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Home My WebLink About186-163Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization {done) ~ Two-Sided RESCAN Color items: Grayscale items: Poor Quality Originals: Other: DIGITAL DATA Diskettes, No. Other, No/Type TOTAL PAGES: ~I~ I NOTES: ORGANIZED BY~ ~REN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [3 Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds o Other By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT, SHERYL MARIA LOWELL DATE: /si PAGES: ~ ~ (at the time of scanning) SCANNEOBY: OREN VINCENT SHERYL MARIA LOWELL DATE: Io, lo. b2- Isl ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: PAG ES: Quality Checked Rev 1 NOTScanned.~xI • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Q Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development II Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 'VitY7 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., l 51 14 12 . Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March2012 186 - 163 / 311 - 320 3. Address: 6. Date Spudded: `` 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 22, 1986 50 029 - 21653 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1160' FSL, 316' FWL, Sec. 35, T13N, RO9E, UM October 29, 1986 3K - 10 Top of Productive Horizon: 8. KB (ft above MSL): 114' RKB 15. Field /Pool(s): 1375' FSL, 628' FEL, Sec. 34, T13N, R9E, UM GL (ft above MSL): 40' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1424' FSL, 906' FEL, Sec. 34, T13N, R9E, UM 6790' MD / 6533' 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 529306 y- 6008154 Zone 4 7300' MD / 6951' TVD ADL 25520 TPI: x - 528360 y - 6008365 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 528082 y- 6008413 Zone 4 1763' MD / 1763' TVD 2556 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) 1700' MD / 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# I-1-40 38' 110' 38' 110' 20" 1540# Poleset 9.625" 36# J -55 37' 3829' 37' 3828' 12.25" 1075 sx AS IV, 305 sx Class G 7" 26# J -55 35' 7274' 35' 6930' 8.5" 325 sx Class G 24. Open to production or injection? Yes ❑ No 0 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" 6772' MD 7092' MD / 6782' TVD and RECEIVED 6795' MD / 6538' TVD 6825 MD 6563' - 6567' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6960' - 6965' MD 6674' - 6678' TVD MAY 1 20'l2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7006-7026' MD 6712' -6728' TVD A�GGG 6825-6830' and 6960' -6965' 30 bbls 15.8# Class G 7041' -7068' MD 6740' -6762' TVD 1 spf for 7072', 7076, 7080', 7084', 7087' MD 27. PRODUCTION 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 0 Sidewall Cores Acquired? Yes ❑ No Ei 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. MAINEDMAY 3 0 4U 1Z NONE Form 10-407 Revised 12/ 1 CONTINUED ON REVERSE Submit original only M ® S MAY 1 8 gii- 5Iit!I -• "Pra-L- ,. . 28. GEOLOGIC MARKERS (List all formations and m• encountered): 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 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: G ry Eller @ 263 - 4172 Printed Nam L. G•Att Title: CTD Engineering Supervisor Signature A p , Phone 263 - 4021 Date \5 Z 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 KUP • 3K -10 Conoc Phillips O$ Well Attributes Max Angle & MD TD A41ska. Inc Wellbore API /UWI Field Name Well Status Inc) (°I MD (ftKB) Act Btm (ftKB) tips 500292165300 KUPARUK RIVER UNIT PROD 35.87 6,100.00 7,300.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: TRDP 100 8/1/2011 Last WO: 39.21 10/30/1986 Well Confie' - 3K -10, 2/23/201211'. 58'.00 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,172.0 10/8/2011 Rev Reason: ADD PERFS ninam 2/23/2012 Casing Strings HANGER, 35 Casing Description String 0... String ID ... Top (CAB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,829.5 3,827.5 36.00 J -55 BTC ' ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd �.._., PRODUCTION 7 6.276 35.0 7,274.3 6,930.1 26.00 J - 55 BTC CONDUCTOR, 38-110 Tubing Strings '_ � Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SAFETY VLV, 3 TUBING 3 1/2 I 2.992 I 35.0 6,772.0 I 6,518.8 I 9.30 L80 EUE 8Rd Mod 1,763 J Completion Details Mr Top Depth (ND) Top not Need... Top (ftKB) MB) (") tom Description Comment ID (In) GAS LIFT, 2,507 35.0 35.0 0.24 HANGER MCEVOY GEN IV TUBING HANGER 2.875 1,762.7 1,762.6 0.46 SAFETY VLV CAMCO TRMAXX- CMT -SR -5 SAFETY VALVE w/ 2.813" X PROFILE 2.812 I I I Fi 6,725.6 6,480.4 34.27 NIPPLE CAMCO X NIPPLE 2.812 y 6,771.1 6,518.1 34.36 SEAL ASSY BAKER 80-40 GBH -22 LTSA SEAL ASSEMBLY w/ 7' SPACE OUT 2.850 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT, - FHL PACKER 3 1/2 2.992 6,772.0 7,092.2 6,782.0 9.30 L80 EUE 8Rd Mod 3,794 Completion Details Top Depth SURFACE, ,J L (TVD) Top Intl Need T (ttK ") (1 Item Description Comment ID (In) 37 -3,829 6,772.0 6,518.8 34.36 PBR BAKER 80-40 PBR w/ 40K SHEAR 3.000 GAS LIFT, 6,795.4 6,538.1 34.41 PACKER BAKER FHL PACKER (60K SHEAR) 3.000 4,704 « _ 7,091.3 6,781.3 35.54 SOS SHEAR OUT WLEG 2.992 IIIIII Perforations & Slots GAS LIFT, Shot 5,452 ••••40... Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment 6,825 6,830 6,562.5 6,566.6 C-4, 3K -10 2/7/2012 6.0 IPERF 6.8 GRBig Hole Charges, 60 Deg Phased case 170 _ � 6,960 6,965 6,673.5 6,677.7 UNIT B, 3K -10 2/7/2012 6.0 IPERF 6.8 GRBig Hole Charges, 60 Deg Phased 7,006 7,026 6,711.5 6,727.9 A -3, 3K -10 9/10/1988 8.0 RPERF 60 deg. ph; 21/8" EnerJet GAS LIFT, 7,009 7,010 6,714.0 6,714.8 A -3, 3K -t0 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet 6,669 It 7,011 7,012 6,715.6 6,716.5 A -3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet N 7,019 7,020 6,722.2 6,723.0 A -3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 7,0231 7,024 6,725.5 6,726.3 A -3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet NIPPLE, 6,726- la 7,041 7,068 6,740.2 6,762.3 A -2, 3K -10 9/10/1988 8.0 RPERF 60 deg. ph; 2 1/8" EnerJet _ 7,046 7,047 6,744.2 6,745.0 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet _ 7,053 7,054 6,750.0 6,750.8 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet SEAL ASSY. 6,771 7,059 7,060 6,754.9 6,755.7 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet PBR, 6,772 PACKER. 6.795 - - _ 7,063 7,064 6,758.2 6,759.0 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet Mili 7,072 7,073 6,765.5 6,766.4 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet IPERF, 7,076 7,077 6,768.8 6,769.6 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 6.626.8,630 _ -..- 7,080 7,081 6,772.1 6,772.9 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet 7,084 7,085 6,775.4 6,776.2 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet IPERF, % /1t 7,087 7,091 6,777.8 6,781.1 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 6,960-6,965 - Notes: General & Safety End Date Annotation _ _ 6/17/2008 NOTE: SURF CSG PATCH ,12' of 16" 62.5# API 5L GR B B. IPERF. f . 7,009 -7,010 i' 7/26/2010 NOTE View Schematic w/ Alaska Schematic9.0 IPERF, 7,011 - 7,01 12/18/2010 NOTE: WAIVERED WELL IA x OA COMMUNICATION 2 RPERF, 7,00 2/18/2012 NOTE: TAGGED TOP OF CEMENT 6790' SLM IPERF, 8 - IPERF, 7,019-7,020 PER _ IPERF. 7.023-7,024 ERF. M-. : . IPERF. 7,046 -7,047 IPERF, 7,003-7,054\ RPERF, 7.041 -7.068 IPERF, 7,059 -7,060 IPERF, 7,083 -7,064 Mandrel Details IPERF, - Top Depth Top Port 7,072 -7,073 = -- (ND) Inc! OD Valve Latch Size TRO Run IPERF. - St n Top (ftKB) (ftKB) ( Make Model (in) Sery Type Type (inl (psi) Run Date Com... 7,076-7.077 - ' 1 2,507.2 2,506.7 3.65 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2011 IPERF, -- 2 3,793.7 3,791.7 1.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2011 7,080 -7,081 3 4,703.7 4,698.0 13.63 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2011 IPERF, = 7.0847,085 = 4 5,451.8 5,402.6 24.81 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/22/2011 5 6,169.6 6,023.9 35.63 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2011 7, °67-7,°x1 -._ - • = 6 6,669.5 6,434.2 34.35 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/8/2011 SOS, 7.091 - }- .,1 1 PRODUCTION. 35 -7,274 N TD, 7,300 ` 3K -10 Well Work Summary DATE SUMMARY 10/20/11 LOGGED GAMMA/CCL CORTION LOG FROM A DEPTH OF 7178'OSURFACE IN ORDER TO OBTAIN A CURRENT JEWELRY LOG. RIGGED DOWN AND TURNED WELL OVER TO DSO. 11/12/11 MEASURED BHP @ 7025' RKB 1903 PSI. COMPLETE. 12/28/11 MEASURED BHP @ 7025' RKB ( 2118 psi max) . JOB COMPLETE. 12/30/11 PRE CTD MIT -OA ( PASSED ), T -POT ( PASSED ), T -PPPOT ( PASSED), IC -POT ( PASSED ), IC-PPPOT( PASSED ). PT SV, MV,SSV ( PASSED) DDT SV, SSV ( PASSED) MV & DDT SSSV ( UNABLE TO PERFORM DUE TO LOW T PRESSURE ). 2/3/12 MEASURED BHP @ 7025' RKE: 2288 PSI. COMPLETE. 2/5/12 ARRIVE AT WELLSITE, STEAM UNIT WAS RIGGED UP NEAR 3K -10 AND IN THE WAY. UNABLE TO RIG UP. JOB SUSPENDED UNTIL DONE STEAMING. 2/7/12 PERFORATE INTERVALS 6960'-6965' AND 6825' -6830' USING 6.8 GR /CHARGE BIG HOLE CHARGES, LOADED 6 SPF, 60 DEGREE PHASED — LOG CORRELATED TO HES GAMMA/CCL CORRELATION LOG DATED 20 OCT 2011 2/16/12 PUMPED 30 BBLS OF 15.8# G CEMENT. SQUEEZED 10 BBLS OF CEMENT. REACHED A SQUEEZE PRESSURE OF 2000 PSI. CIRCULATED WELL TO DIESEL FROM 6800' MD TO SURFACE. MAINTAINED 1:1 RETURNS AFTER SQUEEZE. TRAPPED 1500 PSI ON WELLHEAD. JOB COMPLETE. 2/18/12 RAN 2.72" CENT BLB AND 2.78" GAUGE RING TO 6726' RKB.RECOVERED 2 PIECES OF PKG.TAGGED CEMENT @ 6790' SLM EST TOC @ 6826' RKB, PRESSURE TEST TO 1000 psi PASSED. 2/21/12 RU CTU, WAIT 4 HRS ON MANLIFT MECHANIC AND DIESEL TRANSPORT, MU BHA, RIH TO 4500', DISCOVERED DISCO BALL WOULD NOT DRIFT JARS, F/P TUBING, POOH, RESTART AM, JOB IN PROGRESS 2/22/12 RIH W/ MOTOR & BI- CENTER BIT, TAG TOC @ 6808' CTMD, CORRECT DEPTH TO 6826' RKB. MILLED 284' OF CEMENT TO 7110' RKB, OPEN CIRC SUB, WASH SSSV AND GLV WHILE POOH, F/P TUBING, TURN WELL OVER TO DSO, JOB COMPLETE, READY FOR E -LINE WHIPSTOCK 3/4/12 TAGGED @ 7054' SLM, EST. 7114' RKB. DRIFTED TO SAME WITH 2.62" x 17.5' DUMMY WHIPSTOCK, NO PROBLEMS. COMPLETE. 3/10/12 PRE CTD - -PT SSV, DD TEST ON MV, SSV, (PASSED), DD TEST ON SSSV (FAILED) /14/12 Exempt rig move from 1E pad to 3K -10. Arrive on 3K pad @ 23:00 hrs. 3/15/12 Spot rig and rig up. Rig Accept at 10:00 Am. Start testing BOP's 250 low /4000 high. Start taking on fluids. State test Witnessed by Bob Noble 3/16/12 Complete BOPE test, test inner reel iron and all CTD surface equipment. P/U BHA# 1 with 3.5" Monobore Whipstock and set @ 6963'. P/U BHA #2 with 2.80" mill, start time milling from 6964'. 3/17/12 Milled first stage of window from 6963' - 6970'. P/U BHA # 3 with 2.0 AKO and 2.80" fat radious mill. Milled 7" casing from 6970 - 6974'. Exit point. ,,y Troubleshooting MP choke at surface. i't3/18/12 Continue with 7" window milling down to 6981'. Made a total of 6 backreaming passes due to seeing excess motor J work 45 degrees LOHS. Clean drift. Mud swap and P/U Build BHA with 2.3 AKO & 3" Bi- center bit. Drill Build section v to a TD of 7230'. Started to encounter fluid losses @ 7170' . 24 hour losses = 90 bbls. Tie into RA marker. TOW = 6964' BOW = 6973' RA marker = 6971' 3/19/12 Deploy BHA # 5 - RSM, RIH replace counter on injector. 1.5 hours NPT. Start drilling ahead - slow to average ROP. returns started to heal up while drilling. Total losses for 24 hours = 168 bbls. • • • • i r Application for Sundry to Plug Perforations KRU 3K -10 3K -10 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 quad- lateral from well 3K -10 is December 2011. Summary of Past Operations: Well 3K -10 was originally drilled in October 1986 as an A -Sand producer. A recent work -over was performed to set the well up for CTD to capture the production and reserve base from the planned CTD laterals. The RWO scope included pulling the existing 2 -7/8" completion, cleaning out the fill in the 7" casing, running a 3 -1/2" liner and a new 3 -1/2" L -80 tubing string with a SCSSV completion. This well previously operated under a waiver for its IAxOA annular communication due to thread leaks to gas in the 7" production casing therefore the IC packoffs were also replaced and the casing re- tensioned. Proposed Pre -Rig Work for CTD Operations • Slickline: Tag fill, obtain SBHP • E -line: GR/CCL • E -line: Perforate the 3'/2" tubing tail • Coil: Lay in /squeeze cement plug across perforations and tailpipe • �'. 1 at--/S • Slickline: Tag TOC and PT to 1500 psi. 4.,6 • Coil: Drill out cement in 3 -1/2" tubing tail • E -line: Set whipstock (Time permitting) • Prepare well site for CTD (CDR2 -AC) rig arrival. Rig Work (Proposed CTD Sidetrack Operations) t ' 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. Pull BPV 2. Mill 2.80" window at 6,960'. 3. 3K -10A Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,650' MD b. Run the 2%" slotted liner with an aluminum liner top billet from TD to —7,400' MD. 4. 3K -10AL 1 Lateral tV U .1 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 9,705' MD Page 2 of 3 10/11/2011 Application for Sundry to Plug Perforations KRU 3K -1O c. Run the 2%" slotted liner from TD to 6,955' MD, inside the 3 -1/2" tubing tail of the mother -bore. 5. Set 2" Whipstock at 6,935' 6. Mill 2.80" window at 6,935' 7. 3K -10AL2 Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,865' MD b. Run the 2%" slotted liner with an aluminum liner top billet from TD to 8,500' MD. 8. 3 K- 10AL2 -01 Lateral a. Kick off of the aluminum liner top billet at —8,500' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,335' MD c. Run the 2%" slotted liner from TD to —6,930' MD, inside the 3 -1/2" tubing tail of the mother -bore. Reservoir Pressure 3K -10 measured 1736 psi at 7025' MD (6,658' TVDss; 5.01 ppg EMW) on October 9 2011. Another SBHP is scheduled post rig work -over and pre -CTD. Maximum potential surface pressure is 3717 psi assuming a gas gradient to surface based on the potential pressure from the A -sand (3K -05) interval that measured 4337 psi at 6200' TVDss. /R� � /v ��ll c QA C UT , Pioed . f y W , /I 6 *c,I 1, m a � h /�/ /d1°. zp�191 �f Gfh�1P r�ri ✓a.'f �2��e��ur tveff , , the 5c,/ if fort' c.) Of i4e d, I L lx2'//d ,'` t re co Ve /? : n TI .. pot T; Oh of /4P icbd ! "."0f, ied04 Page 3 of 3 10/11/2011 • • 2 4k WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 27, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 0 9 2011 'Alaska Oil & Gas Cons. Commission RE: Correlation Log: 3K -10 A or4 ;w Run Date: 10/20/2011 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 3K -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21653 -00 I trANSEO MAY 3 1 2012 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: I A 12-0 / Signed: �-+ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 30, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 3K -10 ' I 201 Run Date: 9/25/2011 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 3K -10 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21653 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 2 } V`6 ( fL. Signed: oe8.44 4 - 6 3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 8, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3K -10 " t , �, - 3 ZO1Z Run Date: 2/7/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21653 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 71 Signed: )16-444- • • i'VG4C3 WELL LOG TRANSMITTAL G� To: Alaska Oil and Gas Conservation Comm. September 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 S 207' RE: Bottom Hole Pressure Survey / Tubing Cut Record: 3K -10 Run Date: 9/13/2011 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 3K -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21653 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029- 21653 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: �, � ��j Signed: /44444, &ad?, ALASKA OIL A N[ r1S T CONSERVATION OF COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 25 2.('i 1. Operations Performed: Abandon r Repair j " - Plug I�rforation r Stimula C �� tthh�� Pre CTD set -up p air well AI k8 ©�j� 61.t�8Q11S. Commission Alter Casing J""` Pull Tubing 9 Perforate New Pool f Waiver me Exte nsion Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rjri Exploratory f 186 - 163 3. Address: 6. API Number: Stratigraphic J° Service r P. O. Box 100360, Anchorage, Alaska 99510 - 50 - 029 - 21653 - — 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25520 °' - 3K - 9. Field /Pool(s): // Kuparuk River Field / Kuparuk River Oil Pool c„ 7 " c� tires [m5 10. Present Well Condition Summary: Total Depth measured 7300 feet Plugs (measured) None true vertical 6951 feet Junk (measured) None Effective Depth measured 7189 feet Packer (measured) 6795 true vertical 6860 feet (true vertucal) 6538 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 SURFACE 3792 9.625 3829 3828 PRODUCTION 7239 7 7274 6930 Perforation depth: Measured depth: 7006 -7026, 7041 -7068, 7072 -7073, 7076 -7077, 7080 -7081, 7084 -7085, 7087 -7091 True Vertical Depth: 6712 -6728, 6740 -6762, 6766 -6766, 6769 -6770, 6772 -6773, 6775 -6776, 6778 -6781 Tubing (size, grade, MD, and TVD) 3.5, L80, 6772 MD, 6519 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER (60K SHEAR) @ 6795 MD and 6538 TVD SSSV - CAMCO TRMAXX- CMT -SR -5 @ 1763 MD and 1763 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 shut -in Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development' - Service r Stratigraphic r 15. Well Status after work: -Oil d% Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR " VVINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Ian Toomey Ca 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: 263 -4773 Date `0/ tf/f/ �_ �S OCT i. Form 10 -404 Revised 10/2010 _ 1 0 fb•3 f_r/ Submit Original Only __ OUP • 3K -10 ConocoPhillips . xi - Well Attributes M ax Angle & MD j TD Ala -'L Inc .4r A x A PW WI F ll St W Il Field Name Weatus Inel () MD KB) Act Bim (ftKB) u,n<,t4a1r a 77 500292165300 1KUPARUK RIVER UNI 0 I PROD { 35.87 l _ (R 6,100 00 7,300.0 Comment 142S (ppm) Date Annotation End Date KB (ft) Rig Release Date WiP,>ngneg,, 3K 14,750/5011 PM SSSV TRDP 105 I 10/26/2010 Last WO 39.21 10/30/1986 0 0/5 Aetual Annotation Depth (HER) End Date Annotation Last Mod ... /End Date Last Tag SLM 7.004 0 4/9/2011 Rev Reason: WORKOVER 1 1 nmam 10/5/2011 Casinin HANGER, % -- C g D es gStr ption gs String 0... String ID - Top (ftKB) Set Depth (f Set Depth (NO) ... String Wt... String String Top Thrd CONDUCTOR 16 38.0 110.0 110.0 H0 D . ' C rlg Description ski g O .. so 1 062 9 IO.. Top (tU( Sat Depth (T Set OWa (Tw ... String 62.50 tNt... String String WEL Tap T Nd ED SURFACE 9 5/8 8.921 37 0 3,829.5 3 827.5 36.00 J -55 BTC !Casing Description String O... String ID .. Top (ftKB) Set Depth (t... Set Depth (TVD) . String Wt... String String Top Thrd I PRODUCTION 7 6276 35.0 72743 6.930.1 26.00 J-55 BTC CONDUCTOR, Tubing Strings 110 Tubing Description String O.. String ID... To ftKB) Set Depth f.- Set Depth ND String Wt... String String To Thrd lit 9 IP 9 9 P( ( ( 1� 9 9 9 P TUBING 3 1/2 2.992 35.0 6,772 0 6,518.8 9.30 L80 EUE 8Hd Mod SAFETY VLV, _ - - -_ 763 Completion Details Top Depth 1 (ND) Top Ina/ Hote Top (111(B) (RKB) (h Item Description Comment ID (In) 1 1111 GAS LIFT. . _ 35.0 35.0 0.24 HANGER MCEVOY GEN IV TUBING HANGER 2.875 2.507 1,762.7 1,762.6 0.46 SAFETY VLV CAMCO TRMAXX- CMT-SR -S SAFETY VALVE w/ 2.813' X PROFILE 2.812 6,725.6 6,480.4 3427 NIPPLE CAMCO X NIPPLE 2.812 j 6,771.1 6,518.1 34.36 SEAL ASSY BAKER 80-40 GBH -22 LTSA SEAL ASSEMBLY w/ 7' SPACE OUT 2.850 1 _^ Tubing Description !String 0... Siring ID ... Top (ftKB) Set Depth (f... Set Depth (N m D) . Strg Wt... !String . Thud g String Top Thud FHL PACKER I 3 1/2 � m 2 992 6,772.0 7,092.2 6,782.0 9.30 L80� EUE 8Rd Mod GAS I III. ._..._ 3. 754 Completion Details Top Depth (TVD) Top Inc' Hotel... Top(1tKB) (R (') hem Description Comment ID EM SU37 - 3.RFACE , 6,772.0 6,518.8 34.36'' PBR BAKER 8040 PBR w/ 40K SHEAR 3.000 828 - 6,795 - 6:538 1 34 41 PACKER BAKER FHL PACKER (60K SHEAR) 3.000 GAS LIFT, 7.091.3 (, 781.3 35.54 SOS SHEAR OUT WLEG 2.992 4.704 Perforations & Slots -, Shot Air Top (TVD) Elbe (TVD) Dens GAS LIFT Top (ftKB) et (ftKB] OMB) OMB) Zona Dale (sh_ Type Comment _ 5 452 ' 7,006 7,026 6,711.5 6,727.9 A - 3, 3K - 10 9/10/1988 8.0 RPERF 60 ar deg. ph; 2 1/8" EnerJet 7,009 7,010 6,714.0 6,714.8 A-3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 7,011 7,012 6,715.6 6,716.5 A-3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet GAS LIFT. - -- 6.r70 7,019 7,020 6,722.2 6,723.0 A-3, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet ens i II .,,', 7,027,046 3 7,024 7,047 6,725.5 6,744.2 6,726.3 6,745.0 A-3 -2, , 3K 3K - -10 10 12!26/1986 12/26/1986 1.0 1.0 IPERF IPERF 0 0 deg deg ph; 2 1/8 ph; 2 1/8 E" EnerJnerJet et fi.6s : 7,041 7,068 6,740.2 6,762.3 A -2, 3K -10 9/10/1988 8.0 RPERF 60 deg. ph; 2 1/8" EnerJet lir _ - -- - e 7,053 7,054 6,750.0 6,750.8 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet It 7,059 7,060 6,754.9 6,755.7 A-2. 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 7,063 7,064 6,758 2 6,759.0 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet NIPPLE, 6,726 --- ._.----- ilk 7,072 7,073 6,765.5 6,766.4 A -2, 3K -10 1226/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet N 7,076 7,077 6,768.8 6,769.6 A -2, 3K -10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet all - . 7,080 7,081 6,772.1 6,772.9 A -2, 3K -10 1226/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet SEAL ASSY. _. 6,771 7,084 7.085 6,775.4 6,776.2 A - 2, 3K - 10 112/26/1986; 1.0 IPERF 0 deg ph; 2 1/8" EnerJet PER, 6,772 j 7,091, 6,777 8 6,781 .1 - 2, 3K - 10 112/26/1986 1.0 0 IPERF 0 deg ph; 2 1 /8 " EnerJet B _- Notes: General & Safety End D ate Annotation __ 6/17/2008 NO I E SURF CSG PATCH ,12' of 16" 62511 API SL GR B . 7/26(2010 NOTE View Schematic w/ Alaska Schematic9 0 12/18/2010 NO I E: WAIVERED WELL IA x OA COMMUNICATION IPERF. -,: ; -_ __. - 7,009-7,010 IPERF, - 7,011- 7,012' RPERF. 7,006. 7,026 -- .-. IPERF, 7,0197,020 IPERF, IPERF,_ _ 7,046 -7,047 IPERF -- 7,0517,0541-- - RPERF, 7041 7068 IPERF. 7,0597,060 - 'te . IPERF,_ 7,0617,064 �, I , ;: IPERF Mann Mandrel Details - ' 7,072- 7.073 -----T----- iI Top Depth Top Port IPERF (TVD) Ind OD Valve Latch Size TRO Run 7,076 -7,077 Stn Top (HKB7_ (RICE) (% Make Model (in) See TYPe TYPe (in) (psi) Run Date Com... 1 2,507.2 2,506.7 3.65 CAMCO MMG 1 12 GAS LIFT DMY RK 0. 000 0.0 9/22/2011 7,0697,061 _ 2 3,793.7 3,791.7 1.23 CAMCO MMG / 12 GAS LIFT DMY RK 11.000 0.0 9222011 IPERF _ _ 3 4,703.7 4,698.0 13.63 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/22/2011 7,084 - 7,085 ,'` 4 5,451.8 5,402.6 24.81 CAMCO MMG 1 12 GAS LIFT DMY : RK 0.000 0.0 9222011 7.067 -7.09 IPERF . 5 6,169.6 6,023.9 35.63 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 9/22/2011 6 6,669.5 6,434.2 34.35 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 9/22/2011 SOS, 7.081 . `':. PRODUCTION, 35-7,274N - T0,7,300 3K -10 Pre and Post Rig Work DATE SUMMARY 3/29/11 TAGGED @ 7004' SLM, EST. 53' FILL. SE . 5 CA -2 PLUG @ 6920' RKB; DEPLOYE A CATCHER SUB. PULLED OV @ 6838' RKB. READY FOR CIRC OUT. 3/30/11 CIRC TBG / CSG TO DSL. CMIT 2500 PSI, PASSED. SET OV @ 6837' RKB; FAILED TEST. CONFIRMED OV IN GLM. IN PROGRESS. 3/31/11 RAN HOLEFINDER TO 6837' SLM; TESTED TBG 1000 PSI, BLED IA TO 150 PSI, HELD SOLID. PULLED CATCHER @ 6851' SLM. PULLED 2.25 CA -2 PLUG @ 6920' RKB. COMPLETE. 4/8/11 REPLACED OV @ 6838' RKB, PULLED DV's @ 6442' & 5427' RKB, PULLED GLV's @ 6016', 4294', 2545' RKB, IN PROGRESS. 4/9/11 SET GLV's AT 6442, 5427, 4294, 2546' RKB, SET DV @ 6016' RKB, TAG FILL @ 7004' SLM, COMPLETE. 9/8/11 BRUSH'n FLUSH TBG TO D NIPPLE. SET 2.25" CA -2 PLUG @ 6920' RKB. DEPLOYED CATCHER. REPLACED GLVs @ 6441', 5427' RKB W/ DVs. PULLED GLV @ 2545' RKB. IN PROGRESS. 9/9/11 PULLED GLV @ 4294' RKB. SET DVs @ 4294' & 2545' RKB. PULLED OV @ 6837' RKB & LEFT POCKET OPEN. READY TO LOAD WELL. 9/10/11 CIRC 250 BBL DSL DOWN TBG UP IA. COMBO MIT 2500 PSI, PASSED. PULLED CATCHER @ 6898' SLM. PULLED CA -2 EQ PRONG @ 6920' RKB. IN PROGRESS. 9/11/11 PULLED PLUG BODY @ 6920' RKB. MEASURED BHP @ 7025' RKB: 1411 PSI. BRUSHED AND FLUSHED TRDP -IA -SSA. UNABLE TO SEE FLOW TUBE MOVEMENT OR CATCH FLAPPER; FLOW TUBE APPARENTLY STUCK DOWN. UNABLE TO ENGAGE CHOKE LOCKING RECESS WITH Z -5. READY FOR E /L. 9/13/11 LOG SBHP SURVEY AT TAG DEPTH 7030' RKB. MAX PRESSURE 1435 PSI @162 DEG F. CUT 2.875" TUBING IN FIRST FULL JOINT ABOVE SBR OEJ. CUT DEPTH 6863' CCL- CUTTER HEAD 9.2' CCL STOP DEPTH 6853.8'. i. 9/24/11 LOGGED 40 ARM MIT FROM A TAG DEPTH OF 7185' TO SURFACE TO INSPECT 7" CASING AND VERIFY INTEGRITY. LOG WILL BE POST PROCESSED BY HALLIBURTON ANCHORAGE, ALASKA. 9/29/11 ASSIST NORDIC 3. SET 2.81" XX PLUG @ 6725' RKB. PT TBG TO 2500 PSI. MITIA TO 3500 PSI, PASSED. COMPLETE. 10/8/11 PULLED SOV @ 6669' RKB, REPLACED WITH DV. PULLED XX PLUG @ 6725' RKB. TAGGED @ 7172' SLM. MIT IA 2500 PSI, PASSED. IN PROGRESS. 10/9/11 MEASURED BHP @ 7025' RKB: 1736 PSI & FALLING. COMPLETE. • S C ©noe Phillips Time Log & Summary Weilwew Web Reporting Report Well Name: 3K - 10 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/20/2011 4:00:00 PM Rig Release: 10/1/2011 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/15/2011 24 hr Summary Released Nordic Rig 3 from 1D-105A. Move Rig and Equipment to 3K -Pad. 00:00 00:30 0.50 DEMOB MOVE SFTY P PJSM- Discussed hazards of moving Rig, Good Communication needed. 00:30 04:00 3.50 DEMOB MOVE MOB P Move Rig and Equipment 1D-Pad to 3K -Pad. 04:00 07:00 3.00 DEMOB MOVE MOB P Standing by at KOC for Field Crew Change Out. 07:00 14:45 7.75 MIRU MOVE MOB T Continue to Move Rig and Equipment from KIC to1 E PAd Access, Rig mat shuffle to 1A- Pad access. 14:45 19:00 4.25 MIRU MOVE MOB T Standby at 1A Pad access for mats to be shuffled ahead of rig and Field crew change 19:00 00:00 5.00 MIRU MOVE MOB T Continue to Move Rig and Equipment from 1A -Pad to 3K -Pad. 09/16/2011 Move Rig and Equipment shuffling mats ahead of rig to 3K -Pad. 00:00 00:30 0.50 MIRU MOVE MOB T Continue to Move Rig and Equipment shuffling mats ahead of rig from 1A -Pad to 3K -Pad. 00:30 03:30 3.00 MIRU MOVE MOB T Rig fell thru road approximatley 1/8 mile from 1Q -pad, Using crib, plywood and mats pull rig out, 03:30 12:30 9.00 MIRU MOVE MOB T Continue to Move Rig and Equipment shuffling mats ahead of rig to 10-Pad 12:30 13:30 1.00 MIRU MOVE MOB T Standby at 10 Pad access for mats to be shuffled ahead of rig and Field crew change 13:30 00:00 10.50 MIRU MOVE MOB T Continue to Move Rig and Equipment from 1Q -Pad shuffleing mats ahead of rig to 3K -Pad. 09/17/2011 00:00 14:15 14.25 MIRU MOVE MOB T Continue to Move Rig and Equipment from 10-Pad shuffleing mats ahead of rig to 3K -Pad. 14:15 19:30 5.25 MIRU MOVE MOB T Rig at CPF -3 and set down, shut down for Change out till 19:00 hrs this will allow all logistics to be handled for STP Area, Pionner and ENI. 88 extra mats were acquired from GBR to assist in move from CPF -3 to 3K -Pad. 19:30 22:30 3.00 MIRU MOVE MOB T All logistics complete to STP, Pioneer and ENI. start laying mats in front of Rig. Continue to Move Rig and Equipment from CPF -3 laying mats ahead of rig to 3K -Pad. Page 1 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 MIRU MOVE MOB T Rig at 3C -Pad Access, Move Mats around laying in front of Rig. 09/18/2011 00:00 01:30 1.50 MIRU MOVE MOB T Rig at 3C -Pad Access, Move Mats around laying in front of Rig. 01:30 22:30 21.00 MIRU MOVE MOB T Continue to Move Rig and Equipment from 3C -Pad Access shuffleing mats ahead of rig to 3K -Pad Access. 22:30 00:00 1.50 MIRU MOVE MOB T Rig moved off Oliktok road, set down at entrance of 3K -Pad / E -Pit Access road, move remaining mats off Oliktok and infront of Rig. Check equipment. 09/19/2011 00:00 01:30 1.50 MIRU MOVE MOB T Rig moved off Oliktok road, set down at entrance of 3K -Pad / E -Pit Access road, move remaining mats off Oliktok and infront of Rig. Check equipment. 01:30 00:00 22.50 MIRU MOVE MOB T Continue to Move Rig and Equipment down 3K -Pad / E -Pit Access shuffleing mats ahead of rig to 3K -Pad. 09/20/2011 Move Rig and Equipment shuffling mats ahead of rig to 3K -Pad. Load 11" 5M BOPE to Rig. MIRU on 3K -10 Well Slot. Spot Support Equip. Test lines. Circulate Well to 8.6 lb /gal Seawater. 00:00 01:30 1.50 MIRU MOVE MOB T Arrived at 3K -Pad Access, move mats around to front of Rig. Check equipment.. 01:30 12:30 11.00 MIRU MOVE MOB T Continue to Move Rig and Equipment down 3K -Pad Access shuffleing mats ahead of rig to 3K -Pad. 12:30 13:30 1.00 MIRU MOVE OTHR P Load 11" 5M BOP in cellar, along with production tree. 13:30 16:00 2.50 MIRU MOVE RURD P Pull rig over 3K -10 and set down. Start to berm up around rig and spot auxiliary equipment. 16:00 17:00 1.00 COMPZ WELCTI RURD P Rig up circulating lines. Accept Rig at 16:00 hours. 17:00 18:30 1.50 COMPZ WHDBO MPSP P PJSM. Pick -up Lubricator. Pull BPV. Lay down same. Tbg press = 125. IA press = 100, OA press = 600 psi. 18:30 20:30 2.00 COMPZ MOVE RURD P Additional support equipment arrives on Location. Spot and berm up Cuttings Bin and Boiler Blowdown Box. Complete rigging up hardline to Tree. 20:30 22:30 2.00 COMPZ MOVE RURD P Off -load 8.5 heavy Sea Water into Rig Plts. Page 2 of 12 i • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 COMPZ WELCTL KLWL P PJSM. Test lines at 250/3,000 psi. Good. Bring Pump on line at 5.0 bpm/70 psi. Got returns after pumping 94 bbls (static FL was 3,100 -ft). Continue to circulate Well at 5.0 bpm /280 psi. Returns = Diesel. 09/21/2011 Complete Well Kill. Set BPV /Blanking Plug. ND Tree. NU BOPE. Test BOPE. Pull Blanking Plug /BPV. BOLDS. Pull Tbg Hanger to Floor. Circulate Well. Begin to single down 2 7/8" Completion. 00:00 01:30 1.50 COMPZ WELCTL KLWL P Continue to circulate Well at 5.0 bpm /650 psi. Returns = Sea Water /Diesel. Pumped a total of 445 bbls of Sea Water. Total bbls recovered = 190. Circulation efficiency = —42 %. Final circulating pressures at 5.0 bpm = TP 870, CP = 40 psi. Final returns 8.5 heavy ppg Sea Water. Monitor Well on vacuum. 01:30 02:00 0.50 COMPZ WHDBO MPSP P Install BPV. 02:00 04:00 2.00 COMPZ WHDBO NUND P PJSM. Nipple down Production Tree. Inspect Tubing Hanger Threads. Install Blanking Plug. 04:00 09:00 5.00 COMPZ WHDBO NUND P PJSM. Nipple uo 11" x 5K BOP Stack with 2 7/8" x 5" VBPRs installed in the upper ram gate, Blind Rams in the middle gate, and 2 7/8" x 5" VBPRs installed in the bottom gate. 09:00 09:15 0.25 COMPZ WHDBO SFTY P Held PJSM on testing BOPE 09:15 15:00 5.75 COMPZ WHDBO BOPE P RU test equipment, conduct Initial 1?)DI BOPE test at 250/3.000 psi, RD Test equipment. Right to witness (45 was waived by Matt Herrera at 06:25 hrs on 9- 21 -11. 15:00 15:15 0.25 COMPZ WHDBO MPSP P Drain stack and Pull BPV, well on vacumm 15:15 15:30 0.25 COMPZ WHDBOOTHR P MU 31/2 Landing pup joints, install 3 1/2 8rd FOSV in open position. Secure IA and OA. 15:30 00:00 8.50 COMPZ RPCOM OWFF X Standby with crews, monitoring well VIA Tubing whille waiting on logistics. Mobilize Rig Camp towards 3K Pad. 09/22/2011 Resume normal operations. BOLDS. Pull Tbg Hanger free. Circulate Well. Single down 2 7/8" Completion. MU and RIH with BHA #1 on single 3 1/2" Drill Plpe from Plpe Shed. Engage 2 7/8" Tbg Stump and pull OEJ free. TOOH. 00:00 02:30 2.50 COMPZ RPEQP1OWFF X Complete mobilizing Rig Camp to Location. Spot and level same. Establish phone and inter -net communications before resuming operations on present Well per ConocoPhillips. Page 3 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:00 1.50 0 6 COMPZ WHDBO THGR P PJSM. Pump 30 bbls down IA. Pump 30 bbls down Tubing. BOLDS. Screw into Top Drive. Pull Tubing Hanger off -seat at 75K. Tubing dragging at 100K, then fell back to an expected normal string weight at 80K. 04:00 06:30 2.50 6 COMPZ WELCTL CIRC P Bring Pump on line at 4.0 bpm. Took 128 bbls to catch returns. Circulate Well at 4.0 bpm /510 psi. Had returns at 128 bbls pumped of the 512 bbls pumped. 06:30 07:00 0.50 COMPZ WELCTL OWFF P Monitor well - well taking fluid - BDTD 07:00 16:30 9.50 COMPZ RPCOM PULL P POOH laving down landing joint and 3 1/2 x7" TBG Hanger on full joint of 3 1/2 TBG. Continue to POOH laying down TBG, spooling up control line to SSSV, Recovered 30 SS bands, 6 - GLM, 210 joints of 2 7/8" J -55 tubing and 17.34 -ft of 2 7/8 TBG stub. Offload pipe shed and clear rig floor. 16:30 19:30 3.00 COMPZ RPCOM OTHR P Change over to 3 1/2 DP equipment and finish loading remaining 3 1/2 DP, 9 -4 3/4" OD Drill collars and BHA #1. 19:30 20:00 0.50 0 0 COMPZ RPCOM OTHR P Install Wear Bushing. 20:00 21:30 1.50 0 311 COMPZ RPCOM PULD P PJSM. Pick -up BHA #1: Overshot w/2 7/8" Basket Grapple. 21:30 00:00 2.50 311 3,341 COMPZ RPCOM PUTB P Trip in with BHA #1 and single 3 1/2" Drill Pipe from the Pipe Shed. Up Weight = 95K . Down Weight = 90K 09/23/2011 Complete TIH w /BHA #1. Latch Tbg Stump and pull OEJ free. Circ Well. TOOH. LD BHA #1 and recovered OEJ. MU BHA #2.TIH. Latch Slick Stick and pull Slick Stick/Packer Assy free. TOOH. LD BHA #2 and recovered Fish. MU BHA #3.TIH and clean out Fill. 00:00 03:30 3.50 3,341 6,851 COMPZ RPCOM PUTB P Continue to single in BHA #1 with 3 1/2" Drill Pipe from the Pipe Shed. Up Weight = 149K. Down Weight = 120K. Tagged top of the 2 7/8" Tubing Stump at 6.851 -ft dpmd� 03:30 04:00 0.50 6,851 6,856 COMPZ RPCOM FISH P Bring Pump on line at 3.0 bpm. Swallow the Tubing Stump down to the Top Sub. Pull 50K over string weight. OEJ Fish pulled free. Set back down and stacked out at the same spot. 04:00 05:30 1.50 6,856 6,846 COMPZ RPCOM CIRC P Pick -up. Circulate and condition Well at 4.0 bpm /530 psi. 05:30 06:00 0.50 6,846 6,846 COMPZ RPCOM OWFF P Monitor well - lossing fluid, Blow down top drive 06:00 06:30 0.50 6,846 6,567 COMPZ RPCOM TRIP P POOH from 6,846 -ft to 6,567 -ft. Change out with crews Page 4 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:30 1.00 6,567 6,567 COMPZ RPCOM CIRC P Circulate at 4 bpm to fill hole to gather slow pump rates. Pump (1) 2 BPM 100 psi; 3 BPM 230 psi Pump (2) 2 BPM 100 psi; 3 BPM 220 psi @ 8.6 ppg mud wt. at 6,663 -ft 07:30 11:00 3.50 6,567 311 COMPZ RPCOM TRIP P POOH from 6,567 -ft to 311 -ft. Double displacing, Monitor well for flow. 11:00 12:00 1.00 311 0 COMPZ RPCOM PULL P POOH with BHA #1, lay down 14 -ft c*c. 15 �n of 2 7/8 TBG cut, 8 -ft 2 7/8 pup joint, f 16 -ft of Camco OEJ w/ 3.25" ID Total of 38 -ft recovered. 12:00 13:00 1.00 0 311 COMPZ RPCOM PULD P MU BHA #2 w/ 3.25" Grapple and RIH to 311 -ft 13:00 16:00 3.00 311 6,824 COMPZ RPCOM TRIP P RIH with BHA #2 from 311 -ft to 6,824 -ft. 144k up wt / 120k dn wt. 16:00 16:30 0.50 6,824 6,921 COMPZ RPCOM FISH P Kelly up top drive and break circulation at 3 bpm at 600 psi - took 35 bbls to load hole. Engage OEJ Stem at 6,878 -ft, Let jars bleed and straight pull to 220k, 76k overstring „ wt. Packer came free. 16:30 20:00 3.50 6,921 6,921 COMPZ RPCOM CIRC P Circulate at 3 bpm at 170psi ICP with 75% returns, returns slowed - packer packing off slowed rate to 1 bpm at 60 psi getting 100% returns. Monitor Well. 20:00 00:00 4.00 6,921 2,340 COMPZ RPCOM TRIP P Blow down Top Drive. POOH from 6,921 -ft up to 2,340 -ft. Up Weight = 80K. 09/24/2011 Complete TOOH with Packer "Fish ". LD same. LD BHA #2. MU BHA #3. TIH with BHA #3. Clean -out Fill. TOOH. LD BHA #3. Rig up E -Line and record a 7" Casing Caliper Log. 00:00 01:45 1.75 2,340 44 COMPZ RPCOM TRIP P Finish tripping out with 3 1/2" Drill, Plpe, BHA #2, and the Packer "Fish" 01:45 02:30 0.75 44 0 COMPZ RPCOM PULD P Lay down Fish. Recovered the OEJ Slick Stick, Camco 7" Packer (missing one rubber element), 8 -ft Pup Joint, "D" Nipple, 8 -ft Pup Joint, Camco Shear -Out Sub/WLEG. 02:30 04:00 1.50 0 501 COMPZ WELLPF PULD P PJSM. Clear and clean Floor. Bring BHA #3 components to Floor. Make -up BHA #3 6 1/8" Six Blade Junk Mill and 7" Casing Scraper. 04:00 08:30 4.50 501 6,892 COMPZ WELLPF TRIP P Trip in with BHA #3 and 3 1/2" Drill Pipe from the Derrick to 6,892 -ft. 145k up wt, 122k dn wt. Page 5 of 12 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 14:00 5.50 6,892 7,175 COMPZ WELLPF FCO P Establish parameters circulating at 3 bpm at 235 ICP while rotating at 40 rpm's with 2,700 ft/lbs free torque. ROT Wt at 138k. Increase pump rate to 4 bpm at 560 psi and wash down from 6,982 -ft to 7,140 -ft and tag up expected top of fill was — 7,036 -ft. Increase rpm's to 50 and continue to clean out to 7,175 -ft. Pump 30 bbl hi visc sweep and circulate surface to surface - Frac sand in returns. Pump 2nd 30 bbl hi visc sweep and circulate half of the calculated surface to surface strokes and POOH from 7,175 -ft to 6,982 -ft. Continue to circulate out 2nd sweep at 4 bpm at 430 psi - Frac sand in returns. RIH and dry tag at 7,172 -ft. �. 14:00 18:30 4.50 7,172 0 COMPZ WELLPF TRIP P POOH with Drill Pipe and BHA #3 from 7,172 -ft. to 501 -ft. Lay down BHA #3 18:30 19:30 1.00 0 0 COMPZ WELLPF PULD P Clear and clean Floor. Kick out Baker Fishing Tools and 4 3/4" Drill Collars. 19:30 22:00 2.50 0 0 COMPZ EVALWE NUND P PJSM. Prep for E -Line Ops. ,Nipple down Flow Nipple. Nipple up Shooting Flange. Spot HES E -Line Unit. 22:00 00:00 2.00 0 0 COMPZ EVALWE RURD P PJSM. Rig up E -Line equipment. Attempt pressure test Lubricator at 250/1,500 psi.. "0" Ring leak. Replace. Re -test at 250/1,500 psi. Good. 09/25/2011 RIH with GR /CCU40 -Arm Caliper Tool String. Record 7" Csg Caliper Log. RD E -Line. Prep to run the Lower Completion section. RIH w /FHL Pkr on 3 1/2" Drill Pipe. Pick -up Storm Pkr and set same. ND BOP Stack. ND Tbg Spool. Change out Pack -Offs. 00:00 04:00 4.00 0 0 COMPZ EVALWE FLOG P RIH with GR/CCU40 -Arm Caliper Tool String. Recorded a 7" Caliper Log from 7,185 -ft elmd back to surface at 50- ft/min. Tied into the Schlumberger CBL Log dated, 11 -18 -86 for depth control. 04:00 05:00 1.00 0 0 COMPZ EVALWE RURD P Finish Log. Lay down Logging /Tools. Lay down Lubricator, Rig down E -Line Unit and release. 05:00 06:30 1.50 0 0 COMPZ EVALWE NUND P PJSM. Nipple down Shooting Flange. Nipple up Flow Nipple. 06:30 08:00 1.50 0 0 COMPZ RPCOM OTHR P RU Floor to RIH w/ FHL Packer assy. 08:00 08:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM on MU and RIH w/ FHL Packer assembly, Baker locking all connections below FHL Packer and make up torque 2,240 ft/lbs. 08:15 08:45 0.50 0 327 COMPZ RPCOM PULD P PU, MU and RIH Baker FHL Packer completion to 327 -ft. Page 6 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 11:30 2.75 327 2,336 COMPZ RPCOM TRIP P RIH w/ FHI Packer completion from ,327 -ft to 2,262 -ft. PU and MU Baker Storm Packer and RIH to 50 -ft and set with tail at 2,336 -ft. Rlease off and POOH with setting tool. 11:30 12:30 1.00 50 50 COMPZ WHDBO PRTS P RU Testing equipment and Test void between Blind Rams and Storm packer at 3,000 psi with force equal to 4,100 psi - 75% of 7" Casing Burst of 7,240 psi = 5,430 psi. Held pressure for 5 minutes with no bleed off - no flow - monitored for 15 minutes. Release pressure and RD test equipment. 12:30 12:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew on ND BOPE and TBG spool. 12:45 14:00 1.25 0 0 COMPZ WHDBO NUND P ND BOPE and set back. 14:00 00:00 10.00 0 0 COMPZ WHDBO NUND P Begin ND CIW 7 1/16" 5M x 11" 3M TBG Spool - had growth - call out Hydratight system. Rig up Hydratight Tool and control Casing growth. Beginning pressure was 5,000 psi. Final pressure was 700 psi. Total Tool cycles = 40. Total Casing growth = 13 1/2 ". Rig down Hydratight Tool. Plant 7" Casing Spear. Pick -up on 7" Casing and remove Slips. Install Emergency Slips. Set Slips in 50K tension. Release Spear and lay down same. Rig up WACHS Cutter and cut off Casing per Cameron Service Rep. Rig down WACHS Cutter. Install new Pack -Offs. Nipple up Tubing Spool. Test Pack -Offs at 250 psi x 5 minutes and at 3,000 psi x 10 minutes. 09/26/2011 NU BOP stack and test body break. Release Storm Pkr. Pull and LD same. Continue to RIH with lower Completion. Attempted to set FHL Pkr. Could not get ball to seat. POOH, recovered seal assembly, lost the PBR, FHL and tailpipe. Wait on PBR retrieving tool and fishing hand. 00:00 03:30 3.50 0 0 COMPZ WHDBO NUND P PJSM. Nipple up BOP Stack. 03:30 04:30 1.00 0 0 COMPZ WHDBO PRTS P Rig up test equipment. Test BOP body break at 250/3,000 psi x 5 minutes each. Good test. Record on chart. The State's right to witness the test was waived by C. Scheve. Rig down test equipment. 04:30 05:30 1.00 70 70 COMPZ WELLPF PACK P Set Wear Bushing. Pick -up working joint. Screw into Storm Packer at 70 -ft. Release same. Monitor Well on Vacuum. 05:30 06:15 0.75 70 70 COMPZ WELLPFCIRC P Fill well with 97 BBLS and circulate Well with add! 64 BBLS at 3 bpm at 60 ICP and 90 FCP 06:15 06:45 0.50 70 0 COMPZ WELLPF PULD P POOH with Storm packer and lay down same. Page 7 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 2,262 2,262 COMPZ WELLPF OWFF P Continue to Monitor well for flow - taking fluid. 07:00 10:30 3.50 2,262 7,092 COMPZ RPCOM TRIP P Continue to RIH with FHL Packer assy on 3 1/2 DP from 2,262 -ft. to 7,092 -ft. 125k up wt, 120k do wt. 10:30 14:15 3.75 7,092 7,092 COMPZ RPCOM PACK P Drop 2" steel ball and begin to pump at 1 bpm at 55 psi, increase to 1.5 bpm at 65 psi, increase to 3 bpm at 155 psi with 42 bbls total pumped. POOH for 80 -ft to 7,012 -ft and run back down to 7,092 -ft. Reverse 3 bpm at 50 psi for 5 bbls and switch back to pumping down DP staging up from 1 bpm to 3 bpm for 15 bbls with no change. Mixed 25 bbl hi visc sweep and pumped at 3 bpm at 190 psi followed by 35 bbls of sea water - no change in pressure. Call and talk to RWO Engr about options and possibilities of premature ball seat shear due to impact from ball drop. 2.69" OD and 2.78" OD WRP required for 3 1/2" TBG were unable to be ran due to 2.56" Drift on 3 1/2 DP. Decision was made to POOH till string came wet or till out of the hole with BHA. 14:15 14:45 0.50 7,092 6,818 COMPZ RPCOM TRIP T POOH from 7,092 -ft to 6,818 -ft 14:45 15:00 0.25 6,818 6,818 COMPZ RPCOM SFTY P Held PJSM with rig crew on slip and cut 84 -ft of 1 1/8" Drill line. Inspect and service draw works. 15:00 16:30 1.50 6,818 6,818 COMPZ RPCOM SLPC P Slip and cut 84 -ft of 1 1/8" Drill line. Inspect and service draw works. 16:30 22:00 5.50 6,818 0 COMPZ RPCOM TRIP T Continue to trip out from 6,818 -ft with the FHL Lower Completion section. Up Weight = 123K. Down Weight = 119K. Recovered the Seal Assembly...no PBR /FHL Packer, Tailpipe. The Seal Assembly had sheared from the PBR. However, the "how or why" remains a mystery as the Packer was never set or had hung up on the trip in or the trip out. 22:00 00:00 2.00 0 0 COMPZ RPCOM FISH T Discuss with Baker Packers and Baker Fishing Tools. Order out Pulling Tool. Wait on Fisherman with Pulling Tool. Load 4 3/4" Drill Collars, Oil Jar, and Bumper Sub in Plpe shed. 09/27/2011 MU BHA #4 to fish the PBR/FHL Pkr. Trip in with BHA #4. Engage Fish. Trip out. LD Fish and BHA #5. Re -pin Seal Assembly and inspect Pkr.Trip in the FHL Lower Completion Section. Set Pkr. Shear Seal Assembly. TOOH and single down 3 1/2" Drill Pipe. 00:00 02:00 2.00 0 COMPZ RPCOM FISH T Wait on Fishing Tool and Fisherman to arrive on Location. Page 8 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 06:00 4.00 COMPZ RPCOM FISH T PJSM. Make -up BHA #5....Packer Retrieval Tool. Trip in with BHA #5 on 3 1/2" Drill Pipe from the Derrick. (expected top of Fish at 6,881.8 -ft). 06:00 06:30 0.50 6,853 6,853 COMPZ RPCOM FISH T Up Weight = 120K. Tag Top of Fish at 6 „853 -ft. Latch Fish. Pull up hole with 10K drag. Fill hole down the back -side. Monitor Well on slight vacuum. 06:30 12:30 6.00 6,853 115 COMPZ RPCOM TRIP T Continue to trip out slowly , standing back Drill Pipe in the Derrick. 12:30 14:30 2.00 115 0 COMPZ RPCOM PULD T Change Out Floor Equipment and Lay Lower Packer Assembly. Packer Was sheared 14:30 15:45 1.25 0 0 COMPZ RPCOM OTHR T PJSM. Inspect and Replace Shear Screws on Packer Assembly. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM. Discuss Hazard for Making Up Packer Assembly. 16:00 17:15 1.25 0 352 COMPZ RPCOM PULD T MU FHL Packer Assembly. BakerLok all connections below the FHL Packer. 17:15 22:00 4.75 352 6,794 COMPZ RPCOM TRIP T Continue in hole with Packer Assembly on Drill Pipe. 22:00 23:30 1.50 6,794 6,794 COMPZ RPCOM PACK P Up Weight = 132K. Down Weight = 120K. Position Packer at 6,794 -ft with the end of the Tailpipe at 7,092 -ft. Fill Well and circulate at 2.0 bpm /140 psi. Pump a 20 bbl HI -Vis Pill and spot at the end of the Drill Pipe with 33 bbls of Sea Water. Drop a 2 inch Packer Setting Ball. Wait on ball to fall on seat. Pressure up on the Drill Pipe to 2,527 psi and hold for 5 minutes to set Packer. Good. Bleed press back to 1,000 psi. Pull —30K over the string weight and shear the Seal Assembly free from the PBR at 155K. 23:30 00:00 0.50 6,778 6,778 COMPZ RPCOM PRTS P Pull Seal Assembly from PBR. Pressure up on Wellbore to test the Casing and the Packer at 1,500 psi x 10 minutes. Good. Record on Chart. 09/28/2011 Single down 3 1/2” DP to — 2,200'. PU and set Storm Pkr. Pressure test. Set Test Plug. Perform Weekly BOPE test. Pull test Plug. Release and pull Storm Pkr. Continue to single down DP. Prep for and begin to run Upper Completion. 00:00 06:00 6.00 6,778 1,935 COMPZ RPCOM TRIP P Begin to single down 3 1/2" Drill Pipe & Drill Collars in Pipe shed. Clear Pipe Shed as needed. 06:00 08:30 2.50 1,935 2,000 COMPZ WELCTt PACK P PJSM. M/U Storm Packer and set at 65' and with 60 joints of 3.5" Drill Pipe Below. PT storm packer 250/3000 psi for 5 mins. Perform draw down to zero. 08:30 09:30 1.00 2,000 2,000 COMPZ WELCTL PULD P PJSM. Pull Wear Ring. Set Test Plug. Page 9 of 12 w S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 09:45 0.25 2,000 2,000 COMPZ WELCTLSFTY P PJSM. Discuss Hazards for High Pressure Testing. 09:45 10:00 0.25 2,000 2,000 COMPZ WELCTL PRTS P Perform Shell Test in BOP stack.250 /3000 psi. 10:00 10:30 0.50 2,000 2,000 COMPZ WELCTL OTHR P Standby for AOGCC Rep. 10:30 16:15 5.75 2,000 2,000 COMPZ WELCTL BOPE P AOGCC Rep on Location. Start kW Weekly BOP Test, 250/3000 psi., Number 2 Valve on choke manifold failed during testing operations. 16:15 16:30 0.25 2,000 2,000 COMPZ WELCTL SFTY P PJSM. Discuss Hazard for Changing out High Pressure Valve. 16:30 22:00 5.50 2,000 2,000 COMPZ WELCTL EQRP T Change Out Choke Manifold Valve #2. 22:00 23:00 1.00 2,000 2,000 COMPZ WELLPF BOPE P Test Choke Valve #2 at 250/3,000 psi. Good test. Record on Chart. (as requested by the State Inspector, an e-mail was sent to the AOGCC upon completion of the Valve change -out and a successful test). rig down test equipment. Pull Test Plug. Set Wear Bushing. 23:00 00:00 1.00 2,000 1,935 COMPZ WELCTL PACK P Pick -up Retrieving Tool and two Joints of Drill Plpe. Equalize and release Storm Packer. Up Weight = 63K. Pull out and lay down same. 09/29/2011 Single down remaining Drill Pipe. Rig up Floor to handle the 3 1/2" Upper Completion. Single in the Upper Completion as designed. Space out Completion. Spot Corrosion Inhibited Sea Water. Land Completion. 00:00 02:00 2.00 1,935 0 COMPZ RPCOM TRIP P Continue to single down the remaining 3 1/2" Drill Plpe. Lay down the Baker 80 -40 PBR Seal Assembly. Pull Wear Bushing. 02:00 03:30 1.50 0 0 COMPZ RPCOM PUTB P Change over handling equipment to pick -up 3 1/2" Tubing. Perform final Jewelry inspection. Review running order. 03:30 08:30 5.00 0 4,994 COMPZ RPCOM PUTB P PJSM. Sin0le in the. 3 1/7" (;as I ift. Completion ection as designed. 08:30 10:00 1.50 4,994 4,994 COMPZ RPCOM OTHR P Stop & Wait for SLB to Install SSSV & Run Control Lines. Up Wt =79k / Dn Wt =80k 10:00 13:45 3.75 4,994 6,725 COMPZ RPCOM PUTB P PJSM with SLB & Rig Crew. Install TRMAXX- CMT -SR -5 w/ 2.813" X profile and Pressure Up Control Line to 5000 psi. Continue In hole w/ 3.5" Completions. 13:45 14:45 1.00 6,725 6,763 COMPZ RPCOM OTHR P Located PBR at 6763'md, with charge pump, 60 psi on tbg, saw seals engage PBR with a pressure increase to 140 psi, shut down charge pump and bled down pressure from TBG, continue in hole until lower seal assembly was fully located and No -Go out 6769' ft. Up _Wt 95k and Dn Wt 95k Page 10 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 COMPZ RPCOM PULD P Lay down 3 joints and Made up a 10.15,8.12' & 6.13 space out pup. Pick -up joint number 207 and tubing hanger w /pup. Installed a total of 60SS Bands. 15:00 16:00 1.00 6,745 6,745 COMPZ RPCOM CIRC P Circulated 20 bbls of 8.6 ppg corrosion inhibited seawater down TBG until displace up backside at 4 bpm, 230 psi. 16:00 16:45 0.75 6,768 6,768 COMPZ RPCOM OTHR P Secure Control line to Hanger. Landed Hanger and RILDS. Function tested and PT SCSSV to 5000 psi for 30 mins. 16:45 18:00 1.25 COMPZ RPCOM PRTS P Rig up Testing equipment. Attempted to pressure test Tubing at 2,500 psi. However, at 2,200 psi pressure fell to "0" psi. Pumping Sea Water away at 1.0 bpm /140 psi. (it is assumed that the Shear -Out Sub, sheared). 18:00 20:00 2.00 COMPZ RPCOM SLKL T Call out Slick Line Unit and wait for the Unit to rig down off of a job in progress and arrive on Location. 20:00 22:30 2.50 COMPZ RPCOM SLKL T PJSM. Spot Slick Line Unit and rig up. 22:30 00:00 1.50 COMPZ RPCOM SLKL T Pressure test Lubricator at 500 psi. Run in with a 2.800 "Drift to 6,700 -ft with no problems. POOH. Run in with a 2.813" XX Plug. Set down in the SSSV at 1,762 -ft. POOH to inspect Plug and re -dress same. 09/30/2011 Set BPV, Secure Well. Day Crew scheduled to attend Training. Resume operations at —18:00 hrs to complete Well and Freeze Protect. 00:00 03:00 3.00 COMPZ RPCOM SLKL T Run in with a Brush and clean up the SSSV. Pump 20 bbls of Sea Water. Continue on in the hole and brush the X- Nipple at 6,726 -ft. POOH. Run in with a 2.813" XX Plug. Eased through the SSSV and continue on in the hole. Set the Plug in the X- Nipple. POOH. Set Back Lubricator. 03:00 04:30 1.50 COMPZ RPCOM PRTS T Pressure test the Tubing at 2 500 psi x 15 minutes. (observe "no- flow" from the IA). Bleed tubing pressure back to 1,800 psi. Pressure test casing and Packer at 3,500 psi x 30 minutes. Both tests good. Record on Chart. Bleed the IA pressure to "0 ". Bleed the Tubing pressure to 04:30 05:30 1.00 COMPZ RPCOM SLKL T PJSM. Rig down S -Line and release. 05:30 06:00 0.50 COMPZ WHDBO PLUG T Set BPV. Secure Well. 06:00 16:00 10.00 COMPZ RPCOM SFTY P Suspend operations so the Day Crew could attend the Balmert Safety Training Seminar. Page 11 of 12 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 COMPZ RPCOM PLUG P PJSM. Pull BPV. Well remains static. 17:00 18:30 1.50 COMPZ RPCOM PRTS P PJSM. Line up to pump down the IA. Shear SOV open. Close the SSSV. Pressure up on the closed SSSV from underneath to 1,000 psi x 10 minutes. Good test. Both tests recorded on a Chart. 18:30 19:30 1.00 COMPZ WHDBO PLUG P Install BPV. Rig down hoses in the Cellar. 19:30 22:30 3.00 COMPZ WHDBO NUND P PJSM. Nipple down BOP Stack. Open "Doors" inspect Ram Blocks and flush a small amount of sand from the cavities. Set Stack back on the Stump. 22:30 00:00 1.50 COMPZ WHDBO NUND P PJSM. Nipple up Adaptor Flange. Nipple up Tree. (DSO came by to inspect Tree alignment. OK). 10/01/2011 Test Hanger void and Tree. Pull Dart/BPV. Swap Well over to Diesel. Secure Cellar. Release Rig. 00:00 02:00 2.00 COMPZ WHDBO PRTS P Pressure test hanger void at 250/5,000 psi. Good. Test Production Tree at 250/5,000 psi. Good. Record Tree test on Chart. Pump open SSSV. Block in with 5,000 psi on Control Line. Pull Dart/BPV. 02:00 06:00 4.00 COMPZ RPCOM FRZP P PJSM. Spot and rig up Little Red Services. Spot Diesel Transport. Pressure test lines at 3,000 psi. Pump Diesel down the IA, taking Sea Water returns from the Tubing to the Kill Tank, at 2.0 bpm /800 psi. Pumped a total of 243 bbls of Diesel. Blow down lines. 06:00 12:00 6.00 COMPZ RPCOM RURD P Set BPV. RDMO. Release Rig at 12:00 PM. Page 12 of 12 • • SIATIE AllASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 James Ohlinger Wells Engineer C riz_3- ConocoPhillips Alaska, Inc. V t� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K -10 Sundry Number: 311 -320 - t 4t Dear Mr. Ohlinger: 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 T day of October, 2011. Encl. it. g n 4! 4 ai, -- , ' I V D STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSIO. Z' . OCT 2 c 2 on APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Al*iks Gil & Gas Cons. Commission 1. Type of Request: Abandon r Rug for Redrill i✓ ' Perforate New Pool r Repair well I Changehaprepogram r Suspend r" Plug Perforations 17 , Perforate r Pull Tubing r Time Extension E Operational Shutdow n r Re -enter Susp. Well r° Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fr, Exploratory r 186 -163 " 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21653 - 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 IV 3K -10 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25520 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): 7300 6951 7189' 6860' Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3792 9.625 3829' 3828' PRODUCTION 7239 7 7274' 6930' Perforation Depth MD ( 7006 - 7026, 7041 - 7068, Perforation Depth TVD (ft): 6712 -6728, 6740 -6762, Tubing Size: Tubing Grade: Tubing MD (ft): 7072 - 7073, 7076 - 7077, 7080 - 7081, 7084 - 7085, 7087 - 709' 6766 - 6766, 6769 - 6770, 6772 - 6773, 6775 - 6776, 6778 - 6781 3.5 L80 6772 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER (60K SHEAR) MD= 6795 TVD= 6538 SSSV - CAMCO TRMAXX- CMT -SR -5 MD= 1763 TVD= 1763 12. Attachments: Description Summary of Proposal r7° 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: • I 10/25/2011 OiI . G, lI Gas r WDSPL r Suspended r/ ', 7-C; r 16. Verbal Approval: Date: WINJ r /lc 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: Coiled Tubing Drilling Engineer Signature Phone: 265 -1102 Date /Ol47� // Commission Use Only Sundry Number: ��'�� Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test fiVMechanical Integrity Test r Location Clearance r 3 5 „95,.., i3oP . s-- Other: Subsequent Form Required: /O --L/ O "'Z_ APPROVED BY 6/ Approved by. COMMISSIONER THE COMMISSION Dater efI ( t \k Form eistr /vom �v 1 V � • t• 0R1G1NAL Submit in Duplicate , ,V • • Application for Sundry to Plug Perforations KRU 3K -10 3K -10 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 quad - lateral from well 3K-10 is December 2011. Summary of Past Operations: Well 3K-10 was originally drilled in October 1986 as an A -Sand producer. A recent work -over was performed to set the well up for CTD to capture the production and reserve base from the planned CTD laterals. The RWO scope included pulling the existing 2 -7/8" completion, cleaning out the fill in the 7" casing, running a 3 -1/2" liner and a new 3 -1/2" L -80 tubing string with a SCSSV completion. This well previously operated under a waiver for its IAxOA annular communication due to thread leaks to gas in the 7" production casing therefore the IC packoffs were also replaced and the casing re- tensioned. Proposed Pre -Rig Work for CTD Operations « Slickline: Tag fill, obtain SBHP « E -line: GR/CCL • E -line: Perforate the 3 tubing tail • Coil: Lay in /squeeze cement plug across perforations and tailpipe • Z 1S ( Si f c « Slickline: Tag TOC and PT to 1500 psi. « Coil: Drill out cement in 3 -1/2" tubing tail ✓ « E -line: Set whipstock (Tune permitting) « Prepare well site for CTD (CDR2 -AC) rig arrival. Rig Work (Proposed CTD Sidetrack Operations) ' fr 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. Pull BPV ' 2. Mill 2.80" window at 6,960'. • 3. 3K -10A Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,650' MD ( 1/4 ' b. Run the 2 slotted liner with an aluminum liner top billet from TD to 7,400' MD. 4. 3K -10AL 1 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 9,705' MD Page 2 of 3 10/11/2011 • • Application for Sundry to Plug Perforations KRU 3K -10 c. Run the 2%" slotted liner from TD to 6,955' MD, inside the 3 -1/2" tubing tail of the mother -bore. 5. Set 2 "`' Whipstock at 6,935' 6. Mill 2.80" window at 6,935' 7. 3K -10AL2 Sidetrack a. Drill a 2.70" x 3" bi- center lateral to a TD of 9,865' MD b. Run the 2 slotted liner with an aluminum liner top billet from TD to 8,500' MD. 8. 3K- 10AL2 -01 Lateral a. Kick off of the aluminum liner top billet at 8,500' MD b. Drill a 2.70" x 3" bi- center lateral to a TD of 9,335' MD c. Run the 2%" slotted liner from TD to 6,930' MD, inside the 3 -1/2" tubing tail of the mother -bore. Reservoir Pressure 3K -10 measured 1736 psi at 7025' MD (6,658' TVDss; 5.01 ppg EMW) on October 9 2011. Another SBHP is scheduled post rig work -over and pre -CTD. Maximum potential surface pressure is 3717 psi assuming a gas gradient to surface based on the potential pressure from the A -sand (3K -05) interval that measured 4337 psi at 6200' TVDss. 0✓9 c , riOpOyeat AI( l( !i) /�/1 Lv // C ry fro rh Gi S / G ' 4 h /N o`i' o'• C� /1 Q i ti 01 712 a (rig (2(tt i GlfZ' /ct' / A 11 46.., 7461/ L/e 1( ( i h P 5c, `11 / i r,'Gf3 e fau nt,> 1Ao u ld yrc)v ` p co ver, ,n 06 ,'S poi 7 04, 0 f 74e f' ° Page 3 of 3 10/11/2011 , KU P • 3K-1O Iv 4: , ConocoPhillips t t „. - .,,,, v_vo AMiNte___ F Max Angle & MD TD . :- sWII71w1,..tgy, Wellbore APVUWI ' Name ''''''''' Well Status Id n() iND (MB) Act Btm (ftKB) 4" 500292165300 1 .", KUPARUK RIVER UNIT PROD 35.87 6,100.00 73000 t c0003MILMIU ' 6iiiiii,.74 lios (pp.) IDt. Annotallon End Date KB-Grd (ft) Rig Release DaM ... SSSV: TRDP 105 1 10126/2010 Last WO: , 39.21 10130/1986 wos.4*.#9,. .70 11626 1 --- . _ _ Annolation Depth (ftKB) End Date Annotation It Mod ... ,End Date Last lag SLM 1 7,172.0 I 10/8/2011 Rev Reason GLV C/0, TAG pinam i 10/10/2011 Casing Strings HANGER, 35 . 11 ..' _ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String WI_ String ... String Top Thrd CONDUCTOR ' 16 15.062 38.0 110.0 110.0 62.50 H-40 WELDED ',.....--- 11 casing Desaiption String 0... String ID ... Top (ftift3) Set Depth (f... Set Depth (TVD) _. String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 37.0 3,829.5 3.827.5 36.00 J BTC Casing Desetiption String 0... String ID ... Top (ftKB) Set Depth (f. Set Depth (TVD) ... String Wt... Siring _ String Top Thrd . .. PRODUCTION 7 _ 62/6 350 7,274.3 69301 26.00 J-55 BTC CONDI __ . Tubing Strings ' 'Tubing Description String 0... :String ID ..1Top (8IKS) Set Depth (f . Set epth (TVD) ... String Wt... String ... String Top Thrd TUBING 3 1/2 I 2.992 35.0 6,772 0 6,518 8 9 30 L80 EUE 8Rd Mod SAFETY VLV, 1,763 1 - :` Completion Details ls Top Depth (TVD) Top Ind Top (611(19) (ilkB) n tt De.cdpg.. Comment ID (in) . . , . • GAS LIFT. - ; 35.0 35.0 0.24 HANGER MCEVOY GEN IV TUBING HANGER , 2 875 IM: 2.507 1,762.7 1,762.6 0.46 SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SAFETY VALVE w/ 2.813" X PROFILE 812 6,725.6 6,480.4 34.27 NIPPLE CAMCO X NIPPLE 2 812 6,771.1 6,518.1 34 36 SEAL ASSY BAKER 80-40 GBH-22 LTSA SEAL ASSEMBLY w/ 7' SPACE OUT I 2.850 Tubing Description String 0... String ID ... lop (6868) 568 Depth (8 ISM Depth (TVD) ... String Wt...String ... I String Top Thrd • FHL PACKER 31/2 2 992 6,7720 70922 6,782.0 930 180 ' EUE 8Rd Mod GAS LIFT. _ 1111 'Completion Details 3.794 Top Depth I OW) Top Incl Nomi... [ Top (6IKB)_ (ftKB) 1') Item Description Comment ID (in) SU 6,772.0 6,518.8 34.36 PBR BAKER 80-40 PBR w/ 40K SHEAR 3.000 6,795.4 6,538.1 34 41 PACKER BAKER FHL PACKER (60K SHEAR) 3.000 IW GAS LIFT, ' ,...' 7,091.3 6,781.3 35.54 SOS SHEAR OUT WLEG 2.992 4,704 . Perforations & Slots Mit 1 Shot ' Top (TVD) Btm (TVD) Dens Top (IIKEN Btm (ftKB) (ftKB) (RICE) Zone Date Mk-- T p Comment 5 452 e' 7,006 7,026 6,711.5 6,727.9 A-3, 316-10 9/10/1988 8.0 RPERF 60 deg. ph; 2 1/8" EnerJet it 7,009 7,010 6,714.0 6,714.8 A-3, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet Mt 7,011 7,012 6,715.6 6,716.5 A-3, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet (,AS LIFT IIM' - 676 7,019 - 1020 6,722.2 6,723.0 A-3, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet 7,023 7,024, 6,725.5 6,726.3 A-3, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8' EnerJet 7,041 7,068 6,740.2 6,762.3 A-2, 3K-10 9/10/1988 8.0 RPERF 60 deg. ph; 2 1/8" EnerJet GAS LIFT it_ 7,046 7,047 6,744.2 6,745.0 A 3K 12/26/1986 1.0 IPERF 0 deg ph; 21/8" EnerJet 6 669 III 7,053 7,054 6,750.0 6,750.8 A-2. 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 21/8' EnerJet 111" 7,059 7,060 6,754.9 6,755.7 A-2, 3K-10 12/26/19 . _ 86 1.0 IPERF 0 deg ph; 2 1/8" EnerJet ' 7,063 7,064 6,758.2 6,759.0 A-2, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet NIPPLE, 6,726 Mir 7,072 7,073 6,765.5 6,766.4 A-2. 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 vs- EnerJet 7,076 7,077 6,768.8 6,769.6 A-2, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet IIIII 7,080 7,081 6,772.1 6,772.9 A-2, 3K-10 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet SEAL ASSY, _ , 6,771 ,--- ) 7,084 7,085 6,775.4 6,776.2 A 3K 12/26/1986 1.0 IPERF 0 deg ph; 2 1/8" EnerJet P138, 6,772 - 4 ,.„,,..„.. 7,087 7091 67778 6,781.1A.2 3K [12/26/1986 1 0, IPERF 0 deg ph; 2 1/8" EnerJet PACKER, 6,795 ' -- r -. Notes: General & Safety End Date Annotation 6/17/2008 NOTE. SURF CSG PATCH ,12 of 16" 62 58 API 5L GR 13 7/26/2010 NOTE View Schematic w/ Alaska Schematm9.0 12118/2010 NOTE: VVAIVERED WELL IA x OA COMMUNICATION IPERF, Nr...... , 7,009-7,010 ..,-....- '1,' PERE, 7,011-7,012' RPERF, 7,008-7,026 --- !PERE. 7,019-7,020 ft :• 4t PERE, ... :-.• _.L.1___ 7,023-7,024 .. larair .: ;..... 19898, .1.47M 7 ' Illgt, 7,046.7,047 ''' t, 4..4 !PERE, 7,053-7,054 --'`.----. rei .' i- Rine RPERF. 7,041.7,068 IPERF, Ammo 4 . MA. 7,055 4,444 •• • aurrei IPERF, ---ir " ----`* 7,063.7,064 Mandrel Details 7,07; - .:- '' 1 Top Depth Top Port ' (TVD) Inc! OD Skive Latch Size , T90 Run 7,076-7,077 StN_Top_B) (f 1') Make Model (in) Sere Type Type (on) (Psi) Run Date Com... 1 2,507.2 2,506.7 3.65 CAMCO MMG 1 1/2 GAS UFT DMY RK 0.000 0.0 9/2212011 IPERF, _ 7,1180 23,793.7 3,791.7 1.23 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.09/22/2011 IPERF, 3 4,703.7 4,698.0 13.63 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.09/22/2011 7,084 4 5,451.8 5,402.6 24.81 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/22/2011 IPERF. 5 6,169.6 6,023.9 35.63 CAMCO MMG 1112 GAS LIFT DMY RK 0.000 0.09/22/2011 7,087 1 6 6,669.5 6,434.2 34.35 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 10/8/2011 SOS. 7.091 PRODUCTKM, 35-7,274N I L TO, 7,300 3K -10 Proposed CTD Sidetrack L-- 3-1/2" Schlumberger TRMAXX- CMT -SR -5 ©1763' RKB(2.813" ID) 5 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 16" 62.5# H -40 shoe @ 110' MD 3 -1/2" Cameo MMG gas Itk mandrels @ 2507', 3794', 4704', 5452', 6170' RKB 3 -1/2" Camco MMG GLM © 6669' RKB wl SOV 9 -5/8" 36# J -55 shoe @3829.5'MD 1 ..._ 3 -1/2" X Nipple @ 6726' RKB (2.813" min ID) Ili " • Baker PBR @ 6771' RKB FHL Packer @ 6795' RKB (min 3" ID) 3-1/2" TT r Perfs @ XXXX? 3-1/2" SOS WLEG @ 7091' RKB I KOP #2 @ 6935 MDt 3K -10AL2 & AL2 01 -------------------------- _. 3K- 10AL2 -01 wp02 TD. 9335 MD 3-1/2" TT ';� Perts @ XXXX? KOP #1 @6960' MD „ ',/ IBIllet @ 8500' MD 3K -10A & AL 1 3K -10AL2 wp04 \ - - - - -- TD: 9865' MD 3K -10AL1 wp03 A3 -sand perfs ; , II' TD: 9705 MD 7006' - 7026' _ 7 A2 -sand perfs _ '! 7041' - 7091' _ an out to - •' ®��` �' ■-- 3K -10A wp03 7” 26# J -55 shoe @ 7175' RKB IBillet @ 7400' MD I TD: 9650' MD 7274' MD • • Cono co P hillips RECEIVED OCT 2 0 ?till Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AIa6ka Olt & Gas Cons. Commission Ancno :age October 4, 2011 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a sundry to prepare this well for CTD sidetrack operations in the A sands of Kuparuk Well 3K -10 utilizing cement. The scope of work will include perforating the tailpipe, cementing the existing perforations and " tailpipe, and setting a whipstock for window milling operations. The work is scheduled to begin in October /November 2011. The CTD objective will be to drill an A -sand quad - lateral Producer. 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 • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 10/6/2011 Page 1 of 1 Regg, James B (DOA) ∎ s 0 From: Nordic 3 Company Man [n1433 @conocophillips.com] �� I it Sent: Thursday, September 29, 2011 12:31 PM To: Regg, James B (DOA) Subject: RE: Nordic Rig 3 Yes that is correct. Huey Rowell - Lee Hinkel Cell 907-943-1781 t # "` Office 659 -7446 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, September 29, 2011 11:23 AM To: Nordic 3 Company Man Subject: RE: Nordic Rig 3 Is well KRU 3K -10 (PTD 1861630)? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Nordic 3 Company Man [ mailto :n1433 @conocophillips.com] Sent: Thursday, September 29, 2011 12:40 AM To: DOA AOGCC Prudhoe Bay Subject: Nordic Rig 3 Lou, As per your request. Choke Manifold Valve #2 replacement was completed at 22:00 hrs 09/28/2011. The Valve was tested at 250/3,000 psi x 5 minutes each. Both pressure tests were good and they were recorded on a Chart. tks, Lee H. Huey Rowell - Lee Hinkel Cell 907 - 943 -1781 Office 659 -7446 9/29/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: February 13, 2009 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Repair Petroleum Inspector KRU 3K-30 and 3K-10 --~'"4-44~"~, CPA PTD --- ~5~-~i.3 February 13, 2009: CPA Rep. John Arend told me about 2 surface casing repairs that he had going on 3K-30 and 3K-10. John offered me a chance to look them over. I accepted the offer. Summary: I found the two well to be next to each other. Both of them had the conductor pipe and cement removed. 1 found both wells to have what I would call moderate to heavy pitting on the upper half of the exposed casing. I saw one aprox. 3/8" hole in 3K-30. x~ °~:s~~.~ FED ~~ r~ 200 CPA KRU 3K-30 3K-IO 5-22-08.doc Attachments: Hole in 3K-30 • CPA KRU 3K-30 3K-10 5-22-08.doc • • • ~. ~~ ~~i J Bad pit in 3K-30 CPA KRU 3K-30 3K-10 5-22-08.doc ! • ~. ~. .. a ~~ ~~ ~:. ~ ~~ i r1 .~~ t i> ~R'~~a T '1 y~,i `+~ ~~ S+'= ,. '~ ` - z.ti ~ ~ t a.. ~ ~i~ ~ ~~~`' ~ ` n .. ~._,.- w i .., y. ~ r ~'3; '~~~~y~'y,~ ~Y{ ~~ ~ ~ F Pitting 3K-30 CPA KRU 3K-30 3K-10 5-22-08.doc • • ~~,~ ~ ~ . s .: ~ :~ pA w ~ s • e ,,, \ i Pitting on 3K-10 Confidential: 7 3 ~ .y i q ~ ~.~P ~ ~+,.' ~~' !fit l x ~ ='4 ~,Vy ~ ~~e :~ e J~ ~_ ~ ~ ,~ t e ~ g r ;' ~., r ! ,~~ ~ ' - - a ,~fi ~ l CPA KRU 3K-30 3K-10 5-22-08.doc • • .!~~ ®~. ~QtJB STATE OF ALASKA "~ ALASKA OIL AND GAS CONSERVATION COMMISSION , 3 ~,, § ~,.. ,r,~i0fi REPORT OF SUNDRY WELL OPERATIC` /. ~ -: , ti: 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnoCOPhilllps Alaska, InC. Development ^~ Exploratory ^ 186-163 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21653-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-10 8. Property Designation: 10. Field/Pool(s): ADL0025520~ ALK 2556 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7300' ~ feet true vertical 6951' . feet Plugs (measured) Effective Depth measured 7036 feet Junk (measured) true vertical 6736 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3760' 9-5/8" 3829' 3827' PROD. CASING 7205' 7" 7274' 6930' Perforation depth: Measured depth: 7006-26' 7041-68' 7072-3', 7076-7 7080- 1 7084-5 7087-91 true vertical depth: 6712-28 6740-62 6575-6 6769-70 6772-3 6775-6 6778-81 Tubing (size, grade, and measured depth) 2-7/8", J-55, 6931' MD . ~~ JU~ ~ ~ 2008 UU N~ ' ' J ~3 ~ ty ~J Packers &SSSV (type & measured depth) pkr= CAMCO'HRP-1-SP' pkr= 6904' SSSV= SSSV SSSV= 1772' 12. Stimulation or cement squeeze summary: None Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na na na na na Subsequent to operation na na na na na 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-117 contact Perry Klein/M.J. Lo eland ~ Printed Name M.J. Lpve and ~ Title Well Integrity Projects Supervisor ~ ~'~-~ Signature ,~~r~/ ~% ~ ,~ /""~ Phone 659-7043 Date ~~ ~~ ~, ~ ('~ (~ {~ f j~ S ~. JUG, 1 Q 2D09 ,:'~~(~~ Form 10-404 vised 04/201 f \ ~ G I I \ i H ~ Submit Original Onl~~ g- ~ f ` f ~.J ttt YYY 1... /1D • 3K-10 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/19/2008 Nitrogen purge IA @30 cfu,OA@70 cfu.Cut and removed 12' of conductor,chip out cement,clean for inspection. 5/22/2008 Notified State man (Noble) to witness damage to SC 6/17/2008 6/18/2008 6/19/2008 SC patch weld -Complete. Purged nitrogen while welding 9' SC patch -used 10" .500 wall X65 pipe for collars & 12" .500 X65 pipe for sleeve.Top of SC patch ties into Mandrel Hanger.Patch Welded as per M.E SPECS.Removed 45 bbls of water from excavation. Installed IA and OA VR Plugs and normal annulus jewelry w/2000# 8~ 4000# gauges.MITOA PASSED..Initial T/I/0=0/0/0. Pressure up SC to 1800.T/I/O=0/0/1800. START T/I/O/=0/0/1800.15 min T/I/0=0/0/1720, 30 min T/I/0=0/0/1710, 45 min T/I/O=0/0/ 1700, 60 min T/I/0=0/0/1700.Final T/I/0=0/0/0. Wrapped SC in DENSO TAPE. Installed new Conductor ,12' of 16" 62.5# API 5L GR B Conductor casing.Removed heater hose from excavation. 6123/2008 Pum ed 0.9 bbls. of class G 15.8 PPG cement into conductor w/in 6" of surface.. 6125/2008 Topped off conductor casin with 2 allons RG-2401 sealant. T/I/O = SI/0/10. • • Tills phOtO 1S COp~'rl~llt by c~onocoPhillips _-~1~~s1Lz, II1C. alld cann~~t be released or published «-ithuut elpress ~ti~rittell C1111St'llt l1t ~ +1111L1C11Ph11111~5 .-~1i1S1ti1 ~,- '~~'(_~~~I1~~C~lPllllllps .-~1~1s1t~1, Ills • • ~~~~(~O11000F'llllllps :~l~~ka, Inc ['lug photo is copyright by (_'onocoPlullips ~la~ka, Inc. ~ulcl ;1llllot be rel?c1S?Cl or pttblislied ~i•ithotlt et-I)re» ~V17tt?11 ~olh?llt Ot ('onocoPlulhu~ .-~l<~k<~ • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,~ ~ ~~.~ ~,i, f~ DATE: May 30, 2008 ,~~~~~ ~ ~- v .~ P. I. Supervisor FROM: Bob Noble SUBJECT: ~,rFar.P racinn RP~jr Petroleum Inspector KRU 3K-10 (PTD 186-163) KRU 3K-30 (PTD 197113) CPAI May 30, 2008: CPA Rep. John Arend told me about 2 surface casing repairs that he had going on 3K-30 and 3K-10. John offered me a chance to look them over. I accepted the offer. Summary: I found the two wells to be next to each other. Both of them had the conductor pipe and cement removed. I found both wells to have what I would call moderate to heavy pitting on the upper half of the exposed casing. I saw one approximately 3!8" hole in 3K-30. Attachments: photos (4) ~~~~~ JU1'~ ~ ~ 200 • • ~~1~ ~tK~~(~, ~~~~(~ ~CPAS) Surfae~ Ca~ss~ag ~®~~osu~~ Photos by fob Noble May 22, 2008 Hole in Surface Casing -KRU 3K-30 Bad Pit in Surface Casing -KRU 3K-30 Pitting on Surface Casing -KRU 3K-30 ~- ---- Pitting on Surface Casing -KRU 3K-10 e e FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Marie McConnell Problem Wells Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 .c "' Re: Kuparuk River Field, Kuparuk Oil Pool, 3K-10 Sundry Number: 306-117 \~\¡' \ (p ~ Dear Ms. McConnell: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thi~ day of April, 2006 Encl. 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0' Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 186-163 .- 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21653-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' / 3K-10 ., 8. Property Designation: 10. Field/Pool(s): " Kuparuk River Unit Kuparuk River Field 1 Kuparuk 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): 7300' " 6951' " 7036 6736 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110 SUR. CASING 3760' 9-5/8" 3829' 3827 PROD. CASING 7205' 7" 7274' 6930 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7006-26' 7041-68' 7072-3',7076-7 6712-286740-626575-66769-70 7080-1 7084-57087-91 6772-36775-66778-81 2-7/8" J-55 6931' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= CAMCO 'HRP-1-SP' pkr= 6904' SSSV= SSSV SSSV= 1772' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Marie McConnell 1 MJ Loveland Printed Name ~ie McConnell A. ç Title: Problem Wells Supervisor ~. -'./-" - Date , ~ - 2¿-/1tfJ Signature ~ / Phone 659-7224 /- - .... Commission Use Only Sundry N~()(j \1.1 Conditions of approval: Notify Commission so that a representative may witness <.. fO- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: c..~~c:\- I\f'~e.c.k,·~·· 'O,,~~\\'t \0 Q.~c.. ~ \ N..Ç: ~Q ,<.... ~" c\' \e; "'- ~p~" ~l-\ Uj I ¡ýf'" "ðfO>Q.ù ''''fè'''~ ,,, 0 ~ "- Subsequent Form Required: ~~\, (Ìj ./, ~ \ ~OMMISSIO>l!'R APPROVED BY L/-"'3,'; Approved by: THE COMMISSION Date: Form 10-403 Revised 7/2005 ~~ ~ t' \1::- ~ OMS BFL ·APR /) 2006 Submit in DUPlicat~ ,~ .;&1> l' -1/'''''' f)(f 3/31/,6 e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV A~'aska Oil & G?S Gems. COmmi$sioll W~~~ ~~~ Á RECE!VED I~(~I MAR 5~ 8 ¡OC., ,~ . "- (tJQ e e ConocoPhillips Alaska, Inc. Kuparuk We1l3K-I0 (PTD 186-163) SUNDRY NOTICE 10-403 APPROVAL REQUEST March 26, 2006 ./ This application for Sundry approval for Kuparuk well 3K-I 0 is for the repair of a surface casing leak. The well is an oil producer, completed in October 1986. On March 13, 2006, fluids were observed at the conductor top and a suspected surface casing leak was reported to AOGCC. Subsequent testing indicated a leak: in the surface casing 41 inches below the OA valve. With approval, repair of the surface casing will require the following general steps: 1. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QNQC the repair welds and MIT -OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. e e .. ConocoPfdllips Alaska, Inc. KRU 3K-10 .' '" ....... ............................. ...... ........ ....... } API: 500292165300 Well Type: PROD Angle @ TS: 34deg@ 6811 SSSV Type: TRDP Orig Completion: 10130/1986 Angle !âJ TO: 36 dea !âJ 7300 Annular Fluid: LastW/O: Rev Reason: TAG FILL SS8V L If: Reference Log: Ref Log Date: Last Update: 3/312006 (1772-1773, Last Tag: 7036 TO: 7300 ftKB 00:2.875) Last T ae Date: 2/2612006 TOD II 36 dee !âJ 6100 ....... ........ ................... DescriDtion I Size Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 Gas lift .11. SUR. CASING I 9.625 0 3829 3827 36.00 J-55 MandrelNalve PROD. CASING I 7.000 0 7274 6930 26.00 J-55 1 ................ .............................. .<.. ........ .......................... .< (2546-2547, Size I Top Bottom TVD I Wt Grade Thread 2.875 I 0 6931 6650 I 6.50 J-55 EUE 8RD AB MOD ........ } ....................... Gas lift Interval TVD Zone SIBtus Ft SPF Date TVDe Comment MandrelNalve 7006 ' 7009 6712 - 6714 A-3 3 8 9/10/1988 RPERF 60 deg. ph; 2 118" EnerJet 2 7009 - 7010 6714 - 6715 A-3 1 9 9/10/1988 RPERF 60 deg. ph; 2 118" EnerJet (4294-4295, 7010 - 7011 6715 - 6716 A-3 1 8 9/10/1988 RPERF 60 deg. ph; 2 1/8" EnerJet 7011 ,7012 6716 - 6716 A-3 1 9 9/10/1988 RPERF 60 deg. ph; 2 1/8" EnerJet 7012,7019 6716 - 6722 A-3 7 8 9/10/1988 RPERF 60 deg. ph; 2118" EnerJet 7019·7020 6722 - 6723 A-3 1 9 9/10/1988 RPERF 60 deg. ph; 21/8" EnerJet Gas lift 7020 - 7023 6723 - 6725 A-3 3 8 9/10/1988 RPERF 60 deg. ph; 2 1/8" EnerJet mdrellDummy 7023 - 7024 6725 - 6726 A-3 1 9 9/10/1988 RPERF 60 deg. ph; 2 1/8" EnerJet Valve 3 7024 - 7026 6726 - 6728 A-3 2 8 9/10/1988 RPERF 60 dee. ph' 2118" EnerJet (5427-5428, 704 1 - 7046 6740 - 6744 A-2 5 8 9/10/1988 RPERF 60 dee. ph' 2 1/8" Ener Jet 00:4.750) 7046 - 7047 6744 - 6745 A-2 1 9 9/10/1988 RPERF 60 dee. ph' 2 1/8" EnerJet 7047 - 7053 6745 - 6750 A-2 6 8 9/10/1988 RPERF 60 deo. oh' 2 1/8" EnerJet 7053 - 7054 6750 ' 6751 A-2 1 9 9/10/1988 RPERF 60 dee. ph' 2 118" EnerJet Gas lift 7054 - 7059 6751 . 6755 A-2 5 8 9/10/1988 RPERF 60 dee. ph' 2 1/8" EnerJet MandrelNalve 7059 - 7060 6755 - 6756 A,2 1 9 9/10/1988 RPERF 60 deç¡. ph; 21/8" EnerJet 4 7060 - 7063 6756 - 6758 A,2 3 8 9/10/1988 RPERF 60 deg. ph; 2 1/8" Ener Jet (6016-6017, ...... 7063 - 7064 6758 - 6759 A-2 1 9 9/10/1988 RPERF 60 dee. ph; 2 1/8" Ener Jet 7064 - 7068 6759 - 6762 A-2 4 8 9/10/1988 RPERF 60 deg. ph; 2 1/8" EnerJet 7072 ' 7073 6765 - 6766 A-2 1 1 12/26/1986 IPERF o deg ph; 2 1/8" EnerJet 7076 - 7077 6769 - 6770 A·2 1 1 12/26/1986 IPERF o deg ph; 2 118" EnerJet Gas lift 7080 - 7081 6772 - 6773 A-2 1 1 12/26/1986 IPERF o deg ph; 2 118" EnerJet mdrel/Oummy 7084 ' 7085 6775 - 6776 A-2 1 1 12/26/1986 IPERF o deç¡ ph; 2 118" EnerJet Valve 5 7087 - 7091 6778 - 6781 A-2 4 1 12/26/1986 IPERF o deg ph; 2 1/8" EnerJet (6442,6443, 00:4.750) ... Gas·UftMål'ldl'elsNálves St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt Gas lift ~!¡¡¡¡r 1 2546 2545 Merla TMPD GLV 1.0 BK 0.156 1350 6/1612003 MandrelNalve 2 4294 4292 Merla TMPD GLV 1.0 BK 0.188 1374 6/1512003 6 3 5427 5380 Merla TMPD DMY 1.0 BK 0.000 0 9/10/1989 (6838-6839, 4 6016 5898 Merla TMPD GLV 1.0 BK 0.188 1363 6/1512003 5 6442 6247 Merla TMPD DMY 1.0 BK 0.000 0 6/1512003 6 6838 6573 Merla TGPD OV 1.5 RK 0.188 0 1/2712005 Qth~'Ú ~I.I!I$·..eclllÎó..·..f;I~.}..-.leWELRY SBR Depth TVD Type Description ID (6887-6888, 1772 1772 SSSV Cameo'TRDP-1A-SSA' 2.312 00:2.875) 6887 6614 SBR Cameo 'OEJ' 2.312 6904 6628 PKR Cameo 'HRP,1,SP' 2.347 6920 6641 NIP Cameo '0' Nipple NO GO 2.250 6930 6649 SOS Cameo 2.441 PKR ~ 6931 6650 TTL 2.441 (6904-6905, 00.6.151) NIP (6920-6921, 00:2.875) , TUBING (0-6931, 00:2.875, 10:2.441) 80s (6930-6931, 00:2.875) Perf - f-- (7009-7010) == == Perf - - (7011-7012) - - = = Perf - - (7046-7047) = = Perf = = (7053-7054) - - Perf = = - - (7072-7073) - - Perf == == (7076-7077) RE:'3K-I0 (i>TD 186-163) e - Subject: RE: 3K-I0(PTD 186-163) From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 14 Mar 200612:31:06 -0900 To: Thomas MaUIlder <tom~ ma.lq.Icier@adn1in.state.ak.us> We reported - 6 gallons. The well is secured, however, All of our support equip (including my own manpower) has been working the 2M spill, so we don't have the diagnostics done yet. I'll keep you informed. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message---- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 14,20067:27 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: 3K-10 (PTD 186-163) Thanks MJ. Please keep us informed of the determinations. Any estimate on the volume into the cellar? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 3/13/2006 4:49 PM: Tom, Producer3K-10 (PTD 186-163), appears to have developed a surface casing leak near the surface resulting in a small amount of fluids coming up the conductor and out the top of the tanko head. DHD will diagnose the location (depth) and severity of the leak over the next few days. In the mean time the well was SI and freeze protected. Let me know if you have any questions about this well MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 1 nfl 1/1 1/?006 ??? PM MEMORANDUM. State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 18, ..2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. :S. UMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested', 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc CC; NON-CONFIDENTIAL.. SVS KRU 3K 5-18-0 ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI ., Trip Code Code Code Passed GA..S.,or CYCLE 3K-01 1861010 65 70 50 P P OIL ~K-03 1861030! 65 70, 55! "'P P ' ' OIL 3K-06 1861240! 65 70! 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL ~~' 1861630 65 ' 70 ' 52 " P P ' OIL , ! 3K-11 1861640 65 70 50 P P OIL 3K-14 1861370 65 60 58 P P OIL 3K-16 1861390 65 70 70 P P OIL 3K-17 1861520 ' 65 60 35 "P P' oIL 3K-23 1970970 65 70 58 P P ....... OIL 3K-24 1982490 65 70 50 P P OIL 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70 55 P P OIL 3K-35 1971090 65 70 50 P P .O..I~ Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% [3 9o oar Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc HDVd SIH£ ~l~t(INfl qV1NH&VIN A'kHN XNV ~tDVqd J~ON O(I 00/8~/6 (I~[INqI~IO~IDIIN STATE OF ALASKA ./' ~¢~ ~ . ALASKA OIL AND GAS CONSERVATION COMMISSION ,'-. ~.~.~,t ~ L1 '~ tl;~/~&u~,~(:~,~/, REPORT OF SUNDRY WELL OPERATIONStJ 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 Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1160' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1375' FSL, 628' FEL, Sec. 34, T13N, R9E, UM At effective depth 1413' FSL, 842' FEL, Sec.34, T13N, R8E, UM At total depth 1424' FSL, 906' FEL, Sec. 35, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7300' feet Plugs (measured) 6 9 51 ' feet None 6. Datum elevation (DF or KB) RKB 69 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-10 9. Permit%4er Z.~I 625 · ~ - 10. APl number 5o-029-21 653 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 71 89' feet Junk (measured) 6860' feet None 13. 14. Casing Conductor Surface Intermediate Production Perforation depth: Length Size 80' 16" 3792' 9 5/8" 7239' 7" measured 7006'- 7091 ' true vertical 671 0'- 6780' Tubing (size, grade, and measured depth Cemented Measured depth True vertical depth 1540# Poleset 110' 110' 1075 sx AS IV & 3829' 3827' 305 Sx Class G Top job w/150 Sx AS I 325 Sx Class G 7274' 6930' 2 7/8" J-55 tbg w/tail @ 6931' Packers and SSSV (type and measured depth) HRP pkr @ 6904' & TRDP-1A-SSA SSSV @ 1772' Stimulation or cement squeeze summary Refrac A Sands Intervals treated (measured) 7009'-7080' MD-RKB Treatment description including volumes used and final pressure Attached RECEIVED Cons. ^i]ch0rag~ Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 200 80 0 1100 90 550 1100 0 1100 100 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,/~//(,_~ ~ //~ ~t'4~¢'/¢'~.~7 Title SR OPERATIONS ENGINEER Form ~ ~-4~4 'ICky '05/17/89 SUBMIT IN DUPLICATE ARCO Alaska, I <> CONTRACTOR 3K - I 0 j '7, J.v ~,-,,~ IOPERATION AT RE~RT TIME ~EMARKS WELL SERVICE REPOR' JDAYS IDATE ~ (,~.c.c,,-.,rs . ib~,'~P UP 7"xzr~' 4 ,,/,,/v,. ,./,, 1'.0 ..~t.43o ?(( ,i I Goo 7so 4 ~.' oD zo.. ~ 2~;<3 't~o 2.0 .o ii 4 o ~2oo 1~.~ I z ,o -j~oo /8. ~ [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ITemp' °F Chill Factor. F Ivisibility milos :Wli~'ld Vel. knotl o$/~ 'Nlkl SI ~ og :3sin olnlJ o~O/:dl, q].l. oln'lJ j(~ :IUflU].LNI 901 os;zz 'NlklOI o_~£c 'NII~S :JJO>IU]I ~-~ / / / c~,~/:3111:1 :llt3d G~" /._~x. ' :OUII9 3USJ o~./.~-/ o//~' :dlSI o~,_~ / OX-/~ :UdJ. Hm :Auunls 'J J3 :OUd 'J J3 s~nn0n 'NNU 'clOUd ~iNISUXd · :/1-1,,~. :S:lU3d cl~ ]'IgNU , ,a)OOL. :S:lU3d · 01~ !ILo) :$JU3d~Orl~ / AUkll~kifl$ NOI/UlflI~IIS )INUI:IdN)I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska, Inq. 3. Address P. O. Box 100360, 'Anchorage, AK 99510 Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X~ Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1160' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1375' FSL, 628' FEL, Sec. 34, T13N, R9E, UM At effective depth 1413' FSL, 842' FEL, Sec.34, T13N, RSE, UM At total depth 1424' FSL, 906' FEL, Sec. 35, T13N, RSE, UM Present well condition summary Total Depth' measured true vertical Effective depth: measured true vertical 7300' feet Plugs (measured) 6951 ' feet None 12. 71 89' feet Junk (measured) 6 8 6 0' feet None 6. Datum elevation (DF or KB) feet RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-10 9. Permit number 625 Casing Length Size Structural Conductor 8 0' 1 6" Surface 3792' 9 5/8" Intermediate Production 7 2 3 9' 7" Liner Perforation depth: measured true vertical 10. APl number 5o-g29-2165:~ 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 110' 3827' 7006'-7091' 1540# Poleset 1 1 0' 1075 sx AS IV & 3829' 305 Sx Class G Top job w/150 Sx AS I 325 Sx Class G 7274' 13. 6710'-6780' Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 6931' Packers and SSSV (type and measured depth) HRP pkr @ 6904' & TRDP-1A-SSA SSSV @ 1772' Attachments Description summary of proposal X~ 6930' 14. Estimated date for commencing operation May 17, 1989 16. If proposal was verbally approved ! Name of approver /.~... 5 ~ ,"i ( Date approved Detailed operation program _ 15. Status of well classification as: Oil X Gas BOP sketch Service Date Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /)~ Ot,/t,,?. ~ .... ~ /~--~>"-"*'~'~ Title ¢>¢J~)/k ~-)~, ~~'~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance__ Mechanical Integrity Test ~ Subsequent form require ORIGINAL SIGNED BY' CONNIE C. SMITH Approved by the order of the Commission JApproval No. I 10- 4~proved Copy Returned / Form 10-403 Rev 5/03/89 Commissioner Date ~-- /~¢:'"- ~¢:!' SUBMIT IN TRIPLICATE Well 3K-10 Permission to refracture Well 3K-10 in the A Sand is requested. This well was originally fractured in January, 1987, with 47,000 pounds of sand. The proposed refracture treatment calls for 100,000 pounds of sand and is designed to more effectively stimulate this well's producing intervals. BHP is estimated to be 2300 psi. No workover fluids or BOP equipment will be needed during this job. . STATE OF ALASKA ~'" ~ ALASKA OIL AND GAS CONSERVATION ~,,,MISSION ~ . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~/~, / OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-163 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21653 4. Location of well at surface 9. Unit or Lease Name 1160' FSL, 316' FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1375' FSL, 628' FEL, Sec.34, T13N, R9E, UM 3K-10 At Total Depth 11. Field and Pool 1424' FSL, 906' FEL, Sec.34, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 69'I ADL 25520, ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/22/86 10/29/86 01/28/87*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD). 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7300'MD 6951 'TVD 7189'MD 6860'TVD YES ~] NO [] 1772' feet MD 1700' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 20" 1540# Poleset 9-5/8" 36.0# J-55 Surf 3829' 12-1/4" 1075 sx AS IV & 305 sx Top .iob performed w/150 sx AS I 7" 26.0# J-55 Surf 7274' 8-1/2" 325 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 6931 ' 6904 ' 7009'MD 6713'TVD 7059'MD 6754'TVD Perforated w/1 spF, 7011 'MD 6715'TVD 7063'MD 6758'TVD 0° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7019'MD 6722'TVD 7072'MD 6765'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7020'MD 6722'TVD 7076'MD 6768'TVD 7023'HD 6725'TVD 7080'MD 6772'TVD See attached AddenJum, dated 02/11/87. 7046'MD 6744'TVD 7084'MD 6775'TVD for Fracture data. 7053'MD 6749'TVD 7087'-7091'MD 6777 '-6781'TVD 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE iGAS'OILRATIO TEST PERIOD I~ I Flow Tubing 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 10/30/86. Tubing ran 12/03/86. Form 10-407 WC2: 047: DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30¥ W: GEOLOGIC MA "FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6810' 6550' N/A Base Kuparuk C 6858' 6589' Top Kuparuk A 6985' 6694' Base Kuparuk A 7145' 6825' 31. LIST OF ATTACHMENTS Addendum (dated 02/11/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ) (~/~J~_,/' .~,{ ~ Title 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, sal't 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 10-407 ADDENDUM WELL: 11/16/86 1/28/87 3K-10 Rn CBL/GR/CCL f/7173'-5502'. Rn gyro f/surf to 7100'. Rn GR/JB to 7178' WLM. Frac Kuparuk "A" sand perfs 7009', 7011', 7019', 7020', 7023', 7046', 7053', 7059', 7063', 7072', 7076', 7080', 7084' & 7087'-7091' per procedure dated 1/13/87 as follows: Stage 1: 85 bbls gelled diesel @ 20 BPM, 7000-6163 psi Stage 2: 50 bbls gelled diesel pad @ 20 BPM, 6700-6350 psi Stage 3: 56 bbls gelled diesel 1 ppg 100 mesh @ 20 BPM, 6350-6090 psi Stage 4: 440 bbls gelled diesel pad @ 20 BPM, 6090-5773 psi Stage 5: 34 bbls gelled diesel 2 ppg 20/40 mesh sand @ 20 BPM, 5773-5767 psi Stage 6: 36 bbls gelled diesel 3 ppg 20/40 mesh @ 20 BPM, 5767-5522 psi Stage 7: 47 bbls gelled diesel 4 ppg 20/40 mesh @ 20 BPM, 5522-5425 psi Stage 8: 49 bbls gelled diesel 5 ppg 20/40 mesh @ 20 BPM, 5425-4700 psi Stage 9: 64 bbls gelled diesel 6 ppg 20/40 mesh @ 20 BPM, 4700-4800 psi Stage 10:20 bbls gelled diesel 7 ppg 20/40 mesh @ 20 BPM, 4800-4766 psi Stage 11:22 bbls gelled diesel 8 ppg 20/40 mesh @ 20 BPM, 4766-5229 psi Stage 12:42 bbls gelled diesel flush @ 20 BPM, 5229-5600 psi Fluid to Recover: Sand in Csg: Avg Pressure: Sand in Zone: 895 bbls 961 lbs 5750 psi 2200 100 mesh & 46,870# 20/40 Job complete @ 4:18 hrs, 1/28/87. Dri~ Supervi~ D~te/ ADDENDUM WELL: 8/02/87 3K'10 Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak; tst OK. Drilli~~uperviso~ December 5, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60088 Well: 3K-10 Field: Kuparuk North Slope, Alaska Survey Date: November 16, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARC:O ALASKA, INC:. 3K- I 0 ( '-'~] .... '~ .. · :, ,~. _. .:, ._ "1' 1:3N RC)'?E ) COMPUTAT I ON [!ATE '1 ' 7~ " KLIPARJi.:, NEVEMBER I , 19.86 AL. AF.';KA .......................... VEF:;:'I' I CAi._ E:I.'.-':C]' 101,,I CAI....Ci_iLATED AL. OhlC~ CL..OSI_iF:~Ei: MEASLIRED DE~F"I"F.I DATE OF '" ':' - ..-,LtRVEY NOVEMBE'F;~ · ~ I~i~, · i -- i~* ~- ' i I-, i ~ BO..:,;=, GYRU,:,L. UF I CoL RVE: Y' ,.lOB NUMBER AK-BO-60088 I<EL.L.Y BUSH I N(3 F:'I...L-.:V. : .... 0 P E R A T 0 F;:- M C: (:ii I..i I R E FRL E ~l'lB'-':': A COURSE DOG-LEG ~..~ ..... ..:.~E COURSE ]"OTAL VEERT ICAL. VERTIf3AL INCLINATION DIREC:TION SEVERITY RECTANGULAR C:OC~RD I I,~A"FE'.S DEF:"T'H DEF:'TH E~E:J3 M I N [) E (;~i F~ E: E] E; DEG/1 C)() NORTH/SOL. ITH E:A E:'l" / W[::::~;]" 0 1 O0 2 C) C) :30 0 40C) 500 6 () 0 700 800 ' i i}O0 :1. 100 :1200 .:,c. 47.5A. E N 86.39 E N.=,n 19 E ~i~ I.II N 42./_-,9 E N 2i. 60 E N 16,.?,i') E O. 28 17.65 S 0'21 17. oO S O. 48 17.47 S C). 4(:) 1.72.' (] ,-,~-- . i I"~ i&.50 5: .. 1:3.71 '"" .2:' ',.:.:.'7'(':) '.~:; N :2:6, "::'::~ E 0 4:2: 1-=. o.~-] N 4. '-- .' · ....I d ...._ N 42:. ::i:O [!..: 0.59 :1. ':?. 8 :F.: N ............ VE:RTICAL. SEC:T'ION CAI_C:UL~ATED ALONG CL..OsuR[~: ~EASL.!R([J ......... V..E'-.8.T.]:.C.!.A...~ ............ VERTI!~nL, INCLINATION DE:.'F'T Fi DEP'T'H DEF'TH DEG I'11N ...................................... SPEI:RIRY...-.SLIN WEL_L.. :.=.;I.JRVE'Y I Nl','i Cf3MF'ANY ANCI--IOF::AF!iE A L. A L:.:;KA DATE OF SLIRVEY NOVEHBER · L'~"¢~"~--. · · ~ L" "-- ~ ,--- '~, ! "' C:OHPUTATION DATE BO:,c, OYRu::,CUF IC: .=,URVEY NOVEMBER 19, ':'a . . . .... . I ~,= 6 ..~!:0~ ..'NLII~IBER . " K E L. 1_ Y BI. ! S H I N G E.L. !::. ~, ,, =..'. ................................................................................... 0 PE R A '1' 0 R- M C G U 1' R E ......................................................................................... E. UL RoE [ oO-LEE~ TOTAL. '"': '" '1 ' '" D I REF:T InN ,.,EVER I TY RECTANGULAR NA I I::.::, _ . _ L.I_ LiF~[I I .... ' .... I]EGREES [iEG/10() N ..IR [ H/.:,LIL! I H EE A :..'..i; T / W E :ii;; T · :,.,:= I',i 47 ._O E 0 41 27.11 N '-' ~' · .'.. · 76 · .g:.._1 . :=: 2 ('> 0 :':: 1 '- '-' '-":' 3129 2 >2 "=' ";' ".'" Y,=,, .,:-..' ,- ,...,. N 44 60 E 0 '-' ~" .'30 10 N ""' © '-'"~' · · . ...' .j . " = .~:Z '-., C, / :=::::00 ...-., ..:'";":"-:. ¢, .... ] 5 "-"-"::' '-.' 29 .... .... F:;- · =,z.z;·l.~ '= N 43. 10 E 0 .:;Y·91 N ..::1 .... 7 .............. ::~ii4oij ............. ?~i9:.:.':]'0'i~ ................. -}~D:;FXF..'F -- ~---~ ..... E["-TfYT!D~-~:; ................. o, 4';' 35,21 N -'::ii::.:!,',, :..=.:7 35()0 :34'~):.'=':. (),.':, :342'!;' ,, ()6 1 27 b.i 4-6./.':,'F.> E 0 ,, 18 ::-'.:7.05 N ']i:5. :35 :.:-::/-, (') 0 .... ' ~:'':/'''' . ........ = .... ;,::,. ('):':i ::~: 5 :?=".'.i;>_: ..9 !;i!: ...................... i_ ......... !2 ............. N ...:!7., 5.0...!~ ................. !:).~..A?_I: .................... ::_.::::.:=':. 64 r',l :;:':"?. :3700 '"'/-'"~'"" " · =, o; ,:, O O '::/-,'::"-? 0 O 1 ":'"' .,...:, N :37. :IL O E 0 '-.":'~ 40 """" .......... · . ._-,.:,, N :3':.':' O :-3 d:...' · u . .~,. ,.::,- 9:=: .-, .-,,.., 3 ::_:: C) (') .", 7.'. 7 ..... .=,7.,::.o, 9g 1 i.:, ':' N 4~ ~(') E C) "='~ 42 (...",]'- N 4-A ................. =.:_:. :.::.'='..::...7 · ''~'-' .-,,-,.' ,:,,; .-, 1 16 N ,:.,._,./=,0 E (.} · z:," 4..::, 71 N 4 ] 400C) .'::,,=~,:/'~--;f.~:~.~ ............ --:=;7..'5:::;?;'-;72;:,- ............................. --7.:;, .............. ~]"' ,=~.=-.=;7,,.:~-'-'-= .................... ..-z-. --,, ,-m;-~--- .,-7-~---:: ............................... .: ' "": ................ :,...- ,:,..~ ..:, 1 c, i.I .:,._,. ,:, :: E o. 4 4 4. ,. 1 '.:¢ N 4-:..: 4 7 41 ()0 40'.:;'7. '?.1. 402:E:. 91 () 54 Iq 6/.-,. 6'::> E O, 32 4-6.0'7 Iq 45. (;;);;il ......... 4200 419'7.'?0 412:3.!?0 0 56 N 67. :39 E 0.C) 4 46,69 N 4300 4297 o,_.? , .-:,.=,::, ,-,,: - ,- ._ ...... ~-.,-.. ,.;,. c,.'/ I 10 N 6Y. 60 E O. 24 47..::7 N 4400 4450 4.5 5 0 4 :,._, £) 4700 4800 4o Y7.07 4._~ -."o. 87 4447. :---:4 4:378. ,'_-':4 ..... 4';~,'? 7 ~ '?0 ........ ;'~'4 :Z.::!i?:-'7';:l ................ 4547. :'::: :3 447 :'=':. 3:3 4596.68 4 52'7.68 ........... 4645 4694 55 46,'5. · ,~l 4?9 !. · _ {.) 4722.5C) 4.5 N 4.60 W 1.21 0 N 47.80 W 5.03 · ._, :31. 8 2 10 :30 48.22 4i~.i. ,.,'.v N .18. ].:5: 45..[ :!3 4 () ,. 22 :.:-::3,. 17 ... /:,:3. "~ (.) ?/ N 24.4:3 ~7.27 N 14. 7 ~. 91 N ,_.'=' · 7 :.T.: ........... ,;: ..... · £%- ,,_-,...,, '!:> q. 9 :!.-'.:., 7 '.:'4 . . ~ .9.98 N 13 :.T.:. 75 '-26.79 N 210. :5:7 ..................... 01.70 N 25'2.01 ~ . · ....I ........ . .... 11 49 13 5 15 15 N /:,5.80 W '2·79 N 68. '"9 .=, .'. W 2.78 N 74./;,,9 W ~.'":' 6,(::. 4:318 57 16 .~' . . ._e, N 79.69 W 4'.-.-, i ?::,'s:c) ' i':.:.': '32 I~ :ii:~':' 'i 9 w 500:3.2:3 1 '5 ~- -'-, ...... =, N :36. 0 W '=' 1:3 :3C).'=~'=~ N 2. :=:'..=~ :34.92 N I. :3:_:: :3'7.44 N ! ;,3.1 A R (_': O' A L A S KA '~" I NC. SF'ERRY--SLIN WEL. I .... :iii:URVEYING COMF'ANY ANF.;:Hf]RAt'.!iE AL..AL'-.';I':::A D~I'E OF .=,LRVEY NOVEMBIER :3 K- 10 ( .=, E L...:,._, T 1 ._-, N R L .'. E ) !!!;UPn_~U.!:!: ............................................ ::- .::...:.:.,.,,., ,- ...... ALASKA VER'TI _.¢--.d_ SEC"I'ION CAL..CUI._ATED AL. ONG c..uMF UTAT I ON DATE m NOVEMBER I Buo:=, GYROL:;COF'IC SLIRVE!:Y ,JOB NUMBER AK.-BO-6OF~8:F: K E I.... I.... Y B U :".!; H I hi G E I... E V. fi F:' E R A "1' I;"i R--M (.': G I...t I ..... ['F:I JE ~:U.~m~Eg buLIR._,E bUL ~.:,E DOG-LEC~ TOTAl .... I'IEASUR~_[~ ~ ER..].~.I !;j¢_~ ........... VERT:I:O~L INCLINATION DIRECTION SEVERITY REECTANGUL. AR F:~n,nRD l NA'TES DEF'TH DEP'I"H DEPTH DEG M I N DEGREE:S DEG/1. ()0 NC~RTH / SCH_I'I-FI EAS]" 5 '7 () 0 5:_--:00 5?00 60()0 4, :! ()0 6200 6500 6600 6800 6?00 :3::_':: W 2'7 W ,.'.l-::!: W .l .:':i ::_:J: C, l....I ':" '"; 2'7 W ':.'-/'::;' 14 HOR I Z,)l',lT(:d_. I} I'..:.i;F'LACEMENT = 1250.2..:7 FEET "Al:" '"'NC, RTH"'?'~'" DEG'~ ............ 47'""i;ii N. WEST A-I" MD ..... 7:}0,.", THE CALI~ILATION PROCEDURES ARE BASED ON THE USE OF THREE-. DIMENSIONAL RADIUS OF CLIRVATI_IRtE ............................ P'I F.::_'"l"l-!l'"i.(.l. :i::F'EF~RY-E:LII',I L4E]...t .... Ei:IJF~VEY I N(:~ COMF'(.INY ARCO :3K- 10 ( ... ?:LJ_F__~..R L_!..~:... ............................................... ::::::::::::::::::::::: :: :::::::::::::::::::::::::::::::::::: ALASKA COMPUTATION DATE NOVEMBER 19, 198'6 d.~lB NUMBER AK-BO.--60_.{:?:E.' .............. KEI._L¥ J:ll_l::-'.;H:[Nl:.:i EL.E-.V. :::: E,':?,, (:,,':.i L.-IF'ER/~'J"I::IR-- ~"jl"_':l]:ilj ]: I NTS~:~.~.~:~.[ VALUES FO[:--EVEN 100C) FEET OF MEASURED DEPTH TRUE :E;UB~SEA TOTAL. I~IEF~E;I-IREK~ - VE'IR'~:']~'i~::Ai..: ............... VERTIi~AI..: ........... '~-~::~:'?~1~;~]]'i]'~'~' ......... ',~:'~,~iR'~:~"~'~'~:'~:FE:S MD- TVD VERT I CAi_. I::IEF'TH [:,E:F'TH KiEF'TH NCIRTFI/E;OI..ITF-I E:(~E;T' / WEE;T D I F'F:E F(E:NC:E: CCIRRE:C"F I ON ......... :30 C.) () :2 '.:.;"? :'_E:. 44 4 () C.) 0 '3 :5000 -~:l '.:.:".3 :2 . ./:, 1") 1") (.'.) ,-:..-,,.-, . ........ ::,,:, 4 ::::2 7 00 O /- 70 E. '-"-' · . '-, ., ................. SF'Ii.EF:,'RY-.-F-':I_IN WELl_ SURVIE¥ I NG (':OMPANY ANC:HOI~A f'~iE ALAE:KA ARL. U ALASKA, INC · _-,K- 10 ( ,--.c-,- ..... ,~.- .., :_-. L_ ,... .:, ._, T1 3N RO.-.rE ) COMPUTAT I ON DATE KUPARUK . NOVEMBER I'F~, 1" o~' ......... :.:..? AI_ASKA .............................. DATE OF SURVEY I~i!J:i(~'EMBEI:k ,JOB NUMBER AK--BCI--60088 K'EI...LY BLISHING [EI...Ei'V. : ..... 0 F' E R A T 0 R -M C C'; I..I I I::;~ I::': .................. i"~'~E-D V~-Ei]'~:'::'.'7,-' ~.;0'R-'"~9~'~i' ........ I {.5'"o ....................... FEET UF;=: ;""~:~oUB-..:,En;~ ................. DEF:=;-~TI.-,i .............................................. :..:.: ~.::!~:~:~.~: T'RLtE ::/.EiUB~EA TOTAL MEASIJRED VER'i' I CAI._ VERT I CAL. RECTANGL.IL. AR COORD I NAT'ES MD-TVD VER'T I C:AI .... DEF"I"H DEF:"FH DE:F'TH NOF~Tt4/E;CILI"FH EAS]"/WEST r) IF'FERENCE CORRECT I ON ............ 0 6,9 169 269 4 ,'_'-., '.:.:' ./_-,6,9 769 ?6? () ./:, '? 1./.-,9 5:'6.9 136'.;~ 4. 6'.:.> 5,/v:? 6'..-?. 00 0, A 0 0.09 S 1/-,.. '-?. .00 100 .00 0 .62 ._,o "';::' ;':-. '-:;'. ()o' !~!' 0 ()":"'~T ........................................ .1. : ......................... ::.!: :.:.;~ :}.':,'.'-., 9. ()0 :}:: 0 C.) ,, () 0 2. ():iii: '..'+.'; 469'. () () .4 () () ,, ()0 3. 17 ::-; ./:,6':?. 00 /_-,00. O0 6. ':.:"7 E; 1.77 W 0.04 (). ()1 76'P. 00 '700.0 C) 7.71 '.S 1. 'PC) W c). 05 0 ,, 01 ;!.-'..: ./:,;.:.;' :, i"~Ci ............ ::-;:()'¢i. ,' i':i'iS.. ......................... ':~'-'" :l 4 .S: '2.42 W 0.0/- .... i"; c; .l 'P/-,'.:~. OC) ?OC). O0 10 ,, :34 :.'.:.'; 2.82 W 0.0'7 106'?. C.)O 1 ()OC.). 0() 11.38 :.'.:.: :3.39 W 0.08 i"i";i:"F', "50 ................. i'iiSo. 0i5 1:2 : 58 s :3 :'-';'""~:~::.q .................................... w o 7'-"~o';, ................................. 1 ''~/- '-? 00 120C) O0 1:3 2A :.-'..:; 4. "'-' .,- ......... ~_},:, W 0.0;¢ 1:369.00 1300.00 14 · 10 S 4.27 W 0. O' "'.'/ "i-,IZj.!:}-': 'O'~:i ........ ). zi:iS'(_T.-~i'E,- 14.72 :_:.': 4.0::: w o. i 0 .... 1 P:/-,'.~/ ()0 150 (). 00 :1. -!5.5 'S ":' ' ~- -. ..,,'.: ...... 7._, W 0 · 10 !.'".-i:F'I::RI~V-SLII~/ F,IE]._I... !F:L.IRVE Y I i',113 COHF'ANV AN(":F'IORAI-.'.i[!" AI.AL::KA ARCO ALASKA, INC. DATE OF SURVEY NOVEMBER 'R" '---' "' 9 "~ -'-" i ' · _1':,-10 ( SE1-::35 TloN R(): E) L.I-IMPL TA TION DATE · "11" ...... .. ' '= "~' ........... I.-.._ F ARLIK NOVEMBER 1 '?, 1 ~.~o/_-, ,JOB NUMBER A L. A S K A K E I... L Y B I..IS I---i I N iii I!!.-'. L. E V. INTE:~'~?ED VALUEL~ FuR EVEN I(.)(:) FEET uF ~t.IB-SEA DEPTH IR JE :SLID-SEA TOTAL MEASURE K~ VIER 1:']~ "J~,]~[~'l'"~ VER'I" I CAL. REC TANGUI..AR COORD I NA'I'ES MD- TVI] VERT DE:PT'i-.~ I]EF'TH I]EF:'TFI NOI:~TH / E:OI..I"FH EEAST/WEST D I FF'I~;RENCE; E:EIRF~ECT 101'4 1 ?) 6 '.-? .':-~: 16 ':::' 226 'iF/ :2 E: 6 !i> 2469 25/:.'.:.~ :2 ? :17 O 2 :.'.-'.: '70 196'.:.;'. 00 1 '.-?00. O0 17.81 S ';?. 26 W O. 11 0. ()0 2069. O0 2000.00 17.66 '.3 .t. 72 W 0. i I O. 0() 2 .~. ~ ':;'. o'6 ......... ~!"~."0'~;T';.'i;iS ............................... .1. /:-:.-,: ................................... ':?o :::; o .-"-./-,/-, .... -w n... 1 '::!: .,.."::'";';:','::/., .... . . (")(") .......... '?'~.J~ (')(]) .00. 1 =. ()::'i:._, S 0.64 E C). 15. ~"~... ("~ .!:',.. :;::':.:.:;.'-.,'-? ,. ()0 :;;i~ :L:: () (:) . O0 1 (). 4. 7 t:.'i; 2 ,, :::.':4 [: (). ?7 (} ,, 1 ::': ............... '.--/46'~.)'00 ' "24.¢K),0'0 ................. 4", ~-;:5" S ' 4. i'1'E ' O. 4/:, O. 25/:,9. O0 2500. O0 1.4:3 N 6. :2:4 E O. 67 (). 21 :2(:,6'.'T~. O0 2./:,00.00 '7.60 N ?.?, 54 E 0. '~ 1 (). :2Zl. 276'?. () (} 27 () 0 ,, ()0 13 ,, 4. 7 N 1 :.'-.':. ::it 7 :: 1 ...1. 5 (). 2 ,q. .,'::':::::/-,9 ...... . (-)0 .......28(-)C~ . (")0... I8 . .'=_'-'7, N ].7. 19 ....-' i ,. :'3/-, ........... ~"). ';;' ]. 3070 3069. O0 · '3170 :316 ?. 00 3270 3269. O0 :3:_::70 :3 :..-::6'.:.). O0 :3470 :346'?. 00 '357 o 3.'.¢.9. oO ...... !_-:,'g';7-i~J .... '?:i:"."3?:,~;;i~: ~':i6 ........... ~-,"gO0. O0 :39.77 N :_--:OOC). OC) :26, 21 hi :24.78 E I. 6,5 310(") O0 '--'9 24 hi '":"::' 03 = i 75 . ~. .r.,. ~ .,;.. '...' # .. :]-::20(:) C) O ':":" 13 N 30 '" ~ '=' .-* -- 1 0 '-, :3 :3 ('.') (:~ , O0 34.64 hi 3:3.2;6 .': .1.. ::'::9 :3400. O0 :36, 54 N 3 5, :31 -- 1. '?:'3 ..-T.. .......................................................... ......... :':: ?.: 0 ~'), 0 0 :.-:: ::-.':, 2.3 N 37. 11 :..': 1, '.:'/6 ,:,,.~,. 66 -- 1.99 O. ]. O. 1 ::3 (). 10 O. 0:3 ............ O. <'-~. 0,:1- 0 ,, 0:3 .. O. 02 Ei;F:'IZRF~Y-'SL.IN WELL. Y-.';URVEY I I',IF.~ COMF'ANY ANCI..tOI:;tAGE AI_.AF:;I<A AR- '1~'1-'_. _1 AL.A.--.,[,..A~'" ::' ............., I: ..... Nt..:;':. :2: K- ! 0 (" ..... '= "' '- _ _ _ · :,EL....',._, T 13N RL).-.¢E ) L-:FIMPI ITAT I ON DA'rE " "' - ...................... DATE OF SURVEY NOVEMBER dOB NUMBER AK-BO--6OOF:F': KELi._ Y BUSH I NG El_ Iii..' V. oF:'E R A T 0 R -M C G I...I I F,' IRLE '~" '" ~.,UB~EA ME.'A 3LIRF'D ' VER T'J:.]iii!;:~';i... VERT I CAL DE P'I"H D EI:::"T'I"I DE P I"H TOTAL R E C 'T Fi N G I..i I.._ A R r.:: i"j i..-.i R [:11 N A 1" E S M D -'1' V D V E Fi T I C: A i... NOF(TH/Sr:)L.I]"H E::A'.~:; T / WE.'..E;T I] I I'"'F'EF:,'I:'i]qC:E CORRE:CT I Olxl :3771 ':'°71. 39'71 40 7:1. 4-1 '71 41/.':,'?. 00 ;.1- 271 426 ?9, 0 () ,:1.371 4369. O0 447:1. 't 46'.:}. 00 4.571 456'.~ · 00 467:':: 4'6','-':: 9. (-:i~."~ ..... 47 '76 4 '7/.'::,'i?. 0 () 4::.:8C) 486':.-:. C)0 4'F~ :3.'::_"; :50'.~ 1 50 ./:, 5198 516,'~, 5 41 4 5 :,,9 6 .-,,-', ~- o 4 3, 1 '-' N 41 L-,2 E 04 0 02 ..:,oo ~ 00 3800 O0 '":' 376'.:.) ........ O0 :::90C~ 00 44 q~-,_,.:, N 42, 99.. E ~.'---' 06 O. OK::'_._ ' 4. 0 <.~: s,":"O() ........ ~i:56'i:~' :' ~5'~:~ ................................. 4 ..~ Ti:'2-:::: 9 .............................................. N 44 :" 'L-:,'-, r., .................................... [~ 2 7 ('.,'7:cF: ............................... ~:i':'i 4.100.o0 46.!51 N 46.0.,:. E 2. lO 0.02 4. 2 ()(), () 0 47. J. 6 N 47.66 [ii: 2. 1 ]. C:, ,, C) 1 ~4:~iO0':'i~ii5 ..................................... 48 ~ ......................... 00 N ~"i~. ..... Ir'-,.- ............... E ~.'7; ...... i"~ ................ 0 02 4400.00 50.44 N 47.0'F7 E 2.21 0.08 4 :~_ic) o 00 Fi E, 71 N :37:36 E '" '-.77 c) '71 ;'.i:'L:, 0 O' ~-'Cii] ........................ ,.'.-.,=5"i'-'-i."'~'~("~ :::: .................................... N 19~'",: "i-"i."-.-.' o .......................................... E: 4 ;-i'-~-79 .................................... 1 , :.3 '7 55:2' 5 5'46 '::.". '0 0 ..... 4.00. O0 5636 ='=Y' '--/ 00 .=,SAO, 00 ...I._i 7, -~,~ J. 0 ,. 4 C) II. 67 3 K- 10 ( '~'" ....~' = ' :') '~ oEU.:,..., T ! 3N Rt. PE ) KUPARLIK ALASKA uuMFUTATILN DATE ...... ....:-,..~:::i...: :,%.: :... _ .............. . _ N__O~E__MBER 19, DATE OF SURVEY NOVEMBER ,_!OB NUMBER AK-BO-6()OE:8 KE-:I..L Y BI...I .:.]1...I I IxlG lii..'.l.... [."-_ V, 0 P E: R A T 0 IR ..- M C G IJ T j:;~ [ii: .. ' ii:: ~.:' ~: ~: TRUE ............................. ::::.::i ~ ...SUD:,i~:.''',~.E~ T 0 T MEA :SURF"~i] VERT' Ir''~_.~!... VERT I CAl... RFF:TANi7I ....... IL AR C:OOR[i INA TE.".S MD--"FVD VEl::;,' T I CAI .... I.. EF I H DF'F'TH DEPTH NORTH/F:;r'~! I"I"H EAE;T'/WE:.L:::T 62:25 62:47 646,? 6590 6712 6'754 70'76 6069,00 6000, OC.) 1 (,0, :2:0 N 61 (":,, :31 W 156, :3 '1 2:3, ()::ii: ,'41 A, 9 (')(] 61 C.)0 0() 1:7 J. 7',:: Iq ' '""'::' :2:1. W J '" '"'' .... ' =' '::'";' ................ E, c:, ....,, / c,,.:',.._, .,....,... () '.":1. ./:.2~:..~.-'. i?O .... ;:-, :Z O'ti'. 'i:.) .... . .............. i h!~i-;"5;~ N ....... ?'5:.'::. ?':::~ ~ ............ E-i!;i~;':"i!i-4 2.t . '~..?, z-, ...... :':: F-,'E~. 00 6300 .00 ! 94.24 N ,_, .... z':' '"'' ':'. . :.37 N Z.."I . ,_,..,:,~ ..... 9 ~ . 8 (").. 64/-, 9 0 ("~ 6400 ¢) (") '.'.'('~ F, /-, A kl '.R':"::~ ::: 9 W '-' ''~ ,_ 4._, 00 ,':-..=~;::;~;' :.'i"ih ......... 'Z-:5'i:fi";':'"i:'i?i ............ ................. :::'-'=:;:1., ............................ 27 N 757.: 3OW 264.2O 6, 669.00 6, 600, () 0 2:2:'?, :38 Ixl 102 L=;, :2:2 W 2 :--:5, 6 ,":-, .... 7 ,fi:, 9 ,, ~"~.. C.~_ 6 70 () .00. 241 ,, :"-': .... P; N 1. 09:3 .82 W :--: .... C) 7 . ........ 3:30 . o ~: .~:..:,. 0 (':, :349.43 1:3.81 THE RAI_CLILATI(]N F'ROREDIJREF:; LIE;E A L. INEAR IiqTERF'OI....ATIFIN BETWEEN THE N6~RES!.'[ 20 '.[j:'OE.!T.' p1.£i' .~F.R.!..-.!!~!.. R().[!.I.L:!$.!.....!?.F:......!?n!.R..v...~)..].].!._.!..F<.'..E..). ....... .F]Z!..~.N.T.!-:..ili.ii......i ........... .] ................................ :ili;PERRY-.SUN WELl., S.;LIRVEYIixlG COMF'ANY ~ .... i~i .-, ~ ........ ~-4NL. I..~ ... I.~[.¢...~E ALASKA 'ARCOALA.:,KA, · _*,1-:,- 10 ( '-"*-I ..... · -,,.~ ....:,._, T 1 :'::N RO'PE ) KUPARUK .................................................................. AL. ASKA ................................ buMFUTA1 ION DATE NOVEMBER I c~., 1 '"~;,~,6 :~- TRUE .... "SUBarEA . TOTAL · L *. ~..z~. ':':*',', MEASURE.[] DE-".F']'H V E". F;.: T' I CAL VERT I CAL_ REC'I"A Ni-_.iI...II...AR I'_-:C] OR D I NAT'ES I']IEF'-f'H L EF 1 H I',IORI"H/F:r'~l I'H.-.I EAS'I"/WEF::T .. 4:, :::!: 24.62 /_::, :;:_**: 6 0 ,, 3 7 6 950 ,. 5'7 MARKER DATE.CF'~]='":?7"i ........... ._-,LIR~;;: ~"'7Et; ........... NLIVE:.I:' ......... ;::; "'"IBEF,.::; ..... ' dOB NUMBER AK-BCI./:0088 K El_ L Y BUSH 11'4G EI...E V. - .... 0 P E R A T 0 R-. M C G U I R E ........ ./:, .. 1 .J, 'U6 N :.,'44, ..:, 7 I,.,1 TUF' I,..UF ARI_Ii.... L. :.,=, 10 6985 714._,'= '718 9 '7:3 00 652(). 44 219.68 Ixl ,'_'-.,6'.'74.94 232.32 N 6755./_-, ? 24-:ii!,' ,, 4 .t. N ..S 7 91. ::ii;'7 2 5 2.9 5 I,,I 971. 14 W BASE KLIF'ARLIK C: 1042. 19 Iai TOF-" KI_IPANIJI< R 1 J. (:)'7, ..:: / 14 .:, .~ r'~ v r..'. 'r I:) E P'T' H .. .--.**-r ""'1 Ir..'' ir-x,- il. 1:3:]:;, 0::.'-] b,I BA:'~;I:?.' KI_.II::'ARI.JK A ]. j. F.'."; :.:;. :}".: ;;ir N I:::' b 1...1(;.~ [.}cA L"::K "1" 1221. '.':.~'..T, W "'T'I.~i]~AL;.Y"I]EP'T:i]t "[~f:;~ II....LEI:;; . . A R r'::O A L. A S K A, I NC:. .I(;=,EL..:~._, TlcN RC~E) STRAT I GRAPH I C SUMMAR ':,.. Y : ......... ...::..:'~::DERIVED USING DIL pEPTHS AND :,FERRY :,UN c,L!RVEY DATA [;i I].1 Ii)I:'~ [] ]J l'q A'T i .......................... MAIRi<IER ......................................... . ..... T'VD .................... " THIC:KIqESS BKB SUB-SEA VER'T. I CAL 1 ) FROM L..INEAR EXTRAF'OL'ATI(.'.,N BE[..C.,W I:?E[?;F..':r~iT ":~iynT'i'c.,N~ ................................................................... '-' I"- ' ' ' "- .... '"' "- , . . i I"'" I-' I ' ' -") -.UHFUTER FIRUURAM -' ;:.FERRY SLIN THREE DIHENSIONAL RADI,_::, OF _.LRVATLIRE, DATA C:ALF:UL. ATION AND INTERF'OLATICIN BY RADILIS OF CURVATURE DATE OF :E:URVEY NF)VEMBER IS(_'IMF'LITAT I FiN' DATE .................. NOVEMBER 19, 1'.-286 JOB NUMBER: 'AK-BO-60088 ~:..ELLY:~:::~:.~::NG ELEV. = 69. (}0 FT. ¥ -::~:>;::.::s.~.::~.::!~::?:.!:~:,:... · ':::' 5Ci::tLE :- ~. :..",,?:: -..~ 5:3.3 .... ,' 5GO. O qscs qLqs:q. ' <2' /J ,-% .- CD CD. i. , : ARCO Alaska, Inc. Post Office 00360 A~chorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 19, 1987 Transmittal #5889 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. Open Hole Finals: 3K-10 Cyberlook 10-28-86 '6650-7150 ~(%h~' 5" FDC Raw & 2" FDC Raw 10-28-86 .6600-7146 5" FDC Porosity & 2" FDC Porosity 10-28-86 6600-7146 ~~" DIL & 2" DIL 10-28-86 3830-7172 3K-9A 2" & 5" FDC Porosity 10-19-86 6800-7495 2" & 5" FDC Raw 10-19-86 6800-7495 ~.._.._...~""h~.. 2" & 5" DIL 10-19-86 1000-7521 ~~. Cyberlook 10-19-86 6800-7450 3K-9 Formation Micro Scanner 10-16-86 3175-7407 2" & 5" FDC Porosity 10-15-86 3175-7399 ~~ 2" & 5" FDC Raw 10-15-86 3175-7399 2" & 5" DIL 10-15-86 3175-7425 ~25" High Resolution Passes 10-15-86 3300-7368 ~yberlook 10-15-86 3175-7399 2" & 5" BHCS 10-15-86 3175-7394 Receipt Acknowledged: '~/ ~jT~z--~'~ ~i.~ _~ __ / · NSK ~'0~ng Rathmell D & M L. Johnston (vendor package) Vault (film) Date: Sta,te (~'-Sep) ARCO Alaska, Inc, is a Subsidiary o! AtlanticRichlieldCornpany ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE January 2, 1987 TRANSMITTAL # 5869 ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 '/~i~- - 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. CBL 11-16-86 5547-7730 CBL 11-17-86 5115-7674 Pulse Echo Log 11-16-86 7002-8381 CBL 11-16-86 5502-7173 Receipt Acknowledged: -';.-~?,~i~.:~.%:~..,~.. Chevron ( sop) Vault (film) NSK Mobil (+ sep) SAPC (+ sep) L. Johnston Unocal (+ sep) ARCO Ailtkl. Inc. ii · Sube~di·ry o! AtllnticRichfietdCompiny ~-~- STATE OF ALASKA ALASKA . AND GAS CONSERVATION COMMIE ,)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging '~ Perforate - Pull tubing Alter Casing [] 'Other [~ , C(]vlPLET[ 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1160' FSL, 316' ~L, 5ec,35, T13N, R9E, LIN At top of productive interval 628' FEL, 5ec,34, T13N, R9E, Llvl 842' FEL, Sec.34, T13N, R9E, UM 906' FEL, Sec.34, T13N, R9E, UM 1375' FSL, At effective depth 1413' FSL, At total depth 1424' FSL, 11. Present well condition summary Total depth: measured true vertical Effective depth: 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit 7. Well number -~K-I~I 8. Approval number 9. APl number 5o- 029-21653 10. Pool Kuparuk River 0il Pool 7300'MD feet Plugs (measured) None 6951'TVD feet 7189'MD None measured feet Junk (measured) true vertical 6860 "]'VD feet Casing uctorCo-rld Length Size Cemented Measured depth True Vertical depth 80' 16" 1540//Poleset 1lO'MD 110'TVD Surface 3792' 9-5/8" 1075 sx AS IV & 3829'MD 3827'TVD 305 sx Class G Top job w/150 sx AS I Production 7239' 7" 325 sx Class G 7274'MD 6930'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 6931' Packers and SSSV (type and measured depth) HRP pkr @ 6904' & TRDP-1A-SSA SSSV @ 1772' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressbre 13. Representative Daily Average Production or Injection Data Feet ,, ~ N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History w/Addendun, dated 11/19/86) Daily Report of Well Operations ~' - ., Copies of Logs and Surveys Run ~. G~-z~o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢,~/~/~,.~ ~~/t.~ Title Associate Engineer Date /~2-/'7--~__~' Form 10-404 Rev. 12-1-85 ~/-v (D/~) S1&)/138 Submit in Duplicate ARCO Oil and Gas Company Daily Wel~ History-Final Report Instructions: Prepare and submit the "Final Report" on '.he first Wednesday after al!owable has been assigned or welt is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are susoended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and represemadve test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska County or Parish Field Lease or Unit Kuparuk River Auth. or w.O.mFgnO. AK1428 Title North Slope Borough State Alaska Well no. ADL 25520 3K-L0 Completion Nordic 1 API 50-029-21653 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun [Date Complete I 12/3/86 Iotal number of wells (active or inactive) on this~ ost center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 0600 hrs. Date and depth as of 8:00 a.m. 12/04/86 Complete record for each day reported Old TD New TD Released rig Date 2230 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing 7" @ 7274' 7189' PBTD, RR 6.8 ppg Diesel Accept rig @ 0600 hrs, 12/3/86. ND tree, NU & tst BOPE. RU & rn 211 jts, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1772', HRP Pkr @ 6904', TT @ 6931'. Set pkr, tst tbg & ann to 2500 psi. Tst SSSV; OK. ND BOPE, NU & tst tree. Displ well w/diesel. Set BPV. RR @ 2230 hrs, 12/3/86. PB Depth 12/3/86 Kind of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7189' PBTD Rotary 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate Drilling Supervisor ADDENDUM WELL: 11/16/86 3K-10 Rn CBL/GR/CCL f/7173'-5502'. Rn gyro f/surf to 7100'. Rn GR/JB to 7178' WLM. Drilling Supervisor D~fte ...... STATE OF ALASKA ALASF OIL AND GAS CONSERVATION COMN,..~SION 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- Amend order '- Perforate -- Other ' 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 of well at surface ' FSL, 316' FWL, Sec.35, productive interval 4. Location 1160 T13N, R9E, UM At top of 1296' FSL, 626' FEL, Sec.34, T13N, R9E, UM (Approx) At effective depth 1445' FSL, 883' FEL, 5ec.34, T13N, RgE, UN (Approx) At total depth 1459' FSL, 1902' FEL, 5ec.34, T13N, RgE, UN (Approx) 5. Datum elevation (DF or KB) 69'RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-10 8. Permit number 86-163 9. APl number 50-- 029-21653 10. Pool K'uparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 3792' 7239' Production 7300'MD feet 6947'TVD feet 7189'MD feet 6901'TVD feet Size 1 6" 9-5/8" 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 1540# Poleset llO'MD 1075 sx AS IV & 3829'MD 305 sx Class G Top job w/150 sx AS I 325 sx Class G 7274'MD Wue Verticaldepth llO'TVD 3827'TVD 6925'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Wel 1 Hi story Description summary of proposal Detailed operations program _- BOP sketch - 13. Estimated date for commencing operation November, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~ Title Associate Engineer / Commission Use Only ( DAM ) Date 5A/151 Conditions of approval Approved by Notify commission so representative may witness - Plug integrity - BOP Test Approval No./ .. ,>¢).~>~ .---. -- Location clearance .......... ~ ..... . ........ by order of . I Commissioner the commission Date /~ ~%~¢ J Form 10-403 Rev 12-1-85 Submit in triplicate AI9'6LL 'NI£'66I 'SA L0'96L 'OAZ 6['L~Z9 'AI'OSN 'o6'~[ ',~9 M09'89£ 'MZ0'SZI 'SA 90'[9[ '0AZ 0~'909~ 'M0'08N 'og'zz IaP [,.a~3oa ',6909-1969~/~ a.~ns ~ laP '~u]qIn3/A HI~ 'BOa 0I los '~'V T~ '-- Ha '0I aA '~! Aa '+6'6 'aM AIE'6$Z 'N9Z'0II 'SA Z~'ZZZ 'CIA& ~O'08E~ 'A0*ZgN 'o$'~Z ~9'~9I 'N6~'ZOI 'SA 8~'ZLI '~ 8Z'~I~ 'A6"ZSN 'oZ'IZ Hzg'01 'NZZ'~9 'SA 6['I - '~ Z6'0g~9 'AZ'IgN 'o6'Z ~S/A ,00I ~ ,06I ~ ~np~3o~d 3~d~ $ RO~ -sp~oq 9U~33~ HI~ 'H~8 '~oa~npuo~ .9I x .9/~-6 ~q AOI~ p~5~ea · ~ioq A~U ~0I + d~nb~ aI~ $ 3m~ ~ '~od O00Z~~ga 'HI~ 9 ~os '9'z ~ '0'0t Ha 'g ~~~:~'6 '~A ~q .~d ~a Su~Ids~ '.O. ID xs ~0[ ~ AI ~ xs ~ZOI/A ! 'O'A~ · 1! enlm~ I · 1'/~, OOU¥1 %~Z'95 C~9TZ-6Z0-0~ I~ 0I-~[ 'ou iloM e~,e~,S j IlTa~ "u+! qSnoao~ adols q3aON ,!un~o.e~j, ~u 'O'M JO '#Iffy _ 'AlUO selep e^!snlgu! §U~A!5 LU:OI eql uo pez!J~uJudns eq plnoq$ ~u!ppnc~s o1 Joud ~Jo~ XllaO 'peiJEJS eJE suolleJedo Je^O)~JOM JO peppnO$ sJ IleM I~ Je~,JE AepseupeM isJ!; eql uo ,,I, JO(IOl:l IlllllUl,, eqi l!~ctns pue BJ~OeJd :t'oNorulsUl Al!cC] - I~odeld le!l!Ul - AJols!H IIOM "~'v Auedtuoo seo pue I!000U¥ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit ,.he "Final Report" on the first Wednesday after allowable nas been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also wt~en operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if s0ace is avaHabie. Accounting cost center code District County or Parish Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25520 Auth. or W.O. no. Title AF~. AK1428 Drill Doyen 9 API 50-029-21653 Operator I A.R.Co. W.I. ARCO Alaska, Inc. { 56.241 SPudded or W.O. begun ]Date Spudded [ 10/22/86 State Alaska Well no. 3K-10 Date and depth aa of 8:00 a.m. Complete record for each day reported Old TD Released rig Iotal number of wells (active or inactive) on this i oat center prior to plugging and I bandonment of this well I our ]Prior ltetUl if a W.O, I 0130 hrs. 1230 hrs. 10/29/86 lo/3o/86 10/31/86 ?? 9-5/8" @ 38~1~" 7205', (185'), Cond'g rn WI:. 9.9+, PV 15, YP 17, PH 8.4, WL 4.4, Sol 10 Drl 8½" hole to 7205', 10 sI:d short trip, C&C, spoc 101 diesel pill, POE. RU Schl, rn OHL. RIR, C&C f/7" csg. 6937', 34.7°, N78.4W, 6650.43 TVD, 1082.83 VS, 252.86N:lO57.63W 7150', 35.75°,N76.0W, 6824.42 TVD, 1205.28 VS,280.07N, 1177.43W 9-5/8" @ 38:~' 7300', (95'), Prep to omc 7" Wt. 9.9+, PV 14, YP 5, PE 8.5, WL 4.2, Sol 10 Drl 8½" hole to 7300', short trip, C&C, POE. RU & rn 7". Prep to cmt. 7" @ 7274' 7300' TD, RR 10.2 ppg NaC1/NaBr C&C hole f/csg. M&P 100 sx 50/50 Pozz & 225 sx Cl "G" w/9% D-127, .3% D-13, 3% KC1 & .2% D-46. Displ using rig pmp w/10.2 ppg NaC1/NaBr. Bump plug. NU BOPE, NU & tst tree. ER @ 1230 hfs, 10/30/86. New TD Date 10130186 IPB Depth TD 7300' jKind of rig Rotary Classifications (o11, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data ~ell no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gal I~r day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected The ShOVe is correct For form see Procedures Manual, ~e~tlon 10, Drilling, Pages 8~ and 87. l Date ITitle ~:~ I ~//~ Drilling Supervisor ARCO Alaska, Inc. Post Office 12,0380 Anchorage, Aiaska 995i0-.0360 Tolephon~ g07 278 i2!5 RETUR~.I TO' ARCO ALASKA, !NC. ATTIC: Kuparuk Records Clerk ATO- 1 i 19 P.O. Box 100360 Anchorage, AK 99510-0360 ,DATE' Ii -7-86 Transmittal ~5817 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3K-10 OH LIS Tape + Listing #72028 10-28-86 995.5-7206.5 Receipt Acknowledged' Distribution' State of Alaska D. Wetherel 1 ARCO Alaska. ~nc. is a Subsidiary of Allan!icRichlietdCom. pany· September 24, 1986 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 3K-10 ARCO Alaska, Inc Permit No. 86-163 Sur. Loc. ll60'FSL, 316'FWL, Sec. 35, T13N, R9E, UM. Btmhole Loc. 1343'FSL, 952'FEL, Sec. 34, T13N, RgE, U~. 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. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~IE COMMISSION d!f Enclosure cc: Department of Fish & Game, Habitat Sectiom w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery -~: .... STATE OF ALASKA ALASKA C,_ AND GAS CONSERVATION CO~...,41SSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work Drill ~ Redrill F11 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone ID 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100:360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.O25) llCO'FSL, 316'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1296'FSL, 626'FEL, Sec.34, T13N, R9E, UM 3K-10 #8088-26-27 At total depth 9. Approximate spud date Amount 1343'FSL, 952'FEL, Sec.:34, T13N, RgE, UM 10/03/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prc~perty 15. Proposed depth (MD and TVD) property line 7248 'MD 316' ~ surface feet 3K-9 75'(~ surface feet 2560 (6870'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth4500 feet Maximum hole angle 36 0 Maximum surface 2270 psig At total depth (TVD) 3430 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ?4" 16" 6~_5# H-~_O We!d 80' 35' 35' !!5' !!5' ±200 cf 8-1/2" 7" 26.0# J-55 BTC 7214' 34' 34' 7248' 6870' 200 SX Class G (minimu HF-ERW 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 RECEIVED Intermediate Production SEP 1 7 1986 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission Anchorage true vertical 20. Attachments Fili,n,g fee ~ Property plat [] BOP Sketch~ Diverter Sketch [~ Drilling program J~ Drilling fluid program ~ Time vs depth plot .[] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements~[~, 21. t hereby ce,r,t~Y ~at the foregoi, og is ~rue and correct to the best of my knowledge ,~ ~ . / A ,/ '~' /~'"' ..... Regional Drilling Engineer bigneo ~ / ~,¢,/',~: . ~ ~ , Ti~e Date / Commission Use Only ( LWK ) PD/006 Permit Nurnb~er _ ' I APl number .., I Approval date I See cover letter ~'L,~-(f,~ I 50- ~%'~-'c,'r;JU I 09/24/86I for other requirements Conditions of approval Samples required [] Yes '~-,No Mud Icg required [] Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required 12~,Yes [] No R equiredwor~~/~~M; [] 10M; [] 15M ~/ Other: by order of Approved byk ~ "/ ' ~~~/'~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submiti' triplicate NOI.I. 03S 9¥OI.LB3A 000~ 000 ~ tB~t=d30 B~,~Z=0611 0Z89=0^1 (Id 009)I U./. I £9t t=d30 BD, OZ=0611 60Z9=OAI SaNS d~ /B 6t t [=d30 SX69=OWI 0~99=0A1 alNO 130aVl -~ ~ 9Z0[--~30 ~069-0H1 [6S9-OAt V ~OZ /1 - ~ ES6 a30 ~699=0U~ 'E~9=OAI 0 ~NOZ 71 zee=a30 ~8S9-OUl v~e-OAI 0 3NOZ /1 ~ tZ~=~30 OtZ~=OWI [~9~=OAI 003 a~e~oqouv ' 986[ Z T 'dxS' ............ O=a3O-OOS~,=ONJ. OOS~,=OAJ. aON NtN 8t 030 9£ 3qONV--3OV~3 AY V£8£=OAI Icl 0S0 .B/5; 6 ~£9£=0A/ Et->l 6£££=0A1 SaNS )IVS ~69~=OAI SaNS t9N019 clOl t:~J tmaAl ISOB_-IVI4B3~I 3SVB O00Z -0009 -'O00S - 000~ ..... o - ' o I.=- "-oo'ot ..... ~'" ........ O00g .......... -000 t ............ ~ ......... 'ON1 "~OO/SdIHR :NYN/S¥3 g61d · N~: I J. · '11'1:1 .91£ "15.4 ~ NO ! 1¥00'1 _q0¥.-I~1115 I 0001 (130W¥1 01) .6iii M NIN Z~ 030 [8 N 0 000 [ IS¥]-IS]M i i O00g 000£ - O00Z ' 000 t ' 0 - 000 [ 000~ ..Re, Id ' · ~-'13.:1 .~6Z "IS.-I .0~£! , MO I IVO0'l 13~ldVl ~ B 8o .r..= 09 I, HltlO# Og99-GAI · NEt/ '~£ 'O~S .~g6 'qS3 .~k£t ,NOl/VOOq aZ 'ONI ')lO0.1. SdlH/~ NVWISV3 v~sVqv '3dOqS Hi,ON 'Oq3IJ NN~VdNN OgSOdO~d Ol ,ON qq3~ 'N£ OVd 'ONI '¥)ISVqV O3~V 133J O00l = 'NI I 39VOS NO 1 lO3PO~ 9¥1NOZ IBOH -. :' oo£ .~--0o~ '~ ......... oo t '-" I ~ : O_ vo w >->- z J.~ o..., g, -,- -~ o,.,.,~1I ~n O"} 0 'OZW -'J '::: .- ¢.' 000. OW -J W 0 WI. IJ I--I/: i1~, i __i WWO~ --'--I --I> >.tv' l~b. W W ZZ ~ (:1 ~: I.d >- '-'0. I~JW ~>- I--ri' I-- Xl-- 0 OC) Z ,-, '-" O. W __n~' "" ZW Z :~W t-- ~ .OC.),--, -J O--IW~:~' Z,--,I:~ ~.~>~j n,,>. ~ ,--, ,--- _l O') OW ,-,I-- _1Z ~ ¢n 0,.-, ~1:1~ ~: (~ _J~:W ZOed Z O')O') J ~OOn'W OW '-'0 ~:::: :~ '~ 0 '-' 0 O, 01-- iZ: Cf') '1'0 0 W ~::: '-'WU') W Z '-" tZ:: ~ 00000(%1' 1' I'Y' W :~ W C.)Od I::) I~ I'- ~::: ~'Z 'v"v",x'v' 0 W>(/'l:>r::: (.)G.r,Z) ZWW U)n,'W -' ZZZZ-' --,'- >_10_1 '. n,'~L>...O On'O. 0,-,> 0>_.11~0 ~~o.o~.~-~oo ~~ ~o d~,,, d,.,,.~o · §§§, ,~,~, W GENERAL DRILLING PROCEDo.~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psis. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. DEOASSER HUD CLEANER SHALE STIR STIR STIR SHAKERS HUD CENTRIFU6E CLEANER TYPICAL HUD SYSTEH SCHEHATIC LWK4/ih 1986 Density PV YP Viscosity Initial Gel 10 Minute Gel Filtrate API pH % Solids DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 2O 9-10 10+ Drillout to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance 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. LWK5 / ih ARCO Alaska, inc. ~..: Post Office B~x 10036(I Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat- 3K Pad (Wells I - 18) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-49.44. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl osure If ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ._ _1 I III I I II..~1_11 II1~,~ I I J II II I , ,,, , , ~)CATEO t# PROTRACTED" ~7, Z~ -- .~T,~ ,,. T-I''."gE'.~?~A.S.~ ~ ~~'. ~-'~' '~ ~ 0 '[[*tq' Zone 4 ~ ~ - . · I hB~ , , ,, , ,., LOCATED IN P~OT~ACTED LOCATED I~ SECTION 35~ T. ISN., R. gE.,U.M. SECTION 35~ T. ISN.~ R.~E.,U.M. 14~' ~k, 318' ~ ~- ~.{ p~- ~.5 ll~' FSL, 316' ~ ~- ~.8 P~ - ~.5 X - 5~,~.1{ L~G. 149'45'~.93~' X - 529,~5.73 ~. 149'45'~.9774" 1359' ~L, 3~' ~ ~' ~.7 P~ - ~.5 l~' ~, 31~' ~ ~- ~.0 P~- ~.5 5 - Y - 6,~,3~.~ ~T. 70-~'01.795~ 14 - Y - ~,~,053.7~ ~T. 70'25'S~.0923" 13~' ~, 3~' ~ ~- ~.8 P~ ~.5 1~' ~, 31{' ~ ~ ' 5~,~.05 L~6. 149'45'~,~7~" X - 5~,~5.75 L~. 149'45'~.~' I~' ~, 317' ~ ~- ~.9 P~' ~.5 10~' ~L, 316' ~ 1~' ~L, 317' ~ ~- ~.0 P~- ~.5 10~' FSL, 315' ~ ~ - Y" 6,~,253.70 ~T. 70'26'01.0~" 17 - Y - 6,007,978.8I ~T. 70'25'~.3551' 1259' ~L, 317' ~ ~- ~,0 P~- ~.5 985' FSL, 315' ~ X - 5~,~5.9Z L~G. 149'45'~,~" X - 529,~5.73 L~G. 149'45'~.~" 12~' ~L, 317' ~ ~- ~.1 P~ - ~.5 959' ~L, 315' ~ {. NOTES }.ALL COORDINATES ARE A.S.~ZONE4. ~ALL DISTANCES SHOWN ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ~K CONTROL MONUMENTS PER ~HD ~ ASSOC. 4. VERTICAL POSITIONS BASED ON 3K TBM NO. 4 ~ TBM NO. 5 PER LHD ~ ~SS~. * 5.O.G.E~EVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3070 rev.~ ~m II ~ I I I ~ ~ H ~ ~ Il I, . Ill ~RVEYIN~ IN ~E STATE OF ALASKA ~O THAT llll .... TMIS P~T REPRESENTS ~ ~OC~TION SURVEY a.-.. .' ', THaT ~ DIMENSIONS AND OTHE~ DET~I~S ~ :. ., - ,,, ' .. ~, ' . .. .?,~ . . ....... ~ .:..~ SURVEYED FOR: ~ ~Rco Alaska, Inc. 5 ~~~~' ~[CKEDDRAWN ~T. DRILL SITE 3K CONDUCTOR "(, '"' 8SSO[ -- ..... "' ! ~,~o ~.E.....o~ AS-BUILT LOCATIONS IIDWG. NO. NSK 86-31 ~~ Arct~ ~uteva~, Suhe 2~?, Ancho~ge, Alaska 99503"IIS~L~ NOT TO SCALE ' ......... ]i~e ~. ....... I II I III I IIII II II I LR[ECK LIST FOR NEW W~JJ, PERMITS IT~ APPROVE DATE (1) Fee 5~x_~ ~i.%[~ 1. Is (2) 2. (2' thru 8) 3.' 4. 5. 6. 7. 8. (3) Adn~Ln (9 thru 13), . 10. d '1~) / 12. 13. (4) Casg -(14 thru 22) (5) BOPE (23 thru 28) Company ....... YES the permit fee attached .......................................... Lease & Well No. NO , J Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-daywait ...................... 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 ......................... 14. 15. 16. 17. 18. 19 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect freshwater 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 collapsel ~i~ ~'~~ 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 ............................ (6) OTHER For 29. 30. 31. 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 ~_~OOO psig .. .~ Does the choke manifold comply w/AP1 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 ............................................. Ge9~: Engineering ~~ LCS B~d JAL ~ ' rev: 07/18/86 6. 011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ///6 o ON/OFF SHORE Additional Pumnarks: 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. L~'S TAm~ V~.T!=TCATT. ON L~$TZNG I Z -~IOmO.~ZZZ I Z I rn :x~ CZ C') ~ Z t m I ~ ~4Z--t~.~~, I 7~ I C t -4 I ~ i IC.] I rn I C I ! -4 I ¢"~ t--4 ifT; lLT> -1>- o C..J '--I {J -~ ~ r-- r- -u -',,'- .-X'- .;? II II 11 II ii I:.T~~ r-- (::)c: ~'~/o t'"' ~ (':) (./) -,','- ..r.:. ~,'- r- ('J Z ,'. :) -,"c C -X- (") -.9- ~--~. -,", 2': .~; -,':- .;,,-. ]: -,': c: -;: ;2' r' --4 II1 %,,.- ¢,'- -'4- · · ~J I~[~ r- ]7 _-[ f-- i--t t,5 I I tM [x~ C~ C, '11 11 "11 ' il 11-11 '11 '11 '11 "~t C.J U [:j L:.t Cfi CLI LL) C:'* t.fl fL 3 £:) c,) OC~) () C.) c) (Y~ (.b <':) C ) cZ) ! i U'~ k~ ~,~ CJ'~ Z:~~:~ C~ I I Il · IIi t I I I · i [-..:, ~J'l C} -~1 kJ i ¢2) I1 '-II · 1 C) I I · ,D ,.t3 -Ti ~. ! t I 'o Z ]? C'~ ~ I I I () Z 'TI ;~ C-) t~ ! ~D U, (-) r~ I I I t Uigt UI~ UI ("~ ..'Z.) ~C, I--' I'"'-'4 Z:~. ;:'. G' ) F- 4 u[) ,JD I I I i ¢~ Z ~ F~ t I I i I g~gl gJ CDO0 C, I I I I ['...~ ~ Ix) t~ C~ CD, 0 I I t ! (-) ~5 ;,~ F~ (") >J 7.; F 1'--4 I [.~j U'i (5 I r! r' -11 .K~ C3 k ~ L:: .:&~ F 7< II -xD t-J2' t> r' £: .~) r~ I ,l) · I1 c) I ut H '"1t H-~ Z 111 ]~-~ I'ft Z Z ]~ ~ ~ rT~ F Ill ~ ~ ITt ~ 0 ~ ¢~.~ I · <2 · i11 G; -1'1