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Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~-~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly (~ Vincent Nathan Lowell TO RE-SCAN Notes: ~'-'TZ ~ ~~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd • STATE OF ALASKA • p �� • '' ALASKA OIL AND GAS CONSERVATION COMMISSION i C D WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ AbandoneM Suspended 1b. Well Class: � 20AAC 25.105 20AAC 25.110 Anti+ L`kti l�at C r YniS `1�11�1 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service p graphic Test M 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill NBirit4r! ConocoPhillips Alaska, Inc. orAband.: April 19, 2011 189 - 095 / 311 - 097 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 September 20, 1989 50 103 - 20116 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 69' FNL, 94' FEL, Sec. 11, T1ON, R8E, UM September 28, 1989 2K - 13 Top of Productive Horizon: 8. KB (ft above MSL): 154' RKB 15. Field /Pool(s): 1349' FNL, 1089' FEL, Sec. 10, T1ON, R8E, UM GL (ft above MSL): 118' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1411' FNL, 1443' FEL, Sec. 10, T1ON, R8E, UM 9115' MD / 6131' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498310 y 5938235 Zone 4 9700' MD / 6517' TVD ADL 25589 TPI: x - 492037 y - 5936959 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 491683 y - 5936897 Zone 4 1811' MD / 1657' TVD 2675 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1502' MD / 1424' 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# H -40 36' 115' 36' 115' 24" 170 sx AS II 9.625" 36# J -55 36' 3849' 36' 2913' 12.25" 1125 sx AS III, 500 sx Class G 7" 26# J -55 36' 9677' 36' 6519' 8.5" 300 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 3.5 9149' 9099' MD /6121'TVD perfs cemented off: 9222' - 9238' MD 6200' 6210' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9284' - 9318' MD 6240' - 6262' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9433' 25 bbls of 17 ppg cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged 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. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No • Sidewall Cores Acquired? Yes ❑ No 0 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 ✓�'�`'I AUG 4. ZU "We JUL 0 5 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE f Submit original only //�� 0° '1,% 6 [ 28. GEOLOGIC MARKERS (List all formations and markers a tered): 29. , FORMATION TESTS NAME MD TVD Well tested? ❑ Yes EI 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 1502' 1424' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J. Ohlin er @ 265 - 1102 , 6A0/ Printed Nam G -. Title: CTD Engineering Supervisor / Z r/ // 6 Signature I ! �I/ � f�r'iI..► Phone 263 - 4021 Date Sharon Allsuo -Drake 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 12/2009 KUP 2K -13 . ` Ganacanil } - * Well Attributes Max Angle & MD TD /t$0l(a ell Wbo APWWI F ld Name W Il Status Inc ( °) MD (ftKB) Act 090 (ftKB) Larxt tr : 501032011600 re � RIVER UNIT / PROD 55.59 3,80000 97000 Comment 1142S (ppm) (Date Annotation End Date [KB - Grd (H) Rig Release Date '° . c g , SSSV LOCKED OUT Last WO: I 40.29 10/1/1989 Schanetk AduAl Annotation Depth (ftKB) E nd Date Annotation L t Mod... End Date Last Tag: SLM I 9 392 3/15/2011 Rev Reason: CEMENT PLUG - - 'Last Imosbor J 4/20/2011 Casin r Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd . CONDUCTOR 16 15062 36.0 115.0 115.0 62.50 H-40 BANGER, 31 .. �. - l.'"" Casing Description String 0... String ID ... Top (NCB) Set Depth (L.. Set Depth (TVO) ... String Wt... String ... String Top Thrd SURFACE . 95/8 8.765 35.0 3,848.9 2,9132 36.00 J BTC Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd PRODUCTION 7 6.151 28.7 9,677 3 6,502 1 26 00 J-55 BTC Tubing Strings Tubing Description ( String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd TUBING L 31/2 2.992 31.1 9,149.3 6,1534 9.30 J EUE8rdABMOD CONDUCTOR, Com pl et ion Detail 38-115 T op D ep t h (TV Top Inc( Komi... Top (ft KB) (ftK ('1 Item Des Stan Comment ID (in) 31.1 37.1 - 0.61 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV, 7,811.2 1,657.0 44.72 SAFETY VLV CAMCO TRDP -1A SSSV. (LOCKED OUT 5/27/1994) 2.812 1,811 - 6::' "yx ' - - -- 9,084.8 6,111.9 49.98 PBR BAKER 80-40 w /10' Stroke PBR 3.000 9,098.6 6,120.7 50.03 PACKER BAKER NB PACKER 2.890 ........_ I _ F GAS LIFT, 9,137.3 6 145 6 49.79 NIPPLE OTIS XN NIPPLE " MILLED OUT TO 2.80" ID 4/15/2011 " 2.800 2,888 9,148.6 6,1529 9 49 90 SOS BAKER SHEAR OUT 2.992 Other In Hole se (VVireline retrievable_plug s s, valve pumps, fish, etc.) Depth II (TVD) Top Inc! - I. Top MKS) (9103) r) Description Comment Run Date ID (in) 9,115.0 6,1313 50.10 TBG Punches PRE -CEMENTI NG TUBING PUNCHES IN TTLw/2 "4/1612011 2.992 MILLENIUM BIG BOLE, 6 SPF SURFACE, _. ____ -_ _. __ _._ _. - _ -__ -_ - -__ - -_____ __ - - _ -- 35 -3,e6e .Perfora & Slots shot GAS LIFT, Top (TVD) Btm (TVD) Dens 5,312 Top (ftKB) Btm(HKIR (ftKB) Zone Date ('h... T!'- Comment 9,222.0 9,238.0 6,200.1 6,210.4 C-4, 2K -13 1/9/2001 6.0 APERF 2.5" HSD PJ Chgs, 60 deg Phase - CEMENTED 4/19/2011 GAS LIFT, 6,627 9,284.0 9,318.0 6,240.1 6,261.6 A-4, 2K -13 4/17/1990 4.0 IPERF 4.5" Casing Guns; 180 deg. Phase - CEMENTED 4/19/2011 9,2840 9,311.0 6,240.1 6,256.9 A-4, 2K -13 8/5/1990 4.0 RPERF 2 5" Titan Hollow Sk 180 deg. Phase GAS LIFT. -_ ' = CEMENTED 4/19/2011 7,269 Notes: General & Safety - - End Data Annotation GAS LIFT, 7,835 _ 11/3/2010 NOTE: VIEW SCHEMATIC w /Alaska Sehematic9.0 - ..------ " -' _ - -- - GAS LIFT, -_ 8,442 GAS LIFT, 9,040 PBR, 9,085 , ... / PACKER, 9,099 TBG Punches, 9,115 I NIPPLE,9,137 - SOS, 9,149 APERF. 9,222 -9,238 Mandrel Details Top Depth Top Port (TVG) Inc] OD VaNe Latch Size IRO Run RPERF, Stn Top (ftKB) {HKB) r) Make Model (in) Sere Type Tyne (in) (psi) Run Date Can... 9,284-9,311 � IPERF, 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 9,286 - 9,318 - - - -- - - - - 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 CEMENT 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 PLUG, 9,115 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GASUFT DMY BK 0.000 0.011/8/1991 6 8,441.6 5,706.2 50.36 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 • 7 9,039.9 6,083.3 50.83 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 PRODUCTION, 29 -9,677 TO, 9,700 2K -13 Well Work Summary DATE SUMMARY 3/15%1,1 DRIFT TBG W/ 10' X 2.25" & TAGG @ 9392' SLM. IN PROGRESS 3/16/11 RAN PDS 24 ARM EXTENDED REACH CALIPER f/ 9385' RKB TO SURFACE. GOOD DATA. COMPLETE 3/28/11 MEASURED BHP @ 9270' RKB: 4005 PSI. READY FOR E/L PERFS. 4/15/11 MILL 2.75" XN NIPPLE (ci)_ 9137 RKB W/ 2.80" MILL, TAG NIPPLE 9161 CTMD, MILL THRU NIPPLE TO 9163.3 CTMD, BACK REAMED THRU NIPPLE @ MIN RATE THEN MADE 2 DRI RUNS THRU NIPPLE TO CONFIRM GOOD 2.80" ID. WH FP, IN PROGRESS, 4/16/11 TUBING PUNCH FROM 9115 TO 9120 USING 2" 5' GUN, 11.1 GRAM HMX BIG HOLE MILLENIUM CHARGES 6SPF (30 TOTAL SHOTS), CCL TO TOPSHOT =7.6', PERF ZONE: 9115'- 9120', CCL STOP DEPTH = 9107.4', LOG CORRELATED TO TUBING TALLY 4/17/1990. 4/18/11 MOB UNIT #4 FROM KCC TO 2K, TEST BOPS, CIRC OUT NEW COIL W/ SD AND PIG COIL, MAKE READY FOR AM CMT SQUEEZE, IN PROGRESS 4/19/11 PERFORMED A HESITATION SQUEEZE FROM 9433 RKB PUMPING 25 BBLS OF 17 PPG CEMENT. ONCE SQUEEZE WAS INITIALIZED, COULD NOT ACHIEVE SQUEEZE PRESSURE DESIGNATED IN THE WELL PROCEDURE. TOWN ENGINEER WAS CALLED AND SAID THAT THE SQUEEZE PRESSURE THAT COULD BE ACHIEVED WAS ENOUGH AT 1100 PSI. CT WAS SWAPPED TO BIG AND CEMENT LEFT IN THE TUBING WAS WASHED OUT TO A DEPTH OF 9105' CTMD. ESTIMATED 15 BBLS OF CMT BEHIND PIPE JOB COMPLETE WELL TURNED OVER TO DSO. 4/25/11 PRE - CTD - MITIA- PASSED, PT SV, MV,SSV ( PASSED) DDT SV, MV, SSV ( PASSED ) 4 /25 /11JAGGED TOP OF CEMENT c(D. 9073' SLM. TESTED TBG TO 2000 PSI, DROPPED TO 1625 PSI IN 10 MIN. TESTED TBG TO 1500 PSI, LOST 100 PSI IN 30 MIN. COMPLETE. 4/27/11 ATTEMPTED TEST CMT PLUG, FAILED it I • ConocoPhillips Time Log & Summary We/view Web Reporting Report Well Name: 2K -13 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 5/15/2011 6:00:00 AM Rig Release: 6/9/2011 12:00:00 AM Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 35/14/2011 24 hr Summary Move to 2K -13 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Mobilize rig to 2K -13 35/15/2011 MIRU, Complete BOPE test witnessed by John Crisp AOGCC, Pull BPV 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Get modules spotted, Rigging up 06:00 06:30 0.50 0 0 MIRU WHDBO SFTY P PJSM 06:30 08:30 2.00 0 0 MIRU WHDBO NUND P NU BOP, Continue RU 08:30 10:30 2.00 0 0 MIRU WHDBO CIRC P Move injector to well, reverse circulate coil with inhibited water and fresh water 10:30 11:06 0.60 0 0 MIRU WHDBO BOPE P Test inner reel valve, John Crisp with AOGCC on location to witness BOP testing. 1 11:06 21:06 10.00 0 0 MIRU WHDBO BOPE P Continue with testing, swab valves •Ct F� leaking, called out grease crew. 21:06 23:30 2.40 0 0 MIRU WHDBO BOPE P PJSM, R/U BPV Lubricator and pull BPV First time out no BPV, Got BPV on second attempt R/D and load out lubricator. SIWP= 370PSI 23:30 00:00 0.50 0 0 MIRU WELLPF CTOP P PJSM, Install checks in upper Q/C 35/16/2011 Milled cement in tubing tail and into casing. Cement was of poor quality. PU under reamer. 00:00 00:09 0.15 0 0 MIRU WELLPF CTOP P Install Check valves in UQC (cont) 00:09 00:54 0.75 0 0 MIRU WELLPF SFTY P Hop Pre spud meeting with night crew 00:54 01:42 0.80 0 0 SURPRI WELLPF PULD P PJSM, Load BHA #1, Cement pilot hole .8 degree motor and D -331 01:42 02:42 1.00 0 0 SURPRI WELLPF PRTS P M/U PDL to well, PT PDL & TT line 02:42 04:42 2.00 0 62 SURPRI WELLPF PULD P PJSM, Deploy BHA #1, Surface test tool Initial SIWP =1270. Line up and bleed off to TT. S/I and check for build up 04:42 07:24 2.70 62 - 9,000 SURPRI WELLPF TRIP P RIH, WHP bled to 50, EDC open, weight checks every 1000' 07:24 07:54 0.50 9,000 9,100 SURPRI WELLPF TRIP P Weight check at 9000', 37K PUW. Close EDC, 1.33 BPM, 3150 pump PSI, 200 WHP, 3430 BHP, biozan 15 Bbls out mill, 315 DP at motor. Continue RIH to tag at 9100 CTMD, not tied in. 16K RIW Page 1 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:54 08:18 0.40 9,100 9,113 SURPRI WELLPF MILL P Start milling, at 60 FPH with 300 WOB, 75 PSI motor work 08:18 08:36 0.30 9,113 9,116 SURPRI WELLPFMILL P Bio back to surface, Weight check, 35K PUW, 16K RIW, 1.33 BPM, 3500 pump pressure, 320 DP, 3800 BHP with 250 WHP, cement in returns. Stalls at 9116.4' still not tied in. 08:36 12:06 3.50 9,116 9,130 SURPRI WELLPF MILL P Several stalls at 9116- 9117', CCL log indicates that this is the milled out XN nipple. Worked through very slowly unsing the CRTF method. Had _ difficult time all the way to the TT 12:06 13:06 1.00 9,130 9,152 SURPRI WELLPF MILL P Continue milling ahead, able to mill at 75 FPH at <500 WOB and 150 psi �� motor work 13:06 13:36 0.50 9,152 9,150 SURPRI WELLPF MILL P PUH and log K1, +26.5' correction 13:36 15:42 2.10 9,150 0 SURPRI WELLPF TRIP P POOH 15:42 16:57 1.25 0 0 SURPRI WELLPF PULD P At surface, undeploy BHA #1 16:57 18:00 1.05 0 0 SURPRI WELLPF PULD P Lay down BHA #1 / Crew change 18:00 21:15 3.25 0 0 SURPRI WELLPF PULD P M/U BHA #2 Weatherford Motor and Haily underreamer. Load into PDL and pressure deploy. Surface test coil track 21:15 00:00 2.75 0 8,858 SURPRI WELLPF TRIP P RIH X5/17/2011 RIH begin Underreaming cement from 9170.. Slow ROP throughout the day with multiple stalls starting U/R process. 00:00 00:18 0.30 8,858 8,858 SURPRI WELLPF TRIP P RIH 00:18 01:18 1.00 8,858 8,858 SURPRI WELLPF SFTY P Suspend ops for Iditarod Hazzard Hunt Luncheon 01:18 01:48 0.50 8,858 9,090 SURPRI WELLPF TRIP P Close EDC, start RIH to tie in at .15BPM, Pressured up, PUH to clear, RIH dry to tie in 01:48 02:00 0.20 9,090 9,160 SURPRI WELLPFDLOG P Tie into K -1 for +26', 02:00 05:00 3.00 9,160 9,170 SURPRI WELLPF UREM P RIH to ensure we are out of TT, Pumps online, Pressured up. Make several attempts to spin motor, work 10' area to open blades. 05:00 17:00 12.00 9,170 9,210 SURPRI WELLPF UREM P Underreaming 1.10 bpm, 4050, BHP 3730, diff press 1400psi, WOB 1.2K, ROP 1 - 2 fph. Multiple stalls getting started. P/U weight 38K. Light metal shavings on magents. 17:00 00:00 7.00 9,210 9,234 SURPRI WELLPF UREM P Add water to system to Iwer LSRV to help with pump pressure. 1.10 bpm, 3990psi, BHP 3680, Diff press. 1440 psi, ROP 1 - 2 fph, WOB 1K. Light metal shavings on magnets. ROP 3 - 4 fph from 9222'. IA 885 psi / OA 620 psi. 05/18/2011 POOH to change BHA & U /R. Dep0loy BHA # 3 with BOT motor and 6.14" U/R blades. RIH - encoutered gas influx near bottom. Circ. out gas & try to start Underreaming. Hard time getting started @ 9237'. Page 2 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 9,234 9,241 SURPRI UREAM UREM P 1.1 bpm, 3850 psi, BHP 3640, diff 1450, ROP 2 - 3 fph, WOB 1.2K, light metal shavings with cement _ returns. 41K P/U off bottom. 05:00 07:12 2.20 9,241 111 SURPRI UREAM TRIP P Trip out to inspect BHA, ROP <2 _ FPH, PUW =40K 07:12 10:12 3.00 111 111 SURPRI UREAM TRIP P PJSM, Undeploy BHA #2, Weatherford straight motor and Haily _ underreamer 10:12 11:42 1.50 111 0 SURPRI UREAM PULD P Undeploy BHA #2, Lay down BHA, All blades and mill on surface 11:42 15:00 3.30 0 0 SURPRI UREAM CTOP P S/B on Under reamer, Run injector head tests while waiting on tools 15:00 16:00 1.00 0 0 SURPRI UREAM PULD P Baker under reamer on location. BOT rep stated can't run Baker under reamer on weatherford motor. Break out weatherford motor / P/U baker motor 16:00 17:15 1.25 0 64 SURPRI UREAM PULD P PJSM, Deploy BHA #3, Baker Under reamer on baker motor, M/U to coil track, surface test 17:15 22:15 5.00 64 9,237 SURPRI UREAM TRIP P RIH - tie in with +22.5 ft correction. P/U weight 42K. Rih to 9170' close EDC and start working down with U /R. Trap 120 psi on WHP due to light gas migration from trip in hole. Tag and stall at 9237'. Pump B/U to clear out fluid /gas migration. ECD 12.1. Difficult time getting started due to multiple stalls. Increase ECD to 12.3. 1:1 returns, gas cleaned up. 22:15 00:00 1.75 9,237 9,237 SURPRI UREAM UREM P Begin reaming - WHP 280 psi, ECD 12.3, 1.40 bpm, 3780psi, BHP 3790, diff 740 psi, WOB .5K. Slow ROP, max able to make it down is 9237.14' continue to stall at different speeds, rates etc. back reamed up to ensure clean. P/U and try to dry drift past. No -luck. Max. CT cycle in area 13% 35/19/2011 POOH to lay down BHA # 3 BOT U /R. Pick up hailey U/R 6.150. RIH to continue U/R process from 9237'. Better ROP. 00:00 01:30 1.50 9,237 9,237 SURPRI UREAM UREM P Call town and discuss lack of footage with U /R, BHA or slip sticking. Try one more time to make hole from 9237.14'. Stall @ 7237.17' & 7237.24' speed less than 1 fph. 01:30 04:30 3.00 9,237 64 SURPRI UREAM TRIP P POOH following MPD for BHA change. haily UR & weatherford motor in route. 04:30 06:00 1.50 64 0 SURPRI UREAM PULD P PJSM - Undeploy BHA. Drill out orfice on hailey U/R from 8/32 to 9/32. Page 3 of 20 S . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 SURPRI UREAM PULD P PJSM - crew change P/U BHA # 4 with 2 3/8" Weatherford motor and new Halley U /R., Make up coil track to coil, Surface test. PT TT line to manifold 08:00 10:15 2.25 0 9,100 SURPRI UREAM TRIP P RIH, EDC Open, follow MP schedule 10:15 10:30 0.25 9,100 9,156 SURPRI UREAM DLOG P Gamma tie in for +19.5', close EDC 10:30 11:06 0.60 9,156 9,239 SURPRI UREAM TRIP P Trip into 9163, bring pumps online 1 BPM @ 4081, Stall © 9239 a couple times, time mill past this spot 11:06 18:06 7.00 9,239 9,250 SURPRI UREAM REAM P U -ream ahead. Making 2 to 4 FPH with random stalls. Holding —12.2 ECD 18:06 00:00 5.90 9,250 9,265 SURPRI UREAM REAM P Crew change, ream Ahead 1.04 BPM @ 3950 FS, 300 PSI WHP, 12.34 ECD, 5150 BHP. Multiple stalls @ 9260' worked through. 05/20/2011 Complete U/R down to 9278'. Pump Sweep & SW. perform injection test - min. injection. Static WHP 2560 psi, BHP 5550 •si. 10 min. leak down - WHP 1670, BHP 4274 psi. POOH, purge CT & swap reels. 00:00 02:00 2.00 9,265 9,277 SURPRI UREAM UREM P Continue U/R - 1 bpm, 3900 psi, BHP 3870, WHP 280, ECD 12.3, ROP 7 fph, differential 1180 psi. Mix up visc pill. 02:00 04:00 2.00 9,277 9,278 SURPRI UREAM UREM P Pump down 20 bbl HI -visc Bio pill while reaming last couple of feet. Back ream up past 9230'. 20 bbl Bio sweep/ 20 bbl Bio/ followed by SW. choke pluggin off as sweep came to surface. 04:00 05:00 1.00 9,278 9,250 SURPRI UREAM UREM P Stop pumping, trap 900 psi. Open EDC. Flush choke SW in coil and 40 bbls up the backside. Injectivity test. Start= WHP 950 psi, BHP 3960, Circ 1100psi, depth 9250'. IA 825 / OA 275 pump .3 bpm - WHP 2560 psi, BHP 5550, circ 2550 psi no injection. - 10 min. draw down final = WHP -1670 psi, BHP - 4274 psi. Circ 1380psi 05:00 07:30 2.50 9,250 96 SURPRI UREAM TRIP P POOH holding MPD pumping 1.40 bpm SW 07:30 09:30 2.00 96 0 SURPRI UREAM PULD P PJSM, Tag up and space out, PUD _ BHA #4, Blow down tool 09:30 12:30 3.00 0 0 SURPRI WELLPFSQEZ P PSSM, Mix and pump corrosion inhibitor, N2 Reef blowdown 12:30 17:00 4.50 0 0 SURPRI WELLPF SQEZ P Unstab injector, Cut off CTC, Dress coil for grapple connector, R/U and unstab coil back to reel and secure 17:00 22:00 5.00 0 0 SURPRI WELLPF SQEZ P Remove E -coil & install work string. 22:00 00:00 2.00 0 0 SURPRI WELLPF SQEZ P Install grapple connector and putt test for stabing pipe. PJSM Stab _pipe. Page 4 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/21/2011 24 hr summary Perfrom cement squeeze - Pump 150 bbis heated SW - 15 bbis 17# cement followed by 1.5 #1310. Injection rate .25 bpm @ 3700 psi. Squeezed 7 bbls behind pipe. Start pressure 2100 psi, end pressure 3600 psi. Drop ball, Jet down to 9115' with BIO, POOH @ 80% with 1:1 returns holding 1900 psi on WH. Flush stack, lines & all valves at surface. 00:00 04:00 4.00 0 0 SURPRI WELLPFSQEZ P Pull pipe across and stab pipe. Secure reel & injector. Install counters and reel iron rig up for cement job. 04:00 05:30 1.50 0 0 SURPRI WELLPF SQEZ P Set up mud pumps to fill CT with SW & pump 2" wiper dart through CT string. Zero pump counter when water at inner reel iron. 30.50 bbis until dart & fluid reached EOP. 05:30 10:30 5.00 0 7 SURPRI WELLPFSQEZ P M/U CTC, Pull test 32K, PT CTC and Inner reel iron, M/U Cementing BHA with 5' stinger and 2.25 ball drop nozzle, Inspect pack offs, PT Lubricator and stack to 4K, Perform Lo -Hi PT on inner reel valve. 10:30 13:15 2.75 7 9,238 SURPRI WELLPF SQEZ P RIH, WHP =1000 to maintain 1 to 1 returns, Tag bottom and correct to 9278, PUH 5' and paint flag. 13:15 14:45 1.50 9,238 9,100 SURPRI WELLPFSQEZ P Circulate hot seawater 150 BBIs recip up to TT, 1.8 BPM @ 3200 PSI WHP= 1000PSI to maintain 1 for 1 14:45 15:30 0.75 9,100 9,100 SURPRI WELLPFSQEZ P lnjectivity test .25 BPM @ 3700 PSI, Trip in well 15:30 16:00 0.50 9,100 9,273 SURPRI WELLPF SQEZ P PJSM with crew, cementers, truck drivers 16:00 16:36 0.60 9,273 9,273 SURPRI WELLPF SQEZ P At flag, pump 5 BBI spacer followed by 15 BBIs 17Lb /GI cement / 5 BBIs fresh water 16:36 17:00 0.40 9,273 9,273 SURPRI WELLPFSQEZ P Goto Bio following Cement with rig pumps, 1.15 BPM @ 2850 Circ pressure, 1050 WHP 17:00 17:45 0.75 9,273 7,360 SURPRI WELLPF SQEZ P 3 BBI out PUH in 7 " 1 BPM @ 40 FPM, PUH to TT, Slow pumps to .5 pull @ 55 FPM slowing down as we gained on TOC down to 37 FPM. Pull out of cement @ 8228. Pull up to safety @ 7350, Worst case TOC 7975 WHP= 1000PSI 17:45 18:00 0.25 7,360 7,353 SURPRI WELLPFSQEZ P S/I well © 1000PSI, Pump 2.4 BBIs WHP up to 3700PSI, Shutdon pump WHP dropped to 2550, Pump .BBBIs back up to 3700, S/D pump fell rapidly to 2400 PSI., pump .9 to 3800PS1. Double block surface lines and pump. Static @ 2200 psi. PJSM - crew change Page 5 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 7,353 7,353 SURPRI WELLPF SQEZ P 15 min. - Step # 3 - pumped .9 bbl, WHP 3100 psi, Circ. 4000psi. END WHP 2160 psi, Circ. 2170. 10 min - Step #4 - pumped .6 bbl, WHP 3600 psi, Circ 3840 psi. END WHP 2450, Circ. 2500 15 min - Step #5 - pumped .4 bbls, WHP 3600, Circ 3800 psi END WHP 2940, circ 2940 30 min - Step #6 - pumped .22 bbls, WHP 3700, Circ 3790, Solid straight line. Drop ball in reel while waiting & rig down cement line. Final- WHP 3600, Circ 3640. 20:00 20:30 0.50 7,353 9,115 SURPRI WELLPF TRIP P Estimated 7 bbls behind pipe - pumping ball around with 1.5# bio holding 1900 psi on WH. P/U weight 24K. RIH jetting Blo. Auto choke acting up. Stop flush & reset. good 1850 with 1:1 returns. Circ press. increased to 4150 when ball hit. P/U weight 30K. @ 8650' 8900' circ press climbing slightly. Weight check 28K. RIH - Circ press 4250 @ 1.5 bpm. RIH speed 50 fpm, _WHP 1850, 1:1 returns. 20:30 21:15 0.75 9,115 6,000 SURPRI WELLPF TRIP P POOH 29K Weight swings from 24 - 31 K. at 80% pumping 1.5 bpm, 60 fpm holding 1900 psi WHP 1:1 returns to open top. Heavy Cement/Bio returns. Increase to 80 fpm @ 8900' @ 1.3 bpm. Jet GLM while POOH. IA 880 / OA 97 21:15 21:30 0.25 6,000 5,400 SURPRI WELLPF TRIP P Cement returns to open top cleaned up, reduce pump rate to 1.1 bpm, 80 fpm, WHP 1900 psi. 1:1 returns. Final count 110 bbls into open top. 21:30 21:45 0.25 5,400 6,300 SURPRI WELLPF TRIP P RIH to fix reel spool, reel drag issues while POOH. 21:45 23:15 1.50 6,300 15 SURPRI WELLPF TRIP P POOH holding 1900 WHP 1:1 returns - clean BIO. Pull up slowly through mast/ shut swab valves. Trap 1960 psi on Well. 23:15 00:00 0.75 15 0 SURPRI WELLPFCIRC P Grease crew on location to grease tree valves for BOP test. Pop off injector and inspect BHA. Recover • Ball . Set up to flush BOP stack and all surface valves. 05/22/2011 Full BOPE test waived by John Crisp. Pump inhibitor through workstring, install foam pig & purge with N2. Unstab pipe & remove hard line. Replace shaker bed in mud pits. 00:00 03:30 3.50 0 0 SURPRI WHDBO CIRC P Flush and grease all surface lines, 3 valves and stack after cement job. ./ Replace pack off on injector. 03:30 06:30 3.00 0 0 SURPRI WHDBO BOPE P * ** *Start BOPE test * ** test inner reel iron and tree valves. Page 6 of 20 • Time Logs Date From To Dur S. Depth _ E. Depth Phase Code Subcode T Comment 06:30 10:30 4.00 0 0 SURPRI WHDBO BOPE P End BOPE Test 10:30 10:45 0.25 0 0 SURPRI WELLPF SQEZ P Pump up manage pressure line to 1500PSI, Open up to well, WHP =1385 Consult with town, Plan forward pump corrsion inhibitor N2 Reel blowdown 10:45 12:30 1.75 0 0 SURPRI WELLPF SQEZ P PJSM, M/U nozzle to coil and stab on well, Pump 30bbI fresh water, 30 BBI inhibitor, 3OBBIs fresh water 12:30 14:12 1.70 0 0 SURPRI WELLPFSQEZ P SLB N2 Unit on location, R/U, Break inner reel iron and install foam pig PT N2 Line to 3K 14:12 14:30 0.30 0 0 SURPRI WELLPF SQEZ P N2 Online, 1500 SCM 14:30 15:30 1.00 0 0 SURPRI WELLPF SQEZ P N2 off line, saw dart hit connector, bleed down 15:30 19:00 3.50 0 0 SURPRI WELLPF SQEZ P PJSM, Unstab injector, cut off CTC. Prepare for reel swap Recovered coil pig in nozzle 19:00 00:00 5.00 0 0 SURPRI WELLPF SQEZ P Begin unstabing Coil from injector. Had difficult time with coil position on reel & gooseneck. Stop job, clamp off coil and cut pipe - 40 feet . Re -head cable and pull pipe to get the lifting eyes in the correct position. Clamp and secure reel. Update reel string with 40 ft cut. 05/23/2011 Complete reel swap, injector service, replace motor brakes. Replace Shaker bed. pressure test inner reel iron, CT connector & pack -off. Bleed down Well to zero - no flow. RIH Tag TOC 9077'. Numerous stalls getting started. 00:00 03:00 3.00 0 0 SURPRI WELLPF SQEZ P Remove reel iron & flanges, Lower work string onto Bed truck. 03:00 06:00 3.00 0 0 SURPRI WELLPF SQEZ P P/U E- string off bed truck. Install reel iron and prepare to stab pipe. 06:00 07:45 1.75 0 0 SURPRI WELLPF SQEZ P Crew change, PJSM, Stab coil, R/D stabbing equipment 07:45 09:45 2.00 0 0 SURPRI WELLPFSQEZ P Wire up inner reel line and test E -line - 61 Ohmes Prep coil and install conector, Pull _ test to 30K, 09:45 10:15 0.50 0 0 SURPRI WELLPF SQEZ P Rehead E -Line and test 10:15 11:15 1.00 0 0 SURPRI WELLPF SQEZ P PJSM, Load PDL BHA#6, Pilot hole mill, .8 degree motor 11:15 13:30 2.25 0 0 SURPRI WELLPF SQEZ P Change Injector brakes and service injector, Inspect choke B 13:30 14:06 0.60 0 0 SURPRI WELLPF SQEZ P PJSM, Pump up well via MP line to 2500, Shut R1 and stabilized @ 2450, Bled down to 2421 in 30 Minutes Page 7 of 20 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:06 14:48 0.70 0 0 SURPRI WELLPF SQEZ P Install pressure cap, circ fluid around and fill stack. Equilize across swab valves and open. Bleed well to shaker 14:25 start No Flo Test, test for 20 minutes Good test 14:48 17:48 3.00 0 0 SURPRI WELLPF SQEZ P M/U coil on well and fill coil, Shell test wash pipe and new reel swivel, PT Inner reel valve 17:48 19:00 1.20 0 62 PROD1 WHPST PULD P P/U BHA* 6 with D331 Bit & 0.8 AKO motor. 19:00 22:00 3.00 62 8,500 PROD1 WHPST TRIP P RIH with EDC open monitoring potential electrical surges. POOH from 2000'. Injector & motor surges off /on, minimal. Check for lower amperage off /on, not specific timing with D141 operations. RIH 8500' Close EDC. 22:00 22:30 0.50 8,500 9,078 PROD1 WHPST TRIP P 8570' heard a loud pop on rig floor. Stop & inspect injector. WOB & string weight is normal. P/U weight 36K. up to 8400' - pipe looks good. Injector motor has slight vibration noises. RIH - good. Tag cement top 9080' P/U 41K. Increase pump rate to 1.4 bpm. Starting to get dirty water/bio fluid in returns, scale mixture to surface. No oil or gas. take returns to Tiger tank. IA 880 / OA 0 22:30 23:30 1.00 9,078 9,078 PROD1 WHPST MILL P Ciro 2600 psi at 1.5 bpm. CT weight 33K. RIH light tag @ 9078' Stall, Motor work @ 2600psi & stall at 3400psi. - TF 20 right. B/U - Bring returns inside, clean Blo with cement cuttins. Start time milling due to 8 stalls. 23:30 00:00 0.50 9,078 9,078 PROD1 WHPST MILL P Start time milling. - cannot tie in to correct depth at 9100'. CTES EOP depth 9033'. X5/24/2011 Mill cement pilot hole 9077' to 9275'. Drift cement pilot with Dummy WS. 00:001 02:15 2.25 9,078 9,081 PROD1 WHPST MILL P Time milling - 1.55 bpm, 2780psi, BHP 3270, WHP 0, WOB .55, CT weight 15K. P/U weight 39K. 20 right TF. Stalls. Pressure seem lighter than normal. with higer P/U weights 40K. P/U 200 ft to clean area. Getting very light cement and scale in returns with Bio. 02:15 03:15 1.00 9,081 9,091 PROD1 WHPST MILL P Roll TF to low side to see if it helps with stalls due to possible cement stringers /ramp. 1.55 bpm, 2870, BHP 3320, ROP 6 fph, WOB .3K, CT weight 14.5K. Much better ROP 20 fph. WOB .5K Cement over shakers with samples of scale. Page 8 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:15 1.00 9,091 9,100 PROD1 WHPST MILL P Continue milling ahead Lowside until tie -in depth. 1.55 bpm, 3070psi, BHP 3365, ROP 20, WOB .65, CT weight 15K. Good cement returns to surface. 04:15 06:00 1.75 9,100 9,123 PROD1 WHPST MILL P Roll to 20 ROHS. 1.55 bpm, 3100 psi, ROP 12, WOB .7K. Good hard cement & motor work from 9105'. 1.55 bpm, 3400 psi, BHP 3430, ROP 10, WOB 1.1K. Tie in correction depth = 06:00 12 :00 6.00 9,123 9,160 PROD1 WHPST MILL P Crew change, Continue to mill ahead. Still no depth correction 1.55 BPM @ 3270 BPM, TF 20RHS 12:00 16:00 4.00 9,160 9,275 PROD1 WHPST MILL P Casing contact at 9160.7' uncorrected depth. Continue milling at 1.5 BPM, 3950 CTP, 0 WHP, 11.16 ECD, 2.5 WOB, 250 motor work and 50 FPH. Increase WHP to maintain 12.0 ECD 16:00 16:24 0.40 9,275 9,075 PROD1 WHPST REAM P PUH, low side tool face from 9190' to 9150'. Continue up to 9075' 16:24 16:54 0.50 9,075 9,275 PROD1 WHPST DLOG P Tie -in, no correction. 16:54 17:24 0.50 9,275 9,275 PROD1 WHPST REAM P Dry-drift pilot hole 17:24 19:54 2.50 9,275 0 PROD1 WHPST TRIP P POOH 19:54 20:09 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 20:09 21:09 1.00 0 0 PROD1 WHPST PULD P Undeploy BHA 6 21:09 22:39 1.50 0 0 PROD1 WHPST PULD P Deploy BHA 7, WS drift 22:39 00:00 1.35 71 9,158 PROD1 WHPST TRIP P RIH take weight at 9140 and 9148'. 1 -2K 35/25/2011 Drift cement pilot hole with Dummy WS BHA, down to 9275'. POOH, RIH to Dress cement pilot through transition area with DS331 mill with sidecutters and .8 AKO, POOH, RIH with WS. Set WS at 9255' TOWS oriented high side. 00:00 03:00 3.00 0 0 PROD1 WHPST TRIP P At Surface, PJSM 03:00 06:00 3.00 0 0 PROD1 WHPST PULD P Undeploy Dummy whipstock, deploy milling BHA with D331 with ridge set cutters and 0.8 deg motor 06:00 08:30 2.50 0 9,275 PROD1 WHPST TRIP P RIH, tie in to K1, +21' At 9148' saw 700 WOB with 120 psi motor work 08:30 10:00 1.50 9,275 9,040 PROD1 WHPST REAM P Tag bottom, PUH, pumping at 1.6 BPM, 3600 CTP, 340 WHP for 3900 BHP. Ream up at 6 FPM oriented 180, 135, 225 seeing motor work and negative WOB at 9150' each time 10:00 10:30 0.50 9,040 9,240 PROD1 WHPST DLOG P CCL log to confirm TT depth, no correction Page 9 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 9,240 9,000 PROD1 WHPST REAM P Continue with back reaming passes, 90 and 270. Final pass at 180 slowing to 1 FPM from 9155' to 9135' Dry-drift looks good pump 5 Bbls low vis and 10 Bbls high vis sweeps 12:00 14:42 2.70 9,000 0 PROD1 WHPST TRIP P POOH 14:42 15:00 0.30 0 0 PROD1 WHPST SFTY P PJSM 15:00 17:30 2.50 0 0 PROD1 WHPST PULD P Undeploy milling BHA 17:30 18:00 0.50 0 0 PROD1 RPEQPI SVRG P Service Injector head, reel 18:00 18:30 0.50 0 0 PROD1 RPEQP1SFTY P Crew change PJSM 18:30 19:30 1.00 0 0 PROD1 RPEQP1PULD P Deploy BHA (whipstock) 19:30 21:45 2.25 72 9,100 PROD1 RPEQP1TRIP P RIH 21:45 22:00 0.25 9,100 9,100 PROD1 RPEQP1DLOG P Tie in depth +20.5' correction 22:00 22:30 0.50 9,100 9,266 PROD1 RPEQP1WPST P RIH to 9270', PUH to set WS 9265.5. TOWS= 9255'. 22:30 22:45 0.25 9,266 9,266 PROD1 RPEQP1WPST P Oreint 0 deg TF, Set WS, 4200pst CTP, set odwn 2.5K WOB. Looks good. 22:45 00:00 1.25 9,266 7,000 PROD1 RPEQP1TRIP P POOH 38K PUW. X5/26/2011 Mill window 9258- 9264'. Mill rat hole to 9276'. Back ream HS, 30L and 30R of HS. Dry drift, POQhI,__ 00:00 00:30 0.50 7,000 0 PROD1 RPEQP1TRIP P POOH 00:30 00:45 0.25 0 0 PROD1 RPEQP1SFTY P At surface, PJSM 00:45 01:30 0.75 0 0 PROD1 RPEQP1PULD P Undeploy BHA9 01:30 02:00 0.50 0 0 PROD1 RPEQP1PULD P LD BHA 02:00 03:00 1.00 0 0 PROD1 WHPST PULD P Deploy BHA 10 03:00 05:30 2.50 9,100 PROD1 WHPST TRIP P RIH a �C 05:30 05:45 0.25 9,100 9,100 PROD1 WHPST DLOG P Tie in depth 05:45 06:15 0.50 9,255 9,255 PROD1 WHPST TRIP P RIH to TOWS 06:15 06:48 0.55 9,255 9,255 PROD1 WHPST CIRC P Swap hole over to used Flo -Pro for milling window 0:48 14 :30 7.70 §,259 9,264 PROD1 WHPST MILL P Tag WS dry at 9259', PUH and start pumping at 1.4 BPM, 4000 CTP, 13.5K RIW, WOC for 4050 BHP. Stall at 9258.6'. Start time milling 1 FPH, up to 2K WOB and 200 PSI �V V motor work y j 0 14:30 17:18 2.80 9,264 9,268 PROD1 WHPST MILL P WOB dropped to 600 and motor work t dropped to 100 psi. Bottom of window, continue at 1 FPHto 9264.6 then increase ROP to 2 FPH. 1.4 BPM, 4000 CTP, 4070 BHP with WOC 17:18 19:18 2.00 9,268 9,277 PROD1 WHPST MILL P Drilling foramtion at 3-4 FPH Page 10 of 20 • •curity Level: AK Development , Oft CT Daily Drilling Report 2K -13 Report Number: 8 Conoc ©Phillips Rig: NABORS CDR2 -AC Report Date: 5/21/2011 AFE Costs Network/ID # Total AFE +Sup 10300996 4,032,014.00 Daily Operations Parent Welibore Wellbore Name Field Name Daily Mud Cost Cum Mud Cost Daily Cost Total Cumulative Cost 2K - 13 2K - 13 KUPARUK RIVER UNIT 10,790.86 87,798.89 120,501.36 1,136,715.57 DOL Job Days Ahead (days) Projected Job End Date Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) 8.0 -4.69 6/11/2011 0.0 0.0 Last 24hr Summary Perfrom cement squeeze - Pump 150 bbls heated SW - 15 bbls 17# cement followed by 1.5 # BIO. Injection rate .25 bpm @ 3700 psi. Squeezed 7 bbls behind pipe. Start pressure 2100 psi, end pressure 3600 psi. Drop ball, Jet down to 9115' with BIO, POOH @ 80% with 1:1 returns holding 1900 psi on WH. Flush stack, lines & all valves at surface. Ops and Depth @ Morning Report 24hr Forecast BOPE testing Full BOPE test Waived by John Crisp General Remarks IA 880 / OA 97 Weather Head Count Days Since Lost Time Incident (days) Days Since Recordable Incident (days) 28.0 752.00 231.00 Daily STOP Cards Obsery Type No. Rpts Comment JSA / GO CARD DISCUSSION 0 STOP INTERVENTIONS 0 Supervisor Title James Ohlinger, CTD Engineer CTD Engineer Jim Newell, Wells Supervisor CTD Wells Supervisor CTD Eddie Hylsky, Wells Supervisor CTD Wells Supervisor CTD Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P -T -X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 04:00 4.00 SURPRD WELL... SQEZ P 0.0 0.0 Pull pipe across and stab pipe. Secure reel & injector. Install counters and reel iron rig up for cement job. 04:00 05:30 1.50 SURPRD WELL... SQEZ P 0.0 0.0 Set up mud pumps to fill CT with SW & pump 2" wiper dart through CT string. Zero pump counter when water at inner reel iron. 30.50 bbls until dart & fluid reached EOP. 05:30 10:30 5.00 SURPRD WELL... SQEZ P 0.0 7.4 M/U CTC, Pull test 32K, PT CTC and Inner reel iron, M/U Cementing BHA with 5' stinger and 2.25 ball drop nozzle, Inspect pack offs, PT Lubricator and stack to 4K, Perform Lo -Hi PT on inner reel valve. 10:30 13:15 2.75 SURPRD WELL... SQEZ P 7.4 9,238.0 RIH, WHP =1000 to maintain 1 to 1 returns, Tag bottom and correct to 9278, PUH 5' and paint flag. 13:15 14:45 1.50 SURPRD WELL... SQEZ P 9,238.0 9,100.0 Circulate hot seawater 150 BBIs recip up to TT, 1.8 BPM @ 3200 PSI WHP= 1000PSI to maintain 1 for 1 14:45 15:30 0.75 SURPRD WELL... SQEZ P 9,100.0 9,100.0 Injectivity test .25 BPM @ 3700 PSI, Trip in well 15:30 16:00 0.50 SURPRD WELL... SQEZ P 9,100.0 9,273.0 PJSM with crew, cementers, truck drivers 16:00 16:36 0.60 SURPRD WELL... SQEZ P 9,273.0 9,273.0 At flag, pump 5 BBI spacer followed by 15 BBis 17Lb /GI cement / 5 BBIs fresh water 16:36 17:00 0.40 SURPRD WELL... SQEZ P 9,273.0 9,273.0 Goto Bio following Cement with rig pumps, 1.15 BPM @ 2850 Circ pressure, 1050 WHP 17:00 17:45 0.75 SURPRD WELL... SQEZ P 9,273.0 7,360.0 3 BBI out PUH in 7 " 1 BPM © 40 FPM, PUH to TT, Slow pumps to .5 pull © 55 FPM . slowing down as we gained on TOC down to 37 FPM. Pull out of cement © 8228. Pull up to safety © 7350, Worst case TOC 7975 WHP= 1000PSI Page 1/3 Report Printed: 6/27/2011 • • Security Level: AK Development • CT Daily Drilling Report aL 2K -13 Report Number: 8 ConocoPhillfps Rig: NABORS CDR2 -AC Report Date: 5/21/2011 Time Log Start End Dur Time Depth Start Depth End Time Time (hrs) Phase Op Code Activity Code P -T -X Trbl Code Trbl Class. (ftKB) (ftKB) Operation 17:45 18:00 0.25 SURPRD WELL... SQEZ P 7,360.0 7,353.0 S/I well @ 1000PSI, Pump 2.4 BBIs WHP up to 3700PS1, Shutdon pump WHP dropped to 2550, Pump .8BBIs back up to 3700, SID pump fell rapidly to 2400 PSI., pump .9 to 3800PS1. Double block surface lines and pump. Static © 2200 psi. PJSM - crew change 18:00 20:00 2.00 SURPRD WELL... SQEZ P 7,353.0 7,353.0 15 min. - Step # 3 - pumped .9 bbl, WHP 3100 psi, Circ. 4000psi. END WHP 2160 psi, Circ. 2170. 10 min - Step #4 - pumped .6 bbl, WHP 3600 psi, Circ 3840 psi. END WHP 2450, Circ. 2500 15 min - Step #5 - pumped .4 bbls, WHP 3600, Circ 3800 psi END WHP 2940, circ 2940 30 min - Step #6 - pumped .22 bbls, WHP 3700, Circ 3790, Solid straight line. Drop ball in reel while waiting & rig down cement line. Final - WHP 3600, Circ 3640. 20:00 20:30 0.50 SURPRD WELL... SQEZ P 7,353.0 9,115.0 Estimated 7 bbls behind pipe - pumping ball around with 1.5# bio holding 1900 psi on WH. P/U weight 24K. RIH jetting Blo. Auto choke acting up. Stop flush & reset. good 1850 with 1:1 returns. Circ press. increased to 4150 when ball hit. P/U weight 30K. © 8650' 8900' circ press climbing slightly. Weight check 28K. RIH - Circ press 4250 © 1.5 bpm. RIH speed 50 fpm, WHP 1850, 1:1 returns. 20:30 21:15 0.75 SURPRD WELL... SQEZ P 9,115.0 6,000.0 POOH 29K Weight swings from 24 - 31 K. at 80% pumping 1.5 bpm, 60 fpm holding 1900 psi WHP 1:1 returns to open top. Heavy Cement/Bio returns. Increase to 80 fpm @ 8900' © 1.3 bpm. Jet GLM while POOH. IA 880 / OA 97 21:15 21:30 0.25 SURPRD WELL... SQEZ P 6,000.0 5,400.0 Cement returns to open top cleaned up, reduce pump rate to 1.1 bpm, 80 fpm, WHP 1900 psi. 1:1 returns. Final count 110 bbls into open top. 21:30 21:45 0.25 SURPRD WELL... SQEZ P 5,400.0 6,300.0 RIH to fix reel spool, reel drag issues while POOH. 21:45 23:15 1.50 SURPRD WELL... SQEZ P 6,300.0 15.0 POOH holding 1900 WHP 1:1 returns - clean BIO. Pull up slowly through mast/ shut swab valves. Trap 1960 psi on Well. 23:15 00:00 0.75 SURPRD WELL... BOPE P 15.0 0.0 Grease crew on location to grease tree valves for BOP test. Pop off injector and inspect BHA. Recover Ball . Set up to flush BOP stack and all surface valves. Mud Check Data Date Type Depth (ftKB) Density (lb/gal) Density Temp ( °F) PV Calc (cp) YP Calc (Ibf... pH LSRV (cp) LGS ( %) Chlorides (mg /L) 5/21/2011 Water Base 8.40 10.3 32,000 00:00 Comment Page 2/3 Report Printed: 6/27/2011 • •curity Level: AK Development CT Daily Drilling Report 2K -13 tr ° Report Number: 8 ConocoPhilltps I Rig: NABORS CDR2 -AC Report Date: 5/21/2011 Injection Fluid Fl uid Source From Lease (bbl) Destination Vendor Manifest Number Note Cementing Fluids 2K -13 280.0 1R-18 AES 347976 Cementing Fluids 2K -13 210.0 1R-18 AES 347977 Bulk Totals Cum Cum On Cum Cum Date Supply Item Description Unit Label Consumed Received Returned Consumed Loc Received Returned Note P -T -X Totals Time P -N -T % Total Time ( %) Dur (hrs) P 99.27 599.60 T 0.73 4.40 Survey Data MD (ftKB) Inc' ( °) Azm ( °) TVD (ftKB) VS (ft) NS (ft) EW (ft) DLS ( °l100ft) Note 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Windows / Welllbore Junctions Wellbore Ca Description Item Description Top (ftKB) Btm (ftKB) Comment Whipstocks Wellbore Description Top (ftKB) Btm (ftKB) Comment 2K -13 Whipstock 9,255.0 9,265.5 3.5" MONOBORE WHIPSTOCK Page 3/3 Report Printed: 6/27/2011 2K -13 CTD Completion Schematic MI IR- 3 -1/2" Camco TRDP -1A SSSV (locked out) @ 1811' RKB 16" 62# H -40 — — 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface shoe @ 115' itEVI- MD 3-1/2" Camco MMG gas lift mandrels @ 2860', 5312', 6627', 7269', 7835', 9 -5/8" 36# J -55 shoe 8442', 9040' RKB @ 3848' MD Baker 3 -1/2" 80/40 PBR @ 9085' RKB iii Baker 3-1/2" x 7" HB retrievable packer @ 9099' RKB iii 3 -1/2" Otis 'XN' nipple @ 9137' RKB (2.75" min ID) (Has been milled out to 2 -3/8" liner top 2.80" for CTD) • Lfftevexemeefte @ 9,123' MD 3 -1/2" tubing tail @ 9149' RKB C -sand perts � 9222 -9238' MD ".„ „ .....,– KOP @ 9,259' MD 2K -13AL2 TD @10,123'MD A -sand perfs ------------------ 2K -13A 9284 -9318' MD TD @ 11,691' MD • f (AU billet @ 9,693' MD IAL2 billet @ 9,468' MD PBTD 2K -13AL1 9491' (2/2/11) 7” 26# J - 55 shoe @ 9433' (3/15/11) TD @ 11,712' MD 9677' MD • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPl"uHips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 May 16, 2011 RECEIVED Dan Seamount �� (1 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 AIoska Oil & C0716. C-uilni$sion Anchorage, AK 99501 f tiateraa 3 Dear Mr. Seamount, Enclosed you will find 10 -404 reports of Sundry Well Operations recording the production for Kuparuk Well 2K-13 (PTD 189 -095). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 907 - 659 -7535. Sincerely, .732 Darrell R. Humphrey Attachments , MA`,/ . "'I Sundry Notice Well Schematic STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Ft'rforations _; Stimulate r Other V} INJ to PROD Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Ferforate r Re -enter Suspended VVell r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 189 -095 _ 3. Address: 6. API Number: e, Alaska 99510 Stratigraphic r Service r P. O. Box 100360, Anchorage, - 50 - 103 20116 - -- 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25589, ALK 2675 + 2K - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9700 feet Plugs (measured) None true vertical 6517 feet Junk (measured) None Effective Depth measured 9374 feet Packer (measured) 9085, 9099, 9137, 9149 true vertical 6316 feet (true vertucal) 6112, 6121, 6146, 6153 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 0 0 SURFACE 3814 12 3849 2918 0 0 PRODUCTION 9649 7 9677 6519 0 0 o 0 0 o 0 0 o 0 0 Perforation depth: Measured depth: 9222 - 9238, 9284 - 9318 RECEIVE II, True Vertical Depth: 6217 - 6227, 6257 - 6279 MAY i 8 201i Tubing (size, grade, MD, and TVD) 3.5, J - 55, 9149 MD, 6153 TVD Alaska Oil & t;8% Cam &9tl missio 7 Packers & SSSV (type, MD, and TVD) PBR - BAKER 80 -40 W /10' STROKE PBR @ 9085 MD and 6112 TVD , "`TiCttentrt}® PACKER - BAKER HB PACKER @ 9099 MD and 6121 TVD NIPPLE - OTIS XN NIPPLE @ 9137 MD and 6146 TVD SOS - BAKER SHEAR OUT @ 9149 MD and 6153 TVD SAFETY VLV - CAMCO TRDP -1A SSSV. (LOCKED OUT 5/27/1994) @ 1811 MD and 1657 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 2000 600 1000 3700 Subsequent to operation 132 3237 220 1100 242 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r r Service r Stratigraphic 15. Well Status after work: - Oil FI; Gas r WDSPL r Daily Report of Well Operations X GSTOR r \INJ r WAG r GINJ r SUSP r SPLUG r 16. 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: 311 -110 Contact Darrell Humphrey /Bob Christesen Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659 -7535 Date ,) .› 1 . , / . 0\- - 1------\-"x-e--uc .5" /6 . 1 / Form 10-404 Revised 10/2010 Submit Original Only ROOMS MAY 18 20 7"` sag �� 9 414 • 2K -13 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/09/111WeII brought on production for resevoir pressure reduction prior to CTD for 2K -13A 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 KUP 2K -13 ConocoPhillips it e ll Attributes ax Angle & MD TD Wellborn API /UWI FlaId Name Well Status Incl ( °) MD (ftKB) Act Btm MB) ConornRlimps 501032011600 KUPARUK RIVER UNIT PROD 55.59 3,800.00 9,700.0 Comment H2S (ppm) Date Annotation End Date 8B -0rd (ft) Rig Release Date - SSSV: LOCKED OUT Last WO: 40.29 10/1 /1989 Welt Conti] - 2Kr13, 4202017121.07 PM Schematic - Actual Annotation Depth (ftHB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,392.0 3/15/2011 Rev Reason: CEMENT PLUG Imosbor 4/20/2011 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 36.0 115.0 115.0 62.50 H HANGER, 31 Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 35.0 3,848.9 2,913.2 3611 J-55 BTC Casing PRODUCTION r 1 11 J-55 BTC Details Tubing Strings Tubing Description Stnng 0 . String ID Top (ftKB) Set Depth (f.. Set Depth (TVD) . Strtng V4t String .. String Top Thrd , 16.1 TUBING 3 1/2 2.992 31.1 9,149.3 6,153.4 9.30 J-55 EUE8rdABMOD Completion CONDUCTOR, 36115 f Top Depth J _ •, - 3.500 TP1P OMB) i 1 !tern Description SAFETY VLV, I �� - 9,084.8 1 • 80-40 ' •' 1 111 • • • • 1 811 1•: 1 1 1 91 GAS LIFT, • • • • 2.80" • 1 : 11 2860 9,148.6 6,152.9 49.90 SOS BAKER SHEAR OUT 2.992 Other Top Depth 4 ,°. Description Comment Run Date ID (in) 1 50.10 1 SURFACE, 1 l HOLE, 35 -3,849 Perforations & Slots GAS LIFT i Dens 5,312 _ 1 1 11 1 r 11 1 ■ ■ _ 61 . 1 GAS LIFT, 8,827 I 9,284.0 9,318.0 6,240.1 '/ 4.0 180 . 4 CEMENTED 1 9,284 9,311 1 6,240 •11 RPERF 2.5" Titan :1. - GAS LIFT Hollow a - 1 7,269 Notes: General & Safety End Date Annotation GAS LIFT, 11/3/2010 NOTE: VIEW SCHEMATIC w /Kaska Schematic9.0 I I I T 7,835 GAS LIFT, 8,442 GAS LIFT, j 9,IFT T! PBR, 9 085 {L1.1 l PACKER, 9,099 III TBG Punches, 9,115 NIPPLE, 9,137 1 '. SOS, 9,149 A -9238 9,222 -9.238 \.. Mandrel Details _ a. \\ Top Depth Top _ Sort -- . s (TVD) Incl OD Valve Latch Size TRO Run RPERF, Stn Top (I8KB) ( B) 11 Make Model (in) Sery Type Type (In) (pail Run Date Com... 92849371 �. IPERF, 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 49, 9,28378 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 3 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK ' 0.000 0.0 4/17/1990 CEMENT PLUG, 9,115 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 7 9,039.9 6,083.3 50.83 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 PRODUCTION, 29-9,677 • • TD, 9,700 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 18, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 2K -13 Run Date: 4/16/2011 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 2K -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20116 -00 nI}'LK;it it (t 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. V - , rag-095— _ 5° Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.woo �) Date: Signed: „ 7 / • • EgarE ELAs[K(A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell R. Humphrey Production Engineering Specialist Alaska, Inc. \ CC\\../ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -13 Sundry Number: 311 -110 Dear Mr. Humphrey: APR 0 f 2011 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. Chair DATED this day of April, 2011. Encl. • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 March 31, 2011 REC EJ VED 6,g ) 4 2011 Dan Seamount AOGCC Commissioner R;agka Oi & Gas Cans. Commission State of Alaska, Oil & Gas Conservation Commission A:r 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 2K-13 from . injection to production for reservoir depressurization in regards to an upcoming CTD • sidetrack of this well planned for May 2011. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2K -13 (PTD 189 -095). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, ` Darrell R. Humphrey Attachments Sundry application Well schematic STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION APPLI ION FOR SUNDRY APPROVA 20 AAC 25.280 1. Type of Request Abandon Q Rug for RedriII r Ferforate Naw Pool r Repair w ell r Change Approved Program f Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension Operational Shutdow n ❑ Re -enter Susp. VVell r Stimulate r Alter casing r Other:INJ to PROD r • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development J j Exploratory ❑ 189 -095 3. Address: Stratgraphic r Service m 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20116 -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 PI 2K - 13 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25589, ALK 2675 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): 9700 • 6517. 9374' 6316' _ Casing Length Size MD _ TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3814 12 3849' 2918' PRODUCTION 9649 7 9677' 6519' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9222 -9238, 9284 -9318 6217 -6227, 6257 -6279 3.5 J - 9149 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PBR - BAKER 80-40 W /10' STROKE PBR MD= 9085 TVD= 6112 PACKER - BAKER HB PACKER MD= 9099 TVD= 6121 NIPPLE - OTIS XN NIPPLE MD= 9137 TVD= 6146 SOS - BAKER SHEAR OUT MD= 9149 TVD= 6153 SAFETY VLV - CAMCO TRDP - 1A SSSV. (LOCKED OUT 5/27/1994 MD= 1811 TVD= 1657 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/1/2011 Oil v, • 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: Darrell Humphrey /Bob Christesen Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature Phone: 659 -7535 Date 3 - 3 / • / / Commission Use Only Sundry Number:?] j .r 11 0 Conditions of approval: Notify Commission so that a representative may witness ✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED! Other: 4 �— V S 7 y AA 5`� cl. fti. - 4) /f C•r • 5 5 5 -E�t �O f d P c " in ( f r `f ra �v - y K / Ska & Gas Cats. Commie A rtairpiq Subsequent Form Required: APPROVED BY Approved by: 1 SF r COMMISSIONER THE COMMISSION Date: It Form 10 -403 Revised 1/201, Duplicate RBDMS APR 08 w / if Y. /( Su bmit � et( ORIGINAL ' ., // ' 1( , r 4•• ■ . 2K -13 " DESCRIPTION SUMMARY • OF PROPOSAL A CTD sidetrack on 2K -13 is planned for May of this year. A recent bottom -hole pressure survey confirmed that the bottom hole pressure is higher than normal in this area. The proposal has been made to depressurize 2K -13 and the surrounding area by converting the well to production. Required time for adequate depressurization is predicted anywhere from 1 to 2 months. By the middle or end of May the pressure should be reduced adequately to commence drilling operations. . - KUP 2K -13 C0110C0P11ll1p5 Vali i I Attributes Angle & MD TD A IaSk2 Inc re API /UWI Field Name Well Status ) MD (ftK Act Btm MKS) „.,,,,,,,,,,, > TP01032011600 ,KUPARUK RIVER UNIT INJ 55.59 ( 3,800.00 9,700.0 Comment H2S (ppm) Date Annotation End Date KBS3rd (ft) Rig Release Date wet cont. , 2K - 13 3/18/2011 953:03 AM - SSSV: LOCKED OUT ,Last WO: 40.29 10/1/1989 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag; SLM 9,392.0 3/15/2011 Rev Reason: TAG - Imosbor , 3/17/2011 - - 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 36.0 115.0 115.0 62.50 H HANGER, 31 ems lit wee Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth (TVD) ... String Wt... String ... String Top Thrd s SURFACE 95/8 8.765 35.0 3,848.9 2,913.2 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth ( /... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION Tubing Strings 7 6.151 28.7 9,677.3 6,502.1 26.00 J -55 BTC Tubing Description iption String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)._ String Wt... String ... String Top Thrd I TUBING 3 112 2.992 31.1 9,149.3 , 6,153.4 , 9.30 J - 55 EUE8rdABMOD CONDUCTOR, 36-115 ( Completion Details Top Depth (TVD) Top Incl Noml... Top (ftKB) (ftK81 1 ° ) , Item Description Comment , ID (in) s 31.1 31.1 -0.61 HANGER FMC GEN IV TUBING HANGER 3.500 II 1,811.2 1,657.0 44.72 SAFETY VLV CAMCO TRDP -1A SSSV. (LOCKED OUT 5/27 /1994) 2.812 SAFETY VLV, _ 9,084.8 6,111.9 49.98 PBR BAKER 80.40 w /10' Stroke PBR 3.000 1.811 9,098.6 6,120.7 50.03 PACKER BAKER HB PACKER 2.890 9,137.3 6,145.6 49.79 NIPPLE ' OTIS XN NIPPLE 2.750 GAS LIFT, 9,148.6 6,152.9 49.90 SOS BAKER SHEAR OUT 2.992 2,860 it Perforations & Slots Top (TVD) Btm (TVD) Dane Top (ftKB) atm (ft18) (ftKB) (ftKB) Zone Date I01,, Type Comment 9,222.0 9,238.0 6,200.1 6,210.4 C-4, 2K -13 1/9/2001 6.0 APERF 2.5" HSD PJ Chgs, 60 deg Phase 9,284.0 9,318.0 6,240.1 6,261.6 A-4, 2K -13 4/17/1990 4.0 IPERF 4.5" Casing Guns; 180 deg. Phase SURFACE, . 9,284.0 9,311.0 6,240.1 6,256.9 A-4, 2K -13 8/5/1990 4.0 RPERF 2.5" Titan Hollow St; 180 deg. Phase 35 -3,949 Notes: General & Safety Snot Illit End Date Annotation GAS 5, LIFT, 11/3/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 312 I GAS OF 1 6,627 It I GAS .2 9 T, I GAS LIFT, 7,935 IC- I I GAS LIFT, 8,4<2 I II GAS LIFT, 9,040 I I PBR, 9.065 PACKER, 9,099 I NIPPLE, 9,137 it I SOS, 9.149,. APE 238 II 9 ,222-9, 238 Mandrel Detai Top D th Top Port e p (TVD) Inc/ DO Valve Latch Size TRO Run Stn Top(ftKB) (RKB) (° ) Mak Model (IN Sery Type Type (in) Ipai) Ru n Date Corn... RPERF, 1 2,859.8 2 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/1 4/1991 5,2849,311 � IPERF, 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 9,2849,318 I I 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 6 8,441.6 5,7062 50.36 CAMCO MMG 1 112 GAS LIFT DMY RK 0,000 0.0 11/8/1991 7 9,039.9 6,083.3 50.83 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 PRODUCTION, 29 -9,677 N . TD, 9,700 • • siforE aT AsIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Ohlinger Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -13 Sundry Number: 311 -097 Dear Mr. Ohlinger: d ?til 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. L Chair S DATED this 3 / day o March, 2011. Encl. • • Nov Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED March 17, 2011 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission Aka Oit & Gas Cods. Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 `fcforage Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a sundry to plug the perforations in the A and C sands of Kuparuk Well 2K -13 utilizing cement. The plugging is being done as part of the pre -rig preparation for upcoming coiled tubing drilling (CTD) operations. Prior to cementing the 3 -1/2" Otis "XN" nipple at 9137' RKB will be milled out to 2.80" ID. The work is scheduled to begin in May /June 2011. The CTD objective will be to drill an A -sand trilateral injector. Permit to Drill applications for those laterals have been submitted separately. Attached to this Sundry application is an outline of job operations (including those of the CTD project). If you have any questions or require additional information please contact me at my office 907 - 265 -1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer STATE OF ALASKA c " " ECE1 1 ALASKOL AND GAS CONSERVATION COMMISSI • APPLICATION FOR SUNDRY APPROVA S `.. � ' ; �wi -// 0 AAC 25.280 1 '1' 1. Type of Request: Abandon r Rug for Redd! � /FF rforate New Pool r Repair w ell r Maskallifea Suspend _ Rug Perforations i / o f Perforate r FUII Tubing r ", r �,. t � jc s ion r Shutdown r Re -enter Susp. Well r Stimulate casing ' ►G Alter casin r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 189 -095 - 3. Address: 6. API Number: Stratigraphic r Service iv P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20116 -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 17 2K -13 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25589 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): 9700 - 6517 - 9600' 6449' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3814 9 -5/8" 3849' 2913' PRODUCTION 9649 7 9677' 6519' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9222'- 9238', 9284' -9318' 6200'- 6210', 6240' -6262' 3.5 J - 9149 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB PACKER MD= 9099 TVD= 6121 SAFETY VLV - CAMCO TRDP -1A SSSV MD= 1811 TVD= 1657 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service - 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: !'►�,"/ 4/11/2011 Oil Gas WDSPL r Suspended lir 16. Verbal Approval: Date: WINJ GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Printed Name James Ohlinger Title: Wells Engineer Signature „..... ."4-e_ G Phone:.//O' Date 3 /o? 'Y //,' Commission Use Only Sundry Number: t 1 - Y t 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test /Mechanical Integrity Test r Location Clearance Other: A 1 100 I) ?s, /30t S - z Soo Psi Ahit -- 7; -- s,< Cell-Lt.) Subsequent Form Required: /0 q 7_ APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: 3 1 Form MOMS s / O I G � N A � Submit in Duplicate • • • Application for Sundry to Plug Perforations KRU 2K -13 2K - 13 Sundry (10 - 403) Engineer: James Ohlinger CT Drilling Engineer (907) 265 -1102 The anticipated spud date for Nabors CDR -2AC to drill a CTD A -sand trilateral from well 2K -13 is May /June 2011. Summary of Operations: The 2K -13 original C and A -sand perforations will be cemented off prior to CTD drilling although A -sand injection will be replaced by the laterals drilled in the immediate vicinity. This will be a pilot hole with a whipstock exiting the 7" casing providing 3 laterals. Approximately 5,590 feet of total hole will be drilled and the intervals will be completed with slotted liners. In addition the 3 -1/2" Otis "XN" nipple located at 9137' RKB will be milled out to a 2.80" ID to allow a 2.80" window to be milled for CTD operations. Pre - Rig Work • Slickline: Dummy perf gun drift. Obtain SBHP. MIT -IA. • E -line: Run GR/CCL jewelry log / tie -in log (K1 Marker to Tubing Tail). Shoot holes in the 31/2" tubing below the Baker HB Retrievable Packer from 9115' to 9120' RKB. • Coil: Mill out the XN- nipple at 9137' RKB to 2.80" , • Coil: Lay in cement plug from PBTD up to the perf holes @ 9115' RKB. • Slickline: Tag TOC and PT to 1500 psi. • Prepare well site for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. Pull BPV 2. Mill cement pilot hole. • 3. Set top of whipstock at 9,255' MD. 4. Mill 2.80" window at 9,255'. 5. 2K -13A Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 12,200' MD b. Run the 2 slotted liner with an aluminum liner top billet from TD to 9,950' MD. 6. 2K -13AL1 Lateral a. Kick off of the aluminum liner top billet at 9,950' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 11,700' MD c. Run the 2 slotted liner with an aluminum liner top billet from TD to 9,355' MD. Page 2 of 3 3/22/2011 • • Application for Sundry to Plug Perforations KRU 2K -13 7. 2K -13BL2 Lateral a. Kick off of the aluminum liner top billet at 9,355' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 10,250' MD c. Run the 2 slotted liner from TD to 9,115' MD, inside the 3-1/2" tubing tail of the mother -bore. Reservoir Pressure 2K -13 measured 4078 psi at 9100' MD (5968' TVD; 13.14 ppg EMW) on January 14, 2011. The well has been shut in from injecting since January and will shortly be put on production to further reduce the pressure before CTD operations commence. Per 4t mi l/ w/ dame 5 Nil*. -r p � f' re � S w 1 ' /1 �e d�� ' f /Pc 7 0 f .�ir' / 4 ✓ PC 7 � 14 ,y 1" TkL , g6-- 1 fait q S we% q 5 e f'0% % ec l' c y ,S vffor'` 1 ? - gdJa tpnT v /7 6 /e ?c /'f 7/ er {re clipt264, ey e i</ y7 "^f' li er kia7 OO' 70 olI for ..‘Gir y/GfCA CC�CI�ief, {� o^1 t, Or ' ' lae Page 3 of 3 3/22/2011 A r, / KUP 2K -13 Co tocoPhil ! } Well Attributes Max Angle & MD TD _(B) Wellborn APUUWI Field Name Well Status Inc/ el MD (HKB) Act Bhn (IRKS) l ,� 501032011600 [KUPARUK RIVER UNI l INJ 55.59 3800 00 9,700.0 Comment H25 (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV LOCKED OUT Last WO. 417.24 10/1/1989 Wei) COnhg SrJ'ier�i 9714 Otual 3gA:c.A 0t19'55'83AM _ Annotation (Depth (Rw•c• KB Annotation -- D ) (End Date ( Last Mod -..'E End Date Last Canis Des Tag9 P ' SLM Lion 9,392 Str 0 9 O.. ' 3/15/2011 Stang ID II Rev To P( Reason ) P (TVD) AG Set De ) Imosbor 3,1712011 i;:21111111 Casing Strings String Wt.. String String Top Thrd , - CONDUCTOR 16 15 002 36.0 th (f... Set Depth ND )... 9 9 9 115 0 115 0 6250 H HANGER, 31 - "NM Casirg Des Strtn 0... String 6 ... Top 3 Set Depth (r.. Set Depth (ND) ... String W[... String String Top Thrd / S 95/8 S 765 35.0 3,848.9 2,913.2 36.00 J 55 BTC Casing Description String 0... String ID ... Top (ftK8) Set Depth (f.. Set Depth (ND) .. : String Wt... String ... String Top Thrd PRODUCTION 7 6151 287 9,677.3 6,502.1 2 6.00 3 BTC TUBING P 3 2.992 0.. String ID ... Top 311 ftK8 ) 9,149 - Set Depth (f 6,153.4 Set Depth (ND) . Strip 9.30 Wt.. String s UE8rdABMO D Tubing i ti n Str n Tubing Description EUESro Thrd ... . . I ' Fl Completion Details Top Depth CONDUCTOR, 36-115 (ND) Top Inc! Top (tI B) (ftK8) (1 Item Description _ _ Comment ID (In) 31.1 31.1 -0.61 HANGER FMC GEN IV TUBING HANGER 3.500 i t 1,811.2 1,657.0 44.72 SAFETY VLV CAMCO TRDP -1A SSSV. (LOCKED OUT 5/27/1994) 2.812 SAFETY VLV, 9,084.8 6,111.9 49.98 PBR BAKER 80 -40 w /10' Stroke PBR 3.000 1.811 9,098.6 6,120.7 50.03 PACKER BAKER HB PACKER 2.890 9,137.3 6,145.6 4939 NIPPLE OTIS XN NIPPLE 2.750 GAS LIFT. _.. 9,148.6 6,152.9 49.90 SOS BAKER SHEAR OUT 2 -992 2,860 Perforations & Slots Shot 1 i Top (TVD) Btm (TVD) Dens 1 ' l Top (ftKB) Btm (fUCBL (11KB) (ftK8) Zone Date (oh ... Type Comment 9,222.0 9,238.0 6,200.1 6,210.4 C-4, 2K -13 1/9/2001 6.0 APERF 2.5" HSD PJ Chgs, 60 deg Phase 9.284-0 9,318.0 6,240.1 6261.6 A-4, 2K -13 4/17/1990 4.0 IPERF 4.5" Casing Guns; 180 deg. Phase ; } 9,2840 9,311.0 6,2401 6.256.9 A-4, 2K -13 8/5/1990 4. ) 0 RF 2.5" Titan 180 deg. Phase SURFACE, PER Hollow St; 18 -- 35 -3,849 Notes: General & Safety End Date Annotation GASLI5,312 FT, ^: , 11/32010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1. GAS LIFT, -- 6,627 GAS LIFT, 7,289 s. lilt GAS LIFT, 7,835 ::.` GAS LIFT, 8,442 GAS LIFT, 9,040 PBR, 9,085 I. t -] PACKER, 9,099 -- • NIPPLE, 9,137 il ) t SOS, 9,149 ` oL C !rJ ' MI ''. T APERF.-___-.. 9,222-9,238 I Mandrel Details Top Depth Top ', '. Port (ND) Inc] OD Valve Latch Size TRO Run Stn Top ff9OB) (NW) I') Make Corn... Model (in) Sere Type Type (in) (Psi) Run Date C RPERF, 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 9,284 - 9,311 - IPERF, - 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 9,284 - 9,316 3 6,626.7 4,577.9 51.81 MERLA TMPD 1' GAS LIFT DMY BK 0.000 0.0 4/17/1990 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.011/8/1991 6 8,441.6 5,706.2 50.36 CAMCO MMG -2 1 12 GAS LIFT DMY RIO 0.000 0.0 11/8/1991 I 7 9,039.9 6,083.3 50.83 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 11/9/1991 PRODUCTION, 74t 29 -9,677 TO 9,700 -- • • F. (----' irir., WELL LOG TRANSMITTAL PROACTIVE DIAgNosric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 AR ZU Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road c) l f59 _p 9 3 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 00150a 1) Caliper Report 16- MAr-11 2K-13 1 Report / EDE 50-103-20116-00 2) R E I D - TAR 2Th Signed : Date : Print Name:; t'" PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL : pdsarachorage(a.nemorvIoc.cam WEBSITE : www.memorVIoq.com I I • i Memory Multi - Finger Caliper VS Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2K -13 Log Date: March 16, 2011 Field: Kuparuk Log No.: 10140 State: Alaska I Run No.: 1 API No.: 50- 103 - 20116 -00 Pipel Desc.: 3.5" 9.3 lb. J-55 EUE 8RD AB MOD Top Log Intvll: Surface Pipel Use: Tubing Bot. Log Intvll: 9,149 Ft. (MD) I Pipe2 Desc.: 7" 26 lb. J -55 BTC Pipe2 Use: Production Casing Top Log Intvll: 9,149 Ft. (MD) Bot. Log Intvl2: 9,384 Ft. (MD) Inspection Type : Pre -CTD Sidetrack Inspection I COMMENTS : This caliper data is tied into the shear -out sub at 9,149' (Driller's Depth). I This log was run to assess the condition of the tubing and production casing with respect to corrosive and mechanical damage prior to CTD sidetrack operations. I The caliper recordings indicate the 3.5" tubing appears to be in good to fair condition with respect to internal corrosive and mechanical damage, with a maximum wall penetration of 40% recorded in an isolated pit in joint 20 (632'). Wall penetrations ranging from 20% to 40% are recorded in 39 joints of 299 joints logged. Recorded damage appears as line of pits and isolated pitting. No significant cross - sectional wall loss or I.D. I restrictions are recorded. The caliper recordings indicate the 7" production casing logged appears to be in fair to poor condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 54% recorded in an area I of corrosion (9,366'). Recorded damage appears as general corrosion throughout the casing logged. Cross - sectional wall loss of 22% is recorded in area of corrosion at 9,166'. Heavy deposits restrict the I.D. to 4.80" at 9,366'. A 3 -D log plot of the caliper recordings across the 7" production casing logged and a graph illustrating I minimum recorded diameters on a joint-by-joint basis is included in this report. I 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS : I Isolated Pitting ( 40%) Jt. 20 @ 632 Ft. (MD) Isolated Pitting ( 32%) Jt. 23 @ 734 Ft. (MD) Isolated Pitting ( 30 %) Jt. 21 @ 649 Ft. (MD) Isolated Pitting ( 30 %) Jt. 32 @ 980 Ft. (MD) I Line of Pits ( 28 %) Jt. 19 @ 587 Ft. (MD) 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : I No significant areas of cross - sectional wall loss (> 13 %) are recorded. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : I No significant I.D. restrictions are recorded. I ProActive Diagnostic Services, Inc. / P.O, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com 111 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I • • I 7" CASING - MAXIMUM RECORDED WALL PENETRATIONS : Corrosion / Erosion ( 54 %) Jt. 8 @ 9,366 Ft. (MD) Corrosion / Erosion ( 43 %) Jt. 1 @ 9,151 Ft. (MD) I Corrosion / Erosion ( 34%) (25 %) Jt. 2 @ @ 9,159 Ft. (MD) Corrosion /Erosion Jt. 5 9,273 Ft. (MD) 7" CASING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : I Corrosion / Erosion ( 22 %) Jt. 2 @ 9,159 Ft. (MD) No other significant cross - sectional wall loss are recorded throughout the casing logged. 1 7" CASING - MAXIMUM RECORDED ID RESTRICTIONS : Heavy Deposits Minimum I.D. = 4.80" Jt. 8 @ 9,366 Ft. (MD) I No other significant I.D. restrictions are recorded throughout the casing logged. I I I I I I II I 1 I Field Engineer: E. Gustin Analyst: C. Lucasan Witness: R. Ober I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com I Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2K -13 Date : March 16, 2011 1 Description : Detail of Caliper Recordings Across 7" Casing Logged Comments Depth Max. Pen. ( %) Max. I.D. (ins.) 3-0 Log Image Map lft:240ft a 100 6 7 0° 90 180° 270° 0° Min. I.D. (ins.) 6 7 1 Nominal I.D. 6 7 9130 -- 1 3.5" Tubing .------A1 " � 9140 r NE _. -- IN 1 Joint 1 Corrosion / 9150 _ �,I■ _ ... Erosion ..-- II 9160 i 1 111 . __ __ ..., __ 1 ��w_1- waiLi 1 9170 7 1t1b.. r Joint 2 7 �rMEl�� Corrosion / 1 1411 -_ Erosion 9180 w 111111111101 �►7tl t �E 9190 • 11111 qh. Al 9200 1 �, .-m li t . il 9210 — / . 4 Joint3 ' _. I Erosion 9220 - - - -- Perforations �t7 o- ��rF 9230 �r�r _ IIiil_ 9240 ' ;� Joint 4 ,Z � - Perforations -I I Marker Joint 114 i Perforations 9250 W — . Corrosion iii a: 1 Erosion i "� 9260 � — Joints —1- 1—j-V-1-4—i-4-: I Marker Joint ± s Corrosion 9270_ . ]). ‘ , Erosion 44 iiiimmi a2an 1 1 __ • • M � 7iiii �71 290 Fi 9 � i 1 :i !!ii! Joint 6 l�siti!! _ ,. Perforations ��I��l.��.=JI .� r...w, Corrosion 'G_INIlI♦lI =viii Erosion on ■ i nin g.. lii - . Heavy Deposits 9300 - �'iiiii - fix - 'iliiii ------- - � l iii�r ._.••:,, v.......,., _L.A. Min I.D. = 5.49' _ ��iliiiL�. - 9310 �� — liiii� - - ligtitilliiil .z� P Dratlon�,, _ .. .. 9320 � -- !_ li ' � �� �liiii _= � a'111 �iiii! li Mt IMIIIIIIIIIMIIMW-'=.AIIII 9330 ip--,„ili iG iil! _= � .t`•-2= Joint 7 �-''iii Perforations __ � iili - iii Erosion 9340 -.... i�� – Heavy Deposits = =�i�.ir - 11 1111 . 1111 W IMIIIE'IIIIIIIIIIIIIII • Min I.D. = 5.09" liG1F..� irk - Clliil�1! rdrim 9350 iii ������ s- iillP� M iiil Z =`6-= _ ._ 9360 Ad � ii_w!!ar— _' �. �. Amos aM11.0•111 — _ Joint 8 J • Corrosion ! 9370 Erosion .__ _ 7iii! �� i 9380 Mi w 7 . 1 Nominal I.D. 6 7 I 6 Min. I.D. (ins.) 7 Comments Depth Max. Pen. ( %) Max. I.D. (ins.) 3-0 Log Image Map 1ft:240ft 0 100 6 7 0° 0° 90° 180° 270° 0° i 1 1 1 1 1 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 Pipe 1 3.5 in (31.1' - 9149.1') Well: 2K -13 Pipe 2 7 in (9149.1' - 9362.2') Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: March 16, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 ._,._.. 36 1 25 769 50 1527 1 75 2308 GLM 1 100 3080 125 4 3839 150 4605 1 GLM 2 a/ 175 �• 5382 la E Z 200 ` 6143 t Y 11 3 in 225 6915 ir GLM 4 GLM 5 ' 7 1 1 1 7714 GLM 6 I 1- 275 ^ 8518 1 GLM 7 1 • 9149 8 9362 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) i 1 1 Bottom of Survey = 8 1 1 1 ! • 1 Report Overview ti S ,. Body Region Analysis I Well: 2K-13 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J-55 EUE 8RD ABMOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 EUE 8RD ABMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) 300 Penetration body Metal loss body 0 50 100 250 0 F 1 200 Mil . 150 - 1 100 50 __ 0 I 0 to 20 to 40 to over 20% 40% 85% 85% GLM 1 99 Number of joints analysed (total = 299) I 259 39 1 0 149 I Damage Configuration ( body ) 'MOM GLM 2 I 1OO ---- 199 ---- GLM 3 100 ---- 50 GLM 4 ii 0 ---- GLM 5 249 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole GLM 6 I Number of joints damaged (total = 245) GLM 7 244 0 1 0 0 Bottom of Survey = 292.2 1 1 1 1 1 0 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Iris.) (Ins.) % (Ins.) 0 50 100 I 0.1 31 0 0.03 11 3 2.96 Pup 1 36 004 0.04 15 4 2.92 Shallow Pitting. Lt. Deposits. 2 66 0 0.03 11 5 2.92 Lt. Deposits. 3 96 0.06 0.04 15 6 2.92 Shallow Line of Pits. Lt. Deposits. 4 127 0 0.04 18 3 2.92 Shallow Pitting. Lt. Deposits. 5 157 0 0.03 11 3 2.92 Lt. Deposits. 6 189 0 0.03 11 2 2.92 Lt. Deposits. 7 219 0 0.03 10 4 2.92 Lt. Deposits. 8 250 0 0.02 9 3 2.89 Lt. Deposits. I 9 281 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. 10 312 0 0.05 19 3 2.93 Shallow Line of Pits. Lt. Deposits. 11 343 0 0.04 17 4 2.93 Shallow Line of Pits. 12 373 0 0.03 12 4 2.92 Lt. Deposits. 13 404 0 0.03 12 3 2.94 Shallow Pitting. 14 435 0 0.04 14 5 2.91 Shallow Pitting. Lt. Deposits. 15 466 0 0.04 16 6 2.90 Shallow Pitting. Lt. Deposits. 16 497 0 0.07 26 4 2.91 Line of Pits. Lt. Deposits. I 17 526 0 0.04 18 4 2.92 Shallow Pitting. Lt. Deposits. 18 556 0.03 0.04 17 5 2.93 Shallow Pitting. Lt. Deposits. 19 586 0 0.07 28 4 2.92 Line of Pits. Lt. Deposits. 20 617 0 0.10 40 3 2.94 Isolated Pitting. 21 647 0 0.08 30 4 2.91 Line of Pits. Lt. Deposits. I 22 678 0 0.04 18 3 2.91 Shallow Line of Pits. Lt. Deposits. 23 709 0 0.08 32 2 2.93 Isolated Pitting. 24 740 0.03 0.05 19 4 2.92 Shallow Line of Pits. Lt. Deposits. 25 769 0 0.07 26 3 2.92 Line of Pits. Lt. Deposits. 26 800 0 0.06 23 4 2.92 Line of Pits. Lt. Deposits. 27 831 0 0.04 14 4 2.91 Shallow Pitting. Lt. Deposits. 28 860 0 0.04 16 2 2.93 Shallow Pitting. 29 889 0 0.05 19 4 2.92 Shallow Pitting. Lt. Deposits. 30 920 0.03 0.04 14 4 2.92 Shallow Pitting. Lt. Deposits. I 31 948 0 0.03 11 3 2.92 Lt. Deposits. 32 978 0 0.08 30 4 2.92 Isolated Pitting. Lt. Deposits. 33 1009 0.05 0.07 26 7 2.92 Isolated Pitting. Lt. Deposits. 34 1038 0 0.04 17 4 2.90 Shallow Pitting. Lt. Deposits. I 35 1069 0.04 0.05 19 7 2.91 Shallow Pitting. Lt. Deposits. 36 1099 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. 37 1130 0 0.04 15 2 2.90 Shallow Pitting. Lt. Deposits. 38 1160 0 0.05 18 3 2.90 Shallow Pitting. Lt. Deposits. I 39 1191 0 0.05 21 4 2.90 Line of Pits. Lt. Deposits. 40 1222 0 0.04 15 3 2.89 Shallow Pitting. Lt. Deposits. 41 1253 0 0.04 17 4 2.90 Shallow Line of Pits. Lt. Deposits. 42 1284 0 0.04 17 4 2.89 Shallow Pitting. Lt. Deposits. I 43 1314 0 0.04 18 3 2.92 Shallow Line of Pits. Lt. Deposits. 44 1345 0 0.04 17 3 2.88 Shallow Line of Pits. Lt. Deposits. 45 1375 0.03 0.05 19 8 2.89 Shallow Pitting. Lt. Deposits. 46 1405 0 0.05 21 2 2.92 Line of Pits. Lt. Deposits. 47 1434 0 0.07 26 5 2.92 Line of Pits. Lt. Deposits. I 48 1466 0 0.06 24 4 2.92 Line of Pits. Lt. Deposits. 49 1497 0.03 0.05 20 3 2.90 Shallow Line of Pits. Lt. Deposits. I rati Body Metal Loss on Body Page 1 Penet 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 1527 0 0.07 26 4 2.87 Line of Pits. Lt. Deposits. ■ 51 1559 0 0.04 16 3 2.91 Shallow Pitting. Lt. Deposits. ■ 52 1589 0.04 0.05 20 3 2.92 Shallow Line of Pits. Lt. Deposits. • 53 1620 0 0.07 27 3 2.91 Line of Pits. Lt. Deposits. ■ 54 1650 0 0.06 25 5 2.87 Line of Pits. Lt. Deposits. ■ I 55 1681 0.03 0.06 25 3 2.90 Line of Pits. Lt. Deposits. ■ 56 1712 0.04 0.06 22 5 2.89 Line of Pits. Lt. Deposits. ■ 57 1743 0 0.05 18 4 2.89 Shallow Line of Pits. Lt. Deposits. 58 1773 0.04 0.05 19 3 2.91 Shallow Line of Pits. Lt. Deposits. ■ 1 58.1 1804 0.03 0.04 18 2.93 Pup Shallow Pitting. Lt. Deposits. 58.2 1812 0 0 0 0 2.81 Camco TDRP -1 A SSSV 59 1823 0.03 0.05 19 4 2.89 Shallow Line of Pits. Lt. Deposits. ■ 60 1854 0 0.06 24 4 2.91 Isolated Pitting. Lt. Deposits. ■ I 61 1885 0 0.04 17 3 2.91 Shallow Line of Pits. Lt. Deposits. ■ 62 1916 0.05 0.05 20 7 2.92 Line of Pits. Lt. Deposits. 63 1944 0 0.05 19 3 2.92 Shallow Pitting. Lt. Deposits. ■ 64 1975 0 0.05 21 2 2.94 Line of Pits. ■ 65 2004 0.04 0.05 19 3 2.92 Shallow Line of Pits. Lt. Deposits. • I 66 2035 0 0.05 18 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 67 2065 0 0.04 14 3 2.91 Shallow Pitting. Lt. Deposits. ■ 68 2096 0.04 0.04 14 2 2.92 Shallow Line of Pits. Lt. Deposits. 69 2126 0 0.05 18 4 2.91 Shallow Pitting. Lt. Deposits. ■ I 70 2157 0.04 0.03 13 3 2.91 Shallow Pitting. Lt. Deposits. ■ 71 2187 0 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. • 72 2218 0 0.05 19 4 2.92 Shallow Pitting. Lt. Deposits. ■ 73 2248 0 0.06 25 13 2.90 Isolated Pitting. Lt. Deposits. I 74 2278 0 0.04 17 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ 75 2308 0 0.04 15 4 2.90 Shallow Pitting. Lt. Deposits. ■ 76 2340 0 0.05 19 2 2.92 Shallow Line of Pits. Lt. Deposits. • 77 2369 0 0.04 18 4 2.91 Shallow Pitting. Lt. Deposits. is I 78 2400 0 0.04 15 2 2.92 Shallow Pitting. Lt. Deposits. ■ 79 2430 0 0.04 15 2 2.93 Shallow Pitting. Lt. Deposits. ■ 80 2461 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. ■ 81 2492 0 0.04 17 3 2.90 Shallow Line of Pits. Lt. Deposits. 82 2521 0 0.05 20 3 2.92 Line of Pits. Lt. Deposits. s I 83 2552 0 0.04 18 3 2.92 Shallow Pitting. Lt. Deposits. ■ 84 2583 0 0.05 19 6 2.91 Shallow Line Corrosion. Lt. Deposits. ■ 85 2614 0 0.04 14 3 2.92 Shallow Pitting. Lt. Deposits. • 86 2644 0 0.05 20 3 2.93 Isolated Pitting. ■ I 87 2675 0 0.04 18 4 2.92 Shallow Pitting. Lt. Deposits. ■ 88 2705 0 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. • 89 2737 0 0.04 18 4 2.91 Shallow Line of Pits. Lt. Deposits. • 90 2767 0 0.03 13 4 2.93 Shallow Pitting. Lt. Deposits. • I 91 2798 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. II 2830 0 0.03 13 5 2.92 Shallow Pitting. Lt. Deposits. 92.1 2861 0 0 0 0 2.88 GLM 1 (Latch 2:00) I 93 2868 0 0.04 16 2 2.95 Shallow Line of Pits. • 94 2897 0.04 0.03 11 3 2.91 Lt. Deposits. • I 95 2926 0 0.04 14 2 2.92 Shallow Line of Pits. Lt. Deposits. IN 96 2957 0 0.04 18 2 2.92 Shallow Pitting. Lt. Deposits. ration I Metal Loss Body Page 2 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) lipset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 97 2988 0 0.04 17 9 2.91 Shallow Pitting. Lt. Deposits. 98 3018 0 0.04 14 5 2.93 Shallow Pitting. Lt. Deposits. ■ 99 3049 0.04 0.06 22 3 2.90 Line of Pits. Lt. Deposits. ■ 100 3080 0 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. • 101 3109 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. ■ 102 3141 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. • 103 3171 0 0.03 13 3 2.91 Shallow Pitting. Lt. Deposits. ■ 104 3201 0 0.03 12 4 2.91 Lt. Deposits. ■ 105 3232 0 0.04 17 2 2.92 Shallow Line of Pits. Lt. Deposits. • 1 106 3263 0.03 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. ■ 107 3293 0 0.04 15 3 2.92 Shallow Pitting. Lt. Deposits. ■ 108 3322 0 0.04 15 3 2.88 Shallow Line of Pits. Lt. Deposits. • 109 3352 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 110 3383 0 0.04 16 4 2.91 Shallow Pitting. Lt. Deposits. ■ 111 3413 0 0.03 11 3 2.92 Lt. Deposits. ■ 112 3444 0 0.03 11 4 2.90 Lt. Deposits. ■ 113 3474 0 0.02 9 2 2.92 Lt. Deposits. ■ I 114 3505 115 3535 0 0.04 14 2 2.91 Shallow Pitting. Lt. Deposits. ■ 0 0.04 15 3 2.91 Shallow Pitting. Lt. Deposits. ■ 116 3565 0.04 0.04 15 2 2.90 Shallow Line of Pits. Lt. Deposits. • 117 3596 0.03 0.03 12 6 2.92 Shallow Pitting. Lt. Deposits. ■ 118 3626 0 0.03 11 3 2.91 Lt. Deposits. ■ I 119 3656 0 0.04 16 2 2.92 Shallow Pitting. Lt. Deposits. ■ 120 3687 0 0.03 11 2 2.90 Lt. Deposits. ■ 121 3717 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. • 122 3748 0 0.03 13 3 2.91 Shallow Pitting. Lt. Deposits. • I 123 3778 0 0.03 13 4 2.91 Shallow Pitting. Lt. Deposits. ■ 124 3810 0 0.04 18 3 2.92 Shallow Line of Pits. Lt. Deposits. ■ 125 3839 0 0.04 17 3 2.91 Shallow Pitting. Lt. Deposits. • 126 3871 0 0.04 18 3 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 127 3901 0 0.04 15 3 2.91 Shallow Line of Pits. Lt. Deposits. ■ 128 3932 0 0.03 13 2 2.94 Shallow Pitting. ■ 129 3962 0 0.04 14 4 2.91 Shallow Pitting. Lt. Deposits. ■ 130 3994 0 0.02 9 3 2.90 Lt. Deposits. • 131 4024 0 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. • I 132 4055 0 0.03 12 2 2.92 Lt. Deposits. I. 133 4086 0 0.07 26 3 2.91 Line of Pits. Lt. Deposits. ■ 134 4114 0 0.04 14 3 2.91 Shallow Pitting. Lt. Deposits. • 135 4144 0 0.04 14 2 2.92 Shallow Line of Pits. Lt. Deposits. ■ I 136 4175 0 0.04 16 2 2.93 Shallow Pitting. Lt. Deposits. ■ 137 4206 0 0.03 11 3 2.92 Lt. Deposits. • 138 4236 0 0.04 14 3 2.91 Shallow Pitting. Lt. Deposits. • 139 4267 0 0.05 20 4 2.91 Isolated Pitting. Lt. Deposits. ■ I 140 4299 0 0.04 17 4 2.92 Shallow Pitting. Lt. Deposits. ■ 141 4329 0.03 0.04 18 6 2.91 Shallow Pitting. Lt. Deposits. 142 4360 0 0.03 12 2 2.93 Lt. Deposits. • 143 4390 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. ■ I 144 4421 0 0.03 13 4 2.89 Shallow Pitting. Lt. Deposits. 11 145 4452 0 0.03 12 4 2.92 Shallow Pitting. Lt. Deposits. • ■ 146 4482 1) 0.03 12 3 2.90 Shallow Pitting. Lt. Deposits. rat I Metal Loss ion Body 1 Page 3 Penet 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 147 4513 0 0.03 13 3 2.92 Shallow Line of Pits. Lt. Deposits. • 148 4543 0 0.03 13 4 2.91 Shallow Pitting. Lt. Deposits. • ■ 149 4575 0 0.04 16 2 2.91 Shallow Line of Pits. Lt. Deposits. • 150 4605 0 0.03 10 3 2.90 Lt. Deposits. • 151 4636 0 0.04 16 3 2.90 Shallow Line of Pits. Lt. Deposits. ■ I 152 4666 0 0.03 , 13 4 2.91 Shallow Line of Pits. Lt. Deposits. • 153 4697 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. ■ 154 4728 0 0.03 12 3 2.92 Lt. Deposits. ■ 155 4759 0 0.03 13 4 2.89 Shallow Pitting. Lt. Deposits. • 1 156 4790 0.03 0.03 13 3 2.92 Shallow Pitting. Lt. Deposits. • 157 4821 0 0.03 11 3 2.90 Lt. Deposits. ■ 158 4850 0 0.03 12 3 2.90 Lt. Deposits. ■ 159 4882 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. • I 160 4912 0 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. • 161 4943 0 0.03 12 4 2.90 Shallow Pitting. Lt. Deposits. • ■ 162 4974 0 0.04 17 3 2.91 Shallow Line of Pits. Lt. Deposits. • 163 5006 0 0.03 10 2 2.90 Lt. Deposits. ■ 164 5036 0 0.03 11 3 2.91 Lt. Deposits. • 165 5067 0 0.05 20 5 2.89 Line of Pits. Lt. Deposits. ■ 166 5098 0 0.03 12 3 2.91 Shallow Pitting. Lt. Deposits. ■ 167 5128 0 0.03 12 4 2.89 Lt. Deposits. • 168 5160 0 0.04 15 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ I 169 5190 0 0.04 17 4 2.89 Shallow Line of Pits. Lt. Deposits. • 170 5220 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. ■ 171 5251 0 0.04 14 3 2.91 Shallow Pitting. Lt. Deposits. ■ 172 5282 0 0.04 14 5 2.92 Shallow Pitting. Lt. Deposits. 172.1 5313 0 0 0 0 2.89 GLM 2 (Latch 5:30) d I 173 5320 0.03 0.06 23 7 2.90 Line of Pits. Lt. Deposits. 174 5350 0 0.03 11 3 2.92 Lt. Deposits. • 175 5382 0 0.03 12 4 2.92 Lt. Deposits. • 176 5412 0 0.03 10 3 2.93 Lt. Deposits. • 177 5443 0 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. • ■ 178 5474 0 0.03 11 4 2.92 Lt. Deposits. • 179 5505 0 0.03 13 4 2.91 Shallow Pitting. Lt. Deposits. • 180 5535 0 0.03 12 3 2.94 Shallow Pitting. ■ I 181 5566 0.03 0.04 14 4 2.92 Shallow Line of Pits. Lt. Deposits. • 182 5597 0 0.03 11 2 2.92 Lt. Deposits. ■ 183 5628 0 0.03 12 4 2.91 Shallow Pitting. Lt. Deposits. • 184 5658 0 0.04 15 3 2.90 Shallow Pitting. Lt. Deposits. • I 185 5690 0 0.03 12 4 2.91 Shallow Pitting. Lt. Deposits. • 186 5720 0 0.03 13 4 2.90 Shallow Pitting. Lt. Deposits. • ■ 187 5749 0 0.03 12 2 2.92 Lt. Deposits. ■ 188 5779 0 0.03 10 4 2.89 Lt. Deposits. ■ I 189 5807 0 0.04 14 3 2.90 Shallow Pitting. Lt. Deposits. • 190 5838 0 0.03 11 2 2.92 Lt. Deposits. ■ 191 5869 0 0.04 14 2 2.90 Shallow Pitting. Lt. Deposits. • 192 5899 0 0.03 11 2 2.92 Lt. Deposits. IN 193 5930 0 0.03 13 4 2.92 Shallow Pitting. Lt. Deposits. ■ I 194 5961 0 0.02 9 3 2.90 Lt. Deposits. IN 195 5992 0 0.03 12 1 2.90 Shallow Pitting. Lt. Deposits. Penetrat Body I Metal Loss ion Body Page 4 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 196 6022 0 0.03 10 �1 2.88 Lt. Deposits. 197 6052 0 0.03 11 1 2.92 Lt. Deposits. 198 6082 0.03 0.04 17 4 2.91 Shallow Line of Pits. Lt. Deposits. 199 6112 0 0.03 12 4 2.91 Shallow Pitting. Lt. Deposits. ■ 200 6143 0.04 0.03 11 6 2.91 Lt. Deposits. ■ I 201 6173 0 0.05 20 5 2.89 Line of Pits. Lt. Deposits. ■ 202 6201 0 0.05 19 3 2.91 Shallow Line of Pits. Lt. Deposits. 203 6232 0 0.04 14 4 2.90 Shallow Pitting. Lt. Deposits. ■ 204 6263 0 0.03 13 4 2.88 Shallow Pitting. Lt. Deposits. ■ I 205 6293 0 0.03 12 4 2.89 Lt. Deposits. ■ 206 6324 0 0.04 15 3 2.71 Shallow Pitting. Deposits. 207 6355 0 0.03 13 3 2.88 Shallow Pitting. Lt. Deposits. 208 6386 0 0.03 11 4 2.89 Lt. Deposits. I 209 6416 0 0.03 11 3 2.89 Lt. Deposits. 210 6445 0 0.04 14 2 2.88 Shallow Pitting. Lt. Deposits. 211 6475 0 0.04 15 3 2.89 Shallow Pitting. Lt. Deposits. 212 6506 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. 213 6537 0 0.05 19 4 2.89 Shallow Line of Pits. Lt. Deposits. I 214 6568 0.05 0.04 15 3 2.90 Shallow Pitting. Lt. Deposits. 215 6598 0 0.04 14 3 2.88 Shallow Pitting. Lt. Deposits. 215.1 6628 0 0 0 0 2.85 GLM 3 (Latch @ 2:30) 216 6634 0 0.04 14 3 2.88 Shallow Pitting. Lt. Deposits. I 217 6665 0.03 0.04 15 7 2.91 Shallow Line of Pits. Lt. Deposits. i 218 6695 0.03 0.03 13 4 2.89 Shallow Pitting. Lt. Deposits. 219 6726 0.01 0.04 15 3 2.89 Shallow Line of Pits. Lt. Deposits. 220 6757 0 0.04 15 2 2.90 Shallow Pitting. Lt. Deposits. I 221 6788 0.06 0.04 16 7 2.90 Shallow Pitting. Lt. Deposits. 1 222 6818 0 0.03 11 3 2.87 Lt. Deposits. 223 6851 0 0.03 11 2 2.86 Lt. Deposits. 224 6883 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. I 225 6915 0 0.03 11 2 2.87 Lt. Deposits. 226 6948 0 0.03 13 3 2.87 Shallow Pitting. Lt. Deposits. 227 6980 0 0.04 16 4 2.87 Shallow Line of Pits. Lt. Deposits. 228 7011 0 0.04 15 2 2.86 Shallow Pitting. Lt. Deposits. 229 7044 0 0.03 13 2 2.85 Shallow Pitting. Lt. Deposits. I 230 7076 0.03 0.04 15 4 2.85 Shallow Pitting. Lt. Deposits. ■ 231 7109 0 0.03 12 2 2.88 Shallow Pitting. Lt. Deposits. 232 7141 0 0.04 15 2 2.89 , Shallow Pitting. Lt. Deposits. 233 7174 0 0.04 14 3 2.88 Shallow Pitting. Lt. Deposits. I 234 7206 0 0.04 17 1 2.85 Shallow Pitting. Lt. Deposits. 235 7239 0 0.03 11 4 2.91 Lt. Deposits. 235.1 7269 0 0 0 0 2.86 GLM 4 (Latch @ 11:30) 236 7276 0 0.04 15 3 2.90 Shallow Line of Pits. Lt. Deposits. • 1 237 7308 0 0.05 20 3 2.86 Isolated Pitting. Lt. Deposits. ■ 238 7340 0 0.03 13 2 2.85 Shallow Pitting. Lt. Deposits. 239 7373 0 0.03 12 4 2.87 Shallow Pitting. Lt. Deposits. ■ 240 7405 0 0.03 12 2 2.85 Shallow Pitting. Lt. Deposits. 241 7437 0 0.05 20 4 2.86 Shallow Pitting. Lt. Deposits. ■ I 242 7469 0 0.03 13 3 2.88 Shallow Pitting. Lt. Deposits. 243 7500 0 0.04 14 4 2.89 Shallow Pitting. Lt. Deposits. Penetration Body 1 I I Metal Loss Body Page 5 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) t /psc t Body % Loss I.D. Comments (% wall) (Inc.) (Ins.) % (Ins.) 0 50 100 I 244 7531 0 0.04 17 4 2.87 Shallow Line of Pits. Lt. Deposits. ■ 245 7561 0.03 0.04 14 4 2.88 Shallow Pitting. Lt. Deposits. • 246 7591 0 0.04 14 3 2.88 Shallow Pitting. Lt. Deposits. ■ 247 7621 0 0.06 22 5 2.88 Line of Pits. Lt. Deposits. a 248 7652 0 0.03 11 3 2.90 Lt. Deposits. ■ I 249 7683 0 0.04 17 3 2.89 Shallow Line of Pits. Lt. Deposits. ■ 250 7714 0 0.04 18 3 2.87 Shallow Line of Pits. Lt. Deposits. ■ 251 7743 0 0.03 12 4 2.87 Shallow Pitting. Lt. Deposits. • 252 7774 0 0.04 14 2 2.88 Shallow Pitting. Lt. Deposits. ■ I 253 7804 0.04 0.03 11 2 2.90 Lt. Deposits. 253.1 7834 0 0 0 0 2.84 GLM 5 (Latch @ 10:30) I 254 7842 (1 0.04 14 3 2.87 Shallow Pitting. Lt. Deposits. ■ 255 7873 0.04 0.04 15 4 2.88 Shallow Line of Pits. Lt. Deposits. ■ I 256 7904 0 0.06 22 6 2.88 Isolated Pitting. Lt. Deposits. ■ 257 7935 0 0.04 17 4 2.89 Shallow Line of Pits. Lt. Deposits. ■ 258 7965 0 0.03 11 3 2.88 Lt. Deposits. • 259 7996 0 0.03 12 2 2.89 Shallow Pitting. Lt. Deposits. ■ 260 8026 0 0.03 13 i 2.89 Shallow Pitting. Lt. Deposits. • I 261 8057 0 0.04 18 ; 2.87 Shallow Pitting. Lt. Deposits. ■ 262 8088 0 0.04 16 2 2.87 Shallow Pitting. Lt. Deposits. ■ 263 8118 0 0.04 16 4 2.88 Shallow Pitting. Lt. Deposits. IN 264 8150 0.03 0.03 13 5 2.87 Shallow Pitting. Lt. Deposits. ■ I 265 8179 0.04 0.04 16 4 2.86 Shallow Pitting. Lt. Deposits. ■ 266 8210 () 0.06 22 4 2.86 Isolated Pitting. Lt. Deposits. ■ 267 8241 0 0.03 11 2 2.88 Lt. Deposits. IN 268 8273 0 0.04 15 4 2.87 Shallow Pitting. Lt. Deposits. ■ I 269 8305 0 0.04 14 2 2.87 Shallow Pitting. Lt. Deposits. ■ 270 8338 0 0.03 13 2 2.87 Shallow Pitting. Lt. Deposits. ■ 271 8370 0 0.03 11 2 2.89 Lt. Deposits. • 272 8402 0 0.03 13 3 2.88 Shallow Pitting. Lt. Deposits. ■ I 272.1 8435 0 0.03 12 3 2.86 Pup Shallow Pitting. Lt. Deposits. 272.2 8441 0 0 0 0 2.88 GLM 6 (Latch @ 7:00) 272.3 8450 0 0.02 8 2 2.92 Pup Lt. Deposits. 273 8453 0 0.03 13 3 2.86 , Shallow Pitting. Lt. Deposits. ■ 274 8486 0 0.04 16 3 2.87 Shallow Line of Pits. Lt. Deposits. ■ I 275 8518 0 0.04 16 2 2.86 Shallow Line of Pits. Lt. Deposits. ■ 276 8550 0 0.04 16 2 2.86 Shallow Pitting. Lt. Deposits. ■ 277 8583 0 0.04 17 2 2.85 Shallow Pitting. Lt. Deposits. ■ 278 8614 0 0.05 18 3 2.86 Shallow Line of Pits. Lt. Deposits. ■ I 279 8647 0 0.03 13 2 2.88 Shallow Pitting. Lt. Deposits. • 280 8679 0 0.04 15 2 2.88 Shallow Pitting. Lt. Deposits. ■ 281 8712 0 0.05 21 4 2.87 Isolated Pitting. Lt. Deposits. • 282 8744 0 0.04 16 3 2.86 Shallow Line of Pits. Lt. Deposits. • 283 8776 0 0.04 17 4 2.85 Shallow Line of Pits. Lt. Deposits. ■ 284 8809 0 0.04 14 3 2.84 Shallow Pitting. Lt. Deposits. ■ IN 285 8841 0 0.04 15 4 2.85 Shallow Pitting. Lt. Deposits. 286 8873 0 0.04 16 3 2.84 Shallow Pitting. Lt. Deposits. ■ 287 8906 0 0.05 21 3 2.84 Line of Pits. Lt. Deposits. ■ I 288 8938 0 0.04 17 2 2.85 Shallow Pitting. Lt. Deposits. • 289 8971 0 0.05 21 6 2.85 Line of Pits. Lt. Deposits. I Metal Loss Penetration BoBody dy Page 6 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 EUE 8RD ABMOD Well: 2K -13 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (` wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 290 9002 0 0.05 19 5 2.84 Shallow Line of Pits. Lt. Deposits. 290.1 9035 0 0.05 19 3 2.89 Pup Shallow Line of Pits. Lt. Deposits. 290.2 9039 0 0 0 0 2.87 GLM 7 (Latch @ 7:00) 290.3 9048 0.0 i 0.03 11 3 2.88 Pup Lt. Deposits. 291 9052 0 0.05 19 5 2.86 Shallow Line of Pits. Lt. Deposits. illi I 291.1 9084 0 0.03 11 3 2.89 Pup Lt. Deposits. 291.2 9096 0 0 0 0 3.00 Baker 80-40 with 10' Stroke PBR 291.3 9098 0 0 0 0 2.89 Baker HB Packer 292 9104 0 0.04 15 5 2.86 Shallow Line of Pits. Lt. Deposits. r 1 292.1 9137 0 292.2 9149 0 0 0 0 2.75 Otis XN Nipple 0 0 0 2.99 SOS Baker Shear Out I Pt I Meta enetra l Loss ion BoBody dy 1 1 111 1 1 1 1 1 1 Page 7 1 1 1 • • 1 PDS Report Cross Sections I Well: 2K -13 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf J -55 EUE 8RD ABMOD Analyst: C. Lucasan 1 1 Cross Section for Joint 20 at depth 631.970 ft Tool speed = 48 Nominal ID = 2.992 ' Nominal OD = 3.5 Remaining wall area = 97% I Tool deviation = 10° / �� I • 1 / 1 , 1 1 ��� 1 Finger = 2 Penetration = 0.102 ins Isolated Pitting 0.10 ins. = 40% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 2K -13 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf J -55 EUE 8RD ABMOD Analyst: C. Lucasan 1 1 Cross Section for Joint 23 at depth 734.260 ft Tool speed = 50 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 98% �� Tool deviation = 12° / \\ I 1 1 111 1 / 1 \ / 1 Finger = 22 Penetration = 0.080 ins Isolated Pitting 0.08 ins. = 32% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 Minimum Diameter Profile 1 Well: 2K -13 Survey Date: March 16, 2011 Field: Kuparuk Tool: UW MFC 24 Ext. No. Company: ConocoPhillips Alaska, Inc. Tool Size: 212330 Country: USA Tubing I.D.: 1.69 inches 6.276 inches 1 Minimum Measured Diameters (In.) 1.69 2.19 2.69 3.19 3.69 4.19 4.69 5.19 5.69 6.19 1 1 1 1 2 3 1 1 4 d E Z O 5 1 6 1 7 a 1 1 1 1 • • 1 Report Overview jI \ S' . . Body Region Analysis I Well: 2K -13 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 7 ins 26 ppf J -55 BTC Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7 ins 26 ppf J -55 BTC 6.276 ins 7 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 10 M. Penetration body Metal loss body 0 50 100 1 1 S _11 0 11 1 I 0 to 20 to 40to over — 20% 40% 85% 85% -I , Number of joints analysed (total = 8) _ 1 0 2 4 2 -- I Damage Configuration ( body ) 10 - 1 5 ii. .I"1'11 0 j d 1 Isolated General Line Other Hole/ _= Pitting Corrosion Corrosion Damage Pos. Hole i ill 1 Number of joints damaged (total = 4) 0 4 0 0 0 Bottom of Survey = 8 1 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7 in 26 ppf J -55 BTC Well: 2K -13 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: March 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % pset Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 9149 0.15 0.16 43 13 6.26 Corrosion. Erosion. 2 9153 0.08 0.12 34 22 6.29 Corrosion. Erosion. ■■ ■� 3 9196 0.10 0.17 48 22 6.24 Perforations ■■ 4 9241 0.07 0.22 60 20 6.26 Perforations. Marker Joint. Corrosion. Erosion. 5 9261 0.08 0.09 25 13 6.20 Marker Joint. Corrosion. Erosion. Lt. Deposits. ■ it I 6 9280 0.29 0.62 100 34 5.49 Perforations. Corrosion. Erosion. Heavy Deposi ■ 7 9319 0.26 0.55 100 33 5.09 Perforations. Erosion. Heavy Deposits. • 8 9362 0,05 0.19 54 10 4.80 Corrosion. Erosion. Heavy Deposits. I 1 Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 1 1 Page 1 1 1 1 • 0 1 ji3 PDS Report Cross Sections I Well: 2K -13 Survey Date: March 16, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf J -55 BTC Analyst: C. Lucasan 1 1 Cross Section for Joint 8 at depth 9365.690 ft Tool speed = 50 Nominal ID = 6.276 I Nominal OD = 7 '�•i�` Remaining wall area = 72% " II° Tool deviation = 51° ` ` I i I \ li 1 1r_ / i I 1 / 1 1 Finger = 1 Penetration = 0.194 ins Corrosion / Erosion 0.19 ins. = 54% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections (IPS U. I Well: 2K -13 Kuparuk Survey Date: March 16, 2011 Field: Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf J -55 BTC Analyst: C. Lucasan 1 1 Cross Section for Joint 1 at depth 9151.490 ft Tool speed = 49 Nominal ID = 6.276 I Nominal OD = 7 _ ........0011111.-- Remaining wall area = 88% Tool deviation = 51° 1 / 11/" 1 I 1 I I 1II f ` 1 1 1 1 \ / ` / 1 \ 1 Finger = 1 Penetration = 0.158 ins Corrosion / Erosion 0.16 ins. = 43% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 I 3 KUP ConocoPhillips 8 Attributes ogle & MD TD Wellhore APIAIWI Field Name Wed Status Intl (°) ND (dKB) 2K -13 Act Btrn (MO) ' - Conocoehtlips 501032011600 KUPARUK RIVER UNIT INJ 55.59 3,800.00 9,700.0 Comment H2S (ppm) Date Annotation End Date KBQd (it) Rig Release Dale weu Conk : 13 Act111oors2Am SSSV: LOCKED OUT Last WO: 40.29 10/1/1989 Schematic ic / 02/11 Amatadail Depth RUM) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,270.0 1/14/2011 Rev Reason: TAG Imosbor 1/28/2011 Casing Strings Casing Description String 0... String ID ... Top (I6B) Set Depth (L. Set Depth (ND) ... String Wt.. String... String Top Thrd CONDUCTOR 16 15.062 36.0 1150 115.0 62.50 H I HANGER, 31 - _ Casing Deumpdon String 0... Stag ID... Top (RPM) Set Depth (L.. Set Depth (TVD) ... String Wt... String... String Top ThN SURFACE 95/8 8.765 35.0 3,848.9 2,913.2 36.00 J BTC Casing Description String 0... Stang ID... Top 9118) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd ' PRODUCTION 7 6.151 28.7 9,677.3 6,502.1 26.00 J-55 BTC Tubing Strings Tubing Description String 0... Stang ID ... Top (NB) Set Depth (f... Set Depth (ND) ... String Wt... Sang ... Sang Top Thrd TUBING 3 1/2 2.992 31.1 9,149.3 6,153.4 9. J-55 EUE8rdABMOD Completion Details coNDUCTOR, Tap Deem 38-115 (ND) Top Ind N008,,, TopptK9) (D6) 1( Rem Description eonrxrlent rope) 31.1 31.1 -0.61 HANGER FMC GEN IV TUBING HANGER 3.500 I _ _ 1,811.2 1,657.0 44.72 SAFETY VLV CAMCO TRDP -1A SSSV. (LOCKED OUT5127 / 1994) 2.812 SAFETY vLV 9,084.8 6,111.9 49.98 PBR BAKER 80-40 w /10' Stroke PBR 3.000 811 r 9,098.6 6,120.7 50.03 PACKER BAKER HB PACKER 2.890 9,137.3 6,145.6 49.79 NIPPLE OTISXN NIPPLE 2.750 GAS LIFT , 9,148.6 6,152.9 49.90 SOS BAKER SHEAR OUT 2.992 I 2,880 I I 1 1_1 fl Perforations & Slots Shot Top (ND) Biro (ND) Dens Tap (MB) Btrn (d(B) ROW MB) Zone Date (sh•• Type Comment 9,222.0 9,238.0 6,200.1 6,210.4 C -4, 2K -13 1/9/2001 6.0 APERF 2.5" HSD PJ Chgs, 60 deg Phase . l 9,284.0 9,318.0 6,240.1 6,261.6 A-4, 2K -13 9,284.0 9,311.0 6,240.1 6,256.9 A4, 2K -13 4/17/1990 4.0 IPERF 4.5" Casing Guns; 180 deg. Phase SURFACE, 8/5/1990 4.0 RPERF 2.5" Titan Hollow St; 180 deg. Phase 960.849 Notes: General & Safety End Dale Amotation Gas LFT. 11/3/2010 NOTE' VIEW SCHEMATIC w /Alaska Schematic9.0 5.312 GASLFT. I. I _..... 1 6,627 l GAS LIFT, . 7,289 GAS LIFT. I FT. 1 IIII(] 1 GAS LIFT. 8,442 ' 1 111 GAS LIFT, 1 -_ 9.040 I PBR, 9,085 i* vAGU68,9,oe9 1 NIPPLE, 9137 SOS, 9,149 I APERF, 9,2228238 Mandrel Details Top Depth Top Pon • (TVD) Intl 00 Valve Latch Size TRO Run Stn Tap RIB) RIM () Wake Model (In) Sery TYpe TA. IIM 11m Run Date Can.. RPERF, 9,2848311 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 IPERF. 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 9,284 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 I 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 5 7,835.4 5,328.150.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 ( 6 8,441.6 5,706.2 50.36 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 I 7 9,039.9 6,083.3 50.83 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 I PRODUCTION, 239,677 TO, 9700 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 ~~ ~~ ~ ~ ~;, ~~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 1~ 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 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 cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, Julyl0,and July 24, 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, ~~ M.J. Loveland 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 Date 7/29/2008 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 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7!10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .-:; '/ / ~er£t b " °7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-13 KUPARUK RIV UNIT 2K-13 Src: Inspector \~q,Oq5 Reviewed By: P.I. Suprv .~ Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-I3 API Well Number: 50-103-20116-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601181431 Permit Number: 189-095-0 Inspection Date: 6/1/2007 /' Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-13 Type Inj. w TVD 6138 IA 1220 2370 2300 2300 P.T.D 1890950 TypeTest SPT Test psi 1534.5 OA 400 500 500 500 4YRTST v' Tubing 2500 2500 2500 2500 I Interval P/F p Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity, ¿/ SCANNED JUN 2 0 2007 Wednesday, June 06, 2007 Page 1 of 1 (' ¡l Mike Mooney ~ Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 ConocoPh ¡IIi pS Phone: 907-263-4574 December 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2K-13 (APD # 189-095) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2K-13. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~,/I!~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad " RECEIVED JAN 0 5 2004 Alaska Oi' & Gas Cons. Commission Anchorage SCA~~~EÐ JAN 2 @ 2004 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter Casing D Repair Well D Plug Perforations D Stimulate 0 Time Extension D Other D Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 189-095/ 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20116-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 154' 2K-13 8. Property Designation: 10. Field/Pool{s): ADL 25589, ALK 2675 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9700' feet true vertical 6534' feet Plugs (measured) Effective Depth measured 9374' feet Junk (measured) true vertical 6316' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 3694' 9-5/8" 3848' 2918' PROD. CASING 9523' 7" 9677' 6519' Perforation depth: Measured depth: 9222'-9238',9284'.9318' true vertical depth: 6217'-6227',6257'-6279' RE C E 1\/1= D Tubing (size, grade, and measured depth) 3-1/2" , J-55, 9149' MD. JAN 0 5 2004 Packers & SSSV (type & measured depth) pkr= BAKER 'HB' RETR. pkr= 9099' Alaska Oil & Gas Cons. l,;ommìssion sssv= sssv sssv= 1811' Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7900' Treatment descriptions including volumes used and final pressure: 720 bbls seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation nla - Subsequent to operation nfa 845- 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 WDSPLD 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: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature .~  / .I A Phone Date /:2.-1 z, ~ 10 .3 Nt *" /f/io:-' Preoared bv Sharon AI/suo-Drake 263-4612 ./ f~IRIGINAL ' ' 0 1ML . BFL JAN ~ 'it(un Form 10-404 Revised 2/2003. owl a ,IBIMS SUBMIT IN DUPLICATE ( ( ~PHILLIPS Alaska, Inc. KRU 2K-13 .~ A Subsidiary of PHILLIPS PETROLEUM COMPANY . 2K.13 SSSV API: 501032011600 Well Tvoe: INJ Anale @ TS: 50 dea @ 9220 (1811-1812 SSSV Tvoe: TRDP Oria Completion: 10/1/1989 Anç¡le @.TD: 48 dea @ 9700 00'3500) Annular Fluid: Last W/O: Rev Reason: Taa, PERF bv (mO . . Reference Loa: Ref Loa Date: Last Update: 1/18/2002 Last Taa: 9374 TD: 9700 ftKB Last Taa Date: 1/9/2002 Max Hole Al'lale: 55 deç¡ @. 3800 ... Casina Strina . ALL STRINGS I ~ DescriDtion. Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9,625 0 3848 2918 36.00 J-55 PROD. CASING 7.000 0 9677 6519 26.00 J-55 TubinaStrina.TUBING .. .. .. ... .. .. ." Size I TOD I Bottom I TVD I Wt I Grade I Thread . ~ 3.500 lOT 9149 r 6170 I 9.30 I J-55 I EUE 8RD AB-MOD ; .8I..JJIPII Perforations Summary . . . .... .'.. ... ~ Interval TVD Zone Status Ft SPF Date Type Comment ." ....... 9222 - 9238 6217 - 6227 C-4 16 6 1/9/2001 APERF 2.5" HSD PJ Chgs, 60 deg .... Phase -=.... 9284-9311 6257-6275 A-4 27 8 8/5/1990 RPERF ~,;~~tanHoliowSt;180deg ", 9311 - 9318 6275 - 6279 A-4 7 4 4/17/1990 IPERF 4.5" Casing Guns; 180 deg. , :,; Phase ¡ Ga$LlftMandrel$/Vahjes~~~ ......~.~ ..............",.,....,..,. St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv EÞ Mfr Type Run Cmnt :' ~.. ~~~~--~~~- ~:~J: . ~~~g .,--..--- g~~_.., ..~,:.~,- . ~~ ~:~~t_..~._. 111~;~;::t -- .' . ' 3 6627 4584 Merla TMPD DMY 1.0 BK 0.000 () 4'17/1990 "4-' --i2G9' 4981 Merla -'.-T~1PD DMY--. - '1:õ-------aK-- 0.000 6 n '.,i'17!199Õ- I :_~_,~..§j5':._53_~z..~A~~~!a T~1ÞÖ-'----~~'~-.- .n.~_r-..1'f_n---1.:.0_n_..B.I~ 0.000 '0 11'A'1991 - i (j 8442 5724 C¡:¡mco MMG-2 DMY 1.5 RK 0.000 0 11 '811991 7 90406101 C¡:¡mr.(j-"--¡1r-..1G-2,_n DMY 1.5 RKn".e):õ6ó 0 11'9'1991 ---- .~-~" -~~p~~h;~~. eq~:;'e~tC.t-JEWËLRY---"'.' - .__m. - ~~scriDtion ._" -.....- --... ---- ID , 1811 1662 SSSV Cameo TRDP-1A-SSA 2.812 I' 9085 6129 PBR Baker '80-40' w/10' Stroke 3.000 9099 6138 PKR Baker 'HB' Retr. 2,890 9137 6163 NIP Otis 'XN' Nioole NO GO 2.750 IJ,:--- -,..,....'" 9148 6170 SOS Baker 2.992 ; 9149 6170 TTL 2.992 .. ;;,,;.'j I 1.- : i PBR (9085-9086, 00:3.500) PKR I (9099-9100, 00:6.151) , ~P : (9137-9138, I I 00:3.500) TUBING I 0~:~6~: I...___=~=J 10:2.992) ! -. --- Perf - - - (9222-9238) - - - - == - = Perf - = = (9284-9311) ... -- == === = == Perf (9284-9318) - - - -- -- . ( ( 2K-13 Event History ( Date Comment 11/21/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (8 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/12/2003 PH,LLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 February 19, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2K-l~~,' Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 2K-13. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad Ataska Oii& Gas Otto. Commissio~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · 1. 'Operations performed: : Operation shutdown_ · stimulate _ Plugging _ Perforate _X ' '. Pull tubing _ .::' Alte~ casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development RKB 154 feet 3. Address Exploratory 7. Unit or Property name P. O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service x Kuparuk Unit 4. Location of well at surface 8. Well number 67' FNL, 94' FEL, Sec. 11, T10N, R8E, UM (asp's 498310, 5938235) 2K-13 At top of productive interval 9. Permit number / approval number 1349' FNL, 1089' FEL, Sec. 10, T10N, R8E, UM 189-095 / At effective depth 10. APl number 50-103-20116 At total depth 11. Field / Pool 1371' FNL, 1422' FEL, Sec. 10, T10N, R8E, UM (asp's 491703, 5936935) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9700 feet Plugs (measured) true vertical 6534 feet Effective depth: measured 9374 feet Junk (measured) true vertical 6316 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 170 sx AS U 115' 115' SUR. CASING 3694' 9-5/8" 1125 sx AS III, 500 sx Class G 3848' 2918' PROD. CASING 9523' 7" 300 sx Class G 9677' 6519' Perforation depth: measured 9222' - 9238', 9284' - 9318' true vertical 6217' - 6227', 6257' - 6279' Tubing (size, grade, and measured depth) 3Llt2", 9.3#, J-55 Tbg @ 9149' MD. Anch0r~ Packers & SSSV (~pe & measured depth) BAKER 'HB~ RETR. CAMCO TRDP-1A~SSA ~ 1811' MD. 13. Stimulation or cement squeeze summaw Inte~als treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Avera~e Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation N/A 15. AEachments Copies of Logs and Suweys run Daily Repo~ of Well Operations X Oil Gas Suspended Sewice Water 17. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Sign ed~~~~~ Ti tie Wells Team Leader Date Michael Mooney _ Prepared b~ S~aro~AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 o -~_.~ 'i : ,..; ' ; SUBMIT IN DUPLICATE Date Comment 2K-13 Event History 01/09/02 01 /13/02 01/14/02 01/15/O2 TAGGED @ 9374' RKB, EST 56' OF RATHOLE; ATTEMPTED TO DRIFT W/20' OF 2.62" HC, IN RPOGRESS. [PERF, TAG] DISPLACE TBG W/HOT DSL. ATTEMPT BRUSH TBG. HIGH TBG PRESSURE, VERY SLOW GOING TO 1786' WLM, POH. IN PROGRESS. BRUSHED TBG & DRIFTED W/22' 6" X 2.565" DUMMY GUN TO 9300' WLM. PERFORATED C4 SAND INTERVAL @ 9222'-9238', W/2.5" HSD, 6 SPF (16' GUN), LEFT WELL SI. [PERF] Page 1 of I 2/11/2002 STATE OF ALASKA AI..~,..,dA OIL AND GAS CONSERVATION COMMIS,.510N 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Other 2. Name of Operator ARP,,O 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 69' FSL, 94' FEL, Sec. 11, T10N, R8E, At top of productive interval 1349' FSL, 1089' FEL, Sec. 10, T10N, At effective depth 1359' FSL, 1150' FEL, Sec. 10, T10N, At total depth 1411' FSL, 1443' FEL, Sec. 10, T10N, UM R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 9 70 0' true vertical 6518' feet Plugs (measured) f e e t None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 8K-13 9. Permit number/approval number 89-95 10. APl number 5o-103-20116 11. Field/Pool Kuparuk River Oil Pool fee; Effective depth: measured 9 6 0 0' true vertical 6 4 4 9' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1125 Sx AS III & 500 Sx Class G 300 Sx Class G 115' 3848' 1 6' 9 5/8" 9667' 7" measured 9284'-9318' true vertical 6244'-6266' 4.5" Casing Gun @ 4 SPF Tubing (size, grade, and measured depth) 3.5" J-55 set at 9149' Packers and SSSV (type and measured depth) Brown HB @ 9099', Camco TRDP-1A-SSA @ 1811' Measured depth 115' 3848' 9677' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 115' 2909' 6502' RECEIVED JAN 2 8 19.q Alaska Oil & Gas Cons..C0_mlalSSJlUl ; chorage . 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 117 317 1 0 975 - 0 - 0 - 91 7 800 Tubing Pressure 256 2341 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned C-(.,'~- ~ Form 10-404 Rev 09/12/90 Title Date SUBMIT IN DUPLICATE PRODUCTION WELL STATUS ~AS LIFT STATUS 1.4 Z S E 0 T L N A L E T 1 APR 2 13 PR 3 A PR 4 A PR 7 A PR 8 A PR 9 A PR !1 APR 'i4. A PR 15 A TS 16 A PR 17 A PR 19 A PR 21 A PR 22 A PR 25 A PR ~6 A PR 7," 10" · . TP TT WC H2S CSG . CS~ PSI CHK DEG' % PPM PSI PSI 261 176 76 I ..15 1200 700 267 176 121 29 - 30 1300 900 262 176 43 0 5 ~;100,,, . :: 600 261 176 48 0 5 900 300 ~61 17~ 53 0 42 800 300 261 176 51 5 2~0 176 71 1 261 176 46 0 261 176 35 2 287 176 64 0 256 176 43 0 260 17~ 4I 0 261 176 50 0 259 176 43 1 261 176 33 0 259 !76 19 0 261 176 48 0 i5 1000 300 15 800 600 40 800 700 40 600 400 15 1200 600 0 1000 550 5 800 750 5 1100 ~00 5 1100 600 5 950 700 5 I000 150' 5 800 400 S'[ CN (4..'% S INJ AH TEMP METER RATE LI DEG READING MSCF Eli 68 8020 97~ 0 30 2068 0 0 50 7870 340 0 60 2270 634 0 50 1870 962 0 65 3500 1628 0 50 '3400 426 0 45 160 611 0 44 7640 267 0 60 8200 1257 0 50 1700 711 0 40 2120 735 0 65 100 94.9 0 ' 60 3700 475 0 50 9400 527 0 50 8930, 203 0 45 250 909 0 TOTALS' INJECTION WELL STATUS 11613 INJECTIOn' RATE W Z S E 0 T L N A L E T ALLOW ACT ' 7" 10" INJ INJ TT CSO CSG PSI PSI DEQ CHK PSI PSI IN~ INJ METER RATE RATE READIN~ BPD MMSCFD 5 A SW 6 B SW 10 A SW 12 A SW 13 B SW !8 A SW 20 A SW 23 B SW 24 B SW 2500 1976 67 25 1600 600 2500 1796 67 14 I100 600 2500 2307 66 55 1100 0 2500 2338 66 176 14.00 500 2500 a3~i"' 67 176' 800 900 aSO0 a3a7 67 17& 1600 500 2500 a3a8- &7 176 1000 550 2500 1809 63 27 1000 950 2500 2104 60 102 1400 800 2600 1609 0.000 7230 1494 0.000 6640 1505 0.000 3990 1859 O. 000 350 917 0.000 3825 1417 0.000 8640 864 O. 000 215 2005 0.000 2830 2462 0.000 TOTALS. SWI' 14132 + PWI' 0 = 14132 0.000 S,/I IMPACT H M 0 R ! D EPL S N E BI~L..~ 0000 0 0 0000 0 0 0000 0 0 OOOO 0 0000 0 0 0000 0 0000 0 0 OOOC) n 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0 S/[ C H M 0 R I D S N E 0000 0 0000 0 0~30 55 0000 0 0000 0 0000 0 GO00 0 0000 0 0000 0 RECEIVED JAN 8 199 Alaska Oil & Gas Cons. ARC6 Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action 2K-13 Conv to Wtr Inj 2K-23 Convto Wtr Inj 2K-24 Convto Wtr Inj AnticiDated Start Date November, 1991 November, 1991 November, 1991 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer CC: M. E. Eck ATO 1176 J. D. Bolling ATO 1196 KOE1.4-9 (w/o attachments) (w/o attachments) RECEIVED Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /d~:H; h()0,~; (; STATE OF ALASKA ALASKA OIL AND GAS ~RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 69' FSL, 94' FEL, SEC 11, T10N, R8E, UM At top of productive interval 1349' FSL, 1089' FEL, SEC 10, T10N, R8E, UM At effective depth 1359' FSL, 1150' FEL, Sec. 10, T10N, R8E, UM At total depth 1411' FSL~ 1443' FEL~ Sec. 10~ T10N~ R8E, UM 12. Present well condition summary Total Depth: measured 9 7 0 0 true vertical 6 51 8 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service -- feet Plugs (measured) feet None 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-13 9. Permit number 89-95 feet 10. APl number 5o-1 03-2011 § 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 9 6 0 0 true vertical 6 4 4 9 Casing Length Size Structural Conductor I 1 5' 1 6" Surface 3 84 8' 9 5/8" Intermediate Production 9 6 7 7' 7" Liner Perforation depth: measured 9284'-9318' feet Junk (measured) feet Nolle Cemented Measured depth True vertical depth 115' 115' 1125 Sx AS III & 3848' 2909' 500 Sx Class G 300 Sx Class G 9677' 6502' 4.5" Casing Gun @ 4 SPF RECEIVED Anchorage true vertical 6,244'-6,266' Tubing (size, grade, and measured depth) 3.5" J-55 set at 9,149' Packers and SSSV (type and measured depth) Brown HB @ 9099'~ Camco TRDP-1A-SSA ~ 1811' 13. Attachments Description summary of proposal_ Detailed operation program Convert well from oil producer to water injector. (Wellbore 14. Estimated date for commencing operation 15. November 1991 16~.. If p~r, oposal wa..s verbqlly approved /Name ot approver Date approved Service _Water schematic attached). Status of well classification as: Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢, (~, ~ Title Operations En(~ineer FOR CC~MISSlON USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test~ -- Subsequent form require 10- ~'/~-) Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL SIGNED ElY ........ n ~ ~IITI I LUI~Ii~Jlt~ t~. 0~¥~ ~ ~ ~ BOP sketch_ Suspended In!ector Date IApproval No..., ,,..-.~ Approv~d ColCy Returned Commissioner Date SUBMIT IN TRIPLICATE Messrs. Fontenot and Wild{"-"' 10/26/91 Page 2 1) 2) 3) 4) 5) 6) 7) 8) 9) Wells 2K-13, 2K-23 and 2K-24 Water Injection Conversions Charge Code: Downhole 994901; Surface 994928 10/23/91 If possible, obtain final 12 hour welltest and SI well for 72 hours. This will enable an accurate static BHP measurement which is important for waterflood surveillance analysis. Notify G. Targac(x6849) to insure that the sundry notices for converting the wells to water injection have been approved by the State. MIRU slickline unit and diesel pump truck. RIH and set SV in Otis 'XN' or 'D' nipple. Well 2K-24 has 2-7/8" tubing and a Camco 'D' nipple. Pump diesel down casing while taking return from tubing. volumes shown below: Annulur Volume Well to Btm Mandrel 2 K- 1 3 239 bbls 2 K- 2 3 258 bbls 2 K - 2 4 276 bbls Fill annulus with diesel 3 1/2" tubing X 7" casing 3 1/2" tubing X 7" casing 2 7/8" tubing X 7" casing RIH to replace GLV's and OV's with DV's (see attached wellbore schematics for depths). Ensure the casing/tubing annulus is filled with diesel. Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure testing to prevent tubing buckling. RIH and pull SV. RIH w/Panex gauge or Amerada gauge to mid A Sand perforation for 15 minute static pressure. POOH and take static pressure measurement in the lubricator. RDMO Slickline. Notify the State of the Mechanical Integrity Tests (MIT's). Conduct MIT tests. Packer depths and 7" annular pressures necessary are shown below. Bleed the annulus to 1000 psi after completing the test. TVD Depth Required Casing Well ~ Pressure for MIT 2 K- 1 3 61 25' 3333 PSI 2 K- 2 3 6 081' 3330 PS1 2 K - 2 4 6 2 0 4' 3340 PSI The above pressures were calculated assuming a surface tubing pressure of 2300 psi. If a different surface tubing pressure exists at the time of the test, the required test pressure should be recalculated using the following equation: MTP = Ptbg + ((Tubing gradient - Annular gradient) * TVD of Packer) + 500 psi MTP= Minimum Test Pressure on Tubing/Casing Annulus Ptbg = Pressure in the tubing at the wellhead Tubing gradient is assumed to be seawater with a gradient of 0.44 psi/fi Annular gradient is diesel with a gradient of 0.353 psi/f1 R E C E D Messrs. Fontenot and Wilder 10/26/91 Page 3 10) Prior to initiating water injection, a spear should be injected to clean up the perforations. Depending on the outcome of the tag and bailer samples obtained, the next step will involve a xylene/mutual solvent spear that will be either bullheaded down the tubing or placed across the A Sand perforations with coiled tubing. A separate procedure will be prepared for the CTU cleanout/placement if necessary. For the spear recipe, the following volumes should be pumped at matrix rates (roughly 1-2 BPM) not to exceed 1450 psi surface treating pressure and displace with specified amount of diesel. Displacement volume to top perf is critical since a soak is involved and it is important that SW not be the displacing fluid as the fluids would swap during the soak. Approximately half of the xylene mix will be displaced into the perfs and the remaining half left in the wellbore. Volume of Volume of Mutual Solvent Displacement Volume Well Xvlene Chemlink - 8603 of Diesel to tod Derf . 2K-1 3 16 bbls 1 bbl (6%) 84 bbls 2 K-23 7 bbls 0.5 bbl (7%) 93 bbls 2K-24 14 bbls I bbl (7%) 61 bbls Allow to soak for I hour and overdisplace with SW at approximately 500 BWPD and gradually increase the injection rate to maximum injection pressure. WELL 2K-13 PRODUCER APl # 501032011600 SURFACE LOCATION: 69' FNL, 94' FEL, SEC 11, T10N, R8E, UM TOP KUPARUK: 1349' FNL, 1089' FEL, SEC 10, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3848' TREE: FMC GEN IV 5000 PSI J BAKER PBR: 3.000" ID @ 9085' BROWN HB PKR: 2.892" ID @ 9099' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 9137' SHEAR OUT: 3.000" ID @ 9148' L · GLMI' GLM2: GLM3: GLM4: GLM5: GLM6: GLM7: SPUD: 9/20/89 COMPLETION: 4/17/90 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @1811' 2860' / 5311' / 6627' / 7269' / 7835' / 8441' / 9040' / 1.0" TMPD / 1/4" Port 1.0" TMPD / 1/4" Port 1.0" TMPD/DV 1.0" TMPD/DV 1.0" TMPD / 1/4" Port 1.5" MMG-2 / 1/4" Port 1.5" MMG-2 / 3/16" Port 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 9149' C A5 A4 A3 7": 26# J-55 @ 9677' PBTD: 9467' HOLE ANGLE ACROSS KUPARUK = 49 DEGREES MAX HOLE ANGLE = 55 DEGREES @ 3800' VOLUME TO TOP PERF = 85 BBLS RECEIVED 9284' ~nchorage 4 SPF (~ 180° PHASING ORIENTED 35° CCW 9318' FILL TAGGED AT 9422' MD-RKB (10/24/91) REVISION' 10/22/91 ALA~,, ' STATE OF ALASKA ,,4 OIL AND GAS CONSERVATION COM,,,,SSION WELL COMPLETION OR RECOMPLETION REPORT 1 Status of Well Classification of Service Well OIL [~] GAS [] SUSPENDED r-'"] ABANDONED r-] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-95/9-923 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~.~-....__..~ 50-103-20116 4 Location ~f well at surface ij un,~.~.L~0N~ _ · 9 Unit or Lease Name ! 69' F~'L, 94' FEL, SEC 11, T10N, RBE UM r VE,% Fi;~i}I KUPARUK RIVER 1349'Total DoDthFSL' 1089' FEL,SEC 10, T10N, RBE UM i ._i I;-M- ~ ~~, H, 11 Field2K'13and Pool At '~ 1411' F~L, 1443' FEL, SEC 10, T10N, RBE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. KUPARUK RIVER OIL POOL RKB 154' ADL: 25589 ALK: 2675 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 9/20/89. 9/28/89. 5/28/1990. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost MD &6518' TVD 9600' MD & 6449' TVD YES ~ NO E~]I 1811' feet MD 1400' APPROX 9700' 22 Type Electric or Other Logs Run DILISFLIGR/SP/FDClCNL/CALICBLIGYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II 9 5/8" 36# J-55 SURF 3848' 12-1/4" 1125 SX AS III, 500 SX CLASS G 7" 26# J-55 SURF 9677' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3#, J-55 9149' 9099' 9284' -9318' 4-1/2" @4 SPF MD 6244' - 6266' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9220' 6202' NA KUPARUK C Bo'FrOM 9238' 6214' KUPARUK A TOP 9238' 6214' KUPARUK A BOTTOM 9419' 6333' ' 31. LIST OF ATTACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ ~ .~_~~___ Title AREA DRILLING ENGINEER Date '"~,////~0_._! / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~407 ARCO Oil and Gas Company Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Rel~rt" on tho first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA TNC. Field KUPARUK RIVER UNIT Auth. or W.O. no. ~4273 County, parish or borough NORTH SLOPE Lease or Unit ADL: 25589 ALK: 2675 Title COMP LETI ONS IState AK I Well no. KRU 2~-13 Operator ARCO ARCO W.I. 55,8533 Prior status if a W.O. Spudded or W.O. begun IDate IHOur SPb'D 09/20/89 00:00 Date and depth as of 8:00 a.m. 04/12/90 (12) TD: 9700 PB: 9600 SUPV:GB 04/13/90 (13) TD: 9700 PB: 9600 SUPV:GB 04/14/90 (14) TD: 9700 PB: 9600 SUPV:GB 04/15/90 (15) Complete record for each day reported NORDIC fl TD: 9700 PB: 9600 SUPV:GB 04/16/90 (16) TD: 9700 PB: 9600 SUPV:GB 04/17/90 (17) TD: 9700 PB: 9600 SUPV:GB The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D RIH TO SHOOT SQUEEZE 7"@ 9677' MW:10.5 NaCl MOVE FROM 2K-10 TO 2K-13, ACCEPT RIG 4/12/90 00:30, ND TREE NU BOPE & SET TP TEST BOPE, RU HLS TO SQUEEZE, TEST LUB, RIH W/SQUEEZE GUN. DAILY:S22,061 CUM:$22,061 ETD:S864,842 EFC:$1,305,000 POH W/DP 7"6 9677' MW:10.6 NaCl RIH W/PERF GUN, PERF 9261-9263 & 9126-9128 @ 6 SPF, POH, ASF, RIH W/ GR/JB TO 9400', POH, RIH W/ BP, SET BP AT 9288, POH, RIH W/ EZSV, ATTEMPT TO SET AT 9148, NO SUCCESS, POH, LOST WT AT 7100, CONT. POH, LEFT EZSV & RUNNING TOOL IN HOLE, RIH W/ GR/JB, TAG FISH AT 9275, POH, RD E-LINE, PU OVERSHOT ON DP, RIH ON DP, TAG FISH AT 9282, WORKOVER FISH, POH (PIPE WET) DAILY:S49,299 CUM:$71,360 ETD:S936,202 EFC:$1,305,000 WOC 7"@ 9677' MW:10.6 NaCl CONT. POH W/FISH, RECOVERED EZSV & RUNNING TOOL, PU EZSV ON DP, RIH, SET EZSV AT 9157, PULL OUT OF EZSV, STING INTO EZSV & ESTABLISH INJ RATE OF 2 BPM AT 2150 PSI, BATCH MIX 100 SX CL G CMT, PUMP 25 BBL H20, 18.3 BBLS CMT, 10 BBL H20, CIRC DOWN DP, SHUT ANNULUS AFTER 5 BBL H20 IN ANNULUS, SQUEEZE & HESITATE 14.6 BBL CMT INTO FORMATION, FINAL SQUEEZE PRESSURE 3000 PSI @ .1 BPM STING OUT OF EZSV, REVERSE ON DP VOLUME, BATCH MIX 100 SX CMT, PUMP 10 BBL H20, 18.7 BBL CMT, 2.5 BBL H20, CIRC DOWN DP, POH 633', SQUEEZED 2.7 BBLS AND PRESSURE WENT TO 3100 PSI, SHUT IN AND MONITOR PRESSURE DAILY:S56,916 CUM:$128,276 ETD:S993,118 EFC:$1,305,000 DRILL EZSV AT 9157 7w@ 9677' MW:10.6 NaC1 CONT. HOLDING PRESSURE ON TOP SQUEEZE, RELEASE ANNULUS PRESSURE, PRESSURE DIDN'T DROP ON DP, DP PLUGGED, POH, LD 25 JTS PLUGGED DP, RIH W/ BIT/DC ON DP, TAG CMT AT 8731, DRILL CMT F/8731-9157, TEST SQUEEZE PERFS F/9126-9128 TO 2000 PSI, OK, DRILL EZSV AT 9157 DAILY:S32,891 CUM:$161,167 ETD:S1,026,009 EFC:$1,305,000 CIRC. & FILTER BRINE 7"@ 9677' MW:10.6 NaCl CONT. DRILL EZSV & CMT TO 9295, TEST BTM & TOP SQUEEZE PERFS TO 2000 PSI, OK, DRILL BP AT 9295, WASH TO PBTD AT 9473, POH, RIH W/ BIT/ CSG SCRAPPER, CIRC. & FILTER BRINE DAILY:S36,983 CUM:$198,150 ETD:S1,062,992 EFC:$1,305,000 RIH W/ COMPLETION 7"@ 9677' MW:10.6 NaCl POH, LD 54 JTS DP, STAND BACK 116 STDS, RU E-LINE, TEST LUER., RIH W/ GUN 1, PERF 9298-9318, POH, ASF, MU GUN 2, SHORT IN GUN, ORDER NEW GUN OUT, RIH W/ GUN 2, PERF COMPLETION AS S~N~LY DAILY: $54,303 I CUM: $252,453 9284-9298, POH, ASF, RD E-LINE, MU AND RIH W/ 3-1/2" SINGL~ I I ETD: $1, ~7~29~ ~EF~: $1,~{000 Numbe~ ~lr~ ly-well hlsto~=.Jq[m~~e ~- iPage no. las they ,re prepared for ea~;, Wq-~ .... I I I ARCO O, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, I Accounting cost center code District County or Parish IState ARCO ALASKA INC. NORTH SLOPE ~ AK Field Lease or Unit /Well no, KUPARUK RIVER UNIT ADL: 25589 ALK: 2675 KRU 2K~13 ITitle I COMPLETIONS Auth. or W.O. no. AK4273 Operator ARCO Spudded or W.O. begun . SPUD Date and depth as of 8:00 a.m. 04/18/90 (18) TD: 9700 PB: 9600 SUPV:GB A.R.Co. W.I. Date 55. 8533 09/20/89 Complete record for each day reported NORDIC ~1 Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our ]Prior status if a W.O. I 00:00 RIG RELEASED 7"@ 9677' MW:10.6 Nac1 CONT. RIH W/ 3-1/2" SINGLE COMPLETION ASSEMBLY, MU CONTROL LINE TO TBG HGR & TEST, LD TBG, RILDS, PRESS TBG TO 2500 PSI AND SET PKR, PRESS ANNULUS TO 1000, BLEED TBG TO 1100 PSI, PU AND SHEAR PBR, TEST SSSV, OPEN SSSV, TEST ANNULUS TO 2000 PSI, CLOSE SSSV, SET BPV, ND BOPE, NU TREE, TEST PACKOFF AND TREE TO 5000 PSI, OPEN SSSV, TEST ANNULUS TO 2500 PSI, PRESS TBG TO 3750 PSI AND SHEAR BALL OUT, BLEED PRESS, REV. CIRC 6 BBLS DIESEL INTO ANNULUS, BULLHEAD 2 BBL DIESEL DOWN TBG, RELEASE RIG AT 1800 4/17/90 DAILY:S157,739 Old TD Released rig CUM: $410,192 ETD: $1,275,034 EFC: $1,305,000 New TD PB Depth Date Kind of r g Classifications (oil, gas, etc.) Producing method Official reservoir name(s) Potential test data Type completion (single, dual, etc.) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above ,~rrect Signet u ~;~ ~ I Date / / T~ sFeO; fl~;omc ePdruer%asr ~vlt i n~l, %~ ic~l r~ nb u~ i0o, n, '~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvl~on of AttantlcRIchfleldCompany ADDENDUM WELL: 5/28/90 2K-13 Frac KRU "A" Sand in 5 stages as follows: Stage 1. Stage 2 Stage 3 Stage 4 Stage 5 Pmp 200 bbls Gel H20; Pre Pad @ 20-25 bpm 7300-6350 psi * Pmp 61 bbls Gel H20; Pre Pad @ 20 bpm 5650-6150 psi and pmp 46 bbls Gel H20; Pre Pad @ 15 bpm 5285-5960 psi and 37 bbls Gel H20; Pre Pad @ 10 bpm 5190-5745 psi Pmp 82 bbls Slick Diesel Flush; @ 25 bpm 6420-7200-6575 psi *Lost #5 turbine, but got back on line during shutdown ISIP: 2527 frac grade .75 peal fric 2026 * Pmp 800 bbls Gel H20; pad @ 20-25 bpm 7500-5340 psi Pmp 71 bbls Gel H20; WI2# 16/20 Carbolite @ 25 bpm 5340-5100 psi Pmp 42 bbls Gel H20; W/4# 16/20 Carbolite @ 25 bpm 5100-7600 * lost #4 turbine - (4 turbines on line) Called for flush but screened out before we could get switched to diesel. Fluid to recover: Sand in zone: Sand in casing: 1102 Gel/H20 + 147 diesel 2500# 16/20 + 85O0 Dr~r{tenden~ ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES 11/ 7/89 PAGE DATE OF SURVEY: 11/06/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 100 99.98 200 199.94 300 299.89 400 399.71 -154.00 0 0 -54.02 1 35 45.94 1 42 145.89 1 59 245.71 4 43 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00 .00 N 71.00 W 1.59 .45N 1.31W N 67.80 W .15 1.47N 4.00W N 73.40 W .33 2.53N 7.05W N 81.10 W 2.77 3.66N 12.79W VERT. SECT. .0O 1.20 3.63 6.41 11.81 500 499.11 345.11 600 597.88 443.88 700 695.94 541.94 800 793.08 639.08 900 888.96 734.96 7 37 10 18 12 15 15 9 17 49 N 85.70 W 2.94 4.80N 23.48W N 86.50 W 2.67 5.84N 39.03W N 85.10 W 1.98 7.29N 58.53W N 86.30 W 2.91 9.04N 82.17W N 87.10 W 2.67 10.66N l10.50W 22.07 37.09 55.92 78.73 106.19 1000 983.49 829 1100 1076.62 922 1200 1168.28 1014 1300 1257.54 1103 1400 1343.44 1189 .49 .62 .28 .54 .44 20 14 22 24 24 40 28 53 32 40 N 89.70 W 2.56 11.53N 143.09W S 89.70 W 2.18 11.52N 179.44W S 88.70 W 2.29 10.94N 219.37W S 86.10 W 4.38 8.83N 264.36W S 84.40 W 3.89 4.55N 315.34W 137.95 173.59 212.83 257.34 308.17 1500 1425.99 1271 1600 1504.98 1350 1700 1581.01 1427 1800 1654.23 1500 1900 1723.88 1569 .99 36 1 .98 39 36 .01 41 23 .23 44 27 .88 47 15 S 87.50 W 3.77 .63N 371.61W S 87.90 W 3.60 1.82S 432.86W S 85.80 W 2.24 5.41S 497.69W S 85.10 W 3.10 10.82S 565.56W S 83.50 W 3.03 17.97S 636.94W 364.09 424.61 488.86 556.46 627.84 2000 1790.61 1636 2100 1855.75 1701 2200 1920.87 1766 2300 1986.77 1832 2400 2051.33 1897 .61 49 1 .75 49 41 .87 49 2 .77 48 30 .33 51 4 S 84.40 W 1.89 25.81S 710.99W S 84.50 W .67 33.15S 786.51W S 85.30 W .89 39.90S 862.09W S 85.00 W .58 46.26S 937.04W S 82.40 W 3.24 54.67S 1012.92W 701.97 777.44 852.86 927.57 1003.62 2500 2113.25 1959.25 2600 2174.63 2020.63 2700 2236.81 2082.81 2800 2299.21 2145.21 2900 2360.99 2206.99 52 24 51 51 51 14 51 32 52 9 S 82.20 W 1.35 65.19S 1090.73W S 82.90 W .78 75.43S 1169.01W S 82.70 W .64 85.24S 1246.70W S 82.90 W .34 95.04S 1324.23W S 82.00 W .94 105.37S 1402.18W 1081.97 1160.72 1238.82 1316.74 1395.20 3000 2422.06 2268 3100 2482.31 2328 3200 2541.40 2387 3300 2600.06 2446 3400 2658.45 2504 .06 .31 .40 .06 .45 52 33 53 19 54 13 53 55 54 37 S 82.20 W .43 116.25S 1480.62W S 81.90 W .81 127.29S 1559.65W S 81.50 W .96 138.94S 1639.48W S 80.80 W .64 151.40S 1719.50W S 80.50 W .74 164.59S 1799.60W 1474.23 1553.88 1634.44 1715.33 1796.47 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/06/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 2716.69 2562.69 54 7 S 79.20 W 1.17 3600 2775.12 2621.12 54 20 S 78.60 W .53 3700 2833.05 2679.05 54 50 S 79.10 W .65 3800 2890.25 2736.25 55 22 S 79.20 W .53 3900 2947.25 2793.25 55 7 S 78.60 W .55 178.91S 1879.62W 1877.73 194.53S 1959.24W 1958.87 210.29S 2039.22W 2040.38 225.73S 2119.78W 2122.40 241.55S 2200.40W 2204.57 4000 3004.73 2850.73 54 42 S 78.00 W .65 4100 3062.58 2908.58 54 35 S 77.40 W .50 4200 3121.06 2967.06 53 49 S 76.00 W 1.37 4300 3180.17 3026.17 53 42 S 75.20 W .66 4400 3239.22 3085.22 53 54 S 75.20 W .21 258.14S 2280.53W 2286.39 275.52S 2360.22W 2367.95 294.18S 2439.16W 2449.02 314.23S 2517.29W 2529.57 334.85S 2595.31W 2610.13 4500 3298.15 3144.15 53 52 S 75.00 W .17 4600 3356.96 3202.96 54 5 S 75.00 W .22 4700 3415.58 3261.58 54 7 S 74.80 W .17 4800 3474.20 3320.20 54 5 S 74.70 W .09 4900 3532.67 3378.67 54 20 S 74.60 W .25 355.62S 2673.38W 2690.78 376.56S 2751.51W 2771.50 397.66S 2829.72W 2852.35 418.97S 2907.89W 2933.19 440.45S 2986.12W 3014.13 5000 3590.93 3436.93 54 23 S 74.70 W .10 5100 3649.02 3495.02 54 34 S 74.90 W .25 5200 3707.89 3553.89 53 16 S 74.40 W 1.36 5300 3767.80 3613.80 53 7 S 74.30 W .18 5400 3827.93 3673.93 52 57 S 74.50 W .23 461.96S 3064.50W 3095.22 483.30S 3143.05W 3176.44 504.69S 3220.99W 3257.08 526.29S 3298.09W 3336.93 547.78S 3375.05W 3416.62 5500 3888.12 3734.12 53 1 S 73.90 W .49 5600 3948.47 3794.47 52 44 S 73.40 W .49 5700 4009.19 3855.19 52 28 S 73.20 W .31 5800 4070.40 3916.40 52 2 S 73.60 W .54 5900 4132.29 3978.29 51 28 S 75.40 W 1.52 569.52S 3451.88W 3496.25 591.97S 3528.40W 3575.70 614.80S 3604.50W 3654.81 637.39S 3680.28W 3733.57 658.39S 3755.96W 3811.91 6000 4194.56 4040.56 51 29 S 75.40 W .00 6100 4256.78 4102.78 51 33 S 75.10 W .24 6200 4318.81 4164.81 51 46 S 74.80 W .32 6300 4380.85 4226.85 51 31 S 74.50 W .34 6400 4443.01 4289.01 51 36 S 74.10 W .32 678.11S 3831.68W 3890.03 698.04S 3907.38W 3968.19 718.41S 3983.13W 4046.48 739.17S 4058.76W 4124.72 760.37S 4134.17W 4202.84 6500 4505.04 4351.04 51 43 S 73.90 W .19 6600 4567.01 4413.01 51 40 S 74.70 W .63 6700 4628.96 4474.96 51 46 S 74.90 W .18 6800 4690.65 4536.65 52 2 S 75.00 W .29 6900 4752.43 4598.43 51 38 S 77.60 W 2.09 781.99S 4209.57W 4281.03 803.22S 4285.12W 4359.29 823.81S 4360.88W 4437.63 844.24S 4436.88W 4516.18 862.87S 4513.26W 4594.73 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/06/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7000 4814.71 4660.71 51 18 S 78.10 W .51 7100 4877.05 4723.05 51 33 S 78.30 W .29 7200 4938.87 4784.87 52 4 S 78.10 W .53 7300 4999.95 4845.95 52 37 S 78.00 W .57 7400 5060.95 4906.95 52 11 S 77.90 W .45 879.33S 4589.74W 4672.96 895.32S 4666.28W 4751.14 911.40S 4743.22W 4829.74 927.79S 4820.68W 4908.92 944.33S 4898.17W 4988.15 7500 5122.59 4968.59 51 42 S 77.80 W .50 7600 5184.96 5030.96 51 7 S 77.20 W .74 7700 5247.99 5093.99 50 43 S 76.70 W .56 7800 5311.22 5157.22 50 50 S 76.90 W .20 7900 5374.29 5220.29 50 57 S 76.70 W .18 960.91S 4975.15W 5066.89 977.82S 5051.46W 5145.04 995.35S 5127.09W 5222.64 1013.04S 5202.52W 5300.08 1030.76S 5278.07W 5377.65 8000 5436.89 5282.89 51 31 S 76.30 W .66 8100 5499.13 5345.13 51 29 S 76.50 W .16 8200 5560.90 5406.90 52 12 S 76.20 W .76 8300 5622.55 5468.55 51 40 S 76.20 W .54 8400 5684.74 5530.74 51 24 S 76.10 W .27 1048.97S 5353.89W 5455.58 1067.37S 5429.97W 5533.79 1085.93S 5506.39W 5612.37 1104.71S 5582.85W 5691.04 1123.46S 5658.88W 5769.28 8500 5747.22 5593.22 51 15 S 76.00 W .17 8600 5809.83 5655.83 51 12 S 75.30 W .55 8700 5872.50 5718.50 51 10 S 75.50 W .16 8800 5935.28 5781.28 51 2 S 74.70 W .64 8900 5998.25 5844.25 50 54 S 75.50 W .63 1142.28S 5734.65W 5847.28 1161.60S 5810.19W 5925.15 1181.25S 5885.60W 6002.96 1201.26S 5960.82W 6080.66 1221.24S 6035.89W 6158.20 9000 6061.63 5907.63 50 25 S 75.30 W .50 9100 6125.38 5971.38 50 20 S 76.20 W .70 9200 6189.45 6035.45 49 58 S 78.80 W 2.03 9300 6254.13 6100.13 49 25 S 79.70 W .88 9400 6320.13 6166.13 47 58 S 80.00 W 1.46 1240.73S 6110.75W 6235.43 1259.70S 6185.41W 6312.38 1276.32S 6260.36W 6389.13 1290.54S 6335.28W 6465.38 1303.78S 6409.22W 6540.48 9500 6387.07 6233.07 47 58 S 80.00 W .00 9600 6454.00 6300.00 47 58 S 80.00 W .00 97004 6520.94 6366.94 47 58 S 80.00 W .00 1316.68S 6482.38W 6614.75 1329.58S 6555.54W 6689.02 1342.49S 6628.71W 6763.29 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6763.29 FEET AT SOUTH 78 DEG. 33 MIN. WEST AT MD = 9700 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 258.55 DEG. sPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/06/89 JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 1000 983.49 829.49 2000 1790.61 1636.61 3000 2422.06 2268.06 4000 3004.73 2850.73 5000 3590.93 3436.93 6000 4194.56 4040.56 7000 4814.71 4660.71 8000 5436.89 5282.89 9000 6061.63 5907.63 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 11.53 N 143.09 W 16.51 16.51 25.81 S 710.99 W 209.39 192.87 116.25 S 1480.62 W 577.94 368.56 258.14 S 2280.53 W 995.27 417.33 461.96 S 3064.50 W 1409.07 413.80 678.11 S 3831.68 W 1805.44 396.36 879.33 S 4589.74 W 2185.29 379.85 1048.97 S 5353.89 W 2563.11 377.82 1240.73 S 6110.75 W 2938.37 375.26 9700 6520.94 6366.94 1342.49 S 6628.71 W 3179.06 240.68 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/06/89 JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 54 54.00 -100.00 154 154.00 .00 254 254.00 100.00 354 354.00 200.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 .00 .06 N .18 W .96 N 2.74 W .07 N 5.54 W .11 N 9.58 W MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .04 .04 .09 .05 · 18 .09 454 454.00 300 555 554.00 400 657 654.00 500 759 754.00 600 863 854.00 700 .00 4.31 N 18.01 W .00 5.36 N 31.56 W .00 6.53 N 49.50 W .00 8.35 N 72.03 W .00 10.09 N 99.62 W .55 .37 1.48 .93 3.09 1.61 5.62 2.53 9.38 3.76 968 954.00 800 1075 1054.00 900 1184 1154.00 1000 1295 1254.00 1100 1412 1354.00 1200 .00 .00 .00 .00 .00 11.40 N 132.46 W 11.57 N 170.12 W 11.09 N 212.81 W 8.95 N 262.44 W 3.92 N 322.18 W 14 21 30 41 58 .66 5.27 .53 6.87 .28 8.75 .97 11.69 .60 16.63 1534 1454.00 1300 1663 1554.00 1400 1799 1654.00 1500 1944 1754.00 1600 2097 1854.00 1700 .00 .00 .00 .00 .00 .25 S 392.46 W 3.67 S 473.95 W 10.80 S 565.34 W 21.65 S 669.42 W 32.95 S 784.46 W 80 110 145 190 243 .93 22.33 .00 29.07 .68 35.68 .44 44.77 .30 52.85 2250 1954.00 1800.00 2404 2054.00 1900.00 2566 2154.00 2000.00 2727 2254.00 2100.00 2888 2354.00 2200.00 3052 2454.00 2300 3221 2554.00 2400 3392 2654.00 2500 3563 2754.00 2600 3736 2854.00 2700 .00 .00 .00 .00 .00 43.04 S 900.05 W 55.10 S 1016.19 W 72.18 S 1142.93 W 87.96 S 1267.94 W 104.12 S 1393.27 W 121.96 S 1522.09 W 141.52 S 1656.78 W 163.55 S 1793.43 W 188.71 S 1930.37 W 215.92 S 2068.43 W 296 350 412 473 534 598 667 738 809 882 .48 53.18 .24 53.76 .59 62.35 .45 60.86 .61 61.16 .66 64.05 .56 68.90 .32 70.76 .75 71.43 .39 72.63 3911 2954.00 2800 4085 3054.00 2900 4255 3154.00 3000 4425 3254.00 3100 4594 3354.00 3200 .00 .00 .00 .00 .00 243.47 S 2209.90 W 272.88 S 2348.43 W 305.15 S 2482.83 W 340.03 S 2614.91 W 375.50 S 2747.56 W 957.81 1031.18 1101.79 1171.09 1240.95 75.42 73.37 70.61 69.30 69.86 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/06/89 JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER 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 4765 3454.00 3300.00 411.61 S 2880.97 W 4936 3554.00 3400.00 448.34 S 3014.79 W 5108 3654.00 3500.00 485.13 S 3149.81 W 5277 3754.00 3600.00 521.32 S 3280.39 W 5443 3854.00 3700.00 557.02 S 3408.33 W 1311.55 70.60 1382.59 71.04 1454.59 72.00 1523.01 68.42 1589.27 66.26 5609 3954.00 3800.00 594.05 S 3535.37 W 5773 4054.00 3900.00 631.46 S 3660.12 W 5934 4154.00 4000.00 665.26 S 3782.35 W 6095 4254.00 4100.00 697.14 S 3904.00 W 6256 4354.00 4200.00 730.14 S 4026.18 W 1655.14 65.87 1719.34 64.20 1780.86 61.51 1841.52 60.67 1902.82 61.30 6417 4454.00 4300.00 764.17 S 4147.51 W 6579 4554.00 4400.00 798.88 S 4269.24 W 6740 4654.00 4500.00 832.09 S 4391.57 W 6902 4754.00 4600.00 863.29 S 4515.20 W 7062 4854.00 4700.00 889.43 S 4637.84 W 1963.70 60.87 2025.01 61.32 2086.47 61.46 2148.54 62.07 2208.92 60.39 7224 4954.00 4800.00 915.40 S 4762.21 W 7388 5054.00 4900.00 942.45 S 4889.41 W 7550 5154.00 5000.00 969.33 S 5013.92 W 7709 5254.00 5100.00 997.04 S 5134.23 W 7867 5354.00 5200.00 1025.01 S 5253.74 W 2270.61 61.69 2334.66 64.04 2396.61 61.95 2455.48 58.88 2513.80 58.32 8027 5454.00 5300.00 1054.07 S 5374.81 W 8188 5554.00 5400.00 1083.81 S 5497.75 W 8350 5654.00 5500.00 1114.20 S 5621.44 W 8510 5754.00 5600.00 1144.32 S 5742.85 W 8670 5854.00 5700.00 1175.49 S 5863.34 W 2573.50 59.70 2634.74 61.24 2696.68 61.94 2756.83 60.15 2816.49 59.65 8829 5954.00 5800.00 1207.37 S 5983.15 W 8988 6054.00 5900.00 1238.39 S 6101.82 W 9144 6154.00 6000.00 1267.85 S 6218.94 W 9299 6254.00 6100.00 1290.52 S 6335.12 W 9450 6354.00 6200.00 1310.31 S 6446.24 W 2875.77 59.28 2934.03 58.26 2990.83 56.80 3045.80 54.97 3096.60 50.81 9599 6454.00 6300.00 1329.58 S 6555.54 W 3145.99 9700 6520.94 6366.94 1342.48 S 6628.71 W 3179.06 49.39 33.06 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. 2K-13 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 PAGE 7 DATE -oF SURVEY: 11/06/89 JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3848 2917.53 2763.53 233.13 S 9220 6202.31 6048.31 1279.29 S 9238 6213.89 6059.89 1281.97 S 9238 6213.89 6059.89 1281.97 S 9400 6320.13 6166.13 1303.78 S 2158.57 W 9 5/8" CSG 6275.38 W TOP KUPARUK C 6288.90 W BASE KUPARUK C 6288.90 W TOP KUPARUK A 6409.22 W SURVEY DEPTH 9419 6332.85 6178.85 1306.23 S 9585 6443.96 6289.96 1327.65 S 9677 6505.55 6351.55 1339.52 S 9700 6520.94 6366.94 1342.49 S 6423.12 W BASE KUPARUK A 6544.57 W PBTD 6611.88 W 7" CSG 6628.71 W TD ARCO ALASKA, INC. 2K-13 STRATIGRAPHIC SUMMARY MEASURED ....... MARKER ....... DEPTH BKB 9 5/8" CSG TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A '--TVD BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 69FSL 94FEL SEC 11 T10N R08E 3848 2917.53 2763.53 233.13S 2158.57W 9220 6202.31 6048.31 1279.29S 6275.38W 9238 6213.89 6059.89 1281.97S 6288.90W 9238 6213.89 6059.89 1281.97S 6288.90W 9419 6332.85 6178.85 1306.23S 6423.12W 'PBTD 9585 6443.96 6289.96 1327.65S 6544.57W 7" CSG 9677 6505.55 6351.55 1339.52S 6611.88W TD. 9700 6520.94 6366.94 1342.49S 6628.71W COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE DATE OF SURVEY: 11/06/89 COMPUTATION DATE: 11/ 7/89 JOB NUMBER: AK-BO-90129 KELLY BUSHING ELEV. = 154.00 FT. 2K-13 KUPARUK ALASKA 11/06/89 SPERRY-SUN HORTZONTAL DRLG. ~JVCS. PROJECT_TON START FINISH TVD -- SCALE IS 1100 TVD -- 0 6520.94 FEET/IN DEPARTURE 6600 5500 4400 3300 2200 1100 0 ! ! I I I I ,t 1100 2200 '3300 4400 5500 6600 r- 2K-13 KUPARUK ALASKA 11/06/89 SPERRY---SUN VERTTCAL DRLG. -3VCS. PROJECTTON START FINISH TVD = SCALE IS 1200 TVD = 0 6520.94 FEET/IN LEi 1200 2400 3600 4800 6000 7200 84OO m 9700 6763.29 1200 ~o 36~o ~8oo VERTICAL SECTION DIRECTION = 0.00 6o~)o 72~0 UMI-'LIr- I IUII DATE AOGCC GEOLOGICAL MATERIALS INVENTORY UST , ( check off orlist data as it is p~ceived ! .o?! ~/'~ ~/?o drillin~ history v ' survey ! ~//well tests I core desril]tion cored in{ervals core analysis dr~ ditch intervals digital data i LOG TYPE RUN INTERVALS SCALE NO. ~1 z~/_~/~.~ - ~/~. / /~ '- ?~'~ ' ,~" 2] ~ ~ ,, ~,, ~ p.b~ E:i. ~M~.~~ / ., s~ , IO~ ,. , ARCO Alaska, Inc. . Date: May 17, 1990 Transmittal #: 7760 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510'-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-24 2K-26 2K-23 2K-25 2K-13 KRU State #1 Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET - Pulse Echo Evaluaton PET 2-13-90 7800-9696 2-19-90 8300-10220 2- 1 2-90 .w..~ ~, 2-14-90 8146-10130 2-11-90 6400-9464 2-27-90 559~-7140 Receipt Acknowledged: DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) ....~.: 7:.~. ....... APR-i2-'90 86:'42 ID:NORDIC RiG 1 TEL N0:9076597103 ~?B3 PO1 , , , r ..~o f ~ ., e , ,) , ,~ ~: .-. APR. 1 2 ]gB~ ~.u.~.~',Inspection l~epo[c ~ u,. & Gas ~ns. ~.~L ZZ'/~ ........... .-..- "'~'~ ~~,~ ' "- ' ~ene~al llousekeep~ng ~l ~ _ Fu~I Charge Fre~u~L_~ ..... psig ..... _. ,. ~lud S[~ems Visual ~ = Aud~ ........ Pump G~ Deteccorg ~ ~/ :":' Kemoce ~ Blt;~ds s~tCch cove~ ~el~y and Floor Sefe~y Valves .:~. _ -- . -~ _ ... - _ , , -~.-...._ ~ular ~=evenCer ...~, ~~" Lo-er gelly~TesC.tre~ure__~~ Pipe ~an$ ......... , ...... Ball Type ~. ?e~c Pre~u~e ..... --- Blind ~me_ , ,, ~~ ..... Inside-nC~ ...... Test Pressure ........... Choke Lfne Val~ee - .~D ~ ..... Choke final[old / ' ~est Pressure .~~/ _ , ,.~ - ' ~ - ,. - - .... .,, , Test Resu~Cs; Failure~_ . ........ Teac ~it.e ~ I,,,: Eepair o~ Replacement o~ ta~led equipment to be made ~ithin. , days slid Ittspec~or/ Co~ss~on afl,ce cc' - Opera=o~ cc - SuperVLeor ARCO Alaska, Inc. Date: January 19, 1990 Transmittal #: 7650 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. signed copy of this transmittal. 2K - 0 7 5" Acoustic Cement Bond Log 22 K 07 5" PET Log K 0 8 5" Acoustic Cement Bond Log K 1 3 5" Acoustic Cement Bond Log Please acknowledge receipt and return one 09-27-89 10-20-89 09-27-89 · 11-O5-89 5144-7993 6570...-8016... 6384-9315 6400-9464 Receipt Acknowledged: RECEIVED JAN2/4 1990 ~,~e :~ O, -~,,.,,.,,,,,.,,.,,~ co,s. co,',,~'~°'~ .DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: October 18, 1989 Transmittal #: 7574 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Kneltle CPF-3 Engineering Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ~ 2K-11 2K-13 OH Edit Tape and Listing OH Edit Tape and Listing OH Edit Tape and Listing Please acknowledge receipt and return 9-18-89 #73482 9-29-89 #73498 10-6-89 #73509 Receipt Acknowledged: DISTRIBUTION: ................. r ........... Date: -~-~ ~ ~laska Oil & (~s Cons. Commissio~ (~ ~ Alld~orage Craig Suchland : State o"f-A-ffiska T'-'~-'''' STATE OF ALASKA ~ *,,~oKAOILANDGASCONSERVATIONCOMMISSION0 RIG IN A APPLICATION FOR SUNDRY APPROVALS- 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown X.~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 69' FSL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1266' FSL, 1109' FEL, Sec. 10, T10N, R8E, UM (approx) At effective depth 1296' FSL, 1389' FEL, Sec.10, T10N, R8E, UM (approx) At total depth 1299' FSL, 1462', FEL, Sec. 10,T10N, R8E, UM (approx) 12. Present well condition summary Total Depth: measured 9700' feet (approx) true vertical 651 8' feet Plugs (measured) None 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-13 9. Permit number 89-95 10. APl number 50-103-;~0116 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: estimated (approx) true vertical 9600' feet 64 49' feet Casing Length Size Structural 8 0' 1 6" Conductor Surface 381 4' 9 5/8" Intermediate Production 9642' 7" Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Junk (measured) None Cemented 1125 Sx AS III & 500 Sx Class G 300 Sx Class G (approx) Measured depth True vertical depth 115' 115' 3848' 2909' 9677' 6502' RECEIVED OCT ! ? ; ,iaska 0ii & Gas Cons. mmisslqt Anchorage 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~ 'cJL ~ ~,-,,~ Title Area Drillincj Encjineer / FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission Commissioner IApproval No. · :.',pproved L;o~y heturned Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ARCO ALASKA INC. State AK District KUPARUK County, parish or borough NORTH SLOPE Lease or Unit ADL: 25589 AKL 2675 Title DRILLING 2K-13 Field Auth. or W.O. no. AK3684 Operator ARCO Well no. RECEIVED OCT 1 71989 Jblchorage Spudded or W.O. begun SPUD IDate Hour 09/20/89 22:30 IARCO W I. 55.8533 Prior status if a W.O. Date and depth as of 8:00 a.m. 09/21/89 (1) TD: 983'( 983 SUPV:CD 09/22/89 (2) TD: 2495'( 1512 SUPV:CD 09/23/89 (3) TD: 3864'( 1369 SUPV:CD 09/24/89 ( 4) TD: 3864'( 0 SUPV:CD 09/25/89 (5) TD: 5610'( 1746 SUPV:CD 09/26/89 (6) TD: 7912'( 2302: SUPV:CD 09/27/89 ( 7) TD: 9076'( 1164', SUPV:CD Complete record for each day reported DOYON 14 DRILLING MW: 9.0 ViS: 89 FINISH RU. ACCEPT RIG AT 1700 HRS 9/20/89. NU, TEST DIVERTER. PU BHA, SPUD WELL AT 2230 HRS 9/20/89. DRLD 300', KICK-OFF, DRLD TO 983'. DAILY:S57,900 CUM:$57,900 ETD:S57,900 EFC:$1,305,000 DRILLING MW: 9.3 VIS: 98 CONTINUE DRILLING 983'-1421' REAM TIGHT HOLE COAL SECTION AND CONTINUE DRILLING 1421'-1991' CIRC BOTTOMS UP, DROP SURVEY, AND TOH. CHANGE BHA AND TIH. REAM 1915'-1991' AND DRILL AND SURVEY TO 2495'. DAILY:S52,737 CUM:$110,637 ETD:S11©,637 EFC:$1,305,000 REAMING TIGHT HOLE 9-5/8"@ 3849' MW: 9.3 VIS: 90 DRLG DR/ 2495' TO 3864'. CIRC BTMS UP. SS. TRIP F/ BIT, BHA. DAILY:S51,775 CUM:$162,412 ETD:S162,412 EFC:$1,305,000 NU BOPE STACK 9-5/8"@ 3849' MW: 9.5 VIS:ll6 CONT REAMING F/ 1700' TO 1803'. TIH TO 3864'. CIRC HOLE CLEAN. POOH. RU AND RUN 97 JTST OF 9-5/8" 36.0#, J-55 BTC , R-3 CSG W/ FS AT 3849' AND FC AT 3767'. CMT W/ 1125 SXS OF ARCTIC SET III AT 12.1 PPG, FOLLOWED BY 500 SXS OF CLASS G AT 15.8 PPG. CIP AT 22:30 HRS, 9/23/89. PUMP TOP JOB W/ 150 SXS OF ARCTIC SET I AT 15.7 PPG. NU BRADEN HEAD. NU BOPE STACK. DAILY:S244,872 CUM:$407,284 ETD:S407,284 EFC:$1,305,000 DRLG 9-5/8"@ 3849' MW: 9.1 VIS: 32 CONT NU BOPE STACK. TEST SAME TO 3000 PSI. INSTALL WR. MU BHA AND ORIENT SAME. RIH AND TAG FC AT 3768'. TEST CSG TO 2000 PSI. OK. DRLD FLOAT EQUIP AND 10' NEW HOLE TO 3874'. DISP W/ NEW MUD. TEST FORM TO 12.5 PPG EMW. DRLD TO 5610'. DAILY:S74,947 CUM:$482,231 ETD:S482,231 EFC:$1,305,000 DRILLING 9-5/8"@ 3849' MW: 9.3 VIS: 32 TURBO DRILL AND SURVEY 5610'-7631'. CIRC BOTTOMS UP AND SHORT TRIP TO SURFACE SHOE. CIRCULATE OUT SLUG AND BALANCE MW @ 9.3 PPG. TEST FORMATION TO 10.3 EMW. DID NOT PUMP IN. TIH AND CONTINUE DRILLING 7631'-7912'. DAILY:S56,102 CUM:$538,333 ETD:S538,333 EFC:$1,305,000 The above is_cqrrect DA I LY: $ 57, 10 3 For form di see Procedures Manu I,~0~,6ection 10, ' Drilling, Pages 86 and'ET. TOH FOR BIT 9-5/8"@ 3849' MW: 9.8 VIS: 34 DRILL AND SURVEY 7912'-8866'. CIRC BOTTOMS UP AND MAKE SHORT TRIP TO SURFACE SHOE. CIRC OUT SLUG AND BALANCE MW. TEST FORMATION TO 10.3 EMW, OKi TIH AND DRILL AND SURVEY 8866'-7076'. PENETRATION RATE SLOWED. CIRCULATE BOTTOMS UP AND TOH FOR BIT. AR3B-459-1-D JNumber all dally well history forms consecutively es they are prepared for each well. iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show Iormation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District County or Parish State ARCO ALASKA INC. NORTH SLOPE AK Field Lease or Unit IWell no. I KU?ARUK ADL: 25589 AKL 2675 2K-13 Complete record for each day while drilling or workover in progress DOYON 14 Date and depth as of 8:00 a.m. 09/28/89 ( 8) TD: 9626'( 55)) SUPV:CD 09/29/89 ( 9) TD: 9700'( 7 ) SUPV:CD 09/30/89 ( 10 TD: 9700'( ) SUPV:TM DRLG F/9626 9-5/8"@ 3849' MW:10.0 VIS: 39 CONT. TOH, PU BIT #3, TIH, REAM 9010-9076, DRLG F/9076-9306, CIRC. OUT GAS CUT MUD, DRLG F/9306-9626 (INCR. MW F/9.8 TO 10.0 PPG) DAILY:S61,415 CUM:$656,850 ETD:S656,850 EFC:$1,305,000 TIH 9-5/8"@ 3849' MW:10.2 VIS: 39 DRLG F/9626-9700, CIRC, 30 STD SHORT TRIP, CIRC OUT GAS CUT MUD & RAISE MW TO 10.2, DROP SS, SPOT DIESEL PILL, TOH, RU SOS, LOG W/ TRIPLE COMBO, RD SOS, TIN TO 9-5/8" CSG, CIRC, CONT. TIH DAILY:S88,598 CUM:$745,448 ETD:S745,448 EFC:$1,305,000 TOH LDDP 9-5/8"@ 3849' MW:10.4 VIS: 40 CONT. TIH TO 6861, CIRC & INCR MW TO 10.3, TIH TO 8791, CIRC, TIH TO 9140, CIRC, REAM F/9140-9700, CIRC, SHORT TRIP 10 STDS, CIRC, SPOT DIESEL PILL, TOH 10 STDS, TOH LDDP DAILY:S119,394 CUM:$864,842 ETD:S864,842 EFC:$1,305,000 RECEIVED OCT ! :,iaska Oil & Gas Cons. Commissio Ancflorage For form preparation an/~ist~bution ~ see Procedures ManualtS~ction 10, Drilling, Pages 86 and 87 Date / / AR3B-459-2-B INumber all daily well history forms as they are prepared for each well. consecutively IPage no, ARC~ uil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if Space is available. Accounting cost center code County or Parish NORTH SLOPE Field Lease or Unit KUPARUK ADL: 25589 AKL 2675 2K-13 Auth, or W.O, no, Title AK3684 DRILLING District ARCO ALASKA INC. State JWell no. Operator A.R.Co. W,I. ARCO 55 · 8533 Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 10/01/89 (11) TD: 9700 PB: 0 SUPV:TM Date 09/20/89 Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this est center prior to plugging and J bandonment of this well I our J Prior status if a W.O. I 22:30 RIG RELEASED 7"@ 9677' MW:10.4 NaCl CONT· TOH LDDP, STAND BACK BHA, PULL WEAR RING, RU & RUN 223 JTS 7" CSG TO 9677, CIRC 2-1/2 VOLUMES, RU DOWELL, TEST LINES, PUMP 10 BBLS CW100, 35 BBLS SPACER 3000, 60 BBLS CL G CEMENT (300 SXS) W/ADDITIVES, FOLLOWED BY 370 BBLS 10.5 BRINE, ND BOPE, SET 7" SLIPS, DISPLACE 120' BRINE W/AIR, CUTOFF 7", LD LANDING JOINT, SET PACKOFF, NU TBG SPOOL, TEST TO 3000 PSI, RIG RELEASED 0030 HRS 10-1-89 DAILY:S195,355 CUM:$1,060,197 ETD:S1,060,197 EFC:$1,305,000 RECEIVED OCT .[ 719FJ -,..iaska Oil .& Gas,C0ns. .0j lssl Ancli0rage Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is co.q'ect Signature /~4/} , /~~ '7~,~ ,L Date seeP .... d .... M .... I, '~'eCti on 10~ For form preparation a~istribution, /0/ 7--~/~/~ Drilling, Pages 86 and 87. Number all daily well history forms consecutively I Page no. ~, as they are prepared for each well, 1 AR3B-459-3-C DlvlNon of AtlantlcRIchfieldCompany ARCO Alaska, Inc. Date: October 6, 1989 Transmittal #: 7575 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-13 2" Dual Induction- SFL 9-29-89 1000-9682 2 K - 1 3 5" Dual Induction- SFL 9 - 2 9 - 8 9 1 0 00 - 9 682 2K-13 2" and 5" Raw FDC 9-29-89 9000-9656 2 K - 1 3 2" and 5" Porosity FDC 9 - 2 9 - 8 9 9 0 0 0 - 9 65 6 2K-13 Cyberlook 9-29-89 9000-9630 Receipt Acknowledged' .DISTRIBUTION: Anchorage D&M Drilling Franzen L. Johnston(vendor package) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONS£RVATII',-'"-~OIvlHI W.11 s~gn &,.,-' Full ah.tgi '. .=____. ~.~,~'.. ,. pi{g -- Anaula~ preventer ~ ~. iii i.. Fii ...... I Iliad ram --~, ,~.. ~~. _., - ii flOR va I v. =_ __:, ...... ~ ~0 ..... Cheek vs ave ...... A//A - . NO, LO e - O~erltor C.O0~ lr,v ..... : ......... TO~ ~69,",-~S9 :ON ZOO pmjg .,..,_..~ln ~le pi$g. ..,c.---gltnd swl~oh Teat= ~remsurl . Teat Tilt p~mmure~__3~. , , I ~ted o~ke_ : (i I ~,: 60 68 ,-..g~.-d~S September 7, I989 Telecopy. (907)276-7542 P. J. Archey Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~chora§e, Alaska 99510-0360 Kuparuk River Unit 2K-13 ARCO AlaSkA ' ' Inc." Permit No. 89-95 Sur. Loc. 69'FNL, 94'FEL, Sec. 11, T10N, RSE, UM. Btmhoie Loc. 1366'FNL, i434'FEL, Sec. i0, T10N, RSE, UM. Dear ~. Archey: 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 taw from other governme~tal agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present go witness testing of the equipment before the surface casing shoe is drilled. W/sere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~r~ truly y~]our~s, C. V. Chatterton Chairman of Alaska Oil and Gas Gonservagion Gommission BY O~ER OF THE CO}~iISSION d!f Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS C.,ONS~VATION COMMIS,'31ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill ~[ , Redrill m I lb. Type of Well Exploratory m Stratigraphic Test m Development Oil X Re-Entry Deepen --I Service ~ Development Gas ~ Single Zone ~( Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool AR(~O Alaska. Inc. Rt<;B 154. Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25589 ALK 2675 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 69' FNL, 94' FEL, Sec. 11, T10N, R8E, UM KuDaruk River Unit Statewide At top of productive interval (~ TARGET ) 8. Well number Number 1320' FNL, 1200' FEL, Sec. 10, T10N, R8E, UM 2K-13 #U630610 At total depth 9. Approximate spud date Amount 1366' FNL, 1434' FEL, Sec 10, T10N, R8E, UM 9-1 7-89 $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 2 K- 1 2 9622' MD 1434' @ TD feet 90' at SURFACE' feet 2560 6436' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300'feet Maximum hole angle 52 o Maximum surface 1646 ps~ At total depth ~rVO} 3280 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD 'FVD IVD TVD (include sta~le data) 24 1 6" 62.5# H-40 Weld 80' 35' 35' 1 15' 1 15' :Y_2.00 CF 12.25 9.625 36.0# J-55 BTC 3807' 35' 35' 3842' 2909' 1100 Sx AS III & HF-ERV 475 Sx Class G 8.5 7" 26.0# J-55 BTC 9588' 34' 34' 9622' 6436' 200 Sx Class G HF-ERV Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth ~'°rnUdC~Uc[°al R E C E IV E D Surface Intermediate ProductionAUG 2 ]989 Liner Perforation depth: measured Alaska 0JJ & Gas Cons. C0mmissi0rl true verticalAnchorage 20. Attachments Filing fee X Property plat __ BOP Sketch X Diverter Sketch X Drilling program ;X Drilling lluid program __X_ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements .~. 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~lned F~'~-~,~ ~"~,.- Title Area Drilling Engineer Date Commission Use Only I AP, number [ ^pproval dat. 09/07/89I cove, ,e,te, for Permit Number~ ~_ ~;;~,,50- / ~)~.,~ - ~:~ O//'/~ other requirements Conditions of approval Samples required __Ye s ~ N o Mud log required ~ Yes '~{ N o Hydrogen sulfide measures ~ Yes~ N o Directional survey required '~ Yes ~ N o Required working pressure for BOPE ~ 2M; ~ 3 M; __ 5 M; ~ 1 0 M' ~ I 5 M Other: ~~.~~~~/ by order of Approved by Commissioner the commission Date .. Form 10-401 Rev~'4-89 Su~ nit in triplicate ARCO ALASKA, In~. Pad 2K. Well Not 13 KuparuE Fl el c l. Nor{h Proposed S! ope. A! O ,.. 1000_ 2000 _ ;3000 _ 4000 _ 5000 _ 6000 _ 7000 RKB ELEVAT[ON~ 154' KOP 15 21 TVD=300 TMD=300 DEP=O BUILD ;3 DE~3 PER !00 FT ;3;3 39 4.5 B/ PERMAFROST TVD=1424 TMD=1502 DEP=366 T/ UGNU SNDS TVD=1541 TMD=1651 DEP=458 $I EOC TVD=181:3 TMD=2046 DEP=744 T/ W SAK SNDS TVD=2144 TMD'-2589 DEP~"1174 B/ W SAK SNDS TVD=2709 TMD=3515 DEP=1908 9 5/8' CSG PT TVD=2909 TMD=3842 DEP=2167 K-10 TVD=3160 THD=4254 DEP=2493 K-5 TVD=4513 TMD=6471 DEP=4250 AVERAGE ANGLE 52 DEG 24 T/ ZONE C TVD--6164 TMD=9177 DEP=6393 T/ ZONE A TVD=6189 TMD=9218 DEP=6426 TARGET CNTR TVD=6252 TMD=9321 DEP=6507 B/ KUP SNDS TVD=6314 TMD=9422 DEP=6588 TD (LOG PT) TVD=6436 TMD=9622 DEP=67'46 I 1000 I I I I 2000 3000 4000 5000 VERTICAL SECTION I 6000 7O00 HORIZONTAL SCALE I !N. PROJECTION - !000 FEET ARCO ALASKA, [no. Pad 2K. Well No, 13 Kuperuk Field. North · Propoeed Slope. Aleeka 1000 1 000 2000 3000 7'000 6000 5000 I I TD LOOAT ! ON" 1366' FNL. 14~4' FEL SEC. I0. TION. RSE TAROET CENTER TVD-6252 THD-932! DEpi6507 SOUTH 1251 UEST 6386 TARGET LOCAT ION ~ I;~20' FNL, 1200' FEL - SEC. I0, TION, RSE 4000 I WEST-EAST 3000 I S 78 DEG 6507' (TO 2OO0 I 55 MIN W TARGET) 1000 I 1 000 I SURFACE LOCAT[ON~ 69' FNL, 94' FEL SEC- II,'TION. R8E :300 250 200 150 100 50 0 50 100 150 100 5O 0 50 100 150 -'~f3oo i ~00 I 250 I 200 * 30O O0Ull, ,, ,,, 1 O0 150 im I I I I I 100 50 0 50 100 150 100 50 0 50 100 150 DRILLING FLUID PROGRAM (2K-15) Spud to 9-5/8" Drill out to Weight up _surface casing weight u.~ to TD Density 8.8-9.0 8.7-9.2 9.8 PV 15-30 5-15 1 1-16 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 1 0-1 5 1 0-2 0 6 pH 9- 1 0 9.5-10.5 9.0-10.5 % Solids 10 +/- 4-7 12-15 Drillino Fluid System: -- - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes- 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 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-13 is 2K-12. This well is 90' away at surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU, 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. · 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) NO BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change 'over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22} Fracture stimulate. OEGASSER MUD CLEANER SHALE STI STIR STIR SHAKERS TYPICAL MUD SYSTEM SCHEMATIC KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES WI10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEi=L VALVES CAN BE REMOTELY CONTROl. LED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION I ! 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR~IS DETECTED. OPEN APPROPRIATE VALVE TO ACH~/~WNWlND DIVERSION ' ~ ~,,/, DO NOT SHUT IN % UNDER ANY CIRCUMSTANCES ,... JG 4/26/88 7 , 6 I I 13 5/8" 5000 PS, BOP STACK A(~CUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 30(X) 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. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 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. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL 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 NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND 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. 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. 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 SRE 8/22/89 DOYON 14 ARCO Alaska, Inc. Post Office Box 1(.10360 Anchorage, /~laska 99510-0360 Telephone 90'7 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat- 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & Gas Cons. C0mmissim~ Ancl~orage GRU13/010 ARCO Alaska, Inc. is a Suhsidi,lry of AllanlicRichfieldC~mp~ny o ~J WELLS 1-12 ARE LOCATED IN ~ 3~ 36 $1 ~ SECTION 2., T. I0 N., R. 8 E., ~i UMIAT MERIDIAN. ~ i WELLS 13'24 ARE ~CATED IN N.TS. ~ * ~ 6:7 SECTION 2 ~tt SECTION ~ ' "~ vICi dlTY MAP I"= Imi. ~ i ~RAOTED ~tes: ,~ ~ t4~',~ SECTION CORNER I. COO~INATES ARE &SR ZONE 4. SECTION II tO'tO SECTION f2 P. ALL DISTANCB SHOWN ARE TRUE. . ~Zl i 3. ELEVATIONS ARE B.P.M.S.L. · ' IVED 4. O.G. ELEVATIONS FROM ,J RECE 5. HORIZONTAL POSITION BASED ON ~-K CONTROL j MONUMENTS PER ~NSBURY S A~OClATES. 2 DEC 1 ~ 1988 ~' 58REFERENCE, 59, 6~ 8 66.FIELD BOOK, L 88-~, p~. 55,56, ~'"" ........ DiS[ i Dist. O.G. ' ~d Well~ 'Y' ASP's ' X ' ~lasl ~ Uit~~& G~s b<,,,~. ,;I ~NGITUDE ~ F.S.L. .: EE.L. Elev. Elev. '~6 519" 150°00'49.~'' 296' g4' 114.0 118.5 I 5,9~8,600.18 498,~10.17 I 70°14, . 2 5,g58,575.14 498,510.28 [ 70Ol4 56.275" ~ 150°00'49.150'' 271' 115.g II 4 i 5,9~8,~5.46 , 498~10.06 70°1 35.784 150°00'49.1 2~ 11~.8 5 ~ ~,9~8~500.1g i 498,~10.1~ ~ 70°14'~5.5~6" I~0°00'49.1~4'' ~ 196' : 11~.8 6 ~,9~8,47~.14 498,~10.~ 70 ° 14' ~5.~89" I ~0° 00' 4g. 1~8" 171' 113.8 Z 5~9~8,450.36 498,~10.~6 70°14'~5.046" ~ I~0°00'4g. 127'' 146' I1~.~ 8 ' ~,9~8,4~.~0 498,~10.18 70°!4'~4.799" ~ I~0°00'4g. 1~2'' I~1' ' !1~.8 9 5~g~8,400.~0 498~09.98 70°14'~4.55~'' i I~0°00'49.1~7'' 96' 11~.8 I0 g,9~8,~7~.19 498,810.14 70°14'~4.~06" i 150°00'4g. 1~'' 71' II~.g I I I 5,938,350.22 498,310.14 70°14' 34.061" ' 150°00'49.133'' 46' IF 113.9 12 5 9~8,52520 498,~10 17 70°14'33 815" 150°00'49.131'' 21' 94' 113.9 ~ 118.5 ,~ EN.L. 13 5 9~8,2~5 31 498 31o.37 70Ol4'52.93o'' ~ 15oooo'49.125'' 69' 94' 113.7 ~ 118.5 t ' ~ I 14 5,9~8, 210.14 498,310.16 70°14'32.683" ~ 150 ° 00' 49.131'' 94' 115.7 15 5 ,958,185.12 498,310.16 70°14'32.437'' ~ 150°00'49.131" 119' tl3.8 , .... ,, , oooo . 17 5~938, 135.21 498,310.18 70°1 31.9 150°00'49.130" 169' 113.9 ; ~ 18 5,938, 110.19 ~ 498,310.29 70° 14' 31.700" ~ 150000'49.127'' 194' 114.0 19 5,9~8,085.~0 498,310.27 70014' 31.454" ~ 150°00'49.127'' 219' 114.0 ! 20 5,938,060.14 498,310.22 70°14' 31.207'' 150°00'49.128" 244' 114.1 21 5,9 ~8,0~5.16 498,~10.16 70° 14' 30.962'' 150° 00'49. I~0'' 269' ~ 114.0 j22 5,938,010.40 498,510.19 70°!4'30.718 " 150°00'49.129" 294' 94' 114.0 123 5,937,985.~ 498,310.13 70 °14' 30.471 150° 00'49. 130'' 319' 95' 114.0 ~24 5~937~960.29 498,310.08 70°14'30.~25'' 150°00'49.132" 344' . 95' I 113.9 118.5 I HEREBY CERTIFY THAT I AU ~~," STATE OF ALASKA AND THAI .~,~ Poeeoeo. .......... ~ ....... ~ m m [1 PLAT REPRESENTS A SURVEY MADE ~ ~~~~ ~ BY ME OR UNDER MY DIRECT SUPER- · · DRILL SITE ,, AND OTHER DETAILS ARE CORRECT ~,,... .-~ ~ , I I ..... .0'D i ~:l Ill I I ] I I I Il lilI I I I i I i I i Well ASP's AlaSl a vii & Ga~ 6u,,$. t;o;Ti,,"~;ss:~;:: OiSt Dist. O.G. Pod Nc 'Y' 'X' I-~]~d~ LONGITUDE F.S.L. E E.L. Elev. Elev. I 5,938,6oo. 18 498,$1 o.17 7o° 14'36.519 " 150oo0'49/133" 296' 94' 114.0 118.5 2 5,938,575.14 498,31o.28 70° 14' 36.273" 150ooo'49.15o'' 271' 113.9 3 5,938,550.30 498,31o.35 70° 14' 36.029" 15o °oo'49.128'' 246' 11:5.8 4 5,938,525.46 498,31o .o6 7OOl4' 35.784" 15oooo'49. 136'' 222' 113.8 5 5,938,500.19 498,$10.1z 70o14. 35.536" 150ooo'49.134'' 196' 113.8 6 5,938,475.14 498,31o.33 7o o 14' 35.289" 15oooo'49.128.' 171' 115.8 7 5,938,450.36 498,310.36 70014'35.046" 15oooo' 49.127'' 146' 113.8 8 5,958,425.30 498,31o.18 7oo 14' 34.799" 150 o o0' 49.152'' 121' ' !13.8 9 5,938,400.30 498,309.98 70014' 34.553" 150ooo'49.137'' 96' 113.8 10 5,958,375.19 498,51o.14 70014'34.306.' 150ooo'49.133'' 71' 113.9 I I 5,938,350.22 498,310.14 70°14' 34.061 " 150°00'49.135'' 46' I ~ 113.9 12 5,938,525.20 498,310.17 70°14' 33.815'' 150 °00'49. I$1'' 21' 94' 113.9 118.5 EN.L. I$ 5,938,235.31 498,310.37 70°14'32.930'' 150°00'49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70 °14' 32.683" 150o00'49.131'' 94' 113.7 15 5,938,185.12 498,$10.16 70o14'32.437" 150°00'49.131'' 119' tl3.8 16 5,938,160.11 498,310.20 70°14' 32. 191" 150°00'49.130" 144' 115.8 17 5,938, 135.21 498,310.18 70°14'31.946'' 150o00'49.130'' 169' 113.9 ; 18 5,938,110.19 i 498,310.29 70°14' 31.700" 150°00'49.127'. 194' 114.0 19 5,938,085.20 498,310.27 70014' 31.454" 150o00'49.127.' 219' 114.0 ! 20 5,938,060.14 498,310.22 70°14' 31.207'' 150° 00'49.128'' 244' 114.1 21 5,9 38,035.16 498,310.16 70014'30.962" 150° 00'49. 130'' 269' ,[ 114.0 22 5,938,010.40 498,310.19 70014'30.718'' 150°00'49.129" 294' 94' 114.0 23 5,937,985.32 498,310.13 70 °14' 30.471'' 150° O0'4g. 130'' 319' 95' 114.0 24 51937,960.29 498,310.08 70 °14' 30.225'' 150°00'49.132" 344' 95' I 113.9 118.5 ITEM APPROVE DATE CHECK LIST FOR NEW WELL PERMITS ( 3 ) adm in Z/Y~ ~_~z~ ~ · (9 ~hru 13)-' ' (10 and 13) (4) Casg ~.,~,~.~f, ~-Z-gP (14 thru 22) (23 thru 28) Company 1. Is the permit fee attached .......................................... Lease & Well No. /~Z)~ YES NO 2. Is well to be located in a defined pool ............................. ~ 3. Is we~] located proper distance from property line .................. 4. Is we~,l located proper distance from other wells ................ .... 5. Is su.z~iCient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ............... ". ..... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........ , ................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be. kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... //~r Is the drilling fluid program schematic and list of equipment adequate /z~ Are necessary diagrams and descriptions of diverter and BOPE attached. ,,~ Does BOPE have sufficient pressure rating - Test to ~ocD psig .. .~,,~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ; (6) OTHER ~ 5~~ thru 31) Geology: Eng,i?,n, eerin~: ,cS C rev: 01/30/89 6,011 -For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional requirements ............................................. ~ Additional Remarks: 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. ~'~,- ~L A:S ~ A COMPUTING. C !EN TE R-,."' '~- ........ SCHLUMBERGEq -? WELL N.~ME : 2K- 13 FIELC N~ME ' KUPA~UK 5ORGUGH : NORTH SLOPE STATE : AL4SKA AP~ NUMBER : 50-103-Z~116 RECERENCE NO : 73~9~ :NC. .IS T~.PE VERIF.I,C~TION LISTING SCHLUM~.ERGER AL~.SKA CO!~PUTING C~N'T~ER I0-0CT-1989 15:58 ~X~ REEL HE~BE~ X-'.~ = = SERVICE NAME : EDiT DATE : 89/10/10 ORIGIN : FLiC REEL NAME :: 73~9~ CONTINUATIBN :~ : PREVIOUS R~EL : COMMENT : ~&~CO AL~SKA~ INC. ,KUP~a, RUK 2K- t3 , ~Pl ~50-103-20116 ~ TAP~E HE,&OER SERVICE NAME : EDIT O~TE : ORIGIN : FLIC TAPE NAME : 73499 CONTINUATION ~ : ! PREVIOUS T~PE COMMENT : ~RCO ALASKA, INC. ,KOP~RUK 2K -13 , A~mI ~50-103-20116 FILE N~ME : EDIT .001 SERVICE : =LIC VERSI~3N : 00lA02 DATE : MAX REC SIZE : 1024 FILE TYPE L~ST FILE COMPANY NAME: '4RCO ALASKa, INC. WELL: 2K-13 FI ELD: KUPA ~UK BORDUr~H: NO2TH SLSP5 STATE: ~L~SKA ~PI NUM~E~: 50-103-20116 LOCATION: 69' FNL ~ ~4' SEC"ION: 11 T~WNSHZP: 1CN R~NGE: B= .'IS 'TAPE VERZmICA'TION;, LISTTMzN:~ SCHLUM~ERGER ~LASKA COMPUTING CENTER lO-QCT-1989 1.5:]58 PERMANENT DATUM: MSL rZLEVAT!ON: 0 'LOG MEASURED ~FROM RiK!B !5¢ A~OV'E PER~ANEN'T DATUM ELEV6:TIONS KB: 154 153 GL: 113 DATE LOGGED: 29-SEP-Sg RUN NUMSER: ONE TD DRILLER: 9700 TO LOGGER: 96'9,2 CA:SiNG: 'g 5/8" 47 LB ;9 DRILLER DEPTH,,,'=m, ~848~ AND L'OGGER DEPTH OF 38~67 B'IT SI.Z~: :B 1/2" @ 9700 TYPE F:LUIO IN MOLE: WEIGHTED ~CLYMER OENSITY: IO.Z VISCOSiITY: ,¢0 PM: 9.5 ~LUI-O LOSS: 3.8 MUD RESISTIVITY: FILTRATE RESISTIVITY: ~:UD C~KE ~ESISTIVITY: 4.48 ~ 65 4.89 ,~ 65 3.45 @ 65, TIME CIRCULATION END~Q: 16:30 28-SE:P TiNE LOGGER ON B~TTDM: 23:20 28-SEP MAXIMUM TEMP ~C~RD: LOGGING DISTRICT: LDGGIN'G ENGINEER: WITNESS: PRUDMOE ~Y PEAL/DIXON TDDL NUMB~ERS: g-IS-~C 1131 ~GS-HB 508 CNC-A 1238 I.EM-B O 1290 OIC-D~ 417 P%C-J~ 1041 SGC-JC 2626 NLM-B C 1329 FIELD RE~RKS: 1 1/2" STANDOFFS ~ND A Z' HOLE FINDER USED ON THE OIL. MATRIX DENSITY = 2.65 G/CC., FLUID DENSITY = 1.0 S/CC. N:UTRmN~ M~TRIX~ = SAND, MgLE C~R~ECTION~ = CALIPER. S~ SHI=T AT 5275~. DATE JO~ ST~RTEO: 03-gCT-89 JgB REF:RENCE ND: 734'98 L~P/ANA: J. K3HRING .IS T~PE V!ERIFZCATICN LISTING ~CHLUMSERGcR ~LA,SKA COMPUTING CENT~_R I O-QCT-1989 15:58 PAGE: 2 K - 1.3 50-103-~_01!6 MAIN PASS LOG DAT.& DATA S~MPLED ~V~R'¥ -.5000 FEET T~ ~ g ,~, L E X T ~ N S I O N T O g L T Y P E U S iE C N A M 6 DIT.-D . FDC , FOC :C NT-~./D/H .CNL GR .CSG OUAL INDU.C'TIgN SFL FORMATION D~NSITY COMPENSAT~O NEUTRON GAMMA 9682' TO ~847' 9656' TO 8996' 96~I' TO 8996' ~849~ TO 9T9' TABLE TYP=_ : CONS T UNI VALU u CN ~RCO ALASKa, INC. FN KUPARUK WN 2 ADIN 5 ~'-103-ZO 116 F'L 69' FNL S ~F- CT 1 TOWN ION RANG CDUN NORTH SLOPE STAT ALASK,~ N~TZ ENGI G. W~,RNER WITN ~ E~L/DIXON SON 548739 POAT ~SL EPD :T 0, LMF RKB EK8 FT 154. EOF :T 15.~ EGL FT 113 TDD ~T 9700. BLI FT 9684. TCS 16:30 28-SED TLaB 23:20 23-SEP COMPANY N~ME ~IELD NAME W E L L N ,~ M E API SERIAL NUMBER FIELD LOCATION SSCTION TOWNSHIP RANGE COUNTY ST~TE OR PROVINCE N~TION ENGINEER'S NAME WITNESS'S NAME SERVTCE ORDER NUMBER PERMANENT DATUM LOG ME,&SURED FROM SOTTOM LOG INTERVAL TIME CIRCULATION STOPPED TI~E LOGGER ~T BOTTOM TAPE YER[FICATIgN LISTING ~CNLUM~,ERG~R ALASK~ COMPUTING CENTER t0-0CT-!989 15:58 TABLE TYPE : CUqV DEPT ILO ILM S FLU SP GR TENS g PHI RH08 D RHO FFDC NFDC CALI GR TENS NPHI TNPH TN RA N P g ~ RCNT RCFT CNTC CfTC GR CALI TENS G~ TENS D IL ~L SF .S P GA M~,~ R~Y EFI PTH CHANNEL N,~ME -DEEP ~ESiSTIVITY -MEDIUM ~ESIST~VITY L UNAV~ERAG~ED ONTANEOUS PCTENT!~L TENSION gENSITY PDRCS~TY B, ULK DENSITY [3ELTA FA~ ~DC COUNT R~TE NEAR FOC COUNT RAT~ GAMMA TENSION NEUTRON POrOSiTY 'THi~R~AL NEUTiRON PO:~gSI'TY C~.LIBRATiED TH~ERMAL NiEUTRSN R~'TZD NEIJ'T~DN POROSITY OUTPUT FROM ~N RAW CDRREC~EO NEAR T~qERN~L COUNTS RAW COrReCTED F~ THERMAL C:UNTS CORRECTED CORRECTED GAMMA ~Y CALIPER TENSION GAM~A RAY TENSION NEAR THERMAL COUNTS !F~R TH'ERMAL CCUNTS ,~ P m L I C ~ T ii 0 N PROGRAM FOR!MAT .SPECI~ICATIEN: . RECORD. ~'~'~ ~=~ SET ~YPE - 64E0 ~ 'TYPE REPR,.. ,., V ~LUE Z 66 3 73 ! 1 2 4 66 1 5 6 .73 T 8 68 g. 5 9 65 ~T t ! 66 9 12 68 13 56 O .'IS TAPE VER'IFIC,~TZC'N LISTING ~CHLUMBERGER ~LASKA CCMPUT!NG CENTE~ lg-OCT-1989 15:58, PAGE: T YP E REPR CODE V~LUE t 4 65 F T 15 66 58 ! 6 .66 I SET 'TYPE - CHAN ~- NAME SERV UNIT DEPT FT 548739 O0 OO 0 O0 0 ! I L D :D I L 0 H M M !548739 0 ? 120 4 ILM g!t ~HMM 548739 07 120 44 0 1 1 S:FLU DIL CHM~ 548739 OT 220 O1 0 1 1 SP OIL MV 548739 07 O10 O! 0 I 1 GR OIL G.API 54'8739 0'7 310 O1 0 t 1 TENS DIL L~ 548T~9 07 635 21 0 1 1 DPHI FDC PU 5,48739 07 ~5 21 0 t 1 RHgB ~DC G/C3 543739 07 535 21 0 I 1 DRHg ~DC G/C3 548739 07 635 21 0 1 1 FFDC ~:DC CPS 54873~ OT 535 2! 0 ! 1 NFOC FDC CPS 548739 07 635 2t O 1 1 CALI mDC IN 5~739 0'7 635 2 G~R FE'C GAPZ 548739 07 635 21 0 1 1 TENS ~DC L8 54~739 07 635 21 O 1 1 NPHi CNL PU 54~739 07 635 21 0 1 1 TNPH CNL PU 548739 07 535 21 0 I 1 TNRA CNL 54'~'739 07 5~5 21 0 1 NPOR CNL PU 548739 07 635 21 0 I '1 RCNT CNL CPS 548739 07 635 21 0 I 1 RCFT CNL CPS 548739 07 635 21 O 1 ,1 CNTC CNL CmS 54373~ 07 535 2,1 0 1 1 CFTC CNL CPS 548739 O~ 635 2! 0 1 1 GR CNL GAPI 54~739 07 635 21 0 1 I CALi CNL IN 54~739 07 635 2! 0 1 1 TENS CNL LB 548739 OT 635 21 0 I 1 GR CSG G~PI 54~739 07 310 gl 0 1 TENS CSG LB ~aSTB9 07 635 21 0 I I N U M B EL !E M SI ZE ~EPR CODE PROCESS .(HEX) 68 68 68 6 ;B 68 68 68 68 68 68 68 6~ 68 68 68 6~ 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOO000000 O00000OO00 0000000000 0000000000 O000OOOO00 0000000000 OOOOOO0000 000000O000 OOOO00OO00 0000000000 O00000OO00 0000000000 0000000000 0000000000 OOgO000000 0000000000 0000000000 0000000000 0000000000 DEPT. 9701.500 ILO. CIL 3. 441 SP. OIL -12. 109 GR.OIL 105. 563 RHEa. FDC 2 . 524 gRH.g. F:3C O. 11 O C,~L!. FCC 7.72~ GR.=OC I05. 563 TNPH.CNL 37. 502 TNR~.CNL 3.226 RCFT.CNL 559.956 CNTC.CNL 2013.192 C&LI.CNL 7.723 TENS.CNL 1~65.000 ILM.DIL TENS.DIL FFOC.FOC TENS,FgC NPOR.CNL CFTC.CNL GP.CSG 3.644 1465.000 ~,:0 O . 750 1465.000 37. 502 635,021 -999.250 SFLU.0!L DPHI. mt]C N=DC.FDC NPHI.CNL. RCNT.CNL G~.CNL TENS .CSG 3.436 7.618 656 · 500 39.337 1971.342 10.5.563 -999.250 .I.S TAPE YERIFICATZON LISTINS SCHLUMBERG:R. ,~LASK,~ CgMPUT't~,No~ C~NTER. DEPT. 9'700.0 00 ILO. C.tL SP. DIL .-12.3 5.2 GR. 0IL RHOB.FOC 2.524 C&LI. FDC 7. 723 GR. FgC TNPH.CNL 37.E02 TNRA.CNL RCFT.CNL 559.956 CNTC.CNL C~LI.CNL 7.723 TENS.CNL DEPT. 9600.000 ILO.OIL SP.OIL -15.602 GR.~IL RHDS,FDC 2.469 gRH:.FDC CALl, ~DC 8. 750 GP,. FDC TNPH.CNL ,~3.627 'TNRA.CNL ~CFT.CNL 5~4.924 CNTC.CNL C~LI.CNL 8.750 TENS.CNL OEPT,. 9500. 000 ILO. B IL SP. DI'L -19.4 22 GR. OiL RH08. ~'DC 2.4!2 OPHO.FgC C ALI. ~DC 9.67Z GR. FDC TNPH.CNL 38.454 TNRA.CNL RCFT.CNE 591.606 CNTC.CNL C ,~ L Z. C N L 8.67 .Z T E N S .. C N L DEFT, 94 00.000 ILO, CZL SP,OIL -24.. 8¢4 GP.DIL RH08o~DC 2..420 ORHO.'~:OC CALI. FDC 8.398 G~. FDC TNPH.CNL ~0..132 TNR~.CNL RCFT.CNL 7,~6. 850 CNTC.CNL C~Li. CNL 8.398 TENS.CNL D~PT. 9300. 000 ILO.OIL SP.OIL -:50.1 56 'SR.O IL RHO~.=DC 2.~94 gRHO.FDC C~LI.FDC 8.89~ GP.FOC TNPH.CNL 27.286 TN~A.CNL RCFT.CNL !102.655 CNTC.CNL CALI.CNL 8.,B'78 TENS.CNL SEPT. 9200. 000 iLC.CIL SP.DIL -32.875 GRoEIL RHOS.,=DC 2.455 DRHO. FDC C&LZ.FDC 9.289 GR.FDC TNPH. CNL 36.9 76 TNRA. CNL RCFT.CNL 546.~30 C~TC.CNL C~Li. CNL 9.2B9 TENS.CNL 10-0CT-1989 '115:58 3. ¢~! ILM.O IL 105.56:3 TENS.OIL 0.110 FFOC.FDC 105.563 TENS.FDC 3. ZZ$ NPOR.CNL Z 013 · :1 '92 C F 'T C. C N L 2040. DO0 GR.CSG 4. 262 ILM.DIL 95. 313 TENS.OIL 0.0 ! 8 ~: F D:C. F O C 95.313 TENS .FCC 3,. Z77 NPOR.CNL 21153, [11 CFTC.CNL 4568.000 GR.CSG 7.~42 ILM.D!L 91.563 TENS.D!L 0.086 FFDC.FDC 91.563 TENS.~DC 2.~1~¢ NPOR.CNL 2385.299 CFTC.CNL 4504.000 GR.CSG 32.355 !LM.OIL 43. 875 TENS.D'iL 0.014 FFDC.FDC ~3.87.5 TENS. FDC 2.535 NPOR.CNL '~19~. ?:3., CFTC.CNL 172. goo G~.C SG 2.613 ILM.DIL ~8._,'~75 'TENS.,C IL 0.022 =FDC.FDC 12~. 375 TENS.FgC ~.156 NPOR.CNL a.~6.9~7 CFTC.CNL 4¢2~.00g ~R.C,~G 2.629 iLM.BIL 12 ¢. 37 5 TENS. D IL 0.013 =FOC.FDC 12~.,q75 TENS.~OC 3.563 NP3R.CNL I ~3'3. ~,80 CFTC.CNL ZOz~O.O00 500.750 2040. 000 3 ?. 50 Z 63:5. 021 -~99.250 2.465 448S.000 50 2. 500 4,%88. 000 42,, 651 567.306 - ~99. 250 4.356 4568.000 525.50O 4 568.000 3 8 .,464 ,$64.755 - 99 '9.250 7.763 450,~.000 610.500 30. 996 88.4.120 -999.250 37.047 4172.000 697.000 4172.300 1262.473 -')99.250 2.667 477.750 ~+z~2 ~+. 000 38.285 515.502 -999.25~ 2.674 ~184.000 ~63.250 4154.000 41.073 557.47~ S~LU.OIL DPHI.FDC NFDC.FOC NPHI.CNL RCN'ToCNL gR.CNL TENS.CSG SFLU.OIL DPH!, FDC N;:DC. ~mDC N~H !, C NL RCNT.'CNL GR. CNL TENS.CSG SFiLU.OiL OPHZ.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL T=NS.C~''~- a~ S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TENS.CSG SmLU.DIL DPHi. FDC NFCC.FDC NPHi. CNL RCNT.CNL GR.CNL TENS.CSG S~LU.DIL DPH'I.F~C N:DC.~OC NPHI.CNL RCkT.CNL GR.CNL TSN.S.CSG SFLU.DIL D~i.:DC NFOC.~OC NPHi.CNL RrN~ CNL GR.CNL 3.436 7.618 666.500 39.337 1971.342 105.553 -999,250 2.250 10.954 627.000 42.307 2020.297 110.688 -999.250 3.935 14.434 600,500 38,855 2108,3.~3 95,313 -999.250 6.587 13.951 688.500 31.244 2283.488 91.563 -999.250 51.185 21.604 647.000 26.455 3164.226 4~.875 -999.250 2.54I I1.81~ 587.000 35.722 18.50.982 IZ$.375 -999.250 2.532 11.608 572.500 43.201 1929.492 124.375 _IS TAPE YERI~IC~T.IgN LISTING SCHLUMBERGER ~,LASKA CCMPUTING .C~NTER CALI.CNL 9.281 TENS.CNL DEPT. 9000. 000 ILO. SP. OIL -31. 625 GR. git RHOS,FDC 2.3 26 DRH~,FDC C ALI, FDC 12 o 469 GR, FDC TNPH:.CNL 4'1. 708 TNRA.CNL RCFT.CNL 410.966 CNT.C.CNL C~L!.CNL ~2.46~ TENS.CNL DEPT. 3'900.0 O0 ILO,,.D IL ~SP.OIL '-30.3 59 GR.CIL RH08...~OC ,-999.250 DRHO.FDC C ,,~'L I. F D C - 999.2 i~ 0 G R. F S C TNPH.CNL -999.250 TN~A.CNL RCF'T.CNL -99~.~50 CNTC.CNL C~LI.CNL -~9. 250 TENS. CNL DEPTo 8800. OOO I LO. OIL SP. OIL -39. 375 GR.DIL RHC~5.FDC -999.250 g:RHO.FDC C AL i. FDC -999.250 GR. FDC TNP'H,CNL -999.250 TNRA,CNL RCFT.CNL -999.250 CNTC.CNL C.&LZ.CNL -999.250 T~NS.CNL OEPT· 8700. 000 SP.gIL -42. 1~5~. GR. OIL RHg~,FDC -999,250 DRHO, F.gC CAL'I. ~DC -9 99.250 GR. FDC TNPH.CNL -~9.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.250 T~N'S.CNL DEPT. 8600.000 ICg. GIL ~SP. OIL -35.375 GR..3IL RHOB ~DC -999 250 DRHg CALI. FDC -999.2'50 GR. FDC TNPH.CNL -999.250 TN~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 95 -,SC. OOC ILO. D iL SP.DIL -39.156 GR.CIL R H g'..-5. FD C -~99.250 DPMO.FQC C ~LI .FDC -999. 250 SR . FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.25C CNTC.CNL CALI.CNL -999.250 TSNS.CNL DEPT. 8400,000 ILD.CiL SP..]iL -~1.6.25 GR, C IL RHOB.'mDC -999. 250 CALI. FCC -~ 99. Z 50 GR. FDC TNPH,CNL -999.250 TN R~,CNL IO-OCT-1939 15:58 4:i84,000 GR. CSG 3 . 562 I L M. g I :L 122. 063 TENS.DiL 0.002 FFD'C.FDC I:22.063 TENS,FOC 3.601 NPOR.CNL 165!. 569 CFTC.:CNL 4Z~O. 000 GR.CSG 3. 343 ILM. D IL 216.875 TENS.OIL -999.250 FFgC. FgC -~99. 250 TENS,FDC - 999. ,250 N P 0 R ~, C N L ,-999. 250 rFTC~ ,CNL '-'999. ,250 GR.CSG 3.592 ILM.DIL 236. $75 TENS.D IL - 999. 250 K'FQC. FDC -999.250 T.ENS. FgC -'999.250 NPOR.CN~ - 999.. ,250 C F T C. C N L -999. 250 GR,C SG 3.7518 ILM.DIL 131.250 TENS..DIL -999.250 FFDC.FDC -999.250 TENS.=DC -999.250 NPO~.CNL '-999.250 CFTC.CNI - 999. 250 gR.CSG 3.589 ILM.DIL 12'7.375 TENS.OIL -999.250 FFOC.FgC -999.250 TENS.FDC -999.250 NPQR,CNL -999.259 CFTC.CNL -999.250 GR.CSG 4.621 ILM.DIL 103.438 TENS.OIL -999.250 :FDC.FDC -999.250 TENS.FgC -~99.250 NP3R.CNL -'999.250 C~TC.CNL -99'9. -~50 GR,CSG 5.05~ IL~,DIL 142.250 TENS.DIL -999,250 FFDC.FDC -9S'9. 250 TENS.~gC -999,259 NP~P.CNL -999.250 3.638 424,0.000 624.500 ,¢ 24 0.000 41..479 459.352 -99 9. 250 3·202 4'168.0,00 -999.250 .-999.2!50 -999.250 -'999.250 -999.250 3.659 4000.000 -:999.250 - 999.250 -999.250 -999. 250 -99 9.2 5:0 3.842 386,4. 000 -999. ,250 -999.250 -99'9.250 -999.250 -999.250 3.652 3910.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.673 4180.000 -999.250 -999.250 -999.250 - 999. 250 -999,250 5.031 382~.000 -999.250 -999.250 -999.250 TENS.CS~S SFLU.gIL NF:DC. FDC NPH [. CNL RCNT..CNL GR.CNL T='NS.CSG SFLU,OIL DPHI, FDC NFCC, FDC NPHI,CNL RCNT, CNL GR,CNL TENS ,CSG S~LU.DIL DPHI. mDC NFgC.FDC NPHI.CNL R C NT. CNL G.,R. CNL TENS.CSG SFLU.DIL DPHI,FOC NFDC, ~DC NPHI.CNL RCN'T.CNL G2,CNL TENS.CSG SFLU.DIL DPHI.~-DC NFDC.FDC NmHI.CNL RCNT.CNL GR.CNL TENS .CSG SFLU.DIL DPPI.FDC NFOC.~DC N~HI.CNL RCNT.CNL G2.CNL TENS.CSG SFLU.OIL DPHI.FDC NmOC.FDC NPHI.CNL RCNT.CNL P~GE: -999.250 3.855 19.620 612.500 40.907 1625.093 122.063 -999.250 3. 547 -999.250 .-999.250 -999.250 -999.250 - 999.250 - 999.2 50 4.034 -999.250 -999.250 -999. 250 -999. 250 - 999.250 -999. ,250 3.267 -999.250 -999.250 -999.250 .-999.250 -999.250 -999.250 q 969 .-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~ .739 -999.250 -999.250 -999.250 -999.250 -999. Z 50 -9'99.250 4.494 -999.250 -999.250 -999.250 -999.250 .IS TAPE YERIFIC~TIgN LISTINS ~CHLUM~ERGER ~L,ASK,~ COMPUTING CENTER RCF!r. CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 8300.0 O0 ItO.gIL SP. OIL -37.81 RHD~.F~C -999.250 ORHO.FDC C~LI.FDC -'999.250 GR.. FDC TNPH.CNL -999.250 TNR~.CNL RC:F'T. CNL -999.2 50 CNTC.CNL CALI.CNL -999.250 TENS.CN~ D,EPT. 8200. 000 ILO. C. IL SP. OIL -42. ~44 GR. OIL RHOB.. FDC -999.250 DRHO.FgC C.AL!. F:DC '-'9'99.250 GR. FgC TNPH.CNL -999.250 TNR.~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 51 00.0 O0 ILO.OIL SP.OIL -54.594 GR.DIL RHOB.FOC -999.250 ORHg. FDC C ~'LI. mDC -999.2 ~0 ~R. FOC TNPH.CNL -999.250 TNR4.CNL RCFT.CNL -999.250 CNTC.CNL C,~LI.CNL -999.250 TENS.CNL DEP'T. 3000.0 O0 ILO. OIL SP. OiL - 53.0 63 GR,OIL RHOB.FDC .-9~9.250 gRHC.~OC CALI.FDC -999. 250 G~. FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. T900.OOO ILC.CIL SP. OiL -4'9.4~8;, .GR. OIL R HO;3. FDC -9go. 25 ~ DRHg. C AL I.'.:DC -999.250 GR. FSC TNPH. CNL -999.2 50 TN~,. CNL RCFT. CNL -999.250 CN TC. C NL C~LI.CN[ -999. 250 TENS.CNL DEPT. 7800.000 ILO.OIL SP.DiL --~9. 125 ~R.DIL RHg5..=DC -999. Z 50 GRH:. FgC CALI. FOC -9 ~9.2 5~ GR. FC, C T NPH. CNL -9 99.2 5 ~ TNR~. CNL RCFT.CNL -999.25:0 CNTC.CNL C~LIoCNL --999. 250 TENS. CNL DEPT. ?700.000 IL~.DIL SP.OIL -5~.3!3 GR.2IL RHGS.FDC -999.250 DRHC.F~C C~LI.FDC -999.250 gR.FDC 10-0CT-t9~9 15:]55 -999.250 ,CFTC.CNL -999.250 -999. 250 GR.C SG -999. Z 50 3.lTl ILM.OIL 3. t61 121.688 TENS.OIL 3924.000 -~99.250 FFOC.FDC -999.250 -)9~.250 TENS.F~C -999.2'50 -~99.250 NPOR.~CNL -999.250 -999.250 CFTC.CNL -999.250 --999. Z 50 GR. C SG -999.250 4. 030 ILM. ~IL 1!9.000 TENS.O:ZL -999. 250 FFDC.FDC -999. 250 TENS. FDC -999.250 NPOR.CNL -~99. 250 CF'TC. CNL -999. 250 GR. CSG 4.080 3830.000 -999..2~0 -99 g. 250 -'999.250 -999. 250 '-999.250 4..~68 ILM.DIL 4.~BO 128.250 TENS.OIL 3880.000 -999.250 mFOC.FOC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -99'9.250 CFTC.CNL -999.250 -999.250 GR.CSG -999.250 3.467 ILM.OIL !32.375 TENS.DZL -999. 250 FFDC.FgC -999. 250 'TENS. FDC -999.250 NPOR.CNL -999.Z50 CFTC.CNL -999. 250 SR.CSG 3.465 ILM.DIL 99.43B TENS.OIL -999.250 FFDC.F~C -999.250 TENS.FDC -999. 250 NPOR.CNL -999.250 C~TC.CNL -999.259 GR.CSG 3.488 3524.000 -999.250 -999.250 - 999.250 · -9go. 250 -ggg.250 3.496 3874.000 -999.250 -99'9. 250 -999.250 -999.250 -:999.Z50 2. 926 ILM.DIL 2. 952 120.625 TENS.OIL 3504.000 -999.250 ~FDC.FOC -999.250 -99~.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.Z50 CFTCoCNL -999.250 - 999. 250 GR. C SG -999. 250 ~,.~ 995 iLM.~IL 98.938 TENS.DIL -999.250 ~mFDC.FDC -999.250 TENS.FOC 4.135 3514.~00 -999.250 - 999.250 GR.CNL TENS.CSG S F L U. :~ ~' ~ DPHI. FDC NFDC.FDC NPHi .CNL R C N T. C N L GR. CNL T~NS.CSG S F L U. D I :L DPHI. mDC NFDC.FOC N PH !. CNL RCNT.CNL GR. CNL TENS.CSG SFLU.DIL DPH!.FDC NFDC.FDC NPHI ,.CNL R:CNT.CNL G ~ · C N L TENS.CSG SFLU.DIL DmHI.~DC NFDC. mDC NPHi .CNL RCNT..CNL GR.CNL TENS.CS~ SFLU.OIL DPHI.FDC N=DC.mDC NPHI.CNL RCNT.CNL GRoCNL TENS.CSG SFLU.DIL DPHI.FDC NFCC.FDC NmHI.CNL RCNT.CNL GR.CNL TENS.CSG SmLU.OIL DPHI.FDC NcDC.~OC NPHI.CNL PAGE: -999.250 -999.250 2.639 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.541 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 3.906 -999.250 -999.250 -9'99.250 -999.250 '-999.250 -999.250 3.002 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.958 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.595 -g99.250 -999.250 -999.250 -999.250 -999.250 -999.25C 3.914 -999.250 -999.250 -999.250 LIS TAPE VERI:I~C.~TION LZ,STIN2 SCHLUM~ERG!ER ALASK~ COMPUTING CENT~, 10-0CT'-t9~9 15:58 D !E P'T. '? 6 O 0.0 O 0 I L ~. ~ I L SP. OIL -59. 844 GR.OIL RHO~.F~C --999.250 gRH~.FgC CALI. ~DC -'999.2 50 GR.FgC TN~H.CNL -999. 250 TN~I. CNL ~CFT.CNL -999.250 CN'TC.CNL CALI.CNL -999.250 TENS.CNL D!EPT. TS00.0 O0 I~Lg.g IL SP. DI L -64.313 GGR. OIL RHO~.FOC -999.250 DRHO.FDC CALI !=DC -999 250 ~ ..... ,~. FDC TNPH.CNL -999.250 TNR.~.CNL RCFT.CNL --999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 74 00. 000 ILO. SP.OIL -63.594 ~R.DIL RHOB. FDC -999.250 DRHO.FOC CALI.FDC .-9'99.2 50 GR. FgC TNPH.CNL -999.250 TNR~.CNL RCFT. CNL -999. 250 ,~NTC. CNL CALZ.CNL -999.250 TENS.CNL 4. ¢96 ILM. OIL 4.68) 90.81,3 TENS.DIL 3570.000 -999.250 ~FDC.FDC -999.250 -~99.7_50 TENS.mDC -999.250 -999. 250 NPgR.CNL -999.250 - 999. Z 50 C F'T C. ~C N L - 999.250 -999.2 ~0 G~.C SG -999. 250 3.095 ILM.DZL 3.137 34.438 TENS.OIL 3580.000 -999.250 FFDC. F~C -999.250 -,999.250 'TENS.FgC -'999.250 -~:99o250 N.POR.CNL -999.250 - 999. Z 50 C F T C . C N L - 9 '99 . Z 50 -999. ~50 GR.C SG -999. 250 3.922 ILM. DIL 3.838 87.125 'TENS.OIL -999.250 FFDC.FDC -999.250 -~)99.Z50 TENS.FDC -999.250 -~99.250 NPOR.CNL -999.250 - 999.2. 5 O C F'T C. C N t - 99 '~ . 25 O -999. 250 G~.CSG -999.250 D:EPT. 7300.000 ILD.DIL ¢.335 ILM.DIL 4.382 SP.DIL -62.063 GR.CIL 109.875 'TENS,OiL 317~.000 RHOB.FDC -999.250 gRHO.FOC -999.250 ~FOC.FDC -999.250 CALZ.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 DEPT. 7200.000 ILD.~iL 4.298 ILM.DIL SP.DIL -69.625 GR.DIL 12~.625 TENS.OIL RHOB.FDC -999.250 gRHO.FDC -999.250 FFDC.FDC CALI.FDC -999.250 GR.FOC -999.250 ~ENS.FDC TNPH.CNL -99o~.250 TNRA.CNL -~'~99. 250 NPOR.CNL RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL CALI.CNL -99'9.250 TENS.CNL -999.250 GP,.CSG DEPT. 7100.000 ILO.OIL SP.DiL -65.625 GR.DZL RHOB.FDC -999.250 DRHC.FDC C,&LI. ~DC -9 99.250 GR · F ]C TNPH. CNL -999.250 TNR ~. CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 4.277 3194..000 -999.250 -999.250 -999.250 -999.250 -)99.250 4.285 ILM.C-IL 4.175 122. 500 TENS.OIL 338~.000 -'~99. 250 ~FDC.FDC -999.~50 -999. 250 TENS.FDC -999.250 -999.250 NPDR.CNL -999.250 -:}qg. 250 CFTC.CNL -999.250 - ~99. 250 G~. CSG -999. ZSO RCNT.CNL GR.CNL TENS.CSG SFLU.gIL OPHI.FDC N~DC.FDC N~HI.CNL RCNT.CNL GR.CNL T:~ :CSG SFLU.OIL DPH:I.FgC NFgC.FDC NPHI.CNL RCNT.CNL gR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.=DC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CS$ SFLU.DiL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TSNS.CSG SFLU.gZL DPHI.~DC NFCC.FDC NPHI.CNL RCNT.CNL Gq. CNL TENS.CSG --999.Z50 -999.250 -999.Z50 5.271, '-999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 2.809 -999.250 -999. 250 -999.250 -999.250 -999. 250 -999.Z50 4.162 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.371 -'999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 3.813 -999.250 -999.250 -999.250 -999.250 -999.250 3.671 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .iS TAPE VERIFICATION LISTINS ~CHLUMBERGER ~L~'SK& COMPUTING CENTER DEPT. 7000.000 ILC.DIL SP.OIL -58. 594 GR. OIL RHOBoFDC -999. 250 DRHO.FOC CALl. ~mOC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 6900.0 O0 ILO. OIL S).DIL -58.375 GR. EIL RH~.FDC -999.250 ORHO.FDC C,~LI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RrFT,. . CNL .-9~9 . 250 :CN'TC. C NL C~LI.CNL -999.250 TENS.CNL DEPT. 6800. 000 ILO. CIL SP. OIL -'74.313 ~GR. OIL RHO~.FDC -999.25C DRHO.FDC CALI.PDC '-'999 250 "' . - '~R FDC T NPH.'CNL -999.250 TN R ~. CNL RC~T.CNL -999.250 CNTC.CNL C~LZ.CNL '-999.2 CO 'T ~E NS .CNL DEPT. 6700. 000 ILD.O ZL SP. OIL -54. 875 GR.C IL RHOB.FDC -999°250 ORHO.FOC C~LZ. FDC -999.2 50 GR. FDC TNPHoCNL -~99.2!30 TNR&.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 T~NS.CNL DEFT. 6600. O O0 ILO. OiL SP. DIL - 56.3 ~4 GR.DIL RHOBo~DC --99~.250 OF, HC..FDC C ~LZ. FOC -999.250 GR. FOC TNPH.CNL -999.250 TN~R~.CNL RCFT.CNL '-999.25C CNTC.CNL C~,LZ.CNL -999.250 TENS.CNL DEPTo 6500.000 ILD.DiL SP.DIL -70.188 GR.DIL RHOE.FDC -999.250 CRHG.FOC C ~LI. ~DC -999.250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT. CNL -999.250 CNTC. CNL C~LI.CNL -999.250 TENS.CNL DEPT. 5400.00g i LC. & IL S P. OIL - 64.688 $~. g IL RHOB. F~C -999.250 ~RHC. FOC CALZ. DOC -999.250 GR. FDC TNPH. CNL -9 ~9.2 50 TN R~ .CNL RCFT. CNL -999.250 CNTC.CNL C~Li. CNL -999.250 T~NS. CNL 10-0CT-1989 15:5~ :3.I76 IiLM.DIL 138.875 TENS.OIL -999.250 FFOC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999,.259 CFTC.CN~L 999.250 ~ ,.CSG 4.'73~ ILM. DI~L 112. 188 TENS.OIL -999. 250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL - 999. 250 CFTC.CNL -999. 250 I3R.CSG 5.63:2 ILM.OIL 1.)7.125 T~NS.DIL -999.250 mFDC.FDC -9'9'9.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR..CSG 1.936 iLM.DIL 111.563 TENS..DI~L -999.250 FFOC.FDC -999.250 TENS.FDC -999.250 NFO~.CNL -999.250 CFTC.CNL -999.250 GR.CSG 2.303 tLM.DZL 122.375 TENS.OIL -999.250 FFOC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.~50 GR.CSG 5.502 ILM.DIL 172.125 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -'999.250 CFTC.CNL -999.250 GR.CSG 3.~77 ILM.DZL 75.913 TENS.OIL -999.250 ~=~DC. FDC -999. 253 TENS.FDC -999. 250 NPOR.CNL -999. 250 C~:TC.CNL - ~g ~. 250 GR.C SG 3.16) 3330..000 · .-999. 250 -999.250 - 999. 250 · -99 9.,250 -999.2'50 ~. 651 314 0.000 -999.250 -~999.250 -999.250 -99 9. 250 -999..~0 3064.000 -999. 250 -'999. 250 - 999.25 O -999.250 · -999. 250 1.830 3310. OOO -999.250 -999.250 -999.250 -999. 250 -999. Z 50 2.259 3094.000 -')9 9. 250 - 99 9.250 -'~99.250 -999.250 -999.250 5.827 3524.000 -999.250 -999.250 -999.250 -99'9.250 -999.250 3.437 3294.000 -999.250 .-~99.250 -999.250 -999.250 -999.250 SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL T~NS.CSG SFLU. D'IL DPHi. FOC NFDC.FDC NPHI.CNL RCNT.CNL G R. C N L TENS.CSG SFLU.DIL DPHi. FDC NFOC:.mDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.D!L DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FOC NPHi. CNL RC~T.CNL GR.CNL TENSoCSG SFLU.DIL DOHZ.FDC NFUC.FDC NmHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 10 2.49~ -999..250 -999.250 -999.250 -999.2 '50 -999.250 --999.250 4. 053 -999.250 -999.250 -999. 230 -999.250 -999.250 -999. 250 4.323 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.644 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1. ?06 -'999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 6.104 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.202 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS T/~PE V~RIFIC~TiON ~.'ISTIN~ ;CH:LUMBERGER ~:LA~SK,~ COMPUTING ~NT=~ DEPT. 6300. 000 ltD. gill SP. OIL -66.'~ TS GR. OIL RHOB. ~=DC -999.250 :gRHO. FDC CALl. FDC -999.2 50 GR. FOC TNPH.CNL -999.250 TN~A..CNL RC.FT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 62 DO. 0 O0 ILD.GIL SP. Di~L -6T. 625 GR. D IL RHO~.FDC -~99.Z50 ~RHO.FDC CALi. FDC -999.250 GR. FOC TNPH.CNL '-9~9.250 TN~A.CNL RCFT. CNL -999.2 50 CNTC. CNL CALI.CNL -999. 250 TENS.CNL DEPT. 61 00.000 ILO. OIL SP.OIL -'?0. 875 GR.OIL RH~5,.FDC -999.250 ORHg. FOC C&LI.~:OC -~99.250 GR. FOC TNPH.CNL -999.250 TNR.~. CNL RCFT.CNL -999.259 CNTC.CNL CALI.CNL -999.250 T~ENS.. CNL DEPT. 5000. 000 ILO. SP.O!L '-54.625 GR.DIL RHO~.':CC -999.250 D~HO.FOC CALI. ~:~C -9 99..2 50 GR.~OC TNPH.CNL -999. 250 TNRA.CNL RCFToCNL -999.250 CNTC.CNL C&LI.CNL -999.250 TENS.CNL C ~=pT. 59 O0.0 O0 iLD. OIL SP. OIL -57.6~_ 5 GR. OIL RHO~.FOC -999.250 ORHC.FDC C,&LI. FDC -~ 99.. 250 GR. FOC TNPH.CNL -9 99.2 50 TN.~.CNL RCFT.CNL -9~9.250 CNTC.CNL C~LI.CNL -9~9.250 TENS.CNL DEPT. 5800.000 ILO.OIL SP. OiL - 53. 844 GR.D'IL RHO~. FD C --999.2 50 OR HO. FGC C~L I. FDC -999.250 GR. mDC TNPH.CNL -~99.2~0 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C ~LI. CNL -9 ~g. 2 50 TE NS. C NL DEPT. 5700. OOO ILO. D IL SPo OIL -,53.719 ~S~. C IL RHO~.:DC -999.2 50 ~HO.FgC C ALZ. FOC -9 99.2 50 GR. F DC TNPH.CNL -~99.2 50 TNR~.CNL RCFT. CNL -999.250 CNTC. CNL I0-0CT-1989 15:58 3.126 ILM.DIL 3.1'03 115.~3~ TENS.OIL 3184.000 -999.250 FFOC.FOC -999.250 -999. 250 TENS. F DC -99 9. 250 -999.250 NPOR.CNL -999.250 -~99.250 CFTC.CNt -~99.250 -999. 250 GR.CSG -999. 250 3. 743 ILM.OIL 3.692 I09.563 TENS.OIL 3140.000 -999. 250 FFOC.FOC -999.250 -999.250 TENS.FOC -999.250 '- 999. :Z 5 O N P O R. ~C NL - 99 9.250 -999.250 CFTC.CNL -999.250 GR.CSG -99 ~.'717 ILM.DIL 3-662 12,2. 250 TEN~S.DIL 313~.000 -999.250 FFDC.FgC -9'99.250 -999.250 TENS.FgC -999.250 -999.250 NPDR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. 250 ~R.CSG '-999.250 3.121 ILM.DIL 3.012 B8.588 TENS.OIL 291~.000 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFT~C..CNL -999.250 - 999° 250 gR.C SG -99 9. 250 3. 327 ILM.gIL 109.125 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.2'.50 CFTC.CNL -99}. ZSO ~R.CSG 3.243 2~64.000 -999.250 -999.Z50 -999.250 -999.250 -999.250 3.529 ILM.OIL 3.436 87.438 TENS.OIL 2914.000 -999.250 .PFDC. ~DC -999.259 -999.250 TENS.FDC -999.Z50 -999.259 ,NP~R.CNL -'~99.250 -999.250 CFTC.CNL -999.Z50 - 99~. 250 -GR.C SG -999. 250 .3.5~g ILM.DIL 102.500 TENS.OIL -999.250 FFDC.FDC -999.25~ TENS.F~C -999.250 NPOR.CNL -ggg. ZSO CF'TC.CNL 3.449 2904.000 --999.250 --999.250 -999.250 -- 99 9 o 250 SFLU.OtL DPHI.mDC N~gC.FOC NPHZ.CNL RCNT.CN~ GR.CNL TfNS.CSG S FLU. OIL OPM I. DOC NFOC.FOC NPHI .CNL RCNT.CNL G~.CNL TENS.CSG SFLU.OIL DPHi.~DC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFCC.FDC NPHI.CNL RCNToCNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NmHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DmHi.~DC NFDC.FDC N~MI.CNL RCNT.CNL GR.CNL TENS.CSG SPLU.DIL OOHI.FDC NFDC.FDC NmHZ.~NL= ~ 2CNT.CNL GR.CNL ~AGE: 11 2.704 -999.250 -999.250 -999.250 -9~9. 250 -9 g g . 250 -999.250 3.203 -999.250 -999.250 -999.250 -999.250 -'999.250 -999.250 3.235 -999.250 ,-999.250 -999.250 -999.250 -999.Z50 -999.250 2.529 .-999.2~0 -999.250 -999.250 -999.250 -999.Z50 -999.250 2.735 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 2.945 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 2.904 -999.250 -9'99.250 - 999.250 -999.250 -999.250 .IS TAPE YERIFICATION LISTING ~CHLUMBERGER ALASK~ COMPUTING CENTiER I0-0C?-1989 15:58 CALI.CNL --999.Z50 TFNS.CNL -999.250 D~EPT. 5600.0 O0 ILO. OIL SP.DIL -62. 469 GR.DIL R H g ~. ~ g C - '999. ~ S 0 g R H O. F D C CALI. =DC -999. 250 GR. FgC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2!50 CNTC.CNL C,~,Li. CNL -999.250 TENS.CML DEPT. 5500. 000 ILO. OIL SP.DIL -63.4 38 GR. OIL RHOS. FD.C -999.250 ORHO.FDC C ALI. FDC -9'99.2 50 GR. FDC TNPH.CNL -999. 250 TNRA..CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CN'L D~EPT. 5300.000- ILO.OIL SP. DIL .-98.9 38 GR.D IL RHgB.FDC -999.250 gRHg. FDC CALI. FDC -999.2 50 GR...=DC TNPH.CNL -999.2 50 TNR.~. CNL RC'FT. CN~ '-999.2 50 CNTC.CNL C-~LI.CNL -999.250 'TENS.CNL CEPT. 5200. go0 ILO. C IL SP. OIL -154.0 O0 GR. OIL RH~.F~C -999.250 gRHO.~DC C AL!. FDC -999.2 50 GR. FgC TNPH.CNL -9~9.250 TNRA.CNL RCFT.CNL -999. 250 CNTC.CNL CALI.CNL -999.:250 T~NS.CNL CEPT. 5100.000 ILD.DIL SP.OIL -6.2.2 50 GR.DiL RH08. FgC -999.250 DRH~. FDC C ALI . FDC -999 . 2 ~ O GR. FDC TNPH. CNL -9 99.2 50 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.2150 TENS.CNL 3.557 ILM.DIL 83.813 T~NS.DIL -999. 250 FFDC.FDC -~99.250 TENS.FiDC -999. Z50 NPDR.CNL -~999. 250 CFTC.CNL -999. 250 GR.CSG ~.3T2 ItM.DIL 92.813 TENS.OIL - 999. 250 FFDC. FOC -99:9.250 TENS.FDC -999. 250 NPOR.CNL -999.250 CFTC.CNL -999. 250 :GR-C SG 4. 393 ILM.DIL 143.525 TENS.OIL -999.250 FFOC..FDC -999.250 TENS.FDC - 999. 250 NP g~. CNL -999.250 CFTC.CNL -999.250 GR.CSG ~.411 ILM.O!L !08. 375 TE NS.D IL -999. 250 FFDC.FD~C -'~99.250 TENS.FDC -999.250 NPOR.CNL -999. 250 CFTC.CNL -999.250 GR.CSG 4.273 ILM.DIL :93.68B TENS.OIL -999.250 FFDC.FDC -999.250 TENS.~DC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999. 250 3.4O2 283,4.0O0 -999.250 - 999.250 -999.250 -999. 250 -999.250 3.273 272~.000 -99 9.:;!50 -999.250 -999.250 -999.250 -999.250 4.326 275~+.000 -'999.25 O -'999.250 -999. 250 -999.250 -999.250 3.300 283 O. 000 -999.250 -999.250 -999.250 -999.250 -999.250 4.333 2544.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.881 ILM.DIL 4.523 106. 250 TENS.DIL 2604.000 -999.250 FFOC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NP~R.CNL -999.250 -999.250 CFTC.CNL -999. Z50 --}99. 250 GR. CSG -999. 250 4.125 ILM.OIL 90.063 TENS.DiL -999.250 FFgC.FDC -999.250 TENS.FgC -999.250 NPOR.CNL 3.928 2384.000 -~99.250 -999.250 -999.250 T:NS.CSG S F L U. O I L D~Hi. FOC NFDC.FDC NPHI.CNL RCNT. CNL GR.CNL TENS.CSG SFLU. OIL DPHI.~DC NFDC. FDC NPHI.CNL RCNT .CNL GR.CNL TENS.CSG SFLU.OIL O,~HI. FDC NFDC. FCC NPHI.CNL RCNT.CNL G~ .CNL TENS.CSG SmLU.OIL DPHI.~DC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENSoCSG SFLU.OIL DPHI.FDC NFOC . O~ NPHZ.CNL RC~T.CNL GR.CNL TENS.CSG S~LU.DIL GPHI.FDC NFOC.FDC N~HI.CNL RCNT.CNL GR.CNL TENS.CSG SmLU.DIL DPHI. n~ NFDC.~DC N~HI.CNL RCNT.CNL PA~:: 12 -999.250 2.864 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2. ?96 -999. 250 -999.250 -999.250 -999. 250 -999. 250 -999.250 3.740 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 2.871 -999.250 -999.250 -999.250 -999.250 .-999.250 -999.250 3.483 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.543 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.448 - 999 · Z '50 -999.25C -999.250 -999.250 .IS TAPE :V~RIFICATIgN LISTING ;CHLUMBERGSR .~L~SK.~ COMPUT":.N~'~' CENTER':. RCFT.CNL -999.2 50 CNTC. C NL C .A L I. C N L - 9 99 ,. 2:50 T :E N S. C N L DEPT. 4900. OOO ILg. DIL SP.OIL -59.0 O0 GR. OIL RHCS.FDC -999,250 gRHO.F3C CALI,FDC -9 '99,2 50 GR, FDC TNPH,CNL -999,2~0 TNRA,CNL RCFT,CNL -999,250 CNTC,CNL CALI,CNL -999,250 TENS,CNL DEPT. 4800.0 O0 ILD.OIL SP. OIL -'?0. 000 GR. OIL RHOB.~gC -999.250 DRHg. FDC C~LI. FDC -9 99.250 GR.FDC TNPH.CNL -999o 250 'TN RA.CNL RCFT.CNL -~99.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 4700.0 O0 ILO. SP. OIL -73.37:5 GR. D!L RHOB.~FDC -999.250 DRHCi. FDC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999..250 TNR~.CNL RCFT.CNL --999.250 CNTC.CNL CALI,CNL -999,250 TENS,CNL DEPT. 4600. 000 ILC,.CIL SP.OIL -75.000 GR.OIL RHDB.FDC -999,250 D~HO.FDC C~LI.FDC -999. 250 GR. FOC TNFH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -'9:99.250 TENS.CNL DEPT. 45 00.0 O0 ILD.DIL SP.DIL -79.500 GR.DIL RHOB.FDC -999.250 DRHO.FDC C &L'Z. FDC -999. 250 SR. FOC TNPH.CNL -999.250 TNR~.CNL RCFT,CNL -9'99,250 CNTC.CNL CALI.CNL -999,250 TENS,CNL D-=PT. 4400.0 gO ILD. OIL SP. OIL - 80. ~ 75 GR.DIL RHO~. ~DC -999.2 50 DRHg. C ~LI. FDC -999.250 GR. FOC TNPM.CNL -9~9.2 50 TNR~.CNL RCFT. CNL -9 99.2 ~O CNTC.C NL C.&Li. CNL -9 99.250 T'ENS.CNL 10-gCT-1989 15:58 - '999.250 C ~ T C . C N L - g 99. Z 5 O G R. C .S G 4-055 iLM.DIL 100.313 TENS.OIL '- 999. 250 FFDC.POC -999.250 TiENS. FgC -999.. 250 NPOR.CNL -999. 250 CFTC. CN~L -999.2:50 GR.CSG 3. 417 ILM. 9'IL 99. gO0 'TENS.OIL -999.250 F:FDC.FDC -999,250 TENS.FOC -999. ,~50 NPOR.CNL -'39:9.250 CFTC.CNL -999.250 GR.C SG 3.944 ILM.OZL 90. 563 TENS.DIL -~99. 250 FFOC. FDC -999~.£50 TENS.FDC -'99'9,250 NPOR,CNL -999.250 CFTC,CNL - 999.250 GR,C SG 3. 752 ILM. 92.500 TENS.DIL -999.250 FFDC.FOC -999°250 TENS.FDC -99~.Z50 NPOR.CNL -999,250 CFTC,CNL - 39'9. 250 ~R,C SG 6.447 ILM.DIL 95.8!3 TENS.DIL -999.250 .~FDC. FDC -999.250 TENS,FgC -999,250 NPOR,CNL -999o250 CFTC.CNL -999.250 GR.CSG 4.451 ILM.DZL 102.313 TENS.DIL -999.250 mFDC.FDC -~99.250 TENS.FDC -999,250 NPOR.CNL -999.!50 C.~TC.CNL -999,250 GR.CSG ~.414 ILM,DIL 84,~13 T~NS.DIL -999,250 :~gC.FDC -999,250 TENS,FOC -999.250 -999.250 3.819 2340.000 -999.250 -99 9. 250 -999. 250 - 9 ~99. Z 50 -999.250 3.207 2454.000 - g 99. Z 50 -99'9.250 -999.250 -999.250 -999.250 3.744 2364.000 -999.250 -999. 250 -999.250 -999.250 -999.250 3.35'7 2334.000 -999. 250 -999.250 -999.250 '-999.250 -99 9. 250 5.993 2340.000 -999.250 -999.250 -999.250 -999.250 -999.250 4.176 2290.000 -999.250 -999.250 -999. 250 -999.250 -999.250 4.285 2314.000 -999.250 -999.250 GR.CNL TENS.CSG SFLU.O!L OPHI.FDC NFDC.FDC N~HI.CNL R:CNT.CNL GR.CNL TENS.CSG SFLU,glL DPHI, FOC NFDC.FDC N~'H I .CNL RCNT. CNL GR.CNL TENS,CSG S F L U. D I L DPHI. FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC N~HI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU,OIL DPHI,FDC NF~C,FOC NPHI,CNL RCNT,CNL GR,CNL TENS,CSG SFLU.DIL DPHI.FDC N~DC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL OPHI.mDC N=DC.~DC NPHI.CNL pAGE: 13 -999.250 -999.250 3.162 ;-999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 2.565 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.988 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 2.406. -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5.300 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.835 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.031 -999.250 -999.250 -999.250 'TAPE VERIFICATIC!N L!ST'iN~ SCHLUMbERGeR ~LASK.&, COMPUTING CENT~ 10-gCT-1939 15:58 TNPH.CNL -99'9.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCNT.CNL RCFT. CNL -999.250 CN'TC. CNL - ~99.,, 250 CFTC. CNL - 999.250 GR.CNL CALI.CNL -999.250 T~NS.CNL -999.250 gRoCSG -999.250 TSNS.CSG DEPT. ~200.000 ILD.D~L 6.3.67 ILM.DIL 6.083 SP.OIL -86.813 GR.DIL 106.3,13 TENS.OIL 2110.000 RHO~.mDC -999.250 ORHO. FDC -999.250 FFDC.FOC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.2~50 TN~A.CNL -999.250 NPOR.CNL -999.250 RCF'T.CNL -999.250 CNTC.~CNL -999.250 CFTC.CNL -999.250 CAL].CNL -99'g. 250 TENS.CNL -999.250 G'R.CSG -999.250 DEPT. 4100.000 ILD.DZL 5.395 ILM.glL 5.102 SP. OIL ,-85. ?SO GR. OIL I0-4. 500 TENS.D'~L Z'l 50. 000 RHOB.~DC -'999.250 DRHg. FDC -999. ~50 FFDC.FOC -999.250 CALI.FDC -999.250 GR. F.DC -~999. 250 'TENS. FDC -999.250 TNPH.CNL '-999.250 'TNRA.CNL -9'99.250 NPOR.CNL -999.250 RCFT.CNL -999. 250 :CNTC.CNL -999. 250 CF'TC. CNL -999.250 CALI.C.NL -999.250 TENS.CNL -99'g.250 GR.CSG -999.250 DEPT. ~¢000.000 ILO.OIL 4.572 ILM.gIL 4.396 SP.OIL -87.638 G~.DIL 9,2.313 TENS.OIL 2045.000 RHO~.FDC -999.250 ORSG.FOC .-999.250 :FOC.FOC .-999.,250 C~LI..~DC -999.250 GR.FOC -999.250 TENS.FOC -999.250 TNPH.CNL .-999.250 TNR~.CNL -999.250 NPORoCNL -999.250 RCFT.CNL -999.250 CNTC.CNL -99:9.250 CFTC..CNL -999.250 CA:Li. CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 DEPT. 3900.000 ILO.gilL ~SP.DIL -.83.875 GR.DIL RHO~.~DC -999.250 gRHO.FOC CALIo~OC -999.250 GR.FDC TNPH.CNL -999.250 TNR~oCNL ~CF'T.CNL -999.250 CNTC.CNL Ci&LI.CNL -999.250 TENS.CNL 4.83? ILM.DIL 95.563 TENS.OIL -999.250 ~FDC. FD,C -99~.250 TENS.FgC -999.250 NPgR.CNL -999.250 CFTC.CNL -999.250 ~R.CSG DEPT. 3800.000 ILO.OIL -999.250 ILM.DZL SP.DIL -999.250 GR.DiL -999.250 TENSoDIL RHg~.FDC -999.250 gRHC.FDC -999.!50 FFDC.FgC CALI.FDC -999.250 SR.FDC -Ogg. ZSO T~NS.FDC TNPH.CNL -999.250 TNRA.CNL -999.250 NPgR.CNL RCFT.,~NL -~gg. ZSO CNTC. CNL - 999. ~50. CFTC. . CNL C~LI.CNL -999.250 TENS.CNL -gg9.25D GR.CSG 4.777 1990.000 -999.250 -999. 250 - 99 9. 250 ST. 625 -99'9.250 -999.250 -999. 250 -999.250 -999.250 -999.250 56.969 DEPT. 3TO0.O00 ILO.OIL -999.250 ILM.OIL -999.250 SP.DIL -9g9.250 GR.DiL -999.250 TENS.OIL -999.250 RHGB.,=DC -999.250 DRHG.FDC -999.250 FFOC.FgC -999.250 C~LI.=DC -$99.250 GR.FDC -)99.250 TENS.FDC -999.250 TNPH.CNL -9~9.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 C ~L Z. CNL -999. Z 50 T~. NS . CNL - 999.25 O G~.C S-G 4 3.5 O0 SFLU.OIL DPH Z . FDC NFDC. FDC NPMi.CNL RCNT.CNL G~. CNL TENSoCSG SFLU.OIL OPHI.FgC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL T~S.CSG SF!LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL T~NSoCSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DZL DPHI.~DC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHi. FDC NFgC.FDC NPHi.CNL RCRT.CNL GR.CNL TENS.CSg PAGE: 14 -999.250 -999.250 5.13~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.230 -999.250 -999o250 -999.250 -999.250 -999.250 --999.250 3.287 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.026 -999.250 -999.250 -999.250 -999.250 -999.250 2050.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1865.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1850.000 I.S T~PE YERIFZCATION LISTiNS ;CHLUMS, ERGER ~L~SKA COMPUTING CENT,ER DEP'T. 3600.0 O0 ILO.OIL S P. OIL -9 99.2 50 GR.DIL RHOB.~OC -999.250 ORHg. FDC CALl. ~DC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CN'TC.CNL C,ALI.CN/ -999.250 TENS.CNL DEPT. 3500. 000 ILO. OiL SP.DIL -999.2:.50 GR.DIL RHGB.FDC -999.250 DRMO.FOC CALl. ~DC -9'99. Z 50 GR. FDC TNPH.CNL -999.250 TNRA.:CNL RCFT.CNE -999.250 CNTC.CNL C~LI.CNL '-999.250 T~NS.CNL DEPT. 3400. SP. OIL -999.2 50 RHOB.FDC -999.25-0 DRHD.FDC CAL~. F~C -999. 250 GR.FDC TNPH.CNL -9'99.2~50 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999. 250 T~NS.CNL DEPT. 3300.0 O0 iLg. OIL SP. OIL -9 ')9.2 50 G~. git RHOB.FgC -999.2~0 gRHC.FgC C,~LI.FDC -999..,250 GR. FDC TNPH.CNL '-999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI..CNL -999.250 TENS.CNL DEPT. 3200.000 ILO.OIL SP. OIL -9 99.2 SO GR'. OIL RHOB.FDC -999.250 DP, HG.FOC C ALI. =DC -999.2 50 GR. FDC TNPH.CNL -999.250 'TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALZ.CNL -999.25~ TENS.CNL DEPT. 31OO.~.O00 ILO.DiL SP. OIL -999.250 GR. OIL RHOS. FDC -999.250 DRHO..~OC CALl . :=DC -999 . 2 50 GR. FOC TNPH. CNL -9 99.2 50 'TN RA. CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.2.50 TENS.CNL DEPT. BO00.O00 ILO.git S~.gIt -999.250 GP.DIL RHg~o FDC - 9 ~9.2 50 DR MC. FDC C &LI. FDC -999.2 50 GR · FDC TNPH.CNL -999.250 TNRA.CNL RCFT. CNL -9 ~9.2 50 C~TC. CNL CALI.CNL -9 99.2 50 TENS.C NL lO-CC'T-1989 15:5;9 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -99~.250 -999.250 FFDC.FDC -999.250 -99'9.250 'TENS.:FDC -999.250 -999.250 NPOR.CNL -'999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 6T.625 -999.250 ILM.DIL -999.250 -999. 250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.~50 -999.250 NPOR.CNL -999°250 -999.250 CFTC.CNL -999.250 -999. 250 GR.C SG 5 2. 594 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -!999.250 FFDC.FOC -999.250 -999.250 TENS.FDC -999.250 '-999.250 NPDR.CNL -999.250 -999.'~50 CFTC.CNL -999.250 --999.250 GR. C SG 55. 031 -999.~50 ILM.Di~L -999.250 -999.~50 TENS.DZL -999.250 -999.150 FFDC. FDC -999.250 -999.250 TENS.FgC -999.250 -999.250 NPO~.CNL -999.250 -999.250 CF'TC.CNL -999.250 - 999. 250 GR. CSG 64. ! 25 -999. 250 ILM.OIL -999.250 -~99.250 TENS.OIL -999.250 -999.,~-50 ~FDC.FDC -999.250 -999.250 TENS.~DC -999.250 -999.250 NPOF.CNL -999.250 -999.250 CFTC.CNL -~99.250 -999.250 g~. C SG 5 8. 875 - 999. 250 ILM.DiL -999. 250 -999.250 TENS.OIL -999.250 -999.250 ~:FOC. FDC -999..Z50 -999.250 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.?.50 -999. 250 G~.CSG 61.969 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 ~-FOC. FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -~99.250 -999. 250 GR.CSG 44.43~ S~FLU.DIL OPM I. FDC NFDC. ~DC NPHI.CNL RCNT.CNL G~.CNL T E N S . C S g SF,LU.DIL DPHI.FDC NFDC.FDC NPHZ.CNL RCNT.CNL GR.CNL TENS.CSG SF!LU.O!L DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL T~S.CSG S ~ L U. O I t DPHI.FDC N~DC.~gC NP H I. C NL RCNT.CNL GR.CNL TEN S. CSG SFLU.DIL DPHI.FDC NFDC.FOC NPMI.CNL RCNT.CNL GR .CNL TENS.CSG S~LU.DIL DPHI.FDC NmDC.FDC NPHI.CNL RCNT.CNL GR.CNL T5NS.CSG S~LU.DIL D~HI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: 15 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 19TO.OOO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1820.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1830.000 -999.250 -999.250 -999.250 -999.250 -999.230 -'999.250 1830.000 -999.250 -999.250 -999.250 -999.250 -999.250 ,-999.250 1725.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1820.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1695.000 .[S T~E VERIF'Z:C:~TION L!STZNG ~CHLU~SE!RGER ~L~SK, A COMPUTZNG C'ENTER DEPT. 2900. 000 ILO. OIL SP, DIL -999. 250 GR, OIL RHDB,FDC -999.250 ORHO·FOC C.4LI, FD-C -999,2 50 GR, FDC 'TNPH,CNL -9'99,250 TNR~,CNL RCFT,CNL -999. 250 CN'TC·CNL CALI.CNL -999,250 TENS.CNL OEPT, 2500.000 ILD,DiL S P.OIL -999,2.50 GR,DiL RHO~,FDC -999,250 gRHC,FDC CALI,FDC -999,250 GR.. FDC TNPH,CNL -'999,Z 50 TNRA.CNL RCFT.CNL -999,250 CNTC.:CNL CALI, CNL -999,250 TENS, £NL DEPT, 2'700,00C ILD.D'IL SP,DI[ '-999,250 GR.DIL RHO~..FDC '-999.25~ DRHC.FDC CALI,FDC -999,2 50 GR, FOC TNPH.CNL -999.250 TNRfl. CN~L RCFT.CNL -999.2 50 CNTC.CNL C~LI,CNI -999,250 TENS,CNL DEPT. 2600.0 O0 ILD.DIL SP.DIL -g 99'. Z SO GR. DIL RHO~,FOC -999,2!50 gRHO,FDC CALI. FDC -9 99.2 SO GR.FOC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL C,~L'I.CNL .-~99.25~ TENS.CNL D EFT, 2500,0 gO ILD, DIL SP. OIL -999,250 GR, OIL RHOB.FDC -999.250 ORHO.FDC C~LI. FDC -999.2 50 GR. FDC T NPH. CNL -'999. Z 50 TN Rd,.CNL RCFT.CNL -999.250 CNTC.CNL C~LI,CNL -999.2.50 TENS.CNL DEPT, 2400.0 g g ILD, D IL SP,DIL -999,250 GR.EIL RHOB. FDC -999,2 50 DRHg. FOC CALI..mDC -999,250 SR, FDC TNPH.CNL -999° Z 50 TN R~· CNL RC~T .....CNL -~'~S,Z~O ~N'TC.CNL CALI,CNL -9 99. Z 50 TENS· CNL DEPT. 2300.000 IL~.DIL SP. OIL -9'99. Z 50 -SR. ~iL RHCS. :DC -S .99 · Z 50 DR MC. FDC C~Li ~Dr -99'9 25n GR.'~r TNPH.CNL -999.2 50 TNR~. CNL RCFT. CNL -999, Z 50 CNTC. CNL lO-OCT-19B9 15:58 -999,250 ILM, DIL -999,250 -999.~50 'TENS., DIL -999.,250 .-999.250 FFDC.FDC --999.250 -99'9.250 TENS.FOC -999.250 -999.~250 NPOR.CNL -999,250 '-999. 250 CFTC.CNL '-999.250 -999,250 GR, CSG 39,750 -999. !50 ILM.DIL -999,250 -999.250 TENS.OIL -99'9.250 · -999,250 ..:FDC. F DC -999,250 - '9'99.250 T ~ N S. F O C ,- 99 '9.250 - 999. 250 NPOR.CN:L -999. 250 -999.250 CFTC.CNL -99'9,250 -999,250 GR,CSG 43,000 -999:,250 ILM,DIL -999.250 -:999. 250 TEN:S.O iL .-999. 250 -999,250 FFDC,FDC -999,250 -999,250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 - 999. :250 GR. C SG ~ O, 5613 -'999,250 ILM.DIL -999,250 TENS,DIL -999.250 FFDC,FDC -99:9,250 TENS.FDC -999. Z 5:0 NPOR. CNL -g99. 250 CFTC. CNL -999,250 GR,CSG -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 42.969 -99'9,250 ILM,DIL -999,250 -999,250 TENS.OIL -999,250 -999,250 FFOC. F:DC -999,250 -~99,250 TENS,FDC -~99,250 -999. ZSO NPOR.CNL -999,250 -999,250 CFTC.CNL -999,250 -99'9. Z50 GR.CS~ 20.500 -999,250 ILM,DIL -999,250 -999. 250 TENS,DIL -999,250 -9'99,250 ~FOC.FOC -~99,Z50 -999,250 TENS,FOC -999,250 -999,250 NP2R,CNL -999,250 -999. !50 CFTC.CNL -999,250 -999.259 SR.CSG 60,250 -999,25'2 ILM.DIL -999,250 TENS.DIL -999.250 =FOC. ,cDC - 99'~. 25:0 TENS.F~C -999.250 NPORoCNL -)9'3..Z50 CFTC.CNL -999,250 - 999.250 -999,250 -999.250 -999,250 - 99 9.250 SFLU, OIL DPHI,~mOC N F:gC, FDC NPHI,CNL ~CNT,CNL GR,CNL TENS,CSG SFLU,O!L D PH I. ~D C NFgC.,FDC NPHI, CNL RCNT, CNL Gg,CNL TENS.CSG DPHI. FOC NFDC. FDC NmH'I. CNL RCNT.CNL G~.CNL T E N S. C S G SFLU,DIL DPHi..FDC NFOC.FDC NPHI,CNL RCN'T,CNL Gq,CNL TENS,CSG SFLU,OiL DPHI.FDC NFDC.FDC NPHI,CNL R CNIT. CNL GR,CNL T£NS,CSG SFLU,DZL DPHI,mOC NFDC,FDC NPHI ,CNL RCNT.CNL GR,CNL TENS,CSG S~LU,DIL OPHi. FDC NmDC.;DC NPHi,CNL RCNT,CNL GR,CNL PAGE: 16 -999.250 ,-999. Z50 · -999.250 -999 .ZSO -999.2:50 -999.250 I'770,000 -999,230 -999,250 -999,250 · -999,250 -999,230 - 99'9.250 1645,000 -999,250 -999,250 -999,250 · -99:9. 250 .-999,250 -999.250 :17:15.000 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 1675,0'00 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1455,000 -999.250 -999. Z 50 -999.250 -9~9.250 -999.250 -9.~9.250 1590.090 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VER.IFZCATION LISTING ~CHLUMBERG~ER ALASKA CgMPUTZNG CENTER CALi. CNL -999.250 T:ENS. C NL DEPT. 22 DO. 000 !LD. OIL SP. DIL -999.250 GR.DIL RHOB.FDC -999.2.50 DRHO.FOC CAiLI..~DC -9 99. 250 GR. FDC TNPH.CNE -999.25~ TNR~.CN[ RCF~T- CNL -999.2]50 CNTC:.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 2! gO. 0 O0 iLO. DZL SP. OIL -999.2 50 gR. RHOB.FOC -999.250 DRHg.. FgC C~LI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. ZOO0. OOO ZLD. OIL SP. DIL -9:99. Z 50 GR. D IL RHO~. F:DC -999.25g DRHO.FgC CALI. FDC -9'99.2 50 GR.FiDC TNPH.CNL -999. 250 TNRA.CNL RCF'T. CNL -999.250 CNTC.CNL CALi. CNL -999.250 TENS.CNL DEPT. 1900.000 ILD.gZL SP. DIL -999.250 GR.OIL RHOB o FDC -999.250 ORHO. FDC C~LI. F'~C -99'9.250 GR. FDC TNPH.CNL -~99.250 TNR~.CNL RCFT.CNL -9~9.2.50 CNTC.CNL C~LI.CNL -'999.250 TENS.CNL D~PT. 18 gO. OOO ILO. OiL SP. OIL -'999.250 GR. D iL RHOB.FDC -999.250 C~LI. FOC -9'99.2 50 TNPH.CNL -999°250 TNRA.CNL RCFT.CNL -999.250 CNTC..CNL CALI.CNL -999.250 TENS.CNL DEPT. 1700.000 iLD.DIL SP.OIL -999.250 GR.DIL RHOB.~gC -9~9.250 ORHO.FOC CALI. FDC -999.250 GR. FSC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2~0 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 1600.000 ILO.OIL S,~. OIL -999.250 8R.OIL R HOB. FDC -999.2 50 ~R H~. FOC CALI. FDC -999.2 ~0 'S~. FOC T NFH. CNL -999.250 TN RA. CNL 10-0CT-1989 15:58 -99'9.250 GR.CSG 36.000 -"999.250 ILN.DIL -99'9.250 -'999.250 'TENS.OIL '- 999.250 -999.Z50 ~FgC. :FOC -:,999. 250 -9~99.25.0 TENS.PDC -999.250 -9~9. 250 NPOR.CNL -999.~50 -999.250 CFTC.CN~L -999 ZSO -999. 250 GR.C SG 30. 766 '-999.250 !LM.OIL -999.250 -999.250 TENS.OIL -999.250 -999.259 :FFDC.FOC -999.250 -999.250 T:ENS. FDC -999.250 -9'99.25~ NPOR.:CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 49. 594 -999..Z50 ILM.DiL -999.250 - ,~ 9 '9:2150 T .., N S. g I L - 999.250 .-999.250 ~FOC.~OC -999.250 -999. 250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 - 999. 250 CiFT:C. CNL -999. 250 -999. 250 GR.CSG 55.09~ -999.250 ILM..DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 ~FDC.FDC '-999.250 -999.250 TENS.FDC -999.250 -999.250 NPDR.CNL .-999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 26.I4! -999. 250 ILM.DIL -999.25'0 -999.250 TENS.OIL -999.250 -999. 250 FF DC..FDC -999.250 -999._~50 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999. 250 GR.CSG 45.313 -999.259 ILM.DIL -~99.250 -999.250 TENS.OIL -999.250 -999.250 FFOC.FDC ,-999.250 -~99.250 TENS.FDC -999.250 -999. 259 NPOR.CNL -999.2.50 -999.250 CFTC.CNL -999.250 -999.250 GR. C SG 40. 563 -~99.250 ILM.~iL -999.250 -999.250 TENS.DIL -999.250 -999.250 -:F DC..t:: DC -999.250 -~99.259 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 TENS.CSG SFLU.DIL DPHI.MDC NFQC.FQC NPHi.CNL RCNT.CNL :,.CNL TENS.CSG SFLU.DIL DPHI.FDC N~OC.~OC NmHI .CNL RCNT.CNL GR. C. NL · ~r. :,. N S. C S G SFLU.OIL DPHI.FDC NFDC.FOC NPHI.CNL GR.CNL TENS.CSG SFLU. DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TEN'S.CSG SFLO.DIL OPHI.FDC NFDC.mDC NPHI.CNL RCNT.CNL GR.CNL TENS.~CSG S~LU.OiL O~HI.FOC NmOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG S ~ t U. g I L DPHI.FDC N,:OC.FDC NmHI.CNL RCNT.CNL P AGE: 17 t505.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2:50 1500.000 -999.250 -'999.250 -999.250 -999.250 -999.250 -999.250 1450.000 -999.250 ,-999.250 -999.250 '-999.250 -999.250 -9'99.250 1450.000 .-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1520.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 1395.000 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERZFiC~&TICN LISTING SCHLUMBERGER ALASKA CgMPUTING CENTER 10-3CT-i989 t5:58 RCFT.CNL -999.250 CNTC.CNL ,-:999 250 CFTC.CNL -999. 250 C A'L 't . C N L - 99 g . 2 5 g T E N S . C N L - !~ 99 . Z 50 G R. C S G 40 . 563 OEPT 1500 000 *," ' - ~.~. OIL -999.250 ILM.DIL -999.250 SP.OIL -999.250 GR.~IL -999.250 TENS.OIL -999.250 RH~8.~OC -999.250 ORH~.F~C -999. Z50 FFDC.FDC -99~.25.0 CALI.FDC -999.250 GR,.~FOC -999.250 TENS.FOC -99~g. Z50 TNPH.CNL -999.250 TNR~.CNL -999.250 NPOR.CNL -999.250 RCFT. CNL -999.2 50 CNTC. CNL -999. 250 CFTC. CNL -ggg.zEO CAL!.CNL -'999.2~0 'TENS.CN:L -999.250 G~.CSG 47.~4~ DEPT. I400.000 ItC.Oft -999.250 ILM.DIL -999=Z50' SP.~IL -999 250 ~R miL 9'99.250 TENS.OI[ -999.250 RHOB.~DC -99~. 250 DRHE.FDC -999.250 FFDC. FDC -999.250 CALI.FDC -999.250 GR.FQC -999.250 TENS.FDC -999.Z50 TNPH.CNL -999.2 5'0 TNRa.CNL - 999. 250 NPD~.CNL -99 9. 250 RCFT.CNE -999, 250 CNTC.CNL -~99:~. 250 CFTC.CN[ -999. 250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG 36.375 DEPT. !200. 000 ILO.OIL SP.DIL -'9~9.2 !50 gR. OIL RHO~B. ~DC -999.25C DRHO.~DC CALIoFDC -999..2 50 GR. FDC TNPH.CNL -999. 250 TNR~.CNL RCFToCNL -999.250 CNTC.CNL CALi. CNL -9~9.250 T~NS.CNL DEPT. 1! 00.0 gO ILO.OIL SP. OiL -9 99.2 50 GR. gIL RHO~."mDC -999.250 gRHg-.~gC CAL]. FCC -999.2 50 SR. FDC TNPH.CNL -999.250 'TNR~.CNL RCFT.CNL -9~9.2 50 CN'TC.CNL CALI.CNL -~99.250 TENS.CNL DEPT. 1000.0~0 ILD.gZL SP.DIL -999.250 G~.DIL RHCB. FDC -999.250 ORHC. FED C ~LI. FDC -999.2 50 G~. ~DC TNPH.-CNL -999.2 5~ TN R a. CNL RCFT.CNL -999.250 CNTC.CNL C.&LI. CNL -999.2 50 TENS.CNL DEPT. 977.5 O 0 ILO. ~]IL SP.DIL -999. 250 G~.OIL RHCB. FDC -999 . 2 5C gRH'J. FDC C~LI. :DC -999.2 50 GR.~gC -999.259 ILM.~IL -'999. 250 'TENS.OIL -999. 250 FFDC. FDC -999..250 TENS.FOC -999. 250 NP~R.:C NL -999.250 CFTC.CNL -999.250 .GR.CSG -999.250 ILM. DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS..FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.~50 ~R.CSG -999.250 -'99 9. 250 -999.250 - 999.25'0 -99 9. 250 -999.250 27.609 -999.250 -999.250 -99 9. 250 -999.250 -999.250 -999.250 33.813 -'999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.25~ -999.250 FFDC.~DC -999.250 -:999.250 TENS.FDC -999.2.50 -999.250 NPOR.CNL -999.250 -999 ~50 CFTC.CNL 999 250 -999.250 GR.CSG 30.64I -999.250 ILM.DIL -'999.250 -999.250 TENS.OIL -999.250 -999.250 =FDC.m~C -999.250 -999.250 TENS.FgC -99'9.250 -999.250 NPOR.CNL -999.250 - 999. 259 C~TC. CNL -999. 250 -999.250 GR.CSG 51.500 -999.250 ILM.D!L -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.m~C -999.250 gR.CNL TENS .CSG S~;LU.DIL DPHI.~OC NFDC.FDC NPH!.CNL RC~'T.CNL GR.CNL TENSoCSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCN'T.CNL G~.CNL TENS.CSG S;LU.DIL DPHI. FgC NFgC.FgC N P H i. C N C RCNT. CNL GR o CNL TENS.CSG SFLU.DIL DPHI. F ~ NFDC.FD~ NPHI.CNL ~CNT.CNL G~.CNL T E N S . C S G SFLU.DIL DPHI.FDC NFgC.FDC NPHI.CNL RCNT.CNL GR.CNL TENSoCSG SFLU.DIL DPH!.FDC NFDC.FDC N~HI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL D~H'T.FDC NFDC.FOC NmHI.CNL ~GE: '-999.250 1495.000 -999.250 -999.250 -999.250 -999.Z50 -999.250 -999.2 "50 1,395 .gOO -999.250 -999.,250 -9'99.250 -999.250 -999.250 -999.250 1305.000 -999.250 '-999.250 -999.250 -999.250 -999.250 '-999,.250 1340.000 -999.25:0 -999.250 -999.250 -999.250 -999.250 -999.250 1335.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1270.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 1130.00~ -999. 250 -999 .gso -999.250 -999.250 18 .IS TAPE YERIFICATIgN LISTING ~CHLUM~ERG~R ~LASKA CgMOUTING, . ~,,~ENT,~R~ 10-DCT-1989 15:58 19 TNPHoCNL -999.Z50 TN~A.CNL -!)99.Z50 NPORoCNL RCFT.CNL --999.250 CN'TC.CNL -999oZ50 :CFTC.CNL CALZ.CNL -999.250 TENS.CNL -~9~ 250 GR.~CSG -DOg. ZED RCNT.CNL -999.Z50 G~oCNL 2~.125 T~NS.CSG 11,$0.000 END FILE N~ME : iEDiT .001 SERVICE : FLiC VERSION : 001~02 DATE ' ~9/10/10 MAX R~EC SIZ~ : 1024 LAST ::iLE ': **~ FILE HEADER FILE NA~E : EDiT .002 SERVICE : ~LZC V~RSI.ON : O0tAg2 DATE : ~9/10/10 M,~X REC SiZE : 1024 FILE TYPE : LO L AS'T FILE : FILE - ~OIT.,O02 A~CO ~L~SK~, INC. KUP~RUK 2K - 13 50-I03-Z0116 DAT~ SAMPLED EVERY -.lOgO FEET DATA iNCLUDED - TOOL :×T=NSZON T YP E US-'g FOC . F]H CNT-A/O/H .CNH TCSL NAME FOrMAT.ION D:ENSITY COMPENS~,TED NEUTRON 9556' T3 8996' 9641' '"'g? A996'. .IS TAPE VERIFICATZON LISTING ;CHLUMBEiRGER ALASKA ~CO-~.PUTiNG CENT:ER IO-OCT-IgB9 15:58 PAS E: ZO 'TABLE T'YPE : CONS TUNI VALU CN ~2C0 ALASKa,, FN KUP.&RUK WN 2K- APIN 50-10.3-20116 FL 59' FNL & 94' $ E C T 1 1 TOWN ION RANG COUN NO~TH SLOPE S T A T A L NATI ENGI ~. W~NER WITN BEAL/:D! S 0 N 5 4 8 7.3 9 POAT NSL EPO ~T LMF APO FT 154. EK8 FT E O F F'T 1 :S 3. EGL FT TOO ~T 9700. I NC. FEL DEFI COMP&NY NAME FIEL~ N,&ME WELL N~ME API SERIAL NUMBER FIELD LOC~'TI ON SECTION TOWNSHIP RANGE COUNTY S'T~TE OR PROVINCE NATION :EN'~INEER' S NAM~ WITNESS~S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG ME~SUREO FROM TABLE TYPE : CURV D EF I OEP'T OE'OTH CHANNEL NAME CPHI OENSITY POROSITY RHOB SULK DENSITY DRHO OELT~ RHO i=FDC FAR FCC COUNT RATE N~DC NEAR FDC CgUNT ~ATE CALI CALI~ER GR S~MMA RAY TENS TENSION NPHZ NEUTRON mOROS~TY TNPH 'THERMAL NEUTRON oOqOSITY TNRA C~LI,BRATEO TWSRM&L NEUTRON R~TiC NPCR NEUTRgN mOROSITY CUTPUT :R~P ~N ,&PPLZCATICN RCNT R~W CS~RECT~D NEAR THeRMaL COUNTS RCFT RAW CORRECTED m~R THER~.L CCUNTS CN~C CORRECTE~ NEaR THErMaL COUNTS CFTC CORRECTED FAR TH.ER~L COUNTS .IS TAPE ViERZF.ICATigN LISTING ~CHLUMSEqGER ~.LASK& CgMPUTING C~NTER I0-00T-1989 15:58 Z 1 D E F i CALl CALIPER TENS TENSION ~ D~T~ FgRMAT SPECIF'Zr~'T~ON · ~ ,SET TYP~ - 6~EB TYPE REPR CODE VALUE 0 '1 66 ,2 66 3 73 4 66, ~ 66 6 '73 7 5.5 8 68 9 65 11 66 12 68 1'3 66 14 65 15 66 16 66 0.099 ~F T 12 0 68 ! ! NAM':~. SERV UNIT iD T 'TYPE - CHAN ** SERVICE APl AP1 ~Pi AP1 FILE ORDER ~ LgG TYPE CLASS MOD NUMB NUMB NUMB S.~Mm, EL:M= SIZE REPR CODE PROCESS .CHEX) DEPT FT OPHI ~DH PU RHOB FDH G/C3 DRHO FDH G/C3 FFDC =DH CPS NFDC FD:H CPS CALl FDH IN GR ~DH G~Pi TENS ~OH L8 N~Hi CNH PU TNPH CNH PU TNRA CNH NPgR CNH PU RCNT CNH CmS RCFT CNH CPS CNTC CNH CPS C~TC CNH CPS 548739 O0 000 OD 0 2 1 1 4 68 54:9739 07 890 Ol 0 2 1 1 4 68 548739 07 350 CZ 0 2 ! 1 4 68 548739 07 35,6 O1 O 2 1 1 4 68 543739 07 354 02 0 2 1 1 4 68 54:~739 07 354 O1 0 2 1 1 4 6,5 54B739 07 2~0 Ol 0 2 1 1 4 68 54~739 07 310 Ol 0 2 I ! 4 68 5487139 07 535 21 0 2 1 1 4 68 548739 07 890 OO 0 2 1 1 4 68 $48739 07 890 OO 0 2 1 1 4 68 548739 07 420 O1 C 2 1 1 4 68 548739 07 890 OO 0 2 I ! 4 6.8 54~739 07 420 Ol O 2 1 I 4 68 5~'87 39 07 420 O1 O 2 1 1 4 68 548739 07 420 Ol g 2 1 ! 4 68 5~87.39 07 420 O1 0 2 I 1 4 68 O00000OO00 0000003000 O000OO0000 O00000OOOO 0000000000 OOOO000000 O00000OO00 OOO0000000 0000000000 0000000000 0000000000 0000000000 0000000090 OOOO000000 0000000000 0000000000 0000000000 ......~S TAP~ VE~I~'ICA'TION !~I:ST'',~N,~ SCHLUMBERGER ALASKA COMPUTING CENTER 10-3CT-I989 15:58 PA~E: 2 2 NAHE .SERV UNIT ~ERVIC': ~ ~ API API APi API OROER ~ LOG TYP~ CLASS MOO FILE NUMB NUMB ;SIZE NUMB S:&MP !ELEM R E P R CODE PROC E SS (HEX) GR CNH GAPI 548739 OT 310 Ol 0 CALl CNH 'IN 154873:9 07 280 01 0 TENS CNH :tS 5487139 0'? 535 21 0 2 I 1 ,4 68 2 1 1 4 68 2 1 i ~+ 68 0000000000 0000000000 O00000OO00 DEPT. '"~ 04.5 . '~:~ . O0 DPHi FDH FFDC.FDH 506.500' N~DC.FDH TENS:. !:OH 14.20. OOO NPHI.CNH NPDR.CNH 40.282 RCNT. CNH CFTC, CNH 632. 146 GR.CNH DEPT. 9700. 000 DPH!. FOH FFDC.:DH 506.500 NFDC.FDH T ~E N S. F O H Z 640.00 O N P H I. :C N H N~O~..CNH 40.2~2 ~CNT.CNH CFTC. CNH 632. 146 GR.CNH DEPT. 9600.0~0 gPHI.FDH iFFCC.FDH 490.000 NFDC.FDH TENS.~DH ~512.000 NPHZ.CNH NPOR.CNH 38.~90 RCNT.CNH CFTC.CNH 599.915 G~.CNH DEPT. 9500.000 DPHI.FOH FFOC.FDH 496.250 NFDC.. FDH TEN,S.FDH 4500.000 NPHI.CNH NPOR.CNH 38.~97 ~.CNT.CNH C FTC. CNH 678. 670 -3R. CNH DEPT. 9400.000 DPHI.FDH FFDC.FgH 524.090 NFDC.FDH TENS.FDH ~2~0.000 NPHI.CNH NPOR.CNH 33.253 RCNT.CNH C~TC.CNH 844.5-54 GR.CNH DEPT. 93 00.0 O0 OF HI. F:DH F FDC. -~DH 746.5 gO NF DC. FOH TENS. FD.H 40'90. 000 NPH'r.. CNH NPOR.CNH 28. 131 RCNT.CNH C~TC. CNH 1130. 764 Gq.CNH DEPT. 9200.0 OD DPHI. FOH FFDC. FDH 497. O O0 NFOC. FDH TENS. ~mOH 4060. O 00 NP HI. CNH NPOR. CNH 39. ~ ~ 9 ~C NT. CNH C~TC. CNH :96.171., SR.CNH 8.697 659.500 42.264 2070.761 !.23.313 8.697 659.500 42. 264 2070.761 1.23.313 10.830 515.g00 39.899 2016.949 1 '! 1.063 1.I.T35 509.500 38.Z00 2172.403 84.~i3 9.467 667.000 30.710 2279.74'5 88.313 22.611 ,573.000 27.303 2961. 527 33.156 9. 796 636. 500 40. 512 2964.045 122.913 RH05. F DH C~LI.FOH TNPH.C NH RC'~T. CNH CALl .CNH RHOB .. F DH CALl. FDH T:NPH.CNH RC ~ T. C NH C~LI.CNH ~HOB.FOH C ~LI. FOH TNPH.CNH RCFT. CNH CALI.CNH RHDB.FDH CALI.FDH TNPH.CNH RC~FT.CNH ~ALI.CNH RH:OB.FDH CALI.~OH TNPH.CNH RCFT.CNH CALI.CNH RHOB.FOH C~LI.FDH TNPH.CNH RC=T.CNH CALI.CNH RH.'3B. FDH CALI.FDH TN~H. CNH ~C.:T. CNH CALI.CNH 2.507 7.914 40.282 557.420 7. 914 2.50 T 7.914 40. 282 557.4,20 2.471 8.727 39.250 496.689 8.727 2.. 4 55 8.750 3 7.428 574.594 8.750 2.494 3.641 31.825 717.734 8.641 Z.ZT? · B. 773 29.085 951.732 8.773 2.488 9.266 40.046 9.266 DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH GR.FDH TNRA.CNH CNTC.CNH T~N.S.CNH ORHO. FDH GR. TNR A. C NH CNTC.CNH T E'NS. CNH ORHO.~DH GR.mDH TNRA.CNH CNTC.CNH TENS.CNH ORHO.mDH GR.FDH TNR&.CNH CNTC.CNH TENS.CNH ORHO.FDH GR.FDH TNR~.CNH CNTC .CNH TENS.CNH ORHO.mDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH 0.097 123.313 3.401 21 ! 4.721 1.420.000 0.097 123.313 3.401 2114.721 2640.000 0.048 I 11.063 3.338 19'74. 323 4512. 000 0.039 84.813 3.247 2156.189 4500.000 0.098 88.313 2.799 23'76.984 4280.000 0.025 33.156 2.582 2988.432 4090.000 122.813 3.415 2005.952 4060.000 MEMORANDUM Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 %""~ ~?i ~';i ~tl ~.t, ~"~ SUBJECT:Conoco/PhillipsMeChanical Integrity Tests THRU: Jim Regg P.I. Supervisor [ ~ Kuparuk River Field 2K Pad FROM: John Crisp Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ,~e,I ~-o~ Ty~,ni.I s I T.v.~. I~ ITu~,n~l 2200 122oo 122oo 12200 I,n,~v~, P.T.D.I 1881180 TypetestI P ITestpsil 3000 I Casingl 1380I 2980I 2940I 2930I P/F Notes: OA 600 psi. pretest 680 psi. during test. 4.5 BBL. Pumped. We,,I ~-0~ I Ty~e,ni.I S I ~.V.~. I~00~ I Tu~,,~I23~0 12~0 12~0 12~0 I,,,e~,l 4 I P.T.D.I 1890820 ITypetestl P ITestpsil 3000 I CasingI 1320I 3010 I 2980 I 2975 I P/F I ?-P I Notes: OA 950 psi. during test. 2.6 BBL. Pumped. 1 We,,I 2K40 IType,nj.I G I T.¥.D. I~ I tubingl 3650 1365o I ~6~0 136~0 I,ntervaII 4 I P.T.D.I 1890590 ITypetestl P ITestpsil 3000 I Casingl 410 I 2960 I 2910 I 2900I P/F Notes: OA 200 psi. during test. 5.4 BBL. Pumped I We,,I ~K-~ ITy>e,,j.I S I ~.¥.~. I~ I~,,~I ~o I~o I ~o I ~o I,,~,1 ~ I,~,~ P.T.D,I ~ag09s0 ITypetestl P ITestpsil 3000 I Casingl 1220I 2940 I 2875 I 2860 I P/F I -P I Notes: OA 850 psi. pretest 1020 during test. 4.5 BBL. Pumped. I WellI 2K48 ItypeinJ. I $ I T.¥.D. 15900 Itubingl 2550 12550 12550 12550 I,.{erv~,l 4 I~.~~ I P'T'D'I 1891080 ITypetestl P ITestpsil 3000 I Casingl 1320 I 2980 I 2925 I 2900I P/FI Pi I Notes: OA 300 psi. during test. 5 BBL. Pumped. - I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures., Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during W°rkover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. SCANNED' AUG O. & 2003 2003-0614_M IT_KR U_2 K- 18_jc.xls 6~24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12K-05 P.T.D. I1881180 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type Test Test psi I 1500 I Casing I 13801 29801 29401 29301 P/F Well 12K-06 P.T:D. I1890820 Notes: Well 12K-10 P.T,D.11890590 Notes: TypeTest Test psiI 1502 I Casing I 13201 30101 29801 29751 P/F i y,e,n I [ T.V.D. 3 501 ~501 365011ntervall g TypeTest Test psiI 15oo I Casing I 4101 29601 29101 29751 P/F P.T:D.,i..t~8909.50... Type Test Test psiI 1535 I Casing I 12201 29401 28751 28601 P/F Notes: P.T,D.It891080 TypeTest Test psiI 1500 I Casing I 13201 29801 29201 29001 P/F Notes: "We, 12K-20 I Typelnj I pS I T.V.D. 16143 I Tubing I 20401 20401 204°1 2°4°11ntervall ~ 'P.T.D.I1891180 TypeTest Test psiI 1536 I Casing I 4001 29001 28751 285oI P/F Notes: P.T:D. I1891300 TypeTest Test psiI 1551 I Casing I 13001 28801 28201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0614_MIT_KRU_2K-05 06 10 13 18 20 24.xls 6/2.5/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23-0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) ~_~MIT KRU 2T 06-14-03.xls MIT KRU 2T 06-14-03.xls . '1~ Name: EXCEL File (application/msexcel)l' Type: Encoding: base64 ~MIT KRU 2K 06-14-03.xls MIT KRU 2K 06-14-03.xls ii Name:Type: EXCEL File (application/msexcel) ~.I. Encoding: base64 1 of I 6/25/2003 1:45 P~ IS TA>E VE~'~F~C,AT~ON LISTING SCHLUMBERGER ALASKA CCMPU'TING CENTER I0-0CT-1989 i5:5B DEPT. 9!00.000 DDHI.FDH FFDC.=DM 4¢4.,250 NFDC.FOH TENS.~DH 40134.000 NPHI.CNH NPO~.CNM 40.4T5 ~CNT,.CNH CFTC.CNH 553. 691 GR.CNH DEPT. 9000o000 DPHI..FDH FFDC.¢DH 691.500 NFDC.FEH TENS.FDH 40.50.000 NPHi.CNH NPOR.CNH 44.161 ~CNT.CNH CFTC.CNH 488.481 GR.CNH DEPT., 8996.600 gPHI.FDH FFDC.FDH 765.500 NFgC.FgH TENS.FDH 38~0.000 NPHi.CNH NPOR.CNH ~5.g04 ~CNT.CNH CFTC. CNH 458.124 g~,. CNH END 0¢ D~.T~ ~ 10.210 RHO~,.FgH 572.000 CA:LI.FDH 41.389 TNPH.CNH 1851.662 ~C~T.~CNH 111.125 C~LIoCNH 21.g09 RHDB.FgH 553.000 CALI.FOH 42.04~ TNPH.CNH 1625.093 RC~T.CNH 140.250 CALI.CNH 23.5~3 RHOB.FgH -672. 500 CALI.FgH 43. 682 TNPH.CNH 146~.075 RCFT.CNH 146. i Z.5 CALI. CNH 2.48,2 9.297 40.735 5~1.280 9.297 2.303 12.7ZT 42.012 41Z.962 1Z.TZT 2.262 11.80 5 4 3..291 ~:01.440 11.805 DRHO.FDH G~.FDH 'TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH 0.019 111.125 3.493 1857.681 4034.000 O. OZO 140.250 3.669 1697.184 4060. 000 0.020 146.125 3.735 1716.869 3840.000 * ~-' FILE TR.~ILE R FILE N~M:E : 'EDZT .002 ~SERVICE : FLIC VERSION : OOI~O2 D ~AT L5 : ~9/I0/t0 MAX R~C SIZ~ : 1024 FILE TYPE L,~ST mILE : ~---~- ~- TaPE T~ AIL~'R -,. SERVICE N~E : =~'"' D~TE .: 39/10/10 ORIGIN : :LIC TAP: NAME : 73498 CONTINUATICN ~ ' 1 PREVIOUS T~PE : CGMMENT : &RCS ALASKA, · ~- ~ R:EL TR.&IL~ SERVICE N&~E ' 5gIT D~TE : ~g/lO/lO ORIGIN : :LIC R:EL_ NAME ', CONTINUATION ~ : PREVIOUS .qEEL : COMMENT INC. ,KUP&RUK 2K - 13 , ~PI INC. ,KUP"~UK.. .)K - 13 , ~50-103-20116 ~50-I03-20116
