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TT RR AA NN SS MM II TT TT AA LL FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3H-11 DATE: 10/26/2022 Transmitted: North Slope, Kuparuk River Unit Via SFTP data drop ___ 3H-11 Dean Stark Core analysis Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3H-11 e-transmittal well folder Receipt: Date: Alaska/IT-Support Services|ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: 011 ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended IN 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5 Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 13, 2012 187 - 124 / 312 - 174 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 December 15, 1987 50 - 103 - 20091 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1232' FNL, 281' FWL, Sec. 12, T12N, R8E, UM December 25, 1987 3H - 11 Top of Productive Horizon: 8. KB (ft above MSL): 76' RKB 15. Field/Pool(s): 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM GL (ft above MSL): 33.7' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1316' FNL, 1042' FEL, Sec. 12, T12N, R8E, UM 4530' MD / 3747' TVD Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498655 y - 6000425 Zone 4 7750' MD / 6460' TVD ADL 25531 TPI: x - 502360 y - 6000290 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 502612 y - 6000341 Zone 4 507' MD / 507' TVD 2657 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1721' MD / 1633' TVD 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 CBL not applicable 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 215 sx AS I 10.75" 45.5# J -55 35' 3637' 35' 3088' 13.5" 1200 sx AS III, 600 sx Class G, 130 sx AS I -f . 7" 26# J -55 2701' 7715' 2416' 6432' 8.5" 650 sx Class G, 300 sx AS I 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 3.5" 7346' 7139' MD / 5946' TVD perfs cemented off 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ��� ��� � � by `e� J Was hydraulic fracturing used during completion? Yes El No Q DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 5764' -7328' 67 bbls 15.8# Class G 4530' -5764' 46 bbls nrCt1VED 27. PRODUCTION TEST NOV 0 7 2012 Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Al.e�ry Grr Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE i GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Q 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 MC 25.071. NONE NOV 0 7 2012 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Z.G 13 Submit original only r '? >/' G 29. GEOLOGIC MARKERS (List all formations and •rs encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? 111 Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1721 1633' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na I 31. LIST OF ATTACHMENTS Summary of Daily Operations ( €t it , -ri_ 'ON 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 - 4250 Email: Tyson .M.Wieseeconocophillips.com Printed Name Howard Gober Title: Wells Enaineerina Supervisor y /7 Signature Phone 263 - 4220 Date 11; 2, 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 - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 3H -11 Pre Rig Well Work Summary DATE SUMMARY 6/3/12 PULLED AVA BPC © 7319' RKB TAG BTM @ 7466' RKB (EST 16' RAT HOLE) SBHPS 3554psi Temp 157deg 30 MIN STOP © 7356' RKB. 15 MIN STOP @ 7180' RKB 3488psi JOB IN PROGRESS 6/4/12 SET 2.31 XXN PLUG W/ FILL EXT @ 7339' RKB, SET 2.75 AVA BPI © 7319' RKB SET AVA CATCHER SUB ON TOP OF BPI © 7319' RKB, PULLED OV STA# 2 © 4797' RKB, SET DV STA# 2 @ 4797' RKB, PULLED GLV STA # 1 @ 2928' RKB, SET DV STA# 1 @ 2928' RKB JOB IN PROGRESS. 6/5/12 PULLED DMY VLV STA# 5 @ 7072' SLM, RAN 42B0 SHIFTING TOOL ENSURED CMU CLOSED @ 7180' RKB, CIRC TUBING TO IA W/ 250 BBLS DIESEL, ATTEMPT TO SET DV STA #5 NO LUCK DROPPED VLV, TROUBLE SHOOT FISHING VLV OFF CATCHER SUB W/ FILL. JOB IN PROGRES 6/6/12 SET DV @ 7072' RKB, MIT -T 2000# (PASS), MIT -IA (FAIL), MIT -OA 1400# (PASS) BAIL FILL ONTOP CATCHER SUB W/ DV IN FILL @ 7257' SLM. JOB IN PROGRESS 6/7/12 BAILED 4 CUPS SILTY MUD FROM 7251' SLM ( EST. 29' OF FILL ONTOP OF CATCHER) , MIT -OA 1800# (PASS). RDMO; WILL RETURN AFTER E -LINE. 6/9/12 PERFORMED SPECTRAFLOW LEAK DETECT TO LOCATE IA LEAK. THE UPPERMOST IA CASING LEAK WAS FOUND BETWEEN 4880' AND 4890' WITH A SECOND SIGNIFICANT LEAK NEAR 4970'. A SMALL AMOUNT OF DOWNFLOW WAS OBSERVED BELOW THIS BUT STOPS BY 5300'. NO FLOW IS PASSING THE UPPER PACKER AT 7139'. IA FREEZE PROTECTED AND WELL TURNED OVER TO DSO. 6/12/12 BAIL FILL ON TOP OF C -SUB ON AVA SLEEVE @ 7319' RKB (EST 28' FILL REMAINS) RECOVERED 1 GAL HARD MUD AND SILTY SLURRY. IN PROGRESS 6/13/12 BAIL SILTY MUD OFF TOP OF CATCHER @ 7280' SLM, (EST 15' FILL). IN PROGRESS 6/14/12 BAIL FILL DOWN TO AND TAG AVA CATCHER © 7284' SLM. IN PROGRESS. 6/15/12 BAIL FILL AND RECOVERED DROPPED 1.5" DV; PULLED AVA CATCHER AND BPI @ 7319' RKB. BAILED FILL OFF TOP OF PLUG @ 7339' RKB. IN PROGRESS 6/16/12 BAILED COMPACTED FILL OFF TOP OF PLUG @ 7339' RKB 6/17/12 BAIL FILL & TAG TOP OF PLUG @ 7339' RKB. IN PROGRESS 6/18/12 BAIL FILL OFF TOP AND f/ WITHIN PLUG @ 7339' RKB, ATTEMPT TO PULL PLUG W/ EQ PRONG ( BENT PRONG TRYING TO LATCH UP) ; IN PROGRESS. 6/19/12 BAILED FILL OFF PLUG @ 7339' RKB. DIRECTED TO ABORT EFFORT & LEAVE PLUG J IN PLACE. ATTEMPTED SHIFT CMU OPEN @ 7180' RKB, UNSUCCESFUL. IN ,t4 PROGRESS. 6/20/12 ATTEMPTED WITHOUT SUCCESS TO OPEN CMU @ 7180' RKB. DRIFTED TBG WITH 10' x 2.80" DRIFT TO 7180' RKB. INJECTED 50 BBL DSL: 1 BPM @ 1550 PSI, 1.5 @ 1750, 2 @ 1900. PULLED DV @ 7073' RKB. READY FOR CTU. 6/23/12 (PRE RIG) T -POT (PASS), T -PPPOT (PASS), IC- POT (PASS) & IC- PPPOT (PASS). FUNCTION TESTED LDS ON T AND IC SPOOL. ALL LDS APPEAR TO FUNCTION PROPERLY 7/7/12 MIRU CTU, RIH, LOCATE NPL AT 7165' CTMD, FLAG PIPE, WHILE POOH WE PINHOLED THE CT AT 3078', CALLED FOR N2, BLOW DOWN THE REEL, RDMO, ROAD THE UNIT TO DEADHORSE FOR REEL SWAP, JOB IN PROGRESS 7/11/12 RIH TO LOCATE CMU AT 7169' CTMD (7180.1' RKB), PAINT WHITE FLAG, POOH, RIH TO FLAG AND CORRECT DEPTH TO 7180.1, PUH TO SET DEPTH AT 7164', TRY TO LAUNCH BALL TO SET RETAINER HOWEVER THE INNER REEL VALVE WILL NOT HOLD PRESSURE, JOB SUSPENDED, POOH, F/P TBG, AT SURFACE FOUND THAT THE RETAINER HAD BEEN SET, JOB IN PROGRESS 7/12/12 DRIFT RUN DOWN TO 7158' CTMD, RETAINER SET ON DEPTH, RIH WITH STINGER, STUNG INTO RETAINER AT 7160' CTMD, UNABLE TO GET CIRCULATION SLEEVE TO SHIFT OPEN, POOH, RIH WITH VENTURI, RECOVERED 1 BRASS PIN AND A 1.5" PIECE OF SLIP, F/P TBG, JOB IN PROGRESS 7/13/12 RIH WITH RETAINER NZL, FCO RETAINER RECEPTICLE AT 7157' CT,POOH, RIH WITH RETAINER STINGER1,UNG INTO RETAINER AT 7164' RKB, P ORM INJECTIVITY TEST @ .5 BP 1BPM, 1.5 BPM, 2 BPM, PUMP 67 BBLS 15.8# CEMENT, 20 BBLS BELOW RETAINER, 35 BBLS INTO THE IA, LAY IN 12 BBLS INTO TBG, FCO WITH BIO, TOC AT 5800' RKB, CMT REPORT IN WSR ATTACHMENTS, F/P TBG, READY FOR S /L, JOB IN PROGRESS 7/19/12 TIED INTO GLM © 4797' RKB FOR CORRECTION FACTOR. TAGGED CMT TOP @ 5765' k RKB. MIT TBG 2000 PSI & CHARTED SUCCESSFUL TEST. AOGCC REP BOB NOBLE DECLINED TO WITNESS. COMPLETE. 7/20/12 RUN IN HOLE WITH A RADIAL CEMENT BOND LOG TO THE CEMENT TOP @ 5764' IN TUBING / PULL CEMENT BOND LOG SURVEY AND VERIFY FREE PIPE AT 5600' FOR ✓ PROPOSED JET CUT / RUN BACK IN HOLE WITH A JET CUTTER AND CUT THE TUBING CAP OFF @ 5603' • • ConocoPhilli p s Time Log & Summary Wei/view Web Reporting Report Well Name: 3H - 11 Rig Name: NORDIC 3 Job Type: DRILLING SIDETRACK Rig Accept: 8/26/2012 10:00:00 AM Rig Release: 10/8/2012 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/11/2012 24 hr Summary Breaking down 11" 5M BOPE stack on 2T -Pad. Move Camp to 1Q-Pad. Begin Rig move to 3H -Pad from 2T -Pad moving on mats do to soggy roads. As of Midnight we were 9/10's of a mile from 2A -Pad moving on mats. 09:00 11:00 2.00 MIRU MOVE MOB P Breaking down 11" 5M BOP Stack and racking on skid. Rig Camp on 1Q-pad at 02:30 am. 11:00 00:00 13.00 MIRU MOVE MOB P PJSM- Rig move over mats. Begin Rig move to 3H -pad shuffling mats to 9 /10th of mile from 2A Pad as of Midnight 08/12/2012 Continue to move towards Spine road = 1.8 miles on mats. 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move towards 2A -Pad - made 2/10 of mile shuffling mats with 4 loaders - 7/10 of mile shy of arriving at 2A -Pad. 05:00 18:00 13.00 MIRU MOVE MOB P Rig stopped on south side of 2A pad to check rig tires and torque, also allow mats to be moved around and placed on access road from 2A pad to Spine Rd. at 4 corners approximately 7/10 of a mile. 18:00 00:00 6.00 MIRU MOVE MOB P Continue to move rig on mats from 2A -pad to 1/10 mile from Four Corners as of midnight X8/13/2012 Continue to move on mats to four corners. Stage all mats ahead of rig and place over culverts and pipe line crossings. Cover all known soft spots in spine road. Moved to CPF -2 as of midnight. 00:00 03:30 3.50 MIRU MOVE MOB P Exceptional rig move - Finish moving rig to 4 corners on mats and set down, to wait for mats to be loaded and trucked ahead of rig. 03:30 08:00 4.50 MIRU MOVE MOB T Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. Stay set down and allow CPF 2 and other field change outs. 08:00 09:30 1.50 MIRU MOVE MOB P Normal rig move - Move Nordic 3 w/ mats over culverts and on low spots from 4 corners to 2B Pad 09:30 12:00 2.50 MIRU MOVE MOB P Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. 12:00 17:00 5.00 MIRU MOVE MOB P Exceptional rig move - Move on mats from 28 Pad to 2G Pad and set down. Page 1 of 43 4111 1111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 MIRU MOVE MOB T Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. Stay set down and allow CPF 2 and other field change outs. 19:00 20:30 1.50 MIRU MOVE MOB P Exceptional rig move - Move on mats from 2G Pad to 2F Pad and attempt with no mats - road gave way - repair road w/ gravel. move mats ahead of rig. 20:30 21:30 1.00 MIRU MOVE MOB P Normal rig move - Move Nordic 3 w/ mats over culverts and on low spots from 2F to CPF 2 21:30 00:00 2.50 MIRU MOVE MOB P Wait for KDTH to Truck mats ahead of rig and cover pipeline crossings and culverts. 08/14/2012 Move rig towards 2C -Pad from CPF -2 - found soft spot in road - shore up and attempt to get on mats. - Call out Peak cats to assist in rig move. 00:00 01:00 1.00 MIRU MOVE MOB P Road rig from CPF -2 towards 2C cut across and found soft spot in road. 01:00 05:00 4.00 MIRU MOVE MOB T Place dunnage under move system and lay mats in front of rig. Attempt to climb up on mats.. no luck..increase dunnage under move system. Call Peak for Dozers. 05:00 07:30 2.50 MIRU MOVE MOB T PJSM w/ Peak and Nordic 3 crews. Hook up to 2 Dozers and ease Nordic Rig 3 back up on mats. Release Peak Dozers. Spot mats. 07:30 15:00 7.50 MIRU MOVE MOB P Move rig towards 2C on mats to between 2C acess roads to allow for CPF -2 crewchange out and move mats around rig. 15:00 21:00 6.00 MIRU MOVE MOB P Coninue to move rig towards 2X pad access road on mats due to poor road conditions, once past 2C access road run on Spine road bearfoot to 2X pad access road and set down as of 16:30 hrs for CPF -2 change out and move mats ahead of rig 21:00 22:00 1.00 MIRU MOVE MOB P PJSM, Move rig off mats for 1 mile - road got soft. 22:00 00:00 2.00 MIRU MOVE MOB P Begin moving rig on mats. 08/15/2012 Continue to move on mats to 2Z access road. 00:00 12:00 12.00 MIRU MOVE MOB P Continue to move rig on mats towards 3H pad, 1 mile shy of reaching 2Z access road 12:00 22:00 10.00 MIRU MOVE MOB P Continue to move rig on mats to 2Z Pad access. 22:00 00:00 2.00 MIRU MOVE MOB P Truck mats ahead of rig while waiting at 2Z -Pad access. 08/16/2012 Continue to move on mats From 2Z access road. Stage all mats ahead of rig and place over culverts and pipe line crossings. Cover all known soft spots in spine road. Move towards 1Q -Pad Page 2 of 43 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 MIRU MOVE MOB P Continue to Truck mats ahead of rig while waiting at 2Z -Pad access. 02:00 05:00 3.00 MIRU MOVE MOB P Move rig on mats from 2Z -Pad access towards Oliktock "Y" for 1/10 mile 05:00 06:00 1.00 MIRU MOVE MOB P Pull rig off mats and run .5 miles for Oliktok "Y" 06:00 10:00 4.00 MIRU MOVE MOB X Set down at Oliktok "Y" and wait to stage emergency services at CPF3 and stand by for CPAI field change out. Truck mats ahead of rig and place in front of rig. 10:00 10:30 0.50 MIRU MOVE MOB P Move rig on mats thru KCS pad .5 mile. 10:30 16:00 5.50 MIRU MOVE MOB X Set down in front of KDTH and truck mats around rig, stage all mats ahead of rig and place over culverts, soft areas and pipe line crossings. 16:00 17:30 1.50 MIRU MOVE MOB P Move rig off mats 1 mile from KCS pad towards 1Q pad and encountered soft road, move rig up on mats. 17:30 18:30 1.00 MIRU MOVE MOB X Set down to allow CPF -3 field change out, walk around rig. 18:30 00:00 5.50 MIRU MOVE MOB P Continue to move toward 1Q pad on mats over soft area towards 1 Q -pad 08/17/2012 Continue moving from 1Q Pad towards CPF3 00:00 16:00 16.00 MIRU MOVE MOB P Continue to move toward 1Q pad on mats. 16:00 22:30 6.50 MIRU MOVE MOB X Set down at 1Q-pad, allow for field services to stage equipment, traffic to flow thru and CPF -3 crew change outs. Truck mats ahead and place in front of rig. 22:30 00:00 1.50 MIRU MOVE MOB P Move Nordic 3 on mats from 1Q Pad to .25 miles toward CPF3 08/18/2012 00:00 05:00 5.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats from 1Q Pad 05:00 07:00 2.00 MIRU MOVE MOB X Shut down to allow for CPF -3 crew change outs. 07:00 17:00 10.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 17:00 19:00 2.00 MIRU MOVE MOB X Shut down to allow for CPF -3 crew change outs. Nordic Rig 3 is approximately 1.6 miles from CPF -3 19:00 00:00 5.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 08/19/2012 Continue moving from 1Q Pad towards CPF3. Shuffle all mats ahead of rig - allow Pioneer to time to stage logistics for 5 day road closure during rig move. 00:00 05:30 5.50 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 05:30 07:30 2.00 MIRU MOVE MOB X Shut down to allow for CPF -3 crew change outs. Nordic Rig 3 is 1 mile from CPF -3. Page 3 of 43 1 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 07:30 17:30 10.00 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 17:30 19:30 2.00 MIRU MOVE MOB X Shut down to allow for CPF -3 crew change outs. Nordic Rig 3 is .5 mile from CPF -3. 19:30 00:00 4.50 MIRU MOVE MOB P Continue to move towards CPF3 on mats. 08/20/2012 Continue moving towards CPF 3, set down and shuffle mats around rig. Allow Pioneer to time to stage logistics for 5 day road closure during rig move. Continue to move towards 3H -Pad from CPF 3. 00:00 02:30 2.50 MIRU MOVE MOB P Continue to move rig to 3 way stop at CPF -3 02:30 03:30 1.00 MIRU MOVE MOB P Move rig to back of pad at CPF -3 and set down. 03:30 12:00 8.50 MIRU MOVE MOB X Truck mats ahead of rig and a lot time for Pioneer receive services. 12:00 22:00 10.00 MIRU MOVE MOB P Move rig on mats for 6 /10's of a mile to 3B "Y" and set down. 22:00 23:00 1.00 MIRU MOVE MOB P Shuffle all mats ahead of rig 23:00 00:00 1.00 MIRU MOVE MOB P Move rig on mats for 1 /10's of a mile from 3B "Y" Towards 3 Irene access road 08/21/2012 Continue to move towards 3H -Pad from 3B "Y" access. 00:00 04:00 4.00 MIRU MOVE MOB P Move rig on mats from 3B "Y" to 2/10's of mile past towards 3 H -Pad. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. 08/22/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. Estimated mileage remaining to 3H pad is 3.1 miles, slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. Double rig mats, 08/23/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. Estimated mileage remaining to 3H pad is 2.6 miles, slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. 08/24/2012 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. Estimated mileage remaining to 3H pad is 2.2 miles, slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. 08/25/2012 Continue to move towards 3H -Pad Page 4 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3B "Y" access. Estimated mileage remaining to 3H pad is 1.1 miles, slow and steady. 04:00 00:00 20.00 MIRU MOVE MOB P Continue to move towards 3H -Pad from 3A -Pad 08/26/2012 Arrive on 3H pad, Spot rig over well, Rig up all auxiliary equipment, Pull BPV and Circulate Well 00:00 04:00 4.00 MIRU MOVE MOB P Continue to move rig to 3H -pad. 04:00 10:00 6.00 MIRU MOVE MOB P Arrive on location, spot rig over well, start to rig in all auxiliary equipment. 10:00 18:30 8.50 MIRU MOVE RURD P Accept rig @ 10:00 a.m. Start to offload fluids in pits. Continue to RU Auxiliary Equipment, Hardline 18:30 20:00 1.50 MIRU MOVE RURD P PT Surface Lines 3500 psi, OK 20:00 22:00 2.00 MIRU RPCOM PLUG P PJSM, Pull BPV with Lubricator 22:00 00:00 2.00 MIRU RPCOM CIRC P PJSM, Circulate SW down Tbg, Returns to Kill Tank at 5BPM. ICP 580, FCP 670. Initial OA Pressure 300 psi. Pumped 228 bbls and Returned 226 bbls. OA Pressure up following pump pressure. Continues to pressure a little to 750 psi after off on Pumps. Bleed Down IA to 250 psi. 08/27/2012 ND Tree, NU BOPE, Test BOPE, Pull Blanking Plug 00:00 01:00 1.00 MIRU RPCOM CIRC P Bleed Down OA- 220 psi, Pump 100 bbls of 8.5 ppg SW at 5 bpm at 660 psi, returns 109 bbls, OA 290 psi 01:00 01:30 0.50 MIRU RPCOM OWFF P Monitor Well, Static 01:30 02:30 1.00 MIRU RPCOM PLUG P Set BPV, RD Hoses, BD Hardline 02:30 04:00 1.50 MIRU RPCOM NUND P ND Tree, Inspect threads, Install Blanking Plug, KO Tree 04:00 10:00 6.00 MIRU RPCOM NUND P NU Class III 11" 5M BOPE. Connect Kill and Choke lines. 10:00 23:30 13.50 MIRU RPCOM BOPE P PJSM. Obtain Shell Test On Stack, 250/3500 psi. Start BOP Test 250/3500 psi w/ 3 1/2" Test Joint. Perform Annular test and Draw down test. 24 hr notice was given at 17:00 hrs on 8 -25 -12 and Test witness waived by Lou Grimaldi at 06:45 on 8- 27 -12. (Includes 4 -1/2 hours of changing out HCR and rebuilding Choke Valve #8: [18:00- 22:30]) System pressure = 3,100 psi After closure = 2000 psi 200 psi build = 16 seconds Full system pressure = 85 seconds 4 bottles N2 = 2150 psi Ave psi 23:30 00:00 0.50 MIRU RPCOM PULD P RD Test Joint and Test Hoses. Pull Blanking Plug. Page 5 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/28/2012 24 hr Summary Pull BPV, Pull 3 -1/2" Tbg from cut at 5600', Finish BOPE Test w/ 4" Test Joint, Start 7" Casing Scraper Run, Slip & Cut 00:00 01:30 1.50 SLOT RPCOM PULD P Continue Pulling Blanking Plug and BPV and monitor well, Static 01:30 02:30 1.00 5,600 5,570 SLOT RPCOM PULL P PJSM, MU Landing Joint, BOLDS, Pull Hanger 86k# 02:30 03:30 1.00 5,570 5,570 SLOT RPCOM CIRC P Circ 200 bbls 8.5 ppg SW at 5bpm 300 psi, down tubing, up IA to Kill Tank 03:30 04:30 1.00 5,570 5,550 SLOT RPCOM PULL P Lay Down Hanger and Landing Joint. • Blow Down Top Drive and prep to pull Tbg 04:30 14:00 9.50 5,550 0 SLOT RPCOM PULL P PJSM, Pulling out of hole with 3 -1/2" Tbg. Rack Back 22 Stands (2067 -ft) for upcoming cement job. Continue to TOOH with 3.5" De- completion and Kick -out same. 14:00 15:30 1.50 0 0 SLOT RPCOM OWFF P Observe well for flow. Continue to Rack and Tally 4" Drill pipe. Load and Offload Tools, Changout Floor Equipmnet 15:30 19:30 4.00 0 0 SLOT WHDBO PRTS P PJSM. Set Test Plug and Test Upper and Lower pipe Rams and Annuluar w/ 4" Test Joint 250/3500 psi and chart same. 19:30 20:30 1.00 0 0 SLOT EVALWE PULD P PJSM. Install Wear Ring 20:30 22:00 1.50 0 19 SLOT EVALWE PULD P PJSM. MU 7" Scraper Assembly. 6 1/8" Bit, 7 ",26# Scraper, Bit Sub, Oil Jars and Cross -over. 22:00 23:00 1.00 19 950 SLOT EVALWE TRIP P TIH with 7" Scraper Assembly on Drill pipe down to —950' MD 23:00 00:00 1.00 950 950 SLOT RIGMN7 SLPC P PJSM. Slip and Cut Drilling Line. (Routine) 38/29/2012 Run 7" Casing Scraper- All Clear, Perform Cement Bond Log CAST -M from 5550' to Surface. Field Pick TOC at 2474'. 00:00 01:00 1.00 950 950 SLOT RPCOM SLPC P Continue Slip and Cut 01:00 07:00 6.00 950 5,602 SLOT RPCOM TRIP P Continue RIH with BHA #1: 7" Casing Scraper down 5,602 DPMD. 07:00 08:00 1.00 5,602 5,602 SLOT RPCOM CIRC P Sit down lightly on Tubing stub at 5,602 -DPMD. Up Wt 123k / Dn Wt 95K, Start CBU x2 at 8 bpm, 830 psi, FCP 810 psi, Circulated 305 bbls. 08:00 08:15 0.25 5,602 5,602 SLOT RPCOM OWFF P Blow Down Top Drive and Observe well for Flow. 08:15 08:30 0.25 5,602 5,602 SLOT RPCOM SFTY P PJSM. Discuss for hazard for TOOH with Scraper and Drill Pipe. Conducted Kick while tripping drill. 08:30 12:00 3.50 5,602 19 SLOT RPCOM TRIP P TOOH with 7" Scraper Assembly from 5,602 DPMD while maintaining proper hole fill. Up Wt 123k. Call E -Line Crew. 12:00 12:30 0.50 19 0 SLOT RPCOM PULD P Lay down 7" Casing Scraper Assembly. Page 6 of 43 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:30 1.00 0 SLOT RPCOM RURD P PJSM. RU Dutch Riser for E -Line Operation. 13:30 14:00 0.50 0 0 SLOT RPCOM SFTY P PJSM. Discuss the Hazard for Rigging up E -line Equipment with HES and Nordic Crew. 14:00 17:30 3.50 0 0 SLOT RPCOM ELOG P MIRU and Rig Up E -line Unit and Load Tools to Rig Floor. RU Tools and PT lubricator to 500 psi. 17:30 22:30 5.00 0 0 SLOT RPCOM ELOG P RIH with CAST logging assembly on E -line and log from 5550' to Surface. 22:30 23:30 1.00 0 0 SLOT RPCOM ELOG P PJSM, RD HES Eline 23:30 00:00 0.50 0 0 SLOT RPCOM PULD P PJSM, RD Dutch Riser and Offload 08/30/2012 Run Baker Retrievamatic Test Packer and test Casing. Set Test packer at 5350' and Test Cement Plug below to 2000 psi- Good Test. Set Test Packer at 4800' and Test 7" Casing integrity above to 2500 psi- Good Test. Lay in Class G Cement Plug from 5600' to 4530' and squeeze —5 bbl into 7" Casing Leak. 00:00 01:30 1.50 0 0 SLOT RPCOM PULD P PJSM, MU BHA #2- "EA" Retrievamatic Test Packer, RIH to 5356', Set Packer COE at 5350'. 116k# up, 95k# down. 01:30 04:30 3.00 0 5,356 SLOT RPCOM TRIP P RIH to 5356', Set Packer COE at 5350'. 116k# up, 95k# down. 04:30 05:30 1.00 5,356 5,356 SLOT RPCOM PRTS P RU to Test Casing. Test Cement Plug and 7" Casing below Test Packet to 2000 psi and chart. Good test. 05:30 08:30 3.00 5,356 4,806 SLOT RPCOM TRIP P Pull up Hole to 4806', Set Packer COE at 4800'. Test and Chart 7" Casing to 2500 psi for 5 minutes. Perform Injectivitly test, 1/2 bpm, 1230 psi / 3/4 bpm, 1210 psi / 1 bpm, 1200 psi / 1.5 bpm, 1250 psi / 2 bpm, 1330 psi / 2.5 bpm, 1380 psi, 3 bpm, 1440 psi. 08:30 08:45 0.25 4,806 4,806 SLOT RPCOM OWFF P Observe well flow. Blow down Top Drive. 08:45 11:30 2.75 4,806 500 SLOT RPCOM TRIP P TOOH standing back drill pipe, up wt 107k, do wt 88k. 11:30 11:45 0.25 500 500 SLOT RPCOM OWFF P Observe well flow 11:45 12:15 0.50 500 0 SLOT RPCOM TRIP P Continue OOH standing back drill pipe 12:15 13:15 1.00 0 0 SLOT RPCOM EQRP P CIO and Inspect Handling Equipment. 13:15 13:30 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making and Running Cement Assembly. 13:30 14:30 1.00 0 1,034 SLOT RPCOM TRIP P TIH with 3 1/2" Tubing with Mule Shoe on bottom on 4" Drill Pipe down to 5600' MD 14:30 15:15 0.75 1,034 1,034 SLOT RPCOM EQRP P PJSM. CIO Handling Equipment from 3 1/2" to 4" Drill Pipe. 15:15 17:30 2.25 1,034 5,600 SLOT RPCOM TRIP P Continue to RIH with Cement Assembly. 17:30 18:00 0.50 5,600 5,600 SLOT RPCOM PULD P RU Pumping Iron to Cement String. 18:00 18:30 0.50 5,600 5,600 SLOT RPCOM SFTY P Crew Change Out. PJSM with SLB Cement Pumpers and Nordic Crew. Page 7 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 5,600 5,600 SLOT RPCOM CMNT P PT Lines to 3500 psi, Pump 23 bbls of 15.8 ppg Class G Cement as per SLB Cement Program 19:30 20:30 1.00 5,600 4,996 SLOT RPCOM TRIP P POOH to 4996'. Up 105k#, Down 80k# 20:30 21:00 0.50 4,996 4,996 SLOT RPCOM CIRC P Reverse Circulate 76 bbls at 5 bpm. ICP 680, FCP 520 psi 21:00 22:00 1.00 4,996 4,996 SLOT RPCOM CMNT P PJSM with New SLB Crew, Pump 23 bbles of 15.8 ppg Class G Cement as per SLB Cememnt Program 22:00 22:30 0.50 4,996 4,365 SLOT RPCOM TRIP P POOH to 4365'. Up 96k #, Down 80k# 22:30 23:00 0.50 4,365 4,365 SLOT RPCOM CIRC P Reverse Circ 107 bbls at 5 bpm. ICP 650 psi, FCP 440 psi 23:00 00:00 1.00 4,365 4,365 SLOT RPCOM CMNT P Squeeze 5 bbls Cement @ 1500 psi. Blow Down Cwmwnt Lines 08/31/2012 Set Storm Packer in 7" Casing at 488', No Flow Test Performed- OK, ND BOP, Loosen Bolts on Casing Head- no 7" Caing growth, NU BOPs 00:00 00:30 0.50 4,365 4,524 SLOT RPCOM TRIP P RIH to 4524' to Dress off TOC 00:30 02:00 1.50 4,524 4,524 SLOT RPCOM CIRC P Reverse Circ out 90 bbls at 5 bpm 520 psi ICP, 420 psi FCP 02:00 03:00 1.00 4,524 4,524 SLOT RPCOM EQRP P Change Out Floor Equipment for 3 -1/2" Tubing 03:00 06:00 3.00 4,524 0 SLOT RPCOM TRIP P POOH laying down 1044' of 3 -1/2" Cement Stinger and KO Same 06:00 08:30 2.50 0 0 SLOT RPCOM PULD P Unload 3 1/2' TBG from Pipe Shed and Load Baker Tools to Rig Floor. 08:30 10:30 2.00 0 0 SLOT RPCOM EQRP P CIO Floor Equipment. 10:30 12:30 2.00 0 731 SLOT RPCOM TRIP P MU and RIH with 18 Jts of 4" HWDP and 6 Jts of 4 3/4" Drill Collars 12:30 13:15 0.75 731 731 SLOT RPCOM PULD P MU Baker 7" Storm Packer. 13:15 13:45 0.50 731 1,229 SLOT RPCOM TRIP P Continue In Hole with Storm Packer and 4" Drill Pipe and Set Center Element at 488' ft and bottom of Packer assembly 1229 -ft 13:45 14:15 0.50 488 0 SLOT RPCOM TRIP P TOOH Standing back Drill Pipe. 14:15 14:30 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for High Pressure Testing. 14:30 14:45 0.25 0 0 SLOT RPCOM PRTS P Check Pumping Equipment. PT Storm Packer to 1000 psi for 5 minutes. 14:45 15:15 0.50 0 0 SLOT RPEQP1SFTY P PJSM. Discuss Hazard for Nippling Down BOPE. Observe well for flow 15:15 17:30 2.25 0 0 SLOT RPCOM NUND P ND BOPE. 17:30 21:00 3.50 0 0 SLOT RPCOM THGR P PJSM with PESC Hydratight for Casing growth. Loosen Casing Head and no Casing growth. Remove Casing Head Packoff. 21:00 00:00 3.00 0 0 SLOT RPCOM NUND P PJSM, NU BOPE 09/01/2012 Pull Storm Packer from 488', Cut 7" at 2460' with Baker Multi String Casing Cutter, Spear Casing and Pick up 30' and circulate out Arctic Pack from OA, Pull Caing Slips and prepare to pull Casing. 00:00 00:30 0.50 0 0 SLOT RPCOM NUND P Cont NU BOPs Page 8 of 43 • • Time Logs Date . From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:45 1.25 0 0 SLOT RPCOM EQRP P PJSM Change Out Lower Pipe Rams 01:45 02:15 0.50 0 0 SLOT RPCOM PULD P PJSM, MU BHA #5 Storm Packer Ret Tool 02:15 03:00 0.75 0 1,229 SLOT RPCOM TRIP P RIH to 488', Release Packer and Monitor Well, Static 03:00 04:00 1.00 1,229 741 SLOT RPCOM TRIP P POOH with Storm Packer 04:00 05:30 1.50 741 0 SLOT RPCOM PULD P Lay Down BHA 05:30 06:00 0.50 0 0 SLOT RPCOM PULD P PJSM, MU BHA #6 Multi String Cutter 06:00 07:00 1.00 0 670 SLOT RPCOM TRIP P TIH with Cutter on Drill Pipe. Reach 670' MD and had gas breaking out of fluid. 07:00 09:30 2.50 670 670 SLOT RPCOM OWFF P Called DSO, Kuparuk Security and Pioneer Base Camp, vent gas out to kill tanks and monitor well. 09:30 10:30 1.00 670 2,500 SLOT RPCOM TRIP P Continue to TIH down to 2,474' MD, Up Wt 75k / Dn Wt 70k. Locate 7" Casing collar at 2,500' MD, PUH and Located 7" Casing Collar at 2,465' MD. 10:30 11:00 0.50 2,451 2,451 SLOT RPCOM CPBO P Check Logs and started cutting 7" CSG at 2,451' MD at 5 bpm, 600 psi, Torque at 1850k 11:00 14:00 3.00 2,451 2,451 SLOT RPCOM OWFF P Seen good indication that CSG was cut, had gas break at surface, close annular bag and diverted reuturn to kill tank and allow gas bleed. 14:00 14:15 0.25 2,451 2,451 SLOT RPCOM SFTY P PJSM. Discuss Hazard for TOOH with Cutter. 14:15 16:15 2.00 2,451 0 SLOT RPCOM TRIP P TOOH with Multi- string cutter standing back drill pipe and maintaining proper hole fill. Up Wt 75k 16:15 16:30 0.25 0 0 SLOT RPCOM PULD P Lay Down and Inspect Baker Cutter Assembly. Cutter Blades Look Good. 16:30 16:45 0.25 0 15 SLOT RPCOM PULD P MU 7" Casing Spear Assembly. 16:45 17:15 0.50 15 15 SLOT RPCOM OWFF P Observe Well For Flow. 17:15 17:30 0.25 15 31 SLOT RPCOM PULL P RIH and Spear 7" Casing Stub and Confirm Casing Is free. Pull and Seen Weight Break Over at 100K. 17:30 21:30 4.00 31 31 SLOT RPCOM CIRC P PJSM With LRS and Nordic Rig Crew. PT Lines to 2000 psi. Circ 150 bbls of 70 degF Diesel at 3.5 bpm - 250 psi. RD LRS. Chase with 250 bbls 8.5 ppg Sw at 3 bpm at 160 psi. Circ out Arctic Pack to Open Top Tank. Shut Down and Monitor Well for flow- Static. 21:30 22:30 1.00 31 31 SLOT RPCOM NUND P PJSM. ND BOPE 22:30 23:00 0.50 31 31 SLOT RPCOM OTHR P Remove Casing Slips 23:00 00:00 1.00 31 31 SLOT RPCOM NUND P PJSM. NU BOPE. Page 9 of 43 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/02/2012 24 hr Summary Pull 7" Casing from 2460', Safety Stand Down, Changeout Lower Pipe Rams 00:00 01:00 1.00 31 31 SLOT RPCOM NUND P Continue NU BOPE and test Breaks with Hydrostatic Pressure- OK 01:00 01:30 0.50 31 31 SLOT RPCOM PULD P PJSM, Lay Down Spear Assembly 01:30 02:00 0.50 31 31 SLOT RPCOM EQRP P Change out Floor Equipment to Pull Casing 02:00 05:00 3.00 31 2,420 SLOT RPCOM PULL P Pull Casing from 2420' 05:00 05:45 0.75 2,420 1,024 SLOT RPCOM PULL P At 1024', RU to Circulate Hole Volume. Pumping SW 3 bpm at 150 psi. Returns up OA to Kill Tank. 05:45 06:00 0.25 1,024 1,024 SLOT RPCOM SFTY P Spill Drill 06:00 11:00 5.00 1,024 0 SLOT RPCOM PULL P Continue Pulling Casing out of the Hole from 1024' laying same. Recover Centralizer on every other joint of casing. 11:00 21:30 10.50 0 0 SLOT RPCOM SFTY P Hold Safety Focus on Rig. 21:30 23:00 1.50 0 0 SLOT RPCOM PULD P PJSM, Offload Casing from Rig, Load Tools 23:00 00:00 1.00 0 0 SLOT RPCOM EQRP P PJSM, Open Lower Pipe Rams and Retreive Casing Centralizer. Change out Lower Rams to 2 -7/8" x 5" VBRs. 09/03/2012 Change out Lower Pipe Rams to 2 -7/8" x 5" VBRs and Test- Good. Test downhole Cement Plug to 500 psi - Good. Mill cement in 10 -3/4" x 7" Annulus from 2462' to 2478'. POOH to test BOPE 00:00 01:00 1.00 0 0 SLOT RPCOM EQRP P Change Out Lower Rams to 2 -7/8" x 5" VBRs 01:00 03:00 2.00 0 0 SLOT RPCOM PRTS P PJSM, RU and test BOPE to 250/ 3000 psi 03:00 03:30 0.50 0 0 SLOT RPCOM PRTS P Test Casing and Cement plug 500 psi and chart. Good Test. 03:30 06:30 3.00 0 0 SLOT RPCOM EQRP P Change Out Rig Tongs, Handling Equipment and Load Tools to Rig Floor. 06:30 09:30 3.00 0 176 SLOT RPCOM PULD P PJSM. Pickup and Makup BHA #6. 9 5/8" Washover Pipe,Drag Shoe Assembly. 09:30 10:00 0.50 176 176 SLOT RPCOM CIRC P Circulate Out Arctic Pack Cap from Wellbore at 4 bpm, 60 psi. 10:00 10:30 0.50 176 359 SLOT RPCOM PULD P Continue to MU Drill Collars. 10:30 15:15 4.75 359 2,351 SLOT RPCOM TRIP P Stop at 2,351' MD and Set Parameters. Up Wt 86k / Dn Wt 80k, Circulating at 4 bpm, 280 psi, rotarting at 50 rpm, with 1500# of free torque. 15:15 15:45 0.50 2,351 2,351 SLOT RPCOM EQRP P Service Top Drive 15:45 16:00 0.25 2,351 2,442 SLOT RPCOM WASH P Continue in hole at same parameters washing down to the next stand. 16:00 16:15 0.25 2,442 2,450 SLOT RPCOM TRIP P Made next stand and RIH and Located top of 7" Casing stub at 2,450.05' MD while pumping at 2 bpm, 60 psi. Page 10 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 18:00 1.75 2,450 2,474 SLOT RPCOM WASH P PUH 3 feet, up wt 86k. Start Washing over 7" Casing stub at 4 bpm, 240 psi with 8.5 ppg seawater, rotating at 50 rpm, and torque at 2 -3k. Starting seeing cement stringer at 2,463' MD, Continue washing over 7" Casing with same parameters. 18:00 18:30 0.50 2,474 2,474 SLOT RPCOM CIRC P Pump 40 bbl Hi -Vis Biozan sweep at 7bpm at 600 psi. 18:30 19:30 1.00 2,474 2,474 SLOT RPCOM WASH P Continue Milling from 2474' to 2478', WOB 5k, Pumping SW at 6 bpm at 400 psi, Rotating at 70 rpm, torque 2k-4k. Circulate bottoms up. 19:30 21:30 2.00 2,474 2,320 SLOT RPCOM TRIP P POOH from 2478' to 2320', string pulling heavy and packing off, pump 3 more 40 bbl Hi -Vis sweeps attempting to clean hole. 21:30 00:00 2.50 2,320 1,750 SLOT RPCOM TRIP P Attempt to pull out on elevator, pulling heavy. POOH back reaming at 70 rmp, pumping 8 bpm at 400 psi. Up 85k #, Down 80k #. 39/04/2012 Finish POOH with Wash Over Assy, Test BOPE, RIH with Wash Over Assy, Mill cement in 10 -3/4" x 7" Annulus from 2,478 -ft to 2,485 -ft. 00:00 08:00 8.00 1,750 0 SLOT RPCOM TRIP P Continue POOH back reaming at 70 rmp, pumping 8 bpm at 400 psi. RD BHA #6. 9 5/8" Washover Pipe Drag Shoe Assembly. 08:00 09:30 1.50 0 0 SLOT RPCOM PULD P PJSM. Lay Down BHA #6. Seen Minor wear on the tip of the teeth. Clear & Clean Floor. 09:30 09:45 0.25 0 0 SLOT RPCOM CIRC P PJSM. RU BOP Washing Assembly and Clean Stack. 09:45 10:15 0.50 0 0 SLOT RPCOM MPSP P Install Test Plug and Pumping Lines. 10:15 10:30 0.25 0 0 SLOT RPCOM SFTY P Conduct PJSM. Discuss Hazard for Testing BOPE. 10:30 16:30 6.00 0 0 SLOT RPCOM BOPE P Obtain Shell Test On Stack, 250/3000 psi. Start BOP Test 250/3000 psi w/ 4" Test Joint. Perform Annular test and Draw down test. 24 hr notice was given, witness was waived by Bob Noble at 16:00 on 9/3/2012. verbal extension was granted by John Crisp at 23:26 on 09/03/2012 due to difficulties getting 9 -5/8" washover assembly out of 10 -3/4" casing, test to be performed after midnight in the morning of 09/04/2012 verified by e-mail confirmation. System pressure = 3,100 psi After closure = 2000 psi 200 psi build = 18 seconds Full system pressure = 92 seconds 4 bottles N2 = 2100 psi. Page 11 of 43 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 16:30 18:30 2.00 0 0 SLOT RPCOM PULD P RD Test Joint and Test Hoses. Pull Blanking Plug. Change over floors. 18:30 20:30 2.00 0 133 SLOT RPCOM PULD P PJSM. Pickup and Makup BHA #9. 9 5/8" Washover Pipe, Drag Shoe Assembly (dropped one 42.6 -ft joint of 9 -5/8" washover pipe from assembly) 20:30 22:30 2.00 133 2,437 SLOT RPCOM PULD P Continue to MU Drill Collars and TIH on 4" DP. 22:30 23:00 0.50 2,437 2,478 SLOT RPCOM TRIP P Stop at 2,437 -ft and Set Parameters. Up Wt 86k / Dn Wt 80k, Circulating at 5 bpm, 190 psi, rotarting at 40 rpm, with 1500# of free torque. shut down rotation, TIH washing over 7" casing and tag TOC at 2478 -ft, PUH 3 -ft and set parameters 5 bpm at 220 psi, rotating at 70 rpm and 1500# torque, Up wt 80k, Dn wt 70k. 23:00 00:00 1.00 2,478 2,485 SLOT RPCOM MILL P Continue Milling from 2478 -ft, WOB 5 - 6k, Pumping SW at 5 bpm at 200 psi, Rotating at 70 rpm, torque 2k -4k. Circulate bottoms up. 09/05/2012 Continue working Wash Over Assy, Mill cement in 10 -3/4" x 7" Annulus from 2,485 -ft to 2,543 -ft. TOOH with Wash OverAsembly. RIH with Multi- string Cutter 00:00 00:30 0.50 2,485 2,485 SLOT RPCOM MILL P Continue Milling from 2485 -ft, WOB 5k, Pumping SW at 5 bpm at 200 psi, Rotating at 70 rpm, torque 2k -3k. Circulate bottoms up. 00:30 01:00 0.50 2,485 2,485 SLOT RPCOM CIRC P Pump 20 bbl Hi -Vis Biozan sweep at 8 bpm at 360 psi while reciprocating washover assembly. 01:00 04:00 3.00 2,485 2,495 SLOT RPCOM MILL P Continue Milling from 2485 -ft to 2,495 -ft, WOB 5k, Pumping SW at 5 bpm at 230 psi, Rotating at 70 rpm, torque 2k -3k. Circulate bottoms up. PUH. 04:00 04:30 0.50 2,495 2,495 SLOT RPCOM CIRC P Pump 20 bbl Hi -Vis Biozan sweep at 8 bpm at 350 psi while reciprocating washover assembly. Set assembly in slips and MU stand of 4" DP to assembly. 04:30 08:30 4.00 2,495 2,516 SLOT RPCOM MILL P Continue Milling from 2495 -ft, WOB 5 - 6k, Pumping SW at 6 bpm at 210 psi, Rotating at 70 rpm, torque 2k -4k. Circulate bottoms up. 08:30 09:00 0.50 2,516 2,516 SLOT RPCOM CIRC P Pump 20 bbl Hi -Vis Biozan sweep at 6 bpm at 200 psi while reciprocating washover assembly. Page 12 of 43 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 09:00 13:00 4.00 2,516 2,543 SLOT RPCOM MILL P Continue Milling from 2516 -ft, WOB 5 - 6k, Pumping SW at 6 bpm at 210 psi, Rotating at 70 rpm, torque 4k -8k. Seen small drilling break, made 3 -ft (2534'- 2537') top of casing collar. Work passed casing collar with 5500 torque, 80 rpm, 3 -5k WOB. Reached target depth of 2,543 -MD. 93' of swallow with washpipe and shoe. Pumped 2 -20 bbls sweeps at 9 bpm, 370 psi until clean. 13:00 13:45 0.75 2,543 2,270 SLOT RPCOM TRIP P POOH rotating and pumping off 7" Casing Stump at 60 RPM, 200 psi Up Wt 75k and 2k torque. 13:45 15:30 1.75 2,270 1,670 SLOT RPCOM TRIP P Started dragging 25 to 40 k over while pooh from 2270 -ft to 2214 -ft. Hung up at 60k over, MU T/D PUH pumping with 350 Rotating Pressure, pressure drop dropped to 80 psi. Continue to POOH pumping every other stand. Still hanging up when not rotating or pumping. 15:30 16:00 0.50 1,670 1,670 SLOT RPCOM CIRC P Hung up at 1,670 -ft with 100k over. Pumped and Rotated free. CBU at 9 bpm, 210 psi. 16:00 17:30 1.50 1,670 785 SLOT RPCOM TRIP P Continue POOH from 1,670 -ft MD, still having to pump and rotate to make any progress. 17:30 18:30 1.00 785 785 SLOT RPCOM CIRC P Monitor well, well out of balance, circulate to balance well 2 bpm, 90 psi. 18:30 20:00 1.50 785 317 SLOT RPCOM TRIP P Continue POOH from 785 -ft MD, still having to pump and rotate to make any progress. 20:00 21:00 1.00 317 96 SLOT RPCOM PULD P Stand back DC's and lay down and empty approximately 10 lbs metal shavings /cement from tandem boot baskets, lay down Bumper Sub and Jars. Change over floors. GBR ECKLES unable to break 9 -5/8" Hydril 511 connection. Bring in Baker HT Tongs for 9 -5/8" tools. 21:00 22:00 1.00 96 96 SLOT RPCOM EQRP T Re- assemble Baker HT Tongs to be able to grip 9 -5/8" washpipe, tongs segments assembled upside down prior to arrival. 22:00 23:00 1.00 96 0 SLOT RPCOM PULD P Continue to lay down BHA #9 9 -5/8" Washpipe / Drag Tooth Shoe assembly. Shoe cutting surface approximately at 10% and needs re- surfacing. Change over floors. 23:00 23:30 0.50 0 99 SLOT RPCOM PULD P PJSM- PU MU BHA #10, 3 -1/2" Muleshoe, 5 -1/2" Multi- string Cutter, 6 -1/8" Stableizer, XO Sub, 1 Stand 4" HWDP 23:30 00:00 0.50 99 1,000 SLOT RPCOM TRIP P RIH with BHA #10 on 4" DP to 1000 -ft. Page 13of43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/06/2012 24 hr Summary Run Multi- string Cutter to top of 7" Casing Stub. Clean Out 7" Casing to 2,509 -ft. 00:00 01:00 1.00 1,000 2,451 SLOT RPCOM TRIP P Continue to RIH with BHA #10 on 4" DP from 1000 -ft, Tag up at 2,451 -ft (Top of 7" Tubing Stub) rotate and make several attempts to enter 7" casing, no luck. 01:00 03:00 2.00 2,451 99 SLOT RPCOM TRIP P PJSM- TOOH with MSC from 2,451 -ft, pulled last 3 stands wet. Call out tools. 03:00 03:45 0.75 99 0 SLOT RPCOM PULD P Lay Down BHA #10, MSC blades fully extended out, break down and MSC plugged off with ball of metal shavings, muleshoe on bottom shined up. 03:45 06:00 2.25 0 144 SLOT RPCOM PULD P PJSM- PU MU BHA #11, 6 -1/8" Tapered Mill, Bit Sub, 6 -1/8" String Mill, XO, XO, 8 -1/2" String Mill, Tandem Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 1 std. 6 -1/4" DC's, XO XO 06:00 07:45 1.75 144 2,448 SLOT RPCOM TRIP P RIH with BHA #11 on 4" DP to 2,448' MD where fill or debris was tagged. 07:45 08:30 0.75 2,448 2,460 SLOT RPCOM CIRC P Up Wt 80k / Dn Wt 73k. Start Circulating at 5 bpm, 90 psi at 50 RPM, 1300# torque. Clean down to 2,460' MD remove debris from 7" Casing. PUH to 2,448' MD and Circulated 20 bbl Hi -Vis Sweep at 11 bpm, 350 psi while working pipe at 20 RPM with 950 free torque. 08:30 10:15 1.75 2,460 144 SLOT RPCOM TRIP P PJSM. POOH f/ 2,448'MD 10:15 12:00 1.75 144 0 SLOT RPCOM PULD P Lay down BHA #11. Inspect assembly and found 25 to 30 Lbs of metal shavings from boot baskets. 12:00 14:15 2.25 0 233 SLOT RPCOM PULD P PJSM. RU BHA #12. 6 1/8" Tapered Mill and 6.151string mill with 1 stand of 4" HWDP betweem the Boot Basket. 14:15 15:15 1.00 233 2,451 SLOT RPCOM TRIP P Continue to RIH with C/O assembly on 4" DP down to top 7" Casing Stub at 2,451' MD. 15:15 18:30 3.25 2,451 2,502 SLOT RPCOM CIRC P Tagged debris at 2,478' MD with 5k down weight. Up Wt 80k / Dn Wt 73k, Rotating at 60 RPM with 1400# free torque, start circulating down at 8 bpm, 190 psi, rotating torque 1600# to 1800 #. Rotated down to 2,478' MD to 2,505' MD, PUH to top of 7" Stub at same parameters, RIH again and sat down at 2,494' and at 10K down, continue down hole at same parameters to 2,502 -ft torqueing up all the way. Noticed 5 bbl pit gain in 30 min. Pick up above 7" casing stub and CBU, Monitor well. Page 14 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:00 1.50 2,440 2,505 SLOT RPCOM CIRC P Continued back down hole, Up Wt 80k / Dn Wt 75k, Rotating at 60 RPM with 1400# free torque, start circulating down at 6 bpm, 130 psi, rotating torque 1600# to 1800#. Rotated down to 2,502 -ft MD, milled down to 2,505 -ft MD incountered high torque and stopped making hole. 20:00 20:30 0.50 2,505 2,441 SLOT RPCOM CIRC P Pick up above 7" casing stub and CBU. 20:30 21:30 1.00 2,441 232 SLOT RPCOM TRIP P PJSM- TOOK with milling assembly. 21:30 22:00 0.50 232 0 SLOT RPCOM PULD P Lay down BHA #12, tandem boot baskets empty, tapered mill end completly void of carbide, in 5" to 6" area of taper carbide worn to 50% 22:00 22:30 0.50 0 234 SLOT RPCOM PULD P PJSM. RU BHA #13.61/8" Bladed Junk Mill and 6.151string mill with 1 stand of 4" HWDP betweem the Boot Basket. 22:30 00:00 1.50 234 2,503 SLOT RPCOM TRIP P Continue to RIH with C/O assembly on 4" DP down thru top of 7" Casing Stub to 2,466 -ft Set parameters, Up Wt 80k / Dn Wt 75k, Rotating at 60 RPM with 1400# free torque, start circulating down at 6 bpm, 500 psi, rotating torque 1400# to 1600#. Rotated down to 2,503 -ft. and tag up. 09/07/2012 Clean Out 7" Casing to 2,509 -ft. Pull 60 -ft of 7" Casing. Prep to run Bladed Junk Mill. 00:00 04:00 4.00 2,503 2,509 SLOT RPCOM MILL P Continue with clean out of 7" casing from 2503 -ft using same parameters, Up Wt 80k / Dn Wt 75k, Rotating at 60 RPM with 1400# free torque circulating down at 6 bpm, 400 psi, rotating torque 1400# to 1600 #. Rotated down from 2,503 -ft, Clean down to 2,509 -ft remove debris from 7" Casing. PUH to 2,448' MD and Circulated 20 bbl Hi -Vis Sweep at 11 bpm, 350 psi while working pipe at 20 RPM with 950 free torque. 04:00 07:00 3.00 2,448 234 SLOT RPCOM TRIP P PJSM. POOH from 2,448 -ft. Confer w/ town engineer. 07:00 08:30 1.50 234 0 SLOT RPCOM PULD P Lay down BHA #13. Inspect assembly, marks on bottom of mill indicates working on edge of 7" casing. Inspect Tandem boot baskets, clean & clear floor. 08:30 09:00 0.50 0 0 SLOT RPCOM SFTY P PJSM. Discuss the hazard for servicing top drive. 09:00 09:30 0.50 0 0 SLOT RPCOM SVRG P Service & Inspect top drive before RIH and pulling and jarring on 7" Casing. 09:30 09:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Spear Assembly. 09:45 11:00 1.25 0 230 SLOT RPCOM PULD P MU 3 1/2" Bull Nose, ITCO Spear w/ 6.220 Grapple with 8 1/16 Stop Sub. Page 15of43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 230 2,411 SLOT RPCOM TRIP P RIH to 2,411' MD, Stop and set parameters, 80k up and 77k dn, pumped at 3 bpm, 60 psi. 12:30 13:45 1.25 2,411 2,468 SLOT RPCOM FISH P Ran down, set down with stop sub at 2,468' md, spear nose at 2,474' md, picked up and set back down with 20k, picked and seen 2k weight down. Laid down working Joint. 13:45 15:45 2.00 2,468 230 SLOT RPCOM TRIP P PJSM. TOOH to Check and Inspect Spear. Up 83k and down 80k 15:45 16:45 1.00 230 0 SLOT RPCOM PULD P At Surface with BHA #14. Lay down and Inspect. 16:45 18:00 1.25 0 0 SLOT RPCOM PULD P Recovered a section of 7" casing. The first full joint below the orignal cut was spilt and missing about 25% of the material from the low side from the trapper mill and string mill operation. 18:00 19:30 1.50 0 0 SLOT RPCOM PULD P PJSM- RU Casing Equipment to remove fishing spear and lay down casing. Recovered 7" casing; 13.21 -ft cut joint, 35.31 -ft full joint, 11.80 -ft twisted up joint 8 -ft up inside full joint, 80% of collar from 2,500 -ft MD, 60.32 -ft OAL (see pics in folder) 19:30 20:30 1.00 0 0 SLOT RPCOM OTHR P Confer with town engineer to discuss options. 20:30 00:00 3.50 0 0 SLOT RPCOM OTHR P Prep for Junk Mill run(s) order out tools from Prudhoe, conditon pits to 35 yield point, change over pump liners 4 -1/2" to 5 -1/2 ". Clean and clear floors X9/08/2012 Prep to run Bladed Junk Mill. Time mill from 2,517 -ft to 2,522 -ft. Ran 6 -1/8" Casing Swage to 2,538 -ft. 00:00 00:30 0.50 0 0 SLOT RPCOM OTHR P Continue to wait on tools from Prudhoe, change over pump liners 4 -1/2" to 5 -1/2 ". Clean and clear floors. 00:30 03:00 2.50 0 0 SLOT RPCOM OTHR T Drilling Tool House Truck delivering tools from Prudhoe broke down, continue to clean and organize rig. finish up installing 5 -1/2" liners in 2nd pump, seawater Yeild Point to 35 in pits. 03:00 04:00 1.00 0 0 SLOT RPCOM PULD P Bring in Tools. 04:00 04:15 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Bladed Junk Mill Assembly. 04:15 05:30 1.25 0 232 SLOT RPCOM PULD P PU MU 9.75" Bladed Junk Mill, XO, XO, 9.80" OD String Mill, Double Pin Sub, Tandem 8 -1/2" Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 2 stds. 6 -1/4" DC's, XO, XO. 05:30 07:00 1.50 232 2,414 SLOT RPCOM TRIP P RIH with 9 -3/4" Bladed Junk MITI Assembly on 4" DP down to 2,414' MD. Up Wt 83k / Dn Wt 80k, Continue down to 2,475' MS. Page 16 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:00 3.00 2,414 2,475 SLOT RPCOM CIRC P PJSM. Test Mud Pumps. Condition well w/ new pit system, 8.5 ppg, 90 Vis at 5 bpm, 380 psi. All old fluid system taken to the open top tank. Clean Shakers and Inspect magnets. 10:00 12:00 2.00 2,475 2,519 SLOT RPCOM MILL P Continue Down and tagged top of 7" Casing at 2,517' MD, PUH and set parameters, 12 bpm, 450 psi, 80 RPM, with 2300# Free Torque, 85k Rotating Weight, start milling down with 1 k WOB with 2600 to 2800 Torque. 12:00 14:30 2.50 2,519 2,521 SLOT RPCOM MILL P Time Mill down to 2,419' MD, apply 4k WOB with 2800# to 3000# Torque at 12 bpm,480 psi, 80 RPM 14:30 18:00 3.50 2,521 2,522 SLOT RPCOM MILL P Still Time Milling at 2,521' MD at 12 bpm, 460 psi, 80 RPM, 2800 to 3000 # Torque and 4k WOB. 18:00 18:30 0.50 2,522 2,502 SLOT RPCOM CIRC P Making very little progress at 2,522 -ft. PUH and monitor well 30 min. 18:30 19:45 1.25 2,502 232 SLOT RPCOM TRIP P TOOH w/ Junk Mill Assembly, 82k up / 79k do 19:45 21:00 1.25 232 0 SLOT RPCOM PULD P Lay down BHA #15, recovered several chunks of casing and approximtely 15 Ibs shavings in Boot baskets, Mill indicates casing stub wobbling possibly spinning. Confer with town engineer. 21:00 21:30 0.50 0 0 SLOT RPCOM OTHR P Clean and Clear floor. Bring in tools. 21:30 21:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making up 6 -1/8" Casing Swage Assembly. 21:45 22:15 0.50 0 574 SLOT RPCOM PULD P MU BHA #16- Bull nose, 6 -1/8" OD CSG Swage, XO, Bumper Sub, Jars, XO, 6 stds 4" HWDP. 22:15 00:00 1.75 574 2,538 SLOT RPCOM TRIP P RIH w/ BHA #16 on 4" DP to 2,525 -ft, Up 80k, Dn 75k. bring on pumps 4 bpm at 210 psi, wash down with 6k to 8k SO 2,526 -ft to 2,538 -ft set down 10k, PU with 1k overpull. 39/09/2012 TOOH with 6 -1/8" Casing Swage Assembly and 14.63 -ft of 7" Casing. Slip / Cut Drill Line. Time Mill 7" casing with Bladed Junk Mill from 2,537 -ft to 2,540 -ft. Clean out 7" casing from 2,540 -ft to 2,832 -ft. TOOH w/ Clean Out Assembly. 00:00 02:00 2.00 2,538 26 SLOT RPCOM TRIP P TOOH with BHA #16 from 2,538 -ft standing back DP and HWDP. 02:00 02:30 0.50 26 0 SLOT RPCOM PULD P On surface with 14.63 -ft of 7" casing with 80% of collar on bottom, remove fish from tools, lay down BHA #16 02:30 03:30 1.00 0 0 SLOT RPCOM OTHR P Clean and clear floor. Bring in fresh 9 -3/4" Bladed Junk Mill. 03:30 03:45 0.25 0 0 SLOT RPCOM SFTY P PJSM. Discuss Hazard for Making Bladed Junk Mill Assembly. Page 17 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:30 1.75 0 232 SLOT RPCOM PULD P PU MU BHA #17- 9.75" Bladed Junk Mill, XO, XO, 9.80" OD String Mill, Double Pin Sub, Tandem 8 -1/2" Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 2 stds. 6 -1/4" DC's, XO, XO. 05:30 06:00 0.50 232 232 SLOT RPCOM SVRG P Service Rig, change out pipe handler hose on top drive. 06:00 07:30 1.50 232 2,500 SLOT RPCOM TRIP P RIH with 9 -3/4" Bladed Junk MITI Assembly on 4" DP down to 2,500 -ft. 07:30 11:00 3.50 2,500 2,500 SLOT RPCOM SLPC P Hang Blocks and Slip / Cut Drill Line. 11:00 12:00 1.00 2,500 2,537 SLOT RPCOM CIRC P Wash down to 2,537 -ft, PU 86k, Dn 80k set perameters 8 bpm, 350 psi, 80 rpm, 2600# free torque. 12:00 14:00 2.00 2,537 2,540 SLOT RPCOM MILL P Mill down from 2,537 -ft 12 bpm, 490 psi, 80 rpm, WOB 6k with 2.5k to 3.5k torque to 2,540 -ft. 14:00 15:00 1.00 2,540 2,538 SLOT RPCOM CIRC P PU and pump 10 bbl sweep 12 bpm, 480 psi. Spot 10 bbl dry job. BDTD 15:00 17:00 2.00 2,538 232 SLOT RPCOM TRIP P PJSM- TOOH from 2,538 -ft with BHA #17 17:00 18:30 1.50 232 0 SLOT RPCOM PULD P LD BHA #17, good wear marks on bottom of Junk Mill of 7" casing stub. 18:30 19:00 0.50 0 0 SLOT RPCOM OTHR P Clean and Clear Floors. 19:00 20:15 1.25 0 505 SLOT RPCOM PULD P PJSM- PU MU BHA #18- 6 -1/8" tappered mill, 6.151 string milli, XO, 1 std 4" HWDP, XO, double pin sub, XO, tandem 8 -1/2" boot baskets, bit sub, bumper sub, jars, XO, 2 stds 6 -14" DC's, XO, XO. 20:15 21:00 0.75 505 2,496 SLOT RPCOM TRIP P RIH w/ 7" casing clean out assembly on 4" DP to 2,496 -ft, Up 90k, Dn 80k. 21:00 22:30 1.50 2,496 2,823 SLOT RPCOM WASH P Wash down from 2,496 -ft 4 bpm, 220 psi, 10 rpm w/ 15k free torque and encontered debris /junk at 2,550 -ft, continue in hole with 2k to 3k SO to 2,823 -ft. 22:30 23:00 0.50 2,823 2,823 SLOT RPCOM CIRC P Circulate Bottoms Up. 23:00 00:00 1.00 2,823 978 SLOT RPCOM TRIP P TOOH from 2,823 -ft, Up 95k, Dn 80k with BHA #18 to 978 -ft 09/10/2012 Pilot Mill 7" Casing from 2,540 -ft to 2,584 -ft. 00:00 00:30 0.50 978 505 SLOT RPCOM TRIP P Continue TOOH from 978 -ft with BHA #18. 00:30 02:00 1.50 505 0 SLOT RPCOM PULD P LD BHA #18 cleanout assembly and inspect 02:00 03:00 1.00 0 0 SLOT RPCOM OTHR P Clean and clear floor. Off load and Bring in tools. 03:00 04:00 1.00 0 195 SLOT RPCOM PULD P PJSM- PU MU BHA #19- 8 -1/4" Pilot Mill, Bit Sub Bore for Float, lea. 6 -1/4" DC, XO, 8 -1/2" String Mill, XO, 5ea. 6 -1/4 "DC's, XO, XO Page 18 of 43 • • Time Logs Date From To Dui S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:15 1.25 195 2,540 SLOT RPCOM TRIP P RIH with BHA #19 8 -1/4" Pilot Mill Assembly on 4" DP, tag up on top of 7" casing stub at 2,540 -ft, PU set parameters 12 bpm, 420 psi, 80 rpm w/ 2.5k free torque, ROT Up 83k, Dn 78k. 05:15 10:45 5.50 2,540 2,557 SLOT RPCOM MILL P Mill down at 2,540 -ft to 2,557 -ft - flow line packed off - creating an 8 bbl spill into cellar and secondary containment, this was not an agency reportable spill. 10:45 13:00 2.25 2,557 2,557 SLOT RPCOM OTHR T Clean up 8 bbl viscous sea water spill in secondary containment and dis -lodge metal cuttings packed off in flow line. 13:00 19:00 6.00 2,557 2,573 SLOT RPCOM MILL P Continue to Mill down at 2,557 -ft to 2,573 -ft w/ BHA #19 (8 -1/4" Pilot Mill Assembly) on 4" DP at 12 bpm, 420 psi, 80 rpm w/ 2.5k free torque, ROT Up 83k, Dn 78k. 19:00 20:00 1.00 2,573 2,573 SLOT RPCOM OTHR P Jetting Flowline not enough, Shut down to clear flowline of metal shavings. 20:00 23:00 3.00 2,573 2,584 SLOT RPCOM MILL P Continue to Mill down at 2,573 -ft to 2,584-ft w/ BHA #19 (8 -1/4" Pilot Mill Assembly) on 4" DP at 12 bpm, 430 psi, 80 rpm w/ 2.5k free torque, ROT Up 83k, Dn 78k. 2.5k to 3.5 k Milling TD TQ w/ 3k to 4k WOB, 3.5k to 4.5k Milling TD TQ w/ 8k to 10k WOB 23:00 00:00 1.00 2,584 2,584 SLOT RPCOM OTHR P Jetting Flowline not enough, Shut down to clear flowline of metal shavings. 39/11/2012 Pilot Mill 7" Casing from 2,584 -ft t 2,589 -ft. TOOH w/ Pilot Mill Assembly. Preform Weekly BOPE Test. 00:00 01:30 1.50 2,584 2,584 SLOT RPCOM OTHR P Continueing clear flowline of metal shavings.found ball in buterfly valve. established good fluid movement through flowline. 01:30 04:30 3.00 2,584 2,589 SLOT RPCOM MILL P Continue to Mill down at 2,584 -ft to 2,589 -ft w/ BHA #19 (8 -1/4" Pilot Mill Assembly) on 4" DP at 12 bpm, 430 psi, 80 rpm w/ 2.5k free torque, ROT Up 83k, Dn 78k. 2.5 to 3.5 k Milling TD TQ w/ 3 to 4k WOB, 3.5 to 4.5k Milling TD TQ w/ 8 to 10k WOB. Sporatic milling due to flowline packing off so easily. 04:30 05:30 1.00 2,589 2,566 SLOT RPCOM CIRC P PU off 7" CSG stub and Circulate Bottoms up at 12 bpm at 440 psi. 05:30 06:30 1.00 2,566 2,566 SLOT RPCOM SVRG P Change out grabber box dies and service Top drive. 06:30 08:00 1.50 2,589 226 SLOT RPCOM TRIP P TOOH to BHA #19 at 226 -ft Page 19 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 226 226 SLOT RPCOM CIRC P MU top drive and circulate while rotating 12 bpmn at 100 psi to clean metal debris by turbulent flow thru BOP stack in preparation for cleaning BOP stack prior to Weekly BOP test. 08:30 09:30 1.00 226 0 SLOT RPCOM PULL P TOOH with BHA #19 standing back DP, DC's and lay down mill assembly. 09:30 10:30 1.00 0 SLOT RPCOM OTHR P Clean and Clear work area of non- needed fishing tools. Load string magnets for washing bop stack w/ snozzelator tool. 10:30 13:00 2.50 0 0 SLOT RPCOM CIRC P PU and MU BOP wash tool and wash BOP stack while rotating and reciprocating at 4 bpm at 1,200 psi, cleaning string magnets multiple times. Break down and lay down wash tools. 13:00 13:30 0.50 0 0 SLOT WELCTL PRTS P Close blind rams and pressure test integrity of 10 3/4" and 7" casing against cement plug at 1,500 psi for 15 minutes - good test - 75 psi lost then straight line on chart. Bleed off pressure and open Blind rams 13:30 16:30 3.00 0 0 SLOT WELCTL OTHR P Drain BOPE stack, set test plug, open BOP ram doors and inspect for metal shavings from 7" csg milling and wash out cavities 16:30 18:00 1.50 0 0 SLOT WELCTL BOPE P Rig up test equipment. Obtain Shell Test On Stack, 250/3000 psi. 18:00 00:00 6.00 0 0 SLOT WELCTL BOPE P Start weekly BOP Test 250/3000 psi w/ 4" and 3 -1/2" Test Joints. Perform Annular test. 24 hr notice was given, witness was waived by Jeff Jones at 17:55 on 9/11/2012. D9/12/2012 Complete Weekly BOPE Test. Continue to Pilot Mill 7" Casing from 2,589 -ft to 2,636 -ft 00:00 01:00 1.00 0 0 SLOT WELCTL BOPE P Complete BOP Test 250/3000 psi w/ 4" and 3 -1/2" Test Joints. Perform Annular test and Draw down test. System pressure = 3,100 psi After closure = 1950 psi 200 psi build = 17 seconds Full system pressure = 95 seconds 4 bottles N2 = 2100 psi. 01:00 01:30 0.50 0 0 SLOT WELCTL OTHR P PJSM- Rig down test equipment. Pull Test Plug 01:30 02:30 1.00 0 195 SLOT RPCOM PULD P PJSM- PU MU BHA #20- 8 -1/4" Pilot Mill (2nd run from BHA #19) Bit Sub Bore for Float, lea. 6 -1/4" DC, XO, 8 -1/2" String Mill, XO, 5ea. 6 -1/4 "DC's, XO, XO Page 20 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 195 2,586 SLOT RPCOM TRIP P RIH with BHA #20- 8 -1/4" Pilot Mill Assembly on 4" DP, tag up at 2,586 -ft, PU set parameters 12 bpm, 440 psi, 85 rpm w/ 2.5k free torque, ROT 81k, Up 83k, Dn 78k. 03:45 06:00 2.25 2,589 2,595 SLOT RPCOM MILL P Mill down at 2,589 -ft to 2,595 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 12 bpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 7k WOB jetting flowline every 15 minutes. 06:00 18:00 12.00 2,595 2,618 SLOT RPCOM MILL P Mill down from 2,595 -ft to 2,618 -ft w/ BHA #20 ( 8 -1/4" Pilot Mills 2nd run) on 4" DP at 12 bpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 7k WOB jetting flowline continuously 18:00 00:00 6.00 2,618 2,636 SLOT RPCOM MILL P Mill down from 2,618 -ft to 2,636 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 12 bpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 8k WOB jetting flowline continuously 09/13/2012 Continue to Pilot Mill 7" Casing from 2,636 -ft to 2,690 -ft. 00:00 06:00 6.00 2,636 2,654 SLOT RPCOM MILL P Mill down from 2,636 -ft to 2,654 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 504 gpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 8k WOB jetting flowline continuously. 06:00 12:30 6.50 2,654 2,670 SLOT RPCOM MILL P Mill down from 2,654 -ft to 2,670 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 504 gpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 8k WOB jetting flowline continuously, fighting to maintain fluid properties. 12:30 15:30 3.00 2,670 2,670 SLOT RPCOM COND P bring on 150 bbls of sea water visc up same. 15:30 20:00 4.50 2,670 2,687 SLOT RPCOM MILL P Mill down from 2,670 -ft to 2,687 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 504 gpm, 420 psi, 85 rpm, 3 to 4k Milling TD TQ w/ 8k WOB jetting flowline continuously, still fighting to maintain fluid properties. 20:00 21:00 1.00 2,687 2,687 SLOT RPCOM CIRC P Pump 20 bbl Hi -Vis sweep 580 gpm, 550 psi. Change out shaker screens 21:00 22:00 1.00 2,687 2,687 SLOT RPCOM PRTS P Test 10 -3/4" Casing integrity to 1500 psi on chart, good 15 minutes. install diverter plate. 22:00 00:00 2.00 2,687 2,690 SLOT RPCOM MILL P Mill down from 2,684 -ft to 2,690 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at Up 85k, Dn 80k, 546 gpm, 440 psi, 90 rpm, 3 to 4.5k Milling TD TQ w/ 8k WOB jetting flowline intermittently. 09/14/2012 Complete Pilot Milling of 7" Casing from 2,690 -ft to 2,750 -ft. TOOH with Pilot Mill Assembly. Page 21 of 43 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 06:00 6.00 2,690 2,710 SLOT RPCOM MILL P Mill down from 2,690 -ft to 2,710 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 580 gpm, 460 psi, 90 rpm, 3 to 4.5k Milling TD TQ w/ 8k WOB jetting flowline intermittently, pumping Hi -visc sweep every 5 -ft milled. 06:00 20:30 14.50 2,710 2,750 SLOT RPCOM MILL P Mill down from 2,710 -ft to 2,745 -ft w/ BHA #20 (8 -1/4" Pilot Mills 2nd run) on 4" DP at 580 gpm, 500 psi, 100 rpm, 3 to 4.5k Milling TD TQ w/ 8k WOB jetting flowline intermittently, pumping Hi -visc sweep every 5 -ft milled. 20:30 22:00 1.50 2,750 2,750 SLOT RPCOM CIRC P Circulate bottoms up 3X volume w/ 40 bbl weighted (11 ppg) Hi -visc sweep while reciprocating DP. 22:00 23:30 1.50 2,750 194 SLOT RPCOM TRIP P TOOH w/ BHA #20 Pilot mill assembly standing back 4" DP. 23:30 00:00 0.50 194 40 SLOT RPCOM PULD P Change over floors, stand back 6 -1/4" DC's. 39/15/2012 Lay Down Pilot Mill Assembly. Wash BOPE Stack. Single down 3 -1/2" Tubing f/ Derrick. Load, Drift and Tally 5" HWDP. Test BOPE for 5 ". Run 10 -3/4" Scraper Assembly. 00:00 00:30 0.50 40 0 SLOT RPCOM PULD P Lay Down Pilot Mill Assembly. Pilot worn to 6.0" OD, Blades worn to 7.8125" OD, Mill Blades cut out 2.625" up from bottom. 00:30 02:30 2.00 0 0 SLOT RPCOM OTHR P Clean and Clear floor, MU up wash tool and wash BOPE Stack. Change over floors. 02:30 05:30 3.00 0 0 SLOT RPCOM TRIP P PJSM- RIH with 11 stands of 3 -1/2" De- completion tubing used for cement stinger and 6 stands of 4" HWDP from derrick, Single out same. 05:30 07:00 1.50 0 0 SLOT RPCOM OTHR P PJSM- Bring in 30 jts 5" HWDP, Drift, and Tally same. 07:00 09:00 2.00 0 0 SLOT RPCOM OTHR P Wash BOP Stack of metal shavings and milling debris. 09:00 10:00 1.00 0 0 SLOT RPCOM OTHR P Attempt to set test plug and found that ram spacing would not allow for the use of 5" HWDP - lay down test plug and call out test joint. Load Baker tools in mean time. 10:00 14:00 4.00 0 0 SLOT RPCOM OTHR T 5" test joint arrived, load on rig floor. MU to test plug and RIH - found test joint to be to short for rig design, lay down same, call out for 1 joint of 5" Drill pipe. 14:00 16:00 2.00 0 0 SLOT RPCOM BOPE P Load joint on rig floor and make up to test plug, RIH and land in profile. RU test equipment and test VBR's and annular at 250 / 3,000 psi. RD test equipment. 16:00 20:45 4.75 0 1,179 SLOT RPCOM PULD P PU and MU BHA #21 (Whipstock gauge run and cleanout assy) RIH picking up 5" HWDP to 1,179 -ft. Page 22 of 43 • • Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 20:45 22:30 1.75 1,179 2,594 SLOT RPCOM PULD P Continue to RIH w/ BHA #21, PU remaining 4" DP from pipe shed, Took weight, 5k at 2,594 -ft. 22:30 00:00 1.50 2,594 2,690 SLOT RPCOM CIRC P Kelly up and set parameters 110k Up, 97k Dn, 110k ROT, 60 rpm, 420 gpm at 530 psi, 3.5k free torque, RIH from 2,594 -ft, 4 to 4.5k TD torque, 8- 10k WOB to 2,690 -ft, good cement returns over shakers. 39/16/2012 Run 10 -3/4" Scraper Assembly. Circulate Well. P/T 10 -3/4" Casing. TOOH w/ Scraper Assembly. Wash BOPE Stack. RU E -line. Run CCUGR Log. RD E -line. Prep to Run Whip stock. MU and Run 10 -3/4" Whip stock 00:00 00:30 0.50 2,690 2,690 SLOT RPCOM CIRC P Circulate bottoms up 504 gpm, 625 psi. 00:30 01:30 1.00 2,690 2,750 SLOT RPCOM MILL P RIH from 2,690 -ft, 110k Up, 97k Dn, Rot 110k, 60 rpm, 504 gpm at 625 psi, 3.5k free torque, 4 to 4.5k TD torque, 8 to 10k WOB to 2,750 -ft with good returns. 01:30 02:30 1.00 2,750 2,750 SLOT RPCOM CIRC P Circulate bottoms up 4X volume w/ 40 bbl weighted (11 ppg) Hi -visc sweep while reciprocating DP. 02:30 03:15 0.75 2,750 2,750 SLOT RPCOM PRTS P RU test equipment. Pressure Test 10 -3/4" Casing to 1500 psi for 30 min on chart. Rd test equipment 03:15 05:00 1.75 2,750 262 SLOT RPCOM TRIP P PJSM- TOOH w/ BHA #21 Scraper / Clean Out Assembly standing back 4" DP and 5" HWDP 05:00 07:00 2.00 262 0 SLOT RPCOM PULD P Lay down BHA #21, clean magnets, empty boot baskets. 07:00 09:00 2.00 0 0 SLOT RPCOM OTHR P Clean and Clear work floor 09:00 11:00 2.00 0 0 SLOT RPCOM OTHR P With double barriers in place, Set test plug and wash BOPE at 4 bpm at 1,200 to 1,400 psi 11:00 13:00 2.00 0 0 SLOT RPCOM OTHR P Open BOP Cavity doors. Clean and inspect. Close up doors 13:00 14:00 1.00 0 0 SLOT RPCOM BOPE P Install test jt and RU test equipment and test at 250 / 3,000 against annular to cover all ram cavity doors that were opened for inspection. RD test equipment. 14:00 15:00 1.00 0 0 SLOT RPCOM OTHR P load and Install dutch riser for RU of Eline. 15:00 19:00 4.00 0 0 SLOT RPCOM PULD P Held PJSM w/ eline and rig crew on RU of eline. RIH w/ CCL and GR to 2,800 -ft and log out of the hole for verification of 10 3/4" CSG collars and 7" Casing stub. RD Eline and pull Dutch riser. 19:00 19:30 0.50 0 0 SLOT RPCOM OTHR P Off load tools, verify 10 -3/4" casing collars and prep to run whip stock. 19:30 20:00 0.50 0 0 INTRMI WHPST SFTY P PJSm- Discuss hazards with make up and running of whip stock. 20:00 21:00 1.00 0 0 INTRMI WHPST WPST P PU MU Milling assembly and MWD with float and UBHO sub. Page 23 of 43 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 0 0 INTRMI WHPST WPST P Scribed mills to MWD and had 68.226 offset from mill to MWD, alligned lug in UBHO sub to scribe line. PU and set tools aside. 21:30 22:00 0.50 0 0 INTRM1 WHPST WPST P PU 25 -ft of 7" spacer joint with bull nose and set in hole. PU 10 -3/4" whip stock and MU to 7" casing spacer joint with Baker Lock. 22:00 23:00 1.00 0 48 INTRM1 WHPST WPST P Witness removal of shippig bolt and 3 shear bolts in anchor assembly, 3 3 shear bolts left in anchor assembly at 20k shear. Set whip stock on handleing bar in rotary table, PU milling assembly and bolt mills to whip stock, bolt 45k shear, PU and remove handleing bar. 23:00 00:00 1.00 48 317 INTRMI WHPST WPST P RIH assebeling BHA #1 to drill collars. Up wt. 55k J9/17/2012 Continue to run 10 -3/4" Whip stock Assembly. Orientate and Set Whip stock. Mill Window in 10 -3/4" Casing from TOW @ 2,701 -ft to BOW @ 2,721 -ft plus 10 -ft of OH to 2,731 -ft. Perform LOT. EMW =14.3 ppg. POOH and lay down Milling BHA. 00:00 00:15 0.25 347 347 INTRMI WHPST WPST P Perform shallow pulse test 504 gpm at 650 psi. good per MD Rep. 00:15 03:30 3.25 347 2,660 INTRMI WHPST WPST P RIH w/ Whip stock from 347 -ft to 2,660 -ft 03:30 05:00 1.50 2,660 2,750 INTRMI WHPST WPST P Obtain do wt of 100k, Up wt of 125k with pumps off. 98k do wt and 122k up wt with pumps on. Orient whip stock face to 61° LHS and set anchor with 18k slack off pumps on. overpull 15k pumps on and shear 45k Brass shear screw w/ 50k slack off pumps on. Pick up off whip stock with Top at 2,701 -ft and bottom of slide at 2,721 -ft. 05:00 12:30 7.50 2,701 2,731 INTRM1 WHPST WPST P Held Pre -spud with crew coming on tour for early crew change day prior to milling operations. Held crew change out, gather parameters, Up 125k, Dn 100k ROT 110k, 5k free torque, 80 rpm, 450 gpm, 1000 psi, begin milling ahead from 2,701 -ft Mill torque 6 to 10k, WOB 8 to 10k to 2,731 -ft, Up wt 125k, Dn wt 100k, ROT 110k, Torque off bottom 5k. 12:30 14:00 1.50 2,731 2,696 INTRMI WHPST WPST P Work mill through window pumps on, ROT on /off with no bobbles, reciprocate pipe pumping 35 bbl Hi -visc super sweep, PUH to 2696 -ft and circulate hole clean. Page 24 of 43 '4110 57-[zi WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gamma Ray / Casing Collar Locator: 3H -11 Run Date: 9/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20091 -00 sat4t4ED ,4PR 0 8 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: 011,412 12 Signed: )/ i v�. ✓,-'' Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 31, 2012 11:10 AM To: 'Myers, Monty M' Cc: Regg, James B (DOA) Subject: RE: 3H -11A BOPE Question? (PTD 187 -124) (212 -062) Monty, I looked at the procedure... there is no detail in there about pulling the BOP stack and tubing spool to pull 7" casing. ( It can be inferred and you provided the Wellhead showing a 3000 psi 11" flange that would be used for the BOP stack after the tubing spool is pulled.) That detail should have been spelled out in the procedure and requested a lower pressure in writing. There is no other option: test to 3000 psi .. assume you are testing against the 7" plug set at 4900' md. Document reasons in BOP test report submitted and reference this email. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Myers, Monty M [mailto:Monty.M.Myers @conocophillips.com] Sent: Friday, August 31, 2012 10:34 AM To: Schwartz, Guy L (DOA) Subject: 3H -11A BOPE Question? Guy, I am covering the 3H -11A (Permit# 212062, API# 50- 103 - 2009- 01 -00) for Haibin Guo while he is out of the office. A question came up this morning about the BOP test that I need to discuss with you. We have written in the permit to test the BOP stack to 3500 psi, but after we nipple down the tubing head to perform our 7" casing cut and recover, we will not be able to install a test plug in the casing head to isolate the spool below us that is only rated to 3000 psi. My question is, can we use 3000 psi for our test in this section? We will be working in cased and cemented hole while recovering the 7" csg. Thanks. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907265.6318 office 907.538.1468 cell 8/31/2012 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 31, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Circumferential Acoustic Scanning Tool: 3H -11 Run Date: 8/29/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -11 Data in LAS /DLIS format, Digital Log Image files 1 CD Rom 50 -103- 20091 -00 CASE Log 1 Color Log 50 -103- 20091 -00 SCANNED APR 0 8 2013 ACE Log 1 Color Log 50- 103 - 20091 -00 CAST -M Field print ,. 1 Color Log 50- 103 - 20091 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: 2 , - 110 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 24, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log/Jet Cut: 3H -11 Run Date: 7/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -11 Data in LAS format, Digital Log Image files ,,,,.. 1 CD Rom 50- 103 - 20091 -00 Cement Bond Log 1 Color Log 50 -103- 20091 -00 %MANED APR 0 8 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: </7- 9 12- Signed: ajt,44 • 116 , •- - WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 15, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log - SpectraFlow: 3H -11 SCANNED APR 0 8 2013 Run Date: 6/14/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20091 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1 Signed: 1 `' • Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, June 19, 2012 11:11 AM To: Wiese, Tyson M' Subject: RE: 3H -11 Sundry Variance (PTD 187 -124) Tyson, The change in the approved sundry will required a variance per 20 AAC 25.112 (1) . You have approval to proceed as outlined in the below email. The A and C sand will still be adequately isolated to effectively plug the well and prevent fluid movement into sources of hydrocarbons or freshwater. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wiese, Tyson M [mailto:Tyson.M.Wiese @conocophillips.com] Sent: Tuesday, June 19, 2012 11:01 AM To: Schwartz, Guy L (DOA) Subject: 3H -11 Sundry Variance Guy, S ; NNED JUL &, Z O a Sundry Reference #: 312 -174 On 6/9/2012, multiple leaks were found in the 7" production casing. A passing MIT -T to 2,000 psi was recorded on 6/6/12, with a plug set in the nipple @ 7,339' KB, isolating the A -sand perfs. A passing MIT - OA to 1,800 psi was recorded on 6/7/12. A fish was dropped into the catcher sub @ 7,319' KB, and 30' of additional fill was later found on top of the catcher. Slickline was able to bail down and pull the catcher and fish, but was unable to pull the XXN plug isolating the A- sands. Because the XXN plug @ 7,339' KB was unable to be pulled, no cement will be squeezed into the A -sand perfs as indicated on the original Sundry. The current plan forward too cement the Kuparuk C -sands complies with all relevant plugging regulations. The TOC will be at approx. 5,800' KB (1,470' above the top perforation) Due to the recent change from the original plan forward, I wanted to keep all parties informed. Please let me know if you need a sundry variance letter of any kind from us to proceed with the plug for redrill. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 -263 -4250 Celt:1- 907 - 230 -5388 6/19/2012 r „ ,71; rrp , r'T ir SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, 7) 279-1433 ALASKA 99501-3539 PHONE (90 FAX (907) 276-7542 Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-11 Sundry Number: 312-174 SLANNEDmAY 1 8 2. Dear Mr. Wiese: 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, P)6(/h Cathy P. Foerster Chair WA- DATED this II day of May, 2012. Encl. STATE OF ALASKA D 3'/i/J /2 RECEIVED , ALA OIL AND GAS CONSERVATION COMMI�N ��,,yy MAY 0 4 2012 APPLICATION FOR SUNDRY APPROVALS OrW 20 AAC 25.280 4 'ry/y 2 - A aQ 1. Type of Request: Abandon r Plug for Redrill r • Perforate New Pool r- Repair w ell r Change Ap Suspend [ Plug Perforations r Perforate r Pull Tubing r Time Extension E Operational Shutdown E Re -enter Susp. Well r Stimulate r Alter casing J Other: 1® 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ];r • Exploratory r 187 - 124 • 3. Address: Stratigraphic r Service 1 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20091 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No fY 3H -11 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25531 ' Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7750 • 6460 • 7635' 6363' Casing Length Size MD ND Burst Collapse CONDUCTOR 81 16 115' 115' SURFACE 3602 10.75 3637' 3088' PRODUCTION 7683 7 7716' 6432' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7274'- 7304', 7371'- 7383', 7391'- 7411', 7430'- 7450' 6059'- 6085', 6141' - 6151', 6158'- 6175', 6191' -6208' 3.5 L-80 7346 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER FHL RETRIEVABLE PACKER MD= 7139 TVD= 5946 PACKER - BAKER FB -1 85 -40 PACKER MD= 7328 ND= 6105 PACKER - OTIS 'WD' PACKER W /5' SEAL BORE EXTENSION, XO MD= 7339 TVD= 6114 NIPPLE - CAMCO DS NIPPLE MD =507 ND =507 12. Attachments: Description Summary of Proposal r' 13. Well Class after proposed work: J �,� Detailed Operations Program r BOP Sketch Explora r Developm ly t / „ 4•7 /v' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: ' / 6/1/2012 Oil r Gas r WDSPL r Suspended I'" / Y 16. Verbal Approval: Date: WIND GINJ WAG r Abandoned r 5 ` Commission Representative: .5'1. ( . GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name T ■ on Wiese Title: Wells Engineer Signature Phone: 263 -4250 Date ©S — b3 -- II, Commission Use Only Sundry Number31Z• n L f Conditions of approval: Notify Commission so that a representative may witness Plug Integrity x BOP Test Alf Mechanical Integrity Test [j Location Clearance r Other 35 t '4' / 0,5 DeP ,5t 1V°'f-/ / "5pr' fc.),i !S 1✓1C.IIeel, f--,d Subsequent Form Required: /0 -' 4-i" . ),?,.6.0.../ THEROVED SY _ J) Approved by: (lt '^" COMMISSIONER THE COMMISSION Date: 5 (( lZ-- Form 10 -403 Revised 1/2010 �� ® � � MAY • in Duplicate ORIGINA1 . • • 3H -11 Pre Rig Plug Back for Redrill Permit to Drill #: 187 -124 The objective of the proposed 3H -11 Plug Back is to prepare the well for the rotary side track planned for June 2012, which will include crossing a 60ft sealing fault, converting the well to an injector, and drilling CTD laterals in A2 and A3 sands. This will provide water flood support to 3H- 10C, 3H -34, and 3H -14B, in an area with limited to no active water flood. Proposed Plug back Procedure: (Pre Rig) Slick Line / Little Red: 1. RIH and set plug in XN nipple @ 7,339' KB, Set BPI in AVA nipple @ 7,319' KB. 2. Pull DMY from GLM #5, GLV from GLM #1, and OV from GLM #2. 3. Dummy off GLM's #1 -2, ensure sliding sleeve @ 7,180' KB is closed. 4. Pump 250 bbls of Diesel down the tubing, Dummy off GLM #5. 5. Perform MIT -T to 2,000 psi and MIT -IA to 1,500 psi. Pull DMY from GLM #5. 6. Pull BF�,'11 from AVA nipple, open sleeve @ 7,180' KB, and pull plug from XN nipple. Coil Tubing: 1. Ensure that the 10 -403 Sundry has been approved by AOGCC. 2. RIH and set cement retainer @ a roppx. 7,164' KB. (mid joint below top packer) 3. Perform Injectivity test to ensure adequate rates for cementing operations. 4. Pump 20 bbls of 15.8# cement into the A and C Sand perforations, sting out of retainer, ` PUH to 7,070' KB, and pump 13 bbls (350 ft) of 15.8# cement into tubing and annulus . on top of packer, through GLM #5 @ 7,073' KB. 5. While POOH, lay in tubing freeze protect from 2,500' KB to surface. Slick Line / Little Red: 1. WOC at least 24 hours prior to tag and test. 2. Notify AOGCC Inspector. (659 -2714; 659 -3607 pager) of the timing of the post- cement plug tag and PT. Provide at least 24 hour notice. t 3. Tag TOC @ approx. 6,789' KB. 30 � ,,, 4. Test cement plug to 2,000 psi. MIT -IA to 1,500 psi. Record Results. ' r ehav r 5. Perform a drawdown test bleeding down the tubing, IA, and OA. 6. Pull DMY valve from GLM #4 @ 6,678' KB. 7. Circulate 151 bbls of 11# corr. inhibited brine (KWF), followed by 88 bbls of Diesel. 8. Jumper IA and Tubing at Surface and allow diesel to U -tube for freeze protect. 9. Reinstall DMY valve in GLM #4 @ 6,678' KB. E -line / Little Red / FMC: 1. RIH w/ Jet Cutter and cut tubing at approx. 5,197' KB (270' below the planned 7" B.P. set depth). Pressure up (or bleed off) tubing to verify communication. 2. RD E -Line and LRS. RU FMC and set BPV. � � t5 �I1Jr,'� , �fg 2O/) 4 q �6 �G ,if „,f. 1,,,,, lib /00 h , y �. Qv4d d o(i, �' 1� , ar ./�c� -P/ /�' C� - P, �``o�' T4 i y'764-,ack* 1 well clove,/ c � TW Poi Pail of 7h / OW ---€ -7,:_--• III • 3H -11 Pre and Post Plug Back for Redrill Current Completion Proposed Pre Ria ST P &A _J____ Cameo DS Nipple a. . 507' KB 9.) Set BPV I L 9 518` 36# J-55 Casing @ 3,637' KB Al F. , .- 8 Cut Tubing @ approx. 5,197' KB GL61: GLV(Pre) DMY(Post) @ 2,929' KB 7.) Eire. in 11# KWF and F.P. _D OV(Pre) DMY(Post) @ 4,797' KB DMY @ 5,910' KB Install DMY in GLM #4. DMY @ 6,678' KB 6.) Pull DMY from GLM #4 DMY @ 7,073' KB a 5.) TaglTest TUC C) approx. j reei 6,789` KB, with witness 4.) Sting out, PUH, and pump 13 bbl / %! 1.) Pahl DMY from GLM (350 ft) of cement into tubing and iA �j Al #5 ? 7,073' KB above packer through GLM #5 ��,� r iaa�l = r x..1 #4 FHL Packer @ 7.139' KB TIMINI=M11111T ' 3.) Squeeze 20 into C L y,, e, t through retainer into ! I 2.) Set Cement Retainer rear OM Y■ t a e «ti Baker CMU Sliding Sleeve and C Sand Perfs. bbls 0 approx. 7,164' KB • @ 7,180'KB _ C Sand Perfs: rry a •...�_ 7.274'- 7,304'KB : te r 400 - °--- 314" 9.3# L -80 @ 7.311' KB titat AVA Ported Nipple �a 7,319 KB '^ Baker FB 18540 Packer i - '- • 7,328' KB ®r — 44 xas „,,,, •/,,/, Otis ti4D Perm. Packer @ --..i.gus 7,339' KBinrwrw�- 2 718” Cameo D N pple @ AC / 0/4 Il 7,356' KB 4 t• 'AEG @7,356'KB ''..7' i•i-Zi.-.-- .....4 ,,,,iii.iiiiii'iri A Sand Perfs: em. 7,371'- T,383' KB u ''''..r" �. ,.. � . t — =..�- 7,391' - 7,411' KS ",,i. 7,430' - 7,450 KB / . '-..: ` -a7'"'"' Tag Fill rn` 7 .458' KB -- - -- 1,',4.„,- ' i S u + i►. T Prod. Casing TD @ 7,716' KB TW 04 -13 -2012 - 4 - 11 ( ?) (0,038 is) 0 - - 7131 t ) 1 • /5 fI TW 0 35s 3 h h'1s') ( 1 31 - 6 7 4M 1 ) /3' y b 4113 ¢r 35 ' • • 3H -11 Rotary Sidetrack Program (mill window plus 20' of new formation) 1. Move Nordic 3 on 3H -11 and rig up. 2. Pull BPV and VR plugs. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. ❑ Notify AOGCC field inspector 24 hours prior to BOPE test. ❑ Test BOPE to 250 psi low / 3,500 psi high as per drilling permit. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3 -1/2" completion. 5. Run 7" casing scraper to +/- 5,000' MD. 6. Run CBL in 7" casing to +/- 5,000' MD. 7. Set 7" bridge plug at +/- 4,930' MD. 8. Cut 7 "casing at +/- 4,900' and pull 7" packoff. 9. Lay down 7" casing. 10. RIH to top of cut at +/- 4,900' with DP and pump +/ -110 bbls of Class G cement plus additives at 17.0 ppg for kick off plug. o q 47 a /Ft z um) 'if- "'^ � 11. POOH and WOC minimum of 12 hrs 31_ y`co 12. While WOC prep directional tools and PU bit, motor and MWD tools and perform CO housekeeping. 13. Run in hole kick off BHA to top of cement plug and dress it off to +1- 3,800'. . I 14. Orient MWD and motor and begin to drill off of cement kick off plug j 15. Drill 20' into new formation. Perform LOT with rig pump as per CPAI procedure up to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. l'U Pil ..(Z — a4.Z TW • • 311 -11A Slot Recovery Proposed Schematic 16° conductor set at 115" Schlumberger TRMAXX -CMT SCSSV a 1,930' MD,' 1,800' TVD 10 - X 7" Arctic Pack on 12129/87 49 bbls cement +110 bbls Arctic Pack Cement interface could be +.1- 2,260'. '';': 9.34. Cam; L -S0. EUE Tubing P 7" 50 trash over 7" to +1- 300' below 10 -3 .1 -55, 45.5# surface surface shoe to +11- 3.940" MD �b �L0 casing fix,' 3,637' MU• l'd TAM Port t 011:t r - :.700' MU vt.. 4 ,4„,veo „, •".,:, GLh4 it ND ft MD ft Valve Type 1 2.500 3,027 Dummy 2 3.700 4,450 Dummy Tabasco sand (03,950' - 4,300' _ 4,600 5,456 Dummy - 4 5,281 6 Dummy 5,781 7,023 SOV (annulus to tubing shear) Note- 5 ea Camco 342” x 1-1/2" A• 1MG 1'` I , \ N4 Port collar +/- 4,900' MD 100' Hi-Vis Pill @4,800 - 4,900' MI) • ' C'ut &Pull 7" i- 4,900' MD ' Cut &full plan if no cement behind original " bridge plug +1- 4.930' Ml) ill 7" Casing TOC a 5,500' MD ' 4.957' TVD 3 - tubing Cut (4). +1- 5,197' T(X' in 7" & 3 -'4'" tubing a ` -- / � 6,789' � it- 'Lower put of well toy be abandoned by coil before rig nwve uu / r. d 3'0" HES "X"' selective nipple w' 2.813" ID ft +/- 6,940' MD Cement Retainer +1- 7,164' MD Ili Baker ZXP liner top Packer@ 6,900' MD 5,821' TVD 111 0 I .\'7" 26# L80 BTGM casing set (topset) a 7,124' MD / 5,950' TIM 7" cement job on 12128187: 450 sks lead +200 sks tail.. Theoretical TOC +/- 3.716' (500o excess) No returns. ._ 4-1/2" 12.64 LSO IBT Liner set r - r a 7,512' MD i 6,255' TVD TW t • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art / or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 �/ form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and �/ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. c! file: / /F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 6/2/2011 • ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~Sa+J~tk~f yK~MSA~' t, . ~~ti Y . ~~U.: July 18, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ 1 ~ 7~~ a-`f 3~""~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found.to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the lreatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 26~`, 2009. The corrosion inhibitor/sealant was pumped June 30th & July 16th, 2009. The atta.ched spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. - Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Seatant Top-off Report of Sundry Operations (10-404) Kuparuk Fteld Date 7/18/09 3H, 31 & 3Q PAD Well Name API # PTD # Initial top o eement Vol. of cement um ed Final top of cement Cement top o date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27" NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/20~9 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 ~ 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 191126Q SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 RECE\VED 06/13/06 dUN 1 4 2006 Scblulllbe.ge, .\ \rt \~/,f~ NO. 3850 !\Iækli ŒI &. Ga$ Con!;, A,,(';hor~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .....~..l< Io.;¡i\¡¡t;>') \~. 1:~~~~.,"~L't,:..; ~"",'-i,,.1It ",~ .....-.--., 'f·~·f r~ f<l:':¡¡ IUU~j ¿:., :.:' ..... Field: Kuparuk Well Job# Log Description Date BL Color CD ! l;;' 3J-16 11249908 INJECTION PROFILE 06/03/06 1 1R-08 11249909 INJECTION PROFILE 06/04/06 1 3H-11 . 11213760 PRODUCTION PROFILE W/DEFT 05/31/06 1 1 R-07 11249912 PRODUCTION PROFILE 06/07/06 1 1 F-12 11320981 PRODUCTION PROFILE WIDEFT 06/06/06 1 3G-20 11249911 INJECTION PROFILE 06/06/06 1 2A-16 11213754 PRODUCTION PROFILE WIDEFT 05/25/06 1 2A-22 11213756 LDL 05/27/06 1 1Y -04 11320980 LDL 06/03/06 1 2Z-02 (REDOf 11235362 INJECTION PROFILE 05/28/06 1 1H-19 (REDO) 11320975 INJECTION PROFILE OS/29/06 1 2A-13 (REDO) 11320976 LDL 05/30/06 1 3J-09 11320977 INJECTION PROFILE 05/31/06 1 1F-17 11249913 PRODUCTION PROFILE W/DEFT 06/08/06 1 1 J-170 11320983 USIT 06/11/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r / .(J~~/,--_. () / 1'1(t~ e e ~'-.I...J. ...UJ.-V,J e e Subject: RE: From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 09 Mar 200414:01:53 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom: I forwarded your request to town, I think I can get someone to find some data for you on 3H-11. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 09, 2004 1 :49 PM ~~~f:~t~~~';~_~ell Supv ~ ~'"1- \Ó- ~ ----------- ,- I have looked at the 3H-ll file and I would agree that I doubt if another electo-coil will be deployed. I found Mike Winfree's justification letter. Oh well, it was a good idea at the time. We both have had a few ofthem. In looking through the file, I cannot find any work reports for the CT fishing job for the electro-coil or the running of the usn that you mentioned. I am not sure that you are the one that would/could provide that information, however I would appreciate someone sending in those work reports so we can complete the files. I still need to check the log file for the UIST. That is something that should be in the file as well. I will get back to you on that. Tom NSK Problem Well Supv wrote: I' v Tom: I don't know about actual run time of the ECT, but I do have dates the equipment was ran. 3H-11 was ran in May 1999. 3H-05 completion was ran in April of 2000. So it is a little newer, but not much. I am not sure if it makes any difference how long the ECT pumps actually ran, but exposure to wellbore fluids is our main concern. I understand that lab analysis of the fluids indicates 3H-05 should not be as corrosive as 3H-11 was, but we are not banking on that. The experience with 3H-11 was that as the CT was pulled over the goose-neck it would break, being held together just with the internal cable. It was a real mess. This time they will either pull straight pieces and cut them as they come out, or use tubing-conveyed wash pipe to overshot the CT to pull. It all depends on if they can unstring the pump from the downhole receptacle. The pump sits in a "packer-type" receptacle that may not budge. If that is the case there will be a lot of fishing with this operation. This is not a project anyone is looking forward to. Needless to say, we will probably not be running any of these kinds of completions again. Jerry -----Original Message----- From: Thomas Maunder [mai 1 to -.:..~om~~~":J:ge:r::§!ad~~n. ~!a~~-=-ak_:~~] Sent: Tuesday, March 09, 2004 1:05 PM To: NSK Problem Well Supv Subject: Re: 3H-05 Jerry, Do you have some relative "run-time" information to compare 3H-05 to 3H-11?? I wonder if the -2500' to 3400' depth is where the gas comes 10f3 3/9/2004 3 :09 PM KD: .In-UJ e e out of solution. Having this well on the priority list is a good thing. Needing to keep the well in production in order to keep the pressures down is not the best mode to be in. I take it the the electro-coil is not retrievable with just a coil tubing unit?? Thanks, Tom NSK Problem Well Supv wrote: Tom: 3H-05 was orignally on last years' workover program but was not ultimately done. Due to the ECT completion it is significantly more complex and was not attempted last year. It is on this years' WO program and the completion will be replaced with a standard tubing/packer setup. This well is very high on the priority list for a workover since there is concern about degradation of the coil tubing from corrosion over time. The experience with 3H-ll was that it may come up in pieces, making for long fishing jobs. We do not want the existing completion left in the ground any longer than necessary. We also think this well is safer to operate in a flowing condition to keep wellhead pressures down than it would be to shut it in. Due to the ECT we cannot run plugs into the well, and close tolerances through the pump prohibit solids (sand, CaC03, etc.) from being pumped to plug the perfs. The end result will be high wellhead pressures which we would like to avoid. The purpose for the Sundry extension is to bridge the time gap between the current Sundry expiration and the workover. I have not seen the final schedule to know when the workover will be attempted, but we are scheduled to start them on or around April 15. So it should be only a few months at most until the 3H-05 workover takes place. I put "not to exceed one year" on the Sundry just to cover all those unknowns that happen when planning goes down the drain. We will be performing a casing inspection log and casing MIT as part of the workover. The only similar casing inspection log was ran on 3H-11 on June 14, 2001 as part of the workover. Some casing damage was noted on the USIT ran on that well. The description I can find is as follows from that operation: "USIT log was run late in the evening; the casing had heavy corrosion (both build-up and pitting). Up to 30-50% wall loss in pits. Worst is -2500' to 3400' and then tapers off, although still present. On one good point, there is no real evidence of any erosion at the pump discharge depth. " Recent workovers at West Sak on ESP wells did not find any degradation at all from the casing inspection logs. Let me know if you have any additional questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message~---- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 09, 2004 9:52 AM To: NSK Problem Well Supv Subject: 3H-05 Jerry, Marie, Nina or MJ: 20f3 3/9/20043:09 PM RE: 3H-U5 e e Did I miss anyone?? I am looking at the sundry application for 3H-05. Wasn't there another eltro-coil installation out there that was worked over?? Was there any log of the casing in that workover?? On some of the failed ESP wells that were recently worked over, inspection logs were run. I don't remember the specific comments, but I don't thing there was any "damage" noted. Let me know what you might have on these inspection logs. Thanks in advance. Tom 30f3 3/9/2004 3:09 PM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 September 5, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3H-11 (187-124 / 301-193) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the KRU well 3H-11. If there are any questions, please contact me at 265-6434. Sincerely, Drilling Engineering Supervisor Phillips Drilling CRM/skad RECEIVED SEP 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL. ( (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _X Alter casing _ Repair well _ Other_ 2.-N~me~f~oemtor Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1230' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM Development _X Exploratory m Stratigraphic _ Servia._ (asp's 498655, 6000425) I"}~hJm nl~v~finn (DF nr KR · Nordic 3 RKB 25' 7. Unit or Property name Kuparuk Unit 8. Well number 3H-11 At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM At effective depth At total depth 1315' FNL, 1040' FEL, Sec. 12, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 502613, 6000341) 7750 feet Plugs (measured) 6460 feet 9. Permit number / approval number 187-124 / 301-193 10. APl number 50-103-20091 11. Field / Pool Kuparuk Oil Pool Baker bridge plug @ 7165' Effective depth: measured true vertical 7527 feet Junk (measured) 6273 feet Casing Length CONDUCTOR 115' SUR. CASING 3561' PROD. CASING 7639' Size Cemented Measured Depth True vertical Depth 16' 215 sx AS I 115' 115' 10.75" 12oo sx AS m, 600 sx C~ass e 3637' 3087' 7' 650 sx C~ass G, 300 sx AS ~ 7715' 6431' Perforation depth: measu red 7274'-7304', 7371'-7383', 7391 '-7411', 7430'-7450' true vertical 6059'-6085', 6141'-6151', 6158'-6175', 6191'-6208' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-8O, Tbg O 7320' MD. Packers & SSSV (type & measured depth) RECEIVED SEP 0 6 001 Alaska 0il & Gas Cons. Commission Anchorage BAKER 'FHL' e 7140' MD; BAKER 'FB-I' e 7328', OTIS 'WD' - OLD COMPLETION {~ 7339' MD; NO SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 532 Representative Dally Avert,cie Production or Injection Data Gas-Md Water-Bbl 209 4748 493 356 4866 Casing Pressure Tubing Pressure - 125 120 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations ._.X Oil M X Gas __ Suspended 17. I hereby ~,t, hat~l~ ~,~,~ing is tr~ a~corr~t to the best of my ~owledge. Signed (~~~-j~~~~a,~' Title D rillingEngineeringSupervisor ' ' ORIGINAL Service _ Questions? Call Todd Mushovic 265.6974 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE ii PHILLIPS ALASKA INC. .Page I of 4 Operations Summary Report Legal Well Name: 3H-11 Common Well Name: 3H-11 Spud Date: Event Name: WORKOVER/RECOMP Start: 7/13/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 · Date From.- To HOurs Code (~oUc~e phase ' ." Description of Operations . ..~ 7/14/2001 00:00 - 19:00 19.00 MOVE MOVE MOBMIR Laying matting boards & moving rig for I mile bad road to 3H-11. 19:00 - 00:00 5.00 MOVE MOVE MOBMIR Rig on location @ 1900 hrs. 7/14/2001-Pick up matting boards-repair mad-move camp-change out spools on well head while waiting on road to be repaired to get truck in to clean mud tanks. 7/15/2001 00:00 - 16:00 16.00 MOVE RURD MOBMIR Cleaning mud tanks to take on brine-Load bope in cellar-repair suction valves-pull 4" roms & install 3 1/2" roms in upper gate-lay pit liner-berm cellar. 16:00 - 00:00 8.00 CMPLTI~ NUND WRKOVR Grease choke & cellar valves-set test plug-pressure up-stack leaking @ spool. Seal on test plug leaking-change same. 7/16/2001 00:00 - 04:00 4.00 WELLSI~ NUND WRKOVR Test bope 250-5000# ok.-repair outside kill valve. 04:00 - 08:00 4.00 WELLSF OTHR WRKOVR Load pipe shed w/230 jts. 3 1/2" dp. 08:00 - 09:00 1.00 WELLSI= OTHR WRKOVR Make up jt.-wash out stack-set wear ring. 09:00 - 15:30 6.50 WELLSF PULD WRKOVR Make up bha #1 & rih picking up 3 1/2' dp to 7165'. 15:30 - 18:00 2.50 WELLSF CIRC WRKOVR CBU @ 4 bpm-clean hole. 18:00 - 21:00 3.00 WELLSF SUN WRKOVR Waiting on APC to bring load of mud. (see remarks) 21:00 - 00:00 3.00 WELLSF CIRC WRKOVR Pump 20 bbls. size salt pill-release bridge plug-losing 1.5 bpm fluid-no returns-pump spacer & 11.3# mud-no returns(After midnight)-mix & spot Icm pill-wait 1 hr.-pump mud w/full returns-finish displacement-recovered total of 300+ bbls. brine from hole & pits-approx. 150 bbls. loss. 7/17/2001 00:00 - 05:00 5.00 WELLSR SLIN WRKOVR Mix & spot Icm pill-wait one hr.-pump mud w/full returns-finish displacement-recovered 300+ bbls. brine from pits & hole. Lost approx 150 bbls. brine & mud to hole. 05:00 - 09:00 4.00 WELLSR TRIP WRKOVR POH w/bridge plug. 09:00 - 10:00 1.00 WELLSR PULD WRKOVR Make up bha #2-milling assembly. 10:00 - 12:30 2.50 WELLSR TRIP WRKOVR RIH w/mill to 7175'. 12:30 - 16:00 3.50 WELLSR MILL WRKOVR Mill packer @ 7175' dpm-& push to 7307'. 16:00 - 17:00 1.00' WELLSR CIRC WRKOVR CBU-monitor well-well flowing. 17:00 - 00:00 7.00 WELLSR CIRC WRKOVR Shut in well 90# on dp-170# on annulus-CBU-wt, cut to 10.9 on bottoms up-Cim, dressing mud to 11.3# -slight flow-build to 11.4#. Monitor well-static.- Blow down top drive. 7/18/2001 00:00 - 07:00 7.00 WELLSR TRIP WRKOVR Pooh, well started swabbing. Pump out of hole w/11.4 ppg mud to keep influx [light] fluid as small as possible. Ck flow & fill each 5 stands. Ld bha. 07:00 - 07:30 0.50 WELLSR TRIP WRKOVR Mu bha #3. 07:30 - 09:00 1.50 WELLSFI TRIP WRKOVR Tih on 3.5" dp to 5168'. 09:00 - 12:00 3.00 WELLSR ClRC WRKOVR Dp flowing small stream due to out of balance fluid column, si well pressures ann / dp < 25 psi. Weight system to 11.5 cimulating @ 3 bpm / 600 psi. Flow ck well static. 12:00 - 13:00 1.00 WELLSR TRIP WRKOVR Rih to 7273' [ ?30' ] above packer. 13:00 - 15:00 2.00: WALTON SPLY WRKOVR Si while waiting on 12.8 ppg mud. 15:00 - 16:00 1.00 WELLSFt CIRC WRKOVR SI well & blend 12.8 & 11.1 ppg stored mud to 11.6 ppg for circulation volume. SI csg press <25 psi. 16:00 - 17:30 1.50 WELLSFt ClRC WRKOVR Cimulate hole mud w/surface mud, very little light mud circulated out - retained same in system. Printed: 8/20/2001 8:24:31 AM ' .. PHILLIPS ALASKA INC. Page 2 of 4 .. Operations Summa RepOrt ' Legal Well Name: 3H-11 Common Well Name: 3H-11 Spud Date: Event Name: WORKOVER/RECOMP Start: 7/13/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub · Date · ' From - To. Ho. urs.Code 'Code Phase .. .'. Description of Operations... · .. 7/18/2001 17:30 - 18:00 0.50 WELCTL OBSV WRKOVR Inguage Fish w/Spear - Monitor well static, make crew change. 18:00 - 23:00 5.00 WELLSI; TRIP WRKOVR TOH w/Fish(Milled Baker FB-1 packer, Baker SBE,XO,2 Baker Flapper Valves,XO & WLG-Tdp out speed slow to minimize swab · *Note** Some debris recovered on top of 'Top' flapper valve. 1 large piece(1 1/4"X 1 1/4")of slip & a few small BB size pieces. 23:00 - 23:30 0.50. WELLSF PULD WRKOVR L/D Fish & Spear Assy 23:30 - 00:00 0.50 WELLSF PULD WRKOVR P/U BHA #4 -Baker Reverse Basket Assy 7/19/2001 00:00 - 03:00 3.00 WELLSF TRIP WRKOVR Rih w/rev circulating basket. 03:00 - 05:00 2.00 WELLSF CIRC WRKOVR Brk cir & cir down last jt to top of WD packer. Work tool near & on bottom for 30 min, open pump out sub & cir bottoms up. 05:00 - 06:30 1.50 WELLSF OTHR WRKOVR Cut drlg line & rig service, make crew change. 06:30 - 07:00 0.50 WELLSF ClRC WRKOVR Pump dry slug. 07:00 - 10:00 3.00 WELLSF TRIP WRKOVR Pooh, gained 15 bbl on trip out, well static. 10:00 - 11:00 1.00 WELLSF SLIN WRKOVR Clean out tools & redress same for 2nd run. Estimate 30% of milled slips recovered. 11:00 - 14:00 3.00 WELLSF TRIP WRKOVR Rih w/Rev Cir junk basket. 14:00 - 16:00 2.00 WELLSF CIRC WRKOVR Cir last stand to td, drop ball & open reverse cir tool [cir 30 min], drop bar & open cimulating sub. Circulate & cond mud, recovered 20 bbl [711.4 ppg] light mud from bottom, build recovered mud wt to 11.6 ppg. 16:00 - 17:00 1.00 WELLSF TRIP WRKOVR Pooh 20 stands hole not taking correct fill up, hole gave 9 bus. 17:00 - 18:00 1.00 WELLSF TRIP WRKOVR Return to td to increase mw to 11.8 ppg. 18:00 - 20:30 2.50 WELLSI= CIRC WRKOVR PJSM - Wt up to 11.Sppg pits & hole volume pumping @ 2.5 bpm - HAd a 11.8 going in and 11.7 coming back. Hole began taking 1 bpm. - Shut down pump - Monitor well "Static" 20:30 - 22:30 2.00 WELLSF TRIP WRKOVR TOH 5 stds slowly - Fill for 5 stds 8.3 bbls - Pull 5 more stds - Fill 6.8 bbl$, - Pull 5 more stds -Fill 8.1 bbls . 22:30 23:00 0.50 WELLSI; CIRC WRKOVR Mix & Pump 27 bbl Hi Vis Barazan-D Pill to Minimize fluid loss 23:00 - 00:00 1.00 WELLSI~ TRIP WRKOVR TOH - Monitor Fill & Fluid loss closely · *Note** Lost 69 bbl Mud between 1800 hrs & 2300 Hrs pryor to pumping pill. @ 2400 hrs fluid loss rate 5-6 bph 7/20/2001 00:00 - 02:30 2.50 WELLSI~ TRIP WRKOVR Complete tooh. Lost a total of 26 bbl mud on trip out. 02:30 - 03:00 0.50 WELLSFt OTHR WRKOVR Monitor well, recovered one 12' x 1/16" x 6' "spring · type slip retainer & minor bits & pieces of metal. Printed: 8/20/2001 8:24:31 AM PHILLIPS ALASKA INC. Page 3 of 4 Operations Summar Report Legal Well Name: 3H-11 Common Well Name: 3H-11 Spud Date: Event Name: WORKOVER/RECOMP Start: 7/13/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Da__te From-To HOurs Code Code Phase .. Description of Operations ..... . .. . . 7/20/2001 03:00 - 08:00 5.00 WELLSI= TRIP WRKOVR Make up 30.4' x 2.0625' stinger, 7' x 26 ppf csg scraper, bumper sub / oil jars / dc's. RIH w/same slowly monitoring losses. Lost 28 bbl on trip in. 08:00 - 11:00 3.00 WELLSF OTHR WRKOVR Break cir & cir down to WD packer, continue to run in WD packer bore w/2.0625" stinger, no restriction, made a second pass. Work csg scraper in area immediately above WD packer in seeing area of FB-1 packer [ 7328']. Trip out to 7140', cir work scraper in setting area of FHL packer, cir @ 1.5 bpm / 380 psi. RIH to run stinger through WD 3acker bore. Pu to place end of stinger @ 7325' & spot hi vis Barazan 3ill @ bottom. Good quality mud returns during eps, did not cir bu. Lost a total of 51 bbl mud during scraping eps. 11:00 - 16:00 5.00 WELLSR TRIP WRKOVR Pooh w/stinger / scraper assmby. Lost 20 bbls mud on trip out. 16:00 - 16:30 0.50 WELLSR PULD WRKOVR ~L/D BHA - Clean all equip from Rig floor 16:30 - 23:00 6.50 WELLSFI TRIP WRKOVR P/U Baker B2 setting tool w/Baker FB-1 packer - TIH slowly to minimize fluid loss-( Lost 26 bbls on TIH) 23:00 - 23:30 0.50 WELLSFI PLGM WRKOVR Set Baker FB-1 packer @ 7328'. Tally & tag up ck good. 23:30 - 00:00 0.50 WELLSFI TRIP WRKOVR PJSM- TOH L/D 3.5" DP. Incomplete rpt time. .7/21/2001 00:00 - 06:00 6.00 WELLSFI TRIP WRKOVR Complete tooh laying down dp, dc'c & tools. Lost 21 bbl mud on way out. 06:00 - 06:30 0.50 WELLSI; OTHR WRKOVR Police rig floor, make crew change & prepair to run completion. 06:30 - 07:00 0.50 WELLSI= SFTY WRKOVR PJSM & eps meeting. 07:00 - 16:00 9.00 WELLSI= TRIP WRKOVR Pu Baker 3.5 x 7" FHL retrievable packer w/tail pipe assmby & trip in hole on 3.5' tbg \ tools to locate top of FB-1 pkr @ 7328'. Break cimulation for 15 minutes. NOTE: Tbg landed 1.5' high. NOTE: Lost 51 bbl mud on tih. 16:00 - 17:00 1.00 WELLSF PLGM WRKOVR Ck up / down wts of 80k / 50k lbs. Locate FHL pkr .5' above FB-1 packer. Pressure tbg to 1500 psi in stages, continue on to 2500 psi & hold for 30 minutes [final press -- 2540 psi] setting pks as per program, shear off w/35k lbs over string wt. Note: Chart recorder failed [hole in pressure supply line] during pressure operations, continued w/eps & repaired same for remainder of eps. 17:00 - 18:00 1.00 WELLSR OTHR WRKOVR Space out tbg & Idg on Tbg hanger. 18:00 - 19:00 1.00 WELLSR OTHR WRKOVR RILDS - Pull Ldg Joint - Set BPV 19:00 - 21:00 2.00 WELLSR NUND WRKOVR N/D 11" 5K BOP Printed: 8/20/2001 8:24:31 AM PHILLIPS.ALASKA INC. Page 4 of 4 .... Operations Summa Report " .. Legal Well Name: 3H-11 Common Well Name: 3H-11 Spud Date: Event Name: WORKOVER/RECOMP Start: 7/13/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From'To 'Hours Code Code Phase . DescriptiOn of Operations 7/21/2001 21:00-23:30 2.50 WELLSF NUND WRKOVR N/UFMCGenlV 5KTme 23:30 - 00:00 0.50 WELLSF NUND WRKOVR R/U Cimu Hoses to Tree 7/22/2001 00:00 - 00:30 0.50 WELLSF SEQT WRKOVR Test tbg to 2500 psi / 15 min [charted]. 00:30 - 01:00 0.50 WELLSR SEQT WRKOVR test 7 x 3.5' annulus to 2500psi / 15min [charted]. Bleed off tgb to 0 psi, increasing annulus to 3000 when valve sheared @ 2670 psi. 01:00 - 05:30 4.50 WELLSR INHS WRKOVR Ru & disp to sw as follows: Purge well well w/hi ph pill\Barazan spacer~120 bblo fw~then 580 bbl sw [ck returns as good clean sea wtr] 05:30 - 08:30 3.00 WELLSR FRZP WRKOVR Freeze protect tbg & tbg x 7" annulus w/91 bble diesel [2609']. Allow 1 hr for U-tubing. Ck tbg & annuli press: 3.5" Tbg & 7 x 3.5" annulus = 940 psi 7 x 9.625" annulus = 50 psi. 08:30 - 09:00 0.50 WELLSR OTHR WRKOVR Blow/Rd lines. 09:00 - 10:00 1.00 WELLSR SEQP WRKOVR Set Bpv, dress tree / wash down same. Clean cellar. Prepare to move dg off well. 10:00 - 12:00 2.00 WELLSR OTHR WRKOVR Continue to clean pits. Move rig off well site. Clean up remove Handy Berm liner. Rig released for move to 1R-22A @ 1200hrs 07292001. Printed: 8/20/2001 8:24:;~1 AM STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Alter casing Repair well.. Change approved program ... 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1230' FNL, 4997' FEL, Sec. 12, T12N: R8E, UM At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM At effective depth At total depth 1315' FNL, 1040' FEL, Sec. 12, T12N, R8E , UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Sewi~._ (asp's 49a655, 6000425) ::~;::~~~:~~::~:~::~~:~~~~~;:~~;~::;:::~:::;~::;:::~:::~::::~::~:::;~:~;:::~:::~~:::~::~~::~:::~::~~~::;:::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::: ~~:~~~~~~~:~~~;~~~;~~~;~~~~~~~~~;~;~:~;~~~~~;~~~~~~~:~;~:~~~:~~~~~:~~~~~:~~~;~~~:~;~~~~~:~~~;~:~~~;~~~;~~`~~~~ (asp's 502613, 6000341) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-11 9. Permit number / approval number 187-124 10. APl number 50-103-20091 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7750 feet Plugs (measured) true vertical 6460 feet Effective depth: measured 7635 feet Junk (measured) true vertical 6364 feet Casing Length Size Cemented CONDUCTOR 115' 16" 215 sx AS I SUR. CASING 3561' 10.75" 17oo sx AS III. 600 .,a( Cla.~.~ G PROD. CASING 7639' 7" 650 sx Class G, 30Osx AS I Measured Depth True vertical Depth 115' 115' 3637' 3087' 7715' 6431' RECEIVED Perforation depth: measured 7274'-7304', 7371 -~....3.:i::~i~ii~.:.1.1~ iiii::~i ~ii i!i iii!i iil !iliiiiiii+iiii!~!ii~iiiiiiiiiii~ilililili~ili iiiiiiiii iii! !iii i ii i iiiiii }i i iiii ii JULiOZO01 , ""'"=':'~="'~="'"="="'~'"'"="=:~"="'"="'?"'"';'"'i~ ............... ~=='~ ..................... true vertical 6059'-6085', 6141-6.~.~....~8~.~.~.9]. ~ ......................................... ,, ~ ........... ' ................................ ~ ......................................... k, Commission Anchorage Tubing (size, grade, and measured depth 2-3~8 '.9.3~. J-55 ~g ~ 7185' MD; 2-7/8",6.5~, J-55 ~g ~ 7367' MD; 2-7/8',6.5~, ~55, Tbg ~ 7367' MD. Packers & SSSV (type & measured depth) 13. Attachments Description summary of proposal __X ! 14. Estimated date for commencing operation July 13, 2001 16. If proposal was verbally approved BAKER 'FB-I' ~ 7185' MD; OTIS 'WD' - OLD COMPLETION ~) 7339' MD; ELECIROCOIL ESP PUMP AND MOTOR ASSY PULLED 6/15/2001 ~ 0' MD. ?:?:i::iiii~i~?:~i~:: ~ ===================================== ~::i~ ~ ~: i :: i :: i ~ i~ ::::~i?:~?: ::i~::::::: :::::::: i::::::~ :~::::::~: ::~ i~:~ 15. Status of well classification as: Oil __X Gas __ Suspended _ 17. I hereby certify th~31'~e foregoing Is lrue and corre~__o'the best of my knowledge. Questions? Call Todd Mushovic 265-6974 ~' "~'~ ~' "/ -' Title: Drilling Engineering Supervisor Date Signed o Preparedb~vSharonAIIsu~.Drake263.46f2 ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness '~.~(~ ~:~'.~ ~\~\~ Plug integrity BOP Tost~{~ Location clearan(~e ~ I Mechanical Integrity Toa .. Subsequent form required 10- ORIGINAL SIGNED BY D Taylor Seamount commissioner Approved by order of the Commission Date ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3H-11 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: . . . . , . . 11. 12. 13. 14. 15. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Confirm well is dead. ND tree. NU and test BOPE. PU 3-1/2' drill pipe, RIH and retrieve bridge plug set at 7165' RKB w/Baker model "M' retrieving tool. RIH with mill and mill FB-1 packer at 7185', TOH. RIH with spear and stab into remaining packer. TOH. RIH with reverse junk basket and cleanout misc debris left from mill the FB-1 packer. TOH RIH with mill and casing scraper and cleanout to Otis WD packer at 7339'. TOH. RIH and set bottom permanent packer, with a tubing tail that taps into WD packer, and set packer. TOH RIH with selective single completion jewelry and top packer. Space out; land tubing hanger and set packer. PU and shear PBR. Space out and re-land tubing hanger. Pressure test tubing and annulus. Displace well with seawater. Freeze protect well with diesel. Set BPV. ND BOPE. NU and test tree. RDMO Nordic 3. TJM 7/10/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY . . . 13H-11 PKR (7185-7188, 0D:7.000) (7274-7304) PKR (7339-7340, 0D:6.151) NIP (7356-7357, 0D:2,875) TUBING (7340-7367, 0D:2.875, IB:2,441) Per~ (7371-7383) (7391-7411) Per~ (743O-745O) 3H-11 APl: ! 501032009100 SSSV Type: ~ NONE Annular Fluid:', ! Reference Log:t Last Teg:i 7527 Last Tag Date: 14/1511999 ~ Casing String - ALL STRINGS Well Type:! PROD Orig Completion: 12/28/1987 Last W/O: 4/3011999 i__ Anglel~ TS:i.32d__~ 7273 Angle ~ TD: !33 deg .t~ 7750 .... -R-~v Reason: i Set ~lu.(.(] [ BPV--b~- I Ref Log Date:: ' Last Update: 1611512001 TD: i7750 ttKB Max Hole Ang_le:i 44 deg_(~ 3700 ~Description I Size i Top Bottom', TVD ] Wt I Gmdel Thread I 16.000 __l .-v--0 115 ~ 115 I 62.50 i H-40 I SUR. CASING ~,9.~'~5', [.~- 1'~ 0 3637 , 3087 ; 36.00 ] J-SS , i CONDUCTOR PROD. CASING I- 7.000 i 0 7715 I 6431 ; 26.00 [Tubin_g_String - ,Electocoil Completion " Size I Top I Botto~-n/ TVD J____Wt___J Grade _I Thread ~-~-,'- I 7340 I 7367 6138 I 6.50 L__J'55 _1 EUE 8RD AB MOD . Perforations Summary Interval TVD - ZOne l,.~tus Ft SPF D-~--T.'-_T~--ep_~ Comment 7274-7304 6059-6085 I C-4 I I 30 I 10 I 5113119881-~ERF 15" Csg G-~, 1~. Dh 7371 -7383 6141-6151 ~ A-3 I I 12 12 110/28/19ee] ~P_ER_F_.IE-~' EnerJet, 60 deg. ph 7391 - 7411 6158 - 6175 /--~:-2'---- 1-2-~-1--~-2 110/28/1988 ~F-E-~J=-I'2 1/8" EnerJet; 60 deg. ph 7430 - 7450 6191 - 6208 / A-1 20 4 5/13/1988 PERF 4 1/2" Csg Gun, 120 d~g. Dh _Othe__~_~_(plugs, equip_., etc, ~, JEWELRY . ' . . i . ' . ' ' -De-~-~]-TVDI T~__e_--:- ........ be'scri'pti'on ....... ID 0 J___o_~ ESP ' Electrocoil ESP Pump and motor assy PULLED 6115/2001 .... 0.~0 --~-~--~'967--7-T" P'--'~[O-~'-~AKER RETRIEVABLE BRIDGE PI:CIG 6/15101 .......... ~--~-b~)' 7185 15984 I. PKR Baker'FB-l' - ..... 7188 1~98_~_1- s--~---' Ba---~-- ................... ~..-~ '-7~-~-I~-~-~-1- x--~-- ..................................................... 7198 I89981 P~N ....................................... ~.-~ 7200 I 5997 I FLAPPER Baker flapper valve .............. _7202 .] 5999I FLAPPER Baker fla_~p_p~'~valve ..................... --~2-'~-'] 5999I PIN ............................ 7208 I 6004._ G~g_L~_ ......................... 7339 I ~-~TzJ- PJ-~--P-'~-'- '" ~)t~O~~--N-~ .................... 7356__L_6129_l.__ NIP CamcoT~r~Tp~~--~ ............ ~.-'~-~ --~3~--T-s-T~f-I---S-~--'--~-'~---bLD C~M~-E-T-]~ ........................ 7_~_367 J~3S J'rTL ............................................. ~T-~t'~ .=',=.:, ;::, '.:~ :.~ .:=?.'..! ? ::::, :=~',~..!~?~:~?~'_~?_~?_ ~j¥_ ~:_:.',:~:~? ~:~:~.:':T':~:;::!:_.'i :,.:..:~...'::::~:...j'::i,=?~:: ?~'i.;., ~::.'~.::: :; i~i":..: ': ~=:='., ,:: :. -bate'" Note _4/18/199_~_] Chem cai cut tubing 2 3/8" cutter at 7329' and 7242'. KRU 3H-11 Producer Proposed Completion Schematic PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 26.5# H-40 @ 115' MD Surface csg. 10-3/4" 45.5 J-55 (3637' MD / 3087' TVD) Perforations Perforations Production csg. 7" 26.0# J-55 BTCM (7715' MD / 6431' TVD) 3-1/2' FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 4 - 3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and RK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM. Spaced out w/3-1/2" 9.3# L-80 EUE8RD tubing as follows: 3-1/2" x 1-1/2" Camco 'KBUG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. Set at +/- 3026' MD / 2350' TVD 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing Baker FHL packer 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing Baker Sliding Sleeve w/aCamco 'DS' nipple and a 2.812" No-Go Profile 2 jts of 3-1/2" 9.3# L80 EUE8RD tubing Blast rings 40' set at 7269' to 7309' MD Pup joint to space blastrings out Ported nipple 2' pup joint 5' seals Baker FB-1 packer run on B2 setting tool with a x-over from XX to 3-1/2", 2.75" XN nipple, 2' pup joint, dummy seal stem below 7" x 3-1/2"Otis WD packer w/tubing tail below and as 2.25" Camco no go nipple TJM, 7/10/01, v2 Re: 3H-II USIT & MIT e e Sub.iect: Re: 3H-11 USIT & MTT From: "NSK Problem Well Supv" <n 1 (j 17~Dppco.com> Date: Thu, 28 Jun 2001 16:56:42 -0800 To: Tom Maunder <tom_maundcr(ajadmin.statc.ak.us> \ ){\ - \ ~ \..-\ Tom Aris will contact you with the 3H-11 USIT log information once he receives it and has a chance to review all the data. Also, 3H-11 will be kept shut in until the work over is completed with the conventional gas lift production string. 3H-05 is the only other electro coil completion. I have attached a schematic of the 3H-05 completion and here are some averages. Production: 750 bopd, 2250 bwpd, 3000 bpd of total fluid Pressure: 120 psi producing pressure (See attached file: 3H-05.pdf) Thanks, Peter Nezaticky Tom Maunder <tom maunder@admin.state.ak.us> 06/18/01 12:39 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 3H-11 USIT & MIT Aris and Pete, Thanks for the information update. USIT log and any interpretation you have performed. in a copy of According completed that completion, production rates and pressures. Tom Maunder Would you please submit a copy of the We also would be interested any failure report that is prepared. to my understanding, this leaves 3H-05 as the only electo coil well. Would you please send us updated information regarding NSK Problem Well Supv wrote: Tom, As discussed via phone, we are not planning to rerun the Electrocoil Completion back into the well on 3H-11 due to corrosion problems on the Iof2 '. ~ ~,,(\ Q0¢- ~~J 3/9/2006 11 :36 AM Re: 3H-II USIT & MIT e e Coiled Tubing. The plan for the well is to get a workover rig on it and run tbg and gas-lift. The USIT log on the 7" casing showed corrosion over the same intervals that the Coiled Tubing was corroded. At first look, the USIT log was inconclusive as to whether or not any wash was caused by the impingement of the flow from the pump on the 7" casing, but we are still investigating this. The casing was subsequently MIT'ed successfully with a bridge plug set 20 I above the existing packer. The casing was loaded with 12.5 ppg brine, yielding an equivalent bottom-hole pressure of -3900 psi hydrostatic, and an additional 1500 psi of surface pressure for the MIT. The test was not witnessed by an AOGCC representative. The bridge plug will remain in the well until the workover rig arrives (probably several weeks before the rig arrives). If a State witnessed test is desired this can be arranged. (See attached file: MIT KRU ECT 3H-11 6-16-01.xls) Thanks, Aras Worthington Non-Rig Workover Eng. 265-6802 Peter Nezaticky Problem Well Supv. 659-7224 ------------------------------------------------------------------------ MIT KRU ECT 3H-11 6-16-01.xls (application/msexcel) Name: MIT KRU ECT 3H-11 6-16-01.xls Type: EXCEL File Encoding: base64 (See attached file: tom_maunder.vcf) Content-Type: application/pdf 3H-05.pdf Content-Encoding: base64 Content-Type: application/octet-stream Content-Encoding: base64 20f2 3/9/2006 11 :36 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to;Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us OPERATOR: Phil/ips Alaska, Inc. FIELD I UNIT I PAD: Kuparuk 1 GKA 13H DATE: 611612001 'PERMIT»< N4fv1~~~..·.....·T~~f HH(~UUIN4mST > <WetîlH //ftOIPTYP. NU~'êt.t(/ »> '.' . PTD: 1871240 Brine Well #: 3H-11 COMMENTS: )?//H? · >« <)PRETE$.T$TJ\RT;(15M ~;~~}\!I!~¡ .¡.() PACKER ¡:¡.;;..·¡.:R~q Yif.9'. ¡.j;'M~·· UTiMÈ/H¡T!M~ ...U.; ~þ. .>.ÇMi~Ø;;TBG/TIE~t:¢~Ø¡.T~ø....-rn9:'r~~:, ¡¡~IJN~t ;MÞ .Hs.izeiwti~~~ .·.~~~~..m~~~~>f~~m~:.þ'~~~~¡!!þ,~I~~i:~~~~~¡ .:.¡:~~~..... 5,967 7"1 26# IJ-55 None 1,492 0 1,500 1,500 1,500 1:45 0 7,165 110 110 115 115 ECT completion pulled and a bridge plug set at 7165 ft MD. The 7" casing is full of 12.5 ppg brine which is equivalent to about 3900 psi at the the bridge lu . MIT'ed the casin to 1500 si. ......... .. .......... . .......... . .......... . .......... . .......... . .......... . ......... .. .......... . .......... . .......... . .......... . ·····J¥···p··e······ ... .. ... .... :=:::::::: -: <::: ......... .. . . . , . . . . . . . . :'ÂNNli ........... . .......... . HäuiDH ........... . . . . . . . . . . . . P Brine PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: P.P .G. DIESEL GLYCOL SALTWATER DRILLING MUD OTHER Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other X Distribution: orig - Well File c - Operator c - Database c - Trip Rpt File c - Inspector OPERATOR REP SIGNATURE: Peter Nezaticky AOGCC REP SIGNATURE: Not Witnessed MIT KRU ECT 3H-11 6-16-01.xls (Rev 9/23/99) Re: Phillips 3H-11 ECT ESP - Hewsea Subject: Re: Phillips 3H-11 ECT ESP -Revised Date: Fri, 08 Jun 2001 16:26:14 -0700 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: NSK Problem Well Supv <n1617@ppco.com> CC: AOGCC North Slope Office <aogcc_prudhoe bay@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.a~.us> Jerry, This response confirms our conversation this morning regarding the work on this well and my verbal approval to proceed. After further discussions with Jack, the following are our requirements with regard to "completing" the well with or without the pump. The plan to run a USIT is prudent and is a valid method to investigate the casing condition since it has been exposed to the produced fluid. You indicated that if the log were "questionable", proceeding with the workover would be discussed. "questionable" criteria was not defined. In consideration that the casing has been exposed to the produced fluid, we will require that a MIT be performed on the casing. You indicated you were unsure how that might be accomplished, but would investigate. If such pressure test cannot be accomplished, please contact me so we may discuss this further. I would also appreciate notice if the USIT is "questionable". As I indicated above, subject to performing the MIT and providing the notifications, you have approval to proceed. During the weekend, I can be reached at 345-0850 or the cell is 244-1567. Good luck Jerry. Tom Maunder, PE Petroleum Engineer AOGCC NSK Problem Well Supv wrote: Tom Here is some more information regarding 3H-11 ESP. This is what I have so far'. - pump installed and started producing 5/99 (avg: 800 bopd, 8000 bpb total fluid) - pump went down in 7/00 - continued flowing well past the pump (avg: 500 bopd, 5500 bpd total fluid) - shut in 5/31/01 for workover prep. We have inspected this well several times due to Special Requests from operations and Corrosion Coupon results. The last inspection which included UT of 2 flowline elbows, 4 manifold impingement areas plus the choke, and 4 riser impingement areas was performed on 4/23/01 with no erosion damage noted. As for the flow#ne, this line is a heavy wall pipe (.438") and is far down on our priority list. Future inspections: The dbase has generated a random location inspection on well 3H-11 for 10/2001. 1 of 5 6/8/01 4:26 PM Re: Phillips 3H-11 ECT ESP - Revised > Hope this answers your questions. > Thanks, Pete > > ....Forwarded by NSK Problem Well Supv/PPCO on 06/01/01 01:16 PM .... > > Tom Maunder <torn_maunder@admin. state, ak. us> 06/01/01 08:21 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: Phillips 3H- 11 EC T ESP Jerry and Peter, Julie and I have reviewed the 3H-11 file and the proposed work. According to the file, this installation was designed to test this type of equipment with as long term an installation as possible. From the information, it looks like you got 14 months of run time through July of last year. Due to equipment availability, it is now possible to effect the repair or at least pull the coil. During this operation, you propose to run a casing inspection log to assess the condition of the production casing which has see the produced fluids on a more than casual basis. Based on the file information, we have a couple of questions. Your request is to keep the well flowing while awaiting repair parts if the pump is inoperable. Has the well been flowing since the original pump problems were experienced last July? As indicated in the file information, casing inspection was planned when subsequent work was possible. It is appropriate that a USIT log is planned. During the 14 or more month operating time, was any inspection of the flowline and any valves conducted? It would be appropriate to provide such information if it is available. If such inspection has not been conducted, what type of inspection is planned? On receipt of this requested information, we will further evaluate your request. Thanks. Tom Maunder NSK Problem Well Supv wrote: Tom, The work is scheduled to begin on June 8th. If you would like to discuss this or need more details give me a call 659-7'224. Pete Tom Maunder <tom_maunder~admin. stato, ak. us> 2 of 5 6/8/01 4:26 PM Re: Phillips 3H-11 ECT ESP - Revised 05/29/01 08:34 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subjech Re: Phillips 3H-11 ECT ESP Jerry and Marie, What is your timing on this issue?? / will have to look into this to understand the current approval and where we might go. Tom NSK Problem Well Supv wrote: > Tom: Attached below is a message from Marie McConnell, the CPF3 PE. Her > message describes a problem with the ESP pump on 3H-11. To get right to the > details, the problem is this: to pull and run the ESP it takes 4 to 7 days > of coil tubing time and use of the work platform (there is only one on the > slope). If they puli the pump, motor, and CT/cable and can fix it, they > > will run it back in the ground. If they find the pump or CT/cable is shot > > they will have to order another, or schedule the well for a workover with > > traditional tubing and gas/iff string. That would most likely take 3-6 > months before either could be accomplished. In the meantime we would be > missing out on 500 bopd if the well is not flowing. If we find a component > is bad, can we get temporary approval to #ow the well unassisted until > new motor is obtained or new tubing run without the coil string in the > well? That would mean flowing the well up the casing without any tubing of > any kind in the well. Essentially our request would not change the flowpath > of the well in it's currently approved state. This request would not exceed > a 6-month period. The USIT log to check casing condition will be run as > > soon as the pump & motor are retrieved from the well, as per the original > > agreement when the ESP completion was approved. No part of the surface > safety valve system will be impaired by this request; it will remain fully > functional as per regulations. > We are asking for your opinion prior to the work being performed since > decision will have to be made on-site. There is better than 50% chance that > > repairs can be made and the completion re-run and no variance is needed. > If > > a component is bad and we know approval will be given, the pump will be > > left out of the well and it will be returned to production. If we find > that > > approval will not be given in this situation, the pump will be run back >in > > the ground even though it doesn't work. This will require another > expensive 3 of 5 618101 4:26 PM Re: Phillips 3H-11 ECT ESP - Revisecl > > rigup (roughly $ lOOK) down the road to pull it again in preparation for a > > new pump/motor or tubing string. Since this work is to occur on or about > > June 12, knowing your position and our options as soon as possible is important. To sum up: 1. Can we get approval to flow 3H-11 up the casing for a period not to exceed 6-months, should a failed component need replacing? 2. Should we submit a 10-403 now asking for this variance even though > may not need it if the components can be fixed and re-run? or, > 3. Can you give us a verbal opinion now, and expect a 10-403 submitted > after the work is complete will be approved? > > Thanks for your attention to this request. The costs associated with these > jobs are considerable, so we would like to determine all the options prior > to commencing. Please call if you have any additional comments; we are > looking forward to your response. Jerry Dethlefs Phillips Problem Well Supervisor > > ....Forwarded by NSK Problem Well Supv/PPCO on 05/28/01 07:38 AM > CPF3 Prod Engrs > 05/27/01 11:28 AM > > To: NSK Problem Well Supv/PPCO@Phillips > cc: Aras Worthington/AAI/ARCO@Phillips, Howard B Gober/PPCO@Phillips, Johnny 0 · Golden/PPCO@Phillips Subject: 3H-11 ECT ESP WO state approval Jerry, Please check with Tom Maunder to see if he would be willing to approve · 10-403 Sundry Application for 3H-11's Electra-coil ESP completion workover · that requests continued annular flow if the completion is not ten back into · · the well. A workover is planned for the week of June 12th to repair an · · electrical short between the surface and the motor. The pump section was · · operating normally when the ESP shorted out and it is assumed that the · pump · · can be re-ran after the motor is replaced. If the pump section of the · ESP · · is found to be nonfunctional, the entire completion will be left out of · the · · hole until a new pump section can be installed or a gas lift completion · · installed with the workover rig. The lead time on purchasing a new pump · or · · scheduling the workover rig is 2 to 3 months. The well makes 500 BOPD, · SO 4 of 5 6/8/01 4:26 PM Re: Phillips 3H-11 ECT ESP - Revised . > > the production loss of leaving the well SI for 3 to 5 months is 45 to 75 > > MBO. The annular flow would be temporary, not longer than 6 months, > until · · the Electra-coil ESP is re-ran or a gas lift completion is installed with · · the workover rig. A USIT will be ran prior to returning the well to · · production to ensure adequate casing integrity. The odds that the pump · · will be nonfunctional is less than 10%. During this temporary period · not · · to exceed 6 months, the flow path would not be any different than it has · · been since the electra-coil ESP was installed on 5/17/99. The only · · difference would be the absence of the coiled tubing electric cable and · the · · pump assembly. >> · · Background: · · 3H-11 was completed with an Electra-coil ESP on 5/17/99 as described on · the · · 10-403 application form approved on 2/24/98, approval # 398-009. The · ESP · · operated for 14 months until it failed due to an electrical short to · ground · · on 7/7/00. After evaluating whether the technology should continue to be · · developed or if the well should be converted back to a gas lift completion, · a workover was scheduled for October 2000. Due to various scheduling · conflicts with the Prudhoe Bay work platform required for running the · completion, the workover was continually delayed. Currently the work · platform is scheduled to arrive in Kuparuk the week of June 12th. If work platform is not available at this time, it will not be available work on 3H pad until September 2001. · · Marie · (See attached file: tom_maunder, vcf) (See attached file: tom_maunder, vcf) Tom Maunder <tom maunder~admin.state.ak.us> ~-'~l~eer ' ' Alaska Oil and Gas Conservation Commission 5 of 5 6/8/01 4:26 PM Re: Phil!~s 3H-11 ECT ESP - Revised (, Subject: Re: Phillips 3H-11 ECT ESP - Revised Date: Mon, 4 Jun 2001 13:24:51 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak, us Tom Here is some more information regarding 3H-11 ESP. This is what I have so far: - pump installed and started producing 5~99 (avg: 800 bopd, 8000 bpb' total fluid) - pump went down in 7/00 - continued flowing well past the pump (avg: 500 bopd, 5500 bpd total fluid) -shut in 5/31/01 for workover prep. We have inspected this well several times due to Special Requests from operations and Corrosion Coupon results. The last inspection which included UT of 2 flowline elbows, 4 manifold impingement areas plus the choke, and 4 riser impingement areas was performed on 4/23/01 with no erosion damage noted. As for the flowline, this line is a heavy wall pipe (.438") and is far down on our priority list. Future inspections: The dbase has generated a random location inspection on well 3H-11 for 10/2001. Hope this answers your questions. Thanks, Pete .... Forwarded by NSK Problem Well Supv/PPCO on 06/01/01 01:16 PM ..... Tom Maunder <tom_maunder@admin.state.ak. us> 06/01/01 08:21 AM To: NSK Problem Well Supv/PPCO@Phillips Cc: Subject: Re: Phillips 3H-11 ECT ESP Jerry and Peter, Julie and I have reviewed the 3H-11 file and the proposed work. According to the file, this installation was designed to test this type of equipment with as long term an installation as possible. From the information, it looks like you got 14 months of run time through July of last year. Due to equipment availability, it is now possible to effect the repair or at least pull the coil. During this operation, you propose to run a casing inspection log to assess the condition of the production casing which has see the produced 1 of 6 615/01 2:45 PM Re: Phillips 3H-11 ECT ESP - Revised fluids on a mom than casual basis. Based on the file information, we have a couple of questions. Your request is to keep the well flowing while awaiting repair parts if the pump is inoperable. Has the well been flowing since the original pump problems were experienced last July? As indicated in the file information, casing inspection was planned when subsequent work was possible. It is appropriate that a USlT log is planned. During the 14 or more month operating time, was any inspection of the flowline and any valves conducted? It would be appropriate to provide such information if it is available. If such inspection has not been conducted, what type of inspection is planned? On receipt of this requested information, we will further evaluate your request. Thanks. Tom Maunder NSK Problem Well Supv wrote: Tom, The work is scheduled to begin on June 8th. If you would like to discuss this or need more details give me a call 659.7224. ' Pete Tom Maunder <torn_maunder@admin. state, ak. us> 05/29/01 08:34 AM To: NSK Problem Well Supv/PPCO@Phillips Subject: Re: Phillips 3H- 11 ECT ESP Jerry and Marie, What is your timing on this issue?? I will have to look into this to understand the current approval and where we might go. Tom NSK Problem Well Supv wrote: > Tom: Attached below is a message from Marie McConnell, the CPF3 PE. Her > message describes a problem with the ESP pump on 3H- 11. To get right to 2 of 6 ~/5/01 2:45 PM Re: Phillips 3H-11 ECT ESP - Revised > the > > details, the problem is this: to puli and run the ESP it takes 4 to 7 > days > > of coil tubing time and use of the work platform (there is only one on > the > > slope). If they pull the pump, motor, and CT/cable and can fix it, they > > will run it back in the ground. If they find the pump or CT/cable is shot · · they will have to order another, or schedule the well for a workover with > traditional tubing and gas/irt string. That would most likely take 3-6 · months before either could be accomplished. In the meantime we would be · missing out on 500 bopd if the well is not flowing. If we find a component · is bad, can we get temporary approval to flow the well unassisted until · new motor is obtained or new tubing run without the coil string in the · well? That would mean flowing the well up the casing without any tubing of · any kind in the well. Essentially our request would not change the flowpath · of the well in it's currently approved state. This request would not exceed · a 6-month period. The USIT log to check casing condition will be run as > · soon as the pump & motor are retrieved from the well, as per the original · · agreement when the ESP completion was approved. No part of the surface · · safety valve system will be impaired by this request; it will remain fully · functional as per regulations. · We are asking for your opinion prior to the work being performed since > decision will have to be made on-site. There is better than 50% chance that · · repairs can be made and the completion re-run and no variance is needed. · If · > a component is bad and we know approval will be given, the pump will be · · left out of the well and it will be returned to production. If we find · that > · approval will not be given in this situation, the pump will be run back >in · · the ground even though it doesn't work. This will require another · expensive · · rigup (roughly $100K) down the road to pull it again in preparation for a > · new pump/motor or tubing string. Since this work is to occur on or about · · June 12, knowing your position and our options as soon as possible is · · important. >> > · To sum up: · > 1. Can we get approval to flow 3H-11 up the casing for a period not to 3 of 6 ~/5/01 2:45 PM' Re: Phillips 3H-11 ECT ESP - Revised ,, exceed 6-months, should a failed component need replacing? 2. Should we submit a 10-403 now asking for this variance even though may not need it if the components can be fixed and re-run? or, 3. Can you give us a verbal opinion now, and expect a 10-403 submitted after the work is complete will be approved? :> a > Thanks for your attention to this request. The costs associated with these > jobs are considerable, so we would like to determine all the options prior > to commencing. Please call if you have any additional comments; we are > looking forward to your response. > Jerry Dethlefs > Phillips Problem Well Supervisor > ..... Forwarded by NSK Problem Well Supv/PPCO on 05/28/01 07:38 AM CPF3 Prod Engrs 05/27/01 11:28 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Aras Worthington/AAI/ARCO@Phillips, Howard B Gober/PPCO@Phillips, Johnny 0 > Goiden/PPCO@Phillips > Subject: 3H. 11 ECT ESP WO state approval > Jerry, > >Pioase check with Tom Maunder to see if he would be willing to approve > t0-403 Sundry Application for 3H-11's Electra-coil ESP completion workover > that requests continued annular flow if the completion is not ran back into > > the well. A workover is planned for the week of June 12th to repair an > > electrical short between the surface and the motor. The pump section was > > operating normally when the ESP shorted out and it is assumed that the > pump > > can be re-ran after the motor is replaced, if the pump section of the > ESP > > is found to be nonfunctional, the entire completion will be left out of > the > > hole until a new pump section can be installed or a gas lift completion > > installed with the workover rig. The lead time on purchasing a new pump > or > > scheduling the workover rig is 2 to 3 months. The well makes 500 BOPD, > SO 4 of 6 6/5/01 2:45 PM Re: Phillips 3H-11 ECT ESP - Revised , > > the production loss of leaving the well S! for 3 to 5 months is 45 to 75 > > MBO. The annular flow would be temporary, not longer than 6 months, > until > > the Electra-coil ESP is re-ran or a gas lift completion is installed with > > the workover rig. A USIT will be ran prior to returning the well to > > production to ensure adequate casing integrity. The odds that the pump > > will be nonfunctional is less than 10%. During this temporary period > not > > to exceed 6 months, the flow path would not be any different than it has > > been since the electra-coil ESP was installed on 5/17/99. The only > > difference would be the absence of the coiled tubing electric cable and > the > > pump assembly. > > Background: > > 3H-11 was completed with an Electra-coil ESP on 5/I 7/99 as described on > the > > 10-403' application form approved on 2/24/98, approval # 398-009. The > ESP > > operated for 14 months until it failed due to an electrical short to > ground > > on 7/7/00. After evaluating whether the technology should continue to be > > developed or if the well should be converted back to a gas lift > completion, > > a workover was scheduled for October 2000. Due to various scheduling > > conflicts with the Prudhoe Bay work platform required for running the completion, the workover was continually delayed. Currently the work platform is scheduled to arrive in Kuparuk the week of June 12th. if the to work platform is not available at this time, it will not be available work on 3H pad until September 2001. > > Marie > (See attached file: tom_maunder, vcf) (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 5 of 6 615101 2:45 PM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 RECEIVED JUN 0 4 Z001 Alaska Oil & Gas Cons. Commission Anchorage May 31, 2001 Ms. Camille Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 3H-11 Application for Sundry Approval Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached sundry for tubing change-out for the KRU 3H-11 well. We will be pulling the coil tubing ESP and re-running it. If you have any questions regarding this matter, please contact me at 263-4574 or Aras Worthington at 265-6802.. Sincerely, M. Mooney Staff Engineer PAI Drilling / Wells MM/skad STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ Perforate _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Loca, on of well at surface ~ 2~N~ 1230' FNL, 4997' FEL, Sec. 12, T1 , R8E, UM At top of productive interval At effective depth At total depth 1315' FNL, 1040' FEL, Sec. 12, T12N, R8E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service__ (asp's 498655, 6000425) (asp's 502613, 6000341) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-11 9. Permit number/,~pproval number 187-124 v 10. APl number 50-103-20091 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SUR. CASING 3561' PROD. CASING 7639' Size 16" 9-5/8" 7" 7750 6460 7527 6273 / feet V Plugs (measured) feet / feet Junk (measured) feet Cemented 215 sx AS I 12oo sx ASIII & 600 sx Class G 650 sx Class G & 300 sx AS I Measured Depth 115' 3637' 7715' True vertical Depth 115' 3087' 6431' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7274'-7304', 7371 '-7383', 7391 '-7411', 7430'-7450' 6059'-6085', 6141 '-6151 ', 6158'-6175', 6191 '-6208' 2-3/8",9.3#, J-55 Tbg O 7185' MD; 2-7/8',6.5#, J-55 Tbg O 7367' MD. BAKER 'FB-I' ~ 7185' MD; OTIS 'WD' ~ 7339' MD; No SSSV RECEIVED iI. ~ ~ ~ I1 ~ 2.001 A]asRa Oil & Gas Oo'r,,s. Commission Anchorage 13. Attachments Description summary of proposal _.~ Detailed operations program _ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation June 8, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service 17. I hereby certify that t.he.foreg~ls.~e and correct to the best of my knowledge. Signed v~...-- ~ w....- Title: Staff Engineer Michael Moone~ FOR COMMISSION USE ONLY Questions? Call Mike Mooney 263-4574 Prepared by Sharon AIIsu~-Drake 263-4612 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test .~ Subsequent form required 10-~ Approved by order of the Commission Commissioner I Appr°va'n°' O I-lUq Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. { Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Ron Marquez Production Engineering Supervisor Kuparuk River Unit NSK 69 Phone 659-7226 Fax 659-7314 October 19, 1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Christenson' Attached in duplicate are Report of Sundry Approvals (Form 10-404) for the following Kuparuk and Tarn wells: Well Action Well Action Run ESP 3H-21 Perforate Cont. to Inj. 1L-20X Perforate 1 C-13 Perforate 3J-1'7 Perforate 2M-20 Perforate 3K-15 Perforate 2N-319 Jet Pump 3K-15 Perforate 2N-337A Jet Pump 2T-30 Stimulate 2N-335 Jet Pump 2T-30. Stimulate 2N-345 Jet Pump 2T-30 Perforate 2N-309 Jet Pump 2T-30 Perforate If you have any questions, please call me at 276-1215, ext. 7226. Sincerely, Kuparuk Production Engineering Supe .rvisor ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany bcc: Central Files NSK Well Files ATO-320 NSK-69 I .... STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510°0360 4. Location of well at surface: 1232' FNL, 281' FWL, Sec 12, T12N, RSF, MM At top of productive interval: 1367' FNL, 1294' FI:L, Sec 12, T12N, RSE, UM At effective depth: 1324' FNL, 1103' FEL, Sec 12, T12N, R8E, UM At total depth: 1316' FNL, 1042' FEL, Sec 12, T12N, R8E, UM Operation Shutdown _ Stimulate__ Pull tubing _ Alter casing _ 5. Type of Well: Development X. Exploratory ~ Stratagrapic __~ Service ~ 12. Present well condition summary Plugging _ Perforate Repair well _ Other _X 6. Datum of elavation (DF or KB feet): 76' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 3H-11 9. Permit number/approval number: 87-124/398-009 10. APl number: 500103-20091-00 11. Field/Pool: Kuparuk River Field / Oil Pool Total Depth: measured true vertical 7750 feet Plugs (measured) None 6460 feet Effective Depfl measured true vertical 7635 feet ,Junk (measured) None 6364 feet Casing Length Conductor 80' Surface 3602' Production 7681' Liner Size Cemented Measured depth 16" 215 Sx AS I 115' 10-3/4" 1200 Sx AS III & 3637' 600 Sx Class G w/130 Sx AS I top job 7" 650 Sx Class G & 7716' 300 Sx AS I True vertical depth 115' 3087' 6432' Perforation Depth measured true vertical 7274'-7304'; 7371'-7383'; 7391'-7411'; 7430'-7450' 6059'-6085'; 6141 '-6151 '; 6158'-6175'; 6191 '-6208' Tubing (size, grade, and measured depth) 2-3/8" coiled tubing @ 7185' Packers and SSSV (type and measured depth) Packers: Baker FB-1 @ 7185' (Otis WD left in hole @ 7339'); SSSV:None RECEIVED 0g¥ 27 N~ska Oil & Gas Cons. Anchomg~ 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure Installed coiled tubing deployed electric submersible pump. 14. O IGI IA£ Representitive Daily Average Production or Injection Data OII-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 600 .420 4392 1109 178 Subsequent to' operation 804 164 6379 5 168 15. Attachments X Schematic 16. Status of well classification as: Copies of Logs and Surveys run _ Dally Reporf of Well Operations _~ Oil X Gas _ Suspended m Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~ Title'. Production Engineering Supervisor Date ~/~'~/~SUBMIT IN DUPLICAT'E~ Form 1004041~0611~/88 'ARCO Alaska, Inc. ' KUPARUK RIVER UNIT · ELL SERVICE REPORT '~ 3H-11(4-1)) WELl- JOB SCOPE JOB NUMBER 3H-1 1 DRILLING SUPPORT-EXP WORKOVER 0405991210.3 · DATE DAILY WORK UNIT NUMBER 05/14/99 INSTALL ELECTROCOIL COMPLETION UNIT #5 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR · 12 t~ Yes O NoI ~'~ Yes O No DS-JONES MENKE ESTI MATE 999285 23ODS36HO $23,780 $243,645 Initial Tbg IFinal Tbg I Initial IA I Final IA I Initial OA IFinal OA ITTL Size .I Min ID h . 1100PSII 1200PSII 0PSI 0PSI 0PSI 0PSII 0.000 " 0.000 " 0 FT DAILY SUMMARY [ SPLICE PENETRATORS - NU WELLHEAD AND PENETRATORS - DO ELECTRICAL CHECKS - ALL OK - MU CONNECTIONS ON I TOP HAT - MU PRESSURE RELIEF VALVE - PUMP TEST ESP MOTOR - RDMO CTU [ESP Work] TIME LOG ENTRY 12:00 SCAFFOLDING BEING BUILT AROUND TREE 13:00 TGSM - DISCUSS JOB PLAN - ONLY 2 PEOPLE ALLOWED ON SCAFFOLDING - MUST WEAR FALL PROTECTION ON SCAFFOLDING - ROPED OFF AREA ON FLOOR FOR SPECTATORS 13:30 BEGIN TERMINATION OF POWER CABLE SPLICE TO FLEX LEADS 16:00 NU TOP HAT ON TUBING SPOOL - TEST VOID SPACE TO' 5000 PSI - ALL OK 17:30 RUN FEED THROUGH CONNECTORS THROUGH TOP FLANGE - MU TOP FLANGE - MU PACKING A'ROUND ., FEEDTHROUGHS - DO ELECTRICAL CHECKS ON POWER CABLE AND I-WIRE - ALL OK 19:50 PRESSURE RELIEF VALVE MADE UP.. INJECTION TEST'TO CHECK MOTOR. 5.5 BPM, 2000 PSI. MOTOR CHECKED OUT, COMPLETION STUNG INTO PKR OK. WHP BLED TO 1200 PSI. 08:15 START TO RIG DOWN DS CTU #5. 21:00 CONTACT APC, RELEASE FLOWBACK/DIESEL TANKS/HARDLINE ETC. CONTACT VECO TO COME PICKUP 3 RISER SPOOLS TO RETURN TO MI. CONTACT SCAFFOLD CREW TO BE ON LOC IN A.M. FOR ELECTRICIANS. 22:00 CUT CONNECTOR FROM CT, DS TAKE WITH THEM FOR BAKER TO PICKUP. CONTINUE RIG DOWN, SQUARE . AWAY UNIT 23:30 UNIT RELEASED, LEAVE LOCATION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC '$500.00 $10,200.00 ARCO $6,520.001 $38,427.00 BAKER OIL TOOLS $0.001 $17,487.00 CENTRILIFT . $5,0,00.00 $25,000.00 COBURN $0.00 ~ $250.00 DOWELL $9,760.00 $87,734.00 FMC $0.00 $3,300.00, HALLIBURTON $0.00 $12,001'..00 LITTLE RED $0.00 $9,960.00 PEAK $0.00 $~,000.00 SCHLUMBERGER $0.00 $14,775.00 VECO $2,000.00 $1 e,ooo.oo WAREHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $23,780.00 $243,645.00 'ARCO Alaska, Inc. WELL 3H-1 1 ' DATE~ 05/13/99 , DAY 11 ., FIELD ESTI MATE KUPARUK RIVER UNIT ZLL SERVICE REPORT 3H-11(4-1)) INSTALL ELECTROCOIL COMPLETION OPERATION COMPLI:i E I SUCCESSFUL I KEY PERSON O Yes ~ No I O Yes ![~ No I DS-JONES AFC# ICC# I DAILY COST ACCUM COST 999285 23ODS36HO $33,863 $219,865 0PSII 0PSII 0PSI 0PSI 0PSI OPSII 0.000 " JOB SCOPE JOB NUMBER DRILLING SUPPORT-EXP WORKOVER 0405991210.3 DAILY WORK UNIT. NUMBER UNIT #5 SUPERVISOR GOBER Signed DALLY SUMMARY INSTALL NEW 2-3/8" SLIP RAMS IN 2-7/8" SLOT - CUT PIPE - MU FMC TBG HANGAR ON CT - LAND TBG HANGAR IN TBG SPOOL - ND BOP STACK - BUILD SCAFFOLDING AT REPORT TIME SPLICE PENETRATORS - NU WELLHEAD AND PENETRATORS - DO ELECTRICAL CHECKS - ALL OK - MU CONNECTIONS ON TOP HAT AT REPORT TIME [ESP Work] TIME LOG ENTRY 12:00 DISCUSS OPTIONS - LOOKING FOR REPLACEMENT SLIP RAMS - POOH TO GET SLIP MARKS AT REEL - SOME MARKS ON PIPE 13:30 SENT ALL CENTRILIFT AND TRONIC PERSONNEL TO CAMP FOR SLEEP 15:00 DECIDE TO MAKE NEW 2-3/8" SLIP RAMS FOR BOP STACK - CHECKING FLOWBACK TANK LEVEL PERIODICALLY - NO FLOW - FLAPPERS ARE HOLDING GOOD - 0 PSI ON COIL X CABLE ANNULUS 17:00 19:45 19:55 20:00 20:15 20:30 21:00 21:30 22:15 22:30 FOUND HYDRIL 2-3/8" SLIP BODIES IN DOWELL'S YARD - CONFIRMTHEY ARE CORRECT BODIES - WAIT ON SLIP BODIES TO BE DELIVERED SLIP RAMS ARRIVE, SAFETY MEETING TO DISCUSS CHANGING OUT OF SLIPS. BREAK OUT 2 7/8" SLIP RAMS, REPLACE W! 2 3/8" SLIPS (NOW HAVE TWO SETS OF 2 3/8" SLIPS IN BOP'S) PRESSURE TEST BONNET AND STACK TO 500 PSI, OK MOVE PIPE TO CHECK UP AND DOWN WEIGHTS. POSITION CTU @ FLAG (7147.6' CTM). SET SLIPS. STACK 5000# DOWN, PU 5000# OVER, SLACK OFF TO NEUTRAL POINT. SLOWLY RELEASE INJ. CHAIN PRESSURE SLIPS SET, CLOSE ANNULAR BAG. BLEED AND DRAIN STACK AND LUBRICATOR UNFLANGE SWAB QUICK CONNECT FROM RISER, STRIP LUB AND INJECTOR UP OVER COIL. POSITION DOG COLLAR W/PLATE. CHECK MEASUREMENTS FROM LOCK SCREW DIMPLER AND BOP MARKS'ON PIPE. 53" BELOW CENTER OF T SLIP RAMS. FIND DIMPLER, RIG UP HOT TAP AND HYDRAULIC ROUGH CUTTER. ' HOT TAP CT AND BLEED DIESEL FROM CT. CHAIN AND BOOMER COIL TO REDUCE KICK WHEN CUTTING. CENTRALIFT MEG CABLE ONE LAST TIME. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC : $1,000.00 $9,700.00; ARCO $6,500.00 $31,907.00 BAKER OIL TOOLS $5,403.00 $17,487.00' CENTRILir- i $5,000.00 $20,000.00 COBURN $0.00 $_950.00; DOWELL $9,760.00 $77,974.0~ FMC $2,200.00 $3,300.00 HALLIBURTON $0.00 $12,001.00 .. LI~ ~ LE RED $0.00 $9,960.0~ PEAK $0.00 $,~,000.00 SCHLUMBERGER $0.00 $14,775.00 VECO $4,000.00 $14,000.00 WAREHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $33,863.00 $219,865.00 , TIME 23:00 23:30 00:30 01:00 01:30 02:30 03:30 04:00 04:45 05:00 LOG ENTRY MAKE HYDRAULIC ROU[ iT. ' BREAK OUT QUICK CONNECT FLANGE FROM CT LUB. MAKE UP DSR RISER. CUT CT TO MAKE CTC. FMC MEASURE TO CUT AND INSTALL HANGER. MAKE UP PNEUMATIC CUTTER, MAKE CLEAN FINISH CUT. FOR HANGER INSTALLATION. MU BAKER CONNECTOR, PULL TEST TO 50K, PSI TEST TO 2500, OK MU FMC HANGER, ENERGIZE LOWER PACKING GLAND, PSI TEST TO 5000 FOR 15 MINUTES, OK MU R/R JOINT, ATTEMPT TO STRIP OVER W/LUB, HANGING UP ON SQUARE SHOULDERS OF R/R JOINT. LATCH INTO GS W/CT, PULL TEST LANDING SUB W/TROLLEY TO 6000#, INTERNAL SLIPS NOT HOLDING. BREAK OUT CT HANGER, RE-SET SLIPS, LATCH UP, PULL TEST W/TROLLEY TO 6000#, OK STRIP RISER DOWN ONTO STACK OVER R/R JOINT, FLANGE UP, TAG UP INSIDE LUBRICATOR W/HYD. GS. CHECK EVERYTHING OUT. ATTEMPT TO STING INTO GS INSIDE OF LUBRICATOR. MAKE SEVERAL ATTEMPTS UNSTING LUB, STAB GS BELOW LUB, STRIP OVER W/TROLLEY STING IN, MU LUBRICATOR PULL TEST 30K, OK, PULL 50K, OK, SLACK OFF, PUMP UP CT TO 500 PSI, UNSTING, CHECK HANGER-MARKS, OK 05:45 FINISH FLANGING RISER TO TREE, RE-STAB HYD GS, STRIP LUBRICATOR OVER R/R TOOL, MU, BODY TEST LUBRICATOR TO 500 PSI, OK 06:00 PU STRING WEIGHT, RELEASE SLIPS, PUMP DIESEL .2 BPM, 1033 PSI. LAND COMPLETION INTO HANGiER @ 7165'. PSI UP TO 1300 PSI WHP. SET 4 LOCKDOWN BOLT ON TBG HANGER. VISUALLY VERIFY HANGAR IS IN PLACE BY PULLING 1 LOCKDOWN BOLT. REPLACE LOCKDOWN BOLT. 07:00 PRESSURE TEST HANGAR SEALS TO 5000 PSI - ALL OK 07:30 TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN IN/SIGN OUT IN OPS CAB - DISCUSS ND BOP PROCEDURES - ALL NON;ESSENTIAL PERSONNEL CLEAR OUT OF RIG AREA 08:00 RELEASE HYD GS FROM R&R TOOL - REMOVE INJECTOR AND LUBRICATOR FROM RISER - SET INJECTOR ON BACK DECK - LIFT T-BAR UP - ND RISER 'ON TOP OF BOP STACK - ND ANNULAR PREVENTER AND BLIND SHEAR RAM - ND FLOW CROSS AND DOUBLE GATE BOP - ND MASTER VALVE 11:30 SCAFFOLDING CREW ON LOCATION TO PUT BOARD ACROSS PLATFORM INSIDE SUBBASE - LIFT TOP HAT A TREE CAP ONTO FLOOR ARCO Alaska, Inc. KUPARUK RIVER UNIT -=LL SERVICE REPORT 3H-11(4-1)) WELL JOB SCOPE JOB NUMBER 3H-1 1 DRILLING SUPPORT-EXP WORKOVER 0405991210.3 DATE 05/12/99 DAILY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPLY- I E I SUCCESSFUL Cb ¥,s No I O ¥osNo AFC' ICC# I DAILY COST 999285 23ODS36HO $33,520 Initial Tbg I Final Tbg I Initial IA I 0PSll 1000PSII 0PSI I IKEY PERSON DS-JONES ACCUM COST $186,002 Final IA ]Initial OA IFinal OA ITTL Size 0PSI 0PSI 0PSII 3.188 " DAY 10 FIELD ESTIMATE UNIT NUMBER UNIT #5 SUPERVISOR MENKE Signed ~ IUin ID ,, "[ Depth I 2.250 / 7356 FT DAILY SUMMARY FINISH PICKING UP CENTRILIFT EQUIPMENT - MU TRONIC CONNECTOR BE'rWEEN DEPLOYMENT SUB AND COILED TUBING - RIH W/CT AND BHA - MEG CABLE EVERY 1000' - STAB INTO PKR - PUMP DIESEL THROUGH BHA- PUMP IS TURNING - PULL UP TO CLOSE FLAPPERS - COULD NOT GET 2-3/8" SLIP RAMS TO HOLD - DISCUSSING OPTIONS AT REPORT TIME [ESP Work] TIME LOG ENTRY 12:00 PU UPPER PUMP - BORE OUT EGG SHAPED HOLES ON BOTTOM FLANGE OF UPPER PUMP - MU UPPER PUM LOWER PUMp - MU THRUST CHAMBER/DISCHARGE HEAD WITH SAND SKIRT ON UPPER PUMP - THE THRUST CHAMBER DOES NOT WEIGH MUCH - HAD PROBLEMS GETTING FLANGES TO MAKE UP - SUGGEST MAKING U THRUST CHAMBER ON UPPER PUMP IN CENTRILIFT SHOP 14:30 PU LOWER MOTOR - MU LOWER MOTOR ON THRUST CHAMBER/DISCHARGE HEAD - MU CAP TUBE CLAMPS SUPER. BANDS ON MOTOR WHILE RIH - SET DOWN LOWER MOTOR ON PLATE - VACUUM FILL MOTOR WITH 16:00 PU UPPER MOTOR - MU UPPER MOTOR ON LOWER MOTOR AND SET DOWN ON PLATE - VACUUM FILL UPPE MOTOR WITH OIL 18:00 PU EXPANSION CHAMBER - MU EXPANSION CHAMBER TO UPPER MOTOR - SERVICE EXPANSION CHAMBER 19:00 PU AND MU BAKER DEPLOYMENT SUB ON PUMP/MOTOR'S BHA · 21:00 MU 6 EA SHEAR PINS IN DISCONNECT ON DEPLOYMENT SUB. (4500 #'S EACH -27,000# TOTAL PULLTO SHEAR). START'TO MAKE UP GAUGES ONTO SUB. ' 22:30 GAUGES MADE UP TO DEPLOYMENT SUB, WORK ON HOOKING GAUGES TO TEC WIRE. NEED 1/2" X 1/8" NPT CONNECTOR TO MAKE UP. BAKER DOESN'T HAVE ONE. CALL CFP - 3, WAIT FOR CONNECTION 23:00 FIND CONNECTION FROM DSO, MAKE UP GAUGES, RIH SET SLIPS TO MAKE UP TRONIC CONNECTOR 00:30 SET 2-7/8" SLIPS, DOG COLLAR ON DEPLOYMENT SUB. MU TRONIC CONNECTOR. 01:00 BAKER MU "Y"CONNECTOR, STRIP LUB AND INJECTOR DOWN TO MAKE UP TO SWAB CAP CONNECTION. PU TEST TRONIC CONNECTOR W/10K, SLACK OFF TO STRING WEIGHT OF 6300#, OPEN SLIPS. 03:00 ZERO COUNTER TO RKB AT SNAP LATCH, RIH W/BHA. COUNTER READING BACKWARDS, TROUBLESHOOT. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 ~409.00 APC $500.00 $8,700.00 AR CO $ 6,500.00 $25,407.00 BAKER OIL TOOLS $0.00 $12...,.084.00 CENTRILIFT $5,000.00 $15,000.00 COBURN $0.00 $250.00 DOWELL $19,520.00 $68,214.00 ,,, FMC $0.00 $1,100.00 HALLIBURTON $0.00 $12,001.00 LI-I-rLE RED $0.00 $9,960.00 PEAK $0.00 . $4,000.00 SCHLUMBERGER $0.00 $14,775.00 VECO $2,000.00 $10,00.0.00 WAREHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $33,520.00 $18~,002.00 TIME 03:30 04:00 04:15 04:35 04:50 05:10 05:40 LOG ENTRY E-~"_ MEG CABLE, TAKE PR FPM. .-~TEMP READINGS AT REEL CONNECT(~r .(. RIH W/ELECTROCOIL BHA @ 50 CT @ 1000', 6000# WEIGHT CHECK, MEG ELECTRICAL. OK. HOLD REFRESHER SAFETY MEETING WITH ALL PERSONNEL ON LOCATION. CONTINUE RIH @ 50 FPM. 0 PSI WHP. CT @ 2000', PU WT 10,000#. MEG PIPE AND CHECK ELECTROCOIL. CHECK RETURNS IN TT. 9 BBLS SINCE START RIH - (4.8 BBL/1000' IS CALCULATED CT DISPLACEMENT) ELECTROCOIL CHECKED OUT, RIH. CT @ 3000', PICKUP WT 10,200#. STRAP TANK, RETURNS OK, MEG CABLE, OK. RIH W/BHA. CT @ 4000', PU WEIGHT 19,000#. CHECK RETURNS AND MEG CABLE. 22 BBLS RETURNS-OK, MEG OK, RIH W/CT. 06:05 CT @ 5000', 23,000#. CHECK RETURNS AND MEG CABLE. (29 BBL TOTAL RETURNS). MEG OK, RIH. 06:35 CT @ 6000', WEIGHT CHK, 27,500#, MEG CABLE AND CHECK RETURNS. 33 BBLS TOTAL RETURNS, MEG OK. 07:15 07:30 07:50 08:05 08:20 08:45 09:00 09:20 10:45 11:55 7000' CTM - WEIGHT CHECK 31000 LBS - STRAP TANK - 46 BBLS - RETURNS OK - MEG CABLE - ALL OK - 600 PSI ON COIL X CABLE ANNULUS - BLEED OFF PRESSURE TO BLEED TANK - PRESSURE DOES NOT BUILD BACK UP QUICKLY, THEREFORE RUPTURE DISK IS INTACT CLOSE IN CHOKE - START PUMPING DIESEL AT 0.3 BPM - FLAPPERS OPENED AT 830 PSI - REDUCE RATE TO 0.1 BPM - COIL X CABLE ANNULUS PRESSURE UP TO 375 PSI - BLEED PRESSUE OFF - WEIGHT CHECK 31500 LBS RIH W/CT AT 20 FPM - CONTINUE PUMPING TO KEEP FLAPPER VALVES OPEN - 2000 LBS RUNNING WEIGHT 7100' CTM - STOP RIH - HANGING WEIGHT 5000 LBS - PU WEIGHT 31500 LBS - HANGING WEIGHT AFTER. PU 15000 LBs - CONTINUE RIH AT 20 FPM - TAG DOWN ON PACKER WITH SNAP LATCH AT 7165' CTM - PU WITH CT - PULL OUT OF SNAP LATCH AT 7162' CTM - TOOK 42000 LBS TO PULL OUT (10500 LBS OVERPULL) - PU TO 7145' CTM RIH W! CT - SET DOWN IN SNAP LATCH AT 7165' CTM - SLACK OFF 4000 PSI - HOOK UP LEADS TO POWER CABLE - START PUMPING DIESEL AT 6 BPM AND 1850 PSI - GOOD INDICATION OF VOLTAGE GENERATION FROM MOTOR - SHUT DOWN PUMP - VOLTAGE DROPPED. TO OV TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN IN/SIGN OUT IN OPS CAB - DISCUSS JOB PLAN - CLEAR FLOOR FOR NEXT OPERATION CLOSE 2-3/,8." SLIP RAMS - MARK CT WITH PUNCH LOCK DOWN SCREW - OPEN UP 2-3/8" SLIP RAMS - START PUMPING 0.25 BPM DIESEL TO ENSURE FLAPPERS OPEN - PU18.5' - CAME OUT OF SNAP LATCH WITH 42000 LBS BLEED PRESSURE OFF WELL - NO FLOW TO TANKS - VISUALLy VERIFY - CLOSE 2-3/8" SLIP RAMS AND LOCK CLOSED - ATTEMPT TO SET DOWN WEIGHT ON SLIPS - WOULD NOT HOLD - OPEN SLIP RAMS - FLAG PIPE - POOH TO GET SLIP MARKS AT REEL - SLIP MARKS ON PIPE - SMOOTH OUT MARKS = RIH TO MARK - CONFIRM WITH HYDRIL OK TO USE 3000 PSI TO CLOSE SLIP RAMS - CLOSE 2-3/8" SLIP RAMS WITH '2500 PSI - ATTEMPT TO SET DOWN WEIGHT - SLIGHT SLIPPAGE - PRESSURE UP TO 3000 PSI -.SET DOWN WEIGHT - HOLDING OK - BLEED PRESSURE OFF SKATES - PIPE BEGAN TO MOVE DOWNHOLE - SET INJECTOR BRAKE AND PRESSURED UP SKATES - TUBING STOPPED MOVING- CHECK WELL FOR FLOW NO FLOW - CLOSE ANNULAR PREVENTER -' REPLACE PUNCH SCREW WITH STANDARD LOCK DOWN SCREW TUBING HEAD - OPEN UP ANNULAR PREVENTER - OPEN UP 2-3/8" SLIP RAMS DISCUSSING OPTIONS AT REPORT TIME ARCO Alaska, Inc. KUPARUK RIVER UNIT -'LL SERVICE REPORT 3H-11(4-1)) WELL 3H-1 1 DATE 05/11/99 DAY 9 FIELD ESTIMATE JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPLETE ISUCCESSFUL O Yes .o IO Yes No AFC' ICC, I DAILY COST 999285 23ODS36HO $27,862 IKEY PERSON DS-JONES ACCUM COST $152,482 0PSII 0PSII 0PSI 0PSI 0PSI 0PSII 3.188 ' JOB NUMBER 0405991210.3 UNIT NUMBER UNIT #5 SUPERVISOR GOBER Signed ~ IMinlD 1Del~th 2.250 ' 7356 Fl' DAILY SUMMARY MU TRONIC CONNECTOR ON CABLE AND COIL - PRESSURE TEST TRONIC CONNECTOR W/N2 - FILL CT W/HYDRAULIC OIL - RAN OUT OF OIL - COMPLETED FILLING WITH DIESEL - PRESSURE TEST COIL X CABLE ANNULUS - START MU EQUIPMENT AND RIH AT REPORT TIME [ESP Work] TIME LOG ENTRY 12:00 BEGIN INSTALLATION OF TRONIC CONNECTOR PARTS BELOW COIL CONNECTOR 12:30 DID NOT INSTALL TOP NUT AROUND TRONIC ASSEMBLY - REMOVE TRONIC PARTS INCLUDING COIL CONNECTOR - BEGIN MU OF TRONIC CONNECTOR AGAIN 14:15 THREADS ON PART BELOW COIL CONNECTOR ARE DAMAGED - REMOVE ALL TRONIC PARTS - MEG POWER CABLE TO 1000V - ALL'OK - USE ALL NEW PARTS FOR TRONIC CONNECTOR - BEGIN MU OF TRONIC CONNECTOR - PULL TEST COIL CONNECTOR TO 40000 LBS - ALL OK 15:30 MU ENDS ON POWER CABLE FOR TRONIC CONNECTOR - MEG POWER CABLE TO 1000V - ALL OK 16:45 PRESSURE TEST TRONIC CONNECTOR WITH N2 - ALL OK 19:00 CONTINUE WITH MU OF TRONIC ASSEMBLY - HAVE TO PUT PULL PLATE ON COIL - PUT 4500# DOWN WITH INJECTOR ON PLATE OVER SWAB VALVE TO PUSH BOTTOM PART OF TRONIC CONNECTOR - MU 3 SET SCRE TO HOLD .. 22:00 TRONIC PRESSURE TESTING W/HAND PUMP. LINE UP TRIPLEX TO FILL COIL WI HYDRAULIC OIL. 22:30 CONNECTOR ON CTU @ REEL LEAKING. DISCUSS OPTIONS, BREAK OUT CONNECTOR AND A1-FEMPT TO REPAIR. 23:30 WORKING ON REEL CTU CONNECTOR. LOAD BAKER COMPLETION EQUIPMENT TO RIG FLOOR. 00:10 CONNECTOR OFF OF PIPE, NO O-RINGS INSIDE. PUT O-RINGS INSIDE, MU TO PIPE W/BAKER WIRE PACKOFFS. 01:45 CONNECTOR MADE UP, CHECK OUT REEL MOTOR ON CTU. 02:10 STAB CONNECTOR INTO RISER, PUMP HYDRAULIC FLUID W/TRIPLEX FOR PT 03:20 NOT ENOUGH HYDRAULIC FLUID FOR PRESSURE TEST OF COIL. WAIT ON MORE FLUID. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC $500.00 $8,200.00 ARCO $6,500.00 $18,907.00 BAKER OIL TOOLS $0.00 $12,084~00 CENTRILIFT $5,000.00 $10,000.00 COBURN $0.00 $250.00 , DOWELL $9,760.00 $48,694.00 FMC $0.00 $1,100.00. HALLIBURTON $0.00 $12,001.00; .. LITTLE 'RED $0.00 $9,960.00 PEAK $0.00 $4,000.00 SCHLUMBERGER $0.00 $14,775.00 _VECO $2,000.00 $.8,000.00 _WAREHOUSE $4,102.00 $,4,102.00 TOTAL FIELD ESTIMATE $27,862.00 $152,482.00 i TIME 04:00 04:10 04:40 05:00 06:00 06:30 07:00 07:15 07:30 08:15 10:00 11:30 ,,' , . NO BULK HYDRAULIC F . CALLABLE. MAKE UP TO PUMP DIESEL TL ;MPLETE PT. PUMP ADDITIONAL 1 BBL DIESEL, PRESSURE TEST CONNECTOR TO 2500 PSI. HOLD FOR 5 MINUTES, OK. BLEED OFF. PULL CONNECTOR UP INTO LUB, STAB ONTO WELLHEAD FLOOD LINES TO TIGER TANK PT BODY OF LUBRICATOR TO 1000 PSI, LEAKING THRU STRIPPER. TROUBLESHOOT LEAKING PACKOFFS. FOUND HYDRAULIC HOSES TO PACKOFFS PUT ON BACKWARDS. CORRECT PROBLEM. BREAKOUT LUBRICATOR AND INJECTOR TO CURRENT CHECK CONNECTOR AND CABLE ETC. STRIP CABLE WAIT FOR DSO FOR HOT WORK PERMIT. DSO ISSUED HOT WORK PERMIT TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN IN/SIGN OUT SHEET IN OPS CAB - KEEP PERSONNEL TO A MINIMUM ON FLOOR WHILE MAKING UP ESP EQUIPMENT - DISCUSS WELL CONTROL AND BOP OPERATION MEG POWER CABLE WITH IO00V - ALL OK - CHECK WELL FOR PRESSURE - 0 PSI - OPEN UP MASTER VALVE AND BLIND/SHEAR RAM - REMOVE TREE CAP PU STINGER WITH MULE SHOE ON BOTTOM, BAKER SEAL ASSEMBLY, SNAP LATCH ANCHOR ASSEMBLY, PU JOINT, PORTED SUB, AND PUMP INTAKE - PU LOWER PUMP AND MU TO PUMP INTAKE - TROUBLE MAKING UP 3 BOLTS ON FLANGE PULL PUMP AND INTAKE APART - DECIDE TO RUN THIS PUMP HOUSING AS THE UPPER PUMP - PU OTHER PUMP HOUSING - MU LOWER PUMP ON INTAKE MU 1/4" CAPILLARY TUBE IN PORTED SUB - ATTEMPT TO INSTALL CLAMP AROUND LOWER PUMP FLANGE - CAP TUBE CLAMP WOULD NOT FIT - GRIND DOWN INSIDE EDGES TO MAKE FIT - INSTALL SUPER BAND ON 'PUMP WHILE RIH - SET PUMP DOWN ON PLATE · . ARCO Alaska, Inc. 'WELL 3H-1 1' DAI ~_-' 05/10/99 DAY 8 FIELD ESTIMATE KUPARUK RIVER UNIT _:LL SERVICE REPORT JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPL~IE I SUCCESSFUL I KEY PERSON O Yes (~ No O Yes ~ No DS~JONES AFC, ICC# I DAILY COST ACCUM COST 999285 23ODS36HO $33,770 $124,620 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA I~rLSize 0 PSII 0 PSII 0 PSI 0 PSI 0 PSI 0 PSII 3.188 ' 3H-11(4-1)) JOB NUMBER 0405991210.3 UNIT NUMBER UNIT #5 SUPERVISOR MENKE Signed ~ I 2.250" I 7356 FT DAILY SUMMARY i RIG UP DS CTU, TEST BOPE, MU TRONIC COIL CONNECTOR AND PULL TEST [ESP Work] TIME 12:00 19:00 01:00 03:00 04:00 04:05 06:00 07:00 11:30 11:55 LOG ENTRY AAI WORK PLATFORM IN PLACE, MIRU DOCT # 5 W/7500' OF 2 3/8" ELECTROCOIL. RIG UP HARDLINE ETC. CALL OUT BAKER/TRONIC ETC TO MAKE UP COIL CONNECTOR. CUT CT AND MU MECHANICAL CONNECTOR.. ATTEMP TO PULL TEST TO 40K, PULLED TEST PLATE OVER CONNECTOR AND BUGGERED IT UP. CALL TO COBURN TO HAVE NEW TEST PLATE MACHINED. WAIT ON. BAKER TO ROUND UP SPARE PARTS FO NEW CONNECTOR. CUT PIPE AND DRESS FOR NEW CONNECTOR 2 MORE TIMES. MAKE UP NEW BAKER CONNECTOR. SEND BAKER/TRONIC TRIBE TO THE HOUSE TO RETURN @ 11:00 A.M. TO CONTINUE JOB. FINISH NIPPLING UP RISER TO WELLHEAD. TEST ANNULAR BOP'S TO 2500 PSI (FROM BELOW). OPEN BAG FULL BODY'TEST WELLHEAD ABOVE MASTER VALVE TO 5000 PSI, OK TEST PLATE ARRIVE FROM PRUDHOE BAY. PULL TEST CONNECTOR TO 40,000#'S, OK. DS CREW AND CO. MAN CHANGEOUT WORK ON GOOSENECK ROLLER GUIDE - STANDBY FOR CENTRILIFT PERSONNEL TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN IN/SIGN OUT IN OPS CAB - H2S PAD - DISCUSS FLUID ON LocATION - DISCUSS ESD LOCATIONS - KEEP MINIMUM NUMBER OF PERSONNEL ON FLOOR BEGIN INSTALLATION OF TRONIC CONNECTOR PARTS BELOW COIL CONNECTOR AT REPORT TIME SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC $500.00 $7,700.00 ARCO $6,500.00 $12,407.00 BAKER OIL TOOLS $0.00 $12,084.00 CENTRILIr- I ' $5,000.00 $5','000.00 COBU RN $250.00 ~ $250.00 D OW ELL $19,520.00 ~ $38,934.00 FMC ,, $0.00 , $1,100.00 HALLIBURTON $0.00 $12,001.00 L/~ ILE RED $0.00 $9,960.00 PEAK $0.00 $4,000.00 ..SCHLUMBERGER $0.00 $14,775.00 _VECO $2;000.00 $6,000.00 WAREHOUSE $0.00 $0.00 TOTAL FIELD ESTIMATE $33,770.00 $124,620.00 ARco Alaska, Inc. WELl" 3H-1 1 DA1 E_ 05/09/99 DAY 7 FIELD ESTIMATE KUPARUK RIVER UNIT "LL SERVICE REPORT JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK FISHING BRIDGE PLUG OPERATION COMPLt:I E I SUCCESSFUL I KEY PERSON ~ Yes O No I ~ Yes O No I HFS-LEHMAN AFC# ICC# I DAILY COST ACCUM COST 999285 23ODS36HO $15,387 $90,850 I OA I'IL Inillal Tbg J Final Tbg I Initial IA Final IA Initial OA I Final Size 800PSll 0PSII 0PSI 0PSI 0PSII 0PSI 2,441 " 3H-11(4-1)) JOB NUMBER 0405991210.3 UNIT NUMBER 3437 SUPERVISOR CHANEY Signed IMinlD IDepth 2.250" 7356 FT DALLY SUMMARY RI-I ~llEVED INFLATABLE BRIDGE PLUG FROM BTM PACKER @ 7339' RKB. [Fish] I I TIME 06:00 06:30 LOG ENTRY PU EQUIP @ KIC SHOP. PU TOOLS @ Y-PAD SHOP 06:45 MI HFS, LRS. TGSM- PINCH POINTS, RADIO CONTACT. 07:30 RU HES, LRS. 11:30 PT LUB & ALL FLOW BACK LINES TO TANKS TO 3500#- BONNET FLANGE LEAKED, RE- HAMMERED UP BONNET FLANGE. RE TEST TO 3500#- TEST GOOD. PUMP 10 BBLS .DOWN HOLE. 12:45 RIH W/KJ, 7" GS & BAKER SLV W/7" OTIS FISHING NECK, UNABLE TO PASS THROUGH THE RIG RISER THE ID WAS TO SMALL. 13:15 HOT SHOT FOR 5' PIECE OF 7" LUB. 15:30 17:30 RIH W/SAME SI- I DOWN @ 4525' WLM TAPPED THROUGH TO 4785' WLM, UNABLE TO PASS THROUGH, POOH RIH W/KJ,5.985" GAUGE RING WORKED DOWN TO TOP OF PACKER O 7154' WLM( 7185' RKB), APPEARS TO BE HITTING SOME COLLARS, POOH .; 19:00 RIH W/KJ,7" GS & BAKER SLV W/7' OTIS FISHING 'NECK SET O 7154' WLM(7185' RKB), POOH 21:00 22:00 23:30 03:00 RIH W/KJ, 2.22" CENT'& BOWSPRING CENT & 2" SB, HAD SERVERAL FRICTION BITES, UNABLE TO 'LATCH UP, POOH, MARKS ON SKIRT APPEARS THAT WE WERE ALONG SIDE OF FISH. COMPLETLY RELAX BOW SPRINGS. RIH W/SAME, UNABLE TO LATCH , HUNG UP @ 7180' WLM, BROUGHT PUMP'ON LINE @ 1 BPM, CAME FREE, POOH W/BRIDGE PLUG.PLUG IS IN GOOD CONDITION, RUBBER ELEMENTS IN. GOOD SHAPE. RIH W/KJ, 3" GS PULLED BAKER SLV @ 7154' WLM(7185' RKB), POOH RDMO SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $168.00 $409.00 APC $0.00 ' $7,200.00 ARCO $2,500.00 $5,907.00' BAKER OIL TOOLS $0.00 $12;084.00 CENTRILII- I $0.00 $0.00 COBURN $0.00 $0.00 DOWELL. $0.00 $19,414.00 FMC $0.00 $1,100.00 HALLIBURTON $5,719.00 $12,001.00 Eli 1 LE REU $5,000.00 $9,960.00 PEAK $0.00 $41000.00 SCHLUMBERGER $0.00 $14,775.00 VECO $2,000.00 $4,000.00 WAREHOUSE $0.00 $0.00 TOTAL FIELD ESTIMA I · $15,387.00 $90~'850.00 ARCO Alaska, Inc. WELL 3H-1 1 DATE 05/08/99 _.. DAY 6 FIELi~ ESTI MATE JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK MIRU WELLWORK PLATFORM KUPARUK RIVER UNIT _=LL SERVICE REPORT OPERATION COMPLy- I E I SUCCESSFUL 0 Y,,~ Cfi No I 0 Y,,~ Cfi No AFC, ICC# I DAILY COST 999285 23ODS36HO $11,000 Initial Tbg I Final Tbg I Initial IA I oPsq oPsq oPs~ I IKEY PERSON ACCUM COST $75,463 Final IA I Initial DA IFinal DA IIlL Size 0PSII OPSll 0PSII 0.000 DAILY SUMMARY MIRU WELLWORK PLATFORM - MU LINES TO TANKS - READY FOR CTU AND BOP [ESP Work] 3H-11(4-1)) JOB NUMBER 0405991210.3 UNIT NUMBER SUPERVISOR LIGENZA Signed IMin ID 0.000" IDepth 0 FT TIME 14:00 16:00 LOG ENTRY LEAVE PRB WITH WELLWORK PLATFORM ARRIVE LOCATION WITH PLATFORM - MIRU SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL ' $0.00 $241.0l~.. APC $2,500.00 $7,200.00~7 ARCO $2,500.00 $3,407.00~ BAKER OIL TOOLS $0.00 $12,084.0~' CEN ~ HILIFT $0.00 $0.0~. COBURN ' $o.oo SO.De DOWELL $0.00 $19,414.00)i FMC $0.00 $1,100.0{) HALLIBURTON $0.00 $6,282.0njj Lri i LE RED $0.00 $4,960.0(~ PEAK . $4,000.00 $4,000.0(}~ SCH LUMBERG ER $0.00 $14,775.0~ VECO ' $2,000.00 $~',000.00~- WAREHOUSE $0.00 $0.00~. TOTAL FIELD ESTIMATE $11,000.00 $71~',463.00:~I .. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 16, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3H-11 (Permit No. 87-124/398-009) Report of Sundry Operations Dear Mr. Commissioner: Enclosed is report of Sundry Operations for the recent workover operations on KRU 3H- 11. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineering Supervisor Kuparuk Drilling GLA/skad ORIGINAL ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _ 2. Name of Operator: 15. ARCO Alaska, Inc. I 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 Stimulatem Alter casing _ Type of Well: Development X. Exploratory ~ Stratagraplc ~ Service ~ Plugging _ Perforate _ Repair well _ Other _X 6. Datum of elavation (DF or KB feet): 76' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 3H-11 9. Permit number/approval number: 87-124/398-009 10. APl'number: 50-103-20091-00 11. Field/Pool: Kuparuk River Field / Oil Pool 4. Location of well at surface: 1232' FNL, 281' FWL, Sec 12, T12N, R8E, UM At top of productive interval: 1367' FNL, 1294' FEL, Sec 12, T12N, RSE, UM At effective depth: 1324' FNL, 1103' FEL, Sec 12, T12N, R8E, UM At total depth: 1316' FNL, 1042' FEL, Sec 12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7750 feet Plugs (measured) None 6460 feet Effective Depfl measured true vertical 7635 feet Junk (measured) None 6364 feet Casing Length Conductor 80' Surface 3602' Production 7681' Liner Size Cemented Measured depth 16" 215 Sx AS I 115' 10-3/4" 1200 Sx AS III & 3637' 600 Sx Class G w/130 Sx AS I top job 7" 650 Sx Class G & 7716° 300 Sx AS I True vertical depth 115' 3087' 6432' Perforation Depth measured true vertical 7274'-7304'; 7371'-7383'; 7391'-7411 '; 7430'-7450' 6059'-6085'; 6141'-6151'; 6158'-6175'; 6191'-6208' ORIfilN.AL Tubing (size, grade, and measured depth) 2-3/8" coiled tubing @ 7185' 'RECEIVED Packers and SSSV (type and measured depth) Packers: Baker FB-1 @ 7185' (Otis WD left in hole @ 7339'); SSSV:None 13. Stimulation or cement squeeze summary ~a Oil & ~as Oon.s. C,~.~St'~s 14. N/A Anch0rag0 Intervals treated (measured) N/A Treatment description including volumes used and final pressure Installed coiled tubing deployed electric submersible pump, Representifive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 620 390 4919 875 177 Subsequent to operation 320 168 4517 15. Attachments X Schematic 116. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _Z Oil X .Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 12 741 Suspended Service Form 10-~,04'~ev .... 0'~'''''~ 6/15/88 Title: Drilling Superintendent Date SUBMIT IN DUPUCATE ARCO Alaska, Inc. (" {' ,KUPARUK RIVER UNIT ~!~ ELL SERVICE REPORT ~l~ 3H-11(4-1)) -- -- WELL JOB SCOPE JOB NUMBER 3H-1 1 DRILLING SUPPORT-EXP WORKOVER 0405991210.3 DATE DAILY WORK UNIT NUMBER 05/14/99 INSTALL ELECTROCOIL COMPLETION UNIT #5 DAY OPERATION COMPLP_.IE I SUCCESSFUL KEY PERSON SUPERVISOR 12 ~'~ Yes O NoJ ~'~ Yes O No DS-JONES MENKE · ESTI MATE 999285 23ODS36HO $23,780 $243,645 __ ll00PSII 1200PSII 0PSI 0PSI 0PSII 0PSII 0.000 " ' 0.000 " OFT DALLY SUMMARY I SPLICE PENETRATORS - NU WELLHEAD AND PENETRATORS - DO ELECTRICAL CHECKS - ALL OK - MU CONNECTIONS ON TOP HAT - MU PRESSURE RELIEF VALVE - PUMP TEST ESP MOTOR - RDMO CTU [ESP Work] TIME LOG ENTRY 12:00 SCAFFOLDING BEING BUILT AROUND TREE 13:00 TGSM - DISCUSS JOB PLAN - ONLY 2 PEOPLE ALLOWED ON SCAFFOLDING - MUST WEAR FALL PROTECTION ON SCAFFOLDING - ROPED OFF AREA ON FLOOR FOR SPECTATORS 13:30 BEGIN TERMINATION OF POWER CABLE SPLICE TO FLEX LEADS 16:00 .. NU TOP,HAT ON TUBING SPOOL.- TEST VOID SPACE TO 5000.PSI - ALL OK . · ... 17:30 RUN FEED THROUGH CONNECTORS :THROUGH TOP~'FLANGE - MU TOP FLANGE - MU PACKING AROUND'~ FEEDTHROUGHS - DO ELECTRICAL CHECKS ON POWER' CABLE AND I-WIRE - ALL OK ' 19:50 PRESSURE RELIEF VALVE MADE UP. INJECTION TEST TO CHECK MOTOR. 5.5 BPM, 2000 PSI. MOTOR CHECKED OUT, COMPLETION STUNG INTO PKR OK. WHP BLED TO 1200.PSI. 08:15 START TO RIG DOWN DS CTU #5. ~ 21:00 CONTACT APC, RELEASE FLOWBACK/DIESEL TANKS/HARDLINE ETC..CONTACT VECO. TO COME PICKUP 3 ".RISER SPOOLS TO RETURN TO MI. CONTACT SCAFFOLD CREW TO BE ON LOC IN A.M. FOR.ELECTRICIANS. 22:00 CUT CONNECTOR FROM CT, DS TAKE WITH THEM FOR' BAKER TO PICKUP. CONTINUE RIG DOWN, SQUARE 'AWAY UNIT' .23:30 UNIT RELEASED, LEAVE LOCATION .... SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL , $0.00 $409.00 APC $500.00 $10,200.00 ARCO $6,520.00 $38,427.00 ~ ~IAKER OIL TOOLS $0.00 $17,487.00 C..... E NT RILl FT $5,000.00 $25,000.00 COBURN $0.00 $250.00 DOWELL $9,760.00 $87,734.00 FMC $0.00 $3,300.00 HALLIBURTON $0.00 $12,001.00 LITTLE RED $0.00 $9,960.00 PEAK $0.00 $4,000.00 SCHLUMBERGER $0.00 ' $14,775.00 VECO $2,000.00 $16,000.00 ,, WAR EHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $23,780.00 $243,645.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ZLL SERVICE REPORT 3H-11(4-1)) WELL 3H-1 1 'DATE' 05/13/99 DAY 11 · FIELD ESTIMATE JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPLETE I SUCCESSFUL O Yes ~ No I O Yes ~ NO AFC# ICC# I DAILY COST 999285 23ODS36HO $33,863 Initial Tbg I Final Tbg I oPsq oPsq Initial IA I Final IA10 PSI 0 PSI IKEY PERSON DS-JONES ACCUM COST $219,865 Initial OA I Final OA ITTL Size oPs l oPS l o.ooo" JOB NUMBER 0405991210.3 UNIT NUMBER UNIT #5 SUPERVISOR GOBER Signed .~~ IMin I Depth I o.ooo" I o FT DALLY SUMMARY IINSTALL NEW 2-3/8" SLIP RAMS IN 2-7/8" SLOT - CUT PIPE - MU FMC TBG HANGAR ON CT - LAND TBG HANGAR IN TBG SPOOL - ND BOP STACK - BUILD SCAFFOLDING AT REPORT TIME SPLICE PENETRATORS - NU WELLHEAD AND PENETRATORS - DO ELECTRICAL CHECKS - ALL OK - MU CONNECTIONS ON TOP HAT AT REPORT TIME [ESP Work] TIME 12:00 13:30 15:00 17:00 19:45 19:55 20:00 20:15 20:30 21:00 21:30 22:'15 22:30 LOG ENTRY DISCUSS OPTIONS - LOOKING FOR REPLACEMENT SLIP RAMS - POOH TO GET SLIP MARKS AT REEL - SOME MARKS ON PIPE SENT ALL CENTRILIFT AND TRONIC PERSONNEL TO CAMP FOR SLEEP DECIDE TO MAKE NEW 2-3/8" SLIP RAMS FOR BOP STACK' CHECKING .FLOWBACK TANK LEVEL PERIODICALLY - NO FLOW - FLAPPERS ARE HOLDING GOOD - 0 PSI ON COIL"X CABLE ANNULUS FOUND HYDRIL 2-3/8" SLIP BODIES IN DOWELL'S YARD - CONFIRM?THEY ARE CORRECT BODIES - WAIT ON SLIP BODIES TO BE DELIVERED SLIP RAMS ARRIVE, SAFETY MEETING TO. DISCUSS CHANGING OUT OF SLIPS. BREAK OUT 2 7/8" SLIP RAMS, REPLACE W/2 3/8" SLIPS (NOW HAVE TWO SETS OF 2 3/8" SLIPS IN BOP'S) PRESSURE TEST BONNET AND STACK TO 500 PSI, OK ' MOVE PIPE TO CHECK UP AND DOWN WEIGHTS. POSITION CTU @ FLAG (7147.6' CTM). SET SLIPS. STACK 5000# DOWN, PU 5000# OVER, SLACK OFF TO NEUTRAL POINT. SLOWLY RELEASE INJ.· CHAIN PRESSURE SLIPS SET, CLOSE ANNULAR BAG. BLEED AND DRAIN STACK AND LUBRICATOR UNFLANGE SWAB QUICK CONNECT FROM RISER, STRIP LUB AND INJECTOR UP OVER COIL. POSITION DOG COLLAR W/PLATE. " CHECK MEASUREMENTS FROM LOCK SCREW DIMPLER AND BOP MARKS ON PIPE. 53" BELOW CENTER OF T SLIP RAMS. FIND DIMPLER, RIG UP HOT TAP AND HYDRAULIC ROUGH CUTTER. HOT TAP CT AND BLEED DIESEL FROM CT. CHAIN AND BOOMER COIL TO REDUCE KICK WHEN CUTTING. CENTRALIFT MEG CABLE ONE LAST TIME. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC $1,000.00 $9,700.00 ARCO $6,500.00 $31,907.00 "BAKER OIL TOOLS $5,403.00 $17,487.00 CENTRILIFT $5,000.00 $20,000.00 i COBURN $0.00 $250.00 i DOWELL $9,760.00 $77,974.00; FMC $2,200.00 $3,300.00i HALLIBURTON $0.00 $12,001.00I LITTLE RED . $0.00 $9,960.00 PEAK $0.00 $4,000.00 SCHLUMBERGER $0.00 $14,775.00 VECO $4,000.00 $14,000.00 , WAREHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $33,863.00 $219,865.00 TIME 23:00 23:30 00:30 01:00 01:30 02:30 03:30 LOG ENTRY ["~" {"' MAKE HYDRAULIC ROUG~ ~T. BREAK OUT QUICK CONNECT FLANGE FROM CT LUB. MAKE UP DSR RISER. CUT CT TO MAKE CTC. FMC MEASURE TO CUT AND INSTALL HANGER. MAKE UP PNEUMATIC CUTTER, MAKE CLEAN FINISH CUT. FOR HANGER INSTALLATION. MU BAKER CONNECTOR, PULL TEST TO 50K, PSI TEST TO 2500, OK MU FMC HANGER, ENERGIZE LOWER PACKING GLAND, PSI TEST TO 5000 FOR 15 MINUTES, OK MU R/R JOINT, ATTEMPT TO STRIP OVER W/LUB, HANGING UP ON SQUARE SHOULDERS OF PJR JOINT. LATCH INTO GS W! CT, PULL TEST LANDING SUB W/TROLLEY TO 6000#, INTERNAL SLIPS NOT HOLDING. BREAK OUT CT HANGER, RE-SET SLIPS, LATCH UP, PULL TEST WI TROLLEY TO 6000#, OK STRIP RISER DOWN ONTO STACK OVER R/R JOINT, FLANGE UP, TAG UP INSIDE LUBRICATOR W/HYD. GS. CHECK EVERYTHING OUT. 04:00 ATTEMPT TO STING INTO GS INSIDE OF LUBRICATOR. MAKE SEVERAL ATTEMPTS 04:45 UNSTING LUB, STAB GS BELOW LUB, STRIP OVER W/TROLLEY STING IN, MU LUBRICATOR 05:00 05:45 06:00 PULL TEST 30K, OK, PULL 50K, OK, SLACK OFF, PUMP UP CT TO 500 PSI, UNSTING, CHECK HANGER-MARKS, OK FINISH FLANGING RISER TO TREE, RE-STAB HYD GS, STRIP LUBRICATOR OVER R/R TOOL, MU, BODY TEST LUBRICATOR TO 500 PSI, OK PU STRING WEIGHT, RELEASE SLIPS, PUMP DIESEL .2 BPM, 1033 PSI. LAND COMPLETION INTO HANGER O 7165'. PSI UP TO 1300 PSI WHP. SET 4 LOCKDOWN BOLT ON TBG HANGER. VISUALLY VERIFY HANGAR IS IN PLACE BY PULLING 1 LOCKDOWN BOLT. REPLACE LOCKDOWN BOLT. 07:00 PRESSURE TEST HANGAR SEALS TO 5000 PSI - ALL OK .. 07:30 < 08:00 11:30 TGSM- MUSTER AREA ATiPAD' ENTRANCE- SIGN IN/SIGN OUT IN OPS CAB- DISCUSS ND'BOP .PROCEDURES - ALL NON-ESSENTIAL PERSONNEL'CLEAR OUT OF RIG AREA " ' " RELEASE HYD GS FROM R&R TOOL - REMOVE INJECTOR AND LUBRICATOR FROM RISER.~' SET INJECTOR ON BACK DECK - LIFT T-BAR UP - ND, RISER ON TOP OF BOP STACK -.ND ANNULAR PREVENTER AND BLIND SHEAR RAM -' ND FLOW CROSS AND DOUBLE GATE BOP - ND MASTER VALVE SCAFFOLDING CREW ON LOCATION TO PUT BOARD ACROSS PLATFORM INSIDE SUBBASE - LIFT TOP HAT A TREE CAP ONTO FL:OOR ARCO Alaska, Inc. ~* (' -- KUPARUK RIVER UNIT --'LL SERVICE REPORT 3H-11(4-1)) WELL JOB SCOPE JOB NUMBER 3H-1 1 DRILLING SUPPORT-EXP WORKOVER 0405991210.3 DATE 05/12/99 DAY 10 FIELD ESTI MATE , DALLY WORK INSTALL ELECTROCOIL COMPLETION UNIT NUMBER UNIT #5 OPERATION COMPLETE I SUCCESSFUL I KEY PERSON SUPERVISOR O Yes ~ No I O Yes ~ No I DS-JONES MENKE AFC, ICC# I DAILY COST ACCUM COST Signed ~~~,jt 999285 23ODS36HO $33,520 $186,002 I nitialmbg I Fina, mb; I,nit,a, p I FinallA I lnitialOA I FinalOA I'l-rLSize I MinlD "[ Depth 0PSII 1000PSII SI 0PSI 0PSII 0PSII 3.188" I 2.250 " / 7356 FT DAILY SUMMARY FINISH PICKING UP CENTRILIFT EQUIPMENT - MU TRONIC CONNECTOR BETWEEN DEPLOYMENT SUB AND COILED TUBING - RIH W/CT AND BHA - MEG CABLE EVERY 1000'- STAB INTO PKR - PUMP DIESEL THROUGH BHA - PUMP IS TURNING - PULL UP TO CLOSE FLAPPERS - COULD NOT GET 2-3/8" SLIP RAMS TO HOLD - DISCUSSING OPTIONS AT REPORT TIME [ESP Work] TIME LOG ENTRY 12:00 PU UPPER PUMP - BORE OUT EGG SHAPED HOLES ON BOTTOM FLANGE OF UPPER PUMP - MU UPPER PUM LOWER PUMP - MU THRUST CHAMBER/DISCHARGE HEAD WITH SAND SKIRT ON UPPER PUMP - THE THRUST . CHAMBER. DOES NOT WEIGH MUCH - HAD PROBLE~MS GETTING' FLANGES TO MAKE UP - SUGGEST MA~KINGU THRUST CHAMBER O'N UPPER PUMP IN CENTRILIFT' SHOP .'":. , ..... ~ ".~. 14:30 PU' LOWER'MOTOR -' MU LOWER MOTOR ON THRUST CHAMBER/DISCHARGE HEAD - MU CAP TUBE CLAMPS' .;' SUPER BANDS ON MOTOR WHILE RIH - SET DOWN LOWER MOTOR ON PLATE - VACUUM FILL MOTOR WITH 16:00 PU UPPER MOTOR - MU UPPER MOTOR ON LOWER MOTOR' AND SET DOWN ON PLATE - VACUUM FILL UPPE.. MOTOR WITH OIL · 18:00" PU EXPANSION CHAMBER'- MU EXPANSION CHAMBER TO UPPER MOTOR - SERVICE EXPANSION CHAMBER 19:00' PU AND MU BAKER DEPLOYMENT SUB ON PUMP/MOTOR'S BHA ~ 21:00 ' MU 6 EA SHEAR PINS IN DISCONNECT ON DEPLOYMENT SUB. (4500 #'S EACH - 27,000~ TOTAL PULL TO. : SHEAR). START TO MAKE UP GAUGES ONTO SUBi : : " :. '"' 22:30 GAUGES MADE UP TO DEPLOYMENT SUB, WORK ON HOOKING GAUGES TO TEC WIRE. NEED 1/2" X'1/8" NPT CONNECTOR TO MAKE UP. BAKER DOESN"r HAVE ONE. CALL CFP - 3, WAIT FOR CONNECTION 23:00 FIND CONNECTION FROM DSO, MAKE UP'GAUGES, RIH SET SLIPS TO MAKE UP TRONIC CONNECTOR 00:30 SET 2-7/8" SLIPS, DOG COLLAR ON DEPLOYMENT SUB. MU TRONIC CONNECTOR. 01:00 BAKER MU "Y"CONNECTOR, STRIP LUB AND INJECTOR DOWN TO MAKE UP TO SWAB CAP CONNECTION. PU TEST TRONIC CONNECTOR W/10K, SLACK OFF TO STRING WEIGHT OF 6300#, OPEN SLIPS. 03:00 ZERO COUNTER TO RKB AT SNAP LATCH, RIH W/BHA. COUNTER READING BACKWARDS, TROUBLESHOOT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC $500.00 $8,'700.00 ARCO $6,500.00 $25,407.00 BAKER OIL TOOLS $0.00 $12;084.00 CENTRILIFT . $5,000.00 $15,000.00 COBURN $0.00 $250.00 DOW ELL $19,520.00 $68,214.00 FMC $0.00 $1,100.00 HALLIBURTON $0.00 $12,001.00 LITTLE RED $0.00 $9,960.00 PEAK $0.00 $4,000.00 SCHLUMBERG ER $0.00 $14,775.00 VECO $2,000.00 $10,000.00 WAREHOUSE $0.00 $4,102.00 TOTAL FIELD ESTIMATE $33,520.00 $186,002.00 , , TIME 03:30 04:00 04:15 04:35 LOG ENTRY Si MEG CABLE, TAKE PRE FPM. -:/TEMP READINGS AT REEL CONNECTOF .(. RIH W/ELECTROCOIL BHA @ 50 CT @ 1000', 6000# WEIGHT CHECK, MEG ELECTRICAL. OK. HOLD REFRESHER SAFETY MEETING WITH ALL PERSONNEL ON LOCATION. CONTINUE RIH @ 50 FPM. 0 PSI WHP. CT @ 2000', PU WT 10,000#. MEG PIPE AND CHECK ELECTROCOIL. CHECK RETURNS IN TT. 9 BBLS SINCE START RIH - (4.8 BBL/1000' IS CALCULATED CT DISPLACEMENT) 04:50 ELECTROCOIL CHECKED OUT, RIH. 05:10 CT @ 3000', PICKUP WT 10,200#. STRAP TANK, RETURNS OK, MEG CABLE, OK. RIH W! BHA. 05:40 CT @ 4000', PU WEIGHT 19,000#. CHECK RETURNS AND MEG CABLE. 22 BBLS RETURNS-OK, MEG OK, RIH W/CT. 06:05 CT @ 5000', 23,000#. CHECK RETURNS AND MEG CABLE. (29 BBL TOTAL RETURNS). MEG OK, RIH. 06:35 CT @ 6000', WEIGHT CHK, 27,500#, MEG CABLE AND CHECK RETURNS. 33 BBLS TOTAL RETURNS, MEG OK. 07:15 7000' CTM - WEIGHT CHECK 31000 LBS - STRAP TANK - 46 BBLS - RETURNS OK - MEG CABLE - ALL OK - 600 PSI ON COIL X CABLE ANNULUS - BLEED OFF PRESSURE TO BLEED TANK - PRESSURE DOES NOT BUILD BACK UP QUICKLY, THEREFORE RUPTURE DISK IS INTACT 07:30 07:50 08:05 08:20 08:45 09:00 09:20 10:45 11:55 CLOSE IN CHOKE - START PUMPING DIESEL AT 0.3 BPM - FLAPPERS OPENED AT 830 PSI - REDUCE RATE TO 0.1 BPM - COIL X CABLE ANNULUS PRESSURE UP TO 375 PSI - BLEED PRESSUE OFF - WEIGHT CHECK 3150O LBS RIH W! CT AT 20 FPM - CONTINUE PUMPING TO KEEP FLAPPER VALVES OPEN - 2000 LBS RUNNING WEIGHT 7100' CTM- STOP RIH - HANGING WEIGHT 5000 LBS- PU WEIGHT 31500 LBS- HANGING WEIGHT AFTER. · PU 15000 LBS- CONTINUE RIH AT 20 FPM- TAG DOWN ON PACKER WITH SNAP. LATCH AT 7165' CTM- . '. 'PU WITH CT- PULL OUT OF SNAP LATCH AT '7162' CTM-"TOOK 42000~LBS TO PULL' OUT (10500 LBS OVERPULL)- PU TO 7145' CTM' "'..' RIH W/CT - SET DOWN IN SNAP LATCH AT 7165' CTM - SLACK OFF 4000 PSI - HOOK UP LEADS TO POWER CABLE - START PUMPING DIESEL AT 6 BPMAND 1850-PSI" GOOD.INDICATION OF VOLTAGE GENERATION FROM MOTOR - SHUT DOWN PUMP - VOLTAGE DROPPED TO 0V TGSM'- MUSTER AREA AT PAD ENTRANCE -'SIGN IN/SIGN OUT IN OPS CAB - DISCUSS JOB PLAN - CLEAR FLOOR FOR NEXT OPERATION . .! CLOSE 2-3/,8" SLIP RAMS - MARK CT WITH PUNCH LOCK DOWN SCREW - OPEN UP 2-3/8" SLIP RAMS - START PUMPING 0.25 BPM DIESEL TO ENSURE FLAPPERS OPEN - PU 18.5'.- CAME OUT OF SNAP LATCH ' WITH 42000 LBS BLEED PRESSURE OFF WELL - NO FLOW TO TANKS - VISUALLY VERIFY - CLOSE 2-3/8" SLIP RAMS AND LOCK CLOSED - ATTEMPT TO SET DOWN WEIGHT ON SLIPS - WOULD NOT HOLD - OPEN SLIP RAMS - FLAG PIPE - POOH TO GET SLIP MARKS AT REEL - SLIP MARKS ON PIPE - SMOOTH OUT MARKS' RIH TO MARK - CONFIRM WITH HYDRIL OK TO USE 3000 PSI TO CLOSE SLIP RAMS - CLOSE 2-3/8" SLIP RAMS WITH 2500 PSI - ATTEMPT TO SET DOWN WEIGHT - SLIGHT SLIPPAGE - PRESSURE UP TO 3000 PSI - SET DOWN WEIGHT - HOLDING OK - BLEED PRESSURE OFF SKATES - PIPE BEGAN TO MOVE DOWNHOLE - SET INJECTOR BRAKE AND PRESSURED UP SKATES - TUBING STOPPED MOVING - CHECK WELL FOR FLOW NO FLOW - CLOSE ANNULAR PREVENTER - REPLACE PUNCH SCREW WITH STANDARD LOCK DOWN SCREW TUBING HEAD - OPEN UP ANNULAR PREVENTER - OPEN UP 2-3/8" SLIP RAMS DISCUSSING OPTIONS AT REPORT TIME ARCO Alaska, Inc. KUPARUK RIVER UNIT _=LL SERVICE REPORT 3H-11 (4-1)) WELL 3H-1 1 DATE 05/11/99 DAY 9 FIELD ESTIMATE · JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DALLY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPLETE ISUCCESSFUL 0 Ye, ~ No I ~'~ Ye, ~'~ No AFC. Jr ICC. I DAILY COST 999285 23ODS36HO :$27,862 Initial Tbg0PSIII Final Tbg 0PSI IInitial 0PsllA I IKEY PERSON DS-JONES ACCUM COST $152,482 Final IA I Initial OA I Final OA ITTL Size 0PSII 0PSII 0PSI~ 3.188 " JOB NUMBER 0405991210.3 UNIT NUMBER UNIT #5 SUPERVISOR GOBER Signed ~ IMinlD 1Del~th 2.250" 7356 FT DALLY SUMMARY MU TRONIC CONNECTOR ON CABLE AND COIL - PRESSURE TEST TRONIC CONNECTOR W! N2 - FILL CT W/HYDRAULIC OIL - RAN OUT OF OIL - COMPLETED FILLING WITH DIESEL - PRESSURE TEST COIL X CABLE ANNULUS - START MU EQUIPMENT AND RIH AT REPORT TIME [ESP Work] TIME LOG ENTRY 12:00 BEGIN INSTALLATION OF TRONIC CONNECTOR PARTS BELOW COIL CONNECTOR 12:30 DID NOT INSTALL TOP NUT AROUND TRONIC ASSEMBLY- REMOVE TRONIC PARTS INCLUDING COIL CONNECTOR - BEGIN MU OF TRONIC CONNECTOR AGAIN. 14:15 THREADS ON PART BELOW COIL CONNECTOR ARE DAMAGED - REMOVE ALL TRONIC PARTS - MEG.,POWER ..~ CABLE TO 1000V'"- ALL OK - USE ALL NEW PARTS FOR,.TRONIC CONNECTOR'-'BEGIN MU OF TRONIC .... "~' CONNECTOR - PULL TEST COIL CONNECTOR TO 400'010'. LBS - ALL OK ...... '.'." '" 15:30 MU ENDS ON POWER CABLE FOR TRONIC CONNECTOR -' MEG POWER CABLE TO 1000V - ALL OK 16:45 PRESSURE TEST TRONIC CONNECTOR WITH N2 - ALL:OK.. 19:00 CONTINUE WITH MU OF'TRONIC ASSEMBLY - HAVE TO PUT PULL PLATE ON COIL - PUT 4500# DOWN'WITH INJECTOR ON PLATE OVER SWAB VALVE TO PUSH BOTTOM PART OF TRONIC CONNECTOR - MU 3 SET SCRE TO HOLD . . 22:00 TRONIC PRESSURE TESTING W/HAND PUMP..LINE UP TRIPLEX TO FILL COIL W/HYDRAULIC OIL. 22:30 CONNECTOR ON CTU @ REEL LEAKING. DISCUSS! OPTIONS, BREAK OUT CONNECTOR AND A'I-TEMPT TO REPAIR. , ~ 23:30 WORKING ON REEL CTU CONNECTOR. LOAD BAKER COMPLETION EQUIPMENT TO RIG FLOOR. 00:10 CONNECTOR OFF OF PIPE, NO O-RINGS INSIDE. PUT O-RINGS INSIDE, MU TO PIPE WI BAKER WIRE PACKOFFS .... . . 01:45 CONNECTOR MADE UP, CHECK OUT REEL MOTOR ON CTU. ' 02:10 STAB CONNECTOR INTO RISER, PUMP HYDRAULIC FLUID W/TRIPLEX FOR PT 03:20 NOT ENOUGH HYDRAULIC FLUID FOR PRESSURE TEST OF COIL. WAIT ON MORE FLUID. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00 APC $500.00 $8,200.00 ARCO $6,500.00 $18,907.00 BAKER OIL TOOLS $0.00 $12,084.00 CENTRILIFT $5,000.00 $10,000.00 COBURN $0.00 $250.00 DOW ELL $9,760.00 $48, .694.00_ FMC $0.00 $1,100.00 ..HALLIBURTON $0.00 $12,001.00 LITTLE RED $0.00 $9,960.00. PEAK $0.00 $4,000.00; SCHLUMBERGER $0.00 $14,775.00: VECO $2,000.00 $8,000.00 WAREHOUSE $4,102.00 $4,1' 02.00 , TOTAL FIELD ESTIMATE $27,862.00 $152,482.00 TIME 04:00 04:10 04:40 05:00 06:00 LOG ENTRY U(" (~ NO BULK HYDRAULIC FL . CALLABLE. MAKE UP TO PUMP DIESEL T( .;MPLETE PT. PUMP ADDITIONAL 1 BBL DIESEL, PRESSURE TEST CONNECTOR TO 2500 PSI. HOLD FOR 5 MINUTES, OK. BLEED OFF. PULL CONNECTOR UP INTO LUB, STAB ONTO WELLHEAD FLOOD LINES TO TIGER TANK PT BODY OF LUBRICATOR TO 1000 PSI, LEAKING THRU STRIPPER. TROUBLESHOOT LEAKING PACKOFFS. FOUND HYDRAULIC HOSES TO PACKOFFS PUT ON BACKWARDS. CORRECT PROBLEM. 06:30 BREAKOUT LUBRICATOR AND INJECTOR TO CURRENT CHECK CONNECTOR AND CABLE ETC. STRIP CABLE WAIT FOR DSO FOR HOT WORK PERMIT. 07:00 DSO ISSUED HOT WORK PERMIT 07:15 TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN IN/SIGN OUT SHEET IN OPS CAB - KEEP PERSONNEL TO A MINIMUM ON FLOOR WHILE MAKING UP ESP EQUIPMENT - DISCUSS WELL CONTROL AND BOP OPERATION 07:30 08:15 10:00 11:30 MEG POWER CABLE WITH lO00V - ALL OK - CHECK WELL FOR PRESSURE - 0 PSI - OPEN UP MASTER VALVE AND BLIND/SHEAR RAM - REMOVE TREE CAP PU STINGER WITH MULE SHOE ON BOTTOM, BAKER SEAL ASSEMBLY, SNAP LATCH ANCHOR ASSEMBLY, PU JOINT, PORTED SUB, AND PUMP INTAKE - PU LOWER PUMP AND MU TO PUMP INTAKE - TROUBLE MAKING UP 3 BOLTS ON FLANGE PULL PUMP AND INTAKE APART - DECIDE TO RUN THIS PUMP HOUSING AS THE UPPER PUMP - PU OTHER PUMP HOUSING - MU LOWER PUMP ON INTAKE MU 1/4" CAPILLARY TUBE IN PORTED SUB - ATTEMPT TO INSTALL CLAMP AROUND LOWER PUMP FLANGE - CAP TUBE CLAMP WOULD NOT FIT - GRIND DOWN INSIDE EDGES TO MAKE FIT - INSTALL SUPER BAND ON PUMP WHILE RIH - SET PUMP DOWN ON PLATE ,Alaska OJJ & Gas Cons. Anchora§.3 ARCO Alaska, Inc. "WELL 3H-1 1 ' DATE 05/1 0/99 · DAY 8 FIELD ESTIMATE . KUPARUK RIVER UNIT _=LL SERVICE REPORT 3H-11(4-1)) JOB SCOPE JOB NUMBER DRILLING SUPPORT-EXP WORKOVER 0405991210.3 IKEY PERSON DS-JONES ACCUM COST $124,620 IA IFinal IA Ilnitial OA IFinal OA ITTLSize 0PSI 0PSI 0PSll 0PSll 3.188 " DAILY WORK INSTALL ELECTROCOIL COMPLETION OPERATION COMPLE:I E I SUCCESSFUL o Y,, e .o I oYes j~ NO AFC' JOe. J DAILY COST 999285 23ODS36HO $33,770 Initial Tbg I Final Tbg I Initial OPS~I OPSII UNIT NUMBER UNIT #5 SUPERVISOR MENKE Signed ~ IMin ID I DelSth I 2.250" I 7356 FT DAILY SUMMARY RIG UP DS CTU, TEST BOPE, MU TRONIC COIL CONNECTOR AND PULL TEST [ESP Work] TIME LOG ENTRY 12:00 AAI WORK PLATFORM IN PLACE, MIRU DOCT # 5 W/7500' OF 2 3~8" ELECTROCOIL. RIG UP HARDLINE ETC. 19:00 CALL OUT BAKER/TRONIC ETC TO MAKE UP COIL CONNECTOR. CUT CT AND MU MECHANICAL CONNECTOR. ATTEMP TO PULL TEST TO 40K, PULLED TEST PLATE OVER CONNECTOR AND BUGGERED IT UP. 03:00 . ' 04:00 SEND BAKER/TRONIC TRIBE TO THE HOUSE TO.RE'I~URN ¢~ 11:00 A.M. TO CONTINUE JOB. ...:,.'.. ~'.', "' 04:05 06:00 CALL TO COBURN TO HAVE NEW TEST PLATE MACHINED. WAIT ON BAKER T.O ROUND UP SPARE PARTS .FO NEW CONNECTOR. CUT PIPE AND DRESS FOR..NEW?CONNECTOR~2 MORE TIMES. :'. ,~, . . .... '.. ~..~,," ~. ~. MAKE UP NEw BAKER CONNECTOR.'.' , '..' ..... , . FINISH NIPPLING UP RISER TO WELLHEAD. TEST..ANNULAR BOP'S TO 2500 PSI (FROM BELOW). OPEN BAG FULL BODY TEST WELLHEAD ABOVE MASTER VALVE TO 5000 PSI.~ OK ~.. ... "~' TEST PLATE ARRIVE' FROM" PRUDHOE BAY. PULL TEST CONNECTOR. TO 40,000#'S, OK. DS. CREW AND CO. MAN CHANGEOUT 07:00 .. WORK ON GOOSENECK ROLLER GUIDE"'- STANDBY FOR CENTRILIFT.PERSONNEL . .' 11:30 :. ' TGSM - MUSTER AREA AT PAD ENTRANCE - SIGN. IN/SIGN OUT IN OPS CAB - H2S PAD - DISCUSS FLUID " ON LOCATION -' DISCUSS LSD LOCATIONS - KEEP MINIMUM NUMBER OF PERSONNEL'ON FLOOR . '~', 11:55 BEGIN INSTALLATION OF TRONIC CONNECTOR PARTS BELOW COIL CONNECTOR AT REPORT TIME ' .'..~' ,. , ,: SERVICE.COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $409.00- APC $500.00 $7,700.00: ARCO $6,500.00 $12,407.00 BAKE ROI L TOOLS $0.00 $12,064.00 CENTRILIFr $5,000.00 $5,000.00 CO B U R N $250.00 $250.00 'DOW'ELL $19,5~0.00 $38,934.00 FMC $0.00 $1,100.00 HALLIBURTON $0.00 $12'i001.00 L~ IILE RED $0.00 $9,960.00 PEAK $0.00 $4,000.00 SCH LUMBERG ER $0.00 $14,775.00 VECO $2,000.00 $6,000.00 WAREHOUSE $0.00 $0.00 TOTAL FIELD ESTIMATE $33,770.00 $124,620.00 , ARCO Alaska, Inc. WELi" 3H-1 1 DATE 05/09/99 ' DAY 7 ' FIELD ESTIMATE KUPARUK RIVER UNIT "LL SERVICE REPORT JOB SCOPE DRILLING SUPPORT-EXP WORKOVER DAILY WORK FISHING BRIDGE PLUG OPERATION COMPLt:;E I SUCCESSFUL ~ Yes 0 NO I ~ Yes 0 NO AFC' ICC, I DAILY COST 999285 23ODS36HO $15,387 Initial Tbg I Final Tbg 8OO PSll 0 PSI IKEY PERSON HES-LEHMAN ACCUM COST $90,850 Initial IA I Final IA Ilnitial OA IFinal OA l-I-fL Size 0PSI 0PSI 0PSI 0PSII 2.441 " 3.-11(4-1)) JOB NUMBER 0405991210.3 UNIT NUMBER 3437 SUPERVISOR CHANEY Signed IMin ID I Depth 2.250" 7356 FT DALLY SUMMARY RE:rRIEVED INFLATABLE BRIDGE PLUG FROM BTM PACKER @ 7339' RKB. [Fish] TIME 06:00 06:30 06:45 07:30 11:30 12:45 13:15 15:30 17:30 19:00 21:00 22:00 23:30 03:00 LOG ENTRY PU EQUIP ¢1' KIC SHOP. PU TOOLS O Y-PAD SHOP MI HES, LRS. TGSM- PINCH POINTS, RADIO CONTACT. RU HES, LRS. PT LUB & ALL FLOW BACK LINES TO 'TANKS TO 3500#- BONNET FLANGE LEAKED, RE- HAMMERED BONNET FLANGE. RE TEST TO 3500#- TEST GOOD. PUMP 10 BBLS'DOWN HOLE. . ..' '.. RIH W/KJ, 7" GS & BAKER SLV W/7" OTIS FISHING NECK, UNABLE TO PASS THROUGHTHE RIG RISER THE ID WAS TO SMALL. ~ .. HOT SHOT FOR 5' PIECE OF 7" LUB. RIH W/SAME SET DOWN @ 4525' WLM TAPPED THROUGH TO 4785' WLM; UNABLE TO PASS THROUGH, POOH' RIH W/KJ,5.985" GAUGE RING WORKED'DOWN TO.TOP OF PACKER @ 7154' WLM( 7185' RKB)~ APPEARS. TO BEHITTING SOME COLLARS, POOH .' -.. ' ' ,. RIH W/KJ,7" GS & BAKER SLV W/7" OTIS FISHING NECK SET ¢} 7154!' WLM(7185' RKB), POOH RIH W/KJ, 2.22" CENT & BOWSPRING CENT & 2" SB, 'HAD SERVERAL FRICTION BITES, UNABLE TO ' ~ LATCH UP, POOH, MARKS ON SKIRT APPEARS THAT WE WERE'ALONG SIDE OF FISH' ;'COMPLETLY'RELAX' BOW SPRINGS. '. RIH W/SAME, UNABLE TO LATCH , HUNG 'UP @ 7180"WLM, BROUGHT PUMP.ON LINE @. I BPM, CAME FREE, POOH W/BRIDGE PLUG.PLUG IS IN GOOD CONDITION, RUBBER ELEMENTS IN GOOD SHAPE. RIH W/KJ, 3" GS PULLED BAKER SLV ¢~ 7154' WLM(7185' RKB), POOH ~'~ RDMO S~VICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $168.00 $409.00 APC , $0.00 $7,200.00 AR CO $2,500.00 $5,907.00 BAKER OIL TOOLS $0.00 $12,084.00 CEN / HILIFT $0.00 $0.00 COBURN $0.00 $0.00 DOWELL $0.00 $19,414.00 FMC $0.00 $1 ,..100.00 HALLIBURTON $5,719.00 $12,001.00 LII ~ LE RED ' $5,000.00 $9,960.00 PEAK $0.00 $4,000.00 SCHLUMBERGI::H $0.00 $14,775.00 VECO , $2,000.00 $4,000.00 WAREHOUSE $0.00 $0.00 TOTAL FIELD ESTIMATE $15,387.00 $90,850.00 WELL HISTORY HANDOVER FORI( Well APl # PTD# 3H-11 Workover X 501032009100 New Well 87-124 Completion Date 4/30/99 WELL INFORMATION To Production X To Drilling Rig Name Nordic 3 SITP lAP Packer fluid Above Packer Well toped off OAP BHP /Depth / Date / Inst. Description Weight(ppg) ~rox Depths Kill weight Brine 11.5 PP;I 7185' TD Brine 11.3 ppg 100' 7185' Diesel 6.8 pp; 0' 100' DIRECTIONAL INFORMATION RKB/Tubing Spool 76'131' KOP 600' Avg Hole Angle 38-43 Max angle of 44 @ 3700' Hole Angle @ TD 33 NEW~ ADDED OR RE-PERFED INTERVALS To Bot SPF Gun Type Date ., 7274 7304 10 5" csg gun 120 deg. Phased 5/13/88 7371 7383 12 2 1/8" Enerjet~ 60 deg. Phased 10/28/88 7391 7411 12 2 1/8" Enerjetr 60 deg. Phased 10/28/88 7430 7450 4 4-1/2" csg gun 120 deg. Phased 5/13/88 COMPLETION INFORMATION Cond. Surf. Prod. Tubg. Tubg. Tubg. Tubg. Item Mf Model Vlv Size OD ID Valve Latch Drillers TD 7750' AFE Number 999285 I I I SET UP FOR 2-3/8" Electrocoll ESP Completion 7185' PKR Baker FB-1 5.875" 4.000" 7188' Seal Bore ext Baker - 5.000" 4.000" 7200' Flapper Valve Baker Full open 5.438" 3.188' 7202' Flapper Valve Baker Full open 5.438" 3.188" 7208' WLEG Baker 5.188" 3.958" 7339' PKR Otis WD 2.992 7356' D nipple Camco D 2.25 7366' Shear out BOT 2.441 7367' Tbg Tall 2.441 DOWNHOLE INFORMATION PBTD/Top of fill or Junk: 7527' Date Tagged 4/15/99 BPV Installed ~] IA VR Plug 'Y' BIK Side entry 2 Way Check I I OA VR Plug Downhole Plug CASING/TUBING DATA Depth Size Wt. Grade Conn. Top Bot 16" 62.5# H-40 Welded 0' 115' 10.75" 45.5# J-55 BTC 0' 3637' 7.0" 26# J-55 BTC 0' 7715' KNOWN Communication 7" full open val Tree 11" 3M X 7-1/16" 5M tbg epoolTree Cap Conn 7" Otis 11" 3M X 11" 3M W/3-1/8" Tbg Hgr Conn 3.5" EUE 8rd Side entry for coil tbg Rig released subsequent to full well completion as required on State Drilling permit: Yes No If no, specify remaining operations: Tubing I IA [~ OA ~ SURFACE EQUIPMENT ENVIRONMENTAL SITE INSPECTION Location Clean/Cellar Clean GENERAL INFORMATION · ~ Otis WD PKR & left in Hole set @ 7339' Jewerly Well Bore left w/11.3 ppg Brine fluid F/7185' to 100' of surface. Toped well off w/Diesel Drilling Dept. Rep. Donald L. Wester Title Drlg Foreman Date 4/30/99 Production/Oper Dept. Rep. Title Date PACKER DETAIL ELECTROCOIL ESP-PRODUCTER 3H- 11 ARCO Alaska, Inc. DATE: 4/28/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Set up for 2-3/8" Electrocoil ESP Completion Baker 4"X 7" ( FB-1 ) Packer ID 4.00" OD 5.875" 3.31 7185.00 Baker 10' Seal Bore Ext. OD 5.0" ID 4.00" 9.41 7188.31 Baker X/O Sub ID 3.958" OD 5.688" .64 7197.72 4-1/2" 12.6# Btrs B X LTC pin ID 3.958" 2.01 7198.36 Baker Flapper Valve ID 3.188" OD 5.438" 1.77 7200.37 Baker Flapper Valve ID 3.188" OD 5.438" 1.58 7202.14 4-1/2" 12.6# LCT B X BTRS pin ID 3.958" 4.28 7203.72 Baker WLEG ID 3.958" OD 5.188" .67 7208.00 EOT 7208.67 ORIGINAL EQUIPMENT RUN 5-14-88 Wireline Measurement OTIS 3-1/2"X 7" 'WD' WL set Pkr w/5' Seal bore ext. ID 4.00' 9.00 7339.00 to 2-7/8" X/O EUE 8rd tb~l 7348.00 2-7/8" 6.5# EUE 8rd AB-Mod IPC Pup jt 8.06 7348.00 Camco 2-7/8" 'D' Nipple W/2.25" ID 1.57 7356.06 2-7/8" 6.5# EUE 8rd AB-Mod IPC Pup j! 8.08 7357.63 BaT 2-7/8" Shear out sub WLEG .90 7365.71 EOT 7366.61 Remarks: Equipment ran for Electrocoil completion. Nordic Ri~I #3 Drillin~l Supervisor: Donald L. Wester Date: 5/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3H-11 WELL_ID: 999285 TYPE: AFC: 999285 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:04/22/99 START COMP:04/21/99 RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20091-00 04/21/99 (C1) TD: 7750' PB: 7527' 04/22/99 (C2) TD: 7750' PB: 7527' 04/23/99 (C3) TD: 7750' PB: 7527' 04/24/99 (C4) TD: 7750' PB: 7527' 04/25/99 (C5) TD: 7750' PB: 7527' PUMPING KILL WT FLUID (11 MW: 8.6 SW SUPV:DEARL W. GLADDEN Move rig from 3I pad to 3H pad. Accept rig @ 1200 hrs. 4/21/99. PJSM on well kill. Displace well over to sea water. UPCOMING OPERATIONS:KILL WELL - N/D TREE - N/U BOPS - TEST BOPS KILL WELL - PROBLEMS WITH MW: 0.0 SUPV:DEARL W. GLADDEN Pump HEC LC pill #1, bullhead pill. Pump kill weight fluid. Pump LCM pill #2 and bullhead across pkr. Monitor well, hole taking fluid. Drop mud weight to 11.3 ppg. Hole taking fluid. Spot pill across pkr. Weight system back up to 11.5 PPg. UPCOMING OPERATIONS:KILL WELL - N/D TREE - N/U BOPS CBU AFTER PUMPING LCM PIL MW: 0.0 SUPV:DEARL W. GLADDEN Circulate and condition fluid weight to 11.5 ppg, continue to monitor fluid loss. Continue to circulate to balance system. Pump salt pill. ND tree and NU BOP and function test BOPE. UPCOMING OPERATIONS:CBU - STABILIZE WELL - TOH L/D TBG MONITOR WELL FOR FLOW MW: 0.0 SUPV:DEARL W. GLADDEN Pump, spot and squeeze FloVis LCM pill. CBU. Monitor hole. UPCOMING OPERATIONS:TOH W/ #1 FISH(TOP PKR & STUB) - L/D PKR - TIH FOR FISK #2 (BLAST RINGS & TBG STUB) TOH W/ FISH #2 (BLAST RIN MW: 0.0 SUPV:DEARL W. GLADDEN CBU, small spots oil show on BTU. Spear PKR and jar up. CBU, small gas & oil show on BTU. Monitor well for fluid loss, losing 10-14 BPH. TOH slow w/fish. L/D fish, full recovery. UPCOMING OPERATIONS:L/D FISH # 2 - MAKE OVERSHOT RUN FOR LAST TBG STUB & SEAL ASSY - RUN MILL FOR WD PKR Date: 5/20/99 ARCO ALASKA INC. WELL SLTMMARY REPORT Page: 2 04/26/99 (C6) TD: 7750' PB: 7527' 04/27/99 (C7) TD: 7750' PB: 7527' 04/28/99 (C8) TD: 7750' PB: 7527' 04/29/99 (C9) TD: 7750' PB: 7527' 04/30/99 (C10) TD: 7750' PB: 7527' TIH W/ BIT & SCRAPPER MW: 0.0 SUPV:DEARL W. GLADDEN Continue to spot LCM pill. Monitor well fluid loss. L/D fish. Monitor fluid loss. UPCOMING OPERATIONS:SCRAPPER RUN - TOH - MAKE DRIFT RUN W/ LONG DRIFT(30' +/-) ON DP - SWL RUN USIT LOG CONTINUE TO RUN DUMMY MOT MW: 0.0 SUPV:DONALD L.WESTER PJSM. RIH with 7" tandem csg scrapers. Circ. Fluid loss 20 bph. RIH w/dummy motor to drift 7" casing. UPCOMING OPERATIONS:RUN USIT LOG. RUN BAKER ELETROCOIL PACKER & FLAPPER VALVE ASSEMBLY. MONITOR WELL O.K. L/D 6 J MW: 0.0 SUPV:DONALD L.WESTER Run USIT log. RIH with packer. Set packer $ 7185'. UPCOMING OPERATIONS:INSTALL 'Y' BLOCK & NEW TBG SPOOL L/D 3-1/2" DP & 4-3/4" DC MW: 0.0 SUPV:DONALD L.WESTER Set Baker 7" storm packer. PJSM. Quarter drilling safety assessment. NU BOPE and test to 300/3500 psi. OK. Pull storm packer. UPCOMING OPERATIONS:COMPLETE N/U. MOVE TO 3A PAD. RELEASE RIG $ 1400 HRS 4/ MW: 0.0 SUPV:DONALD L.WESTER ND BOPE. Install test plug and test to 5000 psi. Move rig off well secure well clean up location. Release rig @ 1400 hrs. 4/30/99. UPCOMING OPERATIONS: MOVE TO 3A-03 ARCO Alaska, Inc. {, Kuparuk Operations Post Office Box 196105 Ancl3orags. Alaska 99519-61 Te~epl~one 907 659 2821 February 4, 1998 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: In response to your request for additional information during our meeting of January 21", the following comments are supplied. Corrosion There will be corrosion effects on the casing over time. The extent of the corrosion or rate of corrosion has not been quantified at this time. However, based on observations of corrosion in conventional tubing it is expected that the rate of corrosion would not be greater than what has been observed to date in uncoated production tubing. There are corrosion .coupons currently installed on the Kuparuk production flowlines. The coiled tubing deployed pumps would also have the corrosion monitoring coupons installed. The coupon inspection program would probably be more frequent in the early life of the pump installation until a base line could be established. Currently nearly all the conventional wells yield "A" grade coupons which translates to wall loss less than 1 mil per year and pit loss less than 5 mil per year. Velocity assisted corrosion would not likely be a factor, due to the moderate velocities produced by the plumps. Since the coiled tubing deployed pumps take all the wellbore fluid through the pump the fluid will be highly emulsified. Production fluids will probably be an oil external emulsion until the water phase reaches 80%, then the emulsion would become water external. This will tie up a substantial amount of the free water, which would help in reducing free water induced corrosion. Hydrogen Sulfide is present in many parts of the field. Areas with high concentrations will require a more rigorous evaluation before becoming candidates for coil tubing deployed pumps'. Blair Wondzell February 4, 1998 Page 2 Erosion Presently the coiled tubing deployed pumps have exit ports aligned at approximately 30 degrees to the axis of the casing so there will be some degree of impingement. At maximum rates the exit velocity of the fluid is expected to be approximately 15 ft/sec. Manufacturer's recommended maximum velocity to achieve acceptable wear is 25 ft/sec based on testing various pump stages in their test facility sand loops. Abrasive materials also will erode pump internals causing them to loose efficiency, which in turn reduces volume and velocity. These figures are also confirmed by our frequent inspection of surface piping downstream of our chokes where no erosion problems have occurred when velocities are 25 ft/sec or less. Initial installations of the two pumps will have a casing inspection log run prior to running the pump in order to establish a base line. A follow up log will be run when the pump is removed for the first time. The initial target run life for the pump is 3 to 5 years. Sincerely yours, ~ll~-3W~~e S u pe rvlso r cc: M. Zanghi, ATO-1276 S. P. Kruse, ATO-1128 J. B. Kewin, NSK-69 M.W.Wheatall, NSK-22 II Schematic of Coil Tubing Deployed ESP Wellhead Feb. 2,1998 power cable high pressure pilot Iow pressure pilot surface casing production casing coil tubing surface saffey valve master valve .... STATE OF ALASKA ._. ,:A OIL AND GAS CONSERVATION COMM ,.,iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X P.lugging Perforate__ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1232' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM At effective depth 1324' FNL, 1103' FEL, Sec. 12, T12N, R8E, UM At total depth 1316' FNL, 1042' FEL, Sec. 12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 7 7 5 0 feet true vertical 6460 feet 6. Datum elevation (DF or KB) RKB 76 7. unit or Property name Kuparuk River Unit feet 8. Well number 3H-11 9. Permit number/approval number 87-124 10. APl number 50-103-20091-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 6 3 5 feet true vertical 6217 feet Junk (measured) None 13. 14. Casing Length Size Structural Conductor 8 0' Surface 3 6 0 2' Intermediate Production 7681' Liner Perforation depth: measured Cemented Measured depth True vertical depth 1 6" 215 Sx AS I 1 1 5' I 1 5' 1 0-3/4" 1200 Sx AS III & 3637' 2660' 600 Sx Class G w/130 Sx AS I top job 7" 650 Sx Class G & 7 71 6' 6 5 4 3' 300 Sx AS I 7274'-7304',7371 '-7383',7391 '-741 1',7430'-7450' true vertical 0 61 69'-6194',6251'-6161',6268'-6265',6301'-6318' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7367' Packers and SSSV (type and measured depth) PKR: Baker FH @ 7177' & Otis WD @ 7339'; SSSV: Camco TRDP-I^ @ 1798' stimulation or cement squeeze summary Fracture stimulate 'A' sand on 10/29/97. Intervals treated (measured) 7371 '-7383',7391 '-741 1;,7430'-7450' Treatment description including volumes used and final pressure Pumped 97.8 Mlbs of 16/20 and12/18 ceramic proppant into the formation, fp was 4125 psi Representative Daily Average Production or In!ection Data OiI-Bbl RIGINAI Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 524 235 3329 1392 156 Subsequent to operation 576 146 3659 1420 166 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 c__ertify that the foregoing is true and correct to the best of my knowledge.. Signed .... Title Wells Superintende~~ '"'r ~-~ ~ ~Date Form 1~"04I' I~ 66/1,~'~ i~ ~ ~- ~ t ',t '~,, ~'SUBMIT"IN"DUPLICATE ?_'t 1998 ;=RCO Alaska, Inc. {" (' KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~' K1(3H-11(W4-6)) WELL JOB SCOPE JOB NUMBER 3H-11 FRAC, FRAC SUPPORT 1019970627.2 DATE DALLY WORK UNIT NUMBER 10/29/97 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~ Yes O NoI ® Yes O No DS-GALLEGOS JOHNS ESTIMATE KD1742 23ODS36HL $1 02,290 $1 16,640 Initial Tbcl Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final O~[te~/Ann 1300 PSi 2000 PSI 994 PSI 500 PSII 700 PSII ~,"800 PSI DAILY .SUMMARY PUMPED "A" SANDS RE-FRAC , WITH 97,870# PROPPANT UP TO 8.7 PPA 12/18 TO PERFS , LEFT 12,704 IN PIPE. WELL PRESSURED OUT EARLY , GOT 20 BBLS FLUSH DOWNHOLE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC SUPPORT. 09:10 HELD SAFETY MEETING. 09:47 10:50 PUMP BREAKDOWN WITH 16/20 SCOUR AND FLUSH. TOTAL 226 BBLS FLUIDS AND 25 TO 10 BPM AND 7234 TO 5566 PSI. SHUTDOW.~!.F'.~R ISIP. 2550 PSI. PUMP DATAFRAC .... ~r .... ~ '~'~.~ , ' ,~',,.~' ;~...,.,~,, W!'R-i 126 BBLS FLUIDS 5 TO 10 BPM AND 3612 PSI. SP;~..."!''? ;L~V'..~i"~ ~; .':.~ i'..'!' ~',;~OSURE CALCULATIONS. 12:29 PUMP 65 BBLS PAD. 5 BPM AND 2998 PSI. 12:40 PUMP 3860# 16/20 PROPPANT TO 2 PPA, 10 BPM AND 4125 PSI. 12:46 13:30 PUMP 93,574# 12/18 TO 10 PPA, WELL PRESSURED OUT, WENT TO FLUSH, GETTING 20 FLUSH INTO WELL. RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $800.00 APC $7,100.00 $9,925.00 ARCO $400.00 $400.00 DOWELL $93,090.00 $98,139.00 HALLIBURTON $0.00 $5,677.00 LI'I-I'LE RED $1,700.00 $1,700.00 TOTAL FIELD ESTII~IATE $102,290.00 $11 6,641.00 STATE OF ALASKA AL r~ OIL AND GAS CONSERVATION COMIVliSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1232' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM At effective depth 1324' FNL, 1103' FEL, Sec. 12, T12N, R8E, UM At total depth 1316' FNL, 1042' FEL, Sec. 12, T12N, R8E, UM Abandon_ Suspend_ Operation Shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service 12. Present well condition summary Total Depth: measured true vertical 7750' feet 6460' feet Plugs (measured) Re-enter suspended well _ Time extension _ Stimulate_ Vadance Perforate Other X 6. Datum elevation (DF or KB) 76' RKB feet 7. Unit or Property name Ku@aruk River Unit 8. Well number 3H-11 9. Permit number/approval number 87-124 / Apprv. N/A lO. APl number 50-103-2009100 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical 7635' feet 6364' feet Junk (measured) Casing Length Size Structural Conductor 80' 16" Surface 3602' 10 3/4" Intermediate Production 7681' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 215 Sx AS I 115' 115' 1200 Sx AS III & 3637' 3087' 600 Sx Class G performed top job w/130 Sx AS I 650 Sx Class "G" & 7716' 6432' 300 Sx AS I 7274'-7304', 7371 '-7383', 7391 '-7411, 7430'-7450' MD true vertical 6059'-6085', 6141 '-6151 ', 6158'-6175', 6191 '-6208' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7367' MD RKB Packers and SSSV (type and measured depth) Baker FHL PKR. @ 7177', Otis 'WD' PKR. @ 7339', Camco TRDP-1A SSSV @ 1798' ORIGINAL 13. Attachments Description summary of proposal ~ Detailed operation program BOP sketch _ CONVERT WELL FROM GAS LIFT TO COILED TUBING DEPLOYED ELECTRIC SUBMERSIBLE PUMP 14. Estimated date for commencing operation JUNE 1, 1998 16. If proposal was verbally approved 15. Status of well classification as: Oil x Gas _ Suspended _ To be reclassified as: Date N~me of approver Blair Wondzell Date approved Service 17. I h~eb. ycerti~ that the foregoing is true and correct to the best of my knowledge. Signed y ~,' ~ (.~ ~ Title Drillsite Supervisor [ ) FOR COMMISSION USE ONLY Conditions of approval: Notify Commis~ron so representative may witness Plug integrity _ BOP Test _R~ Location clearance Mechanical. Integrity Test _ Subsequent form require lO- Original $~]~,.~ ..,: David W. Johnston Approved by order of the Commission Commissioner Date 12/20/97 g~BMI'I~IN TRIPLICATE Form 10-403 Rev 06/15/88 o,~e6 JAN 1998 ., r,---'m= ;I B.O.T. GAUGE MOUNT(S) "'15 ~i i~ B.O.T. GAUGE SYSTEM ---- TLC W~RE --CENTRiLiFT POWER CABLE __ CASINO, SHOWN OUT OF POSITION TLC WIRE CONNECTION TRANSITION ASSEMBLY (COIL TUBE-ESP ASM.) SHEAR AREA OF TRANSITION ASM. EXPANSION CHAMBER ~&: POWER FEED THRU SERIES 513 ~ ACTUAL CROSS SECTION ,,.--------CASING (7"© 26#/FT.) SHOWN OUT OF SCALE UPPER MOTOR ASM. SERIES 562 MT .~ CENTRALIZER(S) ALL NECK LOCATIONS LOWER MOTOR ASM. SERIES 562 MT .... CAPILLARY TUBE (1/4") ~~_ TI--IRUST CHAMBER ASM. SERIES 51 3 PUMP DISCHARGE PORTS SAND SKIRT ASM. UPPER PUMP ASM. (MT) SERIES 513 AR SPECIAL .~_LOWER PUMP ASM. (MT) SERIES 513 AR SPECIAL SPECIAL PUMP INLET INTAKE PRESSURE SENTRY CONNECTION STINGER POLISHED BORT RECEPTACLE (ON/OFF TOOL) PACKER ASSEMBLY ~PRODUCTION ZONE/PERFS EQUIPMENT STACK -'£I WELLHEAD SYSTE~, KUPARUK EQUIPMENT, WORK OVER WITH POWER CT FROH¢ ,/ ... CPF THREE ( ARCO Alaska Inc FRX 12-85-97 19=54R P.01 To; Blair Wondzell From; Mike Winfree Fax= 276-7542 P~_e~___. 2 w/o cover Iml~ne: 279-1433 Bate: 12/05/97 lie', Annular production CC: Urgent X For Rewlew ~ Plen~e Comment [] Please Reply [] Pleaso Recycle · Comments: Blair .... As we discussed on the phone, We are looking at applying the technology of coiled tubing deployed ESP's in the Kuparuk field and would like to have consent from the AOGCC for annular production before we commit additional time and money to the project. Please mad it over and if you have any que~ions give me a call on the slope at 659-7407. I'm working a 7 on 7 off schedule and my altemates's name is Ron Marquez. He or I will be able to answer any questions you might have. Thanks .... RECEIVED DEC - $ lg 7 Alaska Oil & Gas Cons. (;0mmissior: Anch0rapc.. FROH'¢ CPF THREE FRX NO.: 6S9 76~9 12-05-97 10:54R P .02 ARCO Alaska, Ino. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907' 276 1215 December 5, 1997 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) RECEIVED DEC - 199 ' Naska 011 & Gas Cons. cornm~s~aor, Anchor~e Re; Waiver Request to Allow Annular Production in KRU Electric Submersible Pump (ESP) Completions Deployed on Internal Power Cable Coile~l Tubing (ElectroCoil) Gentlemen: ARCO requests a waiver to the AOGCC Regulations covering downhole production equipment. The waiver being requested is to Section (d) of 20 AAC 25.200, which requires wells capable of unassisted flow to have the tubing x casing annulus isolated from produced fluids. The waiver is requested to cover those wells with-in the Kuparuk River Unit, to be completed with electric submersible pumps (ESPs) deployed on Internal Power Cable Coiled Tubing (ElectroCoil). The typical Kuparuk ESP completion is deployed on jointed tubing with the ESP power cable banded to the outside of the tubing, The pump is set immediately abo~,e the perforations and produced liquids are drawn into the pump and discharged into the produu--tion tubing. Produced gas is diverted past the pump, up the tubing x casing annulus, and commingled into the production tubing through a shallow gas lift mandrel. Produced fluids exit the well from the production tubing at the wellhead. The proposed 'ElectroCoil' ESP completion is run in the hole on coiled tubing prepped with the ESP power cable inside. The completion is landed in a production packer set immediately above the perforations. Integral to the production packer is a polished bore receptacle and 'flapper type' shut-off valve. When the completion is landed, a seal assembly enters the polished bore creating a hydraulic seal. A stinger run below the seal assembly will open the shut-off valve, allowing communication with the perforations. Production is drawn through the packer by the ESP, and discharge from the pump is into the coiled tubing x casing annulus. Produced fluids flow up the tubing x casing annulus and out the well through the annulus valve in the tubing head. Surface safety systems will be identical to existing conventional trees. However, since production Is through the annulus valve, the tree will be in a horizontal position. All wells will be equipped with two high pressure shut-down sensors designed to shut down the pump if tl~e coiled tubing x casing annulus exceeds a pre-determined pressure. (significantly below the burst rating of the casing).-~ .While in production mode, surface pressure of the coifed tubing x casing FROH~= CPF THREE F~X HO.: 659 76~9 12-05-97 10=54~ P,03 annulus is expected to be equivalent to production header pressure (+/-150 psi). Variations to this pressure should only exist when the well is shut-in or when free flow of produced fluids is restricted. The 'ElectroCoil' completion is desirable to ARCO for several reasons. First, friction pressure consumes approximately 50% of the submersible pump horsepower on current ESP completions. The effective diameter of the coiled tubing x casing annulus is significantly larger than the current production tubing, resulting in substantially lower friction pressures. In addition, the ability to run and retrieve ESP's using a coiled tubing unit will reduce installation and workover cost, as well as pump downtime. Both of these examples will help to substantially reduce ESP operating costs, allowing more ESP installations and increased production rates. It is ARCO's desire tO make 'ElectroCoil' ESP completions a safe, efficient, and cost effective operation in the Kuparuk River Unit. ARCO has one 'ElectoCoil' completion installed offshore in Qatar and a second installation is planned for later this year at ARCO's THUMS operation in California. A full-scale test of the proposed system for Kuparuk is currently scheduled for early second quarter of 1998. ARCO is requesting your early approval of this waiver request in order to commit the funds necessary to proceed with this project. We appreciate your consideration of this request. If you have any questions or require any additional information on this matter, please contact me at 265-6206. Sincerely, Mike Wheatall NSK 22 Mike Zanghi ATO 1276 Bill Isaacson ATO 1290 STATE OF N.ASKA (" ALASKA OIL AND GAS ~RVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchora~le, AK 99510 4. Location of well at surface Stimulate X Alter casing ~ Repair well 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Plugging Perforate ~ Pull tubing O t h e r 6. Datum elevation (DF or KB) 1232' FNL, At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, At effective depth 1324' FNL, 1103' FEL, Sec. 12, T12N, At total depth 1316' FNL~ 1042' FEL~ Sec. 12~ T12N~ 12. Present well condition summary Total Depth: measured 77 true vertical 64 281' FWL, Sec. 12, T12N, R8E, UM R8E, UM R8E, UM R8E~ UM 5 0' feet 60' feet Plugs (measured) 76' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-11 9. Permit number/approval number 87-124 / ADDrV. N/A - . 10. APl number so-103-2009100 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 6 3 5' feet true vertical 6217' feet Junk (measured) Casing Length Structural Conductor 80' surface 3602' Intermediate Production 7 6 81' Liner Perforation depth: measured 7274'-7304', 7371 '-7383', true vertical 6169'-6194', 6251'-6261 ', Size 16" 10 3/4" 7" Cemented Measured depth True vertical depth 215 Sx AS I 1 15' 1 15' 1200 Sx AS III & 3637' 2660' 600 Sx Class G performed top job w/130 Sx AS I 650 Sx Class "G" & 7 71 6' 6 5 4 3' 300 Sx AS I 7391 '-7411, 7430'-7450' MD 6268'-6285', 6301'-6318' TVD Baker FHL PKR. @ 7177'~ Otis 'WD' PKR. @ 7339'~ Camco TRDP-1A SSSV @ 1798' ~.~ Stimulation or cement squeeze summary ~b,C~b,\'~ A SAND FRACTURE STIMULATION . Intervals treated (measured) 7371 '-7383', 7391 '-7411', 7430'-7450' ¥~'~'~'~ ~. ?.. ~OJO~'~0~t~S~t~ TreatmentSEEdescriptionA. l_rAOHEDincludingWELLVOlumeSSERVicEused REPORTand final pressUreSUMMARY Inle att j~.$~(,,~i. [}t~ ~ ~''~=~ ~0~' Pu Reoresentative Daily Averaoe Production or ' ~tion D..-~XtG~Q~ OiI-Bbl Gas-MM Water-Bbl Casing 'Pressure 'r"ubing Pressure 682 348 3866 1316 168 411 711 4721 1417 188 16. Status of well classification as: Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7367' MD RKB Packers and SSSV (type and measured depth) 13. 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil ~( Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C- (x~. ~ Title' Operations EncIineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 05/15/92 TO 05/15/92 CPF-3 DS-3H 3H-11 05/15/92 GSW REFRAC W/BJ SPECTRAFRAC G. PUMP 126 BBL PREPAD @ 22 BPM LAST WHTP=4449 PSI, ISIP=2505 PSI, FG=.85 PSI/FT, XS FRIC= 161 PSI. EST FE & LO USING G FUNCTION ON BJ'S COMPUTER. PUMPED 50 BBL PAD @ 20 BPM, LAST WHTP=4300 PSI. PUMPED 2.8 MLBS 16/20 CL IN 2 PPA STAGE & 17.9 MLBS 12/18 CL IN 4 TO 9 PPA STAGES @ 22 TO 20 BPM, LAST WHTP=5100 PSI. FLUSH W/61 BBL SLK WTR @ 22 BPM, LAST WHTP=4780 PSI, ISIP=2675 PSI, .87 PSI/FT, XS FRIC=322 PSI. TOT PROP: DESIGN=20.7 MLBS, IN FORM=lT.9 MLBS W/9.2 PPA @ PERFS. TOT FLUIDS: WATER=340 BBL, DSL(FLA)=8 BBL, ADD'S=4 BBLS. ALL GEL SAMPLES LOOKED GOOD. (CHIWIS/GRIFFIN/HARRISON) i .. CC: DS Engr. KUPARUK FLUID LEVEL REPORT Well ~ H-II Date sssv GLM Z7z [ 5-o07 7 Z5 DV or GLV Flaid Level Found @/'~"]~. Ft Fluid Lev~h~t Down: Casing CSG Press During Shot Tubing TBG Press During Shot Reason For~,Shooting FL: \_/ To Determine Operating Valve Well Status: On Continuous GL Operating CSG Press= IZZo # GL Rate (If Available)= /0(3 MCFD On Intermittent GL On Time=. Min. Off Time = Hr, Min. ,,, Delta Time From End Of On Cycle = . No GL Min. Date: ARCO Alaska, Inc. August 11, 1989 Transmittal #: 7536 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. , . 30-17 Kuparuk Well Pressue Report .30-1 2 Sub-Surface Pressure Survey 3H-1 1 Kuparuk Fluid Level Report 3H-1 6 Kuparuk Fluid Level Report 3 H-1 8 Kuparuk Fluid Level Report 3 H-1 3 Kuparuk Fluid Level Report 1 - 2 3 - 8 9 Sand W 1-12-89 #71605 8 - 0 7 - 8 9 Casing 8 - 0 7- 8 9 Casing 8 - 0 7 - 8 9 Casing 8 - 0 7 - 8 9 Casing Receipt Acknowledged' DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M sssv / 7~' GLM / · q DV or GLV · ~7~/ /~,7_7,S" t~?oo KUPARUK FLUID LEVEL REPORT CC: DS Engr. - ~ NSK Files OP Engrg. Files Prod. Foreman -.. We, 3# -// Fluid Level S~t Down: Casing Tubing Date ~ '''~? 5/--- O~ CSG Press During' Shot TBG Press During Shot Reason. FOr Sh°oiing' FL:,' To Determine Operating Valve Well Status: ."~ Level Found ~,~4~ Ft ~ On Continuous GL Operating CSG Press = GL Rate (If Available)= On Intermittent GL On Time =_...__ Min. Off Time = Hr. ~"'O MCFD JtlL '~ ~',~ Oil. Min. Delta Time From End Of On Cycle- Min. No GL Comments: · ARCO Alaska, Inc. Date: July 28, 1989 Transmittal #: 7523 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted-herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-09 3B-04 3J'-0'2' 3H-18 3H-11 Post Frac Job Report Kupatuk Fluid Level Report KUparuk ;-'."~id Level' Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report 10-11-.89 7-21;89 "7~'19-8'9 · 7-25-89, 7-24-89 "409747 , ',~asing Casing" Casing Casing Receipt Acknowledged: DISTRIBUTION: BP Chevro'n Unocal Mobil State of Alaska D&M .,, REPORT OF SUNDRY WELL OPERATIONS" · " 1. Type of Request: 2. Name of Operator Operation Shutdown Pull tubing., Alter casing ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Plugging Perforate Repair well Pull tubing Other 5. Type of Well: Development X Exploratory _ Stratigraphic ... Service _ 6. Datum elevation (DF or KB) 76' RKB 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 1232' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1367' FNL, 1294' FEL, Sec. 12, T12N, R8E, UM At effective depth 1324' FNL, 1103' FEL, Sec. 12, T12N, RSE, UM At total depth 1316' FNL, 1042' FEL, Sec. 12r T12N~ R8E~ UM 12. Present well condition summary Total Oepth: measured 7750' feet true vertical 6460' feet 8. Well number ~,, 3H-11/,~, ,~ ~'~ ~,~- 9. Permit number/aa.oroval number 87-124 / &/- '~;' '~ 10. APl numb'er 5o-103-20091 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Cement: 7635'-7750' Effective depth: measured 7 6 3 5' feet true vertical 6 21 7' feet Junk (measured) Casing Length Structural Conductor 1 1 5' Surface 3 6 3 7' Intermediate Production 7 71 6' Liner Perforation depth: measured 7274'-7304', 7371 '-7383', true vertical 6169'-6194', 6251'-6261', Size 16" 10 3/4" 7" 7391'-7411, 6268'-6285', Cemented Measured depth True vertical depth Tubing (size, grade, and meashred depth) 3 1/2" 9.3 Ib/ft, J-55, 7367' MD RKB Packers and SSSV (type and measured depth) Baker FHL PKR. @ 7177'~ Otis 'WD' PKR. @ 7339'~ Camco TRDP-1A SSSV @ 1798' 13, Stimulation or cement squeeze summary 'C' Sand acid Stimulation. Intervals treated (measured) 7274'-7304' MD RKB Treatment description including volumes used and final pressure 30 bbls Diesel/Musol~ 33 bbls Nitrified Acid~ final surface pressure 2100 psi. 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 215 Sx AS I 1 1 5' 1 1 5' 1200 Sx AS III & 3637' 2660' 600 Sx Class G performed top job w/130 Sx AS I 650 Sx Class "G" & 7 71 6' 6 5 4 3' 00sx^s, RECEIVED 7430'-7450' MD 6301'-6318' TVD ~UL ~ 0 ~ Alaska Oil &. Gas Cons. Commiss.li :Anchorage Tubing Pressure Prior to well operation 2 1 0 950 100 Subsequent to operation 1400 700 0 1000 110 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations * 16. Status of well classification as: Oil *, Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Sr. Operations En~lineer Date ,ARCO Alaska, In~ ,,,' ~ Subsidiary of Atlantic Richfield CompS, WELL sH-/i '~NTRACTOR REMARKS IPBDT I FIELD - DISTRICT- STATE IOPERA ION AT REPORT TIME WELL SERVICE REPORT DAY DATE 10~3& CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~d c E'J' REMARKS CONTINUED: DESC RI PTION DAILY ACCU M. TOTAL CAMCO SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B, J. HUGHES Roustabouts + ~/ Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE I!signed STATE OF ALASKA (~.' ALASKA OIL AND GAS CONSERVATION COMMISSION 0 ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .~. Exploratory _ Stratigraphic _ Service RKB 76' 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 1232' FNL, 281' FWL, SEC 12, T12N, R8E, UM At top of productive interval 1367' FNL, 1294' FEL, SEC 12, T12N, R8E, UM At effective depth 1324' FNL, 1103' FEL, SEC 12, T12N, R8E, UM At total depth 1316' FNL, 1042' FEL, SEC 12~ T12N, R8E, UM 12. Present well condition summary Total Depth: measured 7 7 5 0' true vertical 6460' Effective depth: measured 7 63 5' true vertical 621 7' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3 6 3 7' 10 Intermediate Production 7 71 6' 7" Liner Perforation depth: measured 3/4" feet Plugs (measured) feet Cement: 7635'-7750' feet Junk (measured) feet None 8. Well number 3H-11 ~~c 9. Permit number 87-1 24 10. APl number 5o-1 03-20091 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RECEIVE,.r; Cemented Measured depth 'MAY 1 8 Alaska 0ii & Gas Con..~,. Commissi0/1 True v~Ei~lah 215 Sx AS I 115' 115' 1200 Sx AS III & 3637' 2660' 600 Sx Class G, Top Job w/130 Sx ASI 650 Sx Class G 7 71 6' 6 5 4 3' 300 Sx AS I 7274'-7304' 10 SPF, 7371'-7383' true vertical 6169'-6194', 6251'-6261', 6268'-6285', 6301'-6318' Tubing (size, grade, and measured depth 3 1/2" J-55 set at 7367' Packers and SSSV (type and measured depth) Baker FHL @ 7177', Otis 'WD' @ 7339', Camco TRDP-1A $SSV @ 1798' 13. Attachments Description summary of proposal ~ Detailed operation program _ Perform 'C' Sand Acid Stimulation With 10% Acetic Acid. 12 SPF, 7391'-7411' 12 SPF, 7430'-7450' 4 SPF BOP sketch ~ No Workover Fluids. Est. BHTP = 4000 psi. 14. Estimated date for commencing operation May. 1989 Oil X Gas 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~ ~r~ A....'3~.,~~ COMMISS~N USE ~NL'~ /'~'"" ~ '~ ~ - FOR 15. Status of well classification as: m Suspended _ Date ¢ '"/~' - ~ '~ Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test M Location clearance m Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 '~JIIIGINAL 81GNED. ..I~Y LO#NIE C. 8Mrrff" IApproval No. 1 o- ~o ]Approved Copy Returned Commissioner Date ,,.%"'--/'~'~:~ SUBMIT IN TRIPLICATI~ KRU WELL 3H-11 'C' SAND ACID STIMULATION PROCEDURE CHARGE CODE: 230DS36HL Pre-Wireline Work: 1. MIRU slickline unit. 2. Pull Otis blanking sleeve. 3. RIH with Otis XN Flow Sleeve Plug. This sleeve will enable the 'C' Sand to be opened while the 'A' Sand will be closed via the plug in the bottom of the sleeve. This sleeve can be rented from Otis. 4. If the well will flow, obtain a 'C' Sand well test, obtain a wellhead fluid sample, and perform sludge and emulsion tests (see attached forms). 5. If the well will not flow, obtain a fluid sample from offset producer 3H-02 and perform sludge and emulsion tests. Send a copy of the test results to Steve Bradley at ATO-1156. p ~ ¢' ~ ~' ,~ Stimulation: , MIRU CTU, transports, nitrogen, and pumps. Atssk~ 0ii & (.~s 6,.-.,.n:',. (;o~',:;;-~i3:;,¢~'~ Titrate 10% Acetic acid. Anch0~age RIH with CT to 7320' MD-RKB and pump the following fluids at 1 BPM (do not exceed surface formation breakdown pressure of approximately 1900 psi). A. 30 BBLS of diesel with 10% Musol (27 BBLS diesel/3 BBLS Musol). B. 30 BBLS of nitrified MRS200 (nitrify with 500 SCF per BBL of MSR200). C. 5 BBLS of diesel. D. Displace CTU with Nitrogen. 4. Open well to tanks immediately. Nitrogen lift if necessary. 5. Obtain 2 samples of the spent acid and analyze for ferrous and ferric iron (send copy of results to S. Bradley - ATO 1156). 6. Continue to flow to tanks until 300 BBLS of fluid are recovered, 7. POOH with CT. 8. RD equipment. 9. Obtain well test. Post Wireline WQrk: Do not proceed with post wireline work until a valid well test has been obtained. If the well still will not produce, an alternative acid job will be performed before pulling the rented flow sleeve. 1. MIRU slickline unit. 2. RIH and pull flow sleeve. 3. RIH with commingling sleeve. 4. POOH. RDMO slickline unit. NOTE: 1. Dowell will need at least 14 days advance notice before the job can be pumped in order to have the fluids shipped to Kuparuk from the Lower 48. SOB (4/27/89) 4 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI4 1/16" PIPE RAMS 3. 5000 PS14 1/6" HYDRAULIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS 5. 5000 PSI4 1/6" BLIND RAMS 6. 5000 PSI4 1/16" STUFFING BOX (' STATE OF ALASKA (M ~ · ALASKA OIL AND GAS CONSERVATION CO MISSION ' W =LL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well Revised to reflect added perforations OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska s I nc, 87-124 3. Address 8. APl Number P, 0, Box 100360s Anchorages AK 99510 50- 103-20091 4. Location of well at surface 9. Unit or Lease Name 1232' FNL~ 281' FNL~ Sec.12~ T12N~ R8Es UN Kuparuk River Unit _ At Top Producing Interval 10. Well Number 1367' FNL~ 129~' FEL~ Sec. 12~ T12N~ R8E~ UN 3H-11 At Total Depth 11. Field and Pool 1316' FNL~ 10~+2' FELs Sec.12s T12N~ R8Es UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 76' RKBI ABL 25531 ALK 2657 _ 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12/15/87 12/25/87 07/09/88* N/A feet MSLI 1 17. TotalOepth(MD+TVO) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°st 7750'ND/6~60'TVD 7635'MD/6363'TVD YES~] NO [] 1798' feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SPs LDT/CNL/Cal/NGT/EPT~ D IL/SFL/SP/GRs R4S~ BHCS~ RFT~ SWC~ CET~ (;CT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf .115' 24" 215 sx AS 10-3/4" 45.5# J-55 Surf 3637' 13-1/2' 1200 sx AS III Top job w/130 sx AS I 7" 26.0# J-55 Surf 7716' 8-1/2" 650 sx Class G & 300 st AS I 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 (MD) Perforated w/10 spf~ 120° phasing 3-1/2" 7367' 7177' & 739,9' 7274 ' -730~ ' MD/6059 ' - 608~+ 'TVD Perforated w/12 spfs 60° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7371 '-7383'ND/6140'-6151 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7391 '-7411 'MD/6157'-617~'TVD 7332, 733~' Perforated w/4 spf~ 90° phasing 74~2 ........,~? .~ 356 sx Ciass G 7~30'-7~50'MD/6191 '-6208'TVD See ai;~.ached Addeneum~ aate(l 11/11/8B~ for fracture data 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ! GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of litholog¥, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core descri pti on previ BUS1 y submi tted. ~"~'~:~ "" -£"" ,, ' " ......... ~',~.~.~l.& ~,.~ C~r,s. ,".. . ,' * NOTE: Drilled RE 12/28/88. Performed rig squeezes~ perforated well ,~j-, ........ ~.,,~ and ran tubing 5/1~/88. Fractured well 7/9/88. Added perforations 10/29/88. WC5/017 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, ali fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR. and time of each phase. Top Kuparuk C 7273' 6058' RFT Results: Base Kuparuk C 7306' 6086' Hydro Press. Form. Press. Top Kuparuk A 7357' 6129' Depth (psis) (psig) Base Kuparuk A 7477' 6230' 4269. O' 1904 1 631 4268.5 ' 1909 1 637 4268. O' 1904 1630 4049.9 ' 1819 1563 3969.0 ' 1784 1501 3968.5 ' 1782 1501 3968.4 ' 1786 1503 3968.4 ' 1786 1502 3957.5 ' 1784 1499 31. LIST OF ATTACHMENTS Addendum (dated 11/17/88) ., 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t~J ~t_~.~/. Title Area Drilling EngineerDate I~,./~//~, INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM 5129/88 6/11/88 7/09/88 10/29/88 3H-11 RU, pmp 20 bbls diesel/Musol @ 1BPM, 2750 psi. Displ diesel/Musol to perfs w/65 bbls diesel. SI well, RD. RU WL, RIH w/2.25" std'g vlv & set in D nipple @ 7356'. Pmp 30 bbls diesel + 5% Musol. Displ diesel/Musol w/63 bbls diesel into perfs, 1.5 BPM, 2250 psi. POOH w/std'g vlv. RD Otis. Frac Kuparuk "A" sand perfs 7430'-7450' in ten stages per procedure dated 6/22/88 as follows: Prepad of 98.7 bbls gelled diesel at 20 bpm, 4750 psi Pad of 98.7 bbls diesel at 20 bpm, 2580 - 4100.psi Stage 1 through 10 using total of 442.6 bbls, 16/20 carbo gelled diesel using average pressure of 3900 psi at 20 bbls per minute. Fluid to recover: Sand in zone: 17,000# Sand in csg: 0 RU Schl, perf 7371'-7383' & 7391'-7411' @ 12 SPF, 60* phasing. Release well to Production. Drilling Supervisor ~ Da%e ARCO Alaska, Inc. Date: October 28, 1988 Transmittal #: 7333 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3H-14 3K-06 1F-04 3H-11 3H-03 1E-25 3N-17 3H-14 Pressue Build-Up Analysis Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressue Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report 10-24-88 PBU 1 0 - 21 - 8 8 Casing 1 0 - 2 3 - 8 8 Casing & Tubing 1 0-1 0 - 8 8 Amerada 1 0 - 21 - 8 8 Casing 1 0- 21 - 8 8 Tubing 1 0- 21 - 8 8 Casing 1 0- 2 1 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: 0il & Gas Cons. C0~i~lo. D&M State of Alaska Chevron MObil Unocal SAPC {'" STATE OF ALASKA C(b ~..~-"' ALASKA OIL AND GAS CONSERVATION '-,vtMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well " OIL IX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-12/+ 3. Address 8. APl Number P. 0. Box 100360~ Anchorage, AK 99510 50- 10:3-20091 4. Location of well at surface 9. Unit or Lease Name 1232' FNL, 281' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1367' FNL, 129/+' FEL, Sec. 12, T12N, R8E, UM 3H-11 At Total Depth 11. Field and Pool 1316' FNL~ 10/+2' FEL, $ec.12, T12N, R8E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool I 76' RKB I ADL 25531. ALK 2657 12. Date Spudded 13. Date T.D. Reached 14. Date C.omp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/15/8712/25/87 '" N/A feet.MSL [ 1 17. Total Depth (MD+TVD) 18. Ptug'Back Depth (MD+TVD) 19. Directional Su~'ve¢ I .20. Depth where SSSV set I 21. Thickness of Permafrost ___7,750'ND/6~60'TVD 7635'ND/6363'TVD YES [] NO [] 22. Type Electric or Other Logs Run DIL/SFL/GR/SP, LDT/CNL/Cal/NGT/EPT: DIL/SFL/SP/C;R. FNS. BHC:S. RFT. SWC.. C. FT. C,~T 23. CASING, LINEI~ A'ND'CEMEI~TING'RECO~ID ' · "' . . . , ~, , : SETTING DEPTH'MD '.. ' " CASING SIZE WT. PER FT. GRADE TOP' BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~" R?.5~' ~-~n .~,,~ !!5, 2~.,, 2!5 lO-~/M, a5_5~ . .I-5~; K,,,' ~: ~RI~7 ' !$-!/!" · !290 Top job '.':/!~_0 7" ~6.0# .I-5C~ Rilr ~: 771 IR w R. !/_9" ........................ , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25... TUBING RECORD interval., size and number) SIZ.E DEPTH SET (MD) PACKER SET (MD) ,. 3-1/2" 7367' 7!77' & 7Z~9' Perforated w/10 spf, 120° phasi ng 2'6. ACID, 'FRACTURE, CEMENT ~QLJEEZE, ET~.. ., , . , 727a,'-730/+'ND/6059'-608/+'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED Pei'forated w//+ spf, 90° phasing .7~_~2,.7_~3~., . '~ ~,n -- ~--- ~ .... 7/+30 ' - 7/+50 'MD/6191 ' -6208 'TVD .~.a~, ..~,..,.,., .... $66-at%~61~ed Addem um,' dated 8/5/88,' for fracture dat~. · , ,... , ,, , 27. PRQDUCTION TEST Date First Production I Method of Qperation (Flowing, gas lift, etcl) I N/A .. Date of Test Hc;urS Tested PRODUCTION FOR OIL-DeL." 'G/~S-M'C'F wATE'R-~3BL ~HoKE SIZE I GAS-'O,L RATIO TEST PERIOD .1~ ..... , ,.. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-M'c~: 'WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wate r. Submit core chips. See attached core descriptions for core data. '?'"": ?i~i ............. '~"' ': ........ '"'":'. :.. ,, , , ...... :',... ', ,:, .., ,. , ,, , . . · NOTE: Drilled ER 12/28/88. Performed rig squeezes, perforated well and ran tubing 5/1/+/88. Fractured well 7/9/88. .............'. WC5/017 ,, ' :'"' '"" "' ,,,~ Form 10-407 ' Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE '" 29. 30. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7273' 7306' 7357' 7477' TRUEVERT. DEPTH 6058' 6086' 6129' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RFT Results: Hydro Press. Form. Press. Depth !psig) (psig) 6230' 31. LIST OF ATTACHMENTS Core Descriptions. Addendum (dated 8/5/88) 4269.0 4268.5 4268.0 4049.9 3969.0 3968.5 3968.4 3968.4 3957.5 1904 1631 1909 1637 1904 1630 1 819 1563 1784 1501 1 782 1501 1786 1503 1786 1502 1784 1499 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: .Gas injection, water injection, steam injection, air injection, salt water disposal, .water supply for injection; observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3H-11 5/29/88 RU, pmp 20 bbls diesel/Musol @ 1BPM, 2750 psi. Displ diesel/Musol to perfs w/65 bbls diesel. SI well, RD. 6/11/88 RU WL, RIH w/2.25" std'g vlv & set in D nipple @ 7356'. Pmp 30 bbls diesel + 5% Musol. Displ diesel/Musol w/63 bbls diesel into perfs, 1.5 BPM, 2250 psi. POOH w/std'g vlv. RD Otis. 7/09/88 Frac Kuparuk "A" sand perfs 7430'-7450' in ten stages per procedure dated 6/22/88 as follows: Prepad of 98.7 bbls gelled diesel at 20 bpm, 4750 psi Pad of 98.7 bbls diesel, at 20 bpm, 2580 - 4100 psi Stage 1 through 10 using total of 442.6 bbls, 16/20 carbo gelled diesel using average pressure of 3900 psi at 20 bbls per minute. Fluid to recover: Sand in zone: 17,000# Sand in csg: 0 Dri~ Superv~ ARCO ALASKA, INC. KRU 3H-11 SEC 12, T12N, R8E, U.M. API# 50-029-21771 SIDE WALL CORE DESCRIPTIONS FOR THE STATE OF ALASKA DEPTH(MD) 3951 3955 3959 3961 3965 3967 3969 3973 3982 3987 3989 3991 3993 3995 3997 3999 4001 4005 4007 4009 4011 4049 4054 4056 4061 4096 4097 4266 4267 4269 4274 4277 4282 4284 4286 4287 4290 4292 DESCRIPTION SHALE, SANDY, PEBBLY, TRACE OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN SAND, GRAVEL, POROUS, OIL STAIN GRAVEL/CONGLOMERATE(?), RECOVERED VERY LITTLE SPL GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, ARGILLACEOUS, POROUS, OIL STAIN GRAVEL, POROUS, OIL STAIN SAND, ARGILLACEOUS, POROUS, OIL STAIN GRAVEL, ARGILLACEOUS, POROUS, OIL STAIN GRAVEL, ARGILLACEOUS, POROUS, OIL STAIN SAND, GRAVEL, POROUS, OIL STAIN SAND, GRAVEL, POROUS,:OIL STAIN SAND, SOME PEBBLES, POROUS, OIL STAIN SAND, SOME PEBBLES, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN SAND, SOME PEBBLES, POROUS, OIL STAIN SAND, SOME PEBBLES, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, SOME POROSITY, OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, OIL STAIN SAND, ARGILLACEOUS, LITTLE POROSITY, TRACE OIL STAIN SAND, PEBBLY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS., OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN GRAVEL, SANDY, POROUS, OIL STAIN SAND, TRACE GRAVEL, POROUS, OIL STAIN SAND, SOME GRAVEL, POROUS, OIL STAIN CONFIDENTIAL ARCO ALASKA, INC. KRU 3fl-ll SEC. 12, T12N, RSE U.M. API# 50-029-21771 CORE CHIP DESCRIPTIONS FOR THE STATE OF ALASKA DEPTH(MD) 3941' 3944' 3947' 3952' 3953'8.5" 3974'3.5" 3979' 3983' 3993'7" 4025' 4028' 4031' 4O34' 4037' 4057' 4060' 4063' 4066' 4069' 4072' 4073'8" 4077' 4079'6" 4081'10" DESCRIPTION SHALE, SILTY, NO OIL STAIN SHALE, SILTY, NO OIL STAIN SHALE, SILTY, NO OIL STAIN SHALE, SILTY, NO OIL STAIN- CONGLOMERATE(SAND, SILT, CLAY, GRAVEL), SOME POROSITY OIL STAIN SANDSTONE, CONGLOMERATIC, CEMENTED, LITTLE POROSITY, NO OIL STAIN SANDSTONE, CONGLOMERATIC, CEMENTED, LITTLE POROSITY, NO OIL STAIN PEBBLE CONGLOMERATE, SANDY, POROUS, OIL STAIN PEBBLE CONGLOMERATE, SANDY, POROUS, OIL STAIN SAND, PEBBLY, POROUS, OIL STAIN SANDSTONE, CEMENTED, LITTLE POROSITY, SOME OIL STAIN ~ SAND, SOME POROSITY, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, POROUS, OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, NO OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, NO OIL STAIN SAND, ARGILLACEOUS, PART CEMENTED/PART POROUS, SOME OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, SOME OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, NO OIL STAIN SHALE, SILTY, NO OIL STAIN SAND, ARGILLACEOUS, SOME POROSITY, NO OIL STAIN CONFIDENTIAL CORE SUMMARY KRU 3H-11 INTERVAL 3941-3972 3972-3979 BBL ON BOTTOM 3979-3993 3993-4025 4025-4057 4057-4079 4079.5 - 4085.5 CUT 31' , 14' 32' ! 13' 8.5" 2' 3.5" 4' 2" O' 7" 11' 3" 22' 0" 2' 9.5 SUB.~URFACE DIRECTIONAL SURVEY ~ UIDANCE ~]ONTINUOUS F'~ DeL Company ARCO ALA~,,KA), INC r, Well Name 3H-11 (1232' FNL, 281' FWL, SEC 12,T12N, R8E, UM) II ii i II Field/Location KUPARUK. NORTH SLOPE. ALA_~K/~ , Job, Referenc,e.,,, No. 72611 ,Loaned SARBER Date 15-FEB-88 Computed By: KRUWELL SCHLUMBERGER ~CT DIRECTIONAL SURVEY CUSTOMER LISTZNG FOR ARCO ALASKa, t INC. 3H-1! KUPARUK NORTH SLOPEtALASKA SURVEY DATE: 'I_5-FEB-88 ENGINEER: G. SARBER METHODS ~F COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTEO ONTO A TARGET AZIMUTH OF SOUTH 98 OEO 38 MIN EAST ARCO ALASKAp INC. 3H-11 KUPARUK NORTH SLOPE,ALASKA COHPUTATIDN DATE: Z-MAR-88 PAGE 1 DATE 9F SURVEY: tS-FEB-88 .' KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: G. SARaER INTERPOLATED VALUES FOR EVEN tOO FEET OF MEASURED DEPTH TRUE SUR-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -76.00 0 0 N 0 0 E 100.00 100.00 24.00 0 8 S $1 33 E 200.00 ZO0.O0 ti4.00 0 11 S 59 9 E 300.00 300.00 224.00 0 15 S 50 16 E 400.00 399.99 323.99 0 55 S 65 34 E 500.00 499.87 423.87 4 28 S 83 33 E 600.00 599.25 523.25 8 30 S 85 13 E 700.00 697.35 621.35 13 27 S 87 37 E 800.00 793.91 717.~1 16 5 S 87 28 E 900.00 899.57 813.57 17 43 S 86 47 E 1000.00 984.50 908.50 18 56 1100.00 1078.56 1002.56 ZO 56 1200.00. 117]*.41 1095.41 22 32 1300.00 1263.24 1187.24 24 9 1400,00 1354.07 1278,07 25 12 1500.00 1444.02 1368.02 26 53 1600.00 1531.57 1455.57 30 57 1700.00 1615.69 1539.69 34 14 1800..00 1697.43 1621.43 36 2 1900.00 1777.83 1701.83 36 53 VERTICAL DOGLEG RECTANGULAR CqORO[NATES HrJRIZ. DEOARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.DO N 0.00 E 0.15 0.00 0.07 S 0.15 E 0.41 0.00 0.22 S 0.40 E 0.71 0.24 0.43 S 0,70 E 1.44 2.1~ 0.95 S 1.41 E 6.01 2.30 1.79 S 5.97 E 16.83 5.40 2.84 S 16.77 E 36.09 4.43 3.96 S 36.00 E 62.02 1.11 5.00 S 61.92 E 91.14 0.96 '6.43 S 91.01 E S 86 17 E 122.56 S 85 40 E 156.46 S 85 25 E 193.53 S 85 15 E 233.05 S 85 47 E 274.80 S 85 53 E 318,44 S 94 39 E 366.61 S 84 46 E 420.52 S 84 59 E 477.99 S 83 59 E 537.31 2000.00 1857.39 1781.39 37 39 S 83 56 E 597.68 2100.00 1936.23 1860.23 38 11 S q3 38 E 658.97 2200.00 2014.71 1930.71 38 12 . S 33 19 E 720.70 2300.00 2093,44 2017.44 38 10 S 82 2,5 E 782,04 2400.00 2171.72 2095.72 38 50 S ~1 43 E 843.86 2500.00 2249.24 2173.24 39 23 S 81 16 E 906.55 2600.00 2326.02 2250.02, 40 2~ S ,90 44 E 970,04 2700,00 2401.55 2325.55 41 23 S 80 21 E 1034.93 2800.00 2476.21 2400.21 41 55 S 79 59 E 1],00.72 2900.00 2550,44 2474.44 42 13 S 79 41 E 1166,94 S 79 11 E 1233.65 S 78 38 E 1300.75 S 78 26 E 1368.01 S 78 15 E lr, 35.49 S 78 ~ E 1503.28 S 77 30 E 1571.16 S 76 38 E 1638.75 S ?6 30 E 1706.63 S 76 26 E. 1774.88 S 76 29 E 1942.39 3000.00 2624.16 2548.16 42 44 · "*'3100.00 2697.40 2,321.40 43 4 3200.00 2770.42 2694.42 43 8 3300.00 2843.20 2767.20. 43 29 3400.00 2915.64 2939.64 43 37 3500.00 2987.94 2911.94 43 38 3600.00 3060.30 2984.30 43 40 3700.00 3132.29 3056.29 44 23 3800.00 3203.,98 3127.98 44 0 3900.00 3276.20 3200.20 43 23 1.31 2.65 1.32 I .26 1.00 3.16 4.02 2.05, 1.05 0..77 0.64 0.5~ 1.05 0.87 0.98 0.56 1,32 0.51 0.43 0.72 0,75 0,32 0.20 0,42 0,24 1.15 0,40 0.20 0 0.44 0.00 N 0 0 E 0.17 S 66 12 E 0.46 S 60 57 E 0.82 S 59 25 E 1.70 S 56 13 F 6.23 S 73 25 E.. 17.01 S 80 23 :[ 36.22 S 83 ~,3 62.12 S 85 22 E 91.24 S 85 57 E 8.33 S 122.39 E 122.68 S 86 6 E 10.71 S 156,25 E 156.61 S 86 4 E 13.61 S 193.26 E 193.74 S 85 58 E 16.8~ S 232.71 E 233.32 S 85 52 E 20.09 S 274.40 E 275.14 S 85 48 E 23.23 S 317.97 E 3~8.82 S 85 49 E 27.17 S 366.07 E 367.08 S 85 45 E 32.25 S 419.87 E 421.10 5 85 36 E 37.34 S 477.24 E 478.70 S 85 31 E r, 3.14 S 536.43 E 538.16 S 85 24 E 49.58 S 596.67 E 598.72 S 85 1¢ E 56.20 S 657.82 E 660.22 S 85 7 E 63.22 S 719.40 E 722.].7 S 81, 58 E 70.84 S 780.57 E 783.78 S 8~ 48 E · 79.44 S 842.20 E 845.94 S 84 36 E 88.76 S 906.69 E 909.03 S 8~+ 23 F 98.76 S 967.95 E 972.9:~ S 8~+ 10 Fr' 10.9.56 S 1032.6{. E 1038.41 S 83 120.89 S 1098.15 E 1104.7:) S 83 43 132.74 S 1164.10 E 1171.65 S 83 29 E '145.07 S 1230.54 E 1239.07 S 83 16 E 158.25 S 1297.3~ E 1306.96 S 83 2 E 171.83 S 1364.30 E 1375.03 S 82 49 E 185.66 S 1431.49 E 1443.47 S 82 36 E 199,79 S 1498.95 E 1512.20 S 82 24 E 214.28 S 1566.50 E 15,91.09 S 82 12 E 229.82 S 1633.74 E 1669.82 S 81 59 E 245.96 S 1701.25 E 17{.8.94 S 81 46 E. 262.31 S 1769.13 E 1788o47 S 81 33 E 278.46 S 1836.27 E ~857.26 S 81 22 E COHPUTATZgN O~TE~ 2-~AR-88 PA~F 2 ARCO ALASKA~ ZNC. 3H-11 KUPARUK NORTH SLDPEtALASKA DATE OF SURVEY: 15-FEB-83- KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: ~. SARBER ZNTERPDLATED VALUSS FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUO-SEA COURSE HEASURED VERTTCAL VERTTCAL DEVIATION AZ[HUTH OEPTH DEPTH DEPTH DEG MIN DEG MTN VERTICAL DOGLEG RECTANGULAR COORDINATES HOREZ. DEPARTURE SECTION SEVERZTY NORTH/SOUTH EAST/WEST DIST. AZ[HUTH FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3349.12 3273.12 43 4 4100.00 3422.14 3346.14 42 58 4200°00 3495.5~ 3419o~8 42 18 4300.00 3570.30 3494.30 40 54 4400.00 3646.72 3570.72 39 34 4500.00 3724.51 3548.51 38 14 4600.00 3803.28 3727.28 37 45 4700°00 3883.06 3807.06 35 50 4800°00 3964.91 3888.91 34 50 4900.00 4046.94 3970.94 34 49 S 76 17 E 1909.28 S 76 23 E 1976.01 S 78 34 E 2042.52 S 82 ! E 2108.29 S 85 16 E 2172.52 S 89 12 ~ 2235.31 N 88 6 E 2296.87 N 87 3 E 2357°03 N 96 30 E 2414.28 N 86 24 E 2471.26 0.43 0.7! 3.40 2.25 1.63 2.67 1.78 3.60 0.23 0.32 294.52 S 1902.80 E 1925.45 S 81 12 E 310.74 S 1969.16 E 1993.53 S 81 1 325.82 S 2035.33 E 2061.25 S 80 54 E 336.80 S 2100.86 E 2127.69 S 80 53 E 343.99 S 2164.94 E 2192.09 S 80 58 E 347.32 S 2227.66 E 2254.58 S 81 8 346.69 S 2289.26 E 2315.36 S 81 23 ( 344.06 S 2349.49 E 2374.55 S 81 40 L 3.40.73 S 2406.85 E 2430.84 S 81 56 E 337.19 S 2463.93 E 2486.8-2 S 82 12 E 5000.00 4129.02 4053.02 34 37 5100.00 4212.88 4136.88 31 40 5200°00 6298.07 4222.07 31 35 5300.00 6383.36 4307.36 31 21 5600.00 4468.73 4392.73 31 30 5500.00 4553.91 4477.91 31 36 5600.00 4639.17 4563.17 31 25 5700.00 4724.48 4648.48 31 23 5800.,00 4809.81 4733.9! 31 30 N 85 58 E 2528.16 N 84 18.E 2582.27 N 83 50' E 2636.23 N 83. 25 E 2685.95 N 83 6 E 2737.51 N B2 41 E 2789.32 N 82 16 5 2840.96 N 81 67 E 2892.45 N 91 1,8 E 2943.82 5900.00 4894.98 4819.98 31 40 . N 80 52 E 2995.38 I .95 0.69 0.61 0.26 0.34 0.26 0.52 0.31 0.34 0.31 333.52 S 2520.92 E 2562.89 S 82 27 E 328.81 S 2515.:16 E 2596.07 S 82 43 F. 323.43 S 2627.27 E 2647.10 S 82 58 E 317.61 S 2679.14 E 2697.90 S 83 14 E 311.50 S 2730.86 E 2748.57 S 83 29 E 305.06 S 2792.86 E 2799.51 S 83 44 E 298.21 S 2834.65 E 2850.30 S 83 59 E 290.99 S 2886.33 E 2900.97 S 8~. 14 E 2~J3.32 S 2937.90 E 2951.53 S 8~ 29 E 275.20 S 2989.67 E 3002.31 S 8~ 4,6 E 6000.00 6980.02 4904.02 31 49 6100.00 5066.95 498~.95 31 55 6200.00 5149.81 5'073.81 32 6 6300.00 5234.49 5158.4~9 32 7 6600.00 5319.22 524~.22 32 5 6500.00 5403.99 5327.99 32 6600.00 5488.79 5612.79 31 58 6700.00 5573.63 5497.63 32 0 6800.00 56 58.3.::J 5582.38 32 6 6900.00 5743.09 5667.'J9 32 5 000 oo 58:,'7 8o 5'75:L 7100.00 5912.32 5836.32 32,~25 7200.00 5996.61 -5920.61 32,~326 7300.00 6080.99 .-,,6006.99 32,~326 7400.00 6165.33 6089.33 32,~'33 7500.00 6269.61 6173.61 32,~L37 7600.00 6'333.86 6257~. 94 32~'~37 1'700.00 6418.06 6342.06 32.~..~37 7750.00 6660.18 6386.18 N ~0 36 E 3047.08 N ~0 7 E 3998.90 N 79 59 E 3150.79 N 79 40 E 3202.91 N '9 2, E 3254.87 N 79 5 F 3306.74 N 78 45 E 3358.51 N 78 24 E 3410.,2 N 78 6 E 3661.83 ~ 77 46 E 351'3 51 N 77 60 ~3565:15 N 772~47 E 3617.09 N 77~[59 E 3669.60 , 785~5 E 372,.68 N 78I~5 E 3776.09 N 78,T~32 E 3879.12 N 78,~G2 E 3931.68 N 78.~2 E 3957.96 0.39 0.26 0.55 0.22 0.17 0.13 0.22 0.32. 0.36 0.16 0.37 0.19 0.59 0.19 0.19 1.68 0.00 0.00 0.00 266.71 S 3061.59 E 3053.26 S 84 59 E 257.86 S 3093.64 E 3104.3~ S 85 16 E 248.72 S 3165.75 E 3155.57 S 85 28 E 239.36 S 3198.12 E 3207.06 S 95 63 E 229.67 S 3250,32 E 3258.43 S 85 57 E 219.76 S 3302.44 E 3309.75 S 86 11 E 209.57 S 3354.47 E 3361.01 S 86 25 ~' 1'99.12 S 3406.34 E 3612.15 S 86 39 - 188.30 S 3458.33 E 3463.45 S 86 53 t:: 177.20 S 3510.29 E 3514.76 S 87 6 E 165.87 S 3562.21 E 3566.07 S 87 ZO E 154.47 S 3614.43 E 3617.73 S 87 33 E 163.19 $ 3667.03 E 3669.82 S 87 65 E 132.35 S 3719.59 E 3721.96 S 87 57 E 121.73 S 3772.26 E 3774.22 S 88 9 E 111.02 S 3825.00 E 3826.62 S 88 20 E 100.30 S 3877.84 E 3879.13 S 8~ 31 E 89.59 S 3930.67 r:_ 3931.69 S 88 ~1 E 84.23 S 3957.08 E 3957.98 S 88 ~,6 E ARCO ALASKA, INC. 3H-11 KUPARUK NORTH SLOPEpALASKA COMPUTATZON DATE: Z-MAR-g8 PAGE 3 DATE OF SURVEY: IS-FEB-83 KELLY BUSHING ELEVATION: 7,~.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DFPTd TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZTMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N 0.00 0o00 -76.00 0 0 1000.00 984.50 908.50 18 55 2000.00 1857.39 1781.39 37 39 3000.00 2624.16 2549.16 42 4000.00 3349.12 3273.12 43 5000.00 412g.02 4053.02 34 37 6000.00 4980.02 4904.02 31 49 7000o00 5827.80 5751.90 32 7750°00 6460.18 6384.18 32 37 VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZZHUT.q FEET DEG/[00 FEET FEET FEET DEG ~IZN N 0 0 E 0.00 S 36 17 E 122.56 S 83 54 E 597.68 S 79 1! E 1233.65 S 76 1'7 E 1909.28 N ~5 59 E 2528.16 N 80 34 E 3047.08 N 77 40 E 3565.t5 N 78 32 E 3957.96 0.00 1.31 0.64 0.75 0.43 1.95 0.39 0.37 0.00 0.00 N 0.00 E 0.00 N 0 0 E 8.33 S 122.39 E 122.68 S 85 6 E 49.58 S 596.67 E 598.72 S 85 14 E 145.07 S 1230.54 E 1239.07 S 83 16 E 294.52 S 1902.80 E 1925.45 S 81 12 E 333.52 S 2520.92 E 2542.89 S 82 27 ~.- 266.71 S 3041.59 E 3053.26 S 84 59 165.87 S 3562.21 E 3566.07 S 87 20 L 84.23 S 3957.08 E 3957.98 S 88 46 E ARCO ALASKAt ]:NC. 3H-11 KUPARUK NORTH SLOPE.ALASKA COHPUTATTON Da, T E: Z-MAR-88 PAGE 4 ,, DATE OF SURVEY: 15-FEB-88' KELLY BUSHING ELEVATION: 76.00 FT . , ENG£N~ER: G. SARDER INTERPOLATEO VALUES FgR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUD-SEA COURSE HEASUREO VERTICAL VERTICAL DEVZATION AZZNUTH DEPTH DEPTH DEPTH DEG H[N DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT[ON' SEVERITY NORTH/SOUTH EAST/NEST DIST. AZ[NUTH FEET DEG/IO0 FEET FEET FEET DEG qlN 0.00 0.00 -76.00 0 0 N 0 0 E 76.00 76.00 0.00 0 9 S 65 11 E 176.00 176.00 100.00 0 11 S 56 2& E 276.00 276.00 200.00 0 12 S 53 24 E 376.00 376.00 300.00 0 38 S 53 41 E 476.07 476.00 400.00 3 44 S 81 57 E 576.53 576.00 500.00 7 20 S 84,39 E 678.09 676.00 600.00 12 28 S 97 14 E 781.37 776.00 700.00 15 48 S 87 36 E 885.76 87F~.00 BOO.rJO 17 32 S 86 53 E 0.00 0.00 0.00 N 0.00 E 0.10 0.00 0.06 S 0.10 E 0.34 0.00 0.18 S 0.33 E 0.63 0.00 0.37 S 0.63 E 1.16 0.60 0.79 S 1.14 E 4.30 3.89 1.56 S 4.26 E 13.62 4.51 2.55 S 13.57 E 31.16 4.59 3.74 S 31.08 E 56.89 2.13 4.78 S 56.80 i 86.83 1.10 6.20 S a6.71 E 0.00 N 0 0 E 0.10 S 68 5 E 0.38 S 61 35 E 0.73 S 59 15 E 1.38 S 55 13 E 4.54 S 69 51 F' 13.81 S 79 20 31.30 S 83 7 ,. 57.00 S 85 11 E 86.93 S 85 54 E 991.02 976.00 900.00 18 50 i097.27 1076.00 I000.00 20 52 1204.96 1176.00 1100.00 22 37 1313.99 1276.00 1200.00 24 22 14~24.26 1376.00 1300.00 25 2.8 1536.08 1476.00 1~,00.00' 28 14 1652.36 1576.00 1500.00 32 54 1773.58 1676.00 1500.00 35 37 189 7..72 1776.00 1'?00. O0 36 52 S 86 20 E 119.66 1.26 S 85' 41 E 155.50 2.63 S 8.5 25 E 195.~,2 1.21 S 95 15 E 23B.77 .0.80 S 85'51 E 285.17 1.25 S 95 34 E 335.11 4.43 S 84 32 E 394.23 3.'54 S 84 59 E 462.58 1.85 S 34 '3 E 535.95 0.77 612.04 0.68 2023.54 1876.00 1800.00 37 49 , S 83 55 E 6.1~, S 119.50 E 119.77 S 85 6 E 10.63 S 155.29 E 155.65 S 86 4 E 13.76 S 195.15 E 195.63 S 85 57 E 17.29 S 238.42 E 239.05 S 85 41 E 20.85 S 284.76 E 2~5.52 S 85 48 E 24.47 S 334.62 E 335.52 S 85 49 E 29.79 S 393.63 E 394.76 $ 85 60 E 35.99 S 461.85 E 463.25 S 85 32 E 63.00 S 535.07 E 536.80 S 85 24 E 51.11 S 611.00 E 613.13 S 85 13 E 21-50.67 1976.00 1900..O0 3R 22 2277.82 2076.00 2000.00 38 2 2405.50 2176.00 2t00.00 38 53 2534.68 2276.00 2200.00 39 37 2666.01 2376.0.0 2300.00 ~,1 7 2799.71 2476.00 2400.00 4~1 55 2934.56 2576.00 2500.00 42 26 3070.72 2676.00 2600.00 43 0 3207.65 2776.00 2700. DO 43 9 3345.26 2876.00 2!{00.00 43 35 ::13 2 :J 'E 690.14 82 39 E 768.42 81 41 E 847.28 81 6 E 928.42 90 26 E 1012.75 79 58 E 1100.53 79 34 E 1189.93 7a 42 E 1281o06 78 26 E 1373.15 78 1! E 1466.16 0.12 0.81 0.99 1.04 I .06 0.43 0.57 0.60 0.21 0.22 59.72 S 689.02 E ~.91.60 S 85 2 E 69.06 S 766.99 E 770.10 S 84 51 E 79.9~, S 845.61 E: 8~9.39 S 84 35 E 92.14 S 926.49 E 931.06 S 84 19 F 105.82 S 1010.51 E 1016.04 S 84 1 E 120.8,5 S 1097.96 E 1104.60 S 83 43 E.. 136.93 S 1187.00 E 1194.87 S 83 25 ( 154.32 S 1277.75 E 12~7.03 S 83 6 172.88 S 1369.41 E 1380.29 S 82 4,8 L 192.03 S 1462,00 E 1474.55 S 82 31 E 3483.49 2976.00 2900.00 43 41 3621.71 3076.00 3000.00 43 42 3761.15 3176.00 3100.00 44 16 3899.72 3276.00 3200°00 43 23 4036.83 3376.00 3300.00 43 9 4173.46 3&76.00 3400.~0 42 37 4307.53 3576.00 3500.00 40 47 4437.86 3676.00 3600.00 39 8 4565.44 3776.00 3700.00 37 58 4691.23 3876.00 3800.00 36 7 S 77 41 E 1559.97 S 76 35 E ,1653.42 S 76 26 E 17&8.43 S 76 2q E 1842.20 S 76 12 E 1933.86 S 77 32 E 2024,.91 S 82 12 E 2113.18 S 86 20 E 2196.49 N 89 Z E 2275.69 N 87 7 E 2351.84 0.89 0.55 0.61 0.44 0.41 2 2.40 2.70 1.79 3 211.83 S 1555.36 E 1569.72 S 82 14 E 233.30 S 1648.32 E 1664.75 S 81 56 E 255.96 S 1742.82 E 1761.52 S 81 38 E 278.41 S 1836.08 E 1857,07 S 81 12 E 300.51 S 1927.25 E 1950.53 S 81 8 E 322.13 S 2017.80 E 2043.35 S 80 55 E 337.47 S 2105.74 E 2132.61 S 8'0 53 E 345.75 S 2188.87 E 2216.01 S 81 I E · 347.22 S 2258.05 E 22~4.48 S 81 17 E 344.31 $ 23.44.30 E 2369.45 S 8L 38 E ARCO ALASKA! TNC. 3H-1! KUPARUK NORTH SLOPEtALASK~ crJHPUTATI: ON DRTE: Z-HAR-88 PAGE 5 ,, OAT= OF SURVEY: tS-FEB-B8. KELLY BUSHING ELEVATION: 7&.O0 FT ENGINEER: G. S~RBER INTERPOLATE5 VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SU3-SEA COURSE VERTICAL DOGLEG RECTANGULAR C~ORDINAT;S HOR[Z. DEOARTURE qEASURED VERTICAL VERTICAL DEVZATZON AZ[EUTH SECT[ON SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIHUTH DEPTH DEPTH DEPTH DEG 4813.52 3976.00 3900.00 34 52 4935.40 &076.00 4000.00 34 51 5056.44 4276.00 4100.00 32 40 5174.09 4276.00 4200.00 31 35 5291.38 4376.00 4300.00 31 22 5408.52 4476.00 4400.00 31 32 5525.93 ¢576.00 4500.00 31 34 5643.17 ¢676.00 4&O0.O0 31 30 5760.36 4776.00 4700.00 31 25 5877.69 4876.00 4800.00 31 38 5995.27 4976.00 4900.00 31 48 6113.0! 5076.00 5000.00 31 55 6230.93 5176.00 5100.00 32 9 6349.00 5276.00 5200.00 32 Z 64'66.99 $376.00 5300.00 32 1 6584.93 5476.00 5400.00 31 59 6702.79 5576.00 5500.00 32 0 682008! 56.76.00 5600.00 32 6 6938.85 5776.00 5700.00 32 4 7057.00 5876.00 S800.00 32 7175.55 5976.03 5900.00 32 34 7294.08 6076.00 6000.00 32 27 7412.66 6176.00 6100.00 32 32 7750.00 6460.18 6384.18 32 37 DEG H[N FEET OEG/ZO0 FEET FEET FEET OEG H[N N 86 29 E 2421.98 N 86 25 E 2491.42 N 84 49 E 2559.25 N fl4 ! E 2620.77 N ~3 26 E 2681.51 N 83 4 E 2741.92 N 82 35 E 2802.75 N 82 5 E 2963.20 N 81 29 E 2923.44 N 80 57 E 2983.86 N 80 35 E 3044.63 N 80 5 E 3105.65 N 79 55 E 3166.91 N 79 30 E 3228.38 N 79 10 E .3289.63 N 78 43 E 3350.72 N 78 23 E 3411.56 N 78 Z E 3472.60 N 77 40 E 3533.57 N 77 40 E 3594.72 N 77 55 E 3656.61 N 78 35 E 3718.59 N 78 35 E 3780.73 N 78 32 E 3957.96 0.27 0 3.89 0 0.26 0.32 0.25 0.25 0.29 0.28 0.35 0.27 0.29 0.30 0 0.20 0.31 0.33 0.16 0.33 0.62 0.30 0.41 0.00 340.26 S 2414.56 E 2438.42 S 81 58 E 335.92 S 2434.11 E 2506.72 S 82 17 E 331.01 S 2552.08 E 2573.46 S 82 36 E 324.87 S 2613.77 E 2633.88 S 8Z 54 E 318.12 S 2674.68 E 2693.53 S 83 13 E 310.97 S 2735.28 E 2752.90 S 83 30 E. 303.30 S 2796.31 E 2812o71 S 83 48 /' 295.15 S 2856.911 E 2872.18 S 84 6 286.42 S 2917.44 E 2931.47 S '84 23 E 277.05 S 2978.11 E 2990.97 S 84 41 E 267.12 S 3039.13 E 3050.84 S 84 58 E 256.68 S 3100.41 E 3111.02 S 85 16 E 245.85 S 3161.95 E 3171.49 S 85 33 E 234.63 S 3223.71 E 3232.23 S 85 50 E 223.06 S 3285.25 E 3292.81 S 83 6 E 211.13 S 334~..64 E 3353.29 S 8:~ 23 E 198.82 S 3407.79 E 3413.5;3 S 8b 39 E 186.02 S 3469.15 E 3474.13 S 86 55 E 172.81 S 3530.45 E 3534.6,3 S 87 11 E 159.37 S 3591.94 E 3595.47 S 87 27 E 145.92 S 3654.17 E 3657.09 S 87 42 E 132.97 S 3716.48 E 371P..85 S 87 57 E 120.3a S 3778.93 E 37.30.85 S 88 tO E 84.23 S 3957.08 E 3957.98 S 8.9 46 E ARCO ALASKAt INCo 3H-1! KUPARUK NORTH SLOPE~ALASKA COHPUTATION DATEr 2-NAR-88 PA';E 6 '' DATE OF SURVEY: 15-FEB-88. KELLY 8USHING ~LEVAT[D~: 7&.~O FT ENGINEER: ~o SAR~ER .qARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TO INTERPOLATED VALUES FOR CHOSEN HORZZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ~R~GIN= 1232 FNL~ 281 FWL~ SEC. 12~ T~ZN~ RBE~UM TVD RECTANGULAR COORDINATES FROH KB ' SUB-SEA NORTH/SOUTH EAST/NEST 7273o00 7306.00 7357.00 7~77o0Q 7635°00 7750.00 6086.,05 60].0o05 ].~1°71 S 372-?.7' 6230°Z3 6154.23 ~.! 3.48 S 3812o86 .' ARCO ALASKAp INC. 3H-I! KUPARUK NORTH SLOPEtALASKA COMPUTATION DATE: Z-MAR-88 KELLY ************ STRAT IGRAPH1~C SUMMARY HARK.mR TOP KUPARUK C BASE KUPARUK C TOP KUPARUK .a BASE KUPARUK A PBTD TD MEASURED DEPTH BELOW KB FROM KB ORIGIN-- 1232 FNL, TVD SUE-SEA 7273.00 6058.21 5982.21 7306.00 6086.05 6010.05 7357,00 6129.08 6053°08 7477,09 6230.23 615¢.23 7635.00 6363,32 6287.32 7750.00 6460,18 6384.1 a FINAL WELL LOCATION AT TO: TRUE SUa-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7750.00 6460.&8 6384.18 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 3957.98 S 88 46 DATE OF SURV6Y: BUSHING ELEVATION: ENG£NEER: ,. PAGE 7 15-FE8-88 ' 75.00 FT G. SARBER SURFACE LOCATION AT FWL, SEC. L2~ T]ZN, RE'sUM RECTANGULARCOORDINATES NORTH/SOUTH EAST/WEST 135.22 S 3705.38 E t31.7~ S 3722,74 E 126.30 S 3749.$9'E ~3.~8 S 38~Z°~6 E 96°55 S 3896.33 E 84°23 5 3957°08 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3H- 1 1 F I ELO KUPARUK COUNTRY U .S .A. RUN ONE DATE LOOOED 1S - FEB - 88 REFERENCE WE,lL· 232' 3H-11 FNL, 281' r'"C 12 T12N R8E UM) FWL, , , , HORIZONTAL PROJECTION NC)~I'H 4000 - 1000 -2OOO -4000 -2000 NEST I~F I'Z61 ! SCALE = 1/I000 IN/FT .... ~ . . . . . ~ __ ' : . , ; i _ ! ~ - ,, , , : i · : - . : . . : · · · ~ _ , I · ': . :': . I' ~ ~ il;; ' ; '~i ,. (~ I~ ! i!lj ! ~! ~L~!~!~!!,!li!i~:i~s!~iii ~..'~-i~iiii~i~ii ii~ -~Tt~i:I. ;**~ i :~ l'il :ii: ii: . I:i iii ; ;;; i:j : , i; ; -- --- , - ' - : ' , ,;' ;; :; j' : , ; : t ; J ' , ; ! llll ijll l~l( (I)) i!ll lJil ill) llll llillil!i iiiiljl!j ,;; ~,, i~ ii ' iii ii, ,i~ ,.,, ,,,., ,,,. ,, , ,,,, ,,,, ,,,, ,i, ii~'1 Jill iJJJ ii i iiii il . iilj fill Jill l!li iii! Jill j ii~ 111i !i!! ii~! i~ii iiil iiil ilii !iii !iiiliill il , liii llli !iii !iii (J~J.l.llJ itl) ' ..... I iii ilij ljil ~i~ III' J'Ji Jill i liiJliii! .~ii'ii .... iiii iiii iii' iii III! .ii!I I!ii iii! ~li} iI~i liil ilii I!i'i. ~Iii !I..i~ lfii - 1000 0 1000 2000 3000 4000 5000 ( (. WELL- (1232' 3H-11 VERTICAL " ' 12 T12N R8E UM) FNL, 281' FWL, , , , PROJECTION -L~lOO - ! 000 0 0 ! 000 2000 ~JO00 aO00 ;o0_n ? .... ~- -'::- :::- :-':: ~' ~-'-'- -~:~'' ~' ' : L. · ..... · . .~ ~ ~,_;_._ · - . · ' I . . . . ~ ; - .... ~ ~ ~. ~ -.--t--~- .~ ........... :- ......... = .... .............. , .... ..... ..... ~ ~ ~ ~ : ; ~ : - ~ ' I : - *~ ~ ~ ' ' : :~ ' - : ~ : ~ · ' t ~"-t ........ t--'T't' 't"--~'-~'t-t-'~-~ ........... fi':/ iL~ ., :~l]~ ' J -~ -~:; · '- '-i:~: ss [:'-~: [ J - - ] . , J j : , 1 i - - ~ t ~ I J I I ] - · ~--:~ : : - - : ~ ~ . : J ' s J - ~ : ' ~ I ' - . "e ~ _ ' / , , ' : i : I : ' ; , , I , ' .... ' l ' . · - . L..: : ~ : v s: : i. T ~: .i I i I j I j _ . - - j - . ' _ I _ j , j ' . ~'~-I"'c ?-~ '1 ~-,'n-t"~~-~~ -'H~ ~ ; ~ :'-t~ ~",. ':' ~-~ ~4--H + - · 4.~ ;.: - ~ ~ ~ : ~ ~ ~ ~ ~ ; ; , ; i .- : : ~ : ~ ~ ~-~ ~ : : : ~ ~ ~ ~ ~ ~ ~ ~ ~/ ~ ~ ~ , ~ ,] ~ J ~ ~. i ~ I/Il t i ~ ~ * ~ I ~ ~T~ T ~'T ~ t t t t~?"T= "~-'t'"T ;"';'"?'t~'"-~-~'"t-t-~---.~-~...4-,4.~ ; ~ '_ ; ~ ~-..~,. ...... ~.-' ...... :.. I ~ I .. · . ' . ~ · J · ~ ~ · ~ · i t j ~ ~ ~ ~ ~ ~ r I } I J ! I I ] ~ I i J ~ ~ i i i ~-? ~T"!'t-l~" T'l~'t '"?'T'F'i ..... t.4~.,. I" i'-'Fr" ~'-"'"'"""", 1 J ~ ..... I *', I 'J. "'"', ~ .... ~'' [ b.~.'..~ ! "t" F"J-t""T"t"wt-~-t-~'r' ........ ~'~ i i ! I I t ~ J ~ ~ t , ] T , j'~ -~'~T I I ~'T-'~'~'~?t''t' 'm'~ t ? ..... .' 'W~'-~ i~ "'t"'~'t'~-P:~'~~' ~ ~' J ~ - ' ; I - - - , , .. , . . _ . ~ . _ ~ i~ · ' i ' ~ , ' ~ . . . · i j -- I ' - ..... I ........ t . . r : i i J · i . I Il Jill.ii! i!i! Jiii J.lJlll~l~ ~I! Iii~ ! Iilli~ it Iii I iii i i!~ ~ I i I i i J J Jl~ [iii J ilii!i ~iii iii. I i[~i~l{: i:iiii~i: ji [ l~ ~ J J i ~!:~ ~ :~ ,~!Tl"!'t'!'r'J-'1"T'~ .... ~,i~ I~CF~'T! ....... I'r'm' ':~'"r ..... ,:.~ .... til:.~J.:.: :. ,,r.i ":i~'i, J ~ ] I ! I i ]. ! ] I I [ I I : i i i I i J I I ! [ I [ : I I I I I I I , I I I I Jl ! : i I ! i1 i ii I: I - I L ] .... ] ~ = - - : ' - : - i : t ' t I ' , . , : .. ~ i i : ~ .... '--,.4..;l...--~l~ ..... ~_: ~ ~ ~ , ~ ~ :. ~ .~.=_.l~.L~k.:.i_I.4_..~~ ~ . ~ ~ i~ ~ I i i.k~k ~4 [_z~ ...i i .i ~ ] i.::: .l ~.:.l: ~ : ; : ( ~ ~ ; . i. I ,_:_- [ : J~,.~[ I ' . ..... :1.:::1:,:' ? 1 I : · ~ .... I i I i I - ; i ;''''~''t'l:'l:--'1 ; ~ { j : i~ ~ :1 ~ ~ I ~ ~I~ :[ ~ : ] ~ J j :~l J ............ Jl.l~ ..... t' t ........... , i , i i ~ ,. , ~ . PRO,JECTION ON VERTIOaL PLRNE 91. - ~'/1, SO:LEO IN VERTiCRI. OEPTI'~ HOR!Z $CRLE -- !/JODO IN/FT 91. ( (.' STRATIGRAPHIC HIGH RESOLUTION DIP METER LOCATED IN THE APPENDIX STATE OF ALASKA ALA ,,-, OIL AND GAS CONSERVATION CO .,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown 1-; Stimulate [] Plugging ,'~ Perforate~, Pull tubing '~. Alter Casing ~ Other ~[ C0NPLETE 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360~ Anchorages AK 99510-0360 4. Location of well at surface 1232' FNL~ 281' FWL~ Sec.12~ T12N~ R8E~ UN At top of productive interval 1367' FNL~ 129/+' FELl Sec.12, T12N~ R8E~ UN At effective depth 1329' FNL, 1103' FEL, Sec.12~ T12N, R8E, UN At total depth 1316' FNL, 10/+2' FEL~ Sec.12~ T12N, R8E~ UM 5. Datum elevation (DF or KB) RKB 76' 6. Unit or Proper. ty n. ame Kuparuk River Unic 731~/. ~ I number 8. Approval number 8-36 9. APl number 50_103-20091 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 7750 true vertical 6/+60'TVD 7635 ' ND Effective depth: measured 6363 ' TVD true vertical feet feet feet feet Plugs (measured) None None Junk (measured) Casing Conduct;or Surface Length Size 80 ' 16" 3602 ' 10-3//+" 7683 ' 7" .,. Product;i on .,, Perforation depth: measured Cemented Measured depth 215 sx AS I 115'ND ' 1200 sx AS III & 3637'MD 600 sx Class G Top job'w/130 sx AS I 650 sx Class G & 7716'ND 300 sx AS I 7274'-730~'ND~ 7430'-7450'ND Feet true vertical 6059' -608/+ 'TVD~ 6191 ' -6208 'TVD Tubing (size, grade and measured depth) 3~"~ J-55~ l:bg w/t:ail ~ 7367' Packers and SSSV (type and measured depth) FHL pkr ~ 7177'~ WD pkr @ 7339' & TRDP-1A SSSV ~ 1798' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) 7332 ' -733/+, & 7/+/+2 ' -7/+/+/+ ' Treatment description including volumes used and final pressure 350 sx Class G & ;as Cons. CommissiOn ~,, ,~nChorage 13N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure True Vertical depth 115'TVD 3087 ' TVD 6/+31 ' TVD Tubing Pressure 14. Attachments (Complel:i on We11 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run I~ Gyro 15. I hereby .certify that the foregoing is true and correct to the best of my knowledge Title Associat;e Engineer (Dani) SW03/8/+ Form 10-404 Rev. 12-1-8~/ Date ~.H~ Submit in Duplicate ( (' ARCO uII and Gas Company" Well History - Initial Report - Dali,, Instructions: Prepare Ilnd submit the "lnitlll Roi)orr' on tho first Wednesday alter a well la spudded or workover operations are at-,rEed. Oilily work prior to 8Pudding should be summarized on the form glvln0 inclusive dimes only. District IC°untY' parish or borough ARCO Alaska, Inc. I NORTH SLOPE Field ILea. or Unit KUPARUK RIVER FIELD I ADL: 25531 Auth. or W.O. no. ITitle AK2548 I COMPLETION lStat~K 3H-11 roll no. Operator ~CO Spudded or W.O. begun ACCEPT Date end depth es el 8:00 a.m. 05/08/88 ( TD: PB: 7635 SUPV:SC/RD 05/09/88 ( PB: 7635 SUPV:SC/RD 05/10/88 ( TD: PB: 7635 SUPV:SC/RD 05/11/88 ( TD: 7750 ~B: 7635 SUPV:SC/RD 05/12/88 ( TD: 7750 PB: 7635 SUPV:DL IARCO W.I. IPr:or statuil il a W.O, Complete record for each day reported NORDIC i FINISH CEMENT SQUEEZE 7"@ 7716' MW:10.0 MIRU. ACCEPT RIG @ 1115 HRS 5/07/88. NU BOPE AND TEST. RU SOS. PERFORATE 2' 4 SPF FROM 7442-7444'. PERFORATE 2' 4 SPF FROM 7332-7334'. RUN 6.125 GR. RUN AND SET BAKER RETAINER @ 7388'. RD WL. RIH WITH BP STINGER ON DP. TAGGED UP @ 7379'. RU BJ. TEST LINES TO 3500 PSI. EST MAX INJECTION RATE 2 BPM - 1700 PSI, I BPM- 1300 PSI. HAVE COI~L~IUNICATION BETWEEN PERFS. ISOLATE BREAKDOWN. REINJECT. PRESSURE SAME. BATCH MIX 200 SX CLASS 'G' @ 15.8 PPG. PUMP 15 BBLS SLURRY OUT BELOW BP. SPOT 25 BBL SLURRY ON TOP OF BP. POOH ABOVE CEMENT TO SQUEEZE. DAILY:S44,605 CUM:$1,193,125 ETD:S44,605 EFC:$2,538,520 CiRC AROUND SWEEP 7"@ 7716' MW:10.0 SQUEEZE 8 BBLS INTO PERFS. I BPM- 1350 PSI. SQUEEZE CEMENT 1/2 BBL EVERY 15 MINUTES. SHUT IN WELL. RD BJ. WOC. BLED PRESSURE OFF TUBING 1850 PSI. NACL U TUBING UP DP. CIRC TO NORMALIZE NACL WT 9.8-10.0 PPG. POOH LD STAB IN TOOL. RIH WITH BIT AND BOOT BASKETS. WASH FROM 6438-6504'. DRILL CEMENT FROM 6504-6698'. CIRC SWEEP TO CLEAN HOLE. DAILY:S48,305 CUM:$1,241,430 ETD:S92,910 EFC:$2,538,520 RIH WITH OEDP 7"@ 7716' MW:10.0 BRINE CIRCULATE HOLE CLEAN. DRILL CEMENT FROM 6698-7378'. CBU. TEST CASING TO 2000 PSI. BLEEDS OFF 450 PSI IN 5 MINUTES. PRESSURE UP 4 TIMES. POOH. CUT AND SLIP 50' OF DRILLING LINE. DAILY:S24,857 CUM:$1,266,287 ETD:S117,767 EFC:$2,538,520 POOH TO SET HACK BHA 7"@ 7716' MW:10.0 BRINE TAG CEMENT RETAINER @ 7378'. TEST CEMENT LINES TO 4000 PSI. PUMP 3.1 BBLS AT 1/4 BPM @ 3500 PSI. HOLD 3500 PSI FOR I HR. BLED TO 3400 PSI. POOH. RIH TO BP @ 7378'. DRILL CEMENT TO 7433'. CLEAN OUT TO FC @ 7635'. CBU. ATTEMPT TO TEST CASING TO 2000 PSI. BLED TO 1300 PSI IN 5 MINUTES ON 2 TRIES. INJECT AT I BPM @ 2300 PSI. POOH TO SET BACK BHA FOR SQUEEZE. DAILY:S31,023 CUM:$1,297,310 ETD:S148,790 EFC:$2,538,520 DRILLING CEMENT 7"@ 7716' MW:10.0 BRINE FINISH POOH WITH BIT. RIH CE TO 7609'. SPOT 150 SX CLASS 'G' CEMENT. POOH 25 STANDS. SQUEEZE PERFS AT 7442-7444'. POOH WITH TUBING. RIH WITH BHA TO 7011'. RU TO DRILL CEMENT. DAILY:S43,325 CUM:$1,340,635 ETD:S192,115 EFC:$2,538,520 The above Is correct For form preparM(on end distribution, ar/~i~l iPn ~o, epe.?l~: aSl~bannUda I1~ 7ff e t I o n AR3B..459-1-D AS$OOIATE ENGINEER ARCO ~,. and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. I.f ts.ting, coring, or_perforeling, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, work p. erformed by ~'roducJn,.g. Section will be reported on "Interim' sheatl until filial completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when Idled out but not leas frequently than every 30 days., or (~) on Wednesday of the week in which oil string ia ~et. SiJbmlt weekly for workovere and following setting of git string until completion. District JCounty or Perish IState ARCO Alaska, Inc. I NORTH SLOPE AK Field I l.ease or Unit KUPARUK RIVER FIELD I 3H-11 Date and depth Complete record for each day while drilling or workovar in progress as of 8:00 a.m. NORDIC I 05/13/88 ( TD: 7750 PB: 7635 SUPV:DL 05/14/88 ( TD: 7750 PB: 7635 SUPV:DL CIRC AND FILTER BRINE 7"@ 7716' MW:10.0 BRINE DRILL CEMENT TO 7386'. TSTD UPPER PERFS TO 2000 PSI . DRILL CEMENT TO 7513'. TEST LOWER SQUEEZE PERFS TO 2000 PSI. LEAKED OFF TO 1725 PSI IN 15 MIN. DRILL CEMENT TO FC @ 7614'. POOH. RIH WITH BIT AND SCRAPER TO 7614'. DISPLACE WELL WITH CLEAN BRINE. DAILY:S23,037 CUM:$1,363,672 ETD:S215,152 EFC:$2,538,520 RIH W/3-1/2" COMPL. EQ. 7"@ 7716' MW:10.0 NACL/NABR CIRCULATE AND FILTER BRINE. POH WITH BIT. RU SCHLUMBERGER. PERFORATED 'A' SAND F/7430'-7450' & 'C' SAND F/7274'-7304'. 'A' SAND PERFORATED WITH 4 SPF & 'C' SAND PERFORATED WITH 10 SPF. RAN 6.125" GAUGE RING TO 7500'. SET 'WD' WL SET PACKER @ 7339'. RD SCHLUMBERGER. RIH WITH 3-1/2" COMPLETION EQUIPMENT. DAILY:S77,682 CUM:$1,441,354 ETD:S292,834 EFC:$2,538,520 IWall no. The above la correct For form preparetj~j~ and distribution see Procedures I~leJlual Section 10. Drilling, Pages 66,'knd 67 A88OCIATE ENGINEER AR3B-459-2-B I Number all IPage no. prepared for each wall. las they are dally well history forms consecutively ARC uiland Gas Company Dally Well History-Final Report Instructions: Prepare and submil the "Final Reporr' on the first Wednesday after allowable has been assigned or well is. Plugged, Abandoned, or Sold. *'Final RolM)fi" should be submitted Else when operations ere suspended for on indefinite or appreciable length of time. On workovere when an official test II not required upon completion, repeff completion and representative Mst date in blocks provided. The "Flail Repo~t" form may be used tot reporting the entire operation ii space is available. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. ~.K2548 OperatOr ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. FCounty or Pariah NORTH SLOPE Lease or Uni! ADL: 25531 Title COMPLETION .... IA.R.Co. Date 05/15/88 TD: 7750 PB: 7635 SUPV:DL Complete record for each day reported NORDIC i mi: 5o-~1 W.I. 56.0000 05/07/88 rAccountlng colt center code Stat~,K 3H-11 Iwa, ne. Iotal number of wells (active or inactive) on this Dst center prior tO plugging and bandonment of this well our IPrior status if a W.O. 0700 HRS RELEASED RIG 7"@ 7716' ~l~T: 6.9 DIESEL FINISHED RIH WITH 3-1/2" COMPLETION ASSEMBLY WITH TAIL 7367', SSSV @ 1798', FHL PKR @ 7177', WD PKR @ 7339'. LOC. INTO WD PACKER. SPACED OUT & LANDED TUBING. sET PKR & TESTED TUBING TO 2500 PSI. SHEARED PBR. TESTED ANNULUS TO 2500 PSI. TEST SSSV TO 1500 PSI. SHEARED BALL @ 3300 PSI. ND BOPE. NU TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. TEST CV TO 1000 PSI. SET BPV. SECURED WELL AND RELEASED RIG 9 1830 HRS, 5/14/88. DAILY:S194,493 CUM:$1,635,847 ETD:S437,327 EFC:$2,588,520 Old TD Released rig Classifications (o11, gas, etc.) Producing method Potential test data INew TO Cate JPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) weft no, Date. Reservoir Producing Interval Oil or gas Test time Production OII on teat Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected The above Is correct ~- S-~ A.g.~_OCIATE ENGilNE'I;R For form preperet~ and distribution. see Procedures Me, ual. Section 10. Drilling. Pages 86 and 87. AR3B~59~-C INumber all prepared for eaoh well. lea they ,*re dally well history fermi consecutively Page no. Divides iX Affseth:Rk:NleldC~nplny ARCO Alaska, Inc./' Post Office B~.. ;00360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSHITTAL · hand-carried SHIPPED TO: ,. · · State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE' 5-12- 88 OPERATOR: ARCO NAHE- see below S;%~4P LE TYPE· · SAHPLES SENT: Lisb L5-21:11 boxes 12088/89 - 12133/34 12123 - 12144 12145/46 - 12149/50 12151/52 - 12198/99 .12151/52 - 12198/99 12200/01 - 12223/24 12230/31 - 12288/89 ~ 12290/91 - 12371/72 12373/74 - 12390/91 12396/9.7 - 12406/07 12422/23 - 12425/26 12435/36 - 12445/46 12449/50 - 12463/64 12467/"68 - 12471/72 12473/74 -'12581/81.5' 12482/83 - 12490/91 12492/93 - 12510/11 12520/21 - 12614/15 core ch..ips, plug ends NUMBER OF BOXES' 63 KRU 2T-9; I box KRU 33-9:12 boxes 2150.8 - -g&r,u&re~ ' 6320 - 6393 '(~'250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are avai.~able)6459.- 6503 6507 - 6545 KRU 3H-9.: 9 boxes' 6548 -. 6570 '6868 - 6908 KRU '3K-9:16 boxes 6911 - 6958 6971- 7058 3365.2- 3501.3 6967 - 7009 7060 - 7099 ·3941 - 3954 7102 - 7174 3970 "3974 7199 - 7243. '3979- 3983 '" 3993- 3994 4025- 4035 ,4057 - 4059 4061- 4081 · KRU 3M-9 5 boxes 6531 - 6577.0 6579 - 6618 ,6637 - 6650 ,.KRU 3M-16:7 boxes 7580 - 7614 76.17 - 769O SHIPPED BY: ....... BayView Facility Coordinator UPON RECEIPT OF THESE SJu~{PLES, PLF. AS~'~NOTE ANY DISCRF. PANCIES .A/qD ~tklT. A SIGNED COPY'OF THIS FORH TO: ARCO ALASICR, INC. ANCHORAGE, ALASKA 99510" ATTN: Pa leo Lab : '-, t~ · ..,~ · o ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany XEROX 'rELECOPIER 2.':)~.f, ; 6- 8--$8.; 6,' 1-6 AN; " F ~'. 0 I"I : (' .'., =_i .-' C, S ....... 8 7" (', i--;: i '4 , . ',,) ~ ," i 0.." 8 ';'" r-; '2: I 9 <;:;; ,,. 9072?67542 q,%, , I ,., ARCO Alaska, Inc.- (' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 29, 1988 Transmittal #: 7107 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the followins items. Please acknowledse receipt and return one sisned copy of this transmittal. Cement Evaluation Los 2-15-88 5000-7534 ~3~-12 Cement Evaluation Los 2-15-88 4300-7108 ~3H-13 Cement Evaluation Los 2-15-88 4400-7228 ~3H-17 Cement Bond Los 2-19-88 6300-8470 ~3H-14 Cement Bond Los 2-17-88 3150-8102 ~ 3H-15 Cement Evaluation LoS 2-17-88 5250-8330 Receipt Acknowledsed: DISTRIBUTION: NSK Drillins Oil & Gas C,.,ns. Commissk...n Date: State of Alaska(+sepia) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc .... Post Offic{ 100360 Anchorage ..... ska 99510-0360 Telephone 907 276 1215 Date: February 19, 1988 Transmittal #: 7096 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-036'0 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Edit Tape and Listing 12-25-87 ..~ OH Edit Tape and Listing 12-13-87 '"'~3H-21 Open Hole Tape and Listing 2-14-88 tt72596,~'%~0'1'%'' t172595 t/72599 EL~' ~ Naska 0il &'Gas Cons. Commission Anchorage Receipt Agknowledged: DISTRIBUTION: Date: Lynn Goettinger State of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 90? 276 1215 DaCe: February 5, 1988 Transmittal #: 7O83 RIZTURI~I TO: AItCO ,laska, Znc. Attn: Xuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. -~ 3H-13 Colville P$1EDT Tape and Listing 1-8-88 #72566 ~ 3H-13 Colville Result Tape and Lis~ing 1-8-88 #72566 3H-13 Colville HSD Computations 1-8-88 #72566 '~3H-13 Colville Stratigraphic Dipmeter 1-8-88 #72566 Colville 8tratigraphic Dipmetet 12-25-87 #72555;. Receipt Acknowledged: · DI STRIBUTIOI, I: SAPC C+sepia) Unocal {+sep ia) ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfleldCompany ARCO Alaska, Inc. Post Officer 100360 Anchorage'},....ka 99510-0360 Telephone 907 276 1215 Date: January 28, 1988 Transmittal ~ 7065 RETURN TO: ARCO Alaska, Inc. Attn: KuparukReco~ds Clerk AT0-1119 P.O. Box 100360 Anchorage, AX 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Colville HSD Results Tape and Listing Colville PS1 Edit Tape and Listing Colville OH Edit Tape Colville HSD Computations / Colville OH Edit Tape and Listing 12-25-87 ;72555~r_ ~/~ 12-25-87 #72555- 1-7-88 #72565 E - FEbV_. ~ t,~ Alaska Oil & Gas Cons. Commission Anchorage Receipt Aeknowledged: DISTRIBUTION: Date; Stanford SAP-C Unocal State of AlaSka ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.( Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: January 28, 1988 Transmittal #: 7066 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '--" 3H-13 .OH Edit Tape and Listing 1-7-88 1172567 ~ OH Edit Tape and Listing 12-25-87 #72552 '-'- 3H-12 OH Edit Tape and. Listing 1-2-88 #72560 R CE E Alaska Oil & Gas Cons. Commission Anchorage Receipt Acknowledged: DISTRIBUTION: Date: M. Stanford ARCO Alasl~a. Inc. ~s a Subsidiary of Atlant~cRichNeldCompany WEST SAK ENGINEERING TRANSMITTAL 1176 TO: John Bowle STATE DATE: January 21, 1988 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of a blueline and sepia for each: 2" & 5" Natural Gamma Ray Spectrometry Log 5" Electromagnetic Propagation Log 12/18/87 run 1 12/18/87 run I .................. Alas~ Oil & Gas ~;o~. ~i~t~ ...... PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska 99510 · - MEMO'RANDu VlState" ,f Alaska TO: Lonnie C Smith .:.?:'!i~ DATE: January 27 , 1988 Commissioner mLENO: D.ADA.48 THRU: Michael T Minder Sr Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Tes'~ ARCO K.RU ~ Permit No~.--87-147 Kuparuk Rv Field FROM: Doug Amos ~ Petroleum Inspector Friday, December 18~ 1987: I traveled this date .from SAPC Endicott MPI to ARCO ~(RU CPF #3Hw'll well to stand by for the BOP test. Saturday, December 19, 1987: A top cement job ha~ to be performed on the'10-3/4' .... d~si~g whf~h' delayed the test until 7.00 p.m. The test was concluded at 8:30 p.m. There were no failures, and I filled out an AOGCC BOP test report which is attached. In summary, I witnessed the successful BOP test at ARCO CPF #3H-11. Attachments 02-001A (Rev. 8/85) 3/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well J,/-,/'// Location: Sec / Location, General General Housekeeping ~ Rig ~ Reserve Pit Mud System's Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular' Preventer Pipe Rams ~ Blind Rams ~ Choke Line Valves '~"~ H.C.R. Valve ~ Kill Line Valves ~ Check Valve Test Pressure II ACCUMLrLATOR SYSTEM Full Charge Pressure Z-~f) Pressure After Closure /450 Pump incr. clos. pres. 200 psig. psig / psi~ L.--"~" min_~s ec. Full Charge Pressure Attained: ~ min~Z~sec. , Controls: Master Remote Kelly and Floor Safety Valves Upper Kelly / ~'Test Pressure Lower Kelly ! ~-/Test Pressure Ball Type I ~Test Pressure Inside BOP ~ ~'Test Pressure Choke Manifold ~ ~ Test Pressure Va ve ' No. flanges Adjustable Chokes Hydrauically operated choke / Test Time /, hrs. Test Results: Failures "~,~N!~ Repair or Replacement of failed equipment'to be made within Commission office notified. I! // j. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector STATE OF ALASKA ' APPLICATION FOR SUNDRY APPROVALS 1. Type of,Request: Abandon ~ Suspend © Operation Shutdown I~, Re-enter suspended well Time extension ~ Change approved program '~ Plugging [] Stimulate [] Pull tubing ~ Amend order ,"" Perforate .~. Other ,~- 2. Name of Operator ARCO A'laska~ Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1232' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 13207 FNL, 1320' FEL, Sec.12, T12N, R8E, UN (approx) At effective depth 1267' FNL, 1120' FEL~ Sec.12, T12N, RSE, UN (approx) At total depth 1258' FNL, 1061' FEL, Sec.12, T12N, R8E, UN (approx) 11. Present well condition summary Total depth: measured true vertical 7750 ' ND feet Plugs (measured) 6~81 ' TVD feet 5. Datum elevation (DF or KB) RKB 76 * feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-11 8. Permit number 87-12~ 9. APl number 50-- 029-21771 10. Pool Kuparuk River 0il Poo'l None Effective depth: measured true vertical Casing Length Conductor 80* Surface 3602' Production 7683* 7635'ND feet feet 6382 ' TVD Size 1 0-3/~" 7" Junk (measured) None Cemented 215 sx AS I 1200 sx AS II I & 600 sx Class G Top job w/130 sx AS 650 sx Class G Measured depth True Vertical depth 115 *MD 115 'TVD 3637'ND 3092'TVD I 7716'MD 6z~52,TVD Perforation depth: measured None true vertical None Tubing(size, grade and measured depth) None Packers and SSSV(type and measured depth) Non~ 12.Attachments Well History Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation Ha rch ~ 1 988 ~__t ........ ~__~_ ~ .... ,.~.3 .... 14. If proposal was verbally approved .~/.~_.~ Form No. ,/'d ~' LIoL/_ Dated Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ {~/)q/y,j ~/~j~ Title A ssociat:e E na~neer Commission Use Only ( D a n i ) SA3/~9 Date /-/~ .~ Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance j Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned / Commissioner JApproval No. by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate~ ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on tho first Wednesday after a well is spudded or worKover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. Diatdct ARCO Al&sk=,, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2548 Operator ARCO ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25531 Title DRILL API: 50-029-21771 12/15/87 ' IHOur 0700 3H-11 IWell no. IARCO W.I. 56.0000 Prior ~[~iua il a W.O. Spudded or W.O. begun SPUD Date and depth aa of 8:00 a.m. 12/15/87 ( TD:..115'(' su~V':~:.,'..' '.'T~=::,172:8~'("1 ,. SUPVcJ2~':' 12117/87( TD: 3514'( 1 SUPV:RB 12/18/87 ( TD: 3656'( SUPV:RB ,TD: 3656' SUPV: .. 12/20/87 ( . TD: 3666'( SUPV:RB 12/21/87 ( '~' TD: 3979'( SUPV:RB Complete reco~ for each day reported DOYON 14 ,) :15) PU B~A 16"@ 115' MW: 8.6 VIS: 77 MOVE RIG FROM 3H-14 TO 3H-11. ACCEPT RIG 0 2300 HRS 12/14/87. NU DIVERTER AND MIX SPUD MUD. PU BHA. DAILY:$23,000 CUM:$23,000 ETD:$23,000 EFC:$1,390,000 DRILLING' 16"0 115' MW: 9.1 VIS: 81 SPUD 0 0700HRS, 12/15/87. NAVIDRILL 13-1/2" HOLE TO 1728'. 86) DAILY:$67,663 CUM:$90,663 ETD:$90,663 EFC:$1,390,000 ) ,42) DRILLING 16" 0 115 ' DRILL AND SURVEY 13 1/2" HOLE TO 3514'. MW: 9.3 VIS: 69. o) 10) DAILY:$44,458 CUM:$135,121 ETD;II35,121 EFC:$1,390,000 ' LOGGING 16"~ 115' MW: 9.4 ViS: 48 DRILL.13-1/2" HOLE TO 3656'. CONDITION HOLE FOR LOGS. LOGGING OH. DAILY:$38,906 CUM:$174,027 ETD:II74,027 EFC:$1,390,000 .. CEMENTING 10-3/4" CSG 10-3/4"@ 3637' MW: 9.4 VIS: 48 RAN DIL/SFL/GR/SP F/3656'-SURFACE, LDT/CNL/CAL/NGT/EPT F/3656'-SURFACE (EPT F/ 3656'-1700'). CIRC. & COND. MUD. RU TO..RUN 10-3/4" CASING. RAN 90 JTS 10-3/4", 45.59/FT, J-55, BTC CASING W/FC 0 3550' & FS 0 3635'. RU DOWELL, CIRC. & COND., BEGIN CEMENTING 10-3/4" CASING. DAILY:$52,690 CUM:$226,717 ETD:$226,717 EFC:$1,390,000 -) 13) CHANGING OVERMUD 10-3/4"@ 3637' MW: 8.8 VIS: 70 CMTD 10-3/4" CASING W/1200 AS III & 600 SX CLASS G. ND DIVERTER. PUMPED TOP JOB W/130 SX AS I. SET SLIPS ON 10-3/4".CASING. WELD ON BELL NIPPLE & MU STARTING HEAD. NU BOPE & TESTED TO 3000 PSI (WITNESSED BY AOGCC-DOUG AMOS). MU BHA. RIH TO FC. DRILLED FC, CMT, FS, & 10' NEW FORMATION. TESTED TO 12.5 PPG EMW. PUMPED SPACER & CHANGED OUT MUD TO .,'~.'..., BLAND SYSTEM. . '~..''.~"''..., .--'~' DAILY:S217,119 ":CUM.:$443,836 .ETD:$443,83~' EFC:$1,390,000"'i/ i~'~ ...... .. RIH W/CORE BBL ~3 10-3/4"@ 3637' LvM: 8.9 VIS: 62 ~ " CHANGED OUT MUD SYSTEM. DRILLED 9-7/8" HOLE TO 3941'.' POH & PU CORE ASSY. CORED F/3941'-3972'; RECOVERED 11'. CUT CORE ..... .*,,..' ....... ,. ~2 F/3972'-3979', BIT JAMMED; RECOVERED 7'. RIH W/CORE ~BL · "' ...... i...~ .... #3. DAILY:$45,836 CUM:$489,672 ETD:$489,672 EFC:$1,390,000 The above, la correct For form preparation a atrlbutlon, see Procedurea ManualZ~6ectlon 10, Drilling, Pages 86 and 87. ' IDate I Title I-/I.Z~ Associate Engineer ARCO Oil and Gas Company Daily Well History--Interim lnltrUolionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach descriplion of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative lest on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovars and following setting of oil string until completion. District Field ARCO Alaska, Inc. KUPARUK RIVER FIELD County or Parish IStat8 NORTH SLOPE Lease or Unit 3H-11 Well no. Date end daptl~ aa of 8:00 a.m. 12/22/87 ( TD: 4026'( SUPV:RB 12/23/87 ( TD: 4085'( SUPV:RB 12/24/87 ( 1 TD= 6211'( 21 SUPV:JP 12/25/87 TD: 7750'( SUPV:JP 12/26/87 ( TD: 7750'( SUPV:JP 12/27/87 ( TD: 7750'( SUPV:JP Complete record for each day while drilling or workover in progress DOYON 14 I) 47) )) 59) )) L26) ) 39) ~) o) ~) o) RIH W/CORE BBL ~6 10-3/4"@ 3637' MW: 8.9 VIS: 58 RIH W/CORE BBL 93. ATTEMPTED TO BREAK CIRCULATION. POOH WET LOOKING FOR RESTRICTION. BREAKDOWN CORE ASSEMBLY & CLEAN. RIH W/CORE BBL 94, WASHED TO BOTTOM (90'). CORED F/3979'-3993', BIT JA~4ED. POOH. RIH W/CORE BBL ~5 & NEW COREHEAD. CORED F/3993'-4026', POH. RIH W/CORE BBL,6. DAILY:S65,685 CUM:$555,357 ETD:S555,357 EFC:$1,390,000 RIH W/8-1/2" DRLG ASSY 10-3/4"~ 3637' MW: 8.8 VIS: 60 RIH W/CORE BBL 96 & CORED F/4026'-4057'. POH. RIH W/CORE BBL,7 & CORED F/ 4057'-4079'. POH. RIH W/CORE BBL ~8 & CORED F/4079~'. DROPPED SURVEY. POOH. BREAKDOWN CORE ASSY & LD. PU 8-1/2" DRILLING ASSY & TIH. DAILY:S45,898 CUM:$601,255 ETD:S632,869 EFC=$1,358,386 DRILLING 10-3/4"@ 3637' MW: 9.4 VIS: 35 FINISHED MU BHA. INSTALLED WEAN RING & CUT DRILL LINE. TIH. REAMED 140' TO BOTTOM. DRILLED 8-1/2" HOLE TO 621i'. DAILY=S59,327 CUM:$660,582 ETD:S660,582 EFC:$'1,390,000 SHORT TRIP 10-3/4"@ 3637' MW: 9.8 VIS: 38....... '. TURBODRILL 8 1/2" HOLE TO 7750'. SHORT TRIP TO CASING SHOE. DAILY:S47,746 CUM:$708,328 ETD:S708,328 EFC:$1,390,000 LOGGING OH 10-3/4"~ 3637' MW:10.1 VIS: 44 CIRCULATE AND CONDITION HOLE FOR LOGS. LOG OH. RUN bIL/SFL/SP/GR F/7750'- 7050', 4450'-3634', FMS F/7700'-7250', 4450'-3850'. RAN BHCS FROM 7700'-7000', 4450' -3800'. RUNNING RFT. DAILY:S44,163 CUM:$752,491 ETD:S752,491 EFC:$1,390,000 POOH LDDP 7"@ 7716' Mw:lo.2 vis: 47 LOGGING OH. RAN RFT. RAN SWC IN COLVILLE. REAM 7400'- 7750'. CIRCULATE HOLE CLEAN. POOH LDDP., DAILY:S151,182 CUM:$903,673 ETD:S903',673 EFC:$1,390,000 The above la correct Signature , ~; IOate For form preparation and dlstrlbutJ~' see Procedures Manual Section Drilling, Pages 86 and 87 ITitle Associate Engineer ARcO Oil and Gas Compa.y Daily We(Il rfistory-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test ia not required upon completion, report completion and representative test data in blocks provided, The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting coat center code District [Sta1 ARCO Alaska, Inc. I County or Parish I NORTH SLOPE Field ILease or Unit Iwe, no. KUPARUK RIVER FIELD I 3H-11 I ~ Title I D+C Auth. or W.O~o~54 8 Operator ARCO Spudded or W.O. begun SPUD Date and depth aa of 8:00 a.m, Old TD Released rig 12/28/87 ( 14] TD: 7750'( SUPV:JP IA.R.Co. W.I. 56.0000 Date 12/15/87 Complete record for each day reported DO¥ON 14 0) Iotal number of wells (active or inactive) on this, DSt center prior to plugging and 1 bandonment of this well our IPrlor status If a W.O. I 0700 RZG RELEASED 7"g 7716' MIf:10.0 VIS: FIN POOH LDDP. RAN 193 JTS. 7" 26" J-55 BTC CASING. CASING SHOE g 7716'. CEMENTED CASING WITH 450 SX 50/50 PUg 12.0 PPG LEAD, FOLLOWED BY 200 SX CLASS 'G' 15.8 PPG TAIL. CZP ~ 2130 HRS 12/27/87. PUMP IN ANNULUS 110 BBLS OF DIESEL FOR FREEZE PROTECTION. RELEASE RIG ~ 0530 HRS 12/28/87. DAILY:S244,847 CUM:$1,148,520 ETD:S1,148,520 EFC:$1,390,000 New TD Date IPB. Depth Kind of rig Classifications (o11, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ... Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature I Date I Title ~, ~/~/.~., __~~, /_/, ~ Associate Engineer For form preparation and dlatrlbufl~ see Procedures Manual, Section 10fur Drilling, Pagea 86 and 87. January 19", 1988 TELECOPY NO: (907) 276-7542 Mr. Jeffery B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Correction of A.P..I, Numbers for Kuparuk River Unit Wells 3H-11, 3H-14, and 3H-20 Dear Mr. Kewin: An error was made in.the assignment by the Commission of A.P.I, numbers for K.R.U. wells 3H-11, 3H-14 and 3H-20. The erroneous · assignments were based, on the bottom hole locations of these wells. .They should have been based o.n the surface locations.' Accordingly, the A.P.I, numbers for these wells have been corrected by the Commission as follows:. KRU 'Permit No. 8'7-1.24) API number erroneously assigned as 02 1 has been corrected to~ KRU 3H-14 (Permit No. 87-123) API Number erroneously assigned as 029-21770 has been corrected to 103-20092. KRU 3H-20 (Permit No. 87-134) API Number erroneously assigned as 029-21775 has been corrected to. 103-20093. ' Petroleum Information has been notified and the Tuesday report of the Co~ission Will list the corrections. For your reference, I. am enclosing corrected copies of the Commission's permits to drill. (10-401) for these wells. Accordingly, please correct your records, Please telephone me at (907) 279-1433 if you need further infor- mation. Sincere., . W; W. Barnwell Commissioner Attachment ARCO Alaska. Inc.( ~'' Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DaCe: January 11, 1988 Transm±==al # 7059 P~TURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorase, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-9 H~D Formation Evaluation Log 11-21-87 3534-73&0 WesClog. 12-15-87 115-4085 Receipt Acknowledged: DISTRIBUTION:. NSK Drilling Franzen D & M State of Alaska(+sepia) Lucille Johnston Joann Gruber ARCO Alaska, Inc, is a Subslcliary of AtlantlcRichflelclCompany ARCO Alaska, Inc.( Post Office Box 100360 Anchorage. Alaska ~)9510-0360 Telephone 907 276 1215 Date: January 11, 1988 Transmittal ~ 7057 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items, Please acknowledge receipt and return one signed copy of this transmittal. ~3H-12 5" Dual Induction 1-2-88 3104-7286 .~'"~3H-12 2" & 5" Porosity FDC 1-2~88 6580-7260 3H-12 2" Dual Induction 1-2-88 3104-7286 ? ~3H-12_ 2" & 5" Raw Data FDC 1-2-88 6580-7260 '-~'~3H-13 2" & 5" Raw Data FDC 1-7-88 6700-7334 "~"-~3H-13 2" Dual Induction 1-7-88 1000-7360 ~ '~3H-13 5" Dual Induction 1-7-88 1000-7360 "~ '~3H-13 Cyberlook 1-8-88 6800-7200 '~- ~ 3H-13 2" & 5" Porosity FDC 1-7-88 6700-7334 '~ ~-_-~t~l.. Formation Hicro Scanner 1-8-88 6800-7214 --~ -~3H-10 2" & 5" G-~ma Ray In Casing 12-5~87 967-3021 ~ "~ Cyberlook 12-25-87 7050-7600 '~ "~ Formation Hicro Scanner 12-25-87 7250-7724 · '~ -~t 2" & 5" Raw Data FDC 12-25-87 7050-7716 "~ "~ 2" i 5" Porosity FDC 12-25-87. 7050-7716 ~ ~ 5" Dual Induction 12-25-87 3633-7742 ~'-~ 2" Dual Induc~ion 12-25-87 3633-7742 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M .,' State of Alaska(+sepia) Lucille Johnston ARCO Almskih Inc. is a Subsidiary of AtlanllcRlchfleldComRany Date: ARCO Alaska, Inc..... Post Offic~ 100360 Anchorage~ ~.,,..,ska 99510-0360 Telephone 907 276 1215 January 6, 1988 Transmittal # 7055 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AX 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Colville 2" &',..5"'Borehole Compensated Sonic Log Colville Repeat Formation Tester COlville Chronological Sample Taker Colville Formation Micro Scanner Colville 2" & 5" Porosity FDC Colville 2" & 5" Raw Data.FDC Colville 2" & 5" Dual Induction Colville ltWD Camma Ray and Resistivity 12-25-87 3633-7742 12-26-87 3954-4290 12-26-87 12-25-87 3850-4464 12-25-87 3633-4450 12-25-87 3633-4450 12-25-87 3633-4450 12-15-25-87 115-7750 Receipt Acknowledged: DISTRIBUTION: · NSK Drilling Geology SAPC(+sepia) Unocal(+sepia) D & M Plano West Sak(+sepia) State of Alaska(+sepia) Vault(film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. '- Pos! Office Box 100360 Anchorage, Alaska 9~)510-0360 Telephone 907 276 1215 Date: December 24, 1987 Transmittal ~ 7044 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, Ali 99510-0360 Transmitted herewith are the following items, Please acknowledge receipt and return one signed copy of this transmittal. 3H-14 2" & 5" Porosity FDC 12-13-87 7550-8215 3H-14 5" Dual Induction 12-13-87 1000-8215 3H-14 2" & 5" Raw Data FDC 12-13-87 7550-8215 3H-14 2" Dual Induction 12-13-87 1000-8241 3H-11' West Sak 5" Dual Induction 12-18-87 3650-3656 3H-.lI .... West Sak 2" & 5" Raw Data FDC 12-18-87 3636-3656 3H-l}' West Sak 2" Dual Induction 12-18-87 3650-3656 3H-1t"' West. Sal 2" & 5" Porosity FDC 12-18-87 3636-3656 '%. Receipt Acknowledged: DISTRIBUTION: · NSK Franzen Drilling D & M Lucille Johnston(vendor package) ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfleldCompany December 4, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3H- 11 ARCO Alaska, Inc. Permit No. 87-124 Sur. Loc. 1232'FNL, 281'FWL, Sec. 12, T12N, RSE, UM. Btmhole Loc. 1325'FNL, ll02'FEL, Sec. 12, T12N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling .field work, please notify this office 24 hours prior to co~mmencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf. Enclosure cc: :Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ' STATE OF ALASKA ".. ALASKa.' .'IL AND GAS CONSERVATION (~ ,vlMISSION PERMIT TO DRILL 20 AAC 25.005 .'. la. Type of work Drill ~ Redrill F'II lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oi1"3~ Re-Entry [] Deepen,~11 Service [] Developement Gas [] Single Zone .~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Aiaska~ Inc, RKB 76' PAD 39' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Poo P,O, Box 100360 Anchorage~ AK 99510-0360 ADL 25531~'"ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see2OAAC 25.025) 1232'FNLs 281'FWLs Sec.12~ T12N, R8E~ UM Kuparuk River Unit Stal;ewide At top of productive interval ~/,~ m'o.¢'l~c{"~) 8.~rpber Number 1320'FNL, 1320'FEL, Sec.12~ T12N, R8E, UN 3H-11.... #8088-26-27 At total depth "~J. Approximate spud date Amount 1325'FNL, 1102'FEL, Sec.12~ T12N~ R8E, UM 12/15/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15~ Proposed depth (MD and mVD) property line 3H-10 658 'MD 1102'~ TD feet 90' ~ Surface feet 2560 (6/~/~3'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~00 feet Maximum hole angle 360 Maximum surface I 8~1~ psig At total depth ('rVD) .~lOb pslg 18. Casing programl Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~" 16" 62.5~ H-z~O Weld 80' 35' 35' 115' 115' +200 cf 13-1/2 10-3/~ ' z~5.5,~ J-55, BTC 3515' 35' 35' 3550' 3106' 1200 sx AS III & HF-E{W /~00 sx Class G blend 8-1/2" 7" 26.0~I J-55 BTC 762u,' 3~' 3/~' 7658' 6/~/~3' 200 sx Class C(minimur HF-E{W T0C 500' abcve top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVEI) Surface Intermediate D~C 0 ~!:~ ],~87 Production Liner Alaska 0il & Gas Cons. C0mmissl0. Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~ Diverter Sketch [] Drilling program Drilling fluid p[,,~a~ I~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby ~te'rtifyhat the f~oinftrue an, d correct to the best of my knowledge Rag,one1 Drill lng /,~,/~.~.. Signed .~.,,~.~ ~__.~ ~ Title ' ' ' Engi near Date j ~ u / Commission Use Only (AWN) PD2/60 / / ~" I I?0t~ I See cover letter Permit Number / APl number IO~; 'ZoOql Approya~ /87 E~'/- J ~-./-/ 50-- ~2-~"~; ~'7'~'j. for other requirements Conditions of approval Samples required [] Yes [];P'Ro Mud log required [] Yes I~No Hydrogen sulfide measures [] Yes [~.-tq'o Directional survey required E3'~es [] No Required working pressure for BO_PE []2M; ~.3M; [] 5M; [] 10M; [] 15M Other: /~'~r~//~~~ by order of ,__Ap_pr~o..ve.d...by.. ~,~,'~ ..~/. L ;?~/~../~~1 Commissioner the commission Date . Form 10-401 Rev. 12-1-85 Submit ' ) triplicate ^~co '^L^S'~,~'.' ~C. (' Pa(! 3H, 14ell No* 11 Proposed KupBruk Field, North Slope, Alaeke 1000 _ 2000 _ .... 3000 = ..4000 _ .. 5000_ 6000 _ ... ?000.. KOP TVD"400 THD'400 DEP'O ' 3 ' g BUILD 3 DEe 15 PER lO0 FT .. ., 21 · 1 EOC TVD-1514 THD-158g ;OEP-358 al/ PERHAFROST TVD-lSgl THO-1684 DEP-414 .... T/ .UONU SND.$ .... T.VD-19?6 TttD-21.58"DEP-OgO ....... ~ ...................................................................... . ' T/ 14 SAK SNDS "TVD'25g1 TtlD'2915 DEP'1132 ', K-12 TVD-2g06 THD,,3303 DEP-1358 10 3/4" C80 'PiT ' TYD'3106 THD-354g'. DEP-1 $02" : ....................... COLVILLE TVD-3156 THD.3611 DEP-1538 AVERAGE ANGLE 35 'DEG 41 MIN K-5 TVD-4471 THD-5230 OEP-2482 ..... : ............~' ....... ~,,as~',~'i, ' 0ii E G~.s Co~S.-commissio~ T/ ZOnE D T~D-S986 T~D-~O95 DEP~569 , '/ ZONE C TVD-~998 T~D-~110 DE'P-~578 '~T/ ZONE A ~TVD-6120 T~D-7260 DEP-~666 TARGET CNTR TVD-6140 T~D-~284 DEP-~68( B/ KUP SHDS TVD-6281 T~D-7458 DEP-~81 :TD (LOG PT) TVD-644~ T~D-~658 DEP-~89~ ? . ~ooo ~ooo=, *ooo.~ .. ~ooo, ~ . ~' VERTICALSECTION .............................. t ........................................ i .............................................................. ! ...................................... ; ................................................................ i ........... i ............. , ~ ....... : .... k ........... I I ...... I ~ SURFAOE LOOAT~OII ~ ~ 1232' iFNL. 281' : 2000 1000..- 1000 - 2000 . HORIZONTAL _ PROJECT I ON SCALE ! IN. "' 1000 FEET i ARCO kc~s~. ~C. Ped 3H, Well No' 11 Propoeed. Kuperuk Field, No~h Slope, Aleeke 1 000 . O' WEST-EAST 1000 I , 2000 i, j . i = S 88 3680' ~000 DEG 38 MI N E (TO TARGET) 4000 i. TVl)-6140 ~OUTH ~ EA~? 38~g 1320' FILL. 13a0' FEL~ · _.SEQ. I~, .Tt211,. RSE. TD LOOA~TIOll, 1325' FILL. 1102' FEL eEO. 12. T12N. flSE ~50 1000 1050 1100 1150_ 1200. 150 , ! , 350 400 _ 950 ~ !O' -' "69~ 791" '"ag'4-"990- '1'08q: - 1250 . .o ............. 1251 i.I 13;50 ......... ,~oo.]..~..~_~~ ~: ~~ .~oo~., ........ !~ ...... ~.~- ......... ~ ......... ~ ................... ,....~o~ 2O0 250 3;OO 45O I (1' i I I~-;"1 I 646 ........................................ 4 474 820 ........... //' ? 9 0 ... I 291 : /",sg, ' I ~. m ' m l OS/,~s.r :... . I //1499 ' 1 50 200 250 3;00 350 400 450 . 1 05' . 1101 . 115t · I . 1 20~ I 3H-11 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) Move in rig. 2) Install Tankco diverter system. 3) Drill 13-1/2" hole to 10-3/4" surface casing point according to directional plan. 4) Run open hole logs. 5) Run and cement 10-3/4" casing. 6) Install and test blowout preventer. Test casing to 2000 psig. 7) Drilling out cement and 10' new hole. Perform leak off test. 8) Drill 9-7/8" hole to Colville core point according to directional plan. 9) Core Colville with water base polymer mud. 10) Drill 8-1/2" hole to logging point according to directional plan. 11) Run open hole logs. 12) Continue drilling 8-1/2" hole to provide 100' between plug back total depth and bottom of Kuparuk Sands. 13) Run and cement 7" casing. Pressure test to 3500 psig. 14) Downsqueeze Arctic pack and cement in 7" x 9-5/8" annulus. 15) Nipple down blowout preventer and install temporary Xmas tree. 16) Secure well and release rig. ~'~'~IV~, 17) Run cased hole logs. DE'(] 0~~,,~Q,q~7,,.,~ 18) Move in workover rig. Nipple up blowout preventer~ .llf.~sk.~Oil&Sas¢o.s. oornrnis. 19) Pick up 7" casing scraper and tubing, trip in hol to plug baA~h°~lO~al depth. Circulate hole with clean brine and trip out of hole standing tubing back. 20) Perforate and run completion assembly, set and test packer. 3H-11 GENERAL DRILLING PROCEDURE (cont'd) 21) Nipple down blowout preventer and install Xmas tree, 22) Change over to diesel, 23) Flow well to tanks, Shut-in, 24) Secure well and release rig, 25) Fracture stimulate, PD2/60a 11/23/87 RE,CEIVEi) DEC Alaska Oil & Gas Oons. Oommission Allchorcqqe (" ( Density DRILLING FLUID PROGRAH Spud to Drill out JO~.~." Surface Casing to Weight Up 9.6-9.8 ~.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-~5 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate APl 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 Solids 10~ 4-7 9-12 Drilling Fluid system - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit'Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance wich the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated usin$ a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pi~ will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during an'.' extended shutdown in disposal operations. The annulus will 5~ sealed with 175 sx of cement followed by arctic pack upc:: completion of the fluid disposal. L~CS/ih KUPARUK RIVER UNIT :20* DIVERTER SCHEHATIC DESCRIPTION 6 4 I. 16' CONDUCTCll 2. Fl'lC SLIP-0N ~iTLD STkATINO HEA0 3. Fl'lC DIVERTTA A~8"IKY WITN T~O 2-II16' 2000 PSI ~ALL VALVI~ 4. 20' 2000 PSi ~ ~ W/10' ~U~.ETS S. 10' I,C~ 8NJ. VALVESV/10' DWERTER LINES, A SINeLE VALVE ~ AUT0rI~TICALLY UPON CL0SU~ OF ~ I~I~iN~II. VALVES CA~ RE~)~Y CON~ 1'0 AC~LrvE ~1~1) DIVEI~ION. 6. 20" 2000 I~1 ~ I~ ~: AKO ALA~, INC., I~alJESI'~ ~AL OF THIS DIVEI~F~ SY~TB'I AS A VARIANCE FR0t'~ 20AAC25.03~) NAINTENANCE & OPERATION il 2 il . . UPON INITIAL INSTALLATION, CLO~E PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUG. 0~vERTER LINES EVERY 12 HOURS, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WI[LLBORE FLUIDS OR GAS IS DETECTED. OPEN APPR0~RIATE VALVE TO ACHIEVE DOVkff~lN0 DIVERSION. DO NOT SHUT IN WELL -- UNDER ANY C I RCUPISTANCES -- c~.~ C ,'~ .... -. <.., ~ ,~;:.,..;7 ., J6 I I-3-86 II I 6 ACOMJ~TM c~p~Z'l~, 4. ;Ea::IK) :_ __nE!KIT. TI. Il 5 4 vN.v~ ~D O(1(~ aNOLLD BE ~ 4. PRESSLRE LP TO 2~Ol=~Z N~I, KI.DFCR 10MZN. :'~ aqF. A~ ~ TO ~ I~Z MD I.I].D FCIt [0 Mz~ BLE~ ~ T0 0 I~Z. I fl I I Il IIlllt I __ · I S I 0(3840C MAY ~.. II ]12. I · ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. II o ,Y SCALE I NOTES "1. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19,35-441L-~7-11, ~9-32. S. 0.6. ELEVATIONS FROM CED-RIXX- 3471~ 6. HORIZONTA~ POSITION BASEDON 3H CONTROL !&E ASPs 'X' 6,000,110.73 498,655.44 6,000,135. $ I 498,655.43 6,000,160.57 498,655.$9 6,000,185.28 498,655.43 6,000,210.66 498,655.47 000,235.50 498,655.40 000,260.34 498,655.41 6,000,285.82 498,655.44 6,000,310.30 498,655.45 6,000,335.43 496,655.44 6,000,425.37 498,655.44 6,000,450.51 498,655.38 6,000,475.46 498,655.42 6,000, 500.41 4 98,655.43 6,000, 525.44 498,655.41 6,000,550.46 496,655.47 6,000,575.45 498,655.55 498,655.59 6,000,650.45 6,000,675.40 6,000,700A2 498,655.49 498,655.63 49 8,655.73 LATITUDE TOO 24'41.551*' 70° 24'41. 775" ?oo;4.,'4;.02;'', 7o° 24_: 42 70°24 42.514' 7'0 24,42.738. 70° 24 43.003 700 z< 70° 24,43.494, 70°24 4:3.741' 70°24'44.626' 70o24'44.873" 7CP24'45.119" LONGITUDE 150° oo' 39.416" 150000' 39.417' 150° oo~ 39.418" 150°00,39.417:: 150° O0 39.416 150° o_o'. 150° O0 ~g.41~' 150° 00' 39.417" 150° 00', 39.417" 150°00 39.417" 150000, 39.418' 150o 00'39.421~' 150° 00'39.419" 70 24 45.610 ?0o24'45.856" ?0°24'46.102" 70°24' 46.348' 70024'4.6.840" 70e24 '47.085" 70o24'47. 351" 150° O0 39.41~ 150000' 39.417" 1 50°00'3g.415" I SOOO0' 3g.414'' 150o00'39.418''' 15 0°00' :59.41 ~' 150000'39.410" I HEREBY CERTIFY THAT I REGISTERED ANDLICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTSA LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. AM PRO PERLY RFV /~ AI~ CONr). 20.21.22. 7-30-87 I~sf EN.L. I ~a~ka Oil 522', 49 7, 472, 446 1422', 1397 1322 1232' 1207' 1182' 1157~ 1132, 1107 1082" 1057' Dist F..W.L. ga~C'ons. Co, Armk~rage 281, 281, 281~ 28l* 281: 281 . 281' 281' 2 81' ,e,', 281' 282' 282' ' O.G. Elev. amMi~'. 34.0' 33.9', 33.0, 33.T 33,?', 33.6 · 33.6; 33.6, :53.6 33.7' 33.6' 33.0' 33.6', 33.8 33.8' 33.8' 33.8' Pod Elev. 38.8' 38.8' 38.7' 38.8' 3e.e', 38.9 36.7', 36.6, 38.6 38.7' 38.6' 38.8' 38.7; 38.7 38.7' 38.8' 38.9' 1007' 282' 33.9' 38.7' 982' P82' 33.9' 38.6' 957' 282' 33.9' 38.6' ARCO Alaska Inc. ' KUIMRUK PliOJECY D.S. 3 H. WELL CONDUCTOR AS-BUILT PR~'PARED ~Y ' LOUNSBURY Associoles ANCHORAGE ALASKA DWN BY: PJW I CHi BY: JWT I · _ _ naTr: A/g /87 NSK 6.$08-d5 (2~ (2 r.~-~. 8) (10 mini 13) . (6) v- (2.9 U:=u 31) . 'ray: 01/2..8/87 '""--6.011 -..~. La~e & We!I No. 1. I~ fha p~u faa au.ached Z. ~~ ~obe lo~ued~a ~d~l ... ' e a ~ff~ R ~ ............ 7 ~ ~ ~y ~~u d ~ --" · ~~ a p~ ....... .., 8 ~~ub ~~db~cr ~~-~ .......................... ~ ~ ~~~ ~~ ~~ .................................. 14 ~ ~~~ s~ ~~d ' " e . ' ~h ~= z~ .......... 16. ~ ~ c~= ~ad ~ ~~=a ~ ~~r =d ~~a ......... ~. ~ old ~~ ~~~ ~ca~a ~~d ~ 10-403 ............ · i ~9°{cO! ~c- 'o(~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History'file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. SCHLUMBERGER STRATZGRAPHIC HIGH RESOLUTION DIPMETER MSD COMPUTATIONS COMPANY :' ARCO ALASKA, INCo gELL : 3H-11 CCOLVILLE) FIELD : KUPARUK COUNTRY : U.SoA. RUN : TWO DATE LOGGED : 25 - DEC - 87 REFERENCE : 72555 MAGNETIC DECLINATION 31 DEGREES 4' X 2' X 30 MSD LISTING OF MAIN PASS FILE RECEIVED FEB -' Alaska Oil & Gas Cons. Commission,' Anchorage ARCO ALASKA, TNC. 3H-1! (COLVILLE) PAGE 1-FILE Z DEPTH DIP DIP DEV DEV DZAM OI{M Q ~ AZM AZH Z-3 2-4 ~ 3852.61 6.7 72 3854.61 8°0 36 3856.61 4.9 77 3858..61 3.1 41 3860.61 2.2 15 3862.60 14.3 7 3864.60 15.9 191 3866.60 2.6 124 3868.60 8.9 164 3870.60 8.8 129 3872.60 12.2 221 3874.60 10.2 23 3876.60 13.6 27 3878.60 13.3 168 3880.60 4.$ .86 3882.60 4.2 157 3884.60 13.8 262 3886.60 9.4 257 3988.60 5.7 0 3890.60 6.3 12 3892.60 11.2 1~ 3894.60 8.3 181 3896.60 10.9 22 3898°60 10.0 138 3900.60 17.¢ 186 3902.60 21.2 47 3'904,59 10.2 1.48 3 90..6.59 9.0 162 3908.59 10.5 160 3910,59 17.0 236 3912.59 2.1 182 3914.59 5.0 340 3916.59 .13.0 203 3918.59 18.0 18 3920.59 5.1 126 3922.59 1.6 86 3924.59 4.2 76 3926'.59 14.1 246 3928.59 32.0 344 3930.59 9.4 18 44.6 101 9.6 12.2 44.6 100 9.3 12.2 44.6 100 9.6 12.5 44.6 100 9.4 12.5 44.5 100 10.0 12.8 44.5 I00 10.0 12.8 44.5 100 10.0 12.8 44.4 100 lO.l 12.7 44.4 100 9.8 12.7 44.5 100 9.9 12.6 44.5 100 9.7 12.8 44.5 101 9.9 12.7 44.5 101 10.0 12.8 44.5 101 9.8 12.8 44.5 101 10.4 12.7 44.5 101 10.1 12.8 44.5 101 10.1 12.8 44.5 101 10.2 12.6 44.4 101 9.9 12.4 44.4 101 9.7 12.5 44.4 101 10.0 12.6 44.4 100 9.9 12.9 44.4 100 9.7 13.1 44.4 100 9.6 12.9 44.4 100 9.6 13.2 44.4 100 9.4 13.1 44.4 100 9.6 13.4 44.4 100 9,4 13.4 44.'4 100 9.7 13.6 44.4 100 9.8 13.4 44. m4 I 00 9.7 13.4 44.4 100 9.8 13.1 44.4 100, 9.6 13.3 44.4 100 9.7 13.2 44.4 100 9.6 13.4 4,~.4 100 9.8 13.3 44.4 100 9.8 13.0 44.4 100 9.6 13.3 4,4.3 100 10,0 13.0 B ~ A , B , B ~ B ~ D , O , C ~ 0 ~ O ~ C , D ~ D , D :~ O , D , A ~ C , D ~ C , O ~' D ~ C , 0 , C , O , A :~ O , C , 44.3 100 9.3 13.2 ARCO ALASKAt ZNC. 3H-11 CCOLVZLLE) PAGE 2-FZLE 2 DEPTH DIP DZP DEV DEV OIAM DIAM Q ~ AZM AZM 1-3 2-4 ~ 3932.59 24.7 42 44.3 101 9.7 13.2 3934.59 NO CDRR 44.3 101 9°5 13.! 3936.59 7.7 312 44.3 101 9.7 13.0 3938.59 18.8 232 44.3 101 9.2 12.8 3940.59 10.7 328 44.2 101 10.0 12.8 3942.59 13.8 320 44.2 10! 9.2 12.6 3944.58 19.0 282 44.2 lO0 9.8 12.8 3946.58 22.4 193 44.2 100 9.6 12.7 3948.58 4.8 70 44.1 100 9.3 12.6 3950.58 4.2 98 44.1 100 9.1 12.5 3952.58 11.3 16 44.1 100 8.8 12.5 3954.58 14.9 52 44.0 100 8.9 12.7 3956.58 15.4 25 4~.0 100 9.0 12.9 3958.58 19.2 28 44.0 100 9.2 12.8 3960.58 14.7 117 43.9 100 9.1 12.6 396Z.58 10.8 81 43.8 100 9.2 12.2 3964.58 12.3 75 43.8 100 9.0 12.1 3966.58 3.Z 171 43.7 100 9.1 11.9 3968.58 9.3 79 43.7 100 9.0 11.9 3970.58 11.8 62 43.8 100 9.2 11.8 3972.58 13.1 73 43.8 100 9.3 11.7 3974.58 8.0 88 43.9 100 9.5 11.5 3976.58 10.7 106 43.9 100 9-7 11.4 3978.58 12.8 64 43.8 100 9.5 11.3 3980.58 12.8 54 43.8 100 9.8 11.4 3982.58 10.3 79 43.7 100 9.2 11.8 3984.5'8 10.9 97 43.8 100 9.7 11.7 3986.57 12.3 97 43.7 100 9.4 12.1 3988.57 15.6 101 43.7 100 9°6 11.9 3990.57 14.1 105 43.6 100 10.0 11.7 3992.57 16.3 &2 43.6 100 9.9 11.7 3994.57 15.6 3996.57 13.9 3998.57 17.5 4000.57 13.7 4002.57 10.3 '4004.57 17.3 4006.57 16.7 4008.5T 15.7 52 43.6 101 9.9 11.5 75 43.7 101 9.8 10.9 75 43.8 101 9.7 11.4 73 43.8 lOl' 9.6 11.1 65 43.8 lO1 9.7 11.4 52 43.9 101 9.6 11.7 76 43.9 101 9.3 11.7 95 43.9 101 9.3 11,7 D O O C A C C B C O D C C D C O C C C B B A C .* 4010.57 14.0 322 43.9 101 8.8. 12.4 D , ARCO ALASKA, INC. 3H-Z1 CCOLVILLE) PAGE 3-FTLE 2 -,, DEPTH DIP DIP DEV DEV DIAM OIAM Q ~ · AZ~ aZM 1-3 2-4 ~ 4012.57 17. g 76 44.0 101 8.9 12.4 4014.57 4.7 273 44.1 100 8.6 12.5 401&. 57 7.0 349 44. 2 100 B . 5 14 . 1 401B.57 NO CORR 44.4 100 8.9 14.3 4020.57 7.5 75 44.7 100 8.8 16.3 4022.57 NO CaRR 44.B 100 10.5 16.3 4024.57 15.1 220 44.7 101 9.B 1.5.5 4026.56 11.1 47 44.5 100 10.3 15.9 4028.56 13.0 SO 44.4 100 10.9 13.4 4030.56 1B.9 B6 44.3 101 10.0 14.5 4032.56 13.3 72 44.1 101 11.0 12.6 4034.56 10.5 48 44.1 101 10.4 14.3 4036.56 60.B 315 44.1 101 10.3 13.0 4038.56 14.5 .iO 44.2 101 9.8 13.9 4040.56 5.3 3 44.2 101 10.5 15.6 4042.56 38.0 317 44.3 101 9.7 12.3 4044.56 4.9 9 44.2 101 10.1 14.2 4046.56 9.2 67 44.1 100 9.4 11.8 4048.56 9.6 79 44.1 100 9.3 11.4 4050.56 8.2 86 44.1 100 9.3 11.6 4052.56 9.9 195 44.1 101 9.2 11.5 405'4.56 10.0 60 44.1 101 9.2 11.9 4056.56 7.9 75 44.1 101 9.3 11.6 4058°56 27.1 227 44.1 101 9.5 11.7 4060.56 32.5 251 46.0 101 9.4 11.7 4062.56 2,?..2 255 43.9 101 9.4 11.6 4064.56 B.9 71 43.8 101 9.4 11.7 4066.56 B.6 71 43.B 101 9.3 11.5 4068.55 10.5 351 43.8 101 9.4. 11.4 4070°55 11.2 87 43.8 10.1 9.3 11.3 4072.55 9.0 102 43.9 101 9.2 11.4 4076.55 8.5 45 43.9 102 9.3 11.4 4076.55 7..g 56 43.9 102 9.2 11.5: 4078.55 7.1 79 63.9 102 9.3 11.3 40B0.55 '9.1 80 43,9 102 9.3 11.4 4082.55 6.3 78 43.B 102 9.1 10.5 408,4,,55 6.4 62 4;3.6 101 9,,.2 10.8 4086, 55 404 94 43.5 101 B.9 1.0.0 4088.55" 5.0 73 43.4 101 8.9' 10.2 4090.55 4.9 71 4.3.6 101 9.0 10.2 ARCO ALASKA, INC. 3H-11 CCOLVILLE) PAGE 4-FILE Z DEPTH DIP DIP DEV DEV DIAM OIAM Q , AZM AZM 1-3 2-4 ~ 4092.55 7.1 59 43.4 101 8.8 10.2 4094.55 6.5 59 43.4 101 9.0 10.2 4096.55 6.6 52 43.4 107. 8.9 10o1 4098.55 6.4 41 43.5 102 8.9 10.0 4100.55 6.3 40 43.5 102 9.0 9.9 4102.55 7.4 48 43.5 102 8.8 9.8 4104.55 7.2: 51 43.5 102 8.8 9.7 4106.55 7.0 51 43.5 101 8.8 9.7 4108.54 7.6 47 43.5 101 8.9 9.7 4110.54 8.¢ 49 4:3.5 101 8.9 4112,54 7.6 52 43.5 101 8.9 9.7 4114.54 6 2 60 43.5 101 8 8 9 9 4116.54 7.7 54 43.4 101 8.8 9.9 4118.54 8.7 50 43 4 101 8 8 10 0 4120.54 7.5 54 43.3 101 8°8 10.0 4122.5¢ 8.4 47 43.3 101 8.8 9.9 4124.54 7.4 47 43.3 101 8.8 9.9 4126.54 7.6 51 4'3.3 101 8.8 4128.54 8·1 52 43.3 101 8.8 10.0 4130.54 8.7 59 43.3 101 8·8 9.8 4132.54 8.5 54 43.4 101 8·8 9.9 4134.54 8.7 58 43.4 102 8.8 9.9 4136.54 7.5 74 43·4 101 8·8 9.9 4138.54 10.6 52 43.4 101 8.8 9.8 4140,,.54 7.9 47 43.4 101 8°8 9,9 4147..54 7.8 40 43.4 101 8·8 9.9 4144.54 8.3 57 43.4 101 8.9 9.9 414,6.54 8.5 58 43.4 101 8.9 9.9 4148.54 8.5 55 43.4 101 8.9 10.0 4150.5'3 8.5 106 43.4 101 8.8 4152.5'3 3.6 87 43.4 101 8.9 9.9 4154.53 3°9 86'43.3 101 8.7 9.7 4156.5'3 ' 3.4 93 43.3 101 8·8 ~158.53 3.3 97 43.3 101 8.8 9.9 4160.. 53 4.2 55 43.3 101 8.8 9.9 41'62.53 4.5 48 43.3 101 8.8 9.9 .4164o 53 4.1 63 43.3 101 8.8 9.9 4166.53 4.1 61 43.2 '101 8.8 9.9 4168.5'3 4.7 45 43·2 101 8.7 10.0 , 4170.53 . 5.2 57 43.2 101 8.'7 10.0 A , "~:~ ~::0:'4::~ ~ .~:0: ~:~ ~, ~ ~:~ ~0: ~::0: ~:~ ~ :~ :O:& ~::0: ~:~: · ~ ~ ~:~ :0:~ 0:~.:0::~.~:~ ~'::O:~ ~: · ~ ~ ~:,*,, ~: 0~: 0:~ ~, :~ ~: 4172.53 4174.53 6.9 4176.53 4178.53 4.7 4180.53 5°2 4182.53 5.1 4184.53 4186.53 10.6 4188.53 10.4 4190.52 5.7 4192.52 4.8 4194.52 8.7 4,196.52 7.9 4198.52 7.2 4200.52 8.2 4202.52 10.7 4,204,. 52 10.8 4206.52 7.4 4208.52 11.5 4210.52 10.6 4212.52 9.8 4,214.52 8ol 4216.'52 9.0 4,218.51 9.9 4220.52 9.4 4222.52 6.1 4224.52 6°5 4226.52 6.1 4228.52' 8.4 4230.52' 16.9 4232.51 16.9 4234.'51 8.3 4236,,51 12.5 4238.51 13.2 4,240,. 51 424,2.51 11.9 4244.51 10.1 4246.51 8.9 4248,.51 6.2 4250.51 6.5 ARCO ALASKAt INC. 3H-11 CCOLVILLE) PAGE 5-FILE Z DEPTH DIP DIP DEV DEV OTAM OI AM AZM AZM 1-3 2-4, 6 9 64 43 2 101 8.7 10.3 A 4,3.2 101 8-6 10.4 A 55 60 43.2 101 8.7 10.5 80 43.1 101 8.7 10.5 101 43.1 101 8.7 11.0 78 43.1 101 8.8 10.6 51 4,3.0 101 8.7 11.1 62 43.0 101 8.8 10.7 61 4,2.9 101 8.7 10.8 73 42.9 101 8°7 10.7 70 42.9 101 8.6 10.8 94 42.9 100 8.7 10.8 106 42.8 100 8.6 10.9 121 42.8 100 8.7 11.0 113 42.7 100 8.8 11.0 124 42.7 100 8.8 11.2 88 42.6 100 8.8 11.2 86 42.,6' 100 8.8 11.3 ~,6 &2.6 lO0 8.8 11.3 113 42.6 99 8.8 11.4 104 42.5 99 8.8 11.4 98 42.5 99 8.8 11.4 101 4,2.5 99 8.8 11.4 97 42.5 9'9 8.8 11.4 83 4,2.4 99 8.8 11.4 94, 42.4 99 8.8 11.4 115 42.4 99 8.8 11.3 107 42.4, 99 8.8 11.3 99 42.4 99 8.8 11.3 111 42.3 99 8.8 11.3 113 42.3 99 8,,8 11.2 125 42.3 98 8.8 11.2 15'9 42.3 98 8.9 11.1 143 42.3 98 8.9 11.0 142 42.2 98 8.9 11.0 124 42.2 98 9.0 10.9 153 42.2 98 9.1 10.8 138 42,.2 98 9.0 10.7 101 42.2 98 9.0 10.7 A A A A "4: A A A A A A A A .,. A O D O C C A C A A O ,,,. A B B A O O C ¢ A -,. A A A 93 42.2 98 8.9 10.7 A , ARCO ALASKA~ INC. ~* DEPTH DIP DIP OEV O -,- AZM A 4252.51 7.7 108 42.2 42.54.51 9.6 112 42.2 4256.51 :3.5 86 42.2 4258.51 3.4 ~7 42.3 4260.51 2.1 126 42.3 4262.51 1.8 214 42.3 4264.51 3.0 290 42.3 4266.51 16.T 110 4Z.3 4268.51 16,2 66 42.2 4270.51 16.4 51 4Z.2 4272.50 16.1 272 42.1 4274.50 19.6 262 42.0 4276.50 6.~, 105 41.9 4278.50 11.5 27 41.9 4280.'50 37.6 185 41.8 4282.50 8.1 75 41.7 4284.50 7.7 88 41.7 4286.50 7.0 109 41.7 4288.50 10.2 97 41.7 4290.'50 10.1 76 41.7 4292.50 20.7 47 41.7 4294.50 19.B 51 41.7 4296.50 20.4 50 41.6 4298.50 1~.7 58 41.6 .4300.50 '13.0 119 41.6 4302.50 23.6 59 41.6 4304.50 17.1 310 41.6 4306'50 20.1 301 41.7 4308.50 34.0 298 41.7 4310.50 3.4 251 41.6 4312.50 12.9 143 41.5 4314.49 9.1 95 41.5 4316..49 8.3 83 41.5 4318.49 6.2 66 41.4 4320.49 4.3 54 41.5 4322.49 5.3 59 41.5 4324.49 6.2 30 41.3 4326.49 6.7 35 41.2 4328.49 8.1 25 41.1 3H-11 CCOLVILLE) PAGE 6-FZLE 2 TV OIAM DI,~M O , ZM 1-3 2-6 , 98 9.0 10 98 9.0 10 98 9.1 10 98 9.1 10 98 9.1 10 98 9.3 10 97 9.2 10 97 9.3 10 97 9.2 10 97 9.5 10 97 9.5 11 97 9.5 11 97 9.6 11 97 9.4 10 97 9.7 97 9.1 96 9.6 96 9.3 96 9.6 96 10.4 96 9.5 96 10.3 96 9.2 96 9.6 96 9.5 96 9.7 96 12.0 96 11.5 96 11.8 96 11.3 96 9.1 96 9.0 96 8.8 9'6 8.7 96 8.8 96 8.6 96 8.8 96 8.6 96 8°7 .7 .7 .6 .5 .4 o4 .4 .5 .7 .0 .2 -5 .6 10.5 9.8 9.9 9.9 10.0 10.3 10.0 10.3 10.0. 10.1 10.0 10.6 12.5 12.4 13.0 11.7 9.7 10.1 9.5. 10.5 10.5 10.3 10.6 43.30.49 3.4 16 41.0 96 8.7 10.7 A -'- ARCO ALASKA, INC. 3H-11 (COLVILLE) PAGE 7-FILE 2 DEPTH DZP DIP DEV DEV DIAM DIAM Q , ~ZM AZM 1-3 2-4 ~ 4332.49 2. 4334.49 3. 4336.49 4338.49 4340.49 43&2.49 6. 434~.49 7. 4346.49 6. 4348.49 4350.49 4352.49 4354.48 4356.48 3. 4358.48 4360.48 4362.48 4364.48 436&.48 4368.48 4370.48 4372.48 7. 4374.48 .4376.48 5. 4378.48 5. 4380.48 4382.48 6. 4386.48 4388.48 3. 4390.48 3. 4392.&8 3. 4394.48 4396.47 3. 4398°47 3. 4400.47 3. 4402.47 7. 4404.47 3. 4406.47 4408.47 4 12 40.9 96 8.6 10.7 A 2 17 40.9 96 8.T 10.8 A I 33 40.9 96 8.8 10.8 A Z 46 40.8 96 8.7 10.8 A I 50 40.8 96 8.8 10.8 A 8 ¢5 40.8 96 8.7 10.9 A 0 41 40.8 96 8.7 11.0 A 5 40 40.7 96 8.7 11.1 i 8 41 40 7 96 8 ? 11 I A -'- 2 36 40.7 96 8.7 10.9 A 6 42 40.6 96 8.8 10.7 A 4 56 40.6 96 8.8 10.5 A 5 83 40.6 95 8.8 10.3 A 4~ 75 40.5 95 8.7 10.4 A 5 62 40.5 95 8.7 10.3 A 9 39 40.5 95 8.7 10.5 A I 26 40.4 95 8.8 10.5 A I 14 40.3 95 8.8 10.4 A 2 21 40 3 95 8 9 10 4 A 0 35 40.2 95 8.8 10.3 a ~. 27 40.2 94 8.9 10.3 A I 14 40.1 94 8.8 10.2 i 3 20 40.1 94 8.9 10.2 A 8 23 40.1 94 8.9 10.2 i 4 18 40.1 94 8.9 10.0 A 7 11 40.1 94 9.0 10.1 A 8 4 40.1 94 8.9 9.8 B 2 0 40.1 94 9.1 9.9 A 2 97 40.1 94 8.9 9.8 A ,4 82 40.1 94 9.0 9.8 i 5 62 40.1 94 8.9 9.7 A .~. 9 76 40.1 94 8.9 9.8 A 7 74 40.1 93 8°9 9.6 A 1 81 40.1 93 8.9 9.7 A 4 63 40.1 93 8.9 9.6 A 8 98 40.0 93 8.9 9.7 B 4 45 40.0 93 8.9 9.7 A 3 49 40.0 93 8.9 9.7 A. 7 54 40.0 93 8.7 9.6 A ARCO ALASKAt INC. 3H-11 CCOLVILLE) PAGE B-FILE. DEPTH DIP DIP OEV DEV DIAM DIAM Q 4&~Zo¢7 &.2 53 40.0 93 8.6 9.7 4414.47 3.7 48 &O.O 93 8.8 9.7 4416.47 3.4 48 40.0 93 8.7 9.8 4418.47 4.8 38 40.0 93 8.6 4420.47 4.1 18 40.0 93 8.5 9.9 4422.47 4.9 40 40.0 93 8.5 9.9 4424.47 5.7 40 40.0 93 8.4 10.0 4426.47 5.9 34 40.0 93 8.4 9.9 4428.47 4.1 33 40.0 93 8.4 10.0 4430.¢7 5.1 50 40.0 93 8.3 10.0 4432.47 5.3 40 ¢0 0 93 8.2 10 1 4¢34.47 5.5 50 40.0 93 4436~46 5.1 38 40.0 93 8.4 10.3 443B;'46 5.8 54 40.0 93 8.5 10.4 4440.46 5.5 56 39.9 93 8.7 10.3 444Z,46 5.! 41 39.9 93 8.7 10.4 4444.'46 5.¢ 41 39.8 93 8.5 10.2 4446.'46 3.1 50 39.8 93 8.4 10.2 4¢4~.46 5.7 $7 39.7 93 8.3 10.1 4450.46 4.6 61 39.6 93 8.3 10.1 4452.46 4.3 39 39.6 93 8.3 10.0 4454.¢& 4.'7 18 39.5 93 8.4 10.1 4456.46 4°6 332 39.3 94 8.4 10.1 ¢458.~6 37.9 275 38.1 98 8.4 10.1 4~60.~6 38.5 262 38.1 83 8.4 10.1 B ~ A ~ 8 f A f A ~ B f 8 , A ~ A , A , B ,~ B ~ B f A ~ a :~ A ~ A ~ B ~ B , B ~' A ~ A ~ ARCO ALASKA, INCo 3H-1! CCOLV~LLE) SUMMARY · DEPTH ~ DIP DIP · DEV DEV DIAN DIAH = ~ = AZM ~ AZM 1-3 2-~ ~ · TOP · 3852.6~ 6.7 72. 64.6 101 9.6 ~Z.g ~ - · BOTTOM · 4460.46 3B.5 262 38.1 83 8 4 ~0.1 DIP FREQUENCY BY AZ/MUTH 0-10 DEGREE DIPS PRESENTATION 210 240 W 3852- 3900 1 3900- 4000 4000- 4100 4100- 4200 4200- 4300 1 4300- 4400 1 4400- 4460 300 330 N 30 3 2 1 1 1 2 6 30 14 15 1 2 22 6O 3 5 13 10 6 10 3 120 150 2 1 2 6 15 3 1 S 2 2 210 1 1 1 PRESENTATI'ON )10 24~0 3852- 3900 3900- ~000 2 4000- ~100 ¢100- ~200 4200- 4300 4300- 4400 ¢400- 4,460 DIP FREQUENCY ~3Y AZIMUTH 10-90 DEGREE DIPS W 300 330 N 3..0 60 I 5 1 1 2 1 4 6 8 2 3 i i 5 7 I 2 1 1 1 5 3 ! 2 2 ! I 120 150 1 1 S 1 1 210 PRESENTAT]~ON 30 3852- 3900 Z 3900- 4000 4000- 4100 6 ~100- 4200 30 4~20 O- 4300 4300- 4400 ],5 4400- 4460 22 6O "4: OTP FREQUENCY BY AZ]:MUTH * 0-10 DEGRE, 3 5 1 13 Z 10 6 6 15 10 2 3 120 150 S 210 240 2 2 1 I 2 1 1 300 330 30 3 1 2 PRESENTATION ,.m. ,.m .--~, ,..m ,,m. ,m. ,~..m,,.m, ..m,.m, m 3852- 3900 3900- 40O0 ,¢000- 4100 ¢100- 4200 4200- 4~300 4300- 4400 4.400- 4460 3O 6O FREQUENCY ~Y AZIMUTH 0-90 DEGREE O~PS E 120 150 S 210 240 2 3 3 3 2 1 6 13 7 2 3 4 2 11 20 3 I 2 31 12 6 1 6 9 20 7 2 I 1 16 10 3 1 22 3 I 2 1 2 300 330 30 8 5 3 1 16 2 ARCO ALASKAt INC. 3H-11 CCOLVILLE) SUNMARY · DEPTH * DIP DIP * DEV OEV DIAM ~ ~ AZM * AZM 1-3 · TOP · 3852o61 6.7 72° 4&o6 101. 9°6 12.2 B · BOT?O~ · a&60.*6 38.5 262. 38o! 83° 8°¢ ZOo! ENO OF LSF - VERSION 007oE05 30-DEC-ST - 11:0~:37 PROGRAM : LSF VERS]:ON : 007.E05 DATE : 30-DEC-ST TI:ME : 10:34,:02 STRATZGRAPHZC H:[GH RESOLUTZON DZP.qETER HSD COMPUTATIONS COHPANY -" ARCO ALASKAt ]'NC. NELL : 3H-11 CCOLVIL:LE) FIELD : KUPARUK COUNTRY : U.S.A.. RUN : TNO DATE LOGGED : 25 - DEC - 87 REFERENCE : 72555 P.,AGNETIC DECLZNATION 3! DEGREES 4* X Ze X 30 HSD LISTING '~EPEAT PASS FILE ARCO ALASKA DEPTH 3852.13 5.8 73 3854.13 7.7 37 44. 3856.'13 2.5 143 3858.13 1.3 281 3860.13 3.8 144 4/+. 3862.13 6..0 167 44. 3864.13 2.7 158 44. 3866.13 16.4 25 44. 3868.13 5.7 119 3870.13 4.9 138 44. 3872.13 20.0 154 3874.13 10.7 341 44. 3876.13 21.5 17 3878.13 26.9 193 44. 3880.13 18.9 336 44. 3882.13 4.9 52 3884.13 20.5 172 44. 3986o13 NO CORR 44. 3888.12 9.6 27 3890.12 6.2 54 389Z.12 4.4 53 44. 3894.12 10.2 265 3896.12 8.3 250 44. 3898.12 7.4 331 44. 3900.12 5.2 223 44. ' 3902.12 33.4 198 3904.12 10.8 54 3906.1Z 7.8 143 44. 3908.12 19.9 7 44. 3910.12 35.1 180 44. 3912.12 5.9 191 44,, 3'914.12 9.¢ 231 44. 3916.12' 2.0 273 3918.12 14.8 219 44. 3920.12, 2.2 152 3922.12 4.0 142 44. 3924.12 1.9 125 44. 3926.12 6.5 108 3928.11 7.5 111 44. 3930.11 6.0 113 · INC. 3H-11 (COLVTLLE) PAGE 1-FILE DIP DIP DEV DEV DIAM DIAM Q AZM AZM 1-3 2-4 7 98 12.0 9.6 ,6 97 12.1 9. 6 97 1Z.4 9.7 6 97 12.4 9.1 6 97 12.6 9.9 5 97 12 7 9 9 5 97 12.6 9.8 5 97 12.6 9.9 5 97 12.4 9.8 5 97 12.5 9.8 5 97 12.5 9.8 5 97 12.5 9.8 6 97 12.6 10.1 6 97 12.6 9.8 6 97 12.5 10.3 6 98 12.6 10.0 6 98 12.6 10.0 6 98 12.5 9.8 5 98 12.6 9.8 5 98 12.5 5 97 12.7 9.8 5 97 12.7 9.7 5 97 12.8 4 97 12.8 9.5 4 97 12.9 8.9 6 97 12.9 9.3 4 97 13.1 4 97 13.2 9.3 4 97 13.2 9.5 m~ 97 13.2 9 . 5 4 97 13.1 9.6 4 97 13.1 9.6 5 97 13.0 9.5 5 97 13.0 9.5 5 97 13.1 5 97 13.1 9.6 4 97 13.1 9.6 4 97 13.1 9.5 4 97 13.1 9.7 3 97 13.0 9.6 ARCO ALASKA, INC. 3H-11 (COLVILLE) PAGE 2-FILE 1 DEPTH DIP DIP DEV DEV DIeM OlAM AZM AZM 1-3 3932.11 29.6 234 44.3 98 3934.11 32.7 311 44.3 98 3936.11 30.2 351 44.2 98 3938.11 30.Z 214 44.2 98 3940.11 7.1 241 44.3 97 3942.11 10.9 294 44°3 97 3944.11 12.6 291 44.2 97 3946.11 11.5 148 44.2 97 3948.11 7.3 58 44.2 97 3950.11 5.0 125 44.2 97 3952.11 3.1 177 44.1 97 3954.11 9.6 66 44.1 97 3956oll 15.9 28 44.1 97 3958.11 15.6 33 44°0 97 3960.11 30.9 202 44.0 97 3962.11 11.9 48 43.9 97 3964.11 8°0 105 43.9 97 3966.11 12.4 90 43.8 97 3968.10 13.6 69 43.8 97 3970.10 9.4 76 43.8 97 '3972.10 15.2 69 43.9 97 3974.10 9.4 94 43.9 97 3976.10 10.5 93 44.0 97 3978.10 12.3 81 43.9 97 3980.10 15.2 66 43.9 97 3982.10 4.0 105 43.8 97 3984.10 5.6 94 43.8 97 3986.10 12.6 84 43.8 97 3988.10 14.6 96 43.8 97 3990.10 14o0 88 43.7 97 3992,10 17.9 140 43.6 97 3994.10 8.1 68 43.7 97 3996.10 10.Z 76 43.7 97 3998.10 15.3 101 43.8 97 4000.10 16.9 101 43.8 97 4002.10 8.0 11.2 43.8 97 4004.10 10.8 93 43.9 97 4006.10 12.9 77 43.9 97 4008~10 15.7 107 43.9 97 13.0 9.4 D 12.8 9.7 D 12.8 9.5 D 12.6 9.7 O 12.7 9.8 O 12.6 9°9 C 12.7 9.8 D 12.5 9.8 D 12.4 9.3 B 12.4 9.3 C 12.4 8.8 B 12.5 8.8 O 12.6 9.0 C 12.5 9.0 C 12.4 9.1 C 12.1 9.1 O 11.9 9.0 B 11..8 9.0 B 11.7 9.0 8 11.6 9.0 D 11.5 9.0 B 11.3 9.4 C 11.3 9.5 B 11.1 9.7 B -'- 11.3 9.8 C 11.5 9.5 C , 11.5 9.1 A 11.9 9.4 B 11.8 9.2 .C 11.9 9.9 C 11.8 9.6 C 11.8 9.5 C 11.7 9.4 B 11.8 9.0 C 11.7 9.2 O 11.8 9.1 C 11.7 9.0 B ' 11.8 9.0 8 11.6 9.0 B ARCO ALASKA, INC. DEPTH DIP DIP AZM 4012.09 16.3 4014.09 36.0 4016.09 12.2 4018.09 1.7 4020.09 24.8 4022.09 15.8 4024.09 28.2 4026.09 16.7 4028.09 13.0 4030.09 15.5 4032.09 11.0 4034°09 9.9 4036°09 14.6 4038.09 34.1 4040.09 ND C 4042.09 31.5 4044.09 24.1 4046.09 4048.09 4050°08 4052.08 4054.08 4056°08 4058°08 4060.08 4062°08 4064.08 4066.08 4068.08 4070.08 4072.08 4074°08 407,6.08 4078.08 4080.08 4082.08 4084.08 4086.08' 14.7 9.8 9.4 7.9 2.3 7.4 27.6 31.0 11.0 9.7 9.7 11.4 B.2 13.2 .6.9 6° 5 5.6 3.1 7.5 2.7 3H-11 CCOLVILLE) PAGE 3-FILE 1 OEV OEV DIAM D~,~M q ~ AZM 1-3 2-4 ~ 260 44.0 97 11.9 8.9 278 44.1 97 11.9 9.0 282 44.2 97 13.0 8.5 269 44.3 96 13.3 8.5 19 44.6 97 15.2 8.5 345 44.7 97 16.0 9.4 186 44.7 97 15.5 96 44.5 97 14.4 9.8 85 44.4 97 14.4 10.7 42 44.4 98 11.7 10.0 15 44.2 98 13.1 10.3 80 44.1 97 12.3 10.1 42 44.1 97 12.8 9.7 315 44.2 97 12.6 9.6 ORR 44.1 97 13.2 303 44.1 97 12.3 334 44.0 97 12.0 9.6 11 44 0 97 11 8 71 44 0 97 11 4 9 3 66 44.1 97 11.5 9.4 48 44.1 97 11.5 9.2 113 44.1 98 11.7 9.4 250 44.1 98 11.5 9.4 260 44ol 98 11.6 9.4 223 44.0 98 11.5 300 43.9 98 11.4 9.4 78 43.9 98 11.3 9.7 81 43.9 98 11.2 9.5 17 43.9 99 10.9 9.6 33 43.9 98 11.1 9.4 128 43.9 98 10.8 9.3 33 44.0 99 11.2 9.1 54 44.0 99 11.1 9.4 56 44.0 99 11.3 9.1 82 43.9 99 11.3 9.4 79 43.9 99 11.0 9.2 46 43.7 98 10.7 9.3 125 43.6 98 10.2 9.1 , 4088,'08 5.3 89 43.5 98 10.0 9.1 A * 4090,'108 6.6 100 43.5 98 9.4 8°8 A ARCO ALASKA, INC. 3H-1! CCOLVILLE) PAGE 4-FILE OEPTH DIP D~P DEV D~V DIA~ 0I~ ~ AZM AZM 1-3 2-4 3.! 24 43.~ 99 9.8 8.9 4.~ 1.9 43.5 99 9.6 8.9 5.0 53 43.5 99 9.9 9.0 5.4 57 43.5 99 10.0 9.0 5o3 54 43o5 99 9°9 9ol 7.0 52 43.5 99 9.8 8°9 703 51 43o5 99 9.6 8.9 6.~ 39 43.5 98 9.7 8.8 5.9 41 4305 98 9.7 809 9.0 68 43.6 98 9.7 8.9 9.0 51 4306 99 9.T 8.9 7.2 54 43.5 99 9.8 8.9 706 66 43.5 98 9.8 8.8 7.2 52 43.4 98 9.8 8.9 6.6 59 ¢3.6 98 9.8 8.8 609 60 63.4 98 9.8 8.8 7.8 56 43.4 98 9.7 8.8 8.0 52 43.4 99 9.7 8.8 7.5 53 4304 99 9°7 8.8 8°3 '68 6304 99 9°7 8.8 9.! 67 63.4 99 9.7 8.8 7.9 64 43.4 98 9.7 8.8 7.0 64 43.5 98 9.8' 8.8 8.6 62 63.5 98 9.8 8.8 9.0 55 63.5 98 9.8 8.8 7.7 57 43.5 99 908 808 7.3 47 63.5 99 9.8 8.8 7.1 62 43.4 99 9.7 8.9 8.6 79 63°6 99 9.7 8.9 9.8 72 4304 99 9.6 8.9 3.2 97 43.4 99 9.6 8.9 5.9 156 43.4 99 9.5 8.8 6.8 84 43.4 99 906 8.8 4.0 84 43.4 99 9.6 808 306 95 4304 99 908 808 3.4 65 63.3 99 9°8 808 2.6 ~5 4,303 304 54 43°3 99 9.8 8.8 3.6 47 4303 99 10o0 8.9 4092.07 409¢.07 4096.07 6098.O7 4100.07 4102.07 6106.07 4106.07 6108.07 6110.07 4112.07 6116.07 4116.07 4118007 6120.07 6122.07 4126.07 6126.07 4128007 6130.07 4132.06 4134.06 4136.06 4138.06 4140.06 4142006 6164.06 4146.06 6148.06 4150.06 4152,06 4154'06 4156.06 4158,06 4160.06 4162.06 4164.06 4166.06 4{68.06 A , A ~= A ~ A f A :~ A ~ A ~: A :~ A ~: C ~ B ~ A ~ A ~ A ~ A f A :~ A ~ A ~ A ~ A ~ A ~ A :~ A :e B :, A ~ B ~ A ~1 A ~ A ~ C , B ~ C :e A ~ A ~ A ~ A .~.. A :~ A e A ~ ARCO ALASKA~ ZNC. 3H-11CCOLVZLLE) PAGE $-FZLE 1 OEPTH DIP DiP DEV DEV DIAM DIAM Q t AZM AZM 1-3 2-4 · 4172.06 4174.05 5.8 4176.05 5.1 4178.05 4180.05 ~.8 4182.05 4184.05 5.5 4186.05 10ol 4188.05 10.7 4190.05 4192.05 4194.05 5.3 4196.05 7.2 4198.05 7.7 4200.05 4202 o 05 7.3 ~20~.05 8.3 4206.05 25.8 4208,05 26.9 4210,05 14.5 4212.05 7.7 4214.04 7.0 4216,04 6.7 4218.04 4220.04 5.0 4222.04 7.5 4224.04 62 43.3 99 10.2 8.7 A 55 43°3 99 10.2 8.7 A 55 43.2 99 10.4 8 7 A 56 43.2 99 10.7 8.7 63 43.2 99 10.9 8.8 A 75 43.2 99 10.9 8.8 A 69 43.1 99 10.9 8.8 A 55 43. 1 99 10.7 8. 8 A ~"' 55 43.0 99 10.6 8.8 A 76 43.0 99 10.7 8.8 A 76 43.0 99 10.7 8.8 A 76 43.0 99 10.5 8.8 A 107 42.9 99 10.8 8.8 A 123 42.9 99 10.7 8.8 A 123 42.8 99 11.0 8.7 A 119 42.8 98 11.1 8.8 A 95 42.8 98 11.2 8.8 C 357 42.7 98 11.2 8.8 D 319 42.7 98 11.3 8.8 D 42 42.7 98 11.3 8.8 C 97 42.7 98 11.3 8.9 A 109 4Z.7 97 11.3 8.9 A 106 42.6 97 11.3 8.9 B 104 42.6 97 11..3 8.8 A 205 42.6 97 11.2 8.9 D 115 42.6 97 11.2 8.8 A 103 42.6 97 11.2 8.8 A 117 42.5 97 11.2 8.8 A 106 4~2.5 97 11.1 8.8 A 103 42..5 96 11.1 8.8 A 97 42.5 96 11.0 8.8 i 125 .42.5 96 11.0 8.8 O 140 42o4 96 10.9 8.9 C 162 42.4 96 10.9 8.9 B 146 42.¢ 96 10.8 9.0 143 42.4 96 10.8 9.0 A 194 42.4 95 10.7 9.1 B 134 42.4 95 10.7 9.0 A 93 42.4 95 10.7 9.1 A 95 1'0.7 9.0 A 4226.04 7o 1 4228.04' 8.7 4230.04 8.3 4232.04 9.7 4234.04 8,. 1 4236.04 11.0 4238.04 13.3 4240.04 12o8 4242.04 13.1 4244.04 8.1 4246.04" '8.1 ' 4246.04 '5.3 4250.04 5.6 88 42.4 4252.04 6.5 104 4254.04 6.8 113 42.4 4256.03 11.6 118 4258.03 2.6 85 42.4 4260.03 3.7 104 42.4 4262.03 3.0 130 4264.03 2°8 269 42.4 4266.03 7.0 103 42.4 4268.03 19.6 72 42.4 4270.03 20.1 63 42.3 4272.03 36.2 247 42.3 4274.03 39.7 272 42 Z 4276.03 13.2 247 42.0 4278.03 9.3 80 41.9 4280.03 7.4 49 41.8 &282.03 9.3 70 41.8 4284.03 9.2 101 41.8 4286.03 6.2 103 41.8 4288.03 6.8 42 41.8 4290.03 13.1 78 41.8 4292.03 18.5 53 41.8 4294°03 19.5 65 41.8 4296.02 13.8 56 41.T 4298.02 5.7 63 41.7 4300.02 11.5 157 41.6 4302.02 4.3 82 41.6 4304°02 17.5 297 41.6 4306.02 1.8.2 303 41.7 4308=02 4¢.3 288 4310.02 34.2 280 4312.02 7.5 147 41.6 4314.02 6.5 109 41.6 4316.0'2 7.7 116 41.5 4318.02 7.7 53 41.5 4320.02 5.6 49 41.5 4322.02 5.7 42'41.5 4324.02 6.7 41 41.4 4326.02 5.2 39' 41.2 4328.02 6.0 29 41.1 ¢330°02 ARCO ALASKA~ INCo 3H-11 CCOLVZLLE) PAGE 6-FZLE DEPTH DIP DIP DEV OEV DZAM DZAM O AZM AZM 1-3 2-4 95 ].0.6 9.0 95 10.6 95 10.5 9 0 W 95 10.3 9.1 95 10.3 9.1 95 10.2 9.3 95 10.3 9.3 94 10.3 9.3 94 10.3 9.2 94 10.6 9.5 94 10.5 9.3 94 11.1 9.7 94 11.2 9.8 94 10.4 93 10.5 9.9 93 9.6 9.0 93 9.7 9.6 93 9.7 9.2 93 9.7 9.6 93 9.9 93 9.7 9.7 93 9.9 9.7 93 9.6 9.5 93 9.7 9.5 93 9.6 9.6 93 10.3 9.8 93 11.8 11.6 93 12.0 12.3 93 12.4 11.4 93 11.5 11.8 93 9.9 9.3 93 9.7 9.0 93 9,,6 8.9 93 10.1 8.7 93 10.5 8.9 93 10.5. 8.8 93 10.6 8.9 93 10.6 8.8 92 10.5 ' 8.7 ARCO ALASKA, INC. 3H-11 CCDLV[LLE) PaGE DEPTH DIP DIP DEV DEV DIA~ DIAM Q AZM AZM 1-3 2-4 4332.02 g.5 317 41 0 93 10 4 B 7 A 433~.02 1.5 ZO 41.0 g3 10.6 B.7 A ~336.02 3.2 50 40.g 93 10.6 B.B A 433B.01 4 B 3B ~0 9 g3 10 7 B B A 4340.01 B.3 54 40.g g3 10.7 B.g A 4342.01 6.3 &B 40.g 93 10 8 B 7 A 4344.01 7.1 36 40.B g3 lO.g B.7 A 4346.01 5.6 30 ~0.8 93 Ll.0 8.6 A 434B.01 5.2 26 40.B 93 11.0 B.7 A 4350.01 ~.3 22 40. B 93 lO.g 8.7 A 4352.01 4.0 30 40.7 93 10.7 B.B A 435~. 01 3.6 23 40.7 g3 10.5 8.B A 4356.01 2.0 39 ~0.7 92 10.2 B.8 A 4358.01 2.1 324 40..6 g2 10.4 B.8 A 4360.01 1.7 61 40.6 92 10.1 B.B A 4362.01 3.5 50 40.6 92 10.4 B.8 A 4364.01 3.~ 4 40.5 92 10.4 B.8 A &366.01 2.B 355 40.5 9Z 10.3 B.B A 436B.01 1.7 16 40.~ g2 10.3 B.9 R 4370.01 5.0 ~7 40.3 92 10.2 B.8 A 4372.01 6.~ 3B ~0.3 gl 10.1 8.g A 437a.01 5.B 16 &O.2 gl 10.1 8.g A 4375.01 6.6 13 ~0.2 91 10.0 B.9 A · ' 4.37B.00 4.7 17 40.2 90 9.g B.g A 43B0.00 5.5 13 40.1 90 9.g B.9 A 43B2.00 5.B I 40.1 90 9.9 9.0 R ~3B~.O0 10.7 359 40.1 90 9.B B.9 a 4386.00 1'7.0 355 40.1 90 9. B g.1 A 43BB.O0 1B.2 342 40.1 90 9.B B.9 B 4390.00 2.7 BB 40.1 9.0 9.B 9.0 A 4392.00 3.0 80 40.2 gO 9.7 B.9 A 4394. O0 3.3 79 40.2 90 9.B B.9 A ~39B.00 3.4 BO &O.1 gO 9.6 B.9 A a400.O0 4.B 71 ~0.1 B'9 9.5 B.9 A 4402.00 ~.7 76 ~0.1 8g 9.6 B.9 A 4~04.00 3.B B~ 40.1 90 g.6 B.9 A ~06.00 3.0 66 40..1 go g.6 B.B A ~410.00 3.5 56 ~0.1 9.0 g.8 B.B A ARCO ALASKA, INC. 3H-Z1 (COLVILLE) PAGE 8-FILE DEPTH DIP DIP DEV DEV OlAM OIAM Q AZM AZM 1-3 2-4 4412o00 3.5 53 40.0 90 9o8 8.8 4414.00 3.1 49 40.0 90 9.8 8.8 4416.00 2.3 69 40.0 90 9.7 8.8 4418.00 3.Z 65 40.0 90 9.7 8.8 4419.99 3.4 44 40.1 90 9.7 8.8 4421.99 3.7 143 40.1 90 9o7 8.8 4423.99 ¢.1 47 40.1 90 9.8 8.9 4425°99 4.7 49 40.! 90 9.8 8.8 4427.99 .4.Z 44 40.0 90 9.9 8.8 4429,99 3.S 39 40.0 90 9.9 8.9 4431.99 3.8 42 40.0 90 10.0 8.8 4433.99 4.7 50 40.0 90 10.1 8.8 4435.'99 4.2 57 40.0 90 10.2 8.8 4437.99 3.3 45 40.0 90 10.3 8.8 4439.99 4.5 &Z 40.0 90 IO.Z 8.7 4441.99 4.0 47 39.9 90 10.3 8.7 4443.99 4.2 47 39.9 90 10.1 8.5 4445°99 4.8 44 39.8 90 10.0 8.4 4447,99 4.9 64 39.8 90 10.0 8.4 4449.99 5.~ 74 39.7 90 10.0 8.3 4451,99 3.8 51 39.6 90 9.9 8.4 4453.99 6.3 46 3'9.~ 91 10.0 8.4 4455.99 38.1 351 39.0 171 9.9 8.4' 4457.'99 39.Z 94 39.2 2174 10.0 8.4 ARCO ALASKA, INC. 31'1-11 CCOLVILLE) SU[qEARY ~ DEPTH ~ DiP DiP e DEV DEV DIAH DIAE ~ ~ ~Z~ ~ AZ~ 1-3 2-4 · TOP · 3852.Z3 5.8 73. 44.7 98. 12.0 9.6 A · BOTTOM · a&57.99 39.2 9~. 39.2 27~. 10.0 8.~ PRESENTATION 210 24.0 3852- 3900 3900- 4.000 g 4000- ¢100 4100- 4200 4200- 4300 ¢300- ~,400 4400- 4457 DIP FREQUENCY BY AZI.~UTH 0-10 DEGREE OIPS 3OO 33O N 3O 60 1 I 4. 1 1 3 2 8 8 25 18 ,2 5 2 I 15 14 7 19 9 1 7 3 3 19 2 120 150 3 4 1 1 1 210 PRESENTAT]?ON ,?.10 240 3852- 3900 3900- 4000 3 4,000- 4100 1 2 4.100- 4200 4'200- 4300 2 4,300- 4400 4400- 4457 CREQUENCY BY AZ~HUTH 10-90 DEGREE DIPS 300 330 N 30 60 Z 2 1 1 2 3 2 2 4 2 Z 3 ! 1 1 3 1 3 1 120 150 S 2 1 210 1 2 1 PRESENTATION 30 3852- 3900 3900- 4000 4000- 4100 8 4100- 4200 25 4200- 4300 2 4300- 4400 14 ¢400- 4457 19 6O ~ OIP FREQUENCY 3Y AZIqUTH ~ 0-10 DEGREE DiPS E 120 150 S 210 240 1 I 3 2 3 7 ¢ 2 I 2 8 3 I 18 3 1 I 5 19 4 2 7 2 I W 1 1 2 300 330 N 1 15 3O PRESENTATION 3852.- 3900 3900- ~000 ¢000- 4100 4100- ~200 4200- ¢3OO 4300- 4400 4400- .4457 3O · DiP FREQUENCY BY AZIMUTH =~ 0-90 DEGREE DIPS 60 E 120 150 S 210 4 I 1 3 ¢ 1 ¢ 11 10 6 3 3 10 10 8 2 1 27 18 3 1 5 9 20 7 I 2 14 7 2 1 19 9 I 240 5 W 2 1 300 330 15 30 3 2 6 ARCO ALASKA~ INC. 3H-11 CCOLVILLE) SUMMARY ~ DEPTH · DZP DIP ~ DEV OEV DIAH DZAM · ~ ~ AZM · AZM 1-3 2-4 · ~ TOP · 385Z.13 5.9 73. &~.7 98. 12.0 9.6 END OF LS~ - VERSION 007oE05 30-DEC-87- 10:35:10 LIS V~R'[F:[C,~TZ~ N LISTZNG · :'? :: RECEIVED ., LVP 010 HO'~ VEoT.:I~'~'TT~N L'T. -.'N ....... u .S'T! G e~GE w'r--'LL SI?~S 9AT.I INO T.IBLES .IRE NOT INCLUDE¢ IN THIS LIST'ING W~VEF~P~'~'S ~ND FIS'T '~H.;'~NNEL BITt ARE NOI INCLUDEB IN THIS LISTING LVP 010oH02 VERI:)C.&TIgN LISTING SE~VIC~ N~ :SHD~UT DATE :871.12/]0 ORIGIN :FLZ£ RE2L NAME :T2fS5 CONTINUATION ~ PREVIOUS ~EL : CDMN:NTS :SCHLUM~FRG'ER WELL SERVICES CUSTOMER- FLIC · -,--,- T.~PE H;::~,DE~ '""' SERVIC".b' NA:,IE :SF;DOUT gATE :87/12/30 3R "G,'.N · FL _rc " ., ..'. 1 EDT -.,'"DNTINUATTON._ ,.~' . PREVIOUS T..~P .~. : r, CON,'qENTS : 72"1~ 5 T~PE ~$ FiLE HE'~DE~ FILE KAM'n.~ :SHnn'I''':::_. ,,001 SERVICE NA'".F :SHgOUT VERSION ff :0.01D04 DATE :BT/1Z/~O MAXi MU,'! LENGTH FILE TYPE :':S PREVIOUS F~Lq "'-'- COMMEN'T5~-~- SPC, FS"'001.0 31, INC 001. O01 --'-... SCHLU:MBERGFR .,,.~ CO;.1P~Y : ~:.RCg ..~L.~SK~., INC. WELL = ~H-11 (CgLVZLLE) AP'I ~ = 50-029-21771 FIELD : KUPa~UK COUNTY = NORTH SLOPE. STAT: = JOB NU,.qBER AT ,~K.CC: 72555 LVP 010.HO~.= VF~T~'r~TION.. , - ,., L..ISTING PAGE ~UN ,~2 D'~T= Ln~'~'' 9-.-". LOP: J. KOHP, IN~; CASING TYPE FLUID DENSITY VISCOSZTY FLU~. 3 L,.:, : 10.75" D36~'(LOGGER) '- ~I'T SIZE : 8-5" TO 7?50'(LOGGER) '= W'--IGHT~D PO'Ly';v,E~ = 4~.0 S RMF = 4.00 '~ 7-5 DF '= 9.5 RMC = 3601 ~ 76 OF = 4.8 C3 MAGN-:_TIC DECLINaT'!gN 31 DE'GPEE$ R.'4 .,~T e. HT = 2.059 @ 147 OF NOTE: THIC T~mF C"'"'"'" .,. ~ , :J,'~.:,~INS SHOT F,~ST rHANNELS ~N9 SLOW CHANNELS P'EP'.'T~? "--IELg -~:iLE $1 INTFRV~L => 4460' ..TO 3848' ~4AIN P~$S FIELD ~£L"'" ~2 iNTERVaL :---> 4463' T~ .3849' ~. SHOT ~ST CHANNELS B. D~i = ~A9 1-1S' :~.UTTON C. D'BJ.~ = mAO I=2Ng 3UTT3N O. S82 = SPrig BUTTON E. g~2 = P~D 2-IST 3UTTON '~'. D'~2~ = P~.D ~-~Nm ~U'TT~N ~ ~ - . ..... . ., G. OB3 = ~9 .=.~-IST ~UTTON H. D631 = PA9 '3-2N9 !!UTTjN I. D34 = P.~g i-IST ~UTTON . .N., [~UTTnN J EB4A = Pig K. ~V.._ = ,.,.="':X VOLTAGE (~EFORm~ .... ~ILT~RING) STAND~RD CHANNEL 2 SHBT INCL'r m " _ . .,.N..,~:'cTRY CHANN~:LS FiLt: i. SDEV = SONDE D"'VI-IT'TDN ~8. D~V[ = HOLm~ DKV""~.TInN_ .,. .., C. rl.~ZI : HOL~ DEVI~.TION ~Z~UTH ~- PIAZ = "~,3 1 AI'I~UTH =. RADI = RADIUS 1 G. R,~D2 = CADIUS 2 H. RID3 = ~.~9IUS 3 I. R&C4 = RADIUS J. GNC~ = GRAVITY NOq.", / 9.8t LVF OlO HO'~ VERI:-~!r~TI'n.''' S'T ........ · . .~,, Li iNG PAGE 4 EN'T R'¥ BLACKS TYPE SIZ~ 1 1 ~ Z 1 I. t 'l 3 1 16 1 9ATUM SPEC MNEM SERVZ OEPT 'SHSC SBi SHSC DB1 SHSC DB1A SHSC 082 SH'SC OB2A SHSC S~Z SHSC DB3 SHSC DB3A SHSC D84 SHSC OB4A SHSC REV .SHSC SOEV SHSC MAXI SHSC R 8 S H .S 'C PIAZ SHSC RAOl SHSC RAD2 SHSC RADB SHSC RAD4 SHSC 'SNOR SHSC ~NOR SHSC SINI SHSC OEVI SHSC ~V SHSC EI SHSC ZFIC~TIO.N CE .S:RV]TCF 0'" ~LOCKS UN.iT t. DG TYP:~ ".=T O0 O0 510 00 610 O0 ~10 O0 510 OO 510 O0 610 O0 610 O0 610 V 01 OOO D:G~. O0 000 DE~ 76 630 DE~ 76 631 gEG 76 632 IN 70 .ZBO rN 70 280 .f'.' N 'tO 280 IN 70 280 O0 000 ~ :E_~ q O0 000 OD 009 OEG 76 620 V O1 .900 ~,~P O] 000 DEPT 445 ?. 9.844 'CODE 66 66 7.9 66 66 66 66 CLASS MOD 21 0 XO 0 O1 0 tl 0 02 0 12 0 lO 0 · 03 0 13 0 04 1~ 0 O0 0 O0 0 01 0 01 0 01 0 41 0 ~2 0 4~ 0 .~4 0 O0 O. O0 0 O0 0 01 0 O0 0 O0 0 APl FILE NO. 1 1 1 1 1 1 1 1 1 1 ! 1 1 1 1 1 1 1 1 1 1 ! 1 1 1 ! ENTRY 0 0 704 ! 0 1 SIZE SPL 4 1 64 16 64 16 64 1-6 64 16 64 16 64 16 64 16 64 16 64 16 64 /.6 4 1 4 1 ~ 1 4 4 1 4 4 1 4. 1 4 ! 4 1 ¢ 4 1 4 1 ,4 1 4 I REPR PROCESS CODE (OCTAL) 68 00040000000000 68 000~0000000000 68 00040000000000 68 0004000000000.0 68 00040000000000 6.8 00040000000000 68 00040000000000 $8 O00~O'OODO00OO0 6B 00040000000000 68 000~00.00000000 68'000¢0000000000 68 00040000000000 68 00040000000000 68 00040000000000 68 000.40000000000 68 00040.000000000 68 00040000000000 68 00040000000000 68 000400000000'00 68 00040000000000' 68 00040000000000 ' 68 0.0040000000000 . 68 00040000000000 68 00040000000000 68 00040000000000 68 00040000000000 LVP OlO.HO2 VY.~IF!C&TI-':3N LISTING 2.9492 5.387.2 3.0~,46 2.6~14 2.8309 -404n .95~ 7 5955 3.6035 7 · 7%53 3..5964 3.0'367 D B .2 3.3789 2.1¢84 3.6145 2.9679 99. Zfi 3.2861 2.2414 3.4027 2.7140 ~.3057 2.24~I 2.7¢29 D~3 3. 100-6 3.0977 2.7-:328 3.3447 [.4316 ~ ~679 2.9509 12.9910 3.4q62 2.3027 3.4365 2,2073 20.6674 4..5160 2.5310 t. 0.9484 ~. '=927 ~ -6 ~ 7.5 10.5617 3.18'75 3.5303 10.4342 ?.5352 !.6.2321 3.8028 2.3056 1.5.2656 4.035? 2.5255 li.ogoo 2.0982 2.5069 11.3063 2.0270 2.4.549 17.4372 2.3.B04 3.1051 8.2100 3. 935.5 3.6475 7.9296 3.7158 3.5303 7.8553 3.7256 .3.5352 13.7462 2.1445 2.6953 13.819,6 2.3452 9.1891 2.4163 3.124~ 9..3389 2.3564 3.0496 14. 2069 3.0188 3.8224 5.4715 2.6811 2.3717 5.2975 2.6424 2.3567 5.2764 2.6645 2.3811 11.2604 2.605:1 3.2641 11.3736 2.7833 3.5157 7.2881 3.21'72 3.1738 7.3715 3.1412 3.0908 10.9766 3.9675 3.8574 2.7331 2.4159 2.1663 2.6654 2.4490 2.1787 2.6975 2.4620 2.2035 8.7745 3.3582 3.3301 8.9376 3.6165 3.5693 LVP OlD.H02 VERIfICaTION LISTI~'!G PAGE 6 OE4 10.~317 3.1168 3.4082 3.5'79! 3.4082 5.1738 2.5180 2.2~64 2.5949 2.4067 2.1896 REV P1AZ ~AD4 DEVI DEPT 5. 427'7 2.3.5,,1,4 3.5337 2.8605 0.5479 4. :19"53 GNgR 4009.2395 59* ~.7952 5.149q 5.0290 4.4825 0 2623 3.3132 ? .6572 39.6278 4.9834 0.1020 0.5479 4.816! 5.0817 5.0062 HAZI 3.~379 3.6572 332.0465 4.1953 0.5821 0.3730 4.9476 5.0353 4.8929 5.3172 2.8138 2.5438 RB RA03 SINI 5. 092'? ~..0041 4.8150 2.8446 21. 5'765 320.9636 4.9834 0.7881 5.1331 5.0265 4.7207 4. fi48.5 4.9328 4.00.4Z 4.7.864 3.9916 4.1310 5.0582 4.0114 4.1352 5.0959 4.0605 4.2948 5.0.679 6.1391 5.8268 6.5369 6.1703 5. ~ 323 6.0362 6.041! 5.8492 6.1908 5.8945 5.8754 6.2739 5.8434 5.9054 6.3600 5.697 $ 6.04'1 ? : 072,z 4.2290 5.4280 5.9075 1879 .753,5 .0741 5.2963 5.6474 3.3636 5.7942 5.4248 3.3559 5 .:1101 4.6269 4.1429 090'7 ~$6'7 4.102.0 5.0699 4.2018 4.0543 14.9694 4.1463 3.9305 4.7946 4.1428 3.8626 LVP OlO.'uO)., .. V~=eIF].rA~'ISN,~ , LIS'TiNG:' PAGE 7 SgZ 873'.3 4.4q15 4,6049 4.7469 4,1~81 4.6584 4.1453 4,7331 4,4347 4.3509 4.8268 4.2196 4.4289 521 '3 .~877 3.1'323 ~.4!~52 3. 4913 3.0637 3.5Z1~ 3.4731 2,9497 3.5540 3.4313 3.0709 3.6077 3.5B30 2.7TI~ 3.~630 3.2982 3.0].~4 2.81.37 3.0!79 4.9004 2.4399 3.0273 3'.9951 2.5290 3.2545 3.8,~48 DE:4 2.302~ 1.93"4~ . 2.4720 2.8323 '1.8919 2.6390 2.7432 1.9096 2.7971 2.6127 2.5275 2.8848 2.2365 2.6772 REV ~IAZ RAD4 .0624 .254.2 16..3 ~ 'i' 2 4.K!24 4~ 07'~, ~ SDEV R~.Ol :-V SBi ~.6~76 5.5956 5.6161 5.7504 3.948'7 3.81.29 3.6547 43. 8176 5.9.148 1.00t4 16..3672 5.6.218 5.5792 ~. 645~ HAZI RAD2 .FNOR 3.9'520 3.5712 3.9169 5.6019 5.5801 5.6'751 97.5175 4.5124 0.5835 1.2656 4.0866 3.3182 2.5879 RB RA03. $INI 5.5957 5.5957 5.6924 4,1385 2,8642 1,9649 348.6649 5,9148. 0.9871 5.5924 5.6074 5.7170 A .. 1 '3.20 ~ 0 ' "" 2 F 6.1063 6.0650 5.ac7O 6.1084 6,0419 5,9369 6.!117 6.0107 5.9260 6.1000 5.9990 5,9041 LVF OlO.HC2 VF~I'FZCAT'tON LISTING PAGE '8 6 2'12~ ,.<....1 ~$: ~.03'q2 6.2956 6.1'950 6.1906 9'82 5'. ,52 .n 5.34.Z ] 5.2637 6.2553 5.1083 4.8422 4.7974 4..939~ 6..259.~ 5.2355 4.9167 '?. 4974 SB2 6.. 3'.q30 3.9 '33 '7 4.7916 4.8~24 6.3635 3.95.32 4.1755 D~.3 6.6786 8.191g 6.5'760 6.2583 7.5961 6.6'731 7.14'73 6.9.365 6.6521 7.0933 6.6.g91 $. 7:~71 5.792a 5.7633 5.E047 5.8594 6.2814 6.1699 6.0555 6.8284 5.4294 5.1377 5.7226 5.1077 6.9360 6.2818 4.5914 3.9352 6.9332. 6.0436 '7. 9448 6.7042 6.9613 6.5~68 5.7~28 5.8396 5.8708 6.1595 6.1426 6.0:383 6.3657 5.7833 5.9167 5.5068 5.5653 6.3598 5.1643 5.047.4 4.1841 7.1759 6.2891 8.0414 6.8'797 6. 7041 6.4778 5.7686 5.8515 5.8909' 6.2301 6.1348 6.0199 5.8107 5.8350 6.4581 5.1647 6.3.164 6.2?72 4.3567 5.2955 · 4'. 4869 7.0572 6.7065 8.1196 7.0911 6.6573 6.5947 5.7..848 5.8589 5.9092 5.958!5 5.9381 5.9375 5.9375 LVP · ~' .S T l '~ G VEPI:ICA~riGN ..... 57 5 · g 36'g 6.0 .~ 9 g R~'V O. :"76° P/AZ 9:5.17,;6 RAD4 5. OEVI 43.R53! SDEV 5NOP, '_-.' V #-'~ FILE TR'&ILER r-ILE NA.}.1'i: :SH;TPUT.O0! SERV.iC~,- t'J~,~":-~. :SHgOUT VERSION ~ : ~O1. E04 DATE :87/1Z/30 MA X I ~IU q L ~ ",1~, TH FILE TYm~ :?S NEXT FZL · -~,.~ FILE HEADER r-iLE NAN:.., : SH'""'"UT.;~..002 SERVICE NAMe._ '~HOO'IT._, VERSION ~ :O01. EO4 DAT~2 :87/1Z/30 MAXIMUM LENGTH FILE TYP.~ PREVIOUS F Z L "' ' :~, COM~.IE',TS~, ,,.~-"-'- SPC, 'FS'TOO2.001, I"'JC O02.90I 5.9.315 44 6802 HA'I 6.0681 ~A02 1.00'16 ~NOR 9.5769 ~I 5.932¢ 6.0222 98.3775 ~ 04~7 ..F .. 0.58.16 0.4058 5.94.62 6.041! RB RaD3 SIN'I PAGE 5.964.2 6.0563 358.4332 5.0681 0.9871 -.--,- D',ITA ~OR~-..~T ENTRY F. sL 3C K S RgCORn -." -'- TYPE SIZE REPR CODE ] I 66 2 I 66 3 2 79 t '1 ! 66 ,1 '~ I 66 16 ! 6-6 0 0 4%5 · OA'TU q SPEC'ZFIC~TIDN MN.EM ~:~RV[Fr.- S~DVt"'F !9 P,'~DFR .~ DEPT SHSC 5~31 SHSC 08i SHSC g ~ .i A S H S C ~lqC~ !.J N '! T ~PI LOG O0 O0 O0 O0 AP1 AP! 6PI FILE TYPE CL.~SS q-OD NO. 5~ '~ 1 0 " 5!0 10 0 2 51 0 01 0 2 610 11 0 2 ENTRY 0 0 704 1 0 ! SIZE SPt REPR CODE 4 ! 68 64 16 68 64 16 68 64 '16 68 PROCESS (OCT..L) 00040000000000 00040000000000 000~0000000000 00040000000000 LVV 010.HOZ VE,RIF;rATI'~N.~ ..... LIST'"~JG~. PAGE 10 0~2 SHSC DI325. ,.qHSC S~2 SHSC., OB3 SHSC 083A SHSC DB4 SH$C O~4A SHSC REV SHSC SDEV SHSC HAZI SHSC RB SHSC P1AZ SHSC RAD1 SHSC -IADZ .SHSC RAg3 SHSC RAg4 S}{SC GNOR SW'SC FNOR SHSC SINI SHSC DEr] SHSC 5V SHSC EI SHSC DE-PT O0 ~19 02 O0 51~ 12 0 O0 510 ZO 0 O0 610 03 0 O0 6!0 :13 0 O0 5!0 04 0 O0 5.!0 14 0 V O1 000 O0 0 g~S O0 000 O0 0 o~'~ 76 -~0 01 0 3fG 76 621 iN 70 280 41 O IN 70 ~80 42 0 .iN 70 280 4~ 0 ~N 70 280 44 0 O0 000 O0 0 ~FR O0 gO0 O0 0 O0 000 O0 0 O~g 76 620 D1 0 V O1 gOD O0 0 ~ O1 goo O0 0 5,9.~73 5.8510 5.7.416 6.1520 6.ooga 5.7853 5.8015 DB1 7.0 '557 7.0 ':} 4, '3 7.0502 6.7537' 7.0279 7.0996 7.0333 6.95~9 6.972~ 6.9342 6.8:..03! 6.9809 6.9203 7.0313 7.336g .5.026.1 3. 748 2 9. 7016 6.. 7457 5.9756 7.360 8546 7.04],5 7.0920 7.0152 6.9558 6.9824 6.9109 9.1105 5.5349 4.8749 64 64 64 64 64 64 4 & 4 4 4 4 4 4 4 4 4 4 4 4 4 6 68 '0004000000'0000. 6 68 00040000000000 6 68 00040000000000 6 68 00040000000000 6 68 000400000 6 68 000~00000 6 68 000.400000 1 68 00040000.0 I 68 000400000 I 68 000400000 1 58 -000400000 1 68 000400000 1 68 000400000 1 68 00'0400000 1 68 000400000 1 68 '000400000 1 68 000400000 1 68 000400000 1 68 000400000 1 68 000400000 1 68 000400000 1 58 000400000 00000 00000 00000 000.00 00000 00000 00.000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 5.9484 5.7193 5.9780 5.9132 5.7050 6.0645 7;0551. 7.0898 6.9'73-8 7. 072'7 7. 0814 6.9163 6.9626 6.9701 6.8827 6,9678 6,9720 6,8571 8.5193 4.6330 4.4240 7.9281 4.7375 4.1260 LVP 0i0.H02 VE2IFICAT~ON LTS'TING PAGE 3.2.&6! 4.0580 5.2610 4.1397 3.51.24 5.0.367 3.6644 3.7.609 4.8125 ~ 062= 3.9036 4.5882 3.9813 S~2 4.7314 4.6. 787 5.0'320 5.0'76 ~ 4.2710 4.7807 5.4~B4 4.3730 4.4889 5.6212 4.4749 4. 519'3 5.4902 4.5768 4.7805. 5.2830 5.6.29~ 5,950.~ 5.7;520 '5.¢'772 6.0668 5.7066 5.5520 6.0802 5.6911 5.6267 6.0299 .5.7491 5.737'3 5.935'7 5.7953 6.4'160 6.6935 5.2381 5.8494 6.2495 6.4266 5.3712 6.3310 6.2561. 5.5887 6.4126 5.9739 5.743~ 6.484~ 5.5884 5.6833 '3 ~'-4 5.7764 5.7799 5.740~ 5.7.q40 ~.8071 5.7731 5.739~ 5.8~03 5.743~ 5.7441 5.7935 5.7373 5. '7547 5.7867 5.7386 5.7737 REV RAO4 DEVI DEPT ,1084 ,090~ .4639 .8,526 1.4941 30).4156 SDSV GNDR ~V 4gOO. !71.4 3.,0566 2.6'5C, ~ 2.71-~ 5.9549 6.5484 39.5174 4.2331 0.1023 1.49~1 2.9430 2.8599 2.83.37 ~tAZI RAD2 FNOR 5,9~89 6.193Z 6.6453 2.7651 2.6423 2.853.-.9 59.68.27 4.9983 0.5866 1.01'76 6.0229 6.3119 6.7360 RB RAO3 SINI 2...5744 2.4703 2.8418 6.0569 6.3818 6.7859 237.3913 4.Z331 0.3869 2.499'7 .2. 5256 2.8809 LVP 010.~02 VEq!'r-ICATISN LZS'TZNG PAGE 12 2.9619 2.199'7 ~ 291= ~ .'71.9 5 2.6338 2.6270 3.1.65'1 3..5;-48 5 =, 5'557 3.5S12 3.4;-!29 3.5190 2.5559 3.5411 3.4374 6,5069 6,7041 ~.4647 6,7116 8,7041 6,3129 D~ .?. A 5.0.570 4.9'514 '= 6119 2,52.2.~ 5.6181 4.8.554 3.5132 SBZ 2.7059 2.7552 2.6544 3.453.3 2.8451 2.9193 2.8884 4.0!73 ~ 4~38 3.638~ 4.1608 3.8733 3.4396 ~.7624 4.9561 5..2539 5.3493 5.7290 0527 2.52~ .4070 6. 2794 3.3995 3..226.6 .3.2753 3.5499 3.5013 3.4704 6.81393 6.6885 5.9144 5.9644. 4.7030 3.270'6 2.9460 2.9201 3.3,163 3 · 6.606 3 ..4613 3.8690 : 1910 5.2380 5.5039 6.2426 3.456'7 3.3862 3.0884 3.5530 3.458'9 3.4966 6.7845 6.636B 5.6175 5'.8403 4.2763 3.0659 2,9518 2.7-406 3,4185 3.5780 3.4874 3.9595 5.2228 5.2314 5.5859 6.23]39 3.4260 3.7064 2.9398 3.5547 3. 428'0 3. 524'7 6.7399 6.5630 5.3835 5.4705 3.728.4 2.8S39 2.8782 2.5706 3.4051 3.4917 '~.':897 4.0640 5.2465 5.2865 5.6607 6.2039 PAGE 1.3 6. 160'? 5..9~64 6.3320 ~.8~99 6. 0816 5.8.34~ 6.0251 5. 8067 5.9801 S.7945 REV Pl~IZ 3EVI OEPT 5.569 43.11.'5 3q45.'a'75 .Sn 1 6.449~ 6.8798 7.234'9 4.4501 6 SO'EV ~lOl -3 5.0t02 5.7~90 3 =664 6.5216 6.995.4 6.9998 43.7683 4.9791 1.00t6 16.4346 4.9771 4.9447 4.8336 HAZ! 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TYPE 000 'TYPE OOO TYPE 000 TYPE 000 TYPE OOO TY:mE 000 TYPE 000 'TYPE 000 TYPE 000 000 C A.TE 000 C~.TE OOO CATE O04 CATE O04 CATE 00~ C A'T E 000 CATE 000 CATE 000 CATE 000 CATE ~00 006 SIZE SIZE O22 SIZE OO2 SIZE SIZE OO2 SIZE SIZE O .O ¢ SIZE 004 SIZE 004 SIZE 00! 06'5 CODE CODE 055 CODE 06.5 CODE 065 CODE 065 CODE 065 CODE O68 COOE O68 CODE 068 CODE 0~5 LVP 010.. .HO2 VE°I~I"~.TtON. ~ ,~ .,, LiSTINg PAD=,, .12 MN:M CONT EN'T$ 1.0900 CONTENTS O.OgOg CONTENTS .FCOD MNEM LA'TI MNEM SO,F: :~,~ DATA =OR.M~T ENTRY ~L ~C,K~ DATUM SP.=-CIFIC~TIO'N 'AN'~M SmRVIC': ScRV.Tr: ID ORDER ~ DE'PT SHSC GR SHSC 1.5000 T Y 1 2 11 1 1 2 1 1 0 REPR COOE 65 66 66 ~L.OCKS UNIT API Ami API A'PI FILE LOG TYPE CL.,~SS ~400 ~-.T 30 636 2.1 0 GAml '3,r; 310 O1 0 3 UNIT TYPE CATE SIZE CODE 000 .000 0.04 068 UN!'T TYPE CATE SIZE CODE DES OO-O 000 004 068 UNIT TYPE CATE SiZE CODE IN 000 000 004 068 SIZE ENTRY 0 0 8 135 0 1 SPL REPR CODE 68 68 PROCESS (OCTAL) 00040000000000 00040000000000 )~, DATA ~. ]EPT 4~5 g. aB~4 GR DE.~T ]846.Q~49 GR '105.-8750 ~9.'7500 ** FILE TRAIL'ER FILE NAMf~ : SH900T . 003 SERVIC'~ NAME :.SHDOUT VERSION ~ :O01ffO4 DATE :q7/12/'0, MAXIMUN LENGTH :0102 FILE TYPE : NEXT FTL= M.5..ME : FiLE H?-'.~O~R ~,- '.:ILE NAM~ : SH~OUT-,..~ .00~ SERV'IC.S N~-',,E :SHOCJUT LVP 0.10.:iOZ VEPIFIC,~TIgN LiS't'Zt-.',G Pa. GE 13 VEqS'[GN ~ :'901E94 DATE :...37/12/30 MAX!MUiq L:.!NGTH :01024 'mILE TYF'C! :mS PREVIOUS :ILE COMMENTS COS,GARO02.00! -'~ INFOPHATION EFCORDS ~'~ COUN: COUNTY :4NEN CDqT:ENTS CTRY: U.S.-~. MNEM "~NT :N MONT: 12 UNIT UNIT UNiT UN~'T UNIT UNIT UNIT UN'.[ T TYPE 000 TYPE 'TYPE 000 TYPE 000 'TYPE 000' TYPE 000 TYPE 000 TYPE 000 CATE 000 CATE 000 CATE 000 CATE 000 CATE 000 CATE 000 CATE 000 C ATE SIZE 017 S!ZE SIZE 007 SIZE 006 SIZE 006 SIZE O06 SIZE OZZ SIZE 002 CODE ~ .m~ CODE 065 CODE 065 CODE 065 CODE ' 065 CODF m.~ 065 CODE 065 C O.O E O..65 LVP O.lg.HO2 V:RT..F'IC~TION MNEM C 0 ."'1T ENTS DAY : MN EM C E!.,N TENTS YEAR: ~7 MN~H CONT :~NTS -RUN : T W3 MNEM C 0 t-~T E fl.'T S !OEC: 0.000~ f4NEM COt'~T ~NTS MFiN: 0.5700 ~4.N EM CONTENTS HINC: BO.O000 MN~M CON TENTS SHgS: MNE~ CgHT ~N'TS FCgD: ] .gOO0 MNEM CONTENTS %ATI: 14NEM GONT ~ENTS SOFF: ~ .EOOg ** D~TA FO2MAT R~C~RD ,~ ENTR'I ~LO.CKS 1 L [ ST I NC- SIZE ! 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AP! ,1PI :ILE T'YP~ CLASS 'qDD NO. $ ~6 ,:1 0 4 310 O1 0 4 SIZE SPL REPR PRDCESS CODE (OCTAL) 4 1 68 00040000000000 4 1 68 0~040000000000 DEPT 4q62.9~12 9EPT 3~94 ?. 4917 GR 99.7500 ~ FiLS 'TPqlLE~ ~-~'- ~iLE NAM'E : SHOOLITo SERVIC~ NA"~E :ShDOU'T VE2SIC~,.i .¢ :001.~04 9A'TE : MAXIMUM LENGTH :91024 FILE TYP! : =S NEXT ~iLE NAME : ~:-~ T,:~P:2 TR~ILE'R :~-'~: SERVZC~ NA~IE : OATE :87/12/30 DRIGIN :FLZC T~PE N~ME :qESULTS CON%INU,&TI'JN ~ :0~ NEXT T~PE N6,~ : COMMENTS :72~,55 SERVICE NAAE : SHF].L'!'JT DATE :87/12/30 ORIGIN :FLIC 2EEL NAM~ : ~2~.5S CONTZNUATIDN ~% NEXT R,~EL NAqE : C~M~NTt, .,. ., -.SCHL!j~-3E~G~R. W '~ L L SERVICES CUSTOMER TAPE LIS T,~P~. ¥'ERIFICATION LISTING FEB -. :~' Alaska Oil :& Gas Cons. Commission , ~cborage VP OlO.H02 VERIFICATION LISTING PAGE 1 # REEL HE~DER ERVICE NAME :EDIT ATE :88/01/ g RIGIN : EEL NAME :?2552 ONTINUATIgN REVIOUS REEL : OMMENTS :L~S TAPE, .~RCO ALASKA9 INC. 3H-11 API 50-0Z9-21771 .- TAPE HEADER z,*.. ERVICE NAME :EDIT ATE :88/01/ 9 RIGIN :FSIA APE NAME : ONTINUATION # :0! REVIOUS TAPE : OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3H-11 API 50-029-21771 FILE HEADER ,'~ ILE NAME :EDIT .001 ERVICE NAME : 'ERSION e : ~ATE : IAXIMUM LENGTH : "ILE TYPE : 'REVIOUS FILE : INFORMATION RECORDS INEM CONTENTS ,III IIII IIII :N : ARCO ,ALASK.As INC. IN : 3H-11 :N : KUPARUK ~ANG: 8E 'OWN: 12N ;ECT: 12 ',OUN: NORTH SLOPE ;TAT: ALASi~A tNEM CONTENTS 'RES: E .-~ COMMENTS .~. UNIT TYPE CA'TE SIZE CODE fill .ii .Il IilI IIII I! II 000 000 017 065 000 000 014 065 000 000 007 065 000 000 002 065 000 000 003 065 000 000 002 065 000 '000 011 065 000 000 006 065 UNIT 'TYPE CATE SIZE CODE IllI llII IIiI IiII 000 000 001 065 VP 010.H02 VERIFICATION LISTING P.AG E 2 SCHLUMBERGER , ALASKA COMPUTING C.-ZNTER ~ OMPANY = ARCO ALASK~ 'INC. ELL : 3H-11 IELD : KUPARUK OUNTY : NDRTH SLgPE BDRDUGH T~TE = ALASK~ 08 NUMBER aT ~KCC: 72549 UN ~1, DATE LDGGED: 1B-OEC-87 DP: J. KOHRING ASING YPE FLUID ENSITY ISCOSITY H LUID LOSS = 16.00" @ll5'CLOGGER) - BIT SIZE = 1.3.5" TO 3650'CLOGGER) = GEL = 9.40 LB/G RM = 6.10 @ 75 OF = 45.'0 S RMF = 5.30 @ 75 OF = B.5 RMC = ~.Z2 @ 75 DF = 5.4 C3 RM AT BHT = 4.904 ~95 gF IELD REMARKS: DEN=2.65, MATR)X=SAND, HC=CALIPER, BHS=OPEN, FLUID DENS=I.0, SP SHIFT ~1550' VP 010.HOZ VERIFICATION LISTING PAGE OOL TYPES/NUP~ERS: D~S 4969 DIS 1131 NSC 750 D IC 471 CNC 398 SGC 2626 TCC 404 05 NUMBER AT AKCC: 72552 UN ~2, DATE L~GGED: 25-DEC-87 DP: J. KOHR!NG ASING YPE FLUID ENSITY ISCOSITY H LUID LOSS = 10.75" @3633'CLOGGER) - BIT SIZ~ = 9.5" TO 7750'(LOGGER) = WEIGHTED POLYMER = 10.1LB/G RM = 3.82 @ 76 OF = 44.0 S RMF = 4.00 ~ 76 OF = 9.5 RMC = 3.01 @ 76 DF = 4.8 C3 RM AT BHT : 2.07Z 2146 DF IELD REMARKS: 1 1/2" STANDOFF AND 2' HOLE FINDER USED 3N DIL. M~T',RIX - SAND ATRIX DENSITY = 2.65 G/C3. HOLE CORRECTION = CALIPER. CHANGED SURFACE ROUND AND SHUT DOWN WELDERS TO GET GOOO SP FOR MAIN PASS. LOGS TIED INTO UN ~1 OIL 18-DEC-87. OOL TYPES/NUMBERS: DIS 2140 CNC 14~9 DIC 2191 SGC 2259 PGS 1026 IEM 1290 NLM 1312 . . VP 010.H02 VERIFICATION LISTING PAGE THIS DATA HAS NOT BEEN DEPTH SHI.~TED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE CEDIT. O01): (SEE FILE EDIT.O02 FOR 1.2" SAMPLED FDC/CNL DATA> RUN ~1 DUAL INDUCTT_DN SPHERICALLY FOCUSED LOG (.OIL) FIRST TO LAST READIN'~: 3650' TO 115' ~UN ~,2 ~UAL INDUCTION SPHERICALLY FOCUSED LOG C.DIL) FIRST TO LAST RE~DING: 7742' TO 4450' RUN ~1 LITHO-DENSITY COMPENSATED LOG (.LOT) F~RST TO LAST READING: 3636' TO 115' RUN J2 FORMATION DENSITY COMPENSATED LOG (.FDC) FIRST TO LAST RE6DING: 7716' Tg 7050' RUN ~1 COMPENSATED NEUTRON LOG (.CNL) FIRST TO LAST READING: 3618' TO 115' RUN ~2 COMPENSATED NEUTRON LOG C oCNL) FIRST TO LAST RE~DING: 7701' TD 7050' vP 010.HOZ VERIFICATION LISTING PAGE DATA FORMAT RECORD ~ NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 1 66 1_ 8 4 73 60 9 4 65 .liN 16 I 65 1 0 I 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API API API 6PI FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS EPT FT O0 000 O0 R OIL GAPI O0 310 01 P OIL MV O0 010 01 FLU DIL OHMM 00 220 01 LD OIL OHMM O0 120 46 LM OIL OHMM O0 120 44 ENS OIL LB O0 635 21 GR LOT GAPI O0 310 01 HOB LOT G/C3 O0 350 02 PHI LDT PU O0 890 O0 RHO LOT G/C3 O0 356 O! EF LOT O0 3,58 01 LS LDT O0 000 O0 S.S LD'T O0 000 O0 SHY LOT V O0 DO0 O0 SHV LDT V O0 000 O0 L LOT CPS O0 354 01 S LOT CPS O0 354 01 U LOT CPS O0 354 O1 I'TH LD'T CPS O0 354 01 S! LOT CPS O0 000 O0 S2 LOT CPS O0 000 O0 ALI LD'T IN O0 280 01 ENS LOT LB O0 635 .Z1 R FDC GAPI O0 310 01 HOB FDC $/C3 O0 350 02 ~RHO FDC G,/C3 O0 356 01 ,PHI FDC PU O0 B90 O0 ALI FDC IN O0 280 01 'ENS FDC LB O0 635 21 ;R CNL GAPI O0 310 O1 IPHI CNL PU O0 iB90 O0 'NRA CNL O0 420 O! iTNR CNL O0 000 O0 :CFT CNL CPS O0 000 O0 :CNT CNL CPS O0 000 O0 PROCESS CODE COCTAL) ! 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 000000'00000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 OOO000000OO000 ! ~B 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 000000000000'00 I 68 00000000000000 ! 68 O0000OO0000000 ! 68 00000000000000 ! 68 00000000000000 ! 68 O00OO00'O000000 I 68 00000000000000 I 68 00000000000000 VP OIO.HOZ VERIFICATION LISTING FTC CNL CPS O0 000 00 0 NTC CNL CPS O0 000 O0 0 ENS CNL LB O0 635 21 0 EPT 7767.5000 LD 1.8113 HOB -999.2500 DPHI L.S -999.2500 ~SS L -999.2500 LS S1 -999.2500 SS2 R 101.1875 RHOB ALI 9.3984 TENS NRA 3.6537 RTNR FTC 506.2590 CNTC EPT 7700.0000 GR LD 1.7641 ILM HOB -999.2500 OPHI LS -99'9.2500 QSS L -999.2500 LS S! .-'999.2500 SS2 R 107.1250 RHOB ALI 9.4609 TENS NRA 3.5747 RTNR FTC 507.3817 CNTC EPT 7600.0000 GR LO 2.4293 TLM HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS S1 -99'9.2500 SS2 R 105.4375 RHOB ALI 8.7656 'TENS NRA 3.4933 RTNR FTC 54.1.3417 CNTC ,EPT 7500.0000 GR LO 2.7914 'ILM HOB -999.250,0 OPHI !LS -999.2500 QSS ,L -999.2500 LS ;SI -999.2500 SS2 ,R 94.1250 RHOB ,ALI 8.7969 TENS 'NRA 3.3606 RTNR :FTC 545.1989 CNTC tEPT 7400.0000 OR iLO 17.4177 ILM :HOB -999.2500 OPH! 101.1875 SP 1.9592 TENS -99'9.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CALI 2.4590 DRHO 3370.0000 SR 3.7660 RCFT 1818.6772 TENS 107.1250 SP 1.8350 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI 2.3770 DRHO 6~88.0000 OR 3.7069 RCFT 1731.5522 TENS 10:5.4375 SP 2.4585 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CAL! ,Z.41,41 ORHO 6424.0000 GR 3.7119 RCFT 189,6.3579 TENS 94.125,0 SP 2.9476 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI 2..,~2'97 DRHO 6248.0000 GR 3.55'93 ~CFT 1810.1965 TENS 62.9062 SP 17.0869 TENS -999.2500 DRHO -65. 3370. -999. -999. -999. -999. O. 10'1. 463. 3370. -93. 6488. -999. -999. -999. -999. O. 107. 50'1. 6488. -19. -999. -999. -999. -999. O. 105. 481. -11. 6248. -999. -999. -999. -999. O. 94. 508. 6248. -25. 6264. -999. 8750 0000 2500 2500 2500 2500 0718 1875 9021 0000 SO00 0000 2500 2500 2500 2500 0464 1250 3453 0000 0000 0000 2500 25OO 2500 2500 04'30 4375 ,49'39 0000 1250 0000 2500 2,500 2500 2500 0313 125'0 $541 0000 2500 0000 2500 PAGE 6 I 68 00000000000000 i 68 00000000000000 ! 68 00000000000000 SFLU 2.5763 SGR -999.2500 PEF -999..2500 SSHV -999.2500 LZTH -999.2500 TENS -999.2500 DPHI 14.2992 NPHI 4,2.6856 RCNT 185'7.0552 SFLU 3.1451 SGR -999.25'00 PEF -999.2500 SSHV -999.2500 LITH -999.2500 TENS -999.2'500 OPH! 13.3523 NPHI 40.2103 RCNT 1765.2373 SFL'U 36.1696 SGR -999.2500 PEF -999.2500 SFLU 1.9486 SGR -999.2500 PEF -999.2500 SSHV -999.2500 LITH -999.2500 TENS -999.2500 DPHI 16.5483 NPHI 43.1374 RCNT 1661.5247 SFLU 2.2265 SGR -999.2500 PE~ -999.2500 SSHV -999.2500 LITH -999.2500 TENS -999.2500 DPHI 11.5767 NPHI 44.6760 RCNT 1769.4001 VP 010.flOZ VERIFICATION LISTING PASE 7 LS -99'9°2500 QSS -999.2500 L -999. 2500 LS -999. 2500 SI -999.2500 SS2 -999.2500 R 62.9062 :~HOB 2.2461 ALI 8.9375 TENS 6264.0000 NRA 2.B733 RTNR 2.8889 FTC $31.2062 CNTC 2237.3901 EPT 7300.0000 GR 58.2813 LO 25.2989 ILM 28.1963 HOB -999.2500 DPH! -999.2500 LS -999.2500 OSS -999.2500 L -999.2500 LS -999.2500 S1 -999.2500 SS2 -999.2500 R 58.2813 RNOB 2.5273 ALI 8.9609 TENS 6244.0000 NRA 3.2312 ~TNR 3.2877 FTC 713.9752 CN'TC 2093.2280 EPT 720.0.0000 SR 11.4.9375 LO 1.6511 ILM 1.7552 HOB -999.2500 OPHI -999.2500 ,LS -999.2500 ~SS -999.2500 L -999.2500 LS -999.2500 S1 -999.2500 SS2 -9'99.2500 ,R 114.9375 RHOB 2.2949 ALI 9.1328 TENS 5628.0000 NRA 3.7012 RTNR 3.9039 FTC 453.1132 CNTC 1638.5452 ~EPT 7100.0000 GR 113.7500 'LD Z.1675 ILM 2.,,1997 .HOB -999.2500 DPHI -99'9.2500 tLS -999.2500 QSS -'999.2500 .L -999,°2500 LS .-999.2500 ;51 -999.2500 SS2 .-999.2500 ;R 113.7500 RNOB 2.3,633 :ALI g. 6250 TENS 5960.0000 'NRA 3. 7179 RTNR 3.8364 :FTC 469.3691 CNTC 1'733.9089 )EPT 7000. 0000 GR 262. 0000 ;LO 2.9156 ILM 3.0773 ~HOB -999.2.500 DPHI -999.2500 ILS -999.2500 QSS -999.2500 .L -9'99.2500 LS -'999.2500 ;SI -999.2500 SS2 -999.2500 ;R -999.2500 RHOB -999.2500 :ALI -999.2500 TENS -999.2500 'NRA -999.2500 RTNR -999.2500 ~FTC -999. 2500 CNTC -999.25'00 )EPT 6900.0'000 GR 15g.6250 :LO 2.9435 ILM 3..1016 LSHV LU CALI DRHO GR RCFT TENS SP TENS DRHO LSHV LU CALI DRHO GE RCFT TENS SP TENS ORHO LSHV LU CALI DRHO GR RCFT TENS SP TENS ORHO LSHV LU CAL! 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LS -999.2500 .QSS L -999.2500 kS S1 -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 6600.0000 ER LO 2.5311 ILM HOB -999.2500 OPHI ES -999.2500 QSS k -999.2500 LS S1 -999.2500 ,SS2 R -99'9.2500 RHOB ALI -999.2500 'TENS NRA -999.2500 RTNR FTC -999.2500 CNTC ,EPT 6500.0000 GR LO 3.6687 ILM HOB -999.2500 OPHI ILS -999.2500 QSS L -'999.2,500 LS $1 -999.2500 SS2 R -999.2,500 RHOB ALI -999.2500 TENS 'NRA -999.2500 RTNR FTC -999.2500 CNTC LISTING -999.2500 gRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 SR -999.2500 RCFT -999.2500 TENS 120.8125 SP 3.2845 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CAL! -999.2500 DRHO -999.2500 GR -999.2500 RC~T -999.2500 TENS 124.4375 SP 3.8369 TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 122.4375 SP 2.6314 'TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 113.8125 SP 3.7373 'TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -99'9.2500 CALI -999.2500 ORHO -99'9.2500 SR -999.2500 RCFT -999.2500 TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -7.1250 5588.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -5.7500 5472.0000 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -3.7500 5508.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.,2500 -~2.8750 5380.0000 -999.2500 -999. Z500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SGR PEF SSHV LITH 'TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT PAGE -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~.0168 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.0361 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 2.9~62 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.2679 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 IEPT 6~00.0000 GR 113.8750 SP -41.6250 SFLU 3.7002 YP 010.H02 VERIFICATION LISTING PAGE 9 LO 3.6391 ILM HOE -999.2500 DPHI LS -999. 2500 QSS L -999.2500 LS S1 -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 6300.0000 GR LO 4.0323 ILM HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS S1 -999.2500 SS2 R -999.2~00 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 6200.0000 GR LD 4.1573 ILN HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS Si -999.2500 'SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC 'EPT 6100.0000 GR LO ,3.5488 'ILM HOB '-999.2500 OPHI )LS -999.2500 QSS .L -999.2500 LS ;$1 -999.2500 SS2 ;R -999.2500 RHOB iALI -999.2500 TENS 'NRA --999. 2500 RTNR :FTC -999. 2500 CNTC ~EPT 6000.0000 GR iLO 3.6352 ILM :HOB -999.2500 OPHI )LS -999.2500 QSS ,L -999.2500 LS ;S! '-999.250'0 SS2 ;R -999.2500 RHOB ;ALI -999.2500 ITEMS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC 3.6¢~0 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ORHO -999.2500 GR -999.2500 REFT -999.2500 TENS 77.5625 SP 4.3440 TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 ~R -999.2500 REFT -999.2500 TENS 91.2500 SP 4.1925 'TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALl -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 104.2500 SP 3.5850 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999,.2500 RC~T -'999.2500 TENS 101.1250 SP 3.6653 TENS -999.250'0 DRHO -999.2500 LSHV -999.2500 LU -9'99.2500 CALI -999..2500 DRHO -999.2500 GR -999.2500 REFT -999.2500 TENS 5252. -999. -999. -999. -999. -999. -999. -999. -9gg. -62. 5128. -99'9. -999. -999. -999. -999. -999. -999. -999. -40. 5240. -999. -999. -999. -999. -999. -999. -999. -999. -39. 5012. -999. -999. -999. -999.. -999. -999. -999. .-999. .-42,~ 4912. -999. -999. -999. -999. -999. -999. -'999. -999. DO00 2500 2500 2500 2500 2500 2500 2500 2500 0000 0000 2500 2500 2500 2500 2500 2500 2500 2500 6250 0000 2500 2500 2500 2500 2500 2500 2500 2500 375'0 0000 Z500 ,2500 2500 ,2500 2500 2500 2500 2500 500O 0000 2500 2500 2500 2500 2500 2500 2500 2500 SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RENT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RENT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6.3095 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4.0952 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.6770 -999.25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 3.7096 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -99'9.2500 VP 010.H02 VERIFICATION LISTING PAGE 10 EPT 5900.0000 GR LO 2.9750 ILM HOB -999.2500 DPHI tS -999.2500 ~SS k -999.2500 LS SI -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NR/) -999.2500 RTNR FTC -999.2500 CNTC EPT 5~00.0000 GR LD 3.6519 ILM HOB -999.2500 DPHI LS -999.2500 QSS L -999.2500 LS S! -999.2500 552 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 5700.0000 jR LO 2.1337 !LM HOB -999.2500 DPHI !LS -999.2500 QSS ,L -999.2500 LS ;S! -999. 2500 SS2 ;R -99'9.2500 RHOB ;ALI -999.2.500 TENS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC )EPT 5600.0000 GR ~LD 3. 2036 ILM ,~H08 -999.2500 DPHI ILS -999.2500 QSS .L -999.25!00 LS ;$1 -999.2500 SS2 ;R -999.2500 RHOB ;ALI -999.2500 TENS 'NRA -999.2500 RTNR . ;FTC -999.2500 CNTC )EPT 5500.0000 GR :LO 2.6741 [LM :HOB -999.2500 OPHI iLS -999.2500 QSS .L -999.2500 LS ;51 -999.2500 SS2 ;R -99'9.2500 RHOB ' ~ALI · -999. 2500 'TENS rNRA -999.2500 RTNR ~FTC -999.2500 CNTC 97.6250 SP 2.9978 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHD -999.2500 GR -999.2500 RCFT -999.2500 TENS 106.6875 SP 3.4635 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.,2500 GR -999.2500 RCFT -999.2500 TENS 111.7500 SP 2.1808 TENS -99'9.2500 DRHO -999.2500 LSHV '-999.2500 LU -999.2500 CALI -999.2500 9RHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 113.2500 SP 3.1459 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 112.3750 SP 2.5086 'TENS -999.2500 DRHO -99'9.2500 LSHV -999.2500 LU '-999.2500 CALI '-999.2500 9RHO -999.2500 GR -999.2500 RCFT -999.2500 TENS -38.1250 ¢912.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -40.3750 5000.0000 -999.2500 -999.2500 -999.2500 -ggg.2500 -999.2500 -999.2500 -999.2500 -999.2500 -30.6250 4820.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -37.1250 4728.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -33.5000 4568.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF .SSHV LITH 'TENS DPHI NP~II RCNT SFLU SGR PEF SSHV LITH TENS OPHI NPHI RCNT 3.1134 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.4160 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.,2500 -999.2500 -999.2500 2.2512 -999.2500 -999.2500 -999.2500 -999.2.500 -999.2500 -999.2500 -999.2500 -999.2500 3.0205 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 Z.6520 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 VP OlO.H02 VERIFICATION LISTING PAGE EPT 5400.0000 GR LO 3.3008 ILM HOB -999.2500 OPHI LS -999.2500 ~S$ L -999.2500 LS SI -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 5300.0000 9R LO 2.5537 ILM HOB -999.2500 OPM! LS -999.2500 QSS L -999.2500 LS S1 -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 5200.0000 GE LD 1.9098 ILM HOB -999.2500 OPHI LS -'999.2500 qSS L -999.2500 LS S! -999.2500 552 R -999.2500 RHOB ALI -999.2500 'TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 5100.0000 'GR LO 2.10'99 ILM HOB -999.2500 DPH'! LS -999.2500 QSS L -999.2500 LS S! -999.2500 SS2 R -999.2500 RHDB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 5000.0000 GR LO 2.8278 ILM HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS S1 -999.2500 SS2 ,R -999.2500 RHOB ALI -999.2500 'TENS NRA -999.2500 R'TNR 140.1250 SP 3.3330 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.1500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 156.1250 SP 2.5551 TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ORHO -999.2500 GR -999.1500 RC~T -999.2500 TENS 102.5625 SP 1.9861 TENS -9919.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ~RHO -999.2500 GR -999.2500 RCFT -999.25'00 TENS 107.1875 SP 2.1000 TENS -999.2500 DRMO -999.2500 LSHV -999.2500 LU -99'9.2500 CALI -999.2500 ORHO -99'9.2500 GR --999.2.500 RCFT -999.2500 TENS 85.0625 SP 2.8101 TENS -999.2500 ORHO -999.2500 L.SHV -9'99.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 'GR -999.2500 RCFT -44.3750 4472.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -35.3750 4480.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -28.0938 4612.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -31.1250 .4308.0000 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999.2590 -'999.2500 -27.1.250 4/+68.0000 -999.2500 -999.2500 -999. 2500 -999.2500 -999.2500 '-999.2500 -999.2500 SFLU SGR PEF SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT 3.6203 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.1500 -999.Z$00 -999.2500 2.7828 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.1802 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 1.9808 -999.2500 -999.2500 -999.2500 -999.250.0 -999.2500 -999.2500 -999.2500 -999..2500 2.4816 -99'9.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999..2500 -999.2500 -999.2500 YP §lO.H02 VE~I~ICSTION LISTING FTC -999.2500 CNTC EPT 4900.0000 GR LD 2.6081 ILM HOB -999.2500 DPHI LS -999.2500 $SS L -999.2500 LS SI -999.2500 SS2 R -999.2500 RHO~ ALI -999.2500 TENS NRA -999.2500 ~TNR FTC -999.2500 CNTC EPT 4800.0000 GR LO 2.9285 ILM HOB -999.2500 OPHI LS -999.2500 QSS .L -999.2500 LS S1 -999.2500 SS2 ,R -999.2500 RHgB :ALI -999.2500 TENS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC ~EPT 4700.0000 GR iLO 3.0764 ILM :HOB -999.2500 DPH! ILS -999.2500 QSS .L -999.2500 LS ;S1 -999.2500 5S2 ;R -999.2500 RHO~ ;ALI -999.2500 TENS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC )EPT 4600.0000 GR :LD 3.5783 ILM ~HOB -999.2500 DPHI )LS -99'9.2500 QSS .L -999.2500 LS ;S1 -999.2500 SS2 ;R -999.2500 RHOB ;ALI -999.2500 TENS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC )EPT 4500.0000 GR CLD 4.0815 ~HO8 -999.2500 OPHI ~LS -999.2500 OSS .L -999.2500 LS 5,S1 -999.,2500 SS2 DR -999.2500 RHOB ~ALI -99'9.2500 TENS -999.2500 TENS 111.1250 SP 2.5483 TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CAL[ -999.2500 DRMO -999.2500 GR -999.2500 RCFT -999.2500 TENS 89.3750 SP 2.7826 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CAL! -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 113.9375 SP 3.0081 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ORHO -999.2500 GR -999.2500 RCFT -'999..2500 TENS 118.3750 SP 3.4862 TENS -999.2500 ORHO -999.2500 LSHV -999.2500 LU -999.2500 CAL! -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS 109.2500 SP 3.9433 TENS -99'9.2500 ORHO -999..2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999.2500 -31.1250 4148.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -31.0000 4060.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -~99.2500 -999.2500 -99'9.2500 -32.12.50 3984.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -31.750'0 3854.0000 -999.2500 -999.2500 -999. ,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250'0 -33.7500 3820.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 SFLU SGR SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEP SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SGR PEF SSHV LITH TENS OPHI NPHI PAGE 2.4900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.6713 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.8559 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.4100 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 3.7119 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12 VP 010.H02 VERIFICATION LISTING PAGE 13 NRA -999. 2500 RTNR FTC -999. 2500 CNTC EPT 4~00.0000 GR LD -999. 2500 IL~ HOB -999.2500 DPHI LS -999.2500 QSS L -99 9° 2500 LS SI -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999. 2500 CNTC EPT 4300.0000 GR LD -999.2500 HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS SI -999.2500 SS2 R -999.2500 ~HOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -99'9. 2500 CNTC EPT 4200.0000 GR LD -999.2500 ILM HOB -999.2500 DPHI :LS -999.2590 ~SS L -999.2500 LS S1 -999.2500 SS2 ,R -999. 2500 'RHO:B ,.ALI -999.2500 TENS 'NRA -999. 2500 'R'TNR :FTC -999.2500 CNTC ~EPT 4100.0000 GR :LO -'999. 2500 ,ILM :HOB -999.2500 DPHI iLS -999.2500 QSS .L -99'9.2500 LS ;S1 -999.2500 5S2 ;R ,-999.2500 RHOB ',ALI -999.2500 'TENS 'NRA -999.2500 ~:TNR ',FTC -999.2500 CN'TC I'EPT 4000.0000 GR :LO -999.2500 ILM :HOB -999.25'00 DPHI tLS -99'9. 2500 QSS .L -999.2500 LS ;S1 -999.2500 SS2 ;R -99'9.25'00 R'HOB -999.2500 RCFT -999.2500 TENS -999.2500 SP -999.2500 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ~RHO -999.2500 GR -999.2500 RCFT -999.2500 TENS -999.2500 SP -999.2500 TENS -999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999..2500 TENS -999.250'0 SP -999.2500 TENS -'999.2500 DRHO -999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2500 ORHO -999.2500 GR -999.2500 RCFT -999.2500 TENS -999.2500 SP -999.2500 TENS -999.2500 DRHO -999.2500 LSHV ,-999.2500 LU -999.2500 CAL! -999.2500 DRHO -999.2500 GR -999.2500 RCFT -999.2500 TENS -999.2500 SP -999.2500 TENS ,-9'99.2500 DRHO ,-999.2500 LSHV -999.2500 LU -999.2500 CALI -999.2.500 DRHO -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -.999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999,.2500 -999.2500 -999.2500 -'999.2500 -99'9.2500 RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SG~ PEF SSHV LITH TENS DPHI -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.~500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.250,0 -999.2500 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 -999.2500 VP OlO.H02 VERIFICATION LISTING PAGE ALT -999.2500 TENS NRA -399.2500 RTNR FTC -999.2500 CNTC EPT 3900.0000 GR LD -399.2500 ILM HOB -999.2500 OPHI LS -999.2500 QSS L -999.2500 LS S1 -999.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC EPT 3800.0000 GR LO -999.2500 HOB -999.2500 DPHI LS -999.2500 QSS L -999.2500 LS S1 -999.2500 SS2 R -999.2500 RHO8 ~LI -999.2500 TENS NRA -999.2500 RTNR FTC -999.2500 CNTC ,EPT 3700.0000 SR ILO -999.2500 MOB -999.2500 OPHI !LS -999.2500 QSS .L -999.2500 LS ;51 -999.2500 SS2 ;R -999.2500 RHO~ ;ALI -999.2500 TENS 'NRA -999.2500 RTNR ;FTC -999.2500 CNTC tEPT 3600.0000 GR :LD 4.8389 ILM ~'HOB 2.2187 DPH! ILS 0.0000 QSS .L Z33.6250 LS ;51 240.6250 S52 ;R -999.25'00 RHOB ;ALI -999.2500 TENS 'NRA 4.1929 RTNR :FTC 394.0579 CNTC )EPT 3500.0000 GR :LO 5o4810 ILM :HOB 2.1230 DPHI )LS -0.0078 QSS .L 303.2500 LS ;SI 262.7500 SS2 -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. -999. --999. - 9'99. -999. 72. 26. O. 435. 340. -999. -999. 3. 1590. 7'7. 5. 31. O. 562. ,374. 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 2500 25O0 2500 2500 2500 2500 3125 7952 0254 0195 750O 0000 2500 2500 8868 2000 2500 3113 7871 0273 0000 7500 RCFT TENS SP TENS ORHO LSHV LU CALI DRHO GR RCFT TENS Sp TENS LSHV LU CALI ORHO GR RCFT TENS SP 'TENS ORHO LSHV LU CALT DRHO GR RCFT TENS SP 'TENS ORHO LSHV LU ORHO GR RCFT TENS SP TENS DRMO LSHV LU CALI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --9919.2500 --999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -39.6563 2484.0000 0.0107 1188.0000 40~.2500 14.3516 -999.2500 79.3024 344.8881 3164.0000 -33.6250 2530.0000 0.0513 1187.0000 517.5000 15.1250 NPHi RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI. RCNT SFLU SGR PEF SSHV LITH TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 .4.6150 79.3024 2.9609 1147.0000 119.4375 3164.0000 -999.2500 50.8451 1694.9395 5.5563 7'8.3474 2.4629 1147.0000 170.0000 3180.0000 ~P 010.H02 VERIFICATION LISTING PAGE 15 R -999.2500 RHgB ~LI -99 9. 2500 TENS NRA ~.2094 qTNR FTC 34~. 5958 CNTC EPT 3400.0000 GR LD 4.4546 HOB 2.1484 DPH! LS -0.0098 L 266.2500 LS SI 244.5000 $52 R -999.2500 RHOB ALI -999.2500 TENS NRA 4.0137 RTNR FTC 410.0538 CNTC EPT 3300.0000 GR LO 5.6364 ILM HOB 2.1758 DPHI LS -0.0166 QSS L 251.0000 LS S1 241.3750 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA 3.8217 RTNR FTC 65~.8720 CNTC EPT 3200.0000 GR LO 4.9858 ILM HOB 2.2012 DPHI LS -0.0029 QSS L :240. 3750 LS S1 239.6250 SS2 R -999.2500 RHOB ALI -999. 2500 'TENS NRA 4.0795 RTNR FTC 432.T060 CNTC rEPT 3100.0000 GR LO 4.6735 HOB 2.1719 DPMI LS -0.0146 QSS L 253.2500 LS $1 246.5000 SS2 R -999.2500 RHOB ALI -999.2500 TENS 'NRA 3.8851 RTNR :FTC 420.8769 CNTC ~EPT 3000.000'0 GR :LD 6.3266 I'LM IHOB 2.1816 OPHI ILS 0.0063 'QSS .L 248.2500 LS -999. -999. 4. 1450. 83. 4. 30. O. 496. 352. -999. -999. 4. 1626. 6 '6. 5. 28. O. ~71. 348. -999. -999. 3. 1691. 63. 4. 27. O. 448. 346. -9'99. -999. ¢. 1716. 7 2. 4. 28. O. 475. 350. -999. -999. 3. 1618. 70. 6. 28. O. 460 · 2500 2500 4773 6633 1875 3832 2734 0146 7500 2500 2500 2500 0943 2139 5000 6197 7109 0093 5000 2500 2500 2500 8167 0859 25O0 8938 0996 0049 50O0 2500 2500 2500 3725 1135 3125 6593 8574 0151 0'000 5000 2500 2500 8727 '7852 8750 1349 3203 0078 0000 ORHO GR RCFT TENS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS SP TENS DRHO LSHV LU CALI DRHO RCFT TENS SP TENS DRHO LSHV LU CALI ORHO GR RCFT TENS SP 'TENS DRHO LSHV LU CALI ORHO RCFT 'TENS SP TENS ORHO LSHV LU -999.2500 78.3476 333.1082 3180.0000 -3~.5938 2.470.0000 0.0103 1188.0000 460.7500 14.6094 -999.2500 90.8056 407.8406 3234.0000 -49.3750 2370.0000 0.0078 1188.0000 440.7500 15.1094 -999.2500 67.8490 440.3169 2810.0000 -62.2813 2394.0000 0.0078 1188.0000 416.5000 15.2109 -999.2500 76.7193 425.2584 2984.0000 -43.31~5 2330.0000 0.0122 1187.0000 .443.2500 14.4297 -999.2500 75.9935 419.0015 2840.0000 -66.1250 2250.0000 0.0049 1188.0000 423.5000 DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHZ RCNT SFLU SGR PEP SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH -999.2500 50.7789 1507.6702 4.2258 90.8056 2.7871 1147.0000 167.1250 3234.0000 -999.2500 67.6415 1677.7083 5.6357 67.8490 2.7305 1147.0000 137.7500 2810.0000 -999.2500 43.6870 1779.7249 4.7600 76.7193 2.7969 1147.0000 129.1250 2984.0000 -999.2500 48.3559 1783.8145 4.425'1 75.9935 2.9316 114'7.0000 129.62~0 2840.0000 -999.2500 45.1715 1701.7102 7.0463 73.9442 3.505'9 1167.0000 1'19.8125 CP 010.H02 YERIFICATION LISTZNG PAGE 16 S1 233.6250 SS2 344 R -999.2500 ~HOB -999 ALI -999.2500 TENS -999 NRA 3.9032 RTNR 4 FTC 475.0847 CNTC 1814 EPT 2900.0000 GR 79 LO $.4820 [LM 5 HOB 2.2129 OPHI 2.6 LS -0.0122 ~SS 0 L 229.7500 LS 432 S1 233. 5000 5S2 336 R -999.2500 ~HOB -999 ALI -999.2500 TENS -999 NRA 3.8225 RTNR 3 FTC 441.3611 CNTC 1696 EPT 2800.0000 GR 36 LO 6.6429 ELM 6 HOE 2.0723 DPHI 34 LS 0.0005 QSS 0 L 296.5000 LS 549 S1 234.8750 SS2 346 R -999.2500 RHO8 -999 ALI -999.2500 TENS -999 NRA .3. 8792 RTNR 4 FTC 452.3318 CNTC 1704 EPT 2700. 0000 'GR 62 LD 8.2657 ILM 7 HOB 2.1973 DPHI 27 LS 0.0176 QSS 0 t 238. 5000 LS .439 S1 231.25'00 SS2 332 ,R -999.2500 RHrJB -999 ALI -999.2500 TENS -999 'NRA 3.7558 RTNR 3 .FTC 444.6795 CNTC 1635 'EPT 2600.0000 GR 29 'LO 70.7834 HOB 1.8232 DPHI 50 'LS 0.0439 ~SS 0 ,L ¢65.7500 LS 854 ,SI 242.0000 SS2 360 ,R -999.2500 RHOB -999 :ALI '-999.2500 TENS -999 'NRA '4.5955 RTNR 5 ,FTC 341.9723 CN'TC 1564 IEPT 2500.0000 GR 51 :LO 16.4257 ILM 15 :HOB 2.'0996 OPH! 33 ILS -0.0161 QSS 0 .5000 .2500 .2500 .2692 .1982 .4375 .3032 .3672 .0044 .2500 .5000 .2500 .2500 .9909 .8425 .1250 .6062 .8633 .0063 .0000 .2500 .2500 .2500 .3077 .8638 .5313 .6285 .3438 .0078 .7500 .7500 .2500 .2500 .9245 .0874 .5469 .9271 .0488 .0322 .0000 .2500 .2500 .2500 °0233 .9898 .3125 .9125 .3008 .0313 CALI gRHD GR RCFT TE NS SP TENS ORHO LSHV LU CALI DRHO GR RCFT TENS SP TENS ORHO LSHV LU CALI DRHO GR TENS SP TENS ORHO LSHV LU CALI ORHO GR RC F'T TENS SP TENS ORHO LSHV LU CALI ORHO GR RCFT TENS Sp TENS DRHO LSHV -999. 73. 490. 2820. -49. 2164. O. 1188. 15. -999. 2850. -86. 2170. 1187. 504. 13. -999. 33. 448. 2790. -54. 2154. 1188. 15. -999. 76. 450. 2734. -62. 2064. --0. 1187. 775. -999. '30. 314. 2660 o -77. 2005. O. 1187. 0781 2500 9442 4877 0000 0313 0000 0005 0000 7500 0391 2500 2291 9858 0000 2500 0000 0093 0000 7500 8984 2500 8033 9858 0000 5625 0000 0044 0000 7500 0859 2500 3853 7610 OOOO 0938 0000 0176 0.000 0000 4141 2500 3291 6732 0000 375'0 0000 0039 0000 TENS DPHI NPHI RCNT SFLU PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV L[TH 'TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS OPH[ NPH! RCNT SFLU SGR PEF SSHV 2820.0000 -999.2500 45.6736 1920.9836 5.9237 82.2291 2.9082 1147.0000 119.8750 2850.0000 -999.2500 43.7347 1799.0645 6.8663 33.8033 3.3008 1147.0000 153.2500 2790.0000 -999.2500 45.3211 1734.1438 6.8266 76.3853 3.2383 1147.0000 116.1875 2734.0000 -999.2500 42.4903 1670.724! 57.3969 '30o3291 1.8721 1147.0000 308.7500 2660.0000 .-999.2500 5'7.7073 1555.9792 18.9483 53.8531 2.8477 1147.0000 VP 010.H02 VERIFICATIQN LISTING PAGE 17 L 287.7500 LS S1 243.0000 SS2 R -993.2500 RHOB ALZ -999.2500 TENS NRA 3.6983 RTNR FTC 481.5215 CNTC EPT 2400.0000 GR LO 13.0175 ILM HOB 2.1523 OPHI LS -0.0142 L 256.2500 LS S1 236.0000 SSZ R -999.2500 RHDB ALI -999.2500 TENS NRA ¢.0074 RTNR FTC 399.3188 CNTC EPT 2300.0000 GR LD 16.1048 ILM HOB 2.0020 DPHI LS -0.0034 QSS L 33.5.5000 LS 51 236.6250 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA :3.9533 RTNR FTC 436.90:12 CN'TC EPT 2200.0000 GR LD 22.9685 ILM HOB 2.0536 DPHI LS 0.0034 ~SS L 305.5000 LS $1 236.8750 5S2 ,R -99'9. 2500 RHOB ALI -99'9. 2500 'TENS NRA 3.9261 RTNR FTC 429. 2976 CNTC EPT 2100.0000 GR LO 8.6746 ILM HOB 1.9443 DPHI ,'LS 0.0273 QSS L 372.2500 LS ,51 236.0000 SS2 R -999.2500 RHOB ALI -99'9.2500 TENS 'NRA 4.6794 RTNR FTC 315.8243 CNTC ~EPT 2000.0000 GR :LO 36.94'78 ILM ~HOB 1.9717 DPHI 537.3000 3¢5.5000 -999.2500 -999.2500 3.5968 1717.1584 63.1875 12.2381 30.1270 0.0112 ¢80.2500 340.7500 -999.2500 -999.2500 4.4792 160.8.4756 53.8125 15.8904 39.2090 0.0088 625.0000 352.2500 -999.2500 -999.2500 4.0588 1675.2576 53.9062 21.1210 35.7422 0.0186 565.0000 344.5000 -999.2500 -999.2500 ¢.1000 1713.30,64 71.0625 ~.1157 42..6758 0.0010 682.5000 358.2500 -99'9.2500 -999.250.0 ,4.56T6 143,3.3596 45.9062 3'7.1628 41.0645 LU CALI ORHO GR RCFT TENS Sp TENS ORHO LSHV LU CALI DRHO GR RCFT TENS SP TENS DRHO LSHV LU CALI ORHO GR RCFT TENS SP TENS ORHO LSHV LU CALI ORMO GR RCFT TENS' SP TENS DRHO LSHV LU CALI ORHO GR RC~T TENS SP TENS ORHO 498.7500 13.91~1 -999.2500 53.9531 484.4561 2694.0000 -71.3125 2025.0000 -0.0015 1187.0000 447.7500 14.3203 -999.2500 71.7979 403.1289 262¢.O00O -77.5625 1915.0000 -0.0122 1187.0000 579.0000 13.9297 -999.2500 51.978.5 427o&497 2660.0000 -74.5625 1960.0000 -0.0078 1186.0000 518.5000 14.15,62 -999.2500 5,4.9720 417.6680 2660.0000 -67.1875 1900.0000 -0.0176 1186.0000 '621.0000 14.2109 -999.2500 69.3026 280.7546 2480.0000 -81.2500 1855.0000 -0.0083 LITH TENS OPHI NPHI RCNT SFLU SGR PEP SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPMI NPH! RCNT SFLU SGR PEF SSHV LITH 'TENS OPHI NPHI RCNT SFLU SGR PEF 153.2500 2694.0000 -999.2500 42.0022 1850.6997 11.2393 71.7979 3.0469 1147.0000 126.7500 2624.0000 -999.2500 47.46~8 1636.6150 17.7002 51.9785 2.4297 1146.0000 195.7500 2660.0000 -999.2500 46.6605 1744.6655 18.9483 54.9720 '2.6387 1147.0000 157.2500 2660.0000 -'999.2500 46.05'48 1820.9041 7.8199 69.3026 2.3223 1147.0000 207.375'0 2480.0000 -999.2500 59.8215 1513.~204 34.1727 48.1888 2.7754 VP OIO.HOZ VERIFICAITIgN LISTING PAGE 18 LS 0.0176 QSS L 358.5000 LS S1 241.0000 SSZ R -999.2500 RHDB Ali -999.2500 TENS NRA 4.0810 ~TNR FTC 392.9627 CNTC EPT 1900.0000 LO 21.8240 HOB 2.0605 OPHI LS -0.0068 QSS L Z98.5009 LS S1 231.1250 SS2 ,R -')99. 2500 RHOB ALl: -999.2500 TENS NRA 3. 3986 RTNR FTC 443.4536 CNTC ,EPT 1800.0000 6R LO 92.8234 ILM 'HOB Zo0605 DPNI !LS 0.0029 QSS ,L 304.0000 LS iS1 232.7500 552 ;R -99'9.25'00 RHOB :ALT -999.2500 TENS 'NRA 3.6143 RTNR :FTC 45S.5867 CNTC ~EPT 1700.0000 'GR :LO 65.7579 ILM :HOB 1.9736 DPHI ILS 0.0049 QSS ,L 358.2500 LS ;51 2~2.6250 SS2 ;R -999.2500 RHDB ;ALI -999.2500 TENS 'NRA 4.0047 RTNR '.FTC 488.9470 CNTC )EPT 1600.0000 GR :LD 591.8715 ILM :HOB 1.6494 OPHI )LS -0.0181 QSS ,L 6B1.0000 LS ;S1 287.0000 SS2 ;R -999.2500 RHOB :ALI -999°2500 TENS 'NRA 5.1308 RTNR :FTC 251.8180 CNTC )EPT 1500.0000 GR :LD 492.3929 ILM 0.0142 660.0000 359.2500 -999.2500 -999.2530 4.4783 1568.6650 58.5000 19.9768 35.6934 -0.0015 555.5000 345.0000 -999.2500 -999.2500 3.9464 1722.~044 49.6875 100.7952 35.5957 0.0029 562.5000 3,45.5000 -999.2500 -999.2500 3.9815 1707.5110 56.5O00 36.5701 40.966B 0.0103 664.5000 36,2.'7500 -999.2500 -999.2500 4.3051 1914.6890 36.7813 816.3600 60.5957 0.0210 1316.0000 448.7500 -999.2500 -999.2500 5.2187 1252.6047 43.8.125 2000.0000 LSHV LU CALl ORHO GR RCFT TENS SP TENS DRHO LSHV LU CALI 9RHO RCFT 'TE NS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS SP TENS ORHO LSHV LU CAL! DRHO GR RCFT TENS SP TENS DRHO LSHV LU CALI GR RCFT TENS Sp TENS 1187. 603. 13. -999. 386. 2~90. -78. 1765. --0. 1187. 514. -999. 64. 417. 2404. -80. 1700. 1187. 516. 16. -999. 48. 467. 2250. -68. 1660. 1186. 613. 23. -999. 508. 2180,. -81. 1565. O. 1184. 1269. 23. -999. 40. 232. 2010. -45. 1545. OOOO 5000 8594 2500 1838 9744 0000 2500 O000 0156 0000 5000 2891 2500 7737 6680 0000 3125 0000 0132 0000 5000 5625 2500 8908 9563 0000 8125 0000 0059 0000 0000 0156 2500 9630 4943 0'000 7500 0000 0552 0000 0000 1562 2500 6316 5179 0000 5000 0000 SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SGR SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH 'TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR 1146.0000 191.3750 2490.0000 -999.2500 49.0347 1628.9299 41.0547 64.7737 2.7578 1146.0000 155.3750 2404.0000 -999.2500 45.4895 1714.1453 120.6505 48.8908 2.3438 1147.0000 180.8750 2250.0000 -999.2500 39.1889 1803.5466 29.1226 62.9630 2.2402 1146.000,0 212.3750 2180.0000 -999.2500 43.2317 1952.23S1 95.3529 40.6316 2.4883 1146.0000 409.2500 2010.0000 -999,.2500 63.7833 1237.0212 63.5686 42.9304 VP OlO.H02 VERIFICATION LISTING PAGE 19 HOB 1.9235 DPHI LS -0.0166 QSS L 444.7500 LS SI 282.7500 $52 R -999.2500 RHOB ALI -999.2500 TENS NRA 5.8486 RTNR FTC 426.5587 CNTC EPT 1400.0000 GR LO 2000.0000 ILM HOB 1.8789 DPHI LS 0.0112 QSS L 419.5000 LS S1 242.0000 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA 3.7546 RTNR FTC 513.6427 CNTC EPT 1300.0000 GR LO 2000.0000 ILM HOB 1.8291 OPHI LS 0.0093 QSS L 462.7500 LS S1 254.5000 S52 ,R -999.2500 RHOB ,ALI -999.2500 TENS 'NRA 4.0131 RTNR ;FTC 411.1669 CNTC ~EPT 1200.0000 GR :LO 13.6839 ILM IHOB 2.0742 OPHI ILS -0.0005 QSS .L 294.5000 LS ;S1 233.8750 552 ;R -999.2500 RHOB :ALI -999.2500 TENS 'NRA 4.2454 RTNR ~FTC 353.1202 CNTC )EPT 1100.0000 GR :LO 27.3747 ILM IHOB 2.1738 OPHI )LS 0.0117 ,QSS .L 250.5000 LS ;S! 233.7500 SS2 ;R -999.2500 RHO8 :ALI -999.2500 TENS FNRA 4.07:19 RTNR ;FTC 428.5788 CNTC 43. O. 836. 415. -999. -999. 3. 1655. 39. 520. 46. 0. 780. 368. -999. -999. 1923. 28. 266. 49. O. 865. 395. -999. -999. 1688. 71 · 11. 34. O. 545. 347. -999. -999. 4. 1.484. 71. 22. 2,B. O. 46,2. 335. -999. -'999. 4. 1709. 9453 0327 5000 7500 2500 2500 9811 9182 6875 7633 6797 0083 5000 5000 2500 2500 1053 9849 1562 9684 6582 0020 0000 0000 2500 2500 3462 6592 4375 6491 8145 0010 5000 2500 2500 2500 7179 5049 2500 7604 8086 0137 5000 0000 2500 2500 24OO 7014 DRHO LSHV LU CALI DRHO SR RCFT TENS SP TENS DRMO LSHV LU CALI DRHO RE~T TENS SP TENS DRHO LSHV LU CALI DRHO GR RCF:T TENS SP TENS DRHO LSHV LU CALI DRHO GR R'CFT TENS SP TENS ORHO LSHV LU CALI DRHO GR RCFT TENS 1186. 784. 23. -999. 399. 2060. 1500. --0. 1185. 722. 23. -999. 39. 531. 2050. -27. 1505. O. 1183. B04. 23. -999. 48. 409. 2080. -27. 1425. --0. 1186. 502. -99'9. 87. 368. 1980. -34. 1380. --0. 1187. 424. 15. -999. 75. 432. 1930. 0732 OOOO 0000 0313 2500 9304 9673 0000 75O0 0000 0132 0000 0000 1406 2500 7082 1499 0000 5000 0000 0005 0000 5000 1406 2500 2911 7689 0000 OOOO 0000 0107 0000 OOOO 7734 2500 5707 6470 0000 5313 0000 0029 0000 0000 8203 2500 2194 6841 0000 PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI RCNT SFLU SGR PEF' SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT 2.0918 1146.0000 287.0000 2060.0000 -999.2500 40.3656 1731.7622 96.9160 39.7082 2.1113 1146.0000 285.0000 2050.0000 -999.2500 38.5918 2001.3430 77.7879 48.2911 2.2617 1146.0000 274.7500 2080.0000 -999.2500 43.3250 1714.7'146 12.1644 87.5707 2.9355 1146.0000 149.6250 1980.0000 -999.2500 51.6022 1582.2158 19.5758 75.21 9,4 2.8945 1146.0000 130.2500 1930.0000 -999.2500 4'7.925.0 1787.3896 )EPT 1000.0000 GR 38.5625 SP -27.0000 SFLU. 347.7572 VP LD HOe LS L S1 R ALT NRA FTC EPT LD HOB LS L S! R ALT NRA FTC EPT LO HOB LS L $1 ,R ALT NRA FTC rEPT LO 'HOB ~LS ,L ;51 ~R ,ALl' 'NRA :FTC ~EPT IHOB iLS .L ;51 ;ALT rNRA :FTC 010.H02 VERIFICATIDN 1185.8875 ILM 1.5664 OPH! -0.0190 746.0000 LS 279.0000 SS2 -999.2500 RHOB -999.2500 TENS 4.6745 RTNR 302.1094 CNTC 900.0000 GR 150.6172 ILM 1.5439 DPHI -0.0337 715.5000 LS 256.7500 SS2 -999.2500 RHOB -999.2500 T~NS .4.3~59 RTNR 265.6884 CNTC 800.0000 GR 108.9358 ILM 1.8174 DPHI -0.0137 QSS 474.2500 LS 265.2500 SS2 -999.2500 RHOB -999.2500 TENS 4.6339 RTNR 313.01,27 CNTC 700.0000 GR 13.0155 ILM 2.0293 OPHI 0.0190 QSS 320.5000 LS 2'3,0.7500 552 -999.2500 RHOB -999.2500 TENS 4.3961 RTNR 3,14.0718 CNTC 600.0000 .GR 4.24,06 I'LM 1.9922 OPHI -0.0073 QSS 363.2500 LS 262.0000 SS2 -999.2500 RHOB -999.2500 TENS 4.8769 RTNR 263.0255 CNTC LISTING 260. 65. --0. 1455. 470. -999. -999. 4. 1342. 36. 45. 66. O. 1415. 402. -999. -999. 4. 1275. 45. 46. 50. O. 901. 396. -999. - 9'99. 1377. 66. 9. 37. 588. 1351. -999. --999. 4. 1454. 72. 3. 39. O. 677. 376. -999. -999. 5. 1257. 9125 6250 0239 0000 2500 2500 2500 5946 7756 9062 8820 9922 0308 0000 O000 2500 2500 9000 4385 '9687 8848 3906 0332 0000 2500 2500 2500 7353 33.59 7 O0 9~36 5488 0127 0000 7500 2500 2500 7895 0364 4375 4358 7949 0391 5000 7500 2500 2500 0313 1079 TENS DRHO LSHV LU CALI DRHO GR RCFT TENS SP TENS DRHD LSHV LU ORHO ~R RCFT TENS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS SP TENS ORHO LSHV LU CALI DRHD GR RCFT TENS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS 1310.0000 0.0278 1185.0000 1418.0000 23.0938 -g99.2500 44.3716 Z84.1061 1875.0000 -29.7656 1245.0000 -0.0093 1185.0000 1399.0000 23.0781 -999.2500 42.7493 251.6185 1770.0000 -36.7500 1150.0000 0.0142 1186.0000 853.5000 23.0000 -999.2500 50.9839 286.5001 1650.0000 -59.0000 1085.0000 -0.0186 1187.0000 535.000.0 2,2.4063 -999.2500 67.4869 323.5'826 1600.0000 -67.5000 1000.0000 0.0288 1187.000.0 ,$28.0000 18.6875 -999.2500 91.5304 254.7197 1,450.0000 SGR PEF SSHV LITH TENS OPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPH! RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT PAGE 20 44.3716 2.4688 1145.0000 445.0000 1875.0000 -999.2500 55.4581 1389.9116 98.5313 42.7493 2.3164 1146.0000 425.5000 1770.0000 -999.2500 58.42.13 1307.2153 96.9160 50.9839 2.5898 1146.0000 268.2500 1650.0000 -999.2500 54.7594 1337.6621 12.7411 67.4869 2.5566 1146.0000 177.7500 l&O0.O000 -999.2500 50.6918 1570.9404 3.5614 91.5304, 2.7832 1146.0000 191.5000 1450.0000 -999.2500 61.2872 1326.1575 V? 010.H02 VERIFICATION EPT 500.0000 GR LD 10.6924 ILM HOB 1.3252 OPH! LS -0.0430 QSS L 1057.0000 LS S1 267.0000 SS2 R -999.2500 RHOB ALI -ggg.2500 TENS NRA 4.3748 RTNR FTC 297.1845 CNTC EPT 400.0000 GR LO 5.1757 ILM HOB 1.5088 OPHI LS -0.0391 OSS L 848.5000 LS S1 290.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA 4.4651 RTNR FTC 275.6800 CNTC EPT 300.0000 GR LO 4.8572 ILM HOE 1.9502 OPHI LS -0.0132 QSS L 376.0000 LS S1 255.5000 552 R -999.2500 RHDB ALI -999.2500 TENS NRA 4.4615 RTNR FTC 288.9045 CNTC EPT 200.0000 GR LO 29o7103 ILM HOB 2.0273 DPH! LS -0.0078 QSS L 331.7500 LS Sl 250.2500 SS2 R -999.2500 RHOB ALI -999.2500 TENS NRA 4.1702 RTNR FTC 348.5603 CNTC =EPT 100.0000 GR LO 2000.0000 HOB 2.0293 DPHI !LS 0.0947 QSS ,L 89.68'75 LS S1 75.7500 SS2 ;R -999.2500 RHOB iALI -999.2500 TENS 'NRA 4.1628 RTNR :FTC 286.5018 CNTC LISTING 55.6875 8.0350 80.2246 -0.0215 2154.0000 465.0000 -999.2500 -999.2500 4.6571 1311.5793 62.0625 4.0799 69.0918 0.0244 1690.0000 462.5000 -999.2500 -999.2500 5.1935 1264.1113 72.6875 3.4508 42.3828 0.0229 707.0000 3'77.5000 -999.2500 -999.2500 4.8529 1274.3811 42.9687 17.1307 37. 5977 0.0234 618.0000 36,4.2500 -999.2500 -999.,2500 4.3659 1437.8699 29.0313. 1.8976 37.5000 -0.1133 17,4.3750 122.5000 -9'9'9.2500 -999.25'00 4.14'71 1262.6567 SP TENS i]RHO LSHV LU CALI DRHO GR RCFT TENS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS SP TENS ORHO LSHV LU CALl DRHO GR RCFT TENS SP TENS ORHO LSHV LU CALI ORHO GR RCFT 'TENS SP TENS DRHO LSHV LU CALI DRHO GR RCFT TENS -80. 1090. O. 1183. 2194. 22. -999. 64. 300. 1365. -77. 960. O. 1185. 1682. 23. -999. 76. 274. 1335. -71. 865. O. 1186. 661. 14. -999. 76. 267. 1275. -73 · B15. O. 1187. 572. 15. -999. 45. 327. 1285. -78. 765. --0. 118.B. 169. 15. -999. 27. 266. 1195. 7500 0000 0020 0000 0000 9531 2500 5699 0069 0000 0000 0000 0562 0000 0000 0313 2500 3079 5808 0000 7500 0000 0098 0000 5000 6328 2500 7270 3511 0000 2500 0000 0083 OOOO 5000 6641 2500 7804 5574 0000 0000 O000 7061 0000 3750 3125 2500 5534 2389 0000 SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LYTH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPHI NPHI RCNT SFLU SGR PEP , SSHV LZTH 'TENS DPHI NPHI RCNT PAGE 21 11.5919 64.5689 2.3398 1145.0000 652.0000 1365.0000 -999.2500 50.0438 1294.5891 6.2825 76.3079 2.8320 1145.0000 468.0000 1335.0000 -999.2500 51.6540 1314.2668 8.0324 76.7270 2.7578 1146.0000 203.1250 1275.0000 -999.2500 55.6294 1309.1816 67.1804 45.7804 2.2871 1146.0000 189.~750 1285'.0000 -999.2500 49.7990 1488.1936 1.4739 27.5534 18.5000 1148.0000 19.0313 1.195.0000 -999.Z500 49.8324 1441.3772 VP OlO.H02 VERIFICATION LISTING PAGE 22 EPT 30.0000 GR Lg -999.2500 ILM HgB 1.6104 DPHI LS 0.1284 QSS L 155.7500 LS S1 75.6875 SS2 R -999.2500 RHDB ali -999.7500 TENS NRA 5.1907 RTNR FTC 231.5599 CNTC · FILE TR~ILE~, ILE NAME :SDIT ERVICE NAME ERSIDN ,~ : ATE : AXIMUM LENGTH ILE TYPE : EXT FTLE NAME · FILE HEADER ILE NAME :EOIT ERVICE NAME : ERS TDN ,~ : ATE : AXIMUM LENGTH : 'ILE TYPE : REVIOUS FILE :' :~ COMMENTS ,~ .001 1024 .002 1024 -999.2500 SP -999.2500 SFLU -999.2500 -999.2500 TENS -999.2500 SGR 19. Z626 62.9395 DRHO -0.7925 PEF 23.0469 -0.1089 LSHV 1189.0000 SSHV 1149.0000 293.0000 LU 274.5000 LITH 31.9219 129.8750 CAL! 15.3359 TENS -999.2500 DRHO -999. Z500 DPHI -999.2500 -999.2500 GR 19.2626 NPHI 68.6428 5.4138 RCFT Z26.1709 RCNT 1234.7639 1179.9829 TENS 1Z15.0000 EOF ~~~.~ THIS DICTA HAS NOT ;BEFN DEPTH SHIFTED - DVERLRYS FIELD PRINTS VP 010.H02 VERiFICATI.~N LISTING PAGE 23 SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT.OOZ): <SEE FIL= EDiT.O01 ~OR 6" SAMPLED DIL/LDT/FDC/CNL DATA> RUN ~2~ 1.2" FOrMaTION DENSITY COMPENSATED LOG C.~DH) FIqST TO LAST READING: 7716' TO 7049' RUN ~Z~ I~RST TO L~ST READING: 7701' "COMPENSATED NEUTqON LOG (.CNH) T9 7049 ~ ~-a' D~TA FO2M&T RECORD *'".,-~- NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 I 66 1 8 4 73 12 9 4 65 .lIN 16 1 66 l 0 1 66 0 aTUM SPECIFICATION 5LOCKS NEM SERVICE SERVICE UNIT API AP1 API APt FILE SIZE SPL REPR ID ORDER :~ LOG TYPE CLASS MOD NO. EPT FT O0 000 O0 0 R FDH GAPI O0 310 01 0 0 4 HOB FDH G/C3 O0 350 02 0 0 'RHO FDH G/C3 O0 356 O1 0 0 PHI FDH PU O0 '~gO O0 0 0 4 ALI FDH IN O0 250 01 0 0 'ENS FDH LB O0 635 21 0 0 ,R CNH GAPI O0 310 O1 0 0 ,PHI CNH PU O0 $90 O0 0 0 4 NRA CNH O0 .420 O1 0 O 4 :TNR CNH O0 0'00 O0 0 0 :CFT CNH CPS O0 000 O0 0 0 :CNT CNH CPS O0 000 PROCESS CODE (,OCTAL) I 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 I 68 O0000OO0000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000'0.00 1 68 000000000.00000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000'000 VP OlO.HO2 VERIFICATION LISTING FTC CNH CPS O0 NTC CNH CPS O0 ENS CNH LB O0 O00 90 0 0 000 O0 0 0 635 21 0 0 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 EFT 7773.0996 PHI 25.7405 CALI PHI 41.7239 TNRA CNT 1796.6379 CFTC EFT 7700.2998 GR PHI 15.1278 CALI PHI 42.8645 TNRA CNT 1796.1294 CFTC EFT 7600.2998 GR PHI 15.6013 CALI PHI 38.6489 TN~A CNT 1879.9060 CFTC EFT 7500.2998 GR PHI 14.5360 CALI PM! 41.5075 'TNRA CNT 1960.2393 CFTC EFT 7400.2998 GR PHI 22.1117 CALI PHI 31.0963 TNRA CNT 2341.5098 CFTC EFT 7300.2998 GR PHI -4.4034 CALI PHI 36.7513 TNRA CNT 2131.4399 CFTC ,EFT 7200.2998 GR ,PHI 20.45.¢5 CALI IPH! 48.9436 TNRA :CNT 1516.5237 CFTC rEPT 7100.Z998 GR }PHI 15.,8381 CALI IPHI 44.9516 TNRA ICNT 1506.3369 CFTC lEFT 7048.5000 GR IPHI 15.8381 CALI IPHI 44.2224 TNRA ICNT 1612.4839 CFTC 108.4375 7.0742 3.3174 566.3683 103.5625 9.2891 3.5460 535.2640 116.2500 8.8047 3.2760 601.1022 101.8750 3.7969 3.4315 577.0542 69.8125 B.~8594 2.8419 889 .'7402 58 6563 82 219 3.1818 761.5414 107.7500 9.0469 3..8578 452.6994 127.6875 9.7344 3.6965 480.9358 133.3750 9.6172 3.6466 489.9561 RHOB 2.1758 ORHO 0.1689 TENS 1340.0000 GR 108.4375 ~TNR 3.4193 RCFT 518.9822 CNTC 1846.6736 TENS 1340.0000 RHOB 2.4004 ORHD 0.0215 TENS 6088.0000 GR 103.5625 RTNR 3.8571 RCFT 506.51'73 CNTC 1831.7485 TENS 6088.0000 RHOB 2.3926 DRHO 0.0269 TE~S 5752.0000 GR 116.2500 ~TNR 3.2013 RCFT 577.7888 CNTC 1946.0723 TENS 5752.0000 RHOB 2.4102 DRHO 0.0215 TENS 5672.0000 ER 101.8750 RTNR 3.3200 RCFT 536.0573 CNTC 1931.0112 TENS 5672.0000 RHOB Z.2852 ORHO -0.0034 TENS 554~.0000 GR 69.8125 RTNR 3.0909 RCFT 874.3781 CNTC 2389.6084 TENS 5544.0000 RHOB 2.7227 ORNO 0.0742 TENS 5508.0000 GR 58.6563 RTNR 3.2235 RCFT 748.7360 CNTC 2273.7'202 TENS 5508.0000 RHOB 2.3125 .DRHO 0.0181 TENS 534~.0000 GR 107.7500 RTNR 3.7895 RCFT 419.1682 CNTC 167.1.7336 TENS 534,4°0000 RHOB 2.3887 ORHO 0.0479 TENS 5312.0000 GR 127.6875 RTNR 3.3889 RCFT 459.9639 CNTC 1747.049.6 TENS 531Z.0000 RHOB 2.3887 DRHO 0.0127 TENS 5288.0000 ER 133..3750 RTNR 4.3077 RCFT 422.6680 CNTC 1764o3381 TENS 5288.0000 FILE TRAILER · . ,. ~P OIO.HOZ VERIFIC "'" A,~.~ON LISTING PAGE 25 ILE NAME :EDIT ERVICE NAME : ERSION .~ : ATE : ~XIMUM LENGTH : 1024 [LE TYPE EXT FILE NAME : .,. TAPm TRAILER "'-'- ERVICE NAME :EDTT ATE :88/01/ g RIGIN :F$1A APE NAME : ONT[NUATTON .~ :01 EXT TAPE NAME : OMMENTS :LIS T~PE~ ARCO ALASKA, INC. 3H-11 ~PI 50-029-21771 , REEL TRAILER ** ERVICE NAME :EDIT ATE :88/01/ g RIGIN : EEL NAME :7255.2 ONTINUATION # :,01 EXT REEL NAME : OMMENTS :LIS TAPE, ,~RCO ALASK~ INC. 3H-11 API 50-029-217'71 RECEIVED TAPE LVP OIO,HO~ 'v'ERIFICATiLI:'., LIST1NG PAGE I S%iRV IC .F NAME :EDIT DATE :B$/02/12 ORIG1N : REEL NAM{,;, ".72596 CO~TI~U~TIGN ~ CO~ENTS ~bIS TAPE, ARCU A~,ASKA, ~hC, 3H-~I APl 50-~03-20091 ** TAPF HEADE~ SERVICE t;AME DATE :88/02t12 ORIGIN :FS1A CO~TtNUATIO~ ~ PR~'VlOU6 TaPE CO~MKNT8 :L1$ TAPE, ARCU ALASKA, INC, 3H-11 APl 50-10]-20091 ** FILE HEADER FILE NAME :EDIT ,001 SERVICE NA~E VERSlO~ # DATE : ~AXI~UM LENGT}{ : 1024 FILE TYPE PREVIOUS FILE ** INFORhATIO~ RECORDS MNE~ CONTEl!TS UNIT TYPE CATE SIZE CODE RANG". TOWN ~ SECTI STAT~ ARCO ALASKA, INC, 3H,,11 KUPARUK 12 NORTH SLOPE ALASKA 000 000 017 065 000 000 016 065 000 000 007 065 000 000 002 065 000 000 003 065 000 000 002 065 000 000 012 '065 000 000 006 065 LyP 010,H02 VKRIP'.IC.~TiOJ l..,t$'r'[N(; PAGE ~ ALASKA COMPUTING C~mpANY = ARCf) ALASKA, FIf~LD = KUPARI]K COUNTY ~ ~[.]R'.rH 85FIPE STATE : ALASKA AKCC JOB N[IF. BER = 72596 DATE: {LOGGED: LDP; J, KDHR CASING TYPE DENSITY VISCOSITY P H FLU ID 16,00" Oll5'(bt.'.GGER) - BIT SIZE = 13,5" 'FO ::1650'(LUGGER) GEl., 9.~0 L.~/(; R~, - 6,10 0 75 ~F 460. S R~F = 6,30 ~ 75 DF 8,5 R~C = {,22 ~ 75 DF 5,~ C3 R~ AT ["{HT = 4,904 ~95 DF FIELD REMARK8~ = "-' SP SHIFT ~.1550' ~D~N=2,65~ MATRIX SAND, tiC-(.AI~IPER, BHS=OPEN~ FLDID DENS=I,O, TOOL TYPES/NU~BERS: DRS 4969 NSC '7bO CNC 398 TCC 404 VERIFICATION LISTING DIS 1131 ~)IC 471 SGC 2620 ~U~ #2, .{)ATE LOGGED: 25-DEC-87 [,DP: J. K('iHRING CASING TYPE FLUID DENSITY ¥ISCOS~TY PM = lO.7b" ~3633'(b(]G(;ER) - BIT SIZE = 8.5" TO 7750'(LOGGER) = WEIGHTED P~]L, YME~ = 44,0 $ R~F , 76 DF FLUID LOSS = 9.5 R~'4C = ~,01 m 75 DF : 4.8 C3 RM AT BMT = ,072'~146 DF FIELD REAARKS: I 1/2" STAND{IFF AND 2' MOLE FINDER USED ON DIb. ~IATRIX = SAND " ' ' 65 G/C3 HOLE C(]RRECTION = CALIPER. CHANGED SURFACE ~ATRIX DENSITY - 2. GROUND AND SHUT DOW~ ~,EL, DE~$ TO GET GOOD SP FOR ~AIN PAS6. LOGS TIE[.) INTO RUN #! DIL 15-DEC-87. TOOL TYPES/NUNbE~S: DIS 2140 DIC 2~9~, SGC 2259 PGS 1.026 CNC 1449 IEM ~290 NL~ 1312 THIS DATA }~A$ NOT BEEN DEPTH SHIFTED - OVERI~AY$ FIELD ~RINT$ ~~ [,VP OlO,i~02 V.~glFICATIUi~ blS'I'I~G PAGE $C~{LU~'4M. ERGER LOGS INCLIJPED dlTH THIS FILE (EDIT,O01): FILE EDIT,002 FOR 1,2" SAMPLED FDC/CN~ DATA) DUA[~: I.~,DtlCTI~N SPHERICAL5¥ FOCUSED bOG (DIL) IR$T T(.') LAST READ~.~G: 7742' TO {15' R~)N[ & RUN2 ~gRGED ~3650' G~.L~L ~E~GED ~625' AND SP ~ERGED {a3638' FIRST T9 LAST READIN¢~: 77.~2' TO 3633 FOR~A'i'IOI,,' DENSITY COt,iPE~,ISATED bOG ~,Fi'.}C) RU~2 ONlY FIRST T[,~ LAS~ REA[)]'~G: 7716 TO 7050 AND 4450' TO LIT~O-DE~,MITY CO~PENSAT~;D LOG (,bDT) RUNi O~bY FIRST TO bAST READI~G~ 3636' TO 115' CO{~PE~JSATED NEUT90~ bOG FIRST TO L~ST READING: 7701' TU 7050' AND 4450' TO ~15' RONX & RUN2 MERGED ~3618', GR.CNL ~3584' L, VP OI.O,H02 VER1FIC:ATIP.!~ LISTI,~G PAGE 5 ** DATA FORMAT RKCORI) ** ENTRY BLOCKS TYPE SiZE PEPR CODE ENTRY 2 ! 66 0 4 1 66 8 4 73 60 9 4 65 ,lin 16 1 66 1 0 I 66 0 DATUk SPECIFICATION BLOCKS ~NE~ SERVICE SERVICE UNIT API AP1 AP1 APl FiLE ~IZE SPL REPR ID ORDER # 1, OG TYPE CLASS MOD ~0. DEPT GR DI5 SP DIb ILO TENS SGR LOT ~HOB LDT DP~I LD~ D~NO LOT PEF [,,DT ~LS LOT LSHV I.,DT $S~V LQT .b$ LDT LU LDT LITB LDT S$1 LDT $$2 LOT CALl LDT TENS LDT GR FDC RHOB FDC DRHO FDC DP~I FDC CAf.! FDC TENS FD.C GR CNt PROCE$~ FT O0 000 GAPI O0 310 ~V oO Oh~ O0 220 OHMM O0 120 OH~i O0 120 LB O0 635 GAPI O0 310 G/C3 O0 350 PO O0 890 G/C3 O0 356 O0 S58 O0 000 OO 000 V O0 000 V O0 000 CPS O0 354 CPS O0 354 CPS O0 354 CPS O0 354 CPS O0 000 CPS O0 .000 IN 00 280 LB O0 635 GAPI O0 310 G/C3 O0 350 G/C3 O0 356 PU O0 890 I~ O0 280 LB O0 635 (;AP1 O0 310 O0 0 0 4 01 0 0 4 01 0 0 4 O1 0 0 4 46 0 0 4 4~ o o 4 21. O 0 4 01 0 0 4 02 0 0 4 O0 0 0 4 O1 0 0 4 O1 0 0 4 oo 0 0 4 O0 0 0 4 oo 0 'o 4 O0 0 0 4 O1 0 0 4 O1 0 0 4 O1 0 0 4 Ol 0 0 4 O0 0 0 4 O0 0 0 4 01 0 0 4 21 0 0 4 01, 0 0 4 02 0 0 4 Oi 0 0 4 00 0 0 4 01 0 0 4 21 0 0 4 01 0 0 4 CODE {OCTAL) 68 O00000UO000000 ~8 ooooooooooo00o 6~ oooooooooo000o b8 oooooooooo0oo0 66 00000000000000 68 ooooooooo0oooo 68 oooooooooooooo 68 oooooo0oooo0o0 68 00000000000000 68 ooo0oooo0ooooo 68 00000000000000 08 oooooooo00oooo 68 ooooooooo00o~ 68 ooo0ooo0ooo0 68 ooo0ooooo0oo.00 68 ooooooo0oo0o00 68 oo00,oo00oo0000 68 o0o0oo0o0o0ooo ooooooooo oooo ooooooooo oooooooooooooo oooooooooooooo oooooooooooooo LVP 010.H02 VFiRIFICATIOD:, bISTI;'.,~ PAGE 6 ~, P W, I C t,i L P U 0 [) 890 TNRA C~L O0 420 RT~R C~L CO 000 RCFT CN[, CPS O0 000 RC~aT CNL CPS O0 000 CFTC CN[, CPS O0 CNTC fNL CPS O0 000 TF~S CK5 L~ O0 635 00 0 0 4 0 ! 0 C; 4 O0 0 0 4 O0 0 0 4 00 0 0 4 O0 0 0 4 O0 0 0 4 ~1 0 0 4 DATA DEFT ILL RHOB LL SS1 CALI TNRA CFTC 7767 5000 1 -999 -999 -999 -999 101 9 5O6 8113 [L~! 2500 DP~I 2500 OSS 25()e LS 2500 SS2 1875 RHO~ 3984 TENS 6537 RTN~ 2590 CNTC DEFT RMOB QL$ GR CAL! TNRA CFTC 7700 0000 ~R 1 -999 -999 -999 -999 107 9 3 507 7641 2500 DP~I 2500 2500 2500 1250 RHOB 4609 TENS 5747 RTNR 3817 CNTC DEFT SS.~ GR CALX CFTC 7600 0000 GR 2 '999 '999 '999 "999 105 8 3 541 4293 IL~ 2500 DPHI 2500 ~S$ 2500 LS 2500 882 4375 RHOB 7656 TENS' 4933 ~TNR ~417 CNTC DEFT RHOB OhS LL CALl TNRA 7500 0000 GR 2 7914 -999 2500 -999 2500 -999 2500 -999 2500 882 94 1250 R}iOB 8 7969 TENS 3 3606 RTNR lot 1875 SP -999 -999 -999 2 ]370 1818 9592 TENS 2500 DRHO 2500 l, SHV 2500 LU 2500 CALl 4590 DRH[i 0000 GR 7660 RCFT 6772 TENS 107 1250 1 -999 -999 -999 -999 6488 1731 835O TENS 2500 DRHO 250O LSHV 2500 nu 2500 CALl 3770 DRHO 0000 GR 7069 RCFT 5522 TENS 2 -999 -999 -999 -999 2 6424 1896 585 TENS 500 DRHO 2500 LSHV 2500 LU 2500 CAL! 4141 DRHO 0000 GR 7119 RCFT 3579 94 1250 SP 2 9476 TENS -999 2500 DRHO -999 2500 LSHV -999 2500 LU -999 2500 CALl 2~297 DRMO 6248 0o0 GR 3 5593 RCFT ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 -65.8750 SFbU 3370'0000 SGR -999,2500 PEF -999.2500 SSHV -999.2500 LITH -999,2500 TENS 0,0718 DPHI 101,.1875 NPHX 463.9021 RCNT 3370,0000 6~93,5000 Sf'LU 88,0000 SGR '999,2500 PEF -999,2500 SSHV '999,2500 LITH '999,2500 TENS 0,046'4 DPHX 107,1250 NPHI 501,3483 RCNT 6488,0000 'I9 0000 SFLU 6424 0000 SGR -999 -999 -999 -999 0 I05 481 5424 2500 PBF 2500 SSHV 2500 blTH 2500 TENS 0430 DPHI 4375 NPHI 4939 RCNT 0000 11,2250 SF[,U 6;48.0000 SGR 2500 PEP' '999,2 "999, 500 SSHV "'999.2500 LITH -999.2500 TENS 0.0313 DPHI 94.1250 NPH! 508,6541 RCNT 2 2265 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 11 5767 44 6760 1769 4001 .99~,'9486 °o -999 ~500 -999 0 16 548{ 43~1374 1661,,5,247 2 5763 -999 2500 -999 2500 -999 2500 ~999 2500 '999 2500 14 2992, 42 68'56 1857 0552 3,1451 -999, 500 -999 ]500 -999 0 .,,, 1 8o -999 25 1765 3 LVP OIO,H02 VERIFICATIO,',, LI6TING PAGE CFTC 545,1989 C~iTC 1810.1965 TENS DEPT RHOB OhS $Sl GR CALI TNRA CFTC 7400 0000 GR -99 -999 -999 -999 62 8 83! 4177 2500 DPHI 2500 OSS 2500 bS 2500 9062 RHOB 9375 TEN6 8733 RTNR 2062 C~{TC 62,9062 SP 17 0869 TENS -999 2500 DRHO -999 2500 LSNV -999 2500 bO '999 2500 CA[,I 2 2461 DRHD 6264 OOOO GR 2 8889 RCFT 2237 3901 TENS DEPT ibp RHOB QI~S GR CALl TNRA CFTC 7 ]00 0000 GR 25 -999 -999 -999 -999 58 8 3 713 989 ILFi 500 OPHI 2500 aSS 2500 LB 2500 SS2 2813 RHOB 9609 TENS 2312 RTNR 9752 CNTC 58 2613 SP 28 -q99 -999 -999 ,,999 2 5244 2093 624@,0000 DEPT RHOB SSi. CAbI TNRA CFTC 7200 0000 G~ 1 -999 -999 -999 -999 114 9 453 6511 IbM 2500 DPHI 25OO OSS 2500 bS 2500 852 9375 RHOB 1328 TENS 7012 RTNR 1132 CNTC !i2!,2500 SrbU · 6 ,0000 SGR 9 ,2500 PEF 99,2500 $SHV '999,2500 blTH '999,2500 TENS '0,0063 DPHI 62,9062 NPHI 734,1178 RCNT 6264,0000 -41,0000 SFLb 1963 TENS 624~,0000 SGR 2500 DRHO -999,2500 PEF 2~00 bS~V -999,2500 SSHV 2500 LU -999,2500 bITH 2500 CAbI -999,2500 TENS 5273 DRMO 0,0059 DPH~ 0000 GR 58,2813 NPH! 28'77 RCFT 644,3801 RCNT ~280 T~NS 6244,0000 -27 875O SFbU 7552 ~ENS 5628:0000 SGR 2500 DRHO -999,2500 PEF 2500 bSHV -999,2500 SSHV 2500 bb -999,2500 LITH 2500 CAbI -999 .~500 TENS 9039 RCFT 435;9687 RCNT 5452 TENS 5628,0000 DEPT RHOB SSi GR CAb! TNRA CFTC 7100 0000 G~ 2 -999 -999, -999 -999 ~13 9 3 469 1675 IbM 2500 DPHI 2500 QSS 2500 bS 2500 SS2 7500 RHOB 6250 TENS 7~79 RTNR 369~ CNTC 114 9375 SP 1 -999 -999 -999 -999 562~ 3 1638 -26,8750 SFbU 5960,0000 SGR 2500 DRHO -999,2500 PEF 2500 bSHV -999,2500 SSHV ~500 bU. -999,2500 b/TH 2500 CAbI -999,2500 TENS 3633 DRHO 0,0303 DPHI 0000 GR li3,7500 NPHX 8364 RCFT 420,0029 RCNT 9089 T~N8 5960,0000 DF;PT OLS CALI 7O0O 0000 GR 2 9156 II,~ -999 2500 DP~I -999 2500 QS$ -999 O0 SS2 -999 2500 RH08 -999 2500 TENS 750O SP 1997 TENS -999 -99'9 -999 -999 2 5960 1~33 26] 0000 SP 0773 TENS -999 2500 DRHO -999 2500 bSHV -999 2500 LU -999 2500 CALl -999 2500 DRHO -999 2500 GR 3b 1696 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 24 4792 31 4729 2208 2456 41 2539 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 7 43 37 .59~7 1923 560~ I 9074 -999 2500 -999 2500 -999,2500 -999 1500 -999 $00 '19 459495 161~ O735 54 -999; O0 0 -99~,2500 17,3769 45, B -27,5000 SFbU 3,9732 6048,0000 SGR -999,.i~0 -999,.2500 PEF. -999,0m -999.2500 SSHV -999~ O0 -999,2500 GITH -999.,i~00 '999,2500 TEN~ -999, O0 -999,2500 DPH! w999,. O0 '999,2500 NPHX -999,2500 [.VP 010,H02 VEPIFICAI'IO~ LIS']'it:G PAGE 8 CFTC DEPT I6D RHOB CALI CFTC DEPT ILO RHOi:~ Lb G~ CFTC DEPT OLS $$1 GR CALl CFTC DF. PT GR CALI TNRA CFTC DEPT RHOB QbS SSi GR =999,2500 RI'!~R -999,~500 C~TC 6900 2 -999 -999 =999 -999 -999 -999 =999 -999 0000 GR 9435 2500 DPHI 2500 OSS 2500 L$ 2500 2500 ~HOB 2500 TENS 2500 RTMR 2500 C~TC 6800 -999 -999 -999 -999 -999 -999 -999 -999 0000 GE 1790 IbM 2500 DPHI 2500 OSS 2500 £,~ 250O SS2 2500 RHOB ~500 TENS 2500 RTNR 2500 CNTC 6700 3 -999 -999 -999 -999 -999 -999 -999 -999 0000 GR 7422 l~ 2500 DPHI 2500 QSS 2500 h$ 2500 SS2 2500 RHOB 2500 TENS 2500 RTNR 2500 CNTC 6600 2 ~999 '999 '999 '999 '999 '999 '999 '999 0000 GR 5311 IL~ 2500 DPH! 2500 2500 2500 882 2500 RHOB 2500 TENS 2500 RTNR 2500 C~TC 6500 -999 -999 -999 -999 -999 0000 ~687 2500 2'500 O$S 2500 2500 2500 RHOB -999 -999 159 -999 -999 -999 -999 -999 -999 -999 -999 120 3 -999 -999 -999 -999 -999 -999 -999 -999 124 3 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 113 3 -999 -999 -999 '999 -999 .2500 .2500 6250 1016 2500 2500 2500 2500 2500 2500 2500 2500 8125 2845 2500 2500 2500 250O 2500 2500 2500 2500 4375 8369 2500 2500 2500 2500 2500 O0 2500 375 314 2500 2500 2500 ,2500 2500 2500 2500 2500 8125 7373 2500 2500 2500 2509 2500 RCFT SP TENS DRHO LSHV bU CALI DRHO GR RCFT 8P TENS DRHO C~[.,1 DRBO RCFT TENS SP TENS DRHO bSHV LU CALl DRHO GR RCFT TENS TENS DRHO bU CAbI DRHO GR ~CFT TENS SP DRHO LSHV DRHO -999 -999 5648 -999 -999 -999 -999 -999 -999 -999 -999 =7. 5588 '999 '999 '999 '999 -999 -ggg -9gg -999, -5 5472, -999 -999, '999 -999 -999 -999 -999 -999, 5508 -999 -999 -999 -999 -999 -999 -999 -999 -42 5380 -999 -999 -999 °999 -999 .2500 ,2500 .9980 ,0000 ,2500 .2500 2500 2500 2500 2500 2500 2500 1250 000o 2500 2500 2500 2500 2500 2500 2500 2500 7500 0000 2500 2500 2500 O0 500 ~500 2500 7500 0000 500 5OO 2500 2500 2'500 2500 2500 2500 ,8750 .0000 .2500 ,2500 ,2500 ,2500 ,2500 RCDT SFLU SGR PEF SSHV LITH TENS DPH! 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'999,2500 NPHI '999,2500 RCNT '999,2500 -62 0000 SFbU 5128 '999 -999 -999 -999 '999 '999 -999 -999 0000 SGR 2500 PEF 2500 SSHV 2500 LITH 2500 TENS 2500 DPHI 2500 NPHI 2500 RCNT 2500 -40 6250 SFLU 5240 0000 SGR -99 -99~ -999 -999 -999 -999 -999 -999 2500 PEF 2500 8SHV 2500 bITH 2500 TENS 500 DPHI 25OO -39 ,1750 SFbU -999 '999 '999 '999 "999 "999 '999 0000 SGR 2500 PEF 2500 SSHV 2500 GITH 2500 TENS 2500 DPH! 2500 NPH! 2500 RCNT 2500 -42,5000 SFLU 4912,0000 SGR -999,2500 PEF -999,2'500 SSHV -999,~500 blTH -999, 500 T~N$ '999,2500 '999,2500 -999 O0 -999 2500 -999 2500 -999 2500 -999 2500 -999 500 -999 {500 -999 2500 6 3095 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -~99 2500 4,0952 -999 2500 -999 2500 -999 2500 -999,2500 -999,2500 -999 '999 500 3 6?70 -999 2500 -999 ~500 '999 500 '999 2500 -999 2500 -999 2,500 '"99~ '/096 2500 '999 2500 "999 2500 LVP OlO,H02 VER1FiCATIOI~ LISTING PAGE 10 GR -999 2500 CALl -999:2500 TNRA -999.7500 RTNR CFTC 999,2500 ChTC ILD 2 RHOB -999 OL$ -999 L5 -999 SS! -999 GR -999 CALl -999 TNEA -999 CFTC -999 DEPT 5SO~ RHOB -999 OhS -999 Eb -999 $$! -9q9 GR -999 CA5I -999 TNRA -999 CFTC -999 DEPT RHOB OhS GR CAb1 TNRA CFTC DEPT ILD RHOB 551 CALZ TNRA CFTC D'EPT OL, S LL 5900 o0o0 GR 9750 2500 DPH! 2500 2500 2500 552 2500 RHOB 2500 TENS 2500 RTNR 2500 CNTC 0000 GE 4519 2500 OPHI 2500 2500 2500 SS2 2500 RHOB 2500 TENS 2500 RTNR 2500 C~TC 5700 OOUO GR 2 -999 -999 -999 -999 -999. -999 -999 -999 1337 2500 2500 2500 500 RHO'B 500 TENS 2500 RTNR 2500 CNTC 5600 . 3 999, -999 -999 -999 -999 -999 '9'99 '999 i,~000 GR 036 2500 DPHI 2500 2500 2500 2500 RHOB 2500 TENS 2500 R~NR 2500 CNTC 5500 0000 2 4741 -999 2500 -999 2500 -999 2500 GR DPHZ -999.2500 DRHO -999.2500 GR -999.25C0 RCFT -999.2500 TENS 97 6250 SP 2 9978 TENS -999 2500 DRHO -999 2500 LSHV -999 2500 LU -999 2500 CAL! -999:2500 DRHO -999,2500 GR -909,2500 RCFT -999,2500 TENS 106 3 -999 -999 -999 -999 -999 -999 -999 -999 875 SP ~635 TENS 2500 DRHO 2500 LSHV 2500 t, lJ 2500 CAbI 2500 DRHO 2500 GE 2500 RCFT 2500 TENS 111 7500 SP 2 -999 -999 -999 -999 -999 -999 -999 -999 1808 TENS 2500 DRHO 2500 bSHV 2500 LU 2500 CAb! 2500 DRHO 2500 GR 2500 RCFT 2500 TENS 250O SP 1459 TENS -999 -999 -999 -999 -999 -999 -999 -999 2500 DRHO 2500 bSHV 250o LU 2500 CAbI 2500 ORHO 2500 GR 2500 RCFT 2500 TENS 112,3750 SP 2,5086 IENS -999.2500 DRHO -999,2500 t, SHV "999,~500 l.,[J '999,2500 UPH! 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SP TENS 2500 DRHO 2500 LSHV 2500 bU 2500 CALX 2500 DRHO 250O GR 2500 RCFT 2500 TENS 102 ~625 SP 1 861 TENS -999 2500 DRHO -999 -999 -999 -999 -999, -999 -999 2500 LSHV 2500 bU 2500 CALI 2500 DRHO O0 GR ~00 RCFT 2500 TE~S 107 1875 BP 2 -999 -999 -999 -999 -999 -999 -999 -999 1000 TENS 2500 DRHO 25OO LSHV 2500 bU 2500 CALI 2500 DRHO 2500 OR 2500 RCFT 2500 TENS 85 ~625 SP 2:101 TENS -999,2500 DRHO -999.2500 LSHV :999,2500 TENS 999,2500 DPHI -999,2500 NPHI -999,2500 RCNT -999,2~00 ~44,375(') SFLU 72.0000 SGR -999,2500 PEF -999,2500 SSHV -999,2500 hITH -999.2500 TENS -999,2500 DPHI -999,2500 NPH! -999,2500 RCNT -999,2500 -35 3750 4480 -999 -999 -999 -999 -999 -999 -999 -999 SFLU 0000 SGR 2500 PEF 2500 SSHV 2500 LITH 2500 TENS 2500 DPHI 2500 NPHI. 2500 ~CNT 2500 -28 0938 4612 -999 -999, -999 -999 -999 -999 -999 -999 SFbU 0000 SGR 2500 PEF 2500 SSHV 2500 LITH 500 TENS 500 DPH! 2500 NPHI 500 RCNT 5OO 08 -999 "999 '999 '999 '999 '999 '999 '999 1250 SFLD 0000 SGR 2500 PEF 2500 SSHV 2500 hlTH 2500 TENS 2500 DPHI 2500 NPH! 2500 ECNT 2500 -27,1250 SFLU 4468,0000 SGR '999,2500 P'EF -999.2500 '999..2500 -999.2500 -999,2500 -999.2500 3 203 -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,~828 -999, 500 -999, 500 -999,2500 .-999.2500 -999~2500 -999.2500 -999,2500 "999,2500 2 1802 -999 2500 -999 2500 '999 2500 -999 2500 -999 ,2500 -9 2500 ~999 2500 I 9808 -999 2'500 -999 2500 ~999 '999 2BO0 '999 2500 "999 2500 -999 2500 .2,4816 -999,2500 -999,2500 -999,2500 LVP OlO,H02 VERIF.I. 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NPHI RCNT MGR PEF SSHV TENS DPHX NPHI RCNT SGR PEF SSHV 5I'TH TENS DPHI NPHX RCNT SFbU PEF bITH TENS DPHI NPHI RCNT SFbU SGR PEF -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 2 4900 -999 2500 "999 2500 '999 250O -999 2500 -999,2500 -999 2500 -999 2500 -999 2500 2,6713 -999 2500 -999 -999 2500 -999 2500 '"' ~999 "999 2~00 2 8559 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ~999 -999 )500 500 3,4100 '999 ,2500 -999 2500 -'999 2500 '999 2500 -999 2500. -999 3500 -999 2500 ~999 2500 3,7~19 -999,2500 -999,2500 OLS GR CALI CFTC DEPT I LD i~HOB SS1 CALI TNRA CFTC RHOB OL8 CALl T~{RA CFTC DEPT 1ED RHOB SS1 CALl TNRA CFTC DEPT ILD GR CALl DEPT -999 2500 OSS -999 2500 bS -999 2500 SS2 -999 2500 RHOB -999 2500 TENS -999 2~00 RT~R -999 2500 CNTC 4400 0000 GR -999 -999 -999 -999 110 9 3 5O9 09'78 2500 DPHI 2500 2500 250O SS2 8750 0391 TENS 4~33 RTNR 4409 CgTC 4300 0000 GR 19 2332 Ih~ -999 -999 -999 -999 128 9 2 731 250O DPH1 2500 250O bS 250O SS2 1250 7031 TENS 8506 RTNR' 8710 CNTC 4200 0000 Ga 4 -999 -999 -999 -999 89 10 3 545 5382 IbM 2500 DPHI 2500 OSS 2500 bS 2500 $S2 7500 RHOB 2891 TENS 4626 RTNR 4{92 CNTC 4100 0000 GR 6 -9 -999 -999 8O 9 '3 672 6583 Ib~ 25'00 DPHi 2500 O$S 2500 bS 250 RHOB 4609 TENS 2357 RTNR 1031 CNTC' 4000,0000 GR 1'22,3068 -999,2500 hSHV -999,2500 LU -999.2500 CAI.,I 999,2500 RCFT -g99,2500 110 8750 SP 3 -999 -999 -999 -99q 2 3700 3 1785 9244 TENS 2500 DRHO 2500 LSHV 2500 2500 CAbI 2207 DRHO 0000 G~ 6034 RCFT 8232 TE~S 128 1250 SP 16 -999 -999 -999 ~999 2 3510 2 2022 8504 TENS 2500 2500 2500 bU 2500 CA5I 2988 DRHO 0000 GR 7625 RCFT 6245 7500 SP 2057 TENS -999 -999 -999 -999 2 3484 3 1884 2500 DRHO 2500 bSHV 250O bU 2500 CAEZ 2266 DRMO 0000 GR 6290 RCFT 2522 TENS 80 6250 8P 6 '999 '999 '999 -999 2 3354 2056 4438 TENS 2500 DRHO 2500 5SHV 2500 [,U 2500 CAb! 2227 DRHO 0000 GR 6501 RCFT 2329 TENS 1,0313 SP ~0,6723 TENS ~999,2500 SSHV 999,2500 LITH 2999,2500 TENS q99,2500 DPH! -999.2500 NPHI -999,2500 RCNT -999,2500 ~34,0000 SFbU 00,0000 SGR ~999.2500 PEF :999,2500 SSHV 999,2500 ~ITH -999,2500 TENS 0,0117 DPH! 110,8750 NPHI 502,3649 RCNT 3700,0000 -44 5000 SFLU 3510 -999 -999 -999 -999 0 128 693 3510 0000 SGR 2500 PEF 2500 SSBV 2500 bITH 2500 TENS 0571 DPHX 1250 NPHX 8467 RCNT 0000 -36,2500 SFbU 3484,0000 SGR -999,2500 PEF '999,2500 SSHV '999,2'500 blTH '999,2500 TENS 8 750O ~PH2 495,3349 RCNT 3484.0000 '40.5938 SFbU 3354 0000 SGR '999 2500 PEr -999 2500 SSHV "999 2500 hZTH '999 2500 TENS 0.0322 DPHI 80,6250 NPHI 646,9391 RCNT 3354,0000 -68,6875 3330,0000 SGR -999,2500 -999.2500 o999,2500 -999,2500 -999,2500 -999,2500 3 6679 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 41 1810 8401 20 8675 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ]1 2831 0 1961 2027 4089 4 t8'87 -999 2500 -999 '999 ~0'0 -999 2500 25 6629 39 8371 1783 3098 6 622'7 -999 2500 -999 2500 '999 2,500 -99'9 ~500 -9992500 9289 2064 8203 9),7834 -99 ,2500 I.,VP OlO,H02 VErIFiCATiON blST£N(; PAGE 14 GR CALl TN~A CFTC -999 2500 DPHI -990 2500 OSS -999 2500 LS -999 2500 SS2 61 ({t13 RHOB 11 6016 TENS 2 5885 RTNR 851 5714 C!ITC -999 2500 I)RHO -999 2500 LSHV -999 2500 LU -999 2500 CAhI 2 2949 DRHO ~330 0000 GR 3 n240 RCFT 2381 6279 TENS DEPT RHOB OhS GR CALl TNRA CFTC ]900 o000 GR 4 -999 -999 -999 -999 108 13 3 468 4450 2500 DPHI 2500 2500 LS 2500 SS2 6875 RHOB 0.{13 TENS 6625 RTNR 2013 CNTC 108 6875 SP 4 -999 -999 -999 -999 2 3154 1720 1534 TENS 2500 DRHO 2500 LSHV 250O Lb 2500 CAb! 2520 DRHO 0000 GP 7778 RCFT 4639 TENS DEPT ILo RHOB QLS SSi. GR TNRA CFTC 3800 0000 4 -999 -999 -999 -999 91 12 3 458 GR 0773 2500 DPH1 2500 OSS 2500 2500 552 6250 RHOB 4453 TENS 7459 RTNB 0498 CNTC 91 625O SP 3 -999 -999 -999 ~999 2 3214 3 1691 8383 2500 DRHO 2500 hSHV 2500 2500 Ci~l 2109 DRHO 0000 GR 925 RCFT 624 TENS DEPT RHOB OR CALl CFTC 3700 0000 GR 4 -999 -999 -999 -999 93 12 443 9108 2500 DPltI 2500 2500 2500 6875 RHOB 6875 TENS 7680 RTNR 8042 C~TC 93 6875 SP 4 -999 -999 -999 -q99 2 3.184 4 1628 2500 LSHV 2500 bU 250O CAUl 2305 DRHO 6023 TENS DEPT IhD RHOB $$I GR TNRA CFTC 3600 0000 4 2 0 233 240 54 9 4 394 GR 8389 2187 DPHI 0000 6250 [,$ 6250 2187 RHOB 9766 TENS 1929 RTNR 0579 CNTC 72 4 26 0 435 340 2 2964 3 1590 31.25 SP 7952 TENS 0254 DRHO 0195 LSHV 7500 [,U 0000 CALl 0371 DRHO 0000 GR 8868 RCFT 2000 TENS -999.2500 PEF -999.2500 SSHV -999.2500 blTH '999,2500 TENS ~:0073 OPHI 6 0313 NPHi 795.2754 RCNT 3330,0000 '39 7500 3154 -999 -999 -999 -999 0 10B 433 3154 0000 SGR 2500 PEF 25OO SSHV 2500 blTH 2500 TENS 0137 DPHI 6875 NPH! 7109 RUNT 0000 321 -999 -999 -999 -999, 0 91 404 3214 3438 SFbU 0000 SGR 2500 PEr 2500 SSHV 2500 bITH 2500 TENS 0151 DPHI 6250 NPH! 6274 RCNT 0000 -41. 3184 -999 -999 -999, -999 0 93 410 3184 4688 SFbU 0000 SGR 2500 PEF 2500 SSHV 2500 bITH 25O0 TENS 0469 DPHi 6875 NPHI 3296 RCNT 0000 -999 2500 -999 2500 -999 2500 -999 2500 21 5i99 29 1819 2263 4287 3 63b0 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 7704 1649 8801 '999 2500 '999 2500 "" -999 2~ 6099 43 5790 1648 0894 4.231o -999 2500 -999 2500 -999 2500 .999 2500 -999 2~00 25 4261 43 864'2 1547 6619 2 ,0000 SGR 7 24 o.o o l . ,oooo ,3516 TENS 31.64~ O0 '0.4282 DPHI 37,!i49 54,2287 *NPH! 50, 52 344,8881 RCNT 1594. 95 3164.0000 DEPT 3500,0000 GR 77,2500 SP -33,6250 SFbU 5,5563 i,VP 01C.H02 YERIFiCATIU,~, [,ISTib:.C; PAGE 15 OhS CALl CFTC DEPT R HOB L£, GR CALI TMRA CFTC DEPT RROB GR CALI TURA CFTC DEPT RHOB GR CALl TNRA CFTC DEPT RHOB Lb GR CAbI TNRA CFTC 2 -0 303 262 51 9 4 344 3400 4 2 -0 266 244 -999 -999 4 410 3300 5 -0 251 24! -999 -999 454 3200 4 2 -0 24O 239 -999 -999 4 432 3100 4 2, -0 253 244 -999 -999 3 420 ,4810 ibm ,1230 DPhl 0078 OSS 2500 7500 0313 RHO8 8906 TENS 2094 RTNR .5958 C~TC 0000 4546 Ib~ 1484 DPH1 0{)98 OSS 2500 5O0O 882 2500 R~IOB 2500 TENS 013'7 RTMR 0838 CNTC 0000 GR 6364 1758 DPHI 0t66 0000 3750 25OO NH08 2500 TENS 8217 RTNR 8720 CNTC 0000 GR 9858 lhh 201.2 OPH! 0029 OSS 3750 58 6250 SS2 2500 RHOB ,2500 T~NS 0795 RTNR 7060 CNTC 0000 6735 1719 DPHI 0146 2500 5000 ~500 .2500 TENS 8851 RT'~R 8769 CNTC 31 0 562 374 ! 2940 4 1450 4 3O 0 496 352 -999 -999 4 1624 66 5 28 0 471 348 -999 -999 3 1691 63 4 27 0 448 346 -999 -999 4 1716 72 4 28 0 475 350 -999 -999 3 1.618 3113 7871 0273 0000 7500 8457 0000 .4773 ,6633 1875 3832 2'134 0146 7500 2500 2500 2500 139 .5000 .6197 .7109 .0093 .5000 ,2500 ,2500 ,2500 ,8167 ,0859 2500 8938 0996 0049 5000 2500 500 5OO 3725 1135 3125 6593 8574 '0151 0000 5000 2500 2500 8727 7852 TENS LU CAhI DRHO GR RCFT TENS TENS DRHO LSHV LU CALl GR RCFT TENS SP DRHO LSHV bU CAbI DRHO GR RCFT TENS SP TENS DRHO LSHV C~bl DRHO RCFT TENS TENS i)RHO LSHV LU CAL! DRHO GR RCFT TENS .0000 253C~,051~ 1187 0000 517 5000 15 1250 -0 4868 78 3474 333,1082 3180,O000 '34.5938 2470 0000 0 0103 1188 0000 460 750O 14 6094 -999 2500 90 8056 3~07 8406 34 0000 -49 3750 2370 0000 0 0078 1188 0000 440 7500 15 1094 -999 2500 67 8490 440 3149 2810.0000 2394 0 0 00'78 1188 0000 ooo -999,2500 76 7193 425 2584 2984 0000 2330,. O0 0,0122 1187,0000 443,2500 14,4297 '999,2500 75,9935 4~.0()15 28 ,0000 SGR PEF $SHV LITH TENS NPHI RCNT SFLU SGR PEF SSHV LITM TENS DPH! NPH! RCNT SFLU PEF SSHV LITH DPH! NPHI RCNT SFLU SGR PEF SSHV LITH TENS DPH! NPHI' RCNT SGR PEF SSHV LITH TENS DPHI NPHI RCNT 78,~474 2, 629 1147,0000 170,0000 3180,0000 48,7453 50,7789 1507,6702 4 2258 90 8056 1147 147 1250 3234 0000 -999 2500 47 4415 1677 7083 5 6357 67 8490 2 7305 1 7500 tlI~ 0000 oooo 2500 43 6870 1779 7~49 4 7600 7~ 7193 7969 ~147 0000 129 ,~50 2984 0000 -999 2500 48:3559 1783 8145 4 4,25 75 ,9 3~ 2 00,~0 1147 1,29 6250 2840 0900 -999 2500 45,,½ 5 LVP OlO,H02 YE~IFICATIO~ LISTING PAGE 16 D~.IPT 3000,0000 lbo 6,326b IbM RMOB 2,1816 DPHI 055 O,OOb3 l'b 248,2500 L8 851 238,6250 882 GR -999,2500 RHOB CALX -999.2500 TENS T~RA 3,9032 ~TNR CFtC 475,0a47 70,~750 SP 2 3~03 D~HO 46 0000 bU .344,5000 CALl 999.2500 ORHO -999.2500 GR 4,2692 .~CFT 1814,1982 ENS DEPT 2900 0000 ILD 614820 IbM RHOB 2 2129 DPHI ~b$ -0 0122 bb 229'7500 SSI 233:5000 SS2 GR -999,2500 RHOB CALl -999,2500 TENS TNRA 3,8225 RTNR CFTC 441,3611 C~TC 79 4375 SP 6 ~6 0 432 336 -999 -999 3 1696 DRHO 0044 bSRV 2500 bU 5000 CAL! 2500 DRNU 2500 GR 8909 ~CFT 8425 TENS DEPT ILD 6 RHOB 2 QbS 0 bb 296 SS1 234 GR -999 CAbI -999 TNRA 3 CFTC 452 2800 0000 GR 6429 I. bN 0723 DPHI 0005 5000 ~750 2500 RHOB 2500 TENS 8792 RTNR 3318 CNTC 36 1250 6 34 0 549 ,,99 -999 4 ~704 6062 TENS 8633 DRHO 0063 ~SHV 0000 bU 2500 CA~I 2500 DRHO 2500 GE 077 RCFT 638 TENS DEPT IbP CAbI TNRA CFTC 2700 0000 8 2657 2 0 238 231 -Egg -999 3 444 1973 DPHI 0176 ~$S 5000 DS 2500 882 2500 RHOB 2500 TENS, 7558 RTNR 6795 CNTC 7 27 0 439 332 -999 -999, 3 1635 438 DRHO 0078 ESHV 7500 bU 7500 CALl 2500 DRHO 2500 OR 9245 RCFT. 0874 TENS DEPT IGD ' RMOB OL8 b L, CALI TNRA CFTC, 2600 0000 OR 70 7834 I~M , 466 242 -999 -999 4 341 8232 DPHI 0439 OSS 7500 bS 0000 882 2500 RHOB 2500 TENS 5955 RTN~ 9723 CNTC 29 5469 SP 70 50 0 854 360 -999 -999 5 1564 9271 TENS. 0488 DRHO 0322 LSHV 0000 ~U 2500 CAE! 2500 DEHO 2500 GE 0233 RCFT 9888 TENS -66.1250 SFb[J 2250.0000 SGR 0.0049 PEF 1188.0000 SSHV 42{ 5000 hITH 14 0781 TENS -999 2500 DPH! 73 9442 NPHI 490 4877 RCNT 2820 0000 -49,0313 SFbU , :oooo 0005 PEF 1188 0000 SSHV 404 7500 ~ITH 15 0391 TENS -999 2500 OPHI 82 2291 {~PHI 448 9858 RCNT 2850 0000 -86 2500 2170 -0 1187. 5O4 13 -999 33 448 2790 0000 SGR 0093 PEF 0000 SSHV 7500 high 8984 TENS 2500 DPHI 8033 NPHI 9858 RCNT 0000 -54. 5625 ISFbU 215a, '0 1.188 402 . 5 76 450 2734 0000 SGR 0044 PEF 0000 'SSHV 7500 blTH 08~9 TENS I OO 53 NPHI 7610 RCNT 0000 2~ 62 6~' ~0 1187 775 15 '-999 30 .266 0938 SFbU oooo .0176 0000 SSHV 0000 4141 TENS 2500 DPttI 291 NPHI 7 0463 73 9442 3 5059 1147 0000 119 25 -99 2500 45 6736 1920 9836 5 9237 82 2291 2 9082 114~ 0000 11 8750 2850 0000 "999 2500 43 7347 1799 0645 6 8663 33 80 oooo OOoo 6,8266 76,38"~3 ,0000 lti'"'?'oooo 99 2500 42 4903 1670 7241 114½1 0 ~08. 0 ..26 o° "999. .2500 7073 ~555 9792 LyP 010,B02 VERIFICATIo!,i LIS'rING PAGE 17 DEPT RHOB CAL,! CFTC DEPT IDD SSI GR CALI T~RA CFTC DEPT ILD Lb GR 'CFTC DEPT RHOB CFTC DEPT GR 2500,0000 GR 16,4257 IhM 2.0996 DPH] 7,'7500 US 243 0000 SS2 -999 2500 RHOB -999 2500 TEN5 3 6983 RTNR 481 5215 CNTC 2400 o000 GR 13 2 -0 256 236 -999 -999 4 399 0175 1523 DPHi 0142 OSS 2500 bS 0000 S32 2500 2500 TENS 0074 RTNR 3~88 CNTC 2300 0000 I~ 1048 2 O02O -0 O034 335 5000 236 6250 -999 2500 -999 2500 3 9533 434 GR IbM DPHI SS2 RHOB TENS RTNR 9012 CNTC 2200 0000 22 9485 2 0586 0 003~ 30'5 5000 236 8750 -999 9500 -999 2500 3 9261 429 2976 GR RHOB TENS RTNR CNTC 2100 0000 8 6746 I 9443 0 0273 372 2500 236 0000 -999 2500 -999 2500 4 GR 582 RHOB TENS 6794 RTNR 15 33 0 537 345 -999 -999 3 51 3125 Sp 9125 TENS 3008 DRHU 0313 LSHV 0000 btJ 5000 CALI 2500 DRHO 2500 GR 5968 RCFT 1717.1584 TENS 63 ~875 12 30 0 480 340 -999 -999 4 1608 2381 TENS 1270 DRHO 0112 bSHV 25OO bU 7500 CALX 250O ORHO 2500 GR 4792 RCFT 475~ TENS 53 8125 SP 15 39 0 625 352 -999 -999 4 1675 8904 TENS 2090 DRHO 0088 bSHV 0000 bU 2500 CAb[ 2500 DRHO 2500 GR 0588 RCFT 2576 T~N~ 53 9062 21 35 0 565 344 -999 -999 4 17t3 1,210 TENS 7422 DRHO 0186 I.,$HV 0000 LU 5000 CAL! 2500 DRHO 2500 GR 1000 RCFT 3064 TENS 71 06'25 8 42 0 682 358 -999 -999 4 1157 Tg'NS 6758 VRHO 0010 bSHV 5000 bU 2500 CALI 2500 ORHO 2500 GR 5676 RCFT 2005 0 1187 498 484 -77 3750 SFbU 0000 SGR 0039 PEF 0000 SSHV 7500 LITH 9141 TENS 2500 DPH! 8531 NPH/ 4561 RCN? 2694,0000 -71,3125 SFLU 2025,0000 SGR -0,0015 PEF 1187,0000 SSHV 447.7500 blTH 14e3203 TENS '999,2500 OPHI 71,7979 NPHZ 403,1289 RCNT 2624.0000 -77 5625 SFbtl 1915 13 '999 25 0000 SGR 22 PEF ~00 $$HV 0000 L{TH :,~297 TENS 500 DPH! 78NPHI 49~ RCNT 0O00 -74 5625 8FbU 1960 0000 SGR 51'8 14 -999 54 PEF 5000 bITH 1562 TENS 2500 9720 6680 RCNT 0000 -67 1875 SFbU 2900 -0 1186 69 280 0000 SGR 0176 PEF 0000 SSHV 0000 blTH 1 09 ~ENS 500 DPHX 026 NPHX 546 RCNT 18 847½ 1147 oooo 153 2500 2694,0000 -999,2500 420022 1850,6997 l 1 2393 7 t 7979 3 0469 1147 0000 1 6 2614 7500 0000 -999 2500 47 4668 1636 6150 17 7002 1146 0000 195 7500 2660 0000 -999 2500 46,6605 1.744 6655 18,94 500 157. ~0 0 2B60, 0 -ggg ¢9~,2~00 1513,42 4 tYP 01¢',H02 VKRIFICA'I'ION bIST1N(.; PAGE 18 CFIC 315,8243 CNTC O~T 2000 0000 eR LL 358,5000 5S SS1 241,0000 $$2 -999.2500 RHOB ~LI -999,2500 TE~B TNRA 4,0810 RTN~ CFTC 392,9627 CNTC DEPT ].900 RHCfl 2 bt 298 ~R -999 CALf -999 CFTC 448 0000 GR 8240 I[.,N 0605 DPHI 0068 5000 1250 SS2 2500 RilOB 2500 TENS 8986 RTNR 45]6 CNTC DEPT RHOB CALl TNRA CFTC 1800 0000 92 8234 2 0605 0 O029 304 OO00 232 7500 -999 2500 -999 2500 ~ 6143 458 5867 GR DPHI RNOB RTNR CNTC DE~T RHOB SS1 GR TNRA CFTC 1700,~00 65, 79 1,9736 0 0049 358 2500 242 6250 -999 2500 -999 2500 4 0047 488 9470 GR DP~I $$2 RHOB TENS RT~R DEPT ILO RHOB 881 CALl. 1600,0000 GR 591,8715 ,1,6494 DPHI 0,0~1 681,0000 .287,0000 .999,2500 RHO5 999,2500 TENS 1433 ~5 37 41 0 650 358 -999 -999 1568 5~ 19 35 -0 555 3~5 -999 ~999 1722 49 100 3~ 0 -999 -999 1707 56 36 40 0 664 362 -999 -999 4 1914 36 816 6O 0 1316 448 -999 -999 ,3596 9062 1628 0~45 0142 0000 2500 2500 2500 4783 6650 .5000 9768 6934 0015 5O00 0000 2500 2500 9464 8044 6875 7952 5957 0029 5000 5000 2500 2500 815 110 5000 57'01. 9668 0103 5O0O 750O 250O 250O 3051 6890 7813 3600 957 210 0000 7500 25O0 250O TENS T~NS DRHO LSMV CALl DRHO GR SP DR}lB LSHV CAUl DRHO GR RCFT TENS SP TENS ORHQ LU CAb1 DRHO GR RCFT TENS DRHO CA. LI DRHO GR RCFT SP DRHO ~SHV CA. LI DRHO 2480,0000 -81 2500 1855 0000 -0 0083 1187 0000 603 500(1 13 8594 -999 2500 48 1888 386,9744 2490,0000 '78,2500 1765,0000 '0,0156 1187,0000 514,5000 14 2891 -999:2500 65,7757 41 ,6680 2404,0000 125 '80 ~0 1700 O0 -0 0132 1.187 0000 51.6 5000 16 5625 -999 .1500 48 908 467,9563 2250 0000 -68 8125 166'0 0000 -0 0059 1186.0000 613 0000 23 0156 -999 2500 6~ 9630 50 4943 2180 0000 -81,.7~00 1565,0C00 0,0552 1184,0000 1269,0000 .u23,'1562 ...99,2500 40,6316 SFLU SGR PEF SSHV LITH TENS DPH! NPH! RCNT SFLU PEF $SHV TENS DPHI SFbU SGR PEF SSHV blTH TENS NPHI RCNT SF~U SSHV TENS DPHI NPHI RCNT SGR PEr SSHV TENS DPHI NPHI 34 7 2 7754 1146 0000 191 ~750 2490 0000 -999 ~500 49 347 1628 9299 41,0547 64,7737 2 757S 1146 0000 155 3750 404 0000 999 2500 45 4895 1714 1453 120,6505 48,8908 114~'34'38 ,0000 ,0000 999.2500 39;~889 1803, 466 29 i2 6 6~ '402 1146 000 21- 000 218~ ~750 -999 2500 43 2317 1952 2351 95 3529 40 6316 2 4883. 1146 0'000 ,o, 2010 -999 2500 63 7833 T,yp 010,HO2 V[,'RIFiCATlt],,,i 1, ISTING P&GE 19 TNRA 251,8180 CNTC DEPT iLO 492 RHOB 1 OL$ -0 LL 444 $$1 282 GR -999 CALl =999 TNRA 3 CFTC 426 DEPT RHOB Lb GR CALI TNRA CFTC DEPT lbD RHOB GR CAb! CFTC DEPT ILO Lb GR CAbI CFTC ILD 1500 0000 GR 5.2187 ~CFT 1~52.6047 ~E~S 3929 IU~ 2000 9238 OPH! 43 0166 OSS 0 75O0 LS 836 7500 $52 415 2500 RHO8 -999 2500 TENS -999 8486 NTNR 3 5587 CNTC ~655 1400,0000 GR 2000.0000 IL~ 520 1,8789 DPHI 46 0.0112 ()SS 0 4~9,5000 ~$ 780 ~ 2.000O 582 -9q°'2500 RHOB -999 -99~:2500 TENS -999 3,7546 RTNR 4 51~,6427 CNTC 1923 I300 0000 GR 0000 ILN 266 8291 OPHI 49 0093 OSS 0 75O0 b$ 865 5000 SS2 395 2500 RHOB =999 2~00 TENS -999 0 31 RTJ~R 4 1669 CNTC 1688 2000 1 0 462 -999, -999 4, 411 1200 0000 G~ 6839 ILN l[ 0742 DPH! 34 0005 QS$ 0 5000 h$ 545 8750 $$2 347. 2500 RH08 -999 2500 TENS -999 2454 RTNR 4 1202 CNTC 1484 2, -0 294 .233 999 '999 4 1100 .0000 GR 27 3747 IbM 2 1738 OPHI 0 ~1~7 250 000 233 7500 -999 2500 R~OB 43 8125 SP 0000 TENS 9453 DRHO 0327 LSHV 5OO0 bU 7500 CALI 2500 DRHO 2500 GR 9811 RCFT 9182 T~NS 6875 SP 7633 TENS 6797 DRHO 0083 LSHV 5000 LU 5000 CALl O0 DRHO 1055 RCFT 9849 TENS 28 1562 SP 9684 TENS 6582 DRHO 0020 LSHV 0000 E'U ,0000 CALl 2500 DRHO 2500 GR 346.2 RCFT 6592 TENS 71 4375 6491 TENS 8145 DRSO 0010 LSHV 5000 LU 2500 CALI 2500 DRHO ,2500 GR 7179 RCFT 5049 TENS 71. 22 28 0 462 335 -999 500 SP 604 ~E.$ 8086 DRHO' 0t, 37 LSHV 5000 bU 0000 CALI 2500 [)R~O 232,5179 RCNT 2~10.0000 -45 5000 SFLU 1545 0o00 0 0732 PEF 1186 0000 SSHV 784 0000 23 031~ TE~8 -999 2500 OPM! 42 9304 NPHI 399 9673 RCNT 2060 0000 -35.7500 SFLU 1500 0000 SGR -0 0132 PEF 22 23. '999 39 2050 0000 SSHV 0000 LITH 1406 TEN~ 2500 DPH 7082 NPH! 1499 RCNT 00o0 05 0 1183 804 23 -999 48 409 2080 5000 8FLU 0000 SGR 0005 PEF 0000 SSHV 5000 bITH 1406 TENS 2500 OPHI 2911 ~PHI 9689 RCNT 0000 14 ,5 -0 1186 5O2 t'4 -999 87 1980 0000 SFLU 0000 SGR O0 0000 7'734 TENS 2500 OPHl 5707 NPHI 6470 RCNT 0000 -34 1380 -0 1187 424 5313 SFbU 0000 SGR 0029 ~EF 0000 $$HV 0000 8203 2500 DPHI 1237,0212 63 5686 4~ 9304 0918 14~ 0000 128 0000 2060 0000 '999 2500 40 656 1731 ~622 96 9160 39 7082 2 i 3 1146 0~0~0 285 0000 2050 0000 -999 2500 38 5918 2001 3430 77 7879 ' 500 20'8~ 0000 t~,1644 ,5707 ,9355 114 ,0000 14 ,6250 198 -99~,2500 51,6022 158 ,2158 ,2500 193~'0000 ' ~'99 ,2500 LVP 010.H02 YERI?'ICA'?,[Oi, hiSTII,!G PAGE 20 CAI, I -999.2500 TENS -999.9.500 GR lf~Ri 4,0719 RT~,~R 4,2400 GCFT CFTC .425.5788 C~TC 1709,7014 TENS ILD 1185 RHGB aLS -0. LB 746 SS1 279 GR -999 CALl -999 TNRA 4 CFTC 302 1000 8875 5664 DPHI 0190 0000 0000 S$2 2500 2500 TENS 6745 1094 CNTC 38 5625 260 65 -0 1455 470 -999 ~999 i342 SP 9125 TENS 6250 DRHO 0239 LSHV OO00 hO 2500 CA[,I 2500 DRHO 2500 GR 5946 RCFT ?756 TE~S DEPT ILD RHOB Lb SS.1 GR CAL! TNRA CFTC 900 0000 GR 150 6172 ILi~ 1 -0 715 256 -999 -999 4 265 5439 DPHI 0337 USS 500O 7500 2500 RHOB 2500 TENS 8359 RTNR 6884 CNTC 36 9062 SP 48 8920 TENS 66 0 1415 402 -999 -999 4 1275 9922 DRHO 0308 LSHV 0000 £,U 0000 CAbI 2500 DRHO 2500 GR 9000 ~CFT 4385 TENS DEPT RHOB SS1 GR CALl CFTC 800 0000 G~ 108 -0 474 265 -99~ -99 4 9358 a174 DPH! 37 2500 SS2 2500 2500 TENS 6~39 RTNR 0127 CNTC 45 9687 46 50 0 901 396 -999 -999 4 1377 SP 88a8 TENS 3906 DRHU 0332 LSHV O000 LU 2500 CALI ~500 DRHO 2500 GR 7353 RCFT 3359 TENS lbo RHOB SS1 CAbI TNRA CFTC 700 o000 GR 2 0 320 230 -999 -999 4 314 0155 IbM 0293 DPHI 0190 QSS 5000 bS 750O SS2 2500 RHOB 2500 TENS 3961 ~TNR 0718 CNTC 66 7500 9 37 -0 588 351 -999 -999 4 1454 9636 TENS 5488 DRHO 0127 bSHV 0000 bU 7500 CA.bI 2500 DEHO 500 GE 895 RCFT 0364 TENS DEPT ~HOB Lb 610,0000 4,2406 1,9922 DPHI 0.0073 '363,2500 262,0000 882 3 8 TENS 39 7949 DRHO 0 0391. LSHV 677 5000 hU 376 7500 CALl 75.219~ ~PHI 432,6841 RC~'T 1930,0000 -27 0000 SFbU 1310 0 1185 1418 23 -999 44 284 1875 0000 SGR 0278 PEF 0000 SSHV 0000 EXTH 0938 TENS 2500 DPHI 3716 NPHI 1061 RCNT 0000 -29 7656 SFEU 1245 -0 1185 1399 23 -999 42 251 0000 0093 PEF 0000 $SHV 0000 bITH 0781 TENS 2500 OPHI 7493 NPH! 6185 RCNT 0000 36.7500 SFbU 1~50.0000 ~GR 0 0~42 PEF 1186 0000 SSHV 853 5000 hlTH 23 0000 TENS -999 ~500 DPHI 50 839 NPHI 286 5001 RCNT 1650 0000 0'000 SFhU 1085 87 1~35 2~ -999 67 323 1600 0000 SGR 0186 PEF 0000 SSHV 0000 hITH 4063 TENS 2500 DPH! 4869 NPHX 5826 RCNT 0000 · -67 5000 SFLO 1000 0000 SGR 0 0288 PEF 1187 0000 SSHV 628 0000 .bITH t8 6875 TENS 47,9250 1787,3895 347 7572 44 J716 1141 4688 0000 445 0000 1875 0000 -999 2500 55 4581 1389 9t16 98,5{13 42 749{ 2 3164 1146 0000 425,5000 ~770,0000 ~99,2500 58 4213 1307 2153 50 58~98 Il41 0000 268 2500 1650 0000 ~337 6621 12 74t1 67 4869 · 2 5566 oooo ,2500 50,6918 1570,9404 3,5614 91,5304 2,7832 146,0000 119~,5000 145 ,0000 [,VP 010,H02 VE~IFI, CATIO!~ [,ISTXNG PAGE 21 Gp 999.2500 RHUB CAt. I ~999,2500 TENS TNEA 4.8769 RTNR CFTC 263,0255 CNTC DEPT IDD OL$ -0 Lb 1057 SS1 267 GR -999 CAL! -999 TNRA 4 CFTC 297 DEPT GR TNRA CFTC DEPT RHOB bb CAb! TNRA CFTC DEPT 'RHOB LL CALI TNRA CFTC DEPT RHOB 500 0000 GA 692{ 3252 DPHI 0430 QSS 0000 LS 0000 S$2 2500 RHOR 2500 TENS 3748 RTNR ]845 CnTC 400 0000 GR 5 1 -0 848 290 -999 -999 4 275 1757 I£,M 5088 DPH! 0391 OSS 5000 5S 2500 852 2500 RHOS 250O TENS 4651 RTNR 6800 CNTC 30O 0000 GE 4 1 -0 376 255 -999 -999 4 288 8572 9502 DPHI 0132 0000 5000 2500 RHOB 2500 TENS 4615 RTNR 9045 CNTC 200 0000 29 7103 2 "0 331 25O -999 .,-999 4 348 0273 DPHI O078 OSS 75OO 55 25OO SS2 2500 RHOB 2500 TENS ],702 RTNR 5603 CNTC lO0 0000 GR 2000 0000 IbM 2 0293 DPHI 0 0947 Q$8 89 6875 LB -9'99 2500 DRHO '999.2500 GR 5.0313 ~CFT 1257,1079 TENS 55 6875 8 80 -0 2354 465 -999 -999 4 1311 0350 TENS 2246 DRHO 0215 bSHV 0000 bU 0000 CALI 2500 DRt40 2500 GR 6571 RCFT 5793 TE~S 62 0625 SP 4 69 0 69 146~ -999 -999 5 1264 0799 TENS 0918 DRHO 0244 LSHV 0000 bU 5000 CAb! 2500 DRHO 2500 GR 1935 RCFT 1~13 TENS 72 6875 3 42 0 707 377 -999 -999 1274 4508 TENS 3828 DRBO 0229 bSHV 0000 bU 5000 CAbI 2500 DRHO 2500 GR 8529 RCFT 3811 TENS 42 9687 aP 17 1307 TENS 37 0 364 -999 -999 4 1437 5977 DRHO 0234 5SHV 0000 bU 2500 CALl 2500 DRHO 2500 GE 3659 RCFT 8699 TENS 29 0313 SP 1 8976 TENS 37 5000 DRHO -0 ~133 BSHV 174 750 LU '999,2500 DPHI 91,5304 NPHI 254.7197 RCNT 1450.0000 -BO 7500 SFbb 1090~0000 SGR 0,0020 PEF 1183,0000 $SHV 2194,0000 LITH 22.9531 TENS '999.2500 OPM[ 64.5689 NPHI 300,0069 RCNT 1365,0000 -77 0000 SFLU 960 000o SGR 1682 23 -999 76 0562 PEF 0000 SSHV 0000 hlTH 0313 TENS 2500 DPH! 3079 NPHI 5808 RCNT 0000 '71,7500 SFbU 865 0000 SGR 661 14 -999 1275 0098 PEF 0000' SSHV 5000 LITH 6328 TENS 2500 DPHI 7270 NPH! 351i RCNT 0000 -73 815 0 t187 45 1285 !500 SFbU )000 SGR 0083 PEF 0000 SSHV i~000 bITH 541. TENS 2500 DPH! 7804 NPH! 5574 RCNT 0000 -78,0000 SFLU 76~50.0000 SGR 118 ,7061 PEF ~9'0000 SSHV 16 ,3750 LITH -999.2500 61,2872 1326,1575 11 5919 64 5689 2 3398 1145 0000 652 0000 1365 0000 -999 2500 50 0438 1294 5891 8 5 76 2 8320 1145 0000 468 0000 1335 0000 '999 2500 51 6540 131.4 2668 8 0324 76 7270 2 7578 1146 0000 ,19 oooo 2500 55,6294 1309 1816 67 1146 O0 -999 ~500 49 7990 1488 1936 9 18 5000 1148 0000 19 0313 bVP OlO,H02 YER1FICATiO~ bISTIi~G PAGE 22 SS! 75 7500 SS2 GR '999' CALI .999,2500 RHOB ,2500 TE~S TNRA 4,1628 RT~:R CFTC 286,5018 CNTC 122 5000 CALl -999 2500 DRHO -999 2500 GR 4 1471 RCFT 1262 6567 TENS DEPT IUD OhS 0 hL 155 SSi 75 GR -999 CALl -999 TNRA 5 CFTC 231 30 0000 -999 2500 6104 DPHI 1284 75OO 6875 2500 RHOB 2500 TENS 1907 RTHR 5599 CNTC -999 2500 SP -999 2500 TENS 62 -0 293 129 -999 -999 5 1179 9395 DRHO 1089 0000 bU 8750 CAbI 2500 2500 GE 4138 RCFT 9829 TENS ~ FII, E TRAI~ER ~ FII, E NA~E :EDIT ,OOi SERVICE NAME I DATE { ~AXINU~ I, ENGTH : 1024 FILE TYPE NEXT FILE NAME ~ 15 3125 TEN& -999 2500 DPHI 27 5534 NPH! 256 2389 RCNT 1195 0000 -999,2500 SFLU -9~,2500 SGR ,7925 PEF 1189.0000 SSHV 274,5000 blTH 15,3359 TENS -999 2500 DPHI 19 2626 NPHI 226 1709 RCNT 1215 0000 1195 .999'~000 , 500 49, 3 4 1441.~?~2 -999 2500 19 2626 23 0469 1149 0000 31 9219 99 2500 68 64~8 1234 7639 ** FINE HEADER FILE NA~E :EDIT ,002 SERVICE NAif VERSION # Fib 'tYPE PRE~IOU$ FILE ** CO~ENTS ~$ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS LVF 010,~02 VEklFICATIO~,, [:].STING PAGE 23 ~ (SEE FILE EDIT.O01. FOR 6" SaMPh~D DIB/LDT/FDC/CNL DATA) RUN 2" FORMATION DENSITY CO~PE~]SATEO ~OG I~iR8Ta TO bAST READING: 771~' TO 7049' * RUt~ ~2, I~2" ~OMPENSATED NEUTRON bOG * IRS~ TO .bAST kEADING: 770~' 0 7049' * DATA FORMAT RECORD ** E~TRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 1 66 8 4 7~ 9 4 65 16 1 66 1 0 1 66 0 D~Tb~t SPECIFICATIOM ObOCKS ~NE~ SERVICE SERVICE UN'~T AP1 APl AP1 APl FIbE SIZE SPL REPR iD ORDER # DEPT GR FDH RHOB FDH DRHO FDH DPHI FDH CA/,I FDH TENS FDH ~ROCE$6 CODE~CO 6S 00000000000 000 68 00000000000 68 O0000000000g0000 68 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 BOG TYPE CLASS MOD NO. f'T O0 000 O0 0 0 4 GAP! O0 t10 01 0 0 4 G/C3 O0 3 50 02 0 0 4 G/C3 O0 '356 01 0 0 4 PU OO 890 O0 0 0 4 IN O0 280 O1 0 0 4 bB O0 635 2~ 0 0 4 GAPI O0 310 oi 0 0 4 LVP OlO,H02 ¥.~RiFICA'rlO,~ LISTi[i'~G PAGE 24 ~PH! C~H Pd 00 T,~RA C,~'~ OO RTNR C :~ O0 RCFT CM~ CPS 00 ~CkT C~,J~ CPS O0 CFTC C~H CPS 0(') C~;TC C~:~ CPS O0 TE'~$ CNh LB 00 890 ~20 000 000 000 000 000 635 ~ DLTA ~* OEPT 7773 0996 GR DpH! 28,7405 CALl NPHI 41,7239 TNRA RCNT t796.6379 CFTC DEPT 7700 29~8 GR DPHI 15,1278 CALI NPHI 42,8645 TNRA RCNT 1796.1294 CFTC DEPT 7600 2998 GR DPH! 15,6013 CALl NPH! 38,6489 TNR.A RCNT 1879,9060 CFTC DEPT 7500,2998 GR DPHI 1.4,5360 CAGI NPHI 41.5075 TNRA RCNT 1960,2393 CFTC DEPT 7400 2998 GR DpHI 22,1117 CA.bI ~IPHI 31,0963 TNRA RCNT 2341,5098 CFTC DEPT 7300 2998 GR DPH! -4.40]4 CALI ~!PHI 36,7513 TNRA RCNT 2131,4399 CFTC DEPT 7200 2998 GR DPHI 20i4545 CAL! NP~I 48 9436 TNRA RChT 1516.5237 CFTC DEPT 7100 2998 GR DPHI 15:8381 CALI ~PHI 44,9516 TNRh RC~T 1506,3369 , CFTC DEPT 7048 5000 GE DPHI 15:8381 CAI, I. 108 7 566 10:{ 9 3 535 375 742 .~174 683 ,5625 ,2891 .5460 ,2640 116 2500 8,80~7 '3,2760 601.1022 101.~750 8. 969 * 3~5 3'C~542 577. 8, 94 2,~419 889. 402 58,~563 8, 219 3,1818 761,5414 0v vsoo 9.0469 3,8578 452.6994 127 6875 9i7344 3 6965 480 9358 133 9 ,3750 ,6172 O0 O1 oO po O0 O0 O0 21 RHOB TENS C~TC RHOB TENS CNT¢ EHOB TENS RTNR CNTC RHOB TENS RTNR CNTC ~HOB TENS RTNR CN. TC RHOB TENS C~TC TENS CNTC TENS RTNR CNTC RHOB TENS 2, 1340, 2, 6088, 3. 1831, 2, 575~, , 1946. 2, 5672. 193~, 550 3, 2273, 2, 5344., $. 1671', i' 531 . 1747' 2, 5288, 1758 0000 4193 6736 4004 0000 8571 7485 3926 0000 2013 0723 3200 0~!2 2852 0000 0909 6084 7227 000 ~235 ?2O2 3~25 0000 7895 7336 3887 0000 3889 0496 3887 0000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 DRHO GR RCFT TENS DRHO GR RCFT TENS DRHO OR RCFT TENS DRHO RCf'T DRHO RCFT TENS O~HO RCFT TENS ORHO GR RCFT TENS DRHO RCFT TENS 0,1689 108.4375 518,9822 1340.0000 0.0215 103,5625 506.5173 6088,0000 0,0269 li6,2500 577.7888 5752,0000 0,0215 101,8750 536,0573 5672,0000 "0,0034 69,8125 874.3781 5544,'0000 0 0742 58 6563 748 7360 5508 0000 0,0181 107,7500 419,,~682 5344,0000 0,0479 127,6875 459,9639 5312,0000 0,0127 133,3750 LVP 01C,H02 VEmIFICa'I.'IL';,~ [.=IS'['lNG {?AGE 25 {~}P+.~ I 44,2224 T:'~I~ A 3,~466 RC~T 1612,4839 CFTC 489,9561 RTNR C;~TC ** FILE TRAILER FI£,E NA~E :EDIT ,002 8£RVICB' NA~iE DATE : F'~bE TYPE NEXT FILE NA~E EOF **~****{~* 4,3077 RCFT 1764.3381 TENS 422.6680 5288.0000 ** TAPE TRAILER ** SgRVICB: NAMB :EDIT DATE :88t02/12 ORIGI~ :FSlA CONTINLIAT~ON # :01 NEXT TAPE NAME : COMMENTS tLIS TAPE, AMCO ALASMA, INC, 3}{-I1 AP! 50-103-2009! ** REE£, TRAILER SERVICE NA~E :ED1T NEXT REFb MAM, E : CO~}AEhiTS ;bls TAPE, ARCO ALASKA, INC, ~H-11 API 50-~0~-20091 EOF EOF ~: ..... SCHLUMBERGER .... :~ LIS TAPE YERIFIC,~TION LISTING VP OlO.H02 VERIFICATION LISTING PAGE · REEL HEADER ~* ERVICE NAME :EDIT ATE :.~8!01! 9 RTGIN : EEL NAME :72554 ONTINUATION a :01 REVIOUS REEL : OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3H-11~ API 50-029-21771 .- T&P: HEADER ~ E~VICE ,NAME :ED~_T ATE :85/01! 9 RIGIN :FSI~ APE NAME : ONTINUATION # :0! REVIOUS TAPE : OMMENTS :LIS TAPE, 5RCD ALASKA~ INC. 3H-1~ API 50-029-2!77! * FILE HEADER ** ILE NAME :EDIT .001 ERVICE NAME : ERS ION ~ : ATE : AXIMUM LENGTH : 1024 ILE TYPE : REVIOUS FILE :' INFORMATION RECORDS :NEM CONTENTS N : ARCO ALASKA. IN.Co IN : 3H-11 (COLV~LLE) :N : KUPARUK :ANG: 8E 'OWN: ;ECT: 'BUN: NORTH SLOPE ;TAT: ALASKA INEM CONTENTS ~RES: E COMMENTS UNIT TYPE CATE SIZE CODE 000 000 017 065 000 000 016 065 000 000 007 065 000 000 002 065 000 00,0 003 065 000 000 002 065 000 000 012 065 000 000 006 065 UNIT TYPE CATE SIZE CODE m,~m~ m~ mm~ ~ ~ ~,.,m. ~m.~ .,m.m~ ,,,m 000 000 001 065 · VP 010.H02 VERIFICATIgN LISTING PAGE 2 SCHLUU,~ERGER ALASKA COMPUTING CENTER OMPANY = ARCO ~LASKA, INC. ELL = 3H-11 (COLVILLE) IELO = KUP 8, RUK OUNTY = NORTH SLOPE BOROUGH TATE : ALASKA 09 NUMBER AT AKCC: 72554 UN CZ, DATE LOGGE.~: 2,5-0EC-87 DP: J. KOHRINr.., ASING YPE FLUID ENSITY ISCDSITY H LUIO LOSS IELD REMARKS: = 10.75" @3633'CLDGGER) - BIT SIZE = 8.5" TO TTSO'CLOGGER) = WEIGHTED POLYMER = 10-1 LB/G RM '= 3.82 g 76 OF = 44.0 S RMF = 4.00 @ 76 DF = 9.5 RMC = 3.01 @ 76' OF = 4.8 C3 RM AT BHT = 2.072 ~146 DF 1/2" STANDOFF AND 2m HOLE FINDER USED ON OIL. MOEN=Z.65, MATRIX=SAN'De HOLE ORRRECTION:CALIPER, FLUID DENS:I.0. CHANGED SURFACE GROUND AND SHUT DOWN V~ 010.H02 VERIFICATION LISTING PAGE 3 ELD:RS TO GET GOOD SP FOR MAIN PASS. LOGS TIED INTO RUN~I OIL 18-0EC-87. 00L TYP':S/NUM~ERS: DIS 2140 OIC 2191 PGS 1025 CNC 1449 SGC 2259 I:_M 1290 NLM 1312 ~=',--,-~ THIS DAT~ HAS NOT BEEN DEPTH SHI:TEO - OVERLAYS FIELD PRINTS * SCHLUMSERGER LOGS ZNCLUDED WITH THIS FILE CEOIT.O01): * ~ DUAL INDUCTION SPHERICALLY FOCUSED LOG C.OIL) ~ ~ FIRST TD LAST READING: 4500' TO )633' , * FORMATION DENSITY LaG (.FgC) , * FIRST TO LAST RE~DING: 4500' TD 3633m , * CDHPENSATEO NEUTRON LOG (.CNL) , ~ FIRST TO LAST READING: 4500m TD 3633m , * BOREHQLE COMPENSATED SONIC LOG (.BHC) , * F~RST TO LAST READING: 7742m TO 3633' , VD OlO.H02 VERIFICATION LISTING DATA FORMAT NTRY 5LOCKS TYPE SIZE 2 1 4 1 8 4 9 4 16 1 0 I REPR CODE 66 66 73 65 66 66 ATUM SPECIFICATION ~LOCKS NEM SERVICE SERVICE UNIT API APZ APl ID ORDER # LOG TYPE CLASS EFT FT O0 000 O0 FLU OIL OHMM O0 220 01 LO OIL OHMM O0 120 46 LM OIL OHMM O0 120 44 P OIL MV O0 010 01 R OIL GA~I O0 310 O1 ENS Oil LB O0 635 21 T BHC US/F O0 520 80 R BHC GAPI O0 310 01 ENS BHC LB O0 635 R FDC GAPI O0 310 01 HOB FDC ,G/C3 O0 350 02 ~RHO FO( G/C3 O0 356 01 ,PHI FDC PU O0 890 O0 .ALI FO( IN O0 280 01 'ENS FO( LB O0 635 ;R CNL GAPI O0 310 O1 IPHI CNL PU O0 890 O0 'NRA CNL O0 ~20 01 ~TNR CNL O0 000 O0 ICFT CNL CPS O0 000 O0 )CNT CNL CPS O0 000 O0 ;FTC CNL CPS O0 000 O0 ~NTC CNL C'PS O0 000 O0 'ENS CNL LB O0 635 ENTRY 0 1 60 .lIN 1 0 )EPT 7763.5000 SFLU -999.2500 ;P -999.2500 GR -999.Z500 ;R 92.7500 TENS )RHO -99'9. 2500 DPHI -999.2500 ;R -999. 250'0 NPHI -999.2500 ~CFT -999.2500 RCNT -999.2500 FENS -999.2500 )EFT 7700.0000 SFLU -999.2500 ~P -999.2500 GR -999.2500 ;R 97.2:500 TENS 5108.0000 )RHO -999.2500 DPHI -9'99.2500 ;R -999.2500 NPHI -999.2500 ILO TENS GR CALl 'TNRA CFTC ILO TENS GR CALI TNRA apl FILE SIZE SPL MOO ND. 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 0 0 4 1 0 0 4 1 0 0 ¢ 1 0 0 4 1 0 0 4 1 0 ,0 ~ 1 0 0 4 1 O 0 4 1 0 0 ,~ 1 0 0 4 1 0 0 ~ 1 0 0 4 1 0 0 .¢ 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 0 0 4 1 0 0 ~ 1 0 0 4 1 0 0 ~ I -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 PASE 4 REPR PROCESS CODE (OCTAL) 68 00000000000000 68 0000000000000~ 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 .00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6.8 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000000000OO 68 0000000.0000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00'000000000000 ILM -999.2500 OT 105'.1875 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT 106.6875 RHD8 -999.2500 TENS -999.2500 RTNR -999.2500 VP EFT ENS EPT P R RI'tO R EFT ENS EFT P RHO R EFT ENS EFT P R RHO R CFT ENS EFT P ,R ~RHO iR ~CFT 'ENS ~EPT ;P ;R iRHO ;R :EFT 'ENS )EPT ;P ;R )RHO ;R [CFT tENS )EPT ;P OIO.HOZ VERIFICATION -999.2500 RCNT -999.2500 7600.0000 SFLU -999.2500 .~R 91.0000 TENS -999.2500 OPHI -999.2500 NPHI -999.2500 RCNT -999.2500 7500.0000 SFLU -999.2500 SR 95.5000 TENS -999.2500 DPHI -999.2500 NPHI -999.2500 RENT -999.2500 7400.0000 SFLU -99').2500 GR 67.8750 TENS -999.2500 DPH! -999.2500 NPHI -999.2500 RCNT -999.2500 7300.0000 SFLU -999.2500 GR 52.7500 TENS -999.2500 OPH! -999.2500 NPH! -999.2500 RENT -999.2500 7200.0000 SFLU -999.2500 GR 113.1250 TENS -999.2500 OPH! -999.2500 NPHI -999.2500 RCNT -999.2500 7100.0000 SFLU -999.2500 GR 118.0000 TENS -999.2500 OPHI -999.2500 NPH! -999.2500 RENT -999.2500 7000.0000 SFLU -999.2500 GR 259.0000 TENS LISTING -993.2500 CFTC -999.2500 ILO -999.2500 TENS 5108.0000 gR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.2500 ILO -999.2500 TENS 5180.0000 gR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.2500 ILD -999.2500 TENS 5072.0000 SR -993.2500 CAL! -999.2500 TNRA -999.2500 CFTC -999.2500 ILD -999.2500 TENS 4888.0000 GR -999.2500 CALi -999.2500 TNRA -999.2500 CFTC -999.2500 ILO -999°2500 TENS 4824.0000 GE -999.2500 CALI --999..2500 TNRA -999.2500 CFTC -999.2500 ILO -999.2500 TENS 4772.0000 GR -999.25'00 CALI. '-99'9.2500 TNRA -999°2500 CFTC -999.2500 ILD -999.2500 TENS 4880.0000 GR -999.2500 CNTC -999.Z500 ILM -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.Z1500 RTNR -999.2500 CNTC -999.2500 -999.2500 DT -999.2500 RHDB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999.2,500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999..2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM '-999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR '-999.2500 CNTC -999.2500 ILM -999.2500 OT -999.2500 RHO8 PAGE -999.2500 -999.2500 103.3750 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 102.3750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.9375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 75.7500 -999.2500 -999.2500 -999.2500 -999.2500 '-~99.2500 119.5000 -999..2500 -999.2500 -99'9.2500 -99'9.2500 -999.2500 112.6875 -9'99.2500 -999.2500 -999.2500 -999.2.500 -999.25'00 110.8750 -999.2500 VP OlO.H02 VERIFICATION LISTING RHO -999.2500 DPHI R -999.2500 NPHI EFT -999.2500 RCNT ENS -999.2500 -999.2500 CALI -999.2500 'TNRA -999.2500 CFTC EPT 6900.0000 SFLU P -999.2500 GR R 171.1250 TENS RHO -ggg.z500 OPH~ R -999.2500 NPHI CFT -ggg.2500 RCNT ENS -999.2500 -999.2500 ILO -999.2500 TENS 4624.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC EPT 6800.0000 SFLU P -999.2500 GR R 131.1250 TENS RHO -ggg.2SO0 DPHI R -999.2500 NPHI CFT -999.2500 RCNT 5NS -999.2500 -999.2500 ILO -999.2500 TENS 4552.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC EPT 6700.0000 SFLU P -999.2500 SR R 106.5625 TENS RHO -999.2500 OPHI R -999.2500 NPHI CFT -99'9.2500 ~CNT ENS -999.2500 -999.2500 ILO -999.2500 TENS 4432.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC EPT 6600.0000 SFLU P -999.250.0 GR R 113.0000 TENS RHO -999.2S00 OPM! ,R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 '-999.Z500 ,ILO -999.2500 TENS 4384.000.0 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC ~EPT 6500.0000 SFLU .P -999.2500 GR ,R 120.5625 TENS ~RHO -999..2500 DPH! ;R -999.250.0 NPHI :CFT -999.2500 RCN'T 'ENS -999.2500 -999,2500 -999.2500 TENS 4308.0000 -999.2500 CALI -99'9.25'00 TNRA -999.2500' CFTC ~EPT 6¢00.0000 SFLU ;P -99'9.2500 GR ;R 106.0625 TENS ~RHO -999.2500 DPHI ;R -999.2500 NPHI ICFT ,-999.2500 RCNT 'ENS -999.2500 -999..2500 ILO · -999.2500 TENS a.232.0000 GR -999.2500 CAL! -999.2500 TN~A -999.2500 CFTC -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 OT -999.2500 RHOB -999. Z500 TENS -999.2500 RTNR -999.1500 CN'TC -999.2500 ILM -999.2500 DT -999.2500 RHOB -999.2500 TENS -'999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999. 2500 CNTC -999.2500 ILM -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC PAGE -999.2500 -999.2500 -999.2500 -999.2500 114.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100.3750 -999..2500 -999.2500 -999.2500 -993.2500 -999.2500 104.3125 -999.2500 -999.2500 -999.2500 -999.2500 ~EPT 630'0.0000 SFLU -999.2500 ILO -999.2500 ILM -999.,2500 VP 010.H~2 VERIFICATIDN LISTING PAGE 7 P -999.2500 GR R 75.8125 TENS RHO -999.2500 DPHI R -999.2500 NPH! CFT -999.2500 RCNT ENS -999.2500 EPT 6200.0000 SFLU P -999.2500 GR R 89.3125 TENS RHO -999.2500 DPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 6100.0000 SFLU P -999.2500 GR R 99.1250 TENS RHD -999.2500 DPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 6000.0000 SFLU P -999.2500 .~R R 97.5000 TENS RHO -999.2500 DPHI R -999.25,00 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 5900.0000 SFLU P -999.2500 GR ,R 92.1250 TENS ,RHO -999.2500 DPHI ,R -99'9.2500 NPHI :£FT -99.9.2500 RCNT 'ENS --999.2500 ~EPT 5800.0000 SFLU ,P -999.2500 GR ;R '98.3750 'TENS ~RHO -999.2500 DPHI ~R -999.2500 NPHI IC'FT -999.2500 RCNT 'ENS -999.2500 tEPT 5700.0000 SFLU ;P -999.2500 GR ;R [07.B125 TENS )RHO -999. 2500 .DPHI ;R -999.2500 NPHI ~CFT -999.2500 ~CNT 'ENS -999.2500 -999.2500 4120.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 4100.0000 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 405¢.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3964.0000 -999.2500 -999.2500 -999,.2500 -999.2500 -999.2500 3920.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3854.0000 -999.2500 -999.2500 -999.2500 -999.2S00 -999.2500 393~.0000 -999.2500 -999.2500 -999.2500 TENS GR CALI TNRA CFTC ILO TENS GR CALI TNRA CFTC ILO TENS GR CALI C FTC ILO TENS GR CALI TNRA CFTC ILO TENS GR CALI TNRA CFTC ILO TENS GR CALI TNRA CFTC ILD TENS GR CAL! TNRA CFTC -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99. 2500 -999.2500 -'999.25,00 -999.2500 -999.2500 -999.2500 -999.2.500 -999.2500 -999.2500 OT RHOB TENS qTNR CNTC ILM OT RHOB TENS RTNR CNTC ILM DT RHOB TENS RTNR CNTC IL4 DT RHOB TENS RTNR CN'TC DT RHOB TENS RTNR CNTC ILM DT RHOB TENS RTNR CNTC DT RHOB TENS RTNR CNTC 96.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 103.4375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.1250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2'500 106.t250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 105.6250 -999.2500'-999.2500-999.2500-99'9.2500 -999.2500 :[12.8750 -999.2500 -999.2500 -999.2500 -999.,2500 VP O!O.H02 VERIFICATION EPT 5600.0000 SFLU P -999.2500 GR R 103.87.50 TENS RHO -999.2500 DPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 5500.0000 SFLU P -999.2500 GR R 116.0000 TENS RHO -999.2500 DPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 5400.0000 SFLU P -999.2500 GR R 140.2500 TENS RHO -999.2500 OPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS '-999.2500 EPT 5300.0000 SFLU P -999.2500 GR R 153.2500 TENS RHO -999.2500 OPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 5200.0000 SFLU P -999..2500 GR R 105.1875 TENS 'RHO -999.25'00 DPH! ,R -999.2500 NPH! CFT -999.2500 RCNT 'ENS -999.2500 'EPT 5100.0000 SFLU P -999.2500 GR ,R 101.9375 TENS 'RHO -999.2500 DPHI ,R -999.250.0 NPHI CFT -999.2500 RCNT 'ENS -999.2500 'EPT 5000.0000 SFLU ,P -999.2500 GR ;R 72.6250 TENS ~RHO -999.2500 DPHI ;R -999.2500 NPH! LISTING -999.2500 -999.2500 3794.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3780.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3614.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3594.0000 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 35.34.0000 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 3390.0000 -999.2500 -999.2500 '-999.2500 -9'99.2500 -999.2500 3570.0000 -999.2500 -999.2500 ILO TENS CALl TNRA CFTC ILO TENS GR CALI TNRA CFTC TENS GR CALI TNR,A CFTC ILD TENS 'TNRA CFTC ILO TENS GR CALI TNRA CFTC ILO 'TENS GR CALI TNRA, CFTC ILO TENS GR CALI TNRA -999.2500 -999.2500 DT -'999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 DT -999.2500 RHDB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ~LN -99'9.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CN'TC -999.2500 -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR PAGE -999.2500 107.0625 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 121.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 114.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.5625 -999.2500 -999. 2500 -999.2500 '-999.2500 -999.2500 115.2500 -999.2500 -999.2500 -999.25'00 -999.2500 -999.2500 11'3.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '99.8750 -999.2500 -999.2500 -999.2500 VP 010.H92 VERIFICATION LISTING CFT -999.2500 RCNT ENS -999.2500 EPT 4900.0000 SFLU P -999.2500 GR R 109.6250 TENS RNO -999.2500 DPHI R -999.Z500 NPH! CFT -999.2500 RCNT ENS -999.2500 EPT 4800.0000 SFLU P -999.2500 GR R 97.5000 TENS RHD -999.2500 DPH! R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 4700.0000 SFLU P -999.2500 GR R 107.2500 TENS RHO -999.2500 OPHI R -999.2500 NPHI CFT -999.2500 RCNT ENS -999.2500 EPT 4600.0000 SFLU P -999.2500 GR R 107.0625 TENS RHO -999.2500 OPHI ',R '-999.2500 NPHI 'CFT -999.2500 RCNT 'ENS -99'9.2500 'EPT 4500.0000 SFLU 'P -999.2500 GR ;R 100.625.0 TENS 'RHO -99'9.2500 DPHI ,R -999.,2500 NPHI !.CFT -99'9.2500 RCNT 'ENS -999.2500 ~EPT 4400.0000 SFLU ;P -34.0000 GR ;R 95.3125 TENS ~RHO 0.0117 OPHI' ;R 110.8750 NPHI' ICFT 50,2.3649 RCNT 'ENS 3700.0000 IEPT 4300.0000 SFLU ,P -4~.5000 SR ;R 118. 9375 'TENS -999. 2500 CP'TC -999.2500 ILD -999.2500 TENS 3280.0000 SR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.2500 ILO -999.2500 TENS 3300.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.2500 ILO -999.2500 TENS 3290.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.12500 ILO -999.2500 TENS 3094.0000 GR -999.2500 CALI -999.2500 TNRA -999.2500 CFTC -999.2500 ILO -999.2500 TENS 3090.0000' GR -99'9.2500 CALI -999.2500 'TNRA -999.2500 CFTC 3.6679 ILO 110.8750 TENS 2964.0000 GR 25.9766 CALI 41.7324 TNRA 1810.8401 CFTC' 20.8675 IL~ 128.1250 TENS 2814.0000 GR -999.2500 CNTC -999.2.500 IL4 -999.2500 OT -999.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 OT -999.2500 RHO8 -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 -999.2500 DT -999.2500 RHOB -999.2500 TENS -999.2500 ~TNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -9'99.2500 RHOB -999.2500 TENS -999.2500 RTNR -999.2500 CNTC -999.2500 ILM -999.2500 DT -999,25'00 RHOB -999.2500 TENS -9'99.2500 RTNR -999.2500 CN'TC 4.0978 ILM 3700.0000 .DT 110.8750 RHOB 9.0391 TENS 3.4633 RTNR 509.4409 CNTC 19.2332 ILM 3510.0000 OT 128.1250 RHOB PAGE -999.2500 -999.2500 112.1875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 110.1250 -999.2500 -999.2500 -999.2500 -9gg.zso0 -999.2500 106.1250 -999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 104.5625 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 106.8125 -999.2500 -999.2500 -999.2500 -999.2500 3.9244 106.1.875 2.2207 3700.0000 3.6034 1785.8232 16.8504 94.93'75 2.29BB ~P 010.M92 VERI~ICRTION LISTING PAGE 10 ~HO 0.0571 9PHI R 128.1250 NPHI gFT 693.8467 RCNT ENS 3510.0000 EPT 4200.0000 SFLU P -3 6. Z500 GR R 82.2500 TENS RHO 0.0596 DPHI R 89.7500 NPHI CFT 495.3349 RCNT ENS 348.6.0000 EPT 4100.0000 SFLU P -40.5938 GR R 84.5000 TENS RHO 0.0322 gPH! R 80.6250 NPMI CFT 646.9391 RCNT ENS 3354.0000 EPT 4000.0000 SFLU P -68.6875 GR R 53.6875 TENS RHO 0.0073 DPHI R 61.0313 NPHI CFT 795'.2754 R.CNT ENS 33'30.0000 EPT 3900.0000 SFLU P -39.7500 GR R 96.1875 'TENS RHO 0.0137 OPHI R 108.6875 NPHI CFT 433.7109 RCNT ENS 3154.0000 EPT 3800.0000 SFLU P -3'7. 3438 GR R 87.6250 TENS 'RHO 0.0151 DPHI R 91.6250 NPHI CFT 40,4. 6274 RCNT ENS 3214.0000 'EPT 3700.0000 SFLU P -41.4688 GR R 94.3125 TENS 'RHO 0.0469 OPHI ,R 93.6875 NPH! CFT 410.3296 RCNT 'ENS 3184..0000 21.2402 CALI 30.1961 TNRA 2027.4089 CFTC 4.1887 ILD 89.7500 TENS 2814.0000 GR 25.6348 CALI 39.8371 TNRA 1783.3098 CFTC 6.6227 ILO 80.6250 TENS 2~60.0000 GR 25.8789 CALI 36.9289 TNRA 2064.8203 CFTC 95.'7834 ILO 61.0313 TENS 2714.0000 GR 21.4844 CALI 29.1819 TNRA 2263.4287 CFTC 3.6360 ILO 108.6875 TENS 2544.0000 GR 24.1211 CALI 41.7704 TNRA 1649.8801 CFTC 3.5332 ILO 91.16250 TENS 2494.0000 GR 26.5625 CALI 43.5790 TNRA 1648.0894 CFTC 4.2310 ILO 93.6875 TENS 2430.0000 GR 25.3906 CALI 43.864.2 TNRA, 1547.6619 CFTC 9.7031 2.8506 731.8710 4.5382 3484.0000 89.7500 10.2891 3.4626 545.4192 6.6583 3354.0000 80.6250 9.4609 3.2357 672.1031 122.3068 3330.0000 61.0313 11.6016 2.8885 851.5'714 4.4¢50 3154.0000 .108. 6875 13.0313 '3.66,25 468.2013 4.0773 3214.0000 91.6250 12.4453 3.7459 458.0498 4.9108 3184.0000 93.6875 12.6875 3.7680 443.8042 TENS RTNR CNTC OT RHOB TENS RTNR CNTC ILM DT RHOB TENS RTNR CNTC ILM OT RHOB TENS RTNR CNTC OT RHOB TENS RTNR CNTC ILM DT RHOB 'TENS RTNR CNTC OT RHOB TENS RTNR CN'TC 3510.0000 2.7625 2022.6245 4.2057 107.7500 2.2256 3484.0000 3.6290 1884.2522 6.4438 99.1875 2.2227 3354.0000 3.6501 2056.2329 90.6723 105.1250 2.2949 3330.0000 3.0240 2381.6279 4.1534 122.2500 2.2520 315'4.0000 3.'7'7'78 1720.4639 3.8383 121.1250 2.2109 3214.0000 3.7925 1691.¢624 4.6153 119.6250 2.2305 318,4.00'00 4.1277 162~.6023 IEPT 3600.0000 SFLU 2000.0.000 ILD 48.5109 I'LM ZO00.O000 VP OlO.H02 VERIFICATION LISTING P -2.1357 GR R 47.2813 TENS RHO -0.42~2 DPHI R 54.2187 NPHI CFT 278.3944 RCNT EMS 2364.g000 54.2187 TENS 2384.0000 GR 37. I094 CALI 61.9383 TNRA 1276.7788 CFTC EPT 3500.D000 SFLU P -28.7031 GR R -999.2500 TENS RHO -0.4868 9PHI R 51.0313 NPHI CFT 269.9603 ~CNT ENS 2940.0000 2000.0000 ILD 51.0313 TENS -999...~500 GR 48.7305 CALI 54.3146 TNRA 1216.2976 CFTC EPT 3496.0000 SFLU P -25.9375 GR R -999.2500 TENS RHO -0.4609 DPHI R 48.8125 NPHI CFT 252.5189 ~CNT ENS 2910.0000 2000.0000 ILO 48.8125 TENS -999.2500 GR 44.9219 CALI 59.1242 TNRA 1174.4309 CFTC * FILE TRAILER ILE NAME :EDIT .001 ERVICE NAME : ERSION ~ ATE : AXIMUM LENGTH : 102.~ ILE TYPE : EXT FILE NAME : :* TAPE TRAILER ERVICE NAME :EDIT ATE :88/0[/ 9 RIGIN APE NAME ONTINUATION # EXT TAPE NAME : OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3H-11, :* REEL TRAILER ** ERVICE NAME :EDIT ATE :88/01/ 9 i, RIG iN :' EEL NAME :'72554 ONTINUATION # :01 IEKT REEL NAME : ;OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3H-11, 2964.0000 DT 5~.2187 RHOE 9.9766 TENS 4.6438 RTNR 290.0663 CNTC 13.6616 ILM 2940.0000 DT 51.0313 RHOB 9.8906 TENS 4.2211 RTNR 286.1739 CNTC 14.1484 ILM 2910.0000 DT 48.8125 RHOB 9.8828 TENS 4.4826 RTNR 294.1812 CNTC API 50-029-21771 API 50-029-21771 PAGE 57.7500 2.0371 2964.0000 5.1278 1287.3840 2000.0000 -999.2500 1.8457 2940.0000 ~.3030 1216.6897 2000.0000 -999.2500 1.9082 2910.0000 4.1819 1236.0059 11 VP 010..H02 VERIFICATION LISTING PAGE 12
