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Home My WebLink About203-140 Image _oject Well History File c!er 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. ~03_ - 1 W Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: if 3 (Count does include cover sheet) Page Count Matches Number in sca;nj"g prep. aration: V YES BY: ~ Date:(rJ1/3/05 Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11111111111111 11111 R7SCAN 'fÞ Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: o Poor Quality Originals: o Other: NOTES: BY: ~ Date Jf)..., 13/ OS- Project Proofing BY: ~ Date J~ 13/ OS- I X 30 = '-~ 0 + Date ¡do JIÒ /OS- Scanning Preparation BY: ~ BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 111111111111111I111 OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: o Other:: mp 1111111111111111111 mP /sl /sl I:J- = TOTAL PAGES Lj-.?- r (Count does not include cover sheet) ,M.P Isl r r ~ 1111111111111111111 NO V11P Isl YES NO /sl 11111111111111 11111 1111111111111111111 Isl Quality Checked 1111111111/11111111 10/6/2005 Well History File Cover Page.doc • ~~ ~~ _-~ Il ~ • 1 o3io~~2oos DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, January 10, 2008 1:05 PM To: Saltmarsh, Arthur C (DOA) Subject: K-08A, PTD #203-140, 50-029-21408-01-00 H i Art, Sorry far the omission an this 10-407... Box 9 (Plugback Depth) it should read: MD: 12115 TVD: 9037 Thanksl Terrie ~Ad JAi~ 1 ~ ZC Iiloi2oog ~ • ~~ 1 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~CEIU~ DEC 0 7 2007 WELL COMPLETION OR RECOMPLETION REPORT AI Dk~O~G~ Gas Cons. Commission Annltnr7nn 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.,os zoAACZS.,~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/29l2007i 12. Permit to Drill Number 203-140- 307-262 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 09/08/2003 ~ 13. API Number 50-029-21408-01-00 '' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/11/2003 14. Well Name and Number: PBU K-08A- 1830 FNL, 410 EWL, SEC. 04, T11 N, R14E, UM Top of Productive Horizon: 2770' FSL, 46' FEL, SEC. 32, T12N, R14E, UM 8. KB (ft above MSL): 56.4' ~ Ground (ft MSL): I 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3632' FSL, 32' FEL, SEC. 32, T12N, R14E, UM 9. Plug Back Depth (MD+TVD) /,~f/,$'.~lD 903~7y~ Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 670676 y- 5975372 Zone- ASP4 10. Total Depth (MD+TVD) 12150 - 9039 ~ 16. Property Designation: ADL 028299 TPI: x- 670102 y- 5979960 Zone- ASP4 Total Depth: x- 670094 y- 5980822 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, ROP, RES, CCL, Memory CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM. SIZE CEMENTING RECORD PULLED 30" x 20" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2673' Surface 2673' 17-1/2" 3254 cu ft PF'E' 465 cu ft PF 9-5/8" 47# L-80 Surface 10387' Surface 8697' 12-1/4" 1946 cu ft Class'G', 230 cu ft Class'G' 7" 26# L-80 10139' 10565' 8480' 8852' 8-1/2" 280 cu ft Class'G' 3-1/2" x 33116" x 2-7/8" 8.81# / 62# 16.16# L-80 9980' 12150' 8342' 9039' 3-3/4" 118 cu ft Class 'G' 23. Open to production or inject ion? ^ Yes ®No 24. - TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD None 5-1/2", 17#, L-80 10049' 9914' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED 10734' Set Mechanical Packer with Whipstock on top. 26. ~ PRODUCTION TEST Date First Production: No on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form., if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results p r ~ 1. None ~''1 r ~i Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS ' NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 23S6 10565' 8852' None 22TS 10625' 8902' Zone 1 B 10798' 9007' Formation at Total Depth (Name): 30. List of Attachments: Pre Rig Work Summary, Summary of Daily Drilling Reports and a Well Schematic Diagram. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra St man ~ Title Drilling Technologist Date , ~'~ ~p` ~ PBU K-08A 203-140 307-262 Prepared ey NameMumber. Sondra Stewman, 564-4750 Drilling Engineer: Abby Higbie, 564-5480 Well Number Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25,071. Form 10-407 Revised 02/2007 Submit Original Only Digital Well File ~ ~ Page 1 of Well: K-08 Well History Wefl Date Summary K-08A 8/30/2007 T/I/O =SSV/30IVAC. Temp = SI. (Pre-CTD, MIT IA & OA). IA FL @ 1014' (45 bbls). OA FL @ 56' (4 bbls). K-08A 8/31/2007 T/I/0=50/0/0 temp=Sl MIT IA PASSED to 3000 si/ MIT OA PASSED to 2000 si. (Pre-CTD) MiT IA presured up to 3000 psi wit s cru e. ost psi in first mmu es an psi in second 15 minutes. For a total of 100 psi in 30 minutes. Bled back - 7 bbls crude. MIT OA presured up to 2000 psi with 3.4 bbls crude. OA lost 80 psi in first 15 minutes and 40 psi in second 15 minutes. For a total of 120 psi in 30 minutes. Bled back - 2.5 bbls crude. Wing valve left SI and SSV closed position. All other casing valves left in normal position. Tagged IA, OA and wing with info and notified operator of results. FWHP's=150/0/0 K-08A 9/5/2007 ***WELL S/I ON ARRIVAL*** DRIFT TBG W/ KJ, 15' x 2.625" STEM, HIT TIGHT SPOT @ 10,634' SLM. FOUND LINER TOP @ 9945' SLM, 9980' MD. +35' CORRECTION. SET DOWN @ 10,697' SLM + 35' CORRECTION 10,732' MD. COULD NOT GET ANY DEEPER. PULLED 300 LBS OVER PICKUP COMING THROUGH TIGHT SPOT @ 10,634' SLM. DRIFT TBG W/ 2.7" CENT, SD @ 10,832' SLM (10,867' MD) DRIFT TBG W/ 15' x 2.625" STEM (STIFF, NO KNUCKLE) SD @ 10,607' SLM (10,635' MD) ***WELL S/I ON DEPARTURE, NOTIFY PAD OP*** K-08A 9/15/2007 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre CTD. PPPOT-T: Opened bleeder screw to verify 0 psi in test void. Alemite external check installed. Functioned LDS, all moved freely no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). PPPOT-IC: Opened bleeder screw to verify 0 psi in test void. Alemite external check installed. Functioned LDS, all moved freely no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). K-08A 9/15/2007 T/I/O =SSV/40NAC. Temp = SI. Bleed IAP & OAP to 0 psi (CTD prep). No AL line. Bled IAP from 40 psi to 0 psi in 10 min. Monitored pressure for 30 min. Final WHPs SSV/0+/VAC. K-08A 9/27/2007 PRESSURE TEST TREE PRE CTD PASSED K-08A 9/28/2007 Set 6" CIW BPV; rig move... K-08B 10/29/2007 Pulled 6" CIW BPV J-Plug. P.T Lubricator to 1500 P.S.I. Had to grease master valve to hold so we could pull lubricator, extensions & plug off. Print Date: 12/6/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/6/200 ! • BP EXPLORATION Page 1 of 10 Operations Summary-Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To ~ Hours I Task (Code ~ NPT I Phase ( Description of Operations 110/26/2007 105:00 - 00:00 I 19.001 MOB I N I WAIT I PRE 110/27/2007 100:00 - 18:30 I 18.501 MOB I N I WAIT I PRE 18:30 - 19:00 0.50 MOB N WAIT PRE 19:00 - 19:30 0.50 MOB P PRE 19:30 - 00:00 4.50 MOB P PRE 10/28/2007 00:00 - 01:30 1.50 MOB P PRE 01:30 - 02:00 0.50 MOB P PRE 02:00 - 09:30 7.50 MOB P PRE 09:30 - 15:30 6.00 RIGU N WAIT PRE 15:30 - 17:15 1.75 RIGU P PRE 17:15 - 17:30 0.25 RIGU P PRE 17:30 - 22:00 4.50 RIGU P PRE 22:00 - 22:15 0.25 MOB P PRE 22:15 - 23:00 0.75 MOB P PRE 23:00 - 00:00 1.00 BOPSU P PRE 10/29/2007 00:00 - 02:30 2.50 BOPSU P PRE 02:30 - 08:30 I 6.001 BOPSUF~ P I I PRE 08:30 - 12:45 4.25 RIGU P PRE 12:45 - 13:00 0.25 RIGU P PRE 13:00 - 16:00 3.00 RIGU P PRE WOW. Wind at 20-38 mph. Wait for 20 mph wind to lay down wind walls for derrick down rig move. 20 deg F, 2 deg Wind chill. WOW. Wind at 20-40 mph. Wait for 20 mph wind to lay down wind walls for derrick down rig move. 18 deg F, 0 deg Wind chill. Moved rig off well. Parked 30' in front and secured BOP stack. Prep derrick for laying down, lower derrick cylinders, pinned in place, LD bails, hooked bridle line to wind walls, RD gas buster stack H2S DRILL 04:30 HRS Wind gusts dropped below 20 mph. Monitor winds for 30 min. SAFETY MEETING. Reviewed procedure, hazards and mitigation for L/D windwalls and lowering derrick into pipeshed. RD guide line cables, LD wind walls, loosen guide lines, RU Hydraulic hoses, filling holding tank with hydraulic fluid, scope down derrick, LD and secure traveling block on rig floor, secure all cables on roof. Continue w/ derrick down procedure. Open pipeshed roof, L/D derrick, close pipeshed roof. SAFETY MEETING. Reviewed procedure, hazards and mitigation for rig move. Conducted safety meeting w/ security escort and Central Power Station. Move rig to K Pad, stage on side of K-08. WOW. Wait for winds to drop below 20 mph to raise wind walls. Wind gusts dropped below 20 mph. PJSM. Open pipeshed roof, raise derrick, close pipshed roof. Scope derrick up. SAFETY MEETING. Reviewed procedure, hazards and mitigation for raising wind walls. Hooked bridle line to windwalls, raise and secure windwalls. 'Secured guide line cables, disconnected and lowered bridle line to floor. Raise and secure derrick cylinders. SAFETY MEETING. Reviewed procedure, hazards and mitigation for moving rig over well, K-08. Position rig over K-08 and set rig down. RIG ACCEPT 23:00 HRS, 10/28/2007 N/U BOP stack Continue to N/U BOP stack P/U pipe straightener from rig floor and R/U to injector. R/U tiger tank and hardline. PT hardline. Fill rig pits with 290 bbl 2# Biozan. Pressure test BOPE. Witness waived by AOGCC inspecter, Bob Noble. Send BOPE test report to AOGCC. Pick up injecter head from pipe bay. M/U guide arch onto injecter head. SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to injecter. Pull coil to injecter. Cap end of E-line. Cap well and pump thru kill line and choke line to shaker at 3.8 bpm, to clean any Printed: 12/4/2007 8:53:16 AM • `BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11 /8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To I Hours I Task I Code I NPT I Phase I Description of Operations 10/29/2007 ~ 13:00 - 16:00 1 3.001 RIGU I P I 1 PRE 16:00 - 16:15 0.25 BOPSU P PRE 16:15 - 19:15 3.00 BOPSU P PRE 19:15 - 19:30 0.25 RIGU P PRE 19:30 - 22:45 3.25 RIGU P PRE 22:45 - 23:00 0.25 WHIP P WEXIT 23:00 - 00:00 1.00 WHIP P WEXIT 10/30/2007 1000.05 - 03:15 I 1.00 WHIP I P I WEXIT 03:15 - 04:30 I 1.251 WHIP I P I I WEXIT 04:30 - 07:00 I 2.501 WHIP I P I I WEXIT 07:00 - 07:15 0.25 WHIP P WEXIT 07:15 - 08:30 1.25 STWHIP P WEXIT 08:30 - 09:00 0.50 STWHIP P WEXIT 09:00 - 09:20 0.33 STWHIP P WEXIT 09:20 - 11:00 1.67 STWHIP P WEXIT 11:00 - 13:00 I 2.001 STWHIPI P I I WEXIT debris from kill line. M/U injector lubricator and perform slack management on E-Line. Reverse circ at 3.0 bpm, 4000 psi. Heard E-Line move two times. Press test inner reel valve. Chart test. SAFETY MEETING. Review procedure, hazards and mitigation for pulling BP valve. Rig up BPV lubricator and press test. Pull BPV. Rig down lubricator. SAFETY MEETING. Review procedure, hazards and mitigation for cutting coil to expose eline. R/U hydraulic pipe cutter to bottom of injector. Cut 55' of coil to expose eline. M/U SLB Kendall CTC, Re-head eline. Tested at 48 ohms. PT to 4000 psi. SAFETY MEETING. Review procedure, hazards and mitigation for M/U whipstock packer BHA. M/U BTT Whipstock BHA #1. Mechanical WS Packer, Baker #10 'J' Hyd setting tool, BHI CoilTrak. Overall BHA length = 67.55' Open EDC. RIH w/ whipstock BHA #1. Pump at min rate Well on vac. Returns were all gas, take to tiger tank. Log GR tie-in to PDC log from 10350'-10390'. -21' correction. Check RA tag depth at 10,570' from K-O8A. On depth. Tied-in depth is corrected to top of whipstock tray. RIH to 10,734' top of whipstock. Orient TF to 135ROHS. Top of Whipstock at 10,734'. Close EDC. Began pumping at 0.5 bpm. Pumped 7 bbls, Increase rate to 0.8 bpm. Saw pressure spike at 1200 psi. Could have been WS setting, but did not get clear indication of release. WS designed to set at 2800 psi. Pump 40 bbls at 1 bpm w/out seeing any pressure build. Shut off pumps, RIH slow, set down 3K. P/U clean. Open EDC, pump at 2 bpm, 2550 psi, filling wellbore with 2ppb biozan KCL. 'POOH to check WS BHA while circ at 2 bpm, 2580 psi, filling wellbore, send gas returns to tiger tank. Started getting KCL returns to surface after pumping wellbore volume. Full returns. SAFETY MEETING. Review procedure, hazards and mitigation for laying out Whipstock running BHA. UO Whipstock running BHA. All tools looked OK. M/U Window milling BHA #2 with 2.74" HCC Daimond Window mill, String mill, BTT Extreme straight motor, 2 jts 2-1/16" CSH and Coiltrak tools. OAL = 99.62'. RIH with to 1000'. Good retums. Pressure test against Packer Whipstock. 1955 psi for 15 min. Lost 10 psi. Very good test. RIH with BHA #2. Circ at min. rate. Tag whipstock at 10756'. Correct -22' to top of whipstock at 10,734'. Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2600-2900 psi, full retums, 1.5K WOB, 0.5 FPH. Milled to 10735'. Printetl: 12/4/2007 8:53:16 AM • ~~ . BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Spud Date: 9/24/1985 Event Name: REENTER+COMPLETE Start: 10/24/2007 End: 11/8/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2007 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To (Hours Task ~ Code ~ NPT ~ Phase Description of Operations 10/30/2007 113:00 - 15:00 I 2.001 STWHIP P 15:00 - 18:00 I 3.001 STWHIPI P 18:00 - 19:25 1.42 STWHIP P 19:25 - 20:30 1.08 STWHIP P 20:30 - 21:20 0.83 STWHIP P 21:20 - 22:30 1.17 STWHIP P 22:30 - 00:00 1.50 STWHIP P 10/31/2007 00:00 - 01:00 1.00 STWHIP P 01:00 - 02:00 1.00 DRILL P 02:00 - 04:15 2.25 DRILL P 04:15 - 05:00 0.75 DRILL P ~~-y- ~ 05:00 - 05:15 0.25 DRILL P 05:15 - 07:00 1.75 BRILL P 07:00 - 08:00 I 1.001 DRILL I P 08:00 - 10:30 2.50 DRILL P 10:30 - 10:45 0.25 DRILL P 10:45 - 12:30 ~ 1.75 DRILL ~ P 12:30 - 14:30 2.00 DRILL P 14:30 - 14:45 0.25 DRILL P 14:45 - 15:10 0.42 DRILL P 15:10 - 16:30 1.33 DRILL P 16:30 - 16:50 I 0.331 DRILL I P 17:10 - 18:30 I 01.331 DRILL I P 18:30 - 19:00 0.50 DRILL P 19:00 - 20:15 1.25 DRILL P 20:15 - 20:40 0.42 DRILL P 20:40 - 21:00 0.33 DRILL P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-2800 psi, full retums, 1-1.5K WOB, 0.5 FPH. Milled to 10736'. WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-2800 psi, full returns, 1-1.5K WOB, 0.5 FPH. Milled to 10739'. Exit liner at 10,739'. 5' long window. WEXIT Mill at 1' per hour to 10,740'. WEXIT Mill 10' rat hole.l.4/1.4 bpm @ 2570 psi. Drill to 10750 WEXIT Adjust counter wheel. Circulating new Flo Pro to bit. WEXIT Ream window while circulating new mud to bit. Window clean. Dry tag No problem. WEXIT POH. Open EDC. Circulate 1.67bpm @ 2730 psi. WEXIT POH. to surface. PROD1 LD milling BHA. Window mill gauged 2.72 NO GO string mill 2.73N0 GO. PU 2.7 Build assy. PROD1 RIH to 10340'. PROD1 Log tie-in. Correction +18 MWD SLB +2.5'. MWD has new counter wheel. PROD1 RIH. tag at 10751.6' PRAT- n ing .4D~ipm ~ 310 psi F~=-~6Db ps-i,~VOB~~F~ ECO 9.29, ROP 90, TF 90R Drilled to 10,950'. PROD1 Drill Z1 turn section, 1.75 bpm, 3500 - 4000 psi, 1 K wob, 9.4 ECD, 90 fph, 120R TF, Finished build section. Drilled to 10,985'. PROD1 POH for Lateral /RES BHA. Open EDC above window and circ at 1.9 bpm while POH. PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying down the build BHA and picking up the lateral BHA. PROD1 L/O buld BHA. Bit was in good shape. Graded bit at (1,1,1 ). M/U Lateral /RES BHA #4 with HCC BC bit #2, 1.2 deg motor and RES tool. BHA OAL = 67.83'. PROD1 RIH with Lat /RES BHA #4, circ at min. rate, 0.2 bpm, 960 psi. PROD1 Log GR tie-in, -1' CTD. PR001 Log RES MAD pass from window to bottom. Clean hole. PROD1 Drill Z1 lateral, 1.65 bpm, 3550 - 4000 psi, 120R TF, 84 incl, 2K WOB, 90 fph, 9.4 ecd, Drilled to 11,110'. PROD1 Orill Z1 lateral, 1.60 bpm, 3350 - 4000 psi, 90R TF, 86 incl, 1- 2K WOB, 140 fph, 9.4 ecd, Drilled to 11,150'. PROD1 Wiper trip to window. RIH clean to bottom. PROD1 Drill Z1 lateral, 1.60 bpm, 3350 - 4000 psi, 90R TF, 90 incl, 1- 2K WOB, 140 fph, 9.4 ecd, Drilled to 11300'. PROD1 Wiper trip to window. PROD1 Drill Z1 lateral 1.59/1.6 bpm @ 3400psi. 120 R TF,89 incl, .6K WOB,136 fph,9.45 ECD. No evidence of 11400 fault. PROD1 Wiper to10750 PROD1 Log tie-in correction +2'. Printed: 12/4!2007 8:53:16 AM TREE = 6" MCEV OY WEL~LHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 56.40' BF. ELEV = 27.85' KOP = 3496' Max Angle = 50 @ 7420' Datum MD = 10569' Datum ND = 8800' SS 13-318" CSG, 72#, L-80, ~ = 12.347" K-08 B CTD Sidetrack F. ~~J 5-1/2" OTIS ROY SSSV LAND NIP, D = 4.562" ~~ 15-1/2" OTIS XA SL~1rlG SLV, ~ = 4.562" ~ Minimum ID = 2.377" @ 10916' TOP OF 2-7/8" LNR Baker Retrieva D packer 9940. I3-1/2" LNR, 9.3#, L-80, .0087 bpf, ~ = 2.992" ~ 10008' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10049' TOP OF 7" LNR 10133' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10387' TOP OF WHIPSTOCK 10560' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10987' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 91 @ 12117' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 1.56" 6 12117-12497 open 11/07/07 1.56" 6 12697-13062 open 11!07/07 3-3/16" LNR, 6.2#, L-80, .0076 bpf, D = 2.805" ~--~ 10916' FISI-~ PDS MEMORY LOGGING TOOL 11542' CTM LNR, 6.16#, L-80, .0058 bpf, D = 2.441" sAF~nr NoTes: 9899' I~TBG SEAL ASSY 9914' 9-5/8" X 5-1 /2" TfW HBB PKR, ~ = 4.75" 9966' 5-1 /2" OTIS X NIP, ID = 4.562" 9950' C2 Deployment sleeve 9988' 3-112" BKR DEPLOY SLV, ID = 3.0" 9997' 3-1i2" HES X NIP, ID = 2.813" 10008' 3-1/2" X 3-3116" XO, D = 2.786" 10009' 5-1 /2" OTIS XN NIP, ID = 4.455" gEHI ND 10049' 5-1/2" TBG TAIL, b = 4.89") PIPE 10051' ELMD TT LOGGED 11 /22/85 10341' MARKER JOINT MILLOUT WNVDOW (K OA) 10565' - 10571' 11000' Top of Cement 2-318" cmt'ed and perfed 13107' ~ 10734' 1 Mech Packer WS w R/A tagsi 10916' 3-3/16" X 2-7/8" XO, ~ = 2.377" 11050' 2-7/8" BKR CIBP (03/26/07) 11904' CTM wFRO GBP (1/14/06) 12~~~T~ DATE REV BY COMMENTS DATE REV BY COMMENTS 10/13/85 OPoGINAL COMPLETION 11/08/07 RBL Post Sidetrack 09/13/03 JLM/KK CTD SIDETRACK (K-08A) 01/21/06 KCF/PAG CIBP(01/14/06 05/31/O6 CO/DTM TREE CORRECTION (6/13/04) 03/28/07 AHHIPJC FISH 8 SET CBP @ 11050' 03/28/07 AHWPJC P~ZFORATpN PRUDHOE BAY UNfr WELL: K-OSA PERMIT No: 2031400 API No: 50-029-21408-01 SEC 4, T11 N, R14E, 1830' FNL & 410' FWL BP Expb~atlon (Alaska) . ~1f~1fŒ (ffi~ ~~~~æ~ . A.I,A~1iA. OILAlVD GAS CONSBRVATlON COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Abby Higbie CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 aöY 14-0 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-08A Sundry Number: 307-262 SCANNED AU G 1 4 2001 Dear Ms. Higbie: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditio.12~ .9.f..appwval set out in the enclosed form. A review of the Commission file for this well revealed that no Report of Sundry Operations (Form 10-404) has been submitted for the perforating operation performed in March 2007. The required report should be submitted. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weeke d. p rson may not appeal a Commission decision to Superior less rehearing has been requested. DATED this /3 day of August, 2007 Enc!. Ja{/It} ~, Cj " D7 Á .. - STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COM.ION '<i;L APPLICATION FOR SUNDRY APPROVAL ~ 20 AAC 25.280 o 1. Type of Request: ~ Abandon o Suspend o Operation Shutdown o Perforate o Time Extension,n::'L' o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 203-140 3. Address: o Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21408-01-00 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 K-08A , Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028299 ./ 56.4' 4 Prudhoe Bay Field / Prudhoe Bay Pool .-' if'>:.···.· i> vvt:LL .. . ......~........ it::::;>;;>: .. ... ...:. ...... Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12150 ~ 9039 , 12115 9037 11050 None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 30" x 20" 110' 110' 1530 520 Surface 2673' 13-3/8" 2673' 2673' 5380 2670 , Intermediate 10387' 9-518" 10387' 7749' 6870 4750 Production Liner 426' 7" 10139' - 10565' 8480' - 8852' 7240 5410 Liner 2170' 3-1/2" x 3-3/16" x 2-7/8" 9980' - 12150' 8342' - 9039' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10867' - 10987' 9029' - 9038' 5-1/2", 17# L-80 1 0049' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW 'HBB' packer I Packers and SSSV MD (ft): 9914' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: September 1 , 2007 DOil DGas D Plugged ~ Ab~ndoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Abby Higbie, 564-5480 Printed Name Abby Higbie Title CT Drilling Engineer . . /7 . Date~ Iv /ö1 Prepared By Name/Number: Signature . Phone 564-5480 Terrie Hubble, 564-4628 I I Commission Use Onlv T Sundry Number: ~inÎ;Jf-1 ð.:\ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity o BOP Test D Mechanical Integrity Test D Location Clearance Other: ~\.. ß\:)'Ç> «:'~"\>~<L~\- \Xt' ~CJ ~~ »S' l d-.% ~ Subsequent Form Required: \..\0, Ø~~MI~ONER APPROVED BY zr;./i -()~ - Approved By: THE COMMISSION Date Form 10-403 Revised 06/2006 V "! J Submit In Duplicate ORIGINAL RBDMS BFL AUG 1 4 2007 Aò ~.g.o-z ~'~¡67 . . To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission Obp From: Abby Higbie CTD Engineer 564-5480 Date: August I, 2007 Re: K-08A Sundry Approval CC: Well File Sondra StewmanlTerrie Hubble Sundry approval is requested to prepare K-08A for a sidetrack.' Well K-08A was a coil sidetrack with 820' ofZlB perfs. It was drilled in September 2003 and hit MGOR in 08/04. An SCMT/STP/RST was run in June of 2005 and the STP showed the possibility of gas entry in toe but it was choked back too much to be completely certain. In January 2006 a CIBP was set to stop the gas rrom entering the toe, but this plug did little to shut gas entry and ./ the sidetrack hi MGOR within a week. In March of 2007 an attempt was made to access any remaining production in thee well so 50' of add perfs were shot. The well would not kick off so a N2 lift was tried. The well was blown dry with no signs of inflow. - REASON FOR SIDETRACK: K-08A is currently shut in. After shutting off the wells prior production and adding 50' ofZlB pers the well would not flow. An MCNL run in June 2006 showed a good gas pick at 8592'ss (10794'md) giving only 20' of stand offrrom the current set of perfs. The well currently has 0 remaining value. A coiled tubing sidetrack is planned on or around October 30th, 2007. The sidetrack, K-08B, will exit the existing 3-3/16" liner rrom a whipstock and will target the Zone lB/1A sand. The existing perforations will be isolated by the mechanical packer whipstock and the liner cement job. The following describes work planned and is submitted as an attachment to Fonn 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: (Scheduled to begin September 1 st, 2007) 1) S Passed tubing caliper inspection 11/11/06 2) 0 Passed MIT -IA and MIT -OA. 3) 0 AC -LDS; AC-PPPOT-IC, T 4) S Run dummy whipstock drift to 10900' 5) E Set 33/16" mechanical packer WS at 10730' 6) 0 PT mechanical packer WS to 2000psi 7) 0 PT MV, SV, WV 8) 0 Blind and bleed lines 9) 0 Remove wellhouse, level pad Rig Work: (Scheduled to begin October 30th, 2007) 1) MIRV Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mill 2.74" window in 3 3/16" liner at 10730' 3) Drill Build: 3" OR, 395' (40 deg/100 planned) 4) Drill Lateral: 3" OR, 2025' (12 deg/100 planned) '"') I \~ ~ 5) Run 2-3/8" solid liner leaving TOL at 10630' O"(J. - '-J\ 6) Pump cement leaving TOC at 10630' 7) Cleanout liner and MCNL/GR/CCL log 8) Test liner lap to 2000 psi 9) Perforate liner per asset instructions (~800') 10) Freeze protect well, set BPV and RDMO T~'\~ c.\,~~~Q\ t Post-Rig Work: 1) Install well house, GLM and attach production lines 2) Pull BPV . TREE = W8.LHEAD = ACTIJA TOR = KB. 8..EV = BF. 8..EV = KOP= Max Angle = Datum lilt) = Datum lVD = 6" WCBIOY WCBIOY OTIS 56.40' 27.85' 3496' 50@7420' 10569' 8800' 55 K-08A 113-318" CSG, 72#, L-BO, ID = 12.347" H 2673' I ~ Minimum ID = 2.377" @ 10916' TOP OF 2-7/8" LNR r3-1 fZ' LNR, 9.3#, L-BO, .0067 bpf, ID = 2.992" 10008' 15-112" TBG, 17#, L-BO, .0232 bpf, ID = 4.692" H 10049' I I TOP OF 7" LNR 10133' I 19-518" CSG, 47#, L-BO, ID= 6.661" 10387' ~I TOPOFWHlPSTOCK H 10560' J~ 17"L~ 261. L"', .0383 bpf, ID' 6.276" I '"\:' I ~ ~ORATIONSUMMARY REF LOG: ANGLE AT TOP PERF: 78 @ 10867' Note: Refer to A'oduction DB for historical perf data IZE SPF INTERVAL OpnlSqz Ql\TE 56" 6 10867 - 10892 0 03128107 )', 6 10962 - 10987 0 03128107 )', 4 11100-11670 C 09f13J03 )', 4 11720 -11820 C 09113/03 ,.. 4 11960-12110 C 09f13J03 , 13-3116" LNR, 6.2#, L-60, .0076 bpf, ID = 2.805" I 10916' r rFISH- PDS MEMORY LOGGING TOOL 11642' CTM 2-7/6" LNR, 6.16#, L·60, .0056 bpf, ID= 2.441" H 12150' 1___ Ql\TE REV BY COMPÆNTS 10M3I85 ORIGINAL COMPLETION 09M3I03 JLMIKK CTDSlŒTRACK(K-08A) 01/21106 KCF/PAG CBP(01/14106 05/31/06 COIDTM TREECORRECTlON (6113104) 03128107 AHHlPJC ASH & SET CIBP @ 11050' 03128107 AHHlPJC ~ORA TION QI\ TE REV BY i ~ I ~TES' . ~ I I ..., I i2S . --~ I I ---, 1--- ~ '-....... -; '-~ I I - ~ .... ~ ~ K» v ¡.....- I 2331' 1-15-1/2" OTIS RQY SSSV LAND NIP, ID = 4.562" , 9840' 9899" 9914' 9966' 5-112" OTIS XA SLIDING SLV, ID = 4.562" I TBG SEAL ASSY 1 9-5/6" X 5-112" TMf HBB PKR, ID = 4.75" I 9980' 4.37" BKR C2 SETTING SLV, ID = 4.0" I 5-112" OTIS X NIP, ID = 4.562" I 9988' 9997' 10008' 3-1fZ' BKR DEPLOY SLV, ID = 3.0" 1 3-1fZ' HES X NIP, ID = 2.613" I 3-112" X 3-3/16" XO, ID:: 2.786" 10009' 5-112" OTIS XN NIP, ID:: 4.455" I ~EHlND 10049' 5-112" TBG TAIL, ID:: 4.69") I PIPE 1 0051' H 8..MD TT LOGGED 11122/65 I 10341' HMARKERJOINT I MlLLOUT WINDOW (K- OA) 10565' -10571' I 10916' 3-3/16" X 2-7/6" XO, ID:: 2.377" 1 I 11050' H 2- 7/6" BKR CIBP (03126/07) I WFRD CIBP I (1114106) I 12115' H PBTD I 11904' CTM COMPÆNTS PRUDHOE BAY UNIT WELL: K-08A PERMT No: ~1400 API No: SO-Q29.21408-01 SEC 4, T11 N, R14E, 1830' FNL & 410' FVIIL BP Exploration (Alas ka) @ 10916' PERFORATION SUIIIIVIARY REF LOG: ANGLE AT TOP Note: Refer to FISH- PDS MEMORY I I . . Review of Sundry Application 307-262 BP Exploration (Alaska) Inc. Well Prudhoe Bay Unit K-08A Prudhoe Bay Field, Prudhoe Oil Pool AOGCC Permit 203-140 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to plug the existing well to prepare it for sidetracking. Recommendation: I recommend approval of BPXA's request. Discussion: Well K -08 was originally drilled and completed in 1985. The well produced about 7.4 MMBO before being plugged in preparation of the K-08A sidetrack in 2003. The K-08A sidetrack was drilled and completed in September 2003. The well produced on an essentially continuous basis until July 2004 and then was cycled, producing for about 10 days per month, through December 2005. Since that time production has been attempted on an infrequent basis. Initial production was approximately 2,500 BOPD at a GOR of about 4,500 SCF/STB. The GOR began rapidly climbing almost immediately and reached 45,000 to 50,000 SCF/STB. According to BPXA's application they determined the gas was probably coming in from the toe of the well so in January 2006 they set a plug in an attempt to shut off the gas, but this did not work. In March 2007 they attempted to access additional reserves by adding 50 feet of perfs. After performing this operation they were unable to return the well to production, even when a nitrogen lift was attempted. BPXA's application stated "the well was blown dry with no signs of inflow." (Note: I believe a 10-404 is required for the add perfs operation that was performed in March 2007, but none is in our files.) BPXA states that the gas there is not enough offset between the current set of perfs and the gas oil contact to make it viable to add new perfs in an attempt to return this well to production. . . Conclusion: Since the well is currently incapable of production and was a marginal well due to high GOR before the well was lost during the March workover it does not appear that the current wellbore has any future value. Therefore, BPXA's proposal to abandon the existing well so that the well can be sidetracked to a more favorable location appears to be the best option for this well. D.S.RObY~~ Reservoir Engineer August 9, 2007 SChlumbepgep RECEIVED Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 AnChorage, AK 99503-2838 ATTN: Beth JUN 0 8 2006 06/01/06 iisK;n ~Iæxa Cii & Gas Gens. Comm AncOOrnge NO. 3828 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: PrUdhoe Bay ~ 1>..... I If- D Well Job# Loa Deser/otion Date BL Color CD ~ NT- - dZA 1~4 IGLS- 11/rnõš" 1 ~ ,~-:z- -'~:r T10582:m- rwFt 08/18/05" 1 P2-36 í C¡.? _ I ¡~I'--' N/A LDL 07/13/05 1 P2-50B I '-1,,,\- - 0 4r.. N/A LDL 07/16/05 1 16-03 '¿¡;'¡-(~il 11076454 INJECTION PROFILE . 07/28/05 1 P2-36 1':::;1.- _~ 11051061 GLS/LDL 06/15/05 1 4-18/S.30 i'%~ - 1/ 6 10564459 PSP GLS 04/18/03 1 1-33B/L-24 J G ':<- - ~<.;s- 10889175 SCMT 10/12/04 1 04-41A ì èv:ï _ (~:'--....o",\ N/A lDL 07/18/05 1 15-09A C13-/~ N/A Oil PHASE BOTTOM HOLE SAMPLE 02/02/05 1 09-17 -:r--? -10z.¡¿ 11076460 INJECTION PROFilE 08/18/05 1 16-09A ÏC¡j - r<3 G< 11051089 PRODUCTION lOG W/DEFT 08/18/05 1 16-11 I;;;,') -II'Y- 11058249 lDL 09/14/05 1 17-02 I~í\ - O~O N/A SENSA MEMORY LDL 10/17/05 1 NK-38A 7);:.~1 - fJ<:./ I 10687734 MDT 02/27/05 1 R-35 ;C:;'~-J if 11212863 USIT OS/26/06 1 D-09A ¡qq - r)5 ~. 11221576 USIT OS/27/06 1 L5-16 i'5r ~ - (', Ie;; 11212864 USIT OS/28/06 1 K-08A ~/".~ '-IZi>, 11054182 MCNL ~i:~~ 06/06/05 1 1 H-04A './\,::: -/{r I 10715365 MCNL if ì:~ <iq 7:i 11/27/03 1 1 e - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. AnChorage, Alaska 99508 t1 /" r l/// I Q f/ li/ ~vV Alaska Data & Consulting SelVices 2525 Gambe/ Street, Sune 400 Anchorage, AK 99503-2838 A TTN: 8eth e e WELL LOG TRANSMITTAL JOJ -- 140 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 17, 2006 /35/0 RE: MWD Formation Evaluation Logs K-08A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry DriUing Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 K-08A: LAS Data & Digital Log Images: 50-029-21408-01 1 CD Rom u~ }/981lXo )':)D't- DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031400 Well Name/No. PRUDHOE BAY UNIT K-08A Operator BP EXPLORATION (ALASKA) INC 5¡1~gW~~ API No. 50-029-21408-01-00 MD 12150 ~ TVD 9039 ", Completion Date 9/13/2003 .,,-- Completion Status 1-01L Current Status 1-01L UIC N ~"-- ------- REQUIRED INFORMATION Mud Log No Samples No DirectiO~Y Yes ~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, RES, CCL, Memory CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data T~ ¡,(og Electr Digital Dataset Med/Frmt Number Name Production Log Log Scale Media 12 Blu Run No 1 Interval OH / Start Stop CH Received 10392 12040 Case 7/14/2005 . Comments -_._~---~---- Mem Prod Prof Mem PSP GR/CCLlSTP fËD C Tf 12224 Neutron /0 C Pds 12224 Casing collar locator ~ Neutron J.Og L 2 D Las ~~ ¿.A-} I J.,...'f. J,. Inrlllr'tjo,nIRgciotivÌ'l'ý ~ ýL.... ¡,kD D Las 12292 Rate of Penetration I ! Iifi* t...,l..s t...: J y.:, R",tø ?of Pooet,ðtiulI . ~_._..- Casing collar locator 2 Blu 9770 12110 Case 1 0/31/2003 LDWG Cased Hole edit of 2 Pass MCNL data 9770 12110 Case 10/31/2003 Compensated Neutron Log - Memory GRlCCLlCNL 9770 12110 Case 1 0/31/2003 Compensated Neutron Log - Memory GR/CCLlCNL 9770 12110 Case 10/31/2003 Compensated Neutron Log - Memory GR/CCLlCNL 2 2 Blu Directional Survey Name Interval Start Stop 10503 12150 9/24/2003 . 10339 12102 Open 12/8/2003 10339 12102 Open 12/8/2003 10339 12102 Open 12/8/2003 10339 12102 Open 12/8/2003 Sample Set Sent Received Number Comments 12292 Induction/Resistivity Well Cores/Samples Information: DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031400 Well Name/No. PRUDHOE BAY UNIT K-08A Operator BP EXPLORATION (ALASKA) INC MD 12150 TVD 9039 Completion Date 9/13/2003 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~N t!»N Chips Received? J I tJ - Formation Tops Analysis Received? - y /14 Comments: Compliance Reviewed By: ~ Date: API No. 50-029-21408-01-00 UIC N c~~ ~) . . Schlumbøl'gøp Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 1-31/M-21 l.q 5' - 07}.. 07-34A ~ Cc . ð¡.3 15-14A :,UN-;tJ. ~ y -238 ). () 3 .. I (,¡ '1 N-08A J.\ì~~ ~cq K-08A J.!;;,1"1'1~ W-26A I c~ ~ - c 8 \ L5-09 l q û~ ì J.. '1 OWDW-NW I M- J.. '1 ~ C-34 !93 ~ Of)" 01-12A ';2 t. ).. ... I III DS 05-41A )3:.>'- I .,~ 02-26C ). I.:::. '> ... L¡ \ C\ Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051037 10980537 10831309 10928620 10715377 10928619 RST (REVISED)- RST (REVISED)- PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL -REVISED TO CORRECT API# ON DIGITAL DATA Log Description Date 04/14/05 04/26/05 01/16/05 06/09/05 09/24/04 06/24/05 06/23/05 04/27/05 03/26/05 07/09/04 04/03/05 01/21/04 03/20/05 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: :¡ (~;it·.. Îv7.:.~ \ _. NO. 3433 07/14/05 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color 1 1 1 1 1 1 1 1 1 1 CD 1 1 1 1 I Ll ~3 ;J).l;,Y / LA. ) C- IJ J..J ~, . 1 1 1 1 1 1 13 lJ 7 IJ :J.18 ìJ J.J If },} ).'-ll\ jJ )..'-if I) ,14 J. . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9¡Zo32838 I ATTN: Beth ; /¡ . . II Received by: \. ~ l~\.. /1,/1 ( ( tJ WV'vt/' . . åO,3-IL-lO WELL LOG TRANSMI1TAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 02, 2003 RE: MWD Formation Evaluation Logs K-08A, AK-MW-2651862 1 LDWG formatted Disc with verification listing. API#: 50-029-21408-01 /00. C¡'~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-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: Sl'gned~ . .\' ",----- . {~ ..- . \ "C')\JL~f:~~~I~ ECEIVED DEC 0 8 2003 lOti & Cons. Comm_r¡ Aochor~ge ~~~fV" ~ Scblumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description Date Blueline F_1~i~-\3r 10558572 MCNL 09/04/03 1 K-08'" :~ .... J 1-/ 10669977 MCNL 09/12/03 1 A·23 \ -("")(8. 10687642 RST·SIGMA 09/07/03 1 H-35 \ - :fJ· 10563219 RST-SIGMA 09/29/03 1 02-25 --oq ( 10563169 RST -SIGMA 06/07/03 1 01-34 \ ~ (O - II ~ 10563167 RST·SIGMA 06/05/03 1 MPS-06 ). 10672316 CH EDIT SCMT 09/24/03 MPS-06 ()O3-)~ 10672316 SCMT 09/24/03 MPS'14)ð03-/lîi 10559813 CH EDIT SCMT 07/19/03 MPS-14 10559813 SCMT 07/19/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date Delivered: OC~ - · f)Af\";\ I .J ¡ ,-'IV'" .~""'_., "~., """""'m'¡...wv. ¡..'JaSK3 v;'I & G~~ '.,.¡UiIS. 1.tViHu ~\iU P\Jïchor~ge ~~~\'\\~ 10/30/03 NO. 3015 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD . 1 I&~ 1 f!ã~ , 1 1 ~. 1 1 1 1 j ;:.)()a.1 2 2 -= Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received b~~\~ .~~ Q>.h1"J¥\. . STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1830' SNL, 410' EWL, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 2770' NSL, 46' WEL, SEC. 32, T12N, R14E, UM Total Depth: 3632' NSL, 32' WEL, SEC. 32, T12N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 670676 y- 5975372 Zone- ASP4 TPI: x- 670102 y- 5979960 Zone- ASP4 Total Depth: x- 670094 y- 5980822 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, ROP, RES, CCL, Memory CNL 22. One Other 5. Date Camp., Susp., or Aband. 9/13/2003 6. Date Spudded 9/8/2003 7. Date T.D. Reached 9/11/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 56.4' 9. Plug Back Depth (MD+ TVD) 12115 + 9037 Ft 10. Total Depth (MD+TVD) 12150 + 9039 Ft 11. Depth where SSSV set (Nipple) 2331' MD 19. Water depth, if offshore NIA MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-140 13. API Number 50- 029-21408-01-00 14. Well Number PBU K-08A 15. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028299 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 30" x 20" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2673' 17-1/2" 3254 cu ft PF 'E', 465 cu ft PF 9-5/8" 47# L-80 Surface 10387' 12-1/4" 1946 cu ft Class 'G', 230 cu ft Class 'G' 7" 26# L-80 10139' 10565' 8-1/2" 280 cu ft Class 'G' * 8.81# /6.2# /6.16# L-80 9980' 12150' 3-3/4" 118 cu ft Class 'G' * 3-1/2" x 3-3/16" x 2-7/8" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 11100' - 11670' 9040' " 9040' 11720' " 11820' 9040' - 9039' 11960' - 12110' 9033' - 9037' 26. Date First Production: October 3,2003 Date of Test Hours Tested PRODUCTION FOR 10/3/2003 7 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 255 24-HoUR RATE 24. SIZE 5-1/2", 17#, L-80 TLJElING DEPTH SET (MD) 10049' PACKER SET (MD) 9914' DEPTH INTERVAL (MD) 2000' AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 2,472 Oll-Bsl 8,475 GAs-McF 1,039 GAs-McF 3,562 W A TER-Bsl 108 W A TER-Bsl 370 CHOKE SIZE I GAS-Oil RATIO 55° 420 Oil GRAVITY-API (CORR) 24.5 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). sUbmr'7~~.T~J.~¡~e~ none, state "none". None j /~ij~;> l n i ~';11 RBDMStlfl- ocR) Þ~bI A L Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE MnuSBf... OCT ìJ 9 LOu3 · 28. GEOLOGIC MARKERS. 29. ..... ~JRMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted. state "None". 238B 10565' 8852' None 22TS 10625' 8902' Zone 1 B 10798' 9007' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble -1Ofu. ~ Title Technical Assistant Date 10"'08'03 PBU K-08A 203-140 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mary Endacott, 564-4388 Permit NO.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ~ t1". H:.r f\ f ,~ - Page 1 of? BP EXPLORATION Operations Summ,ary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-08 K-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: Spud Date: 9/24/1985 End: 9/13/2003 9/6/2003 9/13/2003 N1 Date I . I From - To ! Hours! Task I Code NPT Phase u___...!. ... .------.---- .---.- 9/6/2003 02:30 - 05:00 2.50 RIGD P 05:00 - 06:30 1.50 MOB P 06:30 - 07:00 0.50 MOB P 07:00 - 10:30 3.50 MOB P 10:30 -11:30 1.00 MOB P 11 :30 - 11 :45 0.25 MOB P 11:45 -13:00 1.25 MOB N 13:00 - 18:30 5.50 MOB P 18:30 - 00:00 5.50 MOB P 9/7/2003 00:00 - 03:00 3.00 RIGU P PRE PRE PRE PRE PRE PRE RREP PRE PRE PRE PRE Description of Operations Rig released from F-15A @ 02:30Hrs on 9/6/2003. Unstab CT from injector. Cut coil to prepare for restabing in injector. Change packoff. Clamp coil. Remove goose neck. Pin tilt rams & prep to move rig off well. PJSM. Pull rig off well & set down. Clean up location & conduct post operations pad inspection. PJSM. UD windwalls. Scope down & LID derrick. PJSM. Jack-up rig & move rig to pad entrance. Held pre-move safety meeting with crew, security, tool services &CPS. Changeout faulty flush pump motor of clutch system. Move rig from F-pad to K-08. Spot rig in front of K-08. Raise derrick and scope up derrick. Retract tilt rams. Raise wind walls. Sim. Ops, spot hot oil truck and fluid to kill well. Raise and pin wind walls. PU injector head out of storage box. Install goose neck. Stab coil. Pull back injector. Hook BOP slings to blocks. Continue Sim. Ops., hot oil truck pumped 411 bbls of KCI to kill K-08. Final injectivity - 5bpm @ 250psi. PJSM for moving over well. Spot rig over K-08A. Accept rig at 04:00 on 9/7/03. Remove tree cap. NU BOP. Install lubricator. Prepare to test BOPE. Attempt to body test BOP stack - observe leak from btm flange. NID BOP. Replace ring gasket. Re-N/U BOP. Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Test rig alarms. Meanwhile fill rig pits with 1 % KCL water. RIU hardline to tigger tank & PfT to 4000psi. DECOMP P/U injector. Cut coil & install Baker CTC. Pull test to 35k - OK. DECOMP Install dart catcher. Load wiper dart. Launch & chase with 1 % KCL. Dart hit @ 60bbls. Press test inner reel valve & CTC to 3500psi - OK. Open up well & observe Opsi WHP - well on vac. lAP = 12psi, OAP = 13psi. FL is disconnected. Held pre-operations safety meeting. Review well plan, potential hazards & Cement squeeze BHA M/U procedures. M/U cement squeeze BHA # 1 with nozzle, XIOvers & 2-3/8" PH6 Stinger. Stab injector on well. PfTest packoff to 3500 psi - OK. Meanwhile RIU Dowell cementers. RIH with BHA #1 circ @ 3.7bpm/2800psi without returns. Start seeing 0.1bpm returns @ 10400'. Wt check @ 10450' = 35klbs. Continue RIH BHA#1 to WS pinch pt tagged @ 10584.6'. Correct CTD (-20') to Pinch pt ELMD of 10564.6'. PUH to 10550' & flag CT. Pumped a total of 486bbls KCL. Call for diesel & more KCL. PJSM with all personnel concerning cementing operations. Circ @ 2.0bpm/760psi while W. O. diesel & KCL trucks to arrive location. Load pits with KCI. Line up to pump diesel down backside. Pump 100 bbls of diesel down CT x tubing annulus. Hold PJSM for cement job with night crew. Pump 5 bbls of water. PT cement lines to 4,000 psi. Pump 25 bbls of 15.8 ppg class G cement. Follow with 5 bbls of water. 03:00 - 04:00 1.00 RIGU P PRE 04:00 - 06:30 2.50 BOPSURP PRE 06:30 - 08:00 1.50 BOPSUR N RREP PRE 08:00 - 13:00 5.00 BOPSURP PRE 13:00 - 13:20 0.33 PXA P 13:20 - 14:45 1.42 PXA P 14:45 - 15:00 0.25 PXA P DECOMP 15:00 - 15:30 0.50 PXA P DECOMP 15:30 - 18:00 2.50 PXA P DECOMP 18:00 - 18:15 0.25 PXA P DECOMP 18:15 - 19:00 0.75 PXA N WAIT DECOMP 19:00 -19:45 0.75 PXA P DECOMP 19:45 - 20:50 1.08 PXA P DECOMP 20:50 - 23:30 2.67 PXA P DECOMP Printed: 9/1512003 9:51:37 AM ,... .. BP EXPLORATION Operations Summary Report Legal Well Name: K-08 Common Well Name: K-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 ~a~F~om - :.~ ' Ho~rs.J Task. Code NPT 9/7/2003 20:50 - 23:30 2.67 PXA P Page 2 of 7 Start: Rig Release: Rig Number: Phase 9/6/2003 9/13/2003 N1 Spud Date: 9/24/1985 End: 9/13/2003 DECOMP 23:30 - 00:00 0.50 PXA P DECOMP 9/8/2003 00:00 - 03:25 3.42 PXA P DECOMP 03:25 - 04:00 04:00 - 04: 1 0 04:10 - 04:30 0.58 PXA P 0.17 STWHIP P 0.33 STWHIP P DECOMP WEXIT WEXIT 04:30 - 06:25 1.92 STWHIP P WEXIT 06:25 - 06:35 0.17 STWHIP P WEXIT 06:35 - 07:00 0.42 STWHIP P WEXIT 07:00 - 09:15 2.25 STWHIP P WEXIT 09:15 - 10:30 1.25 STWHIP P WEXIT 10:30 -11:15 0.75 STWHIP P WEXIT 11:15-11:45 0.50 STWHIP P WEXIT 11 :45 - 12:30 0.75 STWHIP P WEXIT 12:30 - 12:50 0.33 STWHIP P WEXIT 12:50 - 13:55 1.08 STWHIP P WEXIT 13:55 - 15:45 1.83 STWHIP P WEXIT 15:45 - 16:30 0.75 STWHIP P WEXIT 16:30 - 16:45 0.25 DRILL P PROD1 16:45 - 19:00 2.25 DRILL P PROD1 19:00 - 20:30 1.50 DRILL P PROD1 20:30 - 21 :30 1.00 DRILL P PROD1 Description of Operations n_________...__________. Displace with KCI bull heading down CT at 2.5 bpm, 1,600 psi. Slow pump to 2 bpm, 280 psi when cement at nozzle. Perfs took 7 bbls of cement before building to 500 psi WHP. Lay in remaining cement and pull to safety depth. CIP at 21 :30. Lost 3 bbls. Hesitation squeeze building to 1000 psi final squeeze pressure. Hold for 30 minutes. Bleed WHP to 500 psi. Pump 30 bbl biozan pill to nozzle holding 500 psi WHP. Make three passes from 10,300' to 10,550'. POOH pumping 3.1 /3.0/2,400 psi while holding 500 psi WHP with choke. Jet jewelry. Send diesel returns to FS 1 for recycle. Stop to allign goose neck while POOH. MU stack jetter. Jet BOP stack. Held PJSM for M/U & RIH window milling BHA #2. M/U window milling BHA #2 with a 3.80" HC DSM, diamond string reamer, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg. M/U injector. RIH with BHA #2. Wt check @ 10500': Up = 40k, down = 23k. Continue RIH BHA#2 & tag TOC @ 10575'. PUH to 10548'. PfT cement plug to 1 OOOpsi for 1 Omins. WHP drop to 915psi after 5 mins & to 870psi after 10mins. Good enough for CTD sidetrack. Mill cement with 2.6/2.6bpm & 1180/1200psi & hit hard spot @ 10579.9' - suspect we're @ TOWS or WS/Lnr pinch pt. P/U without any O/pull. Retag @ same depth. Flag pipe & correct depth (-15.3') to 10564.6' (pinch pt ELMD). Start milling 3.80" window out 7", 26# Inr with 1/2ppb bio-KCL. Mill from 10564.6' with 2.5/2.5bpm, 1200/1400psi, 1-2K WOB. 10,567' /3k WOB /2.5 bpm, 1380 psi / metal shavings showing at the magnets 10,570' /2.5k WOB /2.5 bpm, 1450 psi / pump 15 bbl bio sweep 10,570.5' stalling as mill tries to exit casing 10,571' exit casing, start milling formation 10,581' TD rathole, PUH start dressing window Backream & dress window 3x & drift window 2x without pumping. Window looks clean. Meanwhile swap the well to reconditioned Flo-Pro mud. Tentative window depths are: TOWS - 10560'; TOW - 10564.6'; BOW - 10571'; RA PIP TAG - 10570'. POOH window milling BHA #2. PJSM. UO & inspect milling BHA#2. DSM gauge 3.80" go / 3.79" no go & DSR gauge 3.79" go /3.78" no go. Wear on DSM face indicates center crossed the casing wall. Held pre-spud safety meeting. Review well objectives, potential hazards & drilling BHA M/U procedures. M/U drilling BHA #3 with Sperry MWD/RES, BHI motor with 1.69deg bend & new HUGHES 3-3/4" x 4-1/8" RWD2ST3043 bicenter Bit #2. Initialize RES tool. Rehead & M/U DS CTC. Pull/Pressure test. RIH. Shallow hole test MWD at 3,500'. Tag bottom. -14' correction. Drill to 10,586' at 2.7/2.7/3,200 psi. TF=36R. Printed: 9/15/2003 9:51 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/8/2003 9/9/2003 9/10/2003 ..... - BPEXPLORATION . .., Operations Summary Report K-08 K-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task lcode 21:30 - 23:10 23: 1 0 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 06:30 06:30 - 08:15 08: 15 - 08:25 08:25 - 09: 10 1.67 DRILL N 0.83 DRILL N 1.00 DRILL N 2.00 DRILL N 3.50 DRILL P 1.75 DRILL P 0.17 DRILL P 0.75 DRILL P 09:10 - 12:30 3.33 DRILL P 12:30 - 13:00 0.50 DRILL P 13:00 - 13:20 0.33 DRILL P 13:20 - 14:00 0.67 DRILL P 14:00 - 14:50 0.83 DRILL P 14:50 - 16:25 1.58 DRILL P 16:25 - 16:40 0.25 DRILL P 16:40 - 17:00 0.33 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 21:45 3.25 DRILL P 21:45 - 22:10 22: 1 0 - 22:20 22:20 - 23:50 23:50 - 00:00 00:00 - 01 :00 01 :00 - 03:00 0.42 DRILL P 0.17 DRILL P 1.50 DRILL P 0.17 DRILL P 1.00 DRILL P 2.00 DRILL P NPT Phase DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 3 of 7 Start: 9/6/2003 Rig Release: 9/13/2003 Rig Number: N1 Spud Date: 9/24/1985 End: 9/13/2003 Description of Operations ............--... . .--.----.....-.....................---............ .......-...-.- MWD quit pulsing. Trouble shoot MWD. Surge coil. Unable to get MWD pulse back. POH. Read MWD tools. Change out pulser and probes. Change out pulser, battery mod., TM, and Gamma mod. Break bit. Pilot ports plugged with formation. Clean ports. RIH. Shallow hole test MWD. RIH. Tag bottom. -27' correction. Orient to 30R. Drill to 10,615' at 2.6/2.6/3,100 psi. Orient & drill to 10650' with 45R TF, 2.7/2.7bpm, 3000/3450psi, 20fph ave ROP. Getting frequent motor stalls due to Zone 2C conglomerates. Wiper trip clean to window. PUH above window to 10400' for tie-in log. Log down GR in 7" 1m & tie-into Gelogy PDC log. Add 3' to CTD. RBIH below window & log down. See RA Pip tag @ 10570' - window depths are confirmed. RBIH to btm. Orient & drill to 10700' with 15-35R TF, 2.7/2.7bpm, 3000/3450psi, 15fph ave ROP. Orient & drill to 10715' with 30-45R TF, 2.7/2.7bpm, 3400/3650psi, 15fph ave ROP. Orient & drill to 10720' with 45R TF, 2.7/2.7bpm, 3400/3550psi, 15fph ave ROP. Orient & drill to 10730' with 705R TF, 2.7/2.7bpm, 3400/3500psi, 15fph ave ROP. Orient to 60R TF, 10,752',2.7 bpm, 3500 psi, 20fph ROP Orient 60R, 10,772',2.7,3600 psi, 20 fph. Drill to 10800' Wiper to window, clean Orient around Drill from 10800' 2.8/3520/30R and penetration rate picking up to 60'/hr. Drill to 10860' Kick while drilling drill Drill from 10860' 2.7/3350/60R 10880', Drilling ahead. 2.65/2.74/3500 psi. Free spin=3250 psi. Pit volume indicator not working properly. The level indicator for pit #3 is intermittant. It has not worked properly since summer shutdown. PVT totals are unreliable. Schlumberger notified and asked to expidite repair. 10946', Time for a wiper trip. Clean PU off bottom at 37 klbs. Attempt to resume drilling. Not able to make much hole. The mud is still in good condition, although only at 1% lubetex. Geo reports we are still getting chert and pyrite in cuttings. Surprising for Zone 1. POH for new bit. Tag up with BHA, stand back injector. Break out bit. Hughes bi center was recovered and graded by DD at 7-5, Ringed out on the pilot section. It was replaced with a DS49. DD checked the motor, it was tight. Sperry downloaded RES data and checked the tool, all was ok. MU Injector to top of BHA. RIH with BHA #5, 1.69 deg bend motor with DS49 bit and RES tool. Shallow hole test at 500' passed ok. While RIH, pump 30 bbls of 5% lubetex pill to observe if it improves weight transfer when back on bottom. Printed: 9/15/2003 9:51:37 AM ~ - BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-08 K-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/6/2003 Rig Release: 9/13/2003 Rig Number: N1 Spud Date: 9/24/1985 End: 9/13/2003 Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2003 03:00 - 03:10 0.17 DRILL P PROD1 Tag up at bottom. Make -22' correction. Orient to 50R. 03: 10 - 03:20 0.17 DRILL P PROD1 10947', Begin drilling. Free spin=3380 psi at 2.65 bpm. Drilling at 2.7/2.7/3600 psi. Pit vol=273 bbls. PVT now working again, but is intermittant. 03:20 - 03:25 0.08 DRILL P PROD1 10955', Take 2 clicks. 03:25 - 04:35 1.17 DRILL P PROD1 Resume drilling. 04:35 - 05:05 0.50 DRILL P PROD1 11054', Wiper trip to shoe. 05:05 - 05: 15 0.17 DRILL P PROD1 Resume drilling. PVT=270 bbls. 05: 15 - 05:25 0.17 DRILL P PROD1 11070', Orient around to left side. 05:25 - 06: 15 0.83 DRILL P PROD1 Drill ahead to 11155'. 06:15 - 06:35 0.33 DRILL P PROD1 Orient around 06:35 - 07: 1 0 0.58 DRILL P PROD1 Drill from 11155' to 11195' 2.6/3530/107L 07:10 - 07:25 0.25 DRILL P PROD1 Wiper to window 07:25 - 07:35 0.17 DRILL P PROD1 Log tie-in up from 10620' 07:35 - 07:55 0.33 DRILL P PROD1 Corr -8.0', RIH to TD tagged at 11191', clean 07:55 - 10:50 2.92 DRILL P PROD1 Drill from 11191' 2.6/3530/90L with two 200' wipers to 11348' and need new mud 10:50-11:30 0.67 DRILL P PROD1 Wiper to window 11 :30 - 12:10 0.67 DRILL P PROD1 Drill from 11348' 2.8/3550/90L with one 200' wiper to 11390' and angle increasing w/ hold assy to 92 deg 12:10 - 12:30 0.33 DRILL P PROD1 Orient around to straight down 12:30 - 14:30 2.00 DRILL P PROD1 Drill from 11390-400' at 160R. Orient to left. Drill from 11400' 2.7/3500/100L Start new mud. Drill to 11500' 14:30 - 15:20 0.83 DRILL P PROD1 Wiper to window, clean 15:20 - 16:05 0.75 DRILL P PROD1 Drill from 11500' 2.6/3040/90L to 11608' and losing angle in soft digging at 8984' TVD 16:05 - 16:30 0.42 DRILL P PROD1 Orient straight up. Drill to 11624'. Orient around to 90L 16:30 - 16:45 0.25 DRILL P PROD1 Drill from 11624' 2.7/2900/90L to 11655' PVT 288 16:45 - 17:40 0.92 DRILL P PROD1 Wiper to window 17:40 - 18:30 0.83 DRILL P PROD1 Drill from 11655' 2.7/3050/60-90L to 18:30 - 17:20 22.83 DRILL P PROD1 11707', Drilling ahead. Free spin 2650 psi at 2.4 bpm. PVT=251 bbls. IAP=22 psi, OAP=15 psi. 17:20 - 17:30 0.17 DRILL P PROD1 11725', Orient to 90L. 17:30 - 21 :20 3.83 DRILL P PROD1 Resume drilling. In a shale, ROP is slow. 21 :20 - 21 :55 0.58 DRILL P PROD1 11800', Wiper trip to the window. Clean PU off bottom. 21 :55 - 22:40 0.75 DRILL P PROD1 Log tie in pass over RA pip tag in whipstock. Make -10' correction. 22:40 - 23:25 0.75 DRILL P PROD1 RIH after logging tie in pass. 23:25 - 00:00 0.58 DRILL P PROD1 Resume drilling. 9/11/2003 00:00 - 01 :50 1.83 DRILL P PROD1 Continue drilling lateral section from 11840'. 2.7/2.7/3285 psi. Electrician worked on float switch for pit #3. PVT = 277 bbls. IAP=21 psi, OAP=16 psi. 01 :50 - 02:05 0.25 DRILL P PROD1 11895', Orient to 90R. 02:05 - 03:00 0.92 DRILL P PROD1 Resume drilling. PVT=272 bbls. 03:00 - 04:05 1.08 DRILL P PROD1 11950', wiper trip to the window. 04:05 - 05:15 1.17 DRILL P PROD1 Resume drilling. 05:15 - 05:20 0.08 DRILL P PROD1 12047', Orient 2 clicks 05:20 - 06:45 1.42 DRILL C PROD1 Drilling ahead. 2.8/3320/80R Drill to tentative TD @ 12150' 06:45 - 07:30 0.75 DRILL P PROD1 Wiper to window 07:30 - 07:40 0.17 DRILL P PROD1 Log tie-in up from 10630' 2.5/2930/42R 07:40 - 08:25 0.75 DRILL P PROD1 Carr -6'. RIH to TD and tagged at 12143'. Drill to 12150' official TD PVT 270 08:25 - 09:20 0.92 DRILL P PROD1 Wiper to window 2.7/3130 Printed: 9/15/2003 9:51:37 AM .... - Page 5 of 7 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-08 K-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code I NPT I Phase ! ' 9/11/2003 09:20 - 10:45 1.42 DRILL P PROD1 10:45 - 12:30 1.75 DRILL P PROD1 12:30 - 12:45 0.25 CASE P COMP 12:45 - 13:00 0.25 CASE P COMP 13:00 - 15:35 2.58 CASE P COMP 15:35 - 16:20 0.75 CASE P COMP 16:20 - 17:45 1.42 CASE P COMP 17:45 - 18:25 0.67 CASE P COMP 18:25 - 19:05 0.67 CASE P COMP 19:05 - 19:50 0.75 CASE N WAIT COMP 19:50 - 22:20 2.50 CASE P COMP 22:20 - 22:40 0.33 CEMT P COMP 22:40 - 23:10 0.50 CEMT P COMP 23: 1 0 - 00:00 0.83 CEMT P COMP 9/12/2003 00:00 - 00:20 0.33 CEMT P COMP 00:20 - 01 :50 1.50 CEMT P COMP 01 :50 - 02:20 0.50 CEMT P COMP Start: Rig Releasè: Rig Number: Spud Date: 9/24/1985 End: 9/13/2003 9/6/2003 9/13/2003 N1 Description of Operations Flag at 9900' EOP. POOH for liner LD drilling BHA. Download resistivity RU to run liner Safety mtg re: liner MU 39 jts 2-7/8" 6.16# L-80 STL liner with float equipment. MU 30 jts 3-3/16" 6.2# L-80 TC11 liner with LSL assy MU 4.375" BOT TC-11 Liner Setting Sleeve w/6' seal assy on 3.5" BOT Deployment Sleeve Cut off DS CTC. Install BOT CTC. PT 35k, 3500 psi RIH w/liner on CT Kick while tripping drill 10500' 36k RIH in open hole with liner to TD tagged at 12192'. Make a -42' correction, set depth to 12150'. PU, at 42 klbs, tag bottom again, same depth. PU 20' to ball drop depth. Drop 5/8" ball to release CTLRT from deployment slv. Run back to bottom. Ball on seat at 50.7 bbls (Coil vol=60 bbls). Good indication of shear at 4100 psi. PU 2', weight up was 27 klbs. Run back to bottom. Reduce rate to minimum rate. Veco vac trucks late arrival on location. Wait for vac trucks to swap well to KCL. Continue circulating mud at minimum rate while waiting on trucks. 0.3 bpm, 1140 psi. Vac trucks on location, begin swap to 2% KCL. Slight losses when pumping KCL around. Pumping 2.8, getting back 2.62 for about 7% losses. Calculated volume of cement required is 19.78 bbls with 40% excess in open hole, and cement top at 10360' as per proceedure. We will pump an additional 7% to account for losses. Plan to pump 21 bbls of cement. Safety meeting with Dowell cementers, rig crew, vac truck driver, BOT, BP. Discuss plan forward for cement job, possible hazards, and mitigation. Batch up cement. Cement up to weight at 23:10. SI rig pumps. Open CT to cementers. Pump 5 bbls water preflush. SI, PT cementers hard lines to 4000 psi. All passed ok. Open up to coil. Come on line with 15.8 ppg Class G cement as per proceedure. Pump 21 bbls cement. Launch dart. Begin displacing dart with 30 bbls of biozan water. Continue displacing cement with biowater. Swap to KCL for displacement after 30 bbls. Land dart in liner wiper plug at 59.4 bbls away. (Coil vol=60 bbls). Got good indication of shear. Landed liner wiper plug with an additional 13.8 bbls away. (Liner vol calculated at 13.9 bbls). Bumped the plug to 2000 psi. Checked floats, floats held fine. Pumped 21 bbls of cement, had losses of 1.8 bbls to formation, got 19.2 bbls behind pipe. (Needed 19.78 as per plan) Estimated cement top behind pipe is 10423'. Pick up, unsting from CTLRT. PU weight =29 klbs, consistent with a good release from the liner. POOH with CTLRT pumping at minimum rate to lay in biozan to replace coil voidage. Tag up at surface, stand back injector, lay down BOT CTLRT. All BOT eq recovered as normal. Printed: 9/15/2003 9:51:37 AM ... - BP EXPLORATION Operations ,Summary Report Legal Well Name: K-08 Common Well Name: K-08 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To I Hours Task Code I 9/12/2003 02:20 - 02:45 0.42 EVAL P 02:45 - 03:00 0.25 EVAL P 03:00 - 05:00 2.00 EVAL P 05:00 - 05: 15 0.25 EVAL P 05: 15 - 06:20 1.08 EVAL P 06:20 - 07:45 1.42 EVAL P 07:45 - 08:30 0.75 EVAL P 08:30 - 09:45 1.25 EVAL P 09:45 - 10:00 0.25 EVAL P 10:00 - 11 :30 1.50 EVAL P 11:30 - f1:40 0.17 EVAL P 11:40 - 12:30 0.83 EVAL P 12:30 - 13:15 0.75 PERF P 13:15-14:15 1.00 PERF P Page 6 of 7 Start: Rig Release: Rig Number: NPT: Phase 9/6/2003 9/13/2003 N1 Spud Date: 9/24/1985 End: 9/13/2003 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 14:15 - 14:30 0.25 PERF P COMP 14:30 - 17:10 2.67 PERF P COMP 17:10 - 18:00 0.83 PERF P COMP 18:00 - 19:55 1.92 PERF P COMP 19:55 - 20:40 0.75 PERF P COMP 20:40 - 22:45 2.08 PERF P COMP 22:45 - 22:55 0.17 PERF P COMP 22:55 - 23:45 0.83 PERF P COMP 23:45 - 00:00 0.25 PERF P COMP 9/13/2003 00:00 - 03:30 3.50 PERF COMP 03:30 - 03:45 0.25 WHSUR COMP 03:45 - 04:10 0.42 WHSUR COMP 04: 1 0 - 04:45 0.58 WHSUR COMP 04:45 - 05:20 0.58 WHSUR COMP 05:20 - 05:30 0.17 WHSUR COMP 05:30 - 07:00 1.50 WHSUR COMP 07:00 - 09:00 2.00 RIGD POST 09:00 - 0.00 RIGD POST Description of Operations --..----..-------- PU Schlumberger equipment for cia - logging run, to rig floor. PJSM prior to installing radioactive source in logging tool, and RIH with it on CSH work string. MU MCNL tool and RIH with it on 72 joints of CSH. MU SWS MHA, PU and stab injector. RIH with BHA #6, MCNL logging tool. Log down from 9800' @ 30'/min while circ perf pill to nozzle Tag PSD at 12132' CTD (did not correct to tally depth of 12115'). PUH logging to 9800' at 60'/min while leave perf pill in liner POOH w/ CT Safety mtg re: pull CSH/changeout day RU to pull CSH. Standback 35 stds and LD 2 singles Safety mtg re: source LD CNL tool. Read data. Cmt comp str=1600 psi Load perf guns in pipeshed. Fax data. ELMD PBD at 12113', TOL at 9979' Cement compressive str=2000 psi. No change to perf intervals RU to PT lap. Pressure wellbore to 2020 psi w/ 3.2 bbls KCI and hold for 30 min. Final WHP 1955 psi. Bleed off press. Minor change to IA. Safety mtg re: perf guns MU 48 2" SWS perf guns MU 19 stds CSH RIH w/ perf guns on CT Tag bottom, set depth on pickup to ELM tag from MCNL run of 12113'. (-29' correction). Position guns at firing depth, pump 8 bbls of perf pill. SD pumps, drop 5/8" ball to fire guns. Follow with 8 bbls of Flopro perf pill, then KCL. Ball on seat at 56.1 bbls away. (Coil vol=60 bbls). Good indication of fire at 3200 psi. Fired perf guns as requested in perf memo dated 9-11-2003; 11100'-11670' 11720'-11820' 11960'-12110' POH with shot perf guns. PJSM for tripping pipe. Stand back 19 stands of CSH. Safety meeting prior to laying down perf guns. Lay down spent perf guns. All guns fired, all shots fired. Make up nozzle to CTC. Stab injector on well. RIH with nozzle to FP well. Pump 27 bbls of methanol. Circulate methanol to nozzle, POH laying in methanol at 110%. (Stringing it into the KCL a bit). Tag up at surface. SI swab valve. Circulate at minimum rate while N2 pumper rigs up. Safety meeting prior to blowing the reel down with N2. Pump N2 to purge the coil of water. ND BOPE. NU tree cap and PT RREL @ 0900 hrs 9/13/2003 TT K-08a 6:05:00 Prep to move rig off tree and had problem w/ Printed: 9/15/2003 9:51 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,., .. Page 7 of 7, BP EXPLORATION Ope'ratiöns Summary Report K-08 K-08 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours i Task Code NPT I 9/13/2003 09:00 - 0.00 RIGD Spud Date: 9/24/1985 End: 9/13/2003 Start: 9/6/2003 Rig Release: 9/13/2003 Rig Number: N1 Phase Description of Operations __.___._......___._..._ ..__n__..n_..___._.____.. _n. .._._...._......_.____ ... POST clutch/brakes-repair Printed: 9/15/2003 9:51:37 AM e . ,903--¡ L\ 0 22-Sep-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well K-08A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,503.29' MD 10,560.00' MD 12,150.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~.'. "'- r ·\JE·O '"'];¥. ','. "r~~; - . *..~ i::\.,¡~ '0=" ~ t ..."., S[~P f) ~ ,.. '"'Î'" ,C L "t ¿1.!lN AiasK;3 i,.:;ürnmis5ton '(;.'~'" " "t) \\\ (:;.L::; Sperry-SunDfill1rigServices North Slope Alaska BPXA PBU_WOA.K Pad K..08A Job No. AKMWOOO2651862,suttrfjYed:t1September, 2003 Sur v.e y R e p 0 r t 22 September, 2003 .,>/::>' Your Réf:;r4iJ!i(jj!Jt!qtJ~1 Surface Coordinates: 5975372.00 N, 67061(S.!J~;i(70020'19.0982· N, 1480 36' 54.0277- W) Grid Coordinate System: NAÎ!J27 JtJasks State Planes, Zone 4 Surface Coordinates relative to Project HReferente: 975372.00 N, 170676.00 E (Grid) Surface Coordinates relativ'3 to SuucttJreRefetence : 2201.37 N, 383.55 E(True) Kelly Bushing: 56.4Oft above Mean Sea Level Elevation relative to Project V Reference: 56. 40ft Elevation relative to Structure Reference: 56.40ft =:tJ-I1::!I' 'I\V-e;u11 OAtL.L.INIL:f SEAVlt::;eS A Halliburton Company DEFINITIVE' . ,f'# . Survey Ref: svy4101 Sperry-Sun Drilling Services Survey Report for PBU_~OAKPad . K·08A Your Ref: API500292140B01 Job No. AKMWOO02651862, $urveyed:11 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0'100ft) 10503.29 28.630 359.390 8742.24 8798.64 4412.24 N 523.66 W 5919771.17 N 670052.05 E 4378.78 Tie On Point MWD Magnetic 10560.00 30.310 359.060 8791.61 8848.01 4440.13 N 524.04 W 5979199.05 N 670051.03 E 2.976 4406.62 Window Point 10590.76 32.860 5.440 8817.82 8874.22 4456.21 N 523.37 W 5919815.14 N 670051.33 E 13.656 4422.71 10620.82 37.000 10.440 8842.47 8898.87 4473.23 N 520.96 W 5979832.22 N 670053.36 E 16.735 4439.84 10651.05 40.880 14.590 8865.98 8922.38 4491.76 N 516.82 W 5979850.83 N 670057.08 E 15.460 4458.56 10681.64 47.050 18.120 8887.99 8944.39 4512.11 N 510.81 W 5919871.32 N 670062.62 E 21.696 4479.19 . 10713.94 52.860 21.310 8908.76 8965.16 4535.36 N 502.44 W 5979894.75 N 670070.45 E 19.508 450;¿.85 10744.96 58.370 24.000 8926.28 8982.68 4558.97 N 492.57 W 5919918.57 N 670079.79 E 19.148 4526.94 10775.08 62.640 30.560 8941.12 8997.52 4582.23 N 480.54 W 5979942.10 N 670091.29 E 23.663 4550.80 10806.35 67.050 36.370 8954.41 9010.81 4605.81 N 464.92 W 5979966.03 N 670106.36 E 21.942 4575.16 10834.98 72.600 39.720 8964.29 9020.69 4626.95 N 448.36 W 5979987.55 N 670122.44 E 22.277 4597.14 10864.32 77.970 45.180 8971.74 9028.14 4647.86 N 429.21 W 5980008.89 N 610141.11 E 25.664 4619.03 10893.62 80.880 48.180 8977.12 9033.52 4667.62 N 408.26 W 5980029.11 N 670161.61 E 14.139 4639.85 10925.21 84.580 54.170 8981.12 9037.52 4687.24 N 383.85 W 5980049.29 N 670185.56 E 22.155 4660.73 10952.14 90.310 59.810 8982.32 9038.72 4701.89 N 361.31 W 5980064.44 N 670207.76 E 29.835 4676.53 10983.98 91.280 65.980 8981.88 9038.28 4716.38 N ~~¡~iyV 5980079.58 N 670235.75 E 19.614 4691.49 11015.03 89.520 73.550 8981.66 9038.06 4727.11 N 303¡87iW 5980090.97 N 670264.61 E 25.029 4704.73 11068.13 87.750 84.650 8982.93 9039.33 4737.14 N 251.83W 5980102.18 N 670316.41 E 21.161 4717.47 11101.39 88.280 76.020 8984.09 9040.49 4742.71 N 219.09 W 5980108.50 N 670349.01 E 25.980 4724.75 11129.84 90.220 70.380 8984.46 9040.86 4750.93 N 191.87 W 5980117.33 N 670376.04 E 20.962 4734.38 11163.39 92.250 62.630 8983.73 9040.13 4764.29 N 161.14 W 5980131.39 N 670406.46 E 23.873 4749.33 11193.07 90.340 56.580 8983.06 9039.46 4779.30 N 135.55 W 5980146.98 N 670431.69 E 21.370 4765.66 11226.90 89.870 49.590 8983.00 9039.40 4799.61 N 108.52 W 5980167.89 N 670458.26 E 20.709 4787.35 .. 11264.28 89.430 40.430 8983.23 9039.63 4826.00 N 82.12 W 5980194.88 N 670484.06 E 24.533 4815.09 11296.59 90.040 32.320 8983.38 9039.78 4852.00 N 62.91 W 5980221.31 N 670502.61 E 25.171 4842.05 11346.32 92.070 23.510 8982.46 9038.86 4895.89 N 39.72W 5980265.71 N 670524.86 E 18.176 4887.10 11376.27 91.810 17.340 8981.45 9037.85 4923.92 N 29.21 W 5980293.98 N 670534.66 E 20.607 4915.64 11406.79 90.400 15.230 8980.86 9037.26 4953.21 N 20.12 W 5980323.46 N 670542.54 E 8.314 4945.34 11435.77 89.600 9.760 8980.86 9037.26 4981.49 N 14.45 W 5980351.87 N 670548.16 E 19.076 4973.91 11466.80 88.900 3.240 8981.26 9037.66 5012.31 N 10.94 W 5980382.76 N 670550.97 E 21.131 5004.86 22 September, 2003 - 10:05 Page 2 of 4 Dri/lQuest 3.03.02.002 'f;1¡~ervices Survey Report førP. . ... .... .~l!.P.d. K-08A Your Ref: A'!l5lJ9292140801 Job No. AKMWOOO2651862,.;Surveyed: 11 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11494.86 88.110 356.550 8982.00 9038.40 5040.34 N 10.99 W 5980410.78 N 670550.28 E 23.999 5032.86 11532.63 88.550 349.320 8983.10 9039.50 5077.78 N 15.63 W 5980448.11 N 670544.79 E 19.169 5070.00 11568.92 89.160 342.800 8983.83 9040.23 5112.98 N 24.37 W 5980483.10 N 670535.26 E 18.041 5104.69 11605.77 89.010 334.430 8984.41 9040.81 5147.25 N 37.79W 5980517.06 N 670521.06 E 22.714 5138.22 11646.51 91.280 328.530 8984.31 9040.71 5183.03 N 57.23 W 5980552.39 N 670500.81 E 15.516 5172.93 11675.63 89.960 322.720 8984.00 9040.40 5207.05 N 73.67 W 5980576.03 N 670483.83 E 20.459 5196.06 . 11704.14 90.480 316.200 8983.89 9040.29 5228.71 N 92.19W 5980597.26 N 670464.82 E 22.942 5216.72 11722.07 91.890 313.020 8983.52 9039.92 5241.30 N 104.9SW 5980609.55 N 670451.78 E 19.397 5228.62 11750.26 90.930 307.560 8982.82 9039.22 5259.51 N 126.44 W 5980627.27 N 670429.88 E 19.660 5245.69 11784.64 90.220 299.280 8982.48 9038.88 5278.43 N 155.10W 5980645.53 N 670400.79 E 24.171 5263.08 11817.13 90.660 293.290 8982.23 9038.63 5292.81 N 184.22 W 5980659.25 N 670371.35 E 18.486 5213.92 11855.73 90.930 286.060 8981.69 9038.09 5305.80 N 220.54 W 5980671.40 N 670334.75 E 18.742 5286.98 11882.50 92.600 281.130 8980.87 9037.27 5312.09 N 246.54W 5980677.10 N 670308.61 E 19.435 5291.90 11918.75 94.450 286.420 8978.63 9035.03 5320.70 N 281.66 W 5980684.91 N 670273.30 E 15.433 5298.66 11950.06 92.950 293.290 8976.61 9033.01 5331.30 N 311.03 W 5980694.84 N 670243.70 E 22.413 5307.72 11983.77 90.220 298.580 8975.68 9032.08 5346.03 N 341.32W 5980708.88 N 670213.08 E 17.652 5329·84 12016.86 88.810 305.620 8975.96 9032.36 5363.61 N 369.33W 5980725.81 N 670184.68 E 21.697 5336.93 12047.42 88.190 312.850 8976.76 9033.16 5382.92 N 392.98 W 5980144.58 N 670160.60 E 23.737 5354.97 12072.43 86.780 315.490 8977.86 9034.26 5400.32 N 410.90 W 5980761.57 N 670142.28 E 11.958 5371.42 12104.58 85.370 321.310 8980.06 9036.46 5424.30 N 432.19 W 5980785.05 N 670120.46 E 18.585 5394.24 12128.98 86.870 327.300 8981.71 9038.11 5444.06 N 446.38 W 5980804.49 N 670105.81 E 25.252 5413.24 12150.00 86.870 327.300 8982.86 9039.26 5461.72 N 457.72W 5980821.89 N 670094.08 E 0.000 5430.28 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 3.000° (True). Magnetic Declination at Surface is 25.799°(07-Sep-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12150.000., The Bottom Hole Displacement is 5480.87ft., in the Direction of 355.209° (True). 22 September, 2003 - 10:05 Page 3 of4 DrlllQuest 3.03.02.002 North Slope Alaska Comments Measured Depth (ft) 10503.29 10560.00 12150.00 Sperry-Sufi ÐrillingServices Survey Report for PBU_WOA K Pad - K-OBA Your Ref: API 500292140B01 Job No. AKMWO002651B62, SurveyecJ: 11 September, 2003 Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 8798.64 8848.01 9039.26 4412.24 N 4440.13 N 5461.72 N Tie On Point Window Point Projeúted Survey 523.66 W 524.04 W 457.72 W Survey tool program for K-OBA From Measured Vertical Depth Depth (ft) (ft) 0.00 10503.29 To Measured Vertical Depth Depth Survey Tool Déscription (ft) (ft) 0.00 10503.29 8798.64 12150.00 8798.64 BP High Accuracy Gyro(K-08) 9039.26 MWD Magnetic(K-08A) 22 September, 2003 - 10:05 Page 40f4 BPXA . .. . DrlllQuest 3.03.02.002 . fi\\ I L, In\ Ll W . / , í I ! j i ! / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS ;' CONSERVATION COMMISSION j 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit K-08A BP Exploration (Alaska), Inc. Permit No: 203-140 Surface Location: 1830' SNL, 410' EWL, Sec. 04, T11N, R14E, UM Bottomhole Location: 3592' NSL, 45' WEL, Sec. 32, T12N, R14E, UM Dear Mr. Endacott: Enclosed is the approved application for permit to redrill the above development well. This 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~e~ Commissioner BY ORDER QF THE COMMISSION DATED this!.!/- day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section _ STATE OF ALASKA ALASKA __ AND GAS CONSERVATION CO_ISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IBI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12100 TVD 8983ss 7. Property Designation: ADL 028299 10. KB Elevation KBE = 15. Distance to Nearest Well Within Pool ./ (Height above GL): 56.4' feet K-02C is 432' away at 11750' MD 17. Anticipated pressure (see 20 MC 25.035) .",.-- 10562 ft Maximum Hole Angle 900 Max. Downhole Pressure: 3289 psig. Max. Surface Pressure: 2233 psig Sèttihg<Depth Top Bottom Grade CouplinQ LenQth MD TVD MD TVD L-80 TC-II/ ST-L 2120' 9980' 8342 12100' 8983 o Drill iii Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1830' SNL, 410' EWL, SEC. 04, T11N, R14E, UM Top of Productive Horizon: 2522' NSL, 100' WEL, SEC. 32, T12N, R14E, UM Total Depth: 3592' NSL, 45' WEL, SEC. 32, T12N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-670676 y-5975372 Zone-ASP4 16. Deviated Wells: Kickoff Depth 1ª:Casing Program Size Hole CasinQ WeiQht 3-3/4" 3-3/16" x 2-7/8" 6.2# /6.4# \#.J4A- SIIY2..POJ ~Øf iii Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: / PBU K-08A 12. Field 1 Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Dati 08/19/03 14. Distance to Nearest Property: 12,320' 9. Acres in Property: 2560 or sacks) (includinQ staqe data) 107 cu ft Class 'G' / PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): 10985 8151 N/A Junk (measured): N/A Structural Conductor 110' 30" x 20" 8 cu yds concrete Surface 2673' 13-3/8" 3719 cu ft PF 'E' Intermediate 10387' 9-5/8" 2176 cu ft Class 'G' Production Liner 846' 7" 280 cu ft Class 'G' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mary Endacott Title CT Drilling Engineer S;,nature 7Jfd4'&1d()/1f#- Permit To Drill ," J I API Number: Number: Zo.3 -/90 50-029-21408-01-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures , Other: T~st ~Oy~ to 3S"00 p~, Perforation Depth MD (ft): 10746' - 10842' 20. Attachments IBI Filing Fee IBI BOP Sketch o Property Plat 0 Diverter Sketch 110' 2673' 10387' 110' 2673' 7749' 10139' - 10985' 8480' - 9220' IperfOration Depth TVD (ft): 9012' - 9095' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 0 Drilling Fluid Program IBI 20 MC 25.050 Requirements Date: Contact Mary Endacott, 564-4388 Date õj 7 /ð-~ Prepared By Name/Number: Terrie Hubble, 564-4628 Phone 564-4388 Commission Use Only I Permit APR~OV 11· . .' Date: fI rL( DS- o Yes ~ No Mud Log R quire ~ ~ Yes D No Directional Survey Required I See cover letter for other requirements DYes ~No ~ Yes D No BY ORDER OF THE COMMISSION s~,ti~}. Approved Bv: ~?Ä ~~ I G Æ>1J1t\\SfIONER Form 10-401 Revi"M":;12003) UK II \I!-\ .¡../ Date e e BP K-08A CTD Sidetrack Summary of Operations: Phase 1: Prep work - integrity testing (complete) / Phase 2: Set whipstock, Downsqueeze Phase 3: Drill and Complete sidetrack Mud Program: · Phase 2: Viscosified Seawater · Phase 3: Flo-Pro (8.6 - 8.7 ppg) ./ Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / /' · 33/16" 6.2# L-80 TC-II x 2 7/8" 6.4# ST-L L-~~80' (-8285 TVDSS) to 12100'. · The liner will be cemented with a minimum L;'~.9J~"lO bring cement up -200ft above the window. / Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to Nearest Well Within Pool: closest approach is 432ft to K-02C at 11,750' in planned well path / · Distance to Nearest Property: 12,320ft to Prudhoe Unit Boundary ./ Logging · MWD Gamma Ray and resistivity will be run in the open hole section. · Memory CNL will be run inside the liner. Hazards / · The maximum recorded H2S on K Pad is 10ppm. · No faults will be crossed Reservoir Pressure · Res. press. is estimated to be 3289 psi at 8800'ss (7.2ppg emw) - measured 7/28/02. · Max. surface pressure with gas (0.12 psi/ft) to surface is 2233 psi. /' TREE = ' WELLHEAD = ACTUATOR = KB. ELEV = ELEV= KOP= Max Angle = Datum MD '" Datum TVD = 6" MCEVOY MCEVOY OTIS 56.35' 27.85' 3496' 50 @ 6398' 10568' 8800' SS NOTES: . 2331' J-\5-1/2" OTIS RQY SSSV LAND NIP, ID '" 4.562" 1 113-3/8" CSG, 72#, L-80, 10'" 12.347" 1-\ 2613' ¡-...t ~ I I 9840' H 5-1/2" OTIS XA SLIDING SL V, ID = 4.562" 1 - i ì 9899' I-TBG SEAL ASSY I g ~ 9914' 1-\9-5/8" x 5-112" TIW HBB PKR, ID = 4.75" I 9966' I- 5-1/2" OTIS X NIP, 10 = 4.562" 1 5-1/2"TBG, 17#, L-80, ,0232 bpf, 10=4,892" H 10049' I \ 10009' H5-1/2" OTIS XN NIP, ID '" 4,455" 1 10049' 1-5-112" TBG TAIL, ID '" 4,89" 10051' H ELMD TT LOGGED 11/22/851 11I\ ITOPOF 7" LNR 10133' 1 I- 19-5/8" CSG, 47#, L-80, ID '" 8,681" H 10381' I ,I I 10341' HMARKERJOINT 1 .. I- PERFORATION SUMMARY REF LOG: BHCS ON 10/08/85 ANGLE AT TOP PERF: 29@ 10746' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10746 - 10786 3-318" 4 10791 - 10807 3-3/8" 4 10811 - 10842 1 reTD I- 10942' IT' LNR, 26#, L-80, ,0383 bpf, ID 6.276" I- 10981' DATE 10/13/85 02/22/01 03/03/01 09/30/01 REV BY COMMENTS ORIGINAL COM PLErION SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL RNlTP CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: K-08 PERMIT No: 1851790 API No: 50-029-21408-00 SEC4, T11N, R14E, 1830' SNL &410' EWL BP Exploration (Alaska) ObP e BP-GDB e Baker Hughes INTEQ Planning Report B". ..... INTEQ Well: K-08. True North System: Mean Sea Level Well (0.00N.0.ooE.3.00Azi) Method: Minimum Curvature Db: Oracle Site: PB K Pad Well: K-08 Wellpath: Plan#3 K-08A ----- Vertical Section Snrvey ----- ------ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5973161.33 ft 670342.10 ft Latitude: 70 19 Longitude: 148 37 North Reference: Grid Convergence: --_._- Alaska. Zone 4 Well Centre bggm2003 57.435 N 5.245 W True 1.30 deg Well: K-08 Slot Name: 08 K-08 Well Position: +N/-S 2202.66 ft Northing: 5975372.00 ft Latitude: 70 20 19.098 N +E/-W 384.04 ft Easting : 670676.00 ft Longitude: 148 36 54.028 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 K-08A 500292140801 Current Datum: 15 : 08 9/24/1985 00:00 Magnetic Data: 8/5/2003 Field Strength: 57575 nT Vertical Section: Depth From (TVD) ft 32.40 Height 56.40 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Targets K-08 10503.29 ft Mean Sea Level 25.66 deg 80.88 deg Direction deg 3.00 K-08A Fault 1 0.00 5692.72 -960.75 5981041.00 669586.00 70 21 15.085 N 148 3722.110 W -Polygon 1 0.00 5692.72 -960.75 5981041.00 669586.00 70 21 15.085 N 148 3722.110 W -Polygon 2 0.00 5593.39 -639.90 5980949.00 669909.00 70 21 14.108 N 148 37 12.732 W -Polygon 3 0.00 5584.72 -258.97 5980949.00 670290.00 70 21 14.023 N 148 37 1.597 W -Polygon 4 0.00 5593.39 -639.90 5980949.00 669909.00 70 21 14.108 N 148 37 12.732 W K-08A Fault 2 0.00 5473.82 -616.62 5980830.00 669935.00 70 21 12.932 N 148 37 12.051 W -Polygon 1 0.00 5473.82 -616.62 5980830.00 669935.00 70 21 12.932 N 148 37 12.051 W -Polygon 2 0.00 5027.10 -942.89 5980376.00 669619.00 70 21 8.539 N 148 3721.586 W K-08A Polygon3.2 0.00 4625.40 -302.82 5979989.00 670268.00 70 21 4.588 N 148 37 2.878 W -Polygon 1 0.00 4625.40 -302.82 5979989.00 670268.00 70 21 4.588 N 148 37 2.878 W -Polygon 2 0.00 4815.67 -48.41 5980185.00 670518.00 70 21 6.460 N 148 36 55.443 W -Polygon 3 0.00 5025.35 100.41 5980398.00 670662.00 70 21 8.522 N 148 36 51.093 W -Polygon 4 0.00 5246.29 62.43 5980618.00 670619.00 70 21 10.695 N 148 36 52.203 W -Polygon 5 0.00 5410.25 -240.94 5980775.00 670312.00 70 21 12.307 N 148 37 1.070 W -Polygon 6 0.00 5504.62 -431.85 5980865.00 670119.00 70 21 13.235 N 148 37 6.650 W -Polygon 7 0.00 5378.93 -534.75 5980737.00 670019.00 70 21 11.999 N 148 37 9.658 W -Polygon 8 0.00 5247.81 -399.69 5980609.00 670157.00 70 21 10.710 N 148 37 5.710 W -Polygon 9 0.00 5135.21 -155.17 5980502.00 670404.00 70 21 9.602 N 148 36 58.563 W -Polygon 10 0.00 4940.75 -225.62 5980306.00 670338.00 70 21 7.690 N 148 37 0.622 W -Polygon 11 0.00 4781.37 -387.30 5980143.00 670180.00 70 21 6.122 N 148 37 5.347 W K-08A T3.1 8983.00 4767.42 -213.56 5980133.00 670354.00 70 21 5.985 N 148 37 0.269 W K-08A T3.2 8983.00 5170.08 -61.35 5980539.00 670497.00 70 21 9.945 N 148 36 55.821 W K-08A T3.3 8983.00 5422.48 -470.74 5980782.00 670082.00 70 21 12.428 N 148 37 7.787 W ObP e BP-GDB e B.. ..... Baker Hughes INTEQ Planning Report IN1'8.Q 3 4; ) :K-'OS", Vertleal (fVD) Reference: System: Mean Sea Level Section(VS) Reference: Well (0.ooN,O.00E,3.00Azi) Survey Cateulatioo Method: Minimum Curvature Db: Oracle _._-~_._--- Annotation 10503.29 8742.24 TIP 10562.00 8793.77 KOP 10582.00 8811.18 3 10929.33 8982.78 4 11079.33 8982.78 5 11879.33 8982.78 6 12079.33 8982.78 7 12100.00 8982.78 TD Plan: Plan #3 Date Composed: 8/5/2003 Identical to Lamar's Plan #3 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information +E/-W DLS Build Turn TFO Target ft deg/10Oft deg/1ooft deg/10Oft deg 10503.29 28.63 359.39 8742.24 4412.24 -523.66 0.00 0.00 0.00 0.00 10562.00 28.66 359.05 8793.77 4440.38 -524.04 0.28 0.05 -0.58 280.28 10582.00 30.23 0.84 8811.18 4450.21 -524.04 9.00 7.86 8.94 30.00 10929.33 90.00 46.68 8982.78 4686.47 -378.10 20.00 17.21 13.20 50.00 11079.33 90.00 76.68 8982.78 4756.83 -247.56 20.00 0.00 20.00 90.00 11879.33 90.00 276.68 8982.78 5320.13 -280.29 20.00 0.00 -20.00 270.00 12079.33 90.00 316.68 8982.78 5408.10 -455.39 20.00 0.00 20.00 90.00 12100.00 90.00 312.54 8982.78 5422.62 -470.11 20.00 0.00 -20.00 270.00 Survey 10503.29 28.63 359.39 8742.24 4412.24 -523.66 5979770.88 670052.09 4378.78 0.00 0.00 TIP 10525.00 28.64 359.26 8761.30 4422.64 -523.78 5979781.28 670051.73 4389.17 0.28 280.28 MWD 10550.00 28.65 359.12 8783.24 4434.62 -523.95 5979793.25 670051.29 4401.13 0.28 280.39 MWD 10562.00 28.66 359.05 8793.77 4440.38 -524.04 5979799.00 670051.06 4406.87 0.28 280.52 KOP 10575.00 29.68 0.23 8805.12 4446.71 -524.08 5979805.34 670050.88 4413.19 9.00 30.00 MWD 10582.00 30.23 0.84 8811.18 4450.21 -524.04 5979808.83 670050.84 4416.68 9.00 28.97 3 10600.00 32.65 5.95 8826.54 4459.57 -523.47 5979818.20 670051.19 4426.06 20.00 50.00 MWD 10625.00 36.30 11.99 8847.15 4473.53 -521.24 5979832.21 670053.11 4440.12 20.00 45.63 MWD 10650.00 40.21 17.04 8866.78 4488.49 -517.33 5979847.25 670056.68 4455.27 20.00 40.65 MWD 10675.00 44.30 21.31 8885.29 4504.35 -511.79 5979863.23 670061.85 4471.39 20.00 36.69 MWD 10700.00 48.53 25.00 8902.52 4520.99 -504.65 5979880.03 670068.61 4488.38 20.00 33.52 MWD 10725.00 52.87 28.22 8918.35 4538.27 -495.98 5979897.50 670076.89 4506.09 20.00 30.98 MWD 10750.00 57.28 31.09 8932.67 4556.06 -485.83 5979915.52 670086.63 4524.39 20.00 28.93 MWD 10775.00 61.75 33.69 8945.35 4574.24 -474.28 5979933.96 670097.76 4543.15 20.00 27.29 MWD 10800.00 66.27 36.08 8956.30 4592.66 -461.42 5979952.66 670110.19 4562.22 20.00 25.97 MWD 10825.00 70.82 38.31 8965.45 4611.19 -447.36 5979971.50 670123.83 4581.45 20.00 24.92 MWD 10850.00 75.39 40.42 8972.71 4629.67 -432.19 5979990.32 670138.58 4600.71 20.00 24.10 MWD 10875.00 79.98 42.44 8978.04 4647.97 -416.03 5980008.99 670154.32 4619.83 20.00 23.49 MWD 10900.00 84.59 44.41 8981.40 4665.96 -399.00 5980027.36 670170.93 4638.68 20.00 23.06 MWD 10925.00 89.20 46.34 8982.75 4683.49 -381.24 5980045.29 670188.29 4657.12 20.00 22.79 MWD 10929.33 90.00 46.68 8982.78 4686.47 -378.10 5980048.33 670191.35 4660.26 20.00 22.69 4 10950.00 90.00 50.81 8982.78 4700.10 -362.56 5980062.31 670206.58 4674.68 20.00 90.00 MWD 10975.00 90.00 55.81 8982.78 4715.03 -342.52 5980077.70 670226.27 4690.64 20.00 90.00 MWD 11000.00 90.00 60.81 8982.78 4728.16 -321.25 5980091.31 670247.23 4704.87 20.00 90.00 MWD 11025.00 90.00 65.81 8982.78 4739.38 -298.93 5980103.04 670269.30 4717.24 20.00 90.00 MWD 11050.00 90.00 70.81 8982.78 4748.62 -275.70 5980112.80 670292.30 4727.68 20.00 90.00 MWD 11075.00 90.00 75.81 8982.78 4755.80 -251.76 5980120.52 670316.07 4736.10 20.00 90.00 MWD 11079.33 90.00 76.68 8982.78 4756.83 -247.56 5980121.64 670320.25 4737.35 20.00 90.00 5 11100.00 90.00 72.54 8982.78 4762.31 -227.63 5980127.58 670340.05 4743.87 20.00 270.00 MWD ObP e BP-GDB e Baker Hughes INTEQ Planning Report B.. ..... INTEQ Section (VS) Reference: --_.~._._~ Survey Calculation Method: -~_. Survey Incl Azim Sys TVD N/S E/W MapN MapE deg deg ft ft ft ft ft 11125.00 90.00 67.54 8982.78 4770.84 -204.14 5980136.64 670363.33 4753.62 20.00 270.00 MWD 11150.00 90.00 62.54 8982.78 4781.39 -181.49 5980147.70 670385.75 4765.34 20.00 270.00 MWD 11175.00 90.00 57.54 8982.78 4793.87 -159.83 5980160.67 670407.11 4778.94 20.00 270.00 MWD 11200.00 90.00 52.54 8982.78 4808.19 -139.35 5980175.45 670427.26 4794.31 20.00 270.00 MWD 11225.00 90.00 47.54 8982.78 4824.24 -120.19 5980191.93 670446.04 4811.34 20.00 270.00 MWD 11250.00 90.00 42.54 8982.78 4841.90 -102.51 5980209.99 670463.32 4829.90 20.00 270.00 MWD 11275.00 90.00 37.54 8982.78 4861.04 -86.43 5980229.48 670478.96 4849.85 20.00 270.00 MWD 11300.00 90.00 32.54 8982.78 4881.50 -72.08 5980250.27 670492.83 4871.04 20.00 270.00 MWD 11325.00 90.00 27.54 8982.78 4903.13 -59.57 5980272.18 670504.85 4893.30 20.00 270.00 MWD 11350.00 90.00 22.54 8982.78 4925.78 -48.99 5980295.06 670514.91 4916.46 20.00 270.00 MWD 11375.00 90.00 17.54 8982.78 4949.26 -40.43 5980318.72 670522.94 4940.36 20.00 270.00 MWD 11400.00 90.00 12.54 8982.78 4973.39 -33.94 5980343.00 670528.87 4964.80 20.00 270.00 MWD 11425.00 90.00 7.54 8982.78 4998.00 -29.59 5980367.70 670532.66 4989.60 20.00 270.00 MWD 11450.00 90.00 2.54 8982.78 5022.90 -27.39 5980392.64 670534.29 5014.58 20.00 270.00 MWD 11475.00 90.00 357.54 8982.78 5047.89 -27.37 5980417.62 670533.74 5039.54 20.00 270.00 MWD 11500.00 90.00 352.54 8982.78 5072.79 -29.53 5980442.46 670531.02 5064.29 20.00 270.00 MWD 11525.00 90.00 347.54 8982.78 5097.40 -33.86 5980466.97 670526.13 5088.64 20.00 270.00 MWD 11550.00 90.00 342.54 8982.78 5121.55 -40.31 5980490.96 670519.13 5112.42 20.00 270.00 MWD 11575.00 90.00 337.54 8982.78 5145.04 -48.84 5980514.25 670510.07 5135.43 20.00 270.00 MWD 11600.00 90.00 332.54 8982.78 5167.70 -59.38 5980536.66 670499.01 5157.51 20.00 270.00 MWD 11625.00 90.00 327.54 8982.78 5189.35 -71.87 5980558.02 670486.04 5178.48 20.00 270.00 MWD 11650.00 90.00 322.54 8982.78 5209.83 -86.19 5980578.17 670471.26 5198.18 20.00 270.00 MWD 11675.00 90.00 317.54 8982.78 5228.99 -102.24 5980596.96 670454.78 5216.47 20.00 270.00 MWD 11700.00 90.00 312.54 8982.78 5246.67 -119.90 5980614.23 670436.72 5233.21 20.00 270.00 MWD 11725.00 90.00 307.54 8982.78 5262.75 -139.03 5980629.87 670417.23 5248.26 20.00 270.00 MWD 11750.00 90.00 302.54 8982.78 5277.10 -159.49 5980643.75 670396.45 5261.52 20.00 270.00 MWD 11775.00 90.00 297.54 8982.78 5289.61 -181.13 5980655.76 670374.54 5272.88 20.00 270.00 MWD 11800.00 90.00 292.54 8982.78 5300.19 -203.77 5980665.82 670351.66 5282.26 20.00 270.00 MWD 11825.00 90.00 287.54 8982.78 5308.75 -227.25 5980673.85 670327.99 5289.58 20.00 270.00 MWD 11850.00 90.00 282.54 8982.78 5315.24 -251.39 5980679.78 670303.72 5294.80 20.00 270.00 MWD 11875.00 90.00 277.54 8982.78 5319.60 -275.99 5980683.58 670279.02 5297.86 20.00 270.00 MWD 11879.33 90.00 276.68 8982.78 5320.13 -280.29 5980684.02 670274.71 5298.17 20.00 270.00 6 11900.00 90.00 280.81 8982.78 5323.27 -300.72 5980686.69 670254.22 5300.24 20.00 90.00 MWD 11925.00 90.00 285.81 8982.78 5329.03 -325.04 5980691.89 670229.78 5304.71 20.00 90.00 MWD 11950.00 90.00 290.81 8982.78 5336.88 -348.76 5980699.20 670205.88 5311.31 20.00 90.00 MWD 11975.00 90.00 295.81 8982.78 5346.77 -371.72 5980708.56 670182.71 5319.99 20.00 90.00 MWD 12000.00 90.00 300.81 8982.78 5358.62 -393.72 5980719.91 670160.44 5330.67 20.00 90.00 MWD 12025.00 90.00 305.81 8982.78 5372.34 -414.61 5980733.16 670139.25 5343.28 20.00 90.00 MWD 12050.00 90.00 310.81 8982.78 5387.84 -434.22 5980748.20 670119.29 5357.73 20.00 90.00 MWD 12075.00 90.00 315.81 8982.78 5404.98 -452.40 5980764.92 670100.72 5373.90 20.00 90.00 MWD 12079.33 90.00 316.68 8982.78 5408.11 -455.40 5980767.98 670097.66 5376.86 19.98 90.00 7 12100.00 90.00 312.54 8982.78 5422.62 -470.11 5980782.15 670082.62 5390.58 20.00 270.00 TO All Measurements are from top of Riser top of bag e Nordic 1 big hole "- Q) en .- cr: e 8/6/2003 t(-08A ~ ----.i Schlumberger J bttm of bag middle of slips middle of pipes ..-.. middle of flow cross - Blind/Shears 2 3/8" combi ram/slips Mud Cross BAG 71/16" 5000psi .......................... TOTs /' I...............········· 7 1/16" 5000psi .' r--' Mud Cross 7 1/16" 5000psi '----' 1 variable bore pipe 3 1/2"-27/8" 1 middle of blind/shears middle of pipe/slips I 2 3/8" combi ram/slips Flow Tee r·················....... TOTs ./ I..................········ 7 1/16" 5000psi e p055112 DATE INVOICE / CREDIT MEMO GROSS DESCRIPTION 7/14/2003 INV# PR071003B PERMIT TO DRILL ~EE ~ .06+1 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 PAY: TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio 1110 5 5 ~ L 2111 I: 0.... ~ 2 0 j B q 5.: 0 L 2 'i' B q ¡; liD -- DATE I 1 CHECK NO. 7/14/2003 055112 VENDOR DISCOUNT NET 56-389 412 No. P 055112 CONSOLIDATED COMMERCIAL ACCOUNT I I *******$100.00******i NOT VALID r>J..\'6-"~~,",N::;'_~"_'. ;.q.:.f-..Ü..·.¡;.··_,¡~ .~ .......~:...:..:.:. ~\;~~··:··:··:~:··.fjA~:···\\···~~:·, "..~.~:...\:~:' :..j, . ........... ~ :;'-~_.........".._. ............. ~~\{;,)~~é~~:.~:~:~~;;~1¡\i Rev: 07/10/02 C\jody\temp)ates e e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new well bore segment of existing well-, Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), 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). SPACING EXCEPTION DRY DITCH SAMPLE 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. (Companv 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. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT K-08A Program DEV Well bore seg 0 Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 nitial ClasslType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 0 Administration 1 P~rm it fee attachep_ · Xes - - - - - - - - - - - -- 2 Leas~numberappropriate. _ _ . Y~s 3 _U_nique weltn_am~_a[ld lJumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ · Y~s - - - . - - . - - - - - - - - ~ - - - - 4 WeJIJQc<lt~d in_a. d_efine_d pool . Y~s 5 Well JQcated proper _distance from driJling unitb_ound~ry_ _ y~s 6 Well JQcat~d proper distance_ from Qtber W!9lJs_ _ _ _ _ _ . _ . _ . . Y~s - - - - - - - - -- 7 _S.utficienLacr!9ageaYaíl~ble in dJilIilJQ unjL y~s 8 Jfd!9viated, js weJlbQre platincJuded . - - - - - - - - - - - - - Xes - - - - - - - - - - - - 9 Op!9rator only affected party _ _ Xes - - - - - - - - - - - - 10 _Operator basappropriateJlond inJQrce _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes - - - - . - - - - - - - - - - - - - -- 11 P~rmit ca[l be issued wjtbQut cOMervaJion order _ _ _ _ _ . _ . . . . . Y~s - - - - - - - - - - - - Appr Date 12 P~rmit ça[l be issued wjtbQut administratille_ approvaJ _ - - - - - - y~s - - - - - - - - - - - - - - - - - - RPC 8/12/2003 13 Can permit be approved before 15-day wait Yes 14 Well JQc<lted within area and_strata _authQrized by_llJjeçtiolJ Ord~r # (put 10# in comments) (FQr. NA e 15 AJI W!9 IJs_with in Jl4_llJile_area_of reyi!9W id~ntifi!9d (FOr servjc_e_weU only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA . - - - - - - - - - - - - - - - - - - - 16 PJe-produ_cecl i[lj!9ctQr; puration_of pœ-propuGtion I~ss than 3 mQnths (Fors!9rvice welt QnJy) . NA 17 ACMP finding of CQn_si;;te[lçy_h_as beeJ1 Jssued. for. tbis pr_olect _ _ _ _ _... _ _ _ _NA Engineering 18 _Co[ldu_ctor string_PJQvid!9d _ . _ . _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ .NA . - - - - - 19 _S_urfac~_casing_pJQtec_ts alLknQwn USDWs . _ _ _. _ _ _ _ _ _ _ _ _ _ _. _. _ _ _NA 20 _CMT vol ad!9quate_ to circ_ulate. on .cond.uctoc & SUJt csg . _ _ _. _.. _ _ _NA - - - - - - - - - 21 .CMT vol ad!9qu.ateJQ tie-inJQngstring to surf csg _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . _NA 22 _CMT wilJ çoyeraJl koownpro_duçtiye bQri~Qn_s _. _ _ _ _ _ _ _ _. _... _ _ Xes - - - - - - - - - - - 23 C_asing designs ad_ec¡uaJe fpr CoT, B .&_ perllJakost - - - - - - - . _ Xes - - - - - - - - - 24 ApequatetankageoJ reserve pit. _ Xes CTDU. 25 Jfa re-príll~ has a to-403 fQr abandQnment been <lPPJQv!9d . - - - - - - - - - ... _ Xes 8/11/2003. 26 _Apequate weUbore separ<ltjo_n .proP9sep. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _Y_es . - - - - - - - - - - - - - - - - - -- 27 Kdiv!9r:.!er Jeq_uiJed, dQes iLme!9t reguJatioos _ _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ . . . . _ _ _NA Sidetrack.. _ Appr Date 28 DJiUiog fluid prQgram sçhematic& eC.uip JistadeC.u<lt~_ Y~s Max MW8> 7 ppg. WGA 8/12/2003 29 _B_OPEs,_d_o _they meet reguJaJion . . - - - - - - -- _ _ _ _ Xes - - - - - - - - - - - e 30 BOPEpress rating appropriate; Jest to (puJ psig in _c9mments). Y~s Test to 3500 psl.MSP 2233 psi 31 ChokellJanifQld cQmpJies w/APt RF'-53 (May 84) · Y~s 32 WQrk wiJl Oçcur withoutoper<ltionshutdown - - - - - -- .. Y~s 33 Js presençe Qf H2S gas_ probable _ .. _ _ _.. No. 34 Mecba.nic<ll.coodJlio[l p{ wells within ,ô.OR yerifiecl (Forß_ervic!9 w~1J QnJy) _ _ _ _ _ _ _ _ _ _ _ . . _ NA Geology 35 P~rmit c:<In be issued w/o hydrogen sulfide meaSUres _ _ _ _ _ _ _ _ _ _.. No_ 36 _D_ata.PJeseotecl Qn_ pote_ntial oveJpressur~ .zone;; _ _ _NA Appr Date 37 _S~ismic.analysjs Qf sbaJlow gas_z_ones. _NA - - - - - - - - RPC 8/12/2003 38 _S~abed .conditiolJ survey (if off-sh9re) . ... .NA 39 CQntact nameLphQnefQrwe~kly progr~ssreports [explor<ltoryonlyt NA ~ <f /-/. . Geologic Date: Engineering Date Public ò-/0 DateY Commissioner: com~ Commissioner '1 ~ ~ e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennilting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ... . . Ðò3 -/L(ð ) ?,J.- ~ ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 02 11:53:49 2003 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Dat.e.....................03/12/02 Origin.................. .STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA K-08A 500292140801 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 02-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002651862 B. JAHN EGBEJIMBA/KO MWD RUN 2 MW0002651862 B. JAHN SARBER/KOLST MWD RUN 3 MW0002651862 S. LATZ SEVCIK/SARBE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 4 T11 R14 1830 410 56.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 5.500 10049.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . RECEIVED DEC 08 2003 Aiaska 0Ii & Gas Cons. eommieeion Anctt«.nge :(~~\,"-~ . . 3. THE WELL WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 10560'MD AND THE BOTTOM WAS AT 10571'MD. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM), UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. UPHOLE (10339'-10434'MD) TIE-IN DGR DATA ACQUIRED WHILE RIH FOR RUN 2 WERE MERGED WITH RUN 1 DATA. 6. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN K-08A ON 12 SEPTEMBER 2003. THESE PDC DATA WERE PROVIDED TO SSDS BY KURT COONEY (BP) ON 3 NOVEMBER 2003. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL K-08A WITH API#: 50-029-21408-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12150'MD/8983'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/02 Maximum Physical Record..65535 File 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 RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 10339.0 10551.5 10551.5 10551.5 10551.5 10551. 5 10582.0 STOP DEPTH 12102.5 12114.5 12114.5 12114.5 12114.5 12114.5 12146.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10360.5 10366.5 10369.5 GR 10360.5 10366.5 10370.0 . . 10372.0 10375.0 10377.0 10381.0 10383.5 10389.0 10401.5 10417.0 10432.5 10538.5 10546.5 10585.0 10589.0 10596.0 10615.0 10629.5 10642.5 10673.0 10688.0 10691.0 10697.5 10705.0 10727.0 10740.0 10754.5 10769.0 10782.5 10793.0 10798.0 10809.0 10829.5 10846.0 10854.5 10864.0 10892.0 10897.5 10900.5 10906.5 10926.5 10946.0 11011. 5 11021. 0 11066.5 11084.5 11096.0 11103.5 11111.0 11137.5 11162.0 11189.0 11220.5 11225.5 11263.5 11279.0 11318.5 11324.0 11334.0 11371. 0 11388.0 11424.0 11456.5 11509.5 11554.0 11569.0 11582.0 11603.5 11636.0 11639.5 11649.0 11668.0 11675.5 11689.5 11697.0 11 707.5 11718.5 10372.5 10376.0 10377.5 10380.5 10383.5 10386.5 10397.5 10411. 0 10427.0 10536.5 10544.0 10584.5 10588.0 10596.5 10615.0 10628.5 10643.5 10673.5 10688.5 10692.5 10696.5 10705.0 10724.0 10738.5 10753.5 10770.5 10784.5 10795.5 10800.5 10811. 0 10830.5 10848.0 10861. 0 10870.5 10904.5 10907.0 10908.0 10913.5 10931. 5 10954.5 11019.0 11030.0 11075.0 11091.5 11102.0 11108.0 11113.5 11141. 0 11168.0 11195.5 11227.5 11231.5 11269.5 11287.5 11322.5 11327.0 11335.0 11373.5 11393.5 11431.0 11461. 5 11514.0 11557.0 11573.5 11588.0 11611.0 11643.5 11648.0 11658.0 11672.5 11678.5 11694.5 11701.5 11714.0 11724.5 . . 11 731. 0 11772.0 11780.0 11 795.5 11809.5 11828.5 11838.5 11845.0 11851.0 11862.0 11871.5 11881. 0 11889.5 11897.5 11916.5 11925.0 11931. 5 11939.5 11948.5 11991.0 11994.0 12002.0 12026.0 12036.5 12053.0 12059.0 12069.5 12076.5 12091.0 $ 11737.0 11778.5 11785.0 11801. 0 11816.5 11833.5 11841.0 11854.0 11859.0 11869.0 11879.0 11889.0 11896.5 11904.0 11923.0 11930.5 11938.0 11946.0 11952.5 11996.0 11998.5 12006.5 12030.0 12041. 5 12060.5 12064.5 12075.0 12080.0 12095.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 10339.0 10542.0 10904.0 MERGE BASE 10587.0 10946.5 12150.5 # 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 10339 12146.5 11242.8 3616 10339 12146.5 ROP MWD FT/H 0.06 754.38 96.3689 3130 10582 12146.5 GR MWD API 15.22 199.75 51.2573 3337 10339 12102.5 RPX MWD OHMM 0.21 777.85 15.36 3127 10551. 5 12114.5 RPS MWD OHMM 0.29 2000 21.6847 3127 10551. 5 12114.5 RPM MWD OHMM 0.1 2000 27.8779 3127 10551.5 12114.5 RPD MWD OHMM 0.13 2000 31. 6741 3127 10551. 5 12114.5 FET MWD HOUR 0.25 10.31 1.29737 3127 10551. 5 12114.5 . . First Reading For Entire File..........l0339 Last Reading For Entire File...........12146.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/02 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.......03/12/02 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RA'" MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10339.0 10549.0 10549.0 10549.0 10549.0 10549.0 10581.5 # LOG HEADER DATA DATE LOGGED: SOFTI^IARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTI^IARE 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 GM EI^IR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # 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): STOP DEPTH 10541.5 10554.5 10554.5 10554.5 10554.5 10554.5 10587.0 09-SEP-03 Insite 4.3 Memory 10587.0 10581. 0 10587.0 .0 .0 RESIS. 4 TOOL NUMBER 82758 126589 3.750 10049.0 Flo-Pro 8.50 .0 . . MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.5 18000 8.8 .250 .230 .300 .470 62.0 152.0 62.0 62.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHl-1M 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10339 10587 10463 497 10339 10587 ROP MWD010 FT/H 0.24 41. 66 17.2308 12 10581.5 10587 GR MWDOI0 API 16.87 183.36 42.296 208 10339 10541.5 RPX MWD010 OHMM 0.53 0.63 0.579167 12 10549 10554.5 RPS MWDOI0 OHMM 0.54 0.96 0.745 12 10549 10554.5 RPM MWD010 OHMM 156.1 1948.82 1111. 89 12 10549 10554.5 RPD MWD010 OHMM 233.74 1282.34 778.916 12 10549 10554.5 FET MWDOI0 HOUR 0.22 1.11 0.68 12 10549 10554.5 First Reading For Entire Fi1e..........10339 Last Reading For Entire Fi1e...........10587 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/02 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.......03/12/02 Maximum Physical Record..65535 Fi 1 e 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 GR FET RPD RPM RPS RPX ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 10542.0 10555.0 10555.0 10555.0 10555.0 10555.0 10587.5 STOP DEPTH 10903.5 10915.5 10915.5 10915.5 10915.5 10915.5 10946.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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 09-SEP-03 Insite 4.3 Memory 10947.0 10587.0 10947.0 30.3 84.6 TOOL NUMBER 93091 126589 3.750 10049.0 Flo Pro 8.60 .0 8.7 18500 7.4 .180 .080 .190 .270 62.0 150.4 62.0 62.0 . . 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 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 10542 10946.5 10744.3 810 10542 10946.5 ROP MWD020 FT/H 0.06 547.62 47.7667 719 10587.5 10946.5 GR MWD020 API 15.22 168.65 39.7649 724 10542 10903.5 RPX MWD020 OHMM 0.21 777.85 17.9836 722 10555 10915.5 RPS MWD020 OHMM 0.29 2000 44.844 722 10555 10915.5 RPM MWD020 OHMM 0.1 2000 56.798 722 10555 10915.5 RPD MWD020 OHMM 0.13 2000 71.6549 722 10555 10915.5 FET MWD020 HOUR 0.44 10.31 2.33373 722 10555 10915.5 First Reading For Entire File..........l0542 Last Reading For Entire File...........l0946.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/02 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...........l.0.0 Date of Generation.......03/12/02 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS header data for each bit run in separate files. 3 .5000 START DEPTH 10904.0 10916.0 10916.0 10916.0 STOP DEPTH 12106.5 12118.5 12118.5 12118.5 . RPX FET ROP 10916.0 10916.0 10947.0 12118. 12118. 12150. $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DO¡~HOLE 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 11-SEP-03 Insite 4.3 Memory 12150.0 10947.0 12150.0 85.4 94.5 TOOL NUMBER 93091 126589 3.750 10049.0 F10 Pro 8.60 65.0 9.2 18500 7.8 .180 .080 .150 .120 68.0 152.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10904 12150.5 11527.3 2494 10904 12150.5 ROP MWD030 FT/H 0.65 754.38 110.981 2408 10947 12150.5 GR MWD030 API 27.86 199.75 55.5231 2406 10904 12106.5 RPX MWD030 OHMM 4.34 51. 17 14.6851 2406 10916 12118.5 RPS MWD030 OHMM 3.89 46.65 14.8956 2406 10916 12118.5 RPM MWD030 OHMM 4.38 55.92 14.992 2406 10916 12118.5 RPD MWD030 OHMM 8.29 47.01 17.1271 2406 10916 12118.5 FET MWD030 HOUR 0.25 6.67 1.00086 2406 10916 12118.5 First Reading For Entire File..........10904 Last Reading For Entire File...........12150.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/02 Maximum Physical Record..65535 File Type.............. ..LO Next File Name...... .....STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date................... ..03/12/02 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNh~OWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/12/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... .............UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File