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') Image Project Well History File Cover Page ) XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :J.. O:J.. - 1 to 3 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 1111111111111111111 R,ESCAN DIGITAL DATA vb¡Skettes, No. d.- O Other, No/Type: OVERSIZED (Scannable) 0 Maps: [] Color Items: [] Greyscale Items: D Other Items Scannable by a Large Scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: 0 Logs of various kinds: NOTES: 0 Other:: Scanning Preparation éÀ x 30 = bTJ + ì P Date ID, J.ß( Dlf /5/ m 1111111111111111111 Date IÓ/J-crf V- /5/ vu P I <2 = TOTAL PAGES '7?S (6{,unt doe¡; n.~ttclude cover slleet) ilI.A.... P' Date: ID :J.-,q/ol..!.- /5/ r '. , 111111111111111111 BY: Helen (" ....Maria_) Project Proofing BY: Helen ~ BY: Helen jc'tãTIã) Production Scanning Stage 1 Page Count from Scanned File: 7 c¡ (Count does include cover sheet) Page Count atches Number in Scanning Preparation: ~ YES , Date: II If. Dlf YES BY: Helen NO /5/ Y11f Stage 1 If NO in stage 1 page(s) discrepancies were found: NO BY: Helen Maria Date: /s/ II r I r 1111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc . STATE OF ALASKA ALASKA OIL GAS CONSERVATION COMMISPN WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 02/09/2011 • 202 - 163 310 - 040 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 08/23/2002 50 029 - 21156 - 01 - 00 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 08/30/2002 • PBU S -18A 2314' FNL, 711' FWL, SEC. 35, T12N, R12E, UM 8. KB (ft above MSL): 72,29' 15. Field / Pool(s): Top of Productive Horizon: 4153' FNL, 1359' FWL, SEC. 02, T11 N, R12E, UM GL (ft above MSL): 38.49' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 177' FNL, 1511' FEL, SEC. 10, T11N, R12E, UM 13160' 8951' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 618885 y 5979169 Zone ASP4 15937' 9033' ADL 028257, & 028260 TPI: x 619655 y 5972061 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 616808 y - 5970713 Zone ASP4 N/A 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: 10936' 8353' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 3055' Surface 2686' 17 -1/2" 4265 cu ft Permafrost 9-5/8" 47# L -80 Surface 10936' Surface 8353' 12 -1/4" • • cu ' ass . I cu ass 7" 26# L -80 10764' 11705' 8232' 8867' _ 8 -1/2" 236 cu ft Class 'G' 4-1/2" 12.6# L -80 11540' 15907' 8762' 9034' 6-1/8" Uncemented Slotted Liner 24. Open to production or injection? ❑ Yes 0 - No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, L -80 11544' 11484' / 8725' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' �� U t1 DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 14023' Plug w/ 16 Bbls Cement 13160' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A _ Date of Test: Hours Tested: Production For OIL -BBL: GAS-MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER-BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil _• as or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and labora ►� C 250.071. None MAR (I 4 7011 RBDMS MAR 0 7 201 at,ks oit & Gas Cons. CROWN Form 10-407 Revised 12/2009 CONTINUED ON REVERSE /24. 3 - 7 II Itastiorage Submit Original Only 29. GEOLOGIC MARKERS (List all formations and markencountered): 30. I ATION TESTS NAME MD TVD Well Tested? ❑ Yes IS No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 11706' 8868' None Shublik 11760' 8900' Sadlerochit 11941' 8987' Sag River 12563' 8976' Shublik B 13307' 8949' Shublik C 13651' 8964' Sadlerochit 13842' 8992' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. � Signed: Terrie Hubble OA& Title: Drilling Technologist Date: C * Y `/� ( PBU S - 18A 202 - 163 310 - 040 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Cody Hinchman, 564 -4468 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water- Altemating -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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • Well History Well Date Summary S -18A 3/18/2010 * **WELL FLOWING ON ARRIVAL * ** (pre ctd) ATTEMPT TO SET 4 -1/2" X CATCHER @ 11,460' SLM (heavy asphaltines back on tools). ** *JOB CONTINUED ON 3/19/10 * ** S -18A 3/19/2010 T /I /0= 950/1380/450 Freeze Protect for Wireline work. Pumped 5 bbls neat and 39 bbls 60/40 down flowline and 5 bbls neat down tbg. Final WHP= 1000/1380/450 Wireline has control of well on departure. S -18A 3/19/2010 ** *JOB CONTINUED FROM 3/18/10 * ** (pre -ctd) SET 4 1/2" X- CATCHER @ 11460' SLM/11463' MD. PULLED ST #1, BK -OGLV FROM 11190' SLM/ 11184' MD. PULLED ST #2. RK -LGLV FROM 9815' SLM/ 9813' MD. PULLED ST #3, RK -LGLV FROM 8525' SLM/ 8528' MD. PULLED ST#4, RK -LGLV FROM 7196' SLM/7199' MD. PULLED ST#6, RK -LGLV FROM 3862' SLM/3876' MD. SET RK -DGLV IN ST. #6 @ 3862' SLM/3876' MD. SET RK -DGLV IN ST. #4 @ 7196' SLM/7199' MD. SET RK -DGLV IN ST. #3 @ 8525' SLM/8528' MD. SET RK -DGLV IN ST. #2 @ 9815' SLM/9813' MD. ** *CONTINUED ON 3 -20 -10 WSR * ** S -18A 3/19/2010 Load FLuids,Road to location S -18A 3/20/2010 ** *CONTINUED FROM 3 -19 -10 WSR *"""'(pre ctd) LRS LOADED IA W/ 650 BBLS OF CRUDE. SET ST# 1 BK -DGLV @ 11190' SLM / 11184' MD. LRS MIT -IA TO 3000 PASSED. PULLED 4 1/2" X- CATCHER FROM 11460' SLM/ 11463' MD. ** *WELL LEFT S/I OPER NOTIFIED * ** S -18A 3/20/2010 T /I /0= 1200/1400/500 Assist S -Line MIT -IA PASSED to 3000 psi (CTD Prep) Loaded IA w/ 650 bbls crude. S -Line set DGLV. Pumped 35.6 bbls crude to reach test pressure. Loss of 20 psi 1st 15 min, Loss of 0 psi 2nd 15 min for a total loss of 20 psi in 30 min Bleed IAP down bleed back aprox. 10 bbls Final Whp's= 1500/400/480 S -Line on well on depart. Wing valve shut Swab open ssv open master open casing valves open to gauges S -18A 3/31/2010 MIRU CTU #5. Perform weekly BOP test. MU 3.45" JSN Pump well kiII.RIH for drift run. * * * * ** Continued on 4/1/10 S -18A 4/1/2010 ( Assist CTU / Heat 200 bbls diesel in CH2MHILL Tanker to 86 *. RDMO / Operator notified. S -18A 4/1/2010 CTU # 5 ( Interact Publishing) Job Scope: Drift/P&A/WS Drift * * * ** Continued from 3/31/10 * * * ** RIH w/3.45" JSN for drift run. No tags or overpulls stopped at 15100' . POOH. MU /RIH w/ 2.25" BDN. Kill well with 275 bbl KCL. Cap with 120 bbl diesel. Pull heavy 38 -40k@ 14000'. Pull to 10000'. Slick up diesel. * * ** Job continued on 4/2/10 * * * * ** S -18A 4/2/2010 CTU #5 ( Interact Publishing)*"""' ** Continued from 4/1/10 * * * * ** Slick up diesel Got all fluids ready. Kill well w /safelube KCL and 120 bbls diesel w/ 5% 776. Get weight cks. Fill coil with KCL. Repeat weight checks. Cool sump w/ 202 bbl KCL @ 0.5 -1 bpm. Lay in 16 bbls cement from 14700'- 14204'. Jet/circ 20 bbl bio pill from 13300'. POOH keeping hole full with diesel. Wait on cement. MU 3.62" whipstock drift RIH to TOC. * ** Job Continued on 4/3/10 * ** S -18A 4/3/2010 CTU #5 Drift and tag * * ** Continued from 4/2/10 * * ** RIH with WS drift to TOC. Tagged at 11990' set down 3-4k retagged to confirm POOH. MU /RIH w/ jars and 3.48" JSN for tag. Find weight bobble /light tag © 11991 -5'. Get light cement tag © 14013'. Work/jet 10' into contaminated cement top to final tag of 14023'. Jet across area of interest around 11990'. Continue to have obstruction/bobble. POOH. Mu 3.79" mill RIH tag at 11987' * * *** Continued on 4/4/10 * * * ** S -18A 4/4/2010 CTU #5 * * *** Continued from 4/3/10'"'' * * ** Tagged at 11987 PUH retag dry seat 4k down PUH displace meth water from coil before milling.Stalled at 11984' had 3 more stalls seeing very little weight on bit never made any footage. POOH Decision to rig down. RDMO. Job incomplete. Note: Tubing restriction at 11987' CTM S -18A 4/7/2010 * **WELL S/I ON ARRIVAL * ** RAN PDS 40 ARM CALIPER. TOOL HUNG UP IN VARIOUS SPOTS MAKING DATA HARD TO READ RAN PDS 24 ARM CALIPER. GOT GOOD DATA ***WELL LEFT S/1 ON DEPARTURE. PAD-OP NOTIFIED OF STATUS * ** S -18A 4/13/2010 T /I /O = 300/0/500 SET 4" CIW "H" TWC #278 THRU TREE @ 102" USING 1 -2' EXT. TORQUED ALL HORIZONTAL VALVE FLANGE NUTS TO API SPEC (NO MOVEMENT). PRESSURE TESTED TREE TO 500 PSI LOW, 5000 PSI HIGH FOR 5 MINUTES, TEST GOOD. PULLED 4" CIW "H" TWC. PRE NORDIC 2. Print Date: 3/4/2011 Page 1 of 2 lA•'!'f•in AIIA • Well Date Summary • • S -18A 6/3/2010 MIRU CTU #9 w/ HS90 0.134" wall, 1.75" coil. Job objective: Drift through tight spot w/ 3.4" dummy mill for W /S. MU BOT dummy drift w/ 3.4" non -bit. Fluid pack well with KCL w/ safelube. RIH w/ drift to target depth of 13300'. No problems © previous tight spot. POOH. Freeze protect well bore to 2500' w/ water /meth. * * ** Job Complete * * * * ** S -18A 9/23/2010 T /I /0 = SSV/210/340. Temp = SI. IA & OA FL's (Pre Fullbore). AL is SI © casing valve, ALP @ 40 psi. IA FL @ 366' (20 bbls). OA FL @ 102' (6 bbls). SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. S -18A 9/25/2010 T /I/O= 0/200/0 Temp =Sl MIT IA Passed to 3000 psi/ MIT OA Passed to 2000 psi (CTD Prep) IA pressured up to 3000 psi with 33 bbls crude. IA lost 130 psi in first 15 minutes and 30 psi in second 15 minutes. For a total of 160 psi in 30 minutes. Bled back —10 bbls. MIT OA pressured up to 2000 psi with 7.8 bbls crude. First test - OA lost 60 psi in first 15 minutes and 60 psi in second 15 minutes. For a total of 120 psi in 30 minutes. Second test - OA lost 0 psi in 30 minutes. Bled back —5 bbls. F W H P's= 0/340/80 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open, AL closed- Well SI S -18A 10/10/2010 T /I /0 =SSV /250/300, Temp =SI. PPPOT-T (PASS), pre CTD. PPPOT -T: Stung into test port, unable to bleed (external check installed over internal check). Bled pressure through SBS. Functioned LDS (standard), all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Removed internal check, re- installed Alemite fitting. PT void to 5000 psi, no leaks. Bled to 0 psi. S -18A 1/29/2011 T /I/0= SSV/260/290. Temp =Sl. Bleed IA/OA to 0 psi (Pre -CTD). AL SI @ casing valve & skid, ALP= 260 psi. Initial IA FL 340' (18 bbls), OA FL @ 30' (2 bbls). Bled IA & ALP from 260 psi to 0+ psi in 3.25 hrs to bleed trailer, (all gas). During IA bleed the ALP tracked down with the casing valve closed and the OAP decreased 10 psi. Bled OAP from 280 psi to 5 psi in 3 hrs, gas /fluid (bled 13 gallons). Monitor for 30 mins, IAP increased 3 psi, OAP increased 15 psi. Final WHPs= SSV/3 /20. Called grease crew to service AL casing valve. Job incomplete. SV, WV, SSV= Closed. MV =Open. IA, OA =OTG. S -18A 1/30/2011 T /I /0= 110/10/70. Temp =Sl. TBG FL (Pre -CTD). ALP =10 psi open © casing valve. TBG FL @ 606' ( <10 BBLS). IAP increased 7 psi to 10 psi, OAP increased 50 psi to 70 psi. SV, WV, SSV =C. MV =0. IA, OA =OTG. NOVP. S -18A 2/1/2011 T /I /0= 30/0/100; Barriers tested to 300 & 3500 psi for 5 min. (passed) (SV charted); Lubricator tested to 300 & 3500 psi for 5 min. (passed); Set 4- 1/16" CIW "H" TWC #257 thru tree for Nordic 2 pre -CTD; 1 -1' ext. used, tagged @ 114"; Remove Lubricator, install pulling tool and retest against SV (passed); Bleed to 0 psi and torqued tree to API specs. using powerhead #2 & ratchet head #2 (calibrated on 2 -1 -11) * * *NO MOVEMENT on any studs** *; Pressure test tree to 300 & 5000 psi for 5 min. (passed & CHARTED); Pulled TWC and RDMO; Install tree cap w/ new 0 -ring & PT to 500 psi for 5 min. (passed) S -18A 2/3/2011 T /I /0= 80/55/200. Temp =Sl. Bleed IA/OA to 0 psi. (pre -CTD). A/L SI @ casing valve. ALP =50 psi. Initial T /1/0 FLs Tbg =550', IA =330', OA =50'. Bleed IAP & OAP to 0 psi in 2 hrs. Held open bleed for an additional 3.5 hrs (all gas returns). Monitored for 30 min. IAP increased to 2 psi and OAP increased to 6 psi. Job complete. FWHPs= SSV /2/6. SV, WV, SSV =C. MV =0. IA, OA =OTG. NOVP. S -18A 2/4/2011 T /1/0 =SSV /20/120. Temp =Sl. WHP's post bleed (pre -CTD). IAP increased 18 psi to 20 psi, OAP increased 114 psi to 120 psi. SV, WV, SSV, MV =C. IA, OA =OTG. NOVP. S -18A 2/5/2011 T /I /0= TWC/25 /150. Temp =Sl. WHP's post -bleed (pre -CTD). AL disconnected. IAP increased 5 psi to 25 psi, OAP increased 25 psi to 150 psi. TWC in TBG. SV, WV, MV =C. SSV =0. IA, OA =OTG. NOVP. S -18A 2/5/2011 T /I /0= 120/0/120 Barriers tested to 300 & 3500 p.s.i for 5 min.(passed) Removed tree cap attached lubricator and 4- 1/16" CIW "H" TWC # 286 on tree.Pressure tested lubricator 300 & 3500 psi for 5 min. (passed) ,Set TWC © 114" with 1' ext. Removed lubricator installed new o -ring on tree cap, attached to tree, shell tested against TWC at 300, 3500, & 5000 psi individually for 5 min. (passed & charted - see TRP folder) Pre- Nordic 2...no problems. S -18A 2/6/2011 T /I /0 =SSV /40/170. Temp =Sl. Bleed OAP to 0 psi. (pre -rig). No Well house. Flowline and A/L disconnected. Initial IA/OA FLs= 330'/50'. Bled IAP & OAP to 0 psi in 2 hrs, held open bleed for an additional 4 hrs (all gas returns). Monitored for 30 min. IAP remained at 0 psi and OAP increased to 2 psi. No change in FLs during bleed. Job complete. Final WHPs= SSV /0/2. SV, WV, SSV =C. M =0. IA, OA =OTG. NOVP. Print Date: 3/4/2011 Page 2 of 2 9!1••)•)•18 A11A • . • North rica ALASKA BP Page t OpitatiOrt, S ummary Report o- Common Well Name: S-18 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/6/2011 End Date: X3- 00V57 -C (2,205,316.00 USD) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/27/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292115600 Active Datum: 34:18 7/26/1985 00:00 @75.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/6/2011 02:00 - 08:00 6.00 MOB P PRE PREP RIG TO MOVE TO S -PAD 08:00 - 20:30 12.50 MOB P PRE MOVE RIG TO S -PAD 2/7/2011 03:00 - 03:30 0.50 RIGU P PRE ACCEPT NORDIC 2 RIG AT 03:00. BACK OVER WELL AND SET RIG DOWN. 03:30 - 04:30 1.00 RIGU P PRE 1 N/D TREE CAP. 04:30 - 07:30 3.00 RIGU P PRE rN /U BOPS 07:30 - 10:30 3.00 i RIGU P PRE START SHELL TEST OF BOPS DOWN TO TVNC. CONDUCT RIG EVAC DRILL AND AAR. 10:30 - 18:00 7.50 BOPSUR P PRE BOP TEST. WITNESS WAIVED BY AOGCC OFFICIAL ,CHUCK 21 TEST ALL RAMS, VALVES, TIW (,/" VALVE. 18:00 - 19:00 1.00 BOPSUR P PRE PU INJECTOR TO TEST PACK OFF AND INNER L ' REEL VALVE TO COMPLETE BOP TEST 19:00 - 19:45 0.75 RIGU P WEXIT I BOP TEST COMPLETED REVERSE CIRCULATE SLACK -- 19:45 - 22:00 2.25 RIGU P PRE I DID NOT HEAR MUCH MOVEMENT AFTER 3 REVERSE CIRC'S PU INJECTOR AND CHECK FOR WIRE 20:00 STILL HAVE WIRE AT END OF COIL 20:30 SLACK PUMPED, CUT COIL 21:15 CUT 228', MU TEMP CTC AND PUMP WIRE FORWARD ' 21:50 TEST WIRE, GOOD MEG AND CONTINUITY TESTS 22:00 - 23:00 f 1.00 RIGU P PRE I MU BTT INTERNAL CONNECTOR AND PT BEFORE HEADING UP BHI UQC 23:00 - 23:15 0.25 RIGU P PRE PULL & PRESSURE TEST BTT CTC GOOD PT 23:15 - 00 :00 0.75 RIGU P PRE MU BHI UQC 2/8/2011 00:00 - 00:30 0.50 RIGU P l PRE RIG EVACUATION DRILL 00:30 - 01:00 0.50 RIGU P PRE BLOW BACK REEL WITH AIR BECAUSE WE WILL NEED BOTH PUMPS TO KILL WELL AND WON'T BE ABLE TO CIRCULATE THE COIL 01:00 - 04:10 3.17 RIGU P PRE 1PJSM TO PULL TWC 01:30 BRING VALVE CREW LUBRICATOR TO RIG FLOOR AND RU HOSES 02:25 PRESSURE TEST LUBRICATOR 02:45 RETRIEVE TWC 03:20 TWC PULLED, PULL ABOVE SSV 03:30 PT MASTER VALVE, GOOD PT CLOSE SSV AND BLEED OFF 03:45 GOOD LEAK TIGHT TEST, RD VC 1 LUBRICATOR 04:10 05:50 1.67 RIGU P PRE PJSM TO BH KILL WELL 04:30 PT NIGHT CAP 1 04:40 GOOD PT, BH KILL WELL W/ 10 BBLS NEAT METH, 290 BBLS 2% KCL FOLLOWED BY POWER -VIS 4.5 BPM © 450 PSI AND INCREASED TO 850 PSI AT THE END OF THE 290 KCL Printed 3/4/2011 10:37:47AM l I v7 BP; k ' S Oration Summary Report Common Well Name: S -18 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/6/2011 End Date: X3- 00V57 -C (2,205,316.00 USD) Project: Prudhoe Bay Site: PB S Pad — — Rig Name /No.: NORDIC 2 Spud Date/Time: 7/27/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292115600 Active Datum: 34 : 18 7/26/1985 00:00 @75.29ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:50 - 06:30 0.67 RIGU T P PRE 290 BBLS OF KCL AWAY AND PRESSURE SLOWLY RISING, SHUT DOWN PUMP AND SEE IF WHP DROPS WHP DROPPED DOWN TO 50 PSI IN 3 MINUTES, BACK ON LINE DISPLACING WELL TO POWER -VIS 06:30 - 07:15 0.75 RIGU P PRE 160 BBLS AWAY WHP /IA/OA= 1165/28/129 PSI 4.5 BPM 06 :351220 PSI 195 BBLS AWAY SHUT DOWN PUMP AND MONITOR WELL 07:15 - 08:15 1.00 WHIP P WEXIT GREW CHANGE AND MONITOR WELL. INSTALL CHECK VALVES IN UQC AND PRESSURE TEST. 08:15 09:15 1.00 WHIP P WEXIT DISPLACE KCL FROM THE CT WITH MUD. 09:15 13:15 4.00 WHIP P WEXIT CIRCACROSS TOP OF WELL. OBSERVE THE FOLLOWING CUMULATIVE LOSSES: 09 :15 0 BBLS 09 :25 -13 09:30 - 20 BBLS 09:40 BBLS - . 09:50 -37 BBLS C 10 :00 -46 BBLS 10:10 -55 BBLS - 10:20 -61 BBLS LOSSES ARE AROUND 50 -60 BBLS/HR. DISCUSS PLAN FORWARD WITH ADE. FILL WELL EVERY 30 MIN WHILE WAIT ON ORDERS. CALL OUT 2 LOADS OF 2# BIOZAN. 10:45 FILL WELL WITH 8.6 BBLS 12:15 - 8.7 BBLS 13:15 - 6.6 BBLS 13:15 - 13:30 0.25 WHIP P WEXIT PJSM FOR P/U WHIPSTOCK. WELL CONTROL AND OVERHEAD LOADS WERE DISCUSSED. 5 13:30 - 14:30 1.00 WHIP P WEXIT M/U BHA #1 - WHIPSTOCK WITH 2 -3/8" W r W COILTRAK. — — � � BHA OAL = 70.04 FT_ 14 :30 - 18:00 3.50 WHIP P WEXIT RIH W/ BHA #1 PUMPING THRU EDC. 0.3 BPM / 700 PSI / 0 RETURNS. _ 18:00 - 19:45 1.75 WHIP P WEXIT LOG GR TIE -IN FROM 12,460 FT- 12,660 FT. MAKE -33.5 FT CORRENCTION. 19:45 - 20:15 0.50 WHIP P WEXIT CONTINUE RIH W/ WHIPSTOCK FOLLOWING TIE -IN. LOG CCL ACROSS WHIPSTOCK SETTING DEPTH. 20:15 - 20:45 0.50 WHIP P WEXIT JPUH TO 13,100 FT. EVALUATE CCL LOG ACROSS WHIPSTOCK SETTING DEPTH. CCL SHOWS COLLARS AT 13,141 FT AND 13,180 FT. DECIDE TO SET TOW AT 13,160 FT BASED ON i I CCL WHICH PUTS ANCHORS AT 13,173 FT.. 20:45 - 21:00 0.25 WHIP P WEXIT RIH TO SETTING DEPTH AND ORIENT WS TO 180 TFO SHUT DOWN PUMP AND CLOSE EDC. PRESSURE UP ON COIL TO 2400 PSI TO SET WHIPSTOCK. SET 5K# DOWN. TOW AT 13,160 FT ORIENTED LOW SIDE. I P/U CLEAN OFF WHIPSTOCK. Printed 3/4/2011 10:37:47AM Sri 1- ALASKA - BP y r r Y 75' Operation Summary R*port Common Well Name: S -18 I AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 2/6/2011 I End Date: X3- 00V57 -C (2,205,316.00 USD) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: NORDIC 2 Spud Date/Time: 7/27/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292115600 Active Datum: 34 : 18 7/26/1985 00:00 @75.29ft (above Mean Sea Level) Date ' From - To Hrs Task 1 Code NPT I NPT Depth I Phase I Description of Operations (hr) (ft) 21:00 23:30 2.50 WHIP P I WEXIT BEGIN TRIP SHEET AND POOH W/ I , WHIPSTOCK SETTING BHA. 1.1 BPM / 1165 PSI / 0.33 BPM RETURNS. LOSSES ARE -0.25 BPM POOH. 23:00 - ISOLATE PITS AND BEGIN BRINGING I ON 2 PPB BIOZAN. 23:30 - 23:45 0.25 WHIP P WEXIT PJSM FOR LAYING DOWN BHA #1. 23:45 - 00:00 0.25 WHIP P WEXIT STOP AT 200 FT. AND FLOW CHECK WELL - ,NO FLOW. I POP OFF INJECTOR AND PLACE OVER (BUNGHOLE. , BEGIN L/D BHA #1. 2/9/2011 00:00 00:30 0.50 WHIP , P WEXIT ICON I N E ACROSS #1 S THE TOP. TOOK 5 BBLS. 00 :30 - 01:00 0.50 STWHIP ! P WEXIT i BOLO AAR FOR L/Q BHA AND PJSM FOR IWU I WINDOW MILLING BHA. 01:00 - 02:00 1.00 STWHIP P ,i WEXIT 'BRING2 JTS. OF 2-1/16" UP PIPE ELEVATORS CIO LOWER CHOKE AND TEST - GOOD. FILL HOLE - TOOK 8 BBLS. r M/U BHA #2 CONSISTING OF 3.2" DSM, 3.2" - STRING MILL, 2 -1/8" XTREME MOTOR 2 JTS 2- 1/16" CSI-1, AND BAKER INTEQ TOOLS. 02:00 - 04:15 2.25 STWHIP P WEXIT RIH W/ BHA #2. 0.23 BPM AT 857 PSI CIRC. START GETTING RETURNS AFTER 5 BBLS PUMPED. I LOSING 0.3 - 0.4 BPM WHILE RIH. 1 04:15 - 05:00 0.75 STWHIP R WEXIT LOG GR TIE -IN FROM 12600 FT. MAKE -32 FT CORRECTION. 1 05:00 - 05:30 0.50 STWHIP L ' P WEXIT j CONTINUE RIH TO TOW PUMPING AT MIN. I RATE. TAG WS AT 13163.3 FT. P/U AND BRING PUMPS UP TO 1.58 BPM. RBIHANDTAGAT13162FT. i 'LOST TOTAL OF 82 BBLS ON TIH. 05:30 - 08:00 2.50 I STWHIP P WEXIT TIME MILL WINDOW FROM 13162 FT. I 1725 PSI FS AT1.58BPM. 75 -100 PSI MW. 0.25K# DHWOB. 408 PSI DIFF. BHP /ECD /PVT: 4411 PSI / 9.56 PPG / 304 BBL. n Printed 3/4/2011 10:37 :47AM TREE= 4- 1/16" CIW • WELLHEAD = 13 -5/8" CIW SAFETY NOTE.ALVE FROM GLM #1 NOT FOUND IN 4 ACTUATOR = AXLESON TBG OR CATC F�ER SUB ON 11/12/04 GLV CIO. VALVE KB ELEV = 72 29' S 18A STILL SOMEWHERE IN WELL (AS OF 12/14/05 ? ?) BF. ELEV = 32.40' **RESTRICTION @ 11987' CTMD ** KOP = 10936' Max Angle = 101 @ 12259' Datum MD = 11714' ' ' I 2093' H4-1/2" HES X NIP, ID = 3.813" Datum TVD = 8800' SS GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I--) 3055' I I ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3876 3224 46 MMG -M DMY RK 0 03/20/10 5 5702 4516 46 MMG -M DMY RK 0 02/28/03 IP 4 7199 5533 45 MMG -M DMY RK 0 03/20/10 Minimum ID = 3.813" @ 2093' 3 8528 6530 37 MMG -M DMY RK 0 03/20/10 2 9813 7527 38 MMG -M DMY RK 0 03/20/10 4 -1/2" HES X NIPPLE 1 11184 8523 47 KBG2 -9 DMY BK 0 03/20/10 TOP OF 7" LNR H 10764' I 1 10764' H7" X 9 -5/8" BKR ZXP LTP, ID = 7.500" I ( 10780' H7" X 9 -5/8" BKR HMC HGR, ID = 6.280" I MILLOUT WINDOW (S- 18A)10936' - 10952' 11463' H 4- 1 /2 "HESXNIP, ID= 3.813 " 11484' I-I 7" X 4-1/2" BKR S -3 PKR, ID = 3.875" I i lk 11508' H 4-1/2" HES X NIP, ID = 3.813" I BKR CIBP 1 0960 i I� I ♦ 9-5/8" CSG, 47 #, L -80, ID = 8.681" I 11650' MI \ , 11529' I-I 4-1/2" HES X NIP, ID = 3.813 WOO* ` •••••••• ,• 4 -1/2" WLEG, ID= 3.958" ,,, 11544 ,, H 11540' 1 7" X 5" BKR ZXP LTP WAWA 1 : w / HMC HGR, ID = 4.400" No& 11565' 1-15" X 4 -1/2" XO, ID = 3.958" !--I 12677' I-I MARKER JT 1 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I-1 12140' � ,�-' ` \ 13945' H MARKER JT I 4 -1/2" LNR, 12.6 #, 11544' \ PERFORATION SUMMARY 13CR -80 VAM TOP, \ 1 � 14023' I� TOC (04/03/10)1 REF LOG: .0152 bpf, ID = 3.958" \44 777 I— FISH - 1" GLV ANGLE AT TOPPERF: 74° @ 12003' 7" LNR, 26 #, L -80 BTC, H 11705' I � `;1 , �;, (11/11/2005) Note: Refer to Production DB for historical perf data SIZE I SPF INTERVAL Opn /Sqz DATE .0383 bpf, ID = 6.276" �1q4 SLTD LNR 12003 - 12519 0 09/03/02 'RESTRICTION (04/04/10) I1 11987' I 7 4 ; 1 4 0 . SLTD LNR 12697 - 13046 0 09/03/02 4 h0► SLTD LNR 13965 - 15905 0 09/03/02 4 -1/2" SLTD LNR, 12.6 #, L -80, —I 15907' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/85 ORIGINAL COMPLETION 09/30/07 CJN /PJC GLV C/0 (09/22/07) WELL: S -18A 09/03/02 DAV /KK RIG SIDETRACK 04/03/10 CJN/SV GLV C/O (03/20/10) PERMIT No: 2021630 12/10/04 RDJ /TLH WAIVER SAFETY NOTE 04/04/10 JKC/SV CMT PLUG SET (04/03/10) API No: 50- 029 - 21156 -01 11/11/05 BMcN /PJC FISH (GLV w /BK LATCH) SEC 35, TI2N, 12E, 2314' SNL & 711' EWL I 11/18/05 EZL/PJC WAIVER SFTY NOTE DELETED 12/13/05 JPK/TLH GLV CORRECTION (11/12/04) ' BP Exploration (Alaska) Schwartz, Guy L (DOA) From: Hinchman, Cody [Cody.Hinchman@bp.com] Sent: Tuesday, March 23, 2010 10:35 AM To: Schwartz, Guy L (DOA) Subject: RE: S-186 Sundry (PTD 202-163) Guy, Page 1 of 2 I appreciate the quick response. There will indeed be open slots above the WS setting depth. The priomary intention of the cement plug is to try and isolate excessive water production from a low spot in the parent well. Given the well's trajectory and the planned primary cement job, the remaining open slots should be P&A after running and cementing the completion. Thanks, Cody Cody Hinchman ~, ~,~~~~ CT Drilling Engineer w3~~ebt~~~~~"' ~P ~ ~`" Office: 907-564-4468 Cell: 303-319-5472 Cody.Hinchman@bp.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, March 23, 2010 10:14 AM To: Hinchman, Cody Subject: RE: S-18B Sundry (PTD 202-163) Cody, This modification to the procedure is acceptable. (It appears you will still have open slots above the Whipstock depth though) will add this email to the well file, the sundry does not need to be resubmitted. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Hinchman, Cody [mailto:Cody.Hinchman@bp.com] Sent: Tuesday, March 23, 2010 9:32 AM To: Schwartz, Guy L (DOA) Subject: S-18B Sundry Guy, The Application for Sundry Approval for the CTD sidetrack S-18B was approved on February 23, 2010. However, [he pre-riq prep work has been modified to include laying in a cement plug with service coil to isolate the parent, well's existing 4-1/2" slotted liner,., The original approved pre-rig prep work is below with this added step in red. T"~~ just wanted to make the state aware of this fact and see if the Sundry needs to be submitted for re-approval or if it is okay to proceed with the planned prep work. re-CTD Drilling Operations to start March 1, 201__0 3/23/2010 Page 2 of 2 1. O MIT-OA: Pass (2000 psi) on 11/24/09 2. O MIT-IA: Pass {3000psi) on 11/26/09. 3. W AC-LDS; PPPOT-T: Passed to 5000 psi on 11/28/09. 4. S Dummy all GLV's 5. C Push fish to bottom. Fish is a 1" GLV w! BK Latch. `vim ~~~~~ " 6. C Lay in cement plug to P&A 4-112 slotted liner below WS setting depth. ~ " ' ~ 7. C Dummy WS drift for Baker 4-1/2 Monobore WS Packer to 13,300 . ~ ~ 8. O PT tree (MV,SV,WV). 9. 10. W O Set BPV Bleed gas lift and production flowlines down to zero and blind flange ~3 . Z 3 • ~ v 11. O Remove S-Riser, Remove well house, level pad, Thanks, Cody Cody Hinchman BPXA CT Drilling Engineer Office: 907-564-4468 Cell: 303-319-5472 Cody.Hinchman@bp.com 3/23/2010 • • ,k ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ;~ ~~ ~s Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. J P.O. Box 196612 ~.~ ~.; t Anchorage, Alaska 99519-6612 ~... n ._.,_ , . Re: Prudhoe Bay Field, Prudhoe Bay Oil P~tsl;"PB°CJ S-18A Sundry Number: 310-040 Dear Mr. McMullen: F ~~~~~~~:, ~`~~~ ~~ ~- ~~~~' ,,~ . 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner r'1 DATED this23 day of February, 2010 Encl. STATE OF ALASKA ~~ ~ ~~~lt~ \~~ ALASKI~L AND GAS CONSERVATION COMMI9•N a' ~' APPLICATION FOR SUNDRY APPROVAL ~ ~n ao,c ~s 2so _~/~ ~/6 /o R~CE~vED FFR 1 ~ 7ntn 1. Type of Request: 1 ~ ~ ~ ~ ' i~11S. 'Proveor S~N Abandon ~(J Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change A rIIIO NI11881 ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ~4itCher~ea ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ After Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-163' 3. Address: ^ Service ^ StratigraphiC 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21156-01-00 - 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 S-18A ` Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028257, 028260 & 028261 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15937 - 9033'- 15937 - 9033' - None Yeg, Unknown Depth Gasi Size MD TVD Burst Colla Structural Conductor ' Surface 1 - / " 4 Intermediate 1 - / " 7 Production Liner 1' 7" - 1 7 ' Liner 4- 7' ' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section: 12003' -15905' 9007' -9034' 41/2", 12.6# L-80 11484' Packers and SSSV Type: 7" x 41/2" Baker'S-3' packer Packers and SSSV 11484' / 8725' MD (ft) and TVD (ft): 12. Attachments: 13. Wall Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Devek~pment ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 1, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR 4bandoned 16. Verbal Approval: Date: , ^ WINJ ^ GINJ ^ WAG ^ Plugg SPLUG Commission Representative: e r l -~S"!/S D / 17. I hereby osrtify that the foregoing is true and correct to the best of my knowledge. Contact Cod Hinchman 564-4468 Printed Name ,1 I cMu en Title Engineering Team Leader Prepared sy NameMumber: Signature Phone 5644711 Date Z / / j jj Terris Hubble, 564-4628 Commission Ust On Condit' of approval: Notify Commission so that a representative may witness ~~~ O~ Sundry Number. - ^ Plug Integrity Cy~'~OP Test ^ Mechanical Integrity Test ^ Location Clearance x35od psi as ~ %'fi Other. n n ~..~4^r ~ t ~" L r,"'~ ~ ~ Z S PSG f ~ Subsequent Form Required: /O , L~Q APPROVED BY O D t ~ 23 a e Approved By: COMMISSIONER THE COMMISSION Form 10-403 Revisedl2/2009 RBDMS FEB 2 5 1010 ~ R I G I ~ A L ~-~- z. ~? . ~o ~ ~j~~~ 5ut3mft In Duplicate • • To: Alaska Oil & Gas Conservation Commission From: Cody Hinchman ~p CTD Engineer Date: 09 February 2010 Re: S-18A Sundry Approval Request Sundry approval is requested for S-18A. Isolation of the existing slotted liner of S-18A will be with the primary cement job of the S-18B completion. WELL HISTORY/CURRENT STATUS: S-18 was originally drilled in 7/85 and POP'd in 11/86. It was SI in 1991 due to TxIA communication and low production rates. It was sidetracked southwest of the original parent , location in 2002. The horizontal was completed with blank/slotted liner in both the Sag and Ivishak horizons. During the sidetrack, both the IA and tubing were successfully pressure tested to 3500 psi. The S-18A wellbore is a 4 '/z" monobore completion. After the first year, production had dropped to 85% of the initial production at 80% WC and 700 GOR. Water cut has continued to increase and the slotted liner prevents WSO options from being implemented. Water sources are likely associated with proximity to the OWC in the lower section of the lateral and/or via faults that the wellbore crosses (the first option being the most likely source). The well has been essentially shut-in since 8/07 with the exception of 2 POP periods of less than 1 week. The last representative well test indicated 95% watercut and 2200 GOR. With the current water cut, on-time production is low and there are no intervention options available. WELL INTEGRITY: As part of pre rig screening, an MIT-IA passed on 11/26/09 to 3000 psi and an MIT-OA passed to 2000 psi on 11/24/09. A PPPOT-T passed to 5000 psi on 11/28/09. No calipers have been run on this well as no communication issues have been noted, nor are any expected. REASON FOR SIDETRACK: Under current operating conditions this well has little remaining value. This well is currently an Ivishak/Sag producer with limited on time due to a higher water-cut through a slotted liner completion. The proposed S-18B sidetrack will isolate the existing perforations and target Ivishak Zone 4B, east of the current location, to capture unswept reserves through a solid, cemented, and perforated c~o/mpletion. ` / Ql,~ p U/~ P~ Qt~OCr~vCevl fjve~~ P/~ODIvC~'f .~1i0/'~l ~f~ ~1®r'~ l~lf~ (®~ /~/~ Cow cv~. I ~ r' ~~ °~ ~"°~~~~ Cvl ~~ ~'~' ~~r°,/i-at~~f~~ If ~ . Inre~r ~1qs li"tt~~ ~~' ~i ~1y~ li T,'l~r-~ a~ rs. `~ ~ 1~stihdo~~~11„ ~~e te~~,jt,,~~ u-<~~~o.-~ ~~~' ~~o a /1 ~w 1o c s r~"~h ~ ,46/e ~~'~©~ fo.- J"jii~ +--~~2 ~,'r.(cr'rRck, %~ +t itic r~rurr iG% "i'8~O ~ Pre- CT D Drilling Operations to sta arch 1, 2010 1. O MIT-OA: Pass (2000 psi) on 11/24/09 2. O MIT-IA: Pass (3000psi) on 11/26/09. 3. W AC-LDS; PPPOT-T: Passed to 5000 psi on 11/28/09. 4. S Dummy all GLV's 5. C Push fish to bottom. Fish is a 1" GLV w/ BK Latch. 6. C Dummy WS drift for Baker 4-1/2" Monobore WS Packer to 13,300'. 7. O PT tree (MV,SV,WV). 8. W Set BPV 9. O Bleed gas lift and production flowlines down to zero and blind flange 10 .0 Remove S-Riser, Remove well house, level pad. Rig Sidetrack Operations (Nordic 2): (Scheduled to begin on April 10, 2010) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV 4. 5. 6. 7. 8. 9. 10 11 12 13 14 15 Set 4-12" monobore WS packer lowside with TOW at 13,180'. Mill 3.80" window at 13,180' MD. Drill build/turn section with 4-1/4" bicenter bit, and land well. Drill lateral section to 15,190' MD. Run 3-1 /2" X 2-7/8" solid 13Cr liner to TD. Place liner top at 11,810' MD. Cement liner from TD to TOL with 45 bbls of 15.8 ppg cement. Cleanout and MCNL. Test liner lap to 2000 psi. Perforate 1200'. Set KB Liner Top Packer if needed. Freeze protect well tot 2200'. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design 4. RU test separator, flow test well. Cody Hinchman CTD Engineer ~ ~~y 5u- 3r~° b~® ~a CC: Well File Sondra StewmanlTerrie Hubble .~ 113.318" CSG,72A, 1.80, ID = 12.347" E = 4-1 M 6" CAN .LNEAD = 13-SS" CfdU 'LtaTCHt = AxLE90N EtFV = 72.29' ELEV = ......._........_.._. 32.40' _ .............. . i= ~~~~ 1 ~ - Ptlgle = 01 ~ 12259' am MD = 11714' un TVD = 8800' SS ~~ ~~ I T416 ©CJtTt71ER ~~ ~~ ~~}FO{I~ ^ ~41C2" HES X NP, ID = 3.813" G&S LET MAI+I<]RELS ST M~1 TVD DEV TYPE VLV LATCH PORT DATE 6 3676 3224 46 MMG-FA DOME RK 16 09l22lfll 5 5702 4516 46 MM+IG-M DMY RK 0 02l28AD3 7199 5533 45 hAMG-MI DOME RK 16 09122!07 3 6528 6530 37 MMNG-M DOME RK 16 091+22~D7 2 9813 7527 38 MMd!(i-MI DOMES RK 16 09122~d7 1 11184 $523 47 KBG2-9 SO BK 24 09l22AD7 Minimum ID ~ 3.813" ~ 2093' 4-1~" HES X NIPPLE TOP OF T' LNR ~BKR CIBP 9.58' CSG, 47*, L-80, ID = 8.681" MILLOUTVVRtiIDCNV {~'I~A~10936' -10962' J~ 4112" HES X NP, ID = 3.813" 4~ 7" X 4112" BKR S• 3 PKR, b = 3.$75" 1150' 412"HESXNP,D=3.813" PERFORATION SUF~AARY REF LOG: ANGLE AT TOP PERF: 74' ~ 12003' Note: Refer to Productan DB for historical rf c~ta SIZE SPF IM1ITERVAL DATE SLTD LNG 12003 -1251 9 O 09lD3A2 SLTD LN4 12697 -13046 O 09AfkiaD2 SLTD LN3 13965-15905 O 0902 T' LNR, 25/, L-80, .0383 bpf, ID = 8.27G" 10T64' -iT' X 9.58" BKR ZXP LTP, ID = T.500" 1O79D' 7" X 9-38" BKR HMIC HGR, ~ = 8380" 11529" -~ 41C2" HES X NP, b = 3A13" 11544' 4112" LEG, ID= 3.958" - 115++5)' 7" X 5" EKR ZXP LTP w! HMC HGR ~ = 4.4C 11566' S" x a-1l2" xo, l~ ~~! `'~ FlSH -1" GLV wBFt ~ LATCH 91 M 112005) 41 C1" LNR,1216*, 1154#" 13CR-80 VAMTOP, 1ZBTT MARKERJT .0152 bpf, ID =3.958" ~ 7" LNR, 26A, LSO BTC, 11TQS' `~ `ti .0383 bpf, ID = 6.276" ~ 13945" M0.RKER JT '` ~ 4-112" SLTD LNR,12.6#, L-~, 159DT' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS MtlMSi O'ti~111U. COIIRETIOr 09l30i07 CJNIPJC GLV C!O (091227 NA]A2 GAYf10t RIG ~ETRI~CK 12M 0~4 RDJ/TLH RIVER SAFETY NOTE 11 M 1105 NiP FISH (GLV w8lt LATCH) 11 M $105 EZLIPJC AVER SFTY NOTE DELETED 12M 3105 JPKM'LH GLV CORRECTION 11 M ZAD4 PRI.bFiOE BAY LMAT VMS.L: S-18A PERMIT No: '2021630 API No: SO-029.211.56-01 T12N,12E, 2314' SNL & 711' BP Exploratkm (Alaska) t i r- 4-1 M 6" LHEAD = 1.3-5x8" 1ATOR= AXLE :i~v ._ .........................~: ............................................. :LEV = 3: .............................................. 1C Pngle = 01 ~ 12 .............................................. mMD= 11 ............................................. m TVD = 880( 13-38" CSG,72#, L-80, ID = 12.347" Minimum ID = 2.3" ~ 11®10' TOL 3-irZ" TOP OF 7" LNR 10764' ~~ Proposed CTD Sidetrack PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 74' @ 12003' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnxSgx DATE SLTD LNR 1 2003 -1 2519 O 09x03x02 SLTD LN4 12697 -13046 O 09103x02 SLTD LNR 13965 -15905 0 09+03x02 19.58" CSG, 47#, L•80, ID = 8.881" I 4-12" TEG,12.6#,13CR-80, VAM 1154d' TOP, 0.0152bpf, ID = 3.95$" TSGR 11686' 7" LNR, 26#, LSO BTC, 71705' ~ .0383 bpf. ID = 6.276" l 1]100' 13.12" x 2.78" crossover II ~ \ ~ i4 3- 1x2" 13Cr~ 2 ' c" 13Cr Liner, Cemented 3. Perf'd 15190' SAFETY NOTES: YALYE FRDM GLM NI NOT FOUND IN TBG OR CATCHER SIIN ON 11~i~104 GLY C10. YALYE 5711 i SiSMEWHERE INtIIIELL (li5 OF 12x14105??~ 11463' -1 412" HES X NIP, ID = 3.813" 11484' 7" X 41/2" BKR S•3 PKR, ID = 3.875" / 11508' ~ 41/2" HES X NIP, ID = 3.813" i / 1149' 4102" HES X NIP. ID = 3$13" 11544' 4102" W LEG, ID = 3.958" 11540' l" X 5" BtR Z7(P LTP ~~° w/ HMC HGR, ID = 4.400" 11800' ~- t2" Bk:F: KB LTP IG = 2.375^ 11810' TOL 312" ID = x.30" DATE REV BY COMMENTS DATE REV BY COMMENTS Oul01ti5 ORIGINAL COMPLETION 09(30107 CJNxPJC GLV CIO 0922x07 0~10]Aa DAYINK RIG SIDETRACIIi 11 +09x09 MSE PROPOSED CTD SIDETRACK 12M Ox04 RDJIFLH WAIVER SAFETY NOTE 11 M 1 ADS BMcNxPJC FISH (GLV wxBK LATCH) 11 M 8x05 EZLxPJC WAIVER SFTY NOTE DELETED 12M 3x05 JPK/FLH GLV CORRECTION 11 M 2x04 4-12" SLTD LNR,12.6#, L-80, 15907' .0152 bpf,ID = 3.958" PRUDHOE BAY UNIT WELL: S-188 PERMIT No: API No: 50-029-21156-02 SEC 35, T12N,12E, 2314' SNL 8 711' EWL BP Exploration (Alaska) 12" HES X NIP, ID = 3.813" GAS I IFT MQNnRFLS ST MD TVD DEV TYPE VLV LATCH PORT DOTE 6 3876 3224 46 MMG-M DOME RK 16 0922x07 5 5702 4516 46 MMG-M DMY RK 0 0228x03 7199 5533 45 MMG-M DOME RK 16 0322x107 3 8528 6530 37 MMG-M DOME RK 16 0922xD7 2 9813 7527 38 MMG-M DOME RK 16 0922x07 1 11184 8523 47 KBG2-9 SO BK 24 0922x07 j7"X9.518" BKR ZXP LTP, ID = 7.500" 7" X 9.58" BKR HMC HGR. ID = 828Ci" MILLOUTVNNDOW ~5-1tiAy10936' -10952' ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, 0~~' ~ ~3 ~ ~~~$~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, s~ yn ,a. s9,~~7J~~~~T~~q 1 F': ~"., L~~~l',~ •~i.~~ Y A tiai V c,r (,~ '"° ti r, biiJ • ~ ` ,, r ~ ~ ~~ JuL a ~ zoo9 ~~~~ka pil ~ Gas ~~r ~e ~~r~~ni~sa~~ An~~~; , Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Spad ~ l~ Date 6/25/2009 Wetl Name PTD ll Initial [op of cement Vol. ot cement um ed Final top of cement Cement rop off date Corrosion inhibitor Corrosion inhibitod sealant date fl bbls ft na al S-01B 1952020 0.25 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 5-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 S-Oa 1830790 0 NA 0 NA 0.9 5/25/2009 S-05A i95f890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 5-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 7.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31I2009 S-11B 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6l1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1I2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.8 6/1/2009 S18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/79/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5l25/2~9 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/37/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.a 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 7921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .BSin 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 125 NA 7~.9 5/27/2009 5-38 1921270 025 NA 025 NA 102 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 i970530 0.5 NA 0.5 NA 1.7 5/26/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29I2009 S-101 2001150 125 NA 1.25 NA 11.9 5/29/2009 5-102L7 2031560 125 NA 725 NA 11.1 5/37/2009 S-103 2001680 1.5 NA 1.5 NA 71.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2070120 1625 NA 1625 NA 174.3 6/2/2009 S-t07 2011130 225 NA 2.25 NA 28.9 5/18I2009 5-108 2011000 3.5 NA 3.5 NA 40 5l30/2009 5-709 2022450 2 NA 2 NA 21.3 5/30/2009 5410 2011290 17J5 NA 11.75 NA 98.6 5/30/2009 S-7~7 2050510 2 NA 2 NA 79.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-774A 2021980 125 NA 125 NA 102 5/30/2009 5-1~5 2022300 2.5 NA 2.5 NA 272 5/29l2009 5-118 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-177 2030120 /.5 NA 1.5 NA 75.3 5/29/2009 S-718 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 S-122 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 175 NA 71.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4J5 NA 4J5 NA 57 5/29/2009 5-217 2070950 025 NA 025 NA 7.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S~4(l1 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 C~ P.I. Suprv -~ ~- Z Z~ ~ Safety Valve & Well Pressures Test Report ReviewedB~ l Comm Pad: Psu_s InspDt: 2/18/2008 Inspected by John Crisp Interval InsPNu svsJCr08022 1 1 40934 Related Insp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) 1NC Operator Rep Rich Vincent Reason 180-Day `' - ____._.. _....._ Src: Inspector Well Data ~ Pclots 1 SSV SSSV1Shtttln Dtl Well Type Well Pressures ~ Gas Lift Waiver , Com»:erets ~ _ . -- -- _ - _...._. .: i:. . -----_ - __ -.:.._ -- -- - - - --L- - --- 1 -- - -- -- - -- -_ - ---- Well Permit Separ Set LIP Test Test Test Date Sl OiI,WAG,GINJ, Inner Outer Tubing --__-___._. ____~ Number Number PSI PSl Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI Yes/No Yes/No S-100 _ 5-103 S-105 S l06 S l08 ___ S-109 S-113 S-I l5 S-117 S-121 -- 5-122 S-125 S-17C .._~S-l8 5-213 i S_44 2000780 -- 2001680 _ _ -- --~ ' 2001520 153 ~ _ , l53 - _. l53 125 ~ _ _ ~ 125 125 ~ 125 ~ -- 120 t ---- ~ 110 P -- P -- P ~ t P i - P --- P ~ I --- ~ -- T -- _ ---- ~ _._ __--- I -j -_-___ _...--r- __~ I -O1L ~ --- _~_ __ i- ---1 l-OlL - -- - -- I-OIL --- -- - -- f -- ~ - - ~ i - - ~ - - --..T - ~ --- ---1 ~_ _ - - , i 2010120 - ~ - - 2011.000 - I- -- -- -- - 153 153 ` --- 125 125 - - i - - 40 l25 ~ --- ~ 30 - P~ ~ --I - P P --- - --- _ --- - _- _ _ - _ ~ 1-O1L I -- 1-OIL ~ i ~ t-- -- -t- - ~ - ' - ~ _ ~ -- - - j I ~- - - - -- --- _-i - --- r - - 2022450 ---- - -- - ~ 2021430 j 153 153 125 ~- 125 I !25 ~ 125 P P ~ --- P - P --- - l-OIL ; ~- -~- -----_ _ 1-OIL j ~ I _-- E -_ _ - --~ - 2022300 __h 2030120 153 l53 ~ 125 ' 125 ~ ~ 120 ]35 P P P I P ~ ~ 1-OIL _ .- 1-OIL _ 2060410 l53 ' 125 125 P P 1-OIl ~ j 2050810 ~ ----- - l53 l25 -- 110 - P ---- Y _ -_. .--- - -- _ - l-OlL j ' _,-. ~ -- ... I -- - -.. -_ . 2070830 2020070 , 2021630 - -- -- 153 153 153 - 125 125 ~ -I 125 + l15 110 ----- 100 P P _ P P P P - _ - ----- 1-OIL 1-OIL - -- ~ - -_ ~ - ` - - - - 1-OIL ~ - -- i ' - -- -- _ -_ -, - ~ - i 2042130 _ i~_1970060 1 l03 153_ 125 125 125 ~00~ P A P - P -~ ~ --- --- ---' 1-OIL j - 1_OIL _~. - - ~ --' ~--- ~ -- - - I - - - -- --- B A A ---- - - - ---, i - -_ --~ - -- - -- --- -- - --- _ __ __ __ -- _ , -- -- - - _- -- _~~ I Comments v - ~ , ~ ~ J ~ t~ Performance -^ ! Wells Components Failures Failure Rate I 16_..--- - 32 - - --1- -- --- 3.12%_ _ ~ I. - ~~I~ MAR ~ 9 ~00~ Monday, February 25, 2008 · ~) f ....'3 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comrn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: M-38A PBl, N-OIA, P-18 Ll, S-18A, W-16A PBl, - - W-32A PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 '¡J. M-38A PBl: U.l.Q. 90l-\3'd- 1L.Ji.../tO Digital Log Images: 50-029-22519-01,70 1 CD Rom SC;AN~IED FEB 0 1 2007 N -01 A:d ef../ - t 13 ~ 14l./ It Digital Log Images: 50-029-20079-01 1 CD Rom P-18 Ll: ';:>Od, - 030 ~ILILIO"6 Digital Log Images: 50-029-22097-60 1 CD Rom S-18A: ~Od-/(P3 #/¿./L//d, Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PBl: QO'3-IOO tt 1L./4ö9 Digital Log Images: 50-029-22045-01,70 1 CD Rom W-32A_PBl: dÖ(j -go'1 .tt t4L/13 Digital Log Images: 50-029-21790-01,70 1 CD Rom -:r e e WELL LOG TRANSMITTAL ¿)O~- 1£03 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian -333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 I'ðLP LÞ 4-- RE: MWD Formation Evaluation Logs S-18A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 S-18A: LAS Data & Digital Log Images: 50-029-21156-01 1 CD Rom ~ ~WI[ifl e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc RE: S-18 Recommend Cancel Waiver 5-1 <bA Suh,iect: RE: ~Recommcnd Cancel Waiver I¡rom: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEnginccr~I~BP.com> Date: Thu, 17 Nov 200521 :17:01 -0900 To: jimJcgg@admin.statc.ak.us, winton_aubert@admin.state.ak.us, "Rossbcrg, R Steven" <RossbcRS@BP.com>, "NSLJ, ADW Well Operations Supervisor" <NSUADWWcIlOperationsSupervisor@}BP.com>, "Young, Jim" <YollngJ3@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "OPB, GC2 Wcllpad Lead" <G.PßGC2Wcl1padLcad@BP.com>, "Kurz, John" <john.kurz@BP.com> CC: "NSlJ, ADW Well Integrity Engineer" <NSUADW\VellIntegrityEngincer@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "Mielke, Robert L." <robcrt.miclke@BP.com>, "Luckett, Ely Z. (VECO)" <luckcz:@BP.com> e e p¡tJ$ ~'2--Ib~, ,:¿_~~¡:~I:i"t&',,, Ket¿q I~ ~ob Hello all. ~ 'OA Wel~has been reclassified from Waiver to Normal. Installing a new OGLV fixed the TxlA communication problem. Lead Operator, would you please ensure any waiver related signage is removed from the wellhouse. Ely, would you please update well status in AnnComm. Please call if you have any questions. Joe 1-907-659-5102 ~CANNEC DEC 162005 From: Hughes, Andrea (VECO) Sent: Thursday, November 17, 200512:48 PM To: N5U, ADW Well Integrity Engineer Subject: 5-18 Recommend Cancel Waiver Joe- "3-1 vf.\ ~ is currently waivered for TxlA communication. It was waivered after the IA inflowed during a TIFL. During a recent attempt to mitigate the communciation, slickline was to change out the OGL V in Sta #1 and found the pocket empty. The GLV was replaced and the well passed a TIFL. I recommend that we cancel the TxlA waiver as tubing integrity has been restored with recent GL V work. Thanks- Andrea Hughes Well Integrity Engineer Office: (907) 659-5525 Pager: (907) 659-5100 x1242 I of 1 11/18/2005 9: 11 AM 3 öii Â,ô~\.1 DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021630 Well Name/No. PRUDHOE BAY UNIT S-18A Operator BP EXPLORATION (ALASKA) INC S(J~ ~3 ~ ~y API No. 50-029-21156-01-00 MD 15937 --/- TVD 9033 ~/ Completion Date 9/3/2002 ~ Completion Status 1-01L .-----------~-~------~ ----.-------- REQUIRED INFORMATION Mud Log No Samples No --- ---~.._~-~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ ~/ ~;-nal Survey ~ D vtf673 US Vtrifio3tion-. V G (2...( [w A ~ (\/\ y1 Log Log Run Scale Media No 1 1 1 Directional Survey ~ Ue'~' Rpt ------e D (;rD ----'ED Directional Survey ~tional Survey LIS Verification C Tf r12192 ldS-VefiflCatioR--- C Pdf ¡ -, 2192 Rate of Penetration I C Pdf !,,-,12192 Induction/Resistivity ",I. ¡ 2 r if, ~.Y -^-f' I ~ ' 1-4 1-4 1-4 25 25 --~. -----------~--- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION yK;) Well Cored? Daily History Received? Chips Received? ~ Formation Tops Analysis Received? ~ - --'._'._'---_.'----~------~~-~- Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) ~' Interval OH / Start Stop CH Received Comments 10922 15937 Open 10/3/2002 MWD 10845 15882 Open 3/26/2003 10922 15937 Open 10/3/2002 10922 10922 10845 10966 10966 10966 15937 Open 15937 Open 15882 Open 15937 Open 15937 Open 15937 Open A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/5/2002. MWD 10/3/2002 10/3/2002 3/26/2003 10/27/2003 1 0/27/2003 1 0/27/2003 Rap, DGR, EWR - MWD ROP, DGR, EWR - MWD ~ Sample Set Number Comments GJN Ø/N DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021630 Well Name/No. PRUDHOE BAY UNIT S-18A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21156-01-00 MD 15937 TVD 9033 Completion Date 9/3/2002 Completion Status 1-01L Current Status 1-01L UIC N --~-----------~--~-~ Comments: Compliance Reviewed By: r r;:) ~ Date: ! C{cJ f1Jz lfùL{ -~------_.._---- ~----~--~ -- .~ ) . \51w ~ ) (s;ê3 \d\q~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 ~chorage, Alaska 99501 October 14, 2003 RE: MWD Formation Evaluation Logs: S-18A, AK-MW-22137 S-18A: Digital Log Images 50-029-21156-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. ~chorage, Alaska 99508 Date: "" Signe~0\~ ~,-Cj~~ ~~~\~\~ étoa- /03 / ICo 73 WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 20, 2003 RE: MWDFonnationEvaluationLogs S-18A, AK-MW-22137 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21156-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: c>fø'WkpJ Signed: RECEIVED MAR 2 6 2003 Alalka on & Gas Cons, Col11ß1ÍtliOn Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 11/05/02, ) 1. Status of Well ISI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2314' SNL, 711' EWL, SEC. 35, T12N, R12E, UM At top of productive. interval 4351' SNL, 1325' EWL, SEC. 02, T11N, R12E, UM At total depth 177' SNL, 1511'WEL, SEC. 10, T11N, R12E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 72.29' ADL 028261 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/23/2002 8/30/2002 9/3/2002 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVO) 19. Directional Survey 15937 9033 FT 15937 9033 FT ISI Yes 0 No 22. Type Electric or Other Logs Run ') Put on Production Classification of Service Well 7. Permit Number 202-163 8. API Number 50- 029-21156-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-18A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2093' MO 1900' (Approx.) 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" 7" GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 8 cu yds Concrete Surface 3055' 17-1/2" 4265 cu ft Permafrost Surface 10936' 12-1/4" 2196 cu ft Class 'G', 230 cu ft 'G' 10764' 11705' 8-1/2" 236 cu ft Class 'G' 11540' 15907' 6-1/8" Uncemented Slotted Liner WT. PER FT. Insulated 72# 47# 26# 12.6# 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner MD TVD 12003' - 12519' 9007' - 8980' 12697' - 13046' 8973' - 8957' 13965' - 15905' 9008' - 9034' 25. SIZE 4-1/2", 12.6#, L-80 MD TVD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 11544' PACKER SET (MD) 11484' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 165 Bbls Diesel 27. Date First Production October 25, 2002 Date of Test Hours Tested 10/26/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 2,801 CALCULATED OIL -BBL 24-HoUR RATE GAs-McF 2,131 GAs-McF WATER-BBL 1,896 WATER-BBL CHOKE SIZE 960 GAS-OIL RATIO 761 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. NOV I 8 R E € E I V E D R B 0 M 5 B F l NOV 0 6 2002 Alaska Oil & Gas G1)ns. Commission AnchoraQe Form 10-407 Rev. 07-01-80 Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 117061 88671 Shublik 117601 8900. Sadlerochit 119411 8987' RE€EIVED NOV 0 6 2002 Alastta Oil. & Gas Gons. Commissioo Anchorage 31. List of Attachments: Summary of Daily Drilling Rèports, Surveys 32. I hereby certify that the foyoin9. is true. and correct to the best of my knowledge SIgned TerrieHubble-J.t1)}\.LQ ~ Title Technical Assistant Date J t,..O S-o a S-18A 202-163 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. DriJling /Engineer: Bil/lsaacson, 564-5521 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27, Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~~~~~~[ w.,~"1 ?~~~a~~c. 35 T12N R12E UMrê5~;i~Ç~'irntl r::'::;:;5~~I'~ At top of productive interval' , , t... t7i' ~~ ....~ ~ '~eg¡HSÐ ' 4351' SNL, 1325' EWL, SEC. 02, T11N, R12E, UM .'.'.'--...1.....'......,-.",.. ... i.. !..s..u.~.~.~.."''''...''~/.'. At total depth' ~n:J] t f, :.. o'J5I-Y!.<£ 177' SNL, 1511' WEL, SEC. 10, T11 N, R12E, UM .. "":::::;:::::"::;J ,~....,. ,. ,- ~',..' 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 72.29' ADL 028261 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/23/2002 ~ 8/30/2002 9/312002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 15937 9033 FT 15937 9033 FT 181 Yes 0 No 22. Type Electric or Other Logs Run Classification of Service Well 7. Permit Number 202-163 8. API Number 50-029-21156-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-18A 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2093' MD 1900' (Approx.) -¡-/t;)¡;'dvw /09 3~ f M!) '/" ~:3S-3 "TVL> 23. CASING SIZE 20" X 30" 13-3/8" 9-518" GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 8 cu yds Concrete Surface 3055' 17-1/2" 4265 cu ft Permafrost Surface 10936' 12-1/4" 2196 cu ft Class 'G', 230 cu ft 'G' 10764' 11705' 8-1/2" 236 cu ft Class 'G' 11540' 15907' 6-1/8" Uncemented Slotted Liner WT. PER FT. Insulated 72# 47# 26# 12.6# 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 12003' - 12519' 9007' - 8980' 12697' - 13046' 8973' - 8957' 13965' - 15905' 9008' - 9034' TVD MD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 11544' PACKER SET (MD) 11484' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 165 Bbls Diesel 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmit~~tE J V E D No core samples were taken. 28. OCT 9 RBDMS BFL Form 10-407 Rev. 07-01-80 OCT 0 4 2002 Alaska on & Gas Gons. Commtsston Anchorage Gf Submit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 11706' 8867' Shublik 11760' 8900' Sadlerochit 11941' 8987' R'ECEI'VED OCT 0 4 2002 Alaska Oil & Gas Gons. Commtsston Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TeffteHubble -(Ø\ftil, ~ Title Technical Assistant Date J/).oa.n~ S-18A 202-163 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Bill Isaacson, 564-5521 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 Legal Name: 8-18 Common Name: 8-18 Test Date 8/22/2002 8/26/2002 FIT FIT Test Type Bp..EXPLOFRÂTION l...eak~Qff..1êst....$ìJÎ11m~ry Test Deþth (TMP) 10,944.0 (ft) 11,705.0 (ft) AMW 11.00 (ppg) 8.50 (ppg) Tes;t DØpth (TVD) 8,363.0 (ft) 8,867.0 (ft) Surface Pressure 660 (psi) 460 (psi) Leak Off Pressure (BHP) 5,439 (psi) 4,375 (psi) Page 1 of 1 EMW 12.52 (ppg) 9.50 (ppg) '-, .~ Printed: 9/4/2002 10:50:47 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Date From ,-To Hours Task Cbde NPT 8/15/2002 04:00 - 05:00 1.00 MOB P 05:00 - 09:30 4.50 MOB P 09:30 - 10:30 1.00 MOB P 10:30 - 11 :00 0.50 MOB P 11 :00 - 12:00 1.00 WHSUR P 12:00 - 15:00 3.00 BOPSUR P 15:00 - 16:00 16:00 - 17:00 17:00 - 20:30 1.00 BOPSURP 1.00 BOPSURP 3.50 BOPSUR P 20:30 - 21 :30 21 :30 - 22:30 22:30 - 23:00 23:00 - 23:30 1.00 BOPSUR P 1.00 BOPSURP 0.50 PULL P 0.50 PULL P 23:30 - 00:00 0.50 PULL P 8/16/2002 00:00 - 01 :00 1.00 PULL P 01 :00 - 01 :30 0.50 PULL P 01 :30 - 04:00 2.50 PULL P 04:00 - 04:30 0.50 PULL P 04:30 - 12:30 8.00 PULL P 12:30 -14:00 1.50 PULL P 14:00 - 15:00 1.00 BOPSURP 15:00 - 15:30 0.50 BOPSU~ P 15:30 - 18:30 3.00 FISH P Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECaMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Held PJSM. Skidded Rig Floor. Held PJSM. Moved off of S 215i. Moved in Rig and Spotted over S-18A. Shimmed and Set Rig. Skidded Rig Floor into Position. Set Cuttings Tank, R / U Rig Floor. Took on Sea Water. Accepted Rig @ 1030 hrs 8/ 15 / 2002 Held PJSM. N / 0 Production Tree, Checked Tubing Hanger Threads, Checked XO Make Up in Hanger, OK. Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram w/ 2-7/8" x 5" Variable Rams, Blind Ram, Lower Pipe Rams w/ 3-1/2" x 6" Variable Rams. R / U Drill Floor Held PJSM. R / U to Test BOPE Equipment. Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 3,500 psi High /250 psi Low. Tested Annular Preventer to 2,500 psi High /250 psi Low. All Tests Held f/ 5 Min. All Pressure Tests Held w/ No Leaks or Pressure Loss. Witnessing of BOPE test Waived by Chuck Sheeve-AOGCC. R /0 BOPE Test Equipment. Held PJSM. R / U DSM Lubricator, Pulled TWC. R /0 DSM. Held PJSM. R / U Equipment to Pull Tubing. M / U 1 Joint 4" DP and XO to 4" TDS Threads. RIH and Screwed into Tubing Hanger. Backed Out Lock Down Screws. Pulled on Tubing, Hanger was Free. Pulled Up 5', String Weight 95,000#. Circulated Bottoms Up. Pump Rate 10 bpm, 300 psi. Held PJSM. Circulated Bottoms Up. Pump Rate 10 bpm, 300 psi, No Gas. R / U Camco Equipment to Spool up Dual Encapsulated Control Line. Pulled Tubing Hanger to Floor. Broke out and L / 0 4" TDS Thread XO and 4" DP. Broke out and L /0 Tubing Hanger. POOH and L / 0 50 Jts 4-1/2" Tubing. Spooled Up Control Line. Broke out and L / 0 SSSV Assembly. Recovered 26 Clamps as per Tally, Did Not Recover 2 Stainless Steel Bands. R /0 Camco Equipment, R / 04-1/2" Equipment and Cleared Floor. R / U 3-1/2" Handling Equipment. POOH and L /0296 Jts of 3-1/2" Tubing., 1 Cut Jt = 1.69' and 5 GLM Assemblies. Cleaned Paraffin and Oil from Tubing off of Rig Floor. R / 0 Tubing Equipment. R / U 4" DP Handling Equipment. Held PJSM. M / U Test Plug and Set in Wellhead. Attempted to Test Lower BOP Rams. Test Plug was not fully seated when RIH. Test Plug Seated under Pressure. Damaged Plug and Lock Down Screws. Pulled Test Plug and Inspected. Ran and Set Wear Bushing. Held PJSM. M / U Fishing BHA-8-1/8" Cut Lip Guide - Overshot Extension - Overshot Bowl w/ 3-1/2" Basket Grapple - XO- Bumper Sub - 6-1/4" Oil Jars - 9 x 6-3/4" D.C. - Accelerator Jars - Pump Out Sub - 15 x 5" HWDP - XO. BHA Length Printed: 9/4/2002 10:51 :08 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 19 ate 8/16/2002 8/17/2002 S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Spud Date: 7/27/1985 End: 9/3/2002 Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: From- To HoUrs Task Codë NPT 15:30 - 18:30 3.00 FISH P DECaMP 773.92'. Top of Fish 11,315'. 18:30 - 20:00 1.50 FISH P DECOMP Held PJSM. Cut and Slip Drilling Line. Serviced Top Drive. 20:00 - 00:00 4.00 FISH P DECOMP RIH wi Fishing BHA, PI U and Drifted 4" Drill Pipe. RIH to 5,736' 00:00 - 04:00 4.00 FISH P DECOMP Held PJSM. RIH wi Fishing BHA, PI U and Drifted Total of 329 Jts 4" Drill Pipe. RIH to 11,262'. 04:00 - 04:30 0.50 FISH P DECOMP Broke Circulation, Established Circulation Rates: 3 bpm-280 psi, 5 bpm-650 psi, 7 bpm-1 ,150 psi. Washed Down to 11,290'. Pump Rate 7 bpm, 1,150 psi. Shut Down Pumps and R I U to Reverse Circulate. Closed Annular and Established Reverse Circulation Rates: 4 bpm-350 psi, 6 bpm-700 psi. R I U Little Red Hot Oil Truck. 04:30 - 06:00 1.50 FISH P DECOMP Held PJSM wi Rig Crew, Hot Oil Crew and Truck Drivers. Little Red Pressure Tested Line to 3,000 psi, OK. Pumped 135 bbls 180 deg Diesel Down Annulus, Took Returns up Drill Pipe. Pump Rate 1.95 bpm, 200 psi. 06:00 - 08:00 2.00 FISH P DECOMP Switched over to Rig Pumps. Chased the 135 bbl Hot Diesel wi 25 bbl Hi-Vis Pill, 300 bbl120 deg Seawater followed with Seawater from pits. Pump Rate 6 bpm, 1,280 psi. Dumped Diesel and 200 bbl Seawater Returns into the Slop Tank. 08:00 - 08:30 0.50 FISH P DECOMP RID Hose and Circulating Head, Opened Annular. M I U Top Drive and Engaged Pump. Checked Parameters: String Weight Up 260,000#, String Weight Down 145,000#, String Weight Rotating 175,000#. Pump Rate 3 bpm, 250 psi. Washed Down to the Top of and Swallowed Fish, Pump Pressure Increased to 770 psi. Shut Down Pump and Fully Engaged Fish at 11,308'. 08:30 - 12:00 3.50 FISH P DECOMP Attempted to Release K Anchor. Overpulled 15,000# and Rotated Drill String to the Right 22 times. Worked Drill String to get Torque to Fish, Torque 22,000 ft I Ibs. No Movement in K Anchor. Backed off 1/2 of the Torque and Jarred on Fish wi 305,000# - 350,000# up Weight. Retorqued Drill String to 22,000 ft I Ibs Worked Torque Down to Fish. Grapples Slipped, No Movement of K Anchor. Reengaged Fish and Obtained 20,000# Overpull. Torqued Drill String to 24,000 ft I Ibs and Worked Torque Down to Fish. No Movement. Backed off Torque to 15,000 ft I Ibs, Jarred on Fish wi 325,000#- 350,000# Up Weight. Retorqued Drill String, No Movement in K Anchor. Grapples Slipped. Reengaged Fish and made Several more attempts as above with No Success. 12:00 - 12:30 0.50 FISH P DECOMP Held PJSM. Released from Fish, Flow Checked Well, Well Static, Prepared to POOH. 12:30 - 18:30 6.00 FISH P DECOMP POOH wi 4" DP from 11,308' to 774'. 18:30 - 19:30 1.00 FISH P DECOMP POOH wi Fishing BHA. Racked HWDP and Drill Collars in Derrick. LID Jars and Overshot. 19:30 - 20:00 0.50 FISH P DECaMP Cleared and Cleaned Drill Floor. 20:00 - 21 :00 1.00 BOPSUR P DECOMP Held PJSM. R I U Test Plug, RIH and Set in Wellhead. Test Plug Fully Seated. Pressure Tested Lower Pipe Rams to 3,500 psi - High I 250 psi - Low. Each Test Held for 5 minutes. Pressure Tests Held wi No Leaks or Pressure Loss. Pulled Test Plug and RID BOP Test Equipment. Ran and Set Wear Bushing. 21 :00 - 22:00 1.00 FISH P DECOMP Held PJSM. M I U Washover Milling BHA. 8-1/2" Burn Shoe - 1 Jt Wash Pipe - Drive Sub - XO - 3 x Boot Baskets - XO - Printed: 9/4/2002 10:51:08AM ) ) BP EXF?LORATION .Op~t_tiPI1$..$lJfnrnaryR~ppï1 Legal Well Name: Com man Well Name: Event Name: Contractor Name: Rig Name: S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 Date From ,-To HoUrs Task Cbde NPT Descri ptionofOperatiOns 8/1712002 21 :00 - 22:00 1.00 FISH P DECOMP Bumper Sub - 6-1/4" Oil Jars - 9 x 6-3/4" D.C. - 15 x 5" HWDP - XO. BHA Length 800.58'. Top of Fish 11,308'. 22:00 - 00:00 2.00 FISH P DECOMP RIH wi Washover Milling BHA on 4" DP to 2,300' 8/18/2002 00:00 - 03:00 3.00 FISH P DECOMP Held PJSM. RIH wi Washover-Milling BHA on 4" DP to 11,300' 03:00 - 03:30 0.50 FISH P DECOMP M I U Top Drive and Broke Circulation. Established Parameters: String Weight Up 285,000#, String Weight Down 145,000#, String Weight Rotating 192,000#: RPM 60, Torque 12,500 ft Ilbs; Pump Rates: 3 bpm-270 psi, 4 bpm-470 psi, 6 bpm-1 ,000 psi, 8 bpm-1 ,640 psi, 10 bpm-2,540 psi. Started Mud Lube into System. Washed Down over K Anchor, Tagged Packer at 11,329'. 03:30 - 07:30 4.00 FISH P DECOMP Milled on Packer from 11,329' to 11,333'. WOM 10,000#, RPM 60, Torque 14,000 ft Ilbs, Pump Rate 7 bpm, 1,340 psi. Pumped Intermittent 10 bbl Hi-Vis Sweeps. 07:30 - 08:00 0.50 FISH P DECOMP Packer Dropped Down Hole, Chased Packer down to 11,363'. Attempted to Jam Packer inside Wash Pipe. 08:00 - 09:00 1.00 FISH P DECOMP Pumped and Circulated around 25 bbl Hi-Vis Sweep. Pump Rate 10 bpm, 2,400 psi. Slight Show of Gas on Bottoms Up. Flow Checked Well, Well Static. 09:00 - 13:00 4.00 FISH P DECOMP POOH wi 4" Drill Pipe to 800'. 13:00 - 15:00 2.00 FISH P DECOMP Held PJSM. POOH Broke out and LID Milling BHA and Wash Pipe, No Fish. Cleaned out Junk Baskets, Recovered 4-1/2 gallons, 100# of metal cuttings. 15:00 - 15:30 0.50 FISH P DECOMP Cleared and Cleaned Rig Floor. 15:30 - 16:30 1.00 FISH P DECOMP Held PJSM. M I U Packer Fishing BHA-8-1/8" Cut Lip Guide- Overshot Extension - Overshot Bowl wi 3-1/2" Basket Grapple - XO - Bumper Sub - 6-1/4" Oil Jars - 9 x 6-3/4" D.C. - Pump Out Sub - 15 x 5" HWDP - XO. BHA Length 761.14'. Top of Fish 11,343'. 16:30 - 18:00 1.50 FISH P DECOMP Held PJSM. Slipped and Cut Drilling Line. 18:00 - 21 :00 3.00 FISH P DECOMP RIH wi Fishing BHA on 4" DP to 11,320' 21 :00 - 21 :30 0.50 FISH P DECOMP M I U Top Drive Broke Circulation. Established Parameters: String Weight Up 250,000#, String Weight Down 160,000#, String Weight Rotating 192,000#, RPM 65, Torque 7,000 ft I Ibs; Pump Rates: 3 bpm-260 psi, 4 bpm-310 psi. Slowed Pump Rate to 3 bpm, 260 psi, Washed Down to the Top of and Swallowed Fish, Pump Pressure Increased to 400 psi. Shut Down Pump and Fully Engaged Fish at 11,350'. Pulled up to Ensure Fish Engaged, Worked Packer through Casing Collars, Drag up 65,000#. 21 :30 - 23:00 1.50 FISH P DECOMP Pumped and Circulated around 30 bbl Hi-Vis Sweep. Pump Rate 10 bpm, 2,300 psi. No Gas Observed on Bottoms Up. 23:00 - 00:00 1.00 FISH P DECOMP POOH wi Fish from 11,343' to 10,400'. Worked Packer through Numerous Casing Collars w/1 00,000# Overpull. Drag up 60,000#. 8/19J2002 00:00 - 03:30 3.50 FISH P DECOMP Held PJSM. POOH WI 4" DP to 700'. Average Drag 10,400'- 9,950' 35,000#. Average Drag 9,950' - 700' 15,000#. 03:30 - 04:00 0.50 FISH P DECOMP Broke Out and LID BHA. Broke out, LID Fish. 100% Recovery. Recovered: Cut Jt, Pup Jt and K Anchor, Packer wi Millout Extension, and 3-1/2" Tail Pipe wi Profile Nipples and WLEG. Total Length of Fish 100.04'. 04:00 - 04:30 0.50 FISH N DPRB DECOMP Cleaned and Cleared Rig Floor. 04:30 - 05:30 1.00 FISH N DPRB DECOMP Held PJSM. R I U Slickline Unit to Fish Chemical Cutter out of Printed: 9/4/2002 10:51 :08 AM '} Legal Well Name: S-18 Common Well Name: S-18 Spud Date: 7/27/1985 Event Name: REENTER+COMPLETE Start: 8/14/2002 End: 9/3/2002 Contractor Name: DOYON Rig Release: 9/3/2002 Rig Name: DOYON 14 Rig Number: Date Fron1~To Hours Task . Code. NPT Phase 8/19/2002 04:30 - 05:30 1.00 FISH N DPRB DECOMP Hole. 05:30 - 09:30 4.00 FISH N DPRB DECOMP RIH w/ Chemical Cutter Fishing Assembly on Slickline. 1.38" Grapple, 4.40" Bell Guide. Fishing Assembly Stacked Out at 11,453', Made Several Attempts to Work Through with No Success. POOH w/ Fishing Assembly. Changed out 4.40" Bell Guide for a 3.80" Bell Guide. RIH w/ Chemical Cutter Fishing Assembly. Stacked Out at 11,453', Again Made Several Attempts to Work Through the Obstruction with No Success. POOH w/ Slickline. 09:30 - 10:00 0.50 FISH N DPRB DECOMP R / D HES Slickline. 10:00 - 11 :30 1.50 FISH N DPRB DECOMP Held PJSM. RIH w/6-3/4" Drill Collars and 5" HWDP. Broke Out and L / D Same. 11 :30 - 12:00 0.50 FISH N DPRB DECOMP R / U to Run 4-3/4" BHA Equipment. 12:00 - 14:30 2.50 FISH N DPRB DECOMP Held PJSM. M / U Fishing BHA-5-3/4" Cut Lip Guide - Overshot Extension - Overshot Bowl w/ 2-1/8" Basket Grapple - Bumper Sub - 4-3/4" Oil Jars - Pump Out Sub - 8 x 4-3/4" D.C. - 16 X 3-1/2" HWDP - XO. BHA Length 747.93'. Top of Fish 11,695'. 14:30 - 17:30 3.00 FISH N DPRB DECOMP RIH w/ Fishing BHA on 4" DP to 10,350' 17:30 - 18:30 1.00 FISH N DPRB DECOMP Held PJSM. Cut and Slipped 60' of Drilling Line. 18:30 - 19:00 0.50 FISH N DPRB DECOMP RIH w/ Fishing BHA on 4" DP to 11,299'. 19:00 - 19:30 0.50 FISH N DPRB DECOMP M / U Top Drive Broke Circulation. Established Parameters: String Weight Up 230,000#, String Weight Down 150,000#, String Weight Rotating 180,000#, RPM 40, Torque 7,000 ft / Ibs; Pump Rates: 6 bpm-950 psi, 7 bpm-1 ,280 psi. Washed Down from 11,299' to 11,445'. Drill String Torqued up to 15,000 ft / Ibs, Set down w/ 10,000#. Worked Drill String in Attempt to Work Through Obstruction with No Success. Set down with Maximum 20,000#, Drill String Picked up Clean, No overpull. 19:30 - 20:30 1.00 FISH N DPRB DECOMP Lined up to Reverse Circulate the Well. Closed Annular and Broke Circulation. Reverse Circulated, Pump Rate 9 bpm, 2,650 psi. Reverse Circulated 2 x Bottoms Up, Very Slight Show of Gas, Very Slight Show of Scale and Metal Cuttings. 20:30 - 21 :30 1.00 FISH N DPRB DECOMP Lined up for Conventional Circulation. Attempted to Wash Down Through Obstruction at 11,445'. Drill String Torqued up to 12,000 ft / Ibs, Set down w/ 30,000#. Drill String Picked Up Clean, No Overpull. Could Not Work Through Obstruction at 11,445'. 21 :30 - 22:00 0.50 FISH N DPRB DECOMP Circulated Well, Pump Rate 7 bpm, 1,410 psi. Shut Down Pumps, Flow Checked Well, Well Static. 22:00 - 00:00 2.00 FISH N DPRB DECOMP POOH w/ 4" DP to 5,740'. 8/20/2002 00:00 - 01 :30 1.50 FISH N DPRB DECOMP Held PJSM. POOH w/4" DP from 5,740' to 750' 01 :30 - 02:30 1.00 FISH N DPRB DECOMP POOH w/ BHA to Surface. Lost Cut Lip Guide and Mill Guide Control from Overshot in Hole. 02:30 - 03:30 1.00 FISH N DPRB DECOMP Broke out and L / D Overshot Assembly. 03:30 - 04:00 0.50 FISH N DPRB DECOMP Evaluated Well operations with Anchorage. Decision Made to Come Up Hole and Set Whipstock in 9-5/8" Casing. 04:00 - 04:30 0.50 BOPSUR P DECOMP M / U Retrieving Tool, Latch and Pull Wear Bushing & Set Test Plug. 04:30 - 07:30 3.00 BOPSUR P DECOMP R / U BOP Test Equipment. Test BOPE to 250 psi low /5 min, 3500 psi high / 5 min. Witness of test waived by AOGCC rep. Chuck Sheave 07:30 - 08:00 0.50 BOPSUR P DECOMP R / D Test Equipment. Pull Test Plug. Install Wear Bushing. 08:00 - 09:30 1.50 FISH DECOMP RIH w/ 4.75" DC'c & 3.5" HWDP. POOH L / D same. Printed: 9/4/2002 10:51 :08 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Daté FtÓm...Tö 8/20/2002 09:30 - 10:30 10:30 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 21 :30 21 :30 - 23:00 8/21/2002 23:00 - 00:00 00:00 - 01 :00 01 :00 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 14:30 14:30 - 15:30 15:30 - 17:00 17:00 - 00:00 8/22/2002 00:00 - 02:30 02:30 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 18:30 18:30 - 21 :30 S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 1.00 CLEAN P 5.00 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 3.50 CLEAN P 1.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 4.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.00 STWHIP P 0.50 STWHIP P 6.00 STWHIP P 1.00 STWHIP P 1.50 STWHIP P 7.00 STWHIP P 2.50 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 4.50 STWHIP P 1.00 STWHIP P 1.00 BOPSURP 4.50 DRILL C 3.00 DRILL C Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INT1 INT1 M / U BHA #5. Bull Nose, Mill, Scraper, 2 - Boot Baskets, LBS, Oil Jars, 9 - Dc's, 15 - HWDP, & DP. Empty and inspect boot baskets. (No metal or cement recovered) TIH w/ BHA #5 on 4.5" DP. Wash Down Last Stand. Tag Liner Top @ 11378'. Reverse Circulate @ 402 gpm, 2200 psi. Pump sweep around @ 580 gpm, 3900 psi. Flow Check. Pump Dry Job. POOH. Change out handling tools for BHA. Stand back BHA. L / 0 Scraper & boot baskets. R / U Electric Line unit to run BP. R IU Electric line unit. RIH w/ 9 5/8" bridge plug on electric line. Tag top of 7" liner @ 11376'. Run GR / CCL correlation log f/11376 ' - 10600'. Tie-in with liner top & previous GR log. Set BP @ 10960'. Pull up 80 '. TIH tag top of BP. POOH. R / 0 Electric line unit. Close Blind rams. Test casng & BP to 3500 psi. Make up whipstock assembly BHA #6: Anchor, Slide, Starting Mill, Lower Mill, Upper Mill, HWDP, Float Sub, MWD / UBHO, LBS, 9 - DC's, 15 - HWDP, & XO. Orient tools. Surface test MWD. TIH with whipstock on 4" DP @ 1.5 min / stand. Orient Whipstock to 60 deg right. Set Whipstock @ 10960' (btm). Trip anchor. Shear off Whipstock. Swap hole to 11.0 ppg LSND mud system @ 454 gpm, 3130 psi. Circulating rates: 300 gpm 1750 psi 400 gpm 2780 psi 450 gpm 3340 psi 500 gpm 3900 psi Mill Window in 95/8" casing. Top of Window @ 10936'. Bottom of Window @ 10952'. Drill to 10957'. 395 gpm, 2580 psi. Drilling formation f/1 0957' - 10966'. 395 gpm, 2580 psi. Pump sweep around. Circulate and condtion mud for FIT. 400 gpm, 2580 psi. FIT. MW = 11.0 ppg, TVD = 8363'. Pressure = 660 psi. EMW = 12.5 ppg. Polish up window. Flow check. Pump slug. TOOH. Stand back 56 stands of 4" DP. Continue POOH laying down 4" DP to make room in derrick for 5"DP. LD Whipstock assembly. Clear rig floor. PU stack washer & wash stack to clear milling debris. LD tool. PU BHA #7: Bit, Mtr, Float sub, Stab, MWD, 2 NM Hang of subs, 3 NM Flex DC's, Jars, XO, 65 Stds 4" DP, XO. Orient mtr, Initialize MWD. Shallow test MWD prior to picking up 4" DP. TIH to 6885'. Cut & Slip Drill line. Change out Top Drive saver sub to 5" HT. Chage grabber dies in TO & roughneck. Change out elevators Printed: 9/4/2002 10:51 :08 AM ") ) Legal Well Name: Com man Well Name: Event Name: Contractor Name: Rig Name: S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Phase Date FrOm-To 8/22/2002 18:30 - 21 :30 3.00 DRILL C 21 :00 - 00:00 3.00 DRILL C 8/23/2002 00:00 - 03:00 3.00 DRILL C 03:00 - 04:00 1.00 DRILL C INT1 INT1 INT1 INT1 04:00 - 23:00 19.00 DRILL C INT1 23:00 - 00:00 1.00 DRILL C INT1 8/24/2002 00:00 - 01 :00 1.00 DRILL C INT1 01 :00 - 01 :30 0.50 DRILL C INT1 01 :30 - 02:00 0.50 DRILL C INT1 02:00 - 03:00 1.00 DRILL C INT1 03:00 - 03:30 0.50 DRILL C INT1 03:30 - 08:30 5.00 DRILL C INT1 08:30 - 10:30 2.00 DRILL C INT1 10:30 - 12:30 2.00 CASE C INT1 12:30 - 13:00 0.50 CASE C INT1 13:00 - 18:00 5.00 CASE C INT1 18:00 - 18:30 0.50 CASE C INT1 18:30 - 19:30 1.00 CASE C INT1 19:30 - 22:00 2.50 CEMT C INT1 22:00 - 23:00 1.00 CEMT C INT1 Spud Date: 7/27/1985 End: 9/3/2002 and handling tools to 5" DP. TIH picking up 5" DP from pipe shed. PU total 33 jts and rack back in derrick. Continue TIH. 8000' @ report time. Continue TIH picking up 5" DP from pipe shed. Break circulation. 460 gpm, 3240 psi. 500 gpm, 3700 psi. Orient tool face to slide through window. Pumps off. MAD pass fl 10880' - 10960' (180 ft/hr). Slight wobble as pass through window. Tag up @ 10960'. Drill directionally fl 10966' - 11705'. 500 gpm, 3900 psi, 5 -10 K WOB. Reduce rate to 470 gpm, 3820 psi on bottom. PU wt = 230 K, SO wt = 118 K, ROT wt = 118 K. AST: 10.9 hrs, ART: 2.17 Hrs, ADT: 12.26 hrs. TO: 8 K off btm, 12 K on btm. Circulate up sample for Geology. Circulate sweep around and hole clean. Some splintering shale in returns. Continue to circulate up cutting sample and sweep around. Rotate @ 80 rpm and reciprocate drill string. 470 gpm, 3600 psi. TO = 6 K. Wiper trip to 9 5/8" window @ 10936'. Hole slick. PU wt pumps off = 250 K. TIH to bottom @ 11705'. No fill. Hole slick. Circulate sweep around @ 500 gpm, 3780 psi. TO = 6 K. Spot Liner pill on bottom. Flow Check. Pump slug. Drop 2" rabbit. POOH for 7" liner. Stand back 5" & 4" DP. SLM. Flow check @ 9 5/8" casing window. LD BHA #7. Clear rig floor. RU Liner equipment. PJSM. Run 7" liner and jewelry: Float shoe, 1 jts 7", Float Collar, 1 jt 7", Landing Collar (insert type in Jt #3 pin), 20 Jts 7" 26# L-80 BTC-M Liner. Baker-Lok Shoe track. PU wt = 75 K, SO wt = 75 K, Liner wt = 20 K. RD 7" Liner tools. MU liner hanger. PU 1 stand 4" DP. Circulate liner volume @ 220 gpm, 140 psi. TIH with 7" liner on 61 stands + 20' pup jt of 4" DP. Change out handling tools to 5". Continue TIH with 7" liner on 5" DP to 9 5/8" casing window @b 10936'. Circulate Liner volume @ window. 296 gpm, 1220 psi. PU wt = 225 K, SO wt = 160 K. Continue TIH with 7" liner to 11675'. MU cement head and lines. Break Circulation & wash to bottom. 100 gpm, 600 psi. Stage pumps up to 296 gpm (7 bpm), 1750 psi. Hole packed off. Work pipe, regain circulation. Set pipe on bottom and stage pumps up to 210 gpm (5 bpm), 1000 psi. RU cementers. PJSM with rig crew and cementers. Batch cement. Switch to Dowell. Pump 5 bbls 12.5 ppg Mud Push XL. Test lines to 4000 psi. Pump 20 bbls 12.5 ppg Mud Push XL @ 5 bpm, 850 psi. Mix & pump 42 bbls (152 sxs) 15.8 ppg, 1.53 ft^3 I sx yield, class "G" cement @ 5 bpm, 1050 psi. Drop pump down plug. Pump 5 bbls water. Switch to rig pumps for displacement. Pump Displacement @ 5 bpm, 500 psi. Pressue increase as Printed: 9/4/2002 10:51 :08 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/24/2002 22:00 - 23:00 23:00 - 23:30 8/25/2002 23:30 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:00 02:00 - 05:30 05:30 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 15:00 15:00 - 18:30 8/26/2002 18:30 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 04:00 - 06:30 06:30 - 07:30 07:30 - 08:00 S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Hòurs Task Code NPT Phase 1.00 CEMT C INT1 0.50 CEMT C INT1 0.50 CEMT C 0.50 CEMT C INT1 INT1 0.50 CEMT C 1.00 CASE C 3.50 CASE C 1.50 CASE C INT1 INT1 INT1 INT1 2.00 CASE C 0.50 CASE C 5.50 CASE C INT1 INT1 INT1 3.50 DRILL P PROD1 5.00 DRILL P 0.50 DRILL P 2.00 DRILL P PROD1 PROD1 PROD1 1.00 DRILL P 1.00 DRILL P PROD1 PROD1 2.50 DRILL P PROD1 1.00 DRILL P PROD1 0.50 DRILL P PROD1 ) Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 mud push going around the corner. Pressure increase to 1120 psi by the time cement is rounding the corner. Pump pressure continued up. Pumped 178 total bbls displacement to bump plug. 113 bbls pmp'd Mud push around 138 bbls Cement around 157 bbls 166 bbls 174 bbls Lost most returns 176 bbls No returns 178 bbls Bump Plug Lost a total of 7 bbls during displacement. Bumped Plug to 4000 psi to set hanger. Bleed pressure off to check floats. Release Liner Hanger. Pressure up to 500 psi and pull pack off from sealing area on packer. Circulate 317 gpm @ 2050 psi to move any cement up hole. PU to release packer setting dogs. Slack off several times 50 - 75 K to set ZXP Liner Top Packer. Packer top @ 10764'. Circulate bottoms up @ 512 gpm, 3290 psi. Continue to circulate bottoms up after 7" Liner cement job @ 512 gpm, 3200 psi. Saw increase blinding shakers, pH up from 8.1 to 11.4, weight increase to 11.2 ppg from 11.0 +. No absolute indication of Cement or Mud Push. ND cement head. Slip and cut drill line. POOH laying down 5" DP. Change out saver sub on top drive to 4" HT 38. Change out to 4" handling equipment. POOH standing back 4" DP. LD liner running tool & clear rig floor. Pull wear bushing. Set test plug. RU & test BOPE to 250 psi low /5 min, 3500 psi high / 5 min. Test Annular to 250 psi low / 5 min, 2500 psi high / 5 min. AOGGCC John Spaulding waived witness of test. Pull Test plug. Set wear bushing. PU BHA # 8: Bit, Mud Mtr, Float sub, LWD / MWD, Hang off sub, PWD, Hang off sub, 3 - Flex DC's, Circulating sub, XO. Shllow test MWD. TIH picking up 4" DP from pipe shed. TIH with 4" DP stands from derrick. Continue TIH w/ BHA # 8 to 11580'. Break circulation, washing last stand down. 106 gpm, 1070 psi. Test 7" casing, liner top, & 9 5/8" casing to 3500 psi / 30 min. Wash last stand down to Landing collar @ 11625'. Drill landing collar, float collar, & shoe track to 11700'. Start mud swap as drilling down. 254 gpm, 2700 psi. Circulate new QUIKDRILn 8.5 ppg mud around. Max circulating pressure 3300 psi @ 264 gpm. Final 326 gpm, pressure 2100 psi. Drill float shoe and 20' new formation to 12725'. 5 bpm 5bpm 3.7 bpm 2 bpm 2 bpm 2 bpm 610 psi 930 psi 1740 psi 2890 psi 3380 psi 3200 psi 4000 psi Pull into casing shoe. Perform FIT test to 9.5 ppg EMW. TVD: 8867', MW: 8.5 ppg, Pressure: 460 psi. Establish baseline Printed: 9/4/2002 10:51 :08 AM ') ) Legal Well Name: Com man Well Name: Event Name: Contractor Name: Rig Name: Date S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 8/26/2002 8/27/2002 8/28/2002 8/29/2002 8/30/2002 07:30 - 08:00 08:00 - 00:00 00:00 - 06:00 06:00 - 07:30 07:30 - 08:00 08:00 - 00:00 00:00 - 10:00 10:00 - 12:00 12:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 11 :00 11 :00 - 15:30 15:30 - 19:30 19:30 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 17:30 17:30 - 19:00 19:00 - 21 :00 21 :00 - 22:30 22:30 - 00:00 0.50 DRILL P 16.00 DRILL P 6.00 DRILL P 1.50 DRILL P 0.50 DRILL P 16.00 DRILL P 10.00 DRILL P 2.00 DRILL P 12.00 DRILL P 1.50 DRILL P 0.50 DRILL P 2.00 DRILL P 1.00 DRILL P 6.00 DRILL P 4.50 DRILL P 4.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL P P P P P 17.50 DRILL P 1.50 DRILL P 2.00 DRILL P 1.50 DRILL P 1.50 DRILL P Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 ECD @ 8.75 ppg. Directionally drill f/12705' -12771'. GPM: 320 , Pmp Press: 2450 psi on btm, 2000 psi off btm, WOB: 10 K , TO: 13.5K on btm, 12.0 K off btm, AST: 8.69 hrs, ART: 2.59 hrs, ADT: 11.28 hrs. 9.08 ECD. Directionally drill f/12771'- 12976'. GPM: 320, Pmp Press: 2000 psi off btm. 9.0 ECD. Pump sweep around. Prep for wiper trip. Trouble getting weight to bit for sliding. Backream to 7" casing shoe @ 10705'. Hole in good shape. Backream to knock down dog legs for sliding. TIH. Hole Slick. Directionally drill f/12976' - 13765'. 320 gpm, Pmp Press: 2450 psi on btm, 2030 psi off btm, WOB: 5 - 15 K , TO:11 K on btm, 9 K off btm, AST: 11.5 hrs, ART: 2.07 hrs, ADT: 13.57 hrs. 9.14 ECD. Drill directionally f/13765' - 14319'. 320 gpm, 2580 psi on btm, 2280 psi off btm.. 9.5 K TO on btm, 8.5 K off btm with 80 rpm. AST: 1.67 hrs, ART: 1.84 hrs, ADT: 3.51 hrs Wiper trip to 12987'. Hole slick. Wash last two stands to bottom. Directionally drill f/14319' - 14903'. 320 gpm, Pmp Press: 2720 psi on btm, 2400 psi off btm, WOB: 5 - 15 K , TO: 11 K on btm, 9 K off btm, Daily Total AST: 7.05 hrs, ART: 5.00 hrs, ADT: 12.05 hrs. 9.30 ECD. Directionally drill f/14903' - 14912'. Difficulty sliding, getting weight to bit, & holding tool face. Wiper trip to 14300'. Hole slick. TIH. Wash & ream last 125' to bottom. Pump sweep around. Attempt to drill new hole. Differential on motor high (+700 psi), no ROP. Saw some trip gas. Finish ciculating sweep out of hole and bottoms up sample. Flow Check. POOH for bit I motor. Flow Checks @ 7" shoe & 7" liner top. POOH with BHA #8. Change out Mud Motor & Bit. Data acquisition with MWD. TIH with BHA #9. Shallow test MWD. TIH wi BHA #9 on 4" DP to 10600'. Slip & cut drill line. Circulate bottoms up. TIH. Tag up @ 14851'. Wash I Ream to TO @ 14912'. Directionally drill f/14912' -14930'. Daily AST: 1.04 hrs, ART: 0.1 hrs, ADT: 1.14 hrs. 325 gpm, 2350 psi off btm, 2500 psi on btm. TO: 8 K off btm, 11 K on btm. WOB: 15 30 K. Directionally drill f/14930' - 15937' (Hole TO). Daily AST:4.89 hrs, ART: 5.56 hrs, ADT: 10.45 hrs. 325 gpm, 2370 psi off btm, 2670 psi on btm. TO: 9 K off btm, 12.5 K on btm. WOB: 15 - 30 K. Had some trip gas on bottoms up from bit trip @ 14912'. Circulate bottoms up. Get SPR's. Flow Check. Wiper trip to 7" casing shoe # 11705'. Hole slick. 14 bbl mud loss on trip. TIH. Wash last stand to bottom @ 15937'. No fill. 4 bbl mud loss on TIH. Circulate sweep around. Chase with liner pill & spot in OH. Printed: 9/4/2002 10:51 :08 AM ) ) BP..EXPLORAT1ON ()pêt~tiÇ)r1~.~~r11rn4!ry~eÞ()r-1 Legal Well Name: S-18 Common Well Name: S-18 Spud Date: 7/27/1985 Event Name: REENTER+COMPLETE Start: 8/14/2002 End: 9/3/2002 Contractor Name: DOYON Rig Release: 9/3/2002 Rig Name: DOYON 14 Rig Number: Hòurs p~scriptióh()fOperati()ns 8/31/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Continue circulate sweep around and spot liner pill. Trip gas up @ +/- 6500 stks (12500'). 01 :00 - 07:00 6.00 DRILL P PROD1 POOH for 4.5" liner. Stand back DP. SLM. No correction. 07:00 - 09:00 2.00 DRILL P PROD1 LDBHA#9. Sm~hXR20HTDGPSB~grnded: 1 ,2,WT,A, 1 ,I,N,TD. 09:00 - 10:00 1.00 CASE P PROD1 Clear rig floor. RU to run 4 1/2" Liner. 10:00 - 12:00 2.00 CASE P PROD1 TIH w/4 1/2" solid & slotted liner per program. 12:00 - 12:30 0.50 CASE P PROD1 Service rig. 12:30 - 14:00 1.50 CASE P PROD1 Continue TIH with 4.5" Liner per program. Run total of: 1 guide shoe, 71 jts 4.5", 12.6#, IBT-M slotted liner, 38 Jts 4.5", 12.6#, IBT-M solid liner + 2 - 20' Marker jts. Spaced out per program. 14:00 - 15:00 1.00 CASE P PROD1 Change out elevators. MU liner hanger assembly of HMC 4.5" x 7" Liner hanger & ZXP liner top packer to top of liner. PU 1 stand 4" DP. PU = 94 K, SO = 87 K (Liner wt = 40 K). Break circulation. 15:00 - 18:30 3.50 CASE P PROD1 TIH with liner on 4" DP to 15900' MD (9034 TVD). Break circulation / 30 stands. Top ZXP packer @ 11534' MD (8758' TVD). 18:30 - 20:00 1.50 CASE P PROD1 Break circulation. Drop liner hanger setting ball. Pump down to seat @ 2 bpm, 410 psi. Pressure up to 1800 psi to set hanger. Bleed pressure to 500 psi. Set down 35 K to verify hanger set. Pressure up to 4200 psi to blow ball seat. PU to release setting dogs. Set down 40K & rotate to set ZXP packer. 20:00 - 23:00 3.00 CASE P PROD1 PJSM for fluid displacement. Pump 80 bbls high vis sweep and follow with 8.4 ppg 1 % KCI water. Displace mud from well @ 11 bpm, 3250 psi while recirprcating pipe. 23:00 - 00:00 1.00 CASE P PROD1 Slip and Cut drill line. 9/1/2002 00:00 - 00:30 0.50 CASE P PROD1 RU to LD DP. Pump dry job. 00:30 - 09:30 9.00 CASE P PROD1 POOH laying down 4" DP. 09:30 - 14:00 4.50 RUNCOrvP COMP Pull Wear Bushing. RU to test BOPE. Test Stack, Choke manifold, Stand pipe manifold, Top Drive IBOP, & floor valves to 250 psi low / 5 min & 3500 psi high / 5 min. Test Annular to 250 psi low / 5 min & 2500 psi high / 5 min. Witness of test waived by Jim Jones, AOGCC. RD test equipment. 14:00 -15:30 1.50 RUNCOrvP CaMP RU to run 4.5" Vam Ace 13 CR 80 tubing. Function Blinds. 15:30 - 00:00 8.50 RUNCOrvP COMP MU tail pipe assembly & S-3 packer assembly. TIH w/4.5", Vam Ace, 12.6 #,13 CR 80 tubing per completion running tally. Having difficulty with MU TO. Change out 6 jts with galled threads prior to report time. 9/2/2002 00:00 - 09:30 9.50 RUNCOrvP COMP Continue TIH w/ 4.5" completion. Total of 267 jts + 2 - 10', 1 - 8', & 1 - 4' pup jts of 12.6#, Vam Ace, 13 CR 80 tubing with completion jewelery: 6 GLM's, 4 "X" niplles, Baker S-3 production packer, & WLEG per completion tally / report. Laid down total of 10 Jts, 26 collars, & 2 XIO pup jts due to MU TO problems & galling. 09:30 - 22:00 12.50 RUNCOrvP COMP Land tubing hanger in head. Visually verify hanger landed properly in head. RILDS. 73 K weight on hanger. 22:00 - 00:00 2.00 RUNCOrvP COMP Circulate 309 bbl inhibited KCI water down the annulus, follow with 306 bbls KCI water. 9/3/2002 00:00 - 01 :30 1.50 RUNCOrvP COMP Continue to circulate inhibited KCI & KCI water down annulus. 01 :30 - 03:30 2.00 RUNCOrvP CaMP Drop ball & rod. Wait 15 min to seat. Pressure up to 3500 psi on tubing to set packer. Perform and Chart test for 30 min. Printed: 9/4/2002 10:51:08 AM ) ) BP .EXPLORATION QPØtátioQ~ ..Slll11tJ1.il~RêpOrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-18 S-18 REENTER+COMPLETE DOYON DOYON 14 Date From'"TÖ. HÖOrs Task Code NPT Phase 9/3/2002 01 :30 - 03:30 2.00 RUNCOIVP COMP 03:30 - 04:00 0.50 RUNCOIVP COMP 04:00 - 05:00 1.00 RIGD P COMP 05:00 - 07:00 2.00 WHSUR P COMP 07:00 - 08:00 1.00 WHSUR P COMP 08:00 - 09:30 1.50 WHSUR P COMP 09:30 - 10:30 1.00 WHSUR P COMP 10:30 - 12:00 1.50 RIGD P COMP Start: 8/14/2002 Rig Release: 9/3/2002 Rig Number: Spud Date: 7/27/1985 End: 9/3/2002 De$criptipnof Operations Bleed tubing down to 1500 psi. Pressure up annulus to 3500 psi. Chart tubing & annulus test for 30 min. Bleed pressure off tubing to shear RP valve @ 5700'. Tubing and annulus bled off thru tubing. Pump 3 bpm downthru RP @ 400 psi. ND test equipment. Back out landing jt and lay down. Set TWC. Test 1000 psi. ND BOPE Change out 2 each lock down screws on tbg spool. NU adaptor flange & tree. Test same 5000 psi 115 mins. RU DSM Pull TWC RU Hot Oil unit. Test lines to 3000 psi. Freeze protect well wi 165 bbls diesel. Pump rate @ 3 BPM wi max 700 psi. RD Hot Oil unit U tube diesel between IA & tbg. Set BPV. Secure well. Police location. Printed: 9/4/2002 10:51 :08 AM ') AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well S-18A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,922.34' MD Window / Kickoff Survey 10,936.00 I MD (if applicable) Projected Survey: 15,937.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ) Õì09-lb3 04-0ct-02 RECE\VED OCT 09 2.002 Ala*- Oi\ & Gas Cons. Commislion AndKßge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU- WOA S Pad S-18A ~ Job No. AKZZ22137, Surveyed: 30 August, 2002 Survey Report 30 September, 2002 Your Ref: API 500292115601 Surface Coordinates: 5979169.00 N, 618885.00 E (70021' 06.2761" N, 149002' 04.9140" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 979169.00 N, 118885.00 E (Grid) Surface Coordinates relative to Structure Reference: 1702.39 S, 941.39 E(True) Kelly Bushing: 72.29ft above Mean Sea Level Elevation relative to Project V Reference: 72.29ft Elevation relative to Structure Reference: 72.29ft 5ï,,,,,""""'Y-5UI! b A 'I '~' Cll,nir~~~~-S"E?A~\( Ice 5 A Halliburton Company Survey Ref: svy11292 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A Your Ref: API 500292115601 Job No. AKZZ22137, Surveyed: 30 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10922.34 44.970 174.690 8270.91 8343.20 6540.52 S 701.26 E 5972640.42 N 619689.94 E 2570.26 Tie On Point AK-6 BP _IFR-AK 10936.00 45.050 174.700 8280.57 8352.86 6550.14 S 702.15 E 5972630.82 N 619690.99 E 0.588 2574.16 Window Point 11035.52 47.160 175.640 8349.57 8421.86 6621.60 S 708.18 E 5972559.47 N 619698.15 E 2.227 2603.67 11133.11 47.070 183.260 8416.04 8488.33 6693.00 S 708.87 E 5972488.09 N 619699.97 E 5.720 2637.81 11227.49 47.510 184.110 8480.05 8552.34 6762.21 S 704.41 E 5972418.82 N 619696.61 E 0.809 2675.39 ~ 11323.41 47.110 185.220 8545.09 8617.38 6832.48 S 698.68 E 5972348.47 N 619692.00 E 0.947 2714.59 11417.58 48.750 185.310 8608.19 8680.48 6902.08 S 692.26 E 5972278.77 N 619686.69 E 1.743 2754.07 11513.06 48.320 187.330 8671.41 8743.70 6973.19 S 684.39 E 5972207.55 N 619679.94 E 1.648 2795.55 11621.24 50.440 192.210 8741.86 8814.15 7054.05 S 670.41 E 5972126.47 N 619667.25 E 3.944 2847.11 11642.15 50.550 192.710 8755.16 8827.45 7069.81 S 666.93 E 5972110.66 N 619664.02 E 1.919 2857.82 11746.74 53.090 189.980 8819.82 8892.11 7150.40 S 650.80 E 5972029.82 N 619649.16E 3.179 2911.14 11779.20 55.070 189.100 8838.86 8911.15 7176.33 S 646.44 E 5972003.83 N 619645.22 E 6.483 2927.56 11810.23 58.540 189.490 8855.85 8928.14 7201.95 S 642.25 E 5971978.15 N 619641.43 E 11 .232 2943.69 11842.52 60.820 189.880 8872.15 8944.44 7229.42 S 637.56 E 5971950.61 N 619637.18 E 7.138 2961.16 11876.06 62.700 190.000 8888.01 8960.30 7258.52 S 632.46 E 5971921.43 N 619632.54 E 5.614 2979.78 11907.48 66.030 189.360 8901.61 8973.90 7286.44 S 627.70 E 5971893.43 N 619628.23 E 10.756 2997.52 11938.15 69.170 189.610 8913.29 8985.58 7314.41 S 623.02 E 5971865.40 N 619624.00 E 10.266 3015.21 11973.91 70.950 189.070 8925.49 8997.78 7347.58 S 617.57 E 5971832.15 N 619619.07 E 5.176 3036.12 12003.43 74.300 187.800 8934.30 9006.59 7375.44 S 613.44 E 5971804.22 N 619615.38 E 12.068 3053.29 12033.88 78.040 187.180 8941 .58 9013.87 7404.75 S 609.59 E 5971774.85 N 619612.00 E 12.440 3070.91 12067.08 83.150 186.720 8947.00 9019.29 7437.25 S 605.63 E 5971742.29 N 619608.55 E 15.452 3090.19 12099.15 86.060 186.890 8950.02 9022.31 7468.95 S 601.84 E 5971710.54 N 619605.27 E 9.089 3108.92 .'"'-./ 12130.66 88.520 186.010 8951.51 9023.80 7500.23 S 598.31 E 5971679.21 N 619602.23 E 8.290 3127.23 12163.16 90.180 185.290 8951 .88 9024.17 7532.56 S 595.11 E 5971646.83 N 619599.55 E 5.567 3145.76 12194.90 94.620 184.480 8950.55 9022.84 7564.15 S 592.41 E 5971615.20 N 619597.35 E 14.219 3163.49 12226.83 99.520 184.270 8946.62 9018.91 7595.74 S 589.99 E 5971583.58 N 619595.43 E 15.360 3180.97 12259.22 100.700 184.290 8940.93 9013.22 7627.54 S 587.61 E 5971551.75 N 619593.56 E 3.644 3198.53 12323.01 98.210 185.190 8930.45 9002.74 7690.24 S 582.41 E 5971488.97 N 619589.35 E 4.144 3233.58 12384.78 97.470 183.880 8922.03 8994.32 7751.24 S 577.57 E 5971427.90 N 619585.48 E 2.418 3267.50 12414.43 97.340 183.860 8918.21 8990.50 7780.57 S 575.59 E 5971398.54 N 619583.97 E 0.444 3283.50 30 September, 2002 - 13:11 Page 2 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU~ WOA S Pad - S-18A Your Ref: API 500292115601 Job No. AKZZ22137, Surveyed: 30 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12449.54 95.600 187.250 8914.25 8986.54 7815.29 S 572.21 E 5971363.77 N 619581.14 E 10.798 3303.35 12479.56 95.360 190.500 8911.38 8983.67 7844.81 S 567.60 E 5971334.18 N 619577.00 E 10.806 3321.74 12514.91 95.910 192.960 8907.91 8980.20 7879.25 S 560.45 E 5971299.63 N 619570.39 E 7.098 3344.75 12544.03 95.980 193.280 8904.89 8977.18 7907.46 S 553.88 E 5971271 .32 N 619564.27 E 1.119 3364.22 12574.92 93.020 195.400 8902.47 8974.76 7937.29 S 546.25 E 5971241 .38 N 619557.11 E 11 .774 3385.40 ~' 12607.65 90.680 195.830 8901.41 8973.70 7968.79 S 537.44 E 5971209.74 N 619548.81 E 7.269 3408.42 12702.42 90.740 192.440 8900.24 8972.53 8060.67 S 514.31 E 5971117.50 N 619527.13 E 3.577 3473.35 12797.27 92.890 191.710 8897.24 8969.53 8153.37 S 494.47 E 5971024.50 N 619508.78 E 2.394 3535.79 12895.69 92.520 193.760 8892.59 8964.88 8249.26 S 472.80 E 5970928.28 N 619488.63 E 2.114 3601.38 12927.46 92.460 194.840 8891.21 8963.50 8280.01 S 464.96 E 5970897.41 N 619481.28 E 3.401 3623.20 12959.83 92.770 196.010 8889.73 8962.02 8311.18 S 456.36 E 5970866.10 N 619473.17 E 3.736 3645.88 12991.45 93.570 198.490 8887.98 8960.27 8341.33 S 447.00 E 5970835.81 N 619464.29 E 8.230 3668.73 13021.78 93.080 200.230 8886.23 8958.52 8369.90 S 436.97 E 5970807.09 N 619454.71 E 5.951 3691.40 13053.94 92.710 201.920 8884.60 8956.89 8399.87 S 425.42 E 5970776.94 N 619443.64 E 5.373 3716.07 13086.31 93.570 205.300 8882.83 8955.12 8429.48 S 412.47 E 5970747.13 N 619431.17 E 10.759 3741 .79 13117.90 93.880 208.670 8880.77 8953.06 8457.57 S 398.17 E 5970718.81 N 619417.31 E 10.691 3767.95 13149.35 93.510 211.750 8878.75 8951.04 8484.69 S 382.38 E 5970691.45 N 619401.95 E 9.844 3794.94 13181.33 93.200 214.910 8876.88 8949.17 8511.36 S 364.84 E 5970664.50 N 619384.84 E 9.912 3823.24 13213.25 90.620 217.970 8875.81 8948.10 8537.02 S 345.90 E 5970638.55 N 619366.30 E 12.534 3852.28 13245.45 88.950 221.280 8875.93 8948.22 8561.81 S 325;36 E 5970613.43 N 619346.17 E 11.513 3882.28 13276.52 89.690 225.200 8876.30 8948.59 8584.44 S 304.09 E 5970590.46 N 619325.25 E 12.839 3911.89 13306.67 89.320 230.430 8876.56 8948.85 8604.68 S 281.75 E 5970569.87 N 619303.24 E 17.389 3941.24 13339.79 88.340 233.580 8877.24 8949.53 8625.06 S 255.66 E 5970549.08 N 619277.48 E 9.959 3973.96 ~ 13373.50 86.610 237.050 8878.72 8951.01 8644.22 S 227.97 E 5970529.48 N 619250.10 E 11 .493 4007.47 13405.07 84.700 239.270 8881 .12 8953.41 8660.83 S 201.24 E 5970512.45 N 619223.62 E 9.261 4038.91 13437.55 83.280 242.180 8884.52 8956.81 8676.62 S 173.06 E 5970496.22 N 619195.71 E 9.925 4071.21 13468.51 85.570 246.410 8887.53 8959.82 8689.98 S 145.31 E 5970482.42 N 619168.17 E 15.479 4101.96 13501.75 88.520 251.120 8889.24 8961.53 8702.00 S 114.38 E 5970469.91 N 619137.43 E 16.702 4134.82 13534.38 91.720 255.890 8889.17 8961.46 8711.26 S 83.10 E 5970460.16 N 619106.31 E 17.602 4166.65 13564.90 91.170 253.990 8888.40 8960.69 8719.19 S 53.64 E 5970451.76 N 619076.98 E 6.479 4196.25 13598.25 88.950 253.380 8888.37 8960.66 8728.55 S 21.64 E 5970441.89 N 619045.12 E 6.903 4228.76 13628.20 85.570 255.020 8889.80 8962.09 8736.70 S 7.14 W 5970433.29 N 619016.48 E 12.541 4257.87 13664.16 82.660 254.620 8893.49 8965.78 8746.06 S 41.66 W 5970423.38 N 618982.11 E 8.168 4292.58 13694.59 82.540 254.790 8897.40 8969.69 8754.02 S 70.77 W 5970414.95 N 618953.13 E 0.680 4321.89 13724.22 82.160 254.650 8901.35 8973.64 8761.76 S 99.10 W 5970406.77 N 618924.93 E 1.365 4350.40 30 September, 2002 - 13:11 Page 3 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_WOA S Pad - S-18A Your Ref: API 500292115601 Job No. AKZZ22137, Surveyed: 30 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO /1 OOft) 13760.33 81 .480 250.810 8906.49 8978.78 8772.37 S 133.22 W 5970395.62 N 618890.98 E 10.693 4385.37 13794.43 80.670 249.910 8911.78 8984.07 8783.69 S 164.95 W 5970383.79 N 618859.44 E 3.527 4418.60 13824.28 80.290 250.550 8916.72 8989.01 8793.65 S 192.65 W 5970373.40 N 618831.89 E 2.468 4447.65 13856.55 81.300 251.210 8921.88 8994.17 8804.08 S 222.75 W 5970362.49 N 618801.97 E 3.724 4479.02 13888.60 81.790 252.300 8926.59 8998.88 8814.01 S 252.86 W 5970352.09 N 618772.02 E 3.695 4510.15 ~ 13920.49 82.410 253.900 8930.97 9003.26 8823.19 S 283.08 W 5970342.43 N 618741.95 E 5.336 4541.02 13952.42 84.830 256.230 8934.52 9006.81 8831.37 S 313.74 W 5970333.77 N 618711.42 E 10.489 4571.78 13984.80 85.320 256.850 8937.30 9009.59 8838.88 S 345.11 W 5970325.76 N 618680.17E 2.435 4602.84 14016.96 85.630 256.750 8939.84 9012.13 8846.20 S 376.32 W 5970317.95 N 618649.08 E 1.013 4633.67 14048.58 84.700 257.870 8942.50 9014.79 8853.12 S 407.06 W 5970310.54 N 618618.46 E 4.594 4663.89 14080.25 83.650 258.670 8945.72 9018.01 8859.52 S 437.91 W 5970303.64 N 618587.72 E 4.160 4693.96 14112.53 83.830 260.050 8949.24 9021.53 8865.45 S 469.44 W 5970297.22 N 618556.28 E 4.286 4724.39 14144.63 84.890 264.120 8952.39 9024.68 8869.84 S 501.07 W 5970292.32 N 618524.72 E 13.042 4754.16 14174.39 84.950 263.430 8955.03 9027.32 8873.06 S 530.54 W 5970288.64 N 618495.31 E 2.318 4781.47 14207.62 86.430 264.190 8957.53 9029.82 8876.63 S 563.48 W 5970284.55 N 618462.42 E 5.004 4811.99 14238.92 84.770 266.980 8959.93 9032.22 8879.03 S 594.60 W 5970281.65 N 618431.36 E 10.349 4840.34 14270.43 85.260 268.250 8962.67 9034.96 8880.34 S 625.96 W 5970279.85 N 618400.02 E 4.306 4868.37 14302.63 85.260 269.830 8965.33 9037.62 8880.88 S 658.04 W 5970278.80 N 618367.95 E 4.890 4896.66 14332.68 86.860 270.500 8967.39 9039.68 8880.79 S 688.02 W 5970278.41 N 618337.97 E 5.770 4922.81 14380.19 89.630 272.280 8968.85 9041 .14 8879.64 S 735.49 W 5970278.81 N 618290.49 E 6.929 4963.71 14428.00 91.410 274.320 8968.41 9040.70 8876.89 S 783.21 W 5970280.80 N 618242.73 E 5.663 5004.07 14475.97 91.350 274.570 8967.26 9039.55 8873.17 S 831.02 W 5970283.76 N 618194.86 E 0.536 5044.03 14525.88 91.170 275.040 8966.16 9038.45 8868.99 S 880.75 W 5970287.15 N 618145.08 E 1.008 5085.43 ~ 14572.86 90.430 274.760 8965.51 9037.80 8864.98 S 927.55 W 5970290.42 N 618098.22 E 1.684 5124.37 14622.11 90.920 275.640 8964.93 9037.22 8860.52 S 976.59 W 5970294.10 N 618049.11 E 2.045 5165.04 14664.02 91.230 275.990 8964.14 9036.43 8856.27 S 1018.28 W 5970297.69 N 618007.36 E 1.115 5199.39 14716.62 91.970 278.150 8962.67 9034.96 8849.80 S 1070.46 W 5970303.33 N 617955.09 E 4.339 5241.82 14764.16 92.650 280.390 8960.75 9033.04 8842.15 S 1117.33W 5970310.24 N 617908.10 E 4.920 5279.05 14812.86 93.450 282.960 8958.16 9030.45 8832.31 S 1164.95 W 5970319.32 N 617860.33 E 5.520 5315.86 14844.69 93.080 286.320 8956.35 9028.64 8824.28 S 1195.70 W 5970326.86 N 617829.46 E 10.603 5338.81 14912.44 93.020 287.280 8952.74 9025.03 8804.72 S 1260.46 W 5970345.39 N 617764.39 E 1.418 5385.88 14943.23 91.170 288.320 8951.62 9023.91 8795.32 S 1289.76 W 5970354.33 N 617734.95 E 6.892 5406.89 14975.33 91.540 288.700 8950.86 9023.15 8785.13 S 1320.19 W 5970364.03 N 617704.37 E 1.652 5428.52 15008.31 88.340 289.230 8950.89 9023.18 8774.41 S 1351.37 W 5970374.25 N 617673.01 E 9.835 5450.55 15102.44 87.170 292.770 8954.58 9026.87 8740.71 S 1439.17 W 5970406.55 N 617584.69 E 3.958 5510.84 30 September, 2002 - 13:11 Page 4 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A Your Ref: API 500292115601 Job No. AKZZ22137, Surveyed: 30 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 15158.27 89.820 295.330 8956.05 9028.34 8717.97 S 1490.13 W 5970428.48 N 617533.38 E 6.598 5544.29 15198.93 89.510 295.780 8956.29 9028.58 8700.43 S 1526.81 W 5970445.44 N 617496.43 E 1.344 5567.80 15248.94 88.030 296.150 8957.36 9029.65 8678.54 S 1571.76 W 5970466.61 N 617451.14 E 3.050 5596.42 15294.65 88.890 296.450 8958.59 9030.88 8658.30 S 1612.72 W 5970486.20 N 617409.86 E 1.993 5622.35 15344.47 88.830 295.830 8959.58 9031.87 8636.35 S 1657.44 W 5970507.44 N 617364.80 E 1.250 5650.74 .~ 15392.17 89.080 297.520 8960.45 9032.74 8614.94 S 1700.05 W 5970528.17 N 617321.85 E 3.581 5677.55 15438.20 88.710 297.320 8961.34 9033.63 8593.75 S 1740.90 W 5970548.71 N 617280.67 E 0.914 5702.92 15486.82 89.020 294.900 8962.30 9034.59 8572.36 S 1784.55 W 5970569.41 N 617236.69 E 5.017 5730.64 15535.73 88.710 292.080 8963.27 9035.56 8552.87 S 1829.39 W 5970588.18 N 617191.54E 5.799 5760.33 15583.96 88.460 290.610 8964.46 9036.75 8535.32 S 1874.30 W 5970605.02 N 617146.36 E 3.091 5791.02 15631.52 89.020 288.840 8965.51 9037.80 8519.27 S 1919.05 W 5970620.35 N 617101.36E 3.903 5822.31 15680.67 89.140 287.980 8966.30 9038.59 8503.75 S 1965.68 W 5970635.13 N 617054.49 E 1.766 5855.49 15728.20 89.140 288.740 8967.01 9039.30 8488.78 S 2010.79 W 5970649.38 N 617009.15 E 1.599 5887.61 15774.35 91.170 288.220 8966.88 9039.17 8474.16 S 2054.56 W 5970663.31 N 616965.16 E 4.541 5918.73 15869.95 92.770 288.700 8963.60 9035.89 8443.90 S 2145.18 W 5970692.12 N 616874.06 E 1.747 5983.18 15937.00 92.770 288.700 8960.36 9032.65 8422.43 S 2208.62 W 5970712.59 N 616810.29 E 0.000 6028.15 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 240.880° (True). ~ Magnetic Declination at Surface is 25.975°(22-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 15937.00ft., The Bottom Hole Displacement is 8707.20ft., in the Direction of 194.694° (True). 30 September, 2002 - 13:11 Page 5 of 6 DríllQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A Your Ref: API 500292115601 Job No. AKZZ22137, Surveyed: 30 August, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10922.34 10936.00 15937.00 8343.20 8352.86 9032.65 6540.52 S 6550.14 S 8422.43 S 701.26 E 702.15 E 2208.62 W Tie On Point Window Point Projected Survey ~ Survey tool program for S-18A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10922.34 0.00 10922.34 8343.20 15937.00 8343.20 AK-2 BP _CG - BP Conventional Gyro(S-18) 9032.65 AK-6 BP _IFR-AK(S-18A) ~' 30 September, 2002 - 13:11 Page 6 of 6 DrillQuest 3.03.02.002 ') ) ~ Q;¡- /03 03-0ct-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-18A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,922.34' MD Window / Kickoff Survey 10,936.00' MD (if applicable) Projected Survey: 15,937.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED OCT 0 9 2002 Alastta or¡ & Gas Cons.Commia8ion Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU- WOA S Pad S-18A MWD ~. Job No. AKMW22137, Surveyed: 22 August, 2002 Survey Report 30 September, 2002 Your Ref: API 500292115601 Surface Coordinates: 5979169.00 N, 618885.00 E (70021' 06.2761" N, 149002' 04.9140" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,~ Surface Coordinates relative to Project H Reference: 979169.00 N, 118885.00 E (Grid) Surface Coordinates relative to Structure Reference: 1702.39 S, 941.39 E(True) Kelly Bushing: 72.29ft above Mean Sea Level Elevation relative to Project V Reference: 72.29ft Elevation relative to Structure Reference: 72.29ft spe""''''''V-5UI! DR I L:t:rl\íl3'-^5fe]¡.~vTE"es A Halliburton Company Survey Ref: svy11327 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A MWD Your Ref: API 500292115601 Job No. AKMW22137, Surveyed: 22 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (1t) (ft) (ft) (o/100ft) 10922.34 44.970 174.690 8270.91 8343.20 6540.52 S 701.26 E 5972640.42 N 619689.94 E 2570.26 Tie On Point MWD Magnetic 10936.00 45.050 174.700 8280.57 8352.86 - 6550.14 S 702.15 E 5972630.82 N 619690.99 E 0.588 2574.16 Window Point 11035.52 47.160 175.500 8349.57 8421.86 6621.59 S 708.27 E 5972559.48 N 619698.24 E 2.198 2603.59 11133.11 47.070 182.930 8416.03 8488.32 6693.00 S 709.25 E 5972488.10 N 619700.35 E 5.578 2637.48 11227.49 47.510 183.810 8480.05 8552.34 6762.22 S 705.17 E 5972418.82 N 619697.37 E 0.829 2674.73 ~/ 11323.41 47.110 185.410 8545.09 8617.38 6832.50 S 699.51 E 5972348.46 N 619692.83 E 1.295 2713.88 11417.58 48.750 185.570 8608.18 8680.47 6902.08 S 692.82 E 5972278.78 N 619687.24 E 1.746 2753.58 11513.06 48.320 187.670 8671 .41 8743.70 6973.14 S 684.58 E 5972207.60 N 619680.13 E 1.709 2795.36 11621.24 50.440 192.410 8741.86 8814.15 7053.94 S 670.22 E 5972126.58 N 619667.05 E 3.859 2847.23 11642.15 50.550 192.710 8755.16 8827.45 7069.69 S 666.71 E 5972110.78 N 619663.79 E 1.226 2857.96 11746.74 53.090 189.730 8819.82 8892.11 7150.32 S 650.75 E 5972029.91 N 619649.12 E 3.303 2911 . 13 11779.20 55.070 188.460 8838.86 8911.15 7176.27 S 646.60 E 5972003.89 N 619645.38 E 6.873 2927.39 11810.23 58.540 189.310 8855.84 8928.13 7201.92 S 642.59 E 5971978.18 N 619641.77 E 11.415 2943.38 11842.52 60.820 189.860 8872.14 8944.43 7229.41 S 637.95 E 5971950.63 N 619637.57 E 7.212 2960.81 11876.06 62.700 189.790 8888.01 8960.30 7258.52 S 632.90 E 5971921.44 N 619632.99 E 5.608 2979.38 11907.48 66.030 189.600 8901.61 8973.90 7286.44 S 628.13 E 5971893.45 N 619628.66 E 10.612 2997.13 11938.15 69.170 189.720 8913.29 8985.58 7314.39 S 623.38 E 5971865.42 N 619624.35 E 10.244 3014.89 11973.91 70.950 189.310 8925.49 8997.78 7347.54 S 617.82 E 5971832.19 N 619619.32 E 5.093 3035.88 12003.43 74.300 187.990 8934.30 9006.59 7375.39 S 613.59 E 5971804.28 N 619615.53 E 12.124 3053.13 12033.88 78.040 187.310 8941.58 9013.87 7404.69 S 609.65 E 5971774.92 N 619612.06 E 12.472 3070.83 12067.08 83.150 186.910 8947.00 9019.29 7437.18 S 605.60 E 5971742.37 N 619608.53 E 15.437 3090.18 12099.15 86.060 187.190 8950.02 9022.31 7468.86 S 601.68 E 5971710.63 N 619605.11 E 9.115 3109.02 ~ 12130.66 88.520 186.320 8951.51 9023.80 7500.11 S 597.98 E 5971679.32 N 619601.90 E 8.280 3127.46 12163.16 90.180 186.010 8951.88 9024.17 7532.42 S 594.49 E 5971646.96 N 619598.93 E 5.196 3146.23 12194.90 94.620 185.210 8950.55 9022.84 7563.98 S 591.39 E 5971615.36 N 619596.33 E 14.213 3164.29 12226.83 99.520 184.880 8946.62 9018.91 7595.53 S 588.61 E 5971583.76 N 619594.04 E 15.380 3182.08 12259.22 100.700 184.970 8940.93 9013.22 7627.30 S 585.87 E 5971551.96 N 619591.81 E 3.653 3199.94 12323.01 98.210 185.950 8930.45 9002.74 7689.93 S 579.88 E 5971489.24 N 619586.82 E 4.187 3235.65 12384.78 97.470 184.280 8922.03 8994.32 7750.88 S 574.42 E 5971428.21 N 619582.33 E 2.934 3270.07 12414.43 97.340 183.900 8918.21 8990.50 7780.21 S 572.33 E 5971398.85 N 619580.70 E 1.344 3286.17 30 September, 2002 - 13:18 Page 2 of6 DríllQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A MWD Your Ref: API 500292115601 Job No. AKMW22137, Surveyed: 22 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12449.54 95.600 188.290 8914.25 8986.54 7814.88 S 568.62 E 5971364.12 N 619577.54 E 13.375 3306.29 12479.56 95.360 191.370 8911.38 8983.67 7844.32 S 563.52 E 5971334.60 N 619572.91 E 10.244 3325.07 12514.91 95.910 193.680 8907.91 8980.20 7878.66 S 555.89 E 5971300.15 N 619565.83 E 6.687 3348.45 12544.03 95.980 193.880 8904.89 8977.18 7906.79 S 548.99 E 5971271.91 N 619559.38 E 0.724 3368.16 12574.92 93.020 195.730 8902.47 8974.76 7936.56 S 541.13 E 5971242.02 N 619551.98 E 11 .290 3389.52 --- 12607.65 90.680 196.150 8901.41 8973.70 7968.01 S 532.14 E 5971210.43 N 619543.50 E 7.264 3412.68 12702.42 90.740 192.760 8900.24 8972.53 8059.76 S 508.49 E 5971118.32 N 619521.30 E 3.577 3477.99 12797.27 92.890 192.120 8897.23 8969.52 8152.33 S 488.07 E 5971025.44 N 619502.36 E 2.365 3540.88 12895.69 92.520 193.790 8892.59 8964.88 8248.14 S 466.03 E 5970929.29 N 619481.84 E 1.736 3606.75 12927.46 92.460 194.930 8891.21 8963.50 8278.89 S 458.16 E 5970898.42 N 619474.46 E 3.590 3628.59 12959.83 92.770 196.080 8889.73 8962.02 8310.05 S 449.51 E 5970867.13 N 619466.31 E 3.676 3651.31 12991.45 93.570 198.470 8887.98 8960.27 8340.19 S 440.14 E 5970836.84 N 619457.41 E 7.960 3674.17 13021.78 93.080 200.040 8886.22 8958.51 8368.77 S 430.16 E 5970808.10 N 619447.88 E 5.414 3696.80 13053.94 92.710 201.740 8884.60 8956.89 8398.78 S 418.70 E 5970777.92 N 619436.91 E 5.403 3721.41 13086.31 93.570 205.010 8882.83 8955.12 8428.45 S 405.88 E 5970748.05 N 619424.56 E 10.431 3747.04 13117.90 93.880 208.580 8880.77 8953.06 8456.58 S 391.67 E 5970719.70 N 619410.80 E 11.320 3773.15 13149.35 93.510 211.460 8878.75 8951.04 8483.75 S 375.97 E 5970692.28 N 619395.53 E 9.214 3800.08 13181.33 93.200 214.790 8876.87 8949.16 8510.48 S 358.53 E 5970665.28 N 619378.51 E 10.440 3828.33 13213.25 90.620 217.610 8875.81 8948.10 8536.22 S 339.69 E 5970639.24 N 619360.09 E 11.970 3857.32 13245.45 88.950 220.850 8875.93 8948.22 8561.16 S 319.33 E 5970613.98 N 619340.12 E 11.320 3887.24 13276.52 89.690 224.850 8876.30 8948.59 8583.93 S 298.21 E 5970590.88 N 619319.36 E 13.092 3916.77 13306.67 89.320 230.140 8876.56 8948.85 8604.30 S 275.99 E 5970570.17 N 619297.47 E 17.588 3946.09 13339.79 88.340 233.090 8877.24 8949.53 8624.86 S 250.03 E 5970549.20 N 619271.85 E 9.384 3978.77 '~ 13373.50 86.610 236.590 8878.72 8951.01 8644.25 S 222.51 E 5970529.37 N 619244.63 E 11.572 4012.26 13405.07 84.700 239.140 8881.11 8953.40 8660.99 S 195.86 E 5970512.21 N 619218.25 E 10.073 4043.69 13437.55 83.280 242.020 8884.52 8956.81 8676.85 S 167.72 E 5970495.90 N 619190.37 E 9.842 4075.98 13468.51 85.570 246.030 8887.52 8959.81 8690.34 S 140.03 E 5970481.97 N 619162.89 E 14.861 4106.74 13501.75 88.520 250.260 8889.24 8961.53 8702.70 S 109.23 E 5970469.13 N 619132.29 E 15.500 4139.66 13534.38 91 .720 254.710 8889.17 8961.46 8712.51 S 78.12 E 5970458.82 N 619101.35 E 16.796 4171.61 13564.90 91.170 253.990 8888.40 8960.69 8720.74 S 48.74 E 5970450.13 N 619072.10 E 2.968 4201.28 13598.25 88.950 252.690 8888.37 8960.66 8730.30 S 16.80 E 5970440.06 N 619040.31 E 7.714 4233.84 13628.20 85.570 254.340 8889.80 8962.09 8738.79 S 11.88 W 5970431.12 N 619011.77 E 12.555 4263.03 13664.16 82.660 254.090 8893.48 8965.77 8748.52 S 46.30 W 5970420.85 N 618977.51 E 8.122 4297.83 13694.59 82.540 254.080 8897.40 8969.69 8756.79 S 75.32 W 5970412.11 N 618948.63 E 0.396 4327.21 13724.22 82.160 253.980 8901.35 8973.64 8764.87 S 103.55 W 5970403.59 N 618920.52 E 1.325 4355.81 30 September, 2002 - 13:18 Page 3 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A MWD Your Ref: API 500292115601 Job No. AKMW22137, Surveyed: 22 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (1t) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 13760.33 81 .480 249.990 8906.49 8978.78 8775.93 S 137.54 W 5970392.00 N 618886.72 E 11.098 4390.87 13794.43 80.670 249.120 8911.78 8984.07 8787.69 S 169.10 W 5970379.73 N 618855.35 E 3.463 4424.17 13824.28 80.290 249.570 8916.71 8989.00 8798.08 S 196.65 W 5970368.91 N 618827.97 E 1.957 4453.29 13856.55 81.300 250.230 8921.88 8994.17 8809.02 S 226.56 W 5970357.49 N 618798.23 E 3.724 4484.75 13888.60 81 .790 251.330 8926.59 8998.88 8819.46 S 256.50 W 5970346.58 N 618768.47 E 3.723 4515.98 ~ 13920.49 82.410 252.910 8930.97 9003.26 8829.16 S 286.56 W 5970336.41 N 618738.56 E 5.279 4546.96 13952.42 84.830 254.710 8934.52 9006.81 8838.00 S 317.03 W 5970327.08 N 618708.24 E 9.425 4577.88 13984.80 85.320 255.010 8937.30 9009.59 8846.43 S 348.17 W 5970318.16 N 618677.24 E 1.773 4609.19 14016.96 85.630 254.510 8939.84 9012.13 8854.85 S 379.10 W 5970309.25 N 618646.44 E 1.825 4640.31 14048.58 84.700 255.690 8942.50 9014.79 8862.96 S 409.55 W 5970300.66 N 618616.13E 4.741 4670.85 14080.25 83.650 257.250 8945.72 9018.01 8870.33 S 440.18 W 5970292.81 N 618585.62 E 5.917 4701.20 14112.53 83.830 258.860 8949.24 9021.53 8876.97 S 471.57 W 5970285.67 N 618554.33 E 4.989 4731.86 14144.63 84.890 261.820 8952.39 9024.68 8882.33 S 503.06 W 5970279.81 N 618522.93 E 9.752 4761.97 14174.39 84.950 261.290 8955.03 9027.32 8886.68 S 532.38 W 5970274.99 N 618493.69 E 1.785 4789.70 14207.62 86.430 262.320 8957.53 9029.82 8891.40 S 565.18 W 5970269.75 N 618460.97 E 5.421 4820.65 14238.92 84.770 264.810 8959.93 9032.22 8894.90 S 596.18 W 5970265.76 N 618430.02 E 9.541 4849.44 14270.43 85.260 265.360 8962.66 9034.95 8897.59 S 627.46 W 5970262.57 N 618398.79 E 2.333 4878.08 14302.63 85.260 266.640 8965.33 9037.62 8899.83 S 659.47 W 5970259.83 N 618366.82 E 3.962 4907.13 14332.68 86.860 267.730 8967.39 9039.68 8901.30 S 689.41 W 5970257.88 N 618336.91 E 6.438 4934.00 14380.19 89.630 270.820 8968.85 9041.14 8901.90 S 736.88 W 5970256.53 N 618289.45 E 8.732 4975.77 14428.00 91.410 272.340 8968.41 9040.70 8900.58 S 784.67 W 5970257.09 N 618241.65 E 4.896 5016.87 14475.97 91.350 273.340 8967.26 9039.55 8898.21 S 832.57 W 5970258.70 N 618193.72 E 2.088 5057.56 14525.88 91.170 275.240 8966.16 9038.45 8894.47 S 882.32 W 5970261.65 N 618143.91 E 3.823 5099.21 ..~ 14572.86 90.430 272.410 8965.50 9037.79 8891.34 S 929.19 W 5970264.04 N 618097.00 E 6.226 5138.63 14622.11 90.920 275.060 8964.92 9037.21 8888.13 S 978.33 W 5970266.46 N 618047.82 E 5.472 5179.99 14664.02 91.230 274.180 8964.14 9036.43 8884.76 S 1020.09 W 5970269.18 N 618006.00 E 2.226 5214.84 14716.62 91.970 276.500 8962.67 9034.96 8879.87 S 1072.44 W 5970273.24 N 617953.59 E 4.628 5258.19 14764.16 92.650 276.830 8960.75 9033.04 8874.35 S 1119.62 W 5970278.00 N 617906.32 E 1.590 5296.72 14812.86 93.450 280.090 8958.16 9030.45 8867.20 S 1167.71W 5970284.39 N 617858.12 E 6.883 5335.26 14844.69 93.080 282.990 8956.35 9028.64 8860.84 S 1198.85 W 5970290.25 N 617826.89 E 9.170 5359.36 14912.44 93.020 289.820 8952.74 9025.03 8841.75 S 1263.71 W 5970308.32 N 617761.74 E 10.067 5406.73 14943.23 91.170 290.070 8951.61 9023.90 8831.25 S 1292.63 W 5970318.35 N 617732.65 E 6.063 5426.89 14975.33 91.540 290.960 8950.85 9023.14 8820.00 S 1322.69 W 5970329.12 N 617702.42 E 3.002 5447.67 15008.31 88.340 288.950 8950.89 9023.18 8808.75 S 1353.68 W 5970339.88 N 617671.25 E 11 .458 5469.27 15102.44 87.170 296.140 8954.58 9026.87 8772.72 S 1440.49 W 5970374.53 N 617583.88 E 7.733 5527.57 30 September, 2002 - 13:18 Page 4 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A MWD Your Ref: API 500292115601 Job No. AKMW22137, Surveyed: 22 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 15158.27 89.820 288.990 8956.05 9028.34 8751.32 S 1491.99 W 5970395.11 N 617532.04 E 13.653 5562.15 15198.93 89.510 307.850 8956.29 9028.58 8732.05 S 1527.59 W 5970413.81 N 617496.15 E 46.390 5583.88 15248.94 88.030 282.990 8957.38 9029.67 8710.76 S 1572.39 W 5970434.39 N 617451.01 E 49.785 5612.65 15294.65 88.890 282.180 8958.61 9030.90 8700.80 S 1616.99 W 5970443.64 N 617406.26 E 2.584 5646.77 15344.47 88.830 309.110 8959.62 9031.91 8679.44 S 1661.48 W 5970464.29 N 617361.44 E 54.044 5675.24 .~ 15392.17 89.080 283.740 8960.50 9032.79 8658.39 S 1703.84 W 5970484.67 N 617318.75 E 53.180 5702.00 15438.20 88.710 310.200 8961.40 9033.69 8637.71 S 1744.49 W 5970504.70 N 617277.77 E 57.479 5727.45 15486.82 89.020 303.800 8962.37 9034.66 8608.47 S 1783.29 W 5970533.32 N 617238.51 E 13.176 5747.12 15535.73 88.710 298.190 8963.34 9035.63 8583.29 S 1825.20 W 5970557.83 N 617196.22 E 11 .485 5771.47 15583.96 88.460 289.660 8964.53 9036.82 8563.76 S 1869.23 W 5970576.66 N 617151.88 E 17.688 5800.43 15631.52 89.020 286.840 8965.58 9037.87 8548.87 S 1914.38 W 5970590.83 N 617106.50 E 6.044 5832.63 15680.67 89.140 287.500 8966.37 9038.66 8534.36 S 1961.33 W 5970604.59 N 617059.32 E 1.365 5866.59 15728.20 89.140 286.910 8967.08 9039.37 8520.31 S 2006.73 W 5970617.93 N 617013.71 E 1.241 5899.41 15774.35 91.170 289.210 8966.95 9039.24 8506.00 S 2050.60 W 5970631.54 N 616969.62 E 6.647 5930.77 15869.95 92.770 290.960 8963.67 9035.96 8473.19 S 2140.33 W 5970662.92 N 616879.38 E 2.479 5993.19 15937.00 92.770 290.960 8960.43 9032.72 8449.24 S 2202.87 W 5970685.88 N 616816.47 E 0.000 6036.17 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 240.880° (True). ~ Magnetic Declination at Surface is 25.974°(22-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 15937.00ft., The Bottom Hole Displacement is 8731.68ft., in the Direction of 194.613° (True). 30 September, 2002 - 13:18 Page 5 of 6 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU- WOA S Pad - S-18A MWD Your Ref: API 500292115601 Job No. AKMW22137, Surveyed: 22 August, 2002 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10922.34 10936.00 15937.00 8343.20 8352.86 9032.72 6540.52 S 6550.14 S 8449.24 S 701 .26 E 702.15 E 2202.87 W Tie On Point Window Point Projected Survey ~' Survey tool program for S-18A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 10922.34 0.00 10922.34 8343.20 15937.00 8343.20 AK-2 BP _CG - BP Conventional Gyro(S-18) 9032.72 MWD Magnetic(S-18A MWD) 30 September, 2002 - 13:18 Page 6 of 6 DrillQuest 3.03.02.002 S 18a Scope Change ') ) Subject: S18a Scope Change Date: Wed, 21 Aug 2002 12:06:54 -0500 From: "Triolo, Mike T" <TrioloMT@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com>, "Stanley, Mark J (AN C) " <StanleMJ@BP.com>, "Isaacson, William S" <IsaacsWS@BP.com>, "Crane, Lowell R" <CraneLR@BP.com> Winton, As per our conversation yesterday (8/20/02) I am sending you an e-mail to inform you of our recent changes to the S-18a Permit to Drill # 202-163. We have had some difficulties being able to proceed along with our original scope of work for this ST due to a chemical cutter that was left down hole during the pre-rig decompletion work. We made several attempts with slickline and the rig to retrieve this fish to no avail, and in the process left a Baker cut lip guide and mill guide control in the hole -200' above the chemical cutter fish. With two fish in the hole, we decided to alter our plans slightly and avoid any further lost time and move up hole and KG in the 9-5/8" casing, put in a 7" drilling liner and proceed along as per the original plan in the Permit. We will still utilize the same bottom hole targets in the reservoir. I am sending over an addendum to the Permit this morning which will include a brief scope of work, a new completion diagram and a new directional profile. Please don't hesitate to call if you have any questions regarding these adjustments. Thanks, Michael (Mik) Triolo Operations Drilling Engineer Work: 564-5774 Cell: 240-8076 E-mail: triolomt@bp.com (GPB) ') ') I Well Name: I S-18A I ReAl,' ~d ltJ 61\- Scope Change Summary CasingfTubing Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 8-1 /2" 7" 26# l-80 BTC-Mod -912' 10,800' /8257' 11,712' I 8859' Directional KOP: I -10,950' MD Maximum Hole Angle: -480 In original wellbore at 6500' MD -960 In Horizontal interval of sidetrack All wells pass BP Close Approach guidelines. The nearest close approach well is the parent wellbore S-18 which. Standard MWD Surveys with IFR & Cazandra from kick-off to TO. If magnetic interference does not improve as planned, a Gyro may need to be dropped to verify survey certainty. Magnetic interference is planned to dissipate within 300' of the KOP. Close Approach Well: Survey Program: Mud ProQram Window Milling Mud Properties: LSND Density (ppg) Viscosity PV 11.0 55-70 12-15 I Whipstock Window in 9-5/8" I Yield Point tauO pH 25 - 35 6 - 9 9.0 - 9.5 HTHP (ee's/3D min) <10 Intermediate Mud Properties: lSND From sidetrack depth to interval TO Density (ppg) Viscosity 11.0 45 - 55 I 8-1/2" hole section PV 13 - 20 Yield Point 15 - 25 tauO 3-7 pH 9.0 - 9.5 HTHP (ee's/3D min) <8 LogQing Program 8 ¥2" Intermediate: Drilling: Open Hole: Cased Hole: MWD IGR IRes - Realtime over entire interval. No open hole logs are planned. No cased hole logs are planned. Cement Proc ram ~ Casing Size 7" Drilling Liner Basis: lead: None Tail: Based on 762' of open hole with 300/0 excess and 82' of 7" shoe joint, 150' liner lap, and 200' of cement above that. Tail TOC: -10,600' MD (8,118' TVD) FIØi.,.,',.-<.' ...d"Sé."',. ... ..,.!t¡... ~.'. ~þ~, ~'{ð. }umes: Pre None ?\ [ t ."'C ';':" Flush Spacer Tail 20 bbls MudPUSH Viscosified Spacer weighted to 12.5 ppg 41 bbl I 150 sks of Dowell Premium 'G' at 15.8 ppg and 1.53 dIsk, BHST 2250 I BHCT 1550 (use actual circulating temps recorded by MWO at TO) *See Attached Dowell Cement Program for Details on Cement Formulation and pumping rates* Alaska QU & Anchorage S-18A Scope Change Summary 8/20/02 Page 1 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. /' Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3,625 psi @ 8,877' TVD - Zone 4 . Maximum surface pressure: 2,737 psi @ surface (based on BH P and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3,500 psi 8.6 ppg seawater / 6.8 ppg Diesel . Planned BOPE Test Pres. I 3,500/250 psi Rams & Valves 2,500/250 psi Annular Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Scope Change Procedural Summary Ria Operations: 1. Finish making tandem scraper / mill / gauge run to 7" liner top packer:t 11,376' MD on DP. 2. RU E-line and make a GR/CCL run to below 11,000' MD. Tie in to collars and GR to determine BP and subsequent whipstock setting depth. Top of window: -10,950' MD. ./ 3. RU and set Halliburton BP at -10,970' MD (set as needed to avoid cutting casing collar). 4. Test 9-%" casing to 3,500 psi for 30 minutes./ 5. RIH with 9-%" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. 6. Shear off of whipstock with mills and then displace over to 11.0 ppg LSND mud. 7. Mill window in 9-%" casing at -10,950' MD. Prior to POH, perform FIT to 12.5 ppg EMW. 8. RIH with 8-%" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-%" intermediate section to Top Sag @ :t11 ,712' MD (8,859' TVD). 9. Run and cement 7", 26# intermediate drilling liner to -150' back into window. POH. 10. Make up and RIH with a 6-%" directional assembly (with MWD/GR/RES/PWD/ABI) to the 7" landing collar. Test the 9-%" casing and 7" liner from the landing collar to surface to 3,500 psi for 30 minutes. 11. Drill shoe track, circulate and condition mud 12. Displace over to new Low density QuickDrill 8.4 - 8.5 ppg and drill 20' of new formation. 13. Conduct FIT to 9.5 ppg EMW. 14. Revert back to original well plan. S-18A Scope Change Summary 8/20/02 Page 2 TREE: 4-1/16" - 5M CIW L-80 WELLHEAO: 135/8" - 5M McEvoy S-18A Scope Change Completion 13-3/8", 72 #/ft, L-80, 8TC I 3055' I .. ----!: 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2050' ~ 4-1/2" 12.6# 13Cr-80 Yam Ace Tubing with GLM's ----!:---- ----!: ----!: ~ 7 6 5 4 3 2 1 GAS LIFT MANDRELS MO Size T80' 1-1/2" T80' 1-1/2" T80' 1-1/2" T80' 1-1/2" T80' 1-1/2" T80' 1" 1 jt above pkr 1 " I +/-10,800' I BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +1-10,950' MO 8ridge Plug set at +1-10,970' MO .' Top of Fish(Cut lip Guide & Mill Guide control): 11,450'MO ~ 7" Liner Top at 111,376' I M "'...i.. ~, 9-5/8",47 H/ft, L-80, BTC 1 11,6so'I ~ .. Top of Fish(Chemical Cutter): 11,694' MO - .:. .::. ~!~t,~ . , -=:¡;. ~ .......:::: ==-- Fill 7",26 #/ft, L-80, IJ4S I 12,140' I 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +/-11,562' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMc' Hydraulic Liner Hanger Cellar Elevation = 38.49' Base Flange = 39.89' Doyon 14 RKB = 72.80' Valve Type OV RP Shear OV OV OV OV OV ".-ø ''--ø'' I ~ 1+/-11,712' MDI 7",26 #/ft, L-80, 8TC-Mod 4-1/2" 12.6 #Ift, L-80, IBT Slotted Liner 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go JD. I +/-15,560' I , A .~ \ ) . ."'. .. .. .'. .'. :~:' 11111111111111111) TOC: 11,722' MO 4-1/2" 12.-6#, L-80, IBT-M Solid liner w/Baker ECP at I +/-1~,564' I Date 08/20102 Rev By MikT Comments Proposed Completion PRUDHOE BAY UNIT WELL: S-18A API NO: 50-029-21156-01 GPB Drilling & Wells Spe!ï'ilV-SLJr1 Qf:U'"ÇIN($ :... e v Jçe$ A H.lJìlllltton Comp'/I)' North Slope Alaska BPXA PBU_WOA S Pad S-18A WP09 . . ~. ~:1::: . Current Well Properties ... ~¡:'" . . Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: S-18 5979169.00 N, 618885.00 E 1702.39 S, 941.39 E 70021' 06.2761' N, 149002' 04.9140' W ~.~, ;~~~~. . 72.8011 above Mean Sea Level 72.8011 above Structure Reference True North Feet (US) -'!;.:~." '.;~~é ;:.'.:~¡. North Reference: Units: S-18A WP09 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip Dip Dir, Formation Name (ft) (ft) (ft) (Deg) (Deg) 11711.96 8858.80 8786.00 0.000 0.000 Sag 11773.17 8897.80 8825.00 0.000 0.000 Shublik 11948,90 8982.80 8910.00 0.000 0.000 TSAD () () c () ~ () - () c: \~7"Llner . ..'1711.96ftMD 8858.8011 TVD !"< \ 8500 - S.1.'i.1 T;i(' 9!J'!7JiO H1) S.J8A 1'7 XW'.Mi S. ¡¡Ùr,} lI' ~~-:7.!?(i '/VD, ~ 'íL \. l).hll,6}', "')... , ~., u>. .),(4 w " "'- _.- -9--- :i.INA . :::;...---- ~9'" ~ 4112" .Lioor 78~~'~' ,~-~ ..'", ,'>IS.,11'k 9037.8OItTVD Z~:;;: ~~ 'C,F:~'y..¡7 L' z~~~n~l;~:s.15 W (34= ~8 --0 £~ C-..c: ()u O.~ -a : 9500 - CJ- ,- cø tu ()(f) > S..lii" SlIg 8858.811 '1'1'1), 7/34.-10 S, 645.95 t: S.UI,I Tic 897),811 l'VlJ, "lRq:;-,96 S', 5~4,;19 H I I I I 3500 4500 5500 6500 Scale: 1 inch = 1000ft Section Azimuth: 232.250° (True North) V crtical 8cction (W cll ncfcrcncc ) '", ~, . :.,f Vertical Origin: Horizontal Origin: Measurement Units: North Reference: t:aslIngs ~ vv ell t1eTerenc~ ) Scale: 1 inch = 1000ft -2000 -1000 I I 1000 I 0 I Q) () C <1> ~ Q) ã5 a: ã> ~ 8.1M 1'7" -8000 - ~~- ~~ S./SA T6f 8997.8f) THt, SS3U.¡ s~ 125.15 W -7000 - en C).t:: CO .-0 ..cO t:T""" 0 II Z..c: u .~ ëri Cõ u (f) w I I -2000 -1000 Scale: 1 inch = 1000ft Reference is True North Eastings (Well Reference) 0 I 1000 Proposal Data for S-18A WP09 Well Reference Well Reference ft True North Dogleg severity : Degrees per 100 feet (US) ~ Vertical Section Azimuth: 232.250° Vertical Section Description:Well Reference Vertical Section Origin: 0.00 N,O,OO E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 1"'''').00 45.128 174.716 s.'r.2.90 ""."'.66S 703.03 E 3460.05 1"";'),00 46.220 177.704 x nt;.87 ..,) \.93 S 703.98 E 3468.05 12.000 111'.~.55 49.980 187.114 s511L/.61 ., i: 1.23 S 697.42 E 3563.41 4.000 11711.96 50.050 187.090 xs ~ ~.80 ~ I '.¡.40 S 645.95 E 3857.06 0.013 11 i'1.97 50.050 187.090 sss~.49 ¡ 1"~.83 S 642.16 E 3878.69 0.000 1: : 'U8 98.314 185.351 lJ1I12.27 ¡,. I \.26 S 594.15 E 4191.18 10.000 1:.1."),87 98.314 185.351 x'/sl.04 ?, ~".06 S 574.22 E 4337.22 0.000 1:':1.91 95.000 190.000 SII7 2.80 !~'..'.96 S 564.79 E 4387.46 8.000 1:"! _~.96 91.334 194.350 xlJt.S.87 ;""'.27 S 549.83 E 4441.73 8.000 1:''1 ~L61 91.334 194.350 SlJt, 1.30 :,:~1 .67 S 469.14 E 4698.62 0.000 1 \:1167 90.000 218.000 slI'7.80 :. ., .wA6 S 339.47 E 4962.65 8.000 1 ".1166 83.579 249.415 x'ISO.77 '7 !~.04 S 22.00 E 5356.67 8.000 1 ,; : \.40 83.579 249.415 xlIlJ2.93 ~~ r ".03 S 79.16 W 5459.92 0.000 1 .: : "~.37 85.000 252.000 sIJ47.80 ~"':.13 S 125.15 W 5506.13 6.000 1 J' ,q.40 88.293 270.464 111111;.21 ~~ ¡".31 S 431.63 W 5777. 35 6.000 1.1 'I \.57 88.293 270.464 1'112.'.04 ~~ 7":.46 S 660.69 W 5957.33 0.000 1.1."";.03 88.880 282.000 1/1I~7.80 ~~."'.60 S 851.63 W 6095.54 6.000 1.1".' \.82 89.499 287.880 '/1121/.89 ~~1~.52 S 994.35 W 6185.07 4.000 1. "''';.96 89.499 287.880 ')(137.80 ~'1".63 S 1855.74 W 6696.04 0.000 , -þc=l""'l"""y-sU1 I:)RI.,",..~ IJ\iGS ~ "'"Ie: e~ A HaIlIeUI'tOll COII\jIaIf; ) ') DrillQuesl~ North Slope Alaska BPXA PBU_WOA S Pad S-18A WP09 S-18A WP09 Target Data Measurement Units: ft Target Coordinate TVDRT Northings Eastings TVDSS ASP4 Y ASP4 X Target Name Point Type Shape (ft) (ft) (ft) (ft) (ft) (ft) 8-1SA T6e Entry Point 9027.80 8856.60 8 851.63 W 8955.00 5970300.00 N 618174.00 E Point 8-1SA T5e Entry Point 8997.80 8832.13 8 125.15 W 8925.00 5970336.00 N 618900.00 E Point 8-1SA T7e Entry Point 9037.80 8540.63 8 1855.74 W 8965.00 5970600.00 N 617165.00 E Point 818-A T3e Entry Point 8957.80 8544.46 8 339.47 E 8885.00 5970631.00 N 619360.00 E Point 8-18A Driller Poly Entry Point 8972.80 7895.968 564.79 E 8900.00 5971283.00 N 619575.00 E Polygon Boundary Point A 8972.80 7203.69 8 616.78 E 8900.00 5971976.00 N 619616.00 E B 8972.80 8529.37 8 333.71 E 8900.00 5970646.00 N 619354.00 E C 8972.80 8651.108 126.76 E 8900.00 5970521.00 N 619149.00 E D 8972.80 8781.348 174.35 W 8900.00 5970386.00 N 618850.00 E E 8972.80 8810.978 449.85 W 8900.00 5970352.00 N 618575.00 E F 8972.80 8796.78 8 839.68 W 8900.00 5970360.00 N 618185.00 E G 8972.80 8743.27 8 1123.86 W 8900.00 5970409.00 N 617900.00 E H 8972.80 8662.348 1307.60 W 8900.00 5970487.00 N 617715.00 E I 8972.80 8406.27 8 1814.60 W 8900.00 5970735.00 N 617204.00 E J 8972.80 8608.27 8 1878.82 W 8900.00 5970532.00 N 617143.00 E K 8972.80 8773.798 1343.38 W 8900.00 5970375.00 N 617681.00 E L 8972.80 8826.00 8 1141.18 W 8900.00 5970326.00 N 617884.00 E M 8972.80 8907.558 855.44 W 8900.00 5970249.00 N 618171.00 E N 8972.80 8944.03 8 446.96 W 8900.00 5970219.00 N 618580.00 E O 8972.80 8907.04 8 131.34 W 8900.00 5970261.00 N 618895.00 E P 8972.80 8762.42 8 209.00 E 8900.00 5970411.00 N 619233.00 E Q 8972.80 8574.68 8 416.00 E 8900.00 5970602.00 N 619437.00 E R 8972.80 7212.148 770.67 E 8900.00 5971970.00 N 619770.00 E 8-1SA T2e Entry Point 8972.80 7895.968 564.79 E 8900.00 5971283.00 N 619575.00 E Point 8-18A 8ag Entry Point 8858.80 7134.40 8 645.95 E 8786.00 5972045.75 N 619644.06 E Point 8-1SA Geo Poly Entry Point 8972.80 7113.738 872.24 E 8900.00 5972070.00 N 619870.00 E Polygon Boundary Point A 8972.80 7113.738 872.24 E 8900.00 5972070.00 N 619870.00 E B 8972.80 7910.948 689.67 E 8900.00 5971270.00 N 619700.10 E C 8972.80 8602.99 8 498.57 E 8900.00 5970575.00 N 619520.00 E D 8972.80 8897.72 8 163.85 E 8900.00 5970275.00 N 619190.00 E E 8972.80 8994.30 8 367.75 W 8900.00 5970170.00 N 618660.00 E F 8972.80 8958.198 752.23 W 8900.00 5970200.00 N 618275.00 E G 8972.80 8901.93 8 1146.38 W 8900.00 5970250.00 N 617880.00 E H 8972.80 8638.328 2002.31 W 8900.00 5970500.00 N 617020.00 E I 8972.80 8319.638 1917.24 W 8900.00 5970820.00 N 617100.00 E J 8972.80 8722.758 1093.53 W 8900.00 5970430.00 N 617930.00 E K 8972.80 8768.69 8 719.22 W 8900.00 5970390.00 N 618305.00 E L 8972.80 8784.178 374.42 W 8900.00 5970380.00 N 618650.00 E M 8972.80 8737.748 148.65 W 8900.00 5970430.00 N 618875.00 E N 8972.80 8543.328 204.48 E 8900.00 5970630.00 N 619225.00 E O 8972.80 7865.71 8 360.25 E 8900.00 5971310.00 N 619370.00 E P 8972.80 7109.458 602.28 E 8900.00 5972070.00 N 619600.00 E DrillQuest 2.00.09.006 Spet .y-Sun Drilling Sf;;.'>vices Proposal Data - 5-18 - 5-18A WP09 001 = 6.4 Approved Plan MD Delta Inclin. Azimuth TVD Delta i Northings (ft) MD (ft) n (°) (ft) TV.~ (ft) ..;... .. . (ft) ...u.. . .~1.. I ..10950.0Ò.: .. . ..45.131 174.72: 8362.90: . 6559.66 S: . . ..m.. um m umu. m ..u. u -,... mm. um . . u_~uumO.mu.... I .. .......m.u...m.. . .; uo ....m.um m... -:u. ...m....O. . . -. ..u. mO.m. . 2 ~O.OOj 20.00 46.22' 177.70: 8376.87: 13.98' 6573.93 S, 3' 11168.55 198.55 49.98 187.11 8509.61 132.74 6721.23 S 4T' 11711.96 543.40 50.05 187.09 8858.80 349.19 7134.40 S -,,--"-,~-_...._. --......-- 5' :o...!!~1.971 40.01 5O.0~ 187.0~: 888~.49: ~5.6~~164.83~' 6 12234.88 482.91 98.31 185.35 9012.27 127.78 7613.26 S 7 12450.87 216.00 98.31 185.35 8981.04 -31.23 7826.06 S 8T 12521.91 71.04 95.00 190.00 8972.80 -8.24 7895.96 S 9 12592.96 71.04 91.33 194.35 8968.87 -3.93 7965.27 S 10 12918.61 325.65 91.33 194.35 8961.30 -7.58 8280.67 S 11T 13214.67 296.07 90.00 218.00 8957.80 -3.50 8544.46 S 12 13614.66 399.99 83.58 249.42 8980.77 22.97 8778.04 S 13 13723.40 108.74 83.58 249.42 8992.93 12.16 8816.03 S 14T 13772.37 48.97 85.00 252.00 8997.80 4.87 8832.13 S 15 14084.40 312.02 88.29 270.46 9016.21 18.41 8879.31 S 16 14313.57 229.17 88.29 270.46 9023.04 6.83 8877.46 S 17T 14506.03 192.46 88.88 282.00 9027.80 4.76 8856.60 S 18 14653.82 147.80 89.50 287.88 9029.89 2.09 8818.52 S 19T 15558.96 905.14 89.50 287.88 9037.80 7.91 8540.63 S 20 August, 2002 - 15:36 Eastings Dogleg A. Build A. Tum Toolface VS (232°) I (ft) (°/1 ooft) (°/1 OOft) (° /lOOft) (°) (ft) ..m.. .."' . ....... n.' ..n... 703.03 E ¡ 3460.1 ...... u ...~_..._....... .. . .m... ... .~~._.~_.,. n, .. ...~....... 703.98 Ef 12.00: 5.46, 14.94. 64.00: 3468.0 4_.____--'---"'-' . -". ,,-,.,-~ -'---'" 697.42 E 4.00 1.89 4.74 64.98 3563.4 645.95 E 0.01 0.01 0.00 345.52 3857.1 642.16 E--"--"".~Ö~.õo~ 0.00; 0.00; 0.00: '~3ã78~-7- .... _.._--_.._._.~_._._.._-,_.....I-..--------- 594.15 E 10.00 9.99 -0.36 357.70 4191.2 574.22 E 0.00 0.00 0.00 0.00 4337.2 564.79 E 8.00 -4.67 6.54 125.38 4387.5 .. - 4 .--..-......_u_n ....-. 549.83 E 8.00 -5.16 6.12 130.03 4441.7 469.14 E 0.00 0.00 0.00 0.00 4698.6 339.47 E 8.00 -0.45 7.99 93.04 4962.6 ......-..--.--_u_u "..M. ---,-"'--~- 22.00 E 8.00 -1.61 7.85 102.18 5356.7 79.16 W 0.00 0.00 0.00 0.00 5459.9 125.15 W 6.00 2.90 5.28 61.21 5506.1 431.63 W 6.00 1.06 5.92 80.50 5777.4 660.69 W 0.00 0.00 0.00 0.00 5957.3 851.63 W 6.00 0.31 5.99 87.24 6095.5 994.35 W 4.00 0.42 3.98 84.03 6185.1 1855.74 W 0.00 0.00 0.00 0.00 6696.0 - 1 - DrillQuest ~' North Slope Alaska BPXA PBU_WOA 5 Pad, Slot 5-18 S-18A WP09 Revised: 20 August, 2002 PROPOSAL REPORT 20 August, 2002 ~ Surface Coordinates: 5979169.00 N, 618885.00 E (70021' 06.2761" N, 149002' 04.9140" W) Surface Coordinates relative to Project H Reference: 979169.00 N, 118885.00 E (Grid) Surface Coordinates relative to Structure Reference: 1702.39 S, 941.39 E (True) Kelly Bushing: 72.80ft above Mean Sea Level spe..........y-su., P.Rl.bJ-.'.N.G...'::.fiE;.B.V..'.Ç;;.E.S A Halliburton Company Proposal Ref: pro11288 Sperry-Sun Drilling Services Proposal Report for S-18A WP09 Revised: 20 August, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10950.00 45.128 174.716 8290.10 8362.90 6559.668 703.03 E 5972621.32 N 619692.02 E 3460.05 8T Exit: Dir @ 12.0000/100ft, 64.00° Right TF : 10950.00ft MD, 8362.90ft TVD 10970.00 46.220 177.704 8304.07 8376.87 6573.93 8 703.98 E 5972607.07 N 619693.19 E 12.000 3468.05 Begin Dir @ 4.0000/100ft: 109í MD, 8376.87ft TVD ~ 11000.00 46.737 179.197 8324.73 8397.53 6595.67 8 704.56 E 5972585.33 N 619694.12 E 4.000 3480.90 11100.00 48.596 183.990 8392.09 8464.89 6669.52 8 702.46 E 5972511.46 N 619693.19 E 4.000 3527.77 11168.55 49.980 187.114 8436.81 8509.61 6721 .23 8 697.42 E 5972459.68 N 619688.97 E 4.000 3563.41 End Dir, 8tart 8ail @ 49.980° : 11168.55ftMD,8509.61ftTVD 11200.00 49.984 187.112 8457.04 8529.84 6745.138 694.44 E 5972435.74 N 619686.37 E 0.013 3580.40 11300.00 49.997 187.1 08 8521 .33 8594.13 6821 .13 S 684.96 E 5972359.60 N 619678.10 E 0.013 3634.42 11400.00 50.010 187.104 8585.60 8658.40 6897.158 675.48 E 5972283.43 N 619669.83 E 0.013 3688.46 11500.00 50.023 187.099 8649.86 8722.66 6973.198 666.01 E 5972207.26 N 619661.56 E 0.013 3742.50 11600.00 50.036 187.095 8714.10 8786.90 7049.248 656.54 E 5972131.07 N 619653.30 E 0.013 3796.54 11700.00 50.048 187.091 8778.32 8851.12 7125.30 8 647.08 E 5972054.86 N 619645.05 E 0.013 3850.60 11711.96 50.050 187.090 8786.00 8858.80 7134.40 S 645.95 E 5972045.75 N 619644.06 E 0.013 3857.06 7" Liner 8ag Target - 8-18A 8ag, Drillers 11751.97 50.050 187.090 8811.69 8884.49 7164.83 8 642.16 E 5972015.26 N 619640.76 E 0.000 3878.69 Begin Dir @ 10.0000/100ft : 11751.97 MD, 8884.49ft TVD 11773.17 52.169 186.982 8825.00 8897.80 7181.21 8 640.14 E 5971998.85 N 619639.00 E 10.000 3890.31 8hublik 11800.00 54.850 186.854 8840.96 8913.76 7202.62 8 637.54 E 5971977.40 N 619636.74 E 10.000 3905.47 11900.00 64.843 1 86.440 8891 .12 8963.92 7288.40 8 627.56 E 5971891.47 N 619628.12 E 10.000 3965.88 ",,-,,/ 11948.90 69.731 186.262 8910.00 8982.80 7333.228 622.57 E 5971846.58 N 619623.85 E 10.000 3997.26 T8AD 12000.00 74.838 186.088 8925.54 8998.34 7381.608 617.34 E 5971798.13 N 619619.38 E 10.000 4031 .02 12100.00 84.833 185.769 8943.17 9015.97 7479.388 607.19 E 5971700.20 N 619610.78E 10.000 4098.91 12200.00 94.828 185.460 8943.46 9016.26 7578.77 8 597.42 E 5971600.66 N 619602.59 E 10.000 4167.48 12234.88 98.314 185.351 8939.47 9012.27 7613.268 594.15 E 5971566.12 N 619599.87 E 10.000 4191.18 End Dir, 8tart 8ail @ 98.314° : 12234.88ftMD,9012.27ftTVD 12300.00 98.314 185.351 8930.06 9002.86 7677.42 8 588.15 E 5971501.88 N 619594.88 E 0.000 4235.21 12400.00 98.314 185.351 8915.60 8988.40 7775.94 8 578.92 E 5971403.23 N 619587.22 E 0.000 4302.82 12450.87 98.314 185.351 8908.24 8981.04 7826.06 8 574.22 E 5971353.04 N 619583.32 E 0.000 4337.22 12500.00 96.027 188.572 8902.11 8974.91 7874.43 8 568.31 E 5971304.58 N 619578.18 E 8.000 4371 .50 20 August, 2002 - 17:32 Page 2 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-18A WP09 Revised: 20 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 12521.91 95.000 190.000 8900.00 8972.80 7895.96 S 564.79 E 5971283.00 N 619575.00 E 8.000 4387.46 Target - S-18A T2c, Current Target 12592.96 91 .334 194.350 8896.07 8968.87 7965.27 S 549.83 E 5971213.46 N 619561.14 E 8.000 4441.73 End Dir, Start Sail @ 91.334° : 12592.96ftMD ,8968.87ftTVD 12600.00 91 .334 194.350 8895.91 8968.71 7972.09 S 548.09 E 5971206.61 N 619559.51 E 0.000 4447.28 12700.00 91 .334 194.350 8893.58 8966.38 8068.94 S 523.31 E 5971109.38 N 619536.27 E 0.000 4526.17 ~ 12800.00 91 .334 194.350 8891.26 8964.06 8165.79 S 498.53 E 5971012.15 N 619513.03 E 0.000 4605.05 12900.00 91 .334 194.350 8888.93 8961.73 8262.65 S 473.75 E 5970914.91 N 619489.79 E 0.000 4683.94 12918.61 91 .334 194.350 8888.50 8961 .30 8280.67 S 469.14 E 5970896.82 N 619485.47 E 0.000 4698.62 Begin Dir @ 8.0000/100ft: 12918.61f1 MD, 8961.30ft TVD 13000.00 90.980 200.853 8886.85 8959.65 8358.19 S 444.55 E 5970818.91 N 619462.11 E 8.000 4765.53 13100.00 90.529 208.841 8885.53 8958.33 8448.85 S 402.57 E 5970727.60 N 619421 .57 E 8.000 4854.23 13200.00 90.068 216.828 8885.01 8957.81 8532.81 S 348.39 E 5970642.79 N 619368.73 E 8.000 4948.47 13214.67 90.000 218.000 8885.00 8957.80 8544.46 S 339.47 E 5970631.00 N 619360.00 E 8.000 4962.65 Target - S18-A T3c, Current Target 13300.00 88.563 224.674 8886.07 8958.87 8608.49 S 283.16 E 5970566.09 N 619304.70 E 8.000 5046.38 13400.00 86.904 232.506 8890.03 8962.83 8674.53 S 208.28 E 5970498.87 N 619230.88 E 8.000 5146.01 13500.00 85.304 240.363 8896.84 8969.64 8729.65 S 125.22 E 5970442.44 N 619148.71 E 8.000 5245.43 13600.00 83.792 248.255 8906.35 8979.15 8772.78 S 35.59 E 5970397.89 N 619059.77 E 8.000 5342.71 13614.66 83.579 249.415 8907.97 8980.77 8778.04 S 22.00 E 5970392.42 N 619046.27 E 8.000 5356.67 End Dir, Start Sail @ 83.579° : 13614.66ftM D ,8980. 77ftTVD 13700.00 83.579 249.415 8917.51 8990.31 8807.85 S 57.39 W 5970361.34 N 618967.36 E 0.000 5437.70 13723.40 83.579 249.415 8920.13 8992.93 8816.03 S 79.16 W 5970352.82 N 618945.73 E 0.000 5459.92 Begin Dir @ 6.0000/100ft: 1372~ AI)f1 MD, 8992.93ft TVD 13772.37 85.000 252.000 8925.00 8997.80 8832.13 S 125.15 W 5970336.00 N 618900.00 E 6.000 5506.13 Target - S-18A T5c, Current Targèr-" 13800.00 85.275 253.640 8927.34 9000.14 8840.26 S 151.45 W 5970327.45 N 618873.83 E 6.000 5531.90 13900.00 86.303 259.568 8934.69 9007.49 8863.35 S 248.42 W 5970302.83 N 618777.24 E 6.000 5622.72 14000.00 87.370 265.481 8940.21 9013.01 8876.33 S 347.37 W 5970288.28 N 618678.51 E 6.000 5708.91 14084.40 88.293 270.464 8943.41 9016.21 8879.31 S 431.63 W 5970283.96 N 618594.31 E 6.000 5777.35 End Dir, Start Sail @ 88.293° : 14084.40ftMD,9016.21ftTVD 14100.00 88.293 270.464 8943.87 9016.67 8879.18 S 447.22 W 5970283.84 N 618578.71 E 0.000 5789.61 14200.00 88.293 270.464 8946.85 9019.65 8878.37 S 547.18 W 5970283.06 N 618478.76 E 0.000 5868.14 20 August, 2002 - 17:32 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for S-18A WP09 Revised: 20 August, 2002 BPXA North Slope Alaska PBU_WOAS Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 14300.00 88.293 270.464 8949.83 9022.63 8877.57 S 647.13 W 5970282.28 N 618378.81 E 0.000 5946.68 14313.57 88.293 270.464 8950.24 9023.04 8877.46 S 660.69 W 5970282.18 N 618365.24 E 0.000 5957.33 Begin Dir @ 6.000o/100ft: 14313.5711 MD, 9023.04ftTVD 14400.00 88.549 275.645 8952.62 9025.42 8872.85 S .746.94 W 5970285.41 N 618278.94 E 6.000 6022.71 14500.00 88.861 281.639 8954.88 9027.68 8857.84 S 845.73 W 5970298.86 N 618179.92 E 6.000 6091.63 ~ 14506.00 88.880 281.998 8955.00 9027.80 8856.61 S 851.60 W 5970299.99 N 618174.03 E 6.000 6095.52 Decrease in Dir Rate @ 4.0000/100ft: 14506.00ft MD, 9027.80ft TVD 14506.03 88.880 282.000 8955.00 9027.80 8856.60 S 851.63 W 5970300.00 N 618174.00 E 6.000 6095.54 Target - S-18A T6c, Current Target 14600.00 89.273 285.739 8956.52 9029.32 8834.08 S 942.83 W 5970321.07 N 618082.45 E 4.000 6153.87 14653.82 89.499 287.880 8957.09 9029.89 8818.52 S 994.35 W 5970335.81 N 618030.69 E 4.000 6185.07 End Dir, Start Sail @ 89.499° : 14653.82ftMD,9029.89ftTVD 14700.00 89.499 287.880 8957.50 9030.30 8804.34 S 1038.30 W 5970349.29 N 617986.53 E 0.000 6211.14 14800.00 89.499 287.880 8958.37 9031.17 8773.64 S 1133.46 W 5970378.48 N 617890.88 E 0.000 6267.59 14900.00 89.499 287.880 8959.24 9032.04 8742.94 S 1228.63 W 5970407.67 N 617795.24 E 0.000 6324.04 15000.00 89.499 287.880 8960.12 9032.92 8712.24 S 1323.80 W 5970436.85 N 617699.60 E 0.000 6380.50 15100.00 89.499 287.880 8960.99 9033.79 8681.54 S 1418.96 W 5970466.04 N 617603.96 E 0.000 6436.95 15200.00 89.499 287.880 8961.86 9034.66 8650.84 S 1514.13 W 5970495.23 N 617508.32 E 0.000 6493.40 15300.00 89.499 287.880 8962.74 9035.54 8620.14 S 1609.30 W 5970524.42 N 617412.68 E 0.000 6549.85 15400.00 89.499 287.880 8963.61 9036.41 8589.43 S 1704.46 W 5970553.60 N 617317.03 E 0.000 6606.30 15500.00 89.499 287.880 8964.48 9037.28 8558.73 S 1799.63 W 5970582.79 N 617221.39 E 0.000 6662.75 15558.96 89.499 287.880 8965.00 9037.80 8540.63 S 1855.74 W 5970600.00 N 617165.00 E 0.000 6696.04 Total Depth: 15558.96ftMD,9037 .80ftTVD 4 1/2" Liner '-' Target - S-18A T7c, Current Target All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.096° (20-Aug-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 232.250° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15558.96ft., The Bottom Hole Displacement is 8739.92ft., in the Direction of 192.259° (True). 20 August, 2002 - 17:32 Page 4 of 10 DrillQuest 2.00.09.006 North Slope Alaska Comments Measured Depth (ft) 10950.00 10970.00 11168.55 11751.97 12234.88 12592.96 12918.61 13614.66 13723.40 14084.40 14313.57 14506.00 14653.82 15558.96 Formation Tops Sperry-Sun Drilling Services Proposal Report for S-18A WP09 Revised: 20 August, 2002 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 8362.90 6559.66 S 703.03 E 8376.87 6573.93 S 703.98 E 8509.61 6721 .23 S 697.42 E 8884.49 7164.83 S 642.16 E 9012.27 7613.26 S 594.15 E 8968.87 7965.27 S 549.83 E 8961.30 8280.67 S 469.14 E 8980.77 8778.04 S 22.00 E 8992.93 8816.03 S 79.16 W 9016.21 8879.31 S 431.63 W 9023.04 8877.46 S 660.69 W 9027.80 8856.61 S 851.60 W 9029.89 8818.52 S 994.35 W 9037.80 8540.63 S 1855.74 W Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 8786.00 8825.00 8910.00 20 August, 2002 - 17:32 BPXA PBU_WOAS Pad ST Exit: Dir @ 12.0000/100ft, 64.00° Right TF : 1 0950.00ft MD, 8362.90ft TVD Begin Dir @ 4.0000/100ft: 10970.00ft MD, 8376.87ft TVD End Dir, Start Sail @ 49.980° : 11168.55ftMD,8509.61ftTVD Begin Dir @ 10.0000/100ft: 11751.97ft MD, 8884.49ftTVD End Dir, Start Sail @ 98.314°: 12234.88ftMD,9012.27ftTVD ---/ End Dir, Start Sail @ 91.334° : 12592.96ftMD,8968.87ftTVD Begin Dir @ 8.0000/100ft : 12918.61ft MD, 8961.30ft TVD End Dir, Start Sail @ 83.579° : 13614.66ftMD,8980.77ftTVD Begin Dir @ 6.0000/100ft : 13723.40ft MD, 8992.93ft TVD End Dir, Start Sail @ 88.293°: 14084.40ftMD,9016.21ftTVD Begin Dir @ 6.0000/100ft: 14313.57ft MD, 9023.04ft TVD Decrease in Dir Rate @ 4.0000/100ft: 14506.00ft MD, 9027.80ft TVD End Dir, Start Sail @ 89.499° : 14653.82ftMD,9029.89ftTVD Total Depth: 15558.96ftMD,9037.80ftTVD Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Formation Name 0.000 0.000 0.000 0.000 11711 .96 0.000 11773.17 0.000 11948.90 8858.80 8897.80 8982.80 8786.00 8825.00 8910.00 Northings (ft) ,-,' Eastings (ft) 7134.40 S 7181.21 S 7333.22 S 645.95 E Sag 640.14 E Shublik 622.57 E TSAD Page 5 of 10 DrillQuest 2.00.09.006 ) TONY KNOWLES, GOVERNOR AI~ASHA. OIL A1WD GAS CONSERVATION COMMISSION 333 W. ]'TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit S-18A BP Exploration (Alaska), Inc. Permit No: 202-163 Surface Location: 2314' SNL, 711' EWL, Sec. 35, T12N, R12E, UM Bottomhole Location: 296' SNL, 1430' EWL, Sec. 10, TIlN, R12E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit 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 terms and conditions of this permit may result in the revocation or suspension of the permit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~~ Chair BY ORDER Of THE COMMISSION DATED this.1t:h.- day of August, 2002 cc: Department of Fish & Game, Habitat Section wlo encI. Department of Environmental Conservation wlo encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2314' SNL, 711' EWL, SEC. 35, T12N, R12E, UM At top of productive intelVal 4287' SNL, 14301 EWL, SEC. 02, T11N, R12E, UM At total depth 296' SNL, 1430' EWL, SEC. 10, T11 N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well /. ADL 028260,1156' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11694' MD Maximum Hole Angle 18. CasinÇJ Program Specifications $Ize Hole CasinQ WeiQht Grade Coupling 6-1/8" 4-1/2" 12.6# L-80 IBT-M ALASKA Û1JND ~~;~g:S~~;:;;ON COMMI~ bN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 72.8' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028261 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-18A / 9. Approximate spud date 08/14/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 .7 155961MD/9038'TVD 0 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 98 Maximum surface 2510 psig, At total depth (TVD) 8900' / 3400 psig Setting Depth TQp Botom Quantitv of Cement LenQth MD TVD MD TVD linçlude st&ae data) 4171' 11425' 8690' 15596' 9038' 331 cu ft Class 'G' ,../ ~~Â- 4iF """,-i -1 (r-!ð'1- ~ ç;( ')ØD¿, 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12140 feet 9173 feet 12098 feet 9147 feet Length Plugs (measured) Junk (measured) 5" Cutter Bar 1-3/4'1 Fishing Neck at about 11934' Size Cemented MD TVD 110' 110' 3055' 2687' 11650' 8848' 110' 20" x 30" 3055' 13-3/8" 11650' 9-5/8" 764' 7" 8 cu yds Concrete 4265 cu ft Permafrost 2426 cu ft Class 'G' 375 cu ft Class 'G' 11376' - 12140' 8658' - 9173' RECE1\JED 0 ? 2002 .Approved By Form 10-401 Rev. 12-01-85 11846' - 11860', 11866' - 11890' Sqzd: 11890' - 11915', 11925' - 11940' true vertical 8983' - 8992', 8996' - 9012' Sqzd: 9012' - 9029', 9036' - 9045' II Filing Fee 0 Property Plat 0 BOP Sketch II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Bil/lsaa , 564-5521 21. I hereby certify that the foregoi IS true and erect to the best of my knowledge Signed Lowell Crane ~ .- - - !itle ~enior Drilling ~ngineer, ,. . - . Date g-¡-O;L .: c ,.-~~"~~{:>": :'\~,,'~y,fl~~..QnìV(~:':~~-,:'.i$;~i;;:)J~~~L:;-{~:;L::: .,... Permit Number API Number Apprf\val Date See cover letter .:z07 - / h 3 50- 029-21156-01 q \1 \ r:::\ for other reQuirements Conditions of Approval: Samples Required 0 Yes t8I No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures 0 Yes lEI No Directional SUlVey Required EI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: '~'.7t- [So fE Þ 'SSD 0 fÇ.¿Î. Onglnal Signed By . . by order o.f . Cammy ()eNt!\Ii Taylo¡ Commissioner the commiSSion Ur~iG'NAL A.laska Oil & lJ\.HmnlSSlm 0 D. S'k t h .. D . ~nct.or2-Ç!.e Iverter e c .. nOihg ....rogram 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 Perforation depth: measured 20. Attachments Date IJ IÎ {\} ti () U.~ Submit n Triplicate ) ) I Well Name: I S-18A Drill and Complete Summary I Type of Redrill (producer or injector): 1 Producer Surface Location: x = 618,885 / Y = 5,979,169 23141 FNL 7111 FWL S35 T12N R12E x = 619,729 / Y = 5,971,929 993' FSL 1431' FWL S2 T11 N R12E x = 617,165 / Y = 5,970,600 296' FNL 1156' FEL S10 T11 N R12E Umiat Target Location: Top Sad Bottom Hole Location: Umiat Umiat I AFE Number: 1 PBD4P1889 I r Estimated Start Date: 1 08/14/02 I Ria: 1 Doyon 14 / I Operatina days to complete: 121.0 1 MD: 115,596' I I TVD: 19038' I I Base Flange Elev: 139.89' I 1 RKB: 172.8' I Well Design (conventional, slim hole, etc.): I Conventional Big Bore - 7" Sidetrack I Objective: 1 Complete well as Horizontal Zone 4 Producer Formation Markers Formation Tops Top Sag River Kick-off Point MD 11,667' 11,694' TVD (not ss) Comments 8859' 8878' Kick-off in Sag River -- Estimated pore pressure of 3338 psi (7.3 ppg EMW). /' Shublik 11,724' 8898' Top Sadlerochit / Z4 11,885' 8983' TD -15,596' -9038' TD Criteria: TD will be as per the wellplan unless additional footage is required to meet the well objective of 2000' of Zone 4b offtake or if cost and economics justify drilling additional footage (500' maximum). Estimated pore pressure in heel 3380 psi (7.3 ppg EMW) CasingfTubing Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 6-1/8" 4-1/2" 12.6# L-80 IBT-M -4171' 11,425' /8690' 15,596' / 9038' Tubing 4-1/211 12.6# 13Cr-80 Vam Ace -11,395' GL 11,425' /8690' NOTE: The 4 1h" production liner will be a Bonzai style completion with the solid cemented section extending down to -13,600', and the uncemented slotted liner to TD at 15,596'. S-18A Permit to Drill 8/01/02 Page 1 ') ) Directional KOP: I -11,694' MD Maximum Hole Angle: -520 In original wellbore at 3400' MD / -980 In Horizontal interval of sidetrack All wells pass BP Close Approach guidelines. The nearest close approach well is S-29 which is -1057' well-to-well at 15,595' MD (- TD in the horizontal section). This well passes under Major Risk rules. Standard MWD Surveys from kick-off to TD. Close Approach Well: Survey Program: Mud Program Window Milling Properties: Low Density Quickdril Density (pp12f) Viscosity LSRV 8.4 (' 45 - 55 -25,000 cP I Whipstock Window in 7" I PV YP MBT 4 - 7 24 - 28 <3 Production M~d Properties: Low Density Quickdril Density (ppQf Viscosity LSRV 8.4 - 8.5J 40 - 50 < 12,000 cP 16-1/8" hole section PV YP 4 - 7 20 - 26 1 MBT <3 API FI pH N/C 8.5-9.0 API FI pH N/C 8.5-9.0 Logging Program 6-1/8" Production: Drilling: MWD IGR IRes I PWD I Inclination at Bit - Realtime over entire interval. Sample catchers required through interval, as per on-site Geologist. Open Hole: No open hole logs are planned. Cased Hole: No cased hole logs are planned. Cement Program Casing Size 14-1/2" Production Liner Basis: Lead: None Tail: Based on 1906' of open hole with 50% excess, 269' of 7" x 4%" liner lap, 5 bbls excess cement above liner top, and 1 bblleft inside inner-string as under-displacement. Tail TOC: -11,425' MD (8690' TVD).- Liner top. Fluid Sequence & Volumes: Pre 20 bbls CW-100 at 8.3 ppg Flush Spacer Lead Tail 30 bbls MudPUSH Viscosified Spacer weighted to 10.5 ppg None / 59 bbl I 331 fe I 216 sks o~owell Premium Latex 'G' with silica flour at 15.8 ppg and 1.53 dIsk, BHST 2360 I BHCT 1650 (use actual circulating temps recorded by MWD at TD), TT = Batch Mix + 4 to 4.5 hrs *See Attached Dowell Cement Program for Details on Cement Formulation* S-18A Permit to Drill 8/01/02 Page 2 ) ') Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum poteno/ surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3400 psi @ 8900' TVD - Zone 4 . Maximum surface pressure: 2510 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi / 8.6 ppg seawater / 6.8 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . S-18A Permit to Drill 8/01/02 Page 3 ) Sidetrack and Complete Procedure Summary -) Pre-Riq Work: 1. Rig up slickline. Pull plug from 'X' nipple in tubing tail at 11,404' MD. Drift tubing and tag top of fill in 7" liner for upcoming CTU P&A. 2. RIH with CTU and perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 7" liner from the top of fill (estimated at -11,878' MD from most recent slick-line tags) to -10,725' MD, plus squeeze 5 bbls to the perforations. Estimated cement volume needed is 10.9 barrels. Use aggregate as required to aid in plugging the perfs (this well was frac'd and has the potential to take cement). Once cement has been laid in and the desired squeeze obtained, RIH and wash out any excess cement down to -10,725' MD. Circulate the well clean above this point. NOTE: The upcoming sidetrack is planned to exit the 7" casing at -11,694', and the requirement to wash-out excess cement to -10,725' is to remove any cement from across the planned whipstock set depth. To meet AOGCC regulations, the top of cement should not extend below 11,746' MD, 100' above the top perf. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 4. Liquid pack both the tubing and 9-5/8" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3000 psi for 30 minutes. The 3Y2" tubing is severely corroded and has known leaks. 5. RU E-line. Cut the 3Y2" L-80 tubing at 11,315' MD using a chemical cutter (all depths referenced to Tubing Summary dated 9-4-89). The specified cut. depth is -2' down into the 3Y2" tubing pup above the 'X' nipple at 11,322.8'. This cut will be fished and the type and location of the cut is critical. As specified, the cut will leave approximately 8' of 3-1/2" tubing stub for fishing operations. 6. Displace the well to clean seawater by circulating down tubing through the tubing cut 1 holes in tubing. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. 7. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 8. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. 9. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Doyon 14. Circulate out freeze protec~n and displace well to seawater. Set TWC. 2. Nipple down tree. Nipple up and test BOPE. 3. Pull and lay down 4Y2" x 3Y2" tubing string from E-line cut and above. 4. MU overshot for 3Y2" tubing and RIH. Wash over and engage 3Y2" tubing stub. Release 'K' anchor from production packer and POH with remaining tubing down to production packer. 5. MU 9-5/8" packer milling assembly with PRT (packer retrieving tool). RIH and mill 9-5/8" packer until free. Engage fish with PRT (in mill out extension below packer) and POH with remaining packer and tubing tail assembly. 6. MU clean-out BHA with MWD/GR. RIH to top of cement in 7" liner and dress cement as required until firm cement is encountered. Use MWD/GR and existing GR/CCL log to tie-in top of cement with desired KOP. 7. Test wellbore to 3500 psi for 30 minutes. POH. /' 8. PU 7" Baker bottom-trip anchor whipstock assembly. Run a tubing spacer below the whipstock to place the top of whipstock at -11,694'MD when spacer bottoms-out on cement plug. Orient whipstock and set on cement plug. Mill window in 7" liner at :t 11,694' MD. Prior to POH, perform FIT to 9.5 ppg EMW. /' 9. RIH with 6-1/8" drilling assembly (with MWD/GR/RES/PWD) to whipstock. Kick-off and drill the 6-1/8" production section as per directional plan to and estimated TO @ :t15,596' MD (9038' TVD). 10. Run and cement a 4 Y2", 12.6# L-80 Bonzai production liner (combination solid and slotted) using an inner- string configuration. Set liner top packer. Test liner top packer and wellbore above liner top to 2500 psi for 10 / minutes. Displace well to clean seawater. POH laying down all DP. 11. Run a 4-1/2", 12.6# 13Cr-80 Vam ACE completion tying into the 4-1/2" liner top. / 12. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect the well to -2200' and secure the well. 15. Rig down and move off. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod 1 RHC plug from 'X' nipple below production packer. Install gas lift valves. S-18A Permit to Drill 8/01/02 Page 4 ) ') Job 1: MIRU Hazards and Contingencies » No wells will require shut-in for the rig move to 8-18. The well is positioned at the end of a well row and the nearest adjacent well (S-40) is approximately 76' from the 8-18 wellhead. Establish a minimum distance of 5' from the S-40 wellhouse. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. If it appears the 5' distance will be crossed, the move should be stopped, the rig backed up, and the move re-attempted. » S Pad is not designated as an H2S site, however Standard Operating Procedures for H28 precautions should be followed at all times. Recent H28 data from the pad is as follows: 5-18 -10 ppm (however well has been shut-in since September 1991) Adjacent producers at Surface: S-17C -10 ppm S-40 50 ppm Adjacent producers at TD: M-05A -10 ppm S-29A -10 ppm The maximum recorded level of H2S on the pad was 130 ppm on S-32 in January of 2000. » The perforations should be isolated by the cement P&A plug, however monitor the well to verify it's dead. .~:::~::~:m,':~;:;:.~.~.':'::.':1:m. H~;~mm. :~.m:.~.>.':";¡.'m."'.~~.~) Job 2: Decomplete Well Hazards and Contingencies » The perforations should be isolated by the cement P&A plug, however monitor the well for gain/loss prior to beginning decompletion operations. » The 4%" and 3%" tubing string is highly corroded and sections of the tubing have high wall loss, with several known penetrations (see attached Kinley Caliper Summary for details). Limit over-pull on tubing string to 800/0 of tensile strength, and if tubing will not pull free on initial attempt, RU e-line to make a second cut. » NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies » Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. ~~i(..MO;'."S'!)I«..:.:..:.IJ.,;;«m.'$'ifI.AI.'$j>M.'1-:ø;.;wm.~~~'M'>~m.'i'!~..rl'<'m~~'\W~i'$.~~~~~~~~II('9>-'.m-",...~)."S'!:~~,"»))$.."~'.~~,\I:iIo~«~I._~"''1-~~SR''j\~ 'J'5~:<t~ Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies » Two expected fault crossings and two possible fault crossings have been identified for this hole section (see the attached cross-section for details on fault throws and expected depths along the well path). The two expected fault crossings are associated with a down-thrown graben block. Throws on these two faults are large (90 to 140'), however the risk of encountering losses at these two faults is considered to be moderate. Both of the crossings are planned near the top Sad, where interbedded shales within the Sad as well as the Shublik and Kingak should provide adequate clay smear to help seal the fractures. The S-18A Permit to Drill 8/01/02 Page 5 ) -) remaining two 'possible faults' are expected to have relatively small throws (if they actually exist) and are considered as low risk for lost circulation. ~ Because of various fault related risks the entire target polygon is considered a hardline. In the heal of the well, fault crossings have been carefully evaluated and planned to minimize any potential for lost circulation. The curve which turns the wellpath to the west is planned to avoid the tip-out section of the second graben fault. And finally in the toe of the well, the polygon is designed to avoid large bounding faults north and south of the wellpath, and the potential fractured area associated with these faults. ~ S Pad has a history of lost circulation events while drilling in the reservoir section. Loss rates have ranged from 20 to 600 bph, and the majority of cases have been fault related. It seems that the majority of lost circulation events have been related to extremely high mud weights (up to 10.1 ppg) andlor crossing faults in high risk areas. Fiberous LCM pills were used with good results on a majority of these faults. Good drilling practices to limit ECD's and surge pressures should be a standard. To be prepared for potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Flow Chart' will be sent to the rig prior to drilling out in the 6-1/8" production interval. ~ Crossing the first graben fault poses a risk of inadvertently entering into the Kingak shale. As planned, we will be drilling in upper Zone 4 prior to encountering the fault, and will enter into the upper Shublik I lower Sag River on the down-thrown side. If fault throws are higher than expected, the wellbore could possibly end up in the Kingak. The decision to open-hole sidetrack will depend upon sample evaluation to determine the nature of the shale we have entered (pure Kingak or transition interval at base Kingak). ~ TD of the well could be extended by as much as 500' if costs are under the expected AFE and economics justify the additional expense. /" ~ Kick Tolerance: The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at -11,890' MD. This is a worst case scenario based on an 7.6 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" window, and 8.4 ppg mud in the hole. ~ Drilling Close Approach: For this hole section all wells pass BP Close Approach guidelines. The nearest close approach well is S-29/S-29A which is -1057' well-to-well at 15,595' M D (- TD in the horizontal section). If the S-18A TD is extended substantially, the close approach will need to be reexamined. .~~~>;:>;:,'?;,~:,','i:f:.'i Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ An entire slotted liner may replace the Bonzai liner if oil saturations within the original S-18 fault block are good and no losses are encountered while drilling the horizontal section. ~ Differential sticking could be a problem over this long horizontal section. Minimize the time the pipe is left stationary while running the liner. ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~~..............-- .""y, ^ ,.m._..w. .m Job 12: Run Completion Hazards and Contingencies ~ 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. S-18A Permit to Drill 8/01/02 Page 6 ) ..) Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. """'V»~~"""^"",,,''''''' S-18A Permit to Drill 8/01/02 Page 7 )5-18 Current 5tatu~) TREE = 4-1/16" CrN WELLHEAD = 13-5/8" I\AcEVOY 'AêTDÄTÕFf;,-~w.'._'_.--'~ëÄMERON KB~ËI.N';^--'~_W'----~'~g.' BF. ELEV ,; , , . 39.89' KOP;~'--'W~"^,,wm~~m~_w,,^w__mww9Õõ' '~~:~~fl~~.~w==:.,^,-,,~,=~~~~-,~^~~:" Datum MD = 11689' Datum TVD = 8800' SS 14-1/2" TBG, 12.6#, l-80, 0.0152 bpf, ID = 3.958" l-l 2028' I TOP OF 3-1/2" TBG l-l 2028' \13-3/8" CSG, 72#, l-80, ID = 12.347" Ii 3055' Minimum ID = 0.0" @ 11404' 3-1/2" XX PLUG I TOP OF 7" lNR 1-1 11376' I 13-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" l-l 11415' I 19-5/8" CSG, 47#,l-80, ID = 8.681" l-l 11650' I~ ÆRFORA TION SUMMARY REF LOG: BHCS/GR ON 08/11/85 ANGLE AT TOP ÆRF: 47 @ 11846' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 4 11846-11860 0 08/06/96 2-1/8" 4 11866-11890 0 08/06/96 2-7/8" 4 11890-11915 S 09/26/86 2-7/8" 4 11925-11940 S 09/26/86 I PBTD 1-1 12098' I 17" lNR, 26#, l-80 U4S, 0.0383 bpf, ID = 6.276" 1-1 12140' I DATE REV BY COMMENTS 08/16/85 ORIGINAL COMPlErION 03/09/01 SIS-MH CONVERTED TO CANVAS 03/12/01 SIS-MD FINAL 09/08/01 RNITP CORRECTIONS DA TE REV BY 8 2004' 1-l4-1/2" OTIS TRVS CP-2 SSSV NIP, ID = 3.813" r-/' / ~- ~. --1 2028' 1-l4-1/2" x 3-1/2" XO I ~ ST MD TVD 5 3553 2927 4 6572 5032 3 8701 6594 2 11202 8464 1 11928 8526 GAS LIFT MANDRElS DEV TYPE Vl V LATCH PORT DATE 50 OTIS RA 48 OTIS RA 37 OTIS RA 47 OTIS RA 48 OTIS RA I . I 11322' Ii 3-1/2" OTIS X NIP, ID = 2.750" I :8: :8: I 11336' 1-l9-5/8" x 3-1/2" BAKER SB-3 PKR, ID = 3.99" I I I ~~ 1-l3-1/2" OTIS X NIP, ID = 2.750" I 1-l3-1/2" XX PlUG I 1-l3-1/2" W/LEG I l-l ELMD IT LOGGED 07/09/90 I 11382' 1-l3-1/2" OTIS X NIP, ID = 2.750" I 11404' 11404' I 11415' I 11402' ~ g Top of fill tagged at 11,878' MD on 2/24/93 I 11934' 1-l5" CUTTER BAR 1-3/4" FISHING NECK I ~ COMMENTS PRUDHOE BA Y UNIT WELl: S-18 PERMIT No: 84-1250 A PI No: 50-029-21156-00 Sec. 35, T12N, T12E BP Exploration (Alaska) J-18 Proposed Pre-~)g TREE = 4-1/16" CIW WELLHEAD = 13-5/8" McEVOY ~AëruATÕFr;v."~-"-'^CArí:1ËRoN .KB. a:Ë\r;;~'-~~~--752g. ,~~~_.... BF. ELEV = 39.89' KÕp;~mm.'m~^Ww",M'WMW~'~'M"__M,_,v9õ'õ;' '§~~~~~~~~==~::,:~,:~=~3=~~~.~~: Datum MD = 11689' . Datum 1VD = -~~,v-^-8ãõo' S5 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 2028' 1 TOP OF 3-1/2" TBG l-i 2028' 113-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 3055' Pre-Rig tubing cut at -11,315' MD - I TOP OF 7" LNR l-i 11376' 1 13-1/2" TBG, 9.2#, L-80, 0.0087 bpf, 10 = 2.992" l-i 11415' I 19-5/8" CSG, 47#, L-80, 10 = 8.681" l-i 11650' ~ ÆRFORA TION SUMMARY REF LOG: BHCS/GR ON 08/11/85 ANGLE AT TOP ÆRF: 47 @ 11846' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11846-11860 0 08/06/96 2-1/8" 4 11866-11890 0 08/06/96 2-7/8" 4 11890-11915 S 09/26/86 2-7/8" 4 11925-11940 S 09/26/86 I PBTD l-i 12098' I 1 7" LNR, 26#, L-80 U4S, 0.0383 bpf, ID = 6.276" l-i 12140' I DATE 08/16/85 03/09/01 03/12/01 09/08/01 07/23/02 REV BY DA TE REV BY SIS-MH SIS-MD RN/TP WSI COMMENTS ORIGINAL COMA-ErION CONVERTED TO CANVAS FINAL CORRECTIONS Proposed Pre-Rig Work 8) Ó'I ~- rJ -1 --- I . :g: :8: ~ t ~ I 2004' 1-f4-1/2" OTIS TRVS CP-2 SSSV NIP, ID = 3.813" ¡ 2028' 1-i4-1/2" x 3-1/2" XO I ~ ST MD 5 3553 4 6572 3 8701 2 11202 1 11928 GAS LIFT MANDRELS TVD DEV ìYPE VLV LATCH PORT DATE 2927 50 OTIS RA 5032 48 OTIS RA 6594 37 OTIS RA 8464 47 OTIS RA 8526 48 OTIS RA I 11322' 1-i3-1/2" OTIS X NIP, ID = 2.750" I 1 11336' 1-i9-5/8" x 3-1/2" BAKERSB-3 PKR, 10= 3.99" 1 I I 11382' 1-i3-1/2" OTIS X NIP, ID = 2.750" I I 11404' 1-i3-1/2" OTIS X NIP, 10 = 2.750" 1 I 11415' 1-i3-1/2" W/LEG 1 I 11402' l-i ELMO TT LOGGED 07/09/90 I ~ Cement P&A plug with top planned at 11,725' MD :~: '..... Top of fill tagged at 11,878' MD on 2/24/93 Filii - -, ~ COMMENTS 1 11934' 1-i5"CUTTERBAR1-3/4"FISHINGNECK I PRUDHOE BAY UNIT WELL: S-18 ÆRMIT No: 84-1250 API No: 50-029-21156-00 Sec. 35,T12N, T12E BP Exploration (Alaska) TREE: 4-1/16" - 5M CIW L-80 WELLHEAD: 135/8" - 5M McEvoy S-18A Proposed Completion I 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' Cellar Elevation = 38.49' Base Flange = 39.89' Doyon 14 RKB = 72.80' 13-3/8", 72 #Ift, L-80, BTC I 3055' 1 a .. --.-!: 4-1/2" 12.6# 13Cr-80 Vam Ace Tubing with GLM's v L 6 5 4 3 2 1 GAS LIFT MANDRELS MD Size TBD 1-1/2" TBD 1-1/2" TBD 1-1/2" TBD 1-1/2" TBD 1-1/2" 1 jt above pkr 1-1/2" Valve Type DV RP Shear DV DV DV DV ~ --.-!: L L 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker' S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. Two full joints of 4-1/2" tubing 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. . . 7" Liner Top at 111,376' I I ~ r: i4 I +/-11,425' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMc' Hydraulic Liner Hanger Window Milled from Whipstock Top of Window at +/-11,694' MD '- ~. 9-5/8",47 lIft, L-80, BTC 111,650'1 ~ 4-1/2" 12.6#, L-80, IBT-M Solid liner wlBaker EcP at 1 +/-13,600' I 4-1/2" 12.6 #/lt, L-80, IBT Slotted Liner I-I 1+/-15,596' I 11;;;II;lillllll I) I-I ~ . 'CemerÍf ~ "$ .......::;: ~ ==- Date 08/01/02 Rev By WSI Comments PRUDHOE BAY UNIT WELL: S-18A API NO: 50-029-21156-01 Proposed Completion Fill 7", 26 lIft, L-80, IJ4S r 12,140' I GPB Drilling & Wells . SIJ~ ¡,;,,;'I"I(J': 14352.52' MD, 9024.13'TVD ---~~,~~-~:,; ;:III-'-;-.-;-.'~'::' -',; ~1'[-):-~~~:~~17~[~:~1:\-"MD:FI ~ \ \: . [1"ln" 11t,''\~7'l\ll) ~"~I X" TV ) \ . ;", "," : ,.'.", :. ,,,,1,. "no \ : : r.d -';;00=" : I\ID x'n: :,; I\D: S~r1 Dir4/IOO': 14544'-"" 1\.1[~. 'III> s'-'ï\T> 1\1[J s'17": l' I \'[1 ¡ ¡ End DIL.: l'::¡I,q_' III~ 1\1[J. ,,(, HI'~:'\' ---- -~ .... -t--_oo ¡ ! I bp COMI'ANY DETAII.S IW Amoco ('ulclllllliou MIJUlo<!; MillinHun Curv¡¡(un: U~~~r ~~~~~~ ~1~~~V[~~IKlcr North Error Surlìlc,",; Elliptical I Casing W"mjlJ~ MelhlKl; Hllles Bused ;1 I I' I I I .I I ; ,I I " ,# ;<: "", ,~ ~ ~ ....7I;'ý '/' ~ .. "»...' ~,~ ,,"~ 8400- '2 ~ 8800 0 0 ::!:. .c:: ß. 0 '" <.J .~ > 2 f-< 9200 I 400 REFERENCE INFORMATION Co-ordinatc (NIE) Reference: Well Centre: S~ 18, True North Vertical (TVD) Reference; 73.8973.89 Se<:tion (VS) Reference; User Defined (-7176.40N,739.80E) Mcas~a~~fa~~o~e~~~~~ '~i~~urn ~~ , Z.8 . CASING DETAILS No. TVD MD Size Name 9038.89 15598.01 4 1/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 2 3 8859.89 11667.79 Sag 8898.89 11725.07 Shublik 8983.89 11885.71 TSad ¡ í I ¡ I I I 1200 1600 Vertical Section at 242.260 [ 400ft/in] SURVEY PROGRAM Wellpath: (S-18/Plan S-18A) Depth Fm Depth To SUfveylPlan Too1 Created By: Ken Allen Checked : Date: Date: 7/23/2002 11695.00 15598.02 PllIlmed; S-18A wp08 V4 MWD Reviewed: Date: WELL DETAILS Name +N/-S +Ef-W Northing Easting Latitude Longitude Slot S-18 -1700.67 93851 5979169.00 618885.00 70"21'06.276N 149"02'04.914W N/A TARGET DETAILS Name lVD +N/-S +E/-W Northing Easting Shape S-18A nc 8958.89 -8545.18 339,49 5970631.00 619359.99 Point S-18A Polygon 1 8973.89 -7114.33 872.31 5972070.00 619869.99 Polygon S-18A T2c 8973.89 -7896.62 564.83 5971283.00 619574.99 Point S-18A T5e 8998.89 -8832.87 -125.17 5970336.00 618899.99 Point S-18A T60 9028.89 -8857.35 -851.70 5970300.00 618174.00 Point 8-18A T7c 9038.89 -8541.35 -1855,91 5970600.00 617164.99 Point SECTION DETAILS See MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 11695.00 46.25 179.18 8878.75 -7095.27 739.15 0.00 0.00 -37.19 2 11715.00 48.51 180.27 8892.29 -7109.98 739.22 12.00 20.00 -30.40 3 12183.53 97.93 196.22 9024.18 -7537.48 668.75 11.00 20.34 230.94 4 12509.41 97.93 196.22 8979.23 -7847.39 578.58 0.00 0.00 454.99 5 12560.81 94.00 195.00 8973.89 -7896.62 564.83 8.00 -162.74 490.07 S-18A T2c 6 12594.88 91.50 193.91 8972.26 -7929.57 556.34 8.00 -156.43 512.92 ~ 7 12951.86 91.50 193.91 8962.90 -8275.96 470.55 0.00 0.00 750.07 8 13253.54 90.00 218.00 8958.89 -8545.18 339.49 8.00 93.35 991.37 S-ISA T3c 9 13653.47 83.58 249.41 8981.85 -8778.74 22.07 8.00 102.18 1381.02 10 13762.26 83.58 249.41 8994.01 -8816.75 -79.14 0.00 0.00 1488.29 II 13811.29 85.00 252.00 8998.89 -8832.87 -125.17 6.00 61.28 1536.54 S-18A T5c 12 14123.30 88.29 270.46 9017.30 -8880.05 -431.64 6.00 80.50 1829.75 13 14352.52 88.29 270.46 9024.13 -8878.20 -660.75 0.00 0.00 2031.67 14 14544.99 88.88 282.00 9028.89 -8857.35 -851.70 6.00 87.24 2190.97 S-18A T6c 15 14692.79 89.50 287.88 9030.98 -8819.27 -994.43 4.00 84.03 2299.57 16 15598.02 89.50 287.88 9038.89 -8541.35 -1855.91 0.00 0.00 2932.71 S-ISA T7c AllTVD depths are ssTVD.plus~ror RKBE. ~",ou"D 6t t lL.ß ~ I 2000 ¡ Dcpt" I""'~ IIC' 1\1D. ''') t~.~4' 1 V[I - 'J"" .~, ! , --..; - 1"111111 2400 I 2800 bp COMPANY )ETAII^~ REFERENCE INFORMATION liP Amoco Co-ordil1atc (NfE) Reference: Wen Centre: S-18, True North Vertical (TVD) Reference: 73.8973.89 Section (VS) Reference: User Defmed (-7176.40N,739.80E) Meas~a~fa~o~e~~~::~ Ui'~mum~ture .%.8 . Calculation Method: Minimum Curvaluro ~~~~;; ~~:~l~:: ~I~~"[~~ndcr North I~rror Surfiu;c: Ellipli~ll-i Casing W.mill~ Methud: Rules Based CASING DETAILS FORMATION TOP DETAILS Size No, TVDPath MDPath Fonnation 4.500 I 8859.89 11667,79 Sag 8898.89 11725.07 Shublik 8983.89 11885.71 TSad No. TVD MD Name 9038.89 15598,01 41/2" AllTVD depths are ssTVD plus ~for RKBE. -s" 0\1 &.1) IE. 11.8' E ;¡;: 0 0 ~ :;:- :E 1:: ~ :E g C/J "II'S s""1 VD I 0 W est( - )/East( +) [600ft/in] Depth Fm Depth To SurveyJPlan 11695.00 15598.02 ptanned: S-18A wp08 V4 See I 11,," ).00 2 11'1 ;,00 3 L I. \.53 4 L "').41 5 1:'.'.'}'81 6 J.:".t88 7 L" . 1.86 8 I': \.54 9 I ". . 1.47 10 I. "._~.26 111"11.29 12 I.J I: \.30 13 I.J' -~,52 14 I.J.J +.99 15 I.J':'_~.79 16 1...":{'02 " J.. --+ i-I / / / f J- S-18 (S-18) 1 \ó~ \ .H'MD, 8981.85' TVD 11762.26' MD, 8994.01'TVD I 6UU SURVEY PROGRAM Name +N/-S Plan: S-18A wp08 (S-18/Plan S-18A) Tool Created By; Ken Allen Date; 7/23/2002 MWD Checked: Date; Reviewed: Date; WELL DETAILS +E/-W Northing Easting Latitude Longitude Slot S-18 ,1700.67 938.51 5979169.00 TARGET DETAILS 618885.00 70"21'06.276N 149"02'04.914W N/A Name TVD +N/-S +E/-W Northing Basting Shape S-18A Bc 8958.89 -8545.18 339.49 5970631.00 619359.99 Point S-18A Pnlygon I 8973.89 -7114.33 872.31 5972070.00 619869.99 Polygon S-18A nc 8973.89 -7896.62 564.83 5971283.00 619574.99 Point S-18A T5c 8998.89 -8832.87 -125.17 5970336.00 618899.99 Puint S-18A T6c 9028.89 -8857.35 -851.70 5970300.00 618174.00 Puint S-18A TIc 9038.89 -8541.35 -1855.91 5970600.00 617164.99 Point SECTION DETAILS Inc Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 46.25 179.18 ss7~. 75 -7095.27 739.15 0.00 0.00 -37.19 48.51 180.27 SS'~2.29 -7109.98 739.22 12.00 20.00 -30.40 97.93 196.22 '1I1~..1.18 -7537.48 668.75 11.00 20.34 230.94 97.93 196.22 s'I7'>.23 -7847.39 578.58 0.00 0.00 454.99 94.00 195.00 S'I] J.89 -7896.62 564.83 8.00 -162.74 490.07 S-18A T2e 91.50 193.91 S' ] 2.26 -7929.57 556.34 8.00 -156.43 512.92 91.50 193.91 s""2.90 -8275.96 470.55 0.00 0.00 750.07 '-"'" 90.00 218.00 s'I"~.89 -8545.18 339.49 8.00 93.35 991.37 S-18A Be 83.58 249.41 S'JS 1.85 -8778.74 22.07 8.00 102.18 1381.02 83.58 249.41 s' '4.01 -8816.75 -79.14 0.00 0.00 1488.29 85.00 252.00 S' 'l~.89 -8832.87 -125.17 6.00 61.28 1536.54 S-18A T5c 88.29 270.46 ')1/17.30 -8880.05 -431.64 6.00 80.50 1829.75 88.29 270.46 "1/2.t13 -8878.20 -660.75 0.00 0.00 2031.67 88.88 282.00 "I/~:i.89 -8857.35 -851.70 6.00 87.24 2190.97 S-ISA T6e 89.50 287.88 '111111.98 -8819.27 -994.43 4.00 84.03 2299.57 89.50 287.88 "11.'):(.89 -8541.35 -1855.91 0.00 0.00 2932.71 S-ISA T7e MD I 1200 Ø¡ l\ Ii Ii ';i 1\ Ii -I: 1:' ,I II .l ~ -) BP My Planning Report MAP ''1 ) Company: Field: Site: Well: Wellpath: Field: Date: 7/23/2002 Time: 18:00:01 Co-ordinate(NE) Reference: Well: S-18, True North Vertical (TVD) Reference: 73.89 73.9 Section (VS) Reference: User (-7176.40N,739.80E,242.26Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 5980854.54 ft Latitude: 70 21 23.002 N 617919.92 ft Longitude: 149 2 32.343 W North Reference: True Grid Convergence: 0.90 deg Slot Name: 5979169.00 ft Latitude: 70 21 6.276 N 618885.00 ft Longitude: 149 2 4.914 W BP Amoco Prudhoe Bay PB S Pad 5-18 Plan S-18A 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: PB S Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: Well: S-18 +N/-S -1700.67 ft Northing: +E/-W 938.51 ft Easting: Position Uncertainty: 0.00 ft Well Position: Well path: Plan S-18A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 739.80 Current Datum: Magnetic Data: Field Strength: Vertical Section: 73.89 8/28/2001 57502 nT Depth From (TVD) ft 0.00 Height 73.89 ft +N/-S ft -7176.40 Plan: S-18A wp08 Date Composed: Version: Tied-to: Principal: Yes Casing Points Page: Alaska, Zone 4 Well Centre BGGM2002 S-18 11695.00 ft Mean Sea Level 26.35 deg 80.80 deg Direction deg 242.26 7/22/2002 4 From: Definitive Path .MD TVI> Diameter ft ft in 15598.01 9038.89 4.500 6.125 41/2" Formations TVI> J)iÞA:i)gl~ J)ippïrection ft d~ deg 11667.79 8859.89 Sag 0.00 0.00 11725.07 8898.89 Shublik 0.00 0.00 11885.71 8983.89 TSad 0.00 0.00 Targets Map Map <..,..-- Latitude --> <--- Longitude --> Name Description TVI> +N/-S +E/- W Northing Easting Deg. Min Sec Deg Min. Sec Dip. Dir. ft ft ft ft ft S-18A T3c 8958.89 -8545.18 339.49 5970631.00 619359.99 70 19 42.235 N 149 1 55.003 W S-18A Polygon1 8973.89 -7114.33 872.31 5972070.00 619869.99 70 19 56.307 N 149 1 39.443 W -Polygon 1 8973.89 -7114.33 872.31 5972070.00 619869.99 70 19 56.307 N 149 1 39.443 W -Polygon 2 8973.89 -7911.60 689.72 5971270.00 619700.09 70 19 48.466 N 149 1 44.777 W -Polygon 3 8973.89 -8603.71 498.60 5970575.00 619519.99 70 19 41.659 N 149 1 50.358 W -Polygon 4 8973.89 -8898.46 163.86 5970275.00 619190.00 70 19 38.761 N 149 2 0.130 W -Polygon 5 8973.89 -8995.05 -367.79 5970170.00 618659.99 70 19 37.810 N 149 2 15.650 W -Polygon 6 8973.89 -8958.94 -752.30 5970200.00 618274.99 70 19 38.165 N 149 2 26.875 W -Polygon 7 8973.89 -8902.68 -1146.49 5970249.99 617879.99 70 19 38.718 N 149 2 38.382 W -Polygon 8 8973.89 -8639.04 -2002.48 5970500.00 617020.00 70 19 41.309 N 149 3 3.372 W -Polygon 9 8973.89 -8320.32 -1917.41 5970820.00 617099.99 70 19 44.444 N 149 3 0.891 W -Polygon 10 8973.89 -8723.48 -1093.63 5970429.99 617929.99 70 19 40.481 N 149 2 36.840 W -Polygon 11 8973.89 -8769.43 -719.28 5970389.99 618304.99 70 19 40.029 N 149 2 25.911 W Compan)': BP Amoco Field: Prudhoe Bay Site: PB 5 Pad Well: 5-18 Wellpath: Plan 5-18A Targets Name Description TVD Dip. Dir. ft -Polygon 12 8973.89 -Polygon 13 8973.89 -Polygon 14 8973.89 -Polygon 15 8973.89 -Polygon 16 8973.89 S-18A T2c 8973.89 S-18A T5c 8998.89 S-18A T6c 9028.89 S-18A T7c 9038.89 Plan Section Information -) BP My Planning Report MAP ') Date: 7/23/2002 Time: 18:00:01 Co-ordinate(NE) Reference: Well: S-18, True North Vertical (TVD) Reference: 73.89 73.9 Section (VS) Reference: User (-7176.40N.739.80E,242.26Azi) Sur\'e)' Calculation Method: Minimum Curvature Db: Oracle Page: 2 +N/-S ft -8784.90 -8738.47 -8544.03 -7866.36 -7110.05 +E/- W ft -374.46 -148.67 204.49 360.27 602.32 ~1ap ~Iap Northing Easting ft ft 5970380.00 618649.99 5970430.00 618874.99 5970630.00 619225.00 5971310.00 619369.99 5972069.99 619599.99 <-- Latitude --> <-- Longitude -> Deg Min Sec Deg Min Sec 70 19 39.877 N 149 2 15.845 W 70 19 40.334 N 149 2 9.254 W 70 19 42.246 N 149 1 58.944 W 70 19 48.911 N 149 1 54.395 W 70 19 56.349 N 149 1 47.327 W 70 19 48.613 N 149 1 48.423 W 70 19 39.406 N 149 2 8.568 W 70 19 39.164 N 149 2 29.777 W 70 19 42.270 N 149 2 59.094 W MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 11695.00 46.25 179.18 8878.75 -7095.27 739.15 0.00 0.00 0.00 0.00 11715.00 48.51 180.27 8892.29 -7109.98 739.22 12.00 11.30 5.48 20.00 12183.53 97.93 196.22 9024.18 -7537.48 668.75 11.00 10.55 3.40 20.34 12509.41 97.93 196.22 8979.23 -7847.39 578.58 0.00 0.00 0.00 0.00 12560.81 94.00 195.00 8973.89 -7896.62 564.83 8.00 -7.64 -2.38 -162.74 S-18A T2c 12594.88 91.50 193.91 8972.26 -7929.57 556.34 8.00 -7.33 -3.20 -156.43 12951.86 91.50 193.91 8962.90 -8275.96 470.55 0.00 0.00 0.00 0.00 13253.54 90.00 218.00 8958.89 -8545.18 339.49 8.00 -0.50 7.99 93.35 S-18A T3c 13653.47 83.58 249.41 8981.85 -8778.74 22.07 8.00 -1.61 7.85 102.18 13762.26 83.58 249.41 8994.01 -8816.75 -79.14 0.00 0.00 0.00 0.00 13811.29 85.00 252.00 8998.89 -8832.87 -125.17 6.00 2.90 5.28 61.28 5-18A T5c 14123.30 88.29 270.46 9017.30 -8880.05 -431.64 6.00 1.06 5.92 80.50 14352.52 88.29 270.46 9024.13 -8878.20 -660.75 0.00 0.00 0.00 0.00 14544.99 88.88 282.00 9028.89 -8857.35 -851.70 6.00 0.30 5.99 87.24 S-18A T6c 14692.79 89.50 287.88 9030.98 -8819.27 -994.43 4.00 0.42 3.98 84.03 15598.02 89.50 287.88 9038.89 -8541 .35 -1855.91 0.00 0.00 0.00 0.00 S-18A T7c Survey MD hid AZim TVD Sys TVD MapN MapE VS DLS ft døg dég ft ft ft ft ft dég/10Oft 11667.79 45.99 178.90 8859.89 8786.00 5972106.54 619735.93 -46.02 0.00 Sag 11695.00 46.25 179.18 8878.75 8804.86 5972086.95 619736.57 -37.19 1.20 Start Dir 12/100': 11695' MD, 11700.00 46.82 179.46 8882.19 8808.30 5972083.32 619736.67 -35.54 12.00 MWD 11715.00 48.51 180.27 8892.29 8818.40 5972072.24 619736.87 -30.40 12.00 Start Dir 11/100': 11715' MD, 11725.07 49.55 180.78 8898.89 8825.00 5972064.63 619736.92 -26.80 11.00 Shublik 11750.00 52.13 181.97 8914.63 8840.74 5972045.31 619736.76 -17.39 11.00 MWD 11800.00 57.35 184.12 8943.49 8869.60 5972004.53 619735.21 3.51 11.00 MWD 11850.00 62.59 186.03 8968.50 8894.61 5971961.38 619732.05 26.98 11.00 MWD 11861.95 63.85 186.46 8973.89 8900.00 5971950.75 619731.06 32.94 11.00 S-18A Polygon1 11885.71 66.35 187.29 8983.89 8910.00 5971929.33 619728.82 45.18 11.00 TSad 11900.00 67.86 187.77 8989.45 8915.56 5971916.25 619727.30 52.78 11.00 MWD 11950.00 73.15 189.38 9006.13 8932.24 5971869.56 619721.01 80.69 11.00 MWD 12000.00 78.44 190.91 9018.40 8944.51 5971821.75 619713.22 11 0.45 11.00 MWD 12050.00 83.75 192.38 9026.13 8952.24 5971773.24 619704.02 141.78 11.00 MWD 12100.00 89.06 193.82 9029.27 8955.38 5971724.48 619693.49 174.40 11.00 MWD 12150.00 94.37 195.25 9027.77 8953.88 5971675.93 619681.72 208.01 11.00 MWD 12183.53 97.93 196.22 9024.18 8950.29 5971643.71 619673.19 230.94 11.00 End Dir : 12183.53' MD, 9024. 12200.00 97.93 196.22 9021.91 8948.02 5971627.98 619668.89 242.26 0.00 MWD 12300.00 97.93 196.22 9008.12 8934.23 5971532.46 619642.73 311.01 0.00 MWD 12400.00 97.93 196.22 8994.32 8920.43 5971436.94 619616.58 379.77 0.00 MWD -7896.62 564.83 5971283.00 619574.99 -8832.87 -125.17 5970336.00 618899.99 -8857.35 -851.70 5970300.00 618174.00 -8541.35 -1855.91 5970600.00 617164.99 ) BP ) My Planning Report MAP Compao)': BP Amoco Date: 7/23/2002 Time: 18:00:01 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: S-18, True North Sjte: PB S Pad Vertical (TVD) Reference: 73.89 73.9 Well: S-18 Section (\'S) Reference: User (-7176.40N,739.80E,242.26Azi) Wellpath: Plan S-18A Surve)' Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 OOft 12509.41 97.93 196.22 8979.23 8905.34 5971332.43 619587.96 454.99 0.00 Start Dir 8/100' : 12509.41' M 12550.00 94.83 195.26 8974.72 8900.83 5971293.45 619577.64 482.74 8.00 MWD 12560.81 94.00 195.00 8973.89 8900.00 5971283.00 619574.99 490.07 8.00 S-18A T2c 12594.88 91.50 193.91 8972.26 8898.37 5971249.92 619567.02 512.92 8.00 End Dir : 12594.88' MD, 8972. 12600.00 91.50 193.91 8972.12 8898.23 5971244.94 619565.87 516.32 0.00 MWD 12700.00 91.50 193.91 8969.50 8895.61 5971147.54 619543.39 582.76 0.00 MWD 12800.00 91.50 193.91 8966.88 8892.99 5971050.15 619520.90 649.19 0.00 MWD 12900.00 91.50 193.91 8964.26 8890.37 5970952.75 619498.41 715.62 0.00 MWD 12951.86 91.50 193.91 8962.90 8889.01 5970902.24 619486.75 750.07 0.00 Start Dir 8/100' : 12951.86' M 13000.00 91.27 197.76 8961.74 8887.85 5970855.75 619474.36 783.24 8.00 MWD 13050.00 91.03 201.75 8960.73 8886.84 5970808.45 619458.22 820.08 8.00 MWD 13100.00 90.78 205.74 8959.94 8886.05 5970762.39 619438.82 859.19 8.00 MWD 13150.00 90.53 209.73 8959.37 8885.48 5970717.79 619416.26 900.37 8.00 MWD 13200.00 90.27 213.73 8959.02 8885.13 5970674.86 619390.65 943.43 8.00 MWD 13253.54 90.00 218.00 8958.89 8885.00 5970631.00 619359.99 991.37 8.00 S-18A T3c 13300.00 89.22 221.63 8959.21 8885.32 5970594.85 619330.82 1034.30 8.00 MWD 13350.00 88.38 225.55 8960.26 8886.37 5970558.11 619296.94 1081.65 8.00 MWD 13400.00 87.54 229.46 8962.04 8888.15 5970523.79 619260.65 1129.96 8.00 MWD 13450.00 86.72 233.38 8964.54 8890.65 5970492.04 619222.12 1179.00 8.00 MWD 13500.00 85.92 237.31 8967.75 8893.86 5970463.02 619181.55 1228.52 8.00 MWD 13550.00 85.13 241.24 8971.65 8897.76 5970436.89 619139.12 1278.29 8.00 MWD 13600.00 84.37 245.18 8976.23 8902.34 5970413.75 619095.05 1328.06 8.00 MWD 13653.47 83.58 249.41 8981.85 8907.96 5970392.46 619046.34 1381.02 8.00 End Dir : 13653.47' MD, 8981. 13700.00 83.58 249.41 8987.05 8913.16 5970375.51 619003.32 1426.90 0.00 MWD 13762.26 83.58 249.41 8994.01 8920.12 5970352.84 618945.76 1488.29 0.00 Start Dir 6/100' : 13762.26' M 13800.00 84.67 251.41 8997.87 8923.98 5970339.69 618910.60 1525.45 6.00 MWD 13811.29 85.00 252.00 8998.89 8925.00 5970336.00 618899.99 1536.54 6.00 S-18A T5c 13850.00 85.39 254.30 9002.13 8928.24 5970324.23 618863.26 1574.42 6.00 MWD 13900.00 85.90 257.26 9005.93 8932.04 5970311.22 618815.14 1622.88 6.00 MWD 13950.00 86.42 260.22 9009.28 8935.39 5970300.71 618766.38 1670.72 6.00 MWD 14000.00 86.95 263.18 9012.18 8938.29 5970292.73 618717.12 1717.78 6.00 MWD 14050.00 87.49 266.14 9014.60 8940.71 5970287.29 618667.48 1763.95 6.00 MWD 14100.00 88.04 269.09 9016.55 8942.66 5970284.42 618617.61 1809. 1 0 6.00 MWD 14123.30 88.29 270.46 9017.30 8943.41 5970283.96 618594.34 1829.75 6.00 End Dir : 14123.3' MD, 9017.3 14200.00 88.29 270.46 9019.58 8945.69 5970283.36 618517.67 1897.32 0.00 MWD 14300.00 88.29 270.46 9022.56 8948.67 5970282.59 618417.73 1985.41 0.00 MWD 14352.52 88.29 270.46 9024.13 8950.24 5970282.18 618365.24 2031.67 0.00 Start Dir 6/100' : 14352.52' M 14400.00 88.43 273.31 9025.48 8951.59 5970282.99 618317.79 2072.92 6.00 MWD 14450.00 88.58 276.31 9026.79 8952.90 5970286.39 618267.94 2115.05 6.00 MWD 14500.00 88.74 279.30 9027.95 8954.06 5970292.39 618218.32 2155.72 6.00 MWD 14544.99 88.88 282.00 9028.89 8955.00 5970300.00 618174.00 2190.97 6.00 S-18A T6c 14600.00 89.11 284.19 9029.86 8955.97 5970311.61 618120.24 2232.59 4.00 MWD 14692.79 89.50 287.88 9030.98 8957.09 5970335.81 618030.70 2299.57 4.00 End Dir : 14692.79' MD, 9030. 14700.00 89.50 287.88 9031.04 8957.15 5970337.91 618023.80 2304.62 0.00 MWD 14800.00 89.50 287.88 9031.92 8958.03 5970367.10 617928.17 2374.56 0.00 MWD 14900.00 89.50 287.88 9032.79 8958.90 5970396.28 617832.54 2444.50 0.00 MWD 15000.00 89.50 287.88 9033.67 8959.78 5970425.47 617736.90 2514.44 0.00 MWD 15100.00 89.50 287.88 9034.54 8960.65 5970454.65 617641.27 2584.38 0.00 MWD 15200.00 89.50 287.88 9035.41 8961.52 5970483.84 617545.63 2654.33 0.00 MWD 15300.00 89.50 287.88 9036.29 8962.40 5970513.02 617450.00 2724.27 0.00 MWD 15400.00 89.50 287.88 9037.16 8963.27 5970542.21 617354.37 2794.21 0.00 MWD 15500.00 89.50 287.88 9038.03 8964.14 5970571.39 617258.73 2864.15 0.00 MWD CompanJ': BP Amoco Field: Prudhoe Bay Site: PB 5 Pad Well: 5-18 Wellpath: Plan 5-18A Survey MD ft 15598.01 15598.00 15598.02 Incl Azim deg deg 89.50 287.88 89.50 287.88 89.50 287.88 ) BP My Planning Report MAP ') Date: 7/23/2002 Time: 18:00:01 Co-ordinate(NE) Reference: Well: 5-18, True North Vertical (TVD) Reference: 73.89 73.9 Section (\'S) Reference: User (-7176.40N,739.80E,242.26Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: 4 TVD Sys TVD l\'lapN MapE VS DLS Tool/Comment ft ft ft ft ft deg/10OO 9038.89 8965.00 5970600.00 617165.00 2932.70 0.00 41/2" 9038.89 8965.00 5970599.99 617165.01 2932.69 0.00 Total Depth: 15598.02' MD, 90 9038.89 8965.00 5970600.00 617164.99 2932.71 0.00 S-18A T7c f 207008 DATE (12/02 INV# CK071002 INVOICE I CREDIT MEMO ') DESCRIPTION PERMIT TO DRILL FEE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) .INC. P.O.BOX196612 ' ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF B P ~f ~..1<"'" ~t~ tlltf().. O(J ~: . i...::1> f'IJ~"ufl" ,.n..n. ........... ALASKA.ÙIL& GAS CONSERVATION COMMISSION .. 333 W7THAVE STE100 ANCHORAGEj AK. 99501 GROSS S - 18 A III 2 0 7 0 0 8 III I: 0'" ¡. 2 0 j 8 g 5 I: 0 0 8 ~... ¡. g "I DATE 7/12/02 CHECK NO. H207008 VENDOR DISCOUNT NET \Z!~f.~~~::~&~~:i%~;~~~~Ú;}:::!~(:;t:~. :""':"\::~~ ~. ::~~..:...~::-...~:.....: :.....~:,,~.. ~~g~~\i]:;.3;::~;~~¡;f~i~;~~ij:~¿~ ) ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME jJ!(A \)-lyA PTD# 202-- /G -S .. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE" The permit is for a newwellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY t< P)¿ WELL NAME ?ð~ S -" /<6/l PROGRAM: Exp - Dev..A Redrll ~ Re-Enter - Serv - Wellbore seg - FIELD & POOL ¡::; q 6 J $' ð INIT CLASS .l.?P~./ /" 0 // GEOL AREA? '/ ("'r UNIT# II h_C: r:) ON/OFF SHORE DA.> ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_!,Y /,..,/. A \ (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ø N 16. Surface casing protects all known USDWs. . . . . . . . . . . éf) N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥--oN- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥:::-N-. J 19. GMT will cover all known productive hortzons. . . . . . . . ~ N ~11ÀA t.r €4œç <;: ~'C 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N P. 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . - N ~ 14. 22. If a re-drill, has a 10-403 for abandonment been approved. . . ß2 N i (I 0 Z- 23. Adequate wellbore separation proposed.. . . . . . . . . . . . æ:. N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-N- AI (~ 25. Drilling fluid program schematic & equip list adequate. . . . . IN rn u . ¡J1 J i. S- P. pc¡ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N I APPR DATE 27. BOPE press rating appropriate; test to 3500 psig. N fYl S J? 2Ç¡ 0 p.s. i . - ,.f 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~A- ~ ~f 0 1.. 29. Work will occur without operation shutdown. . . . . . . . . . . . ..bI 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y & (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . .~N/Ir GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . @ N APPR DATE 33. Data presented on potential overpressure zones. . . . . . . ~ Y N /? /Î 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / {:{ r-/ I 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N (Exploratory Only) 36. Contact name/phone for weekly progress reports. . . . . . . . Y N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER RP~ TEM JDH #.--"" JBR APPR DATE -Rev: 07/12/02 SFD- WGA VJt;A- COMMISSIONER: COT . DTS OY>j07/ðz MJW G:\geology\perm its\checklist.doc Comments/Instructions: ') ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation of this nature is accumulated at the end of the file under APPEN,DIX. No special" effort has been made to chronologically organize this category of infonnation. ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 18 13:06:31 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 /03/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Services ) :J,œ-llo3 I (013 Library. Scientific Technical Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 /03/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Services Library. Scientific Technical Physical EOF Comment Record TAPE HEADER Prudhoe Bay, WOA MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA S-18A 500292115601 BP Exploration Sperry Sun 18-MAR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AKMW22137 C.A. DEMOSKI A. MADSEN MWD RUN 3 AKMW22137 C.A. DEMOSKI A. MADSEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 2314 711 MSL 0) 32.40 72.29 39.89 (Alaska) MWDRUN 4 AKMW22137 T. MCGUIRE L. VAUGHN # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ') ) OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 10936.0 6.125 7.000 11705.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) 1 AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. MWD RUNS 3-4 WERE DIRECTIONAL WITH DGR1 EWR-41 PRESSURE WHILE DRILLING (PWD) 1 AND AT-BIT INCLINATION (ABI). 6. MWD RUNS 1-4 REPRESENT WELL S-18A WITH API # 50-029-21156-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 159371 MD / 90331 TVD. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SMOOTHED FORMATION EXPOSURE TIME = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS SEMP = SEDP = SFXE = SLIDE $ RATE OF PENETRATION WHILE DRILLING GAMMA RAY - GEIGER-MULLER TUBE DETECTORS PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/18 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS 1 clipped curves; all bit runs merged. .5000 START DEPTH 10845.5 10930.0 10930.5 10930.5 10930.5 STOP DEPTH 15882.5 15889.5 15889.5 15889.5 15889.5 ) ) RPX ROP $ 10930.5 10937.0 15889.5 15937.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 10845.0 3 11705.0 4 14912.0 MERGE BASE 11705.0 14912.0 15937.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10845.5 15937 13391.3 10184 10845.5 15937 ROP MWD FT/H 0.07 1096.81 136.659 10001 10937 15937 GR MWD API 14.19 579.95 82.8866 10075 10845.5 15882.5 RPX MWD OHMM 0.7 2000 42.4944 9919 10930.5 15889.5 RPS MWD OHMM 0.47 2000 86.819 9919 10930.5 15889.5 RPM MWD OHMM 0.45 2000 61.818 9919 10930.5 15889.5 RPD MWD OHMM 0.35 2000 129.94 9919 10930.5 15889.5 FET MWD 15889.5 HOUR ) 0.16 ) 58.04 1.68033 9920 10930 First Reading For Entire File... ..... ..10845.5 Last Reading For Entire File........ ...15937 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/18 Maximum physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .03/03/18 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET SGRC GR ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 10845.0 10845.0 10845.0 10845.0 10845.0 10845.5 10845.5 10937.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 11660.5 11660.5 11660.5 11660.5 11660.5 11668.5 11668.5 11705.0 23-AUG-02 Insite 6.02 Memory 11705.0 10930.0 11705.0 ) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER1S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ...... .... ......0 Data Specification Block Type.....O Logging Direction...... ..... ..... . Down Optical log depth units..... ..... .Feet Data Reference Point.... ......... . Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record.. ..... ..... . Undefined Absent value...... .......... ..... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 47.1 50.6 TOOL NUMBER 124724 151812 8.500 10936.0 Water 11.00 43.0 9.3 1000 4.5 Based 1.080 .470 1.380 2.800 68.0 165.2 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10845 11705 11275 1721 10845 11705 ROP MWD020 FT/H 0.07 242.72 84.8714 1537 10937 11705 GR MWD020 API 38.55 165.3 110.104 1647 10845.5 11668.5 RPX MWD020 OHMM 1.08 1834.54 4.75066 1632 10845 11660.5 RPS MWD020 OHMM 1.24 1873.79 4.81702 1632 10845 11660.5 RPM MWD020 OHMM 1.21 1944.72 13.3702 1632 10845 11660.5 RPD MWD020 OHMM 0.56 2000 142.713 1632 10845 11660.5 FET MWD020 HOUR 0.08 2.26 1.01655 1632 10845 11660.5 First Reading For Entire File........ ..10845 Last Reading For Entire File......... ..11705 File Trailer Service name...... ...... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/18 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS 3 header data for each bit run in separate files. 3 .5000 START DEPTH 11660.5 11660.5 11660.5 11660.5 STOP DEPTH 14866.5 14866.5 14866.5 14866.5 ) RPX GR ROP $ 11660.5 11660.5 11705.5 14866.5 14859.0 14912.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record... ......... . Undefined ) 29-AUG-02 Insite 66.37 Memory 14912.0 11705.0 14912.0 53.0 100.0 TOOL NUMBER 65041 148574 6.125 11705.0 QuikDril-N 8.50 42.0 8.9 700 1.0 1.780 .670 4.400 3.400 68.0 191.0 68.0 68.0 ) ) Absent value........... .......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . .. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11660.5 14912 13286.3 6504 11660.5 14912 ROP MWD030 FT/H 1.44 1096.81 149.813 6414 11705.5 14912 GR MWD030 API 14.19 579.95 88.3505 6398 11660.5 14859 RPX MWD030 OHMM 0.7 2000 62.1264 6413 11660.5 14866.5 RPS MWD030 OHMM 0.47 2000 130.632 6413 11660.5 14866.5 RPM MWD030 OHMM 0.45 2000 91.1009 6413 11660.5 14866.5 RPD MWD030 OHMM 0.35 2000 190.985 6413 11660.5 14866.5 FET MWD030 HOUR 0.16 58.04 1.74491 6413 11660.5 14866.5 First Reading For Entire File........ ..11660.5 Last Reading For Entire File......... ..14912 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/18 Maximum Physical Record..65535 File Type.......... ..... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.... ...03/03/18 Maximum Physical Record. .65535 File Type............... .LO ) Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 4 ) header data for each bit run in separate files. 4 .5000 START DEPTH 14857.5 14857.5 14857.5 14857.5 14857.5 14857.5 14912.5 STOP DEPTH 15889.5 15889.5 15889.5 15889.5 15882.5 15889.5 15937.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 30-AUG-02 Insite 66.37 Memory 15937.0 14912.0 15937.0 88.0 93.0 TOOL NUMBER 65041 148574 6.125 11705.0 QuikDril-N 8.50 42.0 9.4 900 8.5 1.750 .600 4.500 3.300 69.0 215.6 69.0 69.0 ) ) HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14857.5 15937 15397.3 2160 14857.5 15937 ROP MWD040 FT/H 0.22 643.44 134.334 2050 14912.5 15937 GR MWD040 API 16.55 132.14 43.819 2051 14857.5 15882.5 RPX MWD040 OHMM 3.32 23.54 7.78628 2065 14857.5 15889.5 RPS MWD040 OHMM 3.26 25.17 8.01118 2065 14857.5 15889.5 RPM MWD040 OHMM 3.2 22.7 7.97918 2065 14857.5 15889.5 RPD MWD040 OHMM 3.48 25.17 8.99112 2065 14857.5 15889.5 FET MWD040 HOUR 0.24 25.61 2.13057 2065 14857.5 15889.5 First Reading For Entire File........ ..14857.5 Last Reading For Entire File......... ..15937 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 -) ) Date of Generation...... .03/03/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/03/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . . UNKNOWN Comments................ .STS LIS Services Writing Library. Scientific Technical Reel Trailer Service name........... ..LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/03/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Services Writing Library. Scientific Technical Physical EOF Physical EOF End Of LIS File
