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Home My WebLink About197-182XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. / ~/7-/~..~ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: n GraYScale, halftones, pictures, graphs, charts - Pages: n Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED .Logs of vadous kinds Other . Complete COMMENTS: Scanned by. Mildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl STATE OF ALASKA {~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: [] Oil [] Gas [] Plugged [] Abandoned [] Suspended [] WAG lb. Well Class: 20AAC 25.105 20AAC25.110 [] Development [] Exploratory [] GINJ [] WINJ [] WDSPL No. of Completions Zero Other [] Stratigraphic [] Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 7/16/2003 197-182 303-177 3. Address: 6. Date Spudded 13. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/11/1997 50-029-21180-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 11/21/1997 PBU 1 $-08B 1645' SNL, 1378' EWL, SEC. 22, TllN, R14E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 439' SNL, 2161' EWL, SEC. 22, T11N, R14E, UM KBE = 69' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+TVD) 1557' NSL, 1225' EWL, SEC. 15, T11N, R14E, UM 12628 + 8772 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 677321 y- 5959869 Zone- ASP4 12628 + 8772 Ft ADL028306 TPh x- 678073 Y- 5961092 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: ---- N/A MD Total Depth: x- 677087 Y- 5963066 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey [] Yes [] No N/A MSL 1900' (Approx.) 21. Logs Run: MWD, GR 22. CASING, LINER AND CEMENTING RECORD CASING .' SETTING DEPTH . HOLE . ' ' . 'SIZE WT. 'PER'FT. '"GRADE " TOP BOTTOM : SIZE CEMENTING''RECORD AMOUNT PuLLED'i ' 20" ' 91.5# H-40 Surface 90' 30" 370 sx Permafrost II 13-3/8" 72# L-80 Surface 2539' 17-1/2" 1938 sx PF 'E', 400 sx PF 'C' 9-5/8" 47# L-80 Surface 7448' 12-1/4" 500 sx Class 'G', 300 sx PF 'C' 7" 26# 13Cr80 7271' 9825' 8-1/2" 534 sx Class 'G' 4-1/2" 12.6# L-80 9768' 10725' 8-1/2" Uncemented Slotted Liner 2-3/8" 4.6# FL4S 10494' 12476' 2-3/4" Uncemented Pre-Perfed Liner 23. Perforations open to Production (MD + TVD of Top and 24..' .. 'TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): S~ZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2# x 4-1/2", 12.6# 8798' - 9456' 9270' MD TVD MD TVD 25. ·. · ACID, FRACTURE, CEMENT SQUEEZE, ETCi' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9083' P&A with 45 Bbls + 22 Bbls Class 'G' 8790' Set EZSV with Whipstock on top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED ~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach seParate sheet, if necessary). Submit core chips; if none, state "none". None 0 R I$1NAL ,, , mm · Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE ':'"h")({"~/'~~) S~SI~ I 5 ~0~.13 28. GEOLOGIC MARKER~ 29. !' 'ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8636' 8235' None Shublik 8693' 8282' Sadlerochit 8779' 8350' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble ,'~~.~ Title TechnicalAssistant Date PBU 15-08B 197-182 303-177 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer' Phil Smith, 564-4897 GENERAL: ITEM la: ITEM 4b: ITEM 8: ITEM 13: ITEM 20: ITEM 22: ITEM 23: ITEM 26: ITEM 27: INSTRUCTIONS This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean Iow Iow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The APl number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). True vertical thickness. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. 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). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGINAL Well: 15-08C Accept: 07/28/03 Field: Prudhoe Bay Unit Spud: 08/03/03 APl: 50-029-21180-03 Release: 08/10/03 Permit: 203-121 Rig: Nabors 2ES Date PRE-RIG WORK 06/02/03 PPPOT-T PASSED. PRESSURE UP ON TUBING HANGER VOID TO 5000 PSI. AFTER 15 MIN THE PRESSURE WAS 4850 PSI AND AFTER 30 MIN THE PRESSURE WAS 4800 PSI. FUNCTION TESTED ALL LDS - OK. PPPOT-IC PASSED. PRESSURE UP lC VOID TO 3150 PSI. PRESSURE AFTER BOTH 15 AND 30 MIN WAS 3150 PSI. ALL LDS WERE FUNCTION TESTED - OK. 06/O5/03 TIO= SI/130/0+. OA FL NEAR SURFACE. 06108/03 TIO = SI/120/0. MITOA TO 3000 PSI PASSED. A/L SPOOL IS DISCONNECTED. PUMPED 4 BBLS OF DIESEL DOWN OA TO 3000 PSI, IN THE 1ST 15 MIN TEST OAP LOST 80 PSI, IN THE 2ND 15 MIN TEST OAP LOST 20 PSI FOR A TOTAL OF 100 PSI IN 30 MINS. BLED OAP BACK TO 0 PSI. FINAL WHPS = SI/120/0. 07/1 2/O3 ATTEMPTING TO PULL 34' 6" ECLIPSE PATCH, UPPER PART 32' 6". UNABLE TO STAY LATCHED INTO DUE TO POSSIBLE FLOW CUT OR PLASTIC COATED TUBING. 07/13/03 T/I/O = 240/120/20. T AND IA FLS FOR E/L. TUBING FL @ 890'. IA FL @ 980'. PULLED 3 1/2 ECLIPSE UPPER PACKER @ 5450' SLM. RECOVERED ELEMENTS BUT LEFT SEAL ASSEMBLY IN HOLE. FISHED OUT SEAL ASSEMBLY. PULLED LOWER PACKER (MISSING ELEMENT). DRIFT W/2' STEM, 2.69 CENT., AND 3 PRONG WIRE GRAB, TOOLS FELL FREELY DOWN TO 9420' SLM (STOPPED DUE TO DEVIATION) ABLE TO RIH AND GET TO 9450' SLM (DID NOT RECOVER ELEMENT). 07/14/03 PERFORMED RST GRAVEL PACK LOG. FLUID LEVEL DETECTED @ 1060' - NO FLUID PUMPING NEEDED FOR LOGGING. LOGGED INTERVAL FROM 7000' TO 9324'. SET DOWN @ 9388' DUE TO DEVIATION. FIELD DATA INTERPRETATION IS INCONCLUSIVE. DATA TO BE PROCESSED. 07/16/03 PRE-RWO, P&A. LOAD IA W/75 BBLS CRUDE. LOAD WELL WITH 205 BBLS 1% KCL. RIH WITH 2.5" BALL DROP NOZZLE. TAG TOP OF 2 3/8" LINER AT 10455' CTMD. CIRCULATE WELL WITH KCL TO COOL~, GETTING 40~ ,R,,ETURNS. LOAD WELL WITH 70 BBLS CRUDE TO MAINTAIN POSITIVE WHP. PUMPir45-~LS OF 15.8 PPG G CEMENT, (30 BBLS WITH 12 PPB AGGREGATE). PUT 31 BBLS BEHIND PIPE. EST.~'OC AT 9630'. DESIRED TOP AT 9220'. PERFORM CLEAN OUT TO 9760' CTM. LOAD MORE CEMENT. 07/17/03 POOH AT 80% AFTER CEMENT CLEANOUT TO 9760',,CTM- RECOVER~A'EE"-F-~OM NOZZLE. RIH TO PUMP MORE CEMENT. TAGGED GREEN CEMENT AT-9760 CTM. LAYED Ir~_2_2 BBt~S OF 15.8 PPG "G" CEMENT FROM 9760' CTM TO -8873'. 7 BBLS BEHIND PIPE. PUH TO 8200'. PT SQuE~EZE TO 300 PSI. LOST 50 PSI IN 15 MIN. RETEST TO 300 PSI. LOST 30 PSI IN 15 MIN. CONTAMINATE AND CLEAN-OUT TO 9200' CTM. MADE SEVERAL PASSES AT 9120'. POOH IN 3 1/2" AT 50%, 80% IN 4 1/2". FREEZE PROTECT WELL TO 2500' WITH 50/50 METH. AT SURFACE TRAP 500 PSI. RD. WELL TO REMAIN SHUT IN FOR RWO. 07/18~03 DRIFT W/2.5" CENT & SB TAGGED HARD BOTTOM @ 9,083' WLM. ATTEMPTED TO PRESSURE TEST CMT PLUG, PUMPED APROX. 5 BBLS, PUMP RAN DRY, TBG NEVER PRESSURED UP. (CEMENT IN BAILER) 15-08C, Pre-Rig Work Page 2 07/20/03 TUBING PUNCHER, STRING SHOT AND CHEMICAL CUT TUBING @ 9025' MD. DEPTHS REFERENCED TO RST-GRAVEL PACK LOG DATED 7/14/03. 1ST RIH = TBG PUNCHER. TAGGED TD @ 9040' MD. INTERVAL PUNCHED: 8940-8942 FT MD WITH 9 HOLES. 2ND RIH - STRING SHOT STRING SHOT LOADED 14 FEET LONG WITH ONE STRAND OF 80 GRAIN CORD. INTERVAL = 9013-9027 FT MD. 3RD RIH - CHEMICAL CUTTER. CUT TUBING AT 9025 FT MD. TOP OF ANCHORS = 9015 FT MD. AT SURFACE - CONFIRMED CU-I-I-ER DETONATION - HEAD SHOWED SIGNS OF SLIGHT ECCENTRALIZATION - A "WASH OUT" HOLE MEASURING 3/4" LONG X 3/16" WIDE WAS FOUND ON ONE SIDE. BUT, CHEMICAL EXPULSION WAS EVIDENT FROM ALL HOLES AROUND CUTTER HEAD. WELL READY FOR CIRC-OUT. 07/21/03 TIO= 0/250/0. (POST CHEM CUT) ClRC OUT WELL. PUMPED 5 BBLS MEOH, 900 BBLS 1% KCL, 151 BBLS DIESEL. 07/22/03 U-TUBE DIESEL & FREEZE PROTECT FLOW LINE WITH 5 BBLS METHANOL & 45 BBLS CRUDE. TIO=500/500/50. BP EXPLORATION Page 1~ Operations Summary Report Legal Well Name: 15-08 Common Well Name: 15-08C Spud Date: 9/16/1984 Event Name: REENTER+COMPLETE Start: 7/28/2003 End: 8/10/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/10/2003 Rig Name: NABORS 2ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 7/28/2003 11:00 - 12:00 1.00 MOB P PRE Prepare for rig move from 15-23 to 15-08. 12:00 - 15:30 3.50 MOB P PRE Move shop, sub base, pits, and camp to 15-08C. MIRU. 15:30 - 20:30 5.00 RIGU P PRE Spot sub structure, pit module, and shop. Rig up on 15-08 location. 20:30 - 21:00 0.50 RIGU P PRE ACCEPT rig at 20:30 hrs, 07-28-2003. Pre spud safety and environmental meeting. 21:00 - 21:30 0.50 WHSUR P DECOMP Install secondary annulus valve. 21:30 - 22:30 1.00 WHSUR P DECOMP Pull BPV with DSM lubricator. ,22:30 - 23:00 0.50 WHSUR P DECOMP PJU circulating lines and test to 3,500 psi. '23:00 - 00:00 1.00 WHSUR P DECOMP PJSM. Open well and monitor pressures. SITP 470 psi 'SICP 500 psi. 7/29/2003 00:00 - 04:45 4.75 WHSUR P DECOMP Circulate 9.8 ppg brine at 2 bpm and 500 psi down to tubing cut at 9,025'. Increase rate to 3 bpm and circulate 9.8 ppg around to surface. 04:45 - 05:15 0.50 WHSUR P DECOMP Shut down and monitor well. No flow. Confirm 0 psi on tubing and annulus. 05:15 - 06:00 0.75 WHSUR P ; DECOMP Blow down lines. RJU and install FMC TWC. Test from below to 1,000 psi. 06:00 - 08:00 2.00 WHSUR P DECOMP Blow down surface equipment. IUD lines. N/D tree and adapter flange. 08:00 - 09:30 1.50 BOPSUR P DECOMP N/U BOPE 09:30 - 14:00 4.50 BOPSUR P DECOMP PJU test equipment. Test BOPE and all related valves to 250 psi Iow and 3,500 psi high. Witness of test by John Crisp of the AOGCC. 14:00- 14:30 0.50 BOPSUrq P DECOMP L/D test joint. 14:30 - 16:00 1.50 BOPSUF; P DECOMP DSM PJU to pull TVVC with lubricator. Encounter difficulties. Pump on TWC to clear debris. Pull TWC. IUD lubricator. 16:00 - 17:30 1.50 PULL P DECOMP PJSM. BOLDS. Unseat hanger with 125K. Pull to 175K up weight. Relax and reseat hanger. Pull up to 195K. Tubing parted; tubing hanging weight 65K. Monitor well. Check derrick and crown sheaves. O.K. 17:30 - 19:00 1.50 PULL P DECOMP Pull hanger to rig floor. L/D hanger. PJU 4 1/2" tubing equipment. R/U Camco control line spooling unit. 19:00 - 22:00 3.00 PULL P DECOMP L/D 4 1/2", 12.6#, L-80, BTRS tubing. 22:00 - 22:30 0.50 PULL P DECOMP L/D SSSV. IUD control line spooler. Recovered 53 SS bands. 22:30 - 23:30 1.00 PULL P DECOMP L/D 4 1/2" tubing to 4 1/2" X 3 1/2" crossover. C/O handling equipment. L/D 3 1/2", 9.2g, L-80, TDS tubing. String parted at pin end of #5 GLM (uppermost GLM). Lower pup joint(9.86'), with coupling, remains in the hole. Total recovery: 75 joints 4 1/2", 12.6, L-80 tubing 1 SSSV and 53 SS control line bands 2 joints 3 1/2", 9.2#, L-80 tubing 1 3 1/2" pup joint (9.93') 1 GLM Top offish at 3,181'. 23:30- 00:00 0.50 PULL P DECOMP IUD tubing equipment. 7/30/2003 00:00 - 02:30 2.50 BOPSUI; P DECOMP Clear rig floor. Test lower rams and Hydril to 250 psi Iow and 3,500 psi high. Install wear bushing. 02:30 - 04:00 1.50 FISH P DECOMP P/U Baker O/S with 4 1/4" grapple, bumper sub, and 9 - 6 1/2" Printed: 811112003 11:00:05 AM BP EXPLORATION Page 2 ~ Operations Summary Report Legal Well Name: 15-08 Common Well Name: 15-08C Spud Date: 9/16/1984 Event Name: REENTER+COMPLETE Start: 7/28/2003 End: 8/10/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/10/2003 Rig Name: NABORS 2ES Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 7~30~2003 02:30 - 04:00 1.50 FISH ~ DECOMP drill collars to 290'. 04:00 - 06:30 2.50 FISH ~ DECOMP RIH P/U 4" HT40 drill pipe from 290' to 3,153'. P/U weight 90K, S/O weight 90K. 06:30 - 08:30 2.00 FISH ~ DECOMP Wash down to fish at 4 bpm and 150 psi. Engage fish at 3,187'. Work pipe to 250K up weight (160K overpull)- 50K down weight. Gained 5' tubing movement. Tubing parted while working pipe. Up weight 90K. Monitor well bore. 08:30 - 10:00 1.50 FISH P DECOMP Inspect derrick and top drive. POOH from 3,187' to 290'. 10:00 - 11:00 1.00 FISH P DECOMP ¢/0 handling equipment. POOH from 290' with BHA. Break down O/S tool. Recover 1 tubing collar. 11:00 - 12:00 1.00 FISH P DECOMP M/U O/S BHA #2 to 293'. 12:00 - 13:00 1.00 FISH P DECOMP RIH with drill pipe from 293' to 3,187'. Up weight 90K, Down weight 95K. Engage fish at 3,187'. 13:00 - 15:30 2.50 FISH P DECOMP Space out for lubricator. PJSM. R/U lubricator and 'Y-block' side door sub. PJU SWS. 15:30 - 18:30 3.00 FISH P DECOMP SWS RIH with 2 3/8" chemical cutter and CCL. Chem cut tubing at 8,797'. SWS POOH and L/D Chemical cutter. NOTE: SWS encountered tight spot at crossover above drill collars. Pulled free. Lower section of chem cutter missing at surface. Approximately 24" in length X 2 3/8" o.d. 18:30 - 19:30 1.00 FISH P DECOMP P/U and flex pipe. Work to 210K P/U weight. Pipe parted. Hanging weight 140K. PJD SWS. PJD side door sub and lubricator. 19:30 - 21:00 1.50 FISH P DECOMP POOH with drill pipe from 3,187' to 293'. 21:00 - 22:00 1.00 FISH P DECOMP L/D fishing assembly from 293' to 16'. Break out fish and L/D. 22:00 - 00:00 2.00 FISH P DECOMP PJU 3 1/2" tubing equipment. L/D 3 1/2" tubing from 5,596' to 4,049'. 7/31/2003 00:00 03:30 3.50 FISH P DECOMP :L/D 3 1/2", 9.2#, L-80, TDS tubing. Recovered 177joints 3 1/2" !tbg, 2 GLM, 5.33' cutoff section of pup joint (9.90') above GLM #2. TOF calculated at 8,797.69'. 03:30 - 05:00 1.50 FISH P DECOMP PJD tubing handling equipment. Clear rig floor. 05:00 - 06:00 1.00 CASE P TIEB1 R/U SWS. PJSM. 06:00 - 10:00 4.00 CASE P TIEB1 SWS RIH with CCL, Junk basket, 6.15" Gauge ring. Clear to tubing stump. POH. RIH with HES 7" EZSV and set at 8,797' (WLM). POH. 10:00 - 10:30 0.50 CASE P TIEB1 PJD SWS 10:30 - 12:00 1.50 CASE P TIEB1 M/U HES 9 5/8" R'i-rs. RIH to 2,749' and set. 12:00 - 13:00 1.00 CASE P TIEB1 Pressure test 9 5/8" casing to surface to 3,500 psi for 30 minutes. Record test. 13:00 - 14:00 1.00 CASE P TIEB1 POH with drill pipe from 2,749' to 43'. 14:00 - 14:30 0.50 CASE P TIEB1 L/D RTTS. Clear rig floor. 14:30 - 16:00 1.50 CASE P TIEB1 PJSM. M/U polish mill. RIH with drill pipe to 2,903'. 16:00 - 18:30 2.50 CASE P TIEB1 P/U drill pipe from 2,903'. Tag Tie-back receptacle at 7,260'. 18:30 - 19:00 0.50 CASE P TIEB1 Polish TBR from 7,260' to 7,266' at 4 bpm and 230 psi. Up weight 138K, Down weight 136K, Rot 140K. Monitor well. 19:00 - 21:30 2.50 CASE P TIEB1 POOH with drill pipe from 7,260' to 9'. Drop rabbit at 3,400'. Brass indicators confirm full insertion of polish mill into TBR. L/D mill. 21:30 - 22:30 1.00 CASE P TIEB1 C/O top rams to 7". 22:30 - 23:00 0.50 CASE P TIEB1 Pull wear bushing. PJU test joint. Test 7" rams to 250 psi Iow and 3,500 psi high. R/D test joint. Set wear bushing. 23:00 - 00:00 1.00 CASE P TIEB1 PJU 7" liner equipment. 8/1/2003 00:00 - 00:30 0.50 CASE P TIEB1 PJSM. PJU to run 7", 26~, L-80, BTC-M liner. Printed: 8111/2003 11:00:05 AM BP EXPLORATION Page 3 ~ Operations Summary Report Legal Well Name: 15-08 Common Well Name: 15-08C Spud Date: 9/16/1984 Event Name: REENTER+COMPLETE Start: 7/28/2003 End: 8/10~2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/10/2003 Rig Name: NABORS 2ES Rig Number: Date From-To Hours Task Code NPT Phase Description of Operations 8/1/2003 00:30 - 02:30 2.00 CASE ~ TIEB1 P/U Seal assembly and casing pup joint. Unwrap seals and discover upper set of seals damaged. L/D assembly and hot-shot for redress. Cut and slip drilling line. Service top drive. Redressed seal assembly returned at 02:30. 02:30 - 09:00 6.50 CASE ~ TIEB1 P/U seal assembly and M/U 7", 26~, L-80, BTC-M liner to 4,729'. Ran a total of 112 joints 7", 26#, L-80, BTC-M liner. Average M/U torque 8,000 fi-lbs. Installed a total of 55 RH turbolators, every other joint. Allowed to free float. Made up liner connections with BOL2000 thread compound. 09:00 - 09:30 0.50 CASE P TIEB1 Circulate one liner volume at 4,729' at 6 bpm and 200 psi. 09:30 - 10:30 1.00 CASE P TIEB1 RIH with drill pipe from 4,279' to 7,249'. 10:30 - 11:00 0.50 CASE P TIEB1 M/U rotary cement head and manifold. 11:00 - 12:00 1.00 CASE P TIEB1 CBU at 6 bpm and 680 psi. 12:00 - 14:00 2.00 CEMT P TIEB1 PJSM. Dowell pump 5 bbl water and test lines to 4,500 psi. Pump 5 bbl 8.4 ppg CW100, 30 bb110.8 ppg MudPUSH. Mix-on-the-fly and pump 88 bb113.5 ppg lead °G' cement, followed by 46 bbl 15.8 ppg tail 'G' cement. Shut down. Drop dart. Dowell displaced plug with 5 bbl water. Turn over to rig and displace with 198.8 bbl; bump plug. ClP at 13:40 hours 8/01/2003. Set liner hanger with 2,500 psi. Increase to 4,000 psi to set liner top packer. Rotate 15 RH turns to release running tool. Increase pressure to 1,000 psi and unsting. 14:00 - 15:00 1.00 CEMT P TIEB1 Circulate at 13 bpm and 2,530 psi. Trace cement (~1 bbl) back to surface. Pump dry job, L/D rotary cement head, BID surface equipment. 115:00 - 16:30 1.50 CEMT P TIEB1 POOH from 2,651'. L/D running tool. 16:30- 18:30 2.00 BOPSUF P TIEB1 C/O7" rams to 3 1/2"X 6" VBR. Pullwear bushing. Install test plug and test 3 1/2" X 6" rams to 250 psi Iow and 3,500 psi high. P. JD test equipment. Install wear bushing. 18:30-21:00 2.50 DRILL P TIEB1 PJSM. M/U BHA#1 to 1,064'. 21:00 - 00:00 3.00 DRILL P TIEB1 P/U drill pipe from 1,064' to 5,268'. 8/2/2003 00:00 - 01:00 1.00 DRILL P TIEB1 RIH with drill pipe from derrick from 5,268' to 7,100'. 01:00 - 01:30 0.50 DRILL P TIEB1 Wash down to 7,229'. 01:30 - 02:30 1.00 EVAL P TIEB1 FUU and pressure test 7" scab liner to 3,500 psi for 30 minutes. Record test. 02:30 - 06:30 4.00 DRILL P TIEB1 Drill cement and float equipment from 7,229' to 7,233°. 06:30 - 07:30 1.00 DRILL P TIEB1 RIH from 7,233' to 8,790' (DPM). Tag EZSV. Set down 30K to verify. 07:30 - 08:00 0.50 EVAL P TIEB1 Test casing to 3,500 psi for 15 minutes. Good test. 08:00 - 10:00 2.00 DRILL P TIEB1 Displace well to 8.4 ppg QuikDril milling fluid at 6 1/2 bpm and 1,420 psi. P/U weight 180K, S/O weight 155K, Rot weight 165K. Clean out from under shakers. Pump dry job. 10:00 - 13:00 3.00 DRILL P TIEB1 POOH from 8,790' to 1,064' 13:00 - 14:30 1.50 DRILL P TIEB1 POOH with BHA from 1,064'. Clean out boot baskets; some cement. Clear rig floor. 14:30 - 16:30 2.00 STVVHIP P WEXIT P/U BHA components. M/U 7" Whipstock and BHA to 1,123'. Surface test MWD at 105 spm and 700 psi. 16:30 - 21:30 5.00 STWHIP P WEXIT RIH from 1,123' to 8,686'. 21:30 - 22:00 0.50 STWHIP P WEXIT Fill pipe. P/U weight165K, S/O weight 160K. Orient whip stock .to 61 degrees LHS at 105 spm and 1,430 psi. Tag EZSV at Printed: 8111/2003 11:00:05 AM BP EXPLORATION Page 4 Operations Summary Report Legal Well Name: 15-08 Common Well Name: 15-08C Spud Date: 9/16/1984 Event Name: REENTER+COMPLETE Start: 7/28/2003 End: 8/10/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/10/2003 Rig Name: NABORS 2ES Rig Number: Date From ~To Hours Task Code NPT Phase Description of Operations 81212003 21:30 - 22:00 0.50 STWHIP = WEXlT 8,790'. Set down 20K and set anchor. P/U to 10K overpull to verify. Set down with 35K to shear bolt. 22:00 - 00:00 2.00 STWHIP = WEXlT Mill 7" window from 8,772' to 8,780'. TOW at 8,772' BOW at 8,784'. 81312003 00:00 - 03:00 3.00 STWHIP P WEXlT Mill window in 7" from 8,780' to 8,784'. Pump Bara Lift sweep. Starter mill drilled to 8,798', giving ~7 feet of gauge hole below bottom of window. P/U weight 165K, S/O 160K, Rot weight 160K. Torque off 3K, Torque on 5 - 6K 03:00 - 04:30 1.50 STWHIP P WEXlT Pump Bara Lift sweep. Work window and CBU at 113 spm and 1,680 psi. At present, only .,.25 lbs. shavings recovered. 04:30 - 05:00 0.50 STWHIP P WEXlT Pull into casing. Conduct FIT at 8,784' MD, 8,345' tvd with 8.5 ppg mud and 650 psi (10.0 ppg EMW). 05:00 - 07:30 2.50 STWHIP P WEXlT Pump dry job. Pull out of hole from 8,798' to 1,123'. 07:30 - 09:00 1.50 STWHIP P WEXlT L/D BHA. Mills full gauge. Clear rig floor. 09:00 - 10:00 1.00 STVVHIP P WEXlT Pull wear bushing. Flush BOPE. Install wear bushing. 10:00 - 11:00 1.00 DRILL P PROD1 P/U 6 1/8" drilling BHA to 229'. Surface check MWD. 11:00 - 13:30 2.50 DRILL P PROD1 RIH with drill pipe from 229' to 8,630'. Fill pipe at 5,835'. 13:30 - 15:00 1.50 DRILL P PROD1 Cut and slip 77' drilling line. Service top drive. 15:00 - 16:00 1.00 DRILL P PROD1 MAD pass from 8,650' to 8,720'. Orient at 60 deg. LHS to slide through window. No problems at window. MAD pass to 8,772'. Tag undergauge hole at 8,789'. 16:00 - 00:00 8.00 DRILL P PROD1 Ream undergauge hole from 8,789' to 8,798'. ...... Directional drill 6 1/8" h"ole from 8,7981'to 8,881'. ART = 0.17 hrs, AST = 3.21 hrs, ADT = 3.38 ~,"' P/U weight 165K, S/O weight 155K,~eight 160K. Slide 83' (8,798'- 8,881') J Slide at TF 30 to 60.,~L-.,RS to initiate LH turn and build Flow rate 275~;~e/~~,000 psi, off btm 1,850 psi. ~cult to maintain differential. Drilling off a couple feet at a j time, then stacking. Once window was cleared, attempted rotation. Erratic torque. Decided to assess bit/BHA condition. J POOH. 8/4/2003 00:00 - 03:00 3.00 DRILL P PROD1 Monitor well. Drop dart, pump dry job. POOH with drill pipe j from 8,881' to 229'. =03:00 - 04:00 1.00~ DRILLj PROD1 Stand back collars. L/D MWD and motor. Break bit. Bit in gauge and good condition. Scarring evident on shirttails. Also, on motor housing stabilizer blades. Motor being sent in for · ~250 assessment. . ~ BOPSUF P PROD1 Pull wear bushing, and install test plug. Test BOPE and all related valves to 250 psi Iow and 3,500 psi high. Witness of test waived by Chuck Scheve of the AOGCC. Pull test plug and install wear bushing. 06:30 - 07:30 1.00 DRILL P PROD1 P/U BHA to 229'. Surface check MWD. Printed: 8111/2003 11:00:05 AM 07/22/03 Schlumberger NO. 2916 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Camm At'tn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 9950t Field: Prudhoe Bay Endicott Well Job # Log Description Date Blueline Color Prints CD Z-39 C'~-~' PROD LOG W/DEFT 07119103 D.S. 2-14 "~<~'~)-'L"~ \ ~ RST GRAVEL PACK 07117103 N-I~B ~Q~ -. ~_~ SBHP SURVEY 07/16/03 D.S. ~5-08B ~ ~ ~' I~ RST G~VEL PACK 071~4/03 K-317B ~[ ' I ~ ( ~ PROD PROFILE W/DEFT 06~09~03 D.S. 5-04A ~ (0~~ MEM PROD PROFILE 06114103 D-13A ~~1 MEM PROD PROFILE 06123103 D.S. S-02A ~[ -~ L~ ~' MEM PROD PROFILE 06110/03 ,- . 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 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571 A'FI'N: Beth Received bY:~~ .~..,~ _i~.~:~ tL~ ~ STATE OF ALASKA t~r' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1645' SNL, 1378' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 439' SNL, 2161' EWL, SEC. 22, T11N, R14E, UM At effective depth 1557' NSL, 1225' EWL, SEC. 15, T11N, R14E, UM At total depth 1557' NSL, 1225' EWL, SEC. 15, T11N, R14E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 677321, Y = 5959869 X = 678073, Y = 5961092 X = 677087, Y = 5963066 X = 677087, Y = 5963066 6. Datum Elevation (DF or KB) KBE = 69' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 15-08B 9. Permit Num..bar 197-182" 10. APl Number 50- 029-21180-02 / 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12628 feet true vertical 8772 feet Effective depth: measured 12628 feet true vertical 8772 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 90' 20" Surface 2539' 13-3/8" Intermediate 7448' 9-5/8" Production Liner 2555' 7" Liner 957' 4-1/2" Liner 1982' 2-3/8" Perforation depth: measured true vertical Cemented MD TVD 370 sx Permafrost II 1938 sx PF 'E', 400 sx PF 'C' 500 sx Class 'G', 300 sx PF 'C' 90' 90' 2539' 2539' 7448' 7194' 534 sx Class 'G' Uncemented Slotted Liner ,,"'" Uncemented Slotted Liner .--' Perf'd & Slotted: 9854'- 12438' 7271'- 9825' 7079'- 8796' 9768' - 10725' 8794' - 8761' .,.1.0494' - 1~476' 8766' - 8769' JUL. Perf'd & Slotted: 8796'- 8767' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 3103'; 3-1/2", 9.2#, L-80 3103' - 9258'~{"~.~t~.I~", 12.6#, L-80 9258' - 9276'; 3-1/2", 9.2#, L-80 9276' - 9456' Packers and SSSV (type and measured depth) 7" packer at 9761'; 7" x 4-1/2" Baker 'SABL-3' packer at 9270'; 4-1/2" Camco TRDP-4A SSSV Nipple at 2026' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 'i 4. Estimated date for commencing operation July 10, 2003 16. If proposal was verbally approved Name of approver Date Approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Phil Sm~ith. 564-4897 Prepared By Name/Number. Terrie Hubble. 564-4628 . I-i 7. I hereby certify that the fore~,~ng is true and correct to the best of my knowledge I 'S gned Lowell Oran9,., ' .~~.~ /~.~~'~' Title Senior Drilling Engineer , , Date '7--2 O~ IJ · ': : · .....· ........... · .......... ' ...... · .................. ' ............... 'cQ..m..m,.,msl,o.,,,~, Us~..,,O..! .......... . .......... , ~Conditions of Approval: Notify Commission s..o representative may witness ......... ~ Approva~ No .~0 ~- ,,ug integrity X BoP Test ~ Location clearance ' i 'r '! I Mechanical Integrity Test~~ Subsequent form required 10- ~'O~ T"-P~.~[- g (~ P ~- ~1~ '~ ~'~O~ i~ ,~ ~17/_~/~'~''' ., Approved by order of the CommissiOnForm 10-403 ~0~6~,.5,/88 jUL/ j; ~-'=~~J~~~'~'~L~ f, Commissioner 2o03sDu~tr~it i~ Tri~31icate 0 bp G To: Winton Aubert - AOGCC Date: June 30, 2003 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: Revised DS15-08B Application for Sundry Approval - P&A for Sidetrack Operations APl # 50-029-21180-02 Approval is requested for the proposed P&A of PBU well DS15-08B. The original 15-08 well was completed in 1984 as the first high angle well to be drilled in the Prudhoe Bay Unit. 15-08A was a horizontal zone lA rig sidetrack drilled in 1993. In May 1996 the well began producing water. A leak detect log found a cretaceous leak in the 9-5/8" casing at 5893'. 15-08A was waivered to produce, but the well would not flow when brought online. 15-08B was drilled in November 1997 and completed with a 2 3/8" slotted liner. In early 2000 the well began making water again, and a leak detect log found that the cretaceous leak had broken through the tubing. Several tubing patches have been set, the latest in January 2002, and all failed. 15-08B ,.--. no longer has enough IOR to justify repairs or diagnostics, hence the sidetrack. The DS15-08C sidetrack is currently scheduled for Nabors 2ES beginning approximately July 26th 2003, after completing the 15-23A sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Scope Pre-ri~ Operations: In preparation for the sidetrack the following pre-work has been performed: v' PPOT-IC passed at 5000 psi and LbS cycled on 6/2/03 -"" ," Passed an outer annulus pressure test to 3000 psi on 6/8/03 Remaining Work: 1. Pull the 3 Y2" Eclipse retrievable tubing patch at 5474' MD (set in January 2002). 2. Drift the tubing and liner to as deep as possible (-65° inclination at 9300' MD, building to horizontal) for CT P&A. 3. RU Schlumberger e-line. Run RST log in gravel pack mode to determine top of fill in the tubing annulus on top of the packer at 9270'. 4. R/U coil tubing ,u, nit. FI,uid pack the tubing annulus and tu~d lay cement abandonment plug fro~ PBTD at 12,,4,38 to ,5,0 above the/pr~uction packer MD/t'32.8/b~ls). Dress the top of cement at 9220' 5. Drift the 4 Y2 X 3 Y~' tubing and~g.,tl~e top of the cemeh~.confirm the tubing is clear to the required.~.~. cut depth of approximately 91207-" 6. R/U E-line.~Jlst with chemical cutter and cut the 3 Y~" tub, jng at -9120' MD. POOH 7. Pressure~.,~__Hhe well (combo IA x tubing) to 3500 psi '- 8. Circulate"t~F~~ well to clean seawater. Note final shut-in pressure for brine weight calculation. Freeze protect to 2,100' with diesel. Set BPV with lubricator. DS15-08B Application for Sundry Ri.q 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Operations: MIRU Nabors 2ES Circulate out freeze protection and displace well to kill-weight brine. Set TWC. Nipple down tree. Nipple up and test BOPE to 3,500psi. Puli the 4Y2" X 3Y2" tubing from the chemical cut at +_9120' MD. PU and RIH with 7-7/16" polishing mill. Polish 7" TBE at 7259' MD. Run and cement a 7" scab liner from 2500' MD to top of existing 7" liner. RIH with 6 1/8" bit and watermelon mill. Test the casing to 3500 psi and drill the scab liner shoe track. RIH to top of cut tubing fish. Displace hole over to 8.4 ppg milling/drilling fluid. PT casing to 3500 psi for 30 min. POOH. P/U and Rill with 7" Baker bottom-trip anchor whipstock assembly. Orient whip stock 80° left of high side and set on the cut tubing stub. Mill window in 7" casing at 9100' MD. Pull up into 7" casing and conduct an FIT to 10.0ppg EMW. POOH. RIH with 6 1/8" Dir/GR/Neu/Den assembly. Kick off and drill the 6 1/8" build section Trip for bit, drop NEU/DEN and continue drilling to TD of approximately 11,530' MD in Zone lA, according to the directional plan. Short trip, spot liner running pill, POOH. Run and cement a 4 Y~", 12.6#, L-80 production liner. POOH. R/U and RIH with Halliburton 2 Y2" dpc perforating guns. Perforate per Halliburton recommendation. Run a 4 1/2", 12.6#, 13Cr-80 completion, stinging into the 4 1/2" liner tie back. Set packer and test the tubing and annulus to 3500psi for 30 minutes. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Freeze protect the well to ~2100' and secure the well. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. Estimated Pre-rig Start Date: Estimated Spud Date: Phil Smith Operations Drilling Engineer 564-4897 07/10/O3 07/26/03 DS15-08B Application for Sundry TI~-E = FMC G EN 3 WELLHEAD = FMC SAFETY NOTES: T X IA COMM @ GLM ~2. IA x 151-08B KB. ~ = 71' PSI. W~L MAY ~T BECAPABLETO ~S ~ ~EIA. ~N NIP ~ 9~4' IS ~D U~ ~S N~ ~ 9~8' F~ . BFq= . I I .... K~ = 5~0'm ~P. 7~ ~ 9413, & ~ ~ ~54, M~ Angb = 96 ~ 11162' m DaumMD= 9m8' ~ -- -- ~ 202~ ~4-1/2" CA~OT~P~A S~V NIP, ID= 3.81~ D~um ~D = 8~0' SS m , LI~ ~N~S ~ 3~78 3~78 0 Minimum ID = 1.75" ~ ~74' '2 54~ ~ 0 ~G Eclipse patch set across GLM ~2 3 7179 7015 45 ~G 4 8802 ~ 16 ~G TG 4-1~"~G, 12.6~,L~0,0.0152bpf, ID=3.9~" ~ 3103' ~ , , ~8987 ~07 44 .~G H~ ~ , ~TA. 2 PATC~D ~ T~ ~ · 1/Z' T~ 3103' I PE~TI~ SUM~ I I REF L~: DLL ON 10/20~3 9-5~" ~OW ~ 7448' AN~EATT~ ~RF: ~ ~ 9~1' ~te:R~erto~oductbn~forhist~i~l~rfdata , ~~ 9227' , H 3-1/2"PA~SWSNIRID=2.813" 2-3/8" ' 10~5-12438 D~D 11/23~7 ~ ~ ~ A / / W/~l/Z'K-22AmHm i 2-1/2" 4 9951-10120 O 11/23~7 ~ ~ ~ ',~-- . ~ 2-1/2" 4 10150-10300 O 11/23~7 N ~~~ I 927* 2-1/2" 4 10~0-1~71 O 11/23~7 ~ ~~1 0~8' ~3-~/2" P~ SWS ~1~, I~= 2.8~3" ~ I~IIZ'~G'O'~'L'O0'0'0087bpf'ID=2'~2" ~ 9258' Y ~ 5 I' ~ X ~ ~' ~ 3-1/2"mWLEG ' ' ''' ~ /~'gT'~l~ ~I/Z L~, 12.~,L-80, .0152 b~, ID= 3.9~' H 98~ ~k , , . ~ [2-3/~' L~ ~ANK 1' 4.6~ ~4S 0.00~7 ~f, ID = 1.99E' H 10495' [ ~. ~ , , , , , , . , ~ ~ I~°~°M°F2'3/°''L~'~°~m H 10~S' I IbOWm ~ 2 3/,' mEml~ H 124~' I I 2-3/8" L~, 4.7~ FL-4S, .~387 ~f, ID = 1.~5" ~ 1~71' } I H 202.' I ~TE R~ BY ~T$ ~ ~ BY C~~ PR~EBAY U~ 1984 OR~I~LCO~I~ 0~2~03 J~/~ $AF~ ~ ~BI~ W~L: 15-08B 10~ 1/~ CO~~ ~ PE~ No: 1971820 11~2/97 SID~CK C~ON ~ AR No: ~-029-21180-02 12~4/~ $~-Isl CO~T~ TO ~AS I SEC22, T11N, R14~ ~50.67 F~ & 3719.~' ~L 01~9/01 , S~ FINAL , ~04~2/02 ~ R~P CO~TI~S BP ~plorat~n (Al~ka) PERFORATION SUMMARY REF LOG: DLL ON 10/20/93 ANGLEATTOP PERF: 95 @ 9951' Note: Refer to R'oductbn DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SL 9854 - 10725 SLTD 11/23/97 2-3/8" SL 10496 - 10585 SLTD 11/23/97 2-3/8" 10585- 12438 DRLD 11/23/97 2-1/2" 4 9951 - 10120 O 11/23/97 2-1/2" 4 10150 - 10300 O 11/23/97 2-1/2" 4 10440- 10471 O 11/23/97 DATE REV BY COIVlVIENTS DATE REV BY COMI~r_NTS 1984 ORIGINAL COIVPLETION 03/22/03 JIVP/KK SAFETY NOTE REVISION 10/21/93 CO k, PLETK~ 11/22/97 SIDETRACK COMPLETION 12/04/00 SIS-Isl CONVERTE) TO CANVAS 01/29/01 SIS-IVID FINAL .04/02/02 RN/TP CORRB3TIONS ,"TREE= · FMC GEN 3 WELLHEAD = FMC ACTUATOR = AXELSON ELEV: 71 BF. ELEV = ~ = 5800' Max Angle = Datum MD = Datum TVD = 8800' SS ,I 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2539' 26# L-80 BTC Sw cab Liner top Id 2500' 15-08C PROPOSED il'" SAFETY NOTES: 2100' Id4-1/2" x NIP, ID = 3.813" GAS LIFT MANDRELS I TOP OF 7" LNR 7259' I 14-1/2"TBG, 12.6#, 13-Cr, 0.0152bpf, ID=3.958"l--~ 8954' I 8880, I~ 8900, I--I s~30, H 8940, H s950. H 9100, I~ 4 1/2" X Nipple 3.813" ID 7" x 4 1/2" Baker S-3 Packer 4 1/2" X Nipple 3.813" ID 4 1/2" XN Nipple, 3.725" ID Top of 4 1/2" Liner 7" Top of Window 13 1/2" Tubing Cut I--~ 9120' I IT°p°f15'°7BAband°nmentcmt H ~220' I PERFORATION SUMMARY REF LOG: DLL ON 10/20/93 ANGLEATTOP PEP, F: 95 @ 9951' F~te: Refer to Product~n DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I-t 12627' I DATE REV BY COMMENTS DATE REV BY COMMENTS 1984 ORIGINAL COMPLETION 03/22/03 JMP/KK SAFETY NOTE REVISION 10/21/93 COMPLETION 06/24/03 PGS Proposed Sidetrack , 11/22/97 SIDETRACK COMPLETION 12/04/00 SIS-Isl CONVERTED TO CANVAS , 01/29/01 SIS-MD FINAL 04/02/02 RN/TP CORRECTIONS ~UDHOE BAY UNIT WELL: 15-08C PEP, M~ I'~: 1971820 APl I~: 50-029-21180-03 SEC 22, T11N, R14E, 4050.67' FEL & 3719.98' FNL BP Exploration (Alaska) '~-~" STATE OF ALASKA ~"' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Tubing Patch Pull tubing _ Alter casing _ Repair well _ Perforate _ Other_X Tubin~l Patch 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1643' FNL, 3898' FEL, Sec. 22, T11 N, R14E, UM At top of productive interval 432' FNL, 2164' FEL, Sec. 22, T11N, R14E, UM At effective depth 3716' FNL, 3897' FEL, Sec. 15, T11N, R14E, UM At total depth 3720' FNL, 4051' FEL, Sec. 15, T11 N, R14E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 677321, 5959869) (asp's 678074, 5961101) (asp's 677243, 5963076) (asp's 677088, 5963066) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-08B 9. Permit number / approval number 197-1820 10. APl number 50-029-21180-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 90' Surface 2468' Production 7377' Liner 2566' Slotted Liner 2708' 12627 feet Plugs (measured) 8772 feet 12471 feet Junk (measured) 8769 feet PBTD tagged (11/22/1997) @ 12471' MD Size Cemented Measured Depth True Vertical Depth 20" 370 sx PF II 90' 90' 13-3/8" 1938 sx PF E, 400 sx 2539' 2539' PFC 9-5/8" 500 sx 'G', 300 sx PFC 7448' 7194' 7" 534 sx Class 'G' 7259' - 9825' 7071' - 8796' 4-1/2"/2-3/8" Uncemented 9768'- 12476' 8794'- 8769' Perforation depth: measured true vertical 'ubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 9951'-10120', 10150'-10300', 10440'-10471', 4-1/2" Slotted Liner 9854'-10725'. 2-3/8" Pre-Drilled Liner 10585'-12438'. Open Perfs 8791'-8783', 8782'-8772', 8767'-8766', 4-1/2" Slotted Liner 8796'-8760'. 2-3/8" Pre-Drilled Liner 8759'-8696'. 4-1/2", 12.6# L-80 f/0'-3103', 3-1/2", 9.3 L-80 f/3103'-9258', 4-1/2", 12.6# L-80 f/9258'-9276', 3-1/2", 9.3# L-80 f/9276'-9456'. 3-1/2" Tubing Tail @ 9456'. 3-1/2" Tubing Patch 5475'-5507' 7"x4-1/2" BAKERSABL-3 PKR @ 9270'MD&7" PKR @ 9761'MD. ~-.~?'!~--._~' ~B~._~'~,,:~L~ 4-1/2" Camco TRDP-4A SSSV Nipple ID = 3.812 ~ 2026' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/01/2002 Subsequent to operation 01/12/2002 Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In Well Shut-In Casing Pressure- ~'UD~ng Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil__X Gas__ Suspended__ Service 17. I hereby cerJify that the foregoing is true and correct to the best of my knowledge. Z. Sc~hno~r~l'~ ,l~Z~,~.~J. Title: TechnicalAssistant Date January 18, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 05/28/2001 06/29/2001 08/06/2001 09/01/2001 09/06/2001 09/07/2001 09/09/2001 10/01/2001 10/04/2001 10/12/2001 10/19/2001 10/25/2001 10/26/2001 12/08/2001 01/03/2002 01/07/2002 01/1 O/2OO2 01/1 2/2OO2 05/28/01 06/29/01 08/06/01 09/01/01 09/06/01 09/07/01 15-08B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TUBING/CASING PATCH: RIH TO N2 LIFT, WELL BEGAN TO FLOW ANN-COMIVi: LOAD IA WITH 9.8 BRINE ESTALBISH LLR ANN-COMIVi: LOAD IA WITH 9.8 BRINE LEAK DETECTION LOG: TIFL LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG LEAK DETECTION LOG TUBING/CASING PATCH TUBING/CASING PATCH TUBING/CASING PATCH TUBING/CASING PATCH (PRE TBG PATCH) : SECURE WELL : MONITOR TUBING AND CASING LEAK : DRIFT W/ 1.73 TAPERED LIB : DISPLACE TBG & IA : LEAK DETECTION LOG : SECURE WELL : DRIFT TBG/FISH ECLIPSE PKR/BRUSH TBG : PULL ECLIPSE TBG PATCH : DRIFT TBG : B & F FROIVl 5400' TO 5600', DRIFT D-PATCH TUBING/CASING PATCH: STRING SHOTS (PREP F/TBG PATCH) TUBING/CASING PATCH: RETRIEVABLE TUBING PATCH SET TUBING/CASING PATCH: MITIA FOR POST PATCH SET TIFL POST PATCH SET - PASSED EVENT SUMMARY RIH TO 5400' CTM (JUST ABOVE PATCH). WH UP TO 200 PSI, OPEN TO TANKS AND WELL CAME ON WITH-OUT N2. LOADED IA WITH 108 BBLS OF 9.8 BRINE 5 BBLS OF DIESEL. ESTABLISHED LEAK RATE OF 0.4 BPM @ 3000 PSI. LOAD IA WITH 80 BBLS OF 9.8 BRINE & 5 BBLS OF DIESEL TO SECURE WELL. T/I/O =T/I/O =2450/2450/150 IA FL @ 5853'. BLED IA FROM 2450 PSI IN 4 HR AND 15 MINS. IA PRESSURE WOULD NOT GO BELOW 1350 PSI. MONITOR IA PRESSURE FOR 20 MIN IA INCREASED TO 2150 PSI. LEFT WELL SI. FINAL T/I/O = 2350/2350/140 (LOAD & KILL) INITIAL TBG FL @ 8570' (94 BBLS). INITIAL IA FL @ 5860'. R/U HB&R AND STARTED PUMPING 130-DEGREE SEAWATER DOWN THE TBG. IA PRESSURE INCREASED TO 2500 PSI. IA FL REMAINED @ 8570' DURING PUMPING. STARTED TO BLEED IA FROM 2500 PSI TO 320 PSI IN 4.5 HRS. IA FL ROSE FROM 8570' TO 1480'. MONITORED IA PRESSURE FOR 15 MINS, IA PRESSURE INCREASED 230 PSI. PUMPED A TOTAL OF 325 BBLS OF SEAWATER AND 65 BBLS OF DIESEL DOWN THE TBG. THE FLOWLINE IS NOT FREEZE PROTECTED. FINAL WHP's - TIO = 890/1600/140, TUBING FL @ 810', IA FL @ 3207'. TUBING PRESSURE INCREASED 640 PSI, lAP INCREASED 750 PSI FROM YESTERDAY. Page I 09/07/01 09/09/01 10/01/01 10/04/01 10/12/01 1 O/19/O 1 1 O/25/O 1 10/26/01 12/08/01 01/03/02 01/07/02 15-08B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS *** IBP REQUESTED (PATCH IN WELL), THEN MIT-T *** DRIFT TBG & PATCH W/1.73 TAPERED LIB TO 9400' WLMD. -- GIVE WELL BACK TO OPERATOR LOAD TBG W/26BBLS CRUDE & IA W/190 BBLS CRUDE COMPLETED LDL. FOUND TBG LEAK @ TBG PATCH @ 5474'. PUMPED DOWN BACKSIDE; TAKING FLUIDS TO THE FORMATION. LOGGED BASELINE PASS DN; SET DN @ 9282' & LOGGED PUMP-IN PASS UP TO SURFACE. LOAD IA & TBG WIH 488 BBLS KCL, 150 BBLS CRUDE TO KILL WELL. ATTEMPT TO LATCH & PULL ECLISPE PATCH @ 5472' MD. NO LUCK . RDMO. WELL LEFT SHUT IN. RAN 2.80"LIB TO PATCH AT 5454'SLM, PICTURE OF VERY JAGGED/ROUGH CIRCLE. RUN 3 1/2 SUPER GS, BAITED W/3 1/2 GR. LATCH PATCH AT 5454'. PULL TOP SECTION OF PATCH OUT IN ONE RUN. NEXT RUN, PULLED BOTTOM 27" SECTION INCLUDING BOTTOM SLIPS BUT MISSING RUBBER ELEMENTS AND SECTION BELOW ELEMENTS. RAN BRUSH AND RECOVERED TWO RUBBER ELEMENTS AND BOTTOM 1 1/2" OF PATCH. MISSING ONE RUBBER ELEMENT. *** WILL LEAVE WELL SHUT IN AFTER GAUGE RUN MADE TO TD*** ***THE INSIDE OF THE ECLIPSE TBG PACKER WAS SEVERELY ERODED( FLOW CUT), THE OUTSIDE SHOWED NO SIGN OF CORROSION OR DAMAGE.*** DRIFTED TO 9398'SLM W/2.70"DRIFT & BRUSH. DRIFTED TO 9432'SLM W/2.61"DRIFT & BRUSH. TOOLS APPEAR TO BE STOPPING DUE TO DEVIATION/DOGLEG (HAW). ***DRIFTED AFTER FISHING ECLIPSE PACKER, LEFT WELL SI*** BRUSH AND FLUSH FROM 5400' TO 5600' AND RUN DRIFT W/DUMMY PATCH TO 5700' SLM ( NO PROBLEMS ). RDMO / LEFT WELL SHUT IN. SHOT INTERVALS 5404'-5410' & 5472'-5478' WITH TWO 6' STRING SHOTS TO CLEAN PIPE PRIOR TO TUBING PATCH. RDFN. *** JOB IN PROGRESS*** SET 3 1/2" ECLIPSE RETRIEVABLE TUBING PATCH FROM 5475' - 5507' (MID- ELEMENTS). 34.6' OAL W/1.745" MIN ID. BOTH TOP (33.6' OAL) AND BOTTOM (2.67' OAL) ARE PULLED W/3 1/2" GS. NOTIFIED PAD OPER OF STATUS. WELL LEFT SHUT IN. Page 2 15-08B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/10/02 MITIA (FAILED) POST PATCH SET. T/I/O = 1450/0/100 MITIA TO 2000 PSI FAILED FOR POST PATCH SET, IA FL @ 90' (5 BBLS). STARTED PUMPING DIESEL DOWN IA. PUMPED 6 BBLS DIESEL DOWN THE IA, IA PRESSURE STARTING TO CLIMB, RAN OUT OF DIESEL WITH 10 BBLS AWAY @ 1720 PSI. IA PRESSURE DROPPED TO 530 PSI. START PUMPING, WITH 3 BBLS AWAY IA PRESSURE IS AT 1140 PSI. START MONITORING PUMP RATE WITH 10 MIN READINGS UP TO 60 MIN, THE TRI-PLEX WAS PUMPING A RATE OF 1 BBL EVERY 10 MIN @ 1140 PSI SHUT DOWN PUMP AND MONITOR FOR I HOUR. SHOOT IA FL AND TBG FL. PUMPED A TOTAL OF 20 BBLS OF DIESEL. IA FL @ SURFACE AND TBG FL @ 4190'? FINAL WHP's - 1450/580/120. 01/12/O2 TIFL POST PATCH SET PASSED INFLOW. T/I/O = 1260/900/120. TIFL PASSED. (POST PATCH SET). INITIAL IA FL @ 810'. PUT GAS LIFT TO IA TO PUSH FL BELOW 3000'. START OF TIFL WHP's = 1480/2120/120. IA FL @ 3300'. STARTED IA BLEED. BLED IA FROM 2120 PSI TO 300 PSI IN 1.5 HOURS. IA FL ROSE FROM 3300' TO 2757'. IA INFLOWED 543' OR 30.5 BBLS. FINAL WHP's 1220/340/120. FLUIDS PUMPED BBLS 5 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (4 TESTS) 10 METHANOL 20 50/50 METHANOL WATER 122 DIESEL 758 CRUDE 488 KCL WATER 325 SEA WATER 188 9.8 BRINE WATER 1916 TOTAL Page 3 ....... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS'~--~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X (Patch) 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1643' FNL, 3898' FEL, Sec. 22, T11N, R14E, UM At top of productive interval 432' FNL, 2164' FEI_, Sec.22, T11N, R14E, UM At effective depth At total depth 3720' FNL, 4051' FEL, Sec. 15, T11N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 677321, 5959869) (asp's 678074, 5961101) (asp's 677088, 5963066) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 15-08B 9. Permit number / approval number 1 97-182 10. APl number 50-029-21 180-02 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 90' Surface 2468' Production 7377' Liner 2566' Slotted / Pre-drilled Liner 2708' 12627 feet Plugs (measured) 8772 feet 12471 feet Junk (measured) 8769 feet PBTD tagged (11/22/1997) @ 12471' MD. ORIGINAL Size Cemented Measured Depth 20" 370 Sx PF II 90' 1 3-3/8" 1938 Sx PFE &400 Sx PFC 2539' 9-5/8" 500 Sx Class G & 300 Sx PFC 7448' 7" 534 Sx C~ass G 9825' 4-1/2/2-3/8" Uncemented 12476' True vertical Depth 90' 2539' 7194' 8796' 8769' Perforation depth: measured (4-1/2" Slotted Liner f/9854' - 10725'); (Perf intervals @ 9951'- 10120'; 10150'- 10300'; 10440'- 10471'); (2-3/8" Pre-drilled Liner ti 10585' - 12438'). true vertical (4-1/2" Slotted Liner f/8796' - 8760'); (Peal intervals @ 8791' - 8783'; 8782' - 8772'; 8767' - 8766'); Tubing (size, grade, and measured depth) (2-3/8" Pre-drilled Liner f/8759' - 8696'). 4-1/2', 12.6#, L-80 Tbg @ 3103' & 9276' MD; 3-1/2", 9.2#, L-80 Tbg @ 9258' & 9456'MD. 7" PACKER @ 9761' MD; 7' X 4-1/2" BAKER SABL-3 PKR @ 9270' MD. 4-1/2" CAMCO TRDP-4A SSSV NIPPLE 113=-3.812 @ 2026' MD. Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) ¢~'~d"-"'¢¢z ,~,:_. ~ .;¢ ~. ,..~:¢ Oi! ,i~ {~:i~.~: ~i~i ;~;?, { ~:0¢i~ii'~,iSSi0Fi Treatment description including volumes used and final pressure 7-~ :;.i~.-'.i:'_~:,'_~ ~:;:~ 14. Representative Daily Average Production or Injection Data " ':" OiFBbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) - - - Subsequent to operation 1418 14812 29 389 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ %, ~ Title PAl Wellwork Design & Optimization Supervisor Erin Oba Date ~.P~'- ~,)~.,00(~ ~ Prepared by Paul Rauf 263-4990 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE ~. 15-08B .-. DESCRIPTION OF WORK COMPLETED SET TUBING PATCH Date Event Summary 2/18~2000: 5/20/2000: 5/21/2000: RIH & ran LDL. Results: tubing leak @ 5492' MD. MIT tubing - failed. RIH & set 3-1/2" Eclipse Tubing Patch. Top element @ 5474' & BTM element @ 5499'. Placed well BOL & obtained a representative well test. Page 1 AOGCC Geological Materials Inventory PERMIT 97-182 ARCO Log Data Sent Received 8814 ~~SCHLUM GR 11/12/1998 11/13/1998 8815 fl~S~HLUM GR PB1 11/12/1998 11/13/1998 DIR SRVY ~SCHLUM 10644-12528 11/21/1997 12/19/1997 DIR SRVY ~""~CHLUM 10644-12088 PB1 ~ 11/15/1997 12/19/1997 GR-MWD ~ 10727-12628 11/12/1998 11/13/1998 D GR-MWD Cia~' 10754-11811 PB1 11/12/1998 11/13/1998 D PERFORM. LTR ~ SCHLUM 10700-12628 11/21/1997 12/19/1997 PERFORM. LTR LR,"~CHLUM 10700-12155 PB1 11/15/1997 12/19/1997 ~ 10-407 Completion Date )l/)~ )'-/~7 Daily well ops __ Are dry ditch samples required? yes ~ no And received? :-- yes ~ no Was the well cored? yes f no Analysis _description received? Are tests required? yes ~no Received? ~ no Well is in compliance Initial Comments Box Wednesday, October 13, 1999 Page 1 of 1 11 / 12/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AT[N: Sherrie 15 NO. 12050 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562~6~.[~ank ~ ALASKA OIL ^~D GAS OONSERVATION OOMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOgiC 3 0 i997 1 Status of Well Classification of Service Well Oil_X Gas Suspended Abandoned__ Service__ AlasJt(a 0il ~ ~ f~^,,, ,~ .... .... "~, ~Uilll 2 Name of Operator ARCO Alaska, Inc. 97-182 ' 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 50-029-21180-02 4 Location of well at surface ~-- ,7;: :.; ~:~ :'~ -, ! 9 Unit or Lease Name 1645' SNL, 1378' EWL, Sec 22, T11N, R14E, UM! v.: ~ PRUDHOE BAY UNIT At Top Producing interval i~~.~_.~ ' ' ' 10 Welll 5-08BNumber 432' SNL, 2164' EWL, Sec 22, T11 N, R14E, UM. ~ .~, 11 Field and Pool At Total Depth 3720' FNL, 4051' FEL, Sec 15, T11N, R14E, UM.~ ........ PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 58' RKB ADL 28306 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 11/11/97 11/21/97 11/22/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12628' MD / 8701' TVD 12628' MD / 8701' TVD YES_X NO__ 2026' feet MD 1900' feet (approx) 22 Type Electric or Other Legs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP DO'FI'OM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 91.5# H-40 Surf 90' 30,, 370 Sx PF II - 13-3/8" 72# L-80 Surf 2539' 17.5" 1938 Sx PF E & 400 Sx PFC - 9-5/8" 47# L-80 Surf 7448' 12.25" 500 Sx Class G & 300 Sx PFC - 7" 26# 13 CR-80 7271' 9825' 8.5" 534 Sx Class G - 4-1/2" 12.6# L-80 9768' 10725' 8.5" Uncemented (slotted liner) - 2-3/8" 4.6# FL4S 10494' 12476' 2.75" Uncemented (pre perfed liner) - 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Slotted Liner: 4-1/2" Tbg 3103' / 9276' 9270' 9854- 10725' MD; 8796- 8752' TVD. 3-1/2" Tbg 9260'/9456' w/perforation intervals shot at: 9951 - 10120' MD; 8791 - 8783' TVD. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10150 - 10300' MD; 8781 - 8774' TVD. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 10440 - 10471' MD; 8766- 8765' TVD. and: 2-3/8" Pre-Drilled Liner: 10585 - 12438' MD; 8759 - 8696' TVD. 27 PRODUCTION TEST Date First Production 12/18/97 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MC ~ V~A"I'E~- 'C~O~ SIZE I GOR 12/19/97 3.3 TEST PERIOD --I 1150 Flow Tubing Press 'Casing Pressure 'CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (COLT) 305 24 HOUR RATE _X 2570 2956 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 10/24/97 (issued Permit # 97-182). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Sag River Shublik Sadlerochit GEOLOGIC MARKERS MEAS DEPTH 8636' 8693' 8779' TRUE VERT DEPTH 8242' 8281' 8348' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. N/A 31 LIST OF ATTACHMENTS Summary of 15-08B Coil Tubing Wellbore Extension Drilling Operations. 321 hereby ceflify that the foregoing is true and correct to the best of my knowledge Signed ~,ff~ ~-~..,~~f~ ¢~1~ Engineering Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. R ~ C F~ IV ~ D Item 28: If no cores taken, indicate "none". Form 10-407 Naska Oil & Gas Cons. Oommission Anchorage 15-08B DESCRIPTION OF WORK COMPLETED COILED TUBING HORIZONTAL WELLBORE EXTENSION DRILLING 11/10/97: MIRU CTU & PT BOPE. 11/11/97: Loaded wellbore w/Seawater & RIH w/milling BHA. Milled through SWN nipple at 9449' MD, then RIH to tag packoff bushing at 10690' MD. Milled & reamed through bushing, then RIH to tag & mill through the cast iron guide shoe at 10731' MD. Continued drilling openhole extension wellbore to 10741' MD. Swapped well to FIo Pro. POOH circulating well to mud. RIH w/drilling BHA. Drilled 2.75" horizontal extension hole to 10855' MD. 11/12/97: POOH w/BHA. RIH w/drilling BHA. Continued drilling to 11183' MD. 11/13/97: POOH w/BHA. RIH w/drilling BHA. Drilled to 11310' MD & stuck pipe. Circulated Crude to free pipe, then displaced w/FIo Pro & continued drilling horizontally to 11710' MD w/periodic shod trips to sweep hole. 11/14/97: Drilled sticky hole to 11750' MD. Swapped to new FIo Pro & continued drilling to 11825' MD. RIH w/drilling BHA. Drilled to 11855' MD. POOH w/BHA. 11/15/97: Drilled to 12085' MD. POOH w/BHA. Continued drilling hole to 12120' MD. RIH w/drilling BHA & reamed sticky shale section at 11750 - 12085' MD. 11/16~97: Drilled to 12155' MD. POOH w/drilling BHA. Decided to sidetrack hole at 11175' due to 95 degree inclination. RIH w/drilling BHA to 11175' & reamed Iow side trough for sidetrack from 11175' to 11190'. Attempted sidetrack kickoff from 11190' to 11205'; couldn't get weight on bit. POOH to pump cement plug. 11/17/97: RIH w/cement nozzle & pumped 4.5 bbls of Class G cement to spot a cement plug to 11275' MD. PT BOPE. WOC. RIH w/drilling BHA. POOH w/nozzle. 11/18/97: Drilled cement plug from 11190' to 11260', then kicked off drilling 2.75" sidetrack hole to 11300' MD. Backreamed hole smooth & POOH w/BHA. RIH w/drilling BHA & displaced well to new FIo Pro. Drilled to 11555' w/shod trips. 11/19/97: Drilled horizontally to 11943' MD w/periodic backreaming through sticky hole sections. w/drilling BHA & continued drilling to 11970' MD. POOH w/BHA. RIH 11/20/97: Drilled to 12040', backreamed hole, & drilled to 12075'. POOH w/BHA. RIH w/drilling BHA. Drilled to 12290' MD. 11/21/97: Swapped to new FIo Pro & continued drilling to TD at 12627' MD w/periodic shod trips to wipe hole. 11/22/97: Pumped Hi Vis sweep & POOH w/BHA. MU & RIH w/2-3/8" pre-perfed liner assembly displaced w/FIo Pro. Landed BOL at 12476'; could not work liner deeper. Disconnected from TOL at 10494' & POOH w/running tools displacing well to Seawater. RIH w/2-1/2" perforation guns & shot perf intervals in the 4-1/2" liner at: 9951 - 10120' MD (71) 10150- 10300' MD (Z1) 10440- 10471' MD (Z1) Shot perfs at 4 spf at 60/120/240/300 degree phasing. POOH w/guns. ASF. RIH w/nozzle & displaced well to Crude from 10400' MD. 11123197: NDBOPE. NU&PTtree. RDOTU&MOL. Placed the well on initial production & obtained a valid welltest. Survey report Client ................... : ARCO ALASKA INC. Field .................... : PRUDHOE BAY Well ..................... : DS 15-8B API number ............... : 50-029-21180-02 Job nLunber ............... : 40001689 Rig ...................... : NABOR 3S County/State ............. : PRUDHOE BAY State/Country ............ : ALASKA Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference --- Permanent datum .......... : MSL Depth reference .......... : RKB GL above permanent ....... : 71.00 ft KB above permanent ....... : 69.00 ft DF above permanent ....... : 70.00 ft Vertical section origin Latitude (+N/S-) ......... : 2800.80 ft Departure (+E/W-) ........ : 1408.50 ft Platform reference point Latitude (+N/S-) ......... : 70.30 ft Departure (+E/W-) ........ : -148.4444 ft Azimuth from rotary table to target: 281.15 degrees Spud date ................ : 11-Nov-97 Last survey date ......... : 21-Nov-97 Total accepted surveys...: 4~ MD of first survey ....... : 10644.00 ft MD of last survey ........ : 12628.00 ft ~eomagnetic data --- Magnetic model ........... : BC~HH 1996 version Magnetic date ............ : 10-Dec-1997 Magnetic field strength..: 1147.34 HCNT Magnetic dec (+E/W-) ..... : 28.45 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference ~ .............. : 1003.20 mGal Reference H .............. : 1147.00 HCNT Reference DiD ............ : 80.74 degrees Tolerance of ~ ........... : (+/-) 3.00 m~al Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 28.45 degrees ~rid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.45 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 Seq Measured Incl Azimuth Course T~D # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) I 10644.00 90.30 15.7 0.00 8689.60 2 10743.00 90.00 16.2 99.00 8689.34 3 10802.00 89.60 8.4 59.00 8689.55 4 10832.00 90.00 3.1 30.00 8689.65 5 10852.20 89.70 1.1 20.20 8689.70 6 10883.50 87.90 354.1 31.30 8690.36 7 10910.30 87.50 346.9 26.80 8691.44 8 10990.10 93.30 326.4 79.80 8690.88 9 11056.40 80.10 316.1 66.30 8694.69 10 11124.40 95.08 300.4 68.00 8697.56 11 11162.20 95.70 295.8 37.80 8694.01 12 11232.00 90.72 287.7 69.80 8690.10 13 11270.48 88.46 281.3 38.50 8690.37 14 11323.42 86.19 272.3 52.90 8692.84 Vertical section (ft) -840.30 -848.59 -849.77 -846.95 -843.77 -836.44 -827.01 -782.07 -731.65 -671'.50 -635.52 -567.09 -528.68 -476.05 Displ Displ Total At DLS Srvy +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (deg) 100f) type 2800.80 1408.50 3135.02 26.70 0.00 TIP 2895.99 1435.70 3232.34 26.37 0.59 MWD 2953.59 1448.26 3289.55 26.12 13.24 MW]3 2983.43 1451.27 3317.68 25.94 17.72 MW]) 3003.61 1452.01 3336.17 25.80 10.01 MWD 3034.86 1450.70 3363.76 25.55 23.09 MWD 3061.25 1446.28 3385.70 25.29 26.89 MWD 3134.09 1414.84 3438.65 24.30 26.69 MWD 3185.56 1373.59 3469.08 23.33 25.22 MW-D 3227.33 1320.52 3487.04 22.25 31.85 MWD 3245.05 1287.33 3491.07 21.64 12.23 MWD 3270.83 1222.68 3491.89 20.50 13.60 MWD 3280.47 1185.42 3488.08 19.87 17.63 MWD 3286.72 1133.01 3476.53 19.02 17.53 MWD OR GiNAL 15 16 17 18 19 2O 21 22 23 24 25 26 27 28 29 30 31 32 33 35 36 37 38 39 42 43 45 11353.49 11381.04 11428.42 11478.42 11528.54 11588.60 11618.40 11669.12 11718.67 11748.57 11798.37 11833.83 11878.80 11916.75 11955.65 11998.63 12048.63 12076.23 12126.26 12156.24 12196.46 12231.54 12280.03 12331.90 12381.88 12432.03 12481.67 12530.51 12573.07 12598.19 12604.94 90.21 275.2 87.74 273.3 85.89 272.7 84.95 266.4 89.14 266.6 90.03 268.7 88.80 266.9 89.86 262.7 88.60 261.2 87.74 258.4 88.66 254.5 90.96 252.6 91.99 251.6 88.53 252.3 89.86 258.6 92.74 262.9 30.10 27.50 47.40 50.00 50.10 60.10 29.80 50.70 49.60 29.90 49.80 35.40 45.00 38.00 38.90 42.90 92.74 265.1 50.00 91.58 267.3 27.60 88.90 265.0 50.10 90.70 266.8 29.90 92.45 270.0 40.30 93.70 271.1 35.00 95.25 273.6 48.50 91.20 276.9 51.90 87.60 274.7 50.00 87.40 273.6 50.10 88.25 269.3 49.70 88.95 267.1 4'8.80 88.25 263.9 42.60 89.65 267.1 25.10 89.55 270.4 6.70 8693.79 8694.28 8696.92 8700.91 8703.49 8703.93 8704.23 8704.83 8705.49 8706.45 8708.01 8708.13 8706.97 8706.80 8707.35 8706.37 8703.98 8702.94 8702.73 8702.84 8701.73 8699.85 8696.07 8693.15 8693.67 8695.86 8697.74 8698.94 8699.98 8700.44 8700.48 -446.22 -418.93 -372.08 -323.29 -274.89 -216.46 -187.46 -138.83 -91.99 -64.16 -18.95 12.42 51.74 84.91 119.94 160.12 207.84 234.49 282.87 311.71 351.00 385.35 433.13 484.65 534.42 584.10 633.04 680.58 721.59 745.75 752.29 3288.69 3290.72 3293.20 3292.81 3289.76 3287.29 3286.15 3281.56 3274.61 3269.32 3257.66 3247.64 3233.81 3222.06 3212.27 3205.38 3200.16 3198.33 3194.97 3192.83 3191.71 3192.04 3194.02 3198.77 3203.82 3207.44 3208.69 3207.16 3203.82 3201.85 3201.71 1103.00 1075.58 1028.32 978.51 928.58 868.54 838.76 788.29 739.18 709.78 661.39 627.45 586.64 568.52 510.89 468.57 -418.91 391.39 341.41 311.59 271.33 236.38 188.07 136.49 86.76 36.84 -12.80 -61.55 -104.00 -129.02 -135.72 3468.73 3462.04 3450.02 3435.13 3418.30 3400.10 3391.51 3374.91 3357.00 3345.48 3324.12 3307.69 3286.24 3268.40 3252.65 3239.45 3227.46 3222.19 3213.16 3208.00 3203.22 3200.78 3199.55 3201.68 3204.99 3207.65 3208.72 3207.75 3205.51 3204.45 3204.58 18.56 18.10 17.34 16.55 15.76 14.80 14.32 13.51 12.72 12~25 11.48 10.93 10.25 9.66 9.04 8.32 7.46 6.98 6.10 5.57 4.86 4.24 3.37 2.44 1.55 0.66 359.77 358.90 358.14 357.69 357.57 16.46 11.33 4.10 12.70 8.37 3.79 7.32 8 3.95 9.79 8.04 8.43 3.19 9.29 16.55 12.06 4.39 9.01 7.05 8.51 9.05 4.75 6.05 10.06 8.44 2.23 8.81 4.73 7.69 13.91 49.27 46 12628.00 89.55 270.4 23.10 8700.67 774.99 3201.87 -158.81 3205.80 357.16 0.00 MWD ~1:,1'4 a m ~'~]~z=~ ~[~[=~-~ Anadrill Survey report Client ................... : ARCO ALASKA INC. Field .................... : PRUDHOE BAY Well ..................... : DS 15-SBPB-1 API number ............... : 50-029-21180-N/A Job number ............... : 40001689 Rig ...................... : NABORS 3S County/State ............. : PRUDHOE BAY State/Country ............ : ALASKA Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference .... Permanent datum .......... : MSL Depth reference .......... : RRB GL above permanent ....... : 40.00 ft KB above permanent ....... : 69.00 ft DF above permanent ....... : 70.00 ft Vertical section origin, Latitude (+N/S-) ......... : 2800.8 ft Departure (+E/W-) ........ : 1408.5 ft Platform reference point Latitude (+N/S-) ......... : 70.30 ft Departure (+E/W-) ........ : -148.4444 ft Azimuth from rotary table to target:- 285.00 degrees Spud date ................ :-11-Nov-97 Last survey date ......... : 21-Nov-97 Total accepted surveys...: 32 MD of first survey ....... : 10644.00 ft MD of last survey ........ : 1208~.00 ft Geomagnetic data Magnetic model ........... : BGGM 1996 version Magnetic date ............ : O-Jan- 0 Magnetic field strength..: 1145 HCNT Magnetic dec (+E/W-) ..... : 28.45 degrees Magnetic dip ............. : 80.74 degrees ..... MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 57300.00 HCNT Reference Dip ............ : 80.74 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : -57252.81 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : -57252.81 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth (ft) (deg) (deg) (ft) (ft) 1 10644.00 90.30 15.7 0.00 8689.60 2 10743.00 90.00 16.2 99.00 8689.34 3 10802.00 89.60 8.4 59.00 8689.55 4 10832.00 90.00 3.1 30.00 8689.65 5 10852.00 89.70 1.1 20.00 8689.70 6 10884.00 87.90 354.1 32.00 8690.38 7 10910.00 87.50 346.9 26.00 8691.42 8 10990.00 93.30 326.4 80.00 8690.86 9 11056.00 80.10 316.1 66.00 8694.66 10 11124.00 95.10 300.4 68.00 8697.51 11 11162.00 95.70 295.8 38.00 8693.94 12 11232.00 90.70 287.7 70.00 8690.02 13 11292.00 90.80 282.5 60.00 8689.24 14 11344.00 85.80 277.5 52.00 8690.78 15 11373.00 85.70 277.2 29.00 8692.93 16 11408.00 85.70 273.6 35.00 8695.55 17 11429.00 86.60 271.6 21.00 8696.96 18 11481.00 89.50 269.3 52.00 8698.73 19 11522.00 88.00 268.1 41.00 8699.63 Vertlcal section (ft) -635.61 -637.25 -634.47 -629.65 -625.19 Displ Displ Total At DLS +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (deg) 100f) 2800.80 1408.50 3135.02 26.70 0.00 2895.99 1&35.70 3232.34 26.37 0.59 2953.59 1&48.26 3289.55 26.12 13.24 2983.43 1451.27 3317.68 25.94 17.72 3003.41 1452.00 3335.98 25.80 10.11 Srvy tool type TIP -615.63 3035.36 1450.66 3364.20 25.54 22.58 MWD_M -60~.86 3060.96 1446.38 3385.~8 25.29 27.71 MWD_M -555.51 3133.99 1414.86 3~38.56 24.30 26.62 MWD_M -502.59 3185.22 1373.79 3468.85 23.33 25.33 MWD_M -440.52 3226.99 1320.73 3486.80 22.26 31.87 MWD_M -403.68 3244.80 1287.36 3490.85 21.64 12.15 MWD_M -334.35 3270.66 1222.52 3~91.67 20.49 13.58 MWD_M -274.38 3286.28 1164.61 3486.5~ 19.51 8.67 MWD_M -222.63 3295.31 1113.46 3478.34 18.67 13.59 MWD_M -193.97 3299.01 1084.78 3472.78 18.20 1.09 MWD_M -159.56 -139.10 -88.81 -49.47 3302.29 1050.04 3465.21 17.64 10.26 MWD_M 3303.24 1029.11 3459.83 17.30 10.42 MWD_M 3303.65 977.15 3445.13 16.48 7.12 MWD_M 3302.72 936.17 3432.83 15.83 ~.68 MWD_M ORIGIN/ £ ~-"~j ~ 1! I iil lDti~ [:]'-j Anadrill 2o 21 22 23 24 25 26 27 28 29 30 31 32 11562.00 11603.00 11652.00 11681.00 11727.00 11772.00 11798.00 11842.00 11897.00 11952.00 12002.00 12052.00 12088.00 85.70 266.9 40.00 8701.83 -11.38 84.60 26&.6 41.00 8705.29 27.19 83.70 260.1 49.00 8710.29 72.16 83.40 257.7 29.00 8713.55 98.04 85.40 252.7 46.00 8718.04 137.75 85.60 253.5 45.00 8721.57 175.83 86.40 253.4 26.00 8723.38 197.94 89.30 252.7 44.00 8725.03 235.24 90.20 254.8 55.00 8725.27 282.26 90.10 262.5 55.00 8725.13 331.50 90.60 265.7 50.00 8724.82 378.21 93.10 260.4 50.00 8723.21 424.54 93.40 261.1 36.00 8721.17 457.31 3300.98 3297.95 3291.46 3285.92 3274.22 3261.18 3253.79 3240.98 3225.59 3214.77 3209.63 3203.59 3197.81 896.27 855.53 807.24 778.96 734.72 691.79 666.93 624.88 572.08 518.19 468.47 418.88 383.41 3420.49 3407.11 3389.01 3376.98 3355.64 3333.75 3321.44 3300.67 3275.93 3256.27 3243.64 3230.86 3220.71 15.19 14.54 13.78 13.34 12.65 11.98 11.58 10.91 10.06 9.16 8.30 7.45 6.84 6.48 6.20 9.32 8.29 11.66 1.83 3.10 6.78 4.15 14.00 6.48 11.71 2.11 Anadrill Date: Well Name: Company: A.P.I. Number: Location: Field: Rig: 21-November-97 15-08b ARCO Alaska Inc. 50-029-21180-02 North Slope Alaska Prudhoe Bay Nabors 3S Anadrill Personnel: Cell Manager: Field Crew: Field Support: Alaska District Manager: Field Service Manager: Mark Brown Dag Hinnaland Don Webb Martin Varco Craig Brown SERVICES PROVIDED Service Directional Survey Services (DSS) Gamma Ray (GR) Service Dates 16-Nov-97 21-Nov-97 16-Nov-97 21-Nov-97 Depth Interval 10700' 12628' 10700' 12628' OPERATING STATISTICS Total MWD Pumping Hours: Total MWD Below rotary Hours: Total MWD Footage: Total MWD Runs: ~IOB PERFORMANCE 106 126.5 1928' 5 DIRECTIONAL Survey (DSS) were provided over the entire well. Continuous inclination was provided, which proved to be a major advantage in determining if we were building or dropping angel before we got to a survey point. Survey on the fly was used through out the well, thereby reducing the risk of getting stuck. FORMATION EVALUATION Realtime GR values were provided in order to identify formation lithology. In doing so we were possible to geosteer the sands and shales. ORIGINAL LESSONS LEARNED While drilling in a easterly direction, we encountered slightly higher (H) mag. field strength, and higher mag. dip angle. Several MWD tools and collars were used, yielding the same findings. Given the results of our roll tests, and the use of more non-mag material above and below MWD, we feel the interference was formation related. Anadrill appreciated the opportunity to provide ARCO Alaska Inc. with MWD SHARP and (GR) services on 15-08b. Sincerely, Mark Brown Cell Manager, Anadrill / ARCO Coil Tubing Craig Brown Field Service Manager ~.'f~Ja mm~m~_q=]2 Anadrill DEC !9 1997 Date: Well Name: Company: A.P.I. Number: Location: Field: Rig: 15-November-97 15-08bPb-1 ARCO Alaska Inc. 50-029-21180-n/a North Slope Alaska Prudhoe B ay Nabors 3S Anadrill Personnel: Cell Manager: Field Crew: Field Support: Alaska District Manager: Field Service Manager: Mark Brown Dag Hinnaland Don Webb Martin Varco Craig Brown SERVICES PROVIDED Service Directional Survey Services (DSS) Gamma Ray (GR) Service Dates 11-Nov-97 15-Nov-97 11-Nov-97 15-Nov-97 Depth Interval 10700' 12155' 10700' 12155' OPERATING STATISTICS Total MWD Pumping Hours: Total MWD Below rotary Hours: Total MWD Footage: Total MWD Runs: JOB PERFORMANCE 76.5 102.0 1412' 6 DIRECTIONAL Survey (DSS) were provided over the entire well. Continuous inclination was provided, which proved to be a major advantage in determining if we were building or dropping angel before we got to a survey point. Survey on the fly was used through out the well, thereby reducing the risk of getting stuck. FORMATION EVALUATION Realtime GR values were provided in order to identify formation lithology. In doing so we were possible to geosteer the sands and shales. From this information, this well had to be plugged back due to the angle of the shale bed and the angle in which we were drilling the well. ORIGINAL LESSONS LEARNED While drilling in a easterly direction, we encountered slightly higher (H) mag. field strength, and higher mag. dip angel. Several MWD tools and collars were used, yielding the same findings. Given the results of our roll tests, and the use of more non-mag material above and below MWD, we feel the interference was formation related. Anadrill appreciated the opportunity to provide ARCO Alaska Inc. with MWD SHARP and (GR) services on 15-08bPb-1. Sincerely, Mark Brown Cell Manager, Anadrill / ARCO Coil Tubing Craig .Brown Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) November 21, 1997 Larry Grant Arco Alaska Inc. Anchorage, Alaska Mr. Grant --'/ / _ Enclosed is a copy of the survey pro,am, and performance letter for 15-08b. Please let me know if you have any questions regarding this data. Craig Brown or myself can be reached at (907)-349-4511. Sincerely, Mark Brown Cell Manager, Anadrill Arco Coil Tubing Criag Brown Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) November 15, 1997 Larry Grant Arco Alaska Inc. Anchorage, Alaska Mr. Grant Enclosed is a copy of the survey pro,am, and performance letter for 15-08bPb-1. Please let me know if you have any questions regarding this data. Craig Brown or myself can be reached at (907)-349-4511. Sincerely, Mark Brown Cell Manager, Anadrill Arco Coil Tubing Criag Brown Field Service Manager TONY KNOWLE$, GOVERNOF{ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 (907) 276-7542 October 24. 1997 Erin Oba Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Prudhoe Bav Unit 15-08B ARCO Alaska. Inc. Permit No. 97-182 Sur. Loc. 1645'SNL, 1378'EWL. Sec. 22, T11N, R14E, UM Btmnhole Loc. 3729'FNL, 4487'FEL. Sec. 15, T1 IN, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced ~vell. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may' be given b~field inspector on the North Slope pager at 659-3607. Chairman ',~ BY ORDER OF TH MMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la, Type of Work Drill_ Redrill X lb, Type of Well Exploratory_ Stratigraphic Test_ Development Oil Re-Entry__ Deepen _ Service_ Development Gas _ Single Zone X Multiple Zone_ 2. Name of Operator i 5.Datum Elevation (DF or KB) ~ 10. Field and Pool ARCO Alaska, Inc. I RKB 58' 3. Address [ 6. Properly Designation P.O. Box 100360 I Prudhoe Bay Field Anchorage, AK 99510-0360 i ADL 28306 Prudhoe Bay Oil Pool I 4. Location of well at surface I 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1645' SNL, 1378' EWL, Sec 22, T11N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval ~ 8. Well number Number 432' SNL, 2164' EWL, Sec 22, T11N, R14E, UM 15-08B #U-630610 At total depth i 9. Approximate spud date Amount (Proposed) I 3729' FNL, 4487' FEL, Sec 15, T11N, R14E, UM. I December, 1997 $200,000 12. Distance to nearest i 13. Distance to nearest well I 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line I ! No Close Approach !, 12900' MD / 8819 TVD 16. To be completed for deviated wellsIl 17, Anticipated pressure (see 2O AAC 25.035(e)(2)) kickoff depth N/A Maximum hole angle 90° [ Maximum surface 2800 peJg At total depth CI'VD) 8800' 18. Casing program I i Setting Depth Size J Specification ! Top Bottom Quantity of cement Hole Casin~ Weight I Grade I Couplin~t ILenCh I MD I TVD MD I -I'VD i (include sta~le data) ....... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10725 feet Plugs(measured) true vedical 8752 feet Effective depth: measured 10725 feet Junk (measured) .~jSSkS. true vertical 8752 feetAnchorage, Casing Length Size Cemented Measured depth True Vertical depth Conductor 90' 20" 370 Sx PF II 90' 90' Surface 2481' 13-3/8" 1938 Sx PF E & 400 Sx PFC 2539' 2539' Production 7390' 9-5/8" 500 Sx CIG & 300 Sx PFC 8621' 7194' Liner 2554' 7" 534 Sx Ci G 9825' 8796' Slotted Liner 957' 4-1/2" Uncemented 10725' 8752' Perforation depth: measured Slotted Liner: 9854 - 10725' true vertical Slotted Liner: 8796 - 8752' 20. Attachments Filing fee X Property plat _ BOP Sketch x Diverter Sketch _ Drilling program X Drilling fluid program __ Time vs depth plot Refraction analysis ~ Seabed repod 20 AAC 25.050 requirements 21. I herebycedifythattheforegoing istrueand correct to the best of my knowledge O, oe~'i'o~, ~ ~frS',~- ~,,/'c4¢'c~ ~ Signed ~¢'~~ '~' ~ Titlle En~lineedn~ Supervisor Date ?../¢:~ _ '~ '7 Commission Use Only Perrn~ Number ' Approval date C.~ j APl number j See cover letter for 50- ~-~, I~'-- ,~ ///~)~:) - O ~ /~ --(:~-~-~ "~ I other requirements / ./... I ~;ondidons~ of approval Samples required . Yes ~No ' ' Mud Icg required ' _ Yes ~'No Hydrogen sulfide measures ,,~Yes _ No Directional survey required zyYes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X 3500 psi for CTU Other: v'"" ali',' ~ r,,,, 0avid W, Johnston byorder of Approved by Commissioner the commission Date /0 Form 10-401 Rev. 7-24-89 Submit in triplicate DS 15-8B CT Extension and Completion Intended Procedure Ob, iective: Directionally drill -2200', 2-3/4" horizontal extension from the Complete with 2-3/8" slotted liner. existing wellbore. Intended Procedure: · RU CTU/Nabors 3S. RIH and mill out shoe in 4-1/2" slotted liner. · Load well with +8.9 ppg polymer mud. Dkectionally drill -2200' of 2-3/4" hmSzontal hole to access Romeo reserves. · Run 2-3/8" slotted liner to TD. · RD CTD, return well to production. September 16, 1997 DS 15-8B Proposed Wellbore Sketch Extension of Wellbore & Completion 4-1/2" Camco TRDP-4A SSSV 3.812" ID 2026' 7" Liner top 7259' 9-5/8" Window 7448-7478' 3-1/2" Parker "SWS" Nipple 9227' 7" Baker Pkr 9270' 3-1/2" Parker "SWS" Nipple 3-1/2" Parker "SWN" Nipple 9388' 9444' 4-1/2" Production Tubing 3-1/2" Production Tubing 3-1/2" Camco GLMs 4-1/2" Slotted Liner to 10725' 7"LinerShoe 9825' TIW SS Packer @ 9761' 2.375" TOL ~10600' 10725' 2.375" Slotted Liner 2.75" Openhole +/-2200' TD +/- 12900' DRILEX - BAKER HUGI4F..~ INTEO NORTH REF. TO TRUE FOR ARCO ALASKA INC. ~'rue NABORS UNIT 4 PRUDHOE BAY, ALASKA " ...................................................................................................................................................................................................................................... ARCO ALASKA INC. 1508AT ~__~600 1508ORTR Approximate Fault Location 28O0 0 0 0 0 CD 0 0 0 0 0 0 CD 0 0 0 0 0 0 0 0 0 E/W Scale 1 inch · 200 ft 8500 1TielnPoint / 2KOP 18748,0 SS --I o o o o o o ~ ~ ~ 0 0 0 0 0 0 0 0 o 8 8 ° o 8 o 8 o Vertical Section Scale 1 inch · 200 ft PLANE OF VERT SECTn 281.15 Relative to True North 1 15-08a.xls 15-08 8 REV. 0 9/11/97 11:41 AM ARCO 15-08 A SIDETRACK Sept. 11, 1997 Revision 1 MD Inc, Dir SS DEPTH VS N/-S E/-W Build Turn Dogleg ASP Y ASP X Comments -- ff deg deg ff ff ff ft degl100 degll00 deg/t00 ft ft __ 10644.00 90.30 15.70 8689.60 0.00 2800.80 1408.50 0.00 0.00 0.00 5,962,702.00 678,663.30 1. Tie In Point/KOP 10650.00 90.28 14.49 8689.60 -0.40 2806.60 1410.00 -0.40 -20.10 20.10 5,962,708.00 678,664.80 Turn left 20°/100. D1-91.1 TFO -- _ 10680.00 90.16 8.45 8689.50 -0.60 2836.00 1416.00 -0.40 -20.10 20.10 5,962,737.50 678,670.00 -- 10710.00 90.04 2.42 8689.40 2.40 2865.80 1418.80 -0.40 -20.10 20.10 5,962,767.50 678,672.10 -- 10740.00 89.92 356.38 8689.40 8.50 2895.80 1418.50 -0.40 -20.10 20.10 5,962,797.50 678,671.10, 10770.00 89.80 350.34 8689.50 17.70 2925.60 1415.00 -0.40 -20.10 20.10 5,962,827.00 678,666.90 -- 10800.00 89.68 344.30 8689.70 29.80 2954.80 1408.50 -0.40 -20.10 20.10 5,962,856.00 678,659.70 10830.00 89.56 338.26 8689.90 44.70 2983.20 1398.80 -0.40 -20.10 20.10 5,962,884.50 678,649.40 10860.00 89.45 332.22 8690.10 62.30 3010.50 1386.30 -0.40 -20.10 20.10 5,962,911.50 678,636.20 10890.00 89.35 326.19 8690.40 82.30 3036.20 1370.90 -0.30 -20.10 20.10 5,962,936.50 678,620.30 -- 10920.00 89.26 320.15 8690.80 104.60 3060.20 1353.00 -0.30 -20.10 20.10 5,962,960.50 678,601.70 10950.00 89.17 314.11 869'1.20 128.90 3082.20 1332.60 .... -0.30 -20.1 O' 20.10 5,962,981.50 678,580.80 10980.00 .... 89.09 308.07 8691.70 154.80 3101.90 1310.00 -0.30 -20.10 20.10 5,963,001.00 678,557.80 -" i1010.d~ ..... 89.02 302.03 8692.20 182.30 3119.10 1285.40 -- -0.20 -20.10 20.10 5,963,017.50 678,532.80 11040.00 88.96 295.99 8692.70 210.80 3133.70 1259.20 -0.20 -20.10 20.10 5,963,031.50 678,506.30 11070.00 88.92 289.95 8693.20 240.10 3145.40 1231.60 -0.20 -20.10 20.10 5,963,042.50 678,478.40 11100.00 88.88 283.91 8693.80 270.00 3154,10 1202.90 -0.10 -20.10 20.10 5,963,050.50 678,449.50 11130.00 88.86 277.87 -8694.40 299.90 3159.70 1173.50 -0.10 -20.10 20.10 5,963,055.50 ~--¢-8,419,90 11160.00 88,85 271.83 8695.00 329.70 3162.30 1143.60 0.00 -20.10 20.10 5,963,057.50 678,390.00 11190.00 88.86 265.79 8695.60 359.00 3161,70 1 ~13.60 0.00 -20.10 20.10 5,963,--056.00 678,3601i0 -- 11209.50 88.86 261.87 8696.00 377.60 3159.60 1094.30 0.00 -20.10 20.10 5,963,053.50 678,340.80 2. Orient to TD 11220.00 88.86 261.98 8696.20 387.60 3158.10 1083.80 -0.101 _ 1.10 1.10 5,963,052.00 678,330.40 1-~'250.00 ....... 88.83 262.31 8696.8-~' 415190 3154.00 1054.10 -0.10 1.10 1.1-~ 5,963,047.00 678,300.80 1~280.00 ---' 88.81 262.64 8697.40 444.30 3150.10 1024.40 -- -0.10 1.10 1.10 5,963,042.5'~ 678,271.10 11310.00 - 88.79 262.97 8698.10 472.80 3146,30 994.60 '-' -0.10 1.10 1.10 5,963,038.00 678,241.40 11340.00 88.76 263.30' 869-~.'70 501.30 3142.70 964.9~- ...... -0.10 1.10 1.10 5,963,033.--5-~'- 678,211.80 11370.00 '- 88.74 263.64 8699.40 529.90 3139.30 935.'10 ---- .0.10 1.10 1.10 5,963,029.50 678,182.10 ............. 11400.O0 --- 88.72 263.97 8700.O0 558.50 3136.10 905.20 -0.10 -- 1.10 1.10 --~,963,025.50 678,152.30 11430.00 88.70 264.30 8700.70 587.20 3133.00 875.40 -0.10 1.10 1.10 5,963,022.00 678,122.60 1'1460.-----'~b-'--- 88.67 264.63 8701.40 615.90 3130.10 845.60 ...... ----0-~10 1.10 1.10 5,963,018.00 ~7--~,092.80 11490.00 88.65 264.96 8702.10 644.70 3127.40 815.70 -0.10 1.10 1.10 5,963,014.50 678,063.00 11520.00 88.63 265.29 8702.80 673.50 3124.80 785.80 -0.10 1.10 1.10 5,963,011.80 678,033.20 11550.00 -- 88.61 265.62 8703.50 702.40 3122.50 755.90 -0.10 1.10 --1.10 5,963,008.50 678,003.40 11580.00 88.58 265.95 8704.30 731.30 3120.30 726.00 -0.10 1.10 1.10 5,963,005.50 677,973.50 -- 11610.00 88.56 266.28 8705.0(~- 760.30 3118.20 696.10 --- -0.10 1.10 1.10 5,963,002.50 677,943.70 11640.00 88.54 266.61 8705.80 789.30 3116.40 666.10 -0.10 1.10 1.10 5,963,000.00! 677,913.80 11670.0~ '----8-8.52 266.94 8706.50 818.40 3114.70 636.20 -0.10 1.10 1.10 5,962,998.00 677,883.90 11700.00 -- 88.49 267.27 8707.30 847.50 3113.20 606.30 ----20.i0 1.10 -- 1.10 5,962,995.50 677,854.00 11730.00 --' 88.47 267.60 8708.10 876.60 3111.80 576.3~ -0.10---- 1.10 1.10 5,962,993.50 677,824.10 11760.00 88.45 267.93 8708.90 905.80 3110.60 546.30 -0.10 1.10 1.10 5,962,991.50 677,794.10 11790.00' 88.43 268.26 8709.70 --- 935.00-- 3109.60 516.40 -0.10 .... 1110 1.1~' 5,962,990.00 ' 677,764.20 11820.00 .... 88.41 268.5~---' 8--~0.60 964.20 3108.80 486.4(~ -0.10 1.10 1.10 5,962,988.50 --6-~7,734.30 11850.00 88.38 268.92 8711.40 993.50 3108.20 456.40' -0.10 1.10 1.10 5,962,987.00 677,704,30 11880.00 88.36 - 269.25 8712.20- 1022.90-- 3107.70 426.40 -0.10 -- 1.10 1.10 5,962,986.00 677,674.30 _. , , ,, . 2 15-osa.xls 15-08 E/REV. 0 9/tl/97 11:41 AM MD ' , inc. Dir Ss DEPTH VS N/.S EI.W 'Build Turn Dogleg ASP Y ASp X Comments .... -- ft deg deg ft ff ft ft deg/100 deg/100 deg/100 ft ft 11910.00 88.34 269.58 8713.10 1052.20 3107.40 396.40 -0.10 1.10 1.10 5,962,984.~0' 677,644.40 - --.. 11940.00 88.32 269.91 8714.00 1081.60 3107.30 366.40 -0.10 1.10 1.10 5,962,984.00 677,614.40 11970.00 88.30 270.24 8714.90 1111.00 3107.30 336.50 -0.101 1.10 1.10 5,962,983.00 677,584.40 12000.00 88.28 270.57 8715.80 1140.50 3107.50 306.50 -0.10 1.10 1.10 5,962,982.50 677,554.40 12030.00 88.25 270.90 8716.70 1170.00 3107.90 276.50 -0.10 1.10 1.10 5,962,982.50 677,524.40 -- 12060.00 88.23 271.23 8717.60 1199.50 3108.50 246.50 -0.10 1.10 1.10 5,962,982.00 677,494.40 -- 12090.00 88.21 271.56 8718.50 1229.10 3109.20 216.50 -0.10 1.10 1.10 5,962,982.00 677,464.40 12120.00 88.19 271.90 8719.50 1258.60 3110.10 186.60 -0.10 1.10 1.10 5,962,982.50 ~ 677,434.50 ,_ 12150.00 88.17 272.23 8720.40 1288.30 3111.20 156.60 -0.10 1.10 1.10 5,962,982.50 677,404.50 -- -, 12180.00 88.15 272.56 8721.40 t317.90 3112.40 126.60 -0.10 1.10' 1.10 5,962,983.50 677,374.50 12210.00 88.13 272.89 8722.40 1347.60 3113.80 96.70 -0.10 1.10 1.10 5,962,984.00 677,344.60 -- 12240.00 88.10 273.22 8723.40 1377.20 3115.40 66.70 -0.10 1.10 1.10 5,962,985.00 677,314.60 12270.00 88.08 273.55 8724.30 1406.90 3117.20 36.80 -0.10 1.10 1.10 5,962,986.00 677,284.60 12300.00 -- 88.06 273.88 8725.40 1436.70 3119.20 6.90 -0.10 1.10 1.10 5,962,947.00 677,254.60 12330.00 88.04 274.21 8726.40 1466.40 3121.30 -23.00 -0.10 1.10 1.10 5,962,988.50 677,224.70 12360.00 88.02 274.54 8727.40 1496.20 3123.60 -52.90 -- .... ~0'.10 1.10 1.10 5,962,990.00- 677,194.80 12390.00 88.00 274.87 8728.50 1526.00 3126.00 -82,80 -0.10 1.10 1.10 5,962,992.00 677,164.80 12420.0-~ --- 87.98 275.20 8729.50 1555.80 3128.60 -112.70 -0.1~' 1.10 1.10 5,962,993.50 677,134.90 12450.00 87.96 275.53 8730.60 1585.60 3131.40 -142.50 -;.0-'~10 1.10 1.10 5,962,996.00 677,105.00 12480.0~ 87.94 275.86 8731.60 1615.50 3134.40 -172.30 -0.10 1.10 1.10 5,962,998.00 677,075.10 12510.00 87,92 276.19 8732.70 1645.30 3137.60 -202.20 -0.10 1.10 1.10 5,963,000.50 677,045.20 12540.00 87.90 276.52 8733.80 1675.20 3140.90 -232.00 -0.10 1.10 1.10 5,963,003.~0 677,015.30 12570.00 87.87 276.85 8734.90 1705.10 3144.40 -261.70 -0.10 1.10 1.10 5,963,006.00 676,985.50 12600.00 87.85 277.18 8736.10 1735.00 3148.00 -291.50 -0.10 1.10 111(~ 5,963,008.50 676,955.60: ,- __ 12630.00 87.83 277.52 8737.20 1764,90 315t.90 -321.20 -0.101 1.10 1.10 5,963,012.00 676,925.80 12660.00 87.81 277.85 8738.30 1794.80 3155.90 -350.90 -~0.10' -- 1.10 1.10 5,963,015.00 676,896.10 12690.0~' 87.79 278.18 8739.50 1824.80 3160.10 -380.60 -0.10 1.10 i.10 5,963,018.50 676,866.30 12720.00 87.77 278.51 8740.60 1854.70 3164.40 -410.30 -0.10 1.10 1.10 5,963,022.00'--676,836.50 - ~ 12750.00 87.75 278.84 8741.80 1884.70 3168.90 -439.90 -0.10 1.10 1.10 5,963,026100 676,806.80 12780.01~---- 87.73 279.17 8743.00 1914.6--~ 3173.60 -469.50 -0.10 1.10 1.10 5,963,030.06' 676,777.10 12810.00 -- 87.71 279.50 8744.20 1944.60 3178.50 -499.10 -0.10 1.10 1.10 5,963,034.00'-- '676,747.40 12840.00 87.69 279.83 8745.40 1974.60 3183.50 -528.60 -~). 10 1.10 1.10 5,963,038.5~ 676,717.70 12870.00 - 87.67 280.16 8746.60 2004.50 3188.70 -558.20 ....-0.10 1.10 1.10 5,963,043.00 676,688.10 12900.00 87.65 280.49 8747.80 2034.50 3194.10 -587.70 -.0.10 1.10 1.10 5,963,047.50 676,658.40 12904,60 - 87.65 280.54 8748.00 2039.10 3194.90 -592.20 -0.10 1.10-- 1.10 5,963,048.00---676,653.90 3. TD 2260' Total feet -- VERTICAL SECTION USED ' 281.15° RELATIVE TO TRUE NORTH ,KB I-- .-71' I NOTE _b___ · Relative Coordinates are off of true North/._A__S_P_ a__r_e relati_ve to grid North _ _ GRID CONVERGENCE:. ' 1.350 MAGNET, C DECL,NAT ON .......... : 2 .46° ' SURFAC E X ;']____ --' 677321.3 '- -- _ . SURFACE Y [ '5959868.8 Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect ~~~..~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I -- 7" Riser I I I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M i~am Type Dual Gate BOPE anua~over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") ri 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Shop Fuel Boilers Mu¸ Water Tanks Pump Roor Fire Ext. Fire Ext. 60/40 I TrplxI ,~Pipe rack i-ire Ext. Dowell Drilling I Equipment Trailer Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY /~"'c..-~ FIELD & POOL ~ d__./2(~/~ C~ INIT CLASS ! WELL NAME ?z¢(-,¢' C~,',// GEOL AREA 8~'_¢',/'''~ PROGRAM: exp [] dev/~edrll, l~serv [] wellbore seg [] ann. disposal para req [] UNIT# '//'"/f~,_,~"(~ ON/OFF SHORE ~::~,-~ ADMINISTRATION APPR~ 1. Permit fee attached ....................... Y 2. Lease number appropriate ................... Y 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... IYv~ 9. Operator only affected party ................... i r 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... REMARKS 14. Conductor string provided ................... Y N "~ ,,. 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg .....,~- 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... ~('-'~N - -- - ~~ -- -- 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... "'- 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... N 25. DOPEs, do they meet regulation .................. 26. DOPE press rating appropriate; test to ~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY / 30. Permitcan be issued w/o hydrogen sulfide measures ..... Y ~"'~A ~ 31. Data presented on potential overpressure zones ....... Y,,, . _ . 32. Seismic analysis of shallow gas zones ............. Y N 33. Seabed condition survey (if off-shore) '" Y N /-~~~-~A'P~R ~D~E/~,p 34. Contact name/phone for we,ekly.progress repo. rtSlexplora,ory only] .... .//. Y N ENGINEERING: COMMISSION: DW BEW~ ..~ l&/'l' RNtC~~ JDH ~ co 0¢ . Comments/instructions' HOW/Ijt - A:\FORMS\chektist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . ............................ , ....... SCHLUFiBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAi~E : DS 15-08B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292118002 REFERENCE NO : 98541 RECEIVED NOV 1,3 1998 Oil & Gas Co~s. Oommi~iort LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/10/27 ORIGIN : FLIC REEL NA~iE : 98541 CONTINUATION # : PREVIOUS REEL : CO~ff4~NT : ARCO ALASKA, INC., DS 15-08B, PRUDHOE BAY, API #50-029-21180-02 **** TAPE HEADER **** SERVICE NA~E : EDIT DATE : 98/10/27 ORIGIN : FLIC TAPE NA~E . 98541 CONTINUATION # : 1 PREVIOUS TAPE : CONff/iENT : ARCO ALASKA, INC., DS 15-08B, PRUDHOE BAY, API #50-029-21180-02 TAPE HEADER PRUDHOE BAY ~/~D LOtS WELL N~CE : API NUMBER ~ OPEP~TOR: LOGGIN~ COMP~VY: TAPE CRF_~TION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 15-08B 500292118002 ARCO ALASKA, INC. ANADRILL 27-0CT-98 BIT RUN 1 98541 ANADRILL ARCO BIT RUN 2 ......... BIT RUN 3 ......... 22 lin 14E 1645 1378 71. O0 70. O0 40.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (F~ 2.750 4.500 10724.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE LDWG FORMATTED MWD GR AND ROP DATA AQUIRED ON ARCO ALASKA'S DS 15-08B WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ PAGE **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE '. FLIC VERSION · O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER : 1 EDITED ~iERGED Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH MWD 12628.0 10727.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (IZiEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE REMARKS: THIS FILE CONTAINS THE EDITED MWD DATA. THE CURVES HAVE BEEN CLIPPED OF INVALID COUNTS AT FIRDT READING AND AT LAST READING. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... MWD ....... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12628. 000 ROP.MWD 35. 020 GR.MWD -999. 250 DEPT. 10727.000 ROP.MWD -999.250 GR.MWD 30.840 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMPUkRY VENDOR TOOL CODE START DEPTH STOP DEPTH 12628.0 10726.5 LOG H~ER 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (?T) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 21-NOV-97 5.36 SHEC V. 33 MEMORY 12628.0 10727.0 12628.0 TOOL NUMBER ........... MWD M _ 2. 750 10724.0 FLOPRO LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 PAGE: FLUID LOSS (C3): RESISTIVITY (OH~f) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: DATA FROM DOWNHOLE ~i~ORY, SHEC V. 33 SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000168 00 000 O0 0 2 1 1 4 68 0000000000 ROPE LOG F/HR 4000168 O0 000 O0 0 2 1 i 4 68 0000000000 GR LOG GAPI 4000168 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 14:36 PAGE: ** DATA ** DEPT. 12628.000 ROPE.LOG 35.020 GR.LOG -999.250 DEPT. 10726.500 ROPE.LOG -999.250 GR.LOG 30.840 ** END OF DATA ** **** FILE TRAILER **** FILE NAI~E : EDIT .002 SERVICE - FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/27 ORIGIN · FLIC TAPE NAME : 98541 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~NT : ARCO ALASKA, INC., DS 15-08B, PRUDHOE BAY, API #50-029-21180-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/27 ORIGIN . FLIC REEL NA~E : 98541 CONTINUATION # : PREVIOUS REEL : CO~ff~2VT : ARCO ALASKA, INC., DS 15-08B, PRUDHOE BAY, API #50-029-21180-02 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... RECEIVED t' OV 15 A~aska Oi~ & G~s Co~s. C~mmissior~ Anchorage COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 15-08B PB1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292118072 REFERENCE NO : 98540 oate~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 PAGE: **** REEL HEADER **** SERVICE NAFiE : EDIT DATE : 98/10/27 ORIGIN : FLIC REEL NAbIE : 98540 CONTINUATION # : PREVIOUS REEL : COt4MENT : ARCO ALASKA, INC., DS 15-08B PB1, API #50-029-21180-72 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 98/10/27 ORIGIN : FLIC TAPE NAbIE : 98540 CONTINUATION # : 1 PREVIOUS TAPE : COt4MENT : ARCO ALASKA, INC., DS 15-08B PB1, API #50-029-21180-72 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUbIBER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) F~ELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS 15-08B PB1 500292118072 ARCO ALASKA, INC. ANADRILL 26-0CT-98 BIT RUN i 98540 ANADRILL ARCO BIT RUN 2 BIT RUN 3 22 llN 14E 1645 1378 71.00 70.00 40.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2.750 4.500 10724.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE LDWG FORMATTED LWD GR AND ROP DATA AQUIRED ON ARCO ALASKA'S DS 15-08B PB1 WELL. ONLY M~MORY DATA IS INCLUDED. THIS LOG IS THE PRIMARY DEPTH CONTROL. $ PAGE: **** FILE HEADER **** FILE NAFZE : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE · 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJM~ER: 1 EDITED FiERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMF2~f: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH IvIWD 10754.0 11811.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (FiEASUREDDEPTH) BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE REM_ARKS: THIS FILE CONTAINS THE EDITED MWD DATA. THE DATA HAS BEEN CLIPPED OF INVALID COUNTS AT FIRST READING AND AT LAST READING. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... MWD ....... BIT RUN NO. ~tERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11811.000 ROP.MWD 67.670 GR.MWD -999.250 DEPT. 10728.000 ROP.MWD -999.250 GR.MWD 33.430 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27~0CT-1998 12:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SETTYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 4000168 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11811.000 ROP.MWD 67.670 GR.MWD -999.250 DEPT. 10728.000 ROP.MWD -999.250 GR.MWD 33.430 ** END OF DATA ** * * ** FILE TRAILER * * * * FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 PAGE: **** FILE HEADER FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUM~ER: 1 DEPTH INCREMF2~f: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12155.0 10726.5 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 16-NOV-97 5.36 SHEC V. 33 MEMORY 12155.0 10754.0 11811.0 TOOL NUMBER MWD M _ 2. 750 10724.0 FLOPRO 'LIS '~ape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 PAGE: FLUID LOSS (C3): RESISTIVITY (OP~4) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: DATA FROM DOWNHOLE MEMORY, SHEC V. 33 SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 4000168 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LOG F/HR 4000168 O0 000 O0 0 2 1 1 4 68 0000000000 GR LOG GAPI 4000168 O0 000 O0 0 2 1 1 4 68 0000000000 'LIS ~ape Verification Listing Schlumberger Alaska Computing Center 27-0CT-1998 12:31 PAGE: ** DATA DEPT. 12155.000 ROPE. LOG -999.250 GR.LOG -999.250 DEPT. 10726.500 ROPE.LOG -999.250 GR.LOG 30.840 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAM~ : EDIT DATE : 98/10/27 ORIGIN · FLIC TAPE NA~E : 98540 CONTINUATION # : 1 PREVIOUS TAPE : COI4MENT : ARCO ALASKA, INC., DS 15-08B PB1, API #50-029-21180-72 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 98/10/27 ORIGIN : FLIC REEL NAME : 98540 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., DS 15-08B PB1, API #50-029-21180-72