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193-028
• • bp BP Exploration (Alaska) Inc.. _ F, Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 4_ May 18, 2012 Mr. Jim Regg 5i A AUG I � 20112 c1 U Alaska Oil and Gas Conservation Commission 0 O" 333 West 7 Avenue R()). Anchorage, Alaska 99501 ""fA Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, 4)AL(L Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A-Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A-03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A-06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA _ NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA _ 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A-31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 _ NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 -17 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ OiI ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. Well Class: 2OAAC 25.105 2OAAC 25. 110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Abend.: 12. Permit to Drill Number. BP Exploration (Alaska) Inc. 1/26/2011 193 -028 310 - 428 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 06/18/1993 50 029 - 22344 - 00 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number. Surface: 06/28/1993 PBU A-39 1482' FNL, 920' FEL, Sec. 35, T11N, R13E, UM 8. KB (ft above MSL): 80.52' 15. Field / Pool( s ) Top of Productive Horizon: 904' FNL, 2507' FEL, Sec. 35, T11N, R13E, UM GL (ft above MSL): 47.32' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD): Oil Pool 815' FNL, 2675' FEL, Sec. 35, T11N, R13E, UM 9063' 8761' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x - 654455 y- 5948965 Zone ASP4 9585' 9250' ADL 028286 TPI: x 652857 y 5949511 Zone ASP4 11. SSSV Depth (MD+TVD): 17. Land Use Permit: Total Depth: x - 652687 y - 5949597 Zone ASP4 N/A 18. Directional Survey: 0 Yes Et No 19. Water depth, if offshore: 20. Thickness of Permafrost (ND): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - Drill /Lateral Top Window MD/TVD: DIL / BHCS / CNL / GR / SP N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING D EPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEIENTING RECORD PULLED 20" 91.5# H-40 32' 110' 32' 110' 30" 11 vds Arcticset 10 -3/4" 45.5# J -55 36' 3050' 36' 3049' 13-1 /2" 1862 cu ft CS III. 408 cu ft Class 'G' 7 -5/8" 29.7# NT -95HS 32' 9032' 32' 8732' 9-7/8" 302 cu ft Class 'G' 5-1/2" 17# 13Cr80 8866' 9585' 8576' 9250' 6-3/4" 136 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top 8 Bottom; Perforation Size and Number): 4-1 /2", 12.6#, 13Cr 8858' 8805' / 8519' MD TVD MD TVD - - 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC RECEIVED' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9063' Set Whipstock MAR 0 3 X1111 9063' P&A w/ 21 Bbls Cement Ali:Aka Oil & Cos Cons. Commission _ 27. F�G1CI8� PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None R BDMS MAR 03 2111 z541..... SIANNED MAR 1 0 n1 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 3, 7, k � , S �� ubmit Original Only . . t i . . . . . 29. .GEOLOGIC MARKERS (List all formations and markcountered): 30. I410AATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9039' 8738' None Shublik 9067' 8764' Sadlerochit 9151' 8843' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. �� ��l /03 Signed: Terrie Hubble Q \ i L ' ' T itle: Drilling Technol Date: PBU A - 193 - 028 310 - 428 Prepared By Name/Number Terris Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Cody Rymut, 564-5452 1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • . A -39, Well History (Pre Rig Sidetrack) Date Summary 12/31/2010 Mill cement sheath, XN with 3.80" mill & string mill. Tag cement @ 8830' CTMD, begin milling to 9180' CTMD. Dry drift. POOH. RDMO for SL operation. Job milling stage complete. 1/1/2011 WELL S/I ON ARRIVAL. RAN 3.70" x 20' DUMMY WHIPSTOCK, FOUND TIGHT SPOT @ 8855' SLM & UNABLE TO PASSED 8888' SLM. RAN 3.70" x 10' DUMMY WHIPSTOCK TO 9179' SLM, HAD TO LIGHTLY WORK THROUGH W/ SAME RESTRICTIONS. RAN PDS GAMMA RAY, CCL & 40 ARM CALIPER FROM 9179' SLM TO SURFACE. GOOD DATA. RAN 4 -1/2 BRUSH, 3.80 G.RING, WORKED TIGHT SPOTS @ 8855' TO 8888' SLM. RAN BAKER DRIFT, 3.68 OD x 14' 51" OAL, SAT DOWN @ 9180 SLM. TESTED TOOLS FOR NORM, ONE READING IS HOT, ONE READING IS IN SAFE WORKING LEVEL. LEFT WELL SHUT IN, PAD OP NOTIFIED. 1/4/2011 INITIAL T /I /O= 0/280/0 PSI. SET BOTTOM OF BAKER 5.5" -17# GEN 1 PERMANENT WHIPSTOCK AT 1,s1V 9075', TOP OF WHIPSTOCK SET AT 9063', FACE OF WHIPSTOCK SET AT 7.9 DEG RIGHT OF HIGH SIDE. 2 RA TAGS IN WHIPSTOCK SET AT 9072'. INITIAL T /I /O= 0/280/0 PSI. JOB COMPLETE. 1/5/2011 BOP test. Cement squeeze. RIH with cement nozzel assembly, tag whipstock at 9046 CTM. Paint flag at 9036'. Pump 100 bbls diesel down backside. Perform injectivity test (1000psi at 1 bpm). Line up to pump 15.8 ppg cement. Pump 21 bbls cement, establish and hold 2000 psi squeeze pressure for 30 mins. Total 8 bbls of cement into perfs. Pump 50 bbls Biozan, clean out down to 9040'. POOH. Freeze protect from 2500' with diesel. Job complete. 1/8/2011 T /I /O = 0/60/0 Pressure tested and charted swab valve to 500 psi low and 3500 psi high. (passed). Rigged up lubricator and tested to 500 psi low and 3500 psi high (passed). Set 4" CIW H TWC @ 111" w/ 1 -1' ext. Pulled off lubricator and installed tree cap. Torqued all tree flanges to API specifications. • Shell tested tree against TWC to 500 psi low and 5000 psi high (Passed). Page 1 of 1 . ! • North America - ALASKA - BP page 1. t f 10 Operation Summary Report Common Well Name: A -39 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) ; Start Date: 1/17/2011 1 End Date: X3- 00Y51 -C (2,553,415.00 ) I Project: Prudhoe Bay ' Site: PB A Pad Rig Name /No.: NORDIC 2 1 Spud Date/Time: Rig Release: 2/6 /2011 Rig Contractor: NORDIC CALISTA 1 UWI: Active Datum: 44 : 39 6/18/199_00 :00 @80.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT 1 NPT Depth ' Phase 1 Description of Operations 1 (hr) I (ft) 1 1/18/2011 00:00 - 06:00 6.00 MOB N WAIT PRE CONTINUE STANDING BY WAITING ON PERMISSION TO MOVE 1 GENERAL RIG HOUSEKEEPING AND ! WORKING ON SMALL PROJECTS. ' 1 WARM UP RIG DRIVE SYSTEM IN PREP FOR !BACKING OFF OF WELL. 1 06:00 - 15:00 9.00 MOB N WAIT PRE 1 START ROLLING RIG TIRES. I WAIT TO BACK OFF WELL DUE TO WEATHER. ■ WORK ON. PAINTING/SMALL PROJECTS. 1 15:00 - 19:00 4.00 MOB N ! WAIT ! PRE - .(PJSM FOR BACKING RIG OFF OF WELL. BACK RIG OFF WELL AND SET BACK DOWN ON PAD. REMOVE j-MATS AND CELLAR BERM. CLEAN 1 ' UP AROUND SAME= ', 1 1 '+ tSECURE BOPS WITHBRIDGE CRANE. 1 I HANG BLOCKS. PULL - DRILLING LINE FROM 1DRUM AND SECURE OUT OF WAY. 119:00 - 00:00 1 5.00 MOB N. i WAIT ( . -.PRE ' PPJSM FOR WORKING ON DRAWWORKS. ti ■ START REPAIR WORK ON DRAWWORKS 1 1 WHILE WAITING ON ORDERS TO MOVE. 1/19/2011 100:00 - 06:00 6.00 MOB 1 - N WAIT 1 PRE , . i TO STANDBY WAITING ON { fORbERS TO MOVE. - jPROCEED W/ REPAIRS ON DRAWWORKS. -C /O CHOKE HCR HYDRAULIC LINE. 106:00 - 06:30 0.50 MOB , N f WAIT ' _ PRE CREW CHANGE DISCUSS OPS. MAKE RIG � ROUNDS AND CHECKS. 06:30 ' - 15:00 8.50 ° MOB N WAIT PRE HOLD PJSM WITH NATIONAL OIL WELL REP TO DISCUSS PLAN FOR DRAWORKS. DISSASSEMBLE BRAKE SYSTEM. REMOVE DRUM. - ' NDI INSPECT DRAWORKS COMPONENTS WITH TUBOSCOPE. 15:00 - 18:00 3.00 MOB N 1 WAIT l PRE 'POSITION BRAKE COMPONENTS FOR 1 RE- ASSEMBLY. 18:00 - 18:30 0.50 MOB 1 N WAIT PRE CREW CHANGE. HOLD PJSM FOR CONTINUING RE- ASSEMBLY 1 j OF DRAWWORKS. 118:30 - 00:00 1 5.50 j MOB I N i WAIT 1 PRE I INSPECT BRAKES AND PADS. 1 1 M/U CHAIN DRIVE SPROCKET TO DRUM. INSTALL GLYCOL HOSES. CLEAN DRAWWORKS BRAKES AND I l 1 1 CARRIAGE. 1/20/2011 100:00 - 04:45 4.75 MOB N WAIT PRE 1 1 104:45 - 06:00 1.25 MOB N WAIT PRE , PJSM TO DISCUSS P/U AND OFF - LOADING 1 BRAKE FLANGE. 1 ! 1OFF -LOAD BRAKE FLANGE USING PIPE 1 1 I 1 ELEVATORS. 106:00 06:30 0.50 MOB N WAIT PRE j CREW CHANGE DISCUSS ONGOING OPS. 1 I MAKE RIG ROUNDS AND CHECKS. CONTINUE 106:30 - 18:00 11.50 MOB N WAIT PRE CONTINUE TO RE- ASSEMBLE DRAW WORKS. j j INSTALL DRUM, BEARINGS, AND BRAKE COMPONENTS. TEST SAME HOOK UP I ' LUBRICATION AND COOLANT PLUMBING (SYSTEM. 1 TEST BRAKES UNDER LOAD FOR 10 MIN. - GOOD TEST. Printed 3/1/2011 12:55:16PM orth America- ALASKA BP Page 2 dip Operation Summary Report Common Well Name: A -39 ; AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 1/17/2011 End Date: X3- 00Y51 -C (2,553,415.00 ) Project: Prudhoe Bay I Site: PB A Pad Rig Name /No.: NORDIC 2 Spud Date/Time: ■ Rig Release: 2/6 /2011 Rig Contractor: NORDIC CALISTA i UWI: Active Datum: 44 : 39 6/18/1993 00:00 @80.50ft (above Mean Sea Level) Date 1 From - To Hrs ! Task Code i NPT 1 NPT Depth 1 Phase 1 Description of Operations (hr) r (ft) 18:00 - 18:30 0.50 MOB N WAIT j PRE 18:45 - 21:30 i 2.75 MOB N WAIT ! PRE IPJSM FOR CUT AND SLIP DRILL LINE. HANG OFF BLOCKS. S CUT AND SLIP 50' OF DRILL LINE. 21:30 - 00:00 2.50 MOB N ! WAIT PRE I 1/21/2011 100:00 - 06:00 6.00 MOB N I WAIT PRE CONTINUE CLEANING RIG AND PREPPING FOR MOVE TO A PAD. � M/U XO SPOOL TO BOPE. 1 (TEST AND FIX LEAK ON KILL HCR HOSE RE-TEST - Na GOOD. I ',TROUBLESHOOT AND REPAIR. 1 0 - 06:30 0.50 MOB N WAIT PRE CREW CHANGE DISCUSS OPERATIONS. I - MAKE RIG CHECKS AND ROUNDS. 06:30 - 18:00 11.50 MOB N WAIT PRE I CONTINUE TO STANDBY FOR OPPORTUNITY TO MOVE RIG. -NORDIC 1 CONTINUES TIRE ' REPAIRVIIORK. ; _ REPLACE HYDRAULIC FITTING ON KILL HCR HOSE AND , TEST - GOOD. HUNG BOP'S OFF BLOCK. 1 CHECKED RIG TIRES AND CLEANED RIG. 18:00 - 18:30 0.50 MOB N WAIT ! PR E . - CREW CHANGE DISCUSS OPS AND MAKE RIG ROUNDS AND CHECKS. 18:30 - 00:00 5.50 MOB N WAIT PRE -STANDBY FOR NORDIC 1 TO COMPLETE , i MOVE. I CONTINUE CLEANING AND ORGANIZING RIG. C/O AIR FITTING ON TIRE #4. ,CLEAN UP BOLTS ON DRILL LINE SPOOL. I HELD TABLE TOP KICK WHILE DRILLS. 1/23/2011 1 - 00 :45 0.75 MOB P 1 PRE I FINISH PREPPING CELLAR. 1 00:45 - 01:15 I 0.50 j MOB P PRE !PJSM FOR SPOTTING RIG OVER WELL. 1 1 ENSURE IA AND OA ARE BLED DOWN TO 0 I 1 PSI AND ALL TREE VALVES ARE CLOSED. 101:15 - 03:00 1.75 MOB P 1 PRE BACK RIG OVER WELL. LEVEL RIG AND SET I ( DOWN. 103:00 - 04:00 1.00 MOB P PRE R/U HANDI -BERM AROUND CELLAR. 04:00 - 04:15 j 0.25 MOB P PRE PJSM FOR N/D TREE CAP AND N/U BOP'S. j 04:15 - MOB P PRE N/D TREE CAP AND BEGIN N/U BOP'S. 1/24/2011 00:00 - 03:15 3.25 RIGU N WAIT PRE WAIT ON WEATHER FOR ADDITIONAL EQUIPMENT TO BE BROUGHT TO LOCATION. I PERFORM GENERAL RIG HOUSEKEEPING 1 AND WORK ON SMALL PROJECTS. 103:15 - 03:45 0.50 RIGU P PRE !HOLD RIG EVAC DRILL AND PERFORM AAR ,W/ ALL CREW MEMBERS. 103:45 - 06:00 2.25 RIGU 1 N WAIT PRE I CONTINUE WAITING ON WEATHER. i 06:00 - 06:30 ! 0.50 RIGU N WAIT PRE CREW CHANGE DSICUSS COLD WEATHER OPERATIONS. USE BUDDY SYSTEM FOR SPILL CHAMP ROUNDS. MAKE OTHER RIG CHECKS. 06:30 - 13:00 6.50 RIGU N WAIT PRE CONTINUE TO WAIT ON WEATHER. __ � I I I !CURRENTLY -43 AMBIEN T . 13:00 - 16:00 3.00 I RIGU P PRE 1 AMBIENT TEMP AT -31 DEG F AND RISING. I ! CALL DSM FOR DELIVERY OF TIGER TANK, I AND MU OF HARDLINE 1 RELL CALLED FOR DELIVERY FROM SLB !YARD IN DEADHORSE. 1N2 ON STANDBY Printed 3/1/2011 12:55:16PM North Amerrca :ALASKA BP Page 3 of 1 0 Operation Summary Report Common Well Name: A -39 — I AFE No Event Type: RE- ENTER- ONSHORE (RON) 1 Start Date: 1/17/2011 End Date: 1 X3- 00Y51 -C (2,553,415.00 ) 1 I I Project: Prudhoe Bay i Site: PB A Pad Rig Name /No.: NORDIC 2 1 Spud Date/Time: I Rig Release: 2/6/2011 Rig Contractor: NORDIC CALISTA I UWI: Active Datum: 44 : 39 6/18/1993 00:00 @80.50ft (above Mean Sea Level) Date From - To ! Hrs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) 1 (ft) 1 16:00 - 18:00 2.00 RIGU P PRE j SPOT REEL TRAILER UNDER RIG. I SPOT TIGER TANK ON OFF DRILLER SIDE. I I PREP MAN CAMP FOR MOVE FROM DS 15 TO A -PAD. 18:00 - 18:30 0.50 RIGU P PRE CREW CHANGE. DISCUSS RIG OPS AND ! ,MAKE ROUNDS/CHECKS. 18:30 - 22:00 3.50 RIGU P PRE SPOT SLB CEMENTERS FOR PUMPING N2. LRS PT TIGER TANK TO 3500 PSI - GOOD. 1 ( SPOT MEOH PUP AND KCL TRUCK FOR _ DISPLACING REEL TROUBLESHOOT POSSIBLE FREEZE LEAK IN I PITS 22:00 - 22:45 j 0.75 RIGU P PRE . MAN CAMP O ARRIVES ON LOCATION. SPOT 1 i AND SET DOWN. '. 1 PJSM FOR Pill THE INJECTOR AND 1 'STABBING ON 'THE'WEELL. I P /U. INJECTOR, REMOVE LEGS. C/O 1 PACK -OFFS I M/U NOZZLE AND STAB ON WELL. 122:45 - 23:45 1.00 RIGU P PRE VVAIT TO BLOW DOWN COIL WHILE NORDIC ., TROUBLESHOOTS POSSIBLE LEAK IN PIT SUCTION LINES. 123:45 - 00:00 1 0.25 RIGU P ' PRE iPJSM FOR BLOWING DOWN COIL W/ N2. LDISCUSS PROCEDURE, HAZARDS, AND I T ' I MITIGATIONS. 1/25/2011 1 00:00 - 00:10 0.17 - -RIGU P PRE I PJSM TO PT REEL IRON & PUMP SLACK OUT 00:10 - 00:15 0.08 RIGU P PRE 11 FINISH W/ PJSM FOR BLOWING DOWN COIL 1W/ N2. 00:15 - 01:30 1.25 RIGU . P PRE 02:15 - 02:30 j 0.25 RIGU P PRE PJSM FOR UNSTABBING INJECTOR AND _ ` PULLING COIL ACROSS. ' 102 - 04:30 2.00 RIGU P - 1 PRE UNSTAB INJ. AND REMOVE NOZZLE ASSY. ` 1 ' CUT OFF CTC AND DRESS END OF COIL. ■ M/U GRAPPLE AND PULL TEST. I I PULL COIL ACROSS AND SECURE ON REEL. 104:30 - 07:00 2.50 RIGU P j PRE 1 1 07:00 - 07:30 0.50 1 RIGU P 1 1 PRE 1 107:30 - 17:00 9.50 RIGU P PRE I HOLD PJSM FOR REMOVING REEL. 1 1 SPOT TRAILER UNDER REEL HOUSE REMOVE REEL 1 I INSTALL NEW REEL AND PLUMB IN I ! HARDLINES 1 17:00 - 19:00 ' 2.00 RIGU P 1 PRE ;STAB IN AND RE -HEAD 119:00 - 19:45 0.75 RIGU P 1 PRE 19:45 - 21:30 1.75 RIGU P PRE I REEL HAS LESS THAN THE 1.5% SLACK NEEDED TO SATISFY SLB STANDARDS SO !WE WILL NEED TO PUMP SLACK OUT, I VERIFY ELINE PUMPED OUT THEN PUMP ' SLACK BACK IN FLUID IN PITS IS ONLY 70 °, AND THE REEL IS STILL VERY COLD. DROP A STEAM HOSE IN I i 1 ' PIT TO WARM FLUID BEFORE FLUID PACKING COIL 123:00 - 23:10 0.17 RIGU P 1 PRE 1 PJSM TO Fl UIIZEACK_C.OILSHEN.RUMP ;SLACK 1 23:10 - 00:00 0.83 RIGU P 1 `, PRE 1 PUMP 10 BBLS OF NEAT METH FOLLOWED i 1 BY 120 DEG KCL Printed 3/1/2011 12:55:16PM • o Am er i ca - ALAS BP Page 4 of 10 410 Operation Summary Repo Common Well Name: A -39 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 1/17/2011 End Date: X3- 00Y51 -C (2,553,415.00 ) i Project: Prudhoe Bay , Site: PB A Pad Rig Name /No.: NORDIC 2 Spud Date/Time: Rig Release: 2/6/2011 Rig Contractor: NORDIC CALISTA ; UWI: Active Datum: 44 : 39 6/18/1993 00:00 @80.50ft (above Mean Sea Level) Date 1 From - To 1 Hrs Task Code NPT NPT Depth 1 Phase I Description of Operations (hr) _ (ft) 1/26/2011 1 00:00 - 00:15 ' 0.25 i RIGU P PRE ;PJSM TO PT REEL IRON AND PUMP SLACK 1 OUT OF COIL NEW REEL PAPERWORK INDICATES THAT THERE IS ONLY 1.2% SLACK IN REEL. SLB ■ MINIMUM IS 1.5 %. NEED TO PUMP OUT . SLACK SO WE CAN START 1:1 THEN PUMP :SLACK BACK IN 00:15 - 00:30 0.25 RIGU P PRE , 1 PUMP SLACK OUT 00:30 - 01:00 0.50 RIGU F P PRE PUMPED 342' OF WIRE OUT, WHICH WOULD HAVE BEEN 2.2% EXCEEDING THE 2% +MAXIMUM. CUT WIRE AND SEAL END TO IREVERSE SLACK BACK IN 02:50 - 03:15 0.42 i RIGU P PRE 1 R - "GOOD TEST, PUMP SLACK BACK r 03:15 - 03:30 ! 0.25 RIGU P PRE I BLOW COIL BACK WITH AIR TO CUT PIPE 04:00 - 05:15 1.25 RIGU P , PRE IBLEW BACK 7.9 BBLS OF KCL, RU PIPE 1 'CUTTER` VALVE CREW ON LOCATION, FINISH RU PIPE CUTTER.. ._ 107:00 - 08:00 1.00 RIGU P � ' PRE . ; PULL TWC, MNO PRESSURE BELOW, FLUID ILEVELAT WELLHEAD, PULL ABOVE MASTER SAND TEST AGAINST SSV WITH 500 PSI FOR 5 'MINUTES, GOOD TEST, BLEED OFF AND LD ' TWC AND LUBRICATOR. 08:00 - 09:00 1.00 RIGU . � P j PRE CUT EXCESS COIL FOR SLACK �. MANAGEMENT 09:00 - 10:30 I 1.50 RIGU P PRE ; ■ 10:30 - 11:30 % 1.00 RIGU 1 P PRE RE-HEADED BHI E -LINE 112:30 - 14:00 1.50 ( STWHIP . P DECOMP ; PJSM ON MU MILLING BHA, MU BHA AS PER 1 BHI 14 :00 - 15:00 1.00 STWHIP � P . ` 1 DECOMP I RIH TO BELOW DIESEL FREEZE PROTECT I AND DISLACE OUT WITH KCL 15:00 - 18:00 3.00 ( STWHIP P DECOMP RIH 18:00 - 18:15 0.25 j STWHIP I N DECOMP +CREW CHANGE AND TIE IN 18:15 - 21:00 2.75 STWHIP N i DECOMP I PUH TO SHALLOWER DEPTH AND RE -LOG. FIRST LOGGING PASS IS TO HOT TO SEE ' THE PEAKS NEEDED TO TIE IN. PULLED AWGRS INFO TO SEE WHAT ELINE REFERENCED FOR THEIR TIE IN AND WE DON'T HAVE THE LOGS THEY USED. CALLED ; ELINE WSL TO PULL REFERENCE AND JOB LOG THEY USED TO SET WS AND SEND ROUSTABOUT TO PBOC TO PU 23:15 - 23:30 + 0.25 j STWHIP ; P I ` DECOMP 1 THE CCL LOG THIS IS THE ONLY THING WE HAVE THAT WE CAN MATCH UP FOR DEPTH CONTROL. CORRECT DEPTH -12' AND RIH TO ;TAG TOP OF CMT OR PINCH POINT. THE i w- 'WINDOW WILL BE MILLED OFF THIS DEPTH SO WE HAVE A REFERENCE POINT WHEN [ + I WE COME BACK IN WITH THE BUILD BHA. I ONCE WE DRILL INTO THE SHUBLIK WE WILL BE ABLE TO TIE EVERYTHING INTO IT. 23:30 - 23:50 0.33 STWHIP P j DECOMP 1 TAG TOC AT 9043.2', PU AND TAG AGAIN SAME DEPTH N 3"1 N I 23:35 START PUMP AND START MILLING CMT AT 9042.6' , WWIA/OA= 56/480/698 PSI 1 1 2.5 BPM @ 1553 PSI FREE SPIN li,- — ___J - ' ,00.75K WOB _ — Printed 3/1/2011 12:55:16PM WELLHEAIO= FMC WARING: RADIO TRANSMITTER IN WEATHER MONITOR ACTUAI - OR- BAKER _ • A"39A SHACK M IE TURNED OFF BEFORE ANY WELLWORK KB`ELEV 8 • INVOLVIN LOSIVES CAN BEGIN. CONTACT PAD BF. ELEV = 51.6' OPER *** CHROM E TBG &LNR *** KOP = 3800' Max Angle '= 98° @ 9483' 2097' 1-14-1/2" OTIS SSSV NIP, ID= 3.813" I Datum MD = N/A GAS LIFT MANDRELS DatumTVD= 8800. SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3406 3405 2 KBMG DMY BK 0 10/25/1( 6 5182 5115 21 KBMG DMY BK 0 10 -3/4" CSG, 45.5 #, J -55 BUTT, ID = 9.953" H 3048' I • 5 6465 6321 20 KBMG DMY BK 0 10/25/1( L 4 7302 7108 20 KBMG DMY BK 0 3 7859 7634 19 KBMG DMY BK 0 10/25/1( 2 8412 8153 21 KBMG DMY BK 0 Minimum ID = 2.377" @ 9047' 1 8703 8424 21 KBMG DMY BK 0 10125/1( 3-1/2" X 2 -7/8" XO ►4 1 -4� 8732' H TOP OF CEMENT SHEATH (04/30/96) 1 • ∎ • � '�. � � 8752' H3.70" BIT GEN 11 DEPLOY SLV, ID = 3.00" I ►�• • .. '�' ►�� 8774' —13-1/2" OTIS X NIP, ID = 2.812" I ►••1 •4 04' ►•1,4 i � ► ► i 4 •1 • ►• � 4, �f� , 8796' —14 -1/2" PARKER SWS NIP, ID = 3.813" I ♦1 1 4 ►•, � • j • ■� j I 8804' H 7 -5/8" TNV LATCH ASSY, ID = 3.92" I ►•. �� ►Q►,� I 8805' H7-5/8" X 4-1/2" TM/ HBBP PKR, ID = 4.00" I ►�♦ .4 ► • ►�.. • •■'} `� 8829' H4 -1/2" PARKER SWS NIP, ID = 3.813" I •1 • 4 ► • • 4 -112" TBG, 12.6 #, 13CR NSCT, 8856' � �� • 0 � • • • 8845' - 4 -1/2" PARKER SWN NIP, BEHIND .0152 bpf, ID= 3.958" � � � • � ► � MILLED TO 3.80" (12/31/10) CT LINER • 7 -5/8" X 5 -1/2" BKR H PKR W/ TIEBACK SLV H 8856' 6104 ►� ' A A I (� I ,1�!. ►.44 8858' 4 - 1/2" WLEG, ID = 3.958" TOP OF BKR C-2 SETTING SLEEVE I--I 8866' , l !j ►j� j 7 -5/8" X 5 -1/2" BKR H ISOLATION PKR/ HGR H 8873' k :�: K 8870' -iBTM OF CMT SHEATH, ID = 3.80" • 7 -5/8" TBG, 29.7 #, NT95HS NSCC, -I 9030' ••• ►�� •• •4 • .0459 bpf, ID = 6.875" •Q �•4 •• •4 • ■ 3 -1/2" LNR, 9.3 #, 13C STL, --I • 9047' � I• 3-1/2" • • I87 b.f ID = 2.992" i ► i i i i ► i i i .4 •►i • i I5 -1/2" WHIPSTOCK (01/04/1S) 9063' •�i �� 9047' —13 -1/2" X 2 -7/8" XO, ID = 2.377 I 5 -1/2" LNR, 17 #, 13CR NSCC, -9064 * ` • • • � ► � • � 4 .0232 bpf, ID = 4.892" :44 t* Id 144 k;.7 �\ _ 5 -1/2" MILLOUT WINDOW (A -39A) 9064' - 9075' PERFORATION SUMMARY REF LOG: GR/ CCL ON 02/03/2011 ANGLE AT TOP PERF: 88° @ 10790' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 1 2" 6 10790 - 10860 0 02/05/11 2" 6 11000 - 11220 0 02/05/11 1 PBTD I- 11715' 2 -7/8" LNR, 6.16 #, 13CR -80 STL, 11752' K1 A - 3'1/ .0058 bpf, ID = 2.441" '... DATE REV BY COMMENTS • DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/10/93 N28E ORIGINAL COMPLETION WELL: A -39A 02/06/11 NORDIC 2 CTD SIDETRACK (A -39A) PERMIT No: 2101850 02/09/11 PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 22344 -01 SEC 35, T11 N, R13E, 1482' FNL & 920' FEL NIP Fvnlnrntinn (AIx4a1 • • sTERE 01 d SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A -39 Sundry Number: 310 -428 Dear Mr. McMullen: 54, DEC. 8 2U)U Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1- Daniel T. Seamount, Jr. Chair DATED this Z/ day of December, 2010. Encl. STATE OF ALASKA . le ALASKA AND GAS CONSERVATION COMMISSI y ti� l �� . APPLICATION FOR SUNDRY APPROVAL DEC 2010 20 AAC 25.280 1. Type of Request: Alaska Qii &Gas Cans. Commissitn ❑ Abandon ■4 Plug for Redrill' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved rogr m ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension Anchorage ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ' ❑ Exploratory 193 - 028 _ 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 22344 - 00 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU A -39 - Spacing Exception Required? ❑ Yes Z No 9. Property Designation: 10. Field / Pool(s): ADL 028286 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9585 ' 9250' • 9506 9176' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 140' 20" 140' 140' Surface 3048' 10 -3/4" 3048' 3047' 3580 2090 Intermediate 9032' 7 -5/8" 9032' 8732' 8180 5120 Production Liner 719' 5 - 1/2" 8866' - 9585' 8576' - 9250' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9045' - 9314' 8744' - 8996' 4 - 1/2" x 12.6# 13Cr 8858' Packers and SSSV Type: 7 -5/8" x 4 - 1/2" TIW HBBP Packer Packers and SSSV 8805' / 8519' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 25, 2010 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - = Suspended 17. I hereby certify that the f• regoing is true and correct to the best of my knowledge. Contact Cody Rymut, 564 -5452 Printed Name Jo i Aren, Title Engineering Team Leader ` Prepared By Name /Number: Signature r/ , Phone 564 -4711 Date /2 ( �? /6 Elizabeth Barker, 564 -4628 Commission Use Only Condition . - pproval: Votify Commission so that a representative may witness v 31 } �! l� Sundry Number ! `l ❑ Plug Integrity Sit BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance f 35o r sz; LoP 54 l Other: �, e S 14-- Cyw„ / jz 2 S o psi- Ann.-4- -- A f4er t,, 4.4. 84 l4 cam' air-44a ,. 2 O A• Z . r. ii ZC � :) J � � Subsequent Form Required: /d — 4/ 6 ' � ' APPROVED BY z z71/0 Approved By. 4 . 1 4 COMMISSIONER THE COMMISSION Date Form 10-403 Revised O tb s DEC 21 N A Sub it In Duplicate • To: Alaska Oil & Gas Conservation Commission h From: Cody Rymut b p CTD Engineer Date: December 6, 2010 Re: A -39 Sundry Approval Sundry approval is requested for well A -39. A -39 is a conventional waterflood well drilled and completed in 1993. The well penetrates to the base of conglomerate, but was perforated in Ivishak Zone 4 only. The well initially came online producing at quality rates. Production declined steeply and by March 1994 the well was producing at an all time low. The Ivishak was fracture stimulated in March 1994 and production increased back up to quality rates, but the water cut quickly climbed and one year - later the well was reduced to making very little oil. Sag River perforations were added in January 1996. A short oil buzz resulted from the adperf. In May - 1996, the sag was frac'd with no apparent change in production. Prior to the frac, the production packer was cement squeezed to repair a packer leak. A production log following the frac showed 33% sag contribution and 64% Z4 upper even though the production trends did not indicate a production increase after the frac. A -39 consistently stayed on production from 1996 to 2005. During this time, the well was acid stimulated in December 2002 with little response and experienced some Anncomm work to correct a failed TIFL in 2002. A -39 was shut -in for high water cut in April 2005. It was POP'd for rate in May 2006 and remained online producing very little oil, with a high GOR and a 96% WC until January 2010 when it was shut -in for uncompetitive H2S. REASON FOR SIDETRACK Given the low oil rates and high water cut A -39A is a good candidate for a coil sidetrack. The proposed well will provide additional offtake in a fault block located in Northwestern A -pad, which will target unswept attic oil banked against the fault to the north of A -39 and A -10. The proposed plan for A -39A is to drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around December 31 2010. The existing perforations will be isolated by a cement downsqueeze after setting the whipstock, as well as the primary cement job. The sidetrack, A- 39A, will exit the existing 5.5" liner and kick off in the Shublik, before landing in zone Z4B. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. ( picot: OiI tort i S plitsIt Ny& Pre -Rig Work: (scheduled to begin December 25, 2010) rho" a Poiv f,d / 14o f 1. S Drift sample bailer and tag on PBTD (9503') CU! Ov . / - t oy 2. S Dummy WS drift to 9175' l'41f 'c7v Yo f r ,G 7° 161 3. S Caliper tubing from 9175' to surface r 1000 f ,, 4. E Set top of whipstock at 9075' ✓ ar / Z /XP 3 v 61 / r 5. C Mill XN nipple at 9249' with LH motor and cement sheath from 8$58' -8870' , . d Z 6. C Down squeeze cement to cover perfs, llbbls of 15.8 unislurry 7. W AC -LDS 8. V PT MV, SV, WV 9. D Bleed gas lift and production flowlines down to zero and blind flange 10. 0 Remove wellhouse, level pad • • Rig Work: (scheduled to begin on December 31, 2010) PEA 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mill 3.8" window at 9075' and 10' of rathole. Swap the well to Geo -Vis. 3. Drill Build: 4.125" OH, 210' (43 deg /100 planned) with resistivity 4. Drill Lateral: 3.75" OH, 3206' (12 deg/100 planned) with resistivity ‘11 5. Run 3 -1/2" x 2 -7/8" solid chrome liner leaving TOL at 8840' N.) PTA 6. Pump primary cement leaving TOC at 8840', 29.2 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL /GR/CCL log n ^ 3 � n 8. Test liner lap to 2400 psi. /^t f� 9. Perforate liner per asset instructions (1000') 10. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's, and pull BPV. 2. Generic GLV's 3. ASRC flow back test Cody Rymut CTD Engineer 564 -5452 CC: Well File Sondra Stewman/Elizabeth Barker TREE= 4- 1/16" CM/ WELLHEAD= FMC _3 SAFETY S WAKING: RADIO TRANSMITTER IN BAKER W MTOR SHACK M UST BE TURNED OFF ACTUATOR= KB. ELEV = 81.5' BEFORE ANY WEL LWORK INVOLVING EXPLOSIVES BF. ELEV = 51.6' I CAN BEGIN. CONTACT PAD OPER *** CHROM E TBG & KOP = 3800' Max Angle = 21° @ 8509' I 2097' I -14 -1/2" OTIS SSSV NIP, ID= 3.813" I Datum MD = 9191' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3406 3405 2 KBMG DMY BK 0 10/25/10 6 5182 5115 21 KBMG DMY BK 0 10 -3/4" CSG, 45.5 #, J -55 BUTT, ID = 9.953" I- j 3048' ■ 5 6465 6321 20 KBMG DMY BK 0 10/25/10 LI 4 7302 7108 20 KBMG DMY BK 0 3 7859 7634 19 KBMG DMY BK 0 10/25/10 2 8412 8153 21 KBMG DMY BK 0 Minimum ID = 3.7" @ 8870' 1 8703 8424 21 KBMG DMY BK 0 10/25/10 BOTTOM OF CEMENT SHEATH — I 8732' I -ITOC: PKRCMTSQZ'D, 04/30/96 I I ' 1 8796' H4 -1/2" PARKER SWS NIP, ID = 3.813" 1 I 8804' I-ITNV LATCH ASSY I �� 8805' 1-1 7-5/8" X 4-1/2" TM/ HBBP PKR, ID = 4.00" I 8829' I -14 -1/2" PARKER SWS NIP, ID = 3.813" 1 I 8845' I-- I4 -1/2" PARKER SWN NIP, ID = 3.725" 1 1 4 -1/2" TBG, 12.6 #, 13 -CR, 0.0152 bpf, ID = 3.958" H 8856' 17 -5/8" X 5 -1/2" BKR H PKR W/ TIEBACK SLV H 8856' I 8858' H 4 -1/2" WLEG I ■ I TOP OF BKR C-2 SETTING SLEEVE H 8866' 1 L ---I 8870' H BTM OF CMT SHEATH, ID = 3.70" 1 1 7 -5/8" X 5 -1/2" BKR H ISOLATION PKR/ HGR 1-1 8873' r 4 - 7 -5/8" 4136, 29.7 #, NT95HS NSCC, -1 9030' I-A ■ .0459 bpf, ID = 6.875" I L' ` 0 7 S d PERFORATION SUMMARY / V REF LOG: BHCS 06/29/93 I ANGLE AT TOP PERF: 20° @ 9045' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9045 -9066 0 03/25/96 I 3 -3/8" 6 9152 -9214 0 07/10/93 3 -3/8" 6 9224 -9286 0 07/10/93 3 -3/8" 6 9296 -9314 0 07/10/93 I PBTD I 9503' I 1 5 -1 /2" LNR, 17 #, 13 -CR, .0232 bpf, ID = 4.892" H 9585' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/10/93 ORIGINAL COMPLETION WELL: A -39 02/06/01 SIS -MH CONVERTED TO CANVAS PERMIT No: 1930280 03/05/01 SIS -LG FINAL API No: 50- 029 - 22344 -00 07/03/01 CH/KAK CORRECTIONS SEC 35, T11 N, R13E, 1482' FNL & 920' FEL 11/13/02 MH/KAK GLV C/O 11/17/10 SWC /PJC GLV C/O (10/25/10) i BP Exploration (Alaska) TREE= 4- 1/16" CIW LHEAT { AC�TUA OR= BAKER • A -3 9 A SAFETY CHROM E TBG & LNR. A PKR CMT SQZ WAS Nit: ON 4/30/96 DUE TO A FAILURE OF THE KB. ELEV = 81.5' Proposed CTD Sidetrack 7 -5/8" X 4 -1/2" TIW PKR @ 8805'. BF. ELEV = 51.6' KOP = 3800' Max Angle = 21 @ 8509' I 2097' - -I4 -1/2" OTIS SSSV NIP, ID= 3.813" Datum MD = 9192' Datum TVD = 8800' SS O _ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3406 3323 4 CAMCO DOME BK 16 6 5182 5034 21 CAMCO DMY BK 0 110 -3/4" CSG, 45.5 #, J -55 BUTT, ID = 9.953" I--I 3048' ' I 5 6465 5240 20 CAMCO DOME BK 16 LJ 4 7302 7027 20 CAMCO DMY BK 0 a ""''- "'' 3 7859 7553 19 CAMCO DOME BK 16 2 8412 8071 21 CAMCO DMY BK 0 Minimum ID = 2.375" @ 8835' 1 8703 8342 21 CAMCO_ SO BK 24 11/13/02 Baker KB LTP seal assy — 8732' (H OC: FKR CMT SQZ'D, 04/30/96 I ' 8796' J- 14 -1/2" PARKER SWS NIP, ID = 3.813" I 8804' — TM/ LATCH ASSY I E g — 8805' — 7 -5/8" X 4 -1/2" TM/ HBBP PKR, ID = 4.00" I ' ' I 8829' H4 -1/2" PARKER SWS NIP, ID = 3.813" I --- I I 8835' I- 14 -1/2" BKR KB chrome LTP ID = 2.375" 21 8840' —1Top of Proposed 3 -1/2" Liner I I 8845' 4 -1/2" PARKER SWN NIP, ID milled to = 3.80" I 1 4-1/2" TBG, 12.6 #, 13 -CR, 0.0152 bpf, ID = 3.958" I---I 8856' 7 -5/8" X 5 -1/2" BKR H PKR W/ TIEBACK SLV I-1 8856' I z 8858' I -14 -1/2" WLEG I TOP OF BKR G2 SETTING SLEEVE H 8866' ___ 1 L I 8870' H BTM OF CMT SHEATH, ID = milled to 3.80" I 17 -5/8" X 5 -1/2" BKR H ISOLATION PKR/ HGR H 8873' I 4 7 -5/8" Tie, 29.7 #, NT95HS NSCC, —1 9030' I-. ■ .0459 bpf, ID = 6.875" J 9075' I 4 -112" x 5 -1/2" Mechanical Whipstock 20 PERFORATION SUMMARY ' REF LOG: BHCS 06/29/93 ANGLE AT TOP PERF: 20 @ 9045' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE - 3 -3/8" 6 9045 -9066 0 03/25/96 3 -3/8" 6 9152 -9214 0 07/10/93 3 -3/8" 6 9224 -9286 0 07/10/93 13-1/2" x 2 -7/8" 13Crr Liner, Cemented & Perf'd H 12490'I 3 -3/8" 6 9296 -9314 0 07/10/93 ill SAFETY NOTES: WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED f PBTD H 9503' I OFF BEFORE ANY WELL WORK INVOLVING ...4* EXPLOSIVES CAN BEGIN. CONTACT PAD I 5-1/2" LNR, 17 #, 13 -CR, .0232 bpf, ID = 4.892" I 9585' ' .�A OPERATOR. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/10/93 ORIGINAL COMPLETION WELL: A -39 02/06/01 SIS -MH CONVERTED TO CANVAS PERMIT No: 03/05/01 SIS -LG FINAL API No: 50- 029 - 22344- 07/03/01 CH /KAK CORRECTIONS SEC 35, T11 N, R13E, 1482' FNL & 920' FEL 11/13/02 MH /KAK GLV C/O 10/25/10 MSE PROPOSED CTD SIDETRACK BP Exploration (Alaska) ,i~~-'',, STATE OF ALASKA ALASKa, .,iL AND GAS CONSERVATION CL. ..MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Acid - TIFL 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1482' SNL, 920' WEL, Sec 35, T11N, R13E At top of productive interval 885' SNL, 2542' WEL, Sec 35, T11N, R13E At effective depth 827' SNL, 2650' WEL, Sec 35, T11N, R13E At total depth 827' SNL, 2651' WEL, Sec 35, T11N, R13E Type of well: [~ Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE: 81.5 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-39 9. Permit Number / Approval No. 93-28 / 10. APl Number 50- 029-22344 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 9585 feet Plugs (measured) BKB 9250 feet 9506 feet Junk (measured) BKB9176 feet Length Size Cemented M D TVD Structural BKB Conductor 110' 20" 99 c.f. Arcticset 140' 140' Surface 3020' 10-3/4" 1862 c.f. CS 111/408 c.f. 'G' 3050' 2998' Intermediate 9002' 7-5/8" 302 c.f. Class 'G' 9032' 8681' Production Liner 720' 5-1/2" 136 c.f. Class 'G' 8866' - 9585' 8525' - 9199' Perforation depth: measured Open Perfs 9045' - 9066', 9152' - 9214', 9224' - 9286', 9296' - 9314' true vertical Open Perfs 8744' - 8764', 8844' - 8902', 8911' - 8970', 8979' - 8996' Tubing (size, grade, and measured depth) 4-1/2" 13CR to 8805' with 4-1/2" tailpipe to 8859' Packers and SSSV (type and measured depth) 7-5/8" packer TIW (HBBP Permanent) (4.0 ID) @ 8805', 4-1/2" Otis SSSV @ 2097' See Attachment 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1l,l,4 y 0 2. ?.a n Anchorage' Commission 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended of Well O [] Daily Repo~ 17. I hereby.~erti~/that/,~/~, ,.~. ~ ~/ - ,/f/~ ¢t'Ke fore/j~fing is tru~.a~dccorrect to the best of my knowledge Signe~~~~//.~..~_~,,~ Title Technical Assistant Form 10-404 Rev. 06/15/88 Service Name/Number: Date ~'/~/~'/ DeWayne Schnorr 564-5174 Submit In Du A.39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/30/2001 ACID: TIFL SUMMARY 01/30/01 T/I/O = 230/1260/340 Temp = 127 TIFL FAILED(?) Pre-Acid Initial IA FL @ 8703' Bled IA From 1630 psi to 320 psi in 1 Hr. IA Inflowed 506' (13 BBIs) During Bleed Down. Monitored for 30 min. IA FL @ 8178' TBG FL @ 8156' FINAL WHP's = 1320/320/100 Fluids Pumped BBLS. Description No Fluids Pumped TOTAL ON OR BEFORE c:LOglXlVtFILNI.DOC t' . "~ ~ STATE OF ALASKA " ~TT~J~LA~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X 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 1482' SNL, 920' WEL, SEC. 35, T11N, R13E At top of productive interval 885' SNL, 2542' WEL, SEC. 35, T11N, R13E At effective depth 827' SNL, 2650' WEL, SEC. 35, T11N, R13E At total depth 827' SNL, 2651' WEL, SEC. 35, T11N, R13E 5. Type of Well: Development X Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE=80.52' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-39(31-35-11-13) 9. Permit number/approval number 93-28 / 10. APl number 50- 029-22344 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9585' feet Plugs (measUred) 9250 feet 9506' feet Junk (measured) 9176' feet Length Size Cemented Measured depth .. 110 20 11 yds Arcitcset 140 3020 10 3/4 1862 c. f cs111/408 c. f "G" 3050 9002 7 5/8 302 c.f Class "G" 9032 .. 720 5 1/2 136 c.f Class "G" 8866 - 9585 measured 9152'-92',9192'-214',9224'-9286',9296'-9314' True vertical depth BKB 140 2998 8681 8525- 9199 true vertical subsea 8844~8881~8881~8902~8911'-8970~8979~8996' Tubing (size, grade, and measured depth) 4-1/2" 13CR80 @8857.5' Packers and SSSV (type and measured depth) Packer @8805, SSSV2097' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3002 3848 703 0 5531 ,,;'"" 6076 886 0 Tubing Pressure 242 266 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~/~hat the~ego/~is true an~.~r~ the best of my knowledge. Signed ~ (..~j.,b/ ~,~'~ Title Technical Assistantlll Form 10-404 Rev 06/15/88 SUBMIT IN DUC)LI(~TE 1/31/96 WELL A-39 (31-35-11-13) _ Addperf/Reperf The following additional interval were perforated using guns, 6 SPF, random orientation and 60° phasing. 3 3/8" 9045'- 9066' MD STIM Operation 3/24/96 A CMT Sandback was performed using the following fluids: SUMMARY RIH and located jewelry, no correction made to E-line measured depths. Layed in a total of 2855# of 2040 carbolite in 2 batches as follows: Batch 1:1905 lbs, calculated top 9102', actual 9177'. Lost 858 lbs to the formation. Batch 2:950 lbs, calculated top 9104', actual 9105'. Minimal losses to the formation. Sanded back to 9105' CTD. Wellbore is freeze protected with 20% Methanol. Flowline is freeze protected with 50/50 methanol. BBLS. DESCRIPTION 262 Filtered Seawater 12 Gel 23 Gel/Carbolite slurry, total of 2,855 lbs of 20/40 carbolite 26 Methanol 323 Total 3/25/96 The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9045'- 9066' MD _ NRWO Operation 4/30/96 A NRWO Packer Squeeze was performed using the following fluids: SUMMARY Sand back from 9040 to 8869 ft with 2525 lbs 20/40 carbolite in two stages. Pump 1.5 bbls neat cement, 1 bbl fibre reinforced and 1.5 bbls neat. Pumping the fibre reinforced was a bitch and we had to go to neat again for the last 1.5 bbls to get the job done. Lay in 0.5 bbls below tailpipe and take 3 bbls returns up the IA. 0.5 bbls left in tubing. Estimated TOC in IA is 8732 ft, in tubing 8820 ft. Pumping the fibre cement gave problems. The pumps clogged almost immediately and several pressure surges occurred while trying to free them. This caused the coil and hardline to jump alarmingly. FLUIDS PUMPED _ BBLS DESCRIPTION 310 Seawater 29 Gel 3.0 G neat cement 1.0 G neat with 0.25% fibres 20 Freshwater 19 Methanol 5 / 12/96 Performed a Data FRAC and Fracture (Sag River) using the following fluids: FLUIDS PUMPED DOWNHOLE -. Establish rate with 40# gel 30/ 30 215/ 245 97/ 343 20/ 363 30/ 393 37/ 430 43/ 473 48/ 521 52/ 573 217/ 790 22 812 1 ppg on perfs 8 ppg on perfs Stage pad Stage 1 ppg 16/20 CL Stage 2 ppg 3 ppg 4 ppg 5 ppg 6 ppg 7 ppg 8 ppg go to flush Sd pumps. Monitor WHP. SI well, bleed IAP to 500. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 1029 Bbls FRAC: 812 Bbls 1 8 4 1 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 5 Diesel to IA, tubing, or GC * * Diesel Recovered (not downhole) Total Diesel LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 8 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 23- DC c-10 ~-i~ c-24 (14-19-11-14) ~1-(~{ F-16 6~ --- ~' :A-39 (31-35-11-13) I PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 542.03 Run # 1 3457.08 Run # 1 4014.04 Run ~ 1 4566.04 Run ~ 1 5999.06 Run # 1 6261.02 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: ~eceived b~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: I April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ? ~ - ~{5-~-01 (13-08-11-~3) ~ ~-~~-39 (31-35-11-13) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 1423.09 Run # 1 2577.10 Run # 1 4060.07 Run # 1 5999.05 Run # 1 6070.01 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 FAnchorage, AK 99518 AX to (907) 563-7803 Date: 9 3 .... 0 2 8 9 3 "- 0 2'8 9 3 --- 0 2 8 B H C: '."~.,,, 9027 .... 9543 93 .... 028 DIL F't,-tASCR '">~L 9027-,-9574 1'!i .... 0 9 ':', 6, R /c c L.. ( ,J W L ) ~ ....-~'~'S S 0 ...... 9 0 ? 7 PER F/P FC:,/GR 93 ...... 028 i::'LS ........... S B L 904-0 .... .9a. 7''~o ..- Da'{fe: 04/18/95 RUN DATE .... RECVD 07,,/19/199 ~ 08/26/' 1993 ,'c, 6/" 08/, ~, 'i 993 08/'26/1993 " " 9 q 07 / 1 .% ,,, 07 / '12/1993 07/' 'i © "'i 993 'i 04 / 2 o ,, 1 07/" 19/1993 1 04/' 19/199a. 07/"3 O/1993 Ar'e dr'.y d'i"t,;::h samp"les r'equ'ir'ed? ¥, :;.~ .... s 't: h e w e '11 c o r" e d o.,,., yes (~"o~. A in a '1 y s '¥ s & cl e s c r" '¥ p t. ~ r' e (:: e. 'ive (:t ? STATE Of ALASKA ALAn'[ '3IL AND GAS CONSERVATION COMMISSI¢ REPORT C,-' SUNDRY WELL OpEhATIONS 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. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1482' SNL, 920' WEL, SEC. 35, T11N, R13E At top of productive interval 885' SNL, 2542' WEL, SEC. 35, T11N, R13E At effective depth At total depth 827' SNL, 2651' WEL, SEC. 35, T11N, R13E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE=80.52' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-39(31-35-11-13) 9. Permit number/approval number 93-28 / 10. APl number 50- 029-22344 11. Field/Pool Prudhoe 0il Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 3020 Intermediate 9002 Production -- Liner 720 Perforation depth: measured 9585' feet Plugs (measured) 9250 feet 9506' feet Junk (measured) 9176' feet Size Cemented 30 11 yds Arcitcset 10 3/4 1862 c.f cs111/408 c.f "G" 7 5/8 302 c.f C/ass "G" 5 1/2 136 c.f Class "G" 9152'-92', 9192'-214',9224'-9286', 9296'-9314' Measured depth 140 3050 9032 8866-9585 ORIGINAL True vertical depth BKB 140 2998 8681 8525- 9199 true vertical subsea 8844'-8881',8881'-8902',8911'-8970',8979'-8996' Tubing (size, grade, and measured depth) 4-1/2" 13CR80 @8857.5' Packers and SSSV (type and measured depth) Packer @8805, SSSV2097' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED ~rn ~ /t lqqz~ At~S~ 0ii & Gas Cons. Commissio~ Anch0ra~e 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3002 3848 703 0 5531 ~ 6076 886 0 Tubing Pressure 242 266 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. Sign e d~"-/f~..~.j~ (/ ,~~ Title Senior TechnicalAssistantl Form 10-404 Rev 06/15/88 Date SUBMIT IN DOPL4CAi'E 3/30/94 WELL A-39(31-35-11-13) Hydraulic Fracturing A Hydraulic Fracture (Ivishak) was performed using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: 369 Bbls 20#/40#Gel DATA FRAC: 396 bbls 40~ gel FRAC: 664 Bbls 40# Gel &Slurry FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. RECEIVED SEP 1 4 1994 Aiaska Oil & Gas Cons. Commissior, Anchors~e Q~- \'L.~, D-01 (23-11-13) ~%-I~ K-07 (23-33-12-14) ~-0~ W-08 (11'26-11-12) ~-~ A-39 (31-35-11-13) /1 DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA ~ PDK/GR/CCL FINAL BL 1 PDK/GR/CCL RF SEPIA ~ CN/GR FINAL BL 1 CN/GR RF SEPIA /1GR JEWELRY FINAL BL 1 GR JEWELRY RF SEPIA 1 GR/CCL FINAL BL / 1. GR/CCL FINL.RF SEPIA Run ~ 1 Run ~ 1 Run # 1 Run ~ 1 Run ~ 1 Run ~ 1 Run $ 1 Run Run $ 1 Run ~ 1 4528.04 3089.01 3770.02 4117.02 5999.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (~ 3-3) !.. Petrotechnical Data Center ..~. BP Exploration(Alaska) Inc..., . 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION W-ii (14-28-11-12) A-03 (44-27-11-13) 1 PLS STATIC FINAL BL ~--BA~STATIC RF SEPIA 1 PLS INJ. FINAL BL ~-'PLS INJ. RF SEPIA A-OS (23-36-11-13) A-39 (31-35-11-13) 1 PLS INJ. FINAL BL ~PLS INJ. RF SEPIA ROF. FINAL BL ROF RF SEPIA s-30 (12-07-11-14) 1 PL STATIC FINAL BL ~ STATIC RF SEPIA W.o- 51 R-27 f6-/9 5 9 S-7A 1 PLS STATIC FINAL BL --1 PLS STATIC RF SEPIA 1 PLS STATIC FINAL BL --1 PLS STATIC RF SEPIA 1 PLS STATIC FINAL BL -T ~ STATIC RF SEPIA 1 PL STATIC FINAL BL ~ P~ STATIC RF SEPIA 1 PLS STATIC FINAL BL ,%'P~ STATIC RF SEPIA z-04 (41-24-11-11) 1 PLS STATIC FINAL BL /I ~t~S STATIC RF SEPIA 1 PLS STATIC FINAL BL _1 PLS STATIC RF SEPIA Date: 14 April 1994 Transmittal of Data Sent by: ANCHORAGE XPRES ECC No. Run ~ 1 5642.01 Run # 1 Run ~' 1 3038.01 Run # 1 Run # 1 6163.00 Run # 1 Run # 1 5999.02 Run ~ 1 Run # 1 3583.02 Run Run # 1 4735.01 Run Run ~ 1 5670.01 Run ~ 1 Run ~ 1 6157.00 Run $ 1 Run ~ 1 6160.00 Run ~ 1 Run ~ 1 6159.00 Run # 1 Run ~ 1 4129.02 Run ~ 1 Run ~ 1 5815.01 Run # 1 Cont/ INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 93-028 BHC 9027-9543 93-028 CNL 9027-9525 93-028 DIL PHASOR 9027-9574 93-028 PERF/PFC/GR 9150-9400 93-028 SBL 8900-9496 93-028 407 93-028 DAILY WELL OP 93-028 SURVEY 93-028 Are well tests required? Was well cored? Yes No... 5712 Yes No COMP DATE:07/10/93 06/18/93-07/04/93 MWD OH/BHC,8453.50-9597 If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL 08/30/1993 PAGE: 1 COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION 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 93-28 !3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50-029-22344 4. Location of well at surface 9. Unit or Lease Name . 10. Well Number 885'SNL, 2542'WEL, SEC. 35, T11N, R13.~:.~~-.~- ~,~~ 11. Field and Pool At Total Depth ~ ~~' PrudhoeBayField/PrudhoeBayPool 827' SNL, 2651' WEL, SEC. 35, T11N, R13 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 80.52' I ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. er Aband. 115. Water Depth, if offshore 116. No. of Completions 6/18/93 6/28/93 7/10/93I N/A feet USE I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD. 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 9585' MD/9250' TVD 9506' MD~9176' TVD YES [] N3 []! 2097' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS/CNL/GR/SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 110' 30" 11 yds Arcitcset 10-3/4" 4,5.5" J-55 36' 3050' 13-1/2" 1862 cu ft CS 111/408 cu ft Class "G" 7-5/8" 29. 7# NT-95HS 32' 9032' 9-7/8" 302 cu ft Class "G" 5-1/2" 17# 13CR80 8866' 9585' 6-3/4" 136 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET tMD) Gun DiameterMD3-3/8" 6 ~/fD 4-1/2" 8857.5' 8805' 9152'-9192' 8844'-8881' 13CR80 9192'-9214' 8881 '-8902' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9224'-9286' 8911'-8970' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9296'-9314' 8979'-8996' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/18/93 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL DIL 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. RECEIVED Alaska Oi~ & Gzs Cons. Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 'i 30. GEOLOGIC MARKERS: i FORMATK)N TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9039' 8738' Shublik 9067' 8764' Sadlerochit 9151' 8843' 31. LIST OF ATTACHMENTS 32. I hereby certify that j~he foregoing is true and correct to the best of my knowledge Signed ' _ _ T it I e Drillino Enoineer Suoervisor D at e INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. J~ E C E iV E D Item 28: If no cores taken, indicate "none". Form 10-407 A U G 2 993 Alaska Oil & Gas Cons. Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: A-39 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 06/18/93 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 06/18/93 (1) TD: 0 PB: 0 RIG MOVE MW: 9.3 NaCl RD & PREPARE TO MOVE. MOVE SUBSTRUCTURE OVER TO A-39. 06/19/93 (2) TD: 1503' ( 0) 06/20/93 (3) TD: 3060' (1557) 06/21/93 (4) TD: 3060' ( 0) 06/22/93 ( 5) TD: 5469' (2409) 06/23/93 (6) TD: 6060' ( 591) 06/24/93 ( 7) TD: 7000' ( 940) POH MW: 9.1 VIS:275 SPOT MOPTOR COMPLEX & MUD PITS. RU FLOOR, MU 5" KELLY & TAKE ON WATER. MU RISER, FLOW LINE, JET LINES & MIX SPUD MUD. STRAP BHA. PU BHA & ORIENT. FUNCTION TEST DIVERTER. DRILLINF F/ 96 TO 1503' CIRC. POH. RUNNING 10 3/4 CSG MW: 9.4 VIS:220 CHANGE BHA & RIH TO 1503' DRILLING F/ 1503 TO 2545. SHORT TRIP TO 1500. DRILL F/ 2545 TO 3060. SHORT TRIP TO 2500' CBU. POH. RU AND RUN 10 3/4 CSG. SLIP DRLG LINE. MW: 9.4 VIS: 46 RIH W/ 10-3/4" CSG. CIRC. PUMP 70 BBLS WATER, CMT. BUMP PLUG W/ 2000 PSI. TOP JOB W/ 400 SX CSII @ 14.9 PPG. N/D DIVERTER. N/U BOPE. TEST BOPE. RIH W/ BHA, BIT. DRLG@ 5469' MW: 9.4 VIS: 39 CBU, TEST 10-3/4" CSG TO 2800 PSI, DRILL OUT FC @ 2965', HARD CMT TO 3048', SHOE TO 3050', CMT TO 3060', NEW FORM TO 3070', PERFORM LOT @ 3070', DRILL F/3070'-4295', SHORT TRIP TO 3060', DRILL F/4295'-5342', SHORT TRIP TO 4250', DRLG F/5342'-5469' POOH W/ REV CIRC BASKET MW: 9.7 VIS: 37 DRILL FROM 5469 TO 6060. CIR BOTTOM UP. TRIP OUT OF HOLE FOR NEW BIT. LAY DOWN DYNA DRILL & MWD. SERVICE WEAR BUSHING. MAKE UP TRI-STATE 9 5/8" O.D. JET BASKET & TRIP IN HOLE TO FISH CONES. TRIP OUT OF HOLE. DRILLING MW: 9.8 VIS: 43 TRIP OUT OF HOLE. RECOVERED 2 CONES & 6 BEARINGS. MAKE UP BIT & 2 JUNK BASKETS & TRIP IN HOLE. REAM FROM 5970 TO 6060'. LOAD JUNK BASKETS & DRILL FROM 6060 TO 6108' TRIP OUT OF HOLE. RECOVERED 9 BEARINGS & JUNK. MAKE UP BHA #6. TRIP IN HOLE WITH BHA #6. FLOW TEST @3200' DRILL FROM 6108 TO 7000' Alaska Oi} & Gas C, ons. Anchorage WELL : A-39 OPERATION: RIG : NABORS 28E PAGE: 2 06/25/93 (8) TD: 8400' (1400) 06/26/93 (9) TD: 8900' ( 500) 06/27/93 (10) TD: 9048' ( 148) 06/28/93 (11) TD: 9080' ( 32) 06/29/93 (12) TD: 9585' ( 505) 06/30/93 (13) TD: 9585' ( 0) DRILLING MW: 9.7 VIS: 42 DRILL FROM 7000 TO 7124. SHORT TRIP FROM 7124 TO 6030. DRILL FROM 7124 TO 8400. DRILLING MW: 9.8 VIS: 40 DRILL FROM 8400 - 8673' CIR BOTTOMS UP AND DROP SINGLE SHOT SURVEY. TRIP OUT OF HOLE FOR BIT & BHA CHANGE. SERVICE WEAR BUSHING. CHANG BIT AND BHA. TRIP IN HOLE TO 10 3/4" CASING SHOE. CUT AND SLIP DRILLING LINE. TRIP IN HOLE. WASH AND REAM 50' TO BOTTOM. DRILL FROM 8673 TO 8900'. RUN 7 5/8" CASING. MW: 9.8 VIS: 39 DRILL FROM 8900 TO 9048'. CIR BOTTOMS UP. SHORT TRIP 15 STANDS. CIRC SWEEP AROUND. DROP TOTCO. LD 5" DP & BREAK KELLY. LD BHA. PULL WEAR BUSHING. CHANGE RAMS TO 7 5/8" INSTALL CASING BOWL PROTECTOR. RIG UP AND RUN 7 5/8" CASING. DRILLING MW: 9.4 VIS: 34 RUN 7 5/8" CASING. CIRC * RECIPROCATE 7 5/8" CASING. TEST CEMENT LINE. LD LANDING JOINT & PULL BOWL PROTECTOR. INSTALL 7 5/8" PACKOFF. CHANGE TOP RAMSS TO 3 1/2" X 6" & TEST BOPE. CHANGE OUT KELLYS. MAKE UP BHA #8 & HWDP. PICK UP 3 1/2" DRILL PIPE & TRIP IN HOLE. TAG FLOAT COLLAT @ 8951'. CIRC BOTTOMS UP. PRESSURE TEST 7 5/8" CASING. DRILL FLOAT COLLAR & HARD CEMENT & SHOE @ 9032' DRILLING FROM 9048 TO 9080'. POOH F/ LOGS MW: 9.0 VIS: 38 DRILL FROM 9080 TO 9585'. CIRC BOTTOM UP. SHORT TRIP TO 7 5/8" CASING SHOE. GOOD HOLE. NO FILL. CIRC SWEEP AROUND. DROP SINGLE SHOT SURVEY. TRIP OUT OF HOLE FOR LOGS. SLM. POOH W/ LINER RUN. TOOL MW: 9.0 VIS: 40 TRIP OUT OF HOLE FOR LOGS. SLM. RIG UP SCHLUMBERGER & LOG OPEN HOLE W/ DIL/BHCS/CNL/GR/SP WLM 9584' SERVICE WEAR BUSHING. TRIP IN HOLE. NO TIGHT HOLE & NO FILL ON BOTTOM. CIR SWEEP AROUND. TRIP OUT OF HOLE & LAY DOWN BHA. RIG UP & MAKE UP 18 JTS OF 5 1/2" LINER & LINER HANGER. MAKE UP CEMENT HEAD & PUMP LINER VOLUME. TRIP IN HOLE WITH LINER ON 3 1/2" DP. TAG BOTTOM @9585' CIRC. TEST CMT LINE. TRIP OUT OF HOLE WITH RUNNING TOOL. RECE ¥ED Alaska Oil & Gas Cons. Anchorage WELL : A-39 OPERATION: RIG : NABORS 28E PAGE: 3 07/01/93 (14) TD: 9585' ( 0) 07/02/93 (15) TD: 9585'( 0) 07/03/93 (16) TD: 9585 PB: 9506 07/04/93 (17) TD: 9585 PB: 9506 CLEAN OUT TIE BACK REC. MW: 9.1 VIS: 45 TRIP OUT OF HOLE WITH RUNNING TOOL. STRAP AND MAKE UP BAH #9. TRIP IN HOLE RO LANDING COLLAR @9503'. PRESSURE TEST 5 1/2" LINER & 7 5/8" CASING. CIRC BOTTOMS UP. TRIP OUT OF HOLE & LAY DOWN 2 7/8" DP & CASING SCRAPER. MAKE UP 7 5/8" RTTS TRIP IN HOLE TESTING CASING. TAG LINER TOP. TRIP OUT OF HOLE & LAY DOWN RTTS. MAKE UP POLISH MILL & 5 4 3/4" DRILL COLLARS & TRIP IN HOLE TO 4600'. CUT AND SLIP DRILLING LINE. TRIP IN HOLE WITH POLISH MILL TO CLEAN OUT LINER TIE BACK. CLEAN OUT TIE BACK RECEPTACLE WITH POLISH MILL. LD 3 1/2" DRILL PIPE MW: 0.0 VIS: 0 TRIP OUT OF HOLE WITH POLISH MILL. MAKE UP SEAL ASSEMBLY & TRIP IN HOLE TO LINER TOP @8868'. STING IN TO TIE BACK RECEPTACLE & TEST LINER. TRIP OUT OF HOLE & LAY DOWN SEAL ASSEMBLY. MAKE UP BAKER RECEPTACLE & SET H-PACKER. TRIP OUT OF HOLE & LAY DOWN SETTING TOOL. MAKE UP BHA #10. TRIP IN HOLE & TAG LANDING COLLAR @9506'. DISPLACE HOLE WITH FILTERED SEA WATER. RETEST CASING & LINER. TRIP OUT OF HOLE LAYING DOWN 3 1/2" DRILL PIPE. SET PACKER MW: 9.3 NaCl TRIP OUT OF HOLE 7 LD 3 1/2" DP & BHA. BREAK KELLY. RIG UP & RUN 4 1/2" COMPLETION. MAKE UP SSSV & CONTROL LINES. RUN 4 1/2" COMPLETION. SPACE OUT FOR TUBING HANGERMAKE UP TUBING HANGER & CONTROL LINES. LAND TUBING HANGER & RUN IN LOCK DOWN SCREWS. PRESSURE UP ON TUBING. RIG RELEASED MW: 9.3 NaCl TEST TUBING. LAY DOWN LANDING JOINT & SET TWO WAY CHECK VALVE. ND BOPE. NU ADAPTER FLANGE. RELEASE RIG 1330 HRS 07/04/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED AUG 2 6 1995 Alaska Oil & Gas Cons. ~ommiss~or'~ Anchorage STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:. ~'~ Workover: DATE: --.,,..m.: ,.,.,,,. CesingSize: Set~ ~/~ Feet Local~on:Sec.~_~,.,<-' T. //,d R. /,~- Merd. /-'//PI Test: In .... Weekly ~,-~' Other ------ · MISC. INSPECTIONS: Localion Gen.: Resewe Pit Wall Sign Dd. Rig BOP STACK: Ann. Preventer Pipe Rams Blind Rams Chk/Ln Valves HCR Valves Kill Une Valves Check Valve Test Qua. Pressure .... I-'/~.~: ~ 1 ~, W_:-'~,~ i / u;/.~ I MUD SYSTEM: Light Tdp Tank Pit Level Indicatom Flow Indicator Gas Detectors Teat FLOOR ~U=ETY VALVES: Quan. Prqssure P/F Lower Kelly / BMI Type ,/ Inside BOP, CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes HYdraulic Chokes ACCUMULATOR SYSTEM: 6ystem Pressure , Pressure Alter Closure Alarm 200 psi Attained After Closure minutes ~_~ · -~ System Pressure Attained / minuteS~r~ /'~' Blind Switch Covers: Master:. ~-'~' Remote: . --' N,;.. ~: Numbir of Fiilur~ / T~'l'me ~ Hours Number of valves tested ~ Repair or Replacement of Failed Equipment shall be mkde within days. NoUfy the Inspec~r on duty and follow with Written or Faxed verification to the AOGCC Commission ~'~t Fax No. 27~.7E42 Inspector North Sbpe Pager No. 86~3607 If your call is not retumnd by the inspector within 12 houm please contact the P. I. Supewbor ~t 2'/~1433 DistHbu~on: orig-Well File c - Oper~ c - Database c - Trip Rpt File c - Inspector STAT~ WITNESS REQUIRED? YES / NO 24 HOUR NOTICE GIVEN YES ,,, / NO Wmes~d By:. FI-021~T Rev. 1/93 MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: David W. John..~~ Commissione~ thru: Blair E Wondzell Petr Insp Supervisor from: '~o~hn Spaulding Petr Inspector date: July 15, 1993 ~e: 062093.doc sub, iect: BOPE Test Nabors 28E PBX PBU A-39 Prudhoe Bay Field PTD 93-28 Sunday, June 20, 1993: I traveled this date to BPX PBU Well A-39 to witness a BOPE test on Nabors 28E. As the affached AOGCC BOP Test .R. epe.rt indicates, there was one failures This failure was a clamp between the upper and lower pipe rams. The clamp was tightened and we were able to resume testing. Summary: I witnessed the BOP test on Nabors 28E PBX PBU A-39; 1 failure, 6 hours. attachments MEMORANDUM TO: David Johnst~ Chairman/-,,~ THRU: Blair Wondzell P.I. Supervisor ,.,,4 FROM: Lou Grimaldi J Petroleum Inspector STATE Ox, ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION DA TE: 6-24-1993 FILE NO: IBMGFXAA. DOC PHONE NO.' 279-1433 SUBJECT: Rig\BOPE inspection Nabor's 28-E BPX well #A-39 Prudhoe Bay Field PTD 93-28 THURSDAY 6-24-93 I made a rig\Bope inspection on Nabor's rig #28-E which is drilling BPX well # A-39 in the Prudhoe Bay Field. I found the rig to be in good shape with all necessary BOP equipment to be in place and in apparent good working order. There was a small amount of flow coming from the return line on the accumulator, also the electric would run approximately every five minutes to bring the system back up to cutoff pressure. I mentioned this to Mike Downey (Nabors Tool pusher), he will check and repair this problem. I spoke with Mike about the possible problem with the choke manifolds and their high failure rates on some Nabors rig's. It was relayed to me that they have discovered that a different type of grease is recommended for use on the McEvoy valves employed in their choke manifolds then they have been using. The recommended grease will be used and will hopefully solve their valve problem's. The area surrounding the rig was neat and orderly as is usually the case. James Carlile (Company Rep.) was friendly and receptive to my visit. SUMMARY; I made a Rig\BOPE inspection on Nabor's rig #28-E. Attachment: IBMGFXAA.XLS ALA~,.I.OIL AND GAS CONSERVATION COI~. ~SION RIG / BPS INSPECTION REPORT OPERATION' Drilling X Workover Compl. UIC DATE: 6\24\93 Well Name: A-39 PTD# 93-28 Drig Contractor: NABOR'S Rig# 28-E Rep. MIKE DOWNEY Operator: BPX Rep. JAMES CARLILE Rig Ph.# 659-4863 Location: Section 35 T. 11N R. 13E M. U (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X ,, 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) × ,, 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level i~i~i~iii?~ii~i~ii~i~i~i:~iii~iii~.i.i.i.~.~i~ii.~.i!~.~..E..:~!~..N....i.~.!~.E:.~.~.~.~.i~i~i.i.i.i.~.i.~.~.i.i.i.i.i.i.i.i.i.~.~.~.~. .i.i.i.i.i.ii~i.i~i~i~i.i.i.i.i.i indicators, gauges) (B.) CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) 18 Operating pressure X 43 Hydraulic choke panel ~ X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X iii~i~i~i~i?:::::~i::~::i::~ii::i::::::i::::ii?:ii?:~i::i::i~[.N~..~E:.~::.`~.~Ni~!!~!~::i.i.i.i.i.lii~iiiiiiii::ii~::i:?~i iiii.i.i ililiiiiii~.'.N.'ii~M~iEiiii 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 4§ Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X "28 Condition (leaks, hoses, ect.) X For Procedures 50 H2S probes X 51 Rig housekeeping X REMARKS: Accumulator has small flow from return line RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? yes 6/2O/93 none Kill Sheet Current? yes Distribution: orig - Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: Louis R. Grimaldi IBMGFXAA.XLS (Rev. 12/92) MEMORANDUM STATE OF ALASKA ALASKA OIL AND CM,g CONSER VA IION COMMISSION TO: David Johnsto~~ Chairman~ DATE: 6-24-1993 FILE N0: IBMGFXAA.DOC THRU: Blair Wondzell P.I. Supervisor FRO31: ~L~0~G rimaldi Petroleum Inspector PHONE NO.' 279-1433 SUBJECT: Rig~OPE inspection Nabor's 28-E BPX well #A-39 Prudhoe Bay Field PTD 93-28 THURSDAY 6-24-93 ! made a rig~ope inspection on Nabor's rig #28-E which is drilling BPX well # A-39 in the Prudhoe Bay Field. I found the rig to be in good shape with all necessary BOP equipment to be in place and in apparent good working order. There was a small amount of flow coming from the return line on the accumulator, also the electric Would run approximately every five minutes to bring the system · back up to cutoff pressure. I mentioned this to Mike Downey (Nabors Tool pusher), he will check and repair this problem, i spoke with Mike about the possible problem with the choke manifolds and their high failure rates on some Nabors rig's. It was relayed to me that they have discovered that a different type of grease is recommended for use on the McEvoy valves employed in their choke manifolds then they have been using. The recommended grease will be used and will hopefully solve their valve problem's. The area surrounding the rig was neat and orderly as is usually the case. James Carlile (Company Rep.) was friendly and receptive to my visit. SUMMARY; i made a Rig~OPE inspection on Nabor's rig #28-E. Attachment: IBMGFXAA.XLS STATE OF ALASKA ALAS~[ ~, AND GAS CONSERVATION CO[ iSSlON RIG / BPS INSPECTION REPORT OPERATION: Drilling X Workover ~Compl. UIC DATE: 6~4\93 Well Name A-39 PTD# 93-28 Drig Contractor NABOR'S Rig# 28-E Rep. MIKE DOWNEY Operator: BPX Rep. JAMES CARLILE Rig Ph.# 659-4863 Location: Section 35 T. 11N R. 13E M. U (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill Ln.) X 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor valves (dad, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X ~flow rate indicator, pit level (B.) CLOSING UNIT YES NO N/A 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) 18 ~Operating pressure X 43 Hydraulic choke panell X 19 Pressure gauges X 44 Choke manifold X 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO N/A 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) 25 Remote control panel X 47 Rese~e pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power soume (backup) X 49 All Drillsite Supewisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures 50 H2S probes X 51 Rig housekeeping X REMARKS: Accumulator has small flow from return line RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test 6/20/93 Resulting Non-Compliance Items: none Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? yes Kill Sheet Current? },es Distribution: orig - Well File c - Oper./Rig c - Database c -Trip Rpt File c -Inspector AOGCC REP Louis R. Grimaldi OPERATOR REP: IBMGFXAA.XLS (Rev. 12/92) MEMORANDUM ALASKA OIL AND GAS CONSERVATION COMMISSION STATE OF ALASKA to: David W Joh ,~t~n Chairman thru: Blair E Wondzell Sr Petr Engineer from: t~t~o~n Spaulding Petr Inspector date: April7, 1993 file: 032593. doc subject: BOP test-_ ~D~,~_~ ARCO PB~l~well 3-25k_~"' PTD 93-2~.~_._~-"'~ · ~ Thursday, March 25, 1993: I witnessed.the BOP test on Doyon Rig 16tARCO PBU well 3-25. The kill line HCR valve leaked internally and was replaced with a manual valve. The accumulator system had three minor internal leaks on the Koomey closing system (kill, choke, lower pipe rams). Doyon Rig 16 was doing a workover and was in the final stages of completing this well. These leaks were not considered to be critical to the system. Doyon Rig 16 was allowed to proceed with. repairs to be made before starting on the next well. The rig was quite clean with good access on 3 sides. Summary: I witnessed the BOP test on Doyon Rig 16, 6 hr test with 4 failures. Attachment ~'RRY-SUN DRZLLZNG SERV'rCES~-'''' ~" ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/A-39 . NORTH SLOPE CONPUTATZON DATE' 6/30/9 / TRUE SUB-SEA COURS COURSE MEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON DEPTH DEPTH DEPTH DG MN DEGREES DATE OF SURVEY: 062693 MWD SURVEY JOB NUMBER: AK-MW-30038 KELLY BUSHZNG ELEV. = 81.50 OPERATOR: BP EXPLORATZON FT. D DG/ LS TOTAL RECTANGULAR COORDZNATES 100 NORTH/SOUTH EAST/WEST .VERT. SECT. 0 .00 -81.50 0 0 N .00 E 218 218.00 136.50 0 24 N 52.90 E 308' 307.99 226.49 0 42 N 67,00 E 399 398.98 317.48 1 0 N 53.50 E 489 488.97 407.47 1 0 N 71.90 E .00 .OON .OOE .00 .18 .46N ,61E -.41 .36 .86N 1.36E -.99 .39 1.55N 2.51E -1.83 .36 2.26N 3.89E -2.88 579 578.96 497.46 1 0 S 77,50 E 669 668.93 587.43 I 30 S 60.80 E 7'59. 758.89 677.39 2 5 S 39,80 E 851 850,82 769.32 2 17 S 34,70 E 946 945.74 864.24 2 17 S 32,60 E .59 2.34N 5.40E .68 1.59N 7.20E .98 .258 9.28E .30 3.068 11.41E .09 6.238 13.53E -4.28 -6.22 -8.81 -11 ,77 -14.84 t042 1041.65 960,15 2 47 S 33,70 E 1138 1137.55 1056,05 2 24 S 32,20 E 1233 1232.48 1150,98 1 a7 S 25,80 E 1328 !327,45 1245.95 1 0 S 35,70 E 1424 1423,44 1341.94 0 42 S 55.70 E · 52 9.818 15.86E ,42 13.468 18.24E .68 16.49S 19.95E .88 18.508 21.08E .43 19.518 22.05E -18,26 -21 ,74 -24.39 -26, 14 -27,40 1518 1517.43 1435.93 0 42 S 87.00 E 1614 !613.42 1531.92 1 23 S 89.70 E 1708 1707.39 t625.89 1 23 S 79.30 E 1804 1803,36 1721.86 1 23 N 88.10 E 1900 1899.33 1817.83 1 12 N 84.00 E ,40 19,878 23,10E ,73 19,908 24,86E ,27 20,128 27,13E ,32 20,308 29,46E ,23 20.168 31,63E -28.51 -30.17 -32.39 -34.63 -36.62 1996 1995.31 1913,81 1 23 N 81,20 E 2092 2091.27 2009,77 1 42 S 89,00 E 2186 2185.23 2103,73 I 42 S 81,20 E 2281 2280.19 2198,69 1 47 S 58.90 E 2376 2375,13 2293,63 2 5 S 61,00 E .22 19.878 33.79E ,42 19.728 36.37E .25 19.968 39.14E ..72 20.948 41.81E .33 22.568 44.61E -38.55 -40.93 -43.61 -46.46 -49,64 2472 2471.07 2389,57 2 5 S 53.50 E 2568 2567.01 2485,51 1 42 S 51,70 E 2662 2660.97 2579,47 i 47 S 42,90 E 2758 2756,93 2675.43 1 30 S 36,80 E 2853 2851,89 2770,39 1 42 S 28,70 E · 29 24.468 47.57E .42 26.388 50.10E .30 28.338 52.20E .36 30,448 53.98E .32 32.678 55.40E -53.07 -56.11 -58.75 -61.14 -63.24 2949 2947.84 2866.34 2 5 S 25,20 E 2987 2985.82 2904.32 2 0 S 18,10 E 3178 3176.69 3095,19 2 5 S 26,80 E 3274 3272.62 3191.12 2 17 S 29,20 E 3369 3367,58 3286,08 ' 1 0 S 8,10 E .43 35.51S 56.83E .72 36.77S 57.33E .17 43.06S 59.95E .23 46.328 61.68E 1.49 48.808 62.73E -65.56 -66.46 -71.08 -73.82 -75.65 Date_ RECEIVED A U 6 2 6 t993. Alaska Oil & Gas Cons, f,;or lmis io;' Anchorage /"'~'RRY-SUN DRTLLTNG SERV~'OES*-'' ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRZLLZNG PBU/A-39 500292234400 NORTH SLOPE COMPUTATZON DATE: 6/30/93 TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH COURS COURSE D ZNCLN DZRECTZON DG MN DEGREES DG/ DATE OF SURVEY: 062693 MWD SURVEY JOB NUMBER: AK-MW-30038 KELLY BUSHZNG ELEV. = 81.50 OPERATOR: BP EXPLORATZON FT. LS TOTAL RECTANGULAR COORDZNATES 100 NORTH/SOUTH EAST/WEST .VERT. SECT. 3463 3461,49 3379,99 3558 3556,15 3474.65 3654- 3651.57 3570,07 3750 3746,67 3665,17 3844 3839,40 3757.90 4 11 N 81.40 W 5 30 N 75.80 W 7 0 N 82.10 W 8 36 N 78.90 W 10 11 N 77.50 W 4,88 49,10S 59.44E 1,45 47,46S 51,58E 1,72 45,53S 41,33E 1,73 43.34S 28,49E 1,72 40.19S 13,47E -72.66 -64.73 -54,43 -41 .62 -26.43 3940 3933,79 3852,29 4035 4026,9'1 3945,41 4129. 4118,53 4037,03 4225 4211,35 4129,85 4319 4301.47 4219.97 10 48 N 71.40 W 12 0 N 66,80 W 13 48 N 65,10 W 15 41 N 71,20 W 17 17 N 72.10 W 1,32 35,48S 3.35W 1.58 28,75S 20.87W 1.96 20,18S 40,02W 2,55 11,17S 62.70~' 1.72 2.78S 88.04W -9.01 9.75 $0.68 55,07 81 .75 4415 4393,03 4311,53 4510 4483,40 4401,90 4604 4572.19 4490.69 4700 4662.28 4580,78 4795 4751,44 4669.94 17 42 N 71.00 W .54 18 12 N 71.90 W .60 20 6 N 70.70 W 2.06 20 17 N 71.40 W .33 20 6 N 70.90 W .28 6.36N 115,42W I10,61 15,67N 143,18W 139,88 25.57N 172.37W 170,70 36.33N 203.73W 203.84 46,93N 234,77W 236,64 4891 4841,68 4760,18 4987 4932,15 4850,65 5081 5020,58 4939,08 5177 5110,56 5029,06 5272 5~99,46 5117,96 19 47 N 69,40 W .62 19 17 N 69,10 W ,53 20 17 N 69,30 W 1.07 20 30 N 68,40 W ,39 20 47 N 69,40 W .49 58.05N 265.58W 269.39 69.43N 295.62W 301.51 80.73N 325.38W 333.35 92.81N 356.59W 366.80 i04.87N 387.85W 400.30 5367 5288.33 5206.83 5463 5378,25 5296,75 5558 5467.32 5385.82 5654 5557.30 5475.80 5750 5647.19 5565.69 20 36 N 69.10 W .24 20 23 N 68.60 W .28 20 17 N 69.60 W .38 20 30 N 70.00 W .25 20 36 N 69.30 W .'28 116,76N 419,25W 433.88 128,89N 450,60W 467,49 140,68N 481.47W 500,52 152,23N 512,87W 533,98 163.95N 544.46W 567,68 5845 5736.20 5654.70 5940 5825.44 5743.94 5990 5872.54 5791.04 6099 5975.51 5894.01 6194 6065.34 5983.84 20 17 N 69,30 W ,32 19 47 N 70,00 W .58 19 23 N 68,20 W 1.45 18 53 N 69,80 W ,67 19 6 N 70,50 W .32 175.68N 575.51W 600.87 187.01N 606.05W 633.44 192.99N 621.72W 650.21 205.81N 655.09W 685.95 216.31N 684.18W 716.88 6291 6156,94 6075.44 6389 6249.41 6167,91 6481 6336,13 6254,63 6576 6425,57 6344,07 6672 6515,83 6434,33 19 17 N 70,30 W .22 19 23 N 70.10 W ,12 19 36 N 70,20 W .22 19 47 N 69,80 W .25 20 0 N 69,10 W ,32 227.01N 714.23W 748.78 238,01N 744.79W 781.25 248.44N 773.67W 811.96 259,39N 803.76W 843,99 270,86N 834.36W 876,66 RECEIVED AUG 2 6 t99b Alaska Oil & Gas Cons. Anchorage ~ERRY-SUN DRZLLTNG SERVZCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRTLLTNG PBU/A-39 500292234400 NORTH SLOPE COMPUTATTON DATE: 6/30 /93 DATE OF SURVEY: 062693 MWD SURVEY JOB NUMBER: AK-MW-30038 KELLY BUSHZNG ELEV, = 81,50 FT. OPERATOR: BP EXPLORATZON TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON RECTANGULAR COORDZNATES VERT, DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST 'SECT, 6768 6606.02 6524.52 20 6 N 68.90 W .13 282.66N 865.09W 909.57 6862 6694.35 6612.85 19 53 N 68.40 W .28 294.36N 895.03W 941.71 6958. 6784,64 6703.14 19 47 N 68.40 W .11 306,36N 925,34W 974,30 7054 6874,97 6793.47 19 47 N 68,40 W ,00 318,33N 955.57W 1006.80 7149 6964,35 6882.85 t9 47 N 69.40 W .36 329,92N 985,60W 1038,98 7245 7054,68 6973.18 19 47 N 69,40 W ,00 341,36N 1016,04W 1071,49 7339 7143.15 7061,65 19 42 N 68,20 W ,44 352,85N 1045,65W 1103,25 7433 7231,67 7!50,17 19 36 N 66,10 W ,76 365,12N 1074,77W 1134,82 7529 7322,19 7240,69 19 17 N 65.20 W ,44 378,29N 1103,90W 1166.69 7624 7411.88 7330.38 19 12 N 63,60 W ,56 391.83N 1132,14W 1197,86 7720 7502.65 7421,15 18 47 N 62,40 W ,58 406,01N 1159,99W 1228.88 7805 7583.00 7501,50 19 17 N 62.10 W ,60 418,93N 1184.54W 1256,38 7900 7672,71 7591.21 19 6 N 63,30 W ,47 433,26N 1212,30W 1287,37 8037 7801,69 7720.19 20 17 N 66,10 W 1.11 452,96N 1254,05W 1333,34 8133 7891,69 7810.19 20 23 N 64,70 W .52 466.86N 1284.40W 1366.62 8228 7980,65 7899,15 20 42 N 67,20 W ,98 480.44N 1314,85W 1399,87 8324 8070,36 7988.86 21 0 N 68,70 W ,64 493,26N 1346,52W 1434,02 8415 8155.32 8073,82 21 0 N 71,70 W 1,18 504,30N 1377,19W 1466.62 8509 8242.99 8161,49 21 17 N 76,30 W 1,79 513,64N 1409,77W 1500.42 8603 8330.59 8249,09 21 12 N 73,00 W 1,28 522,65N 1442.61W 1534.36 8728 8447,21 8365,71 21 0 N 70,90 W ,63 536,59N 1485,39W 1579.33 8822 .8534.97 8453,47 21 0 N 70.00 W ,34 547,86N 1517,13W 1613.01 8918 8624,68 8543,18 20 42 N 68,20 W ,74 560,04N 1549.05W 1647,17 8996 8697,72 8616,22 20 23 N 62.10 W 2,.77 571,52N 1573,86~ 1674,42 9048 8746,46 8664.96 20 23 N 62,10 W ,04 580,00N 1589.88~ 1692.37 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZMENSZON MZNZHUM CURVATURE METHOD. HORZZONTAL DZSPLACEMENT = 1692,37 FEET AT NORTH 69 DEG. 57 MTN, WEST AT MD = 9048 VERTZCAL SECTZON RELATZVE TO WELL HEAD VERTZCAL SECTZON COMPUTED ALONG 290,04 DEG. A U G 2 6 Alaska Oil & Gas Cons. Commiss~o,'~ Anchorage RRY-SUN DRILLING SERVICES~'-% ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/A-39 500292234400 NORTH SLOPE COMPUTATION DATE: 6/30 /93 DATE OF SURVEY: 062693 JOB NUMBER: AK-MW-30038 KELLY BUSHING ELEV. = 81.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-T DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFEREN VD VERTICAL CE CORRECTION O' .00 -81,50 .00 N .00 E .00 1000 999.70 918.20 8.10 S 14.73 E .30 2000 1999.31 1917.81 19.86 S 33.89 E .69 3000 2998.81 2917.31 37.20 S 57.47 E 1.19 4000 3992.68 3911.18 31.62 S 14.18 W 7.32 ,30 ,39 ,50 6.13 5000. 4944,41 4862,91 70,96 N 299,63 W 55,59 6000 5881,98 5800,48 194,23 N 624,80 W 118,02 7000 6824.16 6742,66 311,60 N 938,57 W 175.84 8000 7766,98 7685.48 447,76 N 1242.31 W 233,02 9000 8701,47 8619,97 572,18 N 1575,10 W 298.53 48.26 62.44 57.82 57.18 65.52 9048 8746,46 8664,96 580,00 N 1589,88 W 301,54 3.01 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, RECEIVE[) AU G 2 6 199 Alaska Oil & Gas Cons. Anchorage ~,RRY-SUN DRILLING SERVICES'~-''' ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/A-39 500292234400 NORTH SLOPE COMPUTATION DATE: 6/30/93 DATE OF SURVEY: 062693 JOB NUMBER: AK-MW-30038 KELLY BUSHING ELEV, = 81,50 FT, OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION O. ,00 81 81.50 181 181.50 281 281,50 381 381,50 -81,50 ,00 N ,00 E ,00 ,00 ,00 N ,00 E ,00 .00 100,00 ,31 N .40 E ,00 ,00 200,00 .74 N 1 07 E ,01 ,00 300,00 1,37 N 2,27 E ,02 ,01 481 481.50 581 581 ,50 681 681,5O 781 781 .50 881 881,5O 400,00 2,22 N 3,77 E 500.00 2.33 N 5.45 E 600,00 1,43 N 7.49 E 700,00 ,88 S 9,81 E 800,00 4,07 S 12,11 E ,03 ,01 ,05 ,02 .07 ,03 . 13 .06 .21 ,08 981 981,50 1081 1081,50 1181 1181,50 1282 1281,50 1382 138t,50 900,00 7.45 S 14,30 E 1000,00 11,42 S 16.94 E 1100,00 15,01 S 19,21 E 1200,00 17,S4 S 20,61 E 1300,00 19,22 S 21,63 E .29 ,08 ,40 ,11 ,49 ,09 .54 ,05 ,56 ,01 1482 1481,50 1582 1581,50 1682 1681,50 1782 1781,50 1882 1881,50 1400.00 19,84 S 22,66 E 1500,00 19,90 S 24,08 E 1600,00 20,01 S 26,51 E 1700,00 20,32 S 28,93 E 1800,00 20,20 S 31,26 E ,56 ,01 ,57 ,01 ,60 ,O3 ,63 ,03 ,66 ,O3 1982 1981,50 2082 2081.50 2182 2181,50 2282 2281,50 2382 2381.50 1900,00 19,92 S 33,46 E ,69 ,03 2000,00 19,71 S 36..08 E .72 .04 2100.00 19,94 S 39,04 E ,77 ,04 2200.00 20,96 S 41.85 E ,81 .05 2300,00 22,67 S 44.82 E .87 .06 2482 2481,50 2582 2581,50 2682 2681.50 2782 2781,50 2882 2881,50 2400,00 24,68 S 47.87 E 2500,00 26,65 S 50,44 E 2600,00 28.80 S 52,64 E 2700,00 30.96 S 54,36 E 2800,00 33,44 S 55,82 E ,94 ,07 ,99 .O5 1 .04 ,05 1 ,08 ,04 1, t2 ,04 2982 2981,50 3082 3081,50 3182 3181,50 3282 3281,50 3382 3381.50 2900,00 36,63 S 3000.00 39,95 S 3100,00 43,22 S 3200.00 46,63 S 3300,00 49.01 S 57,29 E I , 18 58,39 E 1 , 24 60,03 E 1.31 61,85 E 1.38 .O6 ,06 .07 ,07 ,04 A U G 2 6 199 Alaska Oil & Gas Cons. Commissior, Anchorage ~'RRY-SUN DRZLLING SERV~'CES~'x ANCHORAGE ALASKA PAGE PRUDHOE BAY DRTLLTNG PBU/A-39 500292234400 NORTH SLOPE COMPUTATTON DATE: 6/30 /93 DATE OF SURVEY' 062693 JOB NUNIBER' AK-NIW-30038 KELLY BUSHTNG ELEV, = 81 .50 OPERATOR' BP EXPLORATTON FT, TNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE NEASD VERTZCAL DEPTH DEPTH SUB-SEA TOTAL VERTZCAL RECTANGULAR COORDZNATES ND-TVD VERTZCAL DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE CORRECTZON 3483' 3481,50 3583 3581.50 3684 3681,50 3785 3781.50 3886 3881,50 3400,00 48,88 S 57,98 E 1,56 ,14 3500.00 46.86 S 49,22 E 1.97 .41 3600,00 45,02 S 3?,69 E 2,66 ,69 3700.00 42,32 S 23,30 E 3,73 1.07 3800,00 38,49 S 6.06 E 5.28 1.55 3988. 3981,50 4090 4081,50 4193 4181,50 4298 4281,50 4402 4381,50 3900.00 32.46 S 12,06 W 7.09 1,81 4000,00 23,99 S 31,79 W 9,38 2.29 4100.00 13.88 S 54.76 W 12.49 3.1'1 4200.00 4,69 S 82,12 W 16.58 4.09 4300,00 5,16 N 111.94 W 21.40 4.82 4507 4481,50 4613 4581,50 4720 4681,50 4827 4781,50 4933 4881,50 4400,00 15,48 N 142,58 W 26,50 5,10 4500,00 26,69 N 175,59 W 32,41 5,92 4600,00 38,60 N 210,46 W 38.99 6,57 4700.00 50,53 N 245,16 W 45,51 6.52 4800,00 63,09 N 278,99 W 51,82 6,31 5039 4981,50 5145 5081,50 5252 5181,50 5359 5281,50 5466 5381,50 4900,00 75,63 N 311,87 W 57,83 6.01 5000,00 88,81 N 346.49 W 64.47 6,64 5100,00 102,47 N 381,46 W 71,29 6,82 5200,00 115,85 N 416,85 W 78,21 6,92 5300,00 129,33 N 451,73 W 84.97 6,76 5573 5481,50 5679 5581,50 5?86 5681,50 5893 5781.50 5999 5881,50 5400,00 142,51 N 486,38 W 91,62 6,65 5500,00 155,33 N 521,37 W 98,34 6.72 5600,00 168.51 N 556,52 W 105,15 6.81 5700,00 181,57 N 591,15 W 111.78 6.63 5800,00 194,16 N 624,65 W 117.99 6,21 6105 5981,50 6211 6081,50 6317 6181,50 6423 6281,50 6529 6381.50 5900.00 206,52 N 657.02 W 123.83 5.83 6000,00 218,18 N 689,46 W 129,61 5,78 6100,00 229.91 N 722.33 W 135.52 5.92 6200,00 241,86 N ?55,42 W 141,53 6.01 6300,00 253,93 N 788,89 W 147.67 6.14 6635 6481,50 6741 6581,50 6848 6681,50 6954 6781,50 7060 6881.50 6400,00 266,41 N 822,69 W 153,96 6,29 6500,00 279,43 N 856,72 W 160,39 6.43 6600,00 292,65 N 890,71 W 166,84 6.44 6700,00 305,95 N 924,29 W 173.16 6,32 6800,00 319,20 N 957,76 W 179.44 6.28 RECEIVED AUG 2 6 t993 Alaska Oil & Gas Cons. budl'lniSS~C,~ J~rldhnr~n~ ~,RRY-SUN DRZLLZNG SERVTCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/A-39 500292234400 NORTH SLOPE COMPUTATZON DATE: 6/30 /93 DATE OF SURVEY: 062693 JOB NUMBER: AK-MW-30038 KELLY BUSHZNG ELEV. = 81.50 OPERATOR: BP EXPLORATZON TNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH T MEASD VERTT DEPTH DE RUE SUB-SEA TOTAL CAL VERTZCAL RECTANGULAR COORDZNATES MD-TVD VERTZCAL PTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE CORRECTZON 7167. 6981 7273 7081 7379 7181 7485 728t 7591 7381 .50 6900,00 332,09 N 991,37 W 185.73 6,28 ,50 7000,00 344,76 N 1025,07 W 192.01 6,28 ,50 7100,00 357.95 N 1058,40 W 198,24 6,23 ,50 7200,00 372,32 N 1090,95 W 204,38 6,14 ,50 7300,00 387,12 N 1122,66 W 210,33 5,95 7697 7481 7803 7581 79O9 7681 8015 7781 8122 7881 · 50 7400.00 402,67 N 1153,61 W 216.16 5.83 .50 7500.00 418.68 N 1184.08 W 221.92 5.76 .50 7600.00 434,63 N 1215.02 W 227.80 5.89 .50 7700.00 449.93 N 1247.22 W 233.98 6.18 .50 7800.00 465.24 N 1280.98 W 240.62 6.65 8228 7981 8335 8081 8443 8181 8550 828t 8657 8381 .50 7900.00 480.56 N 1315.t5 W 247.41 6.79 .50 8000.00 494.81 N I350.50 W 254.43 7.02 .50 8100.00 507.46 N 1386.73 W 261.54 7.11 .50 8200.00 517.23 N 1424.34 W 268.84 7.29 .50 8300.00 528.42 N 1461.49 W 276.10 7,26 8764 8481 8871 8581 8978 8681 9048 8746 .50 8400.00 540.90 N 1497.82 W 283.23 7.13 .50 8500.00 554.02 N 1533.86 W 290.33 7.10 .50 8600.00 568.70 N 1568.53 W 297.19 6.87 .46 8664.96 580.01 N 1589,88 W 301.54 4.35 THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN THE NEAREST 20 FOOT HD (FROM NZNZNUM CURVATURE) POZNTS FT. RECEIVED AU G 2 6 199 Alaska 0it & Gas OOtlS. Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/13/93 T# 84761 BPX/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-40%~'%~ SBA 07/09/93 #1 SBL 07/07/93 #1 S-23 ~'\~% PERF 07/09/93 #1 X-13A ~% SBA 07/06/93 #1 X-13A %~' PERF 07/07/93 #1 Z-06~,%~'~ PRODUCTION LOG 06/07/93 #1 Information Control Well Records 8900.00- 9496.00 ATLAS 5 " 9720.00-10189.00 ATLAS 5 " 10850.00-11130.00 ATLAS 5 " 10220.00-10716.00 ATLAS 5 " 7800.00-10650.00 ATLAS 5 " 9850.00-10350.00 ATLAS 5 " oc/ or ;Sd Cororo/Ssioo ' BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/14/93 T# 84764 BPX/PBUQMAGNETIC TAPE W/LISTING Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-39 BHC 06/29/93 #1 8453.50- 9597.00 SCH Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/14/93 T# 84765 BPX/PBU C~~OGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-39 (PERF~ ~'O~ 06/10/93 #1 N-17~'~% CCL 07/11/93 #1 X-14A PRODUCTION LOG 07/10/93 #1 9150.00- 9400.00 ATLAS 5 " 8890.00- 9130.00 ATLAS 5 " 9345.00-11950.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BPX/PBU~OGS DATE: 07/06/93 T# 84736 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-39 DIL PHASOR 06/29/93 #1 9027.00- 9574.00 SCH A-39 BHC 06/29/93 ~1 9027.00- 9543.00 SCH A-39 CNL 06/29/93 %1 9027.00- 9525.00 SCH 2/5" 2/5" 2/5" Information Control Well Records RECEIVED dUL 7 £ 1993 Alaska 0il & Gas Cons, Cor~mJf~Sion Anchorage OPERATION: Drlg: Workover: convair, d, ' , No. Operator:. ~~~ . ' ...... Well Name: .~-~ . Casing Size: Set ~) .... Feet Test: Initial Weekly '~"' Other STAT.=. OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Te.t MISC. INSPECTIONS: FLOOR ~U:ETY VALV-r~: Quan. Prep~ure P/F Loc(don Gen.: ~ ~_ Well Sign ~ Upper Kelly Housekeeping: ~ "(Gen) DrLRig G~ LowerKelly / !~ Resenm Pit ~-E_ ' Ball Type / I ~-~"~/-~ Test BOP STACK: Qua. Pressure P/F . CHOKE MANIFOLD: .. Ann. Preventer /- '/ -7~ No. Valves Ptpe Rams ,J., No. Flgnges Blind Rams Manual Chokes / Chk/Ln Valves Hydraulic Chokes · ~ HCR Valve~- ~- ~'~,_ Kill Line Valves ACCUMULATOR SYSTEM: Pr~sure After Closure ~///~ , MUD SYSTEM: Light Alarm 200 p,i Attained After Closure minutes Trip Tank ~_..~ V~,~ 6ystem Pressure Alhdn~ ~/" minutes c~ ~ Pit Level lnd*~ators ~ 'v~: BandSwachCovem: Meslm~, ~ Remote: flow Indicator ~._S ~,~ ~_~4~ I~gn. Bits: '~ ~) . i u i L I i I I I I I I I I . · .... - (- - .- - ... -....~ ........... - - -- . ~.~?.:....::::~&~.: :.-. :C-.~...~? - ~... :"Y: -:'*C:.':-:*'.-:'~::. ~-:**~C*::.*~;~':*.~'~::*:*:...'?:~.~:.<:.:.:.:::¥:.y..* .~.:.'? .~.~.ac~ku, am~ ~.:.~: ..... . .. ........................ ,r"H ..... ,,,', ......... :'*t*' ~** u ..... ~ .......... m'*T ...... ,' vu' * ,~~*'T**" _ , Number of Failures .. ~. ... Test T~me d.. Houm Number of valves tested ~ Repair or Replacement of Fmlad Equipment shall be made within ~ -- . days.Notify the Inspector on duty and follow with Wrilten or Faxed vedlicetion to the AOGCC Commission Office al:' F.x No, 27&.7~42 Inspegtor North Sfope Pager No. If your cell is not retumad by the inspector within 12 hours please contact the P. I. Supervisor .t 27~-1433 I II ·1 · I I II I I II REMARKS: Dis~bution: od~-Well Fife c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WlTNE~_~REQUIRED? YES , ~.--'~'... NO .. ~4 HOUR NOTICE GIVEN ii i i i i Waived By:. FI-021L.XLT Rev. 1/93 ALASKA OIL AND GAS CONSERVATION COMMISSION February 23, 1993 Karen Thomas Drilling Engineer Supervisor BP Exploration P O Box 196612 Anchorage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Prudhoe Bay Unit A-39 BP Exploration Permit No: 93-28 Sur. Loc. 1482'SNL, 920'WEL, Sec. 35, TllN, R13E, UM Btmhole Loc. 804'SNL, 2669'WEL, Sec. 35, TllN, R13E, UM Dear Ms. Thomas: 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 drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ printed on recycled paper b y C · i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 i"a. Type of work Drill [] RedriilFlJlb. Type of well. Exploratoryl-i Strut/graphic TestFI Development Oill~ Re-Entry [] Deepen,.FIJ Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum ElevatiOn (DF or KB) 10. Field and Pool ..BP Exploration. KBE = 47'feet Prudhoe Bay Fieid/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28286 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 20 ^AC 25.025) 1482' SNL, 920' WEL, SEC. 35, T11N, R13E Prudhoe Ba,v Unit At top of productive interval 8. Well number Number 850' SNL, 2550' WEL, SEC. 35, T11N, R13E A-39 (31-35-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 804' SNL, 2669' WEL, SEC. 35, T11N, R13E 2/25/93 $200,000.00 i"'2. Distance to nearest 13. Distance to nearest well 4. Number of acres in propertyi15. Proposed depth (MD and'rV0) property line ADL 28287-2609'feet A-9-27' @ 3050' MD feet 2560 9566' MD/9230' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (s~ 20 ,~c 25.035 (e)(2)) Kickoff depth 38~ofeet Maximum hole angle 2~ o Maximum surface 3330psig At total depth (TVD) ~¢OO'/z~9Opslg 18. Casing program Setting Depth . s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 110' 110' 11 yds Arcticset .... 13-1/2" 10-3/4" 45.5# J-55 BTC 3019' 31'I 31' 3050' 3050' 970sxCSIiJ/355sx"G"/250sxCSII 9-7/8" 7-5/8" 29.7# VT95H~ NSCC 8899' 30' 30' 9029' 8729' 265 sx Class "G" 6-3/4" 5-1/2" 17# 13CR80 NSCC 687' 8879' 8589' 9566' 9230' 115 sx Class "G' .... 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 I Structural Surface Intermediate Production ~--, i.,., ...... r; -~ ,,,~,~:~ Liner - Alaska 0ii & ~''' ..... " ~ "-'i Perforation depth: measured true vertical A,:~,hu, 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 hereb ced, i/f)/ that the foregoing is true and correct to the best of my knowledge Signed~42,~,_,~ ~ ~ ~ Title Dr#ling Engineer Supervisor Date~.'//' ..Z'- Commission Use Only --/ -/ '-- Permit Number ]APl number IApp.r_~v~ date ISee cover letter ~_~- 2. ¢' 15 o- o 2. ~-- ~ .2_. Z',¢'-/, ,~' ,,~. ~_.. ~ '~ Ifor other requirements Conditions of approval Samples required [] Yes 1~ No Mud long reqL~ired [] ~es J~! No Hydrogen sulfide measures [] Yes [] No Directional survey required ,1~ Yes [] No Required working pressure for BOPE FI2M; 1-13M; J~5M; 1'-!10M; 1-]15M; Other: Origins[ ~,qned By by order of Approved by David W..Ohnsto" Commissioner ,ne comm,ssion Date~' Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: LOCATIC)N: A-39 Surface: Target: T.D.: [31-35-11-13] PBU 1482' FNL 920' FEL S35 T11N R13E 850' FNL 2550' FEL S35 T11N R13E 804' FNL 2669' FEL S35 T11N R13E ESTIMATED START: Feb 25, 1993 OPR. DAYS TO COMPLETE: 17(13 days drilling, 4 days completion) Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 21.0/N68.8W/3810'/2.0/1877' Estimated Ground level elevation is 47.0' AMSL. KB to ground level elevation is 32.5'. Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR I 1 0 110 8.5 10-3/4" SHOE 3050 3050 9.1 TOP UGNU SANDS 421 9 4220 9.9 SEABEE 5979 6084 9.9 IKRU/LCU 7859 8097 10.0 7-5/8" SHOE 8729 9029 SAG RIVER SANDSTONE 8729 9029 8.8 - 9.0 SHUBLIK 8754 9056 8.8- 9.0 TOP SADLEROCHIT 8821 91 28 8.8- 9.0 T~ 8896 9208 8.8-9.0 TOTAL DEPTH 9230 9566 8.8 - 9.0 CASING PROGRAM: Hole Csg Wt Grade /~ Conn Lenath TgD 30" 20" 91.5# H-40~. WELD 80 32 13-1/2" 10-3/4" 45.5# J-55~'// BTC ~' 3019 31 9-7/8" 7-5/8" 29.7# NT95HS/ / NSCC , 8899 30 6-3/4" 5- 1/2" 1 7# 13Cr-80 N930 687 8879 Btm 110 3050 9029 9566 COMPLETION: Tubing: GLMs: Packer: 4- 1/2" 12.6# 13Cr-80 NSCT 8800 2 9 8829 4-1/2" x 1" - est 6 required, all dummies except RP shear in shallowest GLM Permanent -latched. 7-5/8" x 4-1/2" set at 8829' or +/- 50' above TOL LOC_~ING P~R/~: Open Hole- Cased Hole 9-7/8" Hole: Possible RFT in Cretaceous. 6-3/4" Hole: DIL/BHCS/CNL/GR/SP. LDT optional. No cased hole logs R E C E IV E D PROPOSED DRILLING AND COMPLETION A-39 Procedure PROGRAM I , . . . . . . . . 10. 12. MIRU drilling rig. N/U diverter and function test same. Drill 13 1/2" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 9 7/8" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. Drill intermediate hole to intermediate casing point. Run E-line logs if required. MU and run 7-5/8 casing string and cement as per well plan. Bump cementing plug with mud. RIH and drill 6-3/4" hole through reservoir to TD. RU and run E-line logs. MU 5 1/2" liner on 3 1/2" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. MU casing scraper & clean out 5 1/2" liner. Run 4-1/2", 13Cr-80 tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 3500 psi. NU tree and test to 5000 psi. Release drilling rig. o Anticipated BHP: ° Maximum Anticipated Surface Pressure: o Planned Completion Fluid: 3600 psi @ 8742' TVD SS 2726 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. No potential hazardous levels of H2S are anticipated in this well. do There is 1 close approach requiring shut-in. Note well proximities on close approach sheets. A gyro will be required. R ECEIV'ED Cons. l-~nchor;-]ge MUD PROGRAM: Well A-39 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOI. E Surface: Casina Point: -- . Mud Weight: ppg 8.5 - 9.5 8.5 - 9.1 Funnel Viscosity sec/qt ~300 < 1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 9- 10 9 - 10 APl Fluid loss mi/30 min 1 5- 2 5 1 5- 2 5 Hardness mg/I < 200 <200 MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg 9.0- 9.8 (To to the LCU) 10.0 to Casing Point Yield Point Ibs/100ft2 10 - 15 10secGel Ibs/100ft2 5 - 10 10 min Gel Ibs/100ft2 10 - 20 APl Fluid Loss mi/30 min <15 pH -- 9.5 - 10.0 Hardness m g/I NC-no control MUD SPECIFICATIONS-PRODUCTION INTERVAt.· Non damaging polymer system. Mud Weight ppg 8.8- 9.0 Yield Point lbs/1 00ft2 1 0- 2 0 10 sec Gel Ibs/100ft2 2- 6 10 min Gel Ibs/100ft2 10-20 APl Fluid loss mi/30 min 4.0-5.0 pH 9.O-9.5 Hardness m g/I t r < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at < 3500 ppm chlorides. Over Balance in the Production H~le Design Mud Wt. (6-3/4" Hole): 9.0 ppg. Formation pressure at top Sag River: Formation pressure at Sadlerochit: 3500 psi. (Maximum) 3600 psi at 8742' TVDSS. Over Balance Sag River: 550 psi Over Balance Top Sadlerochit: 490 psi. Current GOC: At top Sad. For more detailed information refer to the Prudhoe Bay Drilling Mud Policy that resides in DRILLING VOLUME #1(file server) under the MUD POLICY folder. 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" CIRC. TEMP 38°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: ColdSet III ADDITIVES: retarder WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx APPROX #SACKS: 970 THICKENING TIME: 4:30 hrs MIX WATER: 10.5 gps TAIL CEMENT TYPE: Class G. ADDITIVES: 2% A-7, CaCI, I ghs FP-6L. WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx APPROX #SACKS: 355 THICKENING TIME: 4 hrs MIX WATER: 4.95 gps TOP JOB CEMENT TYPE: Coldset II ADDITIVES: Retarder WEIGHT: 14.9 ppg YIELD: 0.96 cu ft/sk. APPROX NO SACKS: 250 CENTRALIZER PLACEMENT 1. Run one (1) bow type centralizer per joint for the first 20 joints. 2. Place centralizers in the middle of each joint with a stop collar. CEMENT VOLUME 1. Lead slurry to surface with 100% excess. 2. Tail slurry volume is 500' MD with 100% excess 3. Top job volume is 250 sx. MIX WATER: 3.89 gal/sk 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ SERVICES CIRC. TEMP: 140° F SPACER: 50 bbls Arco preflush+1% S-400, weighted I ppg above current mud weight. TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% F L-52 +0.5%C D-32+ 1%A-2+ 1GHS thickening time WEIGHT: 15.8ppg YIELD: 1.15ft3/sx APPROX #SACKS: 265 THICKENING TIME: 3-4 hrs FP-6L for 3-4 hrs MIX WATER: 5.0 gps CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. Batch mix tail cement - perform fluid loss test. Fluid loss should be 40 cc or less. CEMENT VOLUME: 1. Tail G slurry to 1000' md above casing point with 30% excess. 2. 80' md 7-5/8", 29.7# capacity for float joints. NOTE: No hydrocarbon bearing zones are identified in the Cretaceous interval in this area. AlasI~a Oi~ & Gas 6o;'~s, a,.;,~.~x~issi~ 5-1/2" PRODUCTION LINER CEMENT PROGRAM- BJ SERVICES CIRC. TEMP 140° F BHST 226 deg F at 8800' TVDSS. SPACER: 50 bbls fresh water w/3 ppb ARCO preflush and 1% S-400. CEMENT TYPE: CLASS G ADDITIVES' 0.8%BA-10+0.6%FL-32+0.2%CD-30+0.3%A-2+0.35%R-1+1GHS 6L WEIGHT: 15.7 ppg YIELD:1.18 ft3/sx MIX WATER' 5.03 gps FP- APPROX #SACKS: 115 THICKENING TIME: 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 6-8 bpm. LINER CEMENT VOLUME: , . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar. 150' liner lap (6.750" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. A-39 Casing Design Specificatio SURFACE CASING 10-3/4", 45.5# J-55 BTC CASING ~"'"~ ..... BURST COLLAPSE J-55 3580 2090 PBYS (#) 715000 TJYS (#) 796000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. LOT (ppg) TVD (FT) SIPRESSURE 1 4 3050 2220 Burst S.F. 1.61 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3050 1507 Collapse S.F. 1.39 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 45.5 3050 PBYS Tension S.F. 6.03 Mud Wt. 9.5 ppg TJYS 6.71 String Wt. (#) 118625 .R :C !VE D A!aska Oil & r~.s Oo~s, Oofa~p~iss~of~ A~ch0raga A-39 Casing Design Specificatio Intermediate Casing 7-5/8", 29.7#,NT-95HS,NSCC Casing GRADE BURST COLLAPSE NT-95HS 8180 7150 PBYS (#) 811000 TJYS (#) 841000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 2620 Burst S.F. 3.12 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press I 0 8729 0.1 3666 Collapse S.F. 1.95 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 29.7 9029 PBYS Tension S.F. 3.58 Mud Wt. 10.0 TJYS 3.72 String Wt. (#) 226355 RECEIVED A-39 Casing Design Specificatio PRODUCTION LINER ..-' 5-1/2", 17#,L-80, 13Cr, NSCC Casing / GRADE BURST COLLAPSE L-80 6280 7740 PBYS (#) 397000 TJYS (#) 446000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.6 ppg fluid SlTP Fluid wt (ppg) 3500 9.6 Burst S.F. 1.66 back up (ppg) Burst Pressure 9.0 3775 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 9.6 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse Press 9.6 8800 0.1 3513 Collapse S.F. 2.20 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) Mud Wt. String Wt. (#) 1 7 687 9.6 9858 Tension S.F. PBYS TJYS 40.27 45.24 Prudhoe Bey DriLLing Prudhoe Bo y A PAD WELL', A-39 FiLe', A-39WP1 SNIZTHI O© VERTICAL VIEW SCALE 500 ?t. / DIVISION REFERENCE: WELL HEAD PERMAFROST HBRIZBNTAL VIEW (TRUE NnRTH) SCALE 800 Ft, / DIVISION REFERENCE: WELL HEAD 10-3/4' C~G START OF BUILD BUILD RATE~ 2,00 DEG/iO0 FT 1800 .L ~[]D, ~ 90~9 MD, 8789 TVD 1600 1400 1~00 tO00 800 600 400 ~00 800 "'--600 --400 '--~00 END OF BUILD CRITICAL PDINT DATA MD Inc Azl TIE IN 0 0,00 0,00 PERMAFROST 1879 0.00 0,00 10-3/4' CSG 3050 0.00 0.00 START DF BUILD 3810 0,00 0,00 END OF ]BUILD 4860 ~1.00891.19 SAG RIVER/CSG PI~OP981.00891,19 TARGET 9808 ~1,00891,19 OOWC 9416 ~1,00891.19 TOTAL DEPTH 9566 81,00891,19 TVD Nor'th Eost 0 0 0 1879 0 0 3050 0 0 3810 0 0 4836 69 -177 8789 609 -1571 8896 638 -1630 9090 659 -1700 9830 679 -1750 1685 1749 1883 SAG RIVER/C$G PT 7.685 OD, @ 9089 MD, 8729 TVD TARGET EIDWC TOTAL DEPTH I 2000 1877 I I 0 500 1000 1500 VERTICAL SECTION PLANE: 291.19° BHL DATA TVD 9830.04 VS 1876,88 678.58 East -1749.94 Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 291.19 deg. Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.16.02.88 N - Long, 148.45.03.58 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (fee0:5948965.29 N 654454.83 E Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD North Aligned To: TRUE NORTH Prudhoe Bay Drilling Prudhoe Bay A-PAD Well: A-39 File:A-~WP1 ,Page 1 Date: 2/2/93 Wellpath ID: A-39WP1. Last Revision: 2/2/93 Measured Incl DHft TVD Depth Dir. (ft) (deg.)(deg.) (ft) TIE IN 0.00 0.00 0.00 0.00 PERMAFROST 1879.00 0.00 0.00 1879.00 10-3/4" CSG 3050.00 0.00 0.00 3050.00 Subsea T O T A L Depth Rectangular Offsets (ft) (ft) (ft) -79.50 0.00 N 0.00 E 1799.50 0.00 N 0.00 E 2970.50 0.00 N 0.00 E START OF BUILD 3809.64 0.00 0.00 3809.64 3730.14 3909.64 2.00 291.19 3909.62 3830.12 4009.64 4.00 291.19 4009.48 3929.98 0.00 N 0.00 E 0.63 N 1.63W 2.52 N 6.5 lW 4109.64 6.00 291.19 4109.09 4029.59 5.67N 4209.64 8.00 291.19 4208.34 4128.84 10.08N UGNU 4220.41 8.22 291.19 4219.00 4139.50 10.63N 4309.64 10.00 291.19 4307.10 4227.60 15.73N 4409.64 12.00 291.19 4405.26 4325.76 22.63N 4509.64 14.00 291.19 4502.69 4423.19 30.76N 4609.64 16.00 291.19 4599.28 4519.78 40.12N 4709.64 18.00 291.19 4694.91 4615.41 50.69N 4809.64 20.00 291.19 4789.45 4709.95 62.46N 4836.29 5979.00 4756.79 5899.50 Geographi~oordinates Latitude ] Longitude 70.16.02.8848N148.45.03.5788W 70.16.02.8848N148.45.03.5788W 70.16.02.8848N148.45.03.5788W END OF BUILD 4859.64 21.00 291.19 SEABEE 6083.65 21.00 291.19 SAG RIVER/CSG PT 70.16.02.8848N148.45.03.5788W 70.16.02.8910N148.45.03.6262W 70.16.02.9096N148.45.03.7682W 14.63W 70.16.02.9406N148.45.04.0047W 25.99W 70.16.02.9839N148.45.04.3354W 27.41W 70.16.02.9893N148.45.04.3767W 40.58W 70.16.03.0395N148.45.04.7600W 58.37W 70.16.03.1074N148.45.05.2778W 79.34W 70.16.03.1874N148.45.05.8883W 103.47W 70.16.03.2794 N 148.45.06.5906W 130.73W 70.16.03.3833 N 148.45.07.3841W 161.08W 70.16.03.4991N 148.45.08.2676W 68.79N 177.41W 70.16.03.5613N148.45.08.7428W 227.36N 586.39W 70.16.05.1210N148.45.20.6476W GRID Coordinates Closure Northing Easting Dist. Dir. (ft) (ft) (ft) deg, 5948965.29 654454.83 5948965.29 654454.83 5948965.29 654454.83 5948965.29 654454.83 5948965.89 654453.19 5948967.68 654448.27 5948970.66 654440.09 5948974.84 654428.64 5948975.35 654427.21 5948980.19 654413.94 5948986.72 654396.01 5948994.42 654374.88 5949003.28 654350.56 5949013.29 654323.09 5949024.43 654292.51 5949030.42 654276.06 5949180.59 653863.93 o.oo~ o. oo o. oo~ o. oo o.oo~ o. oo o. oo~ o. oo 1.75~ 291.19 6.98~ 291.19 15.69~291.19 27.88~291.19 29.40~291.19 43.52~291.19 62.60~291.19 85.10~291.19 110.98~291.19 140.21~291.19 172.77~291.19 190.28(~291.19 628.92~291.19 Vertical Section (ft) 0.00 0.00 0.00 0.00 1.75 6.98 15.69 27.88 29.40 43.52 62.60 85.10 110.98 140.21 172.77 190.28 628.92 DLS (dg/lOOft) 0.00 0.00 0.00 0.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 Smith International, Inc. Proposal Report page 2 Date: 2/2/93 WeHpath ID: A-39WP1~ Measured Incl Drift TVD Subsea T O T A L Depth Dir. Depth Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) Geographic Coordinates Latitude / Longitude GRID Coordinates Closure Vertical DLS Northing Easting Dist Dir. Section (ft) (ft) (ft) deg. (ft) (dg/100ft) 9029.30 21.00 291.19 8729.00 8649.50 608.99N 1570.62W 70.16.08.8743N148.45.49.2980W 5949542.06 652872.17 1684.556291.19 1684.55 SHUBLIK 9056.08 21.00 291.19 8754.00 8674.50 612.46N 1579.57W 70.16.08.9084N148.45.49.5584W 5949545.35 652863.16 1694.15~291.19 1694.15 TSAD 9127.84 21.00 291.19 8821.00 8741.50 621.75N 1603.55W 70.16.08.9999N148.45.50.2565W 5949554.16 652838.99 1719.876291.19 1719.87 0.00 0.00 0.00 TARGET 9208.18 21.00 291.19 8896.00 8816.50 632.16N 1630.39W 70.16.09.1023N148.45.51.0379W 5949564.02 652811.95 1748.66~291.19 1748.66 9308.18 21.00 291.19 8989.36 8909.86 645.12N 1663.80W 70.16.09.2297N148.45.52.0105W 5949576.29 652778.28 1784.49~291.19 1784.49 933;}.50 21.00 291.19 9013.00 8933.50 648.40N 1672.26W 70.16.09.2619 N 148.45.52.2569W 5949579.40 652769.75 1793.576 291.19 1793.57 0.00 0.00 0.00 9408.18 21.00 291.19 9082.72 9003.22 658.07 N 1697.21W 70.16.09.3571N 148.45.52.9832W 5949588.57 652744.61 1820.33~ 291.19 1820.33 OOWC 9415.98 21.00 291.19 9090.00 9010.50 659.08N 1699.82W 70.16.09.3670N148.45.53.0591W 5949589.52 652741.98 1823.13~291.19 1823.13 Z2C 9427.76 21.00 291.19 9101.00 9021.50 660.61N 1703.76W 70.16.09.3821N 148.45.53.1737W 5949590.97 652738.02 1827.35~ 291.19 1827.35 0.00 0.00 0.00 TOTAL DEPTH 9565.98 21.00 291.19 9230.04 9150.54 678.52N 1749.94W 70.16.09.5582N148.45.54.5181W 5949607.93 652691.48 1876.88~291.19 1876.88 0.00 Prudhoe Bay Dr'i(Lin9 Prudhoe Sa y A-PAD WeLl', A-39 Fi e',A-39WP1 ISh THI lOC) TrCvel[ing Cylinder - Le(is¢ ]]is%once ReFerence WeU - A-29WP1 TV]]: 0 - 9230 Ft, InCervCL 50 ?t. Atl ]]irec%ions Rel %o True Nor%h 330°% 0° ¢'~ 30' 300° 60' 270° 240* 210' 150' 120° WeUp~%h 003 o04 005 006 007 008 a09 o10 o17 o18 o19 022 024 025 aa6 ~27 028 030 032 033 034 a34~ a35 A-37~P A-38~Pl A-4flWp CLOSEST POINTS A-01 A-02 A-03 A-04 A-05 A-OG A-07 A-08 A-09 A-10 A-11 A-X2 A-13 A-14 A-15 A-16 A-17 A-18 A-19 A-20 A-21 A-22 A-23 A-24 A-25 A-26 A-27 A-28 A-29 A-30 A-31 A-3P A-33 A-34 A-34A A-35 A-37 A-38 A-4O ])is%ance N/A N/A 56%03 171.53 402,60 65.72 212.00 114,32 27.10 122.86 237.55 317,68 464.69 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 156,33 N/A N/A N/A N/A N/A N/A N/A 198,30 253.61 288.60 402.99 N/A N/A ~7q.1¢, I)irec%ion N/A N/A 208,89 180,91 271,50 179.68 180.59 347.00 354,79 1.42 23.68 358.84 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 302,60 N/A N/A N/A N/A N/A N/A N/A 358,97 1,60 3,10 3,67 N/A N/A 1R{3.~5 Re? MD N/A N/A 3400,00 3650.00 2550,00 3450,00 950,00 50,00 3050.00 3750.00 2650,00 4610,39 8700,00 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 3000.00 N/A N/A N/A N/A N/A N/A N/A 750.00 514P.1! 2800,00 4100,50 N/A N/A Re? TV~ N/A N/A 3400.00 3650.00 2550,00 3450,00 950.00 50.00 3050,00 3750.00 2650.00 4600.00 2700,00 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 3000.00 N/A N/A N/A N/A N/A N/A N/A 750,00 5100,00 2800,00 4100,00 N/A N/A 0,00 180° CRITICAL POINT DATA MD Inc Azl TIE IN 0 0,00 0,00 PERMAFRDST 1879 0,00 0,00 10-3/4° CSG 3050 0,00 0,00 START OF BUILD 3810 0,00 0,00 END OF BUILD 4860 21,00291.19 SAG RIVER/CSGP1902921.00291,19 TARGET 9208 21.00291,19 OOWC 9416 21,00291,19 TOTAL DEPTH 9566 21,00291.19 TVD NorthEast 0 0 0 1879 0 0 3050 0 0 3810 0 0 4836 69 -177 8729 609 -1571 8896 632 -1630 9090 659 -1700 9830 679 -1750 8HL DATA TVD 9230,04 MD 9565,98 Vg 1876,88 Nop%h 678,52 Eas% -1749.94 'Smith International, Travelling Cylinder Report Computed by the Sii Win-CADDS Systerr, Least Distance Method Page 1 Date: 2/2/93 REFERENCE WELL: Prudhoe Bay Dri[ting Prudhoe Bay A-PAD WeLt: A-39 FiLe:A-~gwP1 TVD, N/S and E/W are measured from the WELLHEAD We[[path Slot Distance a01 A-01 818.37 a02 A-02 690.29 a03 A-03 567.03 a04 A-04 171.53 a05 A-05 402.60 a06 A-06 65.72 a07 A-07 212.00 a08 A-08 114.32 a09 A-09 27.10 alO A-lO 122.86 all A-11 237.55 a12 A-12 317.68 a13 A-13 464.69 a14 A-14 1306.17 a15 A-15 1427.59 a16 A-16 1531.70 a17 A-17 1643.05 a18 A-18 1756.57 a19 A-19 1866.51 a20 A-20 1888.35 a21 A-21 1788.84 a22 A-22 1691.25 a23 A-23 1195.24 a24 A-24 672.07 a25 A-25 156.33 a26 A-26 1315.58 a27 A-27 1154.96 a28 A-28 1146.11 a29 A-29 935.32 a30 A-30 1701.37 a31 A-31 1483.59 a32 A-32 1373.84 a33 A-33 198.30 a34 A-34 253.61 a34a A-34A 288.60 a35 A-35 402.99 A-37WP A-37 1820.63 A-38WP1 A-38 1572.62 A-40WP A-40 379.16 Closest Points Direction 180.07 162.64 208.89 112.15 180.91 271.50 179.68 180.59 347. O0 354.79 1.42 23.68 358.84 183.99 183.69 183.76 182.93 183.03 182.83 203.97 205.66 207.53 172.89 148.90 302.6O 216.44 158.85 223.30 254.40 183.09 183.49 183.80 358.97 1.60 3.10 3.67 205.43 183.36 180.35 Ref MD 50.00 3450.00 3400.00 3650.00 2550.00 3450.00 950.00 50.00 3050.00 3750.00 2650.00 4610.39 2700.00 2150.00 0.00 2250.00 2700.00 500.00 0.00 1700.00 1450.00 0.00 5302.79 3850.00 3000.00 800.00 9212.46 750.00 2800.00 0.00 100.00 0.00 750.00 5142.11 2800.00 4100.50 0.00 0.00 0.00 Ref TVD 50.00 3450.00 3400.00 3650.00 2550.00 3450.00 950.00 50.00 3050.00 3750.00 2650.00 4600.00 2700.00 2150.00 0.00 2250.00 2700.00 500.00 0.00 1700.00 1450.00 0.00 5250.00 3850.00 3000.00 800.00 8900.00 750.00 2800.00 0.00 100.00 0.00 750.00 5100.00 2800.00 4100.00 0.00 0.00 0.00 SU~-,.:"J,CE ©LE.DIVERTEFt SYSTEM .::.::" Two lines venting 90 deg. apart in directions that ensure sate down wind venling, and ex- tending to a point at least 100' from any potential source at ignition. __ .~~.10' Full Opening Valves ' '35' or as required Dresser Sleeve .o 10' Diverter Line 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movemenL 2.. Manual 10" full opening valves mechanically connected to ensure that one valve is fail-sale open at ali limes. 3. All tums are go deg. and targeted. 10' Full opening ball valve w/ Actuator 2g" Diveder S~oi wf 10" Side M EM 1/3/g0 TO FLARE CAVlEM UNIT 1 CAVlEM UNIT 2 CHOKE MANIFOLD TRIP TANK 170 BBL VOLUME TANK 137 BBL EQ. FILL LINE I. DITCH .:S~ND-._ TRAP 4 BBL 181BBL 81BBL DEGASSlNG TANK DESlLTER NABORS C6NTRIFUGI~ PIONEER MI< I DEGA88ER DR1LC, O 8EEFLOW TO PIT TO STAND PIPE & K~LL~E ITO DISTRIBUTION :VOLUME TANK 180 BBL WATER 87 BBL MUD HOPPERS & MIXING PUMP8 SUCTION 117 BBL MUD PUMPS SUCTION 134 BBL NABOR$ DRI_L!qG LTD. RIG No. 28E MUD SYSTEM SURFACE FACILrrEs TOTAL ACTIVE SYSTEM: 800 BBL TOTAL SURFACE CAPACITY : 970 BBL NABORS 28E 13 5/8" 5,000 psi Stack 2.42 10.93 ,,t 4.50 4.~2 1.51 3.07 2.13 1.13 1.5 G ROUND LEVEL r"' RKB I HYDRIL PIPE RAM BLIND RAM , KR TO RF i RI( 13.18 i F[ ©~ R 5.58. 8.O6 MUD CROSS PIPE RAM MUD CROSS TBG SPOOL '~ASE FLG / 12.58 I16.25 17.33 19.75 A-39CMT.XLS State: WeE Field: State Permit PRLIDHOE 83.28 Engineer: Work Sheet: Date: C. emen! Vo~rne 2/77/$3 Casing Type Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks Cement- Yield Cement- Cubic t't Cement- Cubic tt Cement- Sacks ~2 Cement- Yield Cement- Cubic ft ~2 Cemer,t - Cubic ft ~2 Cement- Sacks ~3 Cement- Yield 1~3 Cement- Cubic ~t Cement- Cubic ft Cement- Cubic ft / Vol Cement- Fill Factor Conducto~ 20.000 80.000 30.000 0.000 0.000 0.000 297.000 0.000 0.000 0.000 0.000 297.000 1.3G1 Surlace 10.750 3,019. 000 13.500 970.000 1.920 1,862.400 1,862.400 355.000 1.150 408.250 408.250 0.000 0.000 0.000 0.000 2,270.650 2.068 Lirlel 5.500 687.000 G.750 115.000 1.180 135.700 135.700 0.000 0.000 0.000 0.000 135.700 2.365 Casing Type Casing Size -Inches Casing Depth- Feet Hole Diameter -Inches Cement- Sacks :l:I1 Cement-Yield ~I! Cement- Cubic ft Cement- Cubic tt Cement- Sacks ~2 Cement- Yieid Ceme~ - Cubic ft ~2 Cement- Cubic ft Cement- Sacks Cement-Yield Cement- Cubic ft 1~3 Cement- Cubic ft Cement- Cubic It /Vol Cement-Intewal ft Top ct~ Cement- Feet Intermediate ~I1 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.00 0.00 0.00 ~IDIV/0! ~DIV/0! Intermediate ~I2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 tIDIV/0! I~DIV/0! Production 7.625 9,029.000 9.875 265.00 1.15 304.75 304.75 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 304.75 1,419.07 7,609.9' Measured Dep'th CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 2 ) Loc ~Pr'_ ~~_. '[2 thru (4) Casg -~;',~..~( ,,,2T,)r- '~ ,~ [14 thru 22] [23 thru 28] le 2. 3. 4. e 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Company ,7-.-//~y... ~ , . : , Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is wel 1 located proper distance from other wells ..................... Is sufficient undedicated acreage avail'able~ in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name @ n~nber ................................ Is conductor st r i ng provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Wil] cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ....... , ........... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to 5OoO psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... Lease & Well YES NO , · REMARKS (6) Other ~ru 3~1] 3 C7) Contact ~ -. [32] - (8) Addl /~/(~.~ geology: engineerinq' DW~L~ MTN RP~ BEW dD~ LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones.. ,.. .e®eeeeeee®eee®,. Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone .n~nber of contact to supply weekly progress data ...... ~ -.~ Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE UM %, ~ TYPE' EXp,Ck~:,) X" Inj MERIDIAN' - SM Redr I-F1 Rev ., , o u~--I 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 CMNTER , ****************************** *-- ..... ' ~CHbUMB~RGER ******************************* COMPANY NAME : BP EXPLORATION WELL ~A~E : A-39 (3!-35-11-13) BOROUGH : NORTH SLOPE STATE ~ AbA6~A API MUMBER : 50-029-22344-00 REFERENCE NO ~ 93293 * ALASKA CO~PUTIMG CENTER , ****************************** ****************************** WELh NAHUM : A-~9 (3!-35-11-13) FieLD NA~E : PRUDNOE BAY REFERENCE ~O ~ 93293 ~I8 Ta~e Verification ;cblu~berqer AlasKa Co~,~outind Center 12-JUL,-!D93 !2:54 D~TF : q3/0~/12 O~!GIN : Fb!C ~:Er; NA~E : 03293 PREVIOUS ~ E ~!5 : CO~,!~E~;T : BP EXP[.~f~ATION,PRi. iDHO~ BAY,A-39 (3!-35-11-13)~50-O29-22344-00 **** TAPE HEADER **** S[:RV'!C~ N~i~E : EDIT C~R IG ! ~' : FbIC CON~INt. JATI~N ~ : l PREVIOUS TAPE : COM~EbI'! · BP EXPLr]RATIO~,~,PRUDHOE BAY,A-39 (31-35-1!-13),50-O29-22344-00 TAPE }~EADER PPI. JDHOE BAY UNIT WELL ~A~E: API NUt, BaR: OPERATOR: LOGO I ~,!G COllOP.ANY: TaPE CREATION [)ATE: JOB DATA OPERATOR ~ITNES$: KALISh.! SECTIOa: TOwt~ISH!P: RANGE: F'SL: FEL: ELEVATION KELLY DE~R!CK FLOOR: GROU~!D LEV~b: W~Lb CASING RECORD !-39 C3!-35-!1-!3) 500292234400 BP EXPLORATION SCHbU~BE~GER ~E;bL SERVICES 12-JUL-93 35 13E 920 ~!.50 0,00 7.00 PAGE: ,I~S Wa~e Verification t, istjDg ich]Umberoer ~%lasKa Comput!no Center 12:54 3RD STRI;!G # TOOLST~ING, ~'~iJT~t]N ~h]?P]:.X = SANDSTO~qE, ~OLE COP~ECTION = LIS FOR~AT DATA LIS FORMAT DATA PAGE: **** FIL~ HEADER SERVICE : FLIC V~RSIO~ : DATE : 93107/!2 ~X REC SIZE : 1024 FILE TYPE ~ LAS? FILE : EDITED CURVES All tool strings: DePth shi,fted and clipped curves; all, runs merged; no cased hole data, DEPTH INCRemeNT: 0,5000 FTL~ VENDOR TOOL CODE STAR~ DEPTN BCE 942'05 9TM 9574,0 C~T~ 9525.0 GR 9516,0 ~ASELINE CURVE FOP SHIFTS: CURVE SMIFT DATA (MEASUPFD DEDTB) ~R6ED DATA SOURCE PBU TOOL COOE R[~N NO. $ STOP DEPTH 9027,0 9027.0 9027,0 9027,0 PASS ~0. RE~4aRKS: NO DSiPTH CORR~CTIONS WErE NEFDED OR APPLIED AS ONLY ONE TOOLSTR!~G :,~AS USE~D, LIS FOrMaT DATA Vane Verification Listinq ;chlumberger Alaska Computin~ Center 12-Oi]b-!.. 993 12:54 ** BATA FORgAT SvMC!FICATIOh ~ECO~D ** ** SET TYPE - CHAN ** v '- '--- '"''''''''''' NA~ $ RV ~NIT SE~ CE: A~! A I APl FILE [:tMB N RE PROCESS ID O~DER # bOG TYPE CLASS MOD NUmB SA~P ELEM CODE [HEX) DFDT ......... PT 59q~69 O0 OOO O0 0 i I ! 4 68 0000000000 ILO DTE IL~ DTE SFL DTK ~g~ DTE ~ES DTE O~E~ 599,369 O0 o~ga 599369 O0 OH~H 599369 O0 OH~ 599369 O0 Og~a 599369 O0 ~V 599369 O0 DEGF 59q369 O~N 599369 O0 NPH! CNT~ FU-S 59936~ 00 CPAT CNTH 599369 00 NRAT CNTH 599369 00 NCNT CNTH CPS 599369 O0 FCNT CNTa CPS 599369 CN~C C~T~] CP$ 599369 00 CFTC C~TH CP6 599369 O0 I)~ BCS {JS/F' 599:369 00 O~ ~C8 000 O0 0 1 o00 OO 0 1 000 O0 0 1 000 O0 o 0o0 ©0 0 000 O0 o i 000 00 0 1 000 O0 O 1 000 O0 0 1 000 O0 0 I O00 00 0 000 O0 0 1 000 00 0 1 000 O0 0 1 000 00 0 ! 000 O0 0 GAPI 599369 O0 000 O0 0 I I 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 ! I 4 68 0000000000 I 1 4 68 0000000000 ! i 4 68 0000000000 1. ! 4 6~ 0000000000 I 1 4 68 0000000000 1 I 4 6~ 0000000000 1 ! 4 68 0000000000 I l 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 PAGE~ ** DAT~ ** Wane Verification 'Ch 1, un~berger 12-JLiI.,-!993 12:54 PAGE: UEP~. 95~4.000 IOP!~.O!E Ih~ riTE -q99,250 ~P~$. DTE I .O38 NC~!T. Ci'~TN -999,250 PT.BCS -999.250 GR.RCS D~PT, 9500,000 IDPH,DTE !L~.DTE t.906 SFL.DTE ~M$.DTE 1.047 ~CNT.Cp~T~ 3~92,305 FC~T.CNT~ OT.BCS 90.90a GR.BCS DMZ?, 94ov.009 rDPH,DTE !b~,PTE 17.339 ~ES,DTE !.062 NP~t,CNT~ NCMT,CNTH 5896,773 FCNT.CNT~ DT,BC$ 72,050 GR,~CS Df::PT, 9300,G00 !DP{'~.DTE !L~.DTE ].8.956 SFL,DTE PRES.DTE 1.07! NCMT.CNTM 3922,601 FCNT.CMTH ~T.BCS 92,050 GR.~CS PEPT, g200 00© I'DPN DTE YL~,DT~ 20.99~ ES.DTE 1.089 NPHI'CNTM NC~T,C~TH 3537.649 FCNT.CNTH DT,BCS 93,550 GR,BCS DMPT. 9!00.000 !b~,DTE 5,930 SFL.DTE MRLS.[>TM 1 129 ~'~ biCi~T,CNT'i.i 2657,473 FC~.~T,CNTN DT.BC$ 75.750 GR.BC$ Df~P~, 9027,000 IDPH,DTE l t,~4.DTF !950,000 S~L,DTE ~$,DTE I,I72 ~PHI.CNTH NCMT,C~TH ~569,284 FCMT,CNTM DT.BCS 140,350 GR,BCS -99~.750 T~{PH,DTE -999.250 SP.DTE -099.250 CRAT.C~TH -999.250 C~TC,C~I%N -999.250 TE;NS.BCS 1.874 I~PH,t)TE 7 139 :t.~575~ CtVTC.C~,iT~ ~!.~723 TEuS,BC$ 17,~92 IMPN,DTE 25,092 SP,DTC 14.6B5 CRAT,CNTM 3350,~u0 C~iTC,CNTH 24,098 I~PH,OTE 27 8~4 25~346 C~AT,CNTM 1.~5 322 Ct,,!TC 2 .1,873 TENS.BCS 27.~39 I~P~,DTE 33..33 SP,DTE 27.72~ CRAT,CNTM ~361.007 CNTC,CNT}{ 22,547 TENS,RCS 6.0~4 I~P~{,DTE !o 202 817.067 CNTC.CNTN !35.355 TENS.~CS ~.404 IMPH.QTE 0.099 SP.i}T;.,~ 367.~ CNTC.CNTH 59.725 TENS,BC8 -990.250 -999.250 -999.250 999 250 2 vs:ooo t.873 -47.188 2.592 3752 989 4 3o:0oo 17.1!5 -4.9.813 'J..597 5558 259 43202000 i91,333 -58,063 2,308 3743,907 429o,0o0 - ,375 2,467 3644.311 4320.00O 5.2~2 .875 ~'094 2664,247 4350'O00 ~,~50.000 ~ 0 1584232 44~52000 !LD,DTM gTEg.DTE NRAT.CNTH CFTC.CNTM TEND,RCS ILD,DTE TEM,DTE R~T,CNTH CFTC,CNTM TEND,RCS ILQ,DTE ~TEM DTE CFTC,C~TH TEND.RCS IbD.DTE MTE~.DTE NaAT.CNTH CFTC,CNTH TEND,RCS ILD.DTE MTE~.DTE NRAT,CNTH CFTC'CNTM TEND,RCS ILD,DTE ~TEM,DTE NRAT.,CNTM CFTC,CNTH TEND'RCS l. bD D:TE MTEMiDTE NRAT CNTH CFTC.CNTH TEND,BCS -999,250 1 -9 ,250 -999,250 935.143 O! !447 6 98~,~44 16'716 105.039 3543.984 ~022.050 22.692 !84.000 2.589 1.626;942 967'171 26,359 18!'679 2,719 1489'872 1059,3t6 6 ,107 179 397 3 ~18 894 1106 5 2 2'29~ 393,077 1200'22! ** EMr) OF DATA ** ,I$ Ta~e Veri~icatton [~istlDq ~chlumberqer AlasKa Computlnq Center I2-JU.L-I993 I?:54 PII.,w ~A~E : EDIT .001 5~V!CE : FLIC YE~gI. ON : 001~07 S~× ~EC SIZ~ : 1024 Fib? TYPE : !.,g **** FILE [4EA[)~ **** S~RV IC~7 : FLIC V~7~S!ON : 001A07 DA~57 ~X REC SIZE : !024 FIb~ TYD~ : hO L~ST FILE ED!~ED CASED H©bg MAIN PASS UeDth shifted and clip~ed curves for open hole lo~S rum lnto casin~, DEPTH INCREmEnT: 0.5000 F!L~ S!J~ARY Vg~POR TOOL CODE START DgPTR 9027'0 S C[JRV~ S~'{I~'T D T ....... R~ ...... P~SELINE D~PTH ~ 8,0 4.5 9029.0 899!.5 8946.5 !00.0 $ ; "7;'" ' .. 8~8~8.0 9044.5 9029.5 899~.5 8988,0 100.0 T(;~ OPEN ~OLE GR FRO~~ T[,!E ~OR,~ilqObg SOix~IC. TH~ DATA FIRST SHIFTE;D AND T!~ff;~,! CLIPP~,TD. ,1,~ Ta~e Verificat.i. on ,cblumberqer AlasKa Compt]t!~.,.'~ Center ! 2-J{J[,-1993 !.2154 ,EB * · * SEro T](PE- 64 1 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT Il 66 42 12 68 !3 66 0 1.4 65 F~ 15 66 68 16 66 1 0 66 ! ** SET T~OE - CNA~ ** ~A~E SERV IJ~IT SERVICE API API APl: AP1 FISE N~ ~{]~ SIZE REPR PROCESS ID ORDER # bOG TYPE CbA~8 ~OO NUM~ S~P E~EM CODE (~EX) D~T VT 599369 O0 000 0(~ O 2 1 I 4 68 0000000000 ~s,cs~ ~9~3,~ ooooo oo o ~ ~ ~ ~ 6~ oooooooooo ~s.cso~, ~99~9 ooooo oo o 2 ~ ~ ~ 6~ oooooooooo ~,~ff '~ ? ...~ .,r,- · g027.000 GRCH ~'~Co · , );~R~;S. BCS 1 . 182 ~TE?~ ~CS t 71 . 2 i 9 . ~' '~ BCS 9000,000 G~C~', BC8 64.437 TEND.aCS 1,224 766 PTRE8~C8 I la2 ~T['~ BC5 :171 068 EPT 8900,000 GRC}{, ~C~ 71,794 TEND, BCS 1237,656 T~]NS, BCS ..... ~,,o BCS I 2~2 qTEi~.~C8 170.~74 4480.000 4455,000 4375.000 ~I8 Taoe Vort{lcation L£stino cblU. m~erqer ~laska ComPuting Center 12-JOL-1993 ~2:54 PACE: DEPT. 8800,000 GRC~{.BC$ ~.:iP EM, BCS 1,234 DEPT, 8700,000 GRCH,dCo DEPT. 85O0.000 ~PMS.~!CS 1.302 DEPT. 8460.000 GRC~i.BC$ ~RE5.~CS !.31! ~TEt'~.aC5 69.837 TENQ.aC5 ~69.5!4 . .......... oC~ .4~ 423 T~0 B,o !65.939 69.610 TEND.SCS 463.840 t60,42! 1222.000 TMN$.BCS 1169.t. 82 TEaiS.BC$ 1,167.409 TENS.BCS 1169.640 TENS.BCS 1!11,296 TENS,BCS 4380.000 4330.000 4t35.000 4090,000 4305,000 **** FILE TaAILER **** FILE NA~E : EO!'T ,002 SFW¥ICE : MLIC D~TE : 93/07/1,2 MAXi ~EC SIZE : 1024 FILE TYPE : bO LA5~ F!bE : **** FILE HEaDEa **** FIIL? MA~E ; EDIT ,003 SERVICE : ~bIC VERSION : 00la07 D~TM : 93!07!12 ~lX REC SIZE : 10~4 FILE TYPE : LO LAST FILE : Curves and !,oq header data :for each run arid tool strino In se~-:~arate files Tool Str Sadlerocni't rub uresented first (primary cie~>t.n cor~trol string use~ to depth shift the Sadler !~terval.) foll. o~ed bV files for other matrl DaSS toO1 strings Der run. TOOL $TR.I~V(; qUr~R: ~ PaSS 'NUanCe. ER: ! DED'rH !~;C;~EaENT: -,5000 FIL~ S[,,l~ bl ~ RY ,IS 9'a~e Verification Listino 'chlnmberger Ala$<a Computing Center 12-JLtb.l. 993 t2:541 YENDOR TOOL .... MC 9 97.0 DTF 9597.0 C~L 9597,0 DATE LO~GED: TI~E LOGGER 0~'~ ROTTO~: TD DRILLER (F'i): TD LOGGER (FT) TOP LOG INTERVAb BOTTO~;~ .!~OG IMTERVAL ~OGG!NG SP~ED (FPHR) 7.5 H937.5 ~937.5 29-JUt{-93 5C0-42] 330 29-JUN-93 837 29-JUN-93 9585.0 95~4.0 9027°O 9574.0 1BOO,O TELE~T~Y ELECTRONICS GAM~ RAY HOUSING ~A RAY C!RTRIDGE COMPENSATED ~!EUTRON BORE~OL~ SONIC CART, SONIC SONDE PS~SOR INDUCTIOM C~RT. PHASOR INDUCTION ~ORMHOLE AND CASING [DATA OPEN HObE BIT SIZE DR!LBERS CA$I~GDEPTH (FT); LOGGERS C~SIN¢ DEPTH (PT): BD~EHOLE CONDITIONS ~UD TYP~: DENSITY 'VISCOSITY PH: FLUID bOSS (C3): ~AXIMHM RECORDED TEmPERATUrE (DEGF): RESISTIVITY (OHMg) AT TEHD~;DATbRE (DEGF): ~UD AT MEASURED TEMPERATURE (MT): ~jD AT BOTTO~ HOLE TEaPERATURE (B~T)~ ~UD FILTRATE; AT (~T): ~UD FILTRATE AT SUD CA~Y AT ~UD CAKE AT ECH-KC 2]20 SGH-K 62 SOO-SA 60 CNC-HA 2190 SLC-UA !]6 SLS-WA 2004 DIC-EB 37'7 aIH-ZA 385 DI$-HB 379 6.750 9036 0 L, SMD 8.90 38,00 9'5O I96.0 3,540 7~.0 4,120 69.0 2,480 69.0 ECH GR GR CNTH aHC SOT DTE gTE RTE TOOL STRING (TOP Ti] VENDOR TOe,[,, CODE TOOh TYPE TUOb 1';"' .... '"' ....... '"' M, AUX!LLiARY ~4EAS!jRE~?iENT8 ~4,M-AA 7.. A~E AUX!bLiARY ~'EA. SURE~<;E~,4T$ A~E-AA 7!2 TCC TEbE~!ETRY C!RT~IDGE TCC-B 320 .,Is Ta[~e Ver1.~!.catlon Llstlnq ;chlumberqer h!.as.~a Computlnq Center 17-J~b-i99] t2:54 TOOt., T~E~NA.L SANDSTONE 2,65' 6.750 TOOL STANDOFF (IN): .7 ~A~S: USE~ ,75" F~USB~ STA.~DOF~"S Ah~D 2' F'~(]LE VIND~]~ ON TO[!LST~,I~. [~EdTROH ~AT~IX : SANDSTONE, HObF. CORRECT!O~,~ : LIS FOR~;iAT DATA PAGE~ ** D~TA F~R~T SPMCIVICATION RECORD ** ** SET TYPE - 64MB ** TYPE . .... ~ CODE L I 66 0 2 66 0 3 73 4 66 5 66 6 73 7 65 ~ 68 9 65 tl 66 5 12 6~ I~ 66 0 14 65 15 66 68 16 66 0 60 I i~ ..~ 8ERV U S~.;R~'[C~ A I ~PI . I ~PI VILli NU~B ... SIZE R~ .... R PRCCE$~ ID ORDE~ # LOG TYPE CLASS ~OD NUMB SANP ELE~ CODE (HEX) ..... ............................................... ..... , ., .. .......... .... .... .............. D~PT FT 59q369 O0 000 oo 0 3 1 1 4 68 0000000000 CIDD !)TE M~H[) 599369 O0 ooo O0 6 3 ! I. 4 68 0000000000 IDP~ DTF OH~ 599369 O0 GOO O0 0 3 1 I 4 68 0000000000 CI~P DT~ ~Ht;~ 599369 O0 OOG O0 fi 3 I I 4 68 0000000000 I~PN DT~ OHa~ 599369 O0 000 O0 0 3 1 i 4 68 O000000OO0 CTLD [)TM ~[) 599369 oo o00 O0 0 3 ! 1 4 68 0000000000 ILD DT~ ~ 599]69 OO OOu D¢ 0 3 1 1 4 68 GO00000000 C!LU DT~ a~HO 599369 O0 000 O0 0 3 1 ! 4 68 0000000000 Tape Verification Listinq icblumberqer Alaska Computing Center 12-JUL-1993 12:54 0 ID ORDE~ ~ bOG TYPE CLhSS ~I[JD M!.i~'6 S~P E~ CODE (HEX) .... (')H~ 599~ ..0 000 . O 3 1 ~ 68 000 000000 599369 O0 000 O0 0 3 1 1 4 6~ 0000000000 599369 O0 000 O0 0 3 ~,!O 599369 O0 000 O0 0 3 M~HO 599369 O0 OhO O0 0 3 ~H[) 599]69 O0 OOO O0 O 3 ~HO 599~69 OO 000 O0 0 ] OH~ 599369 o0 OCo O0 0 3 ~'V 599369 O0 000 O0 0 3 GAPI 599369 O0 000 O0 0 3 LB 599369 O0 OOO O0 0 3 DEGF 599369 OO 000 O0 0 3 OH~ 599369 O0 DO0 O0 0 3 LB 599369 O0 000 O0 0 3 PU 599369 O0 000 O0 0 3 599]69 O0 GO0 O0 0 3 PU 599369 OO 000 O0 0 3 599369 00 000 00 0 3 PU 599369 00 000 O0 0 3 CPa 599369 O0 000 OO 0 3 CPS 599369 OO 000 O0 0 3 CPS 599369 O0 000 O0 0 3 CPS 590369 O0 000 O0 0 3 GAPI 590369 OO 000 O0 0 3 bE 599369 O0 O00 O0 0 3 OH~ 599~69 O0 000 O0 0 3 DE;GF' 599369 O0 000 O0 0 3 58 599369 O0 000 O0 0 3 !JS/F 599369 OO 000 O0 0 3 US 599369 O0 000 O0 0 3 0S 599369 00 000 00 0 3 US 599369 OD ()00 O0 0 3 US 599369 O0 000 O0 0 3 aV 599369 00 000 00 0 3 GAPI 599369 O0 000 O0 O 3 :LB 599369 O0 000 O0 0 3 DEG~ 59q369 O0 000 O0 0 3 ] ! 4 68 0000000000 1 1 4 ~8 0000000000 1 1 4 68 0000000000 I 1. 4 68 0000000000 I 1 4 68 0000000000 I 1 4 68 0000000000 ! t 4 68 0000000000 1 ! 4 68 0000000000 t I 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 I ! 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 I i 4 6~ 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 I 1 4 68 0000000000 1 1 4 6~ 0000000000 I I 4 68 0000000000 ! ! 4 68 0000000000 1 I 4 60 0000000000 ! 1 4 68 0000000000 !. I 4 68 0000000000 ! 1 4 60 0000000000 1 I 4 68 0000000000 ! 1 4 68 0000000000 1 i 4 68 0000000000 1 1 4 68 0000000000 I i 4 68 0000000000 I 1 4 68 0000000000 ! 1 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 ** DATA ** 588.028 iDPH.DTE ~06..!08 0.000 571.606 !IX.~,DTE 5,592 TEMS.DTE -35,~42 NPMi'CMb ~,327 ! 70I CIMP.DTE 0,000 IIRD,DTE ~3oo :ooo ~T~.~T~ 25:6ti RT~R.CNI, 25.495 RC~T,C~L 473 08 5'343 186,848 .500 387 .968 Tape YerJ. ficat~on Listtnq ;ch!umherqer Alaska ComoutJ. Dq Center DEPT. 9500.000 CIDD.DTE I~PH,DT~~ I .873 C!LD.DTE !L~. DTE I .906 IDQF.DTE !!XD.DTE 82,077 SD. DTE -47.1S~ Ga. ~PES. DTE 1.947 HTE~'4. DTE TNP~, CN[,, 29,864 T:'~RA.CNL RCFT.CNL ~325.752 CNTC.CNB TENS.CNL 4430,000 ~RES,C~IL DT. BHC 90. 900 TT1. BH'C TT4. BHC 385,200 SP, BHC DEPT. 9400,000 CIDP,D3g !MPN,DTE 17,115 CiLO,DTE IL~a,[}TK 17,339 'IDOF,DTE SP, DTF. -49.813 :DTE S~ES DTE 1.062 HTE~I,DTE T ~ P ~ ' C r~ L :! 4 481 T ['~ R a. C ~'~ L RCFT ' ' . C N ~, ] 35 o. 100 C ;:J T C. c'~ L TE;~S,CNL 4320.000 ~RES.CNL DT. BHC 72,050 TT1. BHC TT4,BHC 324,800 SP. BHC ~TEM. Bt4C 185,039 ~RES, BHC DEPT. 9300.000 C!DP.DTg I~P{'J. DTE 1,9.333 CILO.DTE !L~, DTE 1.8.956 IDOF-OTE IIXD,DTE -0,388 !IR~i,DTE SP. DT~7 -58,06 ~ GR. DTE M~ES.DTE 1.07! HTE~, [)TE T~!PH,CNb 25,421 RCFT. C~,~L 1.558,.~22 CNTC.CNL TENS, CNL 4290. 000 ~4RKS, CNL QT, BHC 92. 050 TT1,BHC TT4. ~C .368 000 SP BHC NT~'~.BHC i~4.000 [}BPT.. . 9200 OOt; CIOP.L rea' "~ i-~PH. BTM 20: 7 39 C!b!). DTP: IL~:, DT'E 20,998 IOOF,DTg I!XD.DTE -! .007 I iR;~l. DTE 5P, DT~7 -72. 375 GR. DTE ~RES. DTE ! .0~9 HTEN. OT[~ TNP~, C~,~[: 27,625 Tt:aa. C~:~L RCFT, C~.:L 1361,007 C)>JTC. CNL PT, [:~HC 93. 550 TTI.., BHC I 2-JUL-1993 i2:54 374!.526 CPTC.C~L !.o3a ~TE~,CNL 567.200 TT2,BSC -50.000 GR.{~HC 1.038 [!TEM,B~C 533.695 !DPN.DTg 546.036 !LO,DTE CFTC.C~L 568.000 TT2.B~C -4-7. 188 GR. BHC 58,157 IDPH.DT~ 59'~22 ILO,OT~ o.000 !~OF.DT5 U4.761 ZZX~.DT~ 20.2~2 TENS'DTE 1022.0 0 NPH!,CNb 1 597 ~.06~ ~.c~b 473.600 TT2.BHC -49,81~ GR.pHC 4~.~7 IDPq. OTg 4. 8 !LO.UTE O.000 50.107_~__ 23.1~7 T'N~.:E o,DTg ..... 967,.17J [:PHI,C~L 2.308 NPOR,CNL 3743.907 CFTC,CNL 1.07! ~TE~,CNL 574.000 TT2,BNC -58,063 1.071 36,445 37 . g 38 0'000 !~QF.DTE 45.250 IIX~,DTM 22.547 !059.~16 UPH!.Ct4L 2.467 3644,311 CFTC,CNb 1,089 ~{TEg,CNL 566.800 TT2.BHC 1622 477 !86:S4~ 376,800 5.592 -35,142 1.874 1.831 0.000 37.979 4430,000 29 598 342077 1447.706 !.85 891 378:400 21.723 981.1,44 17,192 t6,7t6 0.000 -9,.229 4320,000 14.685 13.885 3543,984 1@5.039 320,800 20'292 1022,050 24,098 22,692 0 000 -1!.:492 4290.000 25 ~46 25i 28 1.626 42 .!84 00 23,187 967.171 27.439 26,359 0,000 -!!.603 4320.000 27.723 30.007 t489.872 181,679 385.600 GR.CNL HTEM.CNL TT3.Bt{C TENS.BHC ClgP.DTE CILM.DTE IIRD.DTE SFLU.DTE MTEM.DTE RT~R,CNL RCNT,CNL GR,CNL HTEN,C~L TT3,BHC TENS.BHC CIMP,DTE CIbM.DTE I!RD.DTE SFLU,DTE MTE~.DTE RTNR,C~L RCNT,CNL GR,CNL HTEN,CNL TT3.BHC TENS.BHC C!MP'DTE CIbM.DTE !IRD,DTE SFLU,DTE HTEM,DTE RTNR~CNL RCNT,CNL GR,CNL HTEN,CNL TT],BMC TENS'BMC CIMP.DTE CIL~,DTE IIRD,DTE SFLO.DTE MTE~,DTE RTNR.CNL RCNT,CNL GR.CNL NTE~,CNL TT3,8MC 5,592 -35,142 574.800 2300,000 533.858 524.767 433.803 7.132 I85. 1 3492,305 2i'723 981.!44 568,000 4430,000 58,428 57'673 53'314 25,092 185.039 706 589 773 ~o 29~ !022 050 475 600 4320 000 51,725 52.754 .40.i87 27.884 !84.000 2~589 3922'69~ 23,!87 967'!7! 572'400 4290,000 48219 33.726 33.033 181.679 2~7~9 3537,649 22.547 1059.31~ 566.800 tl .ils Tape veri. flcation Listinq 'chlu~meroer .~laska ComD~]tj. nq Center I~P~. f)TE 5.282 CILO,DTE IL~x . DTE 5,9]0 I. IXD.PTE 2.290 !IP~;~.DTE Sp. DTE 2.875 GR. ~CFT. C~L 817.067 C{~TC.CNL TF~'~S. C~L ~350.000 DT. Bi.~C 75,75<) TT ~TE~'': ~C '17o.397 DE~'.~, 9000.000 CIDP.DTE !~PH.DTg 1950,000 CILD,DTE Ib~,. DTE 1950,000 IDOF.DTE I!XD.DTE 37.4~.4 II~,DTE SP, OTE -55,3 ! 3 GR, DTE '~,~RES. DTE !. 178 HTEN. DYE TMP~.CNL 52,41.4 Tt~RA.CNb RCFT'CNL 328.65t CNTC.CNb TENS.CNL 4420,000 ~RES.CNL DT. ~HC 54. 050 TTI, 8HC TT4. BHC 306, g00 SP, ETE:~.BMC i73,950 D~PT. 8938. 000 CIDP. DTE i~PF~. DTE 1950.000 CIbD'DTE !L~,~TE 1950,o00 IDOF.DTE I!XD,DTE 29,135 !IR~4.DTE S~,DTE -54,250 GR.bTE ~R~:S. DT~ 1,205 HTE~.I. DTE T~Pt.~, C~,~ L 49,174 TNR~'CNL ~.CFT,CNB 413,060 TENS,CNL 4400.000 DT. Bric 55. 300 TT! · BHC T'r4. B?{C ,:]07. 600 SP, ~'~C ~TE~. BMC t72,i79 ** EM[) OF DATA ** ! 2-JUL-.~ 993 !2:54 -72. 375 GR. a~iC !64.363 IDPH.DTE 163.756 ILD.STE O.0o0 I~4QF,DTE !~8.92B IIX~.OTE 135.355 TEN$.DTE 1.~O6.512 NPHI,CNL 3.094 WPOR,CNL 2604.247 CFTC,CML 1,129 ~TEa,CNL 502.~00 TT2,6~C 2.~75 GR,SNC 1.129 ~TEN.BHC 36.053 IDPH,DTE 38,410 IbD,DTE 0.000 IMOF,DTE -74,!04 IIX~,DTE 60.608 TENS.DTE 121!,331 NPH1,C~L 4,1~0 MFOR,CNL !417,651 CFTC,¢NL .41.41S00 '55,313 GR,BHC 1..178 ~TE~,BHC 48 032 IDP?!,DTE 43,;26~ ILD.DTE 0.000 I~OF,,DTE -~7.294 IIX~.DTE 1227.I01 NP~I,C~f, 3,7~2 'MPOR,C~L I539,231 CFTC,CNL ~.205 ~TEa,CNL 415.200 TT2,BNC -54.250 GR.a~C 1.~05 NTE~,SHC 22 547 1.059."316 6.084 107 :ooo 15 462 4350!000 37 997 37,4~4 894 1791397 338 00() l 5: ss 11(t6.512 27.737 26.035 0 000 -348i313 4420 000 56.405 55'663 52.8t4 ~73.950 306,400 60.608 !21.!,331 0 B19 23i!15 20000 -32~.686 4400"000 0,587 090 4!1.674 17~'179 305.600 6~.543 I227,:101 TENS. BHC C!~P,DTK CILM.DTE IIRD.DTE 8FLU.DTE MTEM,OTE RTNR,CNL RCNT.CNL GR.CNL HTEM,CNL TT3.BHC TENS.B~C CI~P,DTE CIL~,DTE IIRD,DTE SFLU'DTE ~TEM,DTE RTNR.CNL RCNT.CNL GR,CML :~TE.:~,CNL TT3,BMC TENS°BHC CIMP,DTE CILM.DTE II~D,DTM SFLU,DTE ~TE~'DTE RT~'C~L ~C~T,CN5 G~.C~5 HTEN.CNL TT3,BHC TE~S'B~C PAGE: 4320. 000 189,336 168.642 139.355 10.202 179.397 t35,355 1.106,512 500.800 4350.000 -741'889 '77,318 35. 0 173.950 4.476 t387'.559 6O ~ 414o800 4420,000 -79 985 -61 255 3 522 9700 000 ~72 179 4 137 1666 122 68 543 1227101 417 600 4400 000 12 IS Tar..e v'eriftcat. J. on 5istinq chlumberqer Alaska Co.~puti~O Center 12-JUL-1993 12:54 PAGE: 13 **** F I[,,E S~PVICE : FLIC VERSI~ ,~.X REC SIZE : 1024 KILg TYPE : LO LAST FILE FILE ~a~g : EDIT SE~ICE : WLIC ~E~SI,[.)N : O0!a07 DATE : 9]/07/12 MAX REC 8.!ZE : 1024 Fl:bE TYPE : LO L~ST FILE Curves and 1. oo header data for each moss, tool string, and run tn Sevarate ~iles, PaS8 NUNBER~ DEPT~{ INCRENEFIT: -,5000 F!L? S[!M~ARY V~::~DOR TOOL CODE ST ~T~ 9596,5 C~ 9596,5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE V'ERS!ON: TI~E CIRCULaTIO~ TIPE LOGGER ON TD DRILLER TD LOGGE~(FT): TOP LOG I~TE~VAL (ET): BOTTO~ LOG INTERVAL (FT)I [,~[)GGING SPEED (FPHR): 893 8939,5 8939,5 T.f,)OI, STRI~G (TOP 99-JUN-93 5C0-423 33O 837 95~5 0 9027,0 957~,0 !.800.0 29-dON-93 2g-J{J~-93 IS T~3pe Yer!fi. catlon Li~stinq cblumberger Alaska Comoutin,~' Center ! 2-jL.,6-1993 !2:54 i4 '.~CC ECH GR G~ CNT~ DTE DTE $ 'TEL, E,qETR Y CARTRII2GE GAMM~ R~Y HO(ISI'NG GA~A RAY C~.RTRIOGk~ COMPlaiN SA,!;EO NEUTRON BORE~OLE SONIC CA~T. PMASON INDUCTION C~RT, PH~SO~ !NDUCTIO~ PH~SO~ I~,[DOCTION SOS~DE TCC-B 320 MCH-KC 2]20 SGC-SA CSC-WA 2190 SLC-UA 136 SLS-~A 2004 DIC-E8 377 ~IH-Z~ DIS-MB 2OREHO!..,E AMD CASING DATA ()PEN HOLE alT SIZE (IN): OBILLERS CASING DEPTH LOGGERS CASING DEPTH 036 0 ~O~EHOLE CONDIT!O~qS MUD TYPE; ~UD DENSITY (nB/G): MUD VISCOSITY (S): ~{lD PHI FhU!D LOSS (C3): MAXIMUM RECORDED TEmPERATUrE (DEGF): RESISTIVITY (OH~) AT TE~PERATURE ~{ID A~ MEASdRED TEmPERaTURE (~T): ~UD AT 80TTO~ HOLE TE~PE~ATi.IPE ~UD FII,,T~ATE AT (MT)I ~!Jn FILTRATE AT (BHT): ~UD CaKE ~ MIlD CAK~ AT 8.90 9.50 1.96.0 3.540 4.120 2,480 72.0 69.0 69.0 TOOL TYPE (EPITHER~lb OR THERMAL)I MATRIX DENSITY: HF~LE CORRECTIO~ THERMAL SANDSTONE 2.65 6.750 TOOl, STANDOF? (iN): .7 ~f~APWS: USED 75" ~RU'BBEP S~i:iANDOFF'S AND 2' HOLE FINiD~J~ ON T[)O[,$~FilNG, NEUTR[) ~TRIX : SANDSTONF, HOLE CORRECTION : GP HIGH ON ~OTTD~ OF R~PEAT !;;>LJ~ TO INDUCEO ~ADIATION. FOR~aT DAT~ ,IS, Tape Verif!Icat.ion {:,istinq ch]..u~,berger AlasKa Comput,lnq center 2 66 0 3 73 !84 5 66 6 73 7 65 8 69 0,5 g 65 ~T 12 68 1] 66 0 t4 65 FT !5 66 68 16 66 I 0 66 ** SET TYPE - CHAN ** ~E SERV U~IT SERVICE APl aP1 APl APl F!bg ~U~8 ~!J~B SIZE REP~ PROCgS~ ID ORDER # LOG TYPE CLASS ~OD ~UMB SA~P ELE~ CODE (HEX) DEPT FT 599369 00 000 00 0 4 ! ! 4 68 C!DP DTR ~HO 599369 OO 000 O0 0 4 ~ I 4 68 IDP~ DTR OH~Y 599369 O0 000 O0 0 4 1 ! 4 68 CI~P DTR ~H(I 599369 O0 000 O0 0 4 1 ] 4 68 IMPH DTR OH~ 5993&9 O0 000 O0 0 4 I l 4 68 C!L~ DTR ~hO 599369 O0 000 O0 0 4 I ! 4 68 ILD DTR OH~ 599369 O0 000 00 0 4 I ! 4 68 C!L~ DTR ~HO 599369 O0 000 O0 0 4 1 I 4 68 ILy DTR O!{~ 599369 O0 000 00 0 4 1 ! 4 68 IDQF DTR 599B69 OO 000 O0 0 4 ! ~ 4 68 I~OF DTR 599369 O0 000 OD 0 4 1 1 4 68 !!~D DTR ~H[) 599369 OO OOO O0 0 4 ! I 4 68 IIXD DTR ~}40 590~69 O0 000 O0 0 4 ~ I 4 68 I!R~ DTR ~H[~ 599369 O0 000 O0 0 4 ! i 4 68 !I×~ DTR ~gO 599~69 O0 OOO ©0 0 4 ! i 4 68 SPLU DTR Og~ 599369 O0 000 O0 0 4 i ! 4 68 (;R 9~R GAPI 599369 O0 000 O0 0 4 1 1 4 68 TENS DTR bg 59936~ OO 0¢}0 O0 0 4 ! t 4 68 ~TE~ DTR DEGF 599369 O0 000 O0 0 4 ! 1 4 68 ~RES DTR Oag~ 599369 O0 000 O0 0 4 I 1 4 68 HT~Si DTR ~B 599,369 00 00O O0 0 4 I l 4 68 N~N! CNR PU 599369 00 000. 00 0 4 ! I 4 68 RTN~ CgR 599~69 00 000 00 0 4 ] ! 4 6~ TNP~ CNR PU 599369 O0 OOO O0 0 4 I 1 4 68 TNRA C~R 599369 O0 000 O0 0 4 I i 4 68 ~PO~ C~R P[) 599369 O0 ()OO O0 0 4 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 oeo0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 15 Tape Verification Listlpq chlu?:ber~.er ~lasKa Computlnq Center 12-JUb-1993 17:$4 PAGE: 16 {~C~'~ C~ CEo 5 ~FV C~ CP~ C~TC CNR CPS 5 CFTC CNR CPS 5 TENS CNR [aB 5 ~Eg C~iR O~M 5 ~TE~ CNR DEGF ~TEN CNR LB UT ~HR US/F 5 TT! BMR dS 5 T~3 B~P US 5 TT4 B~R US 5 8P BHR ~V 5 GR B~R GAP~ 5 TENS BHR DB 5 ~TE~ ~,R DEGF 5 ~RE8 B~R OH~ 5 ** DATA ** D~PT. 9596. IuP~.DT~ 1. IL~.DT~ 1. G~oDTR HTE~.DTR 142. T~R~,CN~ TTloBH~ SP.BHR -~5. DEPT, 9500. I~P~,DTP 1. IL~.DTR I, !IXD.DTR 79. GR,DTR 34. HT~i.DTR 976. TNRA.CNR 2. C~TC.CNR 3823. TTI.DHR 566: SP.BMR -!6. R ~_:k # [..~O,.,TYPE CLASS 99369 O0 (.)00 OO 99369 O0 000 00 99369 00 000 00 99369 O0 OOO O0 99369 O0 000 O0 901~69 O0 000 nO 99369 O0 000 O0 99369 O0 000 O0 99369 O0 000 00 99369 00 000 O0 99369 O0 000 00 99~69 00 000 OO 99~69 00 000 00 99369 00 0O0 00 ooooo oo ooooo oo ooooo oo . ,',?,o oo mmmmIl, lml. lllli"~t.'4ll I~ 500 CIDP.I)TR 550.71 582 CILD.DTR 600.28 5~5 !DOF,DTR 0.00 9~ IIRS.DT~ 576 98 100 TENS DTR 2485:00 172 NPOR.CNR 2... 350 CFTC CNR 1.622.47 06a ~E~:CNR 1~4..07 000 TT2.BNR 3~0.40 00¢> GR.BHR 67.~0 OO() CI, DP.DTR 54 9~b CILg. DTR 55 910 IDO['r I.)T~ 0.00 476 IIRM:DTR 480 39 ~ DTR 440~: L,O 053 TEN ':ON 2 23 452 NPH e . 167 ~,)POa.CNR 22.30 921 CFTC.C~R 073 ~'.rF~'.CNR 1 ~ 49 iO0 TT2.Baa 37~ :60 750 GR. B~R 34.05 073 HT~i~J.BHR 976.45 4 1 1 4 4 1 ! 4 4 I i 4 4 1. 1 4 4 I I 4 4 1 I 4 4 I ! 4 4 1. I 4 4 1 i 4 4 1 1 4 4 ! I 4 4 1 1 4 4 I 1 4 4 1 I 4 .4 I I 4 4 1, I 4 4 1 I 4 4 1 i 4 4 1 1 4 4: 1 ! SIZE EPR pROcEss E L E M C 0 D E ( H E X ] 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 4 ooooo22.o, oo IlXh.DTR R~'.NR,CNR RCNT,CNR GR.CNR H~'~N.CNR T .... 3 BNR TENS.BUR s6o . 2o TENS.CN~ 67,~00 142.686 DT.BBR 575:200 TT4.BHR 2485,000 NTEN.BHR 1.84! CIMP,DTR 1.794 CI~M..DTR o ooo 3i:456 SFL[!,DTR 183 492 MRES.DTR 2i246 TNPH,CNR 4052 682 RCFT,CNR 34,05] TENS'CNR 976 452 DT.BHR 56~1000 TT4.B~R 4400.000 MTE~,a~R 63!,9!4 631,096 469,78! 5,634 1.068 23'098 152!,916 2485,000 90,300 40~'600 184'071 sig' 440o8'32 o.og8 1,073 23.039 1.707 03~ 4400" ,000 87,300 3810,400 183'492 ~I$ Tame verification l.,lstlnq ~chlumber~er AlasKa Computi. n~ Center DEPT, 9400.000 CID~,DTR I~PM.DTR 18.17~ CILD.DTR IL~.DTR i8.027 IDOF.DTR IIXD.OTR -1.366 I!~M.DTR G~.DTR 22.185 TEN$.DTR MTEM.DTR 973.3~5 ~PHI.C~R C~!C.CMR 5490.085 CFTC.CNN ~RES,CNR 1.09o ~TE~.CNR TT~.BHR 469,600 TT2.~HR S°.~tR -17.625 GR.SHR IIXD.DTR -3.394: GP DTR ~3.065 TE~iS DTR TNR~.CNR 2,454 NPOR.CNR CNTC.CNR 3565,019 CFTC,CMR M~M$.CaR !.!!!. TTI.gaR 578.000 TT2,B~a SP,BHR -47,250 DEPT. 9200,000 CIDP.DTR I~P~.DTR 20.700 CILD,DTR IL~.OTR 20.74~ !DOF.DTR IIXD.DT~ -2,'821 IIRM.DTR G~,DTR 2!,627 TENS.DTR HTE~.DTR 1,048.406 NP~I.CNR C~TC.CN~ 3707.626 CFTC.CN~ ~RES,C~R !.!~4 ~TE~,CNa TTI.B~ 565,200 TT2.B~!R SP,EH~ -63,375 GR.BHR ~RES.B~R 1.1~4 HTEN,~HR DEPT. 9100.000 C!DP.DTR I~P~'!.DTR 5,9i. 6 CILD.DTP !L~.DT~ 6,82~ IDOF,DTR IIXD.OTR 0.3!3 !IRi~.DTR CR,DTR !21,284 HTEN.DT~ t074,66~ ~PHI.C~,!~ TN~:I.CN~ 3,0!~ CNTC,CNR 2735,9!5 CFTC.CN¢ MRES.CNR !.177 ~TE~.CNR SP,B~R !9,188 ~"S.BHR 1.177 I2'J0[,-1993 12:54 54.~49 I'DP?!.OTa o.ooo ~S.OTa s~.6~1 ~X~.~?~ 4375.000 MTg~,DTR 3369.429 GR.CN~ la2..422 aTE~.C~ 329.400 TT3.BHR 973. 335 4!.334 IDPM.DTg 44.045 tLD.DTR 0.000 !~QF.OTR 50.553 !!XM.DTR 4245,000 ~TEM.DTR 27.541 RTNR,CNR 28,2~2 RCNT,CNR 1487.359 GR,CNR ~S0,237 NTEN,CNR 383,200 TT3,~R 23.065 TENS,Ba~ 960.268 36.!43 IVaN DTR O. 000 I~QF.DTR 45.8.04 I!×~'4, DTR 4 3 25 . 0 00 26.369 RTNR.CNR 26,075 RCNT,CNR 1568.102 G~.CNR 177'737 ~TEM,CNR 386.600 TT3.8~ 21.627 104~8. 406 163,977 !DP~.DTa 164.202 ILD.!)TR o.ooo !38.335 I!X~.DTR 4375.000 aTEg. DTR 36,525 gTNR,CNR 35.602 RCNT.CNR 920.516 GR.CNR t74.629 HTEN.CNR 338.400 TT3.8~a 121.2a4 !074.6~8 !8.I99 1.7.582 0.000 -17.1'12 182.422 1.738 5417,652 2~,185 973.335 474,000 4375.000 24 1. g3 221704 0.000 180 237 2:s,! 3553 660 23~065 960.268 578,800 4245,000 7.668 ~6 628 . o.o0o -!8 ooi i772'737 444 387:887 21 62'1 I048:406 566.200 4325,000 6 098 s:o9o 0.000 10.080 !74.629 3.029 2842.685 12t..284 1074.668 507.600 4375'000 C!MP.DTR C!L~.DTR IIRD.DTR SFLU.DTR MRES.DTR TMPH,CNR RCFT.CMR TENS.CNR DT.BHR TT4.BMR STEM,BHR CIMP,DTR CI5~'DTR IIRD.DTR SFLU.DTR ~RES,DTR TNPH.CNR RCFT~NR DT.BMR TT4,BHR ~TE~.BHR CIMP,DTR CILM.DTR IIRD,DTR SFLU,DTR MRES.DYR TNPM.CNR RCFT.CNR TEMS,cMR DT.BHR TT4,BM~ MTE~.BHR CI~P.DTR ClL~.DTR IIRD.DTR SFLU,DTR MRES..D'TR TNPH,CNR RCFT,CNR TENS.CNR DT..BMR TT4.B~R ~TEM.B~R PAGE: 17 55.030 55,474 50,951 22 851 l:oo 15,237 3080.413 4375..000 75.900 400 . 52..~ 6 53' ~5 40,249 24'800 !328,470 4245,.000 92 900 383 600 180 237 48i309 48 209 33 464 32 2~5 211 TM 38.! !464:524 4325.~000 g2~050 386,000 177,737 169'5 § 146, 139.670 10.012 1.177 35.739 824..659 4375,000 75,800 336.'000 1'74,629 lis chlumber~er AlasKa Computin~ Center !3 E P T. 9000,000 C I 0 ?, ii> T R I~PH. pTR ! 950.00(3 CI Ib~.DT~ 1950,000 I!X~.nT~ 37. 605 I ~R. t')TR 59. 455 · -. , I. 7 N~ ~. ~:vp 4. 396 NPO~. CNR ,.... v.. ~ CNTC, C~,~R 1444,254 CFTC,CNR F',P ES. C~ R I..223 ~TE.~4. C~JR TT~ .BHR 41. 4. [~O0 TT2. B, HR S~. E, HR -37.250 · ~ .. . .~.,. OW~T. 8939.500 CIDP,OTR I~PH. DTR ! 950. 000 CtLO. DTR Ib~.DTP !950,000 !DQF.DTR IIXD.DTR 2g.93! IIR~.OTP G~, f)TR 75,397 TENS.,DTR TN[~:~, C~TR .4,058 NPOR,CNR CNTC.C¢~R 1505,!]6 CFTC,CaR ~4RE,S. C~; R I .23i3 MTEq.CNR TT1 .P, HR -999,250 TT2, ~:~HR SD. B[.,!R -40. 938 GR. BHR 1, 2-Ji.iI., l. 993 !.2:54 35.904 ![>P~.DTR 3a.]01 IUD,DTR 0.000 !gOF.DTR -74.14~ !iXM.DTR 4420.000 ~T~ OT~ 51.82a NTN~.CNR 56.216 RCNT,CNR 348,817 GN,CNR 169,410 HTEN.CNR 306.000 TT~,8~R 59.4~5 TENS.SHR 11~8.706 47.~56 IDPN,DTR 40,658 II,,D, DTR 0.000 I~QF.OTR -55.04g ' 7, 387 TENS,BH~ 206 280 27,852 26,109 0,000 -347.05a 169,410 4,326 !459,385 59,465 168 706 14141400 4420,000 20.896 24,505 0,000 -337,454 ~68,259 4 229 1562:294 75:387 1206~,289 ~999 250 48s:ooo CIMP.DTR CILM.DTR !iRD,DTR SFLU,DTR MRES.DTR TNPH.CNR RCFT.CNR TENS.CNR DT.BHR TT4.BMR MTE~.BHR CIMP DTR CIL~:DTR IIRD.DTR ~FLU.DTR ,¢,RES.DTR FNPH.CNR RCFT'CNR TEMS.CNR DT.BMR TT4.BHR ~TEM,BHR PAGE: -75.052 -77.359 35.056 9700.000 1,223 54,770 307,979 4420.000 54.100 306 000 69:4io q4,822 3:6,257 9700,000 "1'238 52.1.45 398,278 4485 000 55 300 -999 250 168 259 1R **** FILE TR~ ILE[~ **** FII.,F N~.tqE : EDIT ,004: SERVICE : FLIC VFRSIOd : 00! A07 t>~Tf : 9310'7/i2 FILE TYPE : LAST F![,E : **** F!L~: N61ADER **** F~LF: NA~E : EDIT ,005 VERSION : O0!A07 DATE : 93!07/12 ~X REC SiZE : 1024 FTLE TYPE : bO LaST ~ILE : Tape Verfftcation List!.,n~ ichl. umheroer AlasKa Compt]tin~ Center 12-JUL-1993 1.2:54 PAGE~ 19 Curves arid lo~ header data ~or ooen ~ole !o~s run into casln~. DFlPT~4 I~C~E;~E~NT: -.500fl FTI..F VE~DOR Tt'~OL COD< ST~'F DEPTH .. ........ . ....... .. ....... bOG ~{E;a.D~jR DATA DATE bOGGEDI SOFTWARE VERSIO~;~: TI~E C!RCULATIO~'~ TO D~II, LER {FT): TD 5OGGE~ (FT): TOP LOG !!~TERVAb (FT): ~OTTO~ LOG IMTERVAL r~OGGING SPEED (FPHR) ~ T[)OI, STRING (TOP T(] BOTTOM) VEt:~DOR TOOL CODE TOOI,, TYPE dR CNTI4 SDT DTE DTE ........... u DATA, OPEb~ HOLE 8IT SIZE DRILLERS CASING DEPTH LOGGERS CASING OEPTH (FT): Bt)PE~OLE ~!JD TYPE: DENSITY (LB/G): VISCOSITY ($): PF: Fi.,1)I~) bUSS (C3)I 5C0-423 9585.o g584.0 9027.0 9574.o !~00,0 29-0UN-93 29-JU~:'-93 TELE~TRY ELECTrUM!CS C~PE~SATED ~EUTRON ~ORFHOLE SONIC CART. SOrbIC SONDE PHASOR INf)t. JCT![]N CART P},i ASOP I ~DUCT~O~ ' P~A$OR INDUCTION SONDE ECH-KC 2320 8GH-K 62 SGC-$A 60 CNC-}',i~ 2190 SLO-UA 136 SLS-WA 2004 DIC-EB 377 YI~-ZA 385 DI$-~ 379 6.750 9027,0 8,90 9250 I96.0 72.0 OOO0000000 89 ~ ! ~ ~ 0 OO 000 O0 69£66g I~D D~ 0000000000 89 ~ I i ~ 0 O0 000 O0 69E'06~ ~ (X3H) ~OOD ~3q~ d~ 6NfiN QO~ ~gVqD 3dA~ DOq ~ 8~OaO '[ 99 0 89 99 0 99 &~ 59 6 ~'g 9 99 i 99 o 99 mm i~lm mi mmm mm mm ~m mmm ~i, mm~ mm~ im ~mm, Imm Imi~ i~ ~mmm mlmm, sim mmm ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O~ OSL'9 S9'g 0 '69 0'69 9Ll'I ,,JSD ~N3& 0i9'69 9W.D ~D 000'009~ DgD' 938~ 00o 08[~' DSD' 9N:.qi L~.8'69 9SD'~D 000'0088 ' i~(1 9Sg'LfEI DSD'a' ............. ' DSD S3~N 000 ~L[~ 99D'gN3£ ~6L'IL DSD'~O 000'0068' 000000000 89 0000000000 89 0000000000 89 J3DVd
