i Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12969 8731 12969 8731 None None Casino Lenoth ize MD TVD Burst CollaDse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2687' 13-3/8" 2687' 2687' 4930 2670 Intermediate 7475' 9-5/8" 7475' 6772' 6870 4760 Production Liner 3567' 7" 7317' - 10884' 6642' - 8741' 7240 5410 Liner 2227' 4-1/2" 10740' - 12967' 8681' - 8731' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10890' - 12923' 8744' - 8734' 3-1/2",9.3# L-80 10736' Packers and SSSV Type: 9-5/8" x 7" BKR ZXP LNR TOP PKR, I Packers and SSSV MD (ft): 7327' 7" X 3-1/2" BKR S-3 PREM PKR 10682' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development o Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: February 1, 2007 DOil DGas D Plugged ~ Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse, 564-5620 Printed Name Mel,Rixse., /\ Title CT Drilling Engineer . {~y~ Prepared By Name/Number: Slgnatu,v .#"p.r~ // _/ Phone 564-5521 DatE2r-:TA,.f')Y\]lSondra Stewman, 564-4750 , '{./ Commission Use Onlv I Sundry Number: ',.t-¡"f7...Q. ~ 4- Conditions of approval: Notify Commission so that a representative may witness - D Plug Integrity ~OP Test o Mechanical Integrity Test D Location Clearance Other: ~SOO ~ '\ ",,-, ~"\ ~..:)~ ~\:§? ~ c:. -\. 1 Subsequent Form Required: ~G1~ 'l 'AMMISSIONER APPROVED BY Date l-t3rDr Approved By: THE COMMISSION Form 10-403 Revised 06/2006 VV~! \. RBDMS 8Ft .IAN 2Si~W In Duplicate '--1 RIG1NAL . . To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission Obp From: Mel Rixse CTD Engineer Date: January 22, 2007 Re: DS17-07A Sundry Approval- Rev. 1 Sundry approval is requested for well 17-07 A. A coiled tubing drilling sidetrack from 17-07 A is proposed. The parent well was a rotary rig sidetrack and was completed February 2004. Well 17-07 A is currently a gas-lifted horizontal Sag River producer. The planned wellbore will be slant profile, exiting 17-07 A at the top of the Sag River, penetrating all of Z4 and most of Z3. The well will be TD'd at the HOT tar mat. Zone 3 is predominantly conglomeratic, and Z4 consists of more sandy' fluvial lithofacies. REASON FOR SIDETRACK: This existing well (17-07 A) is currently a gas-lifted horizontal sag producer and has typically been shut in due to high water cut and low productivity. This sidetrack project will abandon the 17-07 A slotted liner completion. Well 17 -07B will provide access to the Z3/Z4 Ivishak layers to benefit from 03-07 Ai mist injection. The well placement should also produce from the unswept waterflood reserves against the fault boundary. GR and resistivity logs will be recorded while drilling through the Ivishak and into the HOT in order to identify lithography and estimate saturations. The sidetrack is planned on or around February 1, 2007. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram ofthe proposed sidetrack is attached for reference. Pre-Rig Work Summary: 1. C Make 2.70" dummy whipstock run to total depth 10,990' (50' past proposed WS setting depth). 2. C Run SLB MGR/CCL (memory gamma ray/casing collar locator). This is run for tie-in and collar identification. Log 1O,600'to 11,700'. Dummy all gas lift valves Run caliper as deep as possible. MIT - IA and MIT -OA Set BPV AC-LDS; AC-PPPOT-IC, T Bleed production flow lines and GL lines down to zero and blind flange Remove wellhouse, level pad 3. S 4. S 5. 0 6. 0 7. 0 8. 0 9. 0 . . Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull BPV. 'T""L, '0. 2. Run Baker TTWS set IO,940'MD, lowside set. \ "\7 'S,.,J'<\.û~ . 3. Pump 50 bbls of 150 LSRV Flo-Pro 4. S ueeze 50 bbls of 15.8 ppg of cement past whipstock. 5. Mi112.74" window at IO,940'an 10 0 rat 0 e. wap t ewe 0 6. Drill Build: 3.0" OH, 635' (40 deg/IOO planned) 7. Drill Lateral: 3.0" OH, 215' (12 deg/IOO planned), with resistivity 8. Run 2-3/8"" solid liner leaving TOL at 10715', 5 bbls of 15.8 ppg cmt I 9. Pump primary cement leaving TOC at TOL 10715'...0 \..\C) ~ 10. Cleanout liner ~<L 11. MCNL/GR/CCL log 12. Test liner lap to 2000 psi. 13. Perforate liner per asset instructions (~100') 14. Freeze protect well, Set BPV, RDMO Post-Rig Work: 1. Move wellhouse, Install production flowline, pull BPV 2. Run GLVs Me! Rixse CTD Engineer 564-5620 CC: Well File Sondra Stewman/Terrie Hubble TREE = WB.LHEAO = ACTUA TOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MO = Datum lVO = FMC GEN 2 FMC AX8..S0N 71' 36.5' 7450' 90 @ 10972' 12904' 8666' 17-0 A SAÆTY NOTES: 2212' --i 3-1/2"HESXNIP,ID=2.813" I 13-3/8" CSG, 72#, N-80, 10 = 12.347" I ST MD lVO 5 2997 2997 4 4142 4092 3 5729 5383 2 7019 6398 1 9441 8000 GAS LIFT MANDRB.S OEV TYPE VLV LATCH 5 ~DMY RK 28 ~ DOME RK 39 ~ DMY RK 36 ~ DOME RK 53 MMG SO RK PORT OA TE o 02120/04 16 03/08/04 o 02120/04 16 03/08/04 20 03/08/04 Minimum ID = 2.75" @ 10724' 3-1/2" HES XN NIPPLE 7327' --i 9-5/8" X 7" BKR ZXP LNR TOP PKR I MILLOUT W'NDOW 7475" - 7491' EZSV 7488' 9962' 9-5/8" eSG, 47#, L-80, 10 = 8.681" I 5" X 4-112" XO ID = 3.950" 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I , PERFORA TION SUMMA RY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLOTTED LNR 10890 - 12923 0 02120/04 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" I 14-112" LNR, 12.6#, L-80, D= 3.960" I DA TE REV BY COMMENTS 06/11/81 ORlGtNAL COMPLETION 02/21/04 JDM/KA SIDETRACK (17-07A) 03/08/04 RMHlKAK GLV C/O DA TE REV BY COWJIENTS PRUDHOE BAY UNIT WB.L: 17-07A ÆRMIT No: 2040110 API No: 50-029-20596-01 SEe 22, T10N, R15E. 3377.11' FB. & 3628.45' FNL BP Exploration (Alaska) SAFETY NOTES: 03/08/04 02120104 03/08/04 03/08/04 PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical SæE Op 7327' Minimum ID ::: @ 10124' 3-1/2" HES XN NIPPLE EZSV MILLOUT WINDOW 7475" - 7491' 9-5/8" eSG, 47#, L-80, ID = 8.681" 3-112" HES X NIP, 10 = 2.813" PREM PKR 3-1/2" HES X NIP, 10 = 2.813" 7" LNR, 29#, L-80, .0371 bpf, 10 = 6. 3-1/2" TBG, 9.2#, L-BO, .0087 bpf, 10 = 7" LNR, 26#, L-80, ,0383 bpf, 10 = BY COMMENTS UNIT WELL: 17-07A PERMIT No: 2040110 BP Exploration (Alaska) RECEIVED Schlum~erger SEP 1 2 2006 NO. 3952 .~ Oil ,& Gas Gens. commisSicn ~nchora<;~ Company: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 dOL} -0 L I ;ð 1"1 /3d SCANNED SEP 1 92005 Field: Prudhoe Bay WI! J b# L D BL CI D C e 0 og escrlptlon ate o or D X-16 10830812 RSTlGRAVEL PACK 05/31/04 1 C-24A 11209609 MEM PROD PROFILE 06/19/06 1 V-02 40010525 OH EDIT OF MWD/LWD 06/10/04 2 1 N-07 A 40010734 OH EDIT OF MWD/LWD 07/19/04 2 1 17-07A 40010150 OH EDIT OF MWD/LWD 02/17/04 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 09/11/06 . . I Âò M~V't·v... DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2040110 Well Name/No. PRUDHOE BAY UNIT 17-07A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20596-01-00 MD 12969 TVD 8731 Completion Date 2/20/2004 Completion Status 1-01L Current Status 1-OIL UIC N ------ --------.---- REQUIRED INFORMATION Mud Log No Samples No --- Directional surv(' ~ ..) ..,.. ...::::-...... -----~- --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Type ~ I~_- Electr Digital Dataset Med/Frmt Number . Name Log Log Scale Media Run No Interval OH / Start Stop CH Received Comments D Wrd Directional Survey Directional Survey 7394 12969 7394 12969 3/24/2004 3/24/2004 I A'" ao Exœ:æad'he" I -~~~,_.~ Well Cores/Samples Information: Name Interval Start Stop Sent ~. Received Sample Set Number Comments ADDITIONAL INFORMATION r"",, Well Cored? Y ~ Chips Received? Y7f:r' Daily History Received? ."" '~/N /'0. (YN . Formation Tops Analysis Received? '-'f'rÑ- ~---_._-- Comments: ·t 1/\'\.0\ h ~ fàV1~ (Lm",~ I\.f::, V)\.~~ I~ i ------1-~ - fQ(,~c\.w €:. r3 f.C.GV\A. ).& F~I ~ Ie Þ ,t" c' 'IJ (~ U ) Date: JD FJ--~ , Compliance Reviewed By: . STATE OF ALASKA a ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IS! Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic Test D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/20/2004 204-011 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/7/2004 50- 029-20596-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/17/2004 17-07A 2242' SNL, 930' EWL, SEC. 22, nON, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2651' NSL, 2059' EWL, SEC. 15, nON, R15E, UM 65' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ rvD) 3150' NSL, 329' EWL, SEC. 15, nON, R15E, UM 12969 + 8731 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 709176 y- 5928401 Zone- ASP4 12969 + 8731 Ft ADL 028331 -- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 710159 y- 5933323 Zone- ASP4 Total Depth: x- 708415 y- 5933773 Zone- ASP4 (Nipple) 2212' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IS! Yes DNa NIA MSL 1900' (Approx.) 21. Logs Run: 2. CASING, LINER AND CEMENTING RECORD 9~fi~~ GRADE SETTING ~¡;P1'f!MO SETnN<rl ):PTHTVP HOLE .... Wr.·PeR FT. <lOP I BOTTOM Top···· BOTTOM Size ....<..... .. .n. 20" 94# H-40 Surface 80' Surface 80' 32" ~32 sx Arcticset II 13-3/8" 72# N-80 Surface 2687' Surface 2687' 17-112" 3000 sx Fondu, 850 sx PF II 9-5/8" 47# L-80 I SOO-9~ Surface 7475' Surface 8739' 12-1/4" 500 sx Class 'G' 7" 26# L-80 7317' 10884 ' 6642' 8741' 8-1/2" 1211 sx Class 'G', 184 sx Class 'G' 4-1/2" 12.6# L-80 10740' 12967' 8681' 8731' 6-1/8" Uncemented Slotted Liner 23. Perforations oRen to Production (MD + rvD of Top and 24, TUBING - ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 3-1/2",9.3#, L-80 10736' 10682' MD rvD MD TVD 10890' - 12923' 8743' - 8734' 25. ACID,FRACTû~E,·CeMENTSQ\JEe¡.E, ··ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 160 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift. etc.): March 12, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO 3/16/2004 5.3 TEST PERIOD .. 6 455 572 90° 84.027 Flow Tubing Casing Pressure CALCULATED .. Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 25 2,061 2,589 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attactptEe~tVËßary). Submit core chips; if none, state "none". r;'-;;;;: APR -1 2004 *-'t} f. ", ~ ,- :. .. c., ~, .; '",,".. -'J None ~~~ OR!G/~r4L Alaska Oil & Gas Cons. Commis$ion Æ·' I}' ";~~:U ! í An orll8 .. ..~_ .. ._.... ,~··,.",...."""-'w~'.,'·· '" '",,~ 'ìíìf¡L¡ R vi 1220 ~,-).. ~,~ 1\" - - . Form 10407 e sed I 03 CONTINUED ON REVERSE SIDE ~BfL ¡;: .. 28. GEOLOGIC MARKERS' 29. ORMATION 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". CM2 8378' 7368' None CM1 9607' 8100' Top HRZ 10109' 8405' Base HRZ 10685' 8659' LCU 10775' 8695' Sag River 10903' 8748' RECEIVED APR - 1 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Terrie Hubble"l {¿ Title Technical Assistant Date 03- 3[·0 17-07A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 204-011 Permit No. / A roval 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 Or") I (" I '(", A L :\!l.Ji \' Legal Name: 17 -07 Common Name: 17 -07 ._-----"--- Test Date ..... . ..-....--.---.--...-..-... 2/6/2004 2/14/2004 . .... ...~A.. _n'_' ._...._....__ ,Test Type . ..... ... ....._...._ ..... ........n....__._.... _ .............-......-..--r.-- i LOT FIT Test Depth (TMD) 7,465,0 (ft) 10.885.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 6,772.0 (ft) 8,742,0 (ft) ____.___._..._...._ n.." _. AMW 9.70 (ppg) 8,50 (ppg) -_.._._....__._._.........~, --..-.- Surface Pressure 958 (psi) 700 (psi) Leak Off Pressu~~J~~P) i 4,370 (psi) 4,560 (psi) Page 1 of 1 EMW ....................- . 12.42 (ppg) 10.04 (ppg) Printed: 2/23/2004 11:14:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date I From - To 2/1/2004 04:00 - 13:00 13:00 - 00:00 2/2/2004 00:00 - 16:00 16:00 - 00:00 2/3/2004 00:00 - 03:00 03:00 - 04:30 04:30 - 05:45 05:45 - 10:00 10:00 - 15:00 e Page 1 of 13 BP EXPLORATION Operations Summary Report 17 -07 17 -07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Hours I Task 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Start: Rig Release: Rig Number: , I ' ! Code I N PT: Phase i Description of Operations 9.00 MOB P ---.----------.....---- .. ................ -.. .--- ___n_____.._ . ..... ...¥... ._._ PRE PJSM. RID. Move pits and Shop in order to move out with Sub. Move Sub Off Z-30A. RID top drive, bridle up. Lay Down Derrick. PRE PJSM with Rig Crew, Security. Peak. Tool Services and all involved with move, Move Sub off Z Pad down Access Rd. to Spine Rd. . Move East on Spine Rd. toward Kuparuk River Bridges. PRE Continue Moving Sub. Arrived DS 17 @ No Problems, PRE Raised Derrick. Pinned Same. Un-bridle Blocks, Hook up Top Drive. Hang Bridle Line. Connect Lines. Spot Mats & set Herculite, Moved Rig onto Mats, Spotted and Leveled Rig Over 17-07 A. Bermed Rig. PRE Center and level Rig over 17-07. Spot Pit Complex & level same. Hook up all lines, Prepared to take on seawater, DECOMP ACCEPT RIG @ 03:00 HRS 2/3/2004. Take on Seawater. RlU Lines to Tubing and 5 1/2" X 9 5/8" Annulus to Choke Manifold in Preparation to displace diesel from wellbore, Checked 5 1/2" Tubing X 9 5/8" Annulus - on slight vacuum. Bled off trapped 500 psi in control line. DECOMP Pressure Test Lines & Tree to 3500 psi. RlU DSM Lubricator & pull BPV. Tubing also on slight Vacuum. RREP DECOMP Change out Drag Chain in Pits. DECOMP Pump 104 Bbls heated Seawater down lA, dispalcing Diesel out of Tubing. Pumped 30 Bbls before returns. When Clean Returns: Pump Seawater down Tubing taking Diesel returns from Annulus until clean. Monitor Well - Static, RlU DSM Lubricator & Set BPV. Test from below to 1000 psi. NID Tree & Adapter Flange & remove from Cellar. FMC Hand set Blanking Plug in Tubing Hanger. N/U BOPE, Riser & Secure Turnbuckles Test Blind Rams to 250 psi -Low & 3500 psi -High. P/U FMC Plug pulling tool. M/U to Jt 5" DP. Run in and engage Blanking Plug & Pull Same. P/U 51/'2" Landing Jt wI LH Acme Thread Run in and Screw into Tubing Hanger. Fill Stack & Choke Manifold - Resume Testing. Continue to Test BOPE. High Test on Lower failed. Found Seal on Test Jt Failed. Pull test Jt. C/O seal. Run Back in and screw into Hanger, Complete Testing BOPE 250 psi. Low. 3500 psi High all tests 5 minutes, Witness of test waived by John Spaulding, AOGCC. Disengage Test Jt from Tubing Hanger. Pull & UD. RID testing Equipment. PJSM. RlU 7" Shooting Nipple wI Bowen Connector. R/U DSM Lubricator & Pull BPV. RID DSM, PJSM, M/U Baker Spear Assy and Spear into Tubing. Engage Spear 12' below Hanger. B.O.L.D.S. Pulled 160K to Free Tubing = Calculate bouyed Wt + T/D & Blocks. Pull Hanger through BOP to Floor. Fill Hole with 47 Bbls. Monitor Well, (Approx, 16 BPH Losses) Back Out & UD Spear Assy. & Tubing Hanger. Circulate Bottoms Up wI Seawater: 379 Bbls @ 6 BPM & 260 11.00 MOB P 16.00 MOB P 8.00 RIGU P 3,00 RIGU P 1,50 WHSUR P 1.25 WHSUR P 4,25 WHSUR N 5,00 CLEAN P 15:00 - 16:00 1,00 WHSUR P DECOMP 16:00 -18:00 2.00 WHSUR P DECOMP 18:00 - 21 :00 3.00 BOPSUF P DECOMP 21 :00 - 00:00 3,00 BOPSU¡:; P DECOMP 2/4/2004 00:00 - 02:00 2.00 BOPSU¡:; P DECOMP 02:00 - 03:00 1.00 BOPSU¡:; N SFAL DECOMP 03:00 - 04:30 1.50 BOPSU¡:; P DECOMP 04:30 - 05:00 0,50 BOPSU¡:; P DECOMP 05:00 - 06:00 1.00 WHSUR P DECOMP 06:00 - 07:30 1.50 FISH P DECOMP 07:30 - 09:00 1.50 PULL P DECOMP 09:00 - 09:30 0.50 PULL P DECOMP 09:30 - 10:30 1,00 PULL P DECOMP Printed: 2/2312004 11:14:46AM e Page 2 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date i From - To I Hours ¡Task ¡Code NPT: Phase I .. ....-- .-..... 2/4/2004 09:30 - 10:30 1,00 PULL 10:30 - 15:00 4.50 PULL 15:00 - 15:30 0,50 PULL 15:30 - 21:00 5,50 PULL 21 :00 - 22:00 1.00 PULL 22:00 - 23:30 1.50 PULL ___.0"'- ... ..._ ....._n. _...____._..__ DECOMP psi. Losses 6 BPH while Circulating. Rig up Camco Spooling Unit. PJSM with All hands involved POH wI 5 1/2" Tubing. Spooling Dual Control Line to Camco Ball-O Nipple. RID Camco Spooling Unit & Off Load from Floor. Continue POH. UD 5 1/2" Tubing & Jewelry. Setting Plate on Top of YC Elevators Broke. Repair BJ. YC Elevators. Complete POH & UD 5112 Tubing & Jewelry. Total 198 Jts Layed down. Chemical Cut only partial on Jt # 197. Jt # 198 pulled out of Collar. Jts 194 through 198 had heavy corrosion damage. STUB is Collar @ 8535' Total Recovery: 198 Jts. 17#.L-80, AB Mod. Tubing 14 ea, Camco GLM's ww/1 0' Pups above & Below 11 ea Camco Ball-O-Nipple wI 10' Pups Above & Below 12 Lengths of 2178'- Monel 1/4" control Line I 1 ea, 135/8" X 51/2" FMC K-Monel Weld Neck Tubing Hanger I 25 ea. Control Line Clamps I 4 ea SS Bands, P P DECOMP P DECOMP P DECOMP N SFAL DECOMP P DECOMP I I j 23:30 - 00:00 0.50 CLEAN P DECOMP 2/5/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 01 :30 0.50 CLEAN P DECOMP 01 :30 - 02:00 0.50 CLEAN P DECOMP 02:00 - 05:00 3.00 CLEAN P DECOMP 05:00 - 12:00 7,00 CLEAN P DECOMP 12:00 - 18:00 6,00 CLEAN P DECOMP 18:00 - 21 :30 3.50 CLEAN P DECOMP 21 :30 - 23:00 1.50 CLEAN P DECOMP 23:00 - 00:00 1.00 PXA P DECOMP 2/6/2004 00:00 - 02:30 2.50 PXA P DECOMP 02:30 - 03:30 1.00 PXA P DECOMP 03:30 - 07:30 4.00 STWHIP P WEXIT 07:30 - 12:00 4.50 STWHIP P WEXIT 12:00 - 13:00 1,00 STWHIP P WEXIT Start: Rig Release: Rig Number: Spud Date: 5/17/1981 End: 2/20/2004 1/31/2004 2/20/2004 Description of Operations --.------.-----..". . .__ _n. RID Tubing Equipment & Load Out. Load Pipe Shed With 61/4" DC's & 5" HWDP. Clear & Clean Rig Floor. Run Wear Bushing. Bring Baker CIO BHA tools to Floor. P/U & M/U CIO BHA: 8 1/2" Junk Mill, BS, 8 1/2" String Mill, Bumper Sub. Jar, 9 - 6 1/4" De's. 21 Jts 5" HWDP. RIH to 7,595'. P/U 5" DP 1 X 1 From Shed. Close Annular Preventer. Have Little Red pump 135 Bbls Hot Diesel down Annulus, Chase with 240 bbls Hot seawater with Rig pumps @ 6 BPM I 400 psi. to complete Annular Displacement. Then pump down Drill Pipe. Circulating out Diesel. Keep pumping Hot Seawater until Clean. NOTE: During operation: maintained back pressure with choke to keep hydrostatic pressure same throughout Circulation. Rotated Rig Crew Hands on Choke. with pumping schedule. giving them practical experience in a simulated Well Kill, POH wI 5" DP, Stand back DC's & HWDP. UD CIO Tools. Well took 27 bbls over Displacement. Hold PJSM wI Rig Crew, SWS E-Line & Halliburton Tool Hand, RlU SWS. Tour Change - PJSM wI New Crew, MIU EZ Drill Bridge Plug on CCL & RIH. Correlate to 9 5/8" Collars. Collars @ 7458' & 7498'. Set EZ Drill @ 7488'. POH w/E-Line & RID SWS. RlU & Test 9 5/8" Casing & BP to 3500 psi. Chart for 30 minutes. Test OK. Blow down all Lines. PJSM wI crew. Baker & Anadrill DD & MWD. P/U & M/U Whipstock I Casing Milling Assy, Orient, RIH, & Surface test MWD, RIH to 7,451'. M I U Top Drive. Engaged Pumps, Established Parameters: Pump Rate 500 gpm. 1500 psi. String Weight Up 195,000#, String Weight Down 175.000#. Oriented Whipstock 2 deg Right Printed: 2/23/2004 11:14:46AM e BP EXPLORATION Operations Summary Report WEXIT and RIH very slowly. Tagged Up at 7,499' Drill Pipe Measurement. Set Down wI 25.000# and Set Whipstock Trip Anchor. Picked Up wI 10,000# Overpull to Confirm Anchor Set. Slacked Off and Stacked Out wI 40,000# and Sheared off of Whipstock, Pulled up and Confirmed Whipstock was Set and Sheared. WEXIT Displace Wellbore with 9,7 LSND Mud. Staged pumps up to 500 GPM /1500 psi. WEXIT Milled Window from 7,475' to 7,503'. WOM 10.000# - 20,000#. RPM 70 - 100, Torque Off Bottom 4500 ft Ilbs. Torque On Bottom 6.500 to 8,500 ft Ilbs, Pump Rate 500 gpm, 1,950 psi. Pumped 2. 30 bbl Hi-Vis Sweeps wI Super Sweep Material. String Weight Up 195.000#. String Weight Down 170,000#. String Weight Rotating 175.000#. Note: Top of Window 7,475'1 Bottom of Window 7,491'. Drilled New Hole to 7.503'. WEXIT Reamed out Window & Pumped and Circulated Around 30 bbl Hi-Vis Sweep wI Super Sweep Material. Pump Rate 500 gpm. 1,950 psi. Circulated until Returns Over Shakers were Clean. Note: Recovered 187# of Metal Cuttings. WEXIT RIU & Perform FIT -1060 psi with 9.7 ppg mud @ TVD of 6.772' WOULD have given us a 12,7 ppg FIT. The Formation Broke Down @ 45 strokes 1021 psi. The Plot of pressures and strokes shows the Formation starting to take fluid @ 958 psi. This gives us a Leak Off of 12.42 EMW. Pump dry Job, RID Lines. Blow Down, POH 5" DP. Stand Back 5" HWDP. UD Whipstock BHA Pull Wear Bushing. MIU Jetting Tool on Stand of 5" DP. Function & Clean Out BOP, Install Wear bushing. Held PJSM. M I U 8-1/2" Directional BHA: 8-1/2" Hughes HMC605 PDC Bit Ser#71 02718 dressed w/5 x 15 Jets - 6-3/4" 5.0 Stg XP Mud Motor w/1.15 deg Bend - 8-1/2" Stabilizer- CDR Assembly - MWD Assembly - 8-1/2" Stabilizer - 3 x 6-3/4" Flex Collars - XO - Jars - 20 Jts 5" HWDP - 8.1/2" Ghost Reamer - XO. Total BHA Length: 818.79', Oriented Motor to MWD. Pulsed Tested MWD, OK. RIH. Picking Up & Rabbiting. 99 Jts of 4" DP from Shed. Change Out Elevators and P/U 15 Jts of 5" DP. Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES i I ¡ Date . From - To : Hours: Task Code NPT. Phase 2/6/2004 -- 12:00 - 13:00 1.00 STWHIP P 13:00 - 14:30 1,50 STWHIP P 14:30 - 21 :30 7,00 STWHIP P 21 :30 - 23:00 1,50 STWHIP P 23:00 - 23:30 0.50 EVAL P 23:30 - 00:00 0.50 EVAL P WEXIT 2/7/2004 00:00 - 04:00 4.00 STWHIP P WEXIT 04:00 - 06:30 2.50 STWHIP P WEXIT 06:30 - 08:00 1.50 BOPSUF P WEXIT 08:00 - 11 :00 3.00 STWHIP P WEXIT 11 :00 - 15:30 4.50 STWHIP P WEXIT 15:30 - 16:30 1.00 STWHIP P WEXIT 16:30 - 17:30 1.00 STWHIP P WEXIT 17:30 - 23:30 6.00 DRILL P INT1 Page 3 of 13 Start: Rig Release: Rig Number: Spud Date: 5/17/1981 End: 2/20/2004 1/31/2004 2/20/2004 Description of Operations Continue RIH wI Stands to 7,436'. M I U Top Drive, Established Parameters: String Weight Up 170,000#, String Weight Down 160.000#, Pump Rate 560 gpm, 2,150 psi, ECD 10.4 ppg. Oriented Tools High Side, Shut Down Pumps. RIH Through Window. Re-Engaged Pumps. Washed Down as Precaution from 7,496' to 7,503'. Pump Rate 521 gpm, 1,960 psi. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 7,503' to 7.759', WOB Sliding 10,000# - 15.000#, WOB Rotating 10.000# - 12.000#. RPM 60 to 100. Motor RPM 154, Torque Off Bottom 6,000 ft Ilbs - On Bottom 8,000 ft Ilbs, Pump Rate 560 gpm, SPP Off Bottom 2.100 psi. On Bottom 2,450 psi. String Weight Up 175.000#. String Weight Down Printed: 2/23/2004 11:14:46AM e Page 4 of 13 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date I From - To ; Hours, I . .....--.--.... --. ....-..------ 2/7/2004 17:30 - 23:30 2/8/2004 23:30 - 00:00 00:00 - 04:30 04:30 - 00:00 2/9/2004 00:00 - 00:00 2/10/2004 00:00 - 02:00 02:00 - 03:00 03:00 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 08:00 I 17-07 17 -07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Start: Rig Release: Rig Number: Phase I I Task Code NPT ! 6,00 DRILL P 0,50 DRILL N 4,50 DRILL N RREP INT1 RREP INT1 19.50 DRILL P 24.00 DRILL P 2.00 DRILL P 1.00 DRILL P 2.50 DRILL P 1,00 DRILL P 0.50 DRILL P 1,00 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Description of Operations __n_._.._..__________ ____no _. ___u_..._ ..___ ......_ 160,000#, String Weight Rotating 165.000#, Calculated ECD 10.42 ppg PWD ECD 10,65 ppg. Will Pump 30 bbl Hi-Vis Weighted Sweeps as Needed to Clean Hole, ART 0.52 hrs. AST 3,07 hrs, Top Drive Blower Hose caught on Wind Wall and parted while Rotating Last Stand. Repair Blower Hose Removed Parted Hose - was not repairable, Installed New Blower Hose. RIH to 7452'. Orient HIS & run through Window slowly, RIH to 7,720'. Precautionary Wash to Bottom @ 7,759' Drilled 8-1/2" Directional Hole by Rotating and Sliding from 7.759' to 9,330'. WOB 10.000# - 20.000#, RPM 100. Motor RPM 157, Torque Off Bottom 6.000 ft Ilbs - On Bottom 8.000 ft Ilbs, Pump Rate 572 gpm. SPP Off Bottom 2,950 psi, On Bottom 3,250 psi. String Weight Up 195,000#. String Weight Down 173.000#, String Weight Rotating 170.000#. Calculated ECD 11,04 ppg PWD ECD 11,54 ppg. Pumped 30 bbl Hi-Vis Weighted Sweeps at 8.146',8,430',8.900' & 9.185' to Clean Hole. ART 8.36 hrs. AST 4.49 hrs. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 9.330' to 10,560', WOB 10.000# - 35.000#. RPM 100, Motor RPM 154, Torque Off Bottom 7,500 ft Ilbs - On Bottom 9.000 ft Ilbs. Pump Rate 554 gpm, SPP Off Bottom 3,200 psi, On Bottom 3,350 psi. String Weight Up 210.000#. String Weight Down 176.000#. String Weight Rotating 183.000#, Calculated ECD 11,99 ppg PWD ECD 12,25 ppg. Pumping Hi - Vis weighted Sweeps as needed. Drilled 8-1/2" Directional Hole by Rotating and Sliding from 10,560' to 10,694', WOB Rotating 10.000# - 15,000#. WOB Sliding 20,000# - 35,000#. RPM 100. Motor RPM 154, Torque Off Bottom 8,000 ft Ilbs - On Bottom 9.000 ft Ilbs, Pump Rate 540 gpm, SPP Off Bottom 3.100 psi, On Bottom 3,300 psi. String Weight Up 212.000#. String Weight Down 175,000#, String Weight Rotating 183.000#. Calculated ECD 12.05 ppg PWD ECD 12.25 ppg. Pumped 30 bbl Hi - Vis Weighted Sweeps As Needed, ART = 1.16 hrs, AST = 0.10 hrs Circulated For Samples at 10.694'. Pump Rate 540 gpm. 3,100 psi. Drilled 8-1/2" Directional Hole by Rotating from 10.694' to 10,870'. WOB 10.000# - 15,000#, RPM 100, Motor RPM 154. Torque Off Bottom 8.000 ft Ilbs - On Bottom 9,000 ft Ilbs, Pump Rate 540 gpm, SPP Off Bottom 3.100 psi. On Bottom 3.300 psi. ART = 1.82 hrs Circulated For Samples at 10.870'. Pump Rate 540 gpm. 3.100 psi. Drilled 8-1/2" Directional Hole by Rotating from 10,870' to 10.885'. WOB 15.000#. RPM 100, Motor RPM 154. Torque Off Bottom 8,000 ft Ilbs - On Bottom 9,000 ft Ilbs. Pump Rate 540 gpm, SPP Off Bottom 3.100 psi. On Bottom 3,300 psi. ART = 0,14 hrs Circulated For Samples at 10.885'. Pump Rate 540 gpm. 3.100 psi. Printed: 2/2312004 11: 14:46 AM e e BP EXPLORATION Operations Summary Report Page 5 of 13 legal Well Name: 17-07 Common Well Name: 17-07 Spud Date: 5/17/1981 Event Name: REENTER+COMPlETE Start: 1/31/2004 End: 2/20/2004 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 2/20/2004 Rig Name: NABORS 7ES Rig Number: Date J From - To I Hours! Task : Code ! NPT I Phase I Description of Operations I L._, ,.. ...._n_. , --.- .... -....., ..---"--... .... .....--. u__. ...__ _1__. - ----- . ___n.. n' 2/10/2004 08:00 - 09:30 1.50 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Weighted Sweep, Pump Rate 550 gpm, 3.150 psi. 09:30 - 12:30 3.00 DRILL P INT1 Monitored Well, Well Static, POOH fl Wiper Trip to 10.000'. Monitored Well. Well Static, Pumped Dry Job and Blew Down Lines. Continued to POOH fl Wiper Trip to 7,386' wI No Problems. 12:30 - 13:00 0.50 DRILL P INT1 Serviced Rig, 13:00 - 15:30 2.50 DRILL P INT1 RIH After Wiper Trip from 7.386' to 10,885'. No Fill. 15:30 - 17:00 1,50 DRILL P INT1 Pumped and Circulated Around 30 bbl Hi-Vis Sweep. Pump Rate 550 gpm. 3.200 psi. Circulated Until Returns Over Shaker Were Clean. 17:00 - 00:00 7.00 DRILL P INT1 Monitored Well. Well Static. Pumped Dry Job. Blew Down Top Drive and Lines. POOH wI 5" DP. No Excessive Drag. No Overpull. 2/11/2004 00:00 - 01 :30 1.50 DRILL P INT1 Held PJSM. POOH wI 5" DP to 3,976', Calculated Fill 49 bbls. Actual Fill = 53 bbls. 01 :30 - 03:30 2,00 DRILL P INT1 POOH wI BHA. Stood Back 4" DP in Derrick, Broke Out and L I D Directional BHA. 03:30 - 04:30 1.00 DRILL P INT1 Cleared and Cleaned Rig Floor. 04:30 - 05:00 0.50 CASE P INT1 Held PJSM wI Rig Crew. Casing Crew. Toolpusher and Drilling Supervisor. 05:00 - 06:00 1.00 CASE P INT1 R I U 7" Casing Equipment. 06:00 - 07:00 1,00 CASE P INT1 M I U Float Shoe Joint, 1 Jt of 7" Casing wI Float Collar and 3rd Joint wI Insert Landing Collar. Filled Casing and Checked Float Equipment, OK. Bakerloc'd All Connections on Shoe Track. 07:00 - 10:30 3.50 CASE P INT1 M I U and RIH wI 86 Joints 7". 26#. L-80. BTC Casing, Average M I U Torque 7,500 ft Ilbs. Filled Every Joint on the Fly, Stopped and Completely Fill Casing String Every 10 Joints. 10:30 - 11 :00 0,50 CASE P INT1 P I U and M I U 7" x 9-5/8" Baker HMC Liner Hanger wI T' x 9-5/8" ZXP Liner Packer and Tie Back Sleeve. 11:00 -11:30 0,50 CASE P INT1 RID 7" Handling Equipment, R I U 5" DP Handling Equipment. 11 :30 - 12:00 0.50 CASE P INT1 M I U 1 Stand of 5" DP, R I U Circulating Head and Lines. Pumped and Circulated 1 x Liner Volume. Pump Rate 5 bpm. 500 psi. Monitored Well. Well Static. Blew Down Lines. 12:00 -- 16:00 4.00 CASE P INT1 RIH wIT' Liner on 5" DP to 7,366', 16:00 - 17:00 1,00 CASE P INT1 R I U Circulating Head and Lines. Pumped and Circulated 2 x 5" DP and Liner Volume. Pump Rate 5 bpm, 650 psi. Established Parameters: String Weight Up 200,000#, String Weight Down 150.000#. Monitored Well, Well Static. Blew Down Lines. 17:00 -- 19:00 2.00 CASE P INT1 RIH wI 7" Liner on 5" DP to 10.860'. 19:00 - 19:30 0.50 CASE P INT1 M I U Cement Head wI DP Dart to 5" DP, R I U Cementing Lines. 19:30 - 00:00 4,50 CASE P INT1 Engaged Pump, 1 bpm, 300 psi. Circulated and Washed Down to 10.885', Attempted to Stage Up Pump Rate from 1 bpm, 300 psi to 2 bpm. Pressure Increased to 1,200 psi, Hole Packing Off. Slowed Pump Rate to 1 bpm. 620 psi. Slowly Staged Up Pumps to 3 bpm. 1.350 psi. Hole Intermittently Packing Off, Pressure Increased to 1,700 psi. Slowed Pump Rate Back to 2 Printed: 2/23/2004 11: 14:46 AM e e BP EXPLORATION Operations Summary Report Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Start: 1/31/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/20/2004 Rig Name: NABORS 7ES Rig Number: Date I From - Tol Hours I Task i Code I NPT I Phase I " Description of Operations - "...--. ,,_.,....., .....-fo-----....,.,-I -..--."...- -..........-..,......-.. ,'".,--.... ..-_.......__._ -- 2/11/2004 19:30 - 00:00 4.50 CASE P INT1 bpm, 1.000 psi. Staged Pumps Back Up to 3 bpm. 1,250 psi. Attempted to Reciprocate Casing to Assist wI Hole Cleaning. Casing Dragging, Hole Very Sticky, Set Liner 3' Off of Bottom, Held PJSM. Staged Pumps Up to 3 bpm, 1,350 psi. Hole Intermittently Packing Off. Pressure Increased to 1.750 psi. Slowed Pump Rate Back to 2 bpm. 1.000 psi. Staged Pumps Back Up to 3 bpm. 1.250 psi. Achieved 4 bpm, wI a Steady Pressure of 1.050 psi. Pump Rates Over 4 bpm Caused Hole to Pack Off. 2/12/2004 00:00 - 03:00 INT1 3.00 CEMT P 03:00 - 05:00 2.00 CEMT P INT1 Page 6 of 13 , Spud Date: 5/17/1981 End: 2/20/2004 7" Liner Set As Follows: Item Depth Float Shoe 10.882.00' 1 Jt 7" 26.0# L-80 BTC Csg 10.840.30' Float Collar 10.839.31' 1 Jt 7" 26.0# L-80 BTC Csg 10.797.10' 1 Jt 7" 26,0# L-80 BTC Csg wllnsrt Ld Collar 41.39' 10.946.95' 83 Jts 7" 26.0# L-80 BTC Csg 7,339,05' 7" x 9-5/8" HMC Liner Hanger 7.332.45' 7" x 9-5/8" ZXP Liner Top Packer 7,324,81' 7" Tie Back Sleeve 7.314.81' Held PJSM wI Dowell Crew, Rig Crew, Truck Drivers, Toolpusher and Drilling Supervisor. Switched Over to Dowell. Pumped 5 bbls of Water at 3.0 bpm, 950 psi. Shut in Cement Manifold and Tested Lines to 4.500 psi. OK. Pumped 45 bbls 12.5 ppg Mud Push Pump Rate 3.5 bpm, 930 psi. Pumped 90 bbls, (212 sx) 12,0 ppg Lead Cement wI 0.20 %bwoc Antifoam - 1,50 %bwoc Extender - 1.00 %bwoc UniFlac-S - 0.10 %bwoc Retarder - 0.20 %bwoc BIOZAN Viscosifier, Followed by 38 bbls, (184 sx), 15,8 ppg Premium Tail Cement wI 0.20 %bwoc Antifoam - 0.40 %bwoc UniFlac-S - 0.10 %bwoc Retarder. Pumped Cement at the Following Rates: Pumped Rate 5.0 bbls 4,00 bpm 20.0 bbls 3.80 bpm 40.0 bbls 3,80 bpm 60.0 bbls 3.80 bpm 80,0 bbls 3.80 bpm 90.0 bbls 2,50 bpm Tail Cement 100.0 bbls 3,70 bpm Length 1.67' 41.03' 0.99' 42,21' 3,415,66' 6.60' 7.64' 10.00' Pressure 1.000 psi 1.025 psi 1,000 psi 850 psi 780 psi 400 psi 940 psi Printed: 2/23/2004 11:14:46AM e e Page lof 13 BP EXPLORATION Operations Summary Report Start: 1/31/2004 Rig Release: 2/20/2004 Rig Number: I Code I NPT' Phase I Description of Operations ......------L.....-f--.. ... . _...._._~.__._-_..._-_.~------_.. -----..-- P INT1 120,0 bbls 2.50 bpm 320 psi 128.0 bbls 2.50 bpm 300 psi Dropped DP Dart and Pumped 5 bbls of Water at 4 bpm. 200 psi. Switched to Rig Pumps and Displaced wI 248.5 bbls Mud at the Following Rates: Pumped Rate Pressure 15.0 bbls 4.50 bpm 800 psi 50.0 bbls 4.50 bpm 960 psi Hole Attempting to Packoff, Slowed Displacement Rate: 100.0 bbls 3.75 bpm 988 psi Slowed Pump Rate w/11 0 bbls Pumped to Observe DP Dart Latch Up 110.0 bbls 2.75 bpm 900 psi Drill Pipe Dart Latched Up w/115 bbls Pumped, Pressure Increased to 1,400 psi, Observed Wiper Plug Shear. Pressure Decreased to 900 psi 150,0 bbls 3,75 bpm 200.0 bbls 3.75 bpm Slowed Pump Rate wI 240 bbls Pumped 240,0 bbls 3,00 bpm 1.360 psi Wiper Plug Bumped wI 253.5 bbls Total Displacement Pumped, Pressured up to 3.500 psi. Cement in place @ 0500 hrs. 100% Returns wI No Losses While Cementing and Displacing. Pressured Up to 3,500 psi to Set Liner Hanger. Slacked Off and Stacked 35,000# on Hanger to Confirm Hanger Set. Bled Off Pressure and Checked Floats, Floats Held. Rotated Drill String to the Right to Release From Liner. Pressured Up to 1.000 psi and Picked Up on Drill String. Pressure Bled Off Indicating Liner Running Tool Released from Liner. Engaged Pumps and Circulated Hole to Clear Cement Off of Liner Top, Pump Rate 10 bpm. 1,475 psi. Total Volume Pumped 100 bbls, Slowed Pump Rate to 2 bpm. 200 psi. RIH and Stacked 45.000# on Liner Top. Good Surface Indication of ZXP Packer Setting. Picked Up and Repeated Process While Rotating to Ensure Packer Set. Engaged Pumps and Circulate Cement out of Wellbore. Pump Rate 10 bpm, 1,475 psi. Circulated Back 5 bbls of Mud Contaminated Cement. Broke Out and LID Cement Manifold, Blew Down Lines. POOH wI 5" DP. Broke Out and LID 5" HWDP and Liner Running Tool. Held PJSM. M I U Retrieving Tool, Latched and Pulled Wear Bushing, R I U BOPE Test Equipment. Held PJSM. Tested BOPE. Tested Upper and Lower Rams. Blind Rams, Stand Pipe Manifold. Choke Manifold. Valves. HCR. Kill Line. Choke Line, Floor Valves to 3,500 psi High I 250 psi Low. Tested Annular Preventer to 3,500 psi High I 250 psi Low. All Above Tests Held f/5 Min wI No Leaks or Pressure Loss. BOPE Test Witnessed by AOGCC Rep Jeff Jones. Note: IBOP would not Test. PROD1 RID BOPE Test Equipment. Ran and Set Wear Bushing. SFAL PROD1 Held PJSM. Changed Out and IBOP Valve and TIW Valve on Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date I From - To I Hours I Task ---..,..- ,_.._--,_......_...'---, 2/12/2004 03:00 - 05:00 2.00 CEMT 05:00 - 05:30 0,50 CEMT P 05:30 - 06:00 0.50 CASE P 06:00 - 07:00 1.00 CEMT P 07:00 - 07:30 07:30 - 11 :00 11 :00 - 12:00 12:00 - 12:30 0.50 CEMT P 3.50 CEMT P 1.00 CEMT P 0.50 BOPSUF P 12:30 - 19:00 6.50 BOPSUF P 19:00 - 19:30 19:30 - 00:00 0.50 BOPSUF P 4.50 BOPSUF N Spud Date: 5/17/1981 End: 2/20/2004 1 .100 psi 1.250 psi INT1 INT1 INT1 INT1 INT1 INT1 PROD1 PROD1 Printed: 2/23/2004 11: 14:46 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/12/2004 2/13/2004 2/14/2004 01 :30 - 06:00 06:00 - 07:30 07:30 - 13:00 13:00 - 14:00 14:00 - 15:30 15:30 - 19:00 19:00 - 20:00 20:00 - 00:00 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 12:30 12:30 - 14:00 - e Page 8 of 13 BP EXPLORATION Operations Summary Report 4.50 DRILL 1,50 DRILL 5.50 DRILL 1.00 EVAL 1.50 DRILL 3,50 DRILL 1.00 DRILL 4.00 DRILL 1.00 DRILL 2,50 0,50 0.50 3,50 DRILL DRILL DRILL DRILL 17 -07 17 -07 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES From - To I Hours ¡Task ! Code NPT Phase I "n ...._..__.., ...nnn' .., _.." .i.... ,n n,n..n 19:30 - 00:00 4,50 BOPSUF N SFAL PROD1 00:00 - 01 :30 1.50 BOPSUF N SFAL PROD1 0.50 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 0.50 DRILL 1,50 DRILL P PROD1 P P PROD1 PROD1 P PROD1 P PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P P P P PROD1 PROD1 PROD1 PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P PROD1 P PROD1 Start: Rig Release: Rig Number: ! 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Description of Operations -----.-- .." ,-,.- ....- ..........- ......--. Top Drive, Held PJSM, R I U Test Equipment. Tested IBOP to 3,500 psi High I 250 psi Low. Tests Held fl 5 Min wI No Leaks or Pressure Loss, Blew Down Lines. RID Test Equipment. Held PJSM, M I U 6-1/8" Clean Out BHA. Smith XR+ Ser# MP8724 Dressed wI 3 x 20 Jets - Float Sub - 3 x 4-3/4" NM Flex Collars - Hyd Jars - 183 Jts 4" DP - XO. Total BHA Length 5.959.84'. PI U 84 Jts 4" DP from Pipe Shed for BHA. Held PJSM. Slipped and Cut 204' of Drilling Line. RIH wI 6-1/8" Clean Out BHA on 5" DP to 10,759'. Filled DP Every 30 Stands. Tagged Up at 10,759'. Held PJSM, M I U Circulating Head and Line, Engaged Pump and Established Circulation. Shut Down Pump and Closed Pipe Rams. Pressure Tested 7" x 9-5/8" and Liner Top to 3.500 psi fl 30 minutes, OK. Calculated Strokes to Pressure Up to 3.500 psi, 122 - 7.0 bbls. Actual Strokes 126 - 7.3 bbls. Bled off Pressure, Opened Rams. M I U Top Drive. Established Parameters: Pump Rate 250 gpm. 1.800 psi. String Weight Up 190.000#, String Weight Down 160,000#. String Weight Rotating 175,000#, RPM 100. Torque 10.000 ft Ilbs, Drilled Out Cement and Float Equipment from 10,759' to 10,886', WOB 5,000# -10,000#, RPM 100, Torque 11.000 ft Ilbs. Pump Rate 250 gpm, 1.850 psi. Held PJSM wI Drilling Crew. Mud Engr. Truck Drivers. Tool Pusher and Drilling Supervisor. Pumped 125 bbl Spacer Ahead. Displaced Wellbore to 8,5 ppg Flo-Pro Mud, Beginning Pump Rate 300 gpm. 1.900 psi, Ending Pump Rate 510 gpm. 1,800 psi. Cleaned Out Possum Belly and Shaker Beds. POOH wI 5" DP, Held PJSM. POOH wI 5" DP. Calculated Fill = 35 bbls, Actual Fill = 44 bbls. POOH wI 4" DP. POOH, Racked 1 Stand of Flex Collars. Broke Out 6-1/8" Bit. Cleared and Cleaned Rig Floor. Held PJSM. M I U 6-1/8" Directional BHA: STC 6-1/8" XR10 Ser# ML9953 - Short Pak PDW 7/8 3-Stage Motor cut fl Float - NM Pony Collar - MWD - 3 x NM Flex Collars - Circulation Sub - Jars - 183 Jts 4" DP - XO. Total BHA Length 6,025.30', Oriented Motor to MWD, Pulsed Tested MWD, OK. RID 4" DP Handling Equipment. R I U 5" DP Handling Equipment. RIH wI 6-1/8" Directional BHA on 5" DP to 10,760'. Serviced Rig. RIH wI 6-1/8" Directional BHA on 5" DP to 10,886'. M I U Top Drive. Engaged Pump. Pump Rate 250 gpm. 1.600 psi. Made MAD Pass from 10,886' to 10,855'. Drilled 6-1/8" Directional Hole by Sliding from 10,886' to 10.905', WOB 20.000#. Motor RPM 193, Pump Rate 275 gpm, SPP Off Bottom 1,650 psi. On Bottom 1.930 psi. String Weight Up 180.000#. String Weight Down 165,000#, Circulated to Clean Hole and Condition Mud. Pump Rate 260 gpm. 1.580 psi. Printed: 2/23/2004 11:14:46AM e BP EXPLORATION Operations Summary Report , Page 9 of 13 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 17 -07 17-07 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: Rig Release: Rig Number: . I ¡ Code i NPT ' Phase 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Date ! ! ! From - To Hours Task Description of Operations --.---... ......un __. - ..__ _._____n._. -. -.- -- -.---.- --- .......-. - .._.- ____n__ 2/14/2004 14:00 - 14:30 0.50 DRILL P PROD1 Held PJSM. Pulled Back into 7" Shoe, Closed Pipe Rams and Performed FIT. Strokes Pmp'd Pressure 3 43 psi 6 99 psi 9 177 psi 12 261 psi 15 331 psi 18 415 psi 21 472 psi 24 564 psi 27 643 psi 29 700 psi MW 8.5 ppg. Shoe TVD 8.742'. Pressure 700 psi = 10.04 ppg EMW. Held Pressure f/10 minutes wI No Pressure Loss. Bled down Pressure. Opened Pipe Rams. 01 :00 - 02:00 1.00 DRILL P PROD1 Drilled 6-1/8" Directional Hole by Sliding from 10.905' to 11,400', WOB 35.000#, Motor RPM 193. Pump Rate 275 gpm. SPP Off Bottom 1,750 psi, On Bottom 2.150 psi. String Weight Up 195.000#. String Weight Down 173.000#, Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed to Clean Hole, AST 4.7 hrs. Slide Sheet Depth Tool Face Depth Tool Face 10,905' -10.951' 10.0 L 11,172' -11.203' 100,0 L 10.951' - 11.010' 10.0 L 11.203' - 11.234' 90,0 L 11.010' - 11.046' 90,0 L 11,234' - 11,265' 90.0 L 11.046' - 11.077' 120.0 L 11,265' - 11.297' 90.0 L 11,077' -11.111' 90.0 L 11,297' -11.329' 90.0 L 11.111' -11,140' 80.0 L 11,329' -11.361' 90.0 L 11,140' -11.172' 80.0 L 11,361' -11,400' 90.0 L PROD1 Pumped Out of the Hole from 11,400' to 7" Shoe at 10.885'. Pump Rate 225 gpm. 1.530 psi. PROD1 Dropped Circulation Sub Opening Tool. Pumped Tool Down on Seat, Pump Rate 135 gpm, 865 psi. Ball Seated in Circulation Sub, Pressure Increased to 2,450 psi. Circulation Sub Sheared Open, Pressure Dropped to 300 psi. Circulated 2 x Bottoms Up to Clean Hole, Pump Rate 500 gpm. 1.500 psi. PROD1 Held PJSM, Finished Circulating 2 x Bottoms Up to Clean Hole. Pump Rate 500 gpm. 1,500 psi. Circulated Until Returns Over Shaker were Clean. Monitored Well, Well Static, Pumped Dry Job. Blew Down Top Drive. PROD1 POOH wI 5" DP to 7,450', Placed Circulating Sub at 7" Liner 14:30 - 21 :00 6.50 DRILL P 21 :00 - 22:00 1.00 DRILL P 22:00 - 00:00 2.00 DRILL P 2/15/2004 00:00 - 01 :00 1.00 DRILL P Printed: 2/2312004 11: 14:46 AM e BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: I Code i NP~j!:~~=~J PROD1 Top. PROD1 Circulated at 7" Liner Top at 7,316'. Pump Rate 500 gpm. 875 psi. Shut Down Pumps and POOH to Clear 7" Liner wI BHA. Pumped and Circulated Around 30 bbl Hi-Vis Sweep, Pump Rate 500 gpm, 900 psi. Rotated Drill String 60 RPM While Circulating. Monitored Well. Well Static, Pumped Dry Job. Blew Down Top Drive, POOH wI 5" DP, Calculated Fill = 38 bbls. Actual Fill = 44.5 bbls. POOH wI BHA. Racked 4" DP in Derrick. Broke Out MWD, Motor and 6-1/8" Bit. Cleared and Cleaned Rig Floor. Serviced Rig. Removed Top Plate on Iron Roughneck, Trouble Shoot Jaws. Installed Air Quick Connect on Top Drive for Casing Elevators, Removed and Inspected Handler Lock Indicator Switch. Reinstalled and Adjusted Switch, PROD1 Held PJSM. M I U 6-1/8" Directional BHA: STC 6-1/8" MDT52 PDC Bit Ser# JT0990 Dressed wI 6 x 12/32 Jets - AD 718 2-Stage Motor wI 1.50 deg Bend and AIM - NM 6" Stabilizer - NM Pony Collar - MWD - 3 x NM Flex Collars - Circulation Sub - Jars - 183 Jts 4" DP - XO. Total BHA Length 6.034.17'. Oriented Motor to MWD, Pulse Tested MWD. OK. RID 4" DP Handling Equipment. R I U 5" DP Handling Equipment. RIH wI 6-1/8" Directional BHA on 5" DP to 10,885'. M I U Top Drive. Broke Circulation, Pump Rate 195 gpm. 1.150 psi. Pumped DP Volume, RIH wI 6-1/8" Directional BHA on 5" DP to 11,400'. Worked BHA Through High Dog Leg Section, Drilled 6-1/8" Directional Hole by Sliding from 11,400' to 11,500'. WOB 25.000#. Motor RPM 88. Pump Rate 270 gpm, SPP Off Bottom 1.500 psi. On Bottom 1.800 psi. String Weight Up 195.000#, String Weight Down 160,000#, AST 3.50 hrs. Slide Sheet Depth Tool Face 11,400' - 11,435' 150.0 L 11,435' - 11,466' 160.0 L 11,466' - 11.500' 150.0 L PROD1 Held PJSM, Drilled 6-1/8" Directional Hole by Rotating and Sliding from 11.500' to 12.500'. WOB Sliding 20.000#- 40.000#, WOB Rotating 15,000# - 20.000#, RPM 60, Motor RPM 88, Torque Off Bottom 6,000 ft Ilbs - On Bottom 9,000 ft I Ibs. Pump Rate 275 gpm. SPP Off Bottom 1,600 psi. On Bottom 1,975 psi. String Weight Up 210,000#, String Weight Down 160,000#. String Weight Rotating 183.000#, Pumped 30 bbl Hi-Vis Weighted Sweeps as Needed to Clean Hole. AST = 8.22 hrs, ART = 9.28. Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES r-_~~t~n___l From - To I~~~rs: _~~.=k 2/15/2004 01 :00 - 02:00 02:00 - 04:30 1,00 DRILL P 2,50 DRILL P 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 08:00 2,00 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL P PROD1 09:00 - 11 :00 2,00 DRILL N RREP PROD1 11 :00 - 14:30 3.50 DRILL P 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 16:30 1.50 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 00:00 5.50 DRILL P PROD1 2/16/2004 00:00 - 00:00 24.00 DRILL P Page 10 of 13 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Description of Operations ..._"- .. ...---.----..- ........-.... ------ Depth Face 11.500' - 11.528' L Slide Sheet Tool Face Depth Tool 140.0 L 12.252' - 12.278' 160,0 Printed: 2/23/2004 11:14:46AM - . Page 11 of13 BP EXPLORATION Operations Summary Report , Legal Well Name: 17 -07 Common Well Name: 17-07 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 7ES Date I From - To I Hours ¡Task i_, ,_~_ 00:00 - 00:00 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Start: Rig Release: Rig Number: i Code I NPT ; Phase ...-..- ..--- --- 2/16/2004 24.00 DRILL PROD1 P 2/17/2004 00:00 - 01 :00 PROD1 1,00 DRILL P 01 :00 - 01 :30 01 :30 - 09:00 P P PROD1 PROD1 0,50 DRILL 7,50 DRILL 09:00 - 11 :30 2,50 DRILL P PROD1 11 :30 - 15:00 3.50 DRILL P PROD1 15:00 - 16:00 1,00 DRILL P PROD1 16:00 - 17:00 1,00 DRILL P PROD1 17:00 - 20:00 3,00 DRILL P PROD1 20:00 - 23:00 3.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 2/18/2004 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 06:30 3,50 DRILL P PROD1 06:30 - 07:30 1,00 DRILL P PROD1 Description of Operations .-------- -- ------..-.---.. ....n._n. ... ...-...-----.. 11,589' - 11,621' 135.0 L 12,469' - 12,492' L 11,717' - 11,747' 135,0 L 11.747' - 11,779' 90,0 L 11,904' -11,934' 145,0 L 11.934' - 11.967' 110,0 L 12.093' - 12.130' 10.0 L Held PJSM, Drilled 6-1/8" Directional Hole by Rotating and Sliding from 12.500' to 12.563'. WOB Sliding 25.000# - 35.000# WOB Rotating 10,000# - 20.000# RPM 60, Motor RPM 88 Torque Off Bottom 7.000 ft Ilbs - On Bottom 9,500 ft Ilbs Pump Rate 275 gpm, SPP Off Bottom 1.750 psi. On Bottom 2.050 psi. Circulate samples @ 12.563' as per Geologist. Continue drilled 6-1/8" Directional Hole by Rotating and Sliding from 12.563' to 12,969TDMD I 8731'KBTVD, WOB Rotating 10.000# - 20.000# RPM 60. Motor RPM 88 Torque Off Bottom 7.000 ft Ilbs - On Bottom 9.500 ft Ilbs Pump Rate 275 gpm. SPP Off Bottom 1.750 psi. On Bottom 2.050 psi. P/U 190k SIO 163k Rot Wt 180k 140.0 Drilling time last 24 Hrs = 6.45 Hrs AST = 1.26 Hrs ART = 5.19 Hrs Survey & Conntion = 2.05 Hrs Pump a Hi-vis sweep, Circulate hole clean from 12.969' wI 280 gpm @ 1770 psi. Reciprocate & rotate (60 RPM) while circulating ( 2 x annular volumes), Backream out of hole from 12,969' to 11,500'. Pump out of hole from 11,500' to 10,882'. Encountered tight hole from 11,573' to 10,885', Pull bit inside 7" casing to 10.864'. Circulate & condition mud wI 262 gpm @ 1450 psi. TIH to 12.875' with no problems. Establish circulation. Precautionary washlream to bottom @ 12,969' with no problems, Pump a 45 bbl Hi-vis sweep. Circulate & condition mud/hole. Spot a 4% lube pill in open hole, POOH to 10,864' (Pump 4 bbl of 4% lube pill on each stand pulled) with no problems. Hole in good condition. Drop ball-rod down drill string, Shear circ-sub wI 1950 psi. CBU from 10,694' wI 450 gpm @ 1300 psi. Had a small amount of sand come across shakers on Btms-up. Monitor well-static. POOH from 10,864' to 7483' (Circ sub placed at TOL @ 7314'). CBU from 7314' wI 480 gpm @ 1000 psi (Very few cuttings came over shakers while CBU). Flow check-OK. Pump slug. Blow down TDS, Continue POOH from 7483' to top of BHA, UD 6-1/8" directional BHA. Printed: 2/23/2004 11:14:46AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/18/2004 07:30 - 08:15 08:15 - 08:45 08:45 - 09:00 09:00 - 11 :45 11:45 - 12:00 12:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 -18:30 18:30 - 20:00 20:00 - 23:00 2/19/2004 23:00 - 00:00 00:00 - 07:45 07:45 - 08:00 08:00 - 08:45 08:45 - 09:45 09:45 - 10:00 10:00 - 17:30 17:30 - 18:00 e Page 12 of 13 BP EXPLORATION Operations Summary Report 17 -07 17 -07 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Hours I Task ! 1/31/2004 2/20/2004 Spud Date: 5/17/1981 End: 2/20/2004 Start: Rig Release: Rig Number: 'Code I NPT ! .~_h,a~=J P PROD1 P COMP 0.75 DRILL 0,50 CASE 0.25 CASE COMP P 2.75 CASE COMP P 0,25 CASE COMP P 3,00 CASE 0.50 CASE 0.50 CASE P P P COMP COMP COMP 1.00 CASE COMP P 1.50 CASE COMP P 1,50 CASE P COMP 3.00 CASE P COMP 1,00 CASE 7.75 CASE COMP COMP P P 0,25 CASE 0.75 RUNCO 1,00 RUNCO COMP COMP COMP P 0.25 COMP 7.50 COMP RREP COMP Description of Operations Clear & clean Rig Floor, R/U casing tongs & related equipment for running 4,5" slotted liner. SAFETY--- Held PJSM with rig crew & BOT personnel regarding liner running operations. Run 4.5" Production Liner as per Program. Total of 1 solid shoe Jt (4.5" 12.6# L-80 IBT-M) + 49 Jts Slotted & 3 Jts Solid wI Baker 'HMC' Hydraulic Hanger. Total liner length + hanger = 2226.98' RID 4,5" Liner running equipment. Install 4" DP elevators on TDS, TIH with 4.5" slotted liner + hanger on 4" DP to 8225', Change elevators to fit 5" DP. Continue TIH wI 4.5" Slotted Production Liner on 5" DP to 10.819' with no problems. PIU 185k SIO 160k Rot Wt 170k Circulate one DP Volume prior to entering Open Hole. 160 gpm @ 550 psi. Blow down TDS after circulating. P/U Wt. = 185k. SIO Wt = 165k. Finish TIH wI 4,5" Slotted Production Liner on 5" DP to TD @ 12,969', Tag bottom. P/U String 1 (one) Ft. Hole very slick- No Problems, PIU 200k SIO 165k -- No pump Break Circulation - OK. Shut down pumps. BIO TDS & drop Baker 29/32" Setting Ball. MIU TDS & pump ball down for 58 bbl @ 4 bpm. Slow pumps down to 1.5 bpm and pump another 45 bbl to seat ball. Pressure up to 2500 psi to set HMC Hanger. Slack off 50k on hanger to insure slips engaged - OK. Continue pressuring up to 3500 too release HR Tool. Shear ball seat @ 3850 psi. PIU 22' out of Liner with Setting Tool. Note: Liner Set @ 12,967' Top of Liner (TBR) @ 10.740'. Displace well to seawater from 10.740' by pumping 810 bbl seawater @ 270 gpm I 660 psi until clean seawater @ surface. Monitor well after displacement. Well static. Slip & cut 153' of drill line, Reset & check C-O-M. POOH. Rack back 21 Std of 5" DP in Drk (Total 5" DP left in Drk = 45 Std). LID 90 Jts of 5" DP + 183 Jts of 4" DP, LID BOT 4.5" liner running tool Clean and clear rig floor. Pull wear bushing. Rig up to run 3 1/2" production completion string. Made dummy run with tubing hanger & landing jt. SAFETY--- Held PJSM with rig crew & BOT personnel regarding 3.5" completion operations. M/U & run 3.5" Completion Tail Assy. 'X' Nipple Assy & Baker S-3 Packer Assy, Bakerloc all connections below Packer. Continue running 3,5" 9.3# L-80 IBT-M Tubing as per Program. Torque to 2600 ftIlbs. Ran a total of 150 Jts, + jewelry to 4744'. Shut down running 3.5" completion due to a leak that developed on the drawworks brake-cooling radiator. Isolate radiator. Clean up small amount of glycol (Less than 4 gal) that was captured in the secondary containment on the brake-cooling unit. Printed: 2/23/2004 11: 14:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2/19/2004 2/20/2004 e Page 13 of 13 BP EXPLORATION Operations Summary Report 17 -07 17-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES ..---- .---.. I ¡From - To Hours ! I ' Task; Code: NPT I Phase Date 18:00 - 00:00 00:00 - 02:00 6.00 RUNCO COMP COMP 2.00 RUNCO 02:00 - 03:00 1,00 RUNCO COMP 03:00 - 07:00 4.00 RUNCO COMP 07:00 - 08:30 1.50 RUNCO COMP 08:30 - 11 :30 3,00 RUNCO COMP 11 :30 - 12:00 0.50 RUNCO COMP 12:00 - 14:30 2,50 BOPSU P COMP 14:30 - 18:00 3.50 WHSUR P COMP 18:00 - 19:00 1.00 WHSUR P COMP 19:00 - 21:30 2.50 WHSUR P COMP 21 :30 - 23:00 23:00 - 23:30 23:30 - 00:00 1,50 WHSUR P COMP 0.50 RIGD P 0.50 RIGD P COMP COMP Start: 1/31/2004 Rig Release: 2/20/2004 Rig Number: I Spud Date: 5/17/1981 End: 2/20/2004 Description of Operations oh_o...·______ --....-.-..-.-.----...-..----.......- Continue RIH wI 3.5" 9.3# L-80 IBT-M Tubing as per Program. Ran a total of 295 Jts(Midnight) to 9277', Continue RIH wI 3,5" 9.3# L-80 IBT-M Tubing as per Program from 9277. Tag-up @ 10,737.8' with 10k, PIU & apply 1.5 RH turns in string. SIO on string, Tagged-up at same depth. Work string one more time. Tagged up @ same depth, Ran a total of 343Jts, PIU 105k S/O 90k LID 2 jts of 3.5" Tbg. RIU to circulate. EOT @ 10.706' (341 jts in well). Reverse circulate down annulus & up tbg @ 2.8 bpm @ 620 psi with 284 bbl of corexit treated seawater + 254 bbl of clean seawater. RID circulating equipment & blow down same, P/U tubing hanger assembly. Land Hanger & confirm correct space out-OK. NOTE: The tubing hanger is a 13-5/8" x 5,5" (swedged down to 3,5" IBT-M) OCT hanger wI 5-3/4" RH Acme lift thread. Tubing landed with WLEG @ 10736'. RILDS, Drop BOT 1-5/8" packer setting BalllRod down 3.5" tubing, PJSM, Set packer by pressuring up on tubing to 3500 psi, lost 200 psi in 20 minutes. Retest tubing to 3500 psi for 30 minutes. lost 275 psi. Bleed tubing pressure to 1500 psi. Pressure up on annulus to 3500 psi for 30 minutes-OK, Noted tubing pressure dropping indicating ball & seat leak, Bleed-off annulus & tubing pressure to 0 psi. Repeat tubing test with same results, Pressure up on annulus, DCR Valve in GLM at 4143' sheared @ 2300 psi. Pump through DCK valve-OK, LID Landing Jt. Install TWC valve, Test to 1000 psi from below-OK. Blow down CIK lines, Bleed off pressure on BOP control lines. NID BOP's & secure. NIU Tree adapter& Production Tree. Test pack off to 5000 psi. RlU DSM Lubricator. Pull BPV & set TWC, Test tree to 5000 psi. Pull TWC. PJSM wI Little Red Hot Oilers. RlU HP pumping lines from Hot Oil truck to wellhead. Test lines to 3500 psi. Pump 160 Bbls heated diesel down 3-1/2" X 9-5/8" Annulus. Shut in and allow to U-Tube into Tubing. Freeze Protect Tubing & Annulus to 2200' TVD. Install BPV in tubing hanger. Test to 1000 psi from below. RID Little Red's equipment. Secure well. Service TDS & Rig. Clean cellar area & rig floor of all excess drilling & completion equipment. NOTE: Rig 7ES released from DS 17-07A @ 24:00 Hrs on February 20, 2004. Printed: 2/23/2004 11:14:46 AM e e O,··""··""·,·,·",b,,.,.,,þ '";........"" , DS17-07A Survey Report Schlumberuer Report Date: 17·Feb·04 Client: BP Exploration Alaska Field: Prudhoe Bay Unn· EOA StructurelSIOI: DS-171 17-07 Well: 17·07 Borehole: 17-07A UWVAPI#: 500292059601 Survey Name 1 Date: 17-07AI February 17. 2004 Torti AHDI DDl/ERD ratio: 314,859' /7135,00 ftl 6,522 1 0,814 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet location LatlLong: N 70 12 27.701. W 14818 47,912 location Grid NlE YIX: N 5928400,630 ftUS, E 709175,530 ftUS Grid Convergence Angle: +1,58710472' Grid Scale Factor: 0,99994971 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Vertical Section Azimuth: 354,660' Vertical Section Origin: N 0,000 ft, E 0,000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 65,00 ft relative to MSL Sea Bed I Ground Level Elevation: 28,50 ft relative to MSL Magnetic Declination: 25,526' TOIal Field Strength: 57596.412 nT Magnetic Dip: 80,844' Declination Date: February 10. 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North -) True North: +25,526' Local Coordinates Referenced To: Well Head 494,00 0,00 0.00 494,00 429,00 0,00 0,00 0,00 0,00 0,00 0,00 0.00 5928400.63 709175,53 N 70 1227,701 W 148 1847,912 594,00 0,00 0.00 594,00 529,00 0,00 0.00 0,00 0,00 0,00 0,00 0.00 5928400.63 709175,53 N 70 1227,701 W 148 1847,912 694.00 0,00 0,00 694.00 629.00 0,00 0.00 0,00 0,00 0,00 0,00 0,00 5928400,63 709175,53 N 70 1227,701 W 148 1847,912 794.00 0,00 0,00 794.00 729.00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 5928400,63 709175,53 N 70 12 27,701 W 148 1847.912 894,00 0,00 0,00 894,00 829.00 0,00 0,00 0,00 0,00 0,00 0.00 0,00 5928400,63 709175,53 N 70 1227,701 W 148 1847.912 994,00 0.00 0.00 994,00 929,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 5928400,63 709175.53 N 70 1227.701 W 148 1847.912 1094,00 0,00 0,00 1094,00 1029,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 5928400.63 709175,53 N 70 1227.701 W 148 1847,912 1194.00 0,00 0,00 1194,00 1129,00 0,00 0.00 0,00 0,00 0,00 0,00 0.00 5928400.63 709175,53 N 70 1227,701 W 148 1847,912 1294.00 0,00 0,00 1294.00 1229.00 0,00 0.00 0,00 0,00 0,00 0,00 0.00 5928400,63 709175,53 N 70 1227,701 W 148 1847,912 1394,00 0,00 0,00 1394,00 1329.00 0,00 0,00 0,00 0.00 0,00 0,00 0.00 5928400,63 709175,53 N 70 1227,701 W 148 1847,912 1494,00 0,00 0,00 1494,00 1429,00 0.00 0,00 0,00 0,00 0,00 0.00 0,00 5928400,63 709175,53 N 70 12 27,701 W 148 1847,912 1594,00 0.00 0,00 1594,00 1529,00 0.00 0,00 0,00 0,00 0,00 0.00 0,00 5928400,63 709175.53 N 70 1227,701 W 148 1847.912 1694,00 0,50 144,83 1694,00 1629,00 -0,38 0.44 -0,36 0,25 0,50 0.50 0,00 5928400,28 709175,79 N 70 1227,697 W 148 1847.904 1794,00 0,50 148.95 1793,99 1728,99 -1.15 1,31 -1.09 0,73 0,04 0.00 4,12 5928399,56 709176.29 N 701227,690 W 148 1847.891 1894,00 0,00 0,00 1893,99 1828,99 -1,54 1,74 -1.46 0,95 0.50 -0.50 0,00 5928399,20 709176,52 N 70 12 27,686 W 148 1847.884 1994.00 0,00 0.00 1993,99 1928,99 -1,54 1,74 -1.46 0,95 0.00 0.00 0,00 5928399,20 709176.52 N 70 12 27,686 W 148 1847.884 2094.00 0,00 0.00 2093,99 2028,99 -1,54 1,74 -1.46 0,95 0,00 0,00 0,00 5928399.20 709176,52 N 70 1227.686 W 148 1847,884 2194,00 0,50 147.42 2193,99 2128,99 -1,93 2,18 -1,83 1,19 0,50 0,50 0,00 5928398,84 709176.77 N 70 1227.683 W 148 1847,877 2294,00 0,00 0,00 2293.99 2228.99 -2,32 2,62 -2.20 1.42 0,50 -0.50 0,00 5928398.47 709177.01 N 70 1227.679 W 148 1847,870 2394,00 0,00 0,00 2393.99 2328,99 -2,32 2.62 -2,20 1.42 0,00 0,00 0,00 5928398.47 709177,01 N 70 1227,679 W 148 1847,870 2494,00 0.50 132,88 2493,99 2428.99 -2,64 3.05 -2.49 1.74 0,50 0,50 0.00 5928398,19 709177,34 N 70 1227,676 W 148 1847,861 2594,00 1.00 178,03 2593,98 2528.98 -3,84 4.30 -3,66 2.09 0,74 0,50 45.15 5928397.03 709177,72 N 70 1227,665 W 148 1847,851 2694,00 1.00 165,28 2693,97 2628,97 -5.57 6,04 -5,38 2.34 0,22 0,00 -12.75 5928395.32 709178,02 N 70 1227,648 W 148 1847,844 2794,00 1,50 101.47 2793,95 2728,95 -6.81 8,01 -6.48 3,85 1,39 0,50 -63.81 5928394,26 709179,56 N 70 1227,637 W 148 1847,800 2894,00 3,00 36,50 2893,88 2828,88 -5.24 11,57 -4,64 6,69 2,73 1,50 -64,97 5928396,18 709182,34 N 70 1227,655 W 148 1847,718 2994.00 4,75 34.62 2993,65 2928,65 -0.12 18,33 0,87 10,60 1,75 1,75 -1.88 5928401,80 709186,10 N 70 1227,709 W 148 1847.604 3094,00 6,25 19.80 3093,19 3028,19 7,98 27,86 9.40 14,79 2.05 1,50 -14,82 5928410.44 709190,06 N 70 1227,793 W 148 1847.482 3194.00 8,00 18.93 3192.41 3127.41 19,26 40,27 21.11 18,90 1,75 1.75 -0,87 5928422,25 709193,83 N 70 1227,908 W 148 1847.363 3294,00 10,00 15.10 3291,18 3226,18 33.74 55,90 36.07 23.42 2.09 2,00 -3,83 5928437,34 709197,94 N 70 12 28,055 W 148 1847.232 3394,00 11,25 5.45 3389.47 3324.47 51.46 74,30 54.17 26,60 2.17 1.25 -9,65 5928455,51 709200,62 N 70 12 28,233 W 1481847.140 3494,00 13,25 5.63 3487.19 3422,19 72.29 95,52 75.29 28,65 2,00 2.00 0,18 5928476,68 709202,09 N 70 1228.441 W 148 1847,080 3594,00 15,00 0.00 3584.16 3519,16 96.43 119,90 99.63 29,78 2.22 1,75 -5,63 5928501,05 709202,54 N 70 1228,681 W 148 1847.047 3694.00 17,25 354.18 3680,23 3615,23 124,15 147,65 127.33 28,28 2.77 2,25 -5,82 5928528,69 709200,27 N 70 12 28,953 W 148 1847.091 3794,00 20,00 353,90 3774,98 3709,98 156,08 179,58 159.09 24,95 2.75 2,75 -0.28 5928560,34 709196,07 N 70 12 29,265 W 1481847.187 3894,00 22,50 355,63 3868.18 3803,18 192,32 215,82 195.18 21,68 2.58 2.50 1,73 5928596,33 709191,79 N 70 1229,620 W 148 1847.282 3994,00 24,75 357,65 3959.79 3894,79 232,36 255,89 235.18 19,36 2.39 2.25 2,02 5928636,24 709188,37 N 70 1230,014 W 148 1847.350 4094,00 27.00 358,53 4049.76 3984.76 275,92 299,53 278.79 17,92 2.28 2.25 0,88 5928679,80 709185,72 N 701230.443 W 148 1847.392 4194,00 29,00 358.43 4138.05 4073,05 322,76 346.47 325.72 16,67 2.00 2.00 -0,10 5928726,67 709183,18 N 701230,904 W 148 1847,428 4294,00 33.00 358,88 4223.75 4158.75 374,12 397,97 377,20 15.48 4.01 4.00 0.45 5928778,10 709180,55 N 70 12 31.411 W 1481847.462 4394,00 35.25 359,87 4306.53 4241,53 430,03 454,06 433.29 14,88 2.32 2.25 0,99 5928834,15 709178.40 N 701231,962 W 1481847.480 4494,00 35.50 0,37 4388.07 4323,07 487,66 511,95 491,19 15,00 0.38 0.25 0,50 5928892,02 709176,92 N 70 1232,532 W 148 1847.476 4594,00 35.75 359,95 4469.35 4404,35 545,64 570,20 549,43 15,16 0,35 0.25 -0.42 5928950,24 709175,47 N70 1233.104 W 1481847.472 4694,00 36,00 0.45 4550,38 4485.38 603,96 628,80 608,03 15,37 0,39 0.25 0,50 5929008,82 709174,05 N 70 12 33,681 W 148 1847,466 4794.00 35,00 357,85 4631,80 4566.80 661,84 686,87 666,09 14,52 1,81 -1.00 -2,60 5929066,83 709171.60 N 70 12 34.252 W 148 1847.490 4894.00 36,00 358,57 4713,21 4648.21 719,80 744,94 724,13 12,71 1,08 1.00 0,72 5929124,79 709168.18 N 70 12 34,823 W 148 1847,543 SurveyEditor Ver 3.1 RT ·SP3.03-HF4,OO Bld( d031 rt-546 ) 17-07\ 17-07\17-07 AI 17-07 A Generated 3/22/2004 2:46 PM Page 1 of 3 .. e e 5494.00 37.00 7,85 5198.10 5133,10 1070.46 1098,27 1076,97 19,75 2,15 0,50 3.50 5929477.68 709165.44 N 70 12 38.293 W 148 1847,338 5594.00 38.00 11,95 5277.45 5212.45 1129.16 1159.13 1136,91 30,23 2,69 1,00 4,10 5929537,88 709174.26 N 70 1238.882 W 148 1847.034 5694,00 39,00 13.47 5355,71 5290,71 1188,34 1221.38 1197,63 43,94 1,38 1,00 1,52 5929598,95 709186,28 N 70 1239.479 W 148 1846,636 5794,00 39,00 13.05 5433.42 5368.42 1247,99 1284,31 1258.88 58,37 0.26 0.00 -0.42 5929660,58 709199,01 N 70 1240,082 W 148 1846.217 5894,00 39,50 13,60 5510,86 5445.86 1307,93 1347,58 1320.45 72,96 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37,00 14.53 6137.47 6072.47 1776,54 1844.88 1802.50 194.94 1,17 ·1,00 1,00 5930207,75 709320.47 N 70 1245.428 W 148 1842,253 6794,00 37,50 14,22 6217,07 6152.07 1833,52 1905.41 1861.14 209.97 0.53 0.50 -0,31 5930266,77 709333,86 N701246,005 W1481841.816 6894.00 36.00 14,95 6297.19 6232.19 1889,77 1965,24 1919,04 225,03 1.56 -1,50 0,73 5930325,07 709347,31 N 70 1246,574 W 148 1841,379 6994,00 36,00 14,88 6378,09 6313,09 1944.91 2024,02 1975,84 240,16 0,04 0,00 -0.07 5930382.26 709360,86 N 70 1247,133 W 1481840,940 7094,00 35,00 15.43 6459,50 6394,50 1999.31 2082,08 2031,89 255,33 1,05 -1,00 0.55 5930438.70 709374.48 N 70 1247,684 W 148 1840.499 7194,00 35,00 15,35 6541.42 6476.42 2052,95 2139.44 2087,19 270.56 0,05 0,00 -0,08 5930494 .40 709388.16 N 70 1248,228 W 148 1840,057 7294.00 35,00 14,37 6623,33 6558,33 2106,78 2196,80 2142.63 285.27 0,56 0,00 -0,98 5930550.22 709401.33 N 70 1248.773 W 148 1839,630 7394.00 34.50 16,18 6705,50 6640,50 2160,13 2253,80 2197,61 300,28 1.15 -0.50 1,81 5930605,60 709414.81 N701249.314 W1481839.194 7475,00 34,50 16,18 6772.25 6707,25 2202.81 2299,67 2241,67 313,06 0,00 0,00 0,00 5930649,99 709426,37 N 70 1249,748 W 148 18 38,823 7492,00 36,50 16.20 6786,09 6721,09 2211.99 2309,55 2251,15 315,81 11,76 11,76 0.12 5930659,55 709428,86 N 70 1249,841 W 148 18 38,743 7503,00 36,50 16.20 6794,94 6729,94 2218,08 2316,09 2257.43 317.84 0,00 0,00 0.00 5930665.88 709430,51 N 70 1249,903 W 148 18 38,690 7600.38 41,19 16,00 6870,76 6805.76 2274,91 2377,15 2316.10 334,57 4,82 4,82 -0,21 5930724,99 709445,81 N 70 1250.480 W 1481838,199 7696,29 41.77 15,81 6942.61 6877.61 2334,12 2440,68 2377.20 351,97 0,62 0.60 -0,20 5930786,54 709461.51 N 70 1251.080 W 148 1837.693 7791.49 45,04 15,76 7011,77 6946,77 2395,13 2506,08 2440,14 369,77 3,44 3,43 -0,05 5930849,94 709477,56 N701251,699 W1481837.177 7886,56 48.43 16.56 7076,92 7011,92 2459.53 2575,30 2506,62 389,04 3,62 3,57 0,84 5930916,93 709494,98 N 70 1252,353 W 148 18 36.617 7980,57 52,96 16,53 7136.45 7071.45 2527,02 2648,03 2576,33 409,75 4,82 4,82 -0,03 5930987.19 709513,75 N 70 1253,039 W 148 18 36,016 8076.29 55,15 16,27 7192,64 7127,64 2598,99 2725.52 2650,67 431.63 2,30 2,29 -0.27 5931062.10 709533,56 N 70 1253,770 W 148 18 35,380 8173.36 54.46 16.42 7248.58 7183.58 2672.70 2804,84 2726,79 453.95 0,72 -0,71 0,15 5931138,80 709553,77 N 70 12 54,519 W 148 18 34,732 8267.49 53.75 15,79 7303.77 7238.77 2743,68 2881,09 2800.05 475,11 0,93 -0.75 -0,67 5931212,61 709572,88 N 70 1255,239 W 148 1834,118 8361,68 55.48 16,32 7358.31 7293,31 2815,17 2957,88 2873.84 496,35 1,89 1,84 0,56 5931286,96 709592.07 N 701255,965 W 148 1833.501 8453,50 54,98 15,69 7410,68 7345,68 2885.42 3033,31 2946.34 517,14 0,78 -0,54 -0,69 5931360,01 709610.85 N 701256,678 W 148 1832,897 8548,10 54,29 15.48 7465.43 7400.43 2957.48 3110.45 3020,84 537,87 0,75 -0,73 -0,22 5931434,85 709629.51 N 70 12 57.409 W 148 1832,295 8640,55 53,32 15.47 7520,02 7455,02 3027,22 3185,06 3092.55 557,78 1.05 -1.05 -0,01 5931507,28 709847.42 N701258.116 W1481831.717 8736.72 53.45 16.56 7577.38 7512,38 3099.11 3262,25 3166,74 579,07 0,92 0,14 1,13 5931582.03 709666,65 N 70 1258.845 W 14818 31,098 8830.52 52,72 16,14 7633,72 7568,72 3168,79 3337,24 3238,70 600,19 0,86 -0,78 -0.45 5931654,54 709685,76 N 70 1259,553 W 148 18 30.485 8927.49 53,63 17,63 7691,85 7626,85 3240.64 3414,86 3312,97 622,74 1,55 0,94 1,54 5931729,41 709706,24 N 70 130,284 W 1481829,830 9021,90 54.10 17,56 7747,52 7682.52 3310,86 3491.11 3385,65 645.78 0,50 0,50 ·0.07 5931802.69 709727,27 N 70 130,998 W 1481829,161 9115.43 53.52 17,15 7802.74 7737.74 3380,50 3566,60 3457,70 668.30 0,71 -0,62 -0.44 5931875.33 709747,78 N 70 131,707 W 1481828,507 9212,39 53,17 16,85 7860,63 7795,63 3452.45 3844,38 3532.09 691,04 0.44 -0,36 -0.31 5931950,32 709768.45 N 70 13 2.439 W 148 1827,846 9306,74 52,04 17,28 7917,93 7852,93 3521,74 3719,34 3603.74 713,04 1,25 -1,20 0.46 5932022,55 709788.45 N 70 13 3,143 W 148 1827,208 9398,94 52,64 17.76 7974,26 7909,26 3589.00 3792,33 3673.35 735,01 0,77 0,65 0,52 5932092,73 709808.49 N 70 133,828 W 148 1826.569 9490,98 52,74 17.93 8030,05 7965,05 3656.29 3865,53 3743,03 757.45 0,18 0.11 0,18 5932163,01 709828.98 N 70134,513 W 148 1825,918 9586.51 52,95 18.03 8087,74 8022,74 3726.21 3941,67 3815,45 780,95 0.24 0.22 0,10 5932236,05 709850.47 N 70 135,225 W 148 1825.235 9683.04 52,18 18,04 8146.42 8081.42 3796.57 4018,32 3888,33 804,68 0.80 -0.80 0,01 5932309,55 709872.17 N 70 135.942 W 1481824.546 9775.39 52,65 18.41 8202,75 8137,75 3863.65 4091,50 3957,84 827,57 0.60 0.51 0.40 5932379,67 709893.12 N 70 136.626 W 148 1823.881 9869,30 51,84 18,29 8260,25 8195,25 3931,64 4165.75 4028,32 850,94 0,87 -0,86 -0,13 5932450,76 709914,54 N 70 137.319 W 148 1823,202 9963,26 51.70 18.42 8318,39 8253,39 3999.23 4239,56 4098,37 874,18 0.18 -0.15 0,14 5932521.42 709935.83 N 70 138.008 W 148 1822.527 10058,91 54.10 19,09 8376,09 8311.09 4068.86 4315,84 4170,60 898,72 2.57 2.51 0,70 5932594,30 709958.35 N 70 138.718 W 1481821.814 10154,75 57.80 18,33 8429.74 8364.74 4141,37 4395,24 4245,80 924,18 3,92 3.86 -0,79 5932670,18 709981,71 N 70 139.458 W 148 1821,075 10250,17 62.44 16,74 8477.27 8412.27 4217,58 4477.95 4324,68 949,07 5,07 4.86 -1,67 5932749,71 710004.41 N 70 13 10.233 W 148 1820,351 10343,67 84.75 16,75 8518.84 8453.84 4295,18 4561.69 4404,86 973,20 2.47 2.47 0,01 5932830,53 710026,31 N 70 1311,022 W 1481819,651 10435,80 64,69 16,25 8558.19 8493.19 4372,50 4644.99 4484,74 996,86 0,50 -0,07 -0,54 5932911.02 710047,75 N 70 1311,808 W 1481818,963 10529,98 66,23 16,92 8597,30 8532,30 4451,98 4730.66 4566,85 1021.31 1,76 1,64 0.71 5932993.77 710069,92 N 70 1312,615 W 1481818,253 10623,99 66,95 16.56 8634,65 8569,65 4531,92 4816,94 4649.46 1046.16 0,84 0,77 -0,38 5933077.04 710092.47 N 70 1313.428 W 1481817,531 10719,92 66,16 16.89 8672,82 8607,82 4613.48 4904,94 4733,75 1071.49 0,88 -0,82 0,34 5933161.99 710115.45 N 70 13 14,256 W 148 18 16,795 10813,61 65,05 17.23 8711,52 8846,52 4692,37 4990,27 4815,32 1096.52 1,23 -1,18 0.36 5933244.22 710138,21 N 70 13 15,059 W 148 18 16,068 10877.42 64,77 17.20 8738,57 8673,57 4745,74 5048,06 4870,52 1113.62 0.44 -0.44 -0.05 5933299.87 710153,77 N 70 13 15,602 W 148 18 15,571 10905.35 71.41 15.40 8748,99 8683,99 4769,81 5073,96 4895,37 1120.88 24,51 23,77 -6.44 5933324.91 710160,34 N 70 13 15,846 W 148 18 15,360 10939.88 80,66 15,50 8757,31 8692,31 4801.11 5107.43 4927.84 1129,80 26,79 26,79 0,29 5933357,41 710168,36 N 70 1316,163 W 1481815,101 10972,03 87,84 13,69 8760,53 8695,53 4831,16 5139.40 4958.57 1137,85 23.02 22,33 -5.63 5933388,56 710175,55 N 70 13 16.468 W 148 18 14,867 11000,57 94,15 12,81 8760,04 8695,04 4858.19 5167,92 4986,34 1144,39 22,32 22,11 -3.08 5933416.49 710181,32 N 70 13 16,741 W 148 18 14,677 11034,92 94.09 5,31 8757,57 8692,57 4891.35 5202,18 5020,14 1149,78 21.78 -0,17 -21,83 5933450.43 710185,77 N 70 13 17,073 W 148 18 14,520 SurveyEditor Ver 3.1 RT-SP3,03-HF4,OO Bld( do31 rt-546 ) 17-07\17-07\ 17-07 AI 17-07 A Generated 3/22/2004 2:46 PM Page 2 of 3 .. . e e 11095,23 91,75 351,78 8754.91 8689,91 4951,31 5262.43 5080,24 1148.45 23,75 -1.17 -23.74 5933510.46 710182,78 N 70 13 17,664 W 148 18 14,558 11128.63 93,33 343,71 8753.42 8688.42 4984.40 5295.79 5112,82 1141,37 24,60 4,73 -24,16 5933542,83 710174,80 N 70 13 17,984 W 148 18 14,764 11159,97 94,32 336,68 8751,33 8686,33 5014,66 5327,06 5142,22 1130,78 22.60 3,16 -22.43 5933571,92 710163.41 N 70 13 18,274 W 148 18 15,071 11188.47 92,88 330,77 8749,54 8684,54 5041,22 5355,50 5167.71 1118,20 21.30 -5,05 -20,74 5933597,06 710150.12 N 70 1318,524 W 148 18 15.436 11223.47 92.13 321,59 8748,01 8683.01 5071,92 5390.47 5196.73 1098,76 26,29 -2,14 -26,23 5933625,52 710129,88 N 70 1318,810 W 148 18 16,001 11255,38 93.40 315.53 8746.47 8681.47 5097,66 5422,34 5220,61 1077,67 19,38 3,98 -18,99 5933648,81 710108.15 N 70 13 19,045 W 148 18 16.613 11285.76 90.45 308.97 8745.45 8680.45 5120.06 5452.70 5241,01 1055.21 23,66 -9,71 -21,59 5933668,58 710085,13 N 70 13 19.245 W 148 18 17.265 11319,80 89.42 299,73 8745.48 8680.48 5141.78 5486.74 5260,20 1027.14 27,31 -3.03 -27.14 5933686.98 710056,54 N 70 13 19.434 W 148 18 18,081 11351,79 91,78 292,01 8745,15 8680,15 5158,34 5518.73 5274,14 998,38 25,23 7,38 -24,13 5933700,12 710027.41 N 70 13 19,571 W 148 18 18,916 11380,20 94.43 281.40 8743,61 8678,61 5168,97 5547,09 5282.29 971,25 38.44 9,33 -37,35 5933707,51 710000,06 N 70 1319,651 W 1481819,704 11410.16 94.71 276.59 8741.22 8676,22 5176.37 5576,96 5286,96 941.76 16,03 0,93 -16,05 5933711,36 709970.46 N 70 13 19,697 W 148 1820.560 11441.73 93,33 276.54 8739.00 8674,00 5182.86 5608.45 5290,56 910.48 4,37 -4,37 -0,16 5933714,10 709939.09 N 70 1319,733 W 148 1821.469 11471.95 90.65 276.39 8737.95 8672.95 5189,04 5638,65 5293.96 880.47 8,88 -8,87 -0,50 5933716,66 709909,00 N 70 1319,766 W 148 1822,340 11501,83 88,90 276.23 8738.07 8673,07 5195,07 5668,53 5297,24 850,77 5,88 -5,86 -0,54 5933719,12 709879.22 N 70 13 19,799 W 148 1823,203 11533.46 88,15 274.46 8738,89 8673,89 5200,94 5700.15 5300,19 819,29 6,08 -2,37 -5,60 5933721.20 709847,68 N701319.828 W1481824,117 11564.36 88.49 274.51 8739,79 8674.79 5206,21 5731,03 5302.60 788,50 1.11 1,10 0,16 5933722,76 709816,83 N 70 1319,851 W 1481825,011 11597,01 88,83 276,84 8740.56 8675,56 5212.39 5763,67 5305,77 756,02 6,60 1,04 6,52 5933725,03 709784,27 N 70 13 19,883 W 148 18 25,955 11629,19 88,01 274,07 8741.44 8676.44 5218.36 5795,84 5308,77 723.99 8,38 -2,55 -7,99 5933727,14 709752,18 N 70 13 19,912 W 148 1826,885 11660,75 88.46 275.48 8742.41 8677.41 5223.90 5827.39 5311.40 692.56 4,69 1.43 4.47 5933728,90 709720,68 N 70 13 19,938 W 148 1827.798 11692,90 88,66 274,56 8743,22 8678,22 5229,68 5859.53 5314,21 660.54 2,93 0,62 -2.86 5933730,82 709688,60 N 70 13 19,966 W 148 1828.727 11725,24 88.49 274,92 8744,03 8679.03 5235,33 5891,86 5316.88 628,32 1,23 -0,53 1,11 5933732,60 709656,32 N 70 13 19.992 W 148 1829,663 11752,82 87.77 273.79 8744.93 8679.93 5239,98 5919.42 5318.98 600,84 4,86 -2,61 -4,10 5933733,93 709628,79 N 701320.013 W 148 18 30.461 11784,38 87,91 271,66 8746.12 8681.12 5244.40 5950,96 5320.48 569,34 6.76 0.44 -6,75 5933734,56 709597,27 N 70 1320,027 W 14818 31,376 11816,28 88,35 273,14 8747.16 8682,16 5248,69 5982,84 5321,81 537.48 4,84 1,38 4,64 5933735,01 709565,39 N 70 1320,041 W 14818 32,301 11845,17 88,53 272,30 8747,94 8682,94 5252.74 6011,72 5323,18 508,64 2,97 0,62 -2,91 5933735,58 709536,52 N701320,054 W1481833,139 11881.91 88.90 274,11 8748,77 8683,77 5258,20 6048.45 5325,24 471.96 5,03 1.01 4,93 5933736,62 709499,80 N 70 1320.074 W 148 1834.204 11913,93 88.66 273.41 8749.45 8684.45 5263,26 6080.46 5327.34 440,02 2,31 -0.75 -2,19 5933737.83 709467,82 N 70 13 20.095 W 1481835.132 11941,69 88,15 272.19 8750.22 8685.22 5267,19 6108,21 5328.69 412,30 4.76 -1,84 -4,39 5933738.42 709440,08 N 701320.108 W 14818 35,937 11976,81 88,04 269,68 8751.39 8686,39 5271,03 6143,31 5329.26 377,21 7.15 -0,31 -7,15 5933738.02 709404,98 N 70 1320,114 W 14818 36,956 12008.14 88,22 269,91 8752.41 8687.41 5273,83 6174,63 5329,15 345,90 0.93 0,57 0,73 5933737,04 709373,69 N 70 1320,113 W 14818 37,866 12037.78 88.63 270,22 8753,23 8688,23 5276.62 6204.26 5329,19 316,27 1,73 1,38 1,05 5933736,25 709344.07 N701320,113 W1481838,726 12071,09 89,11 271,93 8753,88 8688,88 5280.34 6237.56 5329,81 282,97 5,33 1.44 5,13 5933735,95 709310.77 N 70 1320,119 W 148 1839,693 12103,05 89.69 271,15 8754,22 8689,22 5284,17 6269,52 5330,67 251.03 3,04 1,81 -2.44 5933735,93 709278.81 N 70 1320,128 W 148 1840.621 12130,77 90.75 270.71 8754,11 8689,11 5287,20 6297,24 5331,12 223.31 4,14 3,82 -1.59 5933735,61 709251.10 N701320,132 W1481841.426 12167,07 90,99 271.22 8753.56 8688.56 5291,18 6333.53 5331,73 187.02 1,55 0,66 1.40 5933735,22 709214,81 N 70 13 20,138 W 148 1842.480 12196,85 90,96 271.33 8753.05 8688,05 5294,61 6363,31 5332,39 157,25 0,38 -0.10 0.37 5933735,05 709185,03 N 70 13 20.145 W 1481843.344 12224.70 91,23 271.40 8752,52 8687,52 5297,87 6391,15 5333.06 129,42 1,00 0.97 0.25 5933734,95 709157.19 N701320,151 W1481844.153 12259,02 91,03 274.41 8751.85 8686.85 5302,79 6425.47 5334,79 95,15 8,79 ·0.58 8.77 5933735.73 709122,89 N 70 13 20.169 W 1481845.148 12290.92 90,10 273,90 8751.53 8686,53 5308,05 6457,36 5337.11 63,34 3,32 -2.92 -1,60 5933737.16 709091,03 N 70 13 20.191 W 1481846,072 12319.60 90,31 274.42 8751 .43 8686.43 5312,78 6486,04 5339.19 34,73 1,96 0,73 1,81 5933738.45 709062,38 N 70 1320,212 W 148 1846,903 12354,09 90.27 271,92 8751,25 8686,25 5317.89 6520,53 5341,09 0,30 7,25 -0,12 -7,25 5933739,40 709027,91 N 70 1320,230 W 148 1847,903 12385,37 90.48 272.46 8751,05 8686,05 5321.98 6551,81 5342,29 -30,96 1.85 0,67 1,73 5933739,73 708996,63 N 70 1320,242 W 1481848,811 12414,16 90.86 273,52 8750,71 8685,71 5326.15 6580,60 5343,79 -59,71 3.91 1,32 3,68 5933740,44 708967,85 N 70 1320,257 W 148 1849,646 12444,29 90.99 273.40 8750,23 8685,23 5330.76 6610,73 5345,61 -89,78 0.59 0.43 -0.40 5933741.42 708937,74 N 70 1320,275 W 148 1850,519 12475,89 91,03 276.08 8749,67 8684,67 5336.29 6642,32 5348,22 -121,26 8.48 0,13 8.48 5933743,16 708906,20 N 70 1320,301 W 148 1851.433 12506,96 90,24 275.16 8749,32 8684,32 5342,20 6673.39 5351,26 -152.18 3,90 -2,54 -2,96 5933745,34 708875.21 N 70 1320,330 W 148 1852.331 12540.43 90,21 273.96 8749.19 8684.19 5347,95 6706.86 5353,92 -185,54 3,59 -0,09 -3,59 5933747,08 708841.79 N 70 1320,357 W 148 1853,300 12571.90 90,55 274.65 8748.98 8683.98 5353,23 6738,33 5356,28 -216.92 2.44 1.08 2.19 5933748,57 708810.36 N 70 1320.380 W 148 1854.212 12601.45 91,82 275.43 8748.37 8683.37 5358,55 6767,87 5358,88 -246,35 5,04 4,30 2,64 5933750,35 708780.87 N 70 1320,405 W 148 1855.066 12633.84 92,16 275.41 8747.25 8682.25 5364,59 6800,24 5361,94 -278.58 1,05 1,05 -0,06 5933752,51 708748.57 N 70 13 20.435 W 148 1856.002 12665.63 92,23 274,69 8746.03 8681.03 5370,32 6832,01 5364,73 -310,22 2,27 0.22 -2,26 5933754.43 708716.87 N 70 1320.463 W 148 1856.921 12694.44 92.44 273.47 8744.86 8679.86 5375,03 6860,80 5366,78 -338.93 4,29 0.73 -4,23 5933755,69 708688.11 N 70 1320,483 W 148 1857.755 12728.03 92,78 274.41 8743.33 8678.33 5380.44 6894.35 5369,09 -372.41 2,97 1,01 2,80 5933757,06 708654.58 N 70 1320,506 W 148 1858.727 12759.81 92,50 276,01 8741.86 8676.86 5386,26 6926,10 5371,97 -404.02 5,11 -0,88 5.03 5933759,07 708622.91 N 70 1320,534 W 148 1859.846 12789.48 92,57 276,69 8740.55 8675.55 5392,26 6955,74 5375,25 -433.48 2,30 0,24 2,29 5933761,53 708593.37 N 70 1320.566 W 148 190.501 12823,05 92,57 274,55 8739,05 8674.05 5398,64 6989,27 5378,53 -466,86 6,37 0,00 -6.37 5933763,89 708559.92 N 70 13 20,599 W 148191.470 12853,87 92,68 273,92 8737,63 8672.63 5403,76 7020,06 5380,81 -497,56 2,07 0.36 -2.04 5933765,31 708529.17 N 70 13 20,621 W 148192.362 12884,16 92.95 275,73 8736,15 8671.15 5409,10 7050,31 5383,35 -527,70 6,03 0.89 5,98 5933767,02 708498.96 N 70 13 20,646 W 148193.238 12914,32 93.26 275,77 8734,51 8669.51 5414,89 7080.43 5386,37 -557,67 1,04 1.03 0.13 5933769,21 708468.93 N 70 13 20,676 W 148194.108 12969,00 94.02 275,77 8731,04 8666,04 5425.41 7135,00 5391,85 -611,96 1,39 1.39 0.00 5933773.19 708414,51 N 70 13 20,729 W 148195.685 Leaal DescriDtion: Northina IYI IftUS! Eastina IX} IftUS! Sur/ace: 3038 FSL 4350 FEL S22 T10N R15E UM 5928400.63 709175,53 BHL: 3150 FSL 4951 FEL 515 T10N R15E UM 5933773.19 708414,51 SurveyEditor Ver 3.1 RT-SP3,03-HF4,OO Bld( d031 rt-546 ) 17-07\17-07\17-07 A\17-07 A Generated 3/22/2004 2:46 PM Page 3 of 3 e e Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No DS-17-07A Date Dispatched: 3-Feb-04 Installation/Rig Nabors 7ES Dispatched By: F. Alabi Data No Of Prints No of Floppies Surveys 2 1 RE CEIVEI D r~i :1~ ) 2, 2004 . " , ,~ ~as Cons, Comn1 .10 ',';-:-h!1age -~-~~I\ ~( c "'"- Received By: \('-, \ -; ,ç C'( ."~,, ð{'- ~,/"t"-'\ Please sign and return to: Orilling & Measurements LWD Oivision 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907-561-8417 LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private -':::"~§-...... " ,'" Ì) \" '-. '. ."..,.,) \\\ 0::::::- SCHLUMBERGER Survey report Client. ............... ...: BP Exploration (Alaska) Inc. Field.... ............. ...: Prudhoe Bay Unit - EOA Well. . . . . . . . . . . . . . . . . . . . .: DS-17-07A API number....... ........: 50-029-20596-01 Engineer... ....... .......: B.Barnes NSB.. ..... ....... ........: Nabors 7ES 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. ......: 28.50 ft KB above permanent. ......: N/A Top Drive DF above permanent.......: 65.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).... .....: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).... .....: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 354.66 degrees p>[ (c) 2004 IDEAL ID8_1C_01J '"'------ .:---...::" ~~~\'\\~ (~O~/-Cfll 17-Feb-2004 13:12:31 Page 1 of 5 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.... ...: MD of last survey.... ....: 06-Feb-2004 17-Feb-04 106 7394.00 ft 12969.00 ft . ----- Geomagnetic data ---------------------- Magnetic model......... ..: BGGM version 2003 Magnetic date............: 05-Feb-2004 Magnetic field strength..: 1151.94 HCNT Magnetic dec (+E/W-). ....: 25.53 degrees Magnetic dip.... ..... ....: 80.84 degrees ----- MWD survey Reference Criteria --------- Reference G........... ...: 1002.67 mGal Reference H..............: 1151.94 HCNT Reference Dip............: 80.84 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip..... ....: (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.53 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 25.53 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction RECE'VED "'!)? f)O' fH r~:;--;>~ __ r L JL} '¡~¿;I!;~JJ on &, Gas Cons. CommisalOn J'\\1ooorage SCHLU~BERGER Survey Report 17-Feb-2004 13:12:31 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 (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 7394.00 34.50 16.18 0.00 6705.50 2160.13 2197.61 300.28 2218.03 7.78 0.00 TIP None 2 7475.00 34.50 16.18 81. 00 6772.25 2202.81 2241. 67 313.06 2263.43 7.95 0.00 Window Top 3 7492.00 36.50 16.20 17.00 6786.09 2211.99 2251.15 315.82 2273.20 7.99 11.76 Window Bottom 4 7503.00 36.50 16.20 11.00 6794.94 2218.08 2257.44 317.64 2279.67 8.01 0.00 Mill Rat Hole 5 7600.38 41.19 16.00 97.38 6870.76 2274.91 2316.10 334.57 2340.14 8.22 4.82 DD Inter. Az 6 7696.29 41. 77 15.81 95.91 6942.61 2334.12 2377.20 351. 98 2403.11 8.42 0.62 DD Inter. Az . 7 7791. 49 45.04 15.76 95.20 7011.77 2395.14 2440.14 369.77 2468.00 8.62 3.44 MWD IFR MSA - 8 7886.56 48.43 16.56 95.07 7076.92 2459.53 2506.62 389.05 2536.63 8.82 3.62 MWD IFR MSA - 9 7980.57 52.96 16.53 94.01 7136.45 2527.02 2576.33 409.76 2608.71 9.04 4.82 MWD IFR MSA - 10 8076.29 55.15 16.27 95.72 7192.64 2598.99 2650.67 431. 63 2685.58 9.25 2.30 MWD IFR MSA 11 8173.36 54.46 16.42 97.07 7248.58 2672.70 2726.79 453.96 2764.32 9.45 0.72 MWD IFR MSA - 12 8267.49 53.75 15.79 94.13 7303.77 2743.68 2800.05 475.11 2840.07 9.63 0.93 MWD IFR MSA - 13 8361.68 55.48 16.32 94.19 7358.31 2815.17 2873.84 496.35 2916.39 9.80 1. 89 MWD IFR MSA - 14 8453.50 54.98 15.69 91.82 7410.68 2885.42 2946.34 517.15 2991.38 9.96 0.78 MWD IFR MSA - 15 8548.10 54.29 15.48 94.60 7465.43 2957.48 3020.65 537.87 3068.16 10.10 0.75 MWD IFR MSA 16 8640.55 53.32 15.47 92 .45 7520.02 3027.22 3092.55 557.78 3142.45 10.22 1. 05 MWD IFR MSA 17 8736.72 53.45 16.56 96.17 7577.38 3099.11 3166.74 579.08 3219.25 10.36 0.92 MWD IFR MSA - 18 8830.52 52.72 16.14 93.80 7633.72 3168.79 3238.70 600.19 3293.85 10.50 0.86 MWD IFR MSA - 19 8927.49 53.63 17.63 96.97 7691. 85 3240.64 3312.97 622.74 3370.99 10.65 1. 55 MWD IFR MSA - 20 9021. 90 54.10 17.56 94.41 7747.52 3310.86 3385.66 645.79 3446.70 10.80 0.50 MWD IFR MSA 21 9115.43 53.52 17.15 93.53 7802.74 3380.50 3457.70 668.31 3521.70 10.94 0.71 MWD IFR MSA . - 22 9212.39 53.17 16.85 96.96 7860.63 3452.45 3532.09 691.05 3599.06 11.07 0.44 MWD IFR MSA - 23 9306.74 52.04 17.28 94.35 7917.93 3521.75 3603.75 713.04 3673.61 11.19 1. 25 MWD IFR MSA 24 9398.94 52.64 17.76 92 .20 7974.26 3589.00 3673.35 735.02 3746.16 11.32 0.77 MWD IFR MSA 25 9490.98 52.74 17.93 92.04 8030.05 3656.29 3743.03 757.45 3818.90 11.44 0.18 MWD IFR MSA 26 9586.51 52.95 18.03 95.53 8087.74 3726.21 3815.45 780.95 3894.56 11.57 0.24 MWD IFR MSA 27 9683.04 52.18 18.04 96.53 8146.42 3796.57 3888.33 804.68 3970.73 11.69 0.80 MWD IFR MSA 28 9775.39 52.65 18.41 92 .35 8202.75 3863.65 3957.85 827.57 4043.44 11.81 0.60 MWD IFR MSA - 29 9869.30 51. 84 18.29 93.91 8260.25 3931. 64 4028.32 850.95 4117.21 11. 93 0.87 MWD IFR MSA - 30 9963.26 51. 70 18.42 93.96 8318.39 3999.23 4098.37 874.19 4190.57 12.04 0.18 MWD IFR MSA [(c)2004 IDEAL ID8_1C_01J SCHLill11BERGER Survey Report 17-Feb-2004 13:12:31 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 Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 10058.91 54.10 19.09 95.65 8376.09 4068.86 4170.60 898.72 4266.34 12.16 2.57 MWD IFR MSA 32 10154.75 57.80 18.33 95.84 8429.74 4141.37 4245.80 924.18 4345.22 12.28 3.92 MWD IFR MSA - 33 10250.17 62.44 16.74 95.42 8477.27 4217.58 4324.68 949.07 4427.59 12.38 5.07 MWD IFR MSA - 34 10343.67 64.75 16.75 93.50 8518.84 4295.18 4404.87 973.20 4511.09 12.46 2.47 MWD IFR MSA - 35 10435.80 64.69 16.25 92.13 8558.19 4372.50 4484.74 996.86 4594.20 12.53 0.50 MWD IFR MSA 36 10529.98 66.23 16.92 94.18 8597.30 4451. 98 4566.85 1021.32 4679.66 12.61 1. 76 MWD IFR MSA . - 37 10623.99 66.95 16.56 94.01 8634.65 4531.92 4649.46 1046.16 4765.71 12.68 0.84 MWD IFR MSA 38 10719.92 66.16 16.89 95.93 8672.82 4613.48 4733.75 1071. 49 4853.50 12.75 0.88 MWD IFR MSA - 39 10813.61 65.05 17.23 93.69 8711.52 4692.37 4815.32 1096.52 4938.59 12.83 1.23 MWD IFR MSA - 40 10877 . 42 64.77 17.20 63.81 8738.57 4745.74 4870.52 1113 .62 4996.21 12.88 0.44 DD Interp. Az 41 10905.35 71.41 15.40 27.93 8748.99 4769.81 4895.38 1120.88 5022.06 12.90 24.51 DD Interp. Az 42 10939.88 80.66 15.50 34.53 8757.32 4801.11 4927.64 1129.80 5055.50 12.91 26.79 MWD IFR MSA 43 10972.03 87.84 13.69 32.15 8760.54 4831.16 4958.58 1137.85 5087.45 12.92 23.02 MWD IFR MSA 44 11000.57 94.15 12.81 28.54 8760.04 4858.19 4986.34 1144.39 5115.97 12.93 22.32 MWD IFR MSA 45 11034.92 94.09 5.31 34.35 8757.57 4891.35 5020.15 1149.78 5150.13 12.90 21. 78 MWD IFR MSA 46 11066.12 92.09 358.69 31.20 8755.88 4922.23 5051.26 1150.87 5180.71 12.84 22.13 MWD IFR MSA - 47 11095.23 91.75 351.78 29.11 8754.91 4951.31 5080.24 1148.45 5208.43 12.74 23.75 MWD IFR MSA - 48 11128.63 93.33 343.71 33.40 8753.43 4984.40 5112.82 1141. 38 5238.67 12.58 24.60 MWD IFR MSA 49 11159.97 94.32 336.68 31. 34 8751.33 5014.66 5142.22 1130.79 5265.08 12.40 22.60 MWD IFR MSA 50 11188.47 92.88 330.77 28.50 8749.54 5041.22 5167.71 1118.20 5287.31 12.21 21.30 MWD IFR MSA 51 11223.47 92.13 321. 59 35.00 8748.01 5071. 92 5196.73 1098.76 5311.62 11.94 26.29 MWD IFR MSA . - 52 11255.38 93.40 315.53 31. 91 8746.47 5097.66 5220.61 1077 . 68 5330.68 11.66 19.38 MWD IFR MSA - 53 11285.76 90.45 308.97 30.38 8745.45 5120.06 5241.01 1055.22 5346.18 11.38 23.66 MWD IFR MSA 54 11319.80 89.42 299.73 34.04 8745.49 5141.78 5260.20 1027.14 5359.54 11.05 27.31 MWD IFR MSA 55 11351.79 91. 78 292.01 31.99 8745.15 5158.34 5274.14 998.38 5367.81 10.72 25.23 MWD IFR MSA 56 11380.20 94.43 281. 40 28.41 8743.61 5168.97 5282.29 971. 26 5370.84 10.42 38.44 MWD IFR MSA - 57 11410.16 94.71 276.59 29.96 8741.22 5176.36 5286.96 941.77 5370.18 10.10 16.03 MWD IFR MSA 58 11441.73 93.33 276.54 31.57 8739.00 5182.86 5290.56 910.48 5368.33 9.76 4.37 MWD IFR MSA 59 11471.95 90.65 276.39 30.22 8737.96 5189.04 5293.96 880.47 5366.68 9.44 8.88 MWD IFR MSA - 60 11501.83 88.90 276.23 29.88 8738.07 5195.07 5297.24 850.78 5365.13 9.12 5.88 MWD IFR MSA - [(c)2004 IDEAL ID8_1C_01l SCHL~BERGER Survey Report 17-Feb-2004 13:12:31 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 Carr (ft) (deg) (deg) (ft) (ft) ( ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 11533.46 88.15 274.46 31. 63 8738.89 5200.94 5300.19 819.30 5363.14 8.79 6.08 MWD IFR MSA - 62 11564.36 88.49 274.51 30.90 8739.79 5206.21 5302.60 788.50 5360.91 8.46 1.11 MWD IFR MSA - 63 11597.01 88.83 276.64 32.65 8740.56 5212.39 5305.77 756.02 5359.37 8.11 6.60 MWD IFR MSA - 64 11629.19 88.01 274.07 32.18 8741.45 5218.36 5308.78 724.00 5357.92 7.77 8.38 MWD IFR MSA - 65 11660.75 88.46 275.48 31.56 8742.42 5223.90 5311. 40 692.56 5356.36 7.43 4.69 MWD IFR MSA 66 11692.90 88.66 274.56 32.15 8743.22 5229.68 5314.21 660.54 5355.11 7.09 2.93 MWD IFR MSA . - 67 11725.24 88.49 274.92 32.34 8744.03 5235.33 5316.89 628.33 5353.88 6.74 1. 23 MWD IFR MSA 68 11752.82 87.77 273.79 27.58 8744.93 5239.98 5318.98 600.84 5352.81 6.44 4.86 MWD IFR MSA - 69 11784.38 87.91 271.66 31. 56 8746.12 5244.40 5320.48 569.34 5350.85 6.11 6.76 MWD IFR MSA 70 11816.28 88.35 273.14 31.90 8747.16 5248.69 5321.81 537.49 5348.89 5.77 4.84 MWD IFR MSA 71 11845.17 88.53 272.30 28.89 8747.95 5252.74 5323.18 508.64 5347.43 5.46 2.97 MWD IFR MSA 72 11881. 91 88.90 274.11 36.74 8748.77 5258.20 5325.24 471.97 5346.11 5.06 5.03 MWD IFR MSA 73 11913.93 88.66 273.41 32.02 8749.45 5263.26 5327.34 440.02 5345.48 4.72 2.31 MWD IFR MSA 74 11941.69 88.15 272.19 27.76 8750.22 5267.19 5328.69 412.31 5344.62 4.42 4.76 MWD IFR MSA - 75 11976.81 88.04 269.68 35.12 8751.39 5271. 03 5329.26 377.22 5342.60 4.05 7.15 MWD IFR MSA 76 12008.14 88.22 269.91 31.33 8752.42 5273.83 5329.15 345.90 5340.37 3.71 0.93 MWD IFR MSA - 77 12037.78 88.63 270.22 29.64 8753.23 5276.62 5329.19 316.27 5338.56 3.40 1. 73 MWD IFR MSA - 78 12071. 09 89.11 271. 93 33.31 8753.89 5280.34 5329.81 282.98 5337.32 3.04 5.33 MWD IFR MSA 79 12103.05 89.69 271.15 31. 96 8754.22 5284.17 5330.67 251. 03 5336.58 2.70 3.04 MWD IFR MSA 80 12130.77 90.75 270.71 27.72 8754.12 5287.20 5331.12 223.32 5335.80 2.40 4.14 MWD IFR MSA 81 12167.07 90.99 271.22 36.30 8753.56 5291.19 5331.73 187.02 5335.01 2.01 1. 55 MWD IFR MSA . - 82 12196.85 90.96 271.33 29.78 8753.06 5294.62 5332.39 157.26 5334.71 1.69 0.38 MWD IFR MSA - 83 12224.70 91. 23 271.40 27.85 8752.53 5297.87 5333.06 129.42 5334.63 1.39 1. 00 MWD IFR MSA 84 12259.02 91.03 274.41 34.32 8751.85 5302.79 5334.80 95.16 5335.64 1. 02 8.79 MWD IFR MSA 85 12290.92 90.10 273.90 31. 90 8751.53 5308.05 5337.11 63.34 5337.48 0.68 3.32 MWD IFR MSA - 86 12319.60 90.31 274.42 28.68 8751.43 5312.78 5339.19 34.74 5339.30 0.37 1. 96 MWD IFR MSA - 87 12354.09 90.27 271.92 34.49 8751.26 5317.89 5341.09 0.30 5341. 09 0.00 7.25 MWD IFR MSA - 88 12385.37 90.48 272.46 31. 28 8751.05 5321. 98 5342.29 -30.95 5342.38 359.67 1. 85 MWD IFR MSA - 89 12414 .16 90.86 273.52 28.79 8750.71 5326.16 5343.79 -59.70 5344.13 359.36 3.91 MWD IFR MSA 90 12444.29 90.99 273.40 30.13 8750.23 5330.76 5345.61 -89.77 5346.36 359.04 0.59 MWD IFR MSA [(c)2004 IDEAL ID8_1C_01] SCHLUMBERGER Survey Report 17-Feb-2004 13:12:31 Page 5 of 5 . -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ --..- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Beq 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 Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- =============== ----- ------ -------- ------ ------- ------ -------- -------- ---------------- ------ 91 12475.89 91.03 276.08 31. 60 8749.67 5336.29 5348.22 -121.26 5349.59 358.70 8.48 MWD IFR MSA - 92 12506.96 90.24 275.16 31. 07 8749.33 5342.20 5351.26 -152.18 5353.43 358.37 3.90 MWD IFR MSA 93 12540.43 90.21 273.96 33.47 8749.20 5347.95 5353.92 -185.54 5357.14 358.02 3.59 MWD IFR MSA 94 12571.90 90.55 274.65 31.47 8748.99 5353.23 5356.29 -216.92 5360.68 357.68 2.44 MWD IFR MSA 95 12601. 45 91.82 275.43 29.55 8748.38 5358.55 5358.88 -246.35 5364.54 357.37 5.04 MWD IFR MSA 96 12633.84 92.16 275.41 32.39 8747.25 5364.59 5361. 94 -278.57 5369.17 357.03 1. 05 MWD IFR MSA . 97 12665.63 92 .23 274.69 31. 79 8746.03 5370.32 5364.73 -310.22 5373.70 356.69 2.27 MWD IFR MSA 98 12694.44 92.44 273.47 28.81 8744.86 5375.03 5366.78 -338.93 5377.47 356.39 4.29 MWD IFR MSA - 99 12728.03 92.78 274.41 33.59 8743.33 5380.45 5369.09 -372.41 5381.99 356.03 2.97 MWD IFR MSA - 100 12759.81 92.50 276.01 31. 78 8741.87 5386.26 5371. 97 -404.02 5387.14 355.70 5.11 MWD IFR MSA 101 12789.48 92 .57 276.69 29.67 8740.55 5392.26 5375.25 -433.48 5392.70 355.39 2.30 MWD IFR MSA - 102 12823.05 92.57 274.55 33.57 8739.05 5398.64 5378.53 -466.85 5398.76 355.04 6.37 MWD IFR MSA - 103 12853.87 92.68 273.92 30.82 8737.64 5403.76 5380.81 -497.55 5403.76 354.72 2.07 MWD IFR MSA - 104 12884.16 92.95 275.73 30.29 8736.15 5409.10 5383.35 -527.70 5409.15 354.40 6.03 MWD IFR MSA - 105 12914.32 93.26 275.77 30.16 8734.51 5414.89 5386.37 -557.66 5415.16 354.09 1. 04 MWD IFR MSA 106 12969.00 94.02 275.77 54.68 8731.04 5425.41 5391.86 -611.96 5426.47 353.52 1.39 Projected to TD [(C)2004 IDEAL ID8_1C_01J . . . FRANK H. MURKOWSKI, GOVERNOR AI/ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 17-07A BP Exploration (Alaska), Inc. Pennit No: 204-011 Surface Location: 2242' SNL, 930' EWL, Sec. 22, TlON, R15E, UM Bottomho1e Location: 3057' NSL, 445' EWL, Sec. 15, T10N, R15E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sarah Palin Chair BY ORDER OF: THE COMMISSION DATED thisj]: day of January 2004 ( cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. W6A- 'l"~/w~ _ STATE OF ALASKA a ALASKA dPAND GAS CONSERVATION COMWISSION PERMIT TO DRILL 20 MC 25 005 / 1a. Type of work o Drill III Redrill rb. Current Well Class o Exploratory III Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: IBI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 17-07A ./ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12920 TVD 8753 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028331 2242' SNL, 930' EWL, SEC. 22, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: February 1, 2004 r- 3161' NSL, 1785' EWL, SEC. 15, T10N, R15E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3057' NSL. 445' EWL, SEC. 15, T10N, R15E, UM 2560 19,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: X-709176 y-5928401 Zone-ASP4 (Height above GL): 64.5 feet 17-11 is 667' away at 12835' MD 16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035) / Kickoff Depth 7450 ft Maximum Hole Angle 940 Max. Downhole Pressure: 3200 psig. Max. Surface Pressure: 2350 psig 18. Casing PrÖgram Specifications Setting Deþth QüâritltýiJfCel1iênt Size Top Bottom (c.f. or sacks) Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD (includina stace data) 8-1/2" 7" 26# L-80 BTC-M 3584' 7300' 6630' 10884' 8742' 169 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT 2186' 10734' 8680' 12920' 8753' Uncemented Slotted Liner 19: PRI;SENTWI;Ll..qC)r')IDITION Sl.JMMARY(Tº~, (X)mpløtêq,"·för~edr'iII,ð.ND. Re..~ntiYC)~r~tiQ"$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10790 9515 9880 9880 8664 10632 (: ::./,;,: II:·,·}, ''Co .:..:.:' /:, .'?/ :': 1ß./rl: > if, (,+ «( !~,~ '( StrudlJr~1 Conductor 80' 20" 232 sx AS II 80' 80' ~",.¡:~~= 2687' 13-3/8" 3000 sx Fondu, 850 sx PF II 2687' 2687' 9962' 9-5/8" 500 sx Class 'G' 9962' 8739' ProdlJr.tion Liner 1133' 7" 420 sx Class 'G' 9657' - 10790' 8462' - 9515' Perforation Depth MD (ft): 10026' - 10267' IPerfOration Depth TVD (ft): 8797' - 9022' 20. Attachments IBI Filing Fee o BOP Sketch IBI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Bill Isaacson Title Senior Drilling Engineer l Hl. 1 ~- Dateoth I. Prepared By Name/Number: Sianature -' Phone 564-5521 Terrie Hubble. 564-4628 Commission Use Only Permit To Drill I API Number: I Permit Approval n ..J See cover letter for Number: Zo y- all 50- 029-20596-01-00 Date: .....-,.;.;;.. .-- r"'- Conditions of Approval: Samples Required DYes ÆrNo Mud Log Required L1'Ÿ es ~ NO Hydrogen Sulfide Measures g¡ Yes DNo Directional Survey Requir~N~Y8s2M.tJ0 Other: Test 1> 0 p~ to 3'5 DO )?<{ p,.?.rV UJ AAc. 7..'5 I o~s LIo..) (I).J a..l t€¥~e BoPE ~~' ~ L'Uf-~~aœ Ußrc6~f~ômmission Original Signed By 0 r') I GI [~AL Anchorage (-- Date / /;4/0 Lf ¡\ BY ORDER OF Aooroved Bv: Sarah Palin COMMISSIONER THE COMMISSION Form 10-401 Revised 3/2003 Súbm(t In ¡Duplicate Well 17-07A e e Planned Well Summary Horizontal Sidetrack Sag River I AFE Number: I PBD 4P2184 I I API Number: I 50-029-20596-01 Surface Location Offsets TRS 2,242' FNL / 930' FWL 10 N, 15 E, 22 /' Offsets TRS 2,119' FNL /1,785' FWL 10 N, 15 E, 15 /' Offsets TRS ../" 2,222' FNL / 445' FWL 10 N, 15 E, 15 I Planned TD: 112,920' md /'" Target Location Bottom Location Northin 5,933,683.94 I Planned KOP: 17,450' md I Rig: I Nabors 7ES I / Maximum Hole Inclination: Proximity Issues: I CBE: 136.50' I RTE: 164.50' Directional Proaram W 09 Exit oint: 7,450' md /6,687' sstvd -400 at 5,900' in the original well bore. -93.50 in the planned 61/8" horizontal section from 11,000' md to 12,400' md. There is one close approach issue with well 03-07. The center-to-center distance is 799' at a depth of 11,744' md. Close approach with this well has been approved with minor risk at 1/200. All other surrounding wells ass ma'or risk criteria. Standard MWD with IIFR / Cassandra. Well 17-11, with center-to-center distance of 667' at 12,835' md. 19,000' to the nearest PBU ro e line. Loaaina Proaram Hole Section: Required Sensors / Service 8 ?h" intermediate: Real time MWD Dir/GRlPWD throughout the interval. 61/8" production: Real time MWD Dir/GRlRes/ABI throughout the interval. Two sample catchers will be required at company man call out. Cased Hole: None planned Open Hole:. None planned 17-07 A Sidetrack Page 1 e e Mud Proaram Set Whi stock / mill window in 9 5/8" casin PV YP Tau 0 API FL 15 - 25 40+ 5 - 9 4 - 6 Drillin 8 %" interval window to -200' above THRZ PV YP Tau 0 API FL H 12-15 25-28 3-7 4-6 9.0 Drillin 8 %" interval from -10,000' to BHRZ PV YP Tau 0 API FL H 12-15 25-28 3-7 4-6 9.0 Drillin 8 %" interval from BHRZ to section TD PV YP Tau 0 API FL H 12-15 25-28 3-7 4-6 9.0 ~ H 10-12 9.0-9.5 Casina I Tubina Proaram Hole Casing/Tubing Weight Grade Connection Length Top Bottom Size Size md / tvd md I tvd 8%" 7" 26.0# L-80 BTC-M 3,584' 7,300/6,630 10,884/8,742 61/8" 4 %" slotted 12.6# L-80 IBT 2,186' 10,734/8,680 12,920/8,753 TubinQ 3%" 9.3# L-80 IBT-M 10,734' Surface 10,734/8,680 Slurry Design Basis: Fluids Sequence / Volume: 17-07 A Sidetrack Cementina Proaram Page 2 e e roduction liner Slurry Design Basis: Fluids Sequence I Volume: Casina I Formation Intearitv Testina Test Test Point Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500 si surface 12.7 EMW 3,500 si surface 10.0 EMW ,,-/ r" Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blindlshear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. 0.10 psi/ft) EMW FIT. *" 0.10 psi/ft) Disposal Annular In"ection: Cuttings Handling: Fluid Handling: No annular in'ection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North 510 e Borou h. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for in·ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 17-07 A Sidetrack Page 3 e e Geoloaic Proanosis /' Formation MD TVDbkb TVDss Comments WS1 7,247 6,585 6,520 WS2 CM3 7,560 6,840 6,775 CM2 8,387 7,370 7,305 CM1 9,633 8,120 8,055 THRZ 10,261 8,4 70 8,405 BHRZ 10,674 8,651 8,586 LCU 10,713 8,668 8,603 TJG TJF THE TJD TJC TJB TJA TSGR 10,884 8,743 8,678 Est. Dore Dressure 3,200 Dsi (7.1 DDO EMW) TSHA N/R TSHB N/R TSHC N/R TSAD N/R TZ4B N/R TCGL N/R BCGL N/R TZ2B N/R TZ2A N/R TZ1B N/R TZ1A N/R BSAD N/R iI, r gr TD Criteria TD Criteria: Planned TD of the well is based upon stopping 150 feet short of intersecting the western-most fault. The X, Y coordinate rovided will be TD. Fault Proanosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 HRZ 10,230' 8,390' 25' DtS +1- 150' Fault #2 N/A TD + 150' <20' +1- 150' 17-07 A Sidetrack Page 4 e -- Qperations Summary Pre-Ria ODerations: 1. RlU and RIH with coil tubing to plug and abandon the well bore above the sand plug-back. Confirm tag at top of sand at -9,880' md. Plug and abandon, with 15.8ppg class 'G' cement. Use adequate cement volume to fill the 7" liner above the sand plug, plus -100 feet of 5 %" X 4 W' tubing tail. The estimated minimum cement volume required is 12bbls. 2. RlU slick-line. Drift the 5 %" tubing to 7,800' md to confirm clear to the required cut depth of 7,600'md. 3. Fluid-pack the 5 %" tubing and 9 5/8" x 5 %" annulus to surface. Test to 3,000 psi. 4. RlU E-line. RIH with the appropriate chemical cutter and cut the 5 %" tubing at -7,600' md. 5. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 6. Test the 9 5/8" pack-off and tubing hanger seals to 5,OOOpsi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. Level the pad as necessary. Ria ODerations: 1. Mil RU Nabors rig 7ES 2. Circulate out diesel freeze protection and displace the w~o seawater. Set BPV with blanking plug. /' 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. RlU. Pull 5%" tubing from the cut at -7,600' MD and above. 5. RlU E-line. M/U 8.5" gauge ring I junk basket. RIH and tag t~g stump. POOH. 6. RIH with HES EZSVon E-line. Set bridge plug at -7,470', and as required to avoid cutting a casing collar while milling window. POOH. RID E-line. // 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. / 9. Displace the well to 9.7ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. / 10. Mill window in 9 5/8" casing at ± 7,450' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. /' 11. Pull up into 9 5/8" casing and conduct an FIT to 12.7ppg EMW. POOH. 12. M/U 8 %" Dir/GRlPWD assembly. RIH, kick off and drill the 8 1/2" intermediate section t~e top of the Sag River, per directional proposal. Circulate well clean, short trip-·to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. / 14. M/U 61/8" Rotary I cleanout assembly. RIH to the landing collar. 15. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test., / 16. Drill out the 7" liner float equipment and cement to tl)e shoe. 17. Displace the well to 8.5ppg Flo-Pro drilling fluid. / 18. Drill out the 7" shoe. DO NOT drill new formation with this assembly. POOH for build assembly. 19. M/U 6 1/8" Dir/GRlRes/ABI build assembly. RIH, drill 20' new formation, pull up into the shoe an)t conduct an FIT to 10.0ppg EMW. Drill ahead to end of high dogleg section. POOH. ' ( 20. M/U steerable assembly, RIH, drill to TD of approximately 12,920' MD in the Sag River, according to/ the directional proposal. Circulate well bore clean, short trip to sþoe. POOH. 21. Run a 4 W', 12.6#, L-80 slotted production liner. POOH. / 22. RlU and run a 3 1/2", 9.2#, L-80 completion, stinging into the 4 1/2" liner tie back sleeve. / 23. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 24. Set a BPV, with blanking plug, if required. 25. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. / 26. Freeze protect the well to -2,200'. Secure the well. 17-07 A Sidetrack Page 5 e e 27. Rig down and move off. Post-Ria ODerations: 1. MIRU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Phase 1: Move In I Ria UP I Test BOPE Planned Phase Time 24 hours Planned Phase Cost $63,641 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 17-07A. However, 17-16 is 59.55' to the South. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters are to be used at all times. ~ The 17-07 well bore is secured with 2 barriers, (the cement I sand back plug and seawater). Prior to pulling the tree, verify a static column of seawater to surface and that no pressure exists. If necessary, shoot a fluid level prior to rig MI !ßU. ~ DS 17 is not designated as an H2S site. Standard Operating Procedures for H2S precautions should, however, be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 17-16 38ppm 03-15AL 1 18ppm 17-11 134ppm The maximum level recorded of H2S on the pad was 134ppm, in 12/2000. / » Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time 48 hours Planned Phase Cost $165,157 17-07 A Sidetrack Page 6 e e Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ The 17-07 well bore is secured with 2 barriers, (the cement I sand back plug and the seawater). Prior to pulling the tree, verify a static column of seawater to surface and that no pressure exists. If necessary, shoot a fluid level prior to rig Mil RU. ~ Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ Note that this wellhead is FMC Gen II. The tubing hanger is a 13 5/8" X 51/2" OCT hanger, with 5 304" RH Acme lifting thread. This is likely a K-Monel hanger. The preferred method of retrieval is by utilizing a spear. Be prepared with appropriate equipment. ~ There is a 5Y2" CAMCO Bal-O SSSV nipple with dual W' control lines. Phase 3: Run WhiD Stock Planned Phase Time 35 hours Planned Phase Cost $202,160 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards ~ A 9 5/8" whip stock will be run and set in the existing intermediate casing. ~ There will be no cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 5: Drill 8%" Intermediate Hole Interval Planned Phase Time 158 hours Planned Phase Cost $923,570 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP 17-07 A Sidetrack Page 7 e e .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards ~ This well bore will exit the original well in the lower WS1, and drill the Colville, the Kingak, into the Sag River formation. Previous DS 17 wells drilled the Kingak with 9.8 to 10.5ppg mud weights. For this well, the HRZ will require a mud weight of 11.2ppg and the Kingak will require 11.5ppg. Maintain mud weight at 11.5ppg, minimally, from above the Kingak to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ There will be a fault crossing during the drilling of this interval. The East-West fault has an estimated throw of -25 feet. The projected depth of the crossing is 10,230' md. The fault is not expected to cause any significant lost circulation problems. ~ There is some uncertainty regarding the depth at which the top Sag River will be encountered, once crossing the fault to the downthrown side. ~ Distinguishing the top of the Sag River has proven to be difficult in some of the nearby wells, due to the LAG deposit just on top of the Kingak. In drilling the 3-34B, all indications were that the top of the Sag River had been reached. After drilling out the intermediate liner shoe, it was discovered that there was yet 39 feet of Kingak shale below the shoe. This required increasing the mud weight to attempt to control sloughing shale. It is recommended to take the necessary time to circulate up samples for confirmation of top Sag River penetration in determining casing point. ~ KICK TOLERANCE: In the worst-case scenario of 9.8ppg pore pressure at the Sag River depth, a fracture gradient of 11.8ppg at the 9 5/8" casing window, and 11.5ppg mud in the hole, the kick tolerance is 81 bbls. Phase 6: Run and Cement 7" Intermediate Liner Planned Phase Time 36 hours Planned Phase Cost $219,028 Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab I surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. 17-07 A Sidetrack Page 8 e e Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 143 hours Planned Phase Cost $752,021 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards > There are two near-by faulted areas, with the potential for intersection, while drilling 17-07A. These are of relatively small throw, -15 feet. Historically, these have not been sources of significant lost circulation. They are deemed a low risk. ~ The horizontal section of the planned 17-07 A well will lie between two North-South trending faults. The heel will be just to the west of the eastern-most fault. The trajectory of the well then turns to the west, and will TD prior to crossing the western-most fault. The uncertainties associated with the position of these faults leads to a higher risk that one of these faults or its associated rubble zone may be penetrated by this sidetrack. Due awareness and preparation will be prudent. Phase 9: Run 4%" Production Liner Planned Phase Time 25 hours Planned Phase Cost $139,513 Reference RP .:. N/A Issues and Potential Hazards > The completion design is to run a 4 W', 12.6#, L-80 slotted liner throughout the production interval. > Differential sticking is possible, particularly if some solid liner is placed within the string. The 8.6ppg Flo-Pro will be -650psi over balanced to the Sag River formation. Minimize the time the pipe is left stationary while running the liner. > Ensure the liner hanger is set prior to POOH. > Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner. 17-07 A Sidetrack Page 9 e . Phase 12: Run 3 %"Completion Planned Phase Time 30 hours Planned Phase Cost $298,885 Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ The completion, as designed, will be to run a 3Y2" production tubing string, stinging into the 4 W' liner tieback sleeve. It will be necessary to cross over to a 4 W' WLEG (0.0.) to bottom out in the tieback sleeve, and avoid the risk of extending into the hanger body. Phase 13: ND/NU/Release Ria Planned Phase Time 12 hours Planned Phase Cost $43,321 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ There is one close proximity surface issue, 17-16. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig away from the well and about the pad. 17-07 A Sidetrack Page 10 I 9 5/8" X 7" Baker H!v!C ¡¡ner hanger, ZXP packer w I Tie Sleeve. ./ PRUDHOE SA Y UNIT WELL: 17-07 A PERMIT No: API No: SO-029-20S98-01 SEC22. T1ON. RiSE, 3377,11' FFl. 3628.4S' FNL SF' .ST THIS NOTICE IN THE DOGHOUSEe 17-07A Rig site Summary of Drilling Hazards ./' Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 134 ppm, December 2000. ./' NORM test all retrieved well head and completion equipment. ./' One well, 3-07, fails to pass major risk criteria. It requires a 1 :200 risk based criteria. The closest neighboring well, at surface, is 17-16. It is approximately 60' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./' Due to sidetracking into the West Sak and drilling the HRZ and Kingak shale, mud weight will be maintained from 11.2ppg through the HRZ to 11.5ppg through the Kingak to section TD. Monitor ECD closely. ./' There is one known fault crossing expected, during the drilling of the 8 1/2" intermediate interval. The fault will likely be crossed within the HRZ. The anticipated throw is -25'. No significant losses are expected, but due attention should be paid to the possibility. ./' There are two near-by faulted areas, once the well has landed horizontally in the Sag River. The planned well trajectory crosses neither of these, but again, due diligence is warranted. The uncertainty of the positions of these two faults, and the associated rubble zones, increases the risk of incurring some lost circulation. The lost circulation decision tree should be followed if lost fluid returns are encountered. ./' Differential sticking may be encountered. Overbalance is approximately 650 psi. Always follow established drilling and connection practices for stuck pipe prevention. ./' Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE OS 17 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL ./ INFORMATION. 17-07A COMPANY DETAIL" Date SURVEY PROGRAM Plan: 17~07A wp09 (l7-07/P!an !7-07A) REFERENCE fNFORMA TION BPAmoc0 Dcpih Fm Depth To Survey/Plan 7450.00 12919.92 Planned; 17..o7A wp09 VJ6 Too! Date: 12/19/2003 Created By: Ken AUen Checked: MWD+IFR+MS Reviewed: Date CAS!NG DETAILS WELL DETAILS Nmœ +N!~S +FJ-W "NorIhing &!%ring L.atiludc Ltmgittlde Slot 17-07 2J58.12 829.13 5928400.6J 70911553 70Q12'27.7(jIN 14!P18'47.912W 07 T ARGBT DETAILS Nmœ TVD +N/-S +E1~W Northing Eæring Shape No, TVD MD Size Name WSI 1 2 10883.65 7" 129!9.9] 4 ]12" 680 Start Dir4/IOO': 7450' MD. 675!.56'TVD FORMA T]ON TOP DET A]LS No. TVDPath MDPath Formation I 6584,50 WS] 2 6839.50 CM3 3 7369.50 CM2 4 81 ]9,50 CM! 5 8469,50 THRZ 6 8650,50 BHRZ 7 8667.50 LCU 8 8742,50 TSGR SECTION DETAILS Se<: MD [ne Azi TVD +N/-S +E/-W DLeg TFace VSe<: Target I 7450,00 34.50 16,65 6751.56 2228.3 ! 309.32 0.00 0,00 2]89.88 2 7912.52 53,00 16,65 7084.22 2533.39 400.59 4,00 0.00 2485,15 3 9949.32 53,00 16.65 8310,00 4091.82 866.79 0,00 0,00 3993.46 4 10224.32 64.00 16,65 8453,47 4316.11 933.89 4,00 0,00 4210.54 5 10883.65 64.00 ]6.65 8742.50 4883,86 I 103,73 0.00 0.00 4760.03 6 10989.02 90,00 ]6.65 8766.00 4981.38 1132.90 ,....-14,68 359.99 4854.4 I 7 11002,82 93.31 16.65 8765,60 4994,59 !!36.85 24.00 0,00 4867.19 8 11363.36 93,32 308,02 8741.87 5317.24 1034,08 19,00 -87.74 5198.00 9 1]400,90 93.32 308,02 8739,69 5340,32 1004.56 0.00 0,00 5223,73 10 !J 575.44 90.00 275,00 8734,50 5403.35 844,49 ]9.00 -95.09 5301.38 ]7-07A T2c 11 11743.82 89,17 264.93 8735,72 5403.25 676.33 6,00 -94.74 5316.92 12 12349,92 89,17 264.93 8744,50 5349,70 72.66 0.00 0.00 53]9.75 13 12919.92 89,17 264,93 8752,75 5299.34 -495.05 0.00 0,00 5322.42 720 " 760 ~ '" '" ë'!. '" ë- I:) .. " .~ :> ë 800 f- : 9949.32' MD. 83]O'TVD 840 End Dir : 10224,32' MD, 8453.47' TVD Total Depth: 12919.92' MD, 8752,75' TVD 880 41/2" 2400 2800 5200 5600 3200 3600 4400 4800 4000 Vertical Section at 354,66° [4oof\!in] COMPANY DETAILS BP Arnow 630 REFERENCE INFORM.\. nON J1.{7. TroeNorth CASING DFT AILS No, TVD MD Name 10883,65 7" 12919.91 41/2" SURVEY PROGRAM Dëpth Fill Depth To Survey/Plan 7450.00 1291<),92 Planned: J7..{17A wp09 VJ6 Plan; 17~07A wp09 (17-07/P!an J7-07A) Too! Date: 12119/2003 Coolited By: Ken Allen Cheeked: Date:_ MWD+lFR+MS Reviewed: Date: Name ¡'N/-S "'E/-W WELL DETAILS Northing Easting Latitude Longitude Slot 5928400.61 70917553 70"12'27.70IN 148~J8'47YJJ2W "' Size 17.{7 2158.12 829J3 7,000 4,500 TARGET DEY AILS +Nl-S ¡EI-W Northing Basting Sl)¡¡pe N~ TVD SECTION DFT A[LS Sec MD Ine Azi TVD +N/-S +F/-W DLeg TFace VSec Target 560 I 7450,00 34,50 16,65 6751.56 2228.31 309.32 0.00 0.00 2189,88 2 79[2,52 53,00 [6.65 7084,22 2533,39 400.59 4,00 0.00 2485,15 3 9949,32 53,00 16,65 8310,00 4091.82 866,79 0,00 0,00 3993.46 4 10224,32 64.00 [6.65 8453.47 4316,11 933,89 4.00 0,00 4210,54 5 10883,65 64,00 16.65 8742.50 4883,86 1103.73 0.00 0.00 4760.03 6 10989,02 90,00 16.65 8766.00 4981.38 1132,90 24,68 359.99 4854.41 7 11 002,82 9331 16.65 8765.60 4994.59 1136,85 24.00 0,00 4867.19 8 11363.36 93,32 308,02 8741.87 5317.24 1034.08 19,00 -87,74 5198,00 9 11400.90 93,32 308.02 8739,69 5340.32 1004.56 0.00 0.00 5223,73 10 11575.44 90,00 275,00 8734.50 5403,35 844.49 19,00 -95,09 5301.38 17-07A T2c 11 11743.82 89,17 264,93 8735,72 5403.25 676.33 6,00 -94.74 5316.92 490 12 12349,92 89,17 264,93 8744.50 5349,70 72.66 0,00 0.00 5319,75 13 12919,92 89,17 264.93 8752,75 5299,34 495.05 0,00 0.00 5322.42 FORMA T[ON TOP DETAILS " No, TVDPath MDPath Fonnation ~ I 6584.50 7246,70 WS[ '" t: 2 6839.50 7559,69 CM3 ~ 4200 3 7369,50 8386.55 CM2 4 8119.50 9632.78 CM! 1::: 5 8469,50 10260.89 THRZ " ~ 6 8650.50 10673,79 BHRZ 7 8667.50 10712,57 LCU Et 8 8742.50 10883.65 TSGR 1;; " en 350 280 210 -700 700 West(-)/East(+) pooft/in] 1400 2100 " U-'LU...,.nON t.'OMf'>\M' ttperry-Sun - Draft Copy. KW A Planning ObP spa"""'y-SLn g..IL....INII ....VIC.. Company: Field: Site: Well: Wellpath: Plan: BP Amoco Prudhoe Bay PB DS 17 17-07 Plan 17-07A 17-07A wp09 Date:. .1~1~~º~ . TÍJne:<09!49:46 Co-ordinate(NE) Reference: Well: 17-07, True North Vertical (TVD) Reference: 64.50' 64.5 Section (VS) Reference: Well (0.00N,O.00E,354.66Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Principal: Yes Date Composed: Version: Tied-to: 12/16/2003 16 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 17 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5926220.53 ft 708405.69 ft Latitude: 70 12 Longitude: 148 19 North Reference: Grid Convergence: 6.476 N 11.993 W True 1.58 deg Well: 17-07 Slot Name: 07 17-07 Well Position: +N/-S 2158.12 ft Northing: 5928400.61 ft Latitude: 70 12 27.701 N +E/-W 829.73 ft Easting : 709175.53 ft Longitude: 148 18 47.912 W Position Uncertainty: 0.00 ft Wellpath: Plan 17-07A +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 17-07 7450.00 ft Mean Sea Level 25.62 deg 80.84 deg Direction deg 354.66 Current Datum: Magnetic Data: Field Strength: Vertical Section: 64.50' 11/13/2003 57589 nT Depth From (TVD) ft 30.50 Height 64.50 ft Casing Points Name 10883.65 8742.50 7.000 12919.91 8752.75 4.500 Formations TVD Formations ft 7246.70 6584.50 WS1 7559.69 6839.50 CM3 8386.55 7369.50 CM2 9632.78 8119.50 CM1 10260.89 8469.50 THRZ 10673.79 8650.50 BHRZ 10712.57 8667.50 LeU 10883.65 8742.50 TSGR Targets Name 17-07A fit -Polygon 1 -Polygon 2 17-07A T2c 17-07A Poly -Polygon 1 8.500 7" 6.125 4 1/2" Lithology Dip Angle dég 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip DinlCtiOn deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Map. Map <- ·µtitudf;.......>' ~Longitude ......". +N/-S +E/~W Northing Easting Deg Min· ..Se.C: Deg ..Min .Sec ft ft ft ft 8734.50 4441.82 2148.42 5932900.00 711200.00 70 13 11.383 N 148 17 45.522 W 8734.50 4441.82 2148.42 5932900.00 711200.00 70 13 11.383 N 148 17 45.522 W 8734.50 4172.45 -44.99 5932570.00 709015.00 70 13 8.737 N 148 18 49.218 W 8734.50 5403.35 844.49 5933825.00 709870.00 70 13 20.842 N 148 18 23.385 W 8742.50 5885.92 1047.94 5934313.00 710060.00 70 13 25.588 N 148 18 17.474 W 8742.50 5885.92 1047.94 5934313.00 710060.00 70 13 25.588 N 148 18 17.474 W !5pE!l""l""Y-!!5Ln D"'L.L.ING ....VIC.. A. IJ,U.UlWI{fU'I ("""'ANY ~perry-Sun - Draft Copy. KW A Planning ObP Company: Field: Site: Well: Wellpath: Targets BP Amoco Prudhoe Bay PB DS 17 17-07 Plan 17-07A Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Well: 17-07, True North 64.50' 64.5 Well (0.00N,O.00E,354.66Azi) Minimum Curvature Db: Oracle Map Map <- Latitude --> <- Longitude -> Name Description TVD +N/-S +EI-W Northing Easting Oeg Min Sec Oeg Min See Oir. ft -Polygon 2 8742.50 4689.35 1446.97 5933128.00 710492.00 70 13 13.819 N 148 18 5.891 W -Polygon 3 8742.50 4810.35 -825.66 5933186.00 708217.00 70 13 15.010 N 148 1911.890 W -Polygon 4 8742.50 5940.28 -697.31 5934319.00 708314.00 70 13 26.123 N 148 19 8.165 W 17-07A TD 8752.75 5299.34 -495.05 5933683.94 708533.93 70 13 19.820 N 148 19 2.289 W 17-07A A 8766.00 4981.38 1132.89 5933411.20 710169.97 70 13 16.692 N 148 18 15.010 W Plan Section Information MD Ind Azim DLS Build .. Tl1m ft deg deg dE¡gI10Oft deg/100ftdE!Q/100ft 7450.00 34.50 16.65 6751.56 2228.31 309.32 0.00 0.00 0.00 0.00 7912.52 53.00 16.65 7064.22 2533.39 400.59 4.00 4.00 0.00 0.00 9949.32 53.00 16.65 8310.00 4091.82 866.79 0.00 0.00 0.00 0.00 10224.32 64.00 16.65 8453.47 4316.11 933.89 4.00 4.00 0.00 0.00 10883.65 64.00 16.65 8742.50 4883.86 1103.73 0.00 0.00 0.00 0.00 10989.02 90.00 16.65 8766.00 4981.38 1132.90 24.68 24.68 0.00 359.99 11002.82 93.31 16.65 8765.60 4994.59 1136.85 24.00 24.00 0.00 0.00 11363.36 93.32 308.02 8741.87 5317.24 1034.08 19.00 0.00 -19.04 -87.74 11400.90 93.32 308.02 8739.69 5340.32 1004.56 0.00 0.00 0.00 0.00 11575.44 90.00 275.00 8734.50 5403.35 844.49 19.00 -1.90 -18.92 -95.09 17-07A T2c 11743.82 89.17 264.93 8735.72 5403.25 676.33 6.00 -0.49 -5.98 -94.74 12349.92 89.17 264.93 8744.50 5349.70 72.66 0.00 0.00 0.00 0.00 12919.92 89.17 264.93 8752.75 5299.34 -495.05 0.00 0.00 0.00 0.00 Survey MD IneI Azim TVD Sys TVD I\f¡apN DLS TFO ft dêg deg ft ft ft deg/1.00ft deg 7246.70 35.00 14.83 6584.50 6520.00 5930524.06 709395.29 2081.57 0.00 0.00 WS1 7450.00 34.50 16.65 6751.56 6687.06 5930636.51 709423.00 2189.88 0.57 116.40 MWD+IFR+MS 7500.00 36.50 16.65 6792.27 6727.77 5930664.55 709430.55 2216.80 4.00 0.00 MWD+IFR+MS 7559.69 38.89 16.65 6839.50 6775.00 5930699.79 709440.03 2250.64 4.00 0.00 CM3 7600.00 40.50 16.65 6870.51 6806.01 5930724.64 709446.73 2274.51 4.00 360.00 MWD+IFR+MS 7700.00 44.50 16.65 6944.23 6879.73 5930789.86 709464.28 2337.14 4.00 0.00 MWD+IFR+MS 7800.00 48.50 16.65 7013.05 6948.55 5930859.89 709483.13 2404.38 4.00 360.00 MWD+IFR+MS 7900.00 52.50 16.65 7076.65 7012.15 5930934.38 709503.19 2475.91 4.00 0.00 MWD+IFR+MS 7912.52 53.00 16.65 7064.22 7019.72 5930944.00 709505.78 2485.15 4.00 360.00 MWD+IFR+MS 8000.00 53.00 16.65 7136.87 7072.37 5931011.46 709523.94 2549.94 0.00 180.00 MWD+IFR+MS 8100.00 53.00 16.65 7197.05 7132.55 5931088.57 709544.70 2623.99 0.00 180.00 MWD+IFR+MS 8200.00 53.00 16.65 7257.23 7192.73 5931165.69 709565.46 2698.04 0.00 180.00 MWD+IFR+MS 8300.00 53.00 16.65 7317.41 7252.91 5931242.80 709586.22 2772.09 0.00 180.00 MWD+IFR+MS 8386.55 53.00 16.65 7369.50 7305.00 5931309.54 709604.19 2836.18 0.00 180.00 CM2 8400.00 53.00 16.65 7377.60 7313.10 5931319.92 709606.98 2646.15 0.00 180.00 MWD+IFR+MS 8500.00 53.00 16.65 7437.78 7373.28 5931397.03 709627.74 2920.20 0.00 180.00 MWD+IFR+MS 8600.00 53.00 16.65 7497.96 7433.46 5931474.14 709648.50 2994.25 0.00 180.00 MWD+IFR+MS 8700.00 53.00 16.65 7558.14 7493.64 5931551.26 709669.26 3068.30 0.00 180.00 MWD+IFR+MS 8800.00 53.00 16.65 7618.32 7553.82 5931628.37 709690.02 3142.36 0.00 180.00 MWD+IFR+MS 8900.00 53.00 16.65 7678.50 7614.00 5931705.49 709710.78 3216.41 0.00 180.00 MWD+IFR+MS 9000.00 53.00 16.65 7738.69 7674.19 5931782.60 709731.54 3290.46 0.00 180.00 MWD+IFR+MS 9100.00 53.00 16.65 7798.87 7734.37 5931859.71 709752.30 3364.51 0.00 180.00 MWD+IFR+MS 9200.00 53.00 16.65 7859.05 7794.55 5931936.83 709773.06 3438.57 0.00 180.00 MWD+IFR+MS 9300.00 53.00 16.65 7919.23 7854.73 5932013.94 709793.82 3512.62 0.00 180.00 MWD+IFR+MS 9400.00 53.00 16.65 7979.41 7914.91 5932091.06 709814.58 3586.67 0.00 180.00 MWD+IFR+MS 9500.00 53.00 16.65 8039.59 7975.09 5932168.17 709835.34 3660.72 0.00 180.00 MWD+IFR+MS 9600.00 53.00 16.65 8099.77 8035.27 5932245.28 709856.10 3734.78 0.00 180.00 MWD+IFR+MS lipIiIr.....y-su-1 ~perry-Sun - Draft Copy · ObP C..ILLINII ....VIC.. "'~~~ANY KW A Planning Company: BP Amoco Date: 12/19/2003 Time: 09:49:46 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 17-07, True North Site: PB DS 17 Vertical (TVD) Reference: 64.50' 64.5 Well: 17-07 Section (VS) Reference: Well (0.00N,O.00E,354.66Azi) Wellpath: Plan 17-07 A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD ft deg deg ft 9632.78 53.00 16.65 8119.50 8055.00 5932270.56 709862.90 3759.05 0.00 180.00 CM1 9700.00 53.00 16.65 8159.96 8095.46 5932322.40 709876.86 3808.83 0.00 180.00 MWD+IFR+MS 9800.00 53.00 16.65 8220.14 8155.64 5932399.51 709897.62 3882.88 0.00 180.00 MWD+IFR+MS 9900.00 53.00 16.65 8280.32 8215.82 5932476.63 709918.38 3956.94 0.00 180.00 MWD+IFR+MS 9949.32 53.00 16.65 8310.00 8245.50 5932514.66 709928.62 3993.46 0.00 180.00 MWD+IFR+MS 10000.00 55.03 16.65 8339.78 8275.28 5932554.25 709939.28 4031.48 4.00 0.00 MWD+IFR+MS 10100.00 59.03 16.65 8394.19 8329.69 5932635.24 709961.08 4109.25 4.00 360.00 MWD+IFR+MS 10200.00 63.03 16.65 8442.62 8378.12 5932719.70 709983.82 4190.36 4.00 0.00 MWD+IFR+MS 10224.32 64.00 16.65 8453.47 8388.97 5932740.71 709989.47 4210.54 4.00 360.00 MWD+IFR+MS 10260.89 64.00 16.65 8469.50 8405.00 5932772.46 709998.02 4241.02 0.00 180.00 THRZ 10300.00 64.00 16.65 8486.64 8422.14 5932806.39 710007.16 4273.61 0.00 180.00 MWD+IFR+MS 10400.00 64.00 16.65 8530.48 8465.98 5932893.18 710030.52 4356.95 0.00 180.00 MWD+IFR+MS 10500.00 64.00 16.65 8574.32 8509.82 5932979.96 710053.88 4440.29 0.00 180.00 MWD+IFR+MS 10600.00 64.00 16.65 8618.15 8553.65 5933066.75 710077.25 4523.63 0.00 180.00 MWD+IFR+MS 10673.79 64.00 16.65 8650.50 8586.00 5933130.78 710094.49 4585.12 0.00 180.00 BHRZ 10700.00 64.00 16.65 8661.99 8597.49 5933153.53 710100.61 4606.97 0.00 180.00 MWD+IFR+MS 10712.57 64.00 16.65 8667.50 8603.00 5933164.44 710103.55 4617.44 0.00 180.00 LeU 10800.00 64.00 16.65 8705.83 8641.33 5933240.32 710123.97 4690.31 0.00 180.00 MWD+IFR+MS 10865.41 64.00 16.65 8734.50 8670.00 5933297.08 710139.26 4744.82 0.00 180.00 17-07A fit 10883.65 64.00 16.65 8742.50 8678.00 5933312.92 710143.52 4760.03 0.00 180.00 17-07A Poly 10900.00 68.03 16.65 8749.14 8684.64 5933327.33 710147.40 4773.87 24.68 359.99 MWD+IFR+MS 10910.20 70.55 16.65 8752.75 8688.25 5933336.55 710149.88 4782.72 24.68 359.99 17-07A TD 10920.00 72.97 16.65 8755.82 8691.32 5933345.53 710152.30 4791.35 24.68 359.99 MWD+IFR+MS 10940.00 77.90 16.65 8760.84 8696.34 5933364.22 710157.33 4809.29 24.68 359.99 MWD+IFR+MS 10960.00 82.84 16.65 8764.19 8699.69 5933383.25 710162.45 4827.57 24.68 359.99 MWD+IFR+MS 10980.00 87.77 16.65 8765.82 8701.32 5933402.49 710167.63 4846.05 24.68 359.99 MWD+IFR+MS 10989.02 90.00 16.65 8766.00 8701.50 5933411.20 710169.97 4854.41 24.68 359.99 MWD+IFR+MS 11000.00 92.63 16.65 8765.75 8701.25 5933421.80 710172.83 4864.59 24.00 0.00 MWD+IFR+MS 11002.82 93.31 16.65 8765.60 8701.10 5933424.51 710173.56 4867.19 24.00 0.00 MWD+IFR+MS 11025.00 93.47 12.43 8764.29 8699.79 5933446.09 710178.52 4888.02 19.00 272.26 MWD+IFR+MS 11050.00 93.62 7.67 8762.74 8698.24 5933470.76 710182.19 4912.07 19.00 272.01 MWD+IFR+MS 11075.00 93.75 2.92 8761.13 8696.63 5933495.65 710183.80 4936.58 19.00 271.72 MWD+IFR+MS 11100.00 93.86 358.16 8759.47 8694.97 5933520.58 710183.35 4961.39 19.00 271.41 MWD+IFR+MS 11125.00 93.93 353.40 8757.78 8693.28 5933545.39 710180.82 4986.32 19.00 271.10 MWD+IFR+MS 11150.00 93.98 348.63 8756.05 8691.55 5933569.90 710176.25 5011.20 19.00 270.77 MWD+IFR+MS 11175.00 94.01 343.87 8754.30 8689.80 5933593.94 710169.66 5035.86 19.00 270.45 MWD+IFR+MS 11200.00 94.00 339.11 8752.56 8688.06 5933617.35 710161.09 5060.14 19.00 270.11 MWD+IFR+MS 11225.00 93.97 334.35 8750.82 8686.32 5933639.97 710150.61 5083.86 19.00 269.78 MWD+IFR+MS 11250.00 93.91 329.59 8749.10 8684.60 5933661.65 710138.29 5106.86 19.00 269.45 MWD+IFR+MS 11275.00 93.83 324.83 8747.41 8682.91 5933682.23 710124.21 5128.99 19.00 269.12 MWD+IFR+MS 11300.00 93.71 320.07 8745.77 8681.27 5933701.57 710108.47 5150.09 19.00 268.80 MWD+IFR+MS 11325.00 93.58 315.31 8744.18 8679.68 5933719.54 710091.18 5170.02 19.00 268.49 MWD+IFR+MS 11350.00 93.41 310.56 8742.65 8678.15 5933736.02 710072.45 5188.64 19.00 268.18 MWD+IFR+MS 11363.36 93.32 308.02 8741.87 8677.37 5933744.18 710061.90 5198.00 19.00 267.89 MWD+IFR+MS 11400.90 93.32 308.02 8739.69 8675.19 5933766.43 710031.75 5223.73 0.00 0.00 MWD+IFR+MS 11425.00 92.90 303.45 8738.39 8673.89 5933779.93 710011.84 5239.54 19.00 264.91 MWD+IFR+MS 11450.00 92.45 298.71 8737.22 8672.72 5933792.22 709990.11 5254.36 19.00 264.66 MWD+IFR+MS 11475.00 91.98 293.98 8736.25 8671.75 5933802.68 709967.43 5267.47 19.00 264.44 MWD+IFR+MS 11500.00 91.50 289.26 8735.49 8670.99 5933811.24 709943.96 5278.80 19.00 264.26 MWD+IFR+MS 11525.00 91.01 284.53 8734.95 8670.45 5933817.84 709919.86 5288.25 19.00 264.12 MWD+IFR+MS 11550.00 90.51 279.81 8734.61 8670.11 5933822.43 709895.30 5295.77 19.00 264.01 MWD+IFR+MS 11575.44 90.00 275.00 8734.50 8670.00 5933825.00 709870.00 5301.38 19.00 263.95 17-07A T2c 11600.00 89.88 273.53 8734.53 8670.03 5933826.15 709845.47 5305.48 6.00 265.26 MWD+IFR+MS !!ipEII'T'y-sun ~perry-sun - Draft Copy e ObP CRILLINII .....VIC.. .-.. IttWDt!KIUN t_AI'ð' KW A Planning Company: BP Amoco Date: 12/1912003 Time: 09:49:46 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 17-07, True North Site: PB DS 17 Vertical (TVD) Reference: 64.50' 64.5 Well: 17-07 Section (VS) Reference: Well (0.00N,0.00E.354.66Azi) WelIpath: Plan 17-07A Survey Calculation Method: Minimum Curvature Db: Oracle MapE VS DLS TFO ft ft (\èg/1(>OO 11650.00 89.63 270.54 8734.74 8670.24 5933826.54 709795.48 5311.89 6.00 265.27 MWD+IFR+MS 11700.00 89.38 267.55 8735.17 8670.67 5933824.33 709745.54 5315.71 6.00 265.28 MWD+IFR+MS 11743.82 89.17 264.93 8735.72 8671.22 5933820.24 709701.91 5316.92 6.00 265.30 MWD+IFR+MS 11800.00 89.17 264.93 8736.54 8672.04 5933813.73 709646.12 5317.18 0.00 0.00 MWD+IFR+MS 11900.00 89.17 264.93 8737.98 8673.48 5933802.14 709546.81 5317.65 0.00 0.00 MWD+IFR+MS 12000.00 89.17 264.93 8739.43 8674.93 5933790.56 709447.50 5318.12 0.00 0.00 MWD+IFR+MS 12100.00 89.17 264.93 8740.88 8676.38 5933778.97 709348.19 5318.58 0.00 0.00 MWD+IFR+MS 12200.00 89.17 264.93 8742.33 8677.83 5933767.38 709248.88 5319.05 0.00 0.00 MWD+IFR+MS 12300.00 89.17 264.93 8743.78 8679.28 5933755.79 709149.57 5319.52 0.00 0.00 MWD+IFR+MS 12349.92 89.17 264.93 8744.50 8680.00 5933750.00 709100.00 5319.75 0.00 0.00 MWD+IFR+MS 12400.00 89.17 264.93 8745.23 8680.73 5933744.20 709050.26 5319.99 0.00 0.00 MWD+IFR+MS 12500.00 89.17 264.93 8746.67 8682.17 5933732.61 708950.95 5320.45 0.00 0.00 MWD+IFR+MS 12600.00 89.17 264.93 8748.12 8683.62 5933721.02 708851.64 5320.92 0.00 0.00 MWD+IFR+MS 12700.00 89.17 264.93 8749.57 8685.07 5933709.43 708752.33 5321.39 0.00 0.00 MWD+IFR+MS 12800.00 89.17 264.93 8751.02 8686.52 5933697.84 708653.02 5321.86 0.00 0.00 MWD+IFR+MS 12900.00 89.17 264.93 8752.47 8687.97 5933686.25 708553.71 5322.32 0.00 0.00 MWD+IFR+MS 12919.92 89.17 264.93 8752.75 8688.25 5933683.94 708533.93 5322.42 0.00 0.00 4 1/2" P055200 DATE DATE 11/25/2003 CHECK NO. 055200 INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT RECEIV 0 JAN 0 8 20 4 Alaska Oil & Gas Cons. Commission Anchorage 11/25/200 PR 111803J PERMIT TO DRILL EES \\]·,0111 e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .. AMOUNT ***~~**$100. 00****** NOTr ..:/.I?;~ 3;f~.~ '. . ..~.'JJ. ~;,.. ... i,. " ......~.... . i '. . ;"¡;;'.I'" ,., ,. lž··:·)~,.,;. '. ·\":·::~:~J~~:~~·..t:ª~\l ,.. . " ....... ....U·.·.(......_H:.:~....~"' ._....~............h.,........ .... '. '~. ........ .,.:...,. t·.,' :;'.';'.. ~..:- BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY; NATIONAL CITY BANK Ashland. Ohio 56·389 412 e TO THE ORDER OF; 1/·055 200"· ':0 I. ¡. 20 :lB ~ 5': 0 ¡. 2 ?B ~ bU. NET H No. P 055200 CONSOLIDATED COMMERCIAL ACCOUNT ¡ . J . e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WBA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new well bore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production should continue to be reported as last two (2) digits a function' of the original API number, stated are between 60-69) above. Pll..OT HOLE In accordance with 20 AAC 25.005(f), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ex ception. (Companv Name) assumes the liability of any protest to tbe spacing exception that may occur. DRY DITCH All dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. Rev: 07110/02 C\jody\templates WELL PERM:IT CI-IËÇi~LlST Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 PTD#: 2040110 Company BP EXPLORATION (ALASKA) INC Initial ClasslType 1 P~rmiUee attached .Y~s 2 .Leas~ .nµmber _appropriate. Yes 3 .U.nlque weltn.arn~.atld o~mb.er .Y.es . . 4 WeUJQcat~d in a defined_pool .Y~s 5 WeJUQcat~d pr9per .dlstance. from driJling unitbound.ary. Yes 6 WeUJQcat~d proper .distance from other wells. .Y~s 7 .S.ufficientacreageayailable in.drilJiog ~njt .Y~s 8 Jf.d~viated. js_ weJlbQre plaUocJuded .Y.es 9 Operator only affected party . .Y~s 10 .Operator bas.appr9prlate.Qond lnJorce . .Y~s 11 P~rmit catl be lss~ed INithQut çonservaJion order .Y~s Appr Date 12 P~rmit c.atl be lss~ed INithQut admioistratÍ\le.appr9vaJ .Y~s RPC 1/12/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocated wlthin area and strata_authorized by. I [ljectioo Ord~r # (putlO# in.c9mrneots).(For. NA 15 .AJI wells withi.n .1 14. ruite .area.of reyiew id.eotlfied (F9r ~efVjc.e well only). . . NA 16 Pre-produ.ced itljector; duratiQnof pre-productionl~ss. than 3 months. (For.servi.ce welt QnJy) NA 17 ACMPFïnding 9f Consi$tetlcy.h.as been i~sued. for.tbis project NA Administration Engineering Appr Date WGA 1/13/2004 Geology Appr RPC Date 1/12/2004 18C.otldu.ctor string.prQvided 19 .S.urfaceca~ing_ protect~ all.known. USDWs 20 .CMT v.ot adequ.ate. to circ.utate. oncood.uctor. 8. surf. C$g 21 .CMT vol. adequ.ate to tie-inJQngstring to.surf C$g 22 .CMT will coyera]l !<oo.w.npro.ductiye bQrizon.s 23 .C.asiog desigtls ad.e!:ua.te f9r C. T. B& permafr.ost 24 .Adequatetan.kage.or re.Serve pit 25 Jf.a.re-drilt has.a. 1.0,403 for abandonment be~o apprQved 26 .Adequate weHbore ~eparatjo.n proposed. . 27 Jf.diverter required, dQes jt meet reguJations. 28 .DriUiog fluid program schematic.& equip Jistadequat~. 29 .BOPEs..d9Jhey meet reg uJa.tio n 30 .BOPE.press ra.tiog appropriate; Jest to (put psig i.n .comments). 31 .C.hokemanifold cQmpJie~ wIAPtRF'-53 (May 84) 32 WQrk will Occ.ur withoutoperatio.nsbutdown. 33 J~ pre~ence. of H2S gas. proQable. 34 Mecha.nlcaLcoodJUOtl9f wells wlthin AOR yerified (Fo(service IN~II onM NA .NA NA NA No .Y~s Yes .Y~s . .Y~s . NA .Y~s No .Y~s .Y~s .Y~s .Y~s .NA No .NA NA NA .NA Well Name: PRUDHOE BAY UNIT 17-07A DEV 11-01L GeoArea 890 Unit o o 35 P~rmit catl be lss~ed INfo. hydrogen sutfide measures. 36 .D.ata.preseoted on. pote.ntial oveJPres.sur~ .zone$. 37 .S~ismic.analysjs Qf sbaJlow gas.z90es. 38 .S~abed .conditioo survey.(if off-sh9re) 39 . CQntact namelphoneJor.weekly progre~s.reports [exploratory .0nlYl Program DEV On/Off Shore On Well bore seg Annular Disposal 11650 . · . e · . . Slotted, Nab.ors 7.ES, 1/02/2004, · . . . Sidetrack. Max MW 11.5.ppg.. Lioer ra.m reçuiremeotwalved.. Test t93500. psi. .MSF' 2350 psi.. e . . . . Geologic Commissioner: . DTS Date: Engineering Commissioner: Public ~ Commissioner V'r Date / /IYjOf/ Date 1/)3/1-