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Home My WebLink About187-129 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: August 8, 2011 187 - 129 / 311 - 210 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 December 28, 1988 50 103 - 20088 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1207' FNL, 281' FWL, Sec. 12, T12N, R8E, UM January 1, 1989 31412 Top of Productive Horizon: 8. KB (ft above MSL): 76 ' RKB 15. Field /Pool(s): 1292' FSL, 1175' FWL, Sec. 1, T12N, R8E, UM GL (ft above MSL): 34' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1565' FSL, 1216' FWL, Sec. 1, T12N, R8E, UM 6710' MD / 5899' 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 498655 y 6000451 Zone 4 7298' MD / 6373' TVD ADL 25531 TPI: x - 499548 y - 6002949 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 499589 y 6003222 Zone 4 1804' MD / 1804' TVD 2657 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1983' MD / 1983' 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" 245 sx AS I 9.625" 36# J -55 36' 3104' 36' 2986' 12.25" 1300 sx AS III, 400 sx Class G, 90 sx AS I 7" 26.0# J -55 36' 7225' 36' 6314' 8.5" 320 sx Class G, 175 sx AS I 24. Open to production or injection? Yes ❑ No Hi 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" 6682' 6684' MD / 5878' TVD perfs plugged off: 6832' - 6846' MD 5998' - 6009' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6880' - 6890' MD 6037' - 6045' TVD ,. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6904' -6914' MD 6056' -6064' TVD 4;61 t 5895-5899' 83.2 bbls cement 6934' -6954' MD 6080' -6096' TVD r4 ' j.. ` rr 27. : = - ION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable 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 is Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Na) SEP 30Z011 NONE RECEIVED. SEP $0 2111. RBDMS SEP 2 0 2011 �( kaBo &Gas COS.COMMinkM Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE is Submit original only An h0{ag "2 7 . ?l ' Vzr% G 28. GEOLOGIC MARKERS (List all formations and markers e•tered): 29. . FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1983' 1983' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 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: Jar Ohlinger @ 265 - 1102 a 9M /ir Printed Name L . Ga Title: CTD Engineering Supervisor 9//5/ Signature Q, A I 1' Phone 265 - 6306 Date Sharon Allsup -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 r _ `, . KUP • 3H -12 QPhilf Well Attributes Max Angle & MD TD Alaska. Inc Wellbore APUUWI Field Name Well Status Intl ( °) IMD (NKB) Act Btm (ftKB) csxsx �F^�u • _ 501032008800 I KUPARUK RIVER UNIT SVC 3728 l l 4,400.00 7,298.0 -__ Comment H2S (ppm) Date Annotation End Date KB (It) Rig Release Date _ 42.01 Wcl COnrg 3H - ?2 92812011 2:3944 PM SSSV TRDP - , Last WO ., �_. 4201 1/4/1988 . �_ _ - ' _ Schematic Actual Annotation pth (8103) End Date Annotation Last Mod .. End Date Last Tag_SLM j_6,681.0 8/1/2011 Rev Reason: ADD SIDETRACKS nmem I 9/8/2011 Casing Strings HANGER, 35 - us Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd el ,.. a -, ° CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID ... Top (fIKB) Set Depth (f_. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 35.0 3,103.9 2,986.2 36.00 J - 55 BTC Casing Description String O._ String ID... Top (NKR) Set Depth (f... Set Depth (TVD) String Wt... String ... String Top Thrd CON El 0CTOR, P RODUCTION 7 6.276 35.0 7,224 9 6,314.4 26 00 J B 1 C 36-115 _. -. "- Tubing Strings I SAFETY VLV, Tubing Description String 0... String ID ... Top (NKB) Set Depth 0.. Set Depth (TVD) String Wt... String ... String Top Thrd 1,804 TUBING WO I 3 1/2 2 992 35.0 I 6,681 9 I 5,876 4 9 -30 L80 EUE 8Rd Mod ' Completion Details Nomi. -. Top Depth (NCH Top inci ilt Tp (fIKB) ( ) (1 Iletri Desaiptbn comment 1 10(in) GAS LIFT, - '. _ - 35.0 35.0 - 0.06 HANGER MCEVOY MS/DP TUBING HANGER 2.876 2,584 1,804.1 1,804.1 -2.73 SAFETY VLV CAMCO TRMAXX- CMTSR -5 2.813" X- PROFILE SN#CZS-0415 2.812 6,619.6 5,826.3 36.30 NIPPLE 3 1/2" X 2.812" X NIPPLE 2.812 6,669.9 0,866.7 36.22 SEAL ASSY BAKER 80-40 GBH 22 LTSA SEAL ASSEMBLY W/ 3' SPACE OUT 3.000 1 : i Y.�. __- Tubing Descri ption St. ng 0... String ID ... Top (ftKB) Set Depth (G.. set Depth (TVD) String Wt... String ... String Top Thrd SURFACE, TUBING Original 1 31/2 . 2 .992 I 6,670.7 ( 6 7566 I 5,9368 9.30 I J -55 EUE8rdABMOD 353,104 ...,, a T zi s Completion Details £ Top Depth GAS LIFT, ': (TVD) Top Inel Noml... 4.087 _ To' B (B) (I Item Descripton _ Comment ID (In) 6,670.7 5,867.4 36.22 PBR BAKER PBR 3.000 6,684 -4 5,878.4 36 -20 PACKER BAKER FHL PACKER (75000# pull or rot. rel) 3.000 GAS LIFT, 6,7232 5,909.8 36.14 NIPPLE CAMCO D NIPPLE, MILLED TO 2.80" 2.800 5,211 > - 6755 -7 5,936.0 36.09 BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) IPERF, -' Top Depth -- 5,895.5,899 I ' (TVD) Top Inc' Top (NKB) (RKB) ( Description Comment Run Date ID (in) e , 6,854 6,015.5 36.14 WHIPSTOCK Accidental sidetrack from 7" using 280' D331 mill 8/6/2011 1 GAS LIFT, - 7,030 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/20/1999 • 6,026 downhole. g 7,032 6,159.2 36.47 FISH 5 GRAPPLES - 1 "X 2" 5/11/1995 7,036 6,162.5 36.47 FISH - Bailer Left in Hole 9/6/1988 GAS LIFT, 6,559 iiir Perforations & Slots Shot * Top (TVD) Bim (TVD) Dons Top (ftKB) Btm (ftKB) (ftKB) (NKB) Zone Date (sh • Type Comment 5,895 5,899 5,241.8 5,245.0 7/5/2011 6.0 IPERF 2" HSC Guns 60 Deg, SRC BH NIPPLE, 6,620 + r 6,832 6,846 5,997.7 6,009.0 C-4, 3H -12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,880 6,890 6,036.5 6,044.6 A-3, 31412 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,904 6,914 6,055.6 6,063.8 A -2, 31412 9/21/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph - 6,934 6,954 6,080.0 6,096.2 A -1, 3H -12 5/14/1988 4.0 IPERF 4 1/2" UltraPak, 120 deg. pH; 3 shots SEAL ASS, -. misfired -. I _... ■ PBR. 6.671 �- - i , - Notes: General & Safety End Date - Annotation PACKER, 6,684 10/4/2010 NOTE: View Schematic w/ Alaska Schematie9.0 NIPPLE, 6,723 SOS, 6,756 IPERF, 6,832 -6,848 ■ WHIPSTOCK, 6,854 PERE, 'i 6, 680$890 - IPERF,_ 6,904-6,914 F 7,034 954 FISH, -6 7,030 - FISH, 7,032- FISH, 7,036- . PRODUCTION, - 357,225 TD (36 -12), - _ - - -. 7,296 SLOTS, _, 6,877 -8,151 SLOTS._ 6,850.8,454 ' LINERM., -- - S,t 6,701 -8,454 2 - ' - . 1 L. - Mandrel Details �"�,. Top Depth Top Pori ",' (TVD) Intl OD Valve Latch Sae TRO Run Stn Tc (ftKB) OMB/ ( °) Make _ Model (in) Sirs TY• TYPe (In) (Psi) Run Dab Com... 4 - I 1 2,584.1. 2,553.5 28.44 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/17/2011 L 2 4,087.3 3,791.4 34.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0 -0 6/17/2011 3 5,210.8 4,693.2 36.92 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 ¢�"` , 4 6,026.4 5,347.6 36.42 CAMCO MMG 5 6,559.2 1 12 GAS LIFT DMY RIO 0.000 0.0 6/172011 1 2 5,777.3 36.09 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 722011 ya. i & ° 1 LINERAL3, 6,888 -9,004 • 3H -12 Well Summary • DATE SUMMARY 7/2/11 ASSIST VLV CREW W/ PULLING BPV, REPLACE SOV @ 6559' RKB W/ DV, PERFORM PASSING MIT IA TO 2500 PSI, PULL CATCHER @ 6703' SLM. IN PROGRESS. 7/3/11 BAIL MUD OFF CA -2 PLUG @ 6723' RKB, PULL PRONG FROM PLUG, ATTEMPT TO PULL PLUG BODY. IN PROGRESS 7/4/11 PULL 2.75" CA -2 PLUG BODY @ 6723' RKB, TAG @ 6895' SLM, MEASURE BHP @ 6900' RKB, GRADIENT @ 6780' RKB. READY FOR E -LINE. 7/5/11 SHOT 2" HSC LOADED WITH 5' OF JRC BH 6.7g CHARGES 6 SPF 60 DEG PHASE. TOP SHOT @ 6705'. SHOT INTERVAL 6705'- 6710'. LOGGED TUBING JEWELRY TO 200'. LRS FOLLOW UP INJECTION TEST: PUMPED 140 BBL DIESEL DOWN TUBING AT 1.5 BPM @ 2500 PSI. 7/9/11 RIH TO MILL NIPPLE, PLLUGGED TOOLS W /ROCKS, PIG CT, RETURN IN MORNING 7/10/11 RIH TO MILL NIPPLE, MILL FOR 8HRS, RAN OUT OF PIPE CYCLES, POOH TO CUT PIPE, IN PROGRESS 7/11/11 FINISH MILLING NIPPLE, RETOOL FOR FCO, HARD TAG @ 6878' CTMD, COULD NOT WASH THROUGH, POOH, IN PROGRESS 7/13/11 MILL OUT FILL FROM 6900' TO 7000' CTMD, CIRCULATE CLEAN, PREP FOR SQUEEZE, IN PROGRESS 7/14/11 HARD TAG @6878' CTMD, POSSIBLE CASING DAMAGE, CALL ENGINEER CALIPER REQUESTED,CONTACT SLICKLINE, IN PROGRESS 7/14/11 DRIFTED TBG / CSG WITH 5' x 2" BAILER. LOCATED TBG TAIL @ 6723' SLM, 6755' RKB. TAGGED @ 6969' SLM, EST. 7001' RKB. LOGGED CALIPER SURVEY f/ —7000' TO 6250' RKB. RECOVERED GOOD DATA. COMPLETE. 7/26/11 Performed required weekly BOPE testing. Swapped out failed micro - motion (3 -hr NPT). Attempted cement squeeze pumping 34 -bbl of 17 -pp9 cement. Layed in cement from just above intitial tag at 7000' up to 3.5" tubing at 6507' with 1:1 returns prior to closing choke. Pumped remainder of cement with closed choke but squeeze pressure not obtained throughout. Pumped ball and ran back in from 4450' to 6966' pumping away all cement. Ordered out 30 -bbl 17 -ppg cement, as well as quantity of CemNET for minimum 15 -bbl, for load and testing tonight, and pumping tomorrow. CTU and Cement Van remain rigged up on location for morning re -start. 7/27/11 ATTEMP TO SQUEEZE 33 BBL 17 PPG CMT WITH 1 LB PER BBL CEM NET FIBER ADDITVE, LAY CEMENT IN FROM 6970' TO 6500' ATTEMPED 1 SQUEEZE WITH NO RESULTS. PUSHED ALL CEMENT AWAY, POH TO 1500' PROBLEMS WITH INJECTOR, OUT HOLE, TRAP 1850 PSI WHP, FP, UNIT DN DUE TO INJ PROBLEMS, 4 HR NPT, 7/28/11 DRIFT TBG W/ 2.29 ". TAG TOC @ EST. 6966' RKB. ATTEMPTED INJECTION TEST, TBG PRESSURED UP TO 2250 PSI AFTER .02 BBLS. COMPLETE. 7/30/11 PERFORM CEMENT SQEEZE WITH 16.2 BBL 17 PPG NEAT CEMENT, RIH AND HRD TAG @ 6954 CTMD, CORRECTED DEPTH TO 6966 RKB, CONDITIONED WELL BORE WITH SW, LAYED IN 10 BBL CEMENT FROM 6966' TO 6705', SQUEEZED APPROX 4.2 BBL BEHIND PIPE, WASHED ALL REMAINING CEMENT TO SURFACE, WH FP, IN PROGRESS, 8/1/11 TAG TOC w/ SAMPLE BAILER A 6686' SLM, LOCATE X- NIPPLE w/ X -LINE TOOL © 6586'SLM, TAG TOC @ 6681' SLM, SET BPV w/ VALVE CREW, RDMO • Conocohi[lips Time Log & Summary Wellview Web Reporting Report Well Name: 3H -12 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 8/2/2011 3:00:00 PM Rig Release: 8/28/2011 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/02/2011 24 hr Summary Mobilized rig from 3H -10 to 3H -12. Accept rig at 15:00. MIRU Stabbed pipe, pumped slack management, cut 80' of coil. 04:00 15:00 11.00 MIRU MOVE MOB P Move rig from 3H -10 to 3H -12. Ru equip. 15:00 00:00 9.00 MIRU WHDBO NUND P Accept rig @ 15:00. Continue rigging up. Stab pipe, fluid pack coil with SW, pump slack management. Test & chart inner reel valve & stripper. Cut coil 80' of coil. 38/03/2011 Tested BOPE, test waived by John Crisp. Tagged TOC at 6710' MD. Swap well to Seawater W/ 2 PPB Biozan. Mill 2.80" pilot hole in cement from 6710 to tight spot @ 6843' MD. 00:00 09:00 9.00 MIRU WHDBO BOPE P Finish up cutting coil, rehead while k BOPE test. Test waived by kit 1/ John Crisp. 09:00 11:00 2.00 MIRU WHDBO BOPE P Pull BPV 11:00 12:00 1.00 MIRU WHDBO BOPE P Pressure test PDI and tiger tank line to 2500 PSI 12:00 13:00 1.00 PROD1 WHPST PULD P MU milling BHA strip on well to establish space -out for pressure deployment, 1.9' down from tag up. 13:00 14:48 1.80 0 6,530 PROD1 WHPST TRIP P RIH, displace wellbore fluids to tiger tank with seawater 14:48 16:00 1.20 6,530 6,710 PROD1 WHPST DLOG P Tie into GR, +30', tag cement at 6710'. PUH and log CCL to verify jewelry. 16:00 16:24 0.40 6,710 6,710 PROD1 WHPST TRIP P continue circulating well to biozan 16:24 21:15 4.86 6,710 6,808 PROD1 WHPST MILL P Start milling cement. 1.5 BPM, 3450 CTP, 3180 BHP, with WOC, 10.55 ECD. 21:15 23:45 2.50 6,808 6,843 PROD1 WHPST MILL P Stall @ 6808'. Down on pump, PUH @ 35k. Back on line, ease back down to 6808' 1.5 BPM, 3450 CTP, 3294 BHP, 10.77 ECD. ROP 19. 23:45 23:59 0.24 6,843 6,843 PROD1 WHPST MILL P Stall @ 6843'. Down on the pump. Try again & stall again. 08/04/2011 Continued milling cement pilot hole @ 6843'. Slow milling from 6843' to 6848' with multiple stalls. Trip OOH for D331 mill with gauge cutters & adjust motor to .6. Mill at average ROP of .6 from 6848 to 6853. 00:00 01:30 1.50 6,843 6,847 PROD1 WHPST MILL P Working mill @ 6843' have several stalls. Make tool face changes...210 /280/90/ make it by @ 140 tool face. Ease back to 20 right. 1.5 BPM 3400 CTP. WOB @ 1.5, ROP @ 8.8 @ 6845'. Page 1 of 20 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 04:30 3.00 6,847 6,848 PROD1 WHPST MILL P Stall out @ 6847'. PU @ 35k. RBIH @ 20 right, went by 6843' with no problem. Stall again @ 6847.13. Change tool face to 150 R, stall again @ same depth. Try time drilling, still having muliple stalls. 04:30 05:30 1.00 6,848 6,848 PROD1 WHPST MILL P Continue time milling @ 6848.4 1.5 BPM, 3400 CTP. 05:30 09:00 3.50 6,848 6,848 PROD1 WHPST MILL P Ream down at 6 FPH at 210 then 150 from 6840' to 6848' 09:00 10:54 1.90 6,848 0 PROD1 WHPST TRIP T POOH for mill and motor adjust 10:54 11:12 0.30 6,848 PROD1 WHPST SFTY P Flow check, PJSM 11:12 12:30 1.30 0 0 PROD1 WHPST PULD T Lay down motor and mill, mill came out 2.80 go/2.79 no -go. PU new 2.80" D331 mill with guage cutters 2.81 go /2.80" no -go. Adjust motor to .6 deg. 12:30 14:24 1.90 0 6,715 PROD1 WHPST TRIP T RIH 14:24 14:54 0.50 6,715 6,757 PROD1 WHPST DLOG T Tie into K1, +14' 14:54 16:42 1.80 6,757 6,848 PROD1 WHPST MILL P Tag cement at 6848'. Ream up and down at 180, 210 and 150 degrees at 1 FPM from 6838' to 6848' 16:42 22:00 5.30 6,848 6,853 PROD1 WHPST MILL P Milling cement, 1.5 BPM, 3050 CTP 22:00 00:00 2.00 6,853 6,853 PROD1 WHPST MILL P ROP @ .6 Sample at the shakers showing 80% fine metal shavings. Discuss with engineer, geo, & DD. Keep a real close eye on samples for any changes. Continue Milling at 6853' 38/05/2011 Attempt to mill cement pilot hole, unable to get past tight spot @ 6853'. PU 2.80" craylola mill, ream up /down passes from 6830 to 6852 @ 210, 180,145, & 240 TF @ 18 FPH. 00:00 01:00 1.00 6,853 6,854 PROD1 WHPST MILL P Milling @ 6853'. ROP @ .3. TF @ 210 deg 1.5 BPM CTP 3200, WOB 2.73. 01:00 05:30 4.50 6,854 6,854 PROD1 WHPST MILL P Real slow going. Have had 8 stalls. Have to push to get by tight spots to get back to bottom. Samples are showing 50/50 metal shavings /cement. 05:30 08:42 3.20 6,854 6,854 PROD1 WHPST MILL P Ream up and down at 17 FPH, 150 TF 08:42 10:18 1.60 6,854 0 PROD1 WHPST TRIP T POOH 10:18 10:42 0.40 0 0 PROD1 WHPST SFTY T Flow check, PJSM 10:42 12:45 2.05 0 0 PROD1 WHPST PULD T Lay down motor and mill, Mill came out 2.80 go/2.79 no -go. PU .6 deg motor and weatherford carbide crayola mill, 2.80 go/2.79 no -go 12:45 14:15 1.50 0 6,725 PROD1 WHPST TRIP T RIH 14:15 14:30 0.25 6,725 6,755 PROD1 WHPST DLOG T Tie -in, +15' Page 2 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 00:00 9.50 6,854 6,840 PROD1 WHPST MILL T Tag bottom at 6855.8 with 2K WOB, PUH to 6853' and come online with pump at 1.5 BPM, 3400 CTP, ream up and down at 210, 180, 145, & 240 TF @18FPH 08/06/2011 Mill cement pilot hole from 6854' to 6930'. TOOH for dummy whipstock drift. 00:00 00:45 0.75 6,840 6,852 PROD1 WHPST MILL T @ 6840', Continue reaming down @ 240 TF @ 18 FPH. 1.5 BPM 3068 CTP. 00:45 02:03 1.30 6,852 6,830 PROD1 WHPST MILL T Pass up, 0 TF @ 18 FPH 02:03 03:48 1.75 6,830 0 PROD1 WHPST TRIP T Shut down pump. Open EDC, circulate POOH to surface 03:48 04:18 0.50 0 0 PROD1 WHPST SFTY P Flow check, PJSM. 04:18 05:18 1.00 0 0 PROD1 WHPST PULD T Swap out mills. lay down crayola mill (2.80 no go/ 2.79 go.PU D331 mill with side gauge cutters. Check out coil life @ 6850 area, 14% 05:18 07:06 1.80 0 6,725 PROD1 WHPST TRIP T RIH W/ BHA # 4, D331 mill w/ side cutters. 07:06 07:24 0.30 6,725 6,853 PROD1 WHPST DLOG T Tie -in, +16', close EDC, 31K PUW, 14K RIW 07:24 10:30 3.10 6,853 6,866 PROD1 WHPST MILL P Tag at 6853.4' and start milling at 20� ROHS, 1.5 BPM, 3200 CTP. Note: Looks like we accidentally exited the 7" casing at 6854' MD. 10:30 19:00 8.50 6,866 6,930 PROD1 WHPST MILL P Swap well to 10.3 flo -pro system, 1.4 BPM at 3700 freespin. Continue milling at 20 ROHS, 1.5 BPM 3660 CTP 19:00 20:00 1.00 6,930 6,737 PROD1 WHPST DLOG P PUH to 6823'. RIH @ min rate take surveys to bottom. PUH to 6737' 20:00 20:15 0.25 6,737 6,930 PROD1 WHPST TRIP P RIH, dry drift to bottom with no problems. 20:15 21:00 0.75 6,930 6,930 PROD1 WHPST DLOG P PUH to 6925', tie in for -2 correction. Run CCL log from 6763' to 6930' 21:00 23:00 2.00 6,930 0 PROD1 WHPST TRIP P TOOH to surface 23:00 23:45 0.75 0 0 PROD1 WHPST SFTY P No flow test & PJSM. Bleed down 20 psi, built back up to 300 PSI. repeat several times. Open choke, flowing at .1 for 5 minutes. Shut in SSSV, bleed down held at 0 psi. 23:45 00:00 0.25 0 0 PROD1 WHPST PULD P Undeploy BHA # 4 08/07/2011 Cut 150' of coil. RU E -line, run GyroData log from 6600' to TD@ 6930'. Data sent to Inteq well planner in town. 00:00 05:00 5.00 0 0 PROD1 WHPST SLPC P Continue laying down BHA# 4. Prep to cut coil. Reverse circulate for minor slack management prior to cutting coil. Cut coil, install CTC & pull test. Re -head Inteq & test. 05:00 07:00 2.00 0 0 PROD1 WHPST PULD P MU BHA # 5, Dummy whipstock with USR 07:00 07:48 0.80 0 0 PROD1 WHPST TRIP T Tool shorted while RIH, PUH, shut in and flow check Page 3 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:48 08:12 0.40 0 0 PROD1 WHPST SFTY T PJSM 08:12 11:12 3.00 0 0 PROD1 WHPST PULD T Pull injector off well and trouble shoot Inteq tools. Pulled out of e-line head. Rehead and PT. 11:12 15:30 4.30 0 0 PROD1 WHPST ELNE T MIRU HES e -line unit 15:30 16:00 0.50 0 0 PROD1 WHPST SFTY T PJSM with HES and Gyro -Data personnel 16:00 21:00 5.00 0 0 PROD1 WHPST ELNE T MU gyro -data tools and RIH with e -line. Log & tie in at 6600' down to 6930' W/ CCL & gyro tool. POOH to surface. 21:00 23:00 2.00 0 0 PROD1 WHPST ELNE T E -line out of the hole. PJSM, RD E -line. 23:00 00:00 1.00 0 0 PROD1 WHPST PULD T PJSM. Decided not to run USR tool. Lay down BHA that was staged in the PDL. Re- configure BHA and pick up. 38/08/2011 Run whipstock dummy drift to 6890', window clean. Set anchored aluminum billet w/ RA tag (10 deg LOHS) @ 6880'. Tagged TOB billet @ 6880.23', start time drilling for kick off. 00:00 02:15 2.25 0 0 PROD1 WHPST PULD P Continue picking up BHA #6. Dummy whip stock drift. PJSM for PD. Pressure deploy BHA # 6 dummy drift. 02:15 02:30 0.25 0 0 PROD1 WHPST TRIP T Attempt to pump & RIH W/ BHA # 6. Unable to pump. Look at check list, suspect double valve ball valves are closed. 02:30 03:30 1.00 0 0 PROD1 WHPST PULD T PJSM. Undeploy to check out BHA, ball valves were closed. open ball valves and pressure deploy. 03:30 05:12 1.70 0 6,710 PROD1 WHPST TRIP P RIH W/ BHA # 6 (dummy whipstock) 05:12 05:30 0.30 6,710 6,768 PROD1 RPEQPI DLOG P Tie -in, 05:30 06:30 1.00 6,768 6,750 PROD1 RPEQP1TRIP P Continue RIH, drift through window was clean with 1K WOB at 6867' and less than 1K at 6890'. PUH through "window" was clean. 06:30 08:12 1.70 6,750 0 PROD1 RPEQP1TRIP P POOH 08:12 09:42 1.50 0 0 PROD1 RPEQP1PULD P Undeploy BHA # 6 09:42 11:00 1.30 0 0 PROD1 RPEQP1 SVRG P Injector maintenence and rig service while waiting on BOT 11:00 12:30 1.50 0 0 PROD1 RPEQP1PULD P Deploy BHA # 7. Anchored aluminum billet with RA. 12:30 14:06 1.60 0 6,715 PROD1 RPEQP1TRIP P RIH 14:06 14:18 0.20 6,715 6,767 PROD1 RPEQP1DLOG P Tie -in, +26' 14:18 14:42 0.40 6,767 6,891 PROD1 RPEQP1WPST P Close EDC, RIH 6891, stacked 5K, oriented to 10 deg. LOHS. pressure up to 4400 CTP to set. PUH at 28K 14:42 16:42 2.00 6,891 0 PROD1 RPEQP1TRIP P Close EDC, POOH 16:42 17:00 0.30 0 0 PROD1 RPEQPISFTY P PJSM 17:00 18:00 1.00 0 0 PROD1 RPEQP1PULD P Undeploy billet running BHA Page 4 of 20 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 0 0 PROD1 DRILL SFTY P Change out & pressure deploy PJSM. 18:30 20:30 2.00 0 0 PROD1 DRILL PULD P Pick up BHA # 8, pressure deploy. 20:30 22:30 2.00 0 6,710 PROD1 DRILL TRIP P RIH W/ BHA # 8 22:30 22:45 0.25 6,710 6,880 PROD1 DRILL DLOG P Tie in +18' correction, RIH tag billet @ 6880.39 22:45 00:00 1.25 6,880 6,881 PROD1 DRILL DRLG P Pick up, pump on line @ 1.44 BPM 3436 CTP FS. Start time drilling (1 FPH) @ 6879.60' 08/09/2011 Function tested BOPE.Kicked off billet @ 6880'. Drilled build to 7195'. Drilled ahead in 3H -12A to 7360'. 00:00 01:30 1.50 6,881 6,915 PROD1 DRILL DRLG P Continue kicking off the billet @ 6881' 1.42 BPM 3348 CTP Drill down to 6915'. 01:30 01:45 0.25 6,915 6,915 PROD1 DRILL WPRT P PUH up past billet, drift down, pumps at min, looks good. 01:45 05:54 4.15 6,915 7,060 PROD1 DRILL DRLG P Drill ahead 1.41 BPM 3500 CTP, ROP 30, BHP 3921 PSI. 05:54 06:12 0.30 7,060 6,725 PROD1 DRILL WPRT P Wiper to TT for tie -in, 28K PUW 06:12 06:42 0.50 6,725 6,920 PROD1 DRILL DLOG P Tie -in to K1, +1', Log RA in billet at 6883' 06:42 06:54 0.20 6,920 7,060 PROD1 DRILL WPRT P Wiper back to bottom, 15K RIW 06:54 13:00 6.10 7,060 7,195 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3440 CTP, 4000 BHP with WOC 13:00 14:54 1.90 7,195 0 PROD1 DRILL TRIP P End of build, POOH 14:54 15:12 0.30 0 0 PROD1 DRILL SFTY P PJSM 15:12 16:30 1.30 0 0 PROD1 DRILL PULD P Undeploy BHA # 8 16:30 17:00 0.50 0 0 PROD1 DRILL BOPE P Function test BOP 17:00 19:00 2.00 0 0 PROD1 DRILL PULD P Deploy BHA # 9 19:00 20:45 1.75 0 6,720 PROD1 DRILL TRIP P RIH W/ Drilling BHA 20:45 20:54 0.15 6,720 6,768 PROD1 DRILL DLOG P Tie into K -1 + 22.5 20:54 21:15 0.36 6,768 7,195 PROD1 DRILL TRIP P RIH to BTM 21:15 23:15 2.00 7,195 7,360 PROD1 DRILL DRLG P Drill ahead 1.40 BPM 3739 CTP. BHP @ 3900 PSI, ECD 12.52 23:15 23:59 0.74 7,360 6,900 PROD1 DRILL DLOG P PUH 26k off BTM. Mad pass from 7200' to 6870' 38/10/2011 Drilled ahead in lateral 3H -12A from 7360' to 8520. 00:00 00:15 0.25 6,900 6,870 PROD1 DRILL DLOG P Continue MAD pass to 6870'. 00:15 00:30 0.25 6,870 7,360 PROD1 DRILL TRIP P RBIH 00:30 02:00 1.50 7,360 7,510 PROD1 DRILL DRLG P Drill ahead. 1.5 BPM 3884 CTP BHP, 3923 PSI, ECD 12.61 02:00 02:45 0.75 7,510 7,510 PROD1 DRILL WPRT P Wiper up to 6900'. RBIH 02:45 04:45 2.00 7,510 7,660 PROD1 DRILL DRLG P Drill ahead 1.5 BPM 3700 CTP, 3925 BHP, 12.62 ECD 04:45 05:00 0.25 7,660 6,900 PROD1 DRILL WPRT P Pull Wiper 05:00 05:12 0.20 6,900 6,930 PROD1 DRILL DLOG P Tie in, -3' Page 5 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:12 05:27 0.25 6,930 7,660 PROD1 DRILL WPRT P Wiper back in hole, 14K RIW 05:27 07:21 1.90 7,660 7,810 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM, 3700 CTP, 3985 BHP with WOC 07:21 08:27 1.10 7,810 7,810 PROD1 DRILL WPRT P Wiper to the billet, 26K PUW 08:27 09:51 1.40 7,810 7,960 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM, 3750 CTP, 3960 BHP with WOC 09:51 11:09 1.30 7,960 7,960 PROD1 DRILL WPRT P Wiper to billet, 27K PUW 11:09 13:27 2.30 7,960 8,110 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM, 3750 CTP, 3980 BHP with WOC 13:27 14:21 0.90 8,110 6,900 PROD1 DRILL WPRT P Wiper to the billet, 26K PUW 14:21 14:39 0.30 6,900 6,925 PROD1 DRILL DLOG P Tie -in, 14:39 15:09 0.50 6,925 8,110 PROD1 DRILL WPRT P Wiper back inhole, 14K RIW 15:09 17:27 2.30 8,110 8,260 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3750 CTP, 4010 BHP with WOC • 17:27 19:12 1.75 8,260 8,260 PROD1 DRILL WPRT P Pull wiper, 27k off btm & smooth. wiper up to 6915'. RBIH 19:12 20:27 1.25 8,260 8,410 PROD1 DRILL DRLG P Drill ahead. 1.4 BPM 3839 CTP, 4028 BHP, 13.00 ECD 20:27 22:27 2.00 8,410 8,410 PROD1 DRILL WPRT P Pull wiper, RBIH to BTM. 22:27 00:00 1.55 8,410 8,520 PROD1 DRILL DRLG P Drill ahead 1.43 BPM 3900 CTM, BHP 4043 PSI, ECD 13.07 08/11/2011 Swap to 9.8 drilling mud. Drilled ahead to 9140' 00:00 00:15 0.25 8,520 8,540 PROD1 DRILL DRLG P Continue drilling to 8540' 00:15 01:30 1.25 8,540 6,930 PROD1 DRILL WPRT P Pull wiper, dirty trucks on location for mud swap. RBIH, Tie in for a -5 correction. 01:30 02 :30 1.00 6,930 8,540 PROD1 DRILL TRIP P RBIH, Pump 5 bbls hi /lo vis sweep. Swap mud to 9.8 system. Time it to have new mud to the bit @ TD. 02:30 04:30 2.00 8,540 8,621 PROD1 DRILL DRLG P Drill ahead. Still have old mud on backside. 1.41 BPM, 4052 CTP, 4047 BHP. WHP 106. Get new mud all around. Open choke full open. 1.4 BPM 3981 CTP, BHP 4034, ECD 13.0. Harder drilling starting at -8615' 04:30 04:45 0.25 8,621 8,621 PROD1 DRILL WPRT P Short wiper up, 27k off BTM. RBIH 04:45 06:24 1.65 8,621 8,690 PROD1 DRILL DRLG P Drill ahead. Slow ROP of 6.2. get w/ Geo. 1.40 BPM 3971 CTP, BHP 4059, ECD 13.09. @ 8625' ROP picked up to 48 FPH. 06:24 08:36 2.20 8,690 8,690 PROD1 DRILL WPRT P Wiper to billet, Circulating pressure is up about 100 psi, 1.4 BPM at 3900 CTP and freespin differential pressure is 520 PSI at the BHA. 26K PUW 08:36 11:18 2.70 8,690 8,840 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3850 CTP, 4050 BHP with WOC 11:18 13:36 2.30 8,840 8,840 PROD1 DRILL WPRT P Wiper to the billet, 27K PUW 13:36 16:30 2.91 8,840 8,981 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3850 CTP, 4050 BHP with WOC Page 6 of 20 • • • Time Logs Date From To Dur S. Depth_ E. Depth Phase _Code Subcode T Comment 16:30 19:15 2.75 8,981 8,981 PROD1 DRILL WPRT P Wiper to the billet, 26K PUW RBIH, tie in for -7' correction. 19:15 21:45 2.50 8,981 9,140 PROD1 DRILL DRLG P Drill ahead 1.41 BPM, 4041 CTP, BHP 4108, ECD 13.18 21:45 23:59 2.24 9,140 8,000 PROD1 DRILL WPRT P Wiper to billet, 28k off BTM, RBIH 08/12/2011 Drilled ahead to TD @ 9535'. Pull wiper to swab valve. TIH back to TD, lay in liner beads up through cement pilot hole. Tag up, attempt to get SSSV to hold. 00:00 00:30 0.50 8,000 9,140 PROD1 DRILL WPRT P Continue RBIH from wiper trip. 00:30 02:45 2.25 9,140 9,291 PROD1 DRILL DRLG P Drill ahead 1.40 BPM, 4135 CTP, BHP 4110, ECD 13.23 02:45 05:24 2.65 9,291 9,291 PROD1 DRILL WPRT P Pull wiper to the billet. RBIH. 05:24 08:00 2.60 9,291 9,440 PROD1 DRILL DRLG P Drill ahead, 1.4 BPM, 3950 CTP, 08:00 09:54 1.90 9,440 6,900 PROD1 DRILL WPRT P Wiper to the billet 09:54 10:06 0.20 6,900 6,930 PROD1 DRILL DLOG P Tie -in, -11' 10:06 11:18 1.20 6,930 9,440 PROD1 DRILL WPRT P Wiper back in hole 11:18 13:12 1.90 9,440 9,535 PROD1 DRILL DRLG P Continue driling, 1.4 BPM, 3850 CTP, 4150 BHP. TD lateral. 13:12 16:54 3.70 9,535 0 PROD1 DRILL WPRT P Wiper to the swab valves, pumped low and high vis sweeps, 26K PUW. Clean trip in open hole, clean past _ billet and through window. 16:54 20:30 3.60 0 9,535 PROD1 DRILL WPRT P Wiper back in hole. Send liner pill down in time to be at the bit @ TD. 20:30 23:30 3.00 9,535 0 PROD1 DRILL DISP P Tag TD, Liner beads at the bit, PUH laying beads up past window & cement pilot hole to - 6432' TOOH to surface. All fluids 9.8 ppg. 23:30 00:00 0.50 0 0 PROD1 DRILL OWFF P Conduct pre -job. Shut SSSV, watch for no flow. No good. Trouble shoot. 38/13/2011 Unable to SSSV to hold for liner run. RBIH & layed in 12.8 liner pill & KWF to surface. Attempt to run liner W/ anchored billet but stacked out @ 8680'. Tripping out with liner assembly. 00:00 00:45 0.75 0 0 PROD1 DRILL OWFF T SSSV still not holding. Discuss options. 00:45 02:30 1.75 0 1,804 PROD1 DRILL TRIP T Pump MP while RIH to SSSV @ 1804'. Open ECD, wash acrossed SSSV . Check EDC location to ensure it's washing the valve. Wash valve numerous times -Pull up above valve. Dump SSSV again, bleed thru choke fast, WHP goes down but bounces back up. Repeat a couple time still no good. Estimate 6 bbls bleed back over all the SSSV tests. Call town. Get the 12.5 ppg KWF weighted up to 12.8 ppg. 02:30 04:30 2.00 1,804 6,400 PROD1 DRILL TRIP T RIH while mud is being weighted up. Have another liner bead pill made up as well. 04:30 07:06 2.60 6,400 7,100 PROD1 DRILL TRIP T Wait for liner pill and KWF 07:06 07:24 0.30 7,100 7,150 PROD1 DRILL DLOG T Tie -in to K1 marker Page 7 of 20 • • Time Logs Date From To Dur S. Depth__ E. Depth Phase Code Subcode T Comment 07:24 08:54 1.50 7,150 9,535 PROD1 DRILL TRIP T RIH to TD 08:54 11:54 3.00 9,535 0 PROD1 DRILL TRIP T Lay in 12.8 PPG liner pill and KWF to surface while POOH 11:54 12:18 0.40 0 0 PROD1 DRILL SFTY P PJSM for laying down drilling BHA, watch for no flow. All good. 12:18 13:18 1.00 0 0 PROD1 DRILL PULD P lay down drilling BHA 13:18 13:48 0.50 0 0 COMPZ CASING SVRG P Injector maintenence • 13:48 14:18 0.50 0 0 COMPZ CASING SFTY P PJSM for liner operations 14:18 19:45 5.45 0 0 COMPZ CASING PUTB P RU for liner operations. MU liner, 51 joints slotted with anchor billet attached. 19:45 22:15 2.50 0 8,680 COMPZ CASING RUNL P RIH W/ liner & anchored billet. Get the anchor billet past the window with no problem. Seeing some swings in the open hole, stacked weight @ 8680' PU WT. @ 43k. Reluctant to work pipe down because of anchor billet attached. 22:15 00:00 1.75 8,680 5,500 COMPZ CASING RUNL T Prepare to POH. Having issues with the torque adjust on the panel. Slack off wt, able to get moving up -TOOH. Get EDC back up into the tubing but unable to open the EDC due the heavy weight below the BHA. Have to trickle in KWF down the backside to keep hole full. Note: A Call was made for the electrian & mechcanic to look at injector. X8/14/2011 Repaired injector drive shaft & replaced drive motor. (10 hours billable rig repair time) Set liner (lower section) @ 9235' top at 8530'. Picking up liner for upper section. 00:00 01:15 1.25 5,500 0 COMPZ CASING TRIP T Continue POOH to surface. 01:15 01:45 0.50 0 0 COMPZ CASING SFTY T PJSM, check for no flow. 01:45 03:00 1.25 0 0 COMPZ CASING PUTB T No flow at surface. Lay down BHA. Lay down Anchored billet & 3 joints of liner. install safety joint. 03:00 13:00 10.00 0 0 COMPZ CASING RGRP T Inspect injector for torque problem. Found drive shaft damaged. Make repairs. Changed out drive motor. ""` 10 Hours billable rig repair time ... 13:00 13:30 0.50 0 0 COMPZ CASING PUTB T RU for liner operations 13:30 13:54 0.40 0 0 COMPZ CASING SFTY T PJSM 13:54 15:54 2.00 0 0 COMPZ CASING PUTB T Lay down 27 joints of liner, this will leave 21 joints, 704' of liner and shoe 15:54 16:30 0.60 0 749 COMPZ CASING PUTB T MU BHA, injector to well Page 8 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:30 3.00 749 9,235 COMPZ CASING RUNL T RIH W/ lower liner section, tie into K -1 for a + 22.5' correction. continue RIH get past 9235'. PUH & get good PU WT. Stop @ 9235', short of TD as per decision from town. Up on pump, pump off liner, - 10k, looks good. TOL = 8530', BOL = 9235'. 19:30 21:45 2.25 9,235 0 COMPZ CASING TRIP P TOOH to surface, keeping hole full. 21:45 22:15 0.50 0 0 COMPZ CASING SFTY P Tagged up. PJSM. Watch for flow. 22:15 00:00 1.75 0 0 COMPZ CASING PUTB P Well is dead. lay down BHA and start picking up liner, 21 jts. 38/15/2011 Set upper liner @ 8532', placing anchored billet @ 7821'. Test BOP, test waived by Chuck Sheve on 08 -14 -11 at 12:00. Started picking up kick off BHA. • 00:00 01:15 1.25 0 772 COMPZ CASING PUTB P Continue picking up liner, BHA & Anchored billet. 01:15 03:30 2.25 772 8,533 COMPZ CASING RUNL P RIH W/ liner run # 2 (BHA 12) stop @ flag. 6772' on counter + 27.62' correction. Weight check of 28.5k. RBIH, lower section top should be at 8530', orient to 165 deg.ease down, not seeing wt on bit until 8532.5' pick up to neural wt. Pump up Coil to 4200 psi, set anchor. Pick up 2' & re -tag stack 2k. Looks good. 03:30 06:00 2.50 8,533 0 COMPZ CASING TRIP P TOOH up past window. adjust bit depth. TOOH to surface circulating KWF. 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P OOH, conduct PJSM and change out with day crew. 06:30 08:00 1.50 0 0 COMPZ CASING PULD P Get BOT tools broken off. Lay down BHA. 08:00 10:00 2.00 0 0 PROD2 DRILL SVRG P Grease tree, prep for BOP test 10:00 22:00 12.00 0 0 PROD2 DRILL BOPE P Start testing BOP. State witnessing waived by Chuck Sheve on 8 -14 -2011 at 12:00. 22:00 23:00 1.00 0 0 PROD2 DRILL RGRP P Service injector & fix leaky Koomy line. 23:00 00:00 1.00 0 0 PROD2 DRILL PULD P Pickup. BHA. Check out hole fill, pump .5 bbls to fill hole. 38/16/2011 Sidetrack AL3 lateral 7816' at 165 LOHS TF. Drill to 7994'. Orienter failure. POOH to swap out BHA's 00:00 00:30 0.50 0 0 PROD2 STK PULD P Continue picking up BHA. 00:30 02:30 2.00 0 6,830 PROD2 STK TRIP P RIH W/ Kick off BHA # 13, open EDC Send spacer and 9.8 drilling mud down coil to time out to bit for mud swap. 02:30 03:30 1.00 6,830 6,830 PROD2 STK CIRC P Have spacer close to the bit. Pump @ .35 BPM 2000 psi CTP, 4113 BHP, 13.44 ECD. Ease rate up to 1.25 BPM. Get 9.8 all around. Page 9 of 20 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 6,830 7,816 PROD2 STK TRIP P Continue RIH, tie in for + 22.5 correction. Tag TOB @ 7816' Pick up 10'. Annular @ 4182 @ .86 BPM W/ full open choke. PUH slowly to cir out KWF out of the open hole. getting 11.0 mud over the shakers, Annular tailing off 1.29 BPM 3700 CTP, 4166 BHP. 05:00 09:30 4.50 7,816 7,821 PROD2 STK KOST P Time mill on billet 09:30 12:30 3.00 7,821 7,960 PROD2 DRILL DRLG P Drilling ahead 12:30 14:00 1.50 7,960 7,960 PROD2 DRILL WPRT P Wiper trip - 26K 14:00 14:30 0.50 7,960 7,985 PROD2 DRILL DRLG P Drilling ahead - 1.40 bpm, 4100 psi, BHP 4097, ECD 13.1, ROP 70, WOB 1.7K, CT weight 9K, differential 700psi. 7985' Having TF problems with BHA, keeps rolling to lowside on bottom. Tried locking it in on HS but still rolling. Possible magnetic interference. 14:30 15:30 1.00 7,985 7,985 PROD2 DRILL WPRT T P/U slowly to check end stops on BHA & pull above billet to stop & check Orientator comms. Tool tested fine with MWD. P/U weight check - clean. RIH to try drill again. 15:30 15:45 0.25 7,985 7,994 PROD2 DRILL DRLG P Drilling ahead - inititally no issues - 1.40 bpm, 4000 psi, BHP 4108, ECD 13.2, ROP 90, WOB 1.4K. Once differential and WOB increased the _TF started to fall to Lowside. 15:45 18:00 2.25 7,994 0 PROD2 DRILL TRIP T POOH for BHA swap. P/U weight 25K. 18:00 18:30 0.50 0 0 PROD2 DRILL SFTY T Crew change, At surface, PJSM 18:30 20:30 2.00 0 0 PROD2 DRILL PULD T Undeploy BHA 20:30 21:30 1.00 0 0 PROD2 DRILL PULD T Swap out complete BHA 21:30 23:00 1.50 0 0 PROD2 DRILL PULD T Deploy BHA 14. 23:00 00:00 1.00 72 PROD2 DRILL TRIP T RIH, taking returns to Tiger Tank to swap out mud 08/17/2011 C/O complete BHA. RIH, Swap out mud. Drill ahead AL3 lateral 7994' to 8547'. 00:00 00:30 0.50 5,000 6,720 PROD2 DRILL TRIP T RIH 00:30 00:45 0.25 6,720 6,720 PROD2 DRILL DLOG T Tie in depth +19' correction 00:45 01:06 0.35 6,720 6,850 PROD2 DRILL CIRC T Circ. new mud around 01:06 01:51 0.75 6,850 7,994 PROD2 DRILL TRIP T Close EDC RIH to drill, new to surface * * *BHI back to billable rate*"* 01:51 05:21 3.50 7,994 8,140 PROD2 DRILL DRLG P Orienter holding TF. Drill Ahead 3620 CTP, 3994 BHP, 11K CTW, 05:21 07:51 2.50 8,140 8,140 PROD2 DRILL WPRT P Wiper trip - P/U weight 27K. Town discussion on fault & formation. Page 10 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:51 12:51 5.00 8,140 8,290 PROD2 DRILL DRLG P Drilling ahead - 1.43 bpm, 3680, BHP 3995, WHP 150, ECD 12.8, ROP 55, WOB 1.8K, CT weight 9K. Hit slow ROP 8178'. Clay /shale in returns 12:51 14:36 1.75 8,290 8,290 PROD2 DRILL WPRT P Wiper trip - P/U weight 27K. 14:36 19:21 4.75 8,290 8,440 PROD2 DRILL DRLG P Drilling ahead - 1.42 bpm, 3800, BHP 4030, ROP 30, WHP 150, ECD 13, CT weight 8K. 19:21 20:51 1.50 8,440 8,440 PROD2 DRILL WPRT P Wiper trip to window, 27K PUW 20:51 21:06 0.25 8,440 8,440 PROD2 DRILL DLOG P Tie in depth to RA marker -8' correction 21:06 22:21 1.25 8,440 8,440 PROD2 DRILL WPRT P RBIH to drill 22:21 00:00 1.65 8,440 8,547 PROD2 DRILL DRLG P Drilling ahead - 1.42 bpm, 3800, BHP 4030, ROP 30, WHP 150, ECD 13, CT weight 8K. 38/18/2011 Drill AL3 Lateral. Perform mud swap. 00:00 00:45 0.75 8,547 8,590 PROD2 DRILL DRLG P Drilling ahead - 1.4 bpm, BHP 4030, WHP 150, ECD 13, CT weight 8K. 00:45 03:00 2.25 8,590 8,590 PROD2 DRILL WPRT P Wiper trip back to window, 28K PUW 03:00 04:30 1.50 8,590 8,642 PROD2 DRILL DRLG P Drilling ahead - 1.4 BPM, BHP 4058, ECD 13.07, CT weight 6 -8K. 04:30 04:51 0.35 8,642 8,642 PROD2 DRILL WPRT P Pump high vis sweep. Once out bit, PU BHA wiper slow ROP, 27K PUW 04:51 09:21 4.50 8,642 8,670 PROD2 DRILL DRLG P Drilling ahead - 1.4 BPM, BHP 4079, ECD 13.1, CT weight -5K. Weight check of 27K. ROP 5fph. 09:21 13:21 4.00 8,670 8,740 PROD2 DRILL DRLG P Pump 60 bls of extra bromide mud with total of 4% of lubes. Small change in weight transfer - P/U weight 25K - clean to bottom. Drilling ahead - 1.50 bpm, 3960, BHP 4080, ECD 13.1, ROP 15, WOB 2K, CT weight 1.1K. 13:21 15:51 2.50 8,740 8,740 PROD2 DRILL WPRT P Wiper trip - P/U weight 27K - Seen weight loss /bobbles through shale section @ 8680' - RIH to TD & wipe back through section. P/U 26K to 8600'. Very small weight bobble @ 8680' 15:51 17:30 1.65 8,740 8,790 PROD2 DRILL DRLG P Drilling ahead - 1.50 bpm, 4130, BHP 4111, ROP 15, WOB 2K, Ctweight 1K. - Set up for mud swap with 4% lubes & 2% Klaystop. 17:30 18:30 1.00 8,790 8,819 PROD2 DRILL DRLG P New mud - 1.50 bpm, 4000, BHP 4070, ECD 13, ROP 80, WOB 1.7K, CT weight 11K, WHP 80 18:30 19:00 0.50 8,819 8,819 PROD2 DRILL WPRT P PU 28K PUW, geo wiper 19:00 20:00 1.00 8,819 8,890 PROD2 DRILL DRLG P Drilling ahead - 1.50 bpm, 4000, BHP 4080, 8K CTW, 13.1 ECD, 130 WHP 20:00 22:36 2.60 8,890 8,890 PROD2 DRILL WPRT P Wiper trip to window 26K PUW 22:36 23:09 0.55 8,890 8,939 PROD2 DRILL DRLG P Drilling ahead - 1.50 bpm, 4000, BHP 4080, 8K CTW, 13.1 ECD, 130 WHP Page 11 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:09 00:00 0.85 8,939 9,010 PROD2 DRILL DRLG P PU weight check, 26K. Drill ahead - 1.50 bpm, 4000, BHP 4080, 5 -6K CTW, 13.1 ECD, 130 WHP, 08/19/2011 Drill AL3 lateral to TD 9532'. Pump low /high sweeps, POOH to swab valves. Small dimples in CT from 8600 - 8350'. 00:00 00:30 0.50 9,010 9,040 PROD2 DRILL DRLG P Drill ahead - 1.50 bpm, 4000, BHP 4080, 5 -6K CTW, 13.1 ECD, 130 WHP 00:30 03:15 2.75 9,040 9,040 PROD2 DRILL WPRT P Wiper trip to window, 26K PUW 03:15 06:00 2.75 9,040 9,190 PROD2 DRILL DRLG P Drill ahead - 1.50 bpm, 4000, BHP 4080, 5 -6K CTW, 13.1 ECD, 130 WHP 06:00 08:30 2.50 9,190 6,765 PROD2 DRILL WPRT P Wiper trip - P/U weight 26K. Pull into cased hole. 08:30 09:00 0.50 6,765 6,765 PROD2 DRILL CIRC P Pull into cased hole and repair injector counter (BHI depth control) Open EDC and circulate. Open EDC 09:00 11:00 2.00 6,765 9,190 PROD2 DRILL TRIP P RIH - tie into RA marker. -oft correction. RIH - noticed light marks on pipe from 8400' - 8600' Looks like items stuck in gripper blocks during a wiper trip. 11:00 16:00 5.00 9,190 9,355 PROD2 DRILL DRLG P Drilling ahead - 1.45 bpm, 4110, BHP 4175, ECD13.2, ROP 60 WOB, 2.2K, Ct weight 4K. 16:00 19:30 3.50 9,355 9,355 PROD2 DRILL WPRT P Pump Low /high sweep - wiper trip 27K, Tie in depth to RA marker -1' correction 19:30 21:15 1.75 9,355 9,450 PROD2 DRILL DRLG P Drilling ahead - 1.42 bpm, 3950 CTP, BHP 4113, ECD13.2, Ct weight 4 -5K. 21:15 22:45 1.50 9,450 9,488 PROD2 DRILL DRLG P Pump low high sweeps 10brls. Cont. Drilling ahead 22:45 23:15 0.50 9,488 9,488 PROD2 DRILL WPRT P Hard Stall 9488'.. PU pull heavy 35K. RBIH stacking out cannot get back to bottom. PUH to 9200'. RBIH to drill, Losing returns .25 BPM 23:15 23:45 0.50 9,488 9,532 PROD2 DRILL DRLG P Drilling ahead - 1.42 bpm, 4000 CTP, BHP 4100, ECD13.2, Ct weight 4 -5K. Losses getting better. Losing _ .10 BPM 23:45 00:00 0.25 9,532 9,532 PROD2 DRILL DRLG P Pump 10bbrls low /high sweeps. TD AL3 Lateral. POOH to swab valves - 27K PUW. 08/20/2011 Wiper trip to swab valves, RBIH lay in liner running pill (12.5ppg K- formate) with beads up to window. Completion KWF (12.5ppg K- formate) up to surface. PU/MU AL3 liner, RIH, unable to get liner past 9056'. Injector head unable to POOH. Diagnose problem. 00:00 03:45 3.75 9,532 0 PROD2 DRILL WPRT P POOH to swab valves 03:45 07:15 3.50 0 9,532 PROD2 DRILL TRIP P Tag up, Correct depth. -2.5' correction. RBIH. Started seeing 6 - 8K weight loss & light set downs from 9200' to TD @ 9532' Page 12 of 20 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07:15 08:15 1.00 9,532 8,500 PROD2 DRILL WPRT P P/U weight 28K - increase pump rate to 1.40 bpm, Wipe up 1000' to clean up lower section. Shakers cleaned up. 08:15 08:45 0.50 8,500 9,532 PROD2 DRILL WPRT P RIH - start pumping liner pill down. CT weight 10K. Slight weight bobbles near TD, cleaner than first pass. 08:45 11:45 3.00 9,532 71 PROD2 DRILL TRIP P POOH P/U weight 29K - laying in KWF liner pill followed by KWF. EOP flags 7200' & 4500'. Good KWF around at 1000' from surface. 11:45 12:15 0.50 71 71 PROD2 DRILL SFTY P PJSM for laying down BHA - flow check of well. 12:15 13:15 1.00 71 0 PROD2 DRILL PULD P Lay down BHA. Bi- center bit Different serial number than on BHI spreadsheet. 13:15 14:45 1.50 0 0 COMPZ CASING RGRP P Top up the well with 1/2 bbl. Set up rig floor, Service Top drive & injector 14:45 17:15 2.50 0 2,145 COMPZ CASING PUTB P PJSM for P/U liner. P/U 25jnts slotted, 2 solid, 38 slotted with Liner top billet. Safety joint drill. 17:15 18:00 0.75 2,145 2,145 COMPZ CASING PULD P P/U BHA 18:00 18:30 0.50 2,145 2,145 COMPZ CASING SFTY P MU safety joint. Crew Change, PJSM 18:30 19:30 1.00 2,145 2,145 COMPZ CASING PULD P MU BHA to liner and CT 19:30 20:30 1.00 2,145 6,706 COMPZ CASING RUNL P RIH 20:30 20:45 0.25 6,706 6,725 COMPZ CASING RUNL P Correct depth to EOP flag. 18' Correction. Record up and down weights. 28K up, RIH 16K. Cont. RIH. 20:45 22:30 1.75 6,725 8,782 COMPZ CASING RUNL P 50 FPM, Stack out 8782' -10K CTW, 9K WOB, PU 50K CTW, -15K WOB, RIH 35, 20 FPM. Unable to get down. PU RIH 60FPM. Stack out 8860'. PU 46K CTW, 20K WOB. Stack out 8874', PU 100'. RIH 65 FPM, Stack out 8912. PU RIH 60 -70 FPM Stack out 8923', 8943, 9010, 9038, 9044, 9050, 9056. 22:30 00:00 1.50 9,056 9,056 COMPZ CASING RUNL P Injector unable to POOH. Look into 08/21/2011 problem Repair drive shaft on injector head. Attempt to pull finer out of hole, Unsuccessful. Disconnect off liner POOH. BOL= 9049.68. TOL= 6868.17. At surface inspect injector head. Pull test to 60K. Cut 200' CT. 00:00 06:00 6.00 9,056 9,050 COMPZ CASING RUNL T Diagnose Injector problem. Continous pumping across the top with KWF to keep the hole full. Total of 5 bbls losses since 23:00 hrs. Page 13 of 20 • • Time Logs Date From To Dur S. Depth E. Death, Phase Code Subcode T Comment 06:00 07:00 1.00 9,050 9,050 COMPZ CASING RUNL T Continue troubleshooting Injector Pulling problems. The head will not hold a P/U weight of 20K or over, then the chains free -spin (release). Liner = TD 9050' Bottom of solid = 8211' Top of Solid = 8151' Top of billet = 6868' EOP = 6824' TOW = 6850 BOW = 6854 Anc Billet = 6880' 07:00 11:00 4.00 9,050 9,050 COMPZ CASING RUNL T Injector problems is the front right angle drive motor shaft is sheared. The back one is fine (this is the one that was changed out two weeks ago). 11:00 12:00 1.00 9,050 9,053 COMPZ CASING RUNL T Set to move pipe to check liner movement & test injector - Free point 29K 9048' - Max. P/U 44K ( -13K on BHA - 9045') - RIH Max push 10K WOB (9053') Liner not moving - Down max - 9053' (WOB 10K) Up CTweight 48K (WOB - 16.5K) depth 9045' Nuetral string weight depth = 9048' (WOB 0) Conference call to town. Liner not moving and max. weight on BHA. 12:00 13:00 1.00 9,053 6,720 COMPZ CASING TRIP T Decision to release liner- RIH downweight 4K. Increase pump rate to 1.2 bpm. Release the liner - P/U 27K. Tie in @ 6720' - 6ft correction. RIH & tag TOL to ensure depth. ** *Nabors back on billable time * ** 13:00 15:30 2.50 6,720 62 COMPZ CASING TRIP T TOL 6862' - 9044' BOL - POOH slowly monitoring injector. 15:30 16:00 0.50 62 62 COMPZ CASING SFTY T PJSM for laying down BHA - conduct no -flow test. 46 bbls of formate lost to formation for liner run. 16:00 17:00 1.00 0 0 COMPZ CASING PULD T Lay down BHA & close swab valves. 17:00 17:30 0.50 0 0 COMPZ CASING BOPE P Weekly function test of BOPE stack. 17:30 18:00 0.50 0 0 COMPZ CASING CTOP T Remove BHI upper quick, install pull test plate. Pull test injector to 60K 18 :00 18:30 0.50 0 0 COMPZ CASING CTOP T Set up to cut 200ft of coil. 18:30 19:30 1.00 0 0 COMPZ CASING CTOP P Cut 200' CT 19:30 20:30 1.00 0 0 COMPZ CASING CTOP P MU CT drilling head 20:30 20:45 0.25 0 0 COMPZ CASING CTOP P Pull test connector 35K 20:45 21:15 0.50 0 0 COMPZ CASING CTOP P Pressure test connector 4100psi, finish heading up drilling head. Change stripper rubber Page 14of20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T_ Comment 21:15 22:30 1.25 0 0 PROD3 STK PULD P PU /MU BHA 16 (2.4 AKO) 22:30 00:00 1.50 62 6,000 PROD3 STK TRIP P RIH 08/22/2011 PU /MU /RIH BHA 16 (2.4 AKO w/o USR). Swap well back to drilling mud. KOTB 6862'. Swap out drilling mud. Drill AU lateral build section to 7250'. POOH. Undeploy BHA 16, Deploy BHA 17 00:00 00:15 0.25 6,000 6,725 PROD3 STK TRIP P Tie in depth +13' correction 00:15 02:15 2.00 6,725 6,750 PROD3 STK DISP P Displace KWF OOH. Unable to get returns. PUH to 6625'. Spacer pill start exiting EDC. Start to get returns. RIH slowly to 6750'. Displace to FP 90 bbrls of KWF lost to formation. 02:15 02:24 0.15 6,750 6,861 PROD3 STK TRIP P Close EDC. RIH dry tag TOB 02:24 02:33 0.15 6,861 6,861 PROD3 STK KOST P Tag TOB no pumps 6861.98' PU 25K PUW 02:33 03:18 0.75 6,861 6,862 PROD3 STK KOST P Start milling 1 FPH 6861.29' 1.37 BPM in, 1.25 BPM out, 3282 CTP, 3805 BHP, 15K CTW, 1.6K WOB, 12.3 ECD, wide open choke. .10 BPM losses 03:18 04:18 1.00 6,862 6,863 PROD3 STK KOST P Start to get aluminum in cuttings 6861.89' Cont milling 1 FPH 04:18 04:33 0.25 6,863 6,894 PROD3 STK KOST P Increase ROP 2 FPH, .27K WOB, 3323 CTP, 3830 BHP, 1.36 BPM in, 1.27 out 04 :33 04:48 0.25 6,894 6,865 PROD3 STK KOST P Increase ROP 3 FPH, .52K WOB, 3323 CTP, 3830 BHP, 1.36 BPM in, 1.27 out. Blow down MP choke of aluminum. 04:48 05:03 0.25 6,865 6,866 PROD3 STK KOST P Increase ROP 5 FPH, .80K WOB, 3378 CTP, 3834 BHP, 1.35in, 1.30 out. 05:03 05:24 0.35 6,866 6,869 PROD3 STK KOST P Increase to 10 FPH. Stack 2.5K WOB, No motor work. Shut down pumps, trap pressure, PU 26K PUW. RIH dry tag at 6865.5'. PU 26K, online with pumps. RIH. start to see WOB w/o motor work 6865.3'. 05:24 07:54 2.50 6,869 6,736 PROD3 STK KOST P P/U into cased hole and open EDC - dispace vac truck to swap mud. Discuss with town plan forward. Vac truck arrived on location 07:54 08:54 1.00 6,736 6,869 PROD3 STK KOST P Start pumping new mud -new mud at bit. trap pressure & close EDC. RIH to TOW min. rate. Offline until 6858' 6857' - WOB 1.4K TF 210 ROHS 6858 - WOB .6K TF 280 ROHS - bring pumps up to min. rate 6859' - increase pump rate to 1.35 bpm, WOB zero. RIH Slowly (50fph) 6866' WOB 1.2K No motor work, WOB dropped off to zero 6866.5' 6869.3' motor work - Start milling at 10 fph. Page 15 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:54 09:54 1.00 6,869 6,898 PROD3 STK KOST P Milling 10 fph, 1.35 bpm, 3460, BHP 3860, ECD 12.6, WHP 160, CT weight 15K, WOB 1.5K - Good formation cuttings to surface - no Al. shavings. KOTB - drill additional 20 ft. 09:54 10:24 0.50 6,898 6,898 PROD3 STK KOST P P/U weight 23K. WOB -0.6K off bottom. into cased hole. Slow to min. rate @ 6870' WOB -0.6K Slight weight drags © 6867', 6864'( geometry binding) Slight increase in pressure © 6856' Clean up to 6830' - RIH pumps off @ 10 fpm. - SLight weight bobbles near window exit. 10:24 15:54 5.50 6,898 7,160 PROD3 DRILL DRLG P Drilling ahead -1.40 bpm, 3530, BHP 3930, ECD 12.6, WHP 130, WOB 1.8K, ROP 20, Ct weight 15K. A few difficult TF reactions when first drilling but smoothed out after 20 ft. 15:54 16:24 0.50 7,160 7,160 PROD3 DRILL WPRT P Wiper trip - P/U weigth 28K- Clean up to billet. RIH. 16:24 17:54 1.50 7,160 7,250 PROD3 DRILL DRLG P Drilling ahead - 1.40 bpm, 3540, BHP 3930, ECD 12.6, ROP 70, WOB 1.6K, Ct weight 14K. 17:54 20:09 2.25 7,250 7,250 PROD3 DRILL TRIP P TD build. POOH 20:09 20:24 0.25 7,250 0 PROD3 DRILL SFTY P At surface. PJSM 20:24 21:39 1.25 0 0 PROD3 DRILL PULD P Undeploy BHA. Tag up pulling BHA above swabs with high AKO bend. (2.4 AKO). Close bag to centralize BHA. Open bag, PUH with SL slowly, until BHA is above swabs. 21:39 23:39 2.00 0 0 PROD3 DRILL PULD P MU new BHA, (USR, 1 deg AKO w/ B7 Bi- center) 23:39 00:00 0.35 0 0 PROD3 DRILL PULD P Deploy BHA 17 08/23/2011 Drilled AL1 lateral to TD at 7710' 00:00 01:30 1.50 72 6,725 PROD3 DRILL TRIP P RIH 01:30 01:45 0.25 6,725 6,725 PROD3 DRILL DLOG P Tie in depth to K1. +12' correction 01:45 02:30 0.75 6,725 7,250 PROD3 DRILL TRIP P RIH to drill, small weight bobble going through window due to TF orientation of window vs. TOB KO. Cont. RIH log RA markers to assure which to use on wuiper trip tie in. Did see the RA marker in # 1 billet. Formation marker for tie in 6813' picked up. Cont. RIH 02:30 04:30 2.00 7,250 7,410 PROD3 DRILL DRLG P Drill Ahead 1.4 in, 13K CTW, 3517 CTP, 3912 BHP, 12.5 ECD. 04:30 05:30 1.00 7,410 7,410 PROD3 DRILL WPRT P Wiper trip - P/U 26K. MADD pass _ 7260- 6940'. 05:30 08:00 2.50 7,410 7,560 PROD3 DRILL DRLG P Drilling ahead -1.40 bpm, 3870, BHP4000, ECD 12.8, ROP 60, WON 1.8K, Ct weight 14K. Page 16 of 20 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:15 2.25 7,560 7,560 PROD3 DRILL WPRT P Wiper trip - P/U weight 27K. 10:15 11:15 1.00 7,560 7,710 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM, 3835 CTP, 4000BHP, 11-12K CTW, 12.8 ECD. wide open choke 11:15 12:45 1.50 7,710 6,750 PROD3 DRILL WPRT P TD lateral PU 100' 26K. RBIH pumping low /high 10/10 out CT, Chase pills to window. 12:45 13:00 0.25 6,750 6,750 PROD3 DRILL DLOG P PU into casing. Tie in depth to K1 marker -2'. Talk with town on next operation. 13:00 15:00 2.00 6,750 0 PROD3 DRILL WPRT P POOH to swab valves 15:00 18:00 3.00 0 7,710 PROD3 DRILL WPRT P RBIH, no increase amount of cuttings at surface. Cuttings continued over shakers while RIH down to window. 18;00 20:42 2.70 7,710 0 PROD3 DRILL WPRT P POOH laying in liner pill and KWF, paint EOP flags at 7200 and 6300' 20:42 21:12 0.50 0 0 PROD3 DRILL SFTY P PJSM, check for no -flow 21:12 22:06 0.90 0 0 PROD3 DRILL PULD P Lay down drilling BHA 22:06 00:00 1.90 0 COMPZ CASING PUTB P PU liner string with anchored aluminum billet 08/24/2011 Ran liner in AL1 lateral and set anchored liner top billet at 7350'. Drilled off billet and continued drilling AL2 lateral. 00:00 01:48 1.80 421 6,721 COMPZ CASING RUNL P RIH with liner 01:48 02:30 0.70 6,721 7,710 COMPZ CASING RUNL P Correct to flag, +13', 27K PUW, 18 K RIW, close EDC and continue RIH 02:30 04:30 2.00 7,710 0 COMPZ CASING RUNL P Set anchor at 340 deg orientation, 3900 psi to set. Liner top at 7350'. _ POOH 04:30 04:48 0.30 0 COMPZ CASING SFTY P PJSM, check for no -flow 04:48 05:48 1.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA 05:48 06:18 0.50 0 . 0 PROD4 STK SFTY P Crew change, PJSM 06:18 06:48 0.50 0 0 PROD4 STK PULD P PUMU BHA 19 (.8 AKO 12deg DLS). 06:48 08:48 2.00 72 6,730 PROD4 STK TRIP P RIH 08:48 09:03 0.25 6,730 6,743 PROD4 STK DLOG P Tie in depth +13' correction 09:03 10:33 1.50 6,743 6,743 PROD4 STK DISP P Circulate well to Flo -Pro 10:33 10:48 0.25 6,743 7,349 PROD4 STK TRIP P New mud to surface, RIH to ST AL2 Lateral 10:48 11:33 0.75 7,349 7,349 PROD4 STK TRIP P Dry tag TOB 7349.81'. PU 26K 11:33 13:18 1.75 7,349 7,351 PROD4 STK KOST P ST AL2 Lateral setting auto driller to .5 FPH increasing to 1 FPH 3300 CTP, 120 MP choke, 16K CTW, 1.3 in, 1.3 out Large amount of aluminum across shakers 13:18 13:48 0.50 7,351 7,352 PROD4 STK KOST P Increase ROP 2 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. Page 17 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:48 14:18 0.50 7,352 7,353 PROD4 STK KOST P Increase ROP to 3 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. 14:18 14:45 0.45 7,353 7,358 PROD4 STK KOST P Increase ROP 10 FPH 3350 CTP, 150 MP choke, 15K CTW, 1.4 BPM in, 1.4 BPM out. 14:45 15:15 0.50 7,358 7,375 PROD4 STK KOST P Increase ROP to 25 FPH 15:15 15:24 0.15 7,375 7,385 PROD4 STK KOST P Increase ROP to Drilling rate 15:24 15:36 0.20 7,385 7,385 PROD4 STK KOST P PU drift ST. 24K PUW. Drift looks good. RIH to drill 15:36 18:06 2.50 7,385 7,510 PROD4 DRILL DRLG P Drill Ahead 14K CTW, 3384 CTP, _ 125 MP choke, 12.6 ECD, 1.4 BPM. 18:06 18:48 0.70 7,510 7,510 PROD4 DRILL WPRT P Wiper to the window, 24K PUW, 14K RIW 18:48 20:36 1.80 7,510 7,660 PROD4 DRILL DRLG P Continue drilling, 1.4 BPM, 3350 CTP, 3965 BHP, 150 WHP. Increase rate to 1.6 BPM, 3800 CTP, 3950 BHP, 100 WHP 20:36 21:30 0.90 7,660 7,660 PROD4 DRILL WPRT P Wiper to the window, 24K PUW, 14K RIW 21:30 22:54 1.40 7,660 7,810 PROD4 DRILL DRLG P Continue drilling, 1.6 BPM, 3770 CTP, 3970 BHP, 100 WHP 22:54 23:36 0.70 7,810 6,930 PROD4 DRILL WPRT P Wiper to the window, 24K PUW 23:36 23:42 0.10 6,930 6,950 PROD4 DRILL DLOG P Tie -in, -1' 23:42 00:00 0.30 6,950 7,810 PROD4 DRILL WPRT P Wiper back in hole, 15K RIW 38/25/2011 Drilled to TD at 8454' and killed well with 12.5 PPG KWF 00:00 01:48 1.80 7,810 7,960 PROD4 DRILL DRLG P Continue drilling AL2 lateral, 1.6 BPM, 3800 CTP, 4000 BHP, 80 WHP 01:48 03:00 1.20 7,960 7,960 PROD4 DRILL WPRT P Wiper to the window, 25K PUW 03:00 05:45 2.75 7,960 8,140 PROD4 DRILL DRLG P Continue drilling, 1.6 BPM, 3800 CTP, 4000 BHP, WOC 05:45 07:15 1.50 8,140 8,140 PROD4 DRILL WPRT P Wiper trip to window 26K PUW 07:15 09:30 2.25 8,140 8,290 PROD4 DRILL DRLG P Cont. Drilling 11K CTW, 1.5K WOB, 3771 CTP, 4022 BHP 09:30 11:15 1,75 8,290 8,290 PROD4 DRILL WPRT P Wiper trip to window, 26K PUW 11:15 14:00 2.75 8,290 8,410 PROD4 DRILL DRLG P Cont. Drilling 11K CTW, 1.5K WOB, 3771 CTP, 4022 BHP 14:00 14:15 0.25 8,410 8,455 PROD4 DRILL DRLG P Pump low /high sweeps 14:15 17:15 3.00 8,455 0 • PROD4 DRILL WPRT P TD AL2 lateral. POOH to swab valves _ chasing sweeps 17:15 20:30 3.25 0 8,454 PROD4 DRILL WPRT P RBIH 20:30 23:00 2.50 8,454 0 • PROD4 DRILL DISP P Lay in liner pill and KWF 23:00 23:42 0.70 0 0 • PROD4 DRILL PULD P Lay down drilling BHA 23:42 00:00 0.30 0 0 PROD4 DRILL SFTY P PJSM, check for no -flow 08/26/2011 Ran liner in AL2. Liner top at surface ? ?? 00:00 00:18 0.30 ' 0 0 COMPZ CASING'SFTY P PJSM for liner operations Page 18 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:18 02:30 2.20 0 1,183 COMPZ CASING PUTB P Rig up for liner operations and PU 34 joints slotted liner 02:30 04:42 2.20 1,183 8,458 COMPZ CASING RUNL P RIH, correct depth at flag, 6767.4 to 6782.91, 15.5' correction. 28K PUW, 16K RIW, -3.7 WOB. Tag' bottom, pump at 1.2 BPM, 4000 CTP, release liner. 04:42 07:12 2.50 8,458 0 COMPZ CASING RUNL P POOH 07:12 08:57 1.75 0 0 COMPZ CASING PUTB P Flow check, PJSM, LD BHA 08:57 10:57 2.00 0 0 COMPZ CASING PUTB P PJSM, RU for liner Ops. PU 14jnts slotted, 4 joints solid, with Baker Seal Bore Assembly. 10:57 12:57 2.00 658 6,800 COMPZ CASING RUNL P RIH 12:57 13:12 0.25 6,800 7,315 COMPZ CASING RUNL P Tie in depth to EOP flag. +12.6' correction. 28.5K PUW. RIH, 2nd EOP flag, no correction. 13:12 13:57 0.75 0 6,688 COMPZ CASING RUNL P Tag TOL # 1, Pump off liner 3500psi , 29K PUW. 0 WOB. Open EDC, remove liner length from bit depth. TOL =7315 13:57 15:42 1.75 6,688 6,688 COMPZ CASING DISP P Circulate well to Seawater 15:42 17:54 2.20 6,688 0 COMPZ CASING RUNL P POOH, freeze protect well 2100' MD to surface 17:54 18:30 0.60 0 0 COMPZ CASING SFTY P PJSM for undeploy BHA, Crew change 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P Undeploy BHA, 1400 WHP 19:12 23:30 4.30 0 0 COMPZ CASING PUTB T Slick line parted when opening deployment rams, (After further investigation it was determined that the liner string was still attached) toolstring dropped to no -go. Changed out PDL. Unable to move BHA, while working slickline on second PDL line parted again. Attempted to close SSSV which did not work 23:30 00:00 0.50 0 0 COMPZ CASING PUTB T Load pits to kill well 08/27/2011 Ran liner, displace well to seawater and diesel freeze protect 00:00 01:30 1.50 0 0 COMPZ CASING CIRC T Bullhead 12.5 ppg KWF, 100 Bbls. Well is dead. 01:30 01:42 0.20 0 0 COMPZ CASING SFTY T PJSM 01:42 04:18 2.60 0 658 COMPZ CASING PUTB T Remove PDL, PU BHA, liner sting is still there... Call out for another GS from BOT The nose of the GS was getting wedged inside the seal bore on the deployment sleeve. Ground down the nse to allow clearence inside sealbore 04:18 04:36 0.30 658 658 COMPZ CASING SFTY T PJSM 04:36 05:06 0.50 658 658 COMPZ CASING PUTB T PU liner running BHA. i Page 19of20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:06 05:36 0.50 658 658 COMPZ CASING CIRC T Circulate coil to KWF 05:36 07:36 2.00 658 6,758 COMPZ CASING RUNL T RIH 07:36 07:51 0.25 6,758 6,759 COMPZ CASING RUNL T Tie in depth to EOP flag. +11' correction.Close EDC, Weight check.28K PUW. DHWOB -3.7K, change DHWOB to -2.34K weight of liner. RIH 18K RIHW, -1.6K DHWOB while RIH 07:51 08:03 0.20 6,759 7,315 COMPZ CASING RUNL T RIH to TOL # 1, in open hole, 0 K DHWOB, 16K CTW 08:03 08:09 0.10 7,315 7,315 COMPZ CASING RUNL T Tag TOL # 1 @ 7315.69'. 16K CTW, 2.2K DHWOB. 08:09 08:24 0.25 7,315 6,700 COMPZ CASING RUNL T Release off liner, 4300 CTP, 28K PUW. DHWOB 0. PU 50', 28K PUW, DHWOB 0. RIH, RIHW 18K, OK DHWOB. Liner released. Open EDC. Circ. across top to minimize losses. 08:24 09:24 1.00 6,700 2,200 COMPZ CASING RUNL T POOH 09:24 09:39 0.25 2,200 2,200 COMPZ CASING OWFF T Stop flow check well 09:39 10:39 1.00 2,200 0 COMPZ CASING RUNL T Cont. POOH 10:39 10:54 0.25 0 0 COMPZ CASING OWFF T At surface, flow check. PJSM, 10:54 11:24 0.50 0 0 COMPZ CASING PULD T LD BHA, Liner gone 11:24 11:54 0.50 0 0 COMPZ CASING PULD T PU BHA 23, Nozzle run 11:54 13:54 2.00 22 6,600 COMPZ CASING TRIP T RIH 13:54 14:54 1.00 6,600 2,150 COMPZ CASING TRIP T POOH displacing well to seawater 14:54 15:24 0.50 2,150 2,150 COMPZ CASING TRIP T Wait on LRS for freeze protect 15:24 15:54 0.50 2,150 2,150 COMPZ CASING FRZP T RU LRS 15:54 16:24 0.50 2,150 0 COMPZ CASING FRZP T POOH 16:24 16:39 0.25 0 0 COMPZ CASING SFTY T At Surface. PJSM 16:39 18:00 1.35 0 0 COMPZ CASING PULD T LD Tools, 18:00 18:24 0.40 0 0 DEMOB WHDBO SFTY P PJSM, crew change out 18:24 23:12 4.80 0 0 DEMOB WHDBO NUND P RU and set BPV. After rooling the seal three times, went for a different plg and got a good set. 23:12 00:00 0.80 0 DEMOB WHDBO CIRC P Circulate corrosion inhibitor through coil and surface equipment 08/28/2011 Circulate corrosion inhibitor in coiled tubing and rig down for move, rig released at 06:00 00:00 01:24 1.40 DEMOB WHDBO CIRC P Continue circulating corrosion inhibitor through coiled tubing and surface equipment 01:24 02:54 1.50 DEMOB WHDBO DMOB P Blow down coiled tubing and rig 02:54 04:24 1.50 DEMOB WHDBO DMOB P Unstab CT from injector for injector maintenance. 04:24 06:00 1.60 DEMOB WHDBO DMOB P RDMO, Rig Released at 0600 Page 20 of 20 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 3H -12 Run Date: 6/6/2011 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 3H -12 Digital Data in LAS format, Digital Log Image file -M 1 CD Rom 50- 103 - 20088 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood d f t- K S E P 1 2. 20 .∎ 1 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: I) 14- t Signed: iLS Olvtj 18 7 -J.11 • • WELL LOG TRANSMITTAL PROACTIVE DIAC is SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue r t > �:. Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 14-Jul-11 3H -12 1 CD ✓ 50 -103- 20088 -00 2) 4lc-(790 Signed : `�r- �'`�"'" Date Print Name: K-0 w (70r 4 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E - MAIL : PDSANCHORAGE( MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D: \Archives\ Distribution\ TransmittalSheets \ConocoPhiltips_Transmit.docx l87 -/2 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: 3H -12 Run Date: 7/5/2011 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 311 -12 Digital Data in LAS format, Digital Log Image file I ut es-8 1 CD Rom " 50- 103 - 20088 -00 UAL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com �,) t Date: .) 1 Signed: I8.-l STATE OF ALASKA ALASKA•AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell E Plug Perforations r Stimulate r Other r Alter Casing r Pull Tubing 17 Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r • 187 - 129 3. Address: 6. API Number: Stratigraphic r Service E P. O. Box 100360, Anchorage, Alaska 99510 b 50 - 20088 - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25531 * , 3H - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7298 feet Plugs (measured) None true vertical 6373 feet Junk (measured) 7030', 7032', 7036' Effective Depth measured 7144 feet Packer (measured) 6684 true vertical 6249 feet (true vertucal) 5878 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3069 9.625" 3104 2986 t,411;1 €,tt' PRODUCTION 7190 7" 7225 6314 t ,��V t& AUG 1 6 1 �i01SSt ietrr;; J Perforation depth: Measured depth: 6832'- 6846', 6880'- 6890', 6904'- 6914', 6934' -6954' (3 3' ', °,,,, * True Vertical Depth: 5998'- 6009', 6037'- 6045', 6056'- 6064', 6080' -6096' Tubing (size, grade, MD, and TVD) 3.5, L -80, 6682 MD, 5876 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 3 1/2" X 7" FHL PKR @ 6684 MD and 5878 TVD SAFETY VLV - CAMCO TRMAXX CMT - SR - 5 @ 1804 MD and 1804 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 3 160 951 -- 173 Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p' • Service E Stratigraphic r 15. Well Status after work: Oil 1'7 r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG f 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 -191 k.o Contact Ian Toomey 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature -- Phone: 263 -4773 Date ! l 7 / it BEMs JUl 1 .. �, 4 Si.ro.it Form 10 -404 Revised 10/2010 ✓ Submit Original Only . • KUP • 3H -12 . f ConocoPhillip5 > well Attr Max Angle & MD TD Fi " ° Wel!bore APUUWI Feld Name Well Status !note') MD (ftKB) AA Btm (ftKB) Lv:xxev6n4sr , " 501032008800 KUPARUK RIVER UNIT PROD 37 28 4,400.00 7,298.0 H2S L SSSV: TRDP 6,93 0 7 /471999 ( Rev Rea son W La t t End Date KB-Grd (ft) Rig Release Date (ppm) Last WO: O: 42 01 1/4/1988 Comment -_. _ .-,._ - 9 L - i n S2..3H:a..1, X34.. - 5k` - ,.. 1 - . �- __ _ _ - _ _ _ $,5tl�r� �Annotetion Depth ( ( HKB) End Date Ann!Annotation "Last Mod ... End Dale _ g 1 11 ORKOVER ,.. L ninam 6/20/2011 - _ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String WI -.. String .. String Top Thrd HANGER. 35 ■ , CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 1 WELDED Casing Description String 0... String ID ... Top (ftKB) SN Depth (T... Sat Depth (TVD ... String Wt... String ... String Top Thrd SURFACE 95/8 8 35 3 2 36 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (T... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.0 7,224.9 6,314.4 26.00 J - 55 BTC CONDUCTOR, 36-115 Tubing Strings Tubing Description String 0... String ID ...1TOp (ftKB) (Set Depth (f. (Sat Depth (TVD) . (String Wt... Siring String Top Thrd lit TUBING WO 3 12 2.992 35 0 6,681 9 5,876 4 9.30 L60 EUE 8Rd Mod SAFETY VLV, _ Completion Details _ .. 1,804 Top Depth (ND) Top Incl Nomi... 11 Top (ftKB) (ftKB) (") Item Description Comment ID (in) l _ 35.0 35.0 -0.06 HANGER MCEVOY MS/DP TUBING HANGER 2.876 _ 1,804.1 1,804.1 -2.73 SAFETY VLV CAMCO TRMAXX- CMT -SR -5 2.813" X- PROFILE SN #CZS-0415 2.812 GAS LIFT, ' 6,619.6 5,826.3 36.30 NIPPLE 3 12" X 2.812" X NIPPLE 2.812 2,564 .. 6,669.9 5,866.7 36.22 SEAL ASSY BAKER 8040 GBH -22 LTSA SEAL ASSEMBLY W/ 3' SPACE OUT 3.000 Tufting Description String 0... String ID.. ( Top (HKB) ( Set Depth (f 1506 DepM (TVD).. String Wt... SString ... String Top Thrd TUBING Original 3 1/2 2.992 6,670.7 6,756.6 5,936 8 9.30 J-55 EUE8rdABMOD Completion Details Top Depth (NO) Top Incl NamL.- SURFACE, _ __ -_ . , ." TopjftK6) (tee) (% Hem Daseri , e,,,. •n Comment ID m) 35 - 3,164 6,670.7 5,867.4 36.22 PBR Baker 312 "PBR -_- 3.000 6,684.4 5,878.4 36.20 PACKER BAKER 3 1/2" x 7" FHL PKR (75000# pull or rot. rel) 3.000 GAS LIFT, ' 6,723.2 5,909.8 36.14 NIPPLE CAMCO 312" 'D' Nipple 2 75" ID 2.750 4,087 6,755.7 5,936.0 36 09 SOS ROT 3 1/2" Shear Out Sub 2.992 Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! GAS LIFT, _ Top (TNKS) (ftKB) C) Description Comment Run Date ID(in) 5.211 - 7,030 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/20/1999 downhole. 7,032 6,159.2 3647 FISH 5 GRAPPLES -1" X 2" 5/11/1995 7,036 6,1625 36.47 FISH Bailer Left in Hole 9/6/1988 GAS LIFT, 6,026 Perforations & Slots _.. __ -. - ---------- -- - --- -- ---- - - -- - -- - ---_ -- " -- Shot Top (ND) Btm (TVD) Oena Top (HKB) Bbn (MB) (HKB) (ftKB) Zone Date (sh_. Type Comment 6,832 6,846 5,997.7 6,009.0 C-4, 31-1-12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph GAS LIFT, _ __ 6,880 6,890 6,036.5 6,044.6 A-3, 3H-12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph . - - -- 6 6,904 6,914 6,055.6 6,063.8 A -2, 3H-12 9/21/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,934 6,954 6,080.0 6,096.2 A -1, 3H -12 5/14/1988 4.0 IPERF 4 12" UltraPak, 120 deg. pH: 3 shots misfired Notes General & Safety NIPPLE, 6,620 it End Date - -_� Annotation -- - 10/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 tr --9 SEAL ASSY, 6,671 _ PBR, 6,871 - - -- kffy PACKER, 8,684 NIPPLE, 6,723 - - -- ' * SOS, 6,756 IPERF, - 8,632- 6,646 I IPERF, - . 6,880-6,890 IPERF,_ 6,904 -6,914 Mandrel Details 1PERF, - Top Depth Top Port 6.934-6.954 (TVD) Incl OD Valve Latch Size TRO Run Stn Top (1KB) (HKB( (°) Make Model (in) Sery Type Type (in) ( Run Date Con.._ 1 2,584.1 2,553 5 28 44 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 FISH, 7,030 -- - t 1:6 2 4,087.3 3,791.4 34.71 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/172011 '" 3 5,210.8 4,693.2 36.92 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 FISH, 7,032 - - -- _ - - - 4 _ _ 4 6,026.4 5,347.6 36.42 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/172011 5 6,559.2 5,777.3 36.09 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 6/172011 FISH,7,036 -- -.. t PRODUCTION, 1 ` 35- 7,225 TD. 7,298 3H -12 Well Events Summary DATE SUMMARY '4/21/11' PRE RWO T -POT ( PASSED ), T -PPOT ( PASSED ), IC -POT ( PASSED ), IC -P T ( FAILED ). FT -LDS GN SEIZED TO LDS @ 6:30 / 4:30. 5/4/11 MITOA- PASSED 5/30/11 PULLED SLIP STOP AND SPACER PIPE FROM DAP TOOL FISH @ 1803' RKB. CONFIRMED MINIMUM ID OF SPACER PIPE @ 1.48 ". GAUGED DAP TOOL FISH WITH 2.11" CENT. APPARENT FISH MINIMUM ID: 2.17 ". IN PROGRESS. 5/31/11 SET 21' 3" SPACER PIPE ON TOP OF DAP TOOL @ 1803' RKB, TAG BTM @ 6868' SLM, MEASURED SBHPS @ 6818' SLM =3205 psi.. JOB COMPLETE 6/4/11 PULL 21' 3" SPACER PIPE ASSEMBLY FROM 1803' RKB. JOB SUSPENDED UNTIL PIPE CAN BE MACHINED. 6/6/11 SET 20' 3" SPACER PIPE ASSY (DRIFT W/ 1.60" SWAGE) THRU FRAC SLEEVE IN SSSV @ 1803' READY FOR E -LINE. 6/6/11 PUNCH TUBING AT 6617' TO 6624' RKB WITH , 1 -3/8" X 5', 4 SPF, 11 GRAM IN THE FIRST FULL JOINT ABOVE GAS LIFT MANDRAL AT 6632'. SAW 500 PSI DECREASE IN TUBING PRESSURE. 7/2/11 ASSIST VLV CREW W/ PULLING BPV, REPLACE SOV @ 6559' RKB W/ DV, PERFORM PASSING MIT IA TO 2500 PSI, PULL CATCHER @ 6703' SLM. IN PROGRESS. 7/3/11 BAIL MUD OFF CA -2 PLUG @ 6723' RKB, PULL PRONG FROM PLUG, ATTEMPT TO PULL PLUG BODY. IN PROGRESS 7/4/11 PULL 2.75" CA -2 PLUG BODY @ 6723' RKB, TAG © 6895' SLM, MEASURE BHP © 6900' RKB, y2.""' GRADIENT @ 6780' RKB. READY FOR E -LINE. 7/5/11 SHOT 2" HSC LOADED WITH 5' OF JRC BH 6.7g CHARGES 6 SPF 60 DEG PHASE. TOP SHOT @ 6705'. SHOT INTERVAL 6705'- 6710'. LOGGED TUBING JEWELRY TO 200'. LRS FOLLOW UP INJECTION TEST: PUMPED 140 BBL DIESEL DOWN TUBING AT 1.5 BPM @ 2500 PSI. ConocoPhiilips Time Log & Summary Wel;view Web Reporting Report Well Name: 3H - 12 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/11/2011 5:00:00 AM Rig Release: 6/18/2011 7:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/10/2011 24 hr Summary Released Rig from 2A -15. Begin moving Rig to 3H -Pad. 03:00 00:00 21.00 MIRU MOVE MOB P Begin moving Rig from 2A -Pad to 3H -Pad. (Prep 3H -12 Well Slot for Rig). Stop Rig move as needed to check tires and for crew change -outs. 06/11/2011 Complete Rig move to 3H -Pad. Rig up at 3H -12 Well Slot. Load Pits with 10.7 lb /gal Brine. Rig -up Flow back Tank and Lines. Attempt to kill Well with 10.7 Ibbal Brine. 00:00 03:30 3.50 MIRU MOVE MOB P Continue to move Rig to 3H -Pad. 03:30 05:00 1.50 MIRU MOVE RURD P Rig at 3H -12 Well Slot. Hang Tree in Cellar. Spot Rig over Well and level up. 05:00 05:00 0.00 MIRU RPCOM RURD P Accept rig at 05:00 hrs, 06/11/2011. 05:00 11:30 6.50 MIRU RPCOM RURD P Exchange phone numbers with the pioneer operations folks. Ru lines to tree to prep for well kill. Get rig equip set up. Move camp @ 0900 from 2A -pad to 3H -pad. 11:30 15:30 4.00 MIRU RPCOM RURD P Camp on location. Get comm's hooked up. Still waiting on the kill tank. 15:30 17:00 1.50 MIRU RPCOM RURD P Kill tank on location. Spot tank, RU hardline and PT lines to 4000#. Bleed OA from 200 psi to 0. 17:00 18:00 1.00 MIRU RPEQP1RURD P PJSM. Pick -up Lubricator. Pull Lay down same. 18:00 19:00 1.00 COMPZ RPEQPI RURD P PJSM. Pressure test circulating lines to 4,000 psi. Page 1 of 7 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:30 3.50 COMPZ WELCTL KLWL P PJSM. Discuss Well Kill Operations. Record Tubing Pressure = 890 psi. Casing Pressure = 1,620 psi. Line up the IA thought Choke and bleed gas pressure down to 650 psi. Open up the Tubing and bring pump on line at 2.0 bpm /900 psi. Start 10.7 lb /gal down Tubing. Increase rate to 3.0 bpm taking return through Choke to Flowback Tank. Pumped 100 bbls (tbg volume = 58 bbls). Shut in Choke and bullhead 20 bbls at 850 psi to clear casing volume below circulation holes in the Tubing. Open choke and continue to attempt to bring 10.7 lb /gal KWB back to surface. However, fluid returns remain "milky" at 10.3 - 10.5 lb /gal. Pumped a total of 350 bbls (90 bbls over calculated one time circulation volume). Shut in Well and monitor SITP at 190 psi. 22:30 00:00 1.50 COMPZ WELCTL KLWL P Discuss results and a plan forward with Anchorage Engineer. Order out the needed Vac Trucks and 11.7 lb /gal Drilling Mud from MI Mud Plant. Haul away returns from Flowback Tank. Haul away remaining 10.7 lb /gal Brine in Rig Pits to Tank Farm. 06/12/2011 Wait on 11.7 lb /gal Drilling Mud. Displace the 10.7 lb /gal Brine with 11.7 lb /gal Drilling Mud. Attempt to Kill Well with the 11.7 Ib /qal Mud. ,Well remains slightly un- stable. 00:00 07:00 7.00 COMPZ WELCTL KLWL T Continue to monitor stable SITP at 190 psi (Tubing filled with clean 10.7 lb /gal Brine). Casing pressure = 200 psi. Wait on Drilling Mud to arrive on Location from Mud Plant. Receive one load (200 bbls) of 11.7 Drilling Mud. Off load in Rig Pits. Continue to wait on second load to arrive on Location. 07:00 13:30 6.50 COMPZ WELCTL KLWL T Truck that was hauling second load of fluid broke down on the way back over for 3 hours. The second truck is back over in Prudhoe getting a second load. Page 2 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 18:00 4.50 COMPZ WELCTI KLWL P Fluids on location. load up in the pits. SITP 230 psi . IA = 220 psi. Begin pumping kill, pump 40 bbls spacer pill, followed by 11.7 ppg drilling mud, 3 BPM holding 200 psi on choke, 350 psi pump pressure taking returns to kill tank. Pump 100 bbls of mud, shut in Choke & bull head 20 bbls into the formation. Open choke, maintain 100 psi back pressure, continue pumping 11.7 mud. @ 300 bbls of mud away see spacer at surface, cleaned up to mud in 5 bbls. Start taking samples, 11.4 @ 360 bbls. Shut down @ 360 bbls swap to taking returns to pits, thru the gas buster @ 1 BPM @ 160 psi, holding 10 psi back pressure. Shut down @ 385 bbls, last sample @ 11.5 ppg. SITP: 10 psi, 0 psi on the IA. Monitor well during change out. 18:00 00:00 6.00 COMPZ WELCTI KLWL T Continue to monitor Well. Observe sight flow and breathing. Decission to bump Mud Weight up to 12.0 lbs. Weight up the 200 bbls of Drill Mud in Pits. Order additional 12.0 lb /gal from Mud Plant. 36/13/2011 Well remains un- stable. Decision made to bump Mud weight up to 12.0 lb /gal. KIII Well with 12.0 lb /gal prillin• Mud. Set BPV. ND Tree. Install Blanking Plug. NU BOP Stack. Test BOPE. 00:00 03:00 3.00 COMPZ WELCTL KLWL T Continue to wait on additional Drilling Mud to arrive on Location. 03:00 06:00 3.00 COMPZ WELCTL KLWL P Drilling Mud arrives on Location. Start 12.0 lb /gal Drilling Mud down the Tubing at 2.0 bpm. Increase rate to 4.0 bpm /810 psi. Mud returns = 11.5 lb /gal (MW pumped on second Well Kill attempt = 11.7 lb /gal). Pumped hole volume at 233 bbls, returns = 11.7 lb /gal. Continue to circulate well. Return now at 11.8 lb /gal. after 100 bbls over hole volume. Shut in Well & monitor. 06:00 10:00 4.00 COMPZ WELCTL NUND P Open up; TBG & IA are on a slight vac. Rig down pump line from tree. Check again, still no flow. PJSM; Set ..L "HP" BPV. Pump 5 bbls down IA while monitoring TBG, no flow. PJSM; ND tree. Cap Control line, C/O the 2 damaged LDS. 10:00 13:30 3.50 COMPZ WELCTL NUND P Cameron rep set prong on BPV, now plug holds from both directions. NU BOP. Check IA, still on vac. (Cameron Wellhead Rep replaced two Lock -Down Screws. All LDS are now in working order). Page3 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 21:00 7.50 COMPZ WELLPF BOPE P PJSM. Begin BOPE test 250/4000. 250/3500 annular. Found leak in the QDe Blind Ram (Seal Bore Element). [� • Change out Seal Bore Element. �Et> (Load, drift, and tally 3 1/2" Completion while BOP repairs were in progress). 21:00 00:00 3.00 COMPZ WELCTL BOPE P _ Shell test BOP re ap irs Resume BOPE Test per Conoco /Phillips and AOGCC requirements at 250/4,000 psi. Upper Ram Door Seal Failure at 4,000 psi. 06/14/2011 Complete BOPE Test. Pull Blanking Plug and BPV. Pull Tubing Hanger to Floor. Circulate and Condition Well with 12.0 lb /gal Drilling Mud. Pull TBG stands to the SSSV while spooling Control Line. Recovered 31 control line bands, Dap tool fish & SSSV hold open sleeve. TIH W/ TBG to just above PBR. Circulate well to 10.7 Brine. 00:00 03:30 3.50 COMPZ WELCTL BOPE P Replace Upper Ram Door Seal. Resume BOPE Test at 250/4,000 psi. Continue with BOPE Test with no further failures. Perform Koomey drawdown test. The State's right to witness the test was waived by M. Herrera. Rig down test equipment. 03:30 04:30 1.00 COMPZ WELCTL BOPE P PJSM. Pull Blanking Plug /BPV. Pick -up 3 1/2" Landing Pup Joints. Screw into Top Drive. BOLDS. Unseat Tubing Hanger at 50K. Pull Seal Assembly free from the PBR at 115K. Pull Tubing Hanger to the floor at 94K with normal drag. 04:30 08:30 4.00 COMPZ WELCTL CIRC P Pump 12 bbls to catch returns. Static Fluid Level — 300 -ft. Circulate and condition Well with 12.0 lb /gal Drilling Mud. Camco contrl line hand on the way out. 08:30 11:30 3.00 6,671 4,871 COMPZ WELLPF TRIP P Camco rep on location. PJSM, Set up control line spooler. TOOH W/ 19 stands of pipe. Recovered 31 control line bands. Recovered stuck Dap tool from 4/29/95 and 21' 3" long hold open sleeve that was set 4/6/11. Lay down SSSV. 11:30 14:00 2.50 4,871 6,671 COMPZ WELLPF TRIP P PJSM. TIH W/ old 3.5" TBG Tag PBR. Space out. PUH 8', into postion to circulate well to 10.7 Brine. 14:00 22:00 8.00 6,671 6,671 COMPZ WELCTL COND P Clean pits, and load with 10.5 brine, weight up to 10.7 ppg. 22:00 23:30 1.50 6,671 6,671 COMPZ WELCTL CIRC P Change hole over from 12.0 ppg KWF to 10.7 ppg KWF. ICP = 720 psi, Circulating at 5 bpm. FCP = 620 psi at 6 bpm. Sting seals back into PBR and close well in. 23:30 00:00 0.50 6,671 6,671 COMPZ WELCTL SFTY P Held PJSM with HES Slick line crew and rig crew on RU of Slick line. Page 4 of 7 . ! Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/15/2011 24 hr Summary Brush Nipple, and set CA2 plug, PT at 2,500 psi. Set catcher sub. RD slick line. Circ 1 1/2 hole volumes, POOH with 3 1/2 decompletion. Test 3 1/2 8rd TIW valve and Annular used to shut well in. Begin RIH w/ 110 jts of 3 1/2 Recompletion to 3,605 -ft 00:00 07:00 7.00 6,725 6,725 COMPZ WELCTI SLKL P RU slick line, PT lubricator to 2,500 psi - good test. RIH w/ 2.72" guage ring, brush and 2.80" No -go to 6,725 -ft and clean 2.75" Camco "D" nipple. RIH w/ CA2 Plug and set in, Nipple. PT plug at 2,500 psi for 10 minutes- good test. RIH w/ catcher sub and set on top of plug. POOH and RD Slick line. 07:00 09:00 2.00 6,725 6,717 COMPZ WELLPF CIRC P PJSM. Sting out of PBR, pull up —8'. Circulate 10.7 brine, 1.5 times well bore volume, taking returns to the pits. Monitor well. 09:00 17:00 8.00 6,717 0 COMPZ WELLPF TRIP P TOOH, W/ 3.5" deompletion, singles laying down & strapping. 17:00 20:00 3.00 0 0 COMPZ WELCTI BOPE P RU, set Test plug and Test 3 1/2 8rd TIW valve at 250/4,000 psi and Annular at 250/3,500 psi. The following components were used in shut in of well at 23:30 hrs on 6- 14 -11. 20:00 20:30 0.50 0 0 COMPZ RPCOM SFTY P Held PJSM with Baker Completion Hand and rig crew on proper placement of equipment and RIH with 3 1/2 Recompletion. 20:30 00:00 3.50 0 3,605 COMPZ RPCOM PULD P PU and RIH with 3 1/2 Recompletion, torqing TBG connections to 2,240 ft/lbs to 3,605 -ft. 65k up wt; 58k dn wt. X6/16/2011 Continue to RIH w/ 3 1/2 Recompletion from 3,605 -ft to 4,864 -ft PU Baker Storm pkr and set at 50 -ft. Release off pkr and POOH. PT at 500 psi. Drain stack and ND BOP and TBG spool. Change pack off s. NU TBG spool and BOPE. Release PKR and POOH with same. Continue to RIH from 4,863 -ft. to 6,203 -ft. 00:00 01:00 1.00 3,605 4,863 COMPZ RPCOM PULD P Continue to PU and RIH with 3 1/2 Recompletion, with make up torque at 2,240 ft/lbs on TBG connections from 3,605 -ft. to 4863 -ft. -ft. 75k up wt; 70k dn wt. 01:00 03:30 2.50 50 50 COMPZ WELLPF PACK P Held PJSM with crew and Baker Production hand. PU and RIH w/ Baker Storm PKR to 50 -ft with TBG Tail at 4,913 -ft. Set Baker Storm PKR and Release running tool and POOH. Close Blind rams and Test PKR at 500 psi. - Good Test. 03:30 05:30 2.00 50 50 COMPZ WHDBO NUND P Drain BOP Stack and ND BOPE, il Page 5 of 7 Time Logs I • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 16:30 11.00 50 50 COMPZ WHDBO NUND P ND TBG Spool to Change Inner CSG pack off and inspect TBG Spool. Have a couple inches growth from subsidence. Tree rep hot shot for longer studs but 1 3/8" X 3' studs were not at the tool house. Call Hydro tight, no one available on the slope until tonight. Discuss options. Decided to stack top drive weight on well head. Call town to get input and conduct PJSM. Stack weight on WH, back nuts off, hand tight. Growth was 11" . Spear 7" CSG, pull into 50k tension over block & string weight. Repair IC pack off. Cut 2' of 7" CSG. Test CSG void 300/3000 psi, good. 16:30 18:30 2.00 50 50 COMPZ WHDBO NUND P PJSM. NU BOP 18:30 19:30 1.00 50 50 COMPZ WHDBO BOPE P Set Test plug and RU for BOP shell test. Shell test brek at 250/4,000 psi. RD Test equipment and pull Test plug. 24 hr Notice was given right to witness was waived by Bob Noble. 19:30 20:30 1.00 50 4,863 COMPZ WELLPF PACK P Retrieve Storm PKR and lay down the same. 20:30 21:00 0.50 4,863 4,863 COMPZ RPCOM SFTY P Held PJSM w/ Camco on RU and PU of SSSV and Control line. 21:00 22:00 1.00 4,863 4,863 COMPZ RPCOM PULD P RU sheaves and PU, MU SSSV and connect control line. 22:00 00:00 2.00 4,863 6,203 COMPZ RPCOM PULD P Continue to RIH with 3 1/2 Re completion from 4,863 -ft to 6,203 -ft. 90k up wt, 80k do wt. 06/17/2011 Continue to RIH and Locate, Space out, MU TBG Hanger. Change hole over to 9.5 ppg brine. Spot CI 9.5 ppg at 6,670 -ft. Land TBG hanger, RILDS. RU and Test TBG and CSG plus SSSV. ND BOPE NU Tree. Test Void and Tree. FP with 250 bbls diesel. Secure well and clean rig pits. 00:00 03:00 3.00 6,203 6,682 COMPZ RPCOM PULD P Continue to RIH w/ 3 1/2" EUE 8rd recompletion from 6,203 -ft to 6,682 -ft. Locate and Space out, make up "New" TBG hanger. Bleed off pressure on control line and Terminate control line and splice into TBG hanger and bring back to surface. Pressure back up on control line and open SSSV. 03:00 06:30 3.50 6,682 6,682 COMPZ RPCOM CIRC P Break circulation down TBG to verify SSSV was open. Switch and Reverse circulate 9.6 ppg brine at 5 bpm and displace out 10.7 ppg brine to pits. Water back 50 bbls of 10.7 ppg to 9.6 ppg and pump 25 bbls of CI 9.6 ppg Brine and spot at 6,682 -ft. Blow down lines. 06:30 07:00 0.50 6,682 6,682 COMPZ RPCOM HOSO P Land TBG hanger and RILDS. • Page 6 of 7 Time Logs Date From To Dur S. II ;pth E. Depth Phase Code Subcode T Comment 07:00 10:00 3.00 6,682 6,682 COMPZ EVALWE PRTS P RU test lines and Test TBG at 3,000 psi for 15 minutes - good test, bleed down to 2,250 psi. Pressure up IA to 3,000 psi for 30 minutes - good test. Bleed off IA and TBG pressure. Ramp up pressure on IA and Shear SOV at 2,700 psi - good shear. Bleed pressure off control line and pressure up IA void below SSSV with TBG valve open to verify SSSV was holding - had no returns up TBG. 10:00 10:30 0.50 6,682 6,682 COMPZ WHDBOMPSP P Set BPV 10:30 11:00 0.50 6,682 6,682 COMPZ WHDBO SFTY P Held PJSM on ND BOPE 11:00 12:00 1.00 6,682 6,682 COMPZ WHDBO NUND P ND BOPE and set back 12:00 12:30 0.50 6,682 6,682 COMPZ WHDBO SFTY P Held PJSM on NU Tree and testing the same 12:30 16:30 4.00 6,682 6,682 COMPZ WHDBO NUND P NU Adapter and test voids at 250 / 5,000 psi. Call Chris Davis "DSO" and had him verify orientation of Tree. Tree was off 20 degrees left or right due to bolt hole configuration - not fixable with out rotating TBG Head - TBG head was reinstalled in same alignment and verified by paint mark placed prior to pack off changeout. Pressure test tree at 250 / 5,000 psi. 16:30 17:00 0.50 6,682 6,682 COMPZ WHDBO MPSP P Pull BPV. 17:00 21:00 4.00 6,682 6,682 COMPZ WELLPF FRZP P Freeze protect well, circulating 250 bbls of diesel down IA taking returns to kill tank at 1.75 bpm at 170 psi V ICP and 110 psi FCP with rig pump. Blow down and clear lines to kill tank, suck back with vac truck on suction side. 21:00 21:30 0.50 6,682 0 COMPZ WHDBO MPSP P Install BPV in hanger and secure tree. 21:30 00:00 2.50 0 0 COMPZ WELLPF OTHR P Clean and dress tree, secure cellar and continue to clean pits for for filtration job on next well. 06/18/2011 Continue to clean rig pits and prep for rig move. RDMO and release Nordic Rig 3 at 07:00 hrs on 6- 18 -11. 00:00 05:30 5.50 0 0 COMPZ Clean rig pits for filtration work on next well and prep rig for rig move. 05:30 07:00 1.50 0 0 COMPZ Release Nordic rig 3 at 07:00 hrs Page 7 of 7 • • SEAN PARNELL, GOVERNOR Lm ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C011'I1MSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Ohlinger Wells Engineer 9 ConocoPhillips Alaska, Inc. (, P.O. Box 100360 0 U 1 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -12 Sundry Number: 311 -210 Dear Mr. Ohlinger: 50 . AET) JUL. . 'J 7 ZOi 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, C )4' Daniel T. Seamount, Jr. Chair DATED this day of July, 2011. Encl. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 4 .... *, June 22, 2011 Commissioner- State of Alaska "�F `lSSi011 Alaska Oil & Gas Conservation Commission F= . =.., 333 West 7th Avenue Suite 100 ':..... Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a sundry to plug the perforations in the A and C sands of Kuparuk Well 3H -12 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" Camco D- nipple at 6723' RKB will be milled out to 2.80" ID. The work is scheduled to begin in July /August 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'n � r � s t ( R c, C E NEED ALASKP�. AND GAS CONSERVATION COMMISSI� AP P LICATION FOR SUNDRY APPROVALS I "' y 20 AAC 25.280 ' 1. Type of Request: Abandon r Rug for Redrill (', Perforate New Pool r Repair w ell r 0,1 , SP ilkyrri?.setionsaArrniumion • Suspend r Rug Perforations Perforate r Rill Tubing r ,,T(rpyt� on r Operational Shutdown r Re -enter Susp. Well r Stimulate Ak er casing 9 r Other: I""" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 187 - 129 ' 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20088 - 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 P . 3H -12 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25531 ' Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7298 . 6373 ' 7144' 6249' 7030', 7032', 7036' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3069 9.625" 3104' 2986' PRODUCTION 7190 7" 7225' 6314' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6832' - 6846', 6880' - 6890', 6904' - 6914', 6934' - 6954' 5998'- 6009', 6037'- 6045', 6056- 6064', 6080' -6096' 3.5 L -80 5876 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 3 1/2" X 7" FHL PKR MD= 6684 TVD= 5878 1 SAFETY VLV - CAMCO TRMAXX- CMT -SR -5 2.813" MD= 1804 TVD= 1804 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Development P Service r • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/18/2011 011 r Gas r WDSPL r Suspended f , 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: James Ohlinger @ 265 -1102 Printed Name James Ohlinger Title: Wells Engineer Signature .��° 4 ' Phone: 265 -1102 Date /O? / Commission Use Only n Sundry Number1 _ CCC777"` ', z Conditions of approval: Notify Commission so that a representative may witness —! Plug Integrity r BOP Test irMechanical Integrity Test r Location Clearance r i. 3 Soo ,s gap' 77 �s ` -- Other: �, 4 1"" Z /2 si. n� cs Subsequent Form Required: !o i APPROVED BY 7/4/i/ Approved by: COMMISSIONER THE COMMISSION Date: JUL 0 20 t.:� Form 10 -403 Revised 1/2010 /9 R 1 G "4_ G . Z?• // Submit in Day ike oF � ;o�24U • • Application for Sundry to Plug Perforations KRU 3H -12 II 3H - 12 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 3H -12 is August 2011. Summary of Operations: The 3H -12 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 6,120 feet of total hole will be drilled and the intervals will be completed with slotted liners. In addition the 3-1/2" Camco "D" nipple located at 6723' 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: Pull CA2 Plug, DCR -1 shear valve and replace w/ dummy, tag fill, obtain SBHP • E -line: Caliper /GR/CCL • E -line: Perforate the 3%2" tubing tail • Coil: Mill the D- nipple 7 10 J' r D • Coil: Lay /squeeze cement plug • Slickline: Tag TOC and PT to 1500 psi. . � G Qoo • Prepare well site for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. Pull BPV ps� 2. Mill cement pilot hole. 3. Set top of whipstock at 6,880' MD. 4. 4. Mill 2.80" window at 6,880'. 5. 3H -12A Sidetrack rikkAti � a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,450' MD b. Run the 2 slotted liner with an aluminum liner top billet from TD to 7,400' MD. 6. 3H -12AL1 Lateral a. Kick off of the aluminum liner top billet at —7,400' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 8,750' MD c. Run the 2 slotted liner with an aluminum liner top billet from TD to 7,300' MD. Page 2 of 3 6/22/2011 • • Application for Sundry to Plug Perforations KRU 3H -12 7. 3H -12AL2 Lateral a. Kick off of the aluminum liner top billet at —7,300' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,500' MD c. Run the 2 %" slotted liner from TD to 6,710' MD, inside the 3 -1/2" tubing tail of the mother -bore. Reservoir Pressure 3H -12 measured 3205 psi at 6818' SLM (-5900' TVDss; 10.45 ppg EMW) on May 31 2011. Another SBHP is scheduled post rig work -over and pre -CTD. Page 3 of 3 6/22/2011 3H -12 Proposed CTD Sidetrack 16" 62# H - shoe @ 115' MD ® ' TRMAXX - CMT -SR -5 SCSSV © 1804' MD — MIN ID = 2.813" "X" Profile Camco MMG w/ Dummy -RK Latch @ 9 -5/8" 36# J -55 shoe @ 3103' MD 2584' 4087' 5211' ...••••• 6026' ■ Camco MMG w/ DCR -1 Shear Valve @ 6559' • — 6620' MD 3 -1/2" x 2.812" X Nipple 6671' MD Baker PBR - 3.0" ID = 6684' MD Baker "FHL" Retrievable Packer - 3.0" ID 6723' MD 1■, v Camco "D" Nipple 2.75" ID (mill out to 2.80 ") 6757' RKB - Tubing Tail r h: 1 6756' MD - BOT SOS C -sand perfs 6832' - 6846' MD — i ,,_ �� N '# 3H -12AL2 >s AL1 billet @ 7,400 MD TD @ 9,500' MD - 4. KOP @ 6880' E -line A -sand perfs 4 4 * "- "-"'-- --- - -- 6880' - 6890' MD a /1 - - - -- - _ / • A -sand perfs c , o jw 6' - ,� ' , ,, • ` 6934' - 6954' MD — 3H -12A - TD @ 9,450' MD AL2 billet @ 7,300' MD 3H -12AL1 t4 7 "26 #J - 55 shoe @7225'MD , � �. ". TD @ 8,750' MD .mow c'il a :"` .,rit -A KUP • 3H -12 C�tp5 t >3. Well Attributes: Max Angle & MD TD A ,- Me Wellbore APWWI F Id Name Well Status Inc! r) MD (ftKB) Act Btm (ftKB) Inc_ t6xruc- oM,9NW ; 501032008800 'Field RIVER UNIT PROD 37.28 I 4,400 00 /298 0 - C nt - H2S (ppm) Date Annotation End Date - -- KB -Grd (ft) Rig RelerWe Date "' SSSV: TRDP Last WO: 42 01 1/4/1988 "' we, 2 ; � ' - pt `' " A g a F D �' " ' A Cation (Depth (ftK6) End Date ( Annotat _ ion Last Mod .. End Date Last Tag__ I l 6,938 0 7/4/1 Rev Reason: WORKOVER ninam 6/20/2011 Casio. Strin.s Casing Description String 0... String ID ... Top (ftKB) Set Depth (L. Set Depth (ND) ... String Wt... String .. String Top Thrd !HANGER, 35 * CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H -40 WELDED -.- Casing Description swing 0... smog . . . ID Top (ftKB) set Depth (r... Set Depth (ND) ... smog Wt... swing ... swing Top rent SURFACE 9 5/8 8.835 35.0 3,103.9 2,986.2 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Sal Depth (f... set Depth (ND) ... String Wt... String ... String Top Thal - - PRODUCTION 7 6.276 35.0 7,224.9 6,314.4 26.00 J - 55 BTC CONDUCTOR. -- .� -.._ 36 -115 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 3 1/2 2.992 35.0 6,681.9 5,876.4 j 9.30 L80 EUE 8Rd Mod SAFETY VI .V, _ („ ., i Completion Details 1,804 I - i Top Depth (ND) Top Inc! Nomi... Top(ftKB) (ftKB) (") Item Description Comment ID (in) ,. -.- 35.0 35.0 -0.06 HANGER MCEVOY MS /DP TUBING HANGER 2.876 1,804.1 1,804.1 -2.73 SAFETY VLV CAMCO TRMAXX- CMTSR-5 2.813" X- PROFILE SN #CZS -0415 2.812 GAS LIFT, 2,584 6 619 6 5,826.3 36.30 NIPPLE 3 12" X 2.812" X NIPPLE 2.812 2.581 l .._ 6,669.9 5,866.7 36.22 SEAL ASSY BAKER 80 GBH - 22 LTSA SEAL ASSEMBLY W/ 3' SPACE OUT 3.000 Tubing Description String 0... IStri g ID ... Top MB) Set Depth (f_. I Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING Original 3 1/2 2.992 6,670.7 6,756 6 5,936.8 1 9.30 .1-55 EUE8rdABMOD li Completion Details Top Depth - - - - (ND) Top Inc! Nomi... SURFACE, Top (ftKB) (f8K81 ("1 Item De ipti_ Comment ID (in) 35 - 3,104 6,670.7 5,867.4 36.22 PBR Baker 312 "PBR 3.000 6,684.4 5,878.4 36.20 PACKER BAKER 3 1/2" x 7" FHL PKR (750008 pull or rot. re!) 3.000 GAS LIFT, 6,723.2 5,909.8 36.14 NIPPLE CAMCO 3 1 /2" 'D' Nipple 2.75" ID 2.750 4,087 _ 6,755.7 59360 36.09 SOS BO 3 1/2" Shear Out Sub 2.992 Other In Hole ((Wireline retrievable plugs, valves pumps, fish, etc.) Top Depth (TVD) Top Intl GAS LIFE. _.. . -... Top (yaw) (ft8B) r) Dascdption Comment Run Date ID (in) 5.211 _ 7,030 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/20/1999 downhole. 7,032 6,159.2 36.47 FISH 5 GRAPPLES - 1" X 2" 5/11/1995 7,036 6,162.5 36.47 FISH Bailer Left in Hole 9/6/1988 GAS LI,_ 6,02 Perforations & Slots sn Sh o � ot Top (TVD) Btm (TVD) Dens Top (ftKB) Bon (fBB) (MB) (ftKB) Zone Date (sh - Type Comment 6,832 6,846 5,997.7 6,009.0 C-4, 3H -12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph GASUFr, - ____ -- .__ 6,880 6,890 6,036.5 6,044.6 A-3, 3H -12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,555 6,904 6,914 6,055.6 6,063.8 A -2, 3H-12 9/21/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,934 6,954 6,080.0 6,096.2 A -1, 3H -12 5/14/1988 4.0 IPERF 4 12" UltraPak 120 deg. pH; 3 shots misfired N otes: General & Safety NIPPLE, 6,620- _ -- End Date Annotation 10/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 . SEAL ASSY, r 6,870 PBR, 6,671 I< T PACKER, 6,684 NIPPLE, 6,723 ' mp, i. ir SOS, 6,756 PERF, 6,832 -6.866 ,,.,, IPERF,_ IM 6,880 -6,890 yyr` 9;6648 -5-08 4 mm.4 wham 6,904 -6,914 1 w5 - ± _ Mandrel Details IPERF. Top Depth Top Port - -- fi• mw.. -� (TVD) Inc' OD Valve Latch She TRO Run -..- Stn Top (ftKB) (ftKB) .,. 1') Melte Model (in) Serif Type Type (in) (pail Run Date Com..._ FISH, 7,030 1 2,584.1 2,553.5 28.44 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/172011 - - - 2 4,087.3 3,791.4 34.71 CAMCO MMG 1 12 GAS LIFT DMY RIO 0.000 0.0 6/172011 FISH, 7,032 i 3 5,210.8 4,693.2 36.92 CAMCO MMG 1 12 GAS LIFT DMY RIO 0.000 0.0 6/17/2011 4 6,026.4 5,347.6 36.42 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/17/2011 ��.��), 5 6,559.2 5,777.3 36.09 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 6/172011 FISH, 7,036 Y..D 1! PRODUCTION, 35 -7.225 ■■ TD, 7,298 • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPORD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 V form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 6/29/2011 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 16, 2011 10:13 AM To: 'Toomey, Ian A' Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: RE: 3H -12 (PTD #187 -129) use of BOP Ian, Received the BOP notification and it appears appropriate and explains the event sufficiently. In regards to using BOP's however... in the future notify the Commission by email when the sundry operation ( sundry 311 -191) changes significantly from what the approved procedure authorizes. There was no mention in the sundry about intentionally putting the well into an underbalanced state although your change in procedure makes operational sense. The change in BHP should have also been communicated as that was also a significantly different considering you had a recent static BHP. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC jUY I € 2.1111 793 -1226 (office) (cell) From: Toomey, Ian A [mailto: Ian .A.Toomey @conocophillips.com] Sent: Wednesday, June 15, 2011 5:46 PM To: Schwartz, Guy L (DOA) Subject: 3H -12 (PTD #187 -129) use of BOP Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 6/14/11 2330 hrs Well /Location /PTD Number: 3H -12 /Kuparuk River Unit/187- 129 /Sundry #311 -191 Rig Name: Nordic 3 Operator Contact: lan Toomey 907 - 263 -4773 Ian.A.Toomey @conocophillips.com Operations Summary: The rig completed the initial BOP test at 0330 hrs on 6/14/11. The plug off tool and BPV were pulled and BOLDS. We PU and the seal assembly pulled free from the PBR at 115K on the weight indicator. The tubing hanger was pulled to the rig floor and the well was circulated and conditioned with 12.0 ppg mud (KWF). TOOH standing back the tubing to the SCSSV and laid down same. RBIH to just above the PBR and circulated the well over from 12.0 ppg mud to 10.7 ppg brine then lowered the seals into the PBR. Pressure differential was expected so the annular preventer and 3 -/12" 8rd TIW valve were shut for well control purposes. RU slickline, RIH with CA2 plug and set plug in 2.75" "D" nipple at 6723' RKB to isolate the formation. PT the plug to 2500 psi for 10 minutes and RD slickline. Currently we are POOH with the existing completion. BOPE Used: Annular preventer and 3 -1/2" 8rd TIW valve. Reason for BOPE Use: Control flow of fluids from the wellbore due to reservoir differential. Actions Taken/To Be Taken: Set a CA2 plug in the 2.75" "D" nipple at 6723' RKB to isolate the formation, PT the plug to 2500 psi for 10 minutes and POOH with the existing completion. Once on surface we will set a test pull and test the BOP components that were utilized and test the TIW valve as per 20 ACC 25.285 (f) (2). Please let me know if you have any questions or if you require more information. 6/16/2011 • Page 2 of 2 Regards, Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. Office: 907.263.4773 Cell: 907.903.3987 6/16/2011 • Page 1 of 1 Regg, James B (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 16, 2011 9:29 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: FW: 3H -12 (PTD #187 -129) use of BOP For database. Jim, Want to discuss this with you later. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Toomey, Ian A [mailto: Ian .A.Toomey ©conocophillips.com] Sent: Wednesday, June 15, 2011 5:46 PM To: Schwartz, Guy L (DOA) Subject: 3H -12 (PTD #187 -129) use of BOP " Zit Ott Guy, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE use on Nordic 3 with a written report. Date, Time of BOPE Use: 6/14/11 2330 hrs Well /Location /PTD Number: 3H- 12 /Kuparuk River Unit/187- 129 /Sundry #311 -191 Rig Name: Nordic 3 Operator Contact: Ian Toomey 907 - 263 -4773 Ian.A.Toomey @conocophillips.com Operations Summary: The rig completed the initial BOP test at 0330 hrs on 6/14/11. The plug off tool and BPV were pulled and BOLDS. We PU and the seal assembly pulled free from the PBR at 115K on the weight indicator. The tubing hanger was pulled to the rig floor and the well was circulated and conditioned with 12.0 ppg mud (KWF). TOOH standing back the tubing to the SCSSV and laid down same. RBIH to just above the PBR and circulated the well over from 12.0 ppg mud to 10.7 ppg brine then lowered the seals into the PBR. Pressure differential was expected so the annular preventer and 3 -/12" 8rd TIW valve were shut for well control purposes. RU slickline, RIH with CA2 plug and set plug in 2.75" "D" nipple at 6723' RKB to isolate the formation. PT the plug to 2500 psi for 10 minutes and RD slickline. Currently we are POOH with the existing completion. BOPE Used: Annular preventer and 3 -1/2" 8rd TIW valve. Reason for BOPE Use: Control flow of fluids from the wellbore due to reservoir differential. Actions Taken /To Be Taken: Set a CA2 plug in the 2.75" "D" nipple at 6723' RKB to isolate the formation, PT the plug to 2500 psi for 10 minutes and POOH with the existing completion. Once on surface we will set a test pull and test the BOP components that were utilized and test the TIW valve as per 20 ACC 25.285 (f) (2). Please let me know if you have any questions or if you require more information. Regards, Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. Office: 907.263.4773 CeII: 907.903.3987 6/16/2011 • • slisofE ALAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMI'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. 1 Y 2-1 P.O. Box 100360 NI Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -12 Sundry Number: 311 -191 Dear Mr. Toomey: JUN 9 201 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 June, 2011. Encl. • • . q ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 1, 2011 Commissioner Dan Seamount Afe a tlii' �'� g'� �1?S srll ili�S10/F State of Alaska Alaska Oil & Gas Conservation Commission . 13 Cfi!31'asf6 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3H-12 (PTD 187 -129). Well 3H-12 was originally drilled and completed in 1988 as an A and C sand water injector. An isolation sleeve is stuck above the SCSSV and prior to CTD operations the well will need a workover to recover the e (( fish. The injection in this well has been shut in since August 2010 to allow the area to depressurize. "In an �f 4SS 4 effort to accelerate the process the well was flowed back for about 3 months from February until May 2011. ' De l/ The purpose of this workover is to set it up for upcoming CTD sidetracks. The proposed workover will s: xe-e consist of pulling the existing 3 -1/2" tubing string and run new 3 -1/2" L -80 tubing string with a SCSSV. 3_/5 Passing MIT -IA tests consistently indicate that the production casing and tubing are competent, with the latest test occurring on June 7, 2009. 6.7 or If you have any questions or require any further information, please contact me at 263 -4773. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Wells 1 STATE OF ALASKA II RECEIVED ED ALASKA. AND GAS CONSERVATION COMMISSI• (// 1 APPLICATION FOR SUNDRY APPROVALS 91,144. ; N 1 ') t " ��fit 20 AAC 25.280 t Io � f 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell fl, ,`-4 i rddg 7'o ( S Nn Suspend r Flug Perforations r Perforate r Rill Tubing Pr ' :''. a C iffiftrigt&ns ion r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: G / f(5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 187 -129 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20088 -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 J 3H -12 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25531 . Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7298 6373 7144' 6249' 1803', 7030', 7032', 7036' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3069 9.625" 3104' 2986' PRODUCTION 7190 7" 7225' 6314' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6832'- 6846', 6880' - 6890', 6904' - 6914', 6934' -6954' 5998' - 6009', 6037'- 6045', 6056-6064', 6080' -6096' 3.5 J - 55 6756 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 3 1/2" X 7" FHL PKR MD= 6684 TVD= 5878 SAFETY VLV - Camco 'TRDP -1 A -SSA' MD= 1803 TVD= 1803 f� ?'A 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: / • Detailed Operations Program r BOP Sketch r Exploratory (- Development IV Service ; 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/13/2011 Oil r✓ Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: G •7 GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4773 Printed Name Ian Toomey Title: Wells Engineer Signature --�"`� Phone: 263 -4773 Date (. -/ - // Commission Use Only Sundry Number:3) ( -' g 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test ( Mechanical Integrity Test r Location Clearance r Other 3 500 1'x ' 7;751- _ if Ob PSG 4 n J. (esf 61.4.-.,' ) Subsequent Form Required: /Q -1/0 y APPROVED BY ' PP by: I Approved b : 0 COMMISSIONER THE COMMISSION ` Date: � � d - 2.11 Form 10 -403 Revised 1/2010 7 4 - G,d,` / JUN D. 9 2011submit in D licate Q R IG • • 3H -12 Expense Rig Workover (PTD #: 187 -129) Current Status 3H -12 is currently shut in awaiting a workover. Passing MIT -IA tests consistently indicate that the production " casing and tubing are competent, with the latest test occurring on June 7, 2009. Scope of Work Pull the existing 3 -1/2" tubing string and stack a packer with new 3 -1/2" L -80 tubing string. General Well info MASP: 2626 psi (utilizing 0.1 psi/ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 3228 psi at 6864' MD (6024' TVD) SBHP taken on May 31, 2011 Wellhead type /pressure rating: WKM Gen III, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MITIA and MITOA results: MIT -IA — passed on June 7, 2009 MIT -OA - passed on May 4, 2011 Well Type: Injector (long term status); Currently a producer for pre -CTD flow back purposes. Estimated Start Date: June 11, 2011 Production Engineer: Len Jansen Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Pre -Rig Work Request 1. RU HES E -line. a. RIH with split -shot. Fire split -shot in the middle of the first full joint above GLM #4 at — 6617' RKB. 2. RDMO HES E -line. �~ 3. FT LDS. 4. Set BPV. Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Bleed IA to outside open top tank. Keeping IA open circulate well to 10.7 ppg b s mud until 10.7 ppg mud returns at surface. Monitor well to ensure that it is dead. Set 3" `HP' BPV. ND tree. NU 11" 5K BOP and pressure test BOP to 250/3500 psi. • 2. Pull plug off tool and BPV. MU landing jt and PU tbg hgr to rig floor. Circulate 10.7 ppg mud down tbg taking returns from the IA at max rate to ensure well is loaded with 10.7 ppg mud. 3. MU landing joint, BOLDS and pull tubing from the PBR a. If tubing does not pull free, RU E -line. RIH with RCT and cut the tubing in the middle of the first full joint above the SCSSV at - - 1784' RKB. POOH and RD E- line. (( - Z i°/215# /215# 4. TOOH laying down tubing and spooling up control line. If tubing is not cut skip to step 11. ( e / " 5 d ,. 5. If tubing is cut, MU overshot dressed for 3 -1/2" tubing and single in on drillpipe. Latch onto the tubing. 6. RU E -line and RIH with string shot. Shoot the string shot across the connection at 1843'RKB, POOH and RD E -line. 7. Perform back -off, TOOH with SCSSV and lay down same. 8. RBIH with overshot dressed for 3 -1/2" tubing, latch onto the tubing and pull tubing from PBR. Go to step 11. 9. If tubing does not pull free, RU E -line. RIH with RCT and cut the tubing in the middle of the first full joint above the PBR at — 6656' RKB. POOH and RD E -line. Page 1 of 2 • --Proposed Procedure Continued 10. RBIH with overshot dressed for 3 -1/2" tubing, latch onto the tubing and jar seal assembly from PBR. POOH laying down drillpipe and seal assembly. 11. RIH with locator seal assembly, 2.813" `X' nipple, GLM(s), SCSSV and 3 -1/2" L -80 tubing. ( I . her ?) 12. Locate top of PBR at 6671' RKB. PU and load IA with corrosion, inhibited brine. 13. RIH and tag top of PBR with locator sub. PU neutral weight +3ft and space out; space out positioning one full joint below tubing hanger. Space out should leave locator 3 ft above located position when tubing hanger is landed 14. MU new hanger, feed control line through the hanger and secure with swage -lock fitting. Land the tubing hanger. RILDS. Function test and PT SCSSV. 15. Pressure test tbg to 3000 psi for 15 mins, bleed tbg to 2250 psi, PT IA to 3000 psi for 30 mins and record on chart. 16. Bleed IA to 0 psi followed by tbg pressure to 0 psi. Ramp up IA pressure to 1500 psi to shear SOV. Bleed IA to 0 psi. Close SCSSV and pressure test from below. 17. Pull landing joint, set 2 -way check. ND BOP. 18. NU tree and test. Pull 2-way check. Freeze protect well. Set BPV. 19. RDMO Nordic 3. Post -Rig Work request: 1. Pull BPV. 2. Pull SOV and install DV. 3. Turn well over to operations. Page 2 of 2 1 • KUP • 3H12 It ' " BPhil ips l ell A t ri b�tg _ Max Angle & MD TD 54. Wellbore API/DWI - I Field Name Well Status Incl °) IMD(ftKB) Act Btm(ftKB) c4xr�..aYE4nps ry 50103200880_0_ NJ RIVER UNIT J 37.28 1 4,400 00 7,298 0 Comment H2S (ppm) Data An tation End Date KB - Card (ft) Rig Release Date "' SSSV: TRDP l Last WO:__ � _ 42.01 114/1888 - �.'t�_: ., - ., - S,010r1t11G Anklet ,,. IDepth(ftKB) End Date Annotation � t Mod .. End Date Last Tag: 1 6,938.0 7/4/1999 Rev Reason: SET SPACER PIPE IN TRDP Imosbor 104/2010 Casing Strings „.:. Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) .. String Wt... i String .. String Top Thrd "/_l. CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED HANGER, 35 's 27, 4,', ": Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd SURFACE 9 5/8 8.835 35 0 3,103.9 2,986.2 36.00 J -55 BTC ... Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 9 P 9 5555 Top (ftKB) -- .. - - BTC . - . - PRODUCTION 7 6.276 35 0 7 ,224.9 6,314.4 26 00 J-55 CONDUCTOR, 36 - „6 Tubing Strings Tubing Description tion Str 0... Stri ng ID. ., To (ftKB I Set Depth (f. I Set Depth (TVD) TVD ) ... String Wt_. Strng String Top Thrd TUBING 31/2 2.992 350 6,7566 5,936.8 9.30 J-55 EUE8rdABMOD SAFETYVtV, Completion Details 1,603 Top Depth DAP TOOL, (TVD) Topincl Homi... 1,603 Top (MB) (ftKB) ( °) item Description Comment ID (in) 35.0 35.0 -0.06 HANGER McEvoy Tbg Hanger 2.992 1,802.7 1,802.7 -2.79 SAFETY VLV Camco 'TRDP -IA -SSA' (Set DAP TOOL on 4/29/95) NOTE: SSSV 2.812 GAS LIFT, - hydraulics are disconnected at the tree. TRDP is functional - two closure 2,492 tests 7/4/99. Dap Sleeve not across flapper -- MUST!! maintain control line pressure. Drifted sleeve to 1.925 ". Cannot maintain SSSV control line pressure - LEAK DO WNHOLE. Tracks tubing pressure. Disconnected panel from tree, tagged at i wellhead 4/8/2001 The SSSV is NOT locked out. 5/23/2002 6,670.7 5,867.4 36.22 PBR Baker 3 1/2" PBR 3.000 5555 6,684.4 5,878.4 36.20 PACKER BAKER 3 1/2" x 7" FHL PKR (75000# pull or rot rel) 3.000 SURFACE, _ . - -- 35 - 3,106 6,7232 5,909.8 36.14 NIPPLE CAMCO 3 1/2" 'D' Nipple 2.75" ID 2.750 6,755.7 5936.0 36.09 SOS BOT31/2' Shear Out Sub 2.992 GAS LIFT. �_ *�. _ 4,645 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) _. Top Depth Top Intl - - -- Top 9tKB) (ftKB) (1 Description Comment Run Date ID (in) GAS LIFT, 1,802.7 1,802.7 -2.79 DAP TOOL DAP Tool installed on 4/29/95 (150.5" TL, 2.85" No Go, 4/29/1995 2.460 6,103 , . -. 10= 2.46); - --- " -- -_ -__ - 5555 7,030.0 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/20/1999 downhole. GAS 6,632 LIFT, - -- 7,032.0 6,159.2 36.47 FISH 5 GRAPPLES - 1" X 2" 5/11/1995 • .,: 7,036.0 6,162.5 36.47 FISH Bailer Left in Hole 9/6/1988 Perforations & Slots PBR, 6,671 - ' -' -'- 4 I Shot 1,- ,------j- Top (TVD) Btrn (11/D) Dens Top Btm(ftKS) (RKB) (ftKB Z one Data leb.•• A . C PACKER, 6,684 6,832.0 6,846.0 5,997.7 6,009,0 C-4, 31-1-12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,880.0 6,890.0 6,036.5 6,044.6 A -3, 3H -12 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph 6,904.0 6,914.0 6,055.6 6,063.8 A -2, 3H -12 9/21/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph NIPPLE, 6,723 - 6,934.0 6,954.0 6,080.0 6,096.2 A -1, 3H -12 5/14/1988 4.0 IPERF 4 1/2" UltraPak, 120 deg. pH; 3 shots misfired L . ,5,555 � ',?.. c rv3 .._�.. SOS, 6,756 ti Date Annotation '- 9232010 NOTE: BROKEN FLAPPER IN SSSV @ 1803' 10/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 • IPERF, 6,6326,646 - E E- IPERF, - 6,6606,690 IPERF, 6,9046,914 IPERF, 6,934 -6,954 FISH, 7,030 - - 4 _ 5555 Mandrel Details Top Depth Top Port FISH, 7,032 ' -- - (ND) 1061 OD Valve L atch Sae TRO Run Stn Top(ftK8) (ftKB) (1 Make Model (in) Serv Type Type 5n) (Psi) Run Date Com... 1 2,491.8 2,471.1 24.83 McMu... FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 5/15/1988 2 4,645.1 4,240.2 36.86 McMu... FMHO 1 GAS LIFE DMY BK -2 0.000 0.0 5/1511988 FISH. 7.036 _ y __. 3 6,102.7 5,409.1 36.38 McMu... FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 5/15/1988 4 6,632.2 5,836.4 36.28 Camco MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 5/27/1988 PRODUCTION, 35 -7,225 70,7,296 _ ' - STATE OF ALASKA ALASK L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air w ell Rug I�rforations t Stimulate Ot her WINJ to Prod r P 9 r i Alter Casing r Pull Tubing r Fbrforate New Pool r Waiver f Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r • 187 -129 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service . 50 - 103 20088 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25531 - • 3H -12 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7298 feet Plugs (measured) None true vertical 6373 feet Junk (measured) 7030', 7032', 7136' Effective Depth measured 7144 feet Packer (measured) 6684 true vertical 6249 feet (true vertucal) 5878 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3069 15.25 3104 2986 PRODUCTION 7190 7.656 7225 6314 SttdiANED APR 0 8 2011 Perforation depth: Measured depth: 6830 -6846, 6880 -6890, 6904 -6914, 6934 -6954 True Vertical Depth: 5998 -6009, 6067 -6045, 6056 -6064, 6080 -6096 Tubing (size, grade, MD, and TVD) 3.5, J -55, 6756 MD, 5936 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 3 1/2" X 7" FHL PKR (75000# PULL OR ROT. REL) @ 6684 MD and 5878 TVD SAFETY - Camco 'TRDP -IA -SSA' (Set DAP TOOL on 4/29/95) @ 1803 MD and 1803 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 Subsequent to operation 3 152 2104 700 172 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ` Service r Stratigraphic r 15. Well Status after work: ..Oil P Gas r WDSPL r Daily Report of Well Operations X GSTOR r W W AG WIND r 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 310 -441 Contact Bob Christensen /Darrell Humphrey Printed Name A Rob- i D. C ristensen Title Prod Eng Specialist Signature j ! ,� Phone: 659 -7535 Date 6 RBDAAS APR as 2011 AFL Y4A Form 10-404 Revised 10/2010 pd S' 1/ Submit Original Only • 3H -12 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/15/11 INJECTOR FLOWBACK A/C SAND SCALE SQUEEZE. PUMPED 13 BBLS OF SEAWATER PRE -FLUSH CONTAINING 40 GALLONS OF WAW -5206. PUMPED 78 BBLS OF SEAWATER CONTAINING 430 GALLONS OF SCW -4004. PUMPED 220 BBLS SW OVERDISPLACEMENT. KUP 3H -12 ConocoPhillips °- el! Attributes ax Angle & MD TD AI,i ,i it 1, Wellbore API /UWI Field Name Well Status Inc! (°) MD (01413) Act Btm (ftKB) ionocoMalys 501032008800 KUPARUK RIVER UNIT INJ 37.28 4,400.00 7,298.0 Comment 1426 (ppm) Dale Annotation End Date KB (0) Rig Release Date "' _ SSSV: TRDP Last WO: 42.01 1/4/1988 Well Confi9: -3H -1210/4/2010 9 10.47 AM Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: 6,938.0 7/4/1999 Rev Reason: SET SPACER PIPE IN TRDP Imosbor 10/4/2010 -- Casing Strings r s Casing Description String 0... String ID ... Top (RKB) 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 WELDED HANGER, 35 r Casing Description String 0... String ID ... Top (MB) Set Depth (r... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 35.0 3,103.9 2,986.2 36.00 J - 55 BTC Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 35.0 7,224.9 6,314.4 26.00 J - 55 BTC CONDUCTOR, 36-115 Tubing Strings Tubing Description String 0... String ID ... Top (RKB I ) Set Depth (t... I Set Depth )TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 I 2.992 I 35.0 6 ,756.6 5,936.8 I 9.30 J -55 EUE SAFETY VLV, Completion Details 1,503 - - 7 Top Depth DAP TOO I (TVD) Top Intl Nomi... 1'803 Top vow) I RKS ) ( °) Item Description Comment ID (In) 35.0 35.0 -0.06 HANGER McEvoy Tbg Hanger 2.992 1,802.7 1,802.7 -2.79 SAFETY VLV Camco TRDP-1A-SSA' (Set DAP TOOL on 4/29/95) NOTE: SSSV 2.812 GAS LIFT, .. hydraulics are disconnected at the tree. TRDP is functional - two closure ? 492 tests 7/4/99. Dap Sleeve not across flapper - MUSTII maintain control / 1 , line pressure. Drifted sleeve to 1.925 ". Cannot maintain SSSV control line pressure - LEAK DOWNHOLE. Tracks tubing pressure. Disconnected panel from tree, tagged at wellhead 4/8/2001 The SSSV is NOT locked out. 5/23/2002 6,670.7 5,867.4 36.22 PBR Baker 3 1/2' PBR 3.000 SURFACE, _.° I I 6,684.4 5,878.4 36.20 PACKER BAKER 3 1/2" x 7" FHL PKR (750008 pull or rot. re)) 3.000 35 6,723.2 5,909.8 36.14 NIPPLE CAMCO31/2 "'D' Nipple 2.75" ID 2.750 6,755.7 5,936.0 36.09 SOS BOT 3 1/2" Shear Out Sub 2.992 GAS 4IS 5 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (RKB) (RKB) (e) Description Comment Run Dab ID (In) GAS LIFT, 1,802.7 1,802.7 -2.79 DAP TOOL DAP Tool installed on 4/29/95 (150.5" TL, 2.85" No Go, 4/29/1995 2.460 6103 ID= 2.46); 7,030.0 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/20/1999 downhole. GAS LIFT, __ - 1 7,032.0 6,159.2 36.47 FISH S GRAPPLES - 1" X 2' 5/11/1995 6,632 f 7936.01 6,162.5 36.47 FISH Bailer Left in Hole 9/6/1988 r--,, Perforations & Slots PER, 6,671 Shot Top (TVD) Btm (TVD) Dens PACKER, 6,664 Top (01(8) Btm (MB) (RKB) (TM) Zone Date )Ch... Type Comment 6,832.0 6,846.0 5,997.7 6,009.0 C4, 3H-12 8/30/1988 12.0 IPERF 21/8" EnerJet, 30 deg ph 6,880.0 6,890.0 6,036.5 6,044.6 A -3, 3412 8/30/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph ,t 6,904.0 6,914.0 6,055.6 6,063.8 A -2, 31.12 9/21/1988 12.0 IPERF 2 1/8" EnerJet, 30 deg ph NIPPLE, 6,723 a. 6,934.0 6,954.0 6,080.0 6,096.2 A -1, 3H-12 5/14/1988 4.0 IPERF 41/2" UltraPak, 120 deg. pH; 3 shots misfired Notes: General & Safety 7 End Date Annotation SOS, 6,756 9/23/2010 NOTE: BROKEN FLAPPER IN SSSV @ 1803' 10/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 I IPERF, IPESF IPERF. . 6,86 E II IPERF, _ 6,904 -6,914 '® PEPF 6 -6 954 FISH, 7,030 Mandrel Details Top Depth Top Port FISH, 7,032 • (TVD) Intl OD Valve Latch Size TRO Run Stn Top (RIO) MB) (°) Make Model (In) Sery Type Type ON (Pei) Run Date Com... 1 2,491.8 2,471.1 24.83 McMu... FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 5/15/1988 2 4,645.1 4,240.2 36.86 McMu... FMHO 1 GAS LIFT DMY BK -2 0.000 0.0 5/15/1988 FISH, 7.036 1 ^) 3 6,102.7 5,409.1 36.38 McMu... FMHO 1 GAS LIFT DMY BK -2 0.000 0.05/15/1988 4 6,632.2 5,836.4 36.28 Camco MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/27/1988 PRODUCTION. 357,225 TD, 7,298 • • SIMI DIF ALASIE 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 Lindsey Hunter Drillsite Engineer ConocoPhillips Alaska, Inc. ¢ '' } P.O. Box 100360 "� Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -12 Sundry Number: 310 -441 Dear Mr. Hunter: ED JAN . 2 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, 9 Daniel T. Seamount, Jr. Chair r cl DATED this 3 day of January, 2011. Encl. • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED DEC 222010 December 22, 2010 Alaska Oil & Gas Cons. Commission Anchorage Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to convert the Kuparuk Well 3H -12 (PTD 187 -129). Well 3H -12 is a Kuparuk injector that will be temporarily converted to production to de- pressure the reservoir prior to drilling well 3H -10C. We plan to flow this injector back for approximately four months. If you have any questions or require any further information, please contact me at 265 -6427. Sincerely, Lindsey Hunter GKA Drillsite Petroleum Engineer CPAI Production Engineering - , • (14- ott STATE OF ALASKA • t ' 3 I •' ALASKA OIL AND GAS CONSERVATION COMMISSION t� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r" Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pill Tubing f _ Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate Alter casing r t io� �o� � Other:Convert to producer r+7. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r" 187 - 129 • 3. Address: 6. API Number. Stratigraphic r Service h P. 0. Box 100360, Anchorage, Alaska 99510 50 103 - 20088 - 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 � 3H -12 9. Property Designation (Lease Number): 10. Field / Pool(s): RECEIVED ADL 25531 • Kuparuk River Field 1 Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY 2 2010 Total depth MD (ft): Total Depth TVD (ft): Effective Depth Mo (r6: Effective Depth TVD (ft): Plugs (measured): Junk (mead) . 7298 , 6373 • 7144' 6249' .70_30i, 7032', 7036' Casing Length Size MD Tv° Aldbkd OB6#sas COMcitielifilTIISSIOn CONDUCTOR 115 16 115' 115' Anchcrag'ie SURFACE 3103 9.625 3103' 2986' PRODUCTION 7225 7 7225' 6314' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6832' 6846', 6880' 6890', 6904' 6914', 6934' - 6954' 5998' - 6009', 6037' - 6045', 6056' 6064', 6080' - 6096' 3.5 _ J -55 6757 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PKR - BAKER 'FHL' MD= 6684 TVD= 5878 CAMCO 'TRDP -IA -SSA' MD= 1803 TVD= 1803 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r,+ Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/3/2011 Oil 7 • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Lindsey Hunter @ 265 -6427 Printed Name Lindsey Hunter Title: Drillsite Engineer ^, Phone: 265 -6427 Date -_. ` r , Signature �` %,, 1 ` � t 1 Commission Use Only Sundry Numbe3 j 0 • 041 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity fl BOP Test r Mechanical Integrity Test "" Location Clearance // F / Other: — . cif- Sic. /a Cp h vs.r� -L.L. - :r j e `- l 5 ✓ rl s .� �P"�+ r T SV S clt ec /C p r • i r' r 4 Subsequent Form Required: D — cl U c1 o t...., b te-- Approved by: 0 APPROVED BY COMMISSIONER THE COMMISSION Date: / /371 1 Form 10 -403 R D � Z9 Su bm i t i n Duplicate JQ( 0424 RIGINAL � � / ; I Vfo t KUP 3H -12 COII{ COPE t Weil Attributes Max, Angle & MD TO A?:15k „n l''''' bore YYI Fiel Name Well Status Inc, 1.) MD MKS) Act Btm(CHB) 5010 IKUP ARUK RIVER UNIT INJ 37,28 4,400.00 7,298.0 senips Comment H25 (ppm) Date Annotation End Date KBGrd (11) Rig Release Date "' wen Ceni = a1NU.,au261osfo,o SSSV: TRDP _ Last WO: _ 42.01 114/1988 scnama,c - am:af Annatatten Depth MKS) End Date Annotation Lest Mod... End Date Last Tag: 6,938.0 7/4/1999 IRev Reason: SET SPACER PIPE IN TRDP )masbor 10/4/2010 Casing Strings ' 1 Casing Description Sling 0... String lD - .'Top (itH8) Set Depth lt.,, Set Depth (P/0),.. String Wt... String String Top Thrd _, „_. CONDUCTOR 16 15.062 36.0 115.0 115.0 6250 H40 WELDED HANGER, 36 �z _ Casing Description String 0... String ID ... Top (10(8) Set Depth (L.. Set Depth (ND) ... String Wt... String.,. String Top Thrd ;: ///Z SURFACE 95/8 8.835 35.0 3,103.9 2,986.2 36.00 J-55 BTC xr '®^ - "§ Casing Deacnphon String 0„ Skiing ID... Top(KKB) Set Depth (1.. Set Depth (TV0)... Siting Wt,,, 81009,,, String T09 Thrd cowoucTGR i PRODUCTION 7 6.276 35.0 7,224.9 6,314.4 26.00 J-55 BTC 36a 16 -- - T Strings 1 Tubing 000069tion String 0... String ID ...109(1148) (Set Depth (r. Set Oepih (V ..String 001... String .. S1tin9Tnp Thrd ' TUBING ( 31/2 ( 2.992 1 35.0 ` 6, ( 5, 936 . 8 ( 9 . 30 J 1 EUE8rdAB MOD SAFETY WV. -- Completion Details 1,1#0 Top Depth DAP TOOL, € (rve) Top in l Nora.. 1.803 i _ T op (RKB) (RKB) S °! nom DescA •flan Comment IDP ) t PP s 35.0 35.0 -0.06 HANGER McEvoy TbgHanger 2.992 [ 1,802.7 1,802.7 -2.79 SAFETY VLV Camco'iRUP- tASSA' (Set DAP TOOL m14,'29195) NOTE: SSSV 2.812 GA S 1395, € hydraulics are disconnected at the tree. TROP is functional - two closure 2,492 I tests 7/4/99. Dap Sleeve not across flapper -- MUST!! maintain control Hine pressure. Drifted sleeve to 1.925 ". Cannot maintain SSSV control line pressure - LEAK DOWNHOLE. Tracks tubing pressure. Disconnected panel from tree, tagged at wellhead 4/8/2001 The SSSV is NOT locked cut, 5!23+2002 6,670.7 5,867.4 36.22 PBR Baker 3 1/2' PBR 3.000 svRFACE. -. 6,684.4 5,878.4 36.20 PACKER BAKER 3 1/2 x T' FHL PKR (750004 pull or ro(. re)) 3.000 56 -3,'a' 6,723,2 5,909.8 36.14 NIPPLE CAMCO31/2' D' Nipple 2.75" ID 2.750 6,755.7 5,936.0 36.09 SOS BOT 3 12" Shear Out Sub 2.992 GA + a'805 Other In Hole (Wireline retrievable plugs, Valves, pumps, fish, etc.)' Top Depth (7010) Top Inc! Top INKS) IRKS) (*) Description - Comment Run Date 10 (in) GAS LIFT, 1,802.7 1,802.7 -2.79 OAP TOOL DAP Tool installed on 4/29/95 (150.5" TL, 2.85" No Go, 429/1995 2.460 0 03 ID= 2.46); 7,030.0' 6,157.6 36.47 FISH Flapper Seat From surface line check valve - lost, probably 11/2011999 downtole. OAS U91. 2 %°- 7,032.0 6,159.2 36.47 FISH 5 GRAPPLES -1" X 5/11/1995 6. 63 i�- -- 1,036.0 6,162.5 36.47 FISH Baiter Left in Hole 9/6/1988 Perforations & Slots PBR, 6,17! ® Shot Top (ND) Btm (ND} Dens PACKER.6,654 „,r, -„�,. [>,. Top(ttOB) Blm(R68) (RKB) pole) Zone Date (sh -. Type Continent 6,832.0 6,846.0 5,997.7 6,009.0 C -4, 31-1-12 8/30/1988 12.0 2 1/8" EnerJel, 30 deg ph '.. 6,880.0 6,890.0 6,036.5 6,044.6 A -3, 3H -12 8!30/1988 12 0 PERF 2 1/8" EnerJeL 30 deg ph '.. 6,904.0 6,914.0 6,055.6 6,0638 A -2, 3H-12 921/1988 12.O 2 1/8" EnerJet, 30 deg ph 139909,6iza 6 ,934.0 6,954,0 6.080,0 6,096.2 A -1, 3H -12 5/14/1988 4,01IPERF 4 112" UitraPak, 120deg. pH;3shots mis Notes': General & Safety' .-' ' End Dale Annotation 505, 6.756 .�..;�. 923,2010 NOTE BROKEN FLAPPER IN SSSV x,1803 10/4/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemalic9,0 PEHF, 6,63x6,646 l x } PERF, 6.6806,836 I916F, . - 0,0046.0f 4 IRF, 6,933691954 1 9158, 7.030 A. Vf Mandrel Details Top Depth Top Port 9/5 8. 7,032 (TVD) Inc! OD Valve Latch Size TRO Run 5(n Top MKS) ( I") Make Model (In) Sery Type Typo (in) !psi) Run Dale Com,_ 1 2,491.8 2,471.1 24.83 MCM0... FMHO 1 GAS LIFT DMY BK -2 9000 0.0 5/15/1988 2 4,645.1 4,240.2 36.86 McMu..'FMHO 1 GAS LIFT DMY HK -2 0.000 0.0 5/15/1988 9308.1,036 3 6,102.7 5,409.1 36.38 McMu... FMHO 1 GAS LIFT 0MY BK -2 9000 0 . 0 5/15/1988 4 6,632.2 5,836.4 36.28 Camco MMG-2 11/2 GAS LIFT DMY RK 0.000 90 527/1988 I PROOOCT■SN, 35-7,225N ■■ TO, 7.28a `~J COI'lOC ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission -a _ ~ ~;,.~ 333 West 7~` Avenue, Suite 100 `~~''~"~' }~~"` '' ` _~"' Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ E~~ ~~~ ~4~~ ~~- Enclosed please find a spreadsheet with a list of wells from the Kupasuk 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 July 30~' 2009 and the corrosion inhibitor/sealant was pumped August $~`, 9~' and 10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (70-404) Kuparuk Field Date 08/11/09 ~n_ ou ~v o~n o_~ WeII Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date bbls al 3G-12 50103207310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 78" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30l2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8!8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 ~ MEMORANDUM To: Jim Regg ~~~ 7~2Z ~^~ 7 P.L Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-12 KUPARLJK RIV UNIT 3H-12 Src: Inspector NON-CONFIDENTIAL Reviewed By~ P.I. Suprv ~ Comm Well Name: KUPARUK RN iJNIT 3H-12 Insp Num: mitCS090608145246 Rel Insp Num: API Well Number: 50-103-20088-00-00 Permit Number: 187-129-0 , Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3H'~~ Type Inj. N ~ 1871290 hSPT P.T.D TypeTest I ----~--------~ 8 TVD J~ Test psi ~ 78 ` 5 1500 '~ IA ~ ~too ~~6o QA 1 0 ~ 0 , zioo ~ zioo - 0 0 -- - Interval a~TST p~ P " ' Tubing ~ 2oso zzso 2z~s zz~s NOtes' Pretest pressures observed and found stable. Injection shut in recently, well still in warm condition. ~~~';Fp4-,~ ~i !i": G ~;; ~~~('~t'~ .. V. . . , _ _ . .. .. .. ._ ~A, i Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM ) ') State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '-:J ( P.I. Supervisor "'11' ,~I kl ¿G DATE: Wednesday, June 14,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-12 KUPARUK RIV UNIT 3H-12 (; \'61--1?-- FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3H-12 Insp Num: mitJCr060613123727 Rei Insp N urn API Well Number 50-103-20088-00-00 Permit Number: 187-129-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -Well TTII-1-2]!ype Inj. I w ¡ TvD---i 5878 -TIA ¡ 1250 i -'mo-'T 1880 iï-s:ro-'T- I' P.T. : 1'7I~~:.JTYpeTest I SPT !. Tes~t psi .LI500 I OA I~. 400 _+.~ _,I .380-=71---- 1, _~=-= IntervaL_~_:~:~UST_,.__,_ PIF __~_,._.___,__~ubing ! 2725 I 27=- i 2725 !~_~.:_,___,~____ Notes 1.9 bbl's pumped for test SCANNED JUN 2 7 2006 Wednesday, June 14,2006 Page 1 of 1 · I :JEt- 4j~ Db Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us ') STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) / ~'. 7 '- fZ,,? OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparukl KRUI 3H 03/15/05 Brake/Rogers - AES Well 3H-12 Type Inj P.T.D. 1871290 Type Test Notes: Diagnostic MITIA SWI P Packer T.V.D. T est psi Depth 5878 1500 Tubing Casing Pretest Initial 15 Min. 30 Min. 2250 2250 2250 2250 Interval 1000 3000 2950 2590 P/F o P Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: SC/~NNE[) l~PR 2 0 Z005 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 MIT KRU 3H-12 03-15-05.xls 3/16/2005 MEMORANDUM State of Alaska Alaska Oil and Gas Consentation Commission TO: Camille Taylorf~ DATE: June 27, 2002 Chair ~~..~ · SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska inc. P.I. Supervisor"-'"' "~~ --I\~C;~ 3H multiple FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ' WellI 3H-02 ITypelnj.! N I T.V.D.I 5759 I Tubi'ngi 75oI 7ool 700 !"'7oo Ilnterval'l .P:,,T.D.I 1871070 ITYPe, testl Pi .... J,TeStpsil 4440 I Casingl ~225'I 2100 ! 2075 I,,,2o75 I P/F Notes: Well is curr,ently shut in ............. I WellI 3H-06I TYp~,nJ.I s J T.V.D. 15798 I Tubing I 1450 t ~.o I ~.o i ~o I lntervall' 4 "Notes:PTDl''" 1870780 ITyP~teStl ,'P ITestPsil 1449 I dasing'l '1025 .......... I 2050 I 20~0 ! 2025 l"'p/F i_,,IP''' WellI 3H-07 'l'~¥pelnj.'l G I"f;V.o. I 5790 Ifbbingl '318o.I ~5o ! s,~o' !' ~o I,nte~vail 4' '"P.T.D.I 18707'90 I'i'~petestl'" P I'Testpsil 1448 ld'asing"l '2:~5° I i9'50"! 1950 I 1950' I" 'P/F I --P 'Notes: Draw down was performed :verY'us pressure build up .... 'We,I 3,-o9' I T~pe,ni.'l' 'G I T.v.D. !~, I T'Ub~ng'!~o0 i '~0o' i ~oo-i ~o0'I~"te~va,! "4 P.T.DiI 187'1120"lTyp~testl' P ITe.~tpSil 1432 I casi'ngI 2125 I 275°'1 '2750 I 2750I P/F' I '-EP Notes: we,I 3H-~2 IType,n).! 'G' )T.V.D. I 5878 III I,hterva, I 4' P.T.D.i 1871290. ITypetestl ' 'P ' i'Test psil 1470 l Ca~i'ng I '585o"1 3300 I '3300' ,I, 3275 I piE' i P' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page I of 3 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 dudng Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: none Number of Failures: _0 Total Time during tests: 3 hrs,. CC,: n,one MIT report form 5/12/00 L.G. mit(l) kru 3h 6-27-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 76 feet 3~ Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 servi~__x Kuparuk Unit 4. Location of well at surface 8. Well number 1204' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM (asp's498655, 6000451) 3H-12 At top of productive interval 9. Permit number / approval number 1320' FSL, 1208' FWL, Sec. 1, T12N, R8E, UM 187-129/ At effective depth 10. APl number 50-103~20088 At total depth 11. Field / Pooh 3712' FNL, 4060' FEL, Sec. 1, T12N, R8E, UM (asp's499591, 60o3222) Kuparuk Oil Pool 12. Present Well condition summary Total depth: measured 7298 feet Plugs (measured) true vertical 6373 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 245 sxAS ~ 115' 115' SURFACE 3027' 9-5/8" 13oo sx AS m & 4O0 sx C~ass G, 1 3103' 2985' PRODUCTION 7149' 7" 32O sx C~ass G 7225' 6314' Tubing (size, grade, and measured depth) ========================================================================================================================================================= .................................... Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary :::: ::: ::::: .:::::::;:: ::::-: ::::: ::::::::::::::::::::::: ::::::::::::::::::: :::::: :::::::::: :::::: :::.:: :::::::::::::::::::::::::::::::::::::::::: :::::::::::::: :: :::::::::::::::::::: :::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::: Treatment description including volumes Used and'final pressure ............................ 14. Representative Daily Average Production or Injection Data Gas-Mci OiI-Bbl Water-Bbl Casing Pressure Tubing Pressure Prior to well operation !i! :': · -: - - :- :-:': :- ': -: :- :': - :- :' :' -::- :' :-: :- :-: :- .': .... ; :':-: :- :-.:'. .... :-:':-:' ' -:-: :':: ....... :':-:':-: :-:--: :-: :-: -: :' · :-: >:':-: .... :':: ..... :':-:+:- -:- ' :' ': ..... :-:' - ':-:- :-' -: ..... ::- -- .: ........ : :-:.:-:.:-: ::::::::::::::::::::::::::: :,: :-:.:-: 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed . Title Production Engineering St~pervisor Date~ Jeff A. Spencer Prepared by Robert Christensen 659-7535 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 3H-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/20/011Commeqc,~ ,W~G: EOR. InjeCtion MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Other 1. Type of Request: Operation Shutdown Pull tubing __ Stimulate X Plugging__ Perforate Alter casing Repair well Pull tubing __ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1182' FNL, 281' FWL, SEC. 12, T12N, RSE, UM At top of productive interval 1361' FSL, 1235' FEL, SEC.2, T12N, R8E, UM At effective depth 1506' FSL, 1351' FEL, SEC.2, T12N, R8E, UM At total depth 1571' FWLr 1404' FELt SEC.2r T12Nr R8E~ UM 12. Present well condition summary Total Depth: measured true vertical 7370' feet 6 2 6 9' feet Plugs (measured) 6. Datum elevation (DF or KB) 76' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number :~H-I:~ 9. Permit number/approval number ~7-129 / AI;).Drv. N/A 10. Apl number 5o-103-2008900 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 72 4 0' true vertical 6091 ' feet Junk (measured) feet Casing Length Structural Conductor 80' Surface 3 0 3 7' Intermediate Production 7 3 0 7' Liner Perforation depth: measured 6935'-6959', 6968'-6978', true vertical 5927'-5946', 5953'-5961 ', Size Cemented 1 6" 245 SX AS I 9-5/8" 1300 SX AS III & 400 SX CLASS G 7" 300 SX CLASS "G" & 175 SX AS I 6980'-6985', 6985'-7007', 5962'-5966', 5966'-5984', Tubing (size, grade, and measured depth) 3 1/2" 9.2# J-55 ABM, 6847' MD Packers and SSSV (type and measured depth) BAKER FHL @ 6777', CAMCO TRDP-1A-SSA @ 1801' Measured depth 115' 3072' 7342' True vertical depth 115' 2931 ' 6247' 7020'-7040' MD 5995'-6010' TVD RE6EIVED 13. Stimulation or cement squeeze summary A SAND FRACTURE STIMULATION Intervals treated (measured) 6968'-6978', 6980'-6985', 6985'-7007', 7020'-7040' Treatment description including volumes used and final pressure SEE A'I-I'ACHED WELL SERVICE REPORT SUMMARY d U L - 9 199 ^laska 0il & Gas Cons. tomtitss~'°t~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Avera0e Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -0- -0- -0- 1084 438 176 1023 1453 Tubing Pressure 137 137 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas ~ Suspended ~ Service 7. I he~er~a~i foregoing is, true and correct to the best of my knowledge. Si~ned P~ Title Sr. Petroleum Enqineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 'IS~ SL6S QNflO~ 2~2M SNOI~N2DNOD HgIH NI S2~flgS2~ 9NIA~2~Z £6' 6g8~ ~Z OIZ 96' IE6E §~ 099 ~' 019~ ~E 09 HSfl~ 98' £~ ~ ~E 9~' ~9ZE O~ O~I O~ ~ISI ~A~ ~OA '~OB~M ~I-H~ H£-SG £-~D zs/sz/so oz AH~NN~IS Z~O~.~ 9NINHON STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate m Plugging Perforate Convert Pull tubing Alter casing Repair well Pull tubing Other X to WI well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 1207' FNL, 281' FWL, Sec. At top of productive interval 1292' FSL, 1175' FWL, Sec. At effective depth 1474' FSL, 1202' FWL, Sec. At total depth 1565' FSL, 1216' FWL, Sec. 99510 12. 5. Type of Well: Development Exploratory Stratigraphic Service 12, T12N, R8E, UM 1, T12N, R8E, UM 1, T12N, R8E, UM 1, T12N, R8E, UM Present well condition summary Total Depth: measured 7 2 9 8' true vertical 6373' Effective depth: measured 71 4 4' true vertical 6249' Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-12 9. Permit number/approval number 88-725 10. APl number 50-103-20088 76 feet 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) feet Cement: 7144' 7225' feet Junk (measured) feet 4' Bailer in rathole. Top at 7036' MD Cemented Measured depth True vertical depth 80' 16" 245 Sx AS II 1 1 5' 1 1 5' 3069' 9 5/8" 1300 Sx AS III & 3103' 2986' 400 Sx Class G Top Job w/90 Sx AS I 7190' 7" 320 Sx Class "G" 7225' 6314' 175 Sx AS I measured 6832'-6846', 6880'-6890' 12 SPF 60 degree phasing, 6934'-6954', 4 SPF 90 degree phasing true vertical 5998'-6008', 6036'-6044', 6080'-6096' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55, set at 6757' Packers and SSSV (type and measured depth) Baker FHL Packer @ 6684', Camco TRDP-1A-SSA SSSV @ 1803' 13. Stimulation or cement squeeze summary Intervals treated (measured) Well was converted from oil producer to water injector. Procedure and MIT record are attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 470 430 0 400 psi 0 0 -2600 720 psi 16. Status of well classification as: Oil Gas Suspended 190 psi 1920 psi Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title ~,' t" ':4,~ Date ARCO Alaska, Inc. Date' February 17, 1989 Transmittal Ct: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F o 11 Sub-Surface Pressure Survey I 0- 0 6 - 8 8 3 H- 1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8 3 O- 07 Kuparuk Well Pressure Report 1 2- 2 0 ~ 8 8 3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 06 Kuparuk Well Pressure Report 8- 2 9 - 8 7 3 F- 02 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7 3 F- 11 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 04 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F- 05 Kuparuk Well Pressure Report 1 2 - 1 2 - 88 3 F- 1 3 Kuparuk Well Pressure Report 1 2 - 3 1 o 8 8 3N-10 Kuparuk Well Pressure Report 6- 1 1 - 87 3 N- 1 0 Kuparuk Well Pressure Report 6- 11 - 8 7 3 N- 04 Kuparuk Well Pressure Report 9 - 01 - 8 7 3 N - 09 Kuapruk Fluid Level Report 5 - 04 - 8 7 30-14 Kuparuk Fluid Level Report 2- 1 3 - 8 9 30- 14 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3M-1 8 Kuparuk Fluid Level Report 2- 1 0-8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 13 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 F- 13 Kuparuk Fluid Level Report 6 o 1 8 - 8 7 3 F- 13 Kuparuk Fluid Level Report 6 - 1 6 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F- 08 Kuparuk Fluid Level Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 1 8 o 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 2 4- 8 7 3 F- 13 Kuparuk Fluid Level Report 6 - 05 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 2 / 3 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F- 14 Kuparuk Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Anchorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Ku3aruk Fluid Ku3aruk Fluid Ku3aruk Fluid Ku3aruk Fluid Ku3aruk Fluid Ku )aruk Fluid Ku 3aruk Fluid Ku3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku :)aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku :)aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku3aruk Fluid Ku :)aruk Fluid Ku :)aruk Fluid Acknowledged: Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )orr Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )ort Re )orr Re )ort Re 3ort Re )ort Re 3ort Re 3ort Re 3ort Re 3ort Re 3ort Re 3ort Re 3ort Re :)ort Re :)orr Re 3ort Re 3ort 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing DISTRIBUTION: D&M State of Alaska Mobil Chevron Unocal SAPC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coM'~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well I 1.Status Ot Well ............................. OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-129 , , 3. Addres~ 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20088 4. Location of well at surface 9. Unit or Lease Name 1207' FNL, 281' FWL, 5ec.12, T12N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1292' FSL, 1175' FWL, Sec. 1, T12N, R8E, UN 3H-12 At Total Depth 11. Field and Pool 1565' FSL, 1216' FWL, Sec.1, T12N, R8E, UN Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Pool 76' RKB ADL 25531 ALK 2657 12. Date Spudded~ ,1 2/28/~ ~" 13. Date T.D. Reached01/01/88 14' Date C°mp" Susp' °r Aband' ~ 15' Water Depth' if °ffsh°re 116' N°' °f C°mp'eti°ns07/13/88' N/A feet MSL 1 ~ 7. Total Depth (MD+TVD) 18. Plug Back Depth (M~D, 19. Directional Survey I 20. Depth where sSsv set ~ 21. Thickness of Permafrost 7298'MD/6373'TVD 7144'MD/6249'TVD YES~ NO ~ 1803' feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, CAL, GR, GCT, CET 23. CASING, LINER AND CEMENTING RECORD , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" ~= ~ ~ AS I 9-5/8" ~R.n~ ~-~ ~""~ ~"~"' I ....... i~" AS iii & 400 sx Ciass G '" Top Job w/~u ~x AS i 7" 26,0~ J-~ ~"~¢ 7225' 8-!/2"' 320 ~x C]6os G & 175 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECO'RD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-I/2" 6757 Perforated w/6 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 6831 '-6845'MD/5996'-6007 'T~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6879' -6889 'MD/6035 ' -6043 'TVD 6904 ' -6914 'MD/6055 ' -6063 'TVD ..... O~lllllIO I Perforated w/4 spf, 45° phasing ~. ..... , .~r fracture uoLo. 6934 ' -6954 'MD/6080 ' -6096 'TVD ,,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL 'GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tu~ing 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. None * NOTE: Drilled RR 1/3/87. Perforated well and ran tubing 5/15/88. Fractured well 7/13/88. Added perforations 8/30/88 & 9/21/88. Submit in duplicate Form 10-407 WC5/050 R.v 7_l-Rn CONTINUED ON REVERSE SIDE ~./ 29. ~. ..... :) 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, ali fluids recovered and §rarity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6832' 5997' N/A Base Kuparuk C 6847' 6009' Top Kuparuk A 6867' 6026' Ba se Kupa ruk A 6998 ' 6131 ' 31 LIST OF ATTACHMENTS 'Addendum (dated10/26/88) & Stimulation Summary (dated 7/13/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~J~ ~/ TitleArea Drilling Engineer Date ]~/~/~ 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- lng 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 10407 ARCO Alaska, Ir". Subsidiary of Atlantic Richfield ,_~ '//-/- .Z/ ~-. 1PBDT WELL CONTRACTOR ~?c - R~:MARKS fFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPOF :DAYS i DATE / .,,/-/,o-- ~ ~ / /J"~o [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport. Temp. "F [ Chill Factor j VisibilitYoF! miles il Wind Vel' I Signed knots, ~. ~". ~a ~ ~ REMARKS CONTINUED: " _. CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision /CPc Pre-Job Safety Meeting TOTAL FIELD ESTIMATE DESCRIPTION DAILY ACCUM. TOTAL 2 ?~ KUPARUK STIMULATION SUMMARY WELL: ~ ~-~'~ TUD 4) PERFS: MI) · PERFS: ~oc¥~q / HOLE ANGLE 4)-PERFS: '~* SAND PERF INTERVAL ~.~ ~c~q -~ ~q ' COMPANY DATE: "7..- I~,- CONTRACTOR: ARCO AEP: AFE #: ~ W- ACTUAL UOLUME RATE PRESSURE DESIGN PROP. PROP. ANN. VOLUME si P. HZ WHTPA: 3'.~ ! ~/~ ISlP: l?SO / / / il'7 .A2..~I lq,~' So-/o/~ /~,~ ~/ ~.~ , I i i / i i · - / ii i sir ~"/~.o EFF. SLURRY: SlO FAAC IRAD: TBB.FRIC: PEAF FAIC: EFF. PROP: ~t~4 S p,s., LOG I~EAVAL: --~ ~A. FLUID ~MP: FLUID VISC: LEAK OFF: 5 MIN. ~J ~ .,, I0 MIN. ~ 15 MIN. , A/~,, ADDENDUM WELL: 5/29/88 7/19/88 8/30/88 8/31/88 9/21/88 3H-12 RU HBR. Pmp 20 bbls diesel + 5% Musol. Pmp 64 bbls diesel. Displ diesel/Musol to perfs @ 6934'. SI well & RD. RU arctic coil tbg. Press. test. RIH. Tag sand @ 5000'. Clean through 500' bridge. RIH. Clean out to 7110'. Short trip to tbg tail. POH and displace well to diesel. RU Schl. Perf well f/6831'-6845' @ 6 SPF. Perf 6879'-6889' @ 6 SPF. Flow well to cln out perfs; well did not flow. POOH; well inadvertently opened to production facility w/perf string close to surface and surge caused perf string to stick just below lubr across swab and master vlvs. Remove flow line and RU to kill well. Bleed well dn to ±100 psi. Closed in and bullhead 70 bbls filtered sea wtr, followed by 68 bbls 10 ppg brine @ max pressure of 2000 psi/max rate of 5 BPM. Well dead. Close SSSV, pull lubr loose f/tree. Pull bird nest from top of tree; tls fell clear of tree. Secure well. WL pulled out of rope socket w/WL fsh looking up. RU Schl. Open well, perf 6904'-6914' MD @ 6 SPF, 30° phasing. Turn well over to Production. 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L~...i4 ..... i...;.,LLL.L.Li...i...14..X...L.J...Li4...i ....... i....14...~4.-.X4...i...l..Li4....!., i.--~ --~.-i-..i ...... 1444--l---i--.Li---L14-.bl-..-!..-l..-i..-.L.i4 ....... i4...i4---l..-i..-i4..-i .... .,-bbf-+.M.-++.i-i4.-bbbi.~;~ ~-i.-b~-+.;-~4-~;.i-.H.+.~.b,-i+-bl-;-~...~ ....... i...,..~-.+.;.i...H-b~-H.+,4...H.+.H.++++4-H-H.4-H .... 4--H.-., ....... G+H4...!...~4+!.+.bb FYH..H444..-b:-bbbH4.-H-+H.--f4-.H-.4..-b~--.! ...... · 4...~.4.4 ..... bH-4...Hr~H-..H...>b.H-..H.-.H4.-.i ....... i...H ....... t--H4-.-H-4-+.bi--.H---u.-;--4 ...... H-.-, 4--i"++'H-"t'++'+--%'--H-'-i--'~ ...... H---N.--f+-bH--.~ 20. m i! ..~ PROJECTION ON VERTICAL PLANE 20. - 2P.O. SC~_ED IN VERTICAL DEPTHS HORIZ SCALE = 1/SO0 IN/FT ARCO Alaska, Inc. Date: October 14, 1988 Transmittal #: 7316 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3H-12 3H-12 3H-17 3H-22 2C-11 3H-14 3F-13 3C-16 3K-06 Sub-Surface Pressure Survey Sub-Surface Pressure Survey Sub-Surface Pressure Survey Bottom-Hole Pressure Survey Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report 9 - 2 2 - 8 8 PBU 9 - 2 2 - 8 8 PBU 9 - 2 2 - 8 8 PBU 8 - 0 7 - 8 8 PBU 1 0 - 0 6 - 8 8 Casing 1 0 - 0 7 - 8 8 Tubing 1 0 - 0 7 - 8 8 Casing 1 0 - 0 7 - 8 8 Casing 1 0 - 1 I - 8 8 Casing Receipt Acknowledged: DISTRIBUTION; D&M -'~ State of Alaska' Chevron Unocal Mobil. SAPC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing _ Variance _ Perforate _ 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 1207' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1292' FSL, 1175' FWL, Sec. 1, T12N, R8E, UM At effective depth 1474' FSL, 1202' FWL, Sec. 1, T12N, R8E, UM At total depth 1565' FSL, 1216' FWL, Sec. 1, T12N, R8E, UM X 12. Present well condition summary Total Depth: measured true vertical Other 6. Datum elevation (DF or KB) RKB 76 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-1;~. 9. Permit number 10. APl number $0-103-20088 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7298' feet Plugs (measured) 6373' feet Cement: 7144'-7225' Casing Structural .Conductor Intermediate ..EE0._d u ctio n_ Liner Perforation depth: 71 44' feet Junk (measured) 6249' feet 4' Bailer in rathole. Top at 7036' MD Cemented Measured depth True vertical depth Length Size 1 6" 9 5/8" 80' 3069' 71 90' 7" 245 Sx AS I 1 1 5' 1300SXASIII & 3103' 400 Sx Class G Top Job w/90 Sx AS I 320 Sx Class G & 722 5' 175 Sx AS I measured 6832'-6846', 6880'-6890' 12 SPF 60 degree phasing, 4 SPF 90 degree phasing 5998'-6008', 6036'-6044', 6080'-6096' TVD 6934'-6954' true vertical Tubing (size, grade, and measured depth 3 1/2", J-55, set at 6757' Packers and SSSV (type and measured depth) Baker FHL Packer @ 6684'~ Camco TRDP-1A-SSA SSSV @ 1803' Attachments Description summary of proposal _ Detailed operation program X.~ 115' 2986' 6314' 13. Convert well from oil producer to water injector. 14. Estimated date for commencing operation September, 1988 16. If proposal was verbally approved (Wellbore schematic attached). Date approved 15. Status of well classification as: Oil __ Gas __ Suspended Service Water Injector Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned Title , FOR COMMISSION USE ONLY IApprov~ No. Date /~- 2'Z-~' SUBMIT IN TRIPLICATE Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ~ ,, Subsequentx=lorm.~require 10-.~-)~ Approved by the order of the Commissioner . ~-' _.. Commissioner Form 10-403 Rev 06/15/88 '--'/ ~. "~ Approved Copy ~eturned ~; Well 3H-12 Conversion to Water Injection 1. The proposed procedure is attached. , No BOPE will be necessary to convert the well to water injection service. , The static bottomhole pressure will be acquired by taking a WHP/FL prior to the well's conversion. The reservoir pressure is estimated to be 2300 psi based on the producing GOR. 4. No workover fluid will be used. 3H WATERFLOOD CONVERSIONS GENERAL PROCEDURE . . . . Obtain final 12 hour well test. Check to insure that the sundry notice for converting the well to water injection has been approved by the State (Erin · ext. 6523). SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2" meter runs, and calibrate instrumentation. Notify the State of the upcoming Mechanical Integrity Test. After 72 hour shut in, contact Engineering (ext. 7525) to record wellhead pressure and shoot tubing fluid level. Conduct MIT. Packer depths and required 7" annular pressures are shown in the table below. Bleed the annulus to 500 psi after completing the test. Send a copy of the WSR and the State's MIT form to S. Twiggs at ATO 1130. WELL 3H-07 3H-09 3H-12 3H-22 DEPTH (TVD) OF PACKER 5789' 5727' 5877' 5950' REQUIRED CSG PRESSURE FOR MIT (PSI) 2084 2062 2115 2142 . The targeted injection rates and estimated set pressures are summarized below. After the initial trial, modify the injection set pressure to more closely match the desired rates (+/- 500 BPD is fine). WELL 3H-07 3H-09 3H-1 2 3H-22 DESIRED INITIAL INJECTION RATE (BWPD) 5000 7000 5000 3000 ESTIMATED SET PRESSURE (PSI) 1200 1200 1500 1500 . The above set pressures and rates will apply only until the STP begins winter time operation. Then the injection rates will be increased. ARCO Alaska Inc, Is a subsidiary o! Atlantic Richfield Company AR3B-6001-A WELL 3H-12 SURFACE LOCATION: 1207'FNL, 281'FWL, SEC 12, T12N, R8E, UM TREE: McEVOY 3-1/8" 5000 PSI APl #: 50-1 03-20088 DEPTHS: REFERENCED TO 0' RKB REVISION: 9/9/88 TUBING SPOOL ELEV: 35' RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3103' PBR: BAKER 2.992" ID @ 6671' PKR: BAKER FHL 2.992" ID @ 6684' NOGO: CAMCO 'D' NIPPLE 2.75" ID @ 6723' C B A3 A2 A1 7": 26# J-55 @ 7225' L SSSV · Camco TRDP-1A - SSA ID 2.812" @1803' McMurry FMHO GLMs (BK-2 Latches) GLMI' 2492'/ 1.0" GLM2: 4645'/ 1.0" GLM3:6103'/ 1.0" Camco MMG II GLM (RK Latch) GLM4: 6632'/1.5" 3.5" 9.2# J-55 BTC ABMOD IPC TUBING TAIL @ 6757' HOLE ANGLE ACROSS KUPARUK = 36.5° 6832' 12 SPF 6846' 6880' 12 SPF 6890' 6934' 4 SPF'-~' .... , 3~ ~.~ 6954 .... ~ FISH: 4' BAILER ' ~4 .:,':~ ~-.: ~,-::.; Tagged @ 7036' (163' Rath°le) PBTD: 7140' STATE OF ALASKA ALASK'-' OIL AND GAS CONSERVATION COMM,..,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing ~ Other ~ COMPLETE 2. Name of Operator 5. ARCO Alaska, Inc. 3. Address 6. P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 7. 1207' FNL, 281' FWL, Sec.12, T12N, R8E, UN At top of productive interval 1292' FSL, 1175' FWL, Sec. 1, T12N, R8E, UN At effective depth 1474' FSL, 1202' FWL, Sec. 1, T12N, R8E, UN At total depth 1565' FSL, 1216' FWL, Sec. 1, T12N, R8E, UN Operation shutdown [] Stimulate [] Plugging ~ Perforate ~ Pull tubing Datum elevation (DF or KB) RKB 76 ' Unit or Property name Kuparuk River Unit Well number 3H-12 8. Approval number 8-20 9. APl number 50-- 103-20088 10. Pool Kuparuk River Oil Pool Feet 11. Present well condit Total depth: ion summary measured true vertical Effective depth: measured true vertical 7298 'MD feet Plugs (measured) None 6373 ' TVD feet 7144 'MD feet Junk (measured) None 6249 ' TVD feet Casing Length Size Conductor 80 ' 16" Surface 3069' 9-5/8" Production 7190' 7" Cemented Measured depth 245 sx AS I 115'MD 1300 sx AS III & 3104'MD 400 sx Class G Top job w/90 sx AS I 320 sx Class G & 7225'MD 175 sx AS I True Vertical depth llS'TVD 2986 ' TVD 6314 'TVD Perforation depth: measured 6934'-6954'MD true vertical 6080 ' -6096 'TVD 12. Tubing (size, grade and measured depth) 3½", J-55, tbg w/tail @ 6757' Packers and SSSV (type and measured depth) FHL pkr (~ 6684'& TRDP-1A-SSA SSSV~ 1803' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JUN 1 0 1988 Alaska 011 & Gas Cons. Comm/ss[orl Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj, ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion We.l.1 History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~E] Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer Date (Dani) 5W03/85 Submit in Duplicate ARCO Oil and Gas Company,~, Well History - Initial Report - Daily Instructions: Prepare end submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are sashed. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District 3LRCO Alaska, ];nc. Field KUPARUK RIVER FIELD Auth. or W,O. no. AK2556 ICounty, parish or borough NORT['I SI'.OP~. - KO?~,UI( Lease or Unit ADL: 25531 Title COMPLETION 3H-12 IWell no. APl: 50-103-20088 Operator ~CO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. o5/15/88 ( TD: PB: 7140 SUPV:DL I Date IHour 05/14/88 I1845 Complete record for each day reposed NORDIC 1 ARCO WI 56.0000 IPr or status f a W.O. TEST HANGER & CONTROL LIN 7"@ 7225' MW:10.0 NACL/NABR MOVED RIG FROM 3H-11 TO 3H-12. ACCEPTED RIG @ 1845 HRS, 5/14/88. ND TREE. NU BOPE AND TESTED TO 3000 PSI. RU SCHLUMBERGER & PERFORATED 'A' SAND W/4 SPF, 135 DEGREE PHASE F/6934'-6954'. RIH WITH 3-1/2" COMPLETION EQUIPMENT. MU HANGER. TEST CONTROL LINE TO 5000 PSI. DAILY:S39,669 CUM:$725,843 ETD:S39,669 EFC:$2,023,174 RECEIVED JUN 1 0 1988 Alaska 011 & Gas Cons. Commission Anchorage The above is correct Signature ~, I Date For form preparation and/~istribution, see Procedures Manual, ~dllction 10, Drilling, Pages 88 and 87. AR3B-459-1-D INumber all dally well history forms consecutively as they are prepared for each well. iPage no. ARCO uti 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 RaperS" form may be used for reporting the entire operation if space is available. ARCO Alaska, Inc. NORTH SLOPE - KUPARUK J AK Field Lease or Unit KUPARUK RIVER FIELD ADL: 25531 Auth. orW.O, no. little AK2556 COMPLETE Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m, 05/16/88 TD: PB: 7140 SUPV:DL API: 50-103-20088 IA.R.Co. WI. 56,0000 IDate 05/14/88 Complete record for each day reported NORDIC 1 Accounting cost center code 3H-12 Iwelln°' Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our IPrior status if a W,O, I 1845 HRS RIG RELEASED 7"@ 7225' MW: 6.9 DIESEL TESTED CONTROL LINE TO 5000 PSI. LANDED TUBING. TAIL @ 6757', SSSV @ 1803', FHL PKR @ 6684'. SET PACKER. TESTED TUBING TO 2500 PSI. SHEARED PBR. TEST ANNULUS TO 2500 PSI. TEST SSSV TO 1500 PSI. SHEARED BALL @ 3100 PSI. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. TESTED CV TO 1000 PSI. SET BPV. SECURED WELL AND RELEASED RIG @ 1215 HRS, 5/15/88. DAILY:S134,630 CUM:$860,473 ETD:S174,299 EFC:$2,023,174 RECEIVED JUN 1 0 1988 Alaska 011 & (~,as Cons. C0mmissi0~l Anchorage Old TD I New TD Released rig I Date IPB Depth Kind of rig Classifications (oil, gas, etc.) ] Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test lime Production !Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ~2ftectlve date corrected p p 'o ~rJd distribution, For form re arab n see Procedures Manure', Section 10, Drilling, Pages 86 and 87. AS,9OClATE ENGINEER AR3B-459-3-C INumber ;ill daily well history forms consecutively as they are prepared for each well, iPage no. Dlvlllon o! AtlsnltcRIchfleldContpany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: February 29, 1988 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 7107 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '~3H-11 Cement Evaluation Log ~~~ Cement Evaluation Log ~3H-13 Cement Evaluation Log ~-3H-17 Cement Bond Log ~3H-14 Cement Bond Log ~ 3H-15 Cement Evaluation Log 2-15-88 5000-7534 2-15-88 4300-7108 2-15-88 4400-7228 2-19-88 6300-8470 2-17-88 3150-8102 2-17-88 5250-8330 Receipt Acknowledged: DISTRIBUTION: NSK Drilling GaS CODS. /~:, .... rage Date: State of Alaska(+sepia) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfietdCompany ARCO Alaska, Inc. Post Office Be 30360 Anchorage, Ala=~a 99510.0360' Telephone 907 276 1215 DaCe: january 28, 1988 Transmittal # 7071 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '"~ 3H-13 ~ 3H-13 .3H-13 3H-13 Colville Formation Micro Scanner Colville 2" & 5" Raw Data FDC Colville 2" & 5" Porosity FDC Colville 2" & 5" Dual Induction Colville 2" & 5" Dual Induction Colville 2" & 5" Porosity FDC Colville 2" & 5" Raw Data FDC 1-8-88 3200-3626 1-7-88 3072-3700 1-7-88 3072-3700 1-7-88 3072-3700 1-2-88 3104-3600 1-2-88 3104-3600 1-2-88 3104-3600 ~.-'-'"-'~Ataska Oil & Gas Cons. Commission Receipt Acknowledged. ~//. Date. DISTRIBUTION: West Sak Engineering NSK Drilling Geology D & M Franzen SAPC (+sepia) Unocal(+sepia) State of Alaska(+sepia) ARCO Alaska, Inc. is a Subsidiary of AUanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Da~e: Jauuary 28, 1988 Transmittal #: 7066 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3H-13 .OH Edit Tape and Listing 1-7-88 1/72567 ------ 3H-11 OH Edit Tape and Listing 12-25-87 t;72552 Anchorage Receipt Acknowledged: DISTRIBUTION: M. Stanford Date: '~' .iState of Alaska' ARCO Alaska. [nc. is a Subs[diary of Atlamt~cRicnfieidComl3anY · ' STATE OF ALASKA ALASK~ ,,.)IL AND GAS CONSERVATION COMMI,....,,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing F~ Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1207' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1320' FSL, 1208' FWL, Sec. 1, T12N, R8E, UM At effective depth 1480' FSL, 1216' FWL, Sec. 1, T12N, R8E, UM At total depth 1571' FSL, 1230' FWL, Sec. 1, T12N, R8E, UN ( app r o x ) ( appro x ) ( appro x) 5. Datum elevation (DF or KB) RKB 76 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-12 8. Permit number 87-12.9 9. APl number 50-- 10:~ -20088 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured 7298 ' MD feet true vertical 6366 'TVD feet Effective depth: measured 71 44 ' M D feet true vertical feet 6242 'TVD Length Size 80 ' I 6" 3069 ' 9-5/8" 7" Casing Conductor Surface Producti on 71 90 ' Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth 245 sx AS I 1300 sx AS III & 400 sx Class G Top job w/90 sx AS 320 sx Class G 115'MD 3104'MD 7225'MD 115'TVD 2988'TVD 6307'TVD Perforation depth: measured None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation M a r c h, 1 988 S"h~¥1,,~nt' ~er~ ~-~--'~.--~ --- -- - --~.V.L'"'v~ ~,-'~-~,~ v,,~.~, ,.. ,f ver a,, , a,p,'ove Name of approver Date approved 15. I.hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~Z,LL~t_/LJ Title Associ ate En(~ineer ~/ Commission Use Only (Dani) Date SA3/48 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity [] BOP Test [] Location clearance I b ORIGINAL SIGNED BY Approved Y I nMl~ll[: P RIIIlTH Form 10-403 Re~'"'~:l'-'~5" ......... Approved Copy Returned Commissioner by order of the commission Date / ~/~'~}~ Submit in triplicate 'Zg ~d~ 9~ seDed 'DUtlINQ '0~ uo loeS ' ~Y~kfl seJnpeooJd ees 'uoNnqpls!p pul/oll~JsdeJd LUJOJ Jod e~nleufll$ loeJJoo si e^oqe eqj. ~l NOXOQ (SI ( , (69 (6L ( (~9 peuodeJ &ep qoee Joj pJooeJ eleldtUoo ~H:A~QS ),86EL ) 88/~o/To ~H:A&QS ),86~L :G& ) 88/~0/~0 ~ ),T9~9 ) 88/T0/T0 ),~6~ ) LelT~/~T T ),SIT6 :O& ) Ce/O~/~ ),698I ) £8/6~/~I 0000 '9S J · r~ oOuvl · w'e 00:9 ~o se q~,dep pue eleO unpeg 'O'M .~o peppndS OD~ JOteJedO · ou ileMI BSOOB-EOT-OS :Ia~ O~HI& HHAIH HQH~aQH Pleld 'ouI '~:~I~ lOlJlSla · XlUO selsp eAIsnloul OUlAlO uJJoj eql uo pezHeuJuJn$ eq plnoq$ ~ulppnds ol Jopd ~Jo~ Xli~Q 'PelJEle eJe eUOllgJedo JeAO3JJOM JO peppnde el Ile/~ g JelJ~ J[.pseupeM IgJll eql uo ,,IJOdeU IllllUl.. eql tlwqns puc eJeOeJd :lUOll~nJllUl &Ilea - IJodet] lelllUl - ~JOlSlH lie/vt ~' &uedmoo se~9 pue I!000t:lV '~ii~ ARCo O,1 and Gas company Daily W "~'History Final Report Inslruclions: Prepare and submit the "Final Repo~r' on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or 8old. "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 "Finel Reporr' form may be u~ed for reporting the entire operation If space Is available. Accounting cost center code District I County or Parish ARCO Alaska, Thc. I NORTH SI',OPE - KOPRRUK Field ILease or Unit IWell no. KO?AROK RIVER FIELD I ADL: 25531 3}{-12 I Auth. or W.O. no. ITitle AK2556 I DRILL State API: 50-103-20088 Operator i A.R.Co. W.I. ARCO i 56.0000 Spudded or W.O. begun Date SPUD 12/28/87 Ol/O4/88 ( TD: 7298'( SUPV=RB Date and depth as of 8:00 a.m. Complete record for each day reported DOYON 14 o) Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our ' IPrl°r status If e W.O. I 1500 HRS RIG RELEASED 7"~ 7225' MW:10.0 BRINE RUN 182 JTS OF 7#, 26#, BTC CSG. CIRC AND CONDITION MUD. CMT 7" CASING. ND BOPE. SET SLIPS, INSTALL PACKOFF AND LOWER TREE. TEST TO 3000 PSI. OK. PUMP 55 BBL DIESEL FREEZE PROTECTION DOWN 3H-12. RIG RELEASED AT 2030 HRS 1/3/88. DAILY:S217,409 C0M:$686,174 ETD:S686,174 EFC:$1,337,000 Old TD Released rig Classifications (o11, gas, etc.) Producing method INew TD I PB Depth Date IKInd of rig I II Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature .: ~ ~/)~( ~t~~/ IDate ITM ' ) , /_/~-~ Associate Engineer For form prePm:a[/~'(/n and distribution, see Procedures IV~nual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 11, 1988 Transmittal #7057 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ ~~' ?"~ ~ 5" Dual Induction 1-2-88 3104-7286 ~"~~ 2" & 5" Porosity FDC 1-2-88 6580-7260 2" Dual Induction 1-2-88 3104-7286 ~~-._~' ~ . 2" & 5" Raw Data FDC 1-2-88 6580-7260 '--~~~ 2" & 5" Raw Data FDC 1-7-88 6700-7334 ~'-~3H-13 2" Dual Induction 1-7-88 1000-7360 ~ -'~3H-13 5" Dual Induction 1-7-88 1000-7360 "'- "~ 3H-13 Cyberlook 1-8-88 6800-7200 ~ ~ 3H-13 2" & 5" Porosity FDC 1-7-88 6700-7334 --' ~ -_33tvJJk~ Formation Micro Scanner 1-8-88 6800-7214 -~ ~-3H-10 2" & 5" Gamma Ray In Casing 12--5-87 967-3021 ~ "-C3H-11 Cyberlook 12-25-87 7050-7600 ~"~' "~ 3H-11 Formation Micro Scanner 12-25-87 7250-7724 ~ ~"[3H-11 2" & 5" Raw Data FDC 12-25-87 7050-7716 "'~" "~ 3H-11 2" & 5" Porosity FDC 12-25-87 7050-7716 ~' '~' 3H-11 5" Dual Induction 12-25-87 3633-7742 --~ 3H-11 2" Dual Induction 12-25-87 3633-7742 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M Lucille Johnston ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany State of Alaska (+sepia) December 17, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3H-!2 ARCO Alaska, Inc. Permit No. 87-129 Sur. Loc. ]207.'FNL, 281'FW]~, Sec. 12, T12N, R8E, UM. Btmhole Loc. 1473'FSL, 1264'F~L, Sec. i, T12N, RSE, ~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field'work, please notify this office 24 hours prior to.commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~~~ truly/yqur/~,, / ~, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASK~,,~OIL AND GAS CONSERVATION-,,..~MMISSION PERMIT TO DRILL 20 AAC 25.005 ,_ la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory E3 Stratigraphic Test [] Development Oil ~ Re-Entry ET] DeepenE~I Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska¢ Inc. RKB 76'~ PAD 39' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Ri var 0i 1 Poo P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531/~"~ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1207'FNL, 281'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ target) 8. Well nu.mber Number 1320'FSL, 1208'FWL, Sec. 1, T12N, R8E, UM 3H-12 #8088-26-27 ~..- .... -/~'~-tc-t~-i-~-e-~--'-<~ 9. Approximate spud date Amount ; 1473'FSL, 1264'FWL,I Sec. 1, T12N, R8E, UM 12/23/87 $500,000 l~f2-J-Di-S-f~'~b~"l:o--db~-r-~t'' 13. Distance to nearest well 14. Number of acres in property 15~ Proposed depth (MD and TVD property line 3H-11 180'ND 1264'@ TD feet 25' ~ Surface feet 2560 (6265'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~8~ . ~feet Maximum hole angle 380 Maximum surface 17~5 psig At total depth (TVD) ~040 psig 18. Casing program L. setting Depth size Specifications/ Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4 ' 9-5/8" 36.0~ J-55 BTC 3066' 35' 35' 3101 ' 3016' 1255 sx AS II I & HF-E~W 400 sx Class G blend 8-1/2" 7" 26.0f~ J-55 BTC 7146' 34' 34' 7180'! 6265' 200 sx Class G(minirnu~ HF-EJ~W TOC 500' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate 987 Production ~.', I-' L; -~ -, Liner Perforation depth: measured j.:~S~-,,.~ Oil & Gas C0fts, ~c.horag~, true vertical 20. Attachments Filing fee [] Property plat ~ BOP Sketch i~ Diverter Sketch,~ Drilling program ~ Drilling fluid program j~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ,,, 21. I hereby certi, f,y~at the forego~j,ng/i's true and correct to the best of my knowledge S~gned / ! ~ Title Regional Drilling Engineer Dat .4'./t,,~¢'~j.~ ssion ly ( A WM ) P D 2 / 63 ?' --/ ~' ,//__ /- //' - Commi Use On Permit Number J APInumber IApprovaldate ISeecoverletter ¢3'f-iP-') I 50-Y~*$"-20'0:~ '12/'17/87 for other requirements Conditions of approval Samples required [] Yes E~,-No Mud Icg required [] Yes Hydrogen sulfide measures [] Yes [~P'No Directional survey required [~;;P-Yes E;] No Required wo~~r-~,,~2~~ [] 5M; [] 10M; ~115M Other: by order of Approved by(~_ t._/,( ~/,.~~~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 / Submi/ ~te ARO0 ALASKA. Pad 3H. Nell No~ 12 Kuparuk Field, Nor th Propoeed Slope, Alaaka c m 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 0 S~RFAC~ B/ PERMAFROST TVD=1591 g BUILD ,:3 DEe PER I00 FT 15 ' 2! T/ I,/ SAK SNDS TVD=2586 TMD=2605 DEP=143 K-12 TVD=2816 TMD=2861 DEP=256 EOC (g 5/8' CSO PT). TVD=3016 TMD=3101 COLVILLE TVD=3066 TMD=~164 DEP=427 DEP=389 AVERAGE ANGLE :37 DEG 1.1 .i'11N K-5 TVD=4436 TMD-4884 DEP-1466 ~chora~o · ~ I 1000 2000 VERTICAL SECTION T/ ZONE D TVD=5916 TMD=6742 DEP=2589 ZONE C TVD=5928 TMD=6757 DEP-2598 T/ ZONE A TVD=5995 TMD=6841 DEP=2649 TARGET CNTR TVD=6051 TMD=6911 DEP=2692 B! KUP SNDS TVD-6106 THD=6980 DEP=2733 TD (LOG PT) TVD-6265 TMD-?180 DEP-2854 3000 ? HrRIZONTAL SCALE I IN. PROJECT IP" _ " 1000 FEET ARCO ALASKA. In,. Pod ~H. Well No, l~ P,o:o.ea Kupmeuk Field. Nor Slop . Almmkm z 3000 2O00 1000 1 000 2000 1 000 2000 WEST-EAST 1 000 0 ! TD LOCATION' 1473' FSL. 1264' SEC. 1. TI2N. RSE SURFACE LOCAT [ ON, 1207' FNL. 281' FWL SEC. 12. TI2N. RSE TARGET CENTER TVD-6051 THI~,6911 DEP-2692 NORTH 252? EAST 927 TARGET LOCAT ! ON ' 1320' FSI.. 1208' FWL SEC, 1. T12N. RSE N 20 DE9 9 MI N 2692' (TO TARGET) 1 50 200 250 3;00 3;50 400 450 ,,, I I I ,,~ I I .... I., .... I _ 950 950 1050~ ; '',X /1000// ~ 105~ : t 2600 ¢o / ~oo ,,oo_ I ,~oo~ , ~~L,,o. ~ ~ . / I ',~~oo , ' ',_ ' I ', ~~oo ; - 1200 _ _ 120( 12.50 _ 1'300 _ ~2~000 1 000 iS0 200 250 300 '.350 125(: 1350_ ! 4O0 ~50 _ 130C _ 135C GEI~ DRILLING PROC~'~-'Ti Kb'PAll. IlK RIVER D gVEI. OPt~iEHT WELLS t. l, love in 2. In~tell Tank;co diverter plan, 5. Inl~all and ~es~ bl~ ou~ preventer. Tes~ casing Co 20~ psi[. Drill ou~ cemu~ and 10' new hole. Perfo~ lea~ 7. Drill 8~" hole Co lo~I poin~ accord~I ~o di~ec~io~l pl~. 8. ~ open ~1~ logs. and bocc~ of Kupa~k lO. ~ ~d c~nt 7" caain[. Pressure teat co 3~ plil. D~q~ese ~ccXc Pack and ceMuc ~n 7" x 9-5/8' ~ul~. 12. ~i~le ~ bl~ out preventer ~d ~otall t~ora~ ~ tree. 13. Se~re wll ~ releaoe rig. IS. ~ h ~r~er rig. Nipple up bl~ ~' pE~cer. 16. Fi~ ~ 7u ~s~S s~raper ~ c~~, cr~p t~~ ba~. 17. Perforate ~ m c~le~i~ aoee~ly, eec ~ ~eoC ~cbr. 18. N~pple ~ bl~ out preventer ~d 19. ~e ~er co diesel. 20. Fl~ ~11 Co c~s. Shuc 21. Se~re well ~d release rig. 22. Fracture SHALE STIR ,~ STIR _~ ,~TIR LI4~4 / ih TYPICAL MUD SYSTEM SCHEMATIC ,~,~?~ 0~[ & Gas Co~s' ~jo~[~,~ '~,- Density DRILLING FLUID PROGRAM Spud to Drill out 9.6-9.8 8.7-9.2 10.3 15-30 9-13 20-40 8-12 8-12 Viscosity 50-100 35-40 35.45 Initial G~I 5-15 2-4 3-5 10 Minute GW,~I 15-30 4-8 5-12 Filtrate A~I 20 10-20 pB 9-10 9.5-10.5 9.5-10.5 Solids 10~ 4-7 9-12 Drilliul Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: · Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calcUlated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary co control the fluid level in reserve pi=_~ Will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during a:'.'. extended shutdown in disposal operations, The annulus will f~_ sealed with 175 sx of cement followed by arctic pack upu:: completion of the fluid disposal. LWK5 / ih qOt::lI-LL l:llV/v~Oqg ONY l:l].Ll~^:~:ld I:IY'IFINN~ 'A'l~13dOt:ld $N3ci0 {^'1¥^ ~ V~LL ~v I:ILLN3A]t:td :~aO'l:) 'NOIJ. V'IqYJ.$NI q¥1.LINI NOdn elam 31.1.VI,,13H3S t:I:g.LU:gAICI .0~ .LINFI i::13All:l CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~c~- I~//q/~7' 1. (2 thru 8) (8) (3) Admin~~ /~/'~/~7 9. (9 thru 13) 10. ~...-,-/../.~:/~ _~,,,.~? ~ 1. (10 and 13) 12. 13. (4) Cas~ ~.~. /~-/~'~Z (14 thru 22) (23 thru 28) (6) OTHER Company /~/~C~ Lease & Well No. ~/~ (~. YES NO Is the permit fee attached ................... ' ...................... f~ 2. Is well to be located in a defined pool ............................. ~__ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~/J9 7. Is operator the only affected party ................................. ~ 8 Can permit be approved before fifteen-day wait . 14. 15. 16. 17. 18. 19. 20. 21. 22. REMARKS 23. 24. 25. 26. 27. 28. 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 ......................... ~ F0 r 29. (29 thru 31) 30. 31 (6) Add: Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... 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 ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. 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. Additional requirements ............................................. O ~Z HO tqm Geology: WVA Enging~r%~g: LCS .,/~-~"'BEW .... " rev: 01/28/87 6.01! INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~9o/oo [~o-I ~>r~ ~o I~-o 0/,3 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 APPENDIX. , No special effort has been made to chronologically organize this category of information. , TAPE VE~IFICAT]OM bISTI, NG ~90 9O0 000 000 ~90 t~O 000 000 690 EO0 000 000 ~90 ~00 000 000 ~90 ~00 000 000 690 ,00 000 000 ~gO 600 000 000 690 Li 0 000 000 ~Oq9 ~ON :NflOD N~I :N~O~ '3~i '~gvq~ O~V : N3 : A']I~ 9OOIA3~d [00' £IG3: 3~N 3"iIA : 3d~& 9flOIA, 3~d ~0: # NOI&~flNI~NO3 IE/:0/88: ** ~M~VMM Md~ ** tO: # NOItVflNI~NOO O9~gL: 3~VN q33H 1~/;0/88: 3~VQ £'[0~: 2NVN 3DIA~29 LYP -0i0,!,102 VERIFICAT,IOq LISTI~:!G ************************************************************************************ * SCMLU~.6ERGER * * ALASKA CO~'~PUTING CE~TER * ************************************************************************************ COMPANY = ARCO At..ASKA, INC, ELL = ]H'12 _IELD = KUPARUK COUNTY = NORTH SI,~C]PE BOROUGH OOB ~U~BER AT AKCC; 72560 RUN #~, DATE LOGGED~ 02-JAN-8@ LDP: J, ~OHRING ' A$ING = 9 6~5" ~3104;(LOGGER) YPE FLUID = ~IGHTED POI, MER ' 6EN$ITY : 10,0 LB/G ¥ISCOSIT¥ : 38.0 S PH = 8, $ F[,UID bOSS = 4,8 C] BlT $~iZf = 8,5" TO 7294'CLOGGER) = 5,35 @ 75 DF R~iF3 = 5,85 0 65 DF RM = 3,27 0 75 OF RM A~: BHT =: ],156 0 132 DF FIELD REMARKS: I 1/2" STANDOFF AND 2' HOLE FINDER USED ON DIb; ~ATRIX DENSITY = SAND (2,65); FLUID DENSITY. = 1,0 G/C~; MOLE CORRECTION = CALIPER, bvP.O!0,~02 YERIFICATiOi~.! I;!$TI~'~G TYPES/NU;.ViBERS i DIS 1457 DIC i308 PGS 508 CNC 1238 SGC 2479 !Ei~i 1290 NLM 1312. SCHL!,.~B~;RGE9 bOGS INCLUD:ED WITH THIS FiLE (EDIT 001): <SEE FILE EDIT,O02 FO~ 1,2" SAMPLED FDC/CNL D~TA> DUAL INDUCTION SPH~RICALL~ FOCtJSE[ LOGT FIRST TO bAST R~ADING: 7286 FUPMATION PENSlTY ¢O~:P~N~ATEO LOG F'IR~I TO LAST READI~,G: 72 ' TO 6580' AND 3600' TO 3104' CU~PEN6ATED NEUTROiq LOG FIRST TF} bAST READING: 7245' TO 6580' ANP 3600' TO ]!04' GA~aMA ~AY IN CASING (,CHLi F'!RBT TO bAST RFiAOiNG: 3125' L~P -010,~!02 VER1. FIChTIO~.~ LISTING PAGE 4 DATA FORMAT RECORD ** TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 I 66 I 8 4 73 60 9 4 65 ,lin 16 1 66 1 0 t 66 0 ~NE~ SERVICE SERVICE UNIT APl AP1 AP1 lPI FILE SIZE SPb CODE (OCTAL) ' ID ORDER ~ LOG TYPE CLASS ~OD DEPT FT O0 000 O0 0 0 4 1 68 00000000000000 TE S OIl,, LB O0 635 21 0 0 4 1 68 00000000000000 68 00000000000000 SFLU Plb OM~ O0 220 o! 0 0 4 IbD LIL OH~i~ O0 120 .46 0 0 4 I5.~ DIL OH~ O0 120 44 0 0 4 ~ DIL ~V O0 010 Ol 0 0 4 GR OIL GAPI O0 ]I0 O! 0 0 4 ES ?DC LB O0 635 21 0 0 4 PHI ?DC PO O0 890 o0 0 0 4 RHOB ?DC G/C] O0 350 02 0 0 4 DRHO ?DC G/C3 00 356 01 0 0 4 CALl FDC IN 00 280 O1 0 0 4 G~ ?DC GAP[ O0 310 O1 0 0 4 TENS CNL LS O0 635 21 0 0 4 NpHI C~L PU 0(') 890 O0 0 0 4 TNRA CNL OO 42(! Ol 0 0 4 ~?NR Ca5 O0 000 O0 0 0 4 RCFT CNL CPS 00 000 O0 0 0 4 ~CNT CNL CPS 00 000 O0 0 0 4 CFTC CNL CPS O0 000 O0 0 0 4 CNTC CNL CPS 00 000 O0 0 o 4 ~R CNL GAPI O0 31(.) O1 0 0 4 GR CHL GAPI O0 31o Ol 0 0 4 TENS CHL I,,8 O0 635 2l 0 0 4 1 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 69 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 t 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! ~8 00000000000000 1 68 00000000000000 DEPT 7322,0000 TENS 2724 0000 SFLU 3 1518 lbo Ib~ 2.8947 SP -1 0000 GR 100~9375 TENS DpHI 6,8419 RHO~ 2 5371 DRHO 0.0166 CALl GR I00,9375 TENS 2724 0000 ~PHl 35,8450 TNRA RT~R ] 4898 PC[ 484 9477 RCNT 1712.6558 CFTC 2 3988 2724 0000 10 2969 ] 2448 544 2393 LVP.OIO,h02 V~R IFICATIO~ CNTC 1731,9088 GR DEPT 7300 I L ~ 2 DP~! 6 Gt~ ! O0 !731 DEPT 71200 DPHI 11 GR 103 CNTC 2064 DEPT 7100 IL~: 3 DOH! 10 GR 90 ~NTC 2273 DEPT 7000 DP~I 14 ~T~R 8 4 ~TC 1 7i DP~I 17 NTC ~875 EPT 6800 b~ 2 DPNI 19 GR 106 RTNR 3 CNTC 1768 DEPT 6700 DpHI 17 GR 1,25 RTNR 3 CNTC 1754 EPT 6600 L~ ~ OPHI 14 0000 TENS 8970 8419 9375 TENS 4898 RCFT 9888 ,0000 T~NS ;4238 SP .5767 RNOB .6250 TENS .1579 RCFT ~5142 GR 0000 TENS 0357 SP 8665 ~HOB 5000 TENS 0824 RCFT 6646 GR 0000 TENS 8026. 8P R~OB 4400 RCFT 0657 G~ 0000 TENS 5 3 8!25 TENS 8482 7603 GR ,0000 TENS :0012 8P 6259 ~HOB .5625 TENS .7429 RCW'r .4607 G~ 0000 TE~S :2660 SP 2585 '56~5 TEi~$ 19615 RCFT ,5957 {;R oo00 TENS :6432 SP .6544 ~N[}B L ! ST i N G 100,9375 3!84 0000 -1t 9844 2 5371 31.84 0000 484 9477 100 9375 4588 0000 8 0000 '12 4590 4588 0000 564 0164 103 6250 g~ GR RCNT G~ SFhU GR DRMO NPHI RCNT 4~72,0000 SFbU 27,0000 GR' 2;4707 ORHO 4372~0000 NPHI 726'5348 RCNT 90'5000 GR 4364 0000 -26 0000 2 4043 4364 o000 464 I10 12 0 4168.0000 '40,0000 2,3613 4168,0000 1027.745~ 7'4.8125 4240000O iO000 -I~ 3262 4240 0000 425.3674 106.5625 4148 0000 -32 5000 2 3652 4148 O00n 423 564U 125 5625 4090 ¢)000 '31i5000 ~ 4082 SFLU GR DRHO NPHI ~CNT SFLU GR D~HO aCNT GR 6FLU DRHO NPH1 RCNT G~ DRHO RCNT GR S F t. L! GR D~iO '999.2500 3.1654 100.9375 0.0166 35,8452 ~712.6558 '999.2500 3,q418 ,0 08 36,8302 2~16.6919 '999,2500 3.4257 90.5000 32.4646 2194.9487 -999.2500 3,1485 t10,1250 0:~089 47 550 -999 500 12 2981 74:8125 0 0059 2810O19 3024 6782 -999 2500 2,0462 1106,5625 0,0151 47,9468 705,6611 ~99g,2500 2.4206 125.5625 0,0293 46.2940 1686.6440 '999,2500 4,3913 137.6250 TENS TNRA CFTC IbD TENS CALl. TNRA CFTC TENS ILD TENS CALl TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CALI TNRA CFTC TENS IbD TEN8 CALl PAGE '999,2500 4O 8 0000 544,2448 999,25~ 3,3024 ,0000 458~,0000 3'1923 664'2385 -999'2500 ],9269 437 ,0000 8,6719 2,9180 81~,627t '99 ,2500 2,.6782 4364.0000 'SS28 .7414 506,9567 -999,2500 7 8133 4168 0000 2 6O ~05 !970 99 2500 1 9273 4240 0000 484 7891 -999 2500 2 2050 4148 0000 8 9062 3 7016 25O 2,4795 409~,0000 ,2500 - ....... ~ .~.c, t. NG PAGE 6 GR 137 CN?C ! 8?4 DEPT 6500 Ibm ! DPMI =999 GR .999 ~TNR -999 CNT~ -999 DEPT 6400 DpM! '999 GR -999 RTNR -999 C~TC -999 EPT 6300' pH! -999 R -999 RTNR -999 CNTC -999 DEPT 6200 DPHI -999 GR -999 TNR -999 NTC -999 DMPT 6100 Ib~ 2 DPHI -999 GR -999 RTNR -999 CNTC -999 ,6250 ,9259 RCFT ,0620 GF: ,0000 TENS '9912 SP ,2500 '2500 ,2500 RCFT ,2500 GR 0000 T~NS 4493 2500 2500 TE~,8 2500 ~CFT 2500 0000 TENS 0799 2500 25o0 2500 2500 GR 0000 TENS 6966 SP 2500 2500 TENS 2500 RCFT 2500 GR 0000 TENS 7746 SP 2500 RHOB 2500 TEN6 250O RCFT 250O GR EPT 6000,0000 TENS b~ 3,9461 SP DDHI -999,2500 ~HOB GR -999,2500 TENS RTNR -999,2500 RCFT CNTC -999,2500 GE EPT 5900,0000 LM 4,246~ SP DPHI -999.2500 G~ -999,2500 T~NS RTNR -999,2500 RCFT CNT~ -999,2500 4090, 483, 137, 4~20 '999 '999 '999 '999 4240. .999, .999. .999' 999" 3914 "35, -999, -999. -999, -999, 3~90 -36' , '999, '999~ '999, '999. 3770 -999. -999. -999. -9~9, ~694 -54, -999, -999. -999, -999, 35~0 -999 -999 -999 -999 1843 6250 0000 0000 250O 2500 2500 ~500 0000 oo0 2~ °O O0 2500 2500 O000 0000 2500 2500 2500 2500 0o00 5OO0 250O 2500 2500 2500 0000 0000 2500 2500 2500 2500 0000 0000 2500 2500 2500 2500 0000 5000 25OO 2500 2500 2500 ~iPHI GR RCNT SFbU NPHI RCNT G~ SFLU GR DRHO NPHI RCNT GR SFbU NPH RCN~ SFbU GR DRHC RCNT GR SFbU ORHO NPH! RCNT GR GR DRHU NPHI RCNT 43.1334 1862.9231 '999,2500 2,0832 201,2500 -999,2500 -999,2500 -999,2500 -999'2500 3,6974 -9 ,2500 "999,2500 '999,2500 '999'2500 5,0610 -999 500 -999,2500 - 9,2500 2,'1448 152,2500 -999,2500 -999;2500 -999,2500 -999,2500 7 110 4 -999 2500 -999 2500 -999 2500 -999 2500 4 1405 IlO 6875 -999 2500 -999 2500 -999 2500 -999,2500 4 1640 114 4375 -999 2500 -999 2500 -999 2500 -999 2500 TNRA CFTC TE~:S TENS CALl TNRA CFTC TEN6 TENS CALl TNRA CFTC TENS TENS CALX TNRA CFTC TENS TENS CAI,! TNRA CFTC TENS TENS CALX TNRA CFTC TENS TENS CALl TNRA CFTC TE~S Ibb TENS CALl TNRA CFTC TENS 3,5570 541,4369 -999,2500 1,8802 -999+2500 -999,2500 -999,2500 -999,2500 -999'2500 3 -999 2500 -999 2500 -999 2500 -999 2500 3,9505 -999,2500 .9~'2500 ,2500 -999,2500 -999,2500 2 6619 '9992500 -999 2500 -999 2500 -999 2500 -999 2500 2 7200 -999 2500 '999 2500 '999 2500 '999 2500 '999 2500 3 9092 -999 2500 -999 2500 -999 2500 '999 2500 '999 2500 4 1340 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 DEPT 5800.0000 TE~::S 3500.0000 SFLU 5.4711 ILD 3,6746 ~-::VP. 01 O, t-!02 V E~ I f"'! CA T t. 0:~ b ! ST I NG II,~ _ 3,9259 SP -91, DPHI -999,25~0 RHO~ -999 GR -999,2500 T ~.:';N 8 -999 RTNR -999'2500 RCFT -999 CNTC -999'2500 G~ -999 Dp GR ~.TNR cate D P ~ ! CM rC ~;PT iP~I CNTC DEPT Ib~ DPH! C~tTC DEPT DpHI CNTC DEPT DpHI CNTC 57OO 000O 4 2698 -999 2500 -999 ~500 -999 2500 -999 2500 5600 0000 4 4028 -999 2500 -999 2500 -999 2500 -999 2500 50!,0000 999,2500 -999'2500 -999'2500 5400 0000 $ B26] *999 2500 '999 250O '999 250O '999 250O TENS SP TENS RCFT TEN5 RNOB TENS RCFT G~ TENS SP RHOB TENS RCFT TENS RCFT (;~ 5300,0000 TENS 3,971.0 SP '999,2500 RHO~ -999,2500 TENS -999,2500 RCFT -999,2500 G~ 5200,0000 T~NS 3,0780 -999,25~0 RHO6 -999,2500 TENS -999,2500 RCF~~ -999,2500 Ga 5100,0000 TF~'$ ],6387 SP -999,2500 '999,2500 ~999,2500 ~CFT 999,2500 (iR DEPT Dp ~4 I GR RTNR CN?C 3480 -999 -999 -999 -999 3430 -34 -999 -999 -999 -999 3350 -999 -999 -999 -999 ]280 -999 -999 -999 -999 3250 -47 -999 -999 -999 -999 3240 -999 -999 -999 -999 3544 -41 -999 -999 -999 -999 7500 2500 2500 2500 25oo 0000 8437 2500 2500 25OO 2500 · 000 · 813 , 500 ,2500 500 ' 500 0000 0469 2500 2500 2500 2500 0000 5938 2500 250o 2500 2500 0000 375O 2500 250O 2500 2500 0000 0625 2500 2500 2500 250O 0000 2813 2500 250O 2500 2500 DRHO ~PM I RCNT GR SFLU GR DRMO NPHI RCNT GR SFLU DRHO NPHI RCNT SFLU GR DRHO NPHI RCNT GR GFLU NPHI RCNT GR DRHD ~PHI RCNT GR DRHO ~CNT G~ NPMI 84,~875 -999, 500 -999,~500 '999, 500 '999,2500 6 '999 2500 -999 2500 -999 2500 -999 2500 4 0105 - 2500 -999 2500 -999 2500 -999 2500 4,0 15 97,4 75 '999,2500 -999;2500 -999,2500 -999,2500 3,7881 102,6875 '999,2500 '999,2500 '999,2500 -999,2500 3 7494 99 8125 -999 2500 -999 2500 -999 2500 -999 2500 3 0159 107 3125 -999 250o -999 2500 -999 2500 -999 2500 3,5803 103,3125 99,2500 '999,2500 '999,2500 TE~S TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CAb! TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CAl. I CFTC TENS IbU TENS CALl TNRA CFTC TENS lbo TENS CALl TNRA CFTC TENS -9999 250O -99 2500 '999 2500 -999 2500 -999 2500 4,0636 -999'2500 -999,2500 -999;2500 -999,2500 -999,2,500 -999 2500 '999 2500 '999 2500 '999 2500 '999 2500 3.9131 -999,2500 -999~2500 -999,2500 -999,2500 -999,2500 3,8055 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 4 04 '999 25~ '999 2500 -999 2500 -999 2500 '999 2500 3:0719 -999 250o -999 2500 -999 2500 -999 2500 -999 2500 3 5970 -999 2500 -999 -999 :500 -999 2500 -999 2500 ~VP.GIO,h02 VERIF'IC DEPT 5000 DPHI -99~ GRN. -999 RT.iR -999 CNTC -999 Dv~ _EPT 4900 1L~ 2 DPHI -999 GR -999 RTNR -999 CNTC -999 DEPT 4800 bM 2 PHI '999 R '999 RTNR -999 CNTC -999 DEPT 4700 Ib~ 4 DPHI -999 CNTC -999 EPT 4600 b~ 2 DPHI -999 GR -999 RTNR -999 CNTC -999 DEPT 4500 IbM 3 DPHI -999 GR -999 RTN~ -999 CNTC -999 DEPT PHI ~T~P CNTC DP~I i400, 99~, 999, 4]00 2 -999 -999 0000 'PENS 992~ SP 2500 R~OB 2500 TENS 2500 RCFT 2500 GR 0000 TENS 0117 2500 2500 TENS 2500 RCFT 2500 GR 0000 TENS 7203 SP 2500 RH00 2500 2500 RCF~: 2500 0000 TENS 3231 SP 2500 RHO~ 2500 TENS 25O0 ~CFT 2500 GR 0000 TENS 2500 R~OB 2500 TENS 2500 RCFT 250o GR 0000 TENS 0699 SP 2500 RHOB 2500 TENS 2500 RCFT 2500 GR 0000 TENS 0942 SP 2500 RMOB 2500 TE~:S 2500 RCFT 2500 GR 0000 TENS 6452 SP 250O 2500 LIST1 r:G ~100 -38 5313 -999 2500 -999 2500 -999 2500 -999 2500 5000 ~999,2500 ,999,2500 29 . soo 999,2500 3~04,0000 .35,8437 .999~2500 99922500 '999"2500 '999,2500 2950 0000 '59 0625 'Egg 2500 '999 2500 '999 2500 '999 2500 2890 0000 "38 2500 '999 2500 '999 2500 '999 2500 '999 2500 SFbU NPHI ~CNT GR DRHO NPHI RCNT GR SFLU GR ~PHI RCNT GR GR DRHO MPHI RCNT GR GR DRHO NPHI RCNT GR 28]0 0000 SFbU -42:7500 GR -999,2500 DRHO -999,2500 NPHI -999,2500 RCNT '999,2500 GR 2830 0000 SFLU -42' ,5000 GR -999,2500 DRHO -999,2500 NPHI -999.2500 ~CNT -999,2500 GR 2804 000o SFLU -4210000 -999 ~500 -999 2500 ~,PHI 105 -999 -999 -999 -999 2 ,z 15 250 25O 25O 250 5O 999,2 -999'2 ~999,2 -999,2 130 -999 2 -999 2 -999 2 -999 2 .999,2 .999,2 999,2 "999,~ 2 0 139 3 '999 2 '999 2 '999 2 '999,2 7 9~,2 99~,2 "99 ,2 14,5 81,7 -999,2 -999,2 -999,2 -999,2 2,5 104,3 '999,2 '999,2 037 250 500 50O 5O0 500 914 5OO 5OO 5O0 5OO 500 681 75O 5OO 5OO 5OO 5OO 729 75O 5OO 5OO 50O 5OO 236 375 50O 5OO 500 50O 169 50O 5OO 50O 5OO 50O ~71 750 500 5OO TEN8 CALI TNRA CFTC TENS TNRA CFTC TENS CAb! TNRA CFTC TE~S CALI TNRA CFTC TENS TENS CALl TNRA CFTC TENS ILD TENS TNRA CFTC TENS IbD TENS CALl TNRA CFTC TENS I t,P TENS CALI TNRA PAGE oo 2500 '999,1500 soo 500 2~0o =99 2,6551 -999,2500 -'999,2500 m999,2500 -999,2500 ,3563 ~99 ,2500 -999,2500 ~999,2500 =999,2500 "999'2500 2,0470 -999,~500 -999, 500 '999, ~999, 00 ,9649 '99 ,~500 =999,2500 "999,2500 '999,2500 '999,2500 4 4834 =999 2500 -999 2500 -999 ~500 -999 500 -999 2500 ,67 45 :99 ,2500 99,2500 Lyp.olo,Ho2 VERIFIC~"[Oi'~ LISTING RTNR C~?C DEPT DPHI RTNR CNTC DEPT DPHi RTNR CNTC ~EPT DPHI RTNR CNTC DPHI GR RTNR CN?C DEPT ~R RTNR CN?C DEPT DPHI GR RTNR CNTC DEPT DpH! NTC DEPT 999,2500 RCFT ~999,2500 G[{ 4200.0000 TENS .99~'8571 SP .~2500 RHOB -999,~500 TENS -999,2500 RCFT -999,2500 GR 4100.0000 TENS 2,70'22 SP ~999,2500 RHO8 -999;2500 TENS -999,2500 RCPT -999;~500 GR 4000 0000 TENS -999 2500 -999 2500 TENS -999 2500 -999 2500 0000 TENS '999'2500 RHOB '999,2500 TENS '999,2500 RCFT '999.2500 GR 3800 -999 -999 -999 -999 0000 TENS 4752 SP 2500 RHOB 2500 2500 RCFT 2500 GR 3700 3 -999 ~999 =999 -999 0000 TENS 801B 2500 RHOB 2500 T~NS 2500 RCFT 2500 GR 3600 28 104 3 1758 0000 TE~$ 2784 8589 RHDB 0000 TENS 7407 RCFT 6704 GR 3500.0000 TENS 4.55]8 SP 9992500 RCNT 999' ,2500 GR 2824 0000 -43 0000 -999 2500 -999 2500 -999 2500 -999 2500 SFhU GR DRHD NDHI RCNT GR I04,0 00o SFLU 5,3,7500 GR .999.2500 ORHO ~99"2500 NPMI 99,2500 RCNT -999.2500 GR 2654 0000 -53 5000 -999 2500 -999 2500 -999 2500 -999 2500 SFbU G~ DRHO NPHI GR 2724,0000 SF[,U -51,2500 GR -999.~500 DRHO -999. 500 NPH1 -999.2500 RCNT -999,2500 GR 2650 0000 -5~ 2500 -999 2500 -999 2500 -999 2500 -999 2500 2530 0000 -59 5000 -999 2500 -999 2500 -999 2500 -999 2500 2410 0000 -57 7500 2 1738 2410 0000 387 292? 104 0000 SFbU DRHO ~PHI RCNT GR ORHO NPHI RCNT GR SFLU GR DR}~O NPHI RCN~ GR 2400.0000 SFLU -63,2500 GR -999 -999 2 -999 -999 -999 2 I00 -999 -999 -999 -999 2 107 ~999 -9 -999 3 94 99 -999 -999 3 -9 -999 -999 -999 3 102 -999 -999 -999 -999 3 104 -0 47 1699 -999 4 97 .2500 250o 7478 9375 25O0 5O0 ,2500 .5344 ! 875 0 2500 ,2500 .6998 500 '2500 ,2500 ,2500 2034 0000 2500 2500 2500 2500 .2405 ,8750 ,2500 ,2500 ,2500 ,2500 ,6066 ,7500 .2500 .2500 ,2500 .2500 ,0252 ,0000 ,0010 ,2120 ,9192 .2500 ,2824 ,0000 CFTC TENS TENS CA~I TNRA CFTC TENS TENS TNRA CFTC TENS ILD TENS CAbI TNRA CFTC TENS TENS CALl TNRA CFTC TENS CALl TNRA CFTC TENS IbD TENS CALl I'NRA CFTC TENS TENS CALl TNRA CFTC TENS IbD TE~$ PAGE '999,2500 '999,2500 2,8897 -99~,2500 -99 ,2500 -999.~500 -999,2500 -999~500 2.7651 -999 25:00 -9992500 -999 2500 -999 2500 -999 2500 2,9460 -999;2500 '999,2500 -999.~2500 -999,2500 -999,2500 3,6051 -999,2500 -999,2500 -999;2500 -999,2500 -999,2500 3 6088 -999 1500 -999 [500 -999 [500 -999 2500 -999 2500 3 9252 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 35b0 2410 0000 9 5469 3 8043 491 4027 -999 2500 4,7378 2400,0000 LVP-010,~02 VER.IFICATiO~'~ I,.,I,:qTI~;G PAGE I0 RTNR CtT¢ DEPT TNR NTC ..EPT RTNR CNTC ~p~ DPHI RTN~ CNTC DEPT DPHI TMR -p DPHI RTN~ CNTC DEPT DP~I RTNR C~TC DEPT ILN~ DPMI GR RTNR CNTC 30 2794 RHO8 97 0000 TENS 3 8571 RCFT !755 2786 G~ 3400 0000 6 97] SP 28 ~854 ~0~ 74 0625 TENS 2 7162 RCFT 22]2 9810 GR .3300,0000 TENS 4,2062 SP 26,2547 RHOB 107,6875 TEN~ 4,0185 RCF 1740,8840 GR 3200,0000 TENS 2 , 4 RHOB 96.5000 TENS 4.1569 RCFT {74~,5186 OR 3100,0000 T~N8 2000,0000 SP 28,7405 RH08 0,5625 TENS 64,~947 RCFT 1197,1543 GR 3000,0000 TENS -999.2500 BP -999.2500 RHOB -999,2500 TENS -999,2500 RCFT 'g99,2500 GR 29000000 TENS -999:2500 SP -999,2500 RHO~ -999,2500 TENS -999,2500 RCFT -999.2500 GR 2800 0000 TESS -999 2500 SP -999 2500 ~H08 -999 2500 TENS -999 2500 RCFT -999 2500 GR 240~.1504 DRHO 4!5,9064 ~iCNT 97.0000 GR 30,00O0 SYbU 68i 290 RCNT 74.0625 GR 2194,0000 SFLU O0 NPH! 2170 0000 SFbU -74 0625 GR 2 1973 DRHO 2!70 O00O aPMI 415 6!84 RCNT 96 5000 OR 2!54 0000 SFLU '51 7500 GR 2 1758 ORHO 2154 0000 N?HI 299 9491 RCNT 60 5625 G~ -999 -999 -999 -999 -999 -999 2500 SFbU 2500 GR 2500 D~HO 2500 NPHI, 2500 RCNT 2500 GR -999 2500 SF[.U -999 2500 OR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 GR -g99 2500 SFLU -999 2500 GR -999 2500 DRHO =999 2500 NPHI -999 2500 RCNT -999 2500 OR 0,0083 CALl 45,1197 TNR& 1753,7163 CFTC -999,2500 TENS 14,5890 ILD 4.~ CaUI ' 75 TENS 17 46,1161 TNRA 1753. C~TC -999. 500 TENS 3,3882 IbD 96,5000 TENS 0,0161 CAbI 45,7987 TNRA 1737..4163 CFTC 999'2500 TENS 2000,0000 IbD 60,5625 TENS -0,3257 CA~I 59,1216 TNRA 1420,6331 CFTC 65,3125 TENS -999 2500 ILD -999 ~500 TENS -999 500 CALl -999 2500 TNRA -999 2500 CFTC 49:7500 TENS ~999,2500 IbD 999,~500 TENS -999,2500 CALl -999,2500 TNRA -999,2500 CFTC 58,5918 TENS -999 2500 IbD -999 !500 TENS -999 500 CAbI -999 2500 TNRA -999 2500 C~'TC 45 3438 TENS 497 0201. -999 2500 7 4580 243~ 0000 2734 ~ 0009 .71t 82?5 999 2500 4 5367 2194 0000 10 3'750 ~ ~1o~ 470 2989 -999 2500 $ 8474 2170 0000 10 0547 3 7686 451 2308 -999 2500 ;0000 '9766 ,4080 333,8176 2090;0000 -999 2500 -999 2500 -999 2500 -999 2500 '999 2500 2050 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 2064 0000 -999 2500 ~999 -999 2500 -999 2500 -999 2500 2054 O00O i.,VP.OIO,J~02 VERIFICATION DEPT ~700,0000 TENS 2500 ~ 1,.~ ~999' SP DPHI 999~2500 RHO[~ GR .,999;2500 TENS c~TNR -999~2500 RCFT MTC -999 ~2500 G~ DEPT !600;~000 TEL!S DDH! 9999.,]500 R !<{0~ GR -99 500 TEN8 R~ ~ 999 500 RCFT CNTC -999:500 GR Dpt! RTNR CNTC DPHI RT~R C TC DpH I RTN~ C~?C :EPT DpH I RTNR DEPT DP~I RTNR C~TC DEPT DPHI GR RTNR 2500 0O00 -999 2500 -999 2500 -gg9 2500 -999 2500 -999 2500 2400 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ~30~:0000 99 2500 -99 ,25oo -999'2500 -999,2500 -999'Z500 2200 0000 -999 2500 -999 2500 -999 2500 -999i2500 -999 2500 SP RHOB RCF~ GR TENS SP TENS RCFT GR R H 0 B TENS SP RHDB TENS RCFT GR 2100,0000 TENS .999:!5oo sP -999 500 RHOH -999,2500 TENS -999 500 2000 0000 TENS -999 250o SP -999 2500 RH[;B -ggg 2500 TE~$ -999 2500 RCFT -999:500 GR .999, 8o D HO -999 0 NDHI -999~ 500 RCNT -999,2500 GR -999 2500 '999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 *999 2500 -999 ~500 -999 2500 -999 2500 SFLU GR DRHC NPHi RCNT GR SFLU GR DRHO NPHI RCNT GR 999.2500 SFbU 999.2500 GR :999'2500 DRHO 999'2500 NPHI -999;2500 RCNT -999,2500 GR '999,2500 SFbU '999,2500 GR '999,2500 DRHO '999.2500 NPH! '999,2500 RCNT '999,2500 GR -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 250~ -999 2500 -999 250O -999 25O0 -999 2500 -909 2500 -999 2500 -999 250O -999 250O -999 2500 -999 2500 -999 2500 SFLU GR ORHO hPHI RCNT GR SFLU GR DRHO NPHI GR SFLb GR DRHO NPHI -999,2500 -999'2500 -~99,2500 - 99,2500 -999,2500 54.4063 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 47 4063 -999,2500 -999,2500 -999, 500 -999.]500 -999, 500 33,~125 '999,2500 '999,~500 "999, 500 '999,2500 '999,2500 42,9375 .99 2500 99 2500 999,2500 99]:2500 4 8437 '999,2500 '999,2500 "999,2500 '999,2500 '999,2500 51,8437 '999,2500 '999,2500 -999 2500 -999 2500 '999 2500 47 8437 -999,2500 -999,2500 '999,2500 :999 250,) 999:2soo ILO TENS c bl TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CALl TNRA CFTC TENS TENS CALI TNRA CFTC TE~S TENS CAn! TNRA CFTC TENS ENS ALI TNRA CFTC TENS TEN5 CALk TNRA CFTC TENS IbD TENS CAb! TNRA CFTC -999 2.500 -999 2500 -999 2500 -999 2500 -999 2500 2060 0000 -9'99,2500 '2500 -999,2500 -999*2500 1950 0000 -999 500 "999 0 '999 2500 1920 0000 '999,2500 '999~2500 -999~2500 '999,2500 -999;2500 1855,0000 -999,2500 -999;2500 '999,2500 -999,2500 '999,2500 1800,0000 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 1720 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 1650 0000 -999 2500 -999 2500 -999 2500 -999 2500 · .999 2500 11 LVP.OIO,&.!02 VERiFICA?!O~',~i LI~TI~iG PAGE 12 !::~ rc -999,2500 GR DEPT 1900 ILS' -999 DpHI -999 GR -999 RTNR =999 CNT~ -999 WEPT 1800 IbM -999 DPH! -999 GR -999 RTNR -999 C~ITC ..999 DgPT 1700 I~ -999 DpHI -999 GR -999 RTNR -999 CNTC -999 0000 TE~:$ 2500 SP 2500 RHOB 2500 TENS 2500 RCFT 2500 GR O00O TENS 2500 2500 2500 2500 RCFT 2500 GR 0000 TENS 2500 2500 RHOB 2500 2500 RCf'~ 2500 EPT !600,0000 TENS b~ 999;2500 SP DPHX 999,2500 RHOB 999;2500 TENS ~iR 999.2500 RC~T C 'T' C N.C 999,2500 ...,R DEPT 1500 IGN -999 DPH! -999 GR -999 TNR -999 NTC -999 DEPT 1400 lb~ -999 DpHI -999 gR -999 RTNR -999 CNTC -999 0000 TENS 2500 SP 2500 RHOB 2500 TENS 2500 RCFT 2500 GR 0000 TENS 2500 SP 250O RHOB 250o TEN5 2500 RCFT 2500 GR DEPT ~300,0000 TENS Ib~ 999.2500 SP DPHI -999 2500 RHOB GR -9qg:250u TENS RTNR -999.2500 ~CFT CNTC -999,2500 GR DEPT 1200.000(+ TENS IbM -999 2500 SP DpHI -999:2500 RHOB '999,2500 GR -999 2500 -999 2500 -999 2500 -999 2500 =999 2500 -999 2500 SFGU GR DRHO ~PHI ~CNT GR -999,2500 SFLU -999,2500 GR -999.2500 DRHO -999,2500 NPHI '999.2500 RCNT '999,2500 GR -999 2500 -999 2500 '999 ~1500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 :999.2500 999.2500 -999.2500 SFLU GR DRHO NPH I RCNT Ga SFLU GR DRHO NPHI RCNT GR SFLU GR DRBO NPH! RCNT GR SFbU GR DRHO NPHI RCNT GR SFLU GR DRHO NPHI RCNT GR SFLU GR DRHO 41,6250 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 49 9687 -999,~500 :9v9. m999;25oo .999.,~5oo 999'2500 27,734.4 -999,~5oo -999, 500 '999,2500 '999,2500 '999,2500 ~0.9844 '999.2500 '999,2500 '999,2500 '999,2500 '999.2500 33,1875 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 26 1250 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 20 4531 -999 2500 -999 2500 -999 ~500 =999 500 -999 2500 20 4219 '999.2500 =999.2500 '999.2500 TENS TENS TNRA CFTC TENS I~D TENS TNRA CFTC TENS IUD TENS TNRA CFTC TENS TENS CAbl T~RA CFTC TENS TENS CAbI TNRA CFTC T~NS TENS CAhl TNRA CFTC TENS bO CAUl TNRA CFTC TENS TFN$ CALl 1605,0000 '999.2500 '999'2500 '999,2500 '999,2500 '999,R500 1530.0000 -999 2500 -999:2500 -999.2500 '999,2500 '999,2500 1470,0000 -9~,2500 ;2500 '999'2500 '999,2500 '999,2500 1440~0000 '999,2500 '999'2500 '999'2500 '999,2500 '999,2500 1390,0000 "999 2500 '999 2500 -999 2500 -999 2500 '999 2500 1365 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 1310 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 1285 0000 -999,2500 -999,2500 -999,2500 VERIFICATION L!STI~G GR -999,25()0 TENS RTNR -999,2500 RCFT CNTC -999'2500 GR DEPT ~100,0000 TENS ILS .'999,2500 SP DPHI -999,2500 AH08 GR -999;2500 TESS RTNR -999;2500 RCf'T CNTC -999.2500 GR DEPT 1000.0000 T:EM$ I5~ -999,2500 S~ DpMI -999,2500 RHOB GR ~ -999,2500 TENS RTNR ~999;2500 RCFT CNTC .999'2500 GR -999.2500 ~PHI -999.2500 ~CNT '999.2500 GR -999 2500 '999 2500 '999 2500 '999 2500 '999 2500 '999 2500 GR NPHI -999.2500 SFbU -999.2500 GR -999'~00 DRHO -999~ O0 NPHI -999, 500 RCNT -999~2500 GR -999 -999 42 -999 -999 -999 -999 -999 53 -999 -999 -999 -999 -999 DEPT 997,5000 TENS -999 ~500 SFLD -999 I5~ -999.2500 SP -999: 500 GR -999 DPHI -999~2500 RH~B -999,2~0 DRHO -999 GR -99~ 2500 TENS -999:~ 0 NPHI -999 RTN~ -99:2500 RCFT -999 500 RC~T -999 C~TC -999.2500 GR ~' -999,2500 GR 27 ~,FIbE TRAILERT~ F![,E HAME :EDI ,001 VERSION # DATE . MAXI~[I~ LENGTH : 1024 FILE TYP, E''~ , NEXT FILE NAME ~ FILE HEADER SERVIC~i NAME VE~$IO~ # ~ DATE : MAXI~U~ LENGTH FILE TYPE PREVIOI~S F]'~E , o02 !024 EOF ** CO~ENTS ** ,¸2 ,2 ,2 ,2 ,1 5O 5 0 O0 5O 25 250 50 50 0 687 25O 25O 25O 25O TNRA CFTC TENS CALl TNRA CFTC TENS ILD TENS CALI TNRA CFTC lbo TENS CA&I TNRA CFTC TENS PAGE -999 O0 1225~0000 -999, 500 '999, 500 -~99'2§00 - 99~500 -999;2500 1195,0000 -999,2500 -999,'2500 '999,2500 -999,~500 -999,.2500 1160,0000 -999,2500 ~999;2500 .999~2500 ~999,2500 -999,2500 !160,0000 LVF~OiO,{.{(12 VER.IFICATIi~i~i PAGE 14 ***** THIS DATA H~S NOT SEE D£.PTh S~IFTED OVERLAYS FI£bD PRINTS ********************************************************************************* , * SCHLUaBERG~f~ LOGS INCLUDED WiTH THIS FILE (EDIT.O02): * <SEE FILE EDIT,O01 FOR 6" SAMPLED D!L/FDC/CNb/GR DATA) , * FORMATIO~ [)E~$tTY COMPE~I,ATED bOG (.FDH) * FIRST TO bAST R~iADIMG.: 7260' TO 6590' * CO~PEN*ATE[) NEtiTRO}~ hOG (tCNH) * FIRST TO LAST R~ADING.- ' 7245' TO 6590' , ****************************** . DATA FORMAT RECORD ** ENTRY BLOCKS IYPE 6IZ[ REPR COOE ENTRY 2 1 66 0 4 1 66 8 4 73 12 9 4 65 ,lin 16 ! 66 , , LVP~OIO,,H02 VE.RiFICATIC]N LISTI~tG PAGF 15 0 ! 6 6 0 DATI;M SPECIFICATION SI.tUCKS ~N~ S~RVICE SERVICE ID ORDE~ ~ DEPT FT TE~S FDH LB DPHi FDH PU RHOB FDH G/C3 DRHO FDH C/C3 CALi FDM IN GR ~DH GAPI NPHI C~H PU TN~A RTNR CNH RCFT CNH RCN~ CNH C~¢ CNH CN~C UHIT APl CPS CPS CPS CPS GAPI O0 AP1 API API FILE SIZE SPL REPR C T'.E LO~ YP~ CLASS MOD NO, O0 000 O0 0 0 O0 ~35 21 0 O O0 890 O0 0 0 O0 350 02 0 0 oo 356 O1 O 0 O0 2eO O1 0 0 O0 310 Ol 0 0 O0 b35 2! 0 0 O0 890 O0 0 0 00 420 01 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 0o0 O0 0 0 O0 000 O0 0 0 310 O1 0 O PROCESS CODE (OCT 68 00000000000~ 68 00000000000000 68 00000000000000 68 0000000000 68 000000000088 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 0o000000000000 68 00000000000000 6~ 00000000000000 ** DRTA ** DEPT DRHO NpHI 7316,3994 TENS -0,018~ CALl' 34,9615 TNRA 1722,8474 CFTC DEPT DRHO NPHI RCNT 7300 2998 'rE S'N -0:0t86 CALl 34'7057 TNRA I722,8474 CFTC DEPT DRHO NPHI RCNT 7200,2998 TENS 0,0830 CALl 38,3793 TNRA 2278,9937 CFTC DEPT DRHO NpHI RCNT 7100,2998 TENS 0,0313 CALl 33'4780 TNRA 2300,7930 CFTC DEPT DRHO NPHI RCNT 7000,2998 TENS 0,1724 CALl 44,9517 TNRA i722,1194 CFTC DEPT DRHO NPHI RCNT 6900 299~ TENS 0!0298 CALl 28 5167 T~RA 2816,2549 C~TC 2390 0000 DPHI 9 5547 GR 3 1358 RTNR 566 5787 CNqC 3274,0000 DPHI 9,7266 GR 3,1359 RTNR 566,5787 CNTC 4604 0000 OPHI 9!1094 GR 3 2862 RTNR 661 2823 C~.~C 4344 0000 DPHI 815938 GR 2 9765 RTN~ 773 5311 Ci~TC 418~,0000 DPHI 3,7266 GR 535,6136 RTNR ,3347 CNTC 4172 0000 OPHI 815000 G~ 2,6408 RTNR 1.075,9355 C~TC 14,4176 RI-lOB 107,1875 TENS 3, 725 RCFT 1742,2954 GR 14,4176 RHO8 I07,1875 TENS 3,3725 RCFT 1742,2954 GR 2,4121 o 2504, 6 107,1875 2,41021 3274,00 0 504.~5836 t07, 75 10 2746 RHOB 2,4805 116i6875 TENS 460!i0000 3 1935 RCFT 58 5559 2122 9600 GR 11 6875 11 5767 RHOB 101 3750 T~NS 3 4667 RCFT 2304 8330 GR 10,9849 RHOB 120,3750 tENS 3,6522 RCFT 1848,2888 GR 15,9564 RHOB 68,0000 TENS 3,0909 RCFT 2815,0356 GR 2,4590 4344,0000 699,5577 101,3750 2,4688 4188,0000 465,1553 120,3750 ,3867 417 ,0000 g28,7463 68,0000 LvP.OIO,-H02 VERIFICAT!Oi~ i,iSTING DEP]~ 6800,2998 ~ENS DRHO 0'0117 CALl NpH! 4': 9868 T,N~A EPT 6700.2.998 TENS RHO 0,007] CALl NPHI 48,6318 TNRA RCNT 1649,6348 CFTC DEPT NPHI 6600 299B TENS 0,0415 CAbI 41,1287 TNRA 2039,8~67 CFTC DEPT ~589.7002 TENS DRHO 0'0737 CAbi NPHI 999'2500 TNRA RCNT -999,2500 CFTC 4128,0000 DPHI 3 ~ RTNR 479~9 23 CNYC ~004 0000 DPHI 8 8984 GR 3 8287 RTNR 468 i. 537 CNTC 4090.0000 DPHI 9*2714 GR 3. 4498 R ~ 549,8971 CNTC ~I12 0000 DPiiI 9 0000 OR -999 2500 RTNR -999.2500 CNTC ** FI. LE TRAI~ER ** FILE NAME :EDIT ,002 SEPVICE ~A~E : ATE ~AXI~UM LENGTH I 1024 FILE TYPE { NEXT FILE NAME ~ ********** EOF 19,2'708 RH[}B 102,1250 TENS 3,9091 REFT 1766,6436 GR 9,7443 ~HOB 19,5000 124,1]~4 !760,5999 GR 13,5890 140,8750 TENS ,6296 REFT 189 ,5896 GR '999,2500 RHOB 143,3~50 TENS aC T "999,2 O0 F '999,2500 GR PAGE 16 4128, 0 405,5129 10 2, t :250 2,324:2 4004; 0000 46t~9675 129,5000 2,4258 4090,0000 22'5 7 1 ~40,8~50 2,3 5 '; ,4 -99_9;2$00 -999;~500 -999,2500 ** TAPE TRAILER ** SERVICF NAME :EDIT DATE :88/01/21 ORIGIN :FSIA ~APE NAME : CONTINUATION # :01 NEXT TAPE NAMF : COMMENTS ~bIS TAPE, ARCO ALASKA, INC. ~H-12, API 50-10~-20088 ** REEL TRAILER ** SERVICE NAME :EDIT DATE :88/01/21 ORIGIN : REEL ~E :72560 CONTINUATION # NEXT REEL NA~E : COMMENTS :LIS TAPE, ANCI) ALASNA, INC, ~H-]2, AFl EOF