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196-201
• • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged •- Abandoned IF Suspended ❑ 1b. Well Class: tt�� 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ 0 WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: October 25, 2012 196 - 201 / 312 - 385 • 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 20, 1997 50 029 - 22728 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 68' FNL, 1749' FEL, Sec. 33, T11 N, RO9E, UM • May 20, 1997 2F - 19 . Top of Productive Horizon: 8. KB (ft above MSL): 97' RKB 15. Field /Pool(s): 1681' FNL, 2442' FWL, Sec. 3, T1 ON, RO9E, UM GL (ft above MSL): 32' AMSL Kuparuk River Field • Total Depth: 9. Plug Back Depth (MD + TVD): 1764' FNL, 2592' FWL, Sec. 3, T1 ON, RO9E, UM 10811' MD / 6030' TVD Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: t A; Surface: x 517483 y 5948815 Zone 4 ' 11152' MD / 6394' TVD ADL 25666 7 yll }' TPI: x - 521705 y - 5941933 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 521856 y - 5941851 Zone 4 nipple @ 513' MD / 513' TVD 2587 18. Directional Survey: Yes ❑ No gi 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) 1650' MD / 1602' 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 none 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# I-1-40 42' 121' 42' 121' 24" 260 sx AS I 7.625" 29.7# L -80 41' 4711' 41' 3222' 9.875" 261 sx ASLW, 1220 sx Class G, 60 sx AS I 5.5" 15.5# L -80 39' 10635' 39' 5877' 6.75" 100 sx Class G 3.5" 9.2# L -80 10019' 11150' 5430' 6394' 4.75" 132 sx Class G 24. Open to production or injection? Yes ❑ No El 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" 10019' 10019' MD / 5430' TVD all perfs squeezed 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No II DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED AP 2 RECEIVED ANNE JAN 18 2013 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) OGG� plugged e� Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE 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 El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS JAN 2 81013 Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE / Submit o�al only ski 9I1'��).J1 ///. /57. L-(6 G +29. GEOLOGIC MARKERS (List all formations and ars encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 1650' 1602' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 263 - 4093 Email: James .J.Ohlinaereconocophillips.com o p , Printed Name Lamar Gantt Title: CTD Supervisor Signature V \t� l l V _ 4COULL t Phone 263 - 4021 Date / i$/13 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 2F -19 Pre -Rig Well Work Summary DATE SUMMARY 9/23/12 (PRE -CTD): SCLD (IN PROGRESS) CURRENT OA FL @ 426' 9/24/12 RECOVERED LOST JD & PULLED GLV @ 7600' RKB. IN PROGRESS. 9/25/12 SET DV @ 7600' RKB. PT TBG & IA TRACKING. PULLED DV & SET NEW @ SAME. IA STILL TRACKING. IN PROGRESS. 9/26/12 RAN HOLE FINDER, PREMATURELY SET, AND OBTAIN GOOD TEST TBG. @ 8661' SLM ( STA # 2 GLM @ 7600' RKB ). REPLACED DV @ 9943' RKB W/ TBG X IA STILL TRACKING. RAN HOLE FINDER AND SET ONTOP OF THE CATCHER @ 9995' RKB WITH FAILED TEST. LEAK DETECT UP WITH THE LAST FAILING TEST @ 9450' SLM AND PASSING TEST @ 9240' SLM ( ABOVE GLM # 3 @ 9943 ). UNABLE TO ESTABLISH LLR. READY FOR E -LINE. 10/2/12 (PRE -CTD): SCLD (IN PROGRESS) OA FL © 912'.. 10/6/12 SCLD- PASSED; OA FL © 1074FT. 10/16/12 PULLED GLV @ 3334' RKB. SET DV @ SAME. PULLED CATCHER @ 9992' RKB. PULLED CA -2 PLUG @ 9996' RKB. DRIFT FOR CIBP WITH 2.73 ", 3' OF WB & 2.72" TO 10,813' SLM. READY FOR E -LINE. 10/17/12 MITIA (FAILED) TO 3000 PSI, LLR IA @ 11 GPM. 10/20/12 PERFORMED LEAK DETECT. IDENTIFIED TxIA LEAK IN TUBING COLLAR AT 9361' CORRELATED TO TUBING TALLY. LOCATED LEAK PUMPING 0.2 BPM DOWN IA THROUGH LEAK TO FORMATION. SET TOP OF HALLIBURTON BRIDGE PLUG AT 10811'. CCL TO TOP OF PLUG OFFSET 8.4', CCL STOP DEPTH 10802.6'. 10/21/12 SET TOP OF WHIPSTOCK AT 10790' ORIENTED AT +9.1 DEG ROHS. CCL TO TOWS OFFSET 19.1', CCL STOP DEPTH 10770.9'. RA PIP TAG SET AT 10797'. 10/22/12 Performed injectivity test to 1500 psi; after .61 bbls pressured up and held tight. Attempted to bleed off tubing for no -flow test, unable to bleed below 500 psi. See attached pump report 10/25/12 SET 2.75" CA -2 PLUG @ 9996' RKB. SET AVA STYLE CATCHER ON TOP OF PLUG @ 9995' RKB. BLEED DOWN TBG & IA. IA WENT ON A VAC & TBG DOWN TO A WHISPER. TURN OVER TO DHD. IN PROGRESS. 10/25/12 (PRE -CTD) BLED T & IA TO OPSI. FOR BPV. • • ConocoPhitlips Time Log & Summary WeOview Web Reporting Report Well Name: 2F -19 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 10/28/2012 10:00:00 AM Rig Release: 11/20/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/28/2012 24 hr Summary MI RU on 2F -19. Reel swap, BOPE test 250 low / 4700 psi High. 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Move from 2F -11 to 2F -19. Spot modules. 06:00 10:00 4.00 0 0 MIRU MOVE RURD P PJSM - rig up hard lines, steam lines and set down cribbing around the rig. 10:00 12:30 2.50 0 0 MIRU WELLPF CTOP P * ** Rig Accept ** PJSM for unstabing Coil. Set up rig floor and unstab CT from injector. 12:30 14:30 2.00 0 0 MIRU WELLPFCTOP P Secure reel, peak on location. Remove iron from inside of reel. 14:30 16:00 1.50 0 0 MIRU WELLPF CTOP P PJSM with Peak drivers. Start offloading reel from rig. Reel loaded out. 16:00 18:00 2.00 0 0 MIRU WELLPF CTOP P Swap reel spacer hubs on new work string. 18:00 19:30 1.50 0 0 MIRU WHDBO NUND P PJSM Complete nipple up. Hammer up tree. Complete post rig move checklist 19:30 23:00 3.50 0 0 MIRU WELLPF CTOP P Reconfigure test joint and safety joint, Grease rig valves in prep for BOPE Test, Complete cellar rig up. Get Koomy online. Fluid pack rig 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P Start full BOPE Test, Witness waived by Lou Grimaldi, AOGCC 10/29/2012 Complete BOPE Test, R/U S/L to Pull plug 00:00 09:00 9.00 0 0 MIRU WHDBO BOPE P Continue BOPE Test, Witness waived by Lou Grimaldi, AOGCC. C -16 failed test. Replace valve and re -test. Pass. Tested alarms. 09:00 11:30 2.50 0 0 MIRU WHDBO SEQP P Valve checklist, R/U & Pressure test PDL / Tiger tank lines. 2500 psi. Little bit of ice slush in TT line. Pump 25 bbls to TT to warm up the line. 11:30 12:30 1.00 0 0 MIRU WHDBO MPSP P PJSM - pull BPV. IA = 0 / OA 630 psi. 12:30 16:30 4.00 0 0 SLOT WELLPF SLKL P PJSM - start bringing in SL equipment & set up rig floor. Rig up SL. Pressure test to 2500 psi. 16:30 18:30 2.00 0 9,980 SLOT WELLPF SLKL P Open swab valves - RIH for catcher sub. POOH. Lay down catcher at surface. 18:30 19:00 0.50 0 9,995 SLOT WELLPF SLKL P RIH - stop 50' above CA plug. Pressure up Wellhead to 1500 psi - started to leak off - IA pressure tracking tubing pressure. equalized at 1400 psi. Bump up to 1700 psi. Did not get the plug. Page 1 of 20 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 19:30 0.50 9,995 0 SLOT WELLPF SLKL P Bleed down pressure POOH. Install split skirt tool. 19:30 00:00 4.50 0 9,995 SLOT WELLPF SLKL P RIH - Stop prior to plug. Pressure up to 1700psi. Good indication of latch - pressure bled down 200 psi. POOH. Equalize sub at surface. RIH for plug body. First run failed , P/U spangs. RIH sheared off pins. POOH Set heavier pins - RIH. 10/30/2012 Preform SL Mgmt, Head up BHI 00:00 01:00 1.00 9,995 0 SLOT WELLPF SLKL P Slickline on surface with plug 01:00 02:45 1.75 0 0 SLOT WELLPF PULD P PJSM, R/D and load out slickline equipment 02:45 04:45 2.00 0 0 SLOT WELLPF CTOP P PJSM, R/U grapple to end of coil, pull test grapple, pull coil into injector 04:45 06:00 1.25 0 0 SLOT WELLPF CTOP P Seal end of wire, Stab on and fill coil 06:00 07:00 1.00 0 0 SLOT WELLPF PRTS P Pressure test inner reel iron, pressure bulkhead, and stuffing box. Pressure bulkhead seeping after 3 minutes on HP test. Bleed down and tighten packoff element, Get good test. 07:00 09:00 2.00 0 0 SLOT WELLPF CTOP P Perform Slack Mgmt, Cut 25' to find wire cut a total of 30', test wire good test 09:00 13:00 4.00 0 0 SLOT WELLPF CTOP P Dress coil and install CTC, Pull test to 40K, Head up E -Line to UQC test wire and UQC, All good, PT connector to 4K 13:00 14:00 1.00 0 0 SLOT WELLPF SFTY P Perform Pre Spud with day crew (Corder) 14:00 15:00 1.00 0 0 SLOT WELLPF SFTY P Flow check well, 500 PSI WHP, IA =470. Bleed off to TT and monitor, PJSM 15:00 16:36 1.60 0 73 PROD1 WELLPF PULD P P/U BHA #1, 2.74 Dimond window mill, new 2.74 string reamer, .6° motor, 10' pup, M/U to coil and surface test tools, Strip on and set counters. Inspect packoffs 16:36 19:45 3.15 73 10,660 PROD1 WHPST TRIP P Trip in hole with BHA #1 19:45 20:00 0.25 10,660 10,680 PROD1 WHPST DLOG P 10660ft start tie in correction of - 8ft 20:00 20:30 0.50 10,680 10,645 PROD1 WHPST SFTY P Pre -Spud with crew while swapping fluid over in tubing to power -vis. Moving coil up hole. CO 20:30 20:45 0.25 10,645 10,685 PROD1 WHPST MILL P Bring returns back in side.Trip in hole to 10685ft. Close EDC 20:45 21:00 0.25 10,685 10,790 PROD1 WHPST MILL P Dry Tag TOWS at 10790.3ft. RIW 16k, PUW 37k 21:00 00:00 3.00 10,790 10,792 PROD1 WHPST MILL P 10789.7ft Start Milling window - 1.48bpm at 3400 psi FS. 10/31/2012 Finish milling 2.741D window, Ream window area, POOH and MU Build BHA w' 00:00 03:45 3.75 10,792 10,796 PROD1 WHPST MILL P 10792.2ft Milling Window - 1.42bpm at 3400psi FS. Page 2 of 20 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:51 2.10 10,796 10,800 PROD1 WHPST MILL P 10795.8ft release brake, mill formation ahead at 2fph 05:51 08:03 2.20 10,800 10,811 PROD1 WHPST MILL P Drill Ahead in rathole, 1.45 BPM @ 3450 PSI FS, BHP =3950 08:03 09:21 1.30 10,811 10,811 PROD1 WHPST REAM P Ream window per procedure, PUW =34K, BHP =3955 09:21 12:27 3.10 10,811 55 PROD1 WHPST TRIP P Trip out, PUW =34K, 12:27 14:03 1.60 55 0 PROD1 WHPST PULD P At surface. PJSM, Lay down BHA #1 14:03 15:33 1.50 0 0 PROD1 DRILL SVRG P Service injector, reel, tighten reel hub bolts, and top drive link tilt, reconfig motor 15:33 17:03 1.50 0 62 PROD1 DRILL PULD P PJSM. P/U BHA #2 with 2.4° motor and RR Hughes Bi Center, Make up coil and strip on well, surface test tool, tag up and set counters 17:03 17:15 0.20 62 10,660 PROD1 DRILL TRIP P RIH- Open EDC pumping .30 bpm 17:15 20:15 3.00 10,660 10,683 PROD1 DRILL DLOG P 10660ft - Tie into K1 correction of -17ft. Close EDC 20:15 20:30 0.25 10,683 10,812 PROD1 DRILL TRIP P RIH - ECD closed 20:30 23:00 2.50 10,812 10,938 PROD1 DRILL DRLG P 10812ft Tag bottom - Drill Ahead in Build section as per Geo and DD. 1.41bpm at 3460psi. BHP 3965. WHP 129. IA - 1438, OA - 420 23:00 23:30 0.50 10,938 10,775 PROD1 DRILL TRIP P 10938ft POOH - TD build section. PUW 33k. BHP 4032. WHP 105. IA • 1437, OA 426. 23:30 00:00 0.50 10,775 7,960 PROD1 DRILL TRIP P 10775ft Open EDC. Circulate 1.43 bpm while POOH. 11/01/2012 TD build section / Drill lateral section 00:00 02:00 2.00 7,960 0 PROD1 DRILL TRIP P Continue to trip out of hole. EDC open. pumping 1.43 bpm using the MP tripping schedule. 02:00 02:15 0.25 0 0 PROD1 DRILL SFTY P PJSM - OOH space out 1.9ft 02:15 04:45 2.50 0 0 PROD1 DRILL PULD P Tools OOH - MU BHA #3 .45° AKO w/ HYC bit 2.7x3 (SS# A145576) and install into PDL 04:45 06:30 1.75 0 72 PROD1 DRILL PULD P PJSM - Deploy lateral BHA #3 with .45° Motor and Hycalog rebuild bi center, Make up to coil and surface test 06:30 08:54 2.40 72 10,650 PROD1 DRILL TRIP P Trip in hole EDC open 08:54 09:18 0.40 10,650 10,715 PROD1 DRILL DLOG P Log Tie in for -18' correction, Shut EDC, PUW =34K 09:18 09:42 0.40 10,715 10,938 PROD1 DRILL TRIP P RIH to log RA Marker, RA @ 10795.5, TOWS =10789 clean pass through window, Continue in to drill. 09:42 13:12 3.50 10,938 11,080 PROD1 DRILL DRLG P 10837', Drill Ahead, 1.4 BPM @ 3480 PSI FS, BHP =3980 13:12 14:00 0.80 11,080 11,080 PROD1 DRILL WPRT P Wiper trip to window with MADD Pass 14:00 15:54 1.90 11,080 11,230 PROD1 DRILL DRLG P 11080', Drill Ahead, 1.4 BPM @ 3450 PSI FS, BHP =3950, Wide Open Choke Page 3 of 20 KUP 2F -19 ~ r ConocoPhillips Well Attributes Max Angle & MD TD Alaska it i. Wellbore API /UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) 500292272800 KUPARUKRIVERUNIT SVC 73.70 5,160.01 11,152.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Re Release Date "' SSSV: NIPPLE 55 10/17/2006 Last WO: 5/25/1997 Well Confic.. -2F -19, 11/8/201211'.13'.02 AM Schematic - Actual Annotation IDepth(ftKB) 'End Date 'Annotation Last Mod... End Date Last Tag: SLM 10,813.0 8/23/2012 Rev Reason: GLV C /0, Set Whipstock & Plug ninam 11/8/2012 HANGER, 27 ca,o Casing Strings Casing Description String 0... String ID _. Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth cm)... String Wt... String ... String Top Thrd WINDOW 8 4.950 10,260.0 10,270.0 5,596.0 15.50 L - 80 LTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6 41 4 3,222.1 29 L -80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 38.9 10,270.0 5,596.0 15.50 L LTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,019.3 11,149.8 6,335.8 9.30 L -80 ABM -BTC i III Liner Details Top Depth g CONDUCTOR, [ - (ND) Top Inc! Nom'... 42 -121 Top (ftKB) (ftKB) (°) Item Description Comment ID On) I 10 019.3 5,429.7 50.56 PACKER BAKER SABL -3 PACKE /LINER HANGER 2.780 1.1 : Tubing Strings NIPPLE, 513 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING 31/2 2.992 27.2 10,019.3 5,429.7 9.30 L -80 ABM -BTC Completion Details Top Depth • (TVD) Top Incl Nomi... Top (ftKB) (MB) (°) Item Description Comment ID tin) 27.2 27.2 -0.04 HANGER FMC GEN IV TUBING HANGER 3.500 513.3 513.3 1.22 NIPPLE CAMCO DS NIPPLE 2.812 • II GAS LIFT. 9,995.9 5,414.9 51.60 NIPPLE CAMCO D NIPPLE 2.750 3,335 - 10,003.5 5,419.7 51.26 LOCATOR BAKER LOCATOR 3.000 Ir..; 10,004.7 5,420.4 51.21 PBR BAKER PBR 3.000 10,018.7 5,429.2 50.59 ANCHOR BAKER KBH -22 ANCHOR SEAL NIPPLE 3.000 p it 1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth ii (TVD) Top Intl Top (ftKB) (ftKB) (1 Description Comment R un Date ID (in) 10,260 5,589.2 47.49 WHIPSTOCK WHIPSTOCK SET IN SIDETRACK AFTER PB1 8 PB2 1/2 7/1997 1 COLLAPSED; 3.5" LINER RUN 1 SURFACE, . L. 10,790 6,011.3 29.71 WHIPSTOCK BOT WHIPSTOCK 10/21/2012 0.000 41 - 4,711 0=7.2 10,811 6,029.7 28.32 PLUG HALLIBURTON BRIDGE PLUG 10/20/2012 0.000 PATCH 75/8" Surface casing has external corrosion w/ 50% wall 5/15/2011 GAS LIFT loss in the top 18" of the well. MAWOP 200 PSI . 7.601 D.N.E.1800 PSI. Perforations & Slots Shot Top (ND) Btm (TVD) Dens ( Top (9K8) Btm (MB) (ftKB) (ftKB) Zone Date (eb••• Type Comment GAS LIFT, e.943 1 1 . PI! 10,760 10,770 5,985.8 5,994.2C -4, 2F -19 7/25/1997 6.0 APERF 2.5" HSD BH; 180 deg. Ph 10,816 10,836 6,034.1 6,051.9 A -5, 2F -19 7/25/1997 6.0 APERF 2.5" HSD BH; 180 deg. Ph 10,854 10,874 6,067.8 6,085.6 A-4, 2F -19 6/6/1997 4.0 IPERF 2.5" HSD BH; 180 deg. Ph NIPPLE, s,996 ) ` Notes: General & Safety End Date Annotation 5/2/1997 NOTE: Original production wellbore abandoned during original drill, well sidetracked @ 10260' LOCATOR 0,004 L 10/14/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PBR. 10,005 9/6/2012 NOTE: Installed 6' sleeve from bottom of starter head made w/ 10" x 65.500 pipe. ANCHOR, 10/20/2012 NOTE: LEAK DETECT FOUND LEAK IN TUBING COLLAR @ 9361' 10,019 iiii - WHIPSTOCK. 10,260"- WINDOW, 10,260- 10,270 PRODUCTION, 39- 10,270 APERF, 10,760 - 10,770 WHIPSTOCK, 10.790 PLUG, 10.811 ' Ma ndrel Det T o D p ept Top Port ( rv 0) Incl OD Valve Latch Size TRO Run APERF, Stn Top (fti ( 1 °) Make Model (in) Sery Type Type (n) (psi) Run Date Com... 10,816 - 10,836 1 3 2,637.763.18 BST AXT 1GASLIFT DMY Ti 0.000 0.010/16/2012 8:00 2 7 ,600 .7 4 , 3 7 4 .1 66.37 BST AXT 1 GAS LIFT DMY Tt 0.000 0.0 9/25/2012 9:00 IPERF, 3 9,943.3 5,383.1 52.82 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 9/26/2012 4:00 10,854 - 10,874 LINER, 10.019- 11,150 TD (2F -19), A • 11,152 2F -19 Final CTD Sidetrack Revised: 9- Jan -13 3 -1/2" Camco DS nipple @ 513' RKB 3 -1/2" 9.3# L -80 EUE 8rd Tubing to 16" 62# H -40 shoe @ 121' MD 3 -1/2" Camco Mae @ ', and 7600' 2 -3/8" Weatherford ER gas Patch Min. ndr ID ls = 1.75 Top element at 9350', Bottom element 9372' 3-1/2" Tubing 7 -5/8" 29.7# L -80 __ ' leak at 9361' MD 3 -1/2" Camco MMG gas lift mandrels @ 9943' RKB shoe @ 4711' II1■-- 3 -1/2" Camco D nipple @ 9996' RKB,..75" min ID • „on RKB 1` .” Baker 3 -1/2" locator /seal assembly @ 10,003' RKB (3" ID) Baker PBR @ 10,004' RKB (4" ID seal bore) Baker KBH -22 anchor -seal nipple @ 10,018' RKB (3" ID) d Liner top 5 -1/2" 15.5# L -80, Baker SABL -3 liner top packer @ 10,019' RKB (2.78" ID) window at 10,260' RKB (original shoe at 10,635') Marker joint (15') @ 10,699' RKB (10,693' PDC) . Top of Liner Marker joint (15') @ 10,714' RKB (10,709' PDC) • at 10,777' MD i Top of Whipstock C -sand perfs at 10,790' MD AL2 lateral, A5 sand AL3 lateral, A4 /A5 sand 10760' - 10770' MD — 1 TD @ 11,950' MD TD @ 12,513' MD KOP @ 10790' MD - -- I I Billet @ 11,095' MD A lateral, l, 4 5 sand I L / l Billet @ 11,679' MD CIBP at 10,811' MD A5 sand perfs 10816' - 10836' MD `-"".," A4 sand perfs 10854' - 10874' MD , AL1 lateral, A4 sand 10,850' MD - Suspected casing TD @ 13,647' MD 3-1/2" 9.3# L -80 damage near top A4 perfs Billet @ 11,325' MD shoe @ 11,150' RKB —,....■111 • • s , of Tk o 1//7 , THE STATE Alaska Oil and Gas 1, 0/ALASKA Conservation Commission 4 it /At GOVERNOR SEAN PARNELL 333 West Seventh Avenue P 9 S JAN 1 Anchorage, Main: ALA G� t� 907.279.1433 907.276.7542 %AWED J. Gary Eller D 1 Coiled Tubing Drilling Engineer 0 6 ConocoPhillips Alaska, Inc. " 4 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F -19 Sundry Number: 312 -385 Dear Mr. Eller: 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, Daniel T. Seamount, Jr. Commissioner DATED this /h day of October, 2012. Encl. STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMION � ,, 11e ~ l ' APPLICATION FOR SUNDRY APPROVALS t v 20 AAC 25.280 1. Type of Request: Abandon / Flug for Redrill , Perforate New Pool f Repair well r Change Approved Program r Suspend r P Rug Perforations Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing Other: 1"""' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p' . Exploratory f 196 -201 ' 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22728 -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 67 2F -19 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25666 . Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11152 533817 ` / l 11051' 6302' Casing Length P Size MD TVD Burst Collapse CONDUCTOR 79 ' V /L 16 121' 121' SURFACE 4670 7.625 4711' 3222' RECEIVED PRODUCTION 10594' 5.5 10635' 5877' 07 / t Z LINER 1130 3.5 11150' 6336' UC I U 9 ZUIZ AOGCC Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10760'- 10874' 6044' -6144' 3.5 L - 10019 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SABL -3 PACKER MD =10019 TVD =5430 NIPPLE - CAMCO DS NIPPLE MD =513 TVD =513 12. Attachments: Description Summary of Proposal J;► 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: _ / 10/27/2012 Oil E Gas I WDSPL r Suspended ;V , 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned 4 - ( r q 17 Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and corre to the best of my knowledge. Contact: Gary Eller © 263 -4172 %, Printed Name . Ga E - r Title: Coiled Tubing Drilling Engineer Signature EAU. Phone: 263 -4172 Date \Q ISS(0..._ 'Commission Use Only Sundry Number: 2-3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test X Mechanical) Integrity Test r Location Clearanc e r 7l/�> Other: si r "f psi_ /3 v / / e: A A/k r'ri a�Le� PV elite- dtS i s S ti /4 h A•J•K 1 — a'p• rav" /!'.G z0 .44C Z / /ZN Subsequent Form Required: / 0 -q Q7- �� / APPROVED BY � of/ f_ i / Approved by: �, / 1• / CMMISSIONER THE COMMISSION Date: f� [ A,I,V Form 1 � i � / OW Z0 , j p. /Z IL./ Submit in Dupli ORIGINAL �9,o ;0- • • . , KRU 2F -19 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well KRU 2F -19 is an A/C -sand producer that has been shut in for several months due to problems with sand production from possible casing damage adjacent to the A -sand perforations. Three CTD laterals . will be drilled south of 2F -19 to increase reservoir exposure and improve waterflood sweep in the A5 and A4 sands. Following a lengthy period of pre - production, the 2F -19 CTD laterals will be converted to water injection service., The liner -top packer in 2F -19 is 771' above the planned window exit, which is substantially greater than the 200' allowed for wells equipped for water injection service. There is no means to deepen the packer placement inside the 3'/z' liner. ConocoPhillips requests a variance from the requirements of 20 AAC 25.412(b) regarding packer placement to allow 2F -19 to be converted to water injection service. A permanent plug will be set in the 3W liner at 10,811' to isolate the existing A -sand perfs, and then a 1 mechanical whipstock will be placed at the planned kickoff point of 10,790' MD. ConocoPhillips 1 requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. There is insufficient room to meet these plugging requirements while still accommodating a sidetrack from 10,790' MD. After setting the bridge plug and whipstock, we will perform an injectivity test into the open C -sand perfs at 10,760' -770'. Our expectation is that the C -sand is tight and that we will not be able to establish injection. However, if we are able to establish injection then we will use coiled tubing to perform a cement squeeze ✓ on all open perfs. Either way, all existing 2F -19 perforations will be isolated or rendered unproductive prior to performing the CTD sidetrack. A tubing leak has recently been detected in 2F -19 at ±9350' MD. We have conducted a risk assessment and concluded that CTD managed pressure drilling operations can be safely conducted despite the tubing communication. However, an extra barrier from the formation is required during rig mobilization and demobilization. Prior to rig mobilization we will perform a no -flow test at the conclusion of pre -CTD plugging operations to confirm that barrier. Prior to demobilization we will install a positive plug in the D- nipple at 9995' MD, followed by a no -flow test. The tubing leak will be repaired after the CTD rig has departed. The 2F -19A sidetrack will exit the 3W liner at 10,790' MD and will target the A4 sand south of the existing well with a 3135' lateral. The hole will be completed with a 2 slotted liner to the TD of 13,925' MD with an aluminum billet at 11,940' MD. The 2F -19AL1 lateral will kick off from the aluminum billet at 11,940' MD and will target the A5 sand south of the existing well with a 2490' lateral. The hole will be completed with a 2 %" slotted liner to the TD of 14,430' MD with an aluminum billet at 11,100' MD. The 2F -19AL2 lateral will kick off from the aluminum billet at 11,100' MD and will also target the A5 sand south of the existing well with an 800' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,900' MD with the final liner top located inside the 3W liner at 10,785' MD. Cal ),F -rq WO //ever ot veil, ot 1,,e /f '- "tsi frati" 'o# ,P4/ 4r - 230 or, 4»a oYro h `,, To /eif 7 50 1 4 A* 7,'44. ,gr Ix y l A fiierm i T it f w e lt' feCl v,��. f.?s n firma/eel A,'ne t0�of'u�1 � � ,S�/ ,' T h ,,, pr r,''ori o c 'tie loot, /9CO2.,- Page 1 of 2 October 8, 2012 • • CTD Drill and Complete 2F -19 Laterals: October 2012 /AD Pre -CTD Work )(I) q 3‘b 1. MIRU slickline. Dummy all GLMs. Run whipstock dummy inside 3%2" liner. 2. MIRU a -line. Set permanent plug inside 3 %" liner at 10,811' above all A -sand perfs. 3. Set monobore whipstock at 10,790' MD with 10° ROHS orientation. 4. Perform injectivity test into open C -sand perfs. If unable to establish injection into C -sand perfs, proceed ' to step #5. a. OPTION: If able to establish injectivity into C -sand perfs, then MIRU coiled tubing. Cement whipstock in place, simultaneously squeezing all open perfs. Clean out cement down to the top of the whipstock at 10,790'. b. MIRU slickline. Tag top of cement and pressure test. 5. Perform no -flow test. If well does not pass a no -flow test, have slickline set a positive plug in the 2.75" D- nipple at 9995' prior to rig mobilization. 6. Prep site for Nabors CDR2 -AC, including setting BPV t3411( Rig Work A. 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 2F -19A Sidetrack (A4 sand, south) a. Mill 2.74" window through 3 %" liner at 10,790' MD b. Drill 2.70" x 3" bi- center lateral to TD of 13,925' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 11,940'. Over - balancing completion V fluid will have been circulated in place to serve as a barrier to formation pressure while picking up i t slotted liner. /� 3. 2F -19AL1 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 11,940' MD b. Drill 2.70" x 3" bi- center lateral to TD of 14,430' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 11,100'. Over - balancing completion fluid will have been circulated in place to serve as a barrier to formation pressure while picking up slotted liner. 4. 2F -19AL2 Lateral (A5 sand, south) a. Kick off of the aluminum billet at 11,100' MD b. Drill 2.70" x 3" bi- center lateral to TD of 11,900' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 10,785' inside the 3 %" liner. Over- balancing completion fluid will have been circulated in place to serve as a barrier to formation pressure while picking up slotted liner. 5. Freeze protect. 6. MIRU slickline. Set a positive plug in the 2.75" D- nipple at 9995'. Perform no -flow test. RD slickline. 7. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. MIRU slickline. Pull plug at 9995'. Install gas lift design and patch the hole at —9350' MD. Perform static BHP survey. 3. Put on pre - production for several months prior to submitting a 10-403 application and performing an MIT - IA to convert to water injection. Page 2 of 2 October 8, 2012 • i KUP 2F -19 ConocoPhillips 0 Well Attributes Max Angle & MD TD AI.I�R -f RIG Wei!bore API/UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 500292272800 KUPARUKRIVERUNIT PROD 73.70 5,160.01 11,152.0 Gancsaihilipts Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NIPPLE 55 10/17/2006 Last WO: 5/25/1997 Well Confq_ 2F- 19,102/2012 7'.56'.25 AM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag'. RKB 10,614.0 6/23/2012 Rev Reason: PROD CSG CORRECTION osborl 10/1/2012 HANGER, 27 "�" A Casing Strings Mr Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd ` CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H - 40 WELDED ,i.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I �. WINDOW 8 4.950 10,260.0 10270.0 5,596.0 15.50 L - 80 LTC - MOD {I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 41.4 4,711.0 3,222.1 29.70 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 51/2 4.950 38.9 10,270.0 5,596.0 15.50 L - 80 LTC - MOD r Casing Description String 0... String ID ... Top (5103) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,019.3 11,149.8 6,335.8 9.30 L -80 ABM -BTC Liner Details Top Depth (TV D) Top Incl Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) CONDUCTOR. 42 - 721 1. 10,019.3 5429.7 50.56 PACKER BAKER SABL -3 PACKER /LINER HANGER 2.780 i Tubing Strings a Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE,513 TUBING 31/2 2.992 27.2 10,019.3 5,429.7 9.30 L -80 ABM -BTC Completion Details Top Depth (TVD) Top Incl Nomi... Top (RKB) (ftKB) ( * ) Item Description Comment ID (in) 27.2 27.2 -0.04 HANGER FMC GEN IV TUBING HANGER 3.500 513.3 513.3 1.22 NIPPLE CAMCO DS NIPPLE 2.812 9,995.9 5,414.9 51.60 NIPPLE CAMCO D NIPPLE 2.750 10,003.5 5,419.7 51.26 LOCATOR BAKER LOCATOR 3.000 GAS LIFT 3.635 10,004.7 5,420.4 51.21 PBR BAKER PBR 3.000 10,018.7 5,429.2 50.59 ANCHOR BAKER KBH -22 ANCHOR SEAL NIPPLE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 1 i Top Depth (TVD) Top Inc! Top (RKB) (ftKB) )) Description Comment Run Date ID (in) 10,260.0 5,589.2 47.49 WHIPSTOCK WHIPSTOCK SET IN SIDETRACK AFTER PB1 & PB2 1/27/1997 I COLLAPSED; 3.5" LINER RUN .i PATCH 75/8" Surface casing has external corrosion w/ 50% wall 5/15/2011 loss in the top 18" of the well. MAWOP 200 PSI . D. N.E.1800 PSI. SURFACE, 41 -4,711 f Perforations & Slots ® De Top (TVD) Bbn(TVD) Dens GAS LIFT, Top (ftKB) Btm (RKB) (RKB) (RKB) Zone Date (oh--• Type Comment 7,601 10,760.0 10,770.0 5,985.8 5,994.2 C -4, 2F -19 7/25/1997 6.0 APERF 2.5" HSD BFI; 180 deg. Ph III 10,816.0 10,836.0 6,034.1 6,051.9 A -5, 2F -19 7/25/1997 6.0 APERF 2.5" HSD BH; 180 deg. Ph . 10,854.0 10,874.0 6067.8 6,085.6 A -4, 2F -19 6/6/1997 4.0 IPERF 2.5" HSD BR: 180 deg. Ph Notes: General & Safety GAS LIFT, End Date Annotation 9.943 5/2/1997 NOTE: Original production we((bore abandoned during original drill, well sidetracked @ 10260' ® 10/14/2010 NOTE: View Schematic w/ Alaska Schematic9.0 la 9/6/2012 NOTE: Installed 6' sleeve from bottom of starter head made w/ 10" x 65.500 pipe. NIPPLE, 9696 - - -- LOCATOR, 10,004 ___ ."_._ PBR, 10,005 - ANCHOR, 70,019 WHIPSTOCK, A 10,260 WINDOW, 70,260 - 10,270 PRODUCTION, 39-10.270 APERF, 10,760-10,770 Mandrel Details Top Depth Top Port APERF, (TVD) Inc! OD Valve Latch Size TRO Run 10,816 - 10,836 Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,334.9 2,637.7 63.18 BST AXT 1 GAS LIFT GLV T1 0.156 1,343.0 10/24/1997 IPERF, 2 7,600.7 4,374.1 66.37 BST AXT 1 GAS LIFT GLV T1 0.188 1,371.0 10/24/1997 10,654 - 10,674 3 9,943.3 5,383.1 52.82 BST AXT 1 GAS LIFT OV T1 0.188 0.0 10/24/1997 LINER. 70,019 - 11,750 TD (2F -19). A • 11.152 . ` 2F -19 Proposed CTD Sidetrack Revised: 3- Oct -12 3 -1/2" Camco DS nipple @ 513' RKB 16" 62# H -40 =x' 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface shoe @ 121' MD 3 -1/2" Camco MMG gas lift mandrels @ 3335', 7600', and 9943' RKB _ - 7 -5/8" 29.7# L- 9350' MD - 80 shoe @ 4711' Tubing leak RKB 3 -1/2" Camco D nipple @ 9996' RKB, 2.75" min ID i. Baker 3 -1/2" locator /seal assembly @ 10,003' RKB (3" ID) Baker PBR @ 10,004' RKB (4" ID seal bore) Baker KBH -22 anchor -seal nipple @ 10,018' RKB (3" ID) 5-1/2" 15.5# L -80, window at 10,260' RKB — Liner top (original shoe at Baker SABL -3 liner top packer @ 10,019' RKB (2.78" ID) 10,635') . Marker joint (15') @ 10,699' RKB (10,693' PDC) Marker joint (15') @ 10,714' RKB (10,709' PDC) C-sand perfs _ �... -- . AL2 lateral, A5 sand 10760' - 10770' MD �--- '*' Top of Whipstock @ 10,790' MD TD @ 11,900' MD KOP @ 10790' MD i�. _ _______________ f1 ?fi. 3" openhole, A 2 -3/8" slotted liner L1 lateral, A5 sand CIBP at 10,811' MD ''..'- - ---: ::"... TD @ 14,430' MD • Billet @ 11,100' MD /i _ A5 sand perfs 10816' 10836' MD i e ry / A4 sand perfs - _- 10854' - 10874' MD A lateral, A4 sand 3 9.3# L - 80 — 10,850' MD - Suspected casing TD @ 13,925' MD ' shoe @ 11,150' damage near top A4 perfs Billet @ 11,940' MD RKB 0 0 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 ti/ 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. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • • Iry RECEIVED ConocoPhillips OCT 0 9 2012 Alaska P.O. BOX 100360 AOGCC ANCHORAGE, ALASKA 99510 -0360 October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 , a >. . ± ' ' ,0 h" 4 ) §' Anchorage, AK 99501 _ �© 1°1 Commissioner Dan Seamount: �.� 1 J Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, / /77/ Martin Walters ConocoPhillips Well Integrity Projects Supervisor II • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,IF,2F,2L,2T,2Z,3G,31& 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 F-19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 1 I RECEIVED STATE OF ALASKA ALA& OIL AND GAS CONSERVATION COMNOION SEP 21 20`,'. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Plug Perforations fi Perforate fl Other V Alter Casing f Pull Tubing fl Stimulate - Frac r Waiver fl Time Extension ( t Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r i _ 196 -201 p d; 3. Address: 6. API Number: ., P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service j 50- 029 - 22728 -00 —.0j 7. Property Designation (Lease Number): 8. Well Name and Number: - ADL0025666 — 2F -19 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 11152 feet Plugs (measured) None true vertical 6396 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 10019 true vertical 0 feet (true vertucal) 5491 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 1640 630 SURFACE 4670 10 4711 3259 6890 4790 PRODUCTION 10596 5.5 10635 5936 7000 4990 LINER 1130 4.563 11150 6394 10540 10160 SLEEVE 6 10 6 0 0 0 Perforation depth: Measured depth: 10760'- 10874' JAN 1 2013 True Vertical Depth: 6044' - 6144' SCANNED Tubing (size, grade, MD, and TVD) 3.5, L -80, 10019 MD, 5482 TVD Packers & SSSV (type, MD, and TVD) ANCHOR - BAKER KBH -22 ANCHOR SEAL NIPPLE @ 10019 MD and 5491 TVD 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory fl Development C . Service J Stratigraphic x 16. Well Status after work: Oil p -. Gas r WDSPL r Daily Report of Well Operations GSTOR [ VVINJ fl WAG fl GINJ [ SUSP fl SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -258 Contact Martin Walters / MJ Loveland Printed Name /V1 3 i.- e(e( ,-7JG1 Title Well Integrity Supervisor Signature Phone: 65 - 704 .. Date 9 -16 -12 .7 ---' RRDMS SEP 2 12011 7 4, 7• ' / t- Form 10 -404 Revised 11/2011 Submit Original Only • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 16, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry for ConocoPhillips Alaska, Inc. well 2F -19, PTD 196 -201, Sundry 312 -258 surface casing repair. Please contact MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, d' MJ L eland ConocoPhillips Well Integrity Projects Supervisor • 2F -19 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/20/12 Initial T /I /O= Si/820/160. Cut and removed 8' of conductor piping from wellhead. Chipped cement and buffed SC for upcoming Kakivik inspection for SC repair. Final T /I /0= Si/820/160. 09/04/12 Staged equipment for surface casing repair. Installed purge jewelry on OA. In process of rigging up cooper heat to wellhead. T /I /O =00 /100. 09105/12 Rigged up cooperheat to wellhead and brought temperature up to 475 *. Welded 8" of 10" X65 .500 wall pipe (A & B bands- double stack) onto surface casing. Final T /I /O= si /0/5. 09/06/12 Welded a 5' 5" of 10" X65.500 wall pipe (sleeve) to A & B bands. Awaiting results of Kakivik inspection on final weld of sleeve. Removed N2 purge and wrapped up job site. Total sleeve +r length is 6'. Final T /I /O= Si /0/5. 09/09/12 MIT -00A (failed) due to open shoe. Pressure would only reach 900 PSI pumping at optimal Pafped approximately 10 BBLS of diesel for test. Bled OA to 0 PSI. Final T /I /O = SI /0 /0 09/12/12 Welders welded 7' 3.5" 16" 62.58# .375 conductor pieces in place. TOC= 7' 5 ". Ready for 1/ cement and sealant. Final T /I /O= Si /0 /0 Vi z ' r t ,,, , ,,, , , y +ay..ve -, - .. iF r s r f w, �� C 4 r 3 . * F 4, , , , - 4 1 y a X , •-• „ - — ©Conocq tips Alaska, Inc ,` ' This photo * eyrtght by 4 • f .a.� ConocoP ��[ & ska, Inc. , ..� .< z and canna sd erelea or ► ; ,', published € re ��' - ,..��. �� * written co - ' � � , ° ,� � _ ConocoP ° � ' `[ ;0,;a ., „.,. ; . a 111, ^ , 4 f 2 C Y n y OConocoPhillips Alaska, In( This photo is copyright by ConocoPhillips Alaska, Inc and cannot be released or published without express written consent of -4 "k' CorlocoPhillips Alaska l9 - Zo\ %2 5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 27, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 1‘- iy r ;/ 4 RE: Multifinger Imaging Tool (MIT) : 2F -19 Run Date: 8/23/2012 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 2F -19 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22728 -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 Z Signed: i G 0 • , _i e ti, ( SEAN PARNELL, GOVERNOR 1 0 L CI\ [I. A \\A �T �b ALASKA OIL GA��a7T 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Martin Walters Well Integrity Supervisor r - � 1 ConocoPhillips Alaska, Inc. (0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F -19 Sundry Number: 312 -258 SL JUL 2 0 202 Dear Mr. Walters: 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, i 4,, Cathy 1 Foerster Chair 1 DATED this ! 9 da y of July, 2012. Encl. STATE OF ALASKA R EC E' E Al OIL AND GAS CONSERVATION COM ON 9T ,g - - 27/q' � j2 CfC ' - APPATION FOR SUNDRY APPROVALS JUL 17 2012 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r * CI' to w jogram r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: SC Repair rI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r 196 - 201 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22728 - 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 r 2F -19 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025666 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11152 • 6396 ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' 1640 630 SURFACE 4670 10 4711' 3259' 6890 4790 PRODUCTION 10596 5.5 10635' 5936' 7000 4990 LINER 1130 4.563 11150' 6394' 10540 10160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10760' 10874' 6044' -6144' 3.5 L -80 10019 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER = BAKER SABL -3 PACKER/LINER HANGER MD = 10019 TVD = 5491 SSSV = CAMCO "DS" NIPPLE MD = 513 TVD = 513 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development F Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/1/2012 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Printed Name /, /,/ // Martin Walters Title: Well Integrity Supervisor Signature / /Zdi i"' / Phone: 659 -7043 Date: 7/15/12 t/ Commission Use Only Sundry Number:312 .Z5 Conditions of approval: Notify Commission so that a representative may witness 11 ✓UU Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: - N 'f":7 -2 :5 , e-doiWir 4 -f «J: Subsequent Form Required: /6.— 1 p 1( APPROVED SY 7 G Approved by: ajet7 p9,,,,,,,,,,zp_____ CO MMISSIONER THE COMMISSION Date: / % - 1 Z Form 10 -403 Revised 1/2010 ?,e_. ? /b�'1 R I G I N , 3lJi 1 9 A LRBDMS $ . D plicate i "‘ ler/ „\ • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 July 15, 2012 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2F -19, PTD 196 -201 surface casing inspection and repair. ✓' Please contact MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, eN 1/1,10 Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska, Inc. Kuparuk Well 2F -19 (PTD 196 -201) SUNDRY NOTICE 10 -403 APPROVAL REQUEST July 15, 2012 This application for Sundry approval for Kuparuk well 2F -19 is for the inspection and repair of surface 1 casing with reduced wall thickness. Part of the surface casing on this well was exposed to the atmosphere and it was identified as having corrosion taking place. 2F -19 was found to have 50 -60% wall loss to the surface casing during the process of applying corrosion inhibiting sealant. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s) and/or BPV. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform MITOA 9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and /or BPV and return the well to production. 13. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 7/16/2012 ■ KUP 2F -19 4 ConocoPhillips Well Attributes • Max Angle & MD TD • Wellbore APUUWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) ■ Ata5ka,1!>r u w+,rwps 500292272800 KUPARUK RIVER UNIT PROD 72.69 5,150.00 11,152.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE 55 10/17/2006 Last WO: 5/25/1997 Well Canfia - 2F -19, 75120121:18:58 PM - Schamatic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 10,614.0 6/23/2012 Rev Reason: WELL REVIEW osborl 7/9/2012 Casing Strings HANGER, 27 i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H WELDED '' Cuing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 41.4 4,711.0 3,259.2 29.70 L BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd 191 r { PRODUCTION 5 1/2 4.950 38.8 10 635.1 5,935.8 15.50 L - 80 LTC - MOD ` Caaing Oescr'ption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 10,019.3 11,149.8 6,393.9 9.30 L -80 ABM -BTC Liner De tails . T op Depth (TVD) Top loci Nomi... III Top (ftKB) (ftKB) 1 Item Description Comment ID (in) 10,019.3 5,491.4 51.68 PACKER BAKER SABL -3 PACKER /LINER HANGER 2.780 CONDUCTOR. Tubing Strings 42-121 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 27.2 10,019.3 5,491.4 9.30 L -80 ABM -BTC IIIIF Completion Details NIPPLE, 513 Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (') Item Description Comment ID (in) 27.2 27.2 -0.04 HANGER FMC GEN IV TUBING HANGER 3.500 I 513.3 513.3 1.19 NIPPLE CAMCO DS NIPPLE 2.812 9,995.9 5,476.9 52.79 NIPPLE CAMCO D NIPPLE 2.750 10,003.5 5,481.5 52.42 LOCATOR BAKER LOCATOR 3.000 10,004.7 5,4822 52.37 PBR BAKER PBR 3.000 cos LIFT. � 10,018.7 5,490.9 51.71 ANCHOR BAKER KBH -22 ANCHOR SEAL NIPPLE 3.000 3,335 r -: Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth illr (TVD) Top Incl Top (ftKB) (ftKB) e) Description Comment Run Date ID ('n) PATCH 75/8" Surface casing has external corrosion w/ 50% wall 5/15/2011 loss in the top 18" of the well. MAWOP 200 PSI . D.N.E.1800 PSI. Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (*KB) (ftKB) (ftKB) Zone Date (sh ... Type Comment SURFACE. � 10,760.0 10,770.0 6,044.4 6,052.8 C 2F - 19 7/25/1997 6.0 APERF 2.5" HSD BH; 180 deg. Ph 414,711 10,816.0 10,836.0 6,092.3 6,110.0 A -5, 2F -19 7/25/1997 6.0 APERF 2.5" HSD BH; 180 deg. Ph 10,854.0 10,874.0 6,125.9 6,143.8 A-4, 2F -19 6/6/1997 4.0 IPERF 2.5" HSD BH; 180 deg. Ph GAS LIFT, ._ Notes: General & Safety 7,807 End Date Annotation 10/14/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 GAS LIFT, 9,843 le III NIPPLE, 9,996 MB LOCATOR, 10,004 PBR, 10.005 i - ANCHOR, 10,019 IIIP PRODUCTION, 39- 10,635 APERF, 10,760- 10,770 Mandrel Details Top Depth Top Port APERF, (TVD) 11101 OD Valve Latch 5106 TRO Run 10,816- 10,936 Stn Top (ftKB) (RKB) (°) Make Model (in) Sery TM. Type (in) (psi) Run Date Com... 1 3,334.9 2,647.5 62.80 BST AXT 1 GAS LIFT GLV T1 0.156 1,343.0 10/24/1997 IPERF, 2 7,600.7 4,427.9 66.10 BST AXT 1 GAS LIFT GLV T1 0.188 1,371.0 10/24/1997 10,854 - 10,874 3 9,943.3 5,445.3 53.83 BST AXT 1 GAS LIFT OV T1 0.188 0.0 10/24/1997 LINER, 10,019-11.150 TO (2F -19), 11,152 • • ± ' +/ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 2F -19 Run Date: 7/3/2012 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 2F -19 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22728 -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 f t l Date: ,'.S, � Signed: / — • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 q y Commissioner Dan Seamount 44` Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 t (9,© 0f Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 6130/11 2F,2M,2N,2T,2X,2Z,3B,3O PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # Pm # _ cement pumped cement - . date inhibitor sealant date ft bbls ft _ gal 2F -19 50029227280000 1962010 , 8 N/A 23" - N/A _ 13 6/25/2011 2M -09A 50103201770100 1960900 SF N/A 18" N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" N/A 3.5 6/26/2011 2M -17 50103201500000 _ 1910180 , SF N/A 19" N/A - 3.5 6/26/2011 2M -26 1 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" N/A 7 6/27/2011 2T-40 50103205280000 2060400 2' N/A 2' N/A 6 6/26/2011 2T -202 50103202540000 _ 1980370 6" N/A 20" _ N/A - 9 6/26/2011 2X -07 50029209910000 _ 1831130 SF N/A 21" N/A _ 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A 21" N/A 2.5 6/25/2011 - 2Z -02 50029209600000 1830800 18" N/A 18" N/A 2.6 6/24/2011 3B -01 50029213180000 1850560 SF 1.50 17" 5/23/2011 i 6 6/22/2011 30 -12 50029218040000 1880410 SF N/A 22" N/A 1.7 6/22/2011 • n ~ 'I i Co ocoPh~ I ps Alaska P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ q~,~.ol ~- i 9 Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped October 16, 2008. The attached 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. Sincerely, ~~ ~ ~~ ~~ ~CZ' ~ ~ ~0~~ ,. ~ ~i' G MJ Love and ConocoPhillips Well Integrity Projects Supervisor • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field data 10/22!2008 s Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2F-02 183-188 20" NA 20" NA 2.21 10/16/2008 2F-03 183-187 20" NA 20" NA 2.23 10/16/2008 2F-05X 196-203 7" NA 7" NA 1.7 10/16/2008 2F-06 184-019 18" NA 18" NA 1.72 10/16/2008 2F-11 184-041 .20" NA 20" NA 2.22 10/16/2008 2F-13 183-156 12" NA 12" NA 6.8 10/16/2008 2F-14 183-159 7" NA 7" NA 4.25 10/16/2008 2F-18 196-178 5" NA 5" NA 11.9 10/16/2008 2F-19 196-201 6" NA 6" NA 1.7 10/16/2008 oN oR BEFOt W 2Fro 17, 19, 1Q-02A Stares Change Subject: 2F-17, 19, 1Q-02A Status Change Date: Thu, 18 May 2000 10:3 3:33 -0900 From: "Eric L Zuspan" <N1052~ppco.com> To: steve_mcmains~admin.state.ak.us, blair_wondzell~admin.state.ak.us As per Blairs request this e-mail is to notify the AOGCC of status changes on the following Kuparuk wells° Please disreguard the 403's sent in previously. The sundry for 3Q-08A was a 404 report of a conversion done last year. If you have any questions please call me at 659-7285 Eric Well PTD Permitted Status Current Status As of 1Q-02A 95-0194-0 Prod Inj 8/1/96 ~-~2F-17 96-0204-0 Prod Inj 11/1/97 ~.~2F-19 96-0201-0 Inj Prod 6/1/97 1 ofl 5/18/00 10:52 AM PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 96-201 MWD SRVY ~'~PERRY 0-10641 -, NGP-MD [I/4750-10640 NGP-TVD ~232-5916 MWD SRVY ~R~0175-11152 8012 ~%PERRY MPT/SR/~OP CMT ~P ~8550-9440 CMT ~P P~T II ~8550-9440 CBL ~ 9800-11028 ~-- NGP-MD ~750-10640 D~L/SFL ~06~8-~077.7 SST~ ~"10618-11077.7 PB1 BHP ~0618-11077.7 PB1 7743 ~sc~L~ D~TE/CNTG 8037 ~SC~L~ PDC/GR ~W~ SRVZ ~SPER~Y 0-~064~ MWD SR~ ~ERRY 10175-11152 WELL SRVC RPT ~F NGP-T~ ~5656-6385 NGP-MD ~'10286-11152 Page: 1 Date: 05/24/99 RUN RECVD 03~05/97 FINAL 04/16/97 FINAL 04/16/97 06/20/97 3 07/02/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 07/25/97 FINAL 07/28/97 FINAL 07/28/97 FINAL 07/18/97 FINAL 07/18/97 FINAL 07/18/97 FINAL 07/18/97 1 07/18/97 1 07/18/97 07/31/97 07/31/97 07/31/97 FINAL 09/10/97 FINAL 09/10/97 BOX PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS COMPLETION DATE Page: 2 Date: 05/24/99 RUN RECVD T D BOX .... DAILY WELL OPS R @~,~/~ /~ ~/ TO ~-/~k)~/~/ @~ Are dry ditch samples required? ' yes ~_And received? Was the well cored? yes ,_~Analysis & description received? Are well tests required? ,%yes Well is in compliance~ - Initial COMMENTS nQ.~. ~ Received? - _ ARCO Alaska, Inc. Post Office Oox , o0360 Anchorage Alaska 99510-0360 Telephone 907 276 12t 5 April 9, 1999 ?Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 i 25326 100 0 25426 See ,Vote #J below25426 2L-325 i 8397 100 0 I 8497 11883 20380 2N-321A ] 27507 100 0 27607 0 27607 3K-23 i 15 0 0 15 0 15 3K-25 14202 100 0 4302 0 4302 1C-15 116695 100 0 16795 0 16795 2L-313 i S554. I 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously re 9orted volume o_f 220 barrels was 2umped into this annulus during ttte drilling of the well. This was the vohttne required to flush and freeze protect the attnulus during initial drilling operations, not a volutne o_f disposal fluids injected prior to the receipt ~' authorization for ann ular injection. Total Volumes into Annuli for which Injection Authorization Expired during the quarter I Total I ] Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1C-12 34995 100 0 35095 Open, Freeze Protected 1C-13 i 26800 100 I 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26~h letter, and are only reported here again for the sake of clarity. ARCO Alaska. inc. is a Subsidiary of Atlantic Richfield Company ~,R3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two ~ i Total [ Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume I Volume Injected Annulus 2A-22 16749 100 [ 0 16849 Open. Freeze Protected 2F-19 20725 100 ] 0 20825 Open, Freeze Protected 3K-27 37173 100 i 0 37273 Open, Freeze Protected 3K-26 33970 100I~ 0 34070 Open, Freeze Protected 1E-31 33645 100 I 0 33745 Open, Freeze Protected 1E-32 45205 100] 0 45305 Open, Freeze Protected 3Q-22 6245 100Ii 0 6345 Open. Freeze Protected 1Q-24 23158 100 t 0 23258 Open, Freeze Protected I I 1Q-26 25931 I 1 oo ! 0 26031 Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files STATE OF ALASKA AI_~bKA OIL AND GAS CONSERVATION COMMISb~ON REPORT OF SUNDRY WELL OPERATIONS Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging 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 68' FNL, 1749' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1681' FNL, 2442' FWL, Sec. 3, T10N, R9E, UM At effective depth 1747' FNL, 2556' FWL, Sec. 3, T10N, R9E, UM At total depth 1764' FNL, 2592' FWL, Sec. 3, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 11152 6394 6. Datum elevation (DF or KB) RKB 32 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-19 9. Permit number/approval number 96-201 10. APl number 50-029-22728-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Effective depth: measured 1 1 051 true vertical 6302 feet Junk (measured) None feet 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4656' 7-5/8" 10587' 5.5" 1131' 3.5" measured 10854'-10874' true vertical 6118'-6136' Cemented Measured depth 260 Sx AS I 1 1 2' 261 Sx ASLW & 4702' 1220 Sx Class G w/60 Sx AS I tail 100 Sx Class G 1 0 6 2 6' 132 Sx Class G 1 1 1 5 0' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10019' Packers and SSSV (type and measured depth) Packer: Baker SABL-3 Liner Packer @ 10019'; SSSV: None, nipple @ 513' Stimulation or cement squeeze summary Fracture stimulated well on 6/14/97. Intervals treated (measured) 10854'-10874' Treatment description including volumes used and final pressure True vertical depth 112' 3213' 5926' 6393' ORIGINAL Pumped 42.9 Mlbs of 12/18 ceramic proppant into formation, fp was 7600 psi. ~,,., Representative Daily Average Production or Injection Dat~..":.9 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1100 130 Subsequent to operation 345 2 61 132 1125 135 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. For 4 ' R~v,,~0 6/d~/~'~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMiT'IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(2F-19(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-19 FRAC, FRAC SUPPORT 0605971843.2 DATE DAILY WORK UNIT NUMBER 06/14/97 HYDRAULIC FRACTURE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 ~ Yes ('~ NoI ® Yes O No DS-GALLEGOS KRALIOK FIELD AFC# CC# DAILY COST ACCUM COST ESTIMATE 998615 230DS28FL $1 0,000 $10,000 Initial Tbcl Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial O~er A~n I Final Outer Ann 1550 PSI 3500 PSI 1040 PSI 2500 PSII 2~SII 550 PSI DAILY SUMMARY I PUMP HYDRAULIC FRAC- SCREENOUT W/7 PPA @ PERFS W/36 BBLS FLUSHED. 42,900# PROP BEHIND PIPE 11,866# PROP IN I I I PIPE. ESTIMATED SAND TOP @ 3335'. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC CREW 08:30 SET TREE SAVER -TEST FLUIDS @ 3 MIN AND 2 1/2 MIN ACTIVATION 09:30 SAFETY MEETING 10:30 PFF LINES AND PUMPS TO 9350 PSI 10:45 BREAKDOWN - 50# DELAYED XL GW 28 BPM - GEL TO PERFS - SLOW DOWN RATE TO 15 BPM @ 6270 PSI- 200 BBL STAGE 10:50 FLUSH/OVERDISPLACE - STRAIGHT WATER - 126 BBL 10:55 S/D @ 4366 PSI - ISIP @ 2444 PSI 11:06 PULSE W/STRAIGHT WATER @ 5 BPM - 2680 PSI 11:09 PULSE W/STRAIGHT WATER @ 5 BPM - 2900 PSIG 11:26 PULSE W/STRAIGHT WATER @ 5 BPM - 2943 PSIG 11:40 DISPLACE 50# DELAYED XL GW 5 BPM - 100 BBL- 6600 PSI 12:03 SWAP TO STRAIGHT WATER - 15 BPM @ 6400 PSIG 12:14 S/D 4476 PSIG - ISIP 2919 PSIG 13:15 DECREASE PAD 30 BBLS 13:25 START PAD PER PROCEDURE - 50# DELAY XL GW - 5 BPM - INCREASE TO 15 BPM PER PROCEDURE - ADD SAND PER STAGES - 7PPA @ PERFS AND AT MAX PRESSURE (7600 PSI) CUT ACTIVATOR RATE TO 2.5/2 GAL PER THOUSAND - DROP RATE TO 13/12/11/10 BPM 14:13 FLUSH - PRESSURE @ 7400 PSIG - PUMPED 36 BBLS FLUSH - SCREENOUT 8200 PSI MAX PRESSURE - 7PPA @ PERFS 16:00 RDMO DS - ESTIMATED SAND TOP @ 3335' - 11,866# PROP IN PIPE - 42,900# PROP BEHIND PIPE - SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,000.00 $5,000.00 DOWELL $0.00 $0.00 LITTLE-RED $5,000.00 $5,000.00 TOTAL FIELD ESTIMATE $10,000.00 $10,000.00 STATE OF ALASKA ALAb~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 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 68' FNL, 1749' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1681' FNL, 2442' FWL, Sec. 3, T10N, R9E, UM At effective depth 1747' FNL, 2556' FWL, Sec. 3, T10N, R9E, UM At total depth 1764' FNL, 2592' FWL, Sec. 3, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 11152 6394 6. Datum elevation (DF or KB) RKB 32 7. unit or Property name Kuparuk River Unit 8. Well number 2F-19 9. Permit number/approval number 96-201 10. APl number 50-029-22728-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Effective depth: measured 1 1 05 1 true vertical 6302 feet Junk (measured) None feet 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4656' 7-5/8" 10587' 5.5" 1131' 3.5" measured 10854'-10874' true vertical 6118'-6136' Cemented Measured depth 260 Sx AS I 1 1 2' 261 Sx ASLW & 4702' 1220 Sx Class G w/60 Sx AS I tail 100 Sx Class G 1 0 6 2 6' 132 Sx Class G 1 1 1 5 0' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 10019' Packers and SSSV (type and measured depth) Packer: Baker SABL-3 Liner Packer @ 10019'; SSSV: Stimulation or cement squeeze summary Perforated well on 6/6/97. Intervals treated (measured) True vertical depth 112' 3213' 5926' 6393' ORiGiNAL None, nipple @ 513' 'i..! i:"~ 10854' 10874' ' . . Treatment description including volumes used and final pressure Perforated w/2-1/8" HSD gun w/ BH charges @ 4 SPF, 180° phasing, fp was 1300 ..... Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1075 130 Subsequent to operation 345 2 6 1 132 1100 135 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Signed Form 1.!,~-404 / I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMf'ClN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT ~' WELL SERVICE REPORT ~' K1(2F-19(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-19 PERFORATE, PERF SUPPORT 0528971 902.2 DATE DAILY WORK UNIT NUMBER 06/06/97 PERFORATE FROM 10854' TO 10874' 8337 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 (~) Yes 0 No (~) Yes (~ No SWS-BAILEY BLACK FIELD AFC# CO# DALLY COST ACCUM COST ~ _ ESTIMATE AK8593 230DS28FL $9,304 $55,207 Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer An~ r"'Final Outer Ann 0 PSI 1 300 PSI 0 PSI 1 300 PSII !400 PSI 400 PSI DAILY SUMMARY PERFORATED FROM 10854' TO 10874' WITH 2 1/2" HSD BH @ 4 SPF & 180 DEG PHASED (DUE TO USE OF PETROLINE ROLLERS, UNSURE OF ORIENTATION) TIME LOG ENTRY 07:00 MIRU SWS # 8337 W/BAILEY-LEVY-LISTER 07:30 FINISH R/U. ARM 2 1/2" HSD, 4-SPF, B.H., 180 DEG PHASED CARRIER GUN WITH PETROLINE ROLLERS. 07:45 P/T TO 3500 PSI. RIH. 08:30 DIFFICULTY GE-f-FING DOWN AT 5100'. RU LI'I-I'LE RED ON PUMP-IN SUB AND PUMPED DOWN AT .5 TO 1 BPM. ABLE TO GET DOWN. PUMPED TOTAL OF 36 BBLS DIESEL. 09:30 TIE-IN TO SWS CBL DATED 5-JUN-97. LOG INTO POSITION & PERFORATE W/2.5" HSD BH @ 4 SPF & PHASED 180 DEG (UNSURE OF ORIENTATION DUE TO PETROLINE ROLLERS ) F/10,854 - 10,874'. ELM. PERFORATED OVERBALANCE +/- 200 PSI. LOGGED JEWELRY & POOH. 11:00 AT SURFACE. START R/D. 12:00 FINISH R/D. LEAVE LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $o.oo APO $2,000.00 $11,000.00 ARCO $0.00 $630.00 DOWELL $0.00 $6,200.00 HALLIBURTON $0.00 $1,481.00 LITTLE RED $1,100.00 $1,100.00 SCHLUMBERGER $6,204.00 $34,797.00 TOTAL FIELD ESTIMATE $9,304.00 $55,208.00 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. ('h~o Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2F-19, AK-MW-70143 September 10, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22728-00 NOTE: This Digital Data (2F-19) is replacement Data for well (2F-19A). p, EcE VE S £P 1 0 1997' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~[,._9~'- September 10, 1997 RE: MWD Formation Evaluation Logs 2F-19, AK-MW-70143 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2F-19: 2" x 5" MD Gamma Ray Logs: 50-029-22728-00 2" x 5" TVD Gamma Ray Logs: 50-029-22728-00 Note: These logs (2F-19) are replacment data for well (2F-19A). 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia R CE VJ S£P 10 1997 Alaska Oil & Gas C~ns. Commission ~c~cm~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, In¢, Company ARCO Alaska, Inc. " Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 28, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2F-19 (Permit No. 96-201) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2F-19. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALAS.,, ~ OIL AND GAS CONSERVATION ~,-,MMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well ......................... Classification"of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Pre-Produced Injector 2. Name of Operator 7. Permit Number ARCOAlaska Inc. 96-201 , 397-079 397-019, 397-097 ......................... 3. Address 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22728 4,,,.,.,~._,_. 9. Unit or Lease Name 4. Location of well at surface ;~ ':~?: .::'-': "~'- 68' FNL, 1749' FEL, Sec. 33, T11N, R9E, UM ~ '-"~"' ~*~ :"'; i ' Kuparuk River Unit At top of productive interval~ ~/~,;/';~,h~ -":: ?~" ~.ti_~~:' ~'' 10. Well Number 1681' FNL, 2442' FWL, Sec. 3, T10N, R9E, UM ~.-'~-/~¢-/_.~/_. ~ j ~,~¢~___L._~ ' 2F-19 1764' FNL, 2592' FWL, Sec. 3, T10N, R9E, UM.~ ~..-':-~"'-¢_.~.- ...................................................... ~'-'::~--~-:-::~-:-~.~-:-_.~ ..... -~-_. ................................... Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Rig RKB 32', Pad 97'I ADL 25666, ALK 2587 12. Date Spudded1/20/97 ll 3' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re ' 16' N°' °f C0mpleti°ns5/20/97 6/6/97 .... N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Di~ectional Survey j20. Depth where SSSV set~l. Thickness of"Permafr~'st 11152 6394 F~ 11051 6302 F~ [~Yes I--INo i N/A MD/ 1650' (Approx.) 22. Type Electric or Other Logs Run GR, GR/CCI_/SLTJ !23. CASING, LINER AND CEMENTING RECORD CASING 'SE-I-FINe DEPTH "'ROLE ............. SiZE ~. V~-..__P___E_R__FT. GRADE ...... T0?- ...... DO'FI-OM SiZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 112' 24" 260 sx AS I 7-5/8" 29.7# L-80 .... Surf. , 47_0_2' _ 9.875" 261 sX___ASLW, 1220 sx Class G & 60 sx AS I 5.5" 15.5# L-80 Sud. 10626' 6.75" 100 sx Class G 3~5'~ 9~2# - I._-~0 10~-i§'- 1115~-' ........ ~..?-5'~ 1132 sx Class G 24. Perf0'rations open to ProduCtion (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10019' ' i00~ 9~' ...... MD TVD MD TVD 10854'-10874' 6118'-6136' 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .................. 10760'-10770' 6042'-6051' DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED 6 spf 10854'-1 0874' 7 ppa @-perf~ w/36 blois fi~Shed~ 42~900¢¢ .... 10816'-10836' 6091'-6108' prop behind pipe, 11866# prop in pipe. 6 spf ........................................ 27. PRODUCTION TEST ........ Date First Production iMethod' Of ope~adsn (F:i~wing, gas iift~ ~to~) ........ 6/19/97 I Flowing Date of T~t iHours Tested PRODUCTION FOR OIL-DEL - GAS_MCF-- WATER-DEL CHOKE SIZE I GAS-OIL RATIO 7/14/97 I 6.2 TEST PERIOD ' 63 ............ _29 ......... 1 6 ............ 176 ...... ~ 546 iF'iow---I'-~Jb-i~iCasing PressureCALcU-~-~- · OIL-DEL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) press. 13~ _.N/A 24-HouR RATE 229 . 1.25 62 24.©. ........ :28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIgiNAL . Form 10-407 Rev. 07-01-80 Submit In D,uplicat~' · .. ,, Geologic Mar' 'I-~-(~i .... Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GE)R, and time of each phase. ,, Top Kuparuk C 10761' 6037' Bottom Kuparuk C 10770' 6044' Top Kuparuk A 10800' 6070' Total pump volumes for this event: Bottom Kuparuk A 10947' 6202' Category 1. 20725 Category 2. 100 Category 3. 0 Total: 20825 Total To Date: 20825 t Annulus left open - freeze protected with diesel. . , 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed I~L ~_ ~~,.,,_._. .... Title 0ltf. l.~f.N~ ~t, lf~f,.¢,l~, Date "~'VL1 7..,~! Prepared By Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 7/10/97 ARCO ALASKA INC. WELL SLrMMARY REPORT Page: 1 WELL:2F-19 RIG:NORDIC WELL ID: AK8593 TYPE: AFC: AK8593 AFC EST/UL:$ 1510M/ 1810M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:01/19/97 START COMP: WI: 0% SECURITY: 0 AP1 NUMBER: 50-029-22728-00 FINAL:01/28/97 01/19/97 (D1) TD: 121'(121) SUPV:GRW DAILY:$ 01/20/97 (D2) TD: 3183'(3-062) SUPV:GRW DAILY:$ 01/21/97 (D3) TD: 4728'(1545) SUPV:DCL DAILY:$ 01/22/97 (D4) TD: 4728'( SUPV:DCL 0) DAILY:$ 01/23/97 (D5) TD: 4728'( SUPV:DCL 0) DAILY:$ 01/24/97 (D6) TD: 6764' (2036) SUPV:DCL DAILY:$ 01/25/97 (D7) TD: 8905' (2141) SUPV:DCL DAILY:$ 01/26/97 (DS) TD:10641' (1736) SUPV: DCL DAILY:$ MW: 8.6 VISC: 83 PV/YP: 25/20 APIWL: 12.6 DRILLING $ 715' Heve rig 207' frem 2F-18 te 2F-19. Accept rig @ 05:30 en 1/19/97. Functien test diverter system. M/U BHA. 82,427 CUH:$ 82,427 ETD:$ 0 EFC:$ 1,592,427 MW: 9.2 VISC: 63 PV/YP: 22/22 DRILLING @ 3509' Drill from 121' to 3183' 87,849 CUH:$ 170,276 ETD:$ 273,556 EFC:$ APIWL: 7.0 1,406,720 MW: 9.5 VISC: 62 PV/YP: 20/21 APIWL: 5.6 RIH W/7-5/8" CASING Drill from 3183' te 4728' Circ and cenditien mud to run casing. 78,848 CUM:$ 249,124 ETD:$ 373,195 EFC:$ 1,385,929 ! MW: 9.6 VISC: 55 PV/YP: 18/19 APIWL: 6.0 MU BHA Held prejeb safety meeting. RIH with 7-5/8" casing te 4711' Pump cement. 193,670 CUH:$ 442,794 ETD:$ 373,195 EFC:$ 1,579,599 MW: 8.4 VISC: 38 PV/YP: 5/ 7 APIWL: 15.8 DRILLING Test all BOPE to 300/3000 psi. Wash and ream, clean out cement to 4544' Drill out cement, float equipment and 20' new hole to 4748' Performed LOT at 3218' TVD, 12.76 EMW. 75,366 CUH:$ 518,160 ETD:$ 373,195 EFC:$ 1,654,965 MW: 8.8 VISC: 54 PV/YP: 14/24 DRILLING Drilling from 4748' to 6764' 79,598 CUM:$ 597,758 ETD:6 538,733 EFC:$ APIWL: 8.8 1,569,025 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Drilling frem 6764' te 7687' Hele started breathing. Wiper trip te shee. No problems. Drilling frem 7687' te 8905' 75,707 CUH:$ 673,465 ETD:$ 712,809 EFC:$ 1,470,656 MW: 9.4 VISC: 49 PV/YP: 15/20 APIWL: 5.2 CIRC AFTER WIPERTRIP Drilling from 8905' to 10613' Evaluate logs. Drilling from 10613' to 10641' Evaluate logs. 75,498 CUM:$ 748,963 ETD:$ 853,956 EFC:$ 1,405,007 · Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/27/97 (D9) TD:10641' ( SUPV:DCL o) DAILY:$ 01/28/97 (D10) TD:10641'( 0) SUPV:DCL DAI.LY:$ 03/26/97 (Dll) TD:10626' ( 0) SUPV:DLW DAILY:$ 03/27/97 (D12) TD:10626'( ' 0) SUPV:DLW DAILY:$ 03/28/97 (D13) TD:10887' (261) SUPV:DLW DAILY:$ 03/29/97 (D14) TD:ll123'(236) SUPV:DLW DAI.LY:$ 03/30/97 (D15) TD:ll123' ( 0) SUPV:DLW DAILY:$ 03/31/97 (D16) TD:ll123' ( 0) SUPV:DLW DAILY:$ MW: 9.5 VISC: 53 PV/YP: 18/21 APIWL: 5.6 CEMENT 5.5" CASING Held pre-job safety meeting. Run in hole with 5.5" casing to 4711' RIH to 6539' Diminished returns. Continue to RIH to 8000' Circ and reciprocate casing with partial returns. 71,301 CUH:$ 820,264 ETD:$ 853,956 EFC:$ 1,476,308 MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED RIH to 10635'. ~ole breathing. Circ with partial returns. Pump cement. CIP @ 0720 hrs. Freeze protect annulus. Rig release @ 17:30 hrs. 1/28/97. 184,182 CUM:$ 1,004,446 ETD:$ 853,956 EFC:$ 1,660,490 MW: 8.5 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 RIH W/4.75" DRILLING BHA #1 Turn key move from 2F-17 to 2F-19. Accept rig @ 1300 hrs. 3/26/97. N/D tree. N/U BOPE. Function test. Test BOPE 250/3500 psi. RIH with BHA #1. 51,015 CUM:$ 1,055,461 ETD:$ 852,737 EFC:$ 1,712,724 MW: 12.0 VISC: 47 PV/YP: 13/ 5 APIWL: 3.1 C/O SHOE @ 10536' Continue RIH w/4.75" drill assembly on 2-7/8" DP to 10202' Tag cement 340' above 5.5" float collar. Clean out cement from 10202' to 10478' 41,528 CUH:$ 1,096,989 ETD:$ 852,737 EFC:$ 1,754,252 MW: 11.2 VISC: 44 PV/YP: 24/22 APIWL: 3.1 0600 DRILLING @ 11,020' Continue to clean out cement from 10478' to 10531' Clean out float collar and cement to 10580' Clean out cement and float shoe at 10626' and drill 20' new 4.75" hole to 10652'. FIT test @ 10652' MD, EMW = 14 ppg. Continue drilling 4.75" from 10698'-10887' 52,438 CUM:$ 1,149,427 ETD:$ 873,957 EFC:$ 1,785,470 MW: 12.0 VISC: 50 PV/YP: 24/23 APIWL: 2.8 POOH FOR E-LOGS Continue drilling 4.75" hole from 10887' to 11,123' TD. Raise mud weight to 12.0 ppg. 43,273 CUM:$ 1,192,700 ETD:$ 893,146 EFC:$ 1,809,554 MW: 11.5 VISC: 45 PV/YP: 15/ 7 APIWL: 2.9 RBIH TO 10887' CBU RIH w/GR/SGT/DITE/CNTL/HLDT log. RIH with 3.5" liner to 5.5" casing shoe @ 10626' Run liner through 4.75" open hole, stopped @ 10882'. Unable to get liner past bridge @ 10882' POOH w/liner, tight spot e 10804' POOH with 3.5" liner swabbing. 69,622 CUM:$ 1,262,322 ETD:$ 893,146 EFC:$ 1,879,176 MW: 12.0 VISC: 59 PV/YP: 21/20 APIWL: 2.5 CIRC ON CHOKE @ 0600 HRS Continue to POOH w/3.5" LINER. Unable to get past 10887' CBU. Work liner while circulating. Unable to get passed 10882'. Cut mud weight to 11.5 ppg. Hole taking fluid properly. 41,520 CUM:$ 1,303,842 ETD:$ 893,146 EFC: 1,920,696" Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/01/97 (D17) TD:lll91' ( 68) SUPV:DEB DAILY:$ 04/02/97 (D18) TD:lll91'( 0) SUPV:DEB DAILY:$ 04/03/97 (D19) TD:lllgl' ( 0) SUPV:DEB DAILY:$ 04/04/97 (D20) TD:lllgl'( 0) SUPV:DEB DAILY:$ 04/05/97 (D21) TD:lllgl' ( 0 SUPV:DEB DAILY:$ 04/06/97 (D22) TD:lll91' ( 0) SUPV:DEB DAILY:$ 04/07/97 (D23) TD:lilgl' ( 0) SUPV:DEB DAILY:$ 04/08/97 (D24) TD:lllgl' ( 0) SUPV:DEB MW: 12.5 VISC: 58 PV/YP: 21/ 0 APIWL: 2.7 MONITORING WELL W/12.8 PPG Wash and ream out bridge to 10885' Getting gas and oil cut mud. Well flowing. Weight up to 12.5 ppg. Continue cleaning out from 10906' to bottom @ 11123' Drill from 11123' to 11130' Started losing mud drilling more hole and getting gas cut mud to surface from cleaning out. Continue drilling additional rathole from 11130' to 11191' Losing fluid while drilling. Well still flowing. Shut in well. 42,652 CUH:$ 1,346,494 ETD:$ 898,674 EFC:$ 1,957,820 MW: 12.8 VISC: 57 PV/YP: 26/15 APIWL: 2.6 LD 4 JTS TO CLEAN OUT TO TD Weight up to 12.8 ppg and circulate around. Wash and ream out bridges from 11070' to 11115' 40,995 CUM:$ 1,387,489 ETD:$ 898,674 EFC:$ 1,998,815 MW: 12.8 VISC: 59 PV/YP: 28/16 APIWL: 2.5 WEIGHT UP PITS TO 12.8 PPG Wash and ream to 11177' tag bridge @ 11177'. Monitor well, flow continued and slowly increased. Shut in well. Weight up to 12.8 ppg. 47,811 CUM:$ 1,435,300 ETD:$ 898,674 EFC:$ 2,046,626 MW: 13.1 VISC: 58 PV/YP: 28/16 APIWL: 2.2 WELL SI, WO MUD & LCM Monitor well and weight up returned mud in pits to 12.8 ppg. Weight up surface system to 13.3 ppg. RIH and tag at 10874', worked thru, OK. Tagged bridge at 10906' Wash and ream from 10906' to 10937' Lost returns, hole stays full, but no returns at any pump rate. Shut-in and monitor well. 48,047 CUM:$ 1,483,347 ETD:$ 898,674 EFC:$ 2,094,673 MW: 12.8 VISC: 108 PV/YP: 37/30 APIWL: 4.1 MIX SLUG, MONITOR WELL Wash and ream from 10906' to 11166' Circulate 25 spm, getting partial returns. Tight spot @ 10950', worked thru. Shut down pump and monitor well. Well dead, no flow. 50,664 CUM:$ 1,534,011 ETD:$ 898,674 EFC:$ 2,145,337 MW: 12.7 VISC: 72 PV/YP: 34/19 APIWL: 4.6 SHAKE OUT LCM FOR LINER FILLUP Hole swabbing. Inject mud in kill line to maintain proper hole fill. 78,777 CUM:$ 1,612,788 ETD:$ 898,674 EFC:$ 2,224,114 MW: 12.6 VISC: 65 PV/YP: 32/19 APIWL: 3.8 CIRCULATE AND LD SINGLES DP Continue shaking out LCM from 90 bbls mud for liner fill up and circulation. Run 3.5" liner in stands from derrick. 49,029 CUM:$ 1,661,817 ETD:$ 898,674 EFC:$ 2,273,143 MW: 12.9 VISC: 65 PV/YP: 32/19 APIWL: 3.8 CIRCULATE WITH BIT @ 10294' Attempt to circulate liner, packing off, poor circulation. POOH. Test BOPE. RIH to 8785', mud flowing back up DP CBU, gas cut mud at bottoms up. RIH remaining stands to 10i94', mud flowing back up DP. Circulate hole clean, foamy gas cut mud at bottoms up. Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 DAILY:$ 04/09/97 (D25) TD:lll91' ( 0) SUPV:DEB DAILY: $ 04/10/97 (D26) TD:lll91'( 0) SUPV:DEB DAILY:$ 04/11/97 (D27) TD:lll91' ( 0) SUPV:DEB DAILY:$ 04/12/97 (D28) TD:10626'( 0) SUPV:DEB DAILY:$ 04/13/97 (D29) TD:10626'( 0) SUPV:DEB DAILY:$ 04/14/97 (D30) TD:I0626' ( 0) SUPV:DEB DAI. LY:$ 04/15/97 (D31) TD:10626' ( 0) SUPV: DEB DAILY:$ 40,785 CUM:$ 1,702,602 ETD:$ 898,674 EFC:$ 2,313,928 MW: 12.6 VISC: 49 PV/YP: 34/18 APIWL: 3.8 RIH W/BHA #4 Wash and rotate singles in from 10294' to 10619' Wash and ream below shoe @ 10626' to tight spot @ 10672' Continue reaming from 10641' to 10672', hole packing off and getting tighter. Continue washing and reaming from shoe to 10651' Hole still packing off and tight. Reciprocated and rotated down with kelly continuously to help clean hole. Monitor well - static, well dead. Pump slug. 37,168 CUH:$ 1,739,770 ETD:$ 898,674 EFC:$ 2,351,096 MW: 12.5 VISC: 80 PV/YP: 48/54 APIWL: 3.8 POH W/BHA #4 Wash and ream from inside shoe to 10631' Ream down 7 or 8 times, seeing tight hole last foot or two. Ream thru tight spot at 10635' - 10640'. Ream on tight spot at 10645' - 10650', packs off and torques up motor and rotary. Monitor well. Pump slug. Monitor well - static. 42,568 CUH:$ 1,782,338 ETD:$ 898,674 EFC:$ 2,393,664 MW: 12.5 VISC: 65 PV/YP: 38/37 APIWL: 4.0 WASH OEDP INTO HOLE @ 10654' Circulate te cenditien mud and hele and shake eut selids and LCH. 39,238 CUM:$ 1,821,576 ETD:$ 898,674 EFC:$ 2,432,902 MW: 12.4 VISC: 84 PV/YP: 42/40 APIWL: 4.6 POH WITH OEDP Wash down and work single from 10654' to 10685' Work several times to free up. Make connection and attempt to wash next joint down, unable to get below 10690' Tight and packing off. Worked for several hours with no progress. Pump cement and spot balanced plug. 67,935 CUH:$ 1,889,511 ETD:$ 852,737 EFC:$ 2,546,774 MW: 11.8 VISC: 55 PV/YP: 25/22 APIWL: 7.0 MONITOR WELL - PREPARE TO POH Wash and ream thru stringer of cement to 10127'. Wash down from 10127' to 10597', no cement. Wash and ream to 10629' No cement. Wash and ream and clean up rathole below casing until pipe works free to 10629' Drill from 10629' to 10642' 44,052 CU-M:$ 1,933,563 ETD:$ 852,737 EFC:$ 2,590,826 MW: 11.8 VISC: 54 PV/YP: 27/19 APIWL: 7.0 POH WITH OEDP Pump cement plug. 51,740 CUM:$ 1,985,303 ETD:$ 852,737 EFC:$ 2,642,566 MW: 11.5 VISC: 58 PV/YP: 25/17 APIWL: 9.5 POOH FOR K.O. BHA @ 10615' RIH with BHA %4 to clean out cement. Tag cement @ 10293' Clean out cement plug from 10293' to 10575'. Test 5.5" casing to 3500 psi for 30 min., OK. 54,218 CUM:$ 2,039,521 ETD:$ 852,737 EFC:$ 2,696,784 Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 04/16/97 (D32) TD:10626' ( 0) SUPV:DLW DAILY:$ 04/17/97 (D33) TD:10776'(150) SUPV:DLW DAILY:$ 04/18/97 (D34) TD:10871' ( 95) SUPV:DLW DAILY:$ 04/19/97 (D35) TD:10871' ( 0) SUPV:DLW DAILY:$ 04/20/97 (D36) TD:10871'( 0) SUPV:DLW DAILY:$ 04/21/97 (D37) TD:10450'( 0) SUPV:DLW DAILY:$ 04/22/97 (D38) TD:10450' ( 0) SUPV:DLW DAILY:$ MW: 11.4 VISC: 50 PV/YP: 25/17 APIWL: 9.5 RIH W/MWD TO 10421 Continue to clean out kick off plug from 10575' to 10615' 65,886 CUM:$ 2,105,407 ETD:$ 852,737 EFC:$ 2,762,670 MW: 12.0 VISC: 53 PV/YP: 22/20 APIWL: 5.0 DRILLING AHEAD W/4.75" HOLE Logging MAD pass from 10375' to 10550' w/ MWD. Clean out cement from 10615' to KIP @ 10631' Drill 4.75" hole from 10660' to 10714' Started packing off. Work pipe back out of hole to shoe. Rotate and drill from 10714' to 10776' 58,488 CUM:$ 2,163,895 ETD:$ 864,932 EFC:$ 2,808,963 MW: 12.5 VISC: 60 PV/YP: 31/21 APIWL: 3.8 POOH TO L/D MWD AND CHANGE BHA Continue directional drilling 4.75" hole from 10776' to 10871'. Made connection started pump and going down, packed off unable to circulate. Trying to clean out hole, unable to get past 10680'. Continues to pack off and have to pull back up to establish circulation. Raise mud weight from 12.0 ppg to 12.5 ppg. 55,217 CUH:$ 2,219,112 ETD:$ 872,656 EFC:$ 2,856,456 MW: 12.6 VISC: 55 PV/YP: 30/21 APIWL: 3.6 POOH TO CHANGE BHA @ 10726 Clean out casing from 10560' to 10626' and outside shoe to 10640' packed off. Still getting fine cuttings. Started cleaning out hole from shoe to 10705' Hole cleaning up and not packing off. 52,499 CUH:$ 2,271,611 ETD:$ 872,656 EFC:$ 2,908,955 MW: 12.5 VISC: 50 PV/YP: 26/15 APIWL: 3.6 POOH FOR 5.5" RETAINER Continue to clean out 4.75" hole from 10705' to 10726' Ream from 5.5" shoe at 10626' to 10734' Packed off and had to pull back to shoe to establish circulation. Clean out to 10691', packed off. Had to pull back to shoe to establish circulation. With bit just outside casing circulate at 75 spm ~ 3500 psi. Clean all cuttings from casing. Pump dry job. 39,230 CUH:$ 2,310,841 ETD:$ 872,656 EFC:$ 2,948,185 MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 CLEANING MUD TANKS RIH with Baker N-1 cement retainer on 2-7/8" DP. Set retainer @ 10500' Pump cement to P&A. Test casing to 3500 psi, OK. 55,520 CUM:$ 2,366,361 ETD:$ 838,427 EFC:$ 3,037,934 MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: N/D BOPS POOH L/D 267 joints of 2-7/8" DP. Reverse circulate and displace sea water from 2100' w/diesel for freeze protection. Release rig @ 0500 hrs. 4/23/97. Move rig to 2F-20. 34,015 CUH:$ 2,400,376 ETD:$ 838,427 EFC:$ 3,071,949 . 0.0 Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 04/23/97 (D39) TD:10450' ( 0) SUPV:DLW DAILY:$ 05/15/97 (D40) TD:10450' ( 0) SUPV:DLW DAILY:$ 05/16/97 (D41} TD:10288' ( 0) SUPV:DLW DAILY:$ 05/17/97 (D42) TD:10288' ( 0) SUPV:DLW DAILY:$ 05/18/97 (D43) TD:10286' ( 0) SUPV:DLW DAILY:$ 05/19/97 (D44) TD:10462' (176) SUPV:DLW DAILY:$ 05/20/97 (D45) TD:10935' (473) SUPV:DLW DAILY:$ 05/21/97 (D46) TD:ll152' (217) SUPV:DLW DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVED TO 2F-20 N/D BOPs. N/U tree. Rig down, move rig off hole. Release rig @ 0500 hrs. 4/23/97. 6,545 CUM:$ 2,406,921 ETD:$ 838,427 EFC:$ 3,078,494 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Turn key rig move from 2G pad to 2F-19ST. 72,215 CUM:$ 2,479,136 ETD:$ 838,427 EFC:$ 3,150,709 MW: 10.5 VISC: 66 PV/YP: 21/30 APIWL: 4.0 PICK UP 2-7/8" DP RIH Accept rig @ 0000 hrs. 5/15/97. Test BOPE 250/3500 psi. RIH w/junk basket to 10385' Set bridge plug at 10288' RIH with 2-7/8" DP. 68,830 CUM:$ 2,547,966 ETD:$ 825,255 EFC:$ 3,232,711 MW: 10.5 VISC: 70 PV/YP: 19/32 APIWL: 4.0 RIH W/WHIPSTOCK RIH w/5.5" casing scraper to 10203' Tag bridge plug @ 10282' RIH w/Whipstock assembly. 94,363 CUM:$ 2,642,329 ETD:$ 825,255 EFC:$ 3,327,074 MW: 10.5 VISC: 70 PV/YP: 23/31 APIWL: 3.8 REPAIR FITTING TO AIR TO CLUTC Set Whipstock on bridge plug @ 10282' Start cut out @ 10260' and cut 12' window. Continue drill outside of 5.5" casing to 10286' Perform FIT test to EMW of 13.8 ppg. POOH. 44,226 CUM:$ 2,686,555 ETD:$ 825,093 EFC:$ 3,371,462 MW: 11.3 VISC: 57 PV/YP: 23/20 APIWL: 3.4 DRILL 4.75" HOLE @ 10557' Continue to RIH w/drilling BHA to 9292' While installing Sperry-Sun depth control decoder onto drawworks drum clutch, damaged threads where airline goes into clutch. RIH to 10202' Slide thru window @ 10260' to 10462' · 47,060 CUM:$ 2,733,615 ETD:$ 839,402 EFC $ 3,404,213 MW: 12.0 VISC: 49 PV/YP: 21/24 APIWL: 3.4 DRILLING W/4.75" HOLE @ 11091' Continue to directional drill 4.75" from 10462' to 10620' sliding. Rotate from 10620' to 10705' Slide from 10705' to 10792' Drill from 10792' to 10839' Slide from 10839' to 10935' 43,849 CUM:$ 2,777,464 ETD:$ 877,860 EFC:$ 3,409,604 MW: 12.5 VISC: 53 PV/YP: 29/27 APIWL: 3.2 RUNNING 3.5" LINER Continue sliding for angle and direction while drilling 4.75" hole from 10935' - 11096' Drill from 11096' - 11152' TD 4.75" hole. Raise mud weight from 12.0 ppg to 12.5 ppg. RIH to 11152' Hole in good condition. POOH to 5.5" window @ 10260' Observe well while shut-in "0" psi. Well dead. 78,524 C UM:$ 2,855,988 ETD:$ 895,503 EFC:$ 3,470,485 Date: 7/10/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 05/22/97 (D47) TD:ll152' ( 0) SUPV:DLW DAILY:$ 05/23/97 (D48) TD:ll152' ( 0) SUPV:DLW DAILY:$ 05/24/97 (D49) TD:ll152'( 0) SUPV:DLW DAILY:$ 05/25/97 (D50) TD:ll152'( 0) SUPV:DLW DAILY:$ MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 LAY DOWN 2-7/8" DP Run 3.5" liner w/fleat equipment and Baker packer. Pump cement. 33,465 CUH:$ 2,889,453 ETD:$ 895,503 EFC:$ 3,503,950 MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUN 3.5" COMPLETION POOH L/D 2-7/8" DP. Load pipe house w/3.5" tubing, strap, drift and install seal rings. R/U to run completion. 97,351 CUM:$ 2,986,804 ETD:$ 895,503 EFC:$ 3,601,301 MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TESTING TREE WILL RELEASE RIG Continue to run 3.5" completion. Test 5.5" x 3.5" to 3500 psi. OK. Freeze protect. Pull and L/D hanger work tubing and check space out. Tubing moved down hole 9' to 10019' BTU 'K' anchor would not latch. Pressure up annulus to 3500 psi for 10 min. Then could not shear PBR pressure up on tubing to 1500 psi and pulled 150K. 37,207 CUM:$ 3,024,011 ETD:$ 895,503 EFC:$ 3,638,508 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASE RIG Continue to space out and land 3.5" tubing hanger, test 3.5" tubing to 3500 psi for 15 min. OK. Test 5.5" x 3.5" annulus to 3500 psi for 15 min., OK. Test packoff, test tree to 250/5000 psi. Secure well. Release rig @ 0730 hrs. 5/24/97. 0 CUM:$ 3,024,011 ETD:$ 895,503 EFC:$ 3,638,508 End of WellSummary for Well:AK8593 KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2F-19(W4-6)) ,v2L JOB SCOPE JOB NUMBER 2F-19 FRAC, FRAC SUPPORT 0715971614.3 DATE DAILY WORK UnIT NUMBER 07/25/97 PERF 2.5" HSD 6 SPF DP 8293 DAY OPERATION CO~ ] SUCCESSFUL [ KEYPERSON SUPERVISOR 1 YES YES SWS-ELMORE JORDAN InitialTbgPmss [FinalTbgPrcss [InitiallnnerAnn [FinallnnerAnn IlnitialOuterAnn {FinalOutcrAnn 250 PSI 1500 PSI 200 PSI 0PSI 600 PSI 500 PSI DAILY SUMMARY PERFED 10,760'-10,770' & 10,816'-10,836'. 2.5" HSD GUNS. 31J UJ HMX, 6 SPF, DP. TIME 08:00 LOG ENTRY MIRU SWS-8293-ELMORE. TGSM. PT 3000g 09:30 RIH GUN 1. CCL/MPD/20' X 2.5" HSD, 6 SPF, 31J UJ DP HMX CHARGE. 10:00 LOST WT@ 5100. 71 DEG DEVIATION. 11:30 12:45 13:30 14:50 RU PUMP TRUCK. PUMP DOWN @ .5 - 2 BPM. TIE IN TO SWS CBL DATED 5 JUNE 97. SHOOT GUN 1 @ I0816'-10836'. POOH. RIH GUN 2. WTBAR/CCL/MPD/10' X 2.5" HSD, 6 SPF, 31J UJ DP HMX CHARGES. 15:15 5100'. BEGIN PUMPING @ 2 BPM. 16:00 TIE IN GUN #2. 16:20 ATYEMPT TO SHOOT GUN #2 @ 10760'- 10770'. MISFIRE. POOH. 18:00 19:00 RIH W/GUN 2 (2ND TRIP). PUMP @ 2 BPM.TOTAL BBLS PUMPED/3 TRIPS=200 TIE IN GUN #2. 19:15 SHOOT GUN 2@ 10760'-I0770'. POOH 20:30 RI)MO KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2F-19(W4-6)) 2F-19 06106/97 DAY 4 DAILY JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0528971902.2 DAILY WORK UNIT NUMBER PERFORATE FROM 10854' TO 10874' 8337 OPERATION COMPLEIE I SUCCF~qSFUL ! KEYPERSON SUPERVISOR YES YES SWS-BAII.EY BLACK ) Ann Final Inner Ann I [Final Initial Tbg Press Final Tbg Press ] Initial Inner Initial Outer Ann Outer Ann 0 PSI 1300 PSI ] 0 PSI 1300 PSI 400 PSI 400 PSI SUMMARY PERFORATED FROM 10854' TO 10874' WITH 2 1/2" HSD BH @ 4 SPF & lS0 DEG PHASED (DUE TO USE OF PETROLINE ROLLERS, UNSURE OF ORmNTAT~ON) TIME LOG ENTRY 07:00 MIRU SWS # 8337 W/BAILEY-LEVY-LISTER 07:30 FINISH R/U. ARM 2 1/2" HSD, 4-SPF, B.H., 180 DEG PHASED CARRIER GUN WITH PETROLINE ROLLERS. 07:45 P/T TO 3500 PSI. RIH. 08:30 DIFFICL~TY GETTING DOWN AT 5100'. RU LITILE RED ON PUMP-IN SUB AND PUMPED DOWN AT .5 TO 1 BPM. ABLE TO GE~ DOWN. PUMPED TOTAL OF 36 BBLS DIF_31:~I ~. 09:3 0 TIE-IN TO SWS CBL DATED 5-JUN-97. LOG INTO POSITION & PERFORATE W/2.5" HSD BH @ 4 SPF & PHASED 180 DEG CtJNSURE OF ORIENTATION DUE TO PETROLINE ROLLERS ) F/10,854 - 10,874' ELM. PERFORATED OVERBALANCE +/- 200 PSI. LOGGED JEWELRY & POOH. 11:00 ATSURFACE. STARTR/D. 12:00 FINISH RA). LEAVE LOCATION. ., ST ~{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KRU / 2F-19A 500292272801 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 052097 MWD SURVEY JOB NUMBER: AK-MW-70143 KELLY BUSHING ELEV. = 129.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10175.00 5589.74 5460.74 48 16 10260.00 5646.97 5517.97 47 4 10470.27 5798.95 5669.95 40 35 10501.80 5823.35 5694.35 38 0 10540.96 5854.98 5725.98 34 17 S 30.92 E .00 6632.20S 3967.30E S 31.85 E 1.64 6685.85S 4000.02E S 46.30 E 5.65 6798.91S 4090.43E S 43.40 E 10.09 6813.05S 4104.52E S 49.90 E 13.60 6828.93S 4121.26E 6566.56 6620.23 6752.42 6771.42 6793.58 10571.95 5880.71 5751.71 33 24 10601.70 5905.52 5776.52 33 35 10633.13 5931.91 5802.91 32 12 10663.89 5958.29 5829.29 29 42 10693.87 5984.53 5855.53 28 6 S 51.60 E 4.22 6839.85S 4134.62E S 51.40 E .77 6850.08S 4147.47E S 54.70 E 7.24 6860.34S 4161.10E S 53.30 E 8.46 6869.63S 4173.90E S 51.70 E 5.93 6878.45S 4185.40E 6810.46 6826.57 6843.39 6859.02 6873.28 10-~24.94 6011.74 5882.74 29 36 10758.18 6040.44 5911.44 31 0 10790.18 6068.05 5939.05 29 42 10821.96 6095.94 5966.94 27 36 10853.67 6124.04 5995.04 27 36 S 54.50 E 6.50 6887.44S 4197.39E S 56.50 E 5.19 6896.93S 4211.21E S 55.80 E 4.21 6905.93S 4224.64E S 56.10 E 6.62 6914.46S 4237.26E S 58.30 E 3.21 6922.42S 4249.60E 6888.06 6904.69 6920.75 6935.88 6950.50 10884.40 6151.42 6022.42 26 23 10916.34 6180.14 6051.14 25 30 10947.80 6208.43 6079.43 26 17 10979.27 6236.65 6107.65 26 17 11009.57 6263.93 6134.93 25 17 S 58.00 E 3.93 6929.78S 4261.45E S 61.10 E 5.10 6936.87S 4273.50E S 61.50 E 2.60 6943.47S 4285.55E S 64.20 E 3.80 6949.83S 4297.95E S 65.20 E 3.60 6955.46S 4309.87E 6964.41 6978.36 6992.10 7006.04 7019.21 11040.28 6291.81 6162.81 24 12 11070.05 6319.06 6190.06 23 17 11105.49 6351.61 6222.61 23 17 11152.00 6394.33 6265.33 23 17 _ S 65.20 E 3.58 6960.86S 4321.54E S 64.10 E 3.37 6965.99S 4332.38E S 63.30 E .89 6972.20S 4344.95E S 63.30 E .04 6980.46S 4361.38E THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM ARE BASED ON THE USE OF CURVATURE METHOD. 7032.06 7044.04 7058.06 7076.45 HORIZONTAL DISPLACEMENT = 8230.95 FEET AT SOUTH 31 DEG. 59 MIN. EAST AT MD = 11152 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 117.29 DEG. TIE-IN SURVEY AT 10,175.00' MD WINDOW POINT AT 10,260.00' MD PROJECTED SURVEY AT 11,152.00' MD ORIGINAL .RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 2 ARCO ALASKA INC KRU / 2F-19A 500292272801 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 052097 JOB NUMBER: AK-MW-70143 KELLY BUSHING ELEV. = 129.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10175.00 5589.74 5460.74 6632.20 S 3967.30 E 4585.26 11152.00 6394.33 6265.33 6980.46 S 4361.38 E 4757.67 172.41 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S: .{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KRU / 2F-19A 500292272801 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/17/97 DATE OF SURVEY: 052097 JOB NUMBER: AK-MW-70143 KELLY BUSHING ELEV. = 129.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10175.00 5589.74 5460.74 6632.20 S 3967.30 E 4585.26 10233.61 5629.00 5500.00 6669.43 S 3989.83 E 4604.61 19.35 10376.28 5729.00 5600.00 6752.85 S 4047.84 E 4647.28 42.67 10508.88 5829.00 5700.00 6816.09 S 4107.52 E 4679.88 32.60 10629.68 5929.00 5800.00 6859.25 S 4159.60 E 4700.68 20.80 10744.88 6029.00 5900.00 6893.14 S 4205.59 E 4715.88 15.20 10859.26 6129.00 6000.00 6923.77 S 4251.78 E 4730.26 14.37 10970.74 6229.00 6100.00 6948.15 S 4294.57 E 4741.74 11.48 11080.87 6329.00 6200.00 6967.87 S 4336.22 E 475'1.87 10.13 11152.00 6394.33 6265.33 6980.46 S 4361.38 E 4757.67 5.80 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS %Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 2F-19 500292272800 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 012397 MWD SURVEY JOB NUMBER: AK-MM-70013 KELLY BUSHING ELEV. = 138.00 OPER3kTOR: ARCO ALASKA, INC. FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -138.00 121.00 121.00 -17.00 287.15 287.15 149.15 466.74 466.72 328.72 648.53 648.39 510.39 0 0 0 0 0 18 1 9 2 40 N .00 E N .00 E N 36.88 W S 49.16 E. S 76.79 E .00 .00 .19 .82 .96 .00N .00E .00 .00N .00E .00 .36N .27W -.45 .44S .81E .80 2.62S 6.34E 5.53 740.30 739.95 601.95 832.43 831.55 693.55 923.03 921.10 783.10 1017.68 1014.04 876.04 1110.40 1104.32 966.32 4 44 7 31 9 58 11 45 14 -31 S 74.60 E S 58.51 E S 45.87 E S 40.00 E S 38.38 E 2.25 4.11S 12.09E 9.80 3.53 8.28S 20.91E 17.94 3.42 16.85S 31.61E 30.82 2.21 29.95S 43.69E 48.30 3.00 46.30S 56.99E 69.18 I202.22 1192.55 1054.55 1296.41 1281.68 1143.68 1389.84 1368.38 1230.38 1481.60 1451.77 1313.77 1574.73 1535.12 1397.12 17 38 S 31.91 E 20 4 S 25.48 E 23 37 S 26.61 E 25 41 S 29.45 E 27 15 S 28.88 E 3.92 67.15S 71.50E 94.53 3.39 93.87S 86.00E 124.90 3.82 125.09S 101.29E 159.52 2.60 158.85S 119.30E 197.72 1.71 195.10S 139.53E 239.20 1667.78 1616.76 1478.76 1762.53 1697.69 1559.69 1856.16 1775.43 1637.43 1949.30 1850.27 1712.27 2043.52 1922.68 1784.68 30 3 32 34 35 6 37 56 41 35 S 29.49 E S 30.14 E S 30.58 E S 32.25 E S 31.05 E 3.03 234.05S 161.30E 283.79 2.68 276.77S 185.79E 333.02 2.71 321.75S 212.15E 385.14 3.22 369.04S 241.06E 440.57 3.97 420.35S 272.66E 500.83 2132.96 1987.63 1849.63 2228.32 2052.98 1914.98 2322.21 2114.48 1976.48 2415.09 2174.12 2036.12 2510.12 2233.47 2095.47 45 14 48 14 49 54 50 12 52 28 S 31.35 E S 32.03 E S 32.06 E S 29.45 E S 28.57 E 4.08 472.92S 304.50E 562.29 3.19 532.00S 340.99E 631.73 1.77 592.12S 378.62E 702.65 2.18 653.30S 415.02E 773.83 2.51 718.18S 450.99E 847.96 2603.79 2288.20 2150.20 2697.71 2338.54 2200.54 2974.81 2477.29 2339.29 3156.12 2562.37 2424.37 3430.10 2684.10 2546.10 56 0 S 29.52 E 3.86 59 9 S 30.46 E 3.46 60 44 S 30.90 E .59 63 16 S 30.83 E 1.40 63 58 S 29.39 E .54 784.62S 487.90E 923.90 853.27S 527.54E 1003.15 1059.53S 649.92E 1242.97 1196.92S 732.03E 1403.02 1409.23S 855.14E 1648.39 3706.99 2798.61 2660.61 3983.33 2911.03 2773.03 4266.62 3030.61 2892.61 4648.43 3191.31 3053.31 5020.03 3330.94 3192.94 67 10 64 48 65 15 64 57 70 54 S 32.60 E S 31.70 E S 31.28 E S 31.76 E S 27.05 E 1.57 1625.23S 985.00E 1900.42 .91 1838.89S 1119.31E 2152.76 .21 2057.88S 1253.45E 2409.57 .14 2353.12S 1434.52E 2755.91 1.98 2653.03S 1603.20E 3099.80 ORIGINAL S. ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 2F-19 500292272800 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 012397 MWD SURVEY JOB NUMBER: AK-MM-70013 KELLY BUSHING ELEV. = 138.00 OPERATOR: ARCO ALASKA, INC. FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5298.84 3425.79 3287.79 69 19 S 30.35 E 1.25 2882.98S 1729.05E 5483.94 3492.02 3354.02 68 44 S 29.99 E .37 3032.41S 1815.92E 5669.39 3561.14 3423.14 67 29 S 31.57 E 1.04 3180.24S 1903.96E 5760.48 3597.59 3459.59 65 19 S 32.41 E 2.52 3251.02S 1948.17E 5946.51 3676.82 3538.82 64 15 S 32.38 E .58 3393.14S 2038.34E 3361.65 3534.46 3706.51 3789.97 3958.24 6222.31 3788.88 3650.88 67 48 S 30.49 E 1.43 3608.14S 2169.69E 6497.81 3906.01 3768.01 61 51 S 32.50 E 2.25 3820.69S 2299.79E 6774.61 4028.36 3890.36 65 40 S 34.88 E 1.58 4027.17S 2437.55E 7055.07 4156.09 4018.09 60 9 S 29.29 E 2.65 4238.38S 2570.31E 7330.10 4282.18 4144.18 65 15 S 25.43 E 2.23 4455.41S 2682.41E 4210.19 4459.40 4707.40 4956.84 5200.52 7606.51 4395.88 4257.88 66 10 S 29.27 E 1.31 4679.13S 2798.16E 7879.61 4507.50 4369.50 65 34 S 30.36 E .43 4895.38S 2922.08E 8154.79 4619.77 4481.77 66 16 S 31.09 E .35 5111.34S 3050.43E 8425.85 4731.87 4593.87 64 52 S 33.02 E .83 5320.47S 3181.37E 8704.85 4847.45 4709.45 66 10 S 30.68 E .90 5536.12S 3315.30E 5451.81 5700.96 5952.17 6198.88 6452.73 8986.75 4969.88 4831.88 62 19 S 29.51 E 1.42 5755.74S 3442.64E 9265.99 5102.41 4964.41 61 0 S 29.47 E .48 5969.67S 3563.62E 9535.33 5234.32 5096.32 60 20 S 31.53 E .71 6171.97S 3682.77E 9719.93 5324.29 5186.29 61 18 S 31.57 E .52 6309.33S 3767.11E 9813.98 5369.86 5231.86 60 43 S 32.71 E 1.23 6378.99S 3810.87E 6706.54 6952.18 7186.94 7348.12 7430.39 9905.18 5417.16 5279.16 56 46 S 32.38 E 4.35 6444.70S 3852.81E 9998.45 5470.89 5332.89 52 52 S 31.67 E 4.23 6509.31S 3893.24E 10090.90 5528.41 5390.41 50 9 S 30.84 E 3.01 6571.16S 3930.79E 10184.83 5589.75 5451.75 48 17 S 30.92 E 1.99 6632.20S 3967.30E 10277.00 5651.96 5513.96 46 47 S 32.07 E 1.86 6690.18S 4002.81E 7508.32 7584.53 7656.89 7728.01 7796.00 10373.63 5720.24 5582.24 43 16 S 33.97 E 3.91 6747.52S 4040.03E 10465.15 5787.17 5649.17 42 43 S 33.59 E .65 6799.39S 4074.73E 10557.54 5854.82 5716.82 43 7 S 34.86 E 1.03 6851.41S 4110.12E 10641.00 5915.74 5777.74 43 7 S 34.86 E .02 6898.22S 4142.73E 7864.33 7926.69 7989.52 8046.46 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8046.60 FEET AT SOUTH 30 DEG. 59 MIN. EAST AT MD = 10641 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 148.68 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD SURVEY PROJECTED TO TD AT 10641' MD S PAGE 3 ~Y-SUN DRILLING SERVICES AlqCHORAGE ALASKA ARCO ALAStCA, INC. KUPARUK RIVER UNIT / 2F-19 500292272800 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 012397 JOB NUMBER: AK-MM-70013 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -138.00 .00 N .00 E 1000.00 996.73 858.73 27.19 S 41.38 E 2000.00 1889.71 1751.71 396.08 S 257.89 E 3000.00 2489.60 2351.60 1078.39 S 661.20 E 4000.00 2918.12 2780.12 1851.72 S 1127.24 E .00 3.27 3.27 110.29 107.02 510.40 400.12 1081.88 571.47 5000.00 3324.33 3186.33 2636.21 S 1594.57 E 6000.00 3699.77 3561.77 3434.02 S 2064.08 E 7000.00 4129.13 3991.13 4196.73 S 2546.40 E 8000.00 4557.29 4419.29 4989.96 S 2977.48 E 9000.00 4976.03 4838.03 5765.95 S 3448.42 E 1675.67 593.79 2300.23 624.56 2870.87 570.64 3442.71 571.84 4023.97 581.26 10000.00 5471.82 5333.82 6510.36 S 3893.89 E 10641.00 5915.74 5777.74 6898.22 S 4142.73 E 4528.18 504.21 4725.26 197.08 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. tY-SLrN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. KUPARUK RIVER UNIT / 2F-19 500292272800 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 012397 JOB NUMBER: AK-MM-70013 KELLY BUSHING ELEV. = 138.00 OPERATOR: ARCO ALASKA, INC. FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GUL~%R COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -138.00 38.00 38.00 -100.00 138.00 138.00 .00 238.00 238.00 100.00 338.00 338.00 200.00 .00 N .00 E .0 .00 N .00 E .0 .00 N .00 E .0 .15 N .11 W .0 .58 N .43 W .0 .00 .00 .00 .00 438.01 438.00 300.00 538.04 538.00 400.00 638.13 638.00 500.00 738.34 738.00 600.00 '-838.93 838.00 700.00 .06 S .37 1.38 S 1.91 2.50 S 5.87 4.07 S 11.93 8.74 S 21.64 .0 .0 .1 .3 .9 .01 .02 .09 .21 .59 940.19 938.00 800.00 1042.19 1038.00 900.00 1145.29 1138.00 1000.00 1250.09 1238.00 1100.00 1356.84 1338.00 1200.00 18.92 S 33.74 33.91 S 46.99 53.59 S 62.45 80.14 S 79.01 113.56 S 95.56 2.1 4.1 7.2 12.0 18.8 1.26 2.00 3 .10 4.80 6.75 1466.33 1438.00 1300.00 1577.97 1538.00 1400.00 1692.32 1638.00 1500.00 1810.54 1738.00 1600.00 1933.81 1838.00 1700.00 153.08 S 116.05 196.41 S 140.25 244.75 S 167.35 299.29 S 198.90 361.03 S 236.04 28.3 39.9 54.3 72.5 95.8 9.48 11.65 14.35 18.22 23.27 2064.16 1938.00 1800.00 2206.01 2038.00 1900.00 2358.72 2138.00 2000.00 2517.59 2238.00 2100.00 2696.68 2338.00 2200.00 432.20 S 279.80 517.97 S 332.24 615.79 S 393.45 723.40 S 453.84 852.52 S 527.10 126.1 168.0 220.7 279.5 358.6 30.36 41.85 52.71 58.86 79.09 2894.43 2438.00 2300.00 3101.94 2538.00 2400.00 3325.04 2638.00 2500.00 3556.21 ~2738.00 2600.00 3808.56 2838.00 2700.00 999.36 S 613.90 1155.36 S 707.22 1326.98 S 808.81 1507.83 S 912.38 1704.'10 S 1035.44 456.4 563.9 687.0 818.2 970.5 97.75 107.50 123.10 131.17 152.35 4046.68 2938.00 2800.00 4284.27 3038.00 2900.00 4522.48 3138.00 3000.00 4762.64 3238.00 3100.00 5041.54 3338.00 3200.00 1887.66 S 1149.43 2071.58 S 1261.78 2256.10 S 1374.45 2442.45 S 1488.20 2671.10 S 1612.48 1108.6 1246.2 1384.4 1524.6 1703.5 138 . 12 137.59 138 .21 140. 16 178.90 SUN DRILLING SERVICES A/qCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 2F-19 500292272800 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/25/97 DATE OF SURVEY: 012397 JOB NUMBER: AK-MM-70013 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA, INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5333.43 3438.00 3300.00 2910.90 S 1745.40 E 1895.43 191.89 5608.95 3538.00 3400.00 3132.66 S 1874.72 E 2070.95 175.52 5857.08 3638.00 3500.00 3325.09 S 1995.19 E 2219.08 148.13 6092.32 3738.00 3600.00 3505.53 S 2108.21 E 2354.32 135.24 6345.33 3838.00 3700.00 3704.88 S 2227.65 E 2507.33 153.02 6566.73 3938.00 3800.00 3871.99 S 2332.87 E 2628.73 121.39 6797.78 4038.00 3900.00 4044.51 S 2449.53 E 2759.78 131.06 7018.31 4138.00 4000.00 4210.58 S 2554.47 E 2880.31 120.53 7228.21 4238.00 4100.00 4372.99 S 2641.98 E 2990.21 109.90 7464.58 4338.00 4200.00 4565.02 S 2736.75 E 3126.58 136.36 7710.81 4438.00 4300.00 4762.37 S 2844.81 E 3272.81 146.24 7953.36 4538.00 4400.00 4953.32 S 2956.01 E 3415.36 142.55 8200.08 4638.00 4500.00 5146.84 S 3071.84 E 3562.08 146.72 8440.28 4738.00 4600.00 5331.42 S 3188.49 E 3702.28 140.20 8681.45 4838.00 4700.00 5517.70 S 3304.38 E 3843.45 141.16 8916.98 4938.00 4800.00 5701.81 S 3411.93 E 3978.98 135.53 9133.05 5038.00 4900.00 5868.42 S 3506.41 E 4095.05 116.07 9339.41 5138.00 5000.00 6025.57 S 3595.21 E 4201.41 106.36 9542.78 5238.00 5100.00 6177.48 S 3686.16 E 4304.78 103.37 9748.49 5338.00 5200.00 6330.67 S 3780.23 E 4410.49 105.72 9942.42 5438.00 5300.00 6470.80 S 3869.28 E 4504.42 93.93 10105.86 5538.00 5400.00 6581.03 S 3936.68 E 4567.86 63.44 10256.61 5638.00 5500.00 6677.59 S 3994.92 E 4618.61 50.74 10398.02 5738.00 5600.00 6761.38 S 4049.37 E 4660.02 41.42 10534.49 5838.00 5700.00 6838.49 S 4101.12 E 4696.49 36.47 10641.00 5915.74 5777.74 6898.22 S 4142.73 E 4725.26 28.76 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS .. WELL LOG TRANSNHTTAL To: State of Alaska July 14, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2F-19 PB1, AK-MM-70013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2F-19 PBI: 2"x 5" MD Gamma Ray Logs: 50-029-22728-70 2" x 5" TVD Gamma Ray Logs: 50-029-22728-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia __ 5631 Silverado Way, Suite G · Anchorage, A~aska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company 7/22/97 III IIII I //J GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11171. Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date Ell RF Sepia Floppy Disk lC-06, '~1-02.~ [~A.~¢__.. WATER INJECTION PROFILE 970422 I I ,, 1H-1 c~, .~©O.~ PRODUCTION LOG W/DEFT 970423 1 1 2 F- 19 ~f¢, '~ © I ., CEMENT MAPPING TOOL 970501 I 1 !2 F-'I 9 ~ CEMENT MAPPING TOOL 970501 I 1 ..... 2Z-01 ...~3 . O-~.._% .. TDTWATER FLOW LOG .. 970331 I I ..... 2 Z- 1 3 ~ ::::% ' I ©Lc WATER FLOW LOG 9 7 0 41 9 I 1 .... 3 B- 13 ':¢ ~' (J~ ~ .~ PRODUCTION pROFILE 97041 0 I 1 3H-07 .~'~ , ~..~ L.,k\,f~ INJECTION PROFILE 970424 I 1 3K-22 ~"'( · Of..o Lo (¢L~ ¢._ CEMENT MAPPING TOOL 970509 I 1 3 K- 27 ~ "7' O ~ f'¢ 4~ CEMENT MAPPING TOOL 970508 I 1 3K-32 (--~"-) ' L.b'-7 (.~ '"[ ! CEMENT BOND LOG 970527 1 1 · Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: RL (.;EiVEI9 JUt,, 5 'i997 7/24/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11182 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk .' 1 A- 25 "~ © I L~"~" PRODUCTioN' PROFILE W/DEFT 970609 I 1 " ,, 2F-19 ~... To t CEMENT BOND LOG 970605 I 1 .... 03C-03 ':~<.% · 1%~ GAS LIFT SURVEY 97061 2 I 1 .. , 3C-6... ~q-~q % GAS LIFT SURVEY 970612 I I ,.. 3F..-04 ~, ~ ~ ,l~..~ INJECTION PROFILE 970620 I 1 3F-12 ~:~'~, ~ ~ L~I(~ INJECTION PROFILE 97061 9 I 1 03G-08 ~O, ~% GAS LIFT SURVEY 970613 I 1 03G-11 c~.. O~ ~ GAS LIFT SURVEY 970613 I 1 3G-22 ~O, Iq~ GAS LIFT SURVEY 970616 I 1 3H-23A ~©, I ?~';J~ (~1(% GAS LIFT SURVEY 970616 I 1 ,., 31-17 ~q, ©~/~ GAS LIFT SURVEY 970618 I 1 3N-9 '~L~ ,0.~ GAS LIFT SURVEY 97061 8 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Ci I::~ I I_,1_ I IM 1~ S E l:tb'l r' E S WELL LOG TRANSNHTTAL To: State of Alaska July 23, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. ..~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - B-12A, AK-MW-70079 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20332-01. .. ~ 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 - A Dresser Industries, Inc. Company 7/17/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11158 Company: Field: Alaska Oil & Gas Cons Comm Attn- Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ., Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2F-19PB1 c~.- ~ t ~7'7L/~'~'~ 97146 ..BITE & CNTG 970330 1 2F-19PB1 97146 BITE 970330 I 1 2F-19PB1 97146 CNTG 970330 1 1 2F-19PB1 971 46 BOREHOLE PROFILE LOG 970330 1 1 ............... 2F-19PB1 ~,,r 97146 SSTVD 970330 1 1 31~-3"5 ' q:?-'lc)'~'~ ". '-~?'~-/L( 97307 DITE-GR(PDC) ... 970713 .. 1 3K-35 ,~,,~ 97307 BITE-GE 97071 3 1 1 ...... SIGNED' ~_-~~. DATE: JUL 18 199~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 7/15/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11146 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk ~ (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 2F.19 ~'(,°. ~Oi --~(~'~-"] 97279 PDCGR 970605 ... 1 , ...... ., .,. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUL 0 I::! I I__/I I~J I~ S G I::l~J I i-- E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 _Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 2, 1997 2F-19 PB1, AK-MM-70013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention Of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22728-70 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 - A Dresser Industries, Inc. Company June 19, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 2F-19~' Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2F-19A Tie in point 10,175.00', window point 10,260.00', interpolated depth at 11,152.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation Shutdown__ Re-enter suspended well ~ Plugging_ Time extension Stimulate Pull tubing_ Variance_ Perforate _ Other __ 6. Datum elevation (DF or KB) Abandon Suspend Alter casing _ Repair well _ Change approved program _ 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 68' FNL, 1749' FEL, Sec. 33, T11N, RgE, UM At top of productive interval 1800' FNL, 2517' FWL, Sec. 3, T10N, RgE, UM At effective depth At total depth 1965' FNL, 2616' FWL, Sec. 3, T10N, R9E, UM 1 0871' feet Plugs (measured) 12. Present well condition summary Total Depth: measured (approx) true vertical Rig RKB 32', Pad 97' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-19 9. Permit number 96-201 10. APl number 50-029-22728 11. Field/Pool Kuparuk River Field/Oil Pool 6076' feet 5.5" retainer set at 10500' with 15 bbls 15.8 class G squeezed below and 1.5 bbls dumped on top. Plug from 10871' - 10450'. Effective depth: measured (approx) true vertical 10450' feet Junk (measured) 5 7 5 6' feet None Casing Structural Conductor Surface Intermediate Production Liner Length 80' 4590' 10514' Size 16" 7-5/8" 5.5" Cemented Measured depth 260SxAS I 112' 261 Sx ASLW 4702' 1220 Sx Class G/60 Sx AS I 100 Sx Class G 10626' True vertical depth 112' 3209' 5904' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal ~ Contact William S. Isaacson @ 263-4622 with questions. 14. Estimated date for commencing operation 5/14/97 X Detailed operation program__ 16. If proposal was verbally approved Name of approver Date approved BOP sketch 15. Status of well classification as: Oil Gas Suspended X Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed L~'~ ~. ~ .... Title Drilling Engineer FOR COMMISSION USE ONLY Date ~" '" I'Z, ,- q~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signee i3~wirt W .Inhn.~tnn . ,,,~ommissioner SUBMIT IN TRIPLICATE KRU 2F-19 GENERAL SIDETRACK PROCEDURE 1. MIRU Nordic Rig #2. Verify well is dead. 2. ND tree. NU and test BOPE. 3. RU E-line unit. Run gauge ring through bridge plug setting depth. RIH and set permanent bridge plug at 10,281' MD-RKB. 4. MU and RIH with bottom trip whipstock and window milling assembly. Tag bridge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 5-1/2" casing from +/-10,261' to 10,271'. POOH LD milling assembly. 5. RIH w/4-3/4" bit, mud motor, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. t,,tora=: rt~,,; ~ r- ,~ .fi, .v~,,,,,_ ~,e,]! [o,.,~P,~,,~. 6. Run 3-1/2" liner to TD w/200' of overiap to top of milled window. 7. Cement liner. Set liner top packer. POOH w/DP. 8. Pressure test casing and liner lap to 3500 psi for state test. 9. RIH w/completion assembly and latch tubing anchor into liner top packer. Shear out PBR and space out. Displace well to sea water at max rate. Freeze protect well with diesel. Test tubing and annulus. 10. ND BOPE. NU and test tree. RDMO Nordic Rig. 11. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 9.0 days Expected Case: 11.0 days Upper Limit: 14.0 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window or drilling new hole. WSI 5/9/97 Created by jones I . Dote plotted: g-May--97 Plot R~erence is 19A Version ~14. J Coordinates are in feet re~erenc~ slot t~19A. True Vertical Depths~e RKB (Nordic ~11). ARC0 ALASKA, Inc. Structure : Pad 2F Well: 19A Field : Kuparuk River Unit Location : N6Hh Slope, Alaska WELL PROFILE DATA Point ..... MD Inc Dir TV[] No~h East V. SectDe(3/1 O0 KOP 10261.00 46.91 148.02 5658.36-6686.23 4000.17 6620.46 0.00 End of Build/Turn 10628.00 56.34 117.29 5869.51-6873.07 4210.42 6892.97 7.00 Target 2F-lgA (T/Kup) 10925.11 56.34 117.29 6054.00-6986.44 ¢450.18 7140.26 0.00 End of Hold 11204.74 56.54 117.29 6189.00-7093.15 4657.02 7.375.00 0.00 T.D. & End of Hold 11404.74 56.54 117.29 6299.66-7169.47 4784.95 7559.4.6 0.00 East (feet) -> 3800 3900 4000 4100 4200 - 4300 4400 4500 4600 4700 4800 4900 5000 5100 6400 650O 117.29 AZIMUTH 7140' {TO TARGET) Estimated KOP 5300 55O0 5600 5700 (D 5800 ~ 5900 0 > 6000 I--- 6100 I ¥ 6200 63O0 6400 65O0 Estimated KOP 47.50 Eec 49.50 DLS: 7.00 deg per 100 ft 52.16 55.36 Eec TARGET - T./.Kup. Sends 2F-19A (T,/.K. up) Rvsd 9-May-97 Top um[ ~ Top Unit A4 Bose Kup Sends 6600 MAXIMUM ANGLE 56.34 DEG t 9, ' ~COr_T~C~ TARGET- T/ Kup Sends Top Unit A Top Unit A4 67OO 6800 6900 7000 I V 7100 720O 7300 I I I I I I I I I I I I I I I ] I I I I II I I I I I I I 6300 6400 6500 6600 6700 6800 6900 7000 71 O0 7200 7500 7400 7500 7600 7700 Vertical Section (feet) -> Azimuth 117.29 with reference 0.00 N, 0.00 E from slot #19A Base Kup Sands ;..':;,.ir "~.-;~L,. I, : ,-' ,. [.j..~ !. , . TD ~0~0 ~ 1~ ~-~i"-., 7400 2F-19 Proposed Completion ** All Depths are reference Nordic 2 RKB Liner Top Packer @ +/-10,110' Window from +/-10,261' to 10,271' Bridge Plug @ +/-10,281' Top Cement Plug @ +/-10,440' Retainer @ +/-10,500' 5.5" 15,5# L-80 @ 10,626' MD Nordic RKB Sidetrack 4-3/4" open hole section with TD @ 10,871' MD Original 4-3/4" open hole section with TD @ 11,1 91' MD 3-1/.2" Liner set at +/-11,405' MD WSI 5/1/97 SI'ATEOF~ ,~ .~A OILAND ~ CONSERVATION APPLICATION FOR SUNDRY APPROVALS £, LI 0 1. Type e[ Request: Name of Operator A[::[C_O Alaska. Inc. ~. Address P. O. Box 100360,,A,n,c, horage, AK: 99510 4. Location of well at surface 68' FNL, 1749' FEL, Sec. 33, T11N, RSE, UM At top of productive Intew~l 1800' FNL, 2517' FWL, Sec. 3, T10N, FISE, UM At effective depth Abandon_ Suspend Alter casing _ Repair well _ Change approved program_ P_u!!' !.ubing ............. '5. Type of Well: Development Exploratory _ ,Stratlgraphic _ Service At total depth 1965' FNLr 2616' FWL~ Sec. 3r T10N~ RSE~ UM · ~2. Pre,ant well condition sumrr~ry Total Depth: measured 10871 ' feet (approx) true vertical 6 0 7 6' fa at Variance Operation Shutdown__ Re-enter suspended well _ Plugging ~ Time extension Stimulate _ Pedorate _ Other __ 6. Datum elevation (DF or KB) · Rig RKB 32'. Pad 97' _._ ?, Unit or Property name Kuparuk River Unit _ .. 8. Well number 2E-19 9. Permit number 86-201 lo. APl number .... 50-029-R2_,7_~_~ .......... '1 !. Field/Pool feet __ ..K. uD.aruk River Field/Oil Pool Plugs (measured) ff,.5" retainer set at 10500' with 15 bbls 15.8 class G squeezed below and 1.5 bbls dumped on top. Plug Imm 10871' - 10450'. Effective deplh: measured (approx) true vertical 10450' feat Junk (measured) 5756' feet None Caring Length Size Structural Conductor 8 O' 1 co" Su~ce 4590' 7-5/8" Intermediate Production ..... Lin_er Perforation deplh: 10514' measured None true vertical Tubing (size, grade, and measured depth) None Packem and SSSV (b'pe and measured depth) None Cemented Measured deplh True vertical depth 260 SX AS I 1 1 2' 261 Sx ASLW 4702' 1220 Sx Class G/60 Sx AS I 100 Sx Class G t 0626' 112' 3209' 5904' RECEJV .D 13. Attachments Description summary of proposal ~ Detailed operation program __ BOP sketch __ 14. Eslimated date [or commencing operation 115. Status of well classification as: 4/21/97 ...... I Oil ~ Gas _ Suspended 16. If proposal was verbally approved Blair Wondzell 4/21/97 Name of approver Date approved .... ,, Service 17. I hereby ~erfify tha~ the foregoing is true and correct to the best of my knowledge. Signed ~--~"~' ]~' ~,'----'.-.-. Title Drillin~ En,~ineer Date t'l J Z'~/fl'Jr- FOR COMMISSION USE ONLY Conditions of approval: No~l...fy Commission so representative may witness Plug Integrlly~ BOP Test ~-/'Locafion clearance IApprova[' ~No..~ '" Mechanical Integrity Test _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Subsequent form require lO- David W. Johnston Commissioner Date ................... SU MIT Approved Copy Apr. 23. 1997 9'U'fAM AF~CO ALAS[~A i[4C ~'40. DLD~ · 2F-19 t-,agback and Current We, Status ~, 3/'3 '* All Depths ere reference Nordic 2 RKB Diesel from 2100' to surface Sea water to 2100' MD 15.8 ppg Class G Cement plug placed on top of retainer up to 10,440' MD. Retainer @ +/-10,500' 15.8 ppg Class G Cement downsqueezed below retainer with 100% excess of open hole volume. 5.5" 15.5# L-80 @ 10,626' MD Nordic RKB 17.0 ppg Class G Cement plug from 10,690' MD up into 5-1/2" casing Sidetrack 4-3/4" open hole section with 'ID @ 10,871' MD Original 4-3/4' open hole section with TD @ 11,191' MD WSI 2/23/97 Apr, ~. 199'f ~'USAM A~CO ALASKA l~C ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaeka 99510-0360 Telephon$ 907 27; 1215 April 23, 1997 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK g9501 (907) 27g-1433 (907) 276-7542 (fax) Re.' Application for Sundry Approvals on KRU Well 2F-19 Gentlemen: Enclosed is the Application for Sund~ Approvals for the plug back and suspension of.operations on KRU well 2F-19. The request for suspension was verbally approved on 4/21/97 and all operations were completed on 4/2.3/97, Included with the application is a schematic of the planned plug back and suspended well status. Well 2F-19 was a planned tOP set of the Kuparuk due to high reservoir pressure at the bottom hole location. In January of this year, Parker 245 set 5.1/2" intermediate casing and then moved off the well. Nordic Rig 2 moved on the well March 26th and ddlled 4-3/4" hole to a TD of 11,191' MD, After several days of well control problems and two attempts to run the 3-1/2" liner, the hole conditi~ deteriorated dramatically and it became necessary to plug back the well. A cement plug was placed from the maximum reachable open hole depth up into the 5-1/2" casing, and an open hole sidetrack was done immediately below the 5-1/2" shoe. The sidetrack was planned to get away from the original wellbore while targeting the same bottom hole location, The sidetrack was drilled to a depth of 10,871' MD, at which time hole conditions once again became a problem. Several attempts to reclaim the open hole interval were unsuccessful and eventually the decision was made to plug back the well. A cement retain, er was set +/-125' above the 5-1/2" casing shoe and cement was down-squeezed below the retaIner. A 60' cement plug was also placed on top of the retainer and the wellbore tested for integrity. The well will remain in this condition until a plan is developed as to which direction to proceeo. you have any questions or require any additional information on this matter, please contact me at 263-4622. Sincerely, William S, Isaacson Drilling Engineer Kuparuk Drill Site Development REEEJV. ED ARCO AlUl~ Inc, is a Subsidiao' o[ AtlanlicRlchfleldCompany WELL LOG TRANSNHIWAL To: State of Alaska Alaska Oil and Gas Conservation Cormn. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 Ap~ 16,1997 RE: MWD Formation Evaluation Logs DS 2F-19, AK-MM-70013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 2F-19: 2" x 5" MD Gamma Ray Logs: 50-029-22728-00 2" x 5" TVD Gamma Ray Logs: 50-029-22728-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:i I I--I--I ~ G February 27, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 2F- 19 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2F-19 Tie in point 0.00' and interpolated depth at 10,641.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. RECEIVED MAR 05 1997 ~ & Cas Cons. Commlselm 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company AF, (JO ALAS~(A STATEOF~ ~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Typ~ ~f Request: Abandon Alter oaring _ Change approved pr,o,g,m_m__ 2. Name of Operator Suspend _ Operation Shutdown_ Re.enter suspended well _ Repair well Plugging _ Time extension _ Stimulate _ Perforate Other 6, Datum elavation (DF or KB) Pull tubing_ Variance Type For- Well: Development Exploratory _ Stratigraphic _ Service ~,~;2_Alas ks. Inc. :~. Addre~s P. O. Box 100360, Anchorage, AK 99510 --. Location or well at surface 68' FNL, 1749' FEL, Sec. 33, T11N, RgE, UM At top o! productive intewal 1800' FNL, 2517' FWL, Sec. 3, T10N, RgE, UM (planned) At effective depth At total depth 1965' FN, L.~. 26_16' FWLr Sec. 3~ TlON, RgEr UM (planned) 12. Present well co~dition summary Total Depth: measured 10641 ' feet Plugs None true vertical 59164 feet _ Rig RKB ~41'_.Pad level 45'. _test 7, Unit or Properbj name K~uparuk River Unit 8. Well number 2F-19 g. Permit n~mber-' ~6-201 10, APl number 50.0 2 9 - 2 2 7.2.8 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 10552' feet Junk None true vertical 5852' feat 13. Ca~ing Structural Conductor Surface Intermediate Production Liner Perforation dap{h: Length Size Cemented 8 0' 1 6" 250 Sx AS I 4590' 9-5/8" See Detail Sheet 10514' 5-1/2" 100SxClassG measured true vertical Tubing (size, grade, and measured depth Nc~e Packers and SSSV (b/pa end measured depth) None Attachments Measured depth True vertical depth 121' 121' 4711' 3218' 10635' 5913' ORIGINAL Description summary of proposal X Detailed operation program_ BOP sketch 14_ Estimated date for commencing operation ..... 1/30/97. _.w_ith appr0v~l 16. If proposal was verbally approved Name of approver Date approved 15. Status et well classification as: Oil ~ Gas _ Service Suspended 7. I~hej'e_~ certify ~hat the .[o. regoing Signs d"',~.~'~~ _ ~_.., is true and correct to the bast ol' my knowledge. Title -~r! .... ~--- ....., FOR COMMISSION USE ONLY Date Condition,,~ of approval: Notify Commission so representative may witness Plug integrity ~ I;tOP Test_ Location clearance Mechanical Integrity Test_ Subsequent form require lO. Original Signea Approved by' the order of Ihs Commission David W. Johnston Form 10-403 Rev 06/15/88 Commissioner $1J~'lT 'i~ T~tlP[ICATE Approved Copy ~Retu~led Jan, -- ANNULAR PUMPING OPERATIONS WELL KRU 2F-19 It is requested that 2F-19 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this application, Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 2F surface casing shoes will be set _+200' vertical below the base / ,,.~ of the West Sak into the heart of the shales, /¢ The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure --- (12.0 ppg) ' (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3500 psi This calculation is very conservative, as no frictional losses have been included. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-e0 3 LTC 4790......... ;~072 6'890" ' ..... ~ - 5.500 '!"~'.~5' L-80 3 LTC-M 49904242 7000 5950' Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). RECEIVED JAN 29 1997 Alaska 0il & ~a.~ Con~. Go~limssmr~ Anchorage Jan. 29. i997 2'56PM ~o. 43UU ~. 4/0 ARCO ALAS~[A II~C ARCO ALASKA, Znc. Pad 2F 19 9Lot #19 K~q~ruk R~ver Unit North SLope, ALaska 3-D H Z # [ NU# D [ $ TAN CE C L E A R A N C E R E P O R T by BakeP Hughes INTEO Tour ref : 19 Versfon ~ Our Per : prop16~9 License ~ RECEIVED .te .JAN 29 1997 Date created ; 14-~un-96 Last revised .' lO-Dec-96 Alaska Oil & Gas Cons. ~j$,~j~Ol~ FieLd is centred on n70 16 Structure Js cen~r~ on SLot Location is n70 16 16.788,~t~9 5¶ $0.995 Stat Grid coordinates are N 59AB81t.tOA~ E 5IT&82.&2& SLot Local coordinates are 6~.00 S 1769.00 Project,on type{ alaska - ~ore &, Spheroid~ CLarke - 1866 Reference North Js True North Report ~s Limited to clearances Less than SOO feet DECREASING CLEARANCES of Less than 1000 feet are indicated by an asterisk~ e.g. ~8?,G' Object veL Lpath CLosest approach with 3-D Nin{~O{stance method Last revtsed Distance N,D, D{verging frc~n#,O, PGNS <O-?820'>,,12,pad 2F 4-Feb-92 $40,7 440,0 2725,0 P~$ <O-8452'>,,14,Pad 2F G-Feb-92 1:S6.0 20.0 ~160.0 PGI~$ <0-7837~>,,13,Ped 2F ~-Feb-9~ 195.8 ~0,0 20,0 P~S <0-~50'>,,15,P~ ZF ~-Feb-92 ~.0 1250.0 1250.0 P~S <0-7425'>,,16,P~ ~F G-Feb-92 1~,~ 9~5,0 925,0 P~ <0-6920~>,,1,P~ 2F G-Feb-92 5~,~ ~0.0 20.0 ~ <0-7630,>,,~,p~ ~F ~-Feb-gZ 5~.~ 360.0 5~.0 P~S <O-80~'>,,3,P~ 2F ~-Feb-92 653,8 20,0 20.0 PONS <0-8050'>,,G,P~ ~F q-Feb-gZ 71~.7 20.0 20.0 P~S <O-9470'>,,6,Pmd 2F 4-Feb-gz 712,5 ~0.0 20.0 PGN$ <O-90~'>,,7, P~d 2F G-Feb-92 657.B 20.0 20.0 P~S <O-6]~'>,,~,Ped 2F ~-Feb-92 602.9 B50.O 850.0 P~S ~0-872~'~,,10,P~ 2F ~-Feb-gZ ~89,~ ~00,0 ~00,0 P~S <0-101~>,,11,P~F 4-Feb-92 ~11.4 ZO.O 240.0 PO~ <O-~'>,,5~P~ 2F &-Feb-92 ~.1 BSO,O 8~0,0 17 Vets{an ~7,,17, P~ 2F 9-0eC-96 58,6 900.~ 900.~ Jan, 2~. !~'f 2'5?PM ARCO ALAS~;A II~C ~o. 4~U ~. b/0 -- ARCO Alaska, Inc. Well#; Casing Size 7 5/8" Centralizers 2F-19 Hole Diameter 9.875" Field; Hole Angle Cementin~ Details KUPARUK I Date; 01/22197 Shoe Depth'I Float Depth I % washout .4.,7_ lJ.~.___l.. I 65° 4T582' State .type used, intervals covered and spacing 46 Gernco centralizers. Jts # 1 - 44 and on either side of ES cementer Mud Weight YP(prior cond) YP(afler cond) I PV(prlor cond) PV(after cond) 9,7/g,$ 22 lbs/100 ,2 18 lbs/100 ft21 25 cP 20 cP Gels before Gels after Total Volume Circulated 9/22 6/1 4 400 bbls Spacer Type Volume Weight Water 40/20 8.3 PPG Lead Type lMix wtr temp No. of sacks Weight Yield Cement iASLW J 70 70/1 91 10.5/1 0,5 4.41 STAGE 1/2 Additives Tall Cement ',STAGE 1/2 Displacement G + 3.5% DO44, .6% DO46, 30% D53, 1.5~./~ D.C. 7, .% 50% D124, 1.5% SOO1 G/AS 1 70 1220/60 15.8/15.8 1.15/0.93 STAGE 1' G r 2.66% DO29, .2% DO46T .3% DO65r 1.5% SOO1 STAGE 2: ASI !Rate(before tail at shoe) 8 'R~ciprocation length 10 Theoretical Displacement 210/67 Rate(tail around shoe) 8 Reciprocation speed _fpr. Actual Displacement 21 5/67 STAGE 1/2 Calculated top of cement I CIP 11/26/96 Bumped plug IFioats held ~ 1600'/s u dace 1 1 S:00/1 ?:00 yes/yes[ yes/y es Remarks: Include whether full returns were obtained, reciprocation throughout 01~_rat!0n and any other, pertinent Information. ~ta~e 1: Reciprocated c$~i until cement rounded shoe. Stuck pipe, Had full returns through out job Str, WI, Up 175 Str. Wt. Dh. 135 Slr. Wt. Mud Stage 2: Press csg to 3100 psi to open cementer. Circ 300 bbls mud w/full returns. Had cement contaminated returns at bottoms up. Pumped 2nd sta~e lead and tail slurries w/ 100% returns through out entire job._ pv~ ~,~' . Had cement to surface w/150 bbls lead pumped. Switched to tail slurry_. Displaced w/rig pumps. Closed cementer w/ 1250 psi, Cement Company iRig Contractor Parker ISignature Donald Lutrick Doweil .Jan. 29. 1997 r,lo. 4~U 2'57FM ARCO ALASKA iNC CASING AND LEAK-OF_F_FRACTURE TESTS Well Name: KRU 2F-19 Supervisor: Donald Lutrick Date: 1/23/97 Casing Size and Description: 7 ~8"r 29,7#~ L-80r BTC Casing Setting Depth: 471 1' TMD 3218' TVD Mud Weight: 8.4 ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT= 730psi/(0.O52x,3218ft)~ 8,4ppg = 12.76ppg Fluid Pumped -- .8.~ bbls. Hole Depth (md)= 4748' Pump output = .085 bps 2100 2000 t900 18oo 170o 16oo 15oo 1400 1300 1200 1100 1000 900 800 7oo 600 Boo 400 300 2o0 lOO o o 2 4 6 8 lO 12 14 16 11~ 20 22 2.4 26 2B 30 32 34 36 38 40 42 4d 46 48 50 52 54 58 68 so STROKES D Jan. 29, i997 2'56PM ARCO ALASKA iNC -. ARCO Alaska, Inc. .ji- FACSIMILE __TRANSMISSION )ate: ~.: 7~¢>-~q -rime: ,lumber of Pages (Cover +): - From: c+~ Phone: Location: I I I.lll Iii Location: /x. CS~-~CG .__ I{~._.C. opies To: !llllll l.~'l I! l'": Ii,,,,.., ORIgINaL Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 · ATO-1209 ___ jlll---- _-- -- FAX #: Phone #: Subject: Comments: RECEIVED JAN ~ 1~i' Alaska 011 & Ba~ Con~. Commission Anchorage ARCO Alaska, Inc. Post Office 13;., .00360 Anchorage, Alaska 99510-0360 Telephone 907 278 1215 January 14, 1997 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 STAT ~rEC Subject: Change to casing program on KRU Wells 2F-17 and 2F-19 Dear Mr. Johnston: [ !. This letter is to inform the Commission that ARCO Alaska, Inc., is planning totFiLE , alter the casing program approved in the Permits to Drill for 2F-17 (permit #96- 204) and 2F-19 (96'201). We have decided to topset the Kuparuk in both wells(,,.~.~_ due to the unexpectedly high reservoir pressure seen in offset Well 2F-18. The new casing programs will be: Well Casing Length Top MD Top TVD Btm MD Btm TVD 2F-17 5-1/2" 8984' 41' 41' 9025'. 5909' 3-1/2" 691' 8875' 5808' 9566' 6317' 2F-19 5-1/2" 10630' 41' 41' 10671' 5865' 3-1/2" 674' 10521' 5765' 11195' 6260' 5-1/2" casing is the standard 15.5# L-80 LTC Modified set in a 6-3/4" hole size. The 3-1/2" liners are 9.3# L-80 EUE 8rd Modified set in a 4-3/4" hole size. Both liners will be cemented with +75 sx of Class G to bring cement into the liner lap. If you have any questions on the information, please contact me at 263-4183. Sincerely, Denise Pet'rash Drilling Engineer cc: Blair Wondzell AOGCC Gas Cons. ARSB-6003-93 2,':2-2603 TONY KNOWLES, GOVERNOR ALASKA_ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 27, 1996 Michael Zanghi, Drill Site Develop Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2F-19 ARCO Alaska Inc 96-201 68'FNL, 1749'FEL, Sec. 33, T11N, R9E, UM 1965'FNL, 2616'FWL, Sec 03, T10N, R9E, UM Dear Mr Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize condUcting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission at 279-1433. Sincerely, Tuckerman Babcock Commissioner BY ORDER OF THE COMMISSION dlffencl c: Dept ofFish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl · STATE OF ALASKA ' ALAbr,,A OIL AND GAS CONSERVATION COMMISS,uN PERMIT TO DRILL 20 AAC 25.005 ,a. Typo of Work Drill X Redrill m-1 lb Typo of Well Exploratory m-! Stratigraphic Test D Development Oil Re-Entry m-1 Deepen [] Service X Development Gas m-1 Single Zone X Multiple Zone m-] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 97' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25666, ALK 2587 4. Location of well at surface 7, Unit or property Name 1 I. Type Bond (see 20 AAC 25.025) 68' FNL, 1749' FEL, Sec. 33, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1800' FNL, 2517' FWL, Sec. 3, T10N, R9E, UM 2F-19 #U-630610 At total depth 9. Approximate spud date Amount 1965' FNL, 2616' FWL, Sec. 3, T10N, R9E, UM 1/09/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2F-1 6 11195' MD 1800 ~ TD feet 12.3' ~b 925' feet 2560 6260' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 65.5° Maximum surface 1907 psig At total depth (TVD) 3175 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~) Weight Grade Coupling Length MD TVD MD TVD linclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 4660' 41' 41' 4701' 3221' 1220 Sx Arcticset III & HF-ERW 640 Sx Class G 6.75" 4.5" 12.6# L-80 NSCT 11154 41' 41' 11195' 6260' 240SxClassG Top 1000' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: trmueeaSvUerre~cal ;::: Plugs (measured) 0 Ri GIN A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRE¢£1 Intermediate Production LinerDEC 2 $ 1996 Perforation depth: measured true vertical & Gas Cons. 20, Attachments Filing fee X Property plat J-J BOPSketch X Diverter Sketch X J~#'~rilling program X Drilling fluid program X Time vs depth plot D Refraction analysis [~] Seabed report J~l 20 AAC 25.050 requirements X 21. I hereby certify that the oregoin is true and correct to the best of my knowledge Signed ~'~/~~~:). _ CommissionTitleuse Only Drill Site Develop. Supv. Date I'-'Z--"~ F Perm, j,t, Number I APfnu~ IAppr°val dat?c,~ ~r~ ?-' ~'~.., J See cover letter for 1 5 o- 0 ~__ ~' - ~ ~.. 7 .~ ~ other rec]uirements Conditions of~-approval Samples required [] Yes [~ No Mud Icg required [] Yes ~ No Hydrogen sulfide measures ~J~ Yes D No Directional survey required [] Yes [-~ No Required working pressure for BOPE J--1 2M [] 3M D 5M ~ 10M r'1 15M Other: "")r!gJ~')ai: lgF)ed By by order of · Approved by ~UO~<~,~ll~n ~ok~.~. Commissioner the commission Date Fnrm 1¢)-~.B1 Rnv 7-24-R¢i ~ .q~lhmit in trinlinntn GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2F-1 9 , . , , , , . . . Note: 10. 11. Note: 12. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,701')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test or 16 ppg EMW formation integrity test, whichever is lower. Drill 6-3/4" hole to total depth (11,195') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" Iongstring. Space out as needed to land the hanger and place the external casing packer at the surface casing shoe. The cementing program is designed to reach 1000' above the top of the Kuparuk. If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Set external casing packer at surface casing shoe. Pressure test to ensure seal. Freeze protect annulus through sliding sleeve above packer. ND B©PE and install production tree. As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. Shut in and secure well. Clean location and RDM© in preparation for coiled tubing cleanout and perforating. DRILLING FLUID PROGRAM Well KRU 2F-19 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 5O-8O* 5-15 1 5-40 10-12 9.5-10 _+10% Drill out to weic.) ht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1907 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2F-19 is 2F-16. As designed, the minimum distance between the two wells would be 12.3' @ 925' MD. Drilling Area Risks: Risks in the 2F-19 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 4-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 3-3/4" hole, and run a 3-1/2" FJ or 2-7/8" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be taken to leak-off or tested to a maximum oil 6 ppg EMW upon drilling out of the surfa,~ ~~'V EL. D *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. DEC 2 3 1995 ANNULAR PUMPING OPERATIONS WELL KRU 2F-19 Incidental fluids developed from drilling operations will be pumped down the nearest permitted annulus, or hauled offsite to a permitted disposal well. The tubing will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2F-19 surface/production casing annulus will be filled with diesel after setting the 4-1/2" Iongstring and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons sufficient cement volume will be pumped during the production cement job to cover the formation. 2F-19 will not be permitted for annular pumping as the annular isolation packer does not allow for this operation. ARCO ALASKA, Inc. Pad 2F 19 slot #19 Kuperuk River Unit North Slope, Alaska 3-D MINIMUM D I STANCE CLEARANCE by Baker Hughes INTEG REPORT Your ref : 19 Version ~6 Our ref : prop1659 License : Date printed : 11-Dec-96 Date created : 14-Jun-96 Last revised : 10-0ec-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 50 40.077 Slot location is n70 16 16.788,w149 51 30.995 Slot Grid coordinates are N 5948814.404, E 517482.424 Slot local coordinates are 68.00 S 1749.00 W Projection type: alaska o Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is Limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wetlpath CLosest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <O-7820'>,,12,Pad 2F 4-Feb-92 340.7 440.0 2725.0 PGMS <O-8452'>,,14,Pad 2F 4-Feb-92 136.0 20.0 3160.0 PGMS <O-7837'>,,13,Pad 2F 4-Feb-92 195.8 20.0 20.0 PGMS <O-7550'>,,15,Pad 2F 4-Feb-92 44.0 1250.0 1250.0 PGMS <O-7425'>,,16,Pad 2F 4-Feb-92 12.3 925.0 925.0 PGMS <O-6920'>,,1,Pad 2F 4-Feb-92 534.3 20.0 20.0 PGMS <O-7630'>,,2,Pad 2F 4-Feb-92 593.4 360.0 580.0 PGMS <O-8075'>,,3,Pad 2F 4-Feb-92 653.8 20.0 20.0 PGMS <O-8050'>,,4,Pad 2F 4-Feb-92 713.7 20.0 20.0 PGMS <O-9470'>,,6,Pad 2F 4-Feb-92 712.3 20.0 20.0 PGMS <O-9055'>,,7,Pad 2F 4-Feb-92 657.8 20.0 20.0 PGMS <O-637'5'>,,8,Pad 2F 4-Feb-92 602.9 850.0 850.0 PGMS <O-6560'>,,9,Pad 2F 4-Feb-92 227.7 1477.3 1477.3 PGMS <O-8725'>,,10,Pad 2F 4-Feb-92 289.2 400.0 400.0 PGMS <O-10160'>,,11,Pad 2F 4-Feb-92 311.4 20.0 240.0 PGMS <O-7380'>,,5,Pad 2F 4-Feb-92 763.1 850.0 850.0 17 Version #7,,17,Ped 2F 9-Dec-96 58.6 900.3 900.3 18 (Gold Hills) Vers.~6,,18(GH),Pad 2F 6-Dec-96 210.1 300.0 300.0 ARCO ALASKA, ][nc. Structure : Pad 2F Well: 19 Field : Kuparuk River Unit Location : North Slope, Alaska Greeted by jones For: D PeLrash Dote plotted: lO-Dec-g6 Plot Reference is lg Version C~oro3note~ are in fe~ r~erence slot J19. J T~e Vedlcal Dept~~~ RKB (Pa~er ~245). 1 550 0 550 i i i i i 148.68 Azimuth 8207' (TO TARGET) ***Plane of Proposal*** 7 5/8 Casing 550 55O 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 55, 1100 i East (feet) -> 1650 2200 2750 i i i ii i i 3300 3850 4400 · i i i i i ,oTaraet: ermofrost SURFACE LOCATION: J 68' FNL, 1749' FEL SEC. 33, T11N, RgE Top West Sak Sands Base West Sak Sands (WSIO) Top Tabasco (C80) RKB ELEVATION: 138' ITARGET LOCATION: I 1800' FNL, 2517' FWL SEC. 5, T10N, RgE TARGET TVD= 6030 TMD=10894 DEP=8207 SOUTH 7012 EAST 4266 KOP TVD=700 TMD=700 DEP=O BEGIN TURN TO TRGT -rVD=800 TMD=800 DEP=I 5.19 10.80 DLS: 5.00 deg per 100 ft 16.69 22.65 Est. B/ PERMAFROST TVD=1458 TMD=1455 DEP=130 28.60 34.57 40.56 46.54 52.53 61.52 T/ W SAK SND5 TVD--2453 TMD=2856 DEP=1050 EOC TVD=2485 TMD=2931 DEP=1118 K-5 Begin Angle Drop K-3 (C35) K-2 TARGET / A4 (EOD) 2F- 19(H) Rvsd B/ W SAK SNDS (WSIO) TVD=3021 TMD=4220 DEP=2290 7 5/8" CS(; PT TVD=5221 TUB=4701 DEP=2728 T/ TBSCO (C80) TVD=3454 TMD=5262 BEP=3238 MAXIMUM ANGLE 65.45 I)EG 4950 550 0 55O 1100 1650 2200 2750 3300 3850 4400 495O 5500 6050 6600 7150 7700 0 (- I V J TD LOCATION: I 1965' FNL, 2616' FWL SEC. 3, TION, R9E TARGET ANGLE 40 DEG K-5 (C40) TVD=5023 TMD=9038 DEP=6672 DLS: 2,00 deg per 100 ft BEGIN ANGLE DROP .1-VD=5266 TMD=9622 DEP=7203 63 88 K-3 (C.35) .TVD=5503 TMD=10106 DER=7625 ' ~7 ~ K-2 (C30} TVD=5662 TMD=10571 DEP=7836 .... B/ HRZ (UPP. R KALUEIIK) .TVD=5780 TMD=10550 DEP=7971 ~ 51.88 K-1 (LWR. KALUBIK) .TVD=5865 TMD=10671 OEP=8058 47.88 T/ C SND (C4) TVD=5943 TMD=10779 DEP=8131 43 88 T/ B SNDS (B) TVD=5946 TMD=10783 DEP=8134 ' T/ A SND (A6) TVD=5989 TMD=10840 DEP=8172 TARGET (A4) - EOD TVD=6030 TMD=i0894 DEP=8207 B/ KUP SNDS (MILUVEACH) TVD=6107 TMD=10995 D£P=8272 TD TVD=6260 TMD=11195 DEP=8401 i i i i i i 0 550 11 O0 i i ii i i i i i i ii i ii i iI i i 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 Vertical Section (feet) -> Azimuth 148,S8 with reference 0.00 N, 0.00 E from slot #1g i i i i i i i 7150 7700 8250 8800 True Ve'tlcol Depths a~KB Created b~ j~"~es For: D PeLrash Dote plot'ted: 10-Dec-96, 50 100 150 200 2,.50 300 350 400 450 5OO 55O 600 65O 700 750 800 850 9OO AI CO ALASKA, Inc. Structure : Pad 2F Well: 19 Field : Kuporuk River Unit Location : North Slope, Alaska East (feet) -> 100 50 0 50 1 O0 150 200 250 ,500 350 400 450 500 5§0 600 I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ _~ oo ~o. ~ ~~c5°° ~ ~"~,~ ~oo \ o 11 O0 ~"-~ 500 '",~ 1300 / ~oo "',,,, ~~oo .~oo \"-~ ~o~;" ^ ~. ',, 900 ""~2~oo\"~.- ,; 500'~' ~ 11 O0 "~ 1700 ,,,, ~O~oo ~ ,,,,, -,,, , ~oo/ [ 9°°~ / ~--- ~', .'..i~°° t~oo ~oo ~ ~ ~s,~, ~7oo 1300 i ",\,\\,,,,, 4700 i 1900 550 ~ 1700 ",\, 600 il 500 '\', i '\ 700 ! ' 51 O0 '\,,\ i 1900 750 i 53oo 85o , ~, ~ , ~ , , , ~ ~ ~00 i i i i i i i i i i i i i i i i i i 1 O0 50 0 50 1 O0 150 200 250 300 350 400 450 500 550 600 Eosf (~feef) -> 50 100 150 2OO 250 3O0 35O 0 400 450 V 5O0 7 , 6 5 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THATACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. 16" - 2000 PSI STARTING HEAD 2. 11"- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6.CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. .KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE ,~ OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 ,. WELL PERMIT CHECKLIST COMPANY ,,~/'c---¢ , FIELD & POOL _~/74:~/4::~O INIT CLASS '/ ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE ~ 12_ ENG~E~RiNG ' GEOL AREA ~ ¢' O UNIT# //'/"~--~' O ON/OFF SHORE N N N N N N N N N N Y N N / Permit fee at~ached ...................... J. Lea.se number appropriate .................. Unique we[] name and number ................ Well tocst~ in a defined pool ................. Well located proper distance from dflg unit boundary .... Well Ioca___t~ proper distance from obher we&s ........ Sufficient acreage mraJlable in drilling unit. ......... If devi~teck is wellbore plm included ............. Opemtar only affected party .................. Operator has appropriate bond in force ............ Permit can be issued without conservation order ...... Permit can be issued without administrmive apprmraJ .... Y Can permit be approved before 15-day wail ........ ~Y ~ , 14. Conductor s~ng provided ................... 15. Surface casing protects aJl known USDWs ......... 16. ClVfT' vol adequate to circulme on conductor & surf csg . . . 17. CMT vol adequate to dean long string to surf csg ...... 18. CMT will cover a~l known productive horizons. ........ '(-~N 19. casing designs adequate br C, T, B & permaJmst. ..... ~ . 20. Adequate tankage or reserve pit. .............. ~ , r~__ 21. If a re-drill, has a 10-403 for abndnmnt been approved....-'-'Y--N~v7-F 22. Adequate wellbore separation proposed ............ 23. tf diverl:e, required, is it adequate ................ ~.' 24. Drilling fluid program schen'~dc & equip list adequate .... f~ ) N 25. BOPEs adequate ............. ,,)~ ..... ( N APPR DA'J~E_ 26. BOPE press rating adequate; test to ~ psig.( ) N ~ ,/ 27. Choke manifold complies w/APl RP-53 (May 84) ....... N 28. Work will occur wibhout operation shutdown .......... ( ' N 29. Is presence of H2S gas probable ............... ~ N :-GEOLOGY ......................................... , 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N// 31. Data presented on potential overpressure zones ....... Y 32. Seismic anaJysis of shaJlow gas zones ............. 33. Seabed condition survey (if off-shore) ........... //. Y N APPR DA.,TE / 34. Comactname/phoneforweekJyprogressrepo~,... ,,X...Y N REMARKS GEOLOGY: ENGINEERING: COMMISSION: ' -- I JDH ~ JDN~ TAB '~ Comments/Instructions: HOW/lib- A.-'C-ORMS'cN¢¢~ r~v 44~ 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Sep 03 11:13:04 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MW-70143 E. CRIBBS D. WESTER ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RECEIVED SEP '10 199~' Alaska Oil & Gas Cons, Commi,ssion Anchorage 2F-19 500292272800 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 03-SEP-97 33 liN 09E ~ 1749 129.00 127.50 97.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 11152.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. IvrWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 4. MWD RUNS 1 AND 2 REPRESENT WELL 2F-19 WITH API#: 50-029-22728-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF ll152'MD, 6385'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAN94A RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10229.5 11094.5 ROP 10288.5 11151.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10229.5 10230.5 10231.5 10233.0 10235.0 10237.5 10239.0 10241.5 10244.0 10248.0 10251.0 10253.5 GR 10230.0 10231.0 10232.0 10233.5 10235.0 10238.0 10239 5 10242 0 10244 0 10248 5 10251 5 10253 5 EQUIVALENT UNSHIFTED DEPTH 10256.5 10260.0 10266.0 10268.5 10270.0 10273.0 10275.0 10277.0 10279.5 10280.0 10286.5 10289 5 10292 0 10295 0 10296 5 10298 5 10301 5 10304.5 10310.0 10312.5 10314.5 10315.5 10320.0 10323.5 10325.5 10326.0 10329.5 10333.0 10337.0 10340.5 10342.5 10344.5 10347.0 10349.0 10351.0 10353.0 10355.0 10356.5 10363.5 10365.5 10373,5 10375.5 10376.0 10379 0 10380 5 10381 5 10383 5 10384 5 10386 0 10387 0 10389 0 10390 5 10392 5 10396 0 10398 0 10400 0 10404 0 10405 0 10416 0 10424 0 10255.0 10260.5 10266.0 10268.5 10270.0 10272.0 10274.5 10276.0 10278.5 10279.5 10285.0 10288.0 10291.0 10294.0 10295.5 10297.0 10302.0 10303.5 10309.0 10311.0 10313.0 10314.5 10319.5 10323.5 10325.5 10326.5 10328.5 10333.5 10336.5 10340.5 10342.0 10344.0 10346.5 10349.0 10350.0 10352.5 10354 0 10355 5 10362 0 10364 5 10371 5 10375 0 10376 0 10379 0 10380 5 10381 5 10383 0 10384 5 10385 5 10386 5 10389 0 10390 0 10392 0 10395 5 10397 5 10399 5 10403 0 10404 0 10416 0 10423 5 10428 0 10436 5 10442 5 10463 0 10464 5 10465 5 10469 0 10471.0 10476.5 10480.5 10483.5 10484.5 10485.5 10487.5 10489.5 10491.0 10492.5 10494.0 10496.5 io5oi.5 1O5O5.5 10508.0 10509.5 10511.0 10512.5 10515.5 10517.0 10518.0 10520.0 10521.5 10523.5 10525.0 10527.5 10531.5 10533.5 10535.0 10540.5 10541.0 10543.0 10544.0 10545.5 10547.0 10550.0 10555.5 10560.5 10563 5 10570 0 10582 0 10584 0 10586 5 10587 0 10588 5 10595 5 10597 0 10598 0 10599 5 10601 0 10619 5 10621 0 10624 5 10427.5 10435.5 10442.5 10462.5 10464.5 10465.5 10469.0 10470.5 10476.5 10480.5 10483.5 10484.5 10485.5 10488.0 10489.5 10490.5 10492.5 10494.5 10497.0 10501.0 10505.5 10508.0 10509.0 10510.5 10512.5 10515.5 10517.0 10518.5 10520.5 10521.5 10523 5 10525 0 10528 0 10531 0 10533 0 10534 5 10540 0 10540 5 10543 0 10544.0 10545.5 10548.5 10549.5 10557.5 10564.0 10566.0 10571.0 10581.5 10583.5 10586.0 10587.0 10588.5 10595.0 10597.5 10599.0 10599.5 10601.0 10618.5 10620.0 10624.0 10626 10627 10630 10634 10636 10637 10642 10645 10646 10648 10652 10654 10656 10666 10668 10675 10676 10678 10681 10683 10685 10688 10691 10693 10694 10695 10697 10699 10704 10708 10709 10714 10722 10734 10736 10747 10750 10755 10759 10761 10763. 10765. 10773 10780 10786 10788 10790 10804 10807 10811 10813. 10820 10823 10828 10832 10835 10836 10843 10847 10849 .0 .0 0 0 0 5 0 0 5 5 0 0 5 0 5 0 5 5 0 0 0 0 5 0 0 5 0 5 5 0 0 5 0 0 0 0 5 0 5 0 5 5 5 5 0 0 0 5 0 0 0 0 0 5 0 0 5 5 5 0 10626 10628 10630 10633 10635 10636 10641 10645 10646 10648 10651 10654 10656 10666 10668 10674 10675 10677 10680 10683 10684 10688 10691 10693 10694 10696 10697 10699 10703 10705 10706 10715 10722 10734 10737 10747 10748 10752 10759 10760 10762 10765 10773 10780 10786 10787 10790 10804 10807 10811 10813 10819 10823 10828 10832 10835 10837 10842 10846 10848 5 5 0 0 0 5 5 0 5 0 5 0 .0 .0 .0 .0 .5 .0 .5 .0 .5 .0 .5 .0 .0 .0 .0 .0 .5 .5 .5 .5 .0 .0 .0 .0 .5 .5 .5 .5 .5 .5 .0 .5 .0 .5 .0 .0 5 5 0 5 0 5 5 0 0 0 0 5 10850.0 10856.0 10860.5 10864.5 10868.0 10869.5 10872.5 10874.0 10878.0 10881 0 10883 0 10885 0 10886 0 10888 0 10893 5 10895 0 10899 0 10905 0 10909.0 10911.0 10914.5 10925.5 10927.5 10937.5 10939.0 10940.5 10942.0 10943 0 10946 0 10952 0 10954 0 10957 5 10960 0 10961 0 10963 5 10972 0 10973 5 10975 0 10978 0 10979 5 10981 0 10983 5 10985 0 10993 0 10995 0 10998 5 11005 0 11008 0 11009 5 11012 0 11151 0 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 10849 0 10854 5 10859 5 10864 0 10868 0 10870 0 10872 0 10874 0 10876.0 10879 5 10881 5 10884 5 10886 0 10887 5 10893 0 10894 5 10899 0 10905.0 10907.0 10909.5 10915.0 10925.0 10927 0 10937 0 10938 5 10939 0 10940 5 10942 5 10943 5 10952 0 10953.0 10956.0 10958.0 10959.5 10962.0 10972.0 10973.5 10974.5 10978.0 10978.5 10980.0 10983.0 10985.0 10996.0 10998.0 11000.0 11003.0 11006.0 11008.5 11012.5 11151.5 BIT RUN NO 2 MERGED I~AIN PASS. MERGE TOP 1O286.0 MERGE BASE 11152.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10229.5 11151 10690.2 1844 10229.5 GR 32.75 504.04 149.784 1731 10229.5 ROP 7.69 141.96 49.3498 1726 10288.5 Last Reading 11151 11094.5 11151 First Reading For Entire File .......... 10229.5 Last Reading For Entire File ........... 11151 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10230.0 ROP 10287.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11095.0 11151.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 20-MAY-97 MSC 1.32 DEP 2.042/NGP 5.74 MEMORY 11152.0 10286.0 11152.0 23.3 40.6 TOOL NUMBER NGP 77 4.750 4.8 WEIGHTED LSND 12.00 49.0 9.3 4200 3.4 .000 .000 .000 .000- 56.1 .4 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10230 11151.5 10690.8 1844 10230 GR 32.75 523.44 150.357 1731 10230 ROP 7.69 141.96 49.5045 1730 10287 Last Reading 11151.5 11095 11151.5 First Reading For Entire File .......... 10230 Last Reading For Entire File ........... 11151.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Con~nents ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... RECE VEU ~LIL 7 8 '/997 A..~e O/i 6, G~ Cons, c.m,~on Anc~orege COMPANY NAME : ARCO ALASKA INC. WELL NAME : 2F-19PB1 FIELD NAi~IE : KUPARUK BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 500292272800 REFERENCE NO : 97146 C.J OF LME9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/16 ORIGIN : FLIC REEL NA~iE : 97146 CONTINUATION # : PREVIOUS REEL : COf~4~2~f : ARCO ALASKA INC, 2F-19PB1, PRUDHOE BAY, API #50-029-22728-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/16 ORIGIN : FLIC TAPE NAME : 97146 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT : ARCO ALASKA INC, 2F-19PB1, PRUDHOE BAY, API #50-029-22728-00 TAPE HEADER KU PAR UK OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION RUN 1 97146 H. KIRKBY D. WESTERLY SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2F-19PB1 500292272800 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 16-JUL-97 RUN 2 RUN 3 .......... 33 liN 9E 68 1749 129.00 127.50 96.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 10626.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE DATA ACQUIRED ON ARCO ALASKA INC. WELL 2F-19PB1. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. DTE & CNT LOGGED IN COMBINATION. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUFk4AR Y LDWG TOOL CODE DTE CNT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 11097.0 10618.0 11075.0 10618.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND EDITTED DATA FOR THE DUAL INDUCTION TOOL (DTE) AND COMPENSATED NEUTRON/LITHO DENSITY TOOL (CNT). NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. THE DATA IN THIS FILE WAS ACQUIRED ONLY OVER THE OPEN HOLE SECTION OF THIS LOGGING RUN. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE CNT .............. RUN NO. PASS NO. ............... MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 100 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630289 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE OH~4M630289 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~M 630289 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~ 630289 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~E~ 630289 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OH~M 630289 O0 000 O0 0 1 1 1 4 68 0000000000 · GR DTE GAPI 630289 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 630289 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 630289 O0 000 O0 0 1 1 1 4 68 0000000000 Bi~ES DTE 0tff4~630289 O0 000 O0 0 1 1 1 4 68 0000000000 MTE~DTE DEGF 630289 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 630289 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 630289 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNT PU-S 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 630289 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 630289 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNT 630289 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CArT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNT CPS 630289 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... CALI CNT IN 630289 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11106.000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE -999.250 TEND.DTE TENS.DTE 6123.000 FIRES.DTE -999.250 MTEM. DTE -999.250 SP.DTE NPHI.CNT -999.250 ENPH. CNT -999.250 CPHI.CNT -999.250 NRAT. CNT CRAT. CNT -999.250 EIVRA.CNT -999.250 NCNT. CNT -999.250 FCNT. CNT CNTC. CNT -999.250 CFTC. CNT -999.250 CNEC. CNT -999.250 CFEC. CNT CALI.CNT -999.250 DEPT. 10618. 000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE 100.277 TEND.DTE TENS.DTE 5685. 000 f4~ES.DTE 1 . 121 MTEM. DTE 135. 621 SP.DTE NPHI.CNT 58.088 ENPH. CNT 48.731 CPHI.CNT 52.686 NRAT. CNT CRA T. CNT 4.072 ENRA . CNT 6.174 NCNT. CNT 1450.056 FCNT. CNT CNTC. CNT 1481.167 CFTC. CNT 375.239 CNEC. CNT 3084.857 CFEC. CNT CALI. CNT 1. 242 -999.250 855.314 -999.250 -999.250 -999.250 -999.250 -999.250 768.255 -48.000 4.500 378.190 499.672 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION . O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~ER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREFIENT : 0.5000 FILE SUM~L~RY LDWG TOOL CODE DTE CNT $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 10618.0 10532.0 10618.0 10532.0 BASELIArEDEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE CNT THIS FILE CONTAINS THE CLIPPED AND EDITTED DATA FOR THE DUAL INDUCTION TOOL (DTE) AND COMPENSATED NEUTRON/LITHO DENSITY TOOL (CNT). NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. THIS DATA WAS ACQUIRED ONLY OVER THE CASED HOLE SECTION OF THIS LOGGING RUN. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT 630289 NPHI CNT PU-S 630289 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNT PU-S 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 630289 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 630289 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNT 630289 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNT CPS 630289 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 630289 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 630289 O0 000 O0 0 2 1 1 4 68 0000000000 MTE~DTE DEGF 630289 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 630289 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10618.000 NPHI.CNT 58.088 ENPH. CNT 48.731 CPHI.CNT NRAT. CNT 4.500 CRAT. CNT 4.072 ENRA.CNT 6.174 NCNT. CNT FCNT. CNT 378.190 CNTC. CNT 1481.167 CFTC. CNT 375.239 CNEC. CNT CFEC. CNT 499.672 GRCH.DTE 100.277 TENS.DTE 5685.000 MTE~.DTE TEND.DTE 768.255 DEPT. 10532.000 NPHI.CNT 47.337 ENPH. CNT 37.958 CPHI.CNT NRAT. CNT 3.603 CRAT. CNT 3.484 ENRA.CNT 5.259 NCNT. CNT FCNT. CNT 520.421 CNTC. CNT 1708.881 CFTC. CNT 502.666 CNEC. CNT CFEC. CNT 639.141 GRCH.DTE 190.019 TENS.DTE 5677.000 MTE~.DTE TEND.DTE 779.504 52.686 1450.056 3084.857 135.621 44.033 1752.939 3361.379 133.731 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUFiBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: # , FILE SUFk/zARY FILE HEADER FILE ArUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 11130.5 10531.0 CNTG 11130.5 10531.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AMS AUX. MEAS. SONDE CNTG COMP. NEUTRON DITE DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS 30-MAR-97 8C0-609 930 29-MAR-97 430 30-MAR-97 11123.0 11112.0 10618.0 11077.0 1800.0 TOOL NUMBER ........... AMS-A CNT-G DIT-E 4. 750 10626.0 10618.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): WATER BASED MUD 12. O0 50.0 9.5 149.0 0.993 65.0 0.601 65.0 1. 940 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): REMARKS: RIG: NORDIC 2 Logging depth referenced to Nordic 2 Rig KB No standoffs run due to hole size (4-3/4" bit size) No neutron bowspring run due to hole size Holefinder run on the bottom of the Phasor Maximum Deviation 70 degrees in casing Deviation approx. 45 degrees in open hole. Pef curve by heavy mud constituents (Barite). Caliper closed before entering casing to avoid sticking. THIS IS THE RAW MAIN PASS DITE/CNTG DATA @ 0.5' SAMPLE RATE; OPEN HOLE ONLY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: TYPE REPR CODE VALUE 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630289 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DITE OH~4 630289 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DITE OH~4 630289 O0 000 O0 0 3 1 1 4 68 0000000000 ILD DITE OH~ 630289 O0 000 O0 0 3 1 1 4 68 0000000000 ILM DITE OH~4 630289 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DITE OH~4~ 630289 O0 000 O0 0 3 1 1 4 68 0000000000 HTENDITE LB 630289 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DITE LB 630289 O0 000 O0 0 3 1 1 4 68 0000000000 MRES DITE 0H~630289 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMDITE DEGF 630289 O0 000 O0 0 3 1 1 4 68 0000000000 SP DITE MV 630289 O0 000 O0 0 3 1 1 4 68 0000000000 GR DITE GAPI 630289 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU 630289 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNTG PU 630289 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU 630289 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNTG PU 630289 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNTG 630289 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CNTG 630289 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 630289 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 RCEN CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 630289 O0 000 O0 0 3 1 1 4 68 0000000000 CALI CNTG IN 630289 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11130.500 IDPH.DITE 2.193 IMPH.DITE 2.265 ILD.DITE ILM. DITE 2.264 SFLU. DITE 2.632 HTEN. DITE -21.895 TENS.DITE MRES.DITE 0.988 MTE~.DITE 151.778 SP.DITE -35.000 GR.DITE NPHI.CNTG 43.456 NPOR.CNTG 41.216 ENPH. CNTG 23.619 TNPH. CNTG TNRA.CNTG 3.272 RTNR.CNTG 3.333 ENRA.CNTG 3.796 CFEC. CNTG 2.155 3331.000 161.238 41.216 1016.731 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 10 CNEC. CNTG 3859.281 RCEF. CNTG 997.183 RCEN. CNTG 3592.230 RCNT. CNTG 2535.176 RCFT. CNTG 745.508 CNTC. CNTG 2440. 321 CFTC. CNTG 758.242 CALI. CNTG 1.237 DEPT. 10531.000 IDPH.DITE 58.103 IMPH.DITE 203.895 ILD.DITE 44.636 ILM. DITE 1950.000 SFLU. DITE 9700.000 HTEN. DITE 790.426 TENS.DITE 5639.000 I~RES.DITE 1.297 MTE~.DITE 133.731 SP.DITE -56.000 GR.DITE 195.670 NPHI.CNTG 46.792 NPOR.CNTG 44.842 ENPH. CNTG 38.252 TNPH. CNTG 44.704 TNRA.CNTG 3.455 RTNR.CNTG 3.564 ENRA.CNTG 5.286 CFEC. CNTG 635.903 CNEC. CNTG 3361.379 RCEF. CNTG 592.211 RCEN. CNTG 3137.122 RCNT. CNTG 1770.379 RCFT. CNTG 458.819 CNTC. CNTG 1708.881 CFTC. CNTG 496.388 CALI.CNTG 1.241 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMEN~ : FILE SUR~VX~Y FILE HEADER FILE NUMBER 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH DITE 11147.5 CNTG 11147.5 $ LOG HEADER DATA STOP DEPTH .......... 10486.0 10486.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 11 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TItlE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 30-MAR-97 8C0-609 930 29-MAR-97 430 30-MAR-97 11123.0 11112.0 10618.0 11077.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... AMS AUX. IqEAS. SONDE CNTG COMP. NEUTRON DITE DUAL INDUCTION $ TOOL NUMBER ........... AMS - A CNT-G DIT-E BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4. 750 10626.0 10618.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) '. RESISTIVITY (OH~q) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : WATER BASED MUD 12. O0 50.0 9.5 149.0 O. 993 65.0 O. 601 65.0 1. 940 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL).. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: RIG: NORDIC 2 Logging depth referenced to Nordic 2 Rig KB No standoffs run due to hole size (4-3/4" bit size) No neutron bowspring run due to hole size Holefinder run on the bottom of the Phasor Maximum Deviation 70 degrees in casing Deviation approx. 45 degrees in open hole. Pef curve by heavy mud constituents (Barite). Caliper closed before entering casing to avoid sticking. LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 12 THIS IS THE RAW REPEAT PASS DITE/CNTG DATA @ 0.5' SAMPLE RATE; OPEN HOLE ONLY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630289 O0 000 O0 0 4 1 1 4 68 0000000000 IDPH DITE 0H~630289 O0 000 O0 0 4 1 1 4 68 0000000000 IMPH DITE OH~M630289 O0 000 O0 0 4 1 1 4 68 0000000000 ILD DITE OHM~ 630289 O0 000 O0 0 4 1 1 4 68 0000000000 ILM DITE OHM~ 630289 O0 000 O0 0 4 1 1 4 68 0000000000 SFLU DITE OH~q630289 O0 000 O0 0 4 1 1 4 68 0000000000 HTENDITE LB 630289 O0 000 O0 0 4 1 1 4 68 0000000000 TENS DITE LB 630289 O0 000 O0 0 4 1 1 4 68 0000000000 I~RES DITE 0H~4~4 630289 O0 000 O0 0 4 1 1 4 68 0000000000 MTE~DITE DEGF 630289 O0 000 O0 0 4 1 1 4 68 0000000000 SP DITE MV 630289 O0 000 O0 0 4 1 1 4 68 0000000000 GR DITE GAPI 630289 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU 630289 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNTG PU 630289 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU 630289 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH CNTG PU 630289 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNTG 630289 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 13 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RTNR CNTG 630289 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 630289 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 RCEF CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 RCEN CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 630289 O0 000 O0 0 4 1 1 4 68 0000000000 CALI CNTG IN 630289 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11147.500 IDPH. DITE ILM. DITE 2. 270 SFLU. DITE f~RES.DITE 1. 379 MTEM. DITE NPHI . CNTG 31 . 181 NPOR. CNTG TNRA. CNTG 2. 577 RTNR. CNTG CNEC. CNTG 4018.232 RCEF. CNTG RCFT. CNTG 967. 048 CNTC. CNTG DEPT. 10880. 000 IDPH.DITE ILM. DITE 19. 282 SFLU. DITE MRES.DITE 5.119 MTEM. DITE NPHI. CNTG 26. 729 NPOR. CNTG TNRA. CNTG 2. 280 RTNR. CNTG CNEC. CNTG 4506. 932 RCEF. CNTG RCFT. CNTG 1999.547 CNTC. CNTG 2 186 2 582 149 104 30 574 2 625 967 048 2487 238 IMPH.DITE 2.271 ILD.DITE HTEN. DITE -28. 602 TENS.DITE SP.DITE -35. 000 GR.DITE ENPH . CNTG 26.129 TNPH . CNTG ENRA. CNTG 4.075 CFEC. CNTG RCEN. CNTG 3740.182 RCNT. CNTG CFTC. CNTG 983. 565 CALI. CNTG 18.537 IMPH.DITE 22.715 ILD.DITE 48.154 HTEN.DITE 844.546 TENS.DITE 144.423 SP.DITE -48.313 GR.DITE 26.528 ENPH. CNTG 20.137 TNPH. CNTG 2.342 ENRA.CNTG 3.390 CFEC. CNTG 1316.282 RCEN. CNTG 4153.848 RCNT. CNTG 4624.210 CFTC. CNTG 1992.838 CALI.CNTG 2. 162 1317. 000 128. 492 30. 574 986. 005 2583. 916 1. 222 17.098 6294.000 39.873 27.385 1329.475 4922.099 4.621 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 14 **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMEIVT: 0.5000 FILE SUM~L~2~Y VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 10618.0 10531.0 CNTG 10618.0 10531.0 $ LOG HEADER DATA DATE LOGGED: 30-MAR-97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 930 29-MAR-97 TIME LOGGER ON BOTTOM: 430 30-MAR-97 TD DRILLER (FT) : 11123.0 TD LOGGER (FT) : 11112.0 TOP LOG INTERVAL (FT) : 10618.0 BOTTOM LOG INTERVAL (FT) : 11077.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER .................................... AMS AUX. MEAS. SONDE AMS-A CNTG COMP. NEUTRON CNT-G DITE DUAL INDUCTION DIT-E $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 4. 750 10626.0 10618.0 WATER BASED MUD 12. O0 50.0 9.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 15 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 149.0 RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT M~ASURED TEMPERATURE (MT): 0.993 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 601 MUD FILTRATE AT (BHT) : MUD CAKE AT (FIT): 1. 940 MUD CAKE AT (BHT) : 65.0 65.0 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: RIG: NORDIC 2 Logging depth referenced to Nordic 2 Rig KB No standoffs run due to hole size (4-3/4" bit size) No neutron bowspring run due to hole size Holefinder run on the bottom of the Phasor Maximum Deviation 70 degrees in casing Deviation approx. 45 degrees in open hole. Pef curve by heavy mud constituents (Barite). Caliper closed before entering casing to avoid sticking. THIS IS THE RAW DITE/CNTG DATA @ 0.5' SAMPLE RATE; CASED HOLE ONLY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 16 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 630289 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNTG PU 630289 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNTG PU 630289 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH CNTG PU 630289 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR CNTG 630289 O0 000 O0 0 5 1 1 4 68 0000000000 TNR~ CNTG 630289 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA CNTG 630289 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR CNTG PU 630289 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN CNTG CPS 630289 O0 000 O0 0 5 1 1 4 68 0000000000 GR DITE GAPI 630289 O0 000 O0 0 5 1 1 4 68 0000000000 TENS DITE LB 630289 O0 000 O0 0 5 1 1 4 68 0000000000 HTENDITE LB 630289 O0 000 O0 0 5 1 1 4 68 0000000000 MTEMDITE DEGF 630289 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10618.000 NPHI.CNTG 58.088 ENPH. CNTG 48.731 TNPH. CNTG RTNR.CNTG 4.500 TNRA.CNTG 4.072 ENRA.CNTG 6.174 RCNT. CNTG RCFT. CNTG 378.190 CNTC. CNTG 1481.167 CFTC. CNTG 375.239 CNEC. CNTG CFEC. CNTG 499.672 NPOR.CNTG 56.117 RCEF. CNTG 484.385 RCEN. CNTG GR.DITE 100.277 TENS.DITE 5685.000 HTEN. DITE 768.255 MTEM. DITE DEPT. 10531.000 NPHI.CNTG 46.792 ENPH. CNTG 38.252 TNPH. CNTG RTNR.CNTG 3.564 TNRA.CNTG 3.455 ENRA.CNTG 5.286 RCNT. CNTG RCFT. CNTG 458.819 CNTC. CNTG 1708.881 CFTC. CNTG 496.388 CNEC. CNTG CFEC. CNTG 635.903 NPOR.CNTG 44.842 RCEF. CNTG 592.211 RCEN. CNTG GR.DITE 195.670 TENS.DITE 5639.000 HTEN. DITE 790.426 MTEM. DITE 52.686 1450.056 3084.857 2953.711 135.621 44.704 1770.379 3361.379 3137.122 133.731 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUL-1997 13:22 PAGE: 17 **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/16 ORIGIN : FLIC TAPE NAME : 97146 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 2F-19PB1, PRUDHOE BAY, API #50-029-22728-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/07/16 ORIGIN : FLIC REEL NAME : 97146 CONTINUATION # : PREVIOUS REEL : COMMENT · ARCO ALASKA INC, 2F-19PB1, PRUDHOE BAY, API #50-029-22728-00 .............................. RECEIVED . * · ALASKA COMPUTING CENTER * · * ,JUL 18 1~9~ ****************************** .............................. ,~ Ot & C-~ Cons. CominCo. · ............................ * COMPANY NAME : ARCO ALASKA, INC WELL NAME : 2F- 19 FIELD NAME : KUPARUK RIVER UNIT BOROUGH · NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22728-00 REFERENCE NO : 97279 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 10:47 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/07/11 ORIGIN : FLIC REEL NAME : 97279 CONTINUATION # : PREVIOUS REEL : CO~4~!ENT : ARCO ALASKA INC, KUPARUK, 2F-19, API #50-029-22728-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/07/11 ORIGIN : FLIC TAPE NAME : 97279 CONTINUATION # : 1 PREVIOUS TAPE : CO~9~ENT : ARCO ALASKA INC, KUPARUK, 2F-19, API #50-029-22728-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE LOGS WELL NAME: 2F - 19 API NOT4~ER: 500292272800 OPERATOR: ARCO ALASKA, INC LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: il-JUL-97 JOB ~ER: 97279 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: RANDY BLACK SURFACE LOCATION SECTION: 33 TOWNSHIP: 1 iN RANGE: 9E FNL: 68 FSL: FEL: 1749 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 129. O0 DERRICK FLOOR: 127.50 GROUND LEVEL: 97. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7.625 4711.0 30.00 5.500 10636.0 16.00 3.500 11149.0 9.30 3.500 10019.0 9.30 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. $ REMARKS: il-JUL-1997 10:47 .......... EQUIVALENT UNSHIFTED DEPTH .......... No depth adjustments were made to this data as it is the PDC log for this well. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NOWiBER : 1 DEPTH INCREMENT: 0.5000 FILE SU~4MARY LDWG TOOL CODE START DEPTH STOP DEPTH PDC 11027.0 9785.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH PDC ....... REMARKS: This file contains the CBL GR data. No pass to pass shifts were applied to this data. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1997 10:47 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100795 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDC GAPI 100795 O0 000 O0 0 1 1 1 4 68 0000000000 TENS PDC LB 100795 O0 000 O0 0 1 1 1 4 68 0000000000 CCL PDC V 100795 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11043 . 500 GRCH. PDC 75. 813 TENS. PDC 720. 000 CCL. PDC DEPT. 11000.000 GRCH. PDC 90.688 TENS.PDC 1365.000 CCL.PDC DEPT. 10500.000 GRCH. PDC 149.500 TENS.PDC 1250.000 CCL.PDC -0. 039 O. 029 0.322 DEPT. 10000.000 GRCH. PDC 56.219 TENS.PDC 1130.000 CCL.PDC 0.112 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 10:47 PAGE: 4 DEPT. 9785. 500 GRCH. PDC 81. 688 TENS. PDC 1075. 000 CCL. PDC - O. 029 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE . 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME '. EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11027.5 9785.5 PDC $ LOG HEADER DATA DATE LOGGED: 5-JUN-97 SOFTWARE VERSION: 44.2 TIFZE LOGGER ON BOTTOM: 1130 05-JUN-97 TD DRILLER (FT) : 11018.0 TD LOGGER (FT) : 11036.0 TOP LOG INTERVAL (FT) : 9785.0 BOTTOM LOG INTERVAL (FT) : 11028.0 LOGGING SPEED (FPHR) : 2000.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 10:47 PAGE: CBL CBL SONIC SONDE SLS-JD-175 CBL SONIC CARTR. SLC-SHH-CB-203 GR GAB~VA RAY GR-SHH-CA-535 CCL CCL CCL-AJ-253 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4711.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) '. GAS~OIL RATIO: CHOKE (DEG) : SEAWATER/DIESEL 38.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): ~S: TIED IN TO SPERRY NGP DATED 21-MAY-97. 28 BBLS OF CLASS 'G' 15.8 PPG CEMENT PUMPED. CE~!F2~fJOB IS GOOD. BELOW 10230' IS EXCELLENT CEMENT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUL-1997 10:47 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 ?T 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100795 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CBT GAPI 100795 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CBT LB 100795 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CBT V 100795 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11041.500 GRCH. CBT 75.813 TENS.CBT 720.000 CCL.CBT DEPT. 11000. 000 GRCH. CBT 82. 375 TENS. CBT 1320. 000 CCL. CBT DEPT. 10500. 000 GRCH. CBT 148. 375 TENS. CBT 1260. 000 CCL. CBT DEPT. 10000.000 GRCH. CBT 54.875 TENS.CBT 1155.000 CCL.CBT DEPT. 9783. 500 GRCH. CBT 81 . 688 TENS. CBT 1075. 000 CCL. CBT -0. 039 0.005 -0. 073 -0. 063 -0. 029 ** END OF DATA ** LIS Tape Verification Listing Schlumberge~ Alaska Computing Center il-JUL-1997 10:47 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE ~ FLIC VERSION · O01CO1 DATE : 97/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/07/11 ORIGIN : FLIC TAPE NAME : 97279 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT : ARCO ALASKA INC, KUPARUK, 2F-19, API #50-029-22728-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE . 97/07/11 ORIGIN · FLIC REEL NAME · 97279 CONTINUATION # : PREVIOUS REEL : COf~NT : ARCO ALASKA INC, KUPARUK, 2F-19, API #50-029-22728-00 Sperry-Sun Drilling Services LIS Scan Utility Tue Jul 01 10:52:15 1997 Reel Header Service name ............. LISTPE Date ..................... 97/07/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/07/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/5~AD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~WD RUN 3 AK-MM-70013 S.BURKHARDT D.LUTRICK 1ST STRING 2F-19 PB1 500292272870 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-JUL-97 33 liN 09E 68 1749 139.50 138.00 96.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9.875 7.625 4710.0 6.750 10640.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). THIS RUN CONTAINS NO VALID DATA AND IS NOT PRESENTED. 5. MWD RUN 3 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10640'MD, 5916'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4688.0 10541.0 ROP 4737 . 5 10626.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 4688.0 4700.5 9787.5 9801.5 9788.5 9803.5 9799.5 9811.0 9811.5 9830.0 9819.0 9834.5 10012.0 10024.0 10037.0 10052.5 10040.5 10055.5 10045.0 10060.5 10052.5 10066.0 10057.5 10072.5 10063.0 10076.5 10065.0 10079.5 10073.0 10086.5 10080.5 10094.5 10086.5 10101.5 10219.5 10237.0 10231.0 10247.5 EQUIVALENT UNSHIFTED DEPTH 10235.0 10250.0 10244.0 10260.5 10259.5 10273.0 10626.5 10640.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 4750.0 10640.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4688 10626.5 7657.25 11878 4688 ROP 11.1979 999.098 222.482 11779 4737.5 GR 28.4091 454.545 116.833 11707 4688 Last Reading 10626.5 10626.5 10541 First Reading For Entire File .......... 4688 Last Reading For Entire File ........... 10626.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4700.5 10554.5 ROP 4750.0 10640.0 $ LOG HEADER DATA DATE LOGGED: 26-JAN-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.1 MAXIMUM ANGLE: 70.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ISC 4.88/4.96 CIM 5.46/DEP2 2.042 MEMORY 10640.0 4750.0 10640.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL NUMBER NGP 325 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 6.750 6.8 REMARKS: Data Format Specification Record LSND 9.40 49.0 8.5 400 5.2 .000 .000 .000 .000 51.7 .0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 4700.5 10640 7670.25 11880 4700.5 GR 28.4091 454.545 116.82 11709 4700.5 ROP 11.1979 999.098 222.486 11781 4750 Last Reading 10640 10554.5 10640 First Reading For Entire File .......... 4700.5 Last Reading For Entire File ........... 10640 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/07/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/07/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/07/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
