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195-188
. • RC V l Post Office Box 244027 JUL3 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U 0 201,‘-i 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 • CANNE0 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission5 I g0 333 West 7th Avenue, Suite 100 I g &S— Re: -- Anchorage, AK 99501 / — (oS Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeliNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/020 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/020 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 7„,.....>50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. "5 ., IflS Well History File # Digital Data Added to LaserFiche File CD's ~ # Yes No Yes No Yes No DVD's - # Diskettes - # - Oversized Material Added to LaserFiche File Other # Yes No Yes No Yes No Maps # Mud Logs # - General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us r"\ STATE OF ALASKA ~ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION' WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAY 2 0 2004 Alaska Oil & Gas Cens. Commission 1b. Well C~ashorage 1m Development 0 Exploratory 0 Stratigraphic Test 0 Service 12. Permit to Drill Number ./ 195-188 .£ 303-362 r 13. API Number / 50- 029-22627-00-00 14. Well Name and Number: END 1-65/N-25 / 15. Field I Pool(s): Endicott Field I Endicott Pool . No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 1m Abandoned 0 Suspended 0 WAG 20AAC25.105 20AAC25.110 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 331' NSL, 4260' EWL, SEC. 31, T12N, R17E, UM Total Depth: 26' SNL, 4824' EWL, SEC. 06, T11N, R17E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 258980 y- 5982195 Zone- ASP3 TPI: x- 265368 y- 5979264 Zone- ASP3 Total Depth: x- 265920 y- 5978889 Zone- ASP3 18. Directional Survey 0 Yes 1m No 21. Logs Run: DIFL I ZDL I CN I GR I CHT, SBT, MWD Zero Other 5. Date Comp., Susp., or Aband. 3/16/2004 Af// 6. Date Spudded I 12/13/1995 7. Date T.D. Reached 01/20/1996 8. KB Elevation (ft): 56' 9. Plug Back Depth (MD+ TVD) 13198 + 10089 10. Total Depth (MD+TVD) 13286 + 10088 11. Depth where SSSV set NIA MD 19. Water depth, if offshore 6' - 12' MSL 22. ~f~;:P~~ ..' 30" 10-314" 7-518" 4-1/2" . GRADE Drive L-80 USS-95 L-80 CASING, LINER AND CEMENTING RECORD SeTTING DePTH MD SEl'TING DEPi'J.tTVD' . HÒLE lOP BoTTOM 'IOf? BOTTOM SIZE Surface 60' Surface 60' NIA 43' 5212' 43' 4437' 13-1/2" 41' 12721' 41' 10084' 9-7/8" 12517' 13285' 10058' 10088' 6-3/4" WT. PER FT.- Structural 45.5# 29.7# 12.6# 23. Perforations °Ren to Production (MD + TVD of ToE and Bottom Interval, Size and Number; if none, state' none"): None MD TVD MD 24. SIZE 4-1/2", 12.6#, 13Cr80 TVD Ft Ft 16. Property Designation: ADL 047502 17. Land Use Permit: 20. Thickness of Permafrost 1465' (Approx.) C¡;~ENTING RECORP AMOUNT . PULL.EP:. Driven 845 sx PF 'E', 625 sx Class 'G' 630 sx Class 'G' 180 sx Class 'G' TUBING RECÒRD DEPTH SET (MD) 11987' PACKER SET (MD) 11941' 25. AClò, FRACTURE, CEMENT SQU~, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12990' Set Whipstock ./ PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-BBL GAs-McF WATER-BBL GAs-McF WATER-BBL \ J b k'. løl~\olç" 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ..... Press. 24-HoUR RATE7 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". OIL-BBL None Form 10-407 Revised 12/2003 n~'f'!~,1 f\' ~ ' CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) R8DMS BfL JUM 0 3 70f'~ (:;r::;- ~ 28. GEOLOGIC MARKERS NAME MD TVD Kekiktuk 11855' 9726' K3A 11905' 9754' K2B 12179' 9913' Kekiktuk 12520' 10058' K3A 12593' 10073' k2B 12830' 10086' K2A 13201' 10089' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports ~ 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECJ=~' ,- MAY 2 ij 2004 & " . .. ..~M\)n A\aska Oil \j(>:, vOlh>- .,v, ." AnchlJifage 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHUbble~N\Ù ~ Title Technical Assistant Date 05-PlJ.0C{ END 1-65/N-25 195-188 303-362 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Johnson, 564-5666 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 8: ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 I"'- ~ Well: Field: API: Permit: 1-65A/N-27 Endicott Field 50-029-22627 -01-00 203-212 Accept: Spud: Release: Rig: Accept: 04/05/04 Spud: N/A Release: 04/18/04 . Rig: Nordic #2 , ,.. "" PRE-RIG WORK 01/08/04 ATTEMPT TO SET 3.81 XN PLUG. POOR JAR ACTION @ XN, UNABLE TO GET PLUG SET, POOH. CHANGE TO ROLLER STEM AND PUMP HOT DIESEL. SET 41/2" XXN TTP IN XN-NIP @ 11,969' SLM. 01/09/04 RAN 41/2 EQ PRONG TO EQUALIZE PLUG. PULLED 41/2" XXN TTP FROM XN-NIP @ 11968' SLM. (FINAL WHP T/I/O 725 780 0 FL ON TBG @ 500'). 01/18/04 PERFORM BOP TEST. LOAD WELL WITH 200 BBLS OF 1% KCL. RIH WITH 31/8" PDM WI 3.80" MILL. 01/19/04 RIH WITH MOTOR AND 3.80" MILL. MILL XN-NIPPLE AT 11975' TO 3.80" 10. DRY TRIPPED THROUGH NIPPLE OK. CONTINUE RIH WITH MILL. TAGGED BOTTOM AT 12991' MDBKB (CORRECTION BASED ON NIPPLE). POOH WITH MOTOR AND MILL. RIH WITH 3.0" JSN, FCO TO 13004' CTMD, MAKE THREE JETTING PASSES FROM TO TO TOP OF LINER AT 30 FPM. POOH WITH JSN. RIH WITH PDS MEMORY CALIPER ASSY. ~ 1/ 4 H WITH PDS MEMORY CALIPER. TAGGED PBTD @ 12998' CTMD. PU @ 12992' CTMD. LOG CALIPER UP FROM 12992' TO 11690' CTMD. POOH WI CALIPER. DATA GOOD (CORRECTED PBTD @ 13000' ELMD). CUT OFF 115' OF COIL FOR PIPE MANAGEMENT. MU AND RIH WITH WEATHERFORD DUMMY WS (3.70" DIA. X 17' LONG). TAG TO WITH DUMMY WHIPSTOCK @ 12992' CTMD. PU @ 12988' CTMD. POOH. RIG DOWN. G)FIED PAD OPERATOR TO PUT WELL BACK ON PRODUCTION. JOB COMPLETE. 0212 04 - 0= 2600/2100/250 (SHUT-IN WELL ON ARRIVAL) (PRE CTD). FLUID PACK IA WI 150 BBLS DIESEL. LOAD TBG WI FLO PRO THEN PERFORM PUMP IN TEST (466 BBLS FLO PRO PUMPED. RE SHOT IA FLUID LEVEL (1300 FT/34 BBLS) LOAD IA WI ANOTHER BBLS DIESEL. FINAL WHP'S=0/1000/0. 02129/04 PUMPED CAC03 AND FLOPRO PILL AND DISPLACED WITH SEAWATER TO CONTROL FLUID LOSS. PT LINES TO 3000 PSI AND PUMP INITIAL 4.3 BBLS OF SW. PUMP 94.3 BBLS OF CAC031N FLOPRO PILL. MAX RATE = 2.8 BPM. MAX PRESSURE = 1300 PSI. DISPLACE WI A TOTAL OF 113 BBLS OF SEAWATER. MAX RATE = 2.3 BPM. MAX PRESSURE APPROX. 1600 PSI. RATE FALLING TO 0.2 BPM AFTER 100 BBLS OF SEAWATER AWAY. 03/08/04 MU/RIH WI 2.5" JSN. TAG FILL @ 12388'. FCO TO 13013', PUMPING XTRA SLICK WI FLOPRO SWEEPS. POOH @ 80%. CUT 100' PIPE. MUIRIH WI BAKER WS DRIFT. 03/09/04 RIH WI DRIFT TO 13016'. POOH. PULLED HEAVY/CHOPPY FROM 12552'-12450'. MUIRIH WI SWS GRICCL IN CARRIER. TAG TD @ 13011', LOG UP TO 11700'. POOH. GOOD DATA. RDMO. 03/13/04 LOAD IA WITH 70 BBLS DEAD CRUDE. SET TWC. PT TREE TO 4000 PSI - PASS. FINAL T/IIO = 425/450/0. .. ,....... ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 1/1/m00 3/13/2004 0.00 MOB 2.25 MOB PRE PRE 18:30 - 18:00 - 20:15 P P 20:15 - 00:00 3.75 MOB PRE P 3/14/2004 5.00 BOPSUP P PRE 00:00 - 05:00 05:00 - 12:00 7.00 BOPSUF P PRE 12:00 - 13:30 1.50 BOPSUF P PRE 13:30 - 15:00 1.50 BOPSUP P PRE 15:00 - 15:15 0.25 CLEAN P WEXIT 15:15 - 15:30 0.25 CLEAN P WEXIT 15:30 - 16:00 0.50 CLEAN P WEXIT 16:00 - 18:40 2.67 CLEAN P WEXIT 18:40 - 18:50 0.17 CLEAN P WEXIT 18:50 - 19:15 0.42 CLEAN P WEXIT 19:15-21:45 2.50 CLEAN P WEXIT 21 :45 - 22:00 0.25 CLEAN P WEXIT 22:00 - 00:00 2.00 RIGU P WEXIT 3/15/2004 00:00 - 02:30 2.50 RIGU P WEXIT 02:30 - 04:15 1.75 RIGU P WEXIT 04:15 - 06:30 2.25 RIGU P WEXIT 06:30 - 07:30 1.00 RIGU P WEXIT 07:30 - 07:50 0.33 RIGU P WEXIT 07:50 - 09:30 1.67 RIGU P WEXIT 09:30 - 10:55 1.42 STWHIP P WEXIT 10:55 - 13:50 2.92 STWHIP P WEXIT 13:50 - 15:30 1.67 STWHIP P WEXIT Move from END 2-36 to END 1-65A Rig released from 3-17F at 1800 hrs Move rig off well and move to entrance of SOl PU matting boards and cellar liner Safety mtg re: next steps 1/2 of crew road to MPI and set matting boards and cellar liner on 1-65 while rig fin preps to move Safety mtg re: move to MPI Leave SOl at 2030 hrs and arrive MPI at 2230 hrs Back up and position rig on matting boards Safety mtg re: move over well Move rig over well and set down Accept rig at 0000 hrs 3/14/2004 Remove tree cap. NU BOPE Install sensors on lA, CA. Found IA ODS valve wouldn't seal (this was prior GLG side). Other side was double valved. Grease it, then add heat to warm up to get a seal Initial BOPE test. Witness waived by AOGCC WO DSM to pull TWC MIRU DSM. Pull TWC. RD DSM SIWHP 330, IA 470 Safety mtg re: kill well MU 3.80" D331 , motor, MHA for drift run/kill ops Attempt to bleed down pressure and declined to 80 psi. Monitor. Increased back to 300 psi and rising RIH w/ BHA #1 w/o pump holding 300 psi BP and taking MeOH, crude and KCI returns to flowback tank. Tag CIBP at 13077' CTD (counter error after CCAT shutdown) SafetylTL rntg (crews late due to BOC evacuation drill) Nordic working w/ one man short Start 9.5# used mud. Incr rate to 2.8/2300 holding 300 psi BP and fin circ 9.5# brine out of CT POOH displacing well bore to 9.5# mud Check returns after hole displaced and wellbore stable. Fin POOH and displ CT to FW near surface LD drift assy while displ CT to MeOH Fin displ CT to MeOH. Cut off CTC. Install internal grapple and PT Safety mtg re: pull CT to reel Pull CT to reel and secure Safety mtg re: reel swap (2) Fin secure and load out e-free 2-3/8" Load in 2-3/8" E-CT Safety mtg: pull CT and stab Install grapple connector. Pull CT to floor and stab. Check fluid level and stable at surface. SI swab Fill CT w/12 bbls MeOH, 15 FW followed by mud at 1.3 bpm. PJSM. Stab onto well and pump slack back. Cut 60' coil. Pull test 35K. Rehead coil. Circulate to warm coil. PT coil and MU Whipstock BHA. RIH with whipstock to 12490. Tie - in log. Correction -16'. Intermittent data from MWD Bi Printed' 411912004 12'10 34 PM -- ,,-..., ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 311512004 13:50 - 15:30 1.67 STWHIP P WEXIT 15:30 - 17:05 1.58 STWHIP N DFAL WEXIT 17:05 - 20:00 2.92 STWHIP N DFAL WEXIT 20:00 - 20:45 0.75 STWHIP N DFAL WEXIT 20:45 - 23:15 2.50 STWHIP N DFAL WEXIT 23:15 - 00:00 0.75 STWHIP N DFAL WEXIT 3/16/2004 00:00 - 02:30 2.50 STWHIP N DFAL WEXIT 02:30 - 03:30 1.00 STWHIP N DFAL WEXIT 03:30 - 06:00 2.50 STWHIP N DFAL WEXIT 06:00 - 06:45 0.75 STWHIP N DFAL WEXIT 06:45 - 07:11 0.43 STWHIP N DFAL WEXIT 07:11 - 09:15 2.07 STWHIP P WEXIT 09:15 - 10:20 1.08 STWHIP P WEXIT 10:20 - 13:00 2.67 STWHIP P WEXIT 13:00 - 17:00 4.00 STWHIP P WEXIT 17:00 - 17:35 0.58 STWHIP P WEXIT 17:35 - 19:05 1.50 STWHIP P WEXIT 19:05 - 21:50 2.75 STWHIP P WEXIT 21 :50 - 22:08 0.30 STWHIP P WEXIT 22:08 - 22:30 0.37 STWHIP P WEXIT 22:30 - 00:00 1.50 DRILL P PROD1 3/17/2004 00:00-01:10 1.17 DRILL P PROD1 01:10-01:35 0.42 DRILL P PROD1 01 :35 - 03:50 2.25 DRILL P PROD1 03:50 - 04:05 0.25 DRILL P PROD1 04:05 - 04:45 0.67 DRILL P PROD1 04:45 - 04:50 0.08 DRILL P PROD1 04:50 - 05:20 0.50 DRILL P PROD1 05:20 - 06:00 0.67 DRILL P PROD1 06:00 - 08:30 2.50 DRILL P Directional Communiction Module. Tool cycling between operational t perational. RIH tag 13020. PU to place top of WS at 2990' Commu' n problem continue. Attempt to recover communication to orient. POH MWD failure. Tool restarted and worked for a while. Head back in hole, but quit again. Resume POOH Check WS, okay. Change power and comms sub on BHI BHA RIH wI BHA #3. Tool worked okay to 8000' then intermittent. RIH to 12500' and prepare to tie-in and tool comms not functioning (this also means BHA cannot be disconnected) POOH for MWD failure Stop at 8000' and continuity test at reel (1 hr) wI jumper. Tools powered up, but quit. Resume POOH Check WS, okay. Change power and comms sub for one with baud rate to short reel version and surface test, okay RIH wI BHA #4. Check tool every 2000' 12500' Begin tie-in. Correction -15'. Relog to confirm. OK. RIH. Tæ021. UP WT 55k. Dn Wt 23K. PU place Top of WS a 299 . Orient 92.1 R. Close EDC. Pressure to 4000 psi & hol . 5K & pressure to 4480 psi to shear. Set down 3K. to confirm set. O.K. POH. LD WS setting assy. MU milling assy RIH wI BHA #5 Start milling window fl 12990' 2.65bpm 3650psi free-spin maintaining +1- 100 psi motor work 1-2k wob. Bottom of window appears to be 12999'. "Fast window?" Drill formation fl 12999' to 13009' Reaming window, Reamed 3 times, 3.78" string mill and dry tagged, clean. Pumped 20 bbl HVis sweep POOH with sweep gone. ( Painted Flag at 12800 ft) PUH inspecting CT as per SLB SOPs dealing with Cr tubing Area is at 2.2" ovality LD window exit BHA in preparation of cutting of CT Window mill at 3.79 in, String 3.78in Cut 40 ft CT and rehead as per BHI SOP's. Pull Tested to 35k Ib Finish Re-head CTC, PT CTC to 3500 psi PU BHI BHA wI 1.5 AKO. Off set at 55.7 deg, tested tool at surface RIH. Seen the milled out "XN" nipple at 11975 ft (+6ft) while RIH Tie-in from 12480 ft to 12521 ft (-18 ft correction) RIH, no tag at 13015.3 ft Vp = 414 bbl, Btm up = 142 bbl PUH to confirm Tie-in before preceeding deeper to 12470 ft Tie-in (+3 ft correction) RIH, motor work at 13017' PU, clean, RIH to 1302 t 60 to 70 fph. PU 13025' TF a . 2.58 bpm, ROP at40f h ontinue drilling ahead. Picked up RA's at 13002' 2.6 bpm ann= 5659psi 10,88 ecd 3550 free-spin 3-400psi mw 2-3k wob 70'/hr Drill to 13170' Pnnted, 4/19/2004 12:10:34 PM WJJ...L LOG I Iq5-IS~ TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE : Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration (Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LB2-1 P. O. Box 1369 900 East Benson Blvd. Stafford, TX 77497 Anchorage, AK 99501 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 Res. Eva!. CH 1 . 1 1 1-65/N-25 1-19-04 Mech. GH };:~1~5<:~ Caliper Survey ~ ~ ~'\ Signed: ~~ \ ~~ ""I' ~.JJ !ê'o... ~ /V'.. Date: -REGEIVEÐ Print Name: . 2 '" ')004 JAN 9 t.. ,AJaskl Oil & Gas Cons. Commision Anchorage PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 }69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com SGÁ~~~~ErC' FEB {); 2 [,D04 -'~~~þ ,\\~ " ~ \)..Jú IT- 12..[ ~ lweI's STATE OF ALASKA D ~ ~2J 10 I 3. ALASKA OIL AND GAS CONSERVATION COMMISSIONlJrj~/lêJ APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: ~ Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Other 0 Alter Casing 0 Repair Well ~ Plug Perforations 0 Stimulate 0 Time Extension 0 ChanQe Approved ProQram 0 Pull TubinQ 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number/" BP Exploration (Alaska) Inc. IBI Development 0 Exploratory 195-188 3. Address: 0 Stratigraphic 0 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22627-00-00 7. KB Elevation (ft): KBE = 56 9. Well Name and Number: / END 1-65/N-25 8, Property Designation: 10. Field / Pool(s): ADL 047502 Endicott Field / Endicott Pool 11 ,', ". "~, , "."" ' ," ".;",.,'i' ,", "",;,,"\ 'I, ""'."',"PRESENIWELLCONQITION'SQfV1fv1AR¥'""";\i,,,,""'",:,,',,:','. .,1:"',,...'.,. '..'",ii;i..", i' i, ;', 'i, ",' , ,i:"" ',I ,;i ""i ",,' i", i" ,,:,,',' ; " , '",,' ",", "'",,, "" ",',; ':""', ", "", "" , '" " ,', , ,:", ;,""""":"," ,':i'" ;.'"'i';,, ",,; i'; " ',',' 1," ' "", ",' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measu~): Junk (measured): 13286 10088 13198 10089 13010 None ,Cäsing i " Length '" ' ' . Size, ", 'MD " ',TVD ,Burst .Collapse ' ' Structural r.nnrh 'I'tnr 60' 30" 60' 60' SlJrf:::¡CA 5169' 10-3/4" 5212' 4437' 3580 2090 -,. - ~ 12680' 7-5/8" 12721' 10084' 8180 5120 1I1lt::1 P Liner 768' 4-1/2" 12517' - 13285' 10058' - 10088' 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12488' - 13100' 10049' - 10089' 4-1/2" 13Cr80 11987 Packers and SSSV Type: 7-5/8" Baker 'S-3' packer Packers and SSSV MD (ft): 11941' 4-1/2" HES 'HXO' SSSV Landing Nipple 1570' 12. Attachments: 13. Well Class after proposed work: IBI Description Summary of Proposal 0 BOP Sketch 0 Exploratory IBI Development 0 Service 0 Detailed Operations Program 14. Estimated Date for /' 15. Well Status after proposed work: Commencing Operations: December 15, 2003 IBI Oil 0 Gas 0 Plugged 0 Abandoned 16. Verbal Approval: Date: 0 WAG DGINJ DWINJ 0 WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Johnson, 564-5666 Printed Name. Mark Johnson n Title CT Drilling Engineer Prepared By Name/Number: SiQnature ¿J1~ O. L L~ Phone 564-5666 Date f ~/'f /0 "] Terrie Hubble, 564-4628 " " , " "/I,: ,Commis$ion'UseOnly". ' " , ," '" , , ", ,/ l I Sundry Number: ?')o 3 - 3& 2, i .I Conditions of approval: Notify'é'ommission so that a representative may witness 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance RECEIVED Other: DEC - 5 2003 L 01. Alaska Oil & Gas Cons. Commission Subsequent form required 10- Anchorage Oñg~na~ Signed By I~ ' O()¡ Sarah Palin BY ORDER OF 10 Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 2/2003 Submit In Du licate :§((;AIMNEf)]) DEl~ ~fØ18S Bfl nEC 1 0 JI6b RIG I N A L p (~f' h [IÌ../:] rÄ ¡¡ r - .. ~" , ¡ 1 r r'û <Ðì ' t1 fi1 oj) 1;, \\ßlri\ Il::i 11 ~ ,E:n)i :) h:.1L~ ¿j¡ @ !u OJ 'i/I ~~t~~ ~ . ~¡:::.;'.:..:.:';:~:?; t'1f1 ~::;;::::¡ii~ ~'~,,~ ~~ "'W¥~~ To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mark O. Johnson CTD Engineer Date: December 3,2003 Re: P&A operations for Endicott welll-65/N-25 as part of the CTD sidetrack Endicott welll-65/N-25 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing / prilling rig 011 1/15/04. The sidetrack, 1-65A/N-21, will exit.mtt.efthe existing 4 Yz" liner frOlll a whipstock at /12990' md. The existing perforations in 1-65/N-25 will be abandoned by liner cement from the 1-65A/N-21 r' liner. The following describes work planned for the P &A and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summarv (phase 1\ ~) Slickline -Drift tubing. Dummy GL Vs, Pressure test IA to 3000 psi. /' 2) CT - FCO" log me,mory caliP, er in 'horizontal 4 Yz" liner, bullhea,d CaCO3 to reduce permeability of existin~ p'erforations; mill XN nipple to 3.80" ID, cleanout liner, drift for whipstock. ~ TkÁ<;. 10 - 4o~ A- )fhNd. CTD Sidetrack Summarv (phase ~ 1) MIRV CTD rig, 2) Set 4 Yz" LSX whipstock at 12990' md. 3) Mill window with 3.80" OD diamond speed mill. 4) Drill 3.75" openhole sidetrack to ",15430' TD with MWD/gamma ray/resistivity. 5) Run 3 1/2" x 2 7/8" solid liner completion and cement with 30 Bbls of 15.8 ppg class G cement. Bottom of liner at TD, top of liner at ",11970' md. WOC. Pressure test liner and lap to 2000 psi. Run liner top packer if needed. P&A of 1-65/N-25 is complete, 6) Perforate 1-65A/N-21 liner. 7) RDMO. c~ The pre CTD work is slated to begin on 12/15/03. ~ú.~ Mark O. J ohnson/"i' CTD Drilling Engin~/ 564-5666, 240-8034 CC: Well File Sondra Stewman/Terrie Hubble START BUILDING >- ANGLE 4-1/2" 'X' NIPPLE 111930' I @ "'11500' (34°) (3.813" 1.0.) 7 -5/8" BAKER "5-3" 4-1/2" 'X' NIPPLE 4-1/2" 'XN' NIPPLE (3.725" 1.0.) 111988' I 4-1/2" WLEG ELMO: Ref 1/18/96 SBT 112004' I BAKER "SBP" I 12517' I 7-5/8", 29.7#/ft, NT95HS, NSCC Liner Top Pkr 12721' I > DEV = 74° KB. ELEV = 56.00' BF ELEV = 15.00' MAX DEV = 90° (12770' - 13285') HORIZONTAL COMPLETION KOP = 300' 10-3/4", 45.5#1ft, L-80, BTC I 5212' I >- 4 1/2" 12.6# L-80 NSCT Perforation summary Ref Log: 1/18/96 Atlas SBT/GR Interval 12730-13100 12504-12524 12488-12508 Status Date SPF Open 1/96 6 Open 11/99 6 Open 9/00 6 TREE: COOPER 4-1/16" 5000 psi WELLHEAD: FMC SSH 13-5/8" 5000 psi 0 SSSV LANDING NIPPLE HES "HXO" (3.813" 1.0.) 1569 4-1/2", 12.6#/ft, NSCT 13CR80 tbg GLM's, HES MBX 9CR , 1" BK NO. TVDSS MD-BKB 6 3538 4133 5 5197 6237 4 6236 7547 3 6956 8462 2 7639 9336 11941' 11965' 11975' 12730' DPC 6 SPF -< K-1 Cement retainer 113010' I 13100' 4-1/2", 12.6#/ft 113285' I L-80 NSCT Date B Comments ENDICOTT WELL: 1..65/N..25 1/30/96 TLR COMPLETION API NO. 50..029..22627..00 12/15/99 TP Add-perfs COMPLETION DIAGRAM 9/30/00 MAS Add-perfs & corrections 4/20/01 MAS Cement retainer BP EXPLORATION (ALASKA), INC '" , .. KB. ELEV= 5600' 1-65A1N-27 Proposed ,/ BF ELEV = 15.00' TREE: COOPER 4-1/16" 5000 psi MAX DEV = 90° (12770' -13285') WELLHEAD: FMC SSH 13-518" 5000 psi HORIZONTAL COMPLETION KOP = 300' 10-3/4", 45.5#Ift, L-80, BTC I 5212' I >- GLM's, HES MBX 9CR, 1" BK NO. TVDSS MD-BKB 6 3538 4133 5 5197 6237 4 6236 7547 3 6956 8462 2 7639 9336 1 8323 10209 7-5/8", 29.7#Ift, NT95HS, NSCC 112721' 1 >- Interval 12488-12508 12504-12524 12730-13100 Status Date SPF Open 9/00 6 Open 11/99 6 Open 1/96 6 K-1 Cement retainer @ 13010' 0 0 13100' 4-112", 12,6#1ft l.J3285' I L-80 NSCT Date By Comments 1/30/96 TLR COMPLETION 1 2/1 5/99 TP Add-perfs 9/30/00 MAS Add-perfs & corrections 4/20/01 MAS Cement retainer 1/11/03 MOJ CTD ST Pro ased 0 SSSV LANDING NIPPLE HES "HXO" (3.813" LD.) 1569 4-1/2", 12.6#1ft, NSCT 13CR80 4-1/2" 'X' NIPPLE (3.813" LD.) 7 -5/S" BAKER "S-3" 4-1/2" 'X' NIPPLE 4-1/2" 'XN' NIPPLE (milled to 3.80" 1.0.) 4-1/2" WLEG I ELMD: Ref 1/18/96 SBTI 111930' I 11941' 11965' 11975' 11988' I 12004' I BAKER "SBP" I Liner Top Pkr 12517' DEV = 74° 1-65A1N -27 CTD Sidetrack 3 1/2" 9.3# 13Cr80 liner \ /' \ 2 7/811 6.5# XO at 13Cr80 liner TD @ 13050' 15430 MD 63/4" bit size ENDICOTT WELL: 1-65/N-25 API NO. 50-029-22627-00 COMPLETION DIAGRAM BP EXPLORATION (ALASKA), INC MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser,~'~%~ Commissioner Tom Maunder, ~_,_~~o~. P. I. SupervisoK'v~- ~.5~0 ~ FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI I & 2 May 20. 2001: ! traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. i inspected 25 well houses on MPI Row 1 & 2 w/no problems witnessed. SUMMARy: I witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. Attachm. en..ts: SVS DIU 5-20-01jc cc; .NON-CQNF.ID.EN!!AL SVS DIU 5-20-0 ]jc Alaska Oil and Gas Conservation Commiso.on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Crisp. , Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: LPS 235 Date: 5/20/01 HPS i i i iiii i Well Pemit Separ Set' L/P Test Test Test Date Oil, WAG, GINJ, · Number Number PSI PSI Trip Code Code Code , , Passed GAS or,CYCLE 1-01/J19 1880370 235 150 125 P P P OIL 1-03/P16 1951500 235 150 135 P P P OIL 1-05/O20 1861060 ' ~ ' 1-09A/L2 '1970290! 235 1501 ' 130 P 'I3.. P ' OIL 1-15/P25 1930560 ' ' ' 1-17A/Il 1961990 1-19/I18 '1950930 235 150 125 P' P 9 1-21/K25 1900020 1-25MK2 1970750 235 150 150 P P ' P oil 1-27/P20' 18700~0 235 150 135! ' P P P ~ OIL 1-31/M21 1950720 235 150 125 P'' P' ~ P .... 0IL 1-33B/L2' 1982550 '~35 ~50 145 P ' P P .... [1-35/025 1861840 235 150 135 P P P oIL , 1-39/P17 1880630 ~]-45/Q26 1891240 1-47MM2 1972030 "1-49/P21 1880780 23~ 150 130 P P P L oIL 1--'55/R25 1880210 235 150 145 P P P OIL 1--57/R23 1881140 235 150 140 P P P OIL 1-61/Q20 1941420 235 150 135 P "P" p' ' '~ ' OiL 1-63/T22 1890060 23'5 150 145 P P P OIL 1-65/N25 1951880 235 150 150 P P P OIL 2-04/M19 1860820 2-06/J25' 1870180 ~..... 2-08/K16 1880040 ......... 2-12/Q16 1921170 2-14/016 1861490 2-18/L16 1900430 ....... 2-20/L15 1900600 ~2-26/N14 188055'~J 2-28/P19 1880860 ......... 2-30A/Ei i'~81880 ........... 2-32/SN3 1901190 .......... 2-36/O14 1900240 ,, , 2-38/SN1 1901290 2-fiq/ng¢~ n/, ~11941520 po-, 1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ,2-42/P13 1881450 :2-44A/Q'l 1¢;/0710 ..... 2-46B/S1 1971370 2-48/O13 1951660 2-50/U08 .... 1930670 235 "'i50 145 ..... p, p,r, e 0IL 2-52/S14 1870920 2-56A/EI 1980580 2-58/~09 1900520 ..... ' ......... 2-60/U13 .1930836,', ,, 235 150 130 P P V .1 ...... OiL 2-62/Q17 1861580 2-68/817 1880970 5.0i/sD7 '18'01200 ........ Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.9t5% 1"lo0 oar Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc STATE OF ALASKA OIL AND GAS CONSERVATION COMM~ .... 'ON REPORT ,JF SUNDRY WELL OF RATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Perforate__ Pull tubing__ Alter casing __ Repair well Other. x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E At top of productive interval 198' NSL, 4485' EWL, SEC. 31, T12N, R17E At effective depth 22' NSL, 4750' EWL, SEC. 31, T12N, R17E At total depth 23' SNL, 4825' EWL, SEC. 6 T11N, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ .'-APR i 3 2001 ,'~'dask8 Oil & Gas C,'~n~ Anchoraqe 6. Datum elevation (DF or KB) 56' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-65/N-25 9. Permit number/approval number 95-188~Not Required 10. APl number 50- 029-22627 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 13286 feet Plugs (measured) 10088 feet BKB 13198 feet Junk (measured) 10089 feet BKB Size Cemented Measured depth BKB True vertical depth BKB 19' 30" Driven 60' 60' 5169' 3-1/2" 845 sx PF E', 625 sx 'G' 5212' 4397' 12680' 9-7/8" 630 sx Class 'G' 12721' 10076' 768' 6-3/4" 180 sx Class 'G' 13285' measured 12488'- 12508'; 12730'-13010'(open) 13010'-13100'(squeezed) 10088' true vertical ¢¢P3' - ¢¢¢P'; 1002¢'-10032' (open), 10032'-10033' (squeezed) Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, NSCT 13CR80 set at 11,988' Packers and SSSV (type and measured depth) 7-5/8" Baker "S-3" set at 11,941' and Baker "SBP" Liner Top Packer set at 12517' (Deviation = 74 degrees) 13. Stimulation or cement squeeze summary NRWO Geme~squeeze WSO (2/13/2001) Intervals treated (measured) 13010'- 13100' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 1126 15867 8665 0 698 4269 10941 0 Tubing Pressure 1720 395 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 ~'edify that the.foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06,15,88 Gi L Date 04/05/01 SUBMIT IN DUPLICAT ~-.. ~-.-- Page 1 of 3 Well Service Report Well IlJob Scope II Job Number END1-65 IICEMENT SQUEEZ~ 110209011533.5 Date IIDaily Work IlUnit Number 02/13/2001 CEMENT SQUEEZE: MARASEAL GEL SQZ THRU CTU #3 RETAINER Day IlOP~aOon Complete IlSuc¢~rul False HKey Person [[Supervisor Ilus- IC sr ll M-GOLD G IField I[AFC# Ilcc# IlOaUy Cost IIAccum Cost IlSigned I [ ? II N10165 II m wo- II 45203 II 57463 II Init Tbg Press 2200 IIFin~l Tb~ ~s Ili~it Inner Ann II 1000 Il 500 II~-inal Inner Ann II~it Outer Ann ])*inal Outer Ann II 450 II 0 II 0 Daily CONTINUED FROM 02/12/01 WSR .... LOADING WELL W/SEAWATER. PUMP Summary 232 BBLS SEAWATER. RIH W/3.625 CEMENT RETAINER, TIE-IN @ TBG TAIL, SET RETAINER AT 13010'. CONFIRM SET W/5K SET DOWN WT. POH AND LD SETTING TOOL. RIH W/STINGER. REKIlJL WELL AS RIH. CIRC IN EDTA, STING INTO RETAINER, PUMP 200BBLS MARASEAL. WHP REMAINED CONSTANT. UNSTING.FREEZE PROTECT WELL AND CT. RDMO. NOTIFY WELL TENDER WELL REMAINS SI FOR 4 DAYS. (LOST IN WELL-METAL RING FOR TOP OF BOW SPRING. SUSPECT ON SWAB VALVE. DRAWING IN FILE) [Cement-Poly Squeeze] ITime I[Log Entry 00:01 CONTINUED FROM 02/12/01 WSR. LOADING WELL WITH SEAWATER AT 3.5 BPM. WORK RATE UP AS WHP FALLS OFF. 00:45 11120 BBLS AWAY, RATE- 5.1 BPM, WHP = 1420 PSI AND FALLING. I 01:10 232 BBLS SEAWATER AWAY. SWAP TO 60/40 MW AND PUMP 3 BBLS DOWN BACKSIDE TO FP SURFACE LINES. SD PUMP. RIH W/RETAINER. 01:57 WEIGHT CHECK AT 5300' CTM= ll.5K; @ 8300' CTM= 18K; @ 11900' CTM = 28K. 03:00 RIHTO 12100' CTM. PUH LOOKING TO LOCATE "XN" NIPPLE AT 11991' ELM. LOCATED TWICE AT 12000' CTM. LOCATE A 3RD TIME AND PARK COIL. CORRECT DEPTH (PLACES ELEMENT AT 12001' ELM). RIH. 03:20 DID NOT "SEE" LINER TOP. RIH TO 13040' CTM, PUH W/29K. PARK COIL W/ELEMENT AT 13010'. DROP 0.5" BALL AND COME ON LINE DOWN THE COIL PUMPING 60/40 MW AT 2.0 BPM. 03:49 BALL SEATS W/28.4 BBLS AWAY, SHEARED OFF AT 4700 PSI. PAINT FLAG. SD PUMP W/30 BBLS 60/40 AWAY. STACK 5K ON PLUG. IT IS THERE. POOH. WHP = 600 PSI AND SLOWLY INCREASING. , http://amancs402.anc.xwh.bp.com/sst_dril.../wellevent_awgs.asp?ID=END 165213200106480 4/5/2001 Page 2 of 3 {Al bUled~ALl~,. Wl-ll" = IOtR) V31. DLIgP_.,D Ul'q-~ WI-It', I"UI" UPI~ WP-,LL. LD {SETTING TOOL AND NIPPLE LOCATOR. MAKE-UP 2-1/8" FIXED SPRING {CENTRALIZER AND 3.69" STINGER. NEW OAL = 14.27 . 06:45 IIPRE-JOB SAFETY MEETING. STAB ON WELL, FLUID PACK WITH 60/40 07:00 IIP ssuP TEST LUBRICATOR AND SURFACE LINES. o?:o8 lioN LINE WITH WATER TO REKII,L WELL. SIWHP-1180. 07:15 I[WHP-900 30 BBLS C-H20 AWAY. RIH WITH CT. SWITCH TANKS. 07:57 Il'sD WATER ON BACKSIDE. SWITCH TO MEOH TO FREEZE PROTECT BS ILINE. (144 BBLS C-H20 AWAY). SIWHP-434. I 08:23 IIwT CK AT 6000 IS 12.3K, 11000 IS 27K, 12970 IS 28.5K. 11:06 I[SIWHP-980. ON LINE WITH C-H20 TO REFLUID PACK. PUMPERS ON ILOCATION RU AND MIX 30 BBLS EDTA. 11:36 PUMPING DOWN BS. (100 BBLS AWAY) FREEZE PROTECT LINE WITH 3 IBBLS MEOH. WHP-450. SAFETY MEETING. DISCUSS HANDLING AND INEUTRALIZING MARASEAL. 12:06 IIPe~sstJe~ TEST LINES. 12:10 liON LINE WITH EDTA. SIWHP-500 CTD-12952. 12:29 IISWlTCH TO C-H20. (30 BBLS EDTA AWAY). WITH 15 BBLS OUT NOZZLE IWING. RECIPROCATE ACROSS PERFS WITH REMAINING. EDTA. 12:52 lioN LINE MINIMUM RATE. SIWHP-890 CTP-300. RIH TO STING IN. NO IPROBLEM STINGING IN. SEE PRESSURE INCREASE. HOWEVER UNABLE lIN INJECT INTO. 13:00 IIUNSTING. PICK UP. SD PUMPING. RE-STING IN. CTP PRIO TO STING IN IS 1500 PSI. STING IN-QUICKLY CLIMBS TO 3500. (0.2BBL.) SD AN MONITOR ]CTP. DROPS TO 1000 IN 11 MINUTES. 13:17 IICTP DROPS FROM 300 TO 80. ON LINE AT 0.3 B/M. CTP-289. WHP SAME. IieqCe ASE TO 1 gm{. CTP-lm0. mX CHEMICnLS e4 13:45 lioN LINE WITH MARASEAL. 1 B/M AT 950. 2 B/M AT 3460. 13:s8 Ilw.P-1258 CTP-3817 RATE-1.6 B/M. 30 BBLS AWAY. 14:52 I[100 BBLS AWAY. WHP-1254 CTP-3483. RATE 1.5 B/M. 15:18 IlwHP-1269 CTP-3487 140 BBLS AWAY. is:sa 112oo BBLS MARASEAL AWAY. SWITCH TO WATER. WHP-1276 CTP-3738 IIRATE-1.5 B/M. 16:21 PULL OUT OF RETAINER. PULLING WEIGHT (5K OVER TO UNSTING). ON LINE WITH PUMP DOWN CT TO DISPLACE. DUE TO PULLING WEIGHT WE MAY HAVE PUT MARASEAL ABOVE THE RETAINER. NOT SURE DUE TO THE FACT THAT THE WHP REMAINED CONSTANT THROUGHOUT JOB. HOLD WHP AT 1280. FREEZE PROTECT COIL AND WELL AS POH. I 18:01 IIoo~. RDMO. SIWHP-1000 http://amancs402.anc.xwh.bp.com/sst_dril.../wellevent_awgs.asp?iD=END 165213200106480 4/5/2001 Page 3 of 3 IISer,ice Company - Service ITotal Field Estimate ]lDaily Cost [[Accum Total II II 45,2°3.°°11 ? Fluid 362 BBLS SEAWATER 96 BBLS 60/40 METHANOL WATER. 30 BBLS EDTA Summary !200 BBLS MARASEAL. http://amancs402.anc.xwh.bp.com/sst_dril.../wellevent_awgs.asp?ID=END 165213200106480 4/5/2001 ~- .... Page 1 of 1 Well Service Report Iwen Il Job Scope Il job Number I~D~-65 IIC~mmT SQU~z~ 110209011533.5 IDate IIDaily Work ][Unit Number 02/12/2001 CEMENT SQUEEZE: MARASEAL GEL SQZ THRU CTU #3 RETAINER Day [IOperation Complete II'succ~sful 0 !1 False II False IlKey Person I[Supervisor IIDS-B~GGERST~I ~EM-GOLD~G Field IlAFC# Ilcc# IIDaily Cost IIAccum Cost I[sig~ed ~ II N10165 II NRWO- II 82~8 II 57463 Init Tbg Press I[Final W~g ~r~ IlI~ Inner Ann 2650 II 2600 II 500 IlFin~l Inner Ann Ilinit Outer Ann llFinai Outer Ann Il ~oo II o II o Daily MIRU DOCT #3. SHUT WELL IN. START LOADING WELL W/SEAWATER Summary AT END OF REPORT. OPS CONTINUE ON NEXT W.S.R. [Cement-Poly Squeeze] ITime IILog Entry ~9:oo ~mu ~OCT #3 (^~VOO~m~C~a~ST^~ w/~n63s' O~ TAPa~ ~-~/4" CO~, 547K ~, 32.9 BBL CAPAC~Y.) WELL IS SHUT-~ (SSV CLOSED). 2~:a0 llm~-um 2.75" rom CO~ECTOR. P~L ~ST TO 20K. I 22:15 ~~-UP 3" CHKS, 3" DISCO~ECT. PT TOOLS TO 35~ PSI. ~~-UP 3- 3/8" N~PLE LOCATOR, 2.80" SE~G TOOL, 3-5/8" CEmNT ~T~E~. O~ = 16.40'. LOCATOR TO ~-ELEmNT TO 9.86'. 23:~ IILAY~G BACKSIDE L~E. ST~ ON roLL. I 23:40 I~U~ PACK ~TH 60/40 ~ ~D ~ ~L TO 4~ PSI (GOOD TEST). OPEN uP m~ (26s0 PS~. [m~ up ~0 ~20 ~~ s~w~~ ~OWN ~.~ BACKS~E. 23:59 P~~G SEAWATER DO~ THE BACKS~E AT 3.0 BPM AT END OF ~PORT. CON~ED ON 02/13/01. Service Company - Service Total Field Estimate [[Daily Cost [[Accum Total II 8,2~8.0011 ]Fluid ,Summary 115 BBLS 60/40 METHANOL WATER II http://amancs402.anc.xwh.bp.com/sst_dril.../wellevent_awgs.asp?ID=END 165213200100142 4/5/2001 ........ Page 1 of 1 Well Service Report IWell II Job Scope lEND 1-65 IICEMENT SQUEEZE IDate ]lDaily Work 103/09/2001 IICEMENT SQUEEZE: DRIFT Il Job Number 1[o2o9o 11533.5 Ilunit Number IIHES 70311 Day ]lOperation Complete IlSucc~f~ Ilgey Person IIsupervisor o Il FalseII FalseII HES-NYQUIST l[ SPEARMAN Field ]IAFC# Ilcc# IIDauy Cost IlAccum Cost ~ II N10165 II NRWO- II 2082 Il 57463 IISigned Tbg Press Ilvi~ Tbg Press IlImt Inner Ann IlFin~l Inner Ann IIImt Outer Ann ~0 I1 82~ II 2100 II 1550 II 3~0 IlFinal Outer Ann II 0 Daily DRIFTED TO 12,513' WLM W/3.625 SWADGE, STOPPED DUE TO Summary DEVIATION POP ITime ]lLog Entry 15:15 SAFETY MEETING, S/I LIFT GAS, RIG UP, PRESSURE TEST SURFACE EQUIP: 5 MIN L/P 10 MIN H/P 16:30 RIH W/2 1/2" ROLLER STEM TOOLSTRING(2.72 WHEELS), TOOLS STOPPED @ 12,513' DUE TO DEVIATION(CORRECTED DEPTH IS 12,554' USING BF/KB M~AS~mNT OF 41'), POOH I 18:45 IIOOH W/TOOLS, RIG DOWN I 19:10 Ileom w/LIFT GAS Ilservice Company - Service ITotal Field Estimate [IDailY C°st IlAccum T°tal II 2,082.0011 ? iSummary PUMPED 1 BBL OF DIESEL FOR PRESSURE TEST http://amancs402.anc.xwh.bp.corn/sst_drilli.../wellevent_awgs.asp?ID=END 16539200114351 4/5/2001 STATE OF ALASKA ALAS~=;- OIL AND GAS CONSERVATION COMMISF ....... ~ REPORT L,F SUNDRY WELL OPE {ATIONS 1. Operations performed: Operation shutdown~ Stimulate ~ Plugging Pull tubing ~ Alter casing __ Repair well Perforate × Other~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 3058' NSL, 2218' WEL, SEC. 36, T12N, R 16[: At top of productive interval 198' NSL, 4485' EWL, SEC. 31, T12N, R17E At effective depth 22' NSL, 4750' EWL, SEC. 31, T12N, R17F At total depth 23' SNL, 4825' EWL, SEC. 6 T11N, R171= 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 56' KB 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-65/N-25 9. Permit number/approval number 95-188~Not Required 10. APl number 50- 029-22627 11. Field/Pool Endicott Field/Endicott Pool feet 12. Present well condition summary Total depth: measured true vertical 13286 feet Plugs (measured) 10088 feet BKB Effective depth: measured true vertical 13198 feet Junk (measured) 10089 feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 19' 30" Driven 5169' 3-1/2" 845 sx PF E', 625 sx 'G' 12680' 9-7/8" 630 sx Class 'G' 768' 6-3/4" 180 sx Class 'G' measured 12488'- 12508'; 12730'-13100' Measured depth BKB 60' 5212' 12721' 13285' True vertical depth BKB 60' 4397' 10076' 10088' true vertical 9993' - 9999';10029'-10033' Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, NSCT 13CR80 set at 11,988' ."~,'~.',.~" '::¢ Packers and SSSV (type and measured depth) 7-5/8" Baker "S-3" set at 11,941' and Baker "SBP" Liner Top Packer set at 12517' (Deviation = 74 de.qrees) 13. Stimulation or cement squeeze summary Reperforation (9/30/00) Intervals treated (measured) 12488'- 12508' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1511 5354 6665 0 744 3051 11904 0 Tubing Pressure 1654 267 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 certify that the foregoing is true and correct to the best of my knowledge. ' d Signed ; _E ~-'~'L CC-~'¢_~. ; Title Senior T~chnice! Assistant IV Form 10-404 Rev 0~15/88 Date 10/8/00 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department Endicott WELL SERVICE REPORT PI(END1-6S(W4-6)) WELL JOB SCOPE JOB NUMBER END1-65 PERF(REPERF) 0928002028.9 DATE DAILY WORK UNIT NUMBER 09/30/00 PERF'D SAFE F/12,488' TO 12,508' SWS 2150 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-CLASPER SAUVE FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE $13,440.00 $13,440.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 1750 PSI 1800 PSI 1750 PSI 1800 PSII 250 PSI 0 PSI DAILY SUMMARY I PERFED INTERVAL 12488'-12508' W/2-7/8" PJ 2906 6 SPF TIME 10:15 11:00 12:15 12:30 13:30 14:00 14:05 14:10 15:00 15:30 LOG ENTRY LEAVE SWS SHOP ARRIVE ON LOCATION, START RIG UP PRESSURE TEST TO 3500 PSI RIH W/3.5" ROLLERS, 20' GUN, PGGT START FLOWING WELL SHOOT INTERVAL 12488'-12508' START POOH SHUT IN WELL TO POOH START RIG. DOWN RIGGED DOWN, LEAVE WELL FLOWING SERVICE COMPANY-SERVICE SCHLUMBERGER TOTAL FIELD ESTIMATE DAILY COST $13,440.00 $13,440.00 ACCUM TOTAL $13,440.00 $13,440.00 STATE OF ALASKA ALAS~-~. OIL AND GAS CONSERVATION COMMISS!ON REPORT L.,: SUNDRY WELL OPL. ATIONS 1. Operations performed: Operation shutdown_ Stimulate.__ Plugging Pull tubing ~ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E 5. Type of Well: Development .. Exploratory Stratigraphic Service __ 6. Datum elevation (DF or KB) 56' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-65/N-25 At top of productive interval 198' NSL, 4485' EWL, SEC. 31, T12N, R17E At effective depth 22' NSL, 4750' EWL, SEC. 31, T12N, R17E At total depth 23' SNL, 4825' EWL, SEC. 6 T11N, R17E 9. Permit number/approval number 95-188/Not ReQuired 10. APl number 50- 029-22627 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 13286 feet Plugs (measured) 10088 feet BKB 13198 feet Junk (measured) 10089 feet BKB Size Cemented Measured depth True vertical depth BKB BKB 19' 30" Driven 60' 60' 5169' 13-1/2" 845 sx PF E', 625sx 'G' 5212' 4397' 12680' 9-7/8" 630 sx Class 'G' 12721' 10076' 768' 6-3/4" 180 sx Class 'G' measured 12488'- 12508'; 12730'-13100' 10088' E ..... .. true vertical 9993'- 9999';10029'- 10033' !~'~(~ 0~ ~.999 Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, NSCT 13CR80 set at 11,988' Alaska 0il & 6as ~o~s, Co~ssJol~ Anchorage Packers and SS SV (type and measured depth) 7-5/8" Baker "S-3" set at 11,941'and Baker "SBP" Liner Top Packer set at 12517' [Deviation = 74 deorees} 13. Stimulation or cement squeeze summary Add Perforation (11/21/99) Intervals treated (measured) 12488'- 12508' Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1511 5354 6665 0 744 3051 11904 0 Tubing Pressure 1654 267 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations. x 16. Status of well classification as: 0il X Gas__ Suspended__ Form 10-404 Rev 06/15/~. Service Date 11/30/99 SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed f"~Cc ~,~.'~.~¢~,,t i"~.~.~.L(LEA,.(~EC¢.,£~: Title~nior Technin~l A.~.~i.~tant IV BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 11/21&22/99 WELL N°: 1-65/N-25 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Add-perfs Tave Peruzzi SWS (Boehme) SUMMARY: Shot a gun in the well. RECEIVED INTERVAL(MWD) FEET 12488'-12508' 20 2 7/8" Powerjet 6 spf 60 degree phased casing gun. SUBZONE 2B DATE/TIME 11/21 1000 1100 1900 OPERATIONS SUMMARY FWHP: 1650#, FWHT=190, choke=50, lAP: 1,600 OAP: 250 On location. Pre Job safety and operational meeting. RIH and get to depth with 2 ¥4" guns run with 3 1/2" slickline roller attached below. Got to depth of 12550 feet. (Guns are dragging at the top, rollered at the bottom.) GR-CCL failed. POOH and re-ran a different GR-CCL. Failed again. Both tools working at surface but noisy when rattled. No other tools available. SWS go home. 11/22 1300 1400 1700 Take two. OL. Pre-job safety and operational meeting. RIH. Correlate to 1999 RST log (requested correlation log not available on slope). Correlation is +- 2 feet due to deviation and stretch. Off location. Bring well back on. SSSV: OUT Geo'Jogi'cai 1,4a-ter.'¥aJs .'!rlnventor'.'y' D/.\TA T DATA Pi I..i:5 D ,'.i'~ t' e: it) 1/' 20 / 98 / R U i,..! i-.~: ~'.' ,:? V [) D 95~.' i 88 95 ..... t,o ~ 8. ~070 ~,..'I;FL./-'Zi) I /'~ ..... 'GR . _..,. .... t4/ ? 095 ,----T"~ L...i t'41/" A .R C 5 i','i W P 0 'i / 26/'96 0 r' ,' "!.~ 6 .:~ i 20/" .:q:. 5 ..... i 88 C N/" ,q,. R 95-i88 DZF!.../GR/SP 9S .... i88 'SL.i,.r.HI/'ARC ~S.EPZA /~boa .-, /~}.Se) . 05/' 20 / 96 95 ..... 188 SSVD 9 ::~ .... i P- o Z' D i /' C i'-// ~... ,,..;. .. . ,~... 9B .... 188 SBT/,qR 95 -.- 1o° 8 ? 2 r...., 6 ~,T."'n3 iq: C H / 0 o/q 6 i.i} .'...!/ ~3 nlq P !... E TI ON D ATE //), C /q/, ? d,'S3 TO r'eciu'ir"ed? yes ~_ And r'ece'¥ved? '~,',/a s 't:. h e w e 'i I c c: r" e d ? y e s 7 / °l/':/6 ,/" ? STATE OF ALASKA ALASI'~, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate__ Plugging Pull tubing Alter casing Repair well Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage~ Alaska 99519-6612 4. Location of well at surface 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E At top of productive interval 198' NSL, 4485' EWL, SEC. 31, T12N, R17E At effective depth 22' NSL, 4750' EWL, SEC. 31, T12N, R17E At total depth 23' SNL, 4825' EWL, SEC. 6 T11N, R17E 5. Type of Well: Development Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 56' KB feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-65/N-25 9. Permit number/approval number 95-188/Not Required 10. APl number 50- 029-22627 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13286 feet Plugs (measured) 10088 feet BKB 13198 feet Junk (measured) 10089 feet BKB ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 19' 30" Driven 60' 60' 5169' 13-1/2" 845 sx PF E', 625sx 'G' 5212' 4397' 12680' 9-7/8" 630 sx Class 'G' 12721' 10076' 768' 6-3/4" 180 sx Class 'G' 13285' 10088' measured 12730'-13100' true vertical 10029'-10033' Tubing (size, grade, and measured depth) 4-1/2", 12.6#/ft, NSCT 13CR80 set at 11,988' at- 125,1~,oo,, Packers and SSSV (type and measured depth) 7-5/8" Baker "S-3" set at 11,941'and Baker "SBP" Lir~l~l~b~set ";~°~' (Deviation = 74 degrees) ;:~¢~ ~;;:~, ' ~::~ 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (7/23/96) ' ~'~'~':'' ; ~'\i1:.~!i~_,.. ...... !.' Intervals treated (measured) 12730'.-13100' Treatment description including volumes used and final pressure 48 bbls Seawater/Mutual Solvent Mix, 131 bbls Seawater/Scale Inhibitor Mix, 731 bbls Seawater/2% Surfactant Mix, 229 bbls Seawater Tubing Volume. FSWHP -- 200 psig. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 3320 23091 2716 0 2349 2182 12469 2271 0 2224 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 herebycertify that th~foregoing is true and correct to the best of my knowledge. Signed'"....__~_~f .¢~..f~2~.~~ ~./ I ] ~0-~;7:¢.(" ~? Title Senior Technical Assistant IV Date 8/21/96 Form 10-40,4/Rev 06/15/88 SUBMIT IN DUPLICATE STATE OF ALASKA ' ALASK._. OIL AND GAS CONSERVATION CL ,JMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 3. Address I 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 _' 50-029-22627 4. Location of well at surface ,-. ~ ..¢---~..~,' 9. Unit or Lease Name 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E i C.r.',,'?;P?~-~i.;.?? Duck Island Unit/Endicott At top of productive interval i' ~AT&: r 10. Well Number 198' NSL, 4485' EWL, SEC. 31, T12N, R17E 1-65/N-25 At total depthI V~:::.. i 11. Field and Pool 23' SNL, 4825' EWL, SEC. 6, T11N, R17E Endicott Field/Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation an~l' se'ri~l'NraT-:' KBE = 56'I ADL 047502 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 12/13/95I 01/20/96 I 01/26/96 I 6'- 12' MSLI One 17. Total Depth (MD+'I-VD)118. Plug Back Depth (MD-~TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 13286 10088 FT~ 13198 10089 FT~ I~Yes FINo I 1570' MD/ 1465' (Approx.) 22. Type Electric or Other Logs Run DIFI_/ZDL/CN/G R/CHT,SBT,MWD 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD '-AMOUNT PULLED 30" Struct. Drive Surface 60' Driven 10-3/4" 45.5# L-80 43' 5212' 13-1/2" 845 sx PF 'E', 625 sx'G' 7-5/8" 29.7# USS-95 41' 12721' 9-7/8" 630 sx Class 'G' 4-1/2" 12.6# L-80 12517' 13285' 6-3/4" 180 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD ' and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 4-1/2", 13CR80 11987' 11941' MD TVD MD TVD 12730'-13100' 10084'-10089' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL Freeze protect w/60 bbls diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 01/30/96 I Flowing 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 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Explanation of Bottom Hole Location: The Endicott 1-65/N-25 was to be a horizontal well drilled to 13,967' and pr(~duced from the Kekikt. uk Sand. A pilot hole was drilled to TD and plugged back and then kicked off to horizontal. Upon reaching the Kekiktuk, the well was drilled according to the permitted directional plan to 13,286' where water was encountered on the LWD tools. Drilling operations ceased at this point 681' short of the proposed TD. Isolation was needed to prevent water production and a solid cemented 4-1/2" liner was opted for in place of the slotted liner. The directional coordinants of the new bottom hole location are 23' SNL and 4825' EWL, Section 6, T11N, R17E UM which is depicted on the original directional plot submitted with the permit to drill. This is ~ursuant to conversation Steve Shultz had with Blair Wondzell on 07/02/96. RECEIVED Form 10-407 Rev. 07-01-80 · Subr~t 1~9~{~plicate JUL t) Alaska 011 8, Gas Cons, commission Anchorage 29. Geologic Markers 30. , ,.,rmation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Kekiktu k 12522' 10003' K3A 12618' 10021' K2B 12880' 10030' K2A 13250' 10032' 31. List of Attachments .... Summary of Daily Drilling Reports, Surveys 32. I hereby certify that th s t a~'d c0~rect 1 Signed SteveShultz ~ _ Title Senior Drilling Engineer Date ~ Prepared By Name/Number Kathy Campoamor, 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam ~jecti.ont air~je, ctien,,.sa, lt water disposal, water supply for injection, observation, injection for in-situ combustion. '~ ~'& ~:~' ' ~' ~ i ~''~ ~ ~ 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, Qther-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10~407 Rev. 07-01-80 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WellName: 1-65/N-25 RigName: Doyon 15 AFE: 727103 Accept Date: 1 2/1 2/95 Spud Date: 1 2/1 3/95 Release Date: 01/26/96 (PILOT HOLE) 12/13/95 SKID RIG. RIG MOVED 100%. RU DIVERTER & TEST. MU BHA #1. RU SURVEY WIRELINE UNIT. CIRC @ 40'. SET TOOL FACE. 12/14/95 DRILLED T/1108'. SERVICE WIRELINE UNIT. DRILLED T/1485'. CIRC @ 1485'. POOH T/185'. DRILLED T/2560'. 12/15/95 DRILLED T/2718'. CIRC @ 2718'. POOH T/1400'. RIH T/2718'. DRILLED T/3770'. POOH T/1017'. PULLED BHA. REPAIR FLUID SYSTEM. RIH T/3770'. REPAIR FLUID SYSTEM. 12/16/95 DRILLED T/3876'. SERVICE MUD PUMPS. DRILLED T/5225'. CIRC @ 5225'. POOH T/3400'. RIH T/5225'. CIRC @ 5225'. POOH T/4000'. 12/17/95 POOH T/1017'. PULLED BHA. SERVICE DRILLFLOOR & DERRICK. RU CASING HANDLING EQUIP. RAN 10-3/4" CASING T/5211'. CIRC @ 5211'. MIXED & PUMPED SLURRY, DISPLACE SLURRY. RD CASING HANDLING EQUIP. RD DIVERTER. RU BOP STACK. 12/18/95 RU BOP STACK & TEST. INSTALL WB. MU BHA #3. RIH T/1500'. FUNCTIONED DOWNHOLE TOOLS @ 1500'. RIH T/3000'. SERVICE BLOCK LINE. RIH T/5121'. CIRC @ 5121'. TEST CASING VIA ANNULUS & STRING T/3000 PSI FOR 30 MIN. DRILLED T/5235'. CIRC @ 5235'. PERFORM FIT: MW 9.1 PPG, 5211 MD, 4427 TVD, LO PRESSURE 794, LO EMW 12.6 PPG. OBTAINED REQUIRED LEVEL OF INTEGRITY, 12.6 PPG EMW. RUN BHA #3. DRILLED T/6307'. 12/19/95 DRILLED T/6721'. CBU @ 6721'. POOH T/5211'. RIH T/6721'. DRILLED T/6817'. REPAIR MUD PUMPS. DRILLED T/7445'. RECEIVED DRILLED T/7984'. CBU @ 7984'. POOH T/1000'. PULLED BHA. SERVICE DRILLFLOOR/DERRICK. SINGLED IN DP T/2790'. CBU @ 2790'. POO~[/~.9 1996 SERVICED DRILLFLOO~DERRICK. MU BHA ¢4. Naska Oil & ~as Cons. 6ommission Anchorage Page ! 12/21/95 MU BHA #4. SERVICE TOP DRIVE. RIH T/5774'. TOOP MWD SURVEY @ 5774'. RIH T/7500'. REAMED T/7984'. DRILLED T/8691'. 12/22/95 DRILLED T/8965'. REPAIR STANDPIPE MANIFOLD. DRILLED T/8984'. CBU @ 8984'. REPAIR STANDPIPE MANIFOLD. POOH T/7984'. RIH T/8987'. DRILLED T/9244'. 12/23/95 DRILLED T/9589'. REPAIR SHAKER DISCHARGE LINE. SERVICE DRILLFLOOR & DERRICK. DRILLED T/9903'. CBU @ 9903'. POOH T/8900'. RIH T/9903'. DRILLED T/10095'. 12/24/95 DRILLED T/10948'. CBU @ 10948'. POOH T/9500'. 12/25/95 POOH T/1013'. PULLED BHA. RETRIEVED WB. TEST BOP STACK. INSTALL WB. SERVICE KELLY/TOP DRIVE HOSE. MU BHA #5. RIH T/5211'. SERVICE BLOCK LINE. RIH T/10853'. WASHED T/10948'. DRILLED T/10953'. CBU @ 10953'. POOH T/8163'. RIH T/10953'. DRILLED T/11050'. 12/26/95 DRILLED T/11507'. CBU @ 11507'. POOH T/10837'. RIH T/11507'. CBU @ 11507'. CONDUCT BRAIDED CABLE OPERATIONS-5/16 SIZE CABLE. 12/27/95 CONDUCT BRAIDED CABLE OPERATIONS. CBU @ 11507'. POOH T/1013'. PULLED BHA. REPAIR DRAWWORKS. SERVICE TOP DRIVE. PULLED BHA. MU BHA #6. RIH T/11408'. WASHED T/11507'. DRILLED T/11533'. 12/28/95 DRILLED T/12315'. 12/29/95 DRILLED T/12315'. SERVICED SWIVEL. DRILLED T/12455'. CBU @ 12455'. POOH T/1006'. PULLED BHA. MU BHA #7. RIH T/5200'. SERVICED BLOCKLINE. SERVICE TOP DRIVE. RIH T/12360'. WASHED T/12455'. DRILLED T/12480'. 12/30/95 DRILLED T/13024'. 12/31/95 CBU @ 13024'. FLOW CHECK. POOH T/1005'. PULLED BHA. MU BHA #8. RIH T/5768'. TOOK MWD SURVEY @ 5768'. RIH T/12930'. REAMED T/10324'. DRILLED T/13265'. RECEIVED JUL 0 9 1996 Page 2 Alaska 0il & Gas Cons. Commission Anchorage 01/01/96 DRILLED T/13414'. CBU @ 13414'. POOH T/11995'. RIH T/13413'. CBU @ 13414'. FLOW CHECK. POOH T/12455'. RIH T/13414'. CBU @ 13414'. POOH T/12465'. FLOW CHECK. POOH T/1005'. PULLED BHA. RU LOGGING/BRAIDED CABLE EQUIP. RAN ELECTRIC LOGS. 01/02/96 RAN ELECTRIC LOGS. RU RIGGING EQUIP. MU BHA #9. SINGLED IN DP T/1040'. RIH T/5132'. SERVICE BLOCK LINE. RIH T/11903'. RU LOGGING/BRAIDED CABLE EQUIP. RAN ELECTRIC LOGS. POOH T/0'. RD LOGGING/BRAIDED CABLE EQUIP. 01/03/96 RD LOGGING/BRAIDED CABLE EQUIP. REMOVE WB. TEST BOP STACK. INSTALL WB. SERVICE TOP DRIVE. RAN DP T/2800'. RAN DP IN STANDS T/13414'. CBU @ 13414'. RU HIGH PRESSURE LINES. REPAIR HIGH PRESSURE LINES. MIX & PUMPED SLURRY. DISPLACE SLURRY. PULL DP IN STANDS T/10620'. CBU @ 10620'. POOH DP IN STANDS T/10170'. BATCH MIX SLURRY, MIXED & PUMPED. DISPLACED SLURRY. PULL DP IN STANDS T/9220'. REPAIR DRAWWORKS. 01/04/96 REPAIR DRAWWORKS. PULL DP IN STANDS T/2318'. REPAIR DRAWWORKS. MU BHA #1. RIH T/5189'. SERVICE BLOCK LINE. RIH T/8959'. TOOK MWD SURVEY @ 8959'. WASHED T/9830'. DRILLED T/9860'. 01/05/96 DRILLED T/10321'. Page 3 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WellName: 1-65/N-25 RigName: Doyon 15 AFE: 727103 Accept Date: 1 2/1 2/95 Spud Date: 1 2/1 3/95 Release Date: 01/26/96 ';F~HO:RI;Z'O'NT;AE) ¥~ 01/04/96 MU BHA #1. RIH T/5189'. SERVICE BLOCK LINE. RIH T/8959'. TOOK MWD SURVEY @ 8959'. WASHED T/9830'. DRILLED T/9860'. 01/05/96 DRILLED T/10321'. 01/06/96 -- DRILLED T/10748'. CBU @ 10748'. POOH T/1005'. PULLED BHA. MU BHA #2. TEST MWD TOOL VIA STRING. RIH T/5000'. 01/07/96 SERVICE TOP DRIVE. RIH T/10748'. DRILLED T/11190'. 01/08/96 CBU @ 11190'. FLOW CHECK. POOH T/1015'. PULLED BHA. MU BHA #3. RIH T/5190'. SERVICE TOP DRIVE. SERVICE BLOCK LINE. RIH T/11190'. DRILLED T/11228'. REPAIR MUD PUMP FLUID END. DRILLED T/11370'. 01/09/96 DRILLED T/11507'. CBU @ 11507'. POOH T/1000'. PULLED BHA. MU BHA #4. RIH T/5759'. POOH T/5211 '. TOOK MWD SURVEY @ 5211'. RIH T/11507'. TOOK MWD SURVEY @ 11507'. DRILLED T/11542'. 01/10/96 DRILLED T/11836'. POOH T/5211'. REPAIR HIGH PRESSURE LINES. 01/11/96 REPAIR HIGH PRESSURE LINES. RIH T/11844'. DRILLED T/11950'. 01/12/96 DRILLED T/11988'. REPAIR MUD PUMPS. DRILLED T/12088'. CBU @ 12088'. POOH T/2455'. PULLED BHA. RETRIEVE WB. TEST BOP STACK. INSTALL WB. MU BHA #5. RIH T/5760'. TOOK MWD SURVEY @ 5760'. RIH T/8000'. 01/13/96 RIH T/11750'. WASHED T/12088'. DRILLED T/12507'. CBU @ 12506'. POOH T/11000'. Page 01/14/96 POOH T/2455'. PULLED BHA. MU BHA #6. SERVICE BLOCK LINE. RIH T/12407'. WASHED T/12507'. DRILLED T/12705'. 01/15/96 DRILLED T/12740'. CBU @ 12740'. POOH T/201'. PULLED BHA. MU BHA #7. SERVICE TOP DRIVE. RIH T/12740'. CBU @ 12740'. LD 11318' OF 5" DP. PULLED BHA. 01/16/96 RETRIEVED WB. RU TOP RAM. RU CASING HANDLING EQUIP. RAN 7-5/8" CASING T/12720'. CBU @ 12721'. REPAIR STANDPIPE MANIFOLD. PUMPED SPACERS. MIXED & PUMPED SLURRY. DISPLACE SLURRY. RD CASING HANDLING EQUIP. 01/17/96 INSTALL SEAL ASSY. RU TOP RAM. FREEZE PROTECT WELL, 60 BBL DIESEL. SERVICE TOP DRIVE. WOC. RAN ELECTRIC LOGS. 01/18/96 RAN ELECTRIC LOGS. RD LOGGING/BRAIDED CABLE EQUIP. RETRIEVED WB. TEST BOP STACK. INSTALL WB. RAN DP T/8521'. SERVICE BLOCK LINE. PULL DP IN STANDS T/0'. RU LOGGING/BRAIDED CABLE EQUIP. RIH T/6300'. 01/19/96 RIH T/11473'. RU LOGGING/BRAIDED CABLE EQUIP. RIH T/12620'. POOH T/11473'. RD LOGGING/BRAIDED CABLE EQUIP. POOH T/0'. MU BHA #8. REPAIR MWD TOOL & TEST VIA STRING. RIH T/2000'. TEST MWD. RIH T/12635'. TEST CASING VIA STRING. 01/20/96 DRILLED T/12635'. RU TOP DRIVE. CBU @ 12635'. DRILLED T/12733'. CBU @ 12733'. SERVICE FLUID SYSTEM. DRILLED T/12780'. POOH T/12504'. RIH T/12780'. DRILLED T/12922'. 01/21/96 DRILLED T/13286'. CBU @ 13286'. REACHED GEOLOGICAL END OF RUN. APPEARS TO HAVE ENCOUNTERED WATER IN PRODUCING SAND. POOH T/12721'. RIH T/13286'. CBU @ 13286'. 01/22/96 POOH T/4001'. PULLED BHA. SERVICE DRILLFLOOR/DERRICK. MU BHA #9. RIH T/12721'. SERVICE BLOCK LINE. RIH T/13286'. CBU @ 13286'. POOH T/3800'. PULLED BHA. RU CASING HANDLING EQUIP. RAN 4-1/2" CASING T/766'. RAN DP ON LANDING STRING T/866'. Page 2 01/23/96 RAN DP ON LANDING STRING T/12720'. CBU @ 12720'. RAN DP ON LANDING STRING T/13286'. CBU @ 13286'. BATCH MIXED SLURRY. DISPLACE SLURRY. TEST CASING. REV CIRC T/12517'. RD DRILLSTRING HANDLING EQUIP. PULLED DP IN STANDS T/0'. RU DRILLSTRING HANDLING EQUIP. SERVICE DRILLFLOOR & DERRICK. MU BHA #9. 01/24/96 MU BHA #9. CBU @ 843'. RIH T/12486'. SERVICE BLOCK LINE. RIH T/12554'. WASHED T/13198'. CBU @ 13198'. POOH T/12517'. TEST CASING. POOH T/843'. POOH T/0'. RETRIEVE WB. TEST BOP STACK. REPAIR KILL MANIFOLD. 01/25/96 TEST BOP STACK. INSTALL WB. RU GUN ASSY. RAN DP IN STANDS T/13100'. SET PACKER @ 12235' WITH 0 PSI. RU HIGH PRESSURE LINES. PERFORATED F/12730' T/13100'. REV CIRC @ 12235'. PACKER WORKED @ 12235'. FLOW CHECK. RD HOOK. LD DRILLPIPE T/12235'. 01/26/96 .... RD GUN ASSY. LD HWDP OF 980'. WORKED ON BOP TOP RAM. SERVICE TOP DRIVE. RETRIEVE WB. RU TUBING HANDLING EQUIP. RAN 4-1/2" TUBING T/10417'. TEST DUAL CONTROL LINE. RAN TUBING T/11987'. 01/27/96 RAN TUBING T/11987'. REV CIRC @ 11987'. SET PACKER @ 11941' WITH 4000 PSI. INSTALL HANGER PLUG. RD BOP STACK. INSTALL ADAPTOR SPOOL. RU SURFACE TREE. TEST DUAL CONTROL LINE. TEST XMAS TREE. RETRIEVE HANGER PLUG. RU HIGH PRESSURE LINES. TEST TUBING. TEST PERMANENT PACKER. CBU @ 4133'. INSTALL HANGER PLUG. RD ESD SYSTEM. FREEZE PROTECT WELL 60 BBL DIESEL. RIG RELEASED @ 2359 HRS, 01/26/96. Page _.,, 15 - Endicott ID'659-6512 ..SAN 21'ci6 7'25 No.O05 P.O1 COMPAH~ LOCAT~6N 2 HP! HAGNETIC D~CL~HAT~OH GR~D CONVERG£NCE ANGL~ WELL HU~B£R 0 WELL H~AD LOCATIOH: LAT(N/-~) 0,00 AZI~UYH ~ROH ROTARY TA~L£ TO TA~T IS TI~ IH POIH?(YIP) ~ ~EASUR~D DEPTH 0,00 TRU~ U~RT DEPTH 0,00 INCLIHATIOH 0,00 AZIMUTH 0,00 LAT!TUDE(H/-$) 0,00 D£P~RTUR~(~/.W) 0,00 ~23+90 RECEIVED ,JUL O~ ~ 011 & Gas Cons. Commission Anchorage PAGE MEA~UR£D INT£RgAL V£RTICAL DEPTH DEPTH ft it ft 0,00 0,0 I00,00 100,0 }00,00 ~00,00 100,0 199,99 300,00 100,0 299,91 400,00 100,0 399, a ~00,00 100.0 499,15 &O0,O0 100,0 598,39 700.00 100,0 &97+04 800,00 100+0 79~+05 900,00 100.0 892,36 I000,00 t100,00 I200,00 1300.00 1400,00 1~00,00 I600,00 1700,00 1800,00 1900,00 2000,00 2i00,00 2200,00 2300.00 2400,00 2500,00 2600,00 2700,00 2800,00 2900,00 100,0 988,84 100,0 1084,82 lO0,O 1180,5~ 100,0 1225,62 t00,0 1369,47 100,0 i46i,86 I00,0 i552,38 100,0 I640,8& 100,0 {.727,24 100,0 1811,28 iO0.O i8~2,74 100,0 iO0,O 2052,87 100,0 213~,55 100,0 2212,25 100,0 2292,10 100.0 2371,74 100,0 2450,5~ 100,0 2528,80 I00,0 2&07,33 3000,00 I00,0 2&S&,OP 3100,00 I00,0 27&5,17 3200,00 100,0 ~844,48 3300,00 100,0 2923,72 3400,00 100,0 3004,14 3500,00 3600,00 3700,00 3800,00 3900,00 100,0 3084,72 !00,0 3165,5~ 100,0 324&.17 lO0,O 3327,01 100,0 3406,52 9URV~¥ CALCULATION9 ~K,~K~** CI~CULA~ ARC ~ARO~T ~?ATION AZIMUTH LATITUDE SEgTION INOLN, 0.00 0,00 0,00 0,00 0,14 0,17 144,14 -0,12 1,26 i,13 127,41 -0,84 5,09 3,28 129,80 -3,27 12,56 5,31 t25,61 -7,80 ~/-~ it ft 0,00 0,00 0,09 0.15 0,9~ 1,27 3,94 5,12 9,90 I2,60 AZIMUTH 0.00 144,14 131,26 128,22 de9l lOOft 0,1~ 0,97 2,15 2,05 22,32 §,89 124,12 -13,37 17,91 22,35 1Z6,74 0,60 ' 34,58 B,20 123,62 -20,20 2B,lO 34,60 125,71 2,31 50,9i 10,60 !21,5i -28,95 41,88 50,91 124,66 2,42 70,70 !2,27 !19,83 -39,05 5B,74 70,70 I23,52 1,70 93,63 14,35 118,08 -50,17 79,09 93,6~ 122,39 2,12 Ii9,72 16,11 i16,49 -62,19 147.49 16,49 114,82 -74,33 175,97 17,10 113,55 -86,17 20&,41 19,0~ 111,98 -98,15 240,09 21,30 110,94 -1i0,?~ 102,45 119,~4 121,26 1,81 i27,75 147,80 120,20 0,60 154.10 176,56 117,21 0,71 I82,73 207,42 118,24 2,02 214,83 241,70 117,27 2,27 277,3t 23,69 llO,ll -124,16 250,67 279,73 116,35 2,41 31B,47 26,57 I09,36 -138,48 290,64 321,95 115,48 2,90 363,56 28,96 109,36 -1S3,92 334,59 368,30 114,70 2,39 412,31 31,53 !09,32 -170,60 3B2,1I 418,47 114,06 2,~7 464,?Z 34,09 i09.!4 -i8&,45 520,80 3~,8i 109,12 -207,45 468,06 530,32 113.03 2,72 ~78,~5 36,78 108,$~ -226,84 544,73 ~?0,07 112,6i 0,28 636,~8 36,86 107,97 -245,67 601,62 649,~5 I12,21 0.42 694,40 3~,48 107,4& -264,06 659,18 ?lO,lO 111,83 0,69 752,30 36,83 107,28 -282,07 716,82 770,33 111,48 0,66 ~10,03 37,20 107,53 -300,10 8~,11 37,23 107,93 -318,51 927,20 38,70 107,58 -337,27 986,90 38.37 i06,99 -355,78 I046,0& 38,!3 106.55 -373,64 774,27 830,39 111,19 0,40 831,87 890,77 li0,~5 0,24 890,46 952,19 110,74 1,49 949,~5 i014,38 110,53 0,49 1009,~2 1076,17 I10,3~ 0,36 I068,42 1137,63 110,09 1127,45 1198,40 109,84 118&,36 1259,32 I09,60 1245,03 1317,87 109,37 {302,58 1379,43 109,22 1357,17 1438,30 109,09 1415,7~ 1497,46 109.0! 1472,16 1556,55 108,9~ 1528,30 I~t5,40 I08,90 I586,22 1676,01 108.&4 1104,74 37,95 105,66 -390,74 1162,70 37,49 104,80 -406,81 1220,29 37,60 104,87 '422,42 1~77,76 37,20 I05,14 -43B,14 1334,37 36,11 i05,?0 -454,01 1370,54 36,13 t06,77 -470,47 1447,17 36,46 107,33 -487,85 1503,89 36,02 107,58 -505,58 I560,36 36,10 I07,4~ -523,28 1618,45 38,57 107,02 -541,23 0.5~ 0,I2 0,43 1,14 0,63 0.47 0,46 0,12 2.48 PAH£ NO, 3 I~65/H-25 (HA) SURVEY CALCUL~TIOHB ~w~w~ CIRCULAR ARC D~PTH D£PTH ft ft ft 4000,00 !00,0 3484,26 4100,00 100~0 3561,35 4200,00 100,0 3637,92 4300,00 t00,0 3714,47 4400,00 100,0 379~,~0 TARG£T STATIOH AZIMUTH LATITU~ S~CTIOH IHCLH, ft deq deg f~ !678,47 3g,3& !06+13 1739,12 39,76 105,94 -576,76 1800,26 40,29 105,73 -594,3~ 1861,47 39,81 106,17 -611,99 D~PARTUR£ 9I~PLACE~HT at ft ft 1646,51 1738,86 1707,73 1802,50 1769,60 1866,73 I831,47 1931,01 1891,83 1793,87 AZIMUTH de~/ de9 ~OOft 108,76 108,66 0,40 108,56 0,55 108,48 0,56 i08,41 1,68 4500,00 4600,00 4700,00 4800,00 4900,00 I00,0 3871,30 100,0 3950,7! 100,0 4027,78 100,0 4i08.59 100,0 4187,9! 1979,9& 37,30 i07,24 -647,48 2038,27 37,56 107,81 '665,78 2097,08 37,93 107,7& -684,48 2156,28 38,05 108,20 -703,48 2214,95 36,99 i0},53 ~722,67 1950,37 2055.04 I08,37 0,95 2008,33 2115,&! 108,34 0,43 206~,62 2177,02 10B,33 0,37 2125,16 2238,57 108,32 0,30 ~182.97 2299.4~ 108,32 1,08 5000,00 5100,00 5200,00 5300,00 5400,00 100,0 42A7,77 I00,0 4347,47 100,0 4427,24 100,0 4506,93 100,0 4586,19 2272,92 36,98 108,g2 -741,63 2331,0i 37,36 i07,7! -760,27 ~388,77 36,82 108,03 -778,77 2~47,03 37,51 iOT,~ -797,~8 ~505,50 37,64 107,19 -8i5,54 2240,06 2357,64 108,32 0,18 2297,53 2420,05 108,31 0,49 2354,93 2480,36 108,30 0,57 2412,43 2540,77 108,29 0,73 2470,61 2601,74 10B,27 0,32 5600,00 5700,00 5800,00 5900,00 i00,0 4865,19 i00,0 4743,72 100,0 482~,37 i00,0 4900,77 100,0 4?79,37 2564,27 37;99 i07,46 '833,80 2623,4! 38,I3 107,53 '852,33 ~682,8I 38,5~ i06,9! -870,6~ 2Z42,06 38,20 106,~8 -888,42 2800,8~ 38,2! 105,51 -905,39 2~29,14 2663,04 I08,25 2587,94 2724,69 108,23 0,15 2647,i7 2786,69 I08,2! 0,55 2706,65 2848,72 2766,12 2910,52 108,1~ 0,44 ~000,00 H00,00 6200,00 6300,00 6400,00 100,0 100,0 5137,35 100,0 I00.0 5295,00 100,0 5374,03 2858,84 37,33 104,44 '921,25 2916,57 38,42 103,62 '936,13 2974,28 37,52 103,~3 -950,62 303~,06 38,44 103,?~ -965,27 3089,67 37,13 i04,05 -980+08 2825,28 2971,68 108,06 2884,84 3032,92 107,98 2944,63 3094,27 107,89 0,90 3004,40 3155,66 107,81 0,94 3063,85 3216,79 107,74 i,31 6~00,00 6700,00 6800,00 ~900,00 i00,0 5453,37 100,0 553~,46 i00,0 5692,6{ 100,0 5772,40 3146,98 37,86 104,38 -995,03 3204,75 37,61 104,88 -1010,48 3261,69 36,38 i05,~0 -1026,I0 3318,!9 36,8! 105,36 -i041,81 3375,43 37,34 i05,6~ 3122,86 3277,55 ]07,67 0,76 3182,07 3338,66 i07,62 0,37 3240,I9 3398,78 107,57 1,24 3297,69 3458,34 107,53 0,44 3355,75 35i8,60 107,50 0,62 7000,00 7100,00 7200,00 7300,00 7400,00 100,0 585i,41 IO0,O 5929,45 100,0 100,0 &086.96 100,0 3433,7S 38,26 i06,0~ -1074,92 3~73,33 39,1S 106,35 -1092,38 3552,77 37,90 i06,71 -ill0,i0 36i0,97 37,20 106,60 -1127,56 3668,96 37,65 106,40 -II4~,82 3414,67 3579,67 107,47 0,93 3474,72 3642,38 I07.45 3534,43 3704,66 107,44 1,27 3592,81 3765,60 107,42 0,70 3651,08 3626,3~ 107,4$ 0,47 7500,00 7600+00 7700,00 7800,00 7900,00 i00,0 6245,30 100,0 6324+09 100,0 6403+47 100,0 6483,02 I00o0 6561,84 3727,57 38,12 I06,68 -1162,3! 3786,40 37+~0 106,70 -1177,99 3H4,44 37,02 106,32 -i197,28 3902,29 37,58 106,86 -i214,5~ 3961,23 3B,IB I07,50 -1232,76 3709,95 37~8,94 3827,25 3885,32 3944,Ii 3887,76 I07,40 0,50 394~,34 4070,74 107,36 0,65 4~2,2e dULloO$6 Alaska Oil & Gas Cons. Commission Anchorage CIRCULAR ARC (HA) M~ASUR£D INTERVAL V~RIICA~ D£PTH D~PTH &O00,OO I00,0 6699,94 HO0,O0 100,0 6717.45 8~00,00 100.0 6794,88 ~300,00 100,0 a400,O0 ~00.0 6949,88 1'AR~£T S?ATIOM AZIRUTH LATITUDE S£CTIOH INCLM, ~/-~ ft de9 ~eg ft 4021,09 38,92 107,17 -1251,37 4081,54 39,44 106,82 -1269,83 4t42,03 39,08 106,82 -1~88,15 q202,19 39,10 t06,t! -1306,02 4262,3I 39,50 105,05 -1323.03 DEPARTURE DISPLACEMENT ~t AZIMUTH ~I-~ ft ft de9 4003,73 4194,73 107.36 4064,35 4257,91 107,35 4124,73 4321,19 t07,34 4~85,19 4384,24 307,33 4246,20 4447,54 107,31 DL~ deg/ 100ft. 0.58 0.56 0,36 0,45 0,78 ~500,00 8600,00 8700,00 8800,00 8900,00 100,0 7027,81 I00~0 7~06,32 100,0 7184,35 100,0 7262,14 100,0 7340,6~ 4321,63 38,11 i05,10 -1337,32 4380,24 38,42 105,06 -1355,44 4~39,45 39,0i t05,12 -1371,72 4499,08 38,86 105,71 -1388.53 4558,i0 37,62 106,82 -1405,96 4306,71 4~10,16 107,27 4366,51 4572,05 107,25 4426,90 4634,55 107,22 4487,45 4697,36 107,19 4546,84 4759,25 107,18 1,39 0,3i 0,59 0,52 1,36 9000,00 9100,00 9200,00 9300,00 9400,00 100,0 7420,23 100,0 7499,97 i00,0 7579,38 100.0 7658.49 i00,0 7737,4S 4H6,11 36,97 107,46 '1423,6I 4~74.09 37.26 i0~,I2 '1442,25 4732,69 37,60 108~96 '1461,5a 479i,77 31.82 I08,84 '1481,39 4851,07 37,90 I07,07 "1501,33 4604,74 4819,84 107,I8 4662,I9 4880,18 107,19 4719,82 4940,94 107,21 4777,68 5002,08 107,23 4835,73 5063,42 107+25 0,76 0,49 0,61 0,23 0,16 9500,00 9600,00 9700,00 9708,32 9000,00 100,0 7816,24 100o0 7894,67 I00,0 7972,67 8,3 7979,13 91,7 8050,15 4910,62 38,12 109,2i -1521,52 4970,~8 38,56 i09,60 -1542,13 5031,31 38,92 109,56 '1563.10 5036,39 39,07 I10,I7 -1564,88 5092°74 39,39 110,36 -1~84,96 4893,91 5124,?7 107,27 4952,41 5IB6,96 107,30 5011,37 5249,49 i07,32 5016,30 5254,72 107,33 5070,69 5312,63 107,36 0,24 0,50 0,36 4,94 0,37 985~,50 9919.65 10015,34 10111,45 10396,37 10490,?9 i0683,76 6!,2 8142,71 95,7 8218,45 94,0 8374,88 94,4 8454,89 96,5 8537,67 94,6 8619,03 97.1 8702.34 95,9 8784,89 5128,81 39,60 109,00 -1597,49 5166,08 38,73 108,5Z -1609,91 5222,69 36,67 Ii0,01 -1629,20 5277,17 34,47 111,95 -1649,19 5328,57 32,83 117,95 -167i,09 5378,55 31,32 121,~6 -1695,93 5428,04 30,56 129.31 -1724,60 5476.07 30.85 130,92 -1755,73 5525,40 30,94 !33.35 -1789.17 5572,96 30,27 I39,83 -1824,5~ 5105,73 5349,80 107,37 5142,29 5388,4i 107,38 5197,53 5446,89 107,40 5247,73 5502,68 107,44 5296,94 5554,2? 107,51 5340,47 5603,28 107,62 5380,83 5650,45 107,77 5417,77 5695,16 107,96 5454,73 5740,67 108,I6 5488,25 57~3,60 108,39 1,52 i,5i 2,35 2,57 3,94 2,58 4,20 0,92 1,29 3o5! i0770,74 10871 i09~5.25 1i061,99 11253.47 it~46,27 11441,21 11471,14 li506,80 94,8 8866,2g 93,0 8945,72 93.5 9025,75 96,7 9108,51 95,0 918f),50 96,5 9271.55 92,8 9349,93 94,9 9429,~5 29,9 9454,80 33,7 9484,66 5619,78 31,37 13},75 -t8H.37 5666,55 31.39 139,38 -i897,98 5712,87 30,81 I41,I0 -1935,0~ ~760,66 31,56 141,5~ ~1974,20 5807,91 31~50 I42,1~ -2013,28 5855,94 31,94 143,12 -20~3,61 5703,07 32,82 141,64 -2072,97 5952,11 32,97 142,14 -2133,~4 5967,49 32,70 i42,82 -2146.41 5985,97 33,57 142,i0 5519,9~ 5825,32 108,63 5551,68 ~067,15 108,87 5582,55 5908,42 109,12 5413,04 5950,66 109,38 5644,51 5~92,82 109,68 5~75,28 6035,40 109,89 5705.62 6077,3~ 110,I4 5737,44 6121,29 110,40 5747,3~ 6195,04 110,48 5759,17 6151,58 110,57 1.30 1,14 0,82 0,34 0,60 0,33 1,54 CIRCULAR ARC HE?HO~**w~,~ )£A£UR~ IN?~RVAC ~PTH ft ft ft 11534°46 27,7 9)07,40 11564,7) 30,3 9581,6I 11~77,10 3~,3 ~556,7~ 11628,83 31,7 9580,80 i1660o13 31,3 9603,5! T~RGET STATION AZZHUT~ LATITUA£ S~CTIOH IHCCH. H/-S ft deq de? ft 6001+05 35,86 137,38 -H74,05 60i8,74 38,10 I36,25 -~187,54 6038,63 3f,65 134,40 -2201,97 60]9,05 41,98 133,44 -2~16,35 ~0~0,3I 44,75 132,4~ -2231,01 ~PA~?UR~ ~I~PLAC~H~NT ~t AZIMUTH ft ft de? 5769,17 6165,~1 110,65 5781,42 6181o44 110,73 5795.$9 61~?,89 110,80 58i0,63 62i8,97 110,88 5826,39 6238,?3 110,95 de~/ 100ft 10,02 5,97 7,6I i1690,91 11723,70 117~4,84 ii7~,07. I1822,00 30.8 9624,73 31,i 9666,77 37.2 9659,59 6102,~0 46,82 i30,69 ~45,67 AI~&,43 4%I9 ~150,29 51,99 I2~,ll -2276,40 6119,62 52,?~ 128,31 6203,73 54,81 128,37 -2309,59 5842,72 62)?,61 111,02 )8~1,)5 6282,65 11i,10 5880,~1 &305,46 111,I6 5909,3~ ~333,5B lil,24 $~22,28 6356,70 Ill,30 7,37 7,61 7,97 4,31 6,08 11849,52 12040,02 12133,13 2Y,5 97~,97 95,8 7776,7Y 94,7 983t,75 93,1 9887,30 622~,25 55,40 127,09 -~323,40 6382,49 5~,65 i23,~0 -2414,67 6457,21 54,10 123,90 -2456,25 6539,57 58,74 i23,76 -2~02,10 5940,14 6378,36 111,36 6003.86 M54,74 111,55 6067,04 6529,90 111,?0 6129,13 6602,78 111,84 6197,54 6683,5~ 111,79 4,38 1,34 4.35 1,57 4,70 12264,97 12~76,79 31,} 9973,58 31,4 3~,0 i0014,08 6568,09 61,i0 125,47 -~518,3I 6596,08 ~,34 127,47 -2534,96 6622,55 6~,42 I29,37 -~55i,47 6650,74 64,93 !29,07 -2569,37 6679,71 66.33 130.87 -2588,i0 6~21,01 6711,40 112,04 8,44 6243,54 6798,54 112,10 6,78 6~64,35 6764,0g 112,~6 6,72 6286,27 6791,09 112,23 4,86 6308,60 6818,85 112,31 6,69 12421,20 124~2,07 -12488,18 12519,69 12~49,24 31,1 !0026,13 30,9 10037,19 36,1 I0049,08 31,5 10058,29 2~,5 10065,44 6708,23 68,15 127,81 -2606,67 673~,89 69,86 130,12 -~625,17 6770,81 71,68 i29,31 -~46,77 6800,83 74,34 128,68 -~665,93 6829,39 77,64 128,i} -26~3,74 6330,48 6846,14 I12,38 ~35~,57 6879,67 112,45 6378,79 6906,19 112,94 6402,21 6935,09 112o61 6424,66 6962,67 1H,61 6,66 5,60 5,46 8,66 II,28 12580,50 12641,42 12675,29 1~766,70 12798,43 I2033,00 12866,30 12893,00 !2~8,00 9i,9 10071,33 31,~ 10075,84 2g,7 1007~,15 33,9 10061,9! 91,4 3t,7 10085,2? 34,6 10085,59 33,3 10085,94 26,7 i0086,2g , 35,0 10086,69 6860,03 80,65 127.27 -2702,~3 6~90,90 82,73 124,63 -2720.66 69~0,4I 84,48 i23,6~ -2737,23 6954,16 86,17 123,98 -2756,02 7045,41 89,83 119,46 -2804,03 ?077,05 89,54 1!9,36 -2819,61 7i11,50 89,40 119,20 -2836,52 7144,6~ 09,40 119,20 -28~2,76 7171,3I I)9,10 120,00 -286)i,95 7206,25 89,60 121,50 -2883,85 &448,95 6992,~2 112,74 6473,96 702g,40 112,79 6498,38 7051,34 112,84 6526,41 7084,47 112,89 6604,09 7174,72 113,01 6631,23 7206,26 113,03 6661,89 7240,62 113,06 6690,95 7273,73 113,09 6714,17 7300.25 II3,1~ 6744,~4 7334,94 113,I5 10,06 6,70 6,36 0,97 0,6i 0,08 3,20 4,52 13021,&0 I305~,68 I3083,30 29,5 10086,97 31,8 10087,39 3~,3 10081,81 31,1 I008},17 30,6 10088,60 7235,14 89,30 123,80 -2899,76 7267,5~ 89,20 123,20 -2917,31 7299,84 89,30 123,80 -2935,13 7330,91 89,29 123,32 -~952,31 7361,53 89,17 12~,80 -2769,02 6769,08 7364,04 I13, I9 6795,59 7395,32 ii3,I73 6822.52 74~7,10 6848,42 7457,68 113,32 6874,08 7487,8& 113,36 7.a6 1,91 1,54 1,74 ft ft fc ft de~ 1~I51,15 34,8 I0089,i8 742?,37 90,40 123o60 13180,73 29,6 1008B,78 7458,75 90,34 123,80 13207,46 26,7 I00~! 7485,68 90,40 t23,60 13285,64 . 78,2 10088,2? 7563,8~ ?0,40 HI-9 £/-~ deQ/ -2987,13 &901,&9 7520.39 113.40 2,82 -3006,48 6930,64 7554,~5 113,45 3,37 -3022,94 6955,22 758~+75 I13,49 0,17 -3037,77 6977,4~ 7610,06 i13,53 0,78 I1 II Ii i 11 COMPANY YEL~ HARE I-~5/X-25 LOCATIOX 1 BHDICCTT LOCAT~DH 2 MAGNETIC DECLINATlOH 28,~3 CRI~ CONVERGENCE AHGL£ DATE: 3I-D~C-?5 ~ELL HUMBER 0 AP] NO. ~0-0~o22~27-70 ~O~ NO, 374?6 YELL X£AD LOCATION: L~T:X/-S) 70,35177570 'D£P(E/-Y) -147.957237 AZIHUTH FROH ROTARY TABLE TO TARGET IS 13C,17 TIE IN POINT(TIP) : HEASURED DEPTH 9900 TRUE VERY DEPTH 51~7,2 IXCLIXATIOX 3~,37 AZIHUTH 110.32 LATITUD£{N/-S) -1606,8 DEPARTURE(E/-g) 5~0.6 lO0' - ?900' 10025.01' - 13341,81' GYRO SURVEYS M~D SURVEYS II I1 P~G£ HO, SUR~EY [ALC~LATIOHS ************* CIRCULAR ARC RECEIVED 1-65iH-25 JUL 0 9 199~ Alaska 0il & Gas Cons. Commission Anchorage M£ASUR£O INT£RVAL VERTICAL DEPTH DEPTH ft ft ft 0,00 0,0 0.00 tO0,O0 lO0,O 100,00 200,00 100,0 199,99 300.00 100,0 299.91 400.00 I00,0 399,63 TARCET STATION AZIMUTH LAIITUD£ S£CTION INCLtl, ft de9 de9 ft 0,00 0,00 0.00 0,00 0.14 0,17 144,14 -0,12 1,27 1,13 127,41 -0,84 5.12 3,2~ 129,80 -3,27 12.59 5.3I 125.61 -7,~0 DEPARTURE DISPLAC£M£h? at E/'W ft 0,00 0,09 0,96 3,94 9,90 AZIMYT~ DLS de9/ ft deg lOOft O,OO 0,00 0,00 0,15 144,14 0,17 1,27 131,26 0,97 5,12 12~,70 2,15 12,6~ I28,22 2,05 500,00 100,0 499,!5 600,00 100o0 598,29 700,00 100.0 697,04 800.C0 100,0 795,05 900.00 100,0 892,36 22.31 5,89 124,12 -13,~? 17,91 22.35 126.7¢ 0,60 34,50 ~,20 123,62 -20,20 28,10 34,&0 125.7I 2,31 50,68 10,60 121.51 -28.~5 41,88 50,?I 124,66 2,42 70,22 12,27 119,83 -39,05 58,94 70,70 123,52 1,70 92,79 14,35 118,08 -50,17 79o09 93,66 122,39 2,12 IO00,CO I!O0,O0 1200.00 1300,00 1400.¢0 100,0 988,84 100.0 105:.82 lO0,O 1180,56 i00,0 1275,62 100,0 1369,47 118,39 16,1! [16,49 -62,19 102,45 145,56 16.49 114,82 -74,33 127,75 173,33 17,10 t13.55 -86,17 154,10 202.93 19,06 111,98 -95,15 182,73 235,59 21,20 110,94 -110,76 214,83 119,84 121,26 1,81 147,80 120.20 0,60 176,55 119,21 0.71 207,42 118,2~ 2,02 241,73 117,27 2,27 1500,00 1600.00 1700.0:) 1800.00 1900 100,0 1461,86 I00.0 1552,38 100.0 1640,&6 100,0 1727,24 lO0,O 1811.28 271.61 23,69 lIO,11 -124,16 250,67 311,39 26,57 109,36 -138,48 290,64 354,93 2~,96 109,36 -153,~2 334,59 401.99 31,53 IC?,32 , -170,60 382,11 452,59 34,09 109,14 -18~o45 433,27 279,73 116,35 2,41 321,9~ 115,48 2,90 368.30 114.7~ 2,39 41~,4~ 114,06 2,57 472,48 113,51 2,56 2000.00 2100,00 2200.00 2300.00 2400,00 100,0 1892,74 lO0,O 1972,82 I00,0 2052,87 100.0 2132,55 100.0 2212.25 506,71 36,81 109,12 -207,45 488.06 530,32 113,03 2,72 562,51 36.7S 108.66 -226,84 544,73 590.07 112,51 0,28 618,13 36,86 107,97 . -245.67 601,62 649,85 112,21 0.42 673,95 37,45 107,46 -264.06 659,18 71C.10 111.53 0,69 729,62 36.83 107.28 -282,09 716,82 77~,33 111,48 0,66 2500,00 2600.00 2700,00 2800.C0 2900,00 100.0 2292,10 100.0 2371,74 100,0 2450,58 I00.0 2528,80 100,0 2607,33 785,13 37,20 107,53 -300.10 774,27 841,02 37,23 107.93 -318o51 831,87 897,88 36,70 107,58 -337,27 890,46 955.27 38,37 106,99 -355,78 949,95 1012,07 36,I3 106,55 -373,64 1009,22 830,39 111.19 0,40 890,77 110,95 0,24 952,19 110,74 1,49 1014,38 110,53 '- 0,49 1076,17 110.32 0,36 3000,00 3100.00 3200.00 3300,00 3400,00 100,0 2686,09 100.0 2765,19 I00,0 2844,48 100,0 2923.92 IO0,O 3004,14 1068,33 37,95 105.66 -390,74 1123,80 37.49 104,80 -406.81 1178,86 37,~0 104,87 -422.42 1233.83 37,20 105,14 -435,14 1288,03 36,11 105.70 -454,01 1068,42 1127,45 I186,36 1245,03 I302,58 1137,63 110.09 0.58 1198,60 109.84 0,70 1259,32 109,60 0,12 1319.87 109.39 0,43 1379,43 109.22 I,I~ 350~,00 3600,00 3700.00 3800,00 3900,03 100,0 tO0,O 3165,52 lO0,O 3246.17 100,0 3327,01 lO0.O 3406.52 1341,90 36,13 106.77 -470.49 i396,33 36,46 107.33 -487,85 1450.85 36,02 107,58 L505,58 1505,16 36,10 107,42 -523,28 1560.99 38,57 107,02 -541,23 1359,17 1415,76 1472,16 1528,30 1586,22 1438,30 10~.39 0,63 1497,45 109,01 0,47 155&.55 I08.~5 0,46 1615,43 I08,90 0,12 1676.01 108.5~ 2,48 NE~SLR£~ IHTERVAL VERTIEAL ft ft ft 4000,00 100,0 ~4~¢,2~ 4100,00 i00,0 3561,35 4200,00 -I00,0 3637,92 4300.¢0 100o0 3714,47 4400.00 100,0 3792,20 W I{ il ii il ,m ii d I1 d 4500,00 4600,00 4700,00 4800,00 4900,00 5000,00 5100,00 5200,00 5300,00 54OO,00 5600,00 5700,00 5800,00 ¥oo.oo 6000,00 6100,00 6200,00 6300,00 6400.00 6500,00 6600,00 6700,00 6800,00 6900,00 7000,00 7100,00 7200,00 7300,00 7400,00 7500.00 7600,00 7700,00 7800,00 7900,00 I00,0 3871.30 I00,0 3950.7! I00,0 4029,78 I00,0 410S,59 100,0 4187,91 100,0 4267,79 100,0 4347,47 100,0 442?,24 I00o0 4506,93 100,0 4596,19 100,0 4665,19 I00,0 4743,92 I00,0 4822,37 100,0 4900,79 100,0 4979.37 100,0 5058,41 100,0 5137,35 I00,0 5216,15 100,0 5295,00 I00,0 537:,03 lO0,O 5453,37 I00,0 5532,46 100,0 5612,32 iO0oO 5692,61 I00,0 5772,40 100,0 5851,41 I00,0 5929,45 I00,0 6007,68 I00,0 6086,96 I00,0 6166,35 lO0,O 6245,30 100,0 6324,09 100.0 6403.47 100,0 6483,02 100,0 6561,84 SURV£~ CALCULATIONS ********~*** CI~CULA~ ARC TARGET ST~TIOH AZIHUTH LATITU)t SECTION IHCLH, H/-S ft deo deg ft 1618.62 39,35 106,13 -559.16 1676,75 39,76 105,~4 -576,76 1735,33 40,29 105,73 -594,3~ 1794,01 39oaI 106,17 -611.99 1851.54 38,15 I06,55 -129.70 1907,74 37.30 107,24 -647.48 1963,83 37,56 107,81 -665,78 2020,42 37.93 107,76 -684,48 2077,40 38,05 108,20 -703,48 2133,94 36.~9 i08,53 -722.~7 2189,79 36,98 108,22 -741,~3 2245,72 37,36 107,71 -760.27 2301,5I 36,82 108,03 -77~,77 2357,38 37,5I i07,66 -777.Z~ 2413,61 37.64 107.19 -815,54 2470,11 37,99 i07,46 -833.J0 2526,98 38,I3 I07,53 -852,33 2584,08 38,52 106,91 -870.6~ 2640,g5 38,20 106,28 -889,42 2697,33 38,2I 105,57 2752,76 37,33 104,44 -V21.25 2807,86 38.42 103,62 -936,13 2862,89 37,52 103,63 -950.62 2918,00 38,44 I03.~2 -965.27 2972,77 37,t3 104.05 -VSO,G8 3027,69 37,86 104,38 -995,03 3082,90 37.61 I04,88 -1:I0,48 3137,37 36,38 105,20 -t026.10 3191,44 36,81 I05,3~ -1641,~I 3246,27 37,34 105,~8 -I058,04 3302.17 38,26 106,0~ -1C74.92 3359,30 3~,15 i06.35 -I092,38 3416,35 37,90 106,7I -lifO,lO 3472,23 37.20 [06.60 -1127.5~ 3527,88 37,65 106,40 -1144.~2 3584,i3 38,12 106.68 -I162,3I 3640,60 37,90 t06.70 -1179.?? 3696.30 37,02 106.32 -1197,28 3751,83 37,5~ 106.86 -12!4.5~ 3808,47 3~,$8 I¢7.50 -1232.?~ 1-65/H-25 ~ .... 3ZPARTURE DISPL~CEM£HT ~t ft ft 1646,5I 1738,86 I707.73 1802,59 1769,60 186~.73 I831.47 1931,01 1891,83 1993,87 ~ZIMUTH deg I08,7& 108,66 10~,56 108,48 108,41 i950,37 2055,04 108,37 2008.33 2115,91 108,34 2066,62 2177,02 108,33 2125,16 2238,57 IO~.]Z 2182,97 22~?,45 108,32 2240.06 235~.5: 108.32 2297.53 2420,05 I08,31 2354,93 2480.36 108.30 2412,43 2540,77 108,29 2470.61 2601.74 108,27 2529.14 2663,04 108,25 2587.94 2724,69 108.23 2647.17 2786,69 108,21 2706.~5 2848.72 108,17 2766.I2 2910,52 108,12 2825.28 2971,66 108,0& 2884.84 3032,?2 107,98 2944,63 3094,27 I07,89 3004.40 3!55,66 107,81 3063.85 3216,79 107,7: 3122.86 3277,55 107,67 3182,07 3338.~6 107,62 3240,19 339~ ~ ,,~ !07,57 3297,69 3458,3~ 101,53 3355,75 351~,~3 107,50 3414,67 3579,57 107,47 3474.72 3642.38 I07,45 3534,43 3704,66 107,4: 3592,81 37~5,60 107,42 3651.08 382J.3~ 107.41 3709,95 3887.7-~ 107,40 3768,94 3949.3: 107.38 3827,25 4010,15 107,37 3885.32 4070.7: 107,36 3944.11 4132.25 107,36 DLS deg/ lOOft 0,98 0.40 0,55 0,56 1,68 0,95 0,43 0.37 0,30 I,)~ 0,18 0,49 0,57 0.73 0,32 0,39 0,15 0,55 0,51 0,44 :,12 1.20 0,90 0.94 1,31 0,76 0,39 1,24 0,44 0,62 0,93 0,91 1,27 0,70 0,47 0,50 0,22 O,PI 0,65 0,89 II **k ..******* ~NAI)RILL SURVEY CALCULATIOHS ************* CIRCULAR ARC METHOI)****~*~ 1-65/H-25 M£ASURED IHTERVAL VERTICAL I)£PTH I)EPTH ft ft ft 8000.00 100.0 6639,94 8100,00 I00,0 6717,45 8200.00 I00.0 6794,88 8300,00 I00.0 6872,50 8400,00 lO0.O 6949,88 8500,00 8600.¢0 8700,00 8800,00 8900,00 9000,¢0 9100.00 V200,CO 9300,00 9400.00 9500,00 9600.00 9700,00 9800.00 9900,00 100,0 7027.81 100.0 7106.32 100.0 7154,35 100.0 7262.I4 100,0 7340,65 100,0 7420,23 100,0 7499.97 I00.0 7579,38 100.0 765~,49 100,0 7737.45 100.0 7816,24 100.0 7894.67 100.0 7972,67 100.0 8050.21 100,0 8!27,19 TARGET STATIOH AZIMUTH LAZiTU~E SECTION IHCLN, H/-S ft deg deg ft 3866,03 38,92 107,17 -1251,37 3924,09 39,44 106,82 -1269.E3 3982,I9 39,08 106,82 -1288.15 4039,91 39,[0 106.11 -1306,02 4097,49 39.50 105.05 -1323.03 4154,23 38,11 105,10 -1339,~2 4210,31 38,42 105,06 -1355o44 4266,95 39,01 105,12 -1371,72 4324.05 38,86 105,91 -1388,52 4380,67 37,62 106,82 -1405,96 4436,42 36.97 [07,46 -1423,~1 4492,21 37.26 108.12 -1442,25 4548,70 37.~0 108.96 -1461.58 4605,69 37,82 108,84 -1481.39 4662,90 37,90 109,07 -1501.32 4720,37 38,12 ,109,21 -1521,52 4778,36 38.56 109,60 -1542.13 4836,94 38,92 109,56 -1563.I0 4896.18 39.39 II0,36 -1584.6~ 4956.23 39.95 110,32 -1606,84 DEPARTURE OlSPLACE~ZHT ~: E/'W ft ft 4003,73 41~4,73 4064,15 4257,91 4124,73 432l,!~ 4185,19 4384,2~ 4246,20 4447,54 AZI~JTi~ dec 107,36 107,35 107,34 i07,33 I07,31 4306,71 4510,16 I07,27 4366,51 4572,05 107,25 4426,90 4634,55 107,22 4487,45 4697,3~ 107,19 4546,84 4759.25 107,18 4604,74 4819,84 107,18 4662,19 4850.15 107,19 4719,82 4940,94 107,21 4777,68 5002.0~ 107,23 4835,73 5063,42 107,25 4893,91 5124.97 107,27 4952,41 5186,96 107,30 5011,37 52~,49 107,32 5070,72 5312,5~ 107,35 5130,58 5376,32 I07,37 deq/ iOOft 0,58 0,56 0,36 0,45 0.78 1,39 0,31 0,59 0,52 1,36 0,76 0,49 0,61 0,23 0,I6 0,24 0,50 0,36 0,69 0,56 II II II II 10025,01 10119,71 10215,36 10310,21 10405,32 10502.51 10597,17 10689,86 10785.54 10880,82 10965,v7 11058,8i 11154,16 I1245,67 I1343,~I 11438,26 11534,90 11629,91 11723,90 1181~,75 125,0 8222,29 94.7 8293.23 95,7 8363,47 94,8 8431,29 95,! 8497.47 97.2 8563,20 94.7 8625,14 92,7 865:,42 95.7 8745,03 95,3 880:,79 85,i 8857.44 92,8 8913,44 95,4 8969.53 94,5 902¢,39 95,1 9079,84 94,5 9136,67 96.6 9195.70 95,0 9253,L1 94,0 9310,36 94,8 ~3~,76 5033.25 41,00 113.42 -1637.08 5093,91 41.99 117.50 -1~64,06 5157,53 43.51 119,97 -1695.29 5223,00 45,20 122,16 -1729.52 5290,78 46,62 123,97 -1766,80 5362,13 48.29 127,28 -180~,51 5433,67 49,97 129.72 -1853.08 5504,92 50,51 130,19 -1895,84 5578,96 50,88 129,80 -1946,42 5653,17 51,43 129,66 -1993,~5 5720.08 52,18 129,79 -2036,62 5794,12 53,62 129,30 -2083,76 5871,23 54.32 131.01 -2133.~9 5948,19 54,73 130.62 -Z183,80 6025.49 53.96 129,16 -2233.37 6100,92 52,05 130,39 -2281.62 6177,41 52,66 132,33 -2332,19 6253,08 52,99 131,59 -2382,80 6327.58 51,97 132,77 -2432,~5 6402,24 52,02 132,72 -2483.58 5205,85 5457,19 107.46 5262,47 5519,30 107,55 5319,38 5582,9~ I07,68 5376.16 56~7o51 107.53 5433,40 5713,44 I08,01 5491,57 5781,70 108.23 5547,57 5848,89 108,47 5602,18 5915,2~ 108.72 5658,90 5984,29 108,98 5715,97 6053,74 109,23 5767,44 6116,47 109,45 5824,54 6186,06 109,6~ 5883,47 6258,36 109,93 5941,72 6330.33 110.1~ ~001,03 6403,15 110,41 6059,01 6474,36 6116,43 6545,9-5 6172,73 6616,67 6282,86 R6 110.63 110,87 II1.11 JUL 0 9 1996 Alaska 0il & Oas Cons. Commission Anchorage 1,62 3,04 2,37 2,40 2,02 3,04 2,6~ 0,70 0.50 0,59 0.89 1,61 1.63 0,55 1,49 2,27 1,71 0,71 1,47 0,07 DEFTH 9EPTH f~ ft ft 11914,50 95.8 9427,77 12011,09 96,6 9487,19 12106,14 95.0 9545.54 12203,13 97.0 9604,83 12297,07 93.9 9661,57 12392.53 12457.07 12582.47 12675,46 12771.07 12866.93 I2957.~6 1305¢.97 13151.50 13245,33 13341,81 95.5 9718.80 94,5 ?775.40 95,4 9832.49 93,0 9897,88 95.6 9945,24 95,9 10003.04 90,9 10056,86 97,i 10113,82 96,5 10170.80 93,8 10226,83 96.5 102~5,I0 ~URU£¥ CALCULATIONS CIRCULAR ARC ME~H33~,~ TARGET STATION AZIMUTH LATITUDE S£CTIOH INCLN, N/-S ft de~ deq f: 6477,56 51.85 132,96 -2534,85 6553,61 52,19 133,48 -2587.00 6628,47 52.07 134,62 -2639,16 6704,93 52,56 i35,81 -2693.64 6779,51 53,13 134,47 -2746.71 6855,75 53.20 133.56 -2799,79 6731,42 53.26 131,01 -2850,74 7007,85 53.23 129,78 -2900.28 7082,54 53,65 129,65 -2~4~,00 7159,02 52,~2 i29.06 -2996,51 7235,48 53,21 129,58 -3044,97 7308,77 54,21 129,60 -3091,68 7387,42 53.97 129.57 -3141,80 7465,33 53,J7 [29.75 -3191,53 7540.59 53,00 128,82 -3239,19 7617,47 52,~9 129.21 -3287,~0 ]£PARTUR£ DISPLACEM£HT at £/'W ft f: 6338.15 6826,24 6393,64 6897,18 6447,57 6966,80 6501.63 7037,54 6554,45 7106,70 AZIMUTH DLS deq/ deq lOOft 111.90 0,25 112,03 0,53 112,26 0,96 112,50 1.09 112.7~ 1,29 6609,39 7177,94 112,96 0,79 6665,4! 7249,44 11~.16 2,16 ~723,62 7322,49 113,33 1,33 6781,07 7394.16 113.50 0,47 6840,2I 7467,77 113,66 1,18 6899,37 7541,43 113.91 0,75 ~955,85 7611,99 113,96 I,I0 7016,46 7667.76 114,12 0,25 7076.45 7762,8~ 114,28 0.3: 7134.70 7835.5~ I14.42 1,06 7194.44 7910,01 I14.56 0.45 RECEIVED JUL 0 9 1996 .. Alaska Oil & Gas Cons. Commission Anchorage Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 14, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the SLIM 1 & ARC 5 for well BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1-65/N-25, Job # 96075 was sent to: 1 OH LIS Tape 2 BLUELINES 1 FILM 1 DEPTH SHIFT MONITOR PLOT Arco Alaska Inc. Attn: Dede Schwartz, ATO-1336 Anchorage, Alaska 99510-0360 1 OH LIS Tape 1 RROLLED SEPIA ¢~StateSf Alaska Alaska Oil & Gas Conservation Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 1 OH LIS Tape '"; ~ .... 1 BLUELINE 1 RFOLDED SEPIA ..... _ _ .. .. . .. Exxon ComPany, USA Alaska Interest Organization Attn: Susan Nisbet 800 Bell St., EB3083 Houston, Texas 77002-7420 1 OH LIS Tape 1 BLUELINE 1 RFOLDED SEPIA Sent Certified Mail Z 777 937 418 UNOCAL Attn: Debra Childers 909 W. 9th Ave. Anchorage, Alaska 99519-0247 1 OH LIS Tape 1 BLUELINE 1 RFOLDED SEPIA Amoco Production Company 1 OH LIS Tape Attn: Shirley A. Kuhr 1 BLUELINE 18506 Osprey Circle 1 RFOLDED SEPIA Anchorage, Alaska 99516 Sent Certified Mail Z 777 937 422 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: i.,';,~ i ~- ~- IJS~HLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD Date Delivered: Received By: LARRY GRANT Attn. ALASZ~LA OiL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHCP~.GE ~, 99501. Date: 24 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear S ir/}!adam, Enclosed, .o~=_~a~.=:.= _~':~_~ ~:~o~..~ data as described below: W~LL ~ DESCRiPTiON i PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 5723.09 Run # 1 6569.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 /~/ ~ Or F,~X to /(907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 January 1996 RE: Transmittal of Data ECC #: 6569.00 Sent by: HAND CARRY Data: SBT/GR Dear Sir/Madam, Reference: 1-65/N-25 ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ 0~~o (907) 563-7803 RECEIVED Date: FEB 0 O %99~ Alaska Oil & Gas Cons. Oommission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1-65/N-25 1 ZDL/CN FINAL BL+RF 1 DIFL FINAL BL+RF 1 CN FINAL BL+RF 1 SSVD FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6558.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by:AY ~C~-~ ~r~FAX t°~~~/~(907) 563-7803 Date: ,~J~ska 0~i & Gas Co~. /~chora§e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 16 January 1996 Transmittal of Data ECC #: 6558.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: ~~ BP ~? ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Received by: Suite 201 Anchorage, AK 99518 to (907) 563-7803 ~ssk~ Oil & Gas Co~s. Commi~ion ~qchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FRO,M: David Chairm~ Blair Wondzell, P. !. Supervisor ' Bobby Foster,'?~: ?:f' Petroleum Inspector DATE: FILE NO: SUBJECT: December 17, 1995 AKHILQCD.doc BOPE Test - Doyon 15 BPX- DIU - 1-65 / N-25 PTD # 95-0188 Endicott Field Sunday,..December.17, 1995: i traveled this date to BPX's Endicott field well 1-65 / N -25 and witnessed the BOPE test on Doyon rig 15. As the attached AOGCC BOPE Test Report shows, there was 1 failure. The upper pipe ram control valve on the accumulator leaked. The rig mechanic adjusted the actuator on the valve and the valve stopped leaking. Ail of the control valves on the unit are worn and I spoke with Eddie Vaughn, BPX rig rep. and Allen Sinclair, Doyon tootpusher, and they agreed to rebuild all of the valves as soon as the rig sets the 7.624" casing. The rig was clean and all equipment seemed to be in good working order. The location was clean and all excess equipment was stored properly. S,.,ummary: i witnessed the BOPE test on Doyon rig 15 drilling BPX Endicott well 1- 65 / N-25 - Test time 3.5 hours - 1 failure. Attachment · AKHILQCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Drlg Contractor: DOYON Operator: BPX Welt Name: 1-65 / N-25 Casing Size: 10. 750" Set @ Test: Initial X Weekly Rig No. 15 PTD# Rep.: Rig Rep.: 5,211' Location: Sec. Other DATE: 12/17/95 95-0188 Rig Ph.# 659-65110 EDDIE VAUGHN ALLEN SINCLAIR 36 T. 12N R. 16E Meridian Urn. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig O/~ Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure 1 500/5,000 I 500/5,000 1 1 500/5,000 500/5,000 P/F P P P BOP STACK: Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves I Check Valve Quan. Test Press. 300/3,000 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 PtF 500/5,000 P CHOKE MANIFOLD: No. Valves 17 ~ No. Flanges 42 Manual Chokes . 2 Hydraulic Chokes I ~ Test Pressure P/F 5,00/5,000 P ,,p 50O/5, O0O Functioned Functioned P ACCUMULATOR SYSTEM: N/A. . System Pressure 3,100 I P Pressure After Closure 1,400 i P- . MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 35 sec. , , ,, Trip Tank YES YES System Pressure Attained 2 minutes 50 sec. Pit Level Indicators YES YES Blind Switch Covers: Master: YES RemOte:' YES Flow Indicator YES YES Nitgn. Btl's: 4 @ 2200 Meth Gas Detector YES 'YEJ$ Psig. H2S Gas Detector YES YES Number of Failures: I ,Test Time: 3.5 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within NOTE days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I I I ' I I II I I I I I I I I I I I II I I I REMARKS: NOTE: The failure was on the accumulator unit. The control valve on the top p. ipe rams was leaking.- the hydraulicaccuator was adjusted and the valve quit leaking. Ali of the valves on the unit will be overhauled when the 7.625" casing is set and an inspector will be notified per.mY request. Distribution: orig-Weli File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I I I I Waived By: Wrtnessed By: BOBBY D. FOSTER FI-021L (Rev.12/94) AKHILQCD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman~ THRU' Blair Wondzell, ~j2~ FILE NO: P. I. Supervisor FROM: Lou Grimaldi, u-~.- SUBJECT: Petroleum Inspector December 13, 1995 EKHJLLCD.DOC Diverter Test - Doyon 15 BPX- DIU - 1-65/N-25 PTD # 95-188 Endicott Field Tuesday, December 12, 1995: I traveled to BPX's DIU well 1-65/N-25 and inspected and function tested Doyon rig #15's diverter system. I arrived at approximately 2130 and the test lasted until 0100 Wednesday morning. I found the layout of the diverter to be satisfactory although both vent lines were filled with blown-in snow. I requested that the snow be removed from the lines. This required that the vent lines be disassembled, cleaned and reassembled. The system tested and functioned properly. The Annular preventer closed in fourty seconds and a recharge of the accumulator was accomplished in 2 minutes fourty five seconds. Summary: I witnessed the satisfactory function test and inspected the installation of the diverter installed on Doyon rig 15 drilling BPX' DIU 1-65/N-25. i found obstructions in the vent line Attachment:' EKHJLLCD.XLS cc; Scott Sigurdsen/Randy Thomas ~"~ STATE OF ALASKA ALASKA OIL Ah,~J GAS CONSERVATION COMMISSI~JN Diverter Systems Inspection Report Operation: Drlg Contractor: Doyon Rig No. Operator: BPX Oper. Rep.: Well Name: 1-65/N-25 Rig Rep.: Location: Sec. 36 T.12N R. 16E Development 15 PTD # Date: 12/12/95 X Exploratory: 95-188 Rig Ph. # 659-6510 James Carlisle Merdian Greg Burley Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: P Well Sign: P Systems Pressure: 3000 psig Housekeeping: P (Gen.) Drlg. Rig: P Pressure After Closure: 1800 psig Reserve Pit: N/A Flare Pit: N/A 200 psi Attained After Closure: min. 35 sec. Systems Pressure Attained: 2 min. 45 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: Four Bottles Diverter Size: 20 Divert Valve(s) Full Opening: P Valve(s) Auto & Simultaneous: P Vent Line(s) Size: 10 ~" Vent Line(s) Length: Line(s) Bifurcated: P Line(s) Down Wind: P Line(s) Anchored: P Turns Targeted / Long Radius: P in. 2700 Average psig in. 174 ~' ft. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: P P Mud Pits: P P Flow Monitor: P P GAS DETECTORS: Light Alarm Methane P P Hydrogen Sulfide: P P North ~Wind Non Compliance Items I Repair Items Withi Immediate Day (s) And contact the Inspector @ 659-3607 Remarks: Vent lines obstructed with snow, removed lines and cleared out snow. Line ends were covered with plastic bags. DistribulJon orig.- Well File c - OpedRep c- Database c- Trip R~i.F(j~ (Rev. 7/93 c- Inspector AOGCC REP.: EKHJLLCB.XLS OPERATOR REP.: Louis R. Grimaldi ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 5, 1995 Larry Wolfson, Senior Drilling Engineer BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Duck Island Unit/Endicott 1-65/N-25 BP Exploration (Alaska) Inc 95-188 3058'NSL, 2218'WEL, Sec 36, T12N, R16E, UM 4749'NSL, 5243'WEL, Sec 05, T11N, R17E, UM Dear Mr Wolfson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before ddiling below the surface casing ? shoe must be given so that a representative of the Commission may witness the test. Notice may be ector on the North Slope pager at 659-3607. .~.~; David W J Chairman BY ORDER OF THE COMMISSION Ijb/enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - wlo encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill[]llb. Type of well. Exploratory[] Stratigraphic Test[] Development Oil[] Re-Entry [] DeepenFlI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047502 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25,025) 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 300'NSL, 354' WEL, SEC. 31, T12N, R17E 1-65/N-25 2S100302630-277 At total depth 9. Approximate spud date Amount 4749'NSL, 5243' WEL, SEC. 05, T11N, R17E 12/10/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 312828 531 feet No Close Approach feet 2560 13967' MD / 10106' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 800 feet Maximum hole angle 9o o Maximum surface 4254 psig At total depth (TVD) 9761'/5230 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 30" Struct. Drive Pipe 90' Surface Surface 90' 90' Drive 13-1/2" 10-3/4" 45.5# L-80 BTC 5364' Surface surface 5364' 4431' 860sxPF'E',580sx'G', 150sxPF'E' 9-7/8" 7-5/8" 29.7# uss-95 Butt 13048' Surface Surface 13048' 10106' 5275x Class 'G' 6-3/4" 4-1/2" 12.6# L-80 919 13048' 101o6' 13967' 10106' Uncemented Slotted Liner Slotted 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ................. Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce, j:tYq~that the,,foregoi~g, is true and correct to the best of my knowledge Signed~[ ~'---,"~.4..~ ~'./ ~,('~~~"' z,'~, Title Senior Drilling Engineer Date ~" /' ~/ ' Commission Use Only Permit Number IAPI number Approval d~at~e . See cover letter '~,.~-.--/,'(~? J50-c::~,~.-.~-- 2_2_~.~_ 7 /-~- ~..~. '~_~- for other requirements Conditions of approval Samples required [] Yes ~'No Mud Icg required [] Yes ~[ No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No pressure r M, Required working :~'J'°Jal~l:"~e'~' ',._.~.[ .,..~,, u ~.y 1-13M; j~I'5M; I-I10M; r-115M; Other: ,'~ ~r~.f ,Johnston by order of ...// Approved by '" Commissioner me commission Date/~.~/,..;;-/¢/ Form 10-401 Rev. 12-1-85 Submit in I Well Name: I 1-65/N-25 Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 3058 FSL 2218 FEL S36 T12N R16E UM Target Location: 300FSL 354 FEL S3! T12N R17E UM Bottom Hole Location: 4749 FSL 5243 FEL S05 TI 1N R 17E UM I AFENumber: ]727103 I Estimated Start Date: ] 12-10-95 [ ]Rig: I DOYON 15 I Operating days to complete: [ 35 ]MD: I 13967 I ITVD: I1°1°6 I IKBE: I56 I Well Design (conventional, slimhole, etc.): ] SLIMHOLE HORIZONTAL Formation Markers Horizontal Well Bore: Formation Tops MD TVD (BKB) UPPER SV SHALE 3958 3366 BASE UPPER SV 4380 3686 TOP SV MARINE 4968 4131 SHALE BASE SV 5120 4246 MARLINE SHALE SV-5 5146 4266 BASE SV-5 5496 4531 TOP UGNU 6982 5656 TOP WEST SAK 8533 6831 TOP 9722 7731 SEABEE/AYLYAK TOP SHALE 11043 8866 WALL/TUFFS HRZ 11750 9481 BASE HRZ 12135 9746 - PUT RIVER Absent Absent LCU 12164 9761 KEKIKTUK 3C Absent Absent 3B 12164 9761 5230 psi. 3A 12309 9836 4631 psi. 2B 12580 9976 4630 psi 2M 2A Absent in Absent in 4336 psi HAW HAW lC Absent in Absent in HAW HAW Well Plan Summary Page 1 Casing/Tubing Program: Hole Size Csg/ WtfFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 13.5 10.75 45.5 L-80 BTC 5364 0 5364/4431 9.875 7.625 29.7 USS-95 Butt 13048 0 13048/10106 6.75 4.5 12.6 L-80 919 13048/10106 13967/10106 Logging Program: Open Hole Logs: I Cased Hole Logs: DIL/MSFL/LDT/CNL/GR FMT 10-15 points dependent on hole conditions Horizontal Hole MWD,GR SBT Mud Program: I Special design c°nsiderati°ns I Refer t° attached change °ver pr°cudure t° dissplace mud t°IFlo-Pro Surface Mud Properties: I SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 300 40-60 30-60 60-80 8.5-9.5 none- 10 to to to to to to to 9.5 100 20-40 15-20 20-30 8.5-9.5 none-10 Intermediate Mud Properties: Subject to Pilot Hole Properties. The mud weight in the change based on pilot hole drilling results, intermediate hole may vary based on the pilot hole results. Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.2-10.5 50-6- 20-30 12-15 25-30 9.5-10.0 <6 to to to to to to to Lubtex as required. Production Mud Properties: Subject to I FLO_PRO change based onPilot hole drilling results I Density Marsh Yield 10 sec 10 min LSRV Fluid (PPG) Viscosity Point gel gel cps Loss 9.3 NA 40-45 18-23 24-29 + 50,000 +6 Clorided mg/liter _+ 40,000 K:N ratio >1 Well Plan Summary Page 2 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and drilling fluid system schematics on file with AOGCC. Directional' · I~OP: 180o IMaximum Hole Angle: Close Approach Well: 45 in pilot hole and 90.0 in High angle hole I NONE I The above listed wells will be secured during the close approach. Deep well intersections NONE. Well Plan Summary Page 3 1-65/N-25 OPERATIONS SUMMARY: Dig out cellar, Weld on landing ring. Ensure landing ring is the proper height with Endicott Field personnel install diverter. MIRU Doyon 15. Hold pre spud meeting with crew. 1. Test diverter. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadrill & Gyrodata to insure they are following JORPS. Drill hole to 4431' TVD. 2. Run 10-3/4" 45.5 ppf surface casing 3. Cement surface casing. 4. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. 5. ND diverter. NU Bop's & test. 6. Drill out shoe and perform LOT. 7. Directionally drill pilot hole to 13,248' TD. Well site geologist will help pick final TD (175' below the base of the horizontal target interval)..Have sample catchers and well site geologist on site before drilling the Kekiktuk. 9. Use key seat wiper for Tuffs and HRZ 10. RU E/Line & run open hole logs ("Triple Combo" ).+ FMT Optional based on hole conditions. 11. Plug back the pilot hole to 9600' MD. Spot balanced cement plug across reservoir. Spot 50 high vis pill and kickoff plug.WOC 12 hours. 12. Directionally drill intermediate hole to 10,106 TVD. Well site geologist will help pick final target TVD based on pilot hole results. 13. Run 7-5/8" production casing and cement. 14. Run bond logs on wire as deep as possible. 15. PU 6-3/4 "BHA and drill 10' outside 7-5/8" casing. Change over mud system to Xanvis. Directionally drill horizontal section to 13,967'. 16. Optional based on hole conditions. Make hole opener with 7-5/8" casing scraper spaced out to the packer setting depth approximately 11,900'. 17. Run 4-1/2" L-80 slotted/solid liner with liner top packer at 11,900'. Lotate XN nipple at 45 degrees and liner top packer set in no greater tha 6/100 dog leg. Release from the packer and displace Xanvis mud to filtered seawater. Spot lithium hypochloride breaker across the liner. 18. Pull bowl protector. Run 4-1/2" 13CR-80 completion with SBR. Establish space out. Reverse in inhibited brine. Spaceout and land the robing.2' from fully inserted. 19. Set BPV.ND Bop's. NU tree. Replace BPV with TWC and test 4-1/16" 5M# tree. Test packer. 20. Freeze protect tubing. 21. RD MO Rig. Distance to nearest well 1-63/T-22 andl-67/T-20 ten ft Max surface pressure 4254 psi based on @ 5230 psig at 9761 (TVD). Hazards'. Pressure: Abnormally high pressures may be encountered in the 3C/3B due to gas injection approximately 1500' downdip of the target location at well 1-15/P-25. Estimated sandface pressure based on average 1995 wellhead injection pressure is shown in Section III (right). Gas: Moved GOC is expected in the uppermost 2B. Mud: Equivalent mud wt. in the pilot hole across 3B of 10.5 lb/gal, possible. Faults: Datum: Top K2B Fault Distance Throw from target Mid-field 1000' South < 50 ft Unnamed I 400' south <30 ft Unnamed 2 750' SE <30 ft Unnamed 3 600' NE <30 ft Geologic Notes · Potential high pressure (5000+/- psi) in 3A/3B due to gas in- jection in NW MPI (10.7 ppg mud required recently at nearby well 1-33/M-23) · Midfield fault, located 200-500 ft beyond planned end of horizontal section should not be penetrated due to possible loss circulation during drilling and/or water/gas influx during production. · Top 2B along horizontal well bore is expected to range from 9940 at BHS to 9900 ft TVDss at EHS; minor faulting is expected along horizontal wellbore path. · The lateral and vertical extent of top 2B gas underrun/cone associated with 2B production at 1-35/O-25 is the cause for the uncertainty in the 2B target GOC FLUIDS/CONTACTS 3B Gas 3A3 Gas 3A2 Gas 2B Oil/Gas 2A Tar/WtdOil I Aquifer/Tar Original Gas Cap Original Gas Cap - high pressure Original Gas Cap - high pressure Moved GOC 9955; COW(::; 10125 COWC 10140' ss; Tar 10195 Kick Tolerance: 118 bbls 13.9 LOT (ref 1-03/P-16) and 10.7 MW. Close approach · none requiring wells to be shut-in' H2S: No potential hazardous levels of H2S are anticipated in this well. Lost Circulation: No recent loses have occurred on the MPI. Stuck Pipe: Practice Good Stuck Pipe Prevention Procedure. Request for Annular Injection Well 1-65/N-25 will be drilled in accordance with the attached Permit to drill. The following criteria for annular injection have been met. 1)The Surface casing will be set 4431 TVD BKB which is below the required SV shale 3,200'-3,500' TVD, 2) A determination has been made the pumping operation will not endanger the integrity of the well being ddiled by the submission of data to AOGGC on 7-24-95 which demonstrates the confining layers, porosity, a_nd permeability of the injection zone. 3) Pumping into hydrocarbon reservoir will not occur. Annular Injection: The Doyon solids handling unit will be utilized for the entire well. injected should be hauled to CC-2A. All other cuttings thst cannot be The following Annular Injection Guidliines will be followed. DO NOT EXCEED 35,000 bbis IN ANY ANNULUS. Maximum injection rate is 3 BPM and maximum volume is 1,000 bbls in any 24 hr period.' Maximum injection pressure is 2000 psi. In addition to annular injecting into 1-65/N-25 the following well(s) have been previously approved for annular injeotion: IT is requested that the well previously approved but whose expiration is 12-31-95 will be reapproved for continued use provided that the total injected volume does not exceed 35,000 bbl. AREA -"" " WELL PREV VOL PE~IMn-i'ED PERMITTED'I~ATE$ INJECTED VOl. (BB,L$) IBBLS) I III END - MDI 2-40/S-22 16242 35,000 1-1-95 to 12-31-95 9-16-95 END_ MI~! 1-31/M-21 ' 0 35,000" 1-1-95 to 1~'-~1-g5 END-MP'I 1-19/I-18' 0 ' 35,000 ' 6-28-95 to6-28'-96 END_MPI 1-33/M-23 0 35,000 8-31-95 to 8-31-96 END_MPI 1-03/P-16 0 35,000 9-21-95 to 9-21-96 EN D_M PI 2-48/O-13 0 35,000 10-31-95 to10-:31 - 96 END._.MP! 1-61/Q-20 0 35,000 1/1/95 to 12/31/95 END - MDi 1-23/O-15 20464 35,000 1-1-95 to12-31-~5- 3-31-95 - ECEiYED 0 lgg AMMa 0il & Oa~ Cons. Oommi,~ Request for Annular Injection Well 1-65/N-25 will be drilled in accordance with the attached Permit to drill. The following criteria for annular injection have been met. 1)The Surface casing will be set 4431 TVD BKB which is below the required SV shale 3,200'-3,500' TVD. 2) A determination has been made the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 3) Pumping into hydrocarbon reservoir will not occur. Nov-14-95 12:22 Anadr- 1 DPC 9~07 "~4 2160 P.05 I .....SHARED SERVICES DRILLING <KB>o , i-65/N-25 [PILOT HOLE] (P4) "-- VERTICAL SECTION VIEW i i 7§0-~~ ~ -- --- Sect ion at: ! 13.47 , - TVD Sca]e · t i'nch = 1500 feet l§oo ................. ' ......'~%-~.~r-r~ Dep Scale ' ~ inch : ~500 feet ~~ .._ Drawn · 1t/14/95 225o .... AnadrJ 1] Schlumberger Nar&er Iclentif~cation MB BKB SECTN INCLN 3000 . ~ . A) KB 0 0 0 0.00 'J~'S~/'~ m'~V-S~L- ' 3~r~' ''']''..~,' _ i .... ' B) NUDGE ~..5/100 BUILD 200 200 .0 0.00 CI END 1.5/t00 BUILD BOO 7§B 46 9.00 3750 -.--',,.,-,~-.~,~'-,-*m- · .... D) START 2.5/~00 CURVE BO0 /98 46 9.00 ' .: %, El' END 2.5/t00 CURVE 2080 tg44 576 40.78 8 ~~~3~'-'-'-; .................-_=~. F) $0-3/4" CASING POINT 5364 443~ 2721 40.78- G) TARGET. (PILOT HOLE) t2687 9976 7504 40.78 K 4500 '~m¢¢mc-~3t ...... ' '---~-'~' ...... ~ ..... H) TD ~3248 ~0403 7870 40.78 , "T~-I..~,U ................. ~ ....... "- - ................. 5800 6750- _ "'l'~¢"gt ~ ' ~ ....... ~ ' ' ~%'' ................ .. 7500 ~ '~ , 'r~-SDU~ ~ tM- '~T~' .... ' ' ' \ 8250- 9000 'flD"s~4.,'[ ~ CL'TT'~rS- ' ~ .......................... ; ..... , 'Ti~"k~' ~,iBC' ..... '- '-~ =. ~=. ;-": = --=2-,2::2,'2=::2 ;:;:::--;,,'el_,,:;;!-';;, :2222~ 22 =. =.. ~0500 H J ANADRILi -~KA-DP" ~., r' ,..., ,, ¥.~ '/.~: I ~,~o ..... LIT¢ PLAN -' ~i'.:) EXE:CU'I"ION '~" ~ 13500 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 Sect ion Depart, ute (Ina~3'ill (cJ~ N25of.P4 2.50.03 lO: ~1 AN P) ., SERVICES DRILLIN$ " _. i ,4nadrJ 1 ] Sch]ucbenger -65/N-25 (PILOT HOLE) ,(P4) PLAN VIE~ CLOSURE · 7870 feet at Azimuth 113.69 -- , -- " ' JDECLINATION.: +0.000 (E) JSCALE ....... : ] inch = ]000 feet --~ ' ' , . . .arken Ident:~fica'[ion 1'4D' N/S ~ DJ STA"T 2.5/'00 CO,YE 'BO0 27 39 ~ ~0-3/4' 6ASZN6 POINT 5364 t ~ i ~ 2484 : G) TARGET (PILOT HOLE) t2687 30~6 687~ j F:EAS Bi L ITY 'f LAK "I E;(EC( 'T'ON I .... : ................. nnn ~:nn ~nnn ~nn . ~nnn n~nn 7000 · 7500 BOO0 850~ 500 0 500 1000 t500 2000: 2500 3000, 3500 4000 <- WEST · EAST -> ~nadrill [c)95 N25PHP4 2.~.03 lO: 13 ~ P) Z 0 < I I O f~ NOv-14-95 12:32 Anad~ '3 DPC 907 .... 44 2160 P.18 .-- SHARED SERVICES ORILLING ' A) TIE-IN CURVE 3/~00 :g600 2213 5022 . ,,, o1-END e/~ CUnVE .~taS ~25 CLOSURE ' 7992 feet .at Azimuth 116.66 El CURVE~8/IO0 .- '~2599 2403 6510 .-, F). 9-5/8' CASING POINT ~3048 2755 6747 · DECLINATION. +0.000 (E) .' Gl END B/lO0 CURVE .13048 2755 · 6747 SCALE: · l'inch = 400 feet H) TAROT (BSL} i3048 2755 6747 ' - Il. TO (E~) 13967 3586 7142 . . Anadr~] ] SchJumberger . . .. ~ .. . . - . . . ~ .. . ~-. . . - ~ -- . . . . ~.~ - . . . . . . · .. . ... . . . . .. 4800 5000 5200 54~ 5600 5800 6000 ~00 6400 '~00 6800 ' 7000 7200 7400 7600 EAST -> (c) 95 N2~M34 2..~.04 tt: ~ k~l P| Nov-14-95 12:29 Anad~ -1 DPC 907 ¢4 2160 P.14 I SHARED SERVICES. DRILLING I VERTICAL SECTION VIEW .... Section at: ~54.57 · , . , TVD Scale.' ~ inch = ~200 feet' o-- ', . Oep Scale'. 1 inch = 1200 feel ~ Dra~n . li/j4/95 · · ,,. /nadrj]] SchlUmberger ~ 0- ' Harker ~Oentifica~Jon HD BKB SECTH ]NCLN - "~ A) TIE-IN CURVE 3/100 9600 7639 4155 40.78 · ~ ~ B) END -3/100 CURVE .- 10865 8710 4382 29.04 ' · . C) CURVE 8/~00 t~363 9146 4309 29.04 0-- ~,-- D) END B/~O0 CURVE 12~45 975~ 4598' 58.83 ~ E) CURVE 8/$00 12599 gg~ 4966' 58.83 ~~ ~ ~¢~L-'~ .... ~- ............. ~---,- F) 9-5/8' CASING POINT 13048~ $0106 5385 90.00 ' D- ~ G) END B/JO0 CURVE 13048 .~0t06 5385 90.00 '~~ ~ ................... ,~- Jr -- ' ...... H) TARGET (BSL) t3o48 $0106 5385 90.00 ~ I) TD (ESL) 13967 ~0t06 6305 90.00 ~~ ~-~'~---....... ~ ' ....... .... ....-.... ,.. .... . ...... -,. ...... , ~ · 2, ~~J~ L AK~,-DPC ~ ~ ~ ~ . - ..... , F~:A~I'Bt L.~T'¢ L ., " ',. ~40T APPEOV~D FOR , ",, [ XEC U-FIrDN )-~~ ,~2¢-,.. ' " ..... ~LA~_ ~'~_'~ x'~> ) ~ 1~ ~,~ m~ ~- ~r ......... ' A _~ ......... ~ ~ ~_.~ .:. ~ .. ; .~ ...... ~ .......... .--------· ; ' i L~, ~'~ I - " . ' · I - '~- ~ ..... ~~ ~ =, =:: =: ~ ' ' .... - -'r - - - ' ......... , ::==:, :::= ..... ~_. ::~:= I , 3000 3600 ~00 4~00 5400 6000 6~00 7200 7800 Sect ion Oeparture P-07 Rig Name Sud Csg Dep ....... VOLUME (BBLS} Method of displosal=pumping down outer annulus SOURCEWELL DATE OF DIESEL/ Daily Cum. MUD/CTGS BRINE WATER COMPMCATIONS, COMMENTS NUMBER INJECTION FREEZE PROT. T o t a I Page I Pilot Hole Abandonment Plug Well 1-65/N-25 RIH to TD of pilot hole 13,262 MD. with 5 drillpipe and 3.5 drillpipe stinger open ended DP. Circulate. RU Halliburton. Lay 140 bbl of balanced plugs across the reservoir. Volume based on bringing cement top 500' above reservoir and 10% excess over gauge hole. G Cement +.2%Halad 344+.2% CFR-2 15.8 ppg 1.15 Yield TT 3 Hours POH to 10400' leaving mud of drilling weight or greater between plugs. Spot 50 bbl high vis pill of weight equal to or greater than mud weight..POH to 9900 circulate and lay cement plugs kick off plug.. RU Halliburton. Lay 50 bbl balanced plug. Volume based on placing cement to 100' above KOP of(9600') + 30% excess G Cement .6% CFR-3,.25% LAP 17 ppg .99 Yield TT 2:45 hours POH Wait on cement a minimum of 12 hours but no more than 16. IF its not hard in 16 hours it never will be. 1-65/N-25 Cementing Summary 1-65/N-25 CEMENT PROGRAM- HALLIBURTON 10-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 860 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 580 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 £t3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Lead slurry w/30% excess over gauge hole. 2. Tail slurry to 3958w/30% excess over guage hole. 3958'MD = top of SV shale 2. Top job volume 150 sx. RECEIVED 9-7/8 Pilot Hole Abandonment CEMENT TYPE: Premium ADDITIVES: .2% Halad 344,.2% CFR-2 WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. SACKS: 685 THICKENING TIME: 3hrs CEMENT VOLUME Volume based on placing cement to 500' above the top of the Kekektuk with 10% excess. MIX WATER: 5.00 gps 9-7/8" Kick Off Plug CEMENT TYPE: Premium ADDITIVES: .6% CFR-3,.25% LAP WEIGHT: 17ppg YIELD: .99ft3/sx APPROX. SACKS: 277 THICKENING TIME: 2:45hrs CEMENT VOLUME Volume based on placing cement 100' above kickoff point of 9600' with 30% excess. MIX WATER: 3.6gps 7 5/8" PRODUCTION CASING CASING SIZE: 7-5/8", 29.7# CIRC. TEMP 135°F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 527 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. Note: Cement to be mixed on fly the last half to have .4# of Super CBL per sack added and increase density to 16.1ppg. (1.05 cu-ft/sx) Have Halliburton record density on chart recorder. SPACERS: Pump 50 bbls Fresh Water; 70 bbls NSC! (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Displace at 14 bpm with rig pumps. CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 12164 BP EXPLORATION BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Fax # (907) 564-5200 Pages to follow (not including cover) ENDICOTT ASSET GROUP TO: Name Company FAX # FROM: Name & Phone ~_ ~_~Z' ~'~ c.,'/-~ - - '"'" VC:LJ .,. PERMIT CHECKLIST FIELD & POOL COMPANY INIT CLASS dev~ redrll [] aery [] ON/OFF SHORE ~ ~ ADMINISTRATION D~TE y ENGINEERING APPR DA~E 1. Permit fee attached ........... ' ........ 2. Lease number appropriate ................ 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. REMARKS N N N N N N N N N N N N N Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf csg.. N CMT vol adequate t° tie-in l°ng string t° surf csg ' ' '.~N ~'g2.~/~ -'~ ~ CMT will cover all known productive horizons ...... Casing designs adequate for C, T, B & permafrost.. . . Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved. .Y Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... i~~ N Drilling fluid program schematic & equip list adequate N BOPEs adequate .................... N BOPE press rating adequate; test to ~~)dg~C> psig.~ N Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ ~ N GEOLOGY .~PPR D~TE ~ 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . . ~/. Y N [exploratory only] GEOLOGY: ENGINEERING: JDH COMMISSION: DWJ .~---~' Comments/Instructions: HOW/Ijb - A;\FORMS~cheklist rev 11/95 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 * ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : 1-65/N-25 FIELD NAME : DUCK ISLAND UNIT BOROUGH · NORTH SLOPE STATE : ALASKA API NOWIBER : 50-029-22627-00 REFERENCE NO : 96075 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/05/ 6 ORIGIN : FLIC REEL NAM~ : 96075 CONTINUATION # : PREVIOUS REEL : COMFIEAUf : B.P. EXPLORATION, DUCK ISLAND UNIT 1-65/N-25, API #50-029-22627-0 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 96/05/ 6 ORIGIN : FLIC TAPE NA~E : 96075 CONTINUATION # : 1 PREVIOUS TAPE : COf4MFJg~f : B.P. EXPLORATION, DUCK ISLAND UNIT 1-65/N-25, API #50-029-22627-0 TAPE HEADER DUCK ISLAND UNIT MWD LOGS WELL NAME: API NUM~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN1 96075 MILTON E. VAUGHN WELL CASING RECORD 1ST STRING 2ND STRING 1 - 65/N- 25 500292262700 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 6-MAY-96 BIT RUN2 96075 MILTON E. VAUGHN BIT RUN 3 36 12N 16E 3058 58 56. O0 56. oo 11. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 12721.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 3RD STRING PRODUCTION STRING Well drilled 08-JAN through 21-JAN-96 with SLIM1 and ARCS. Data was collected in a multiple bit runs. The SLIM1 and ARC5 data was merged together for the final pres en t a ti on. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SO?4~zARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEAS~DEPTH) START DEPTh' STOP DEPTH 11435.0 13263.0 BASELINE DEPTH 88888.O 12867.5 12796.0 12502.0 12397.0 12375.5 12340.5 12297.0 12286.0 12180.0 12133.0 12109.0 12067.0 12052.0 12001.0 11976.0 11971.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... MWD 88866.0 12845.5 12769.5 12478.0 12374.5 12350.5 12320.0 12276.0 12262.5 12156.5 12107.5 12083.5 12041.5 12024.0 11971.0 11945.0 11940.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: 11915.0 11886.5 11881.5 11858.5 11846.5 11825.0 11822.5 11793.0 11789.0 11768.5 11785.0 11764.5 11726.0 11703.5 11705.0 11682.5 11653.0 11632.0 11640.0 11620.0 11612.0 11588.0 11530.0 11508.0 11525.0 11502.0 11517.0 11493.5 11509.0 11484.5 11499.0 11474.0 11400.0 11375.0 $ ~iERGEDDATA SOURCE LDWG TOOL CODE $ REMARKS: BIT RUN NO. FZERGE TOP MERGE BASE 1 11435.0 12740.0 2 12740.0 13263.0 The depth adjustments shown above reflect the MWD GR to the GR logged by Atlas. All other MWD curves were carried with the GR. The SLIM1 and ARC5 were merged together prior to shifting. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAM~ 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 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OH~i~ O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~4 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OH~4~ O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~k4 O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~4~ O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13262.500 ROP.~4~D 11.186 FET.MWD -999.250 GR.MWD RPYOf. MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 DEPT. 13000.000 ROP.MWD 76.154 FET.MWD 0.931 GR.MWD RPXX.MWD 15.376 RPX.MWD 43.030 RPS.MWD 115.088 RPM.MWD RPD.MWD 1000.000 DEPT. 12500.000 ROP.MWD 26.400 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 DEPT. 12000.000 ROP.MWD 18.700 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 DEPT. 11500.000 ROP.MWD 22.200 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 DEPT. 11435.000 ROP.MWD 36.800 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 -999.250 -999.250 22.741 261.313 16.900 -999.250 74.900 -999.250 191.600 -999.250 -999.250 -999.250 END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: * * * * FILE TRAILER * * * * FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFLARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11460.0 12700.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~) : 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 GAM~A RAY $ 14-JAN-96 ADVISOR 5.5 REAL- TIME 13285.0 11460.0 12700.0 50 33.0 86.2 TOOL NUMBER SLIM1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 6. 750 12721.0 BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S) : 65.0 MUD PH: 9.8 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 4.2 RESISTIVITY (OH~ff4) AT TE~IPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 850 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 3. 120 MUD CAKE AT (MT) .. 2.630 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) RE~!APJ4S: ************ RUN 1 (GR ONLY) ********* DRILLED INTERVAL 11460' - 12740' HOLE ANGLE = 86.17 DEG @ 12675' DATA FROM REAL TIldE, 5.5 SOFTWARE ************ RUN 2 (ARC5) ********* DRILLED INTERVAL 12740' - 13285' RES TO BIT: 31.9'; GR TO BIT: 36.80' DATA FROM DOWNHOLE MEMORY, 5.5 SOFTWARE $ LIS FORMAT DATA 70.0 70.0 70.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: TYPE REPR CODE VALUE 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROPE INT. F/HR O0 000 O0 0 2 1 1 4 68 0000000000 GR INT. GAPI O0 000 O0 0 2 1 1 4 68 0000000000 GRRW LW1 O0 000 O0 0 2 1 1 4 68 0000000000 RP5 LW1 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 O0 000 O0 0 2 1 1 4 68 0000000000 CPS LW1 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12700. 000 ROPE. INT. 40. 400 GR. INT. -999. 250 GRRW. LW1 RPS.LW1 40.400 ROP.LW1 33.100 CPS.LWl -999.250 DEPT. 12500. 000 ROPE. INT. 11. 700 GR. INT. 89.1 O0 GRRW. LW1 RPS.LW1 11. 700 ROP.LW1 10.300 CPS.LW1 55. 400 DEPT. 12000. 000 ROPE. INT. 22. 100 GR. INT. 48. 700 GRRW. LW1 RPS.LW1 22.100 ROP.LW1 22.300 CPS.LW1 30.200 DEPT. 11500. 000 ROPE. INT. 32. 400 GR. INT. 209. 800 GRRW. LW1 RPS.LW1 32.400 ROP.LW1 23.900 CPS.LW1 128.300 DEPT. 11460. 000 ROPE. INT. 36. 800 GR. INT. -999. 250 GRRW. LW1 RP5. LW1 36. 800 ROP. LW1 33. 700 CPS. LW1 -999. 250 -999.250 89.100 48.700 209.800 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lvTJMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NIJMBER : 2 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12669.0 13285.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ 21 -JAN-96 IDEAL 5.5C M~IOR Y 13285.0 12669.0 13285.0 50 86.2 90.4 TOOL NUMBER ARCS-O16 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : 6. 750 12721.0 BOREHOLE CONDITIONS MUD TYPE: FLOPRO MUD DENSITY (LB/G) .. 9.40 MUD VISCOSITY (S) : 65.0 MUD PM.. 9.8 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 4.2 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT MEASLrRED TEMPERATURE (MT): 2.850 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 3. 120 MUD CAKE AT (MT): 2.630 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 RE~a~J4S: ************ RUN 1 (GR ONLY) ********* DRILLED INTERVAL 11460' - 12740' HOLE ANGLE = 86.17 DEG @ 12675' DATA FROM REAL TI~E, 5.5 SOFTWARE ************ RUN 2 (ARCS) ********* DRILLED INTERVAL 12740' - 13285' RES TO BIT: 31.9'; GR TO BIT: 36.80' DATA FROM DOWN-HOLE Mt~ORY, 5.5 SOFTWARE $ LIS FORMAT DATA 70.0 70.0 70.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: 10 TYPE REPR CODE VALUE 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 $ 1 1 4 68 0000000000 RPXX LW2 OPiM~I O0 000 O0 0 3 1 1 4 68 0000000000 RPX LW2 OPiM~ O0 000 O0 0 3 1 1 4 68 0000000000 RPS LW2 OH~4 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 OHl~q O0 000 O0 0 3 1 1 4 68 0000000000 RPD LW2 0H~94 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13284.500 ROP.LW2 11 . 186 FET.LW2 2. 869 GR.LW2 21. 669 RPXX. LW2 2. 409 RPX. LW2 3. 401 RPS. LW2 4. 358 RPM. LW2 4. 858 RPD. LW2 5.246 DEPT. 13000. 000 ROP. LW2 20. 000 FET. LW2 2. 667 GR.LW2 17. 466 RPXX. LW2 7. 927 RPX. LW2 23. 641 RPS. LW2 68. 523 RPM. LW2 114.717 RPD. LW2 267. 681 DEPT. 12669. 000 ROP.LW2 180. 000 FET. LW2 O. 000 GR.LW2 8. 622 RP3Of. LW2 121. 894 RPX. LW2 1000. 000 RPS.LW2 1000. 000 RPM. LW2 1000. 000 RPD. LW2 1000. 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-MAY-1996 14:53 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/05/ 6 ORIGIN : FLIC TAPE NAME : 96075 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, DUCK ISLAND UNIT 1-65/N-25, API #50-029-22627-0 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/05/ 6 ORIGIN : FLIC REEL NAME : 96075 CONTINUATION # : PREVIOUS REEL : COFk4ENT : B.P. EXPLORATION, DUCK ISLAND UNIT 1-65/N-25, API #50-029-22627-0 Z > . e ~,lU, d OL 0~LII MO~ SS~ D~IDDO~ ~MJ~ZANOD Z~I~ HLIM ~ZD~ZN '~O~LNOD HLdZ~ ~0~ S~Mk~ DILZND~fI4 I-LLIM N/I~ S~M '~ZM SIHL ~0~ HDNZEZfZ~ HLdZ~ HHL SI SS~fd ZHL ZDNIS GZL~IHS HLdZG iON S~M (SS~d NI~) I ~ ~ZM SIH£ ~0~ ZDNZ~Z~Z~ HLdZ~ ZHL SI SIHL ~ HLdZ~ ~ZL~IHSNi1 LNZ~f~fAIQ~Z SZDIAHZS ~NI©OO~ Sk~Ii~ N-HZLSZM 96-N~f£-SI I I HDH~ H£dZCI MAII ~IZS~f~t :A/T~dMOD ONID~O~ :HZ~qNNflH :ZGOD HAM/lO ~ :ZGOD %00~ ~d (i,~/~t~I) LHDIZM (i,~) HidafI (NI) .qZIS (MI) .qZIS LI~t DNIS~fD SHZq~II%{~ DNIS~fD Z~IOH NZdO 0g' ~I 00'9~ 00'9~ .q9I 9£ SI :edAq ST g eIT~qns 12608. ~TA WAS MERGED IN THE FIEI GAMMA RAY sPIKES PRESENT IN THE PIPE CONVEYED SECTION ARE DUE TO PCL OPERATIONS. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10300.0 12563.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT BP EXPLORATION (ALASKA) 1 - 65/N - 25 ENDICOTT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 57 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 4 30 635 99 1 Tape File Start Depth = 12609.000000 Tape File End Depth = 10251.000000 Tape File Level Spacing = 0.500000 Tape File Depth Un.~ ~ = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14152 datums Tape Subfile: 2 153 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 11550.0 11708.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH 11553.0 11560.5 11567.0 11576.5 11579.5 11583.5 11588.5 11594.5 11601.5 11620.0 11632.0 11652.5 11654.0 11656.0 11667.0 11677.0 11682.5 11703.5 $ REMARKS: GRCH 11554.0 11561.5 11568.0 11577.0 11580.0 11584.0 11589.0 11595.0 11602.5 11621.0 11633.0 11653.0 11654.5 11656.5 11668.0 11678.0 11683.5 11704.0 EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS - WIRELINE). TENS WAS SHIFTED WITH GRCH. CN WN FN COUN STAT / ? ?MATCH1. OUT $ : BP EXPLORATION (ALASKA) : 1 - 65/N - 25 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 7 Tape File Start Depth = 11793.000000 Tape File End Depth = 11517.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1660 datums Tape Subfile: 3 57 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes (~~) ~dO%S PLL~ON : IIODIGN~ : S~ - N/S9 - I : NOI~f~O%dX~ d~ : J. YIO ' EHDJ. N 6 & / NnOD NM ND 'HD%{D HJ. IM ~.~.T..4IHS S~fM '(%D~ - SS%rd .l.k~d.w~) £ SS~fd 0'SI£II 0'£0LII 0'089II S'L99II S'6S9II ~'~9II 0'~9II S'ES9II S'IP9II 0'E£9II S'0E9II 0'~09II 0'E09II 0'~8SII 0'08SII S'Lg§II S'L9~II 0'E9SII 0'6~II 0'I~SII S'6E~II 0'0E~II 0'II,II 0'80SII ~'I0~II HD~O I 0'SILII 0'~0tII 0'089II 0't99II ~'6~9II 0'9~9II 0'5~9II S'CS9II 0'I~9II -0'E£9II ~'0E9II 0'~09II S'I09II S'£SSII S'6LSII 0'LLSII ~'99SII S'I9SII 0'6~II 0'ISNII ~'6ESII 0'0E~II 0'II,II 0'80~II ~'IOSII ~GOO ~LA%LGD ~d (HId~G G:EEGS~N) 0'0SLII H~d~G dOIS 0'00SII HJ~d~G i%5fIS SA~IHS HO~ ~AhIflD SS~d Oi SS~d - ~i~G ~IHS HDHD HGOD ~OOi XR-k~NNMS ~I~ 000S' :J~N~N~DNI Hid~G a~das u~ ss~d qo~a ~o~ s~no padd~IO pue p~qs q~daG SEA%ElD G~IIG~ :~~rl~ ~I~ ~~H ~I~ STAT : ALA'~ .~ * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 8 Tape File Start Depth = 11750.000000 Tape File End Depth = 11450.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15956 datums Tape Subfile: 4 65 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes :(T~f~HHL HO ~~HLId~) ZdXL TOOL TOOL NOHJJI~N , 000 ' 000 ' 000 ' 0' 0 0' 0' 0£'0I (INST O~ O'Ig£gI 000 ' : (J..~) HJ.d.~G ONIS~fD S : (J..~) HJ.dZ~ ONIS%fD S,H.~ITIHG : (NI).~ZIS J.I~ ZqOH ~fJ.~f~ ONIS~fD ~ .~IOH~HO~ ZZ£0£~ ZZ£0£~ ~fX~E~I ~fX£E6£ ~-~5£9I ~X605I VN0££E ~fXSt6£ ~XPP6£ TOOL 0'00LE 0'009EI 0'0050I 0'809EI 0'~£9~I 96-Ntf£-SI 0££ I'~ S~IqO~ 96-N%f~-SI TOO.I. f56IO~ J.NIO£ NO,OD D IJ.SflOD~f 'DO~I ~r~IqOD ~NIS~fD ~K1S NOI SN.~J. g/1S TZAIMS ~I(IA OD%f J.HD AIMS ZdAL q00L HGOD qOOL HOGNE{A (NOLLO~ OL dOL) DNIHLS TOOL 0'59SEI punoxBMo~q ~x fssIi~ s~mx~dss uy sswd qo~s xo~ m~wp xspmsq 6oI pu~ s~A~no SZA%K1D M~ :HHS~EIN H~I~ MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW sCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS) . $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 65/N - 25 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 2 CCL SBT 68 3 SPD SBT 68 4 TEN SBT 68 5 TTEN SBT 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 225 Tape File Start Depth = 12609.000000 Tape File End Depth = 10251.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 58259 datums Tape Subfile: 5 Minimum record length: Maximum record length: 305 records... 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NI3MBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11550.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB CHT TENSION SUB CCL CASING COLLAR LOC. GR GAMMA RAY ACC ACOUSTIC COMMON KNJT KNUCKLE JOINT SBT SEGMENTED BOND TOOL CENT CENTRALIZER VDL VDL SUB CENT CENTRALIZER $ STOP DEPTH 11748.0 18-JAN-96 ECLIPS 2.1 12635.0 12608.0 10300.0 12600.0 2700.0 YES 18-JAN-96 TOOL NUMBER 3944XA 3974XA 2330NA 1309XA 1633EA 3923XA 1424XA 4307ZZ 1424PA 4307ZZ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .00O 12721.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG) : LSND 10.30 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): FLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAIt COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS - WIRELINE). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 65/N - 25 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAP I 4 2 CCL SBT 68 1 4 3 SPD- SBT 68 1 F/MN 4 4 TEN SBT 68 1 LB 4 5 TTEN SBT 68 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 27 Tape File Start Depth = 11793.000000 Tape File End Depth = 11517.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22587 datums s~Xq ~IOI s~Xq E9 :q~BuoI pxooo~ mnm!x~M :q~BuoI pxooox mnm!u!x · '-sp~oos~ £0I Tape Subfile 7 is type: LIS FILE HEADER F I LE NUMBER: 6 RAW CURVES · Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11500.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT CCL GR ACC KNJT SBT CENT VDL CENT $ SWIVEL SUB TENSION SUB CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON KNUCKLE JOINT SEGMENTED BOND TOOL CENTRALIZER VDL SUB CENTRALIZER STOP DEPTH 11750.0 18 -JAN- 96 ECLIPS 2.1 1400 18-JAN-96 12635.0 12608.0 10300.0 12600.0 2700.0 YES TOOL NUMBER 3944XA 3974XA 2330NA 1309XA 1633EA 3923XA 1424XA 4307ZZ 1424PA 4307ZZ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT) : .000 12721.0 .0 BOREHOLE CONDITIONS FLUID TYPE: ~ FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: .. CHOKE (DEG) : LSND 10.30 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): ~TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 3 (REPEAT PASS - PCL). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 65/N - 25 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 CCL SBT 68 1 4 3 SPD SBT 68 1 F/MN 4 4 TEN SBT 68 1 LB 4 5 TTEN SBT 68 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 4 81 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 29 Tape File Start Depth = 11750.000000 Tape File End Depth = 11450.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 65466 datums Tape Subfile: 7 Minimum record length: Maximum record length: 109 records... 62 bytes 1014 bytes Tape Subfile 8 is type: ~IS 96/01/23 01 **** REEL TRAILER **** 96/ 1/23 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 23 JAN 96 ll:18a Elapsed execution time = 2.47 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY.' TAPE CREATION DATE: JOB DATA JOB NUMBER: IX)GGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6558.00 K. RICHARDS P. BARKER OPEN HOLE 1-65/N-25 PH 500292262780 BP-EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 12-JAN- 96 RUN 2 RUN 3 36 12N 16E 3058 2218 56.00 54.00 15.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 5211.0 9.875 13414.0 DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 2100, 31-DEC-95. PIPE CONVEYED LOGGING OPERATION. MAIN PASS IS FROM THE DOWN PASS. REPEAT pAss IS FROM THE UP PASS. GAMMA RAY SPIKES AT 12533, 12630, 12726, 12822, 12919, 13036, 13130, 13204, 13300 ARE CAUSED FROM R/A SOURCE CHARGING THE FORMATION WHILE MAKING THE DRILL PIPE CONNECTION. DEEP INDUCTION NOT PRESENTED DUE TO INVALID RESPONSE. NO TORNADO CHART CORRECTIONS WERE APPLIED TO THE DIL DATA. NO CALIPER CURVE WAS RECORDED ON THE MAIN PASS AS THE CALIPER TOOL WAS CLOSED DUE TO LOGGING DOWN. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CORRECTION = 9 875" CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12434.0 13328.0 DIL 12500.0 13393.0 SDN 12464.0 13348.0 2435 12442.0 13335.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) 12660 12664 12668 12673 12678 12683 12706 12706 BASELINE DEPTH 12524.5 12525.0 12532.5 12588.0 12588.5 12607.0 12625.5 12626.0 12630.5 12635.5 12636.0 12640.5 12653.0 12659.0 .5 .5 .5 .5 .0 .5 .0 .5 12713.0 12713.5 12715.0 12717.0 12717.5 12719.5 12726.5 12727.0 all runs merged; no case ......... EQUIVALENT UNSHIFTED DEPTH ......... LL8 ILM RHOB NPHI 12524.5 12524.0 12526.0' 12588.5 12532.0 12588.5 12607.5 12605.5 12607.0 12624.5 12629.5 12633.5 12635.0 12626.5 12636.5 12639.5 12653.0 12653.0 12660.0 12678.0 12677.5 12707.0 12713.5 12658.5 12717.0 12719.5 12727.0 12663.5 12667.5 12673.5 12677.5 12683.5 12706.0 12706.5 12712.5 12712.0 12773.5 12714.0 12716.0 12768.5 12718.5 12726.0 12760.0 12759.0 12763.0 12763.5 12768.5 12774.5 12790.0 12790.0 12790.0 12792.5 12791.5 12801.0 12801.5 12809.5 12810.0 12813~.5 12814.0 12814.5 12'818 ~-0 12818.0 12822.0 12826.0 12845.0 12845.5 12848.0 12853.0 12875.5 12876.5 12878.0 12878.5 12879.0 12879.5 12886.5 12887.0 12892.5 12895.5 12896.0 12905.5 12909.5 12930.0 12932.5 ~12933.0 12941.5 12942.5 12962.0 12975.0 12983.5 12985.5 12993.0 13008.5 13012.5 13023.0 13029.5 13060.0 13060.5 13061.0 13069.0 13077.5 13079.0 13088.5 13092.0 13095.5 13098.0 13113.5 13123.5 13131.5 13135.5 13138.5 13142.0 13142.5 13145.5 13157.5 13160.0 13165.5 13171.0 13197.0 13199.0 13203.0 13208.5 13211.5 12877.5 12879.5 12886.5 12943.0 12985.5 13061.5 13089.0 13131.5 13197.0 13199.0 13212.0 12825.5 12844.5 12877.0 12886.5 12893.5 12897.0 12905.5 12909.0 12932.5 12942.0 12985.5 13023.0 13061.0 13068.0 13079.0 13088.5 13112.o 13135.0 13159.0 13170.5 13197.0 13199.0 12822.0 12846.0 12848.5 12875.0 12877.5 12885.5 12895.5 12929.5 12932.0 12974.5 12983.0 13008.5 13012.0 13022.5 13029.5 13091.5 13095.0 13124.0 13138.0 13141.5 13164.5 13197.0 13211.0 12849.0 12854.0 12879.5 12941.5 12962.0 12984.0 12993.5 13023.0 13060.5 13078.0 13098.0 13123.0 13141.5 13145.5 13157.0 13197.0 13203.5 13208.5 13211.0 .1.3212.5 13215.0 13215.5 13218 13221.5 13224.5 13228.5 13229.5 13230.0 13235.5 13244.5 13248.5 13255.5 13266.0 13270.5 13271.0 13279.5 13281.0 13284.5 13292.0 13304.0 13306.5 13307.0 13315.5 13331.5 13346.0 13364.5 13369.5 13375.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL SDN 2435 $ REMARKS: 13215.5 13219.0 13221.5 13230.0 13235.5 13291.5 13307.0 13212.5 13221.5 13224.5 13229.5 13234.5 13277.5 13282.5 13290.5 13306.0 13315.0 13331.0 13345.5 13364.0 13369.0 13374.0 13220.5 13224.0 13228.0 13265.5 13270.0 13215.0 13218.5 13221.5 13244.0 13248.5 13255.5 13271.0 13279.5 13281.0 13304.0 13306.0 13308.0 RUN NO. PASS NO. MERGE TOP 1 I 12434.0 1 1 12500.0 1 1 12464.0 I i 12442.0 MAIN PASS (LOGGED DOWN). MTEM, SP, TEND, & TENS WERE SHIFTED WITH LLS. DRHO & PEF WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 13328.0 13393.0 13348.0 13335.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT / ? ?MATCH3. OUT / ??MATCH4. OUT $ CN : BP EXPLORATION WN : 1-65/N-25 PH FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) (ALASKA) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units I GR DIL 68 i GAPI 2 LL$ DIL 68 i OHMM 3 ILM DIL 68 I OHMM 4 SP DIL 68 i MV 5 MTEM DIL 68 i DEGF 6 TEND DIL 68 ~1 LB 7 TENS DIL 68 i LB 8 RHOB SDN 68 i G/C3 9 DRHO SDN 68 1 G/C3 10 PEF SDN 68 I BN/E 11 NPHI 2435 68 i PU-S 12 FUCT 2435 68 i CPS 13 NUCT 2435 68 i CPS API API API AP1 Log Crv Crv Size Length Typ Typ Cls Mod 4 4 08 310 01 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 08 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 49 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 995 99 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 109 Tape File Start Depth = 13400.000000 Tape File End Depth = 12425.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27315 datums TaPe Subfile: 2 347 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type.' LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String $1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 1 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12434.0 13329.5 DIFL 12493.5 13394.0 ZDL 12463.0 13348.0 2435 12440.5 13336.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 01-JAN-96 FSYS REV. J001 VER. 1.1 2100 31-DEC-95 2038 01-JAN-96 13414.0 13395.0 12500.0 13393.0 900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL GR CN ZDL KNJT TEMP PCM RB KNJT DIFL $ SWIVEL SUB CABLEHEAD'TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB SUB KNUCKLE JOINT DUAL INDUCTION TOOL NUMBER 3944XA 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806](t% 3506XA 3975XA 3921NA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 5211.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 'MUD PH: LSND 10.30 60.0 10.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS (LOGGED DOWN). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-65/N-25 PH : ENDICOTT : NORTH SLOPE : ALASKA 4.3 194.0 1.280 .432 1.160 .000 1.220 .000 THERMAL SANDSTONE 2.65 9.875 1.5 61.0 194.0 61.0 .0 61.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR DIFL 68 I GAPI 4 2 RFOC DIFL 68 i OHMM 4 3 RILM DIFL 68 i OHMM 4 4 SP DIFL 68 i MV 4 5 TEMP DIFL 68 i DEGF 4 6 CHT DIFL 68 i LB 4 7 TTEN DIFL 68 i LB 4 8 SPD DIFL 68 i F/MN 4 9 ZDEN ZDL 68 1 G/C3 4 10 ZCOR ZDL 68 1 G/C3 4 11 PE ZDL 68 1 BN/E 4 12 CNC 2435 68 i PU-S 4 13 CNCF 2435 68 1 PU-S 4 14 CN 2435 68 1 PU-L 4 15 LSN 2435 68 1 CPS 4 16 SSN 2435 68 1 CPS 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 010 01 4 07 660 99 1 4 07 635 99 1 4 07 635 99 4 07 636 99 1 4 46 350 01 4 46 356 99 1 4 46 358 01 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Recoru~: 280 Tape File Start DePth = 13399.000000 Tape File End Depth = 12422.000000 Tape File Level Spacing t 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66454 datums Tape Subfile: 3 362 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13197.0 13350.0 DIFL 13197.0 13396.0 ZDL 13197.0 13349.0 2435 13197.0 13336.5 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL GR CN ZDL KNJT TEMP PCM RB KNJT DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB SUB KNUCKLE JOINT DUAL INDUCTION 01-JAN-96 FSYS REV. J001 VER. 1.1 2100 31-DEC-95 2211 01-JAN-96 13414.0 13395.0 12500.0 13393.0 1200.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3975XA 3921NA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 5211.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): LSND 10.30 60.0 10.0 4.3 MAXIMUM RECORDEL ~'EMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS (LOGGED UP). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : ' 1-65/N-25 PH : ENDICOTT : NORTH SLOPE : ALASKA 194.0 1.280 .432 1.160 .000 1.220 .000 THERMAL SANDSTONE 2.65 9.875 1.5 61.0 194.0 61.0 .0 61.0 .0 * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 SP DIFL 68 1 MV 5 TEMP DIFL 68 i DEGF 6 CHT DIFL 68 i LB 7 TTEN DIFL 68 i LB 8 SPD DIFL 68 i F/MN 9 ZDEN ZDL 68 I G/C3 10 ZCOR ZDL 68 I G/C3 11 PE ZDL 68 i BN/E 12 CAL ZDL 68 i IN 13 CNC 2435 68 1 PU-S 14 CNCF 2435 68 i PU-S 15 CN 2435 68 i PU-L 16 LSN 2435 68 I CPS 17 SSN 2418 68 I CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 4 4 07 635 99 1 4 4 07 635 99 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 42 334 30 1 68 * DATA RECORD (TYPES 0) 1014 BYTES * Total Data Records: 62 Tape File Start Depth = 13408.000000 Tape File End Depth = 13192.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42886 datums Tape Subfile: 4 143 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS 96/ ./12 O1 **** REEL TRAILER **** 96/ 1/15 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 15 JAN 96 3:02p Elapsed execution time = 6.86 seconds. SYSTEM RETURN CODE = 0
