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185-101
Imagi~Project Well History File' Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _/ ~_- ~ _~//_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [3 Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: .~ [] Other: .... OVERSIZED (Non-Scannable) · ~ : Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: Is/ Scanning Preparation ~ x 30 = '~O + // = TOTALPAGES ?/- BY: ~ BREN VINCENT SHERYL MARIA LOWELL DATE: //," g.j~,- ~O'~/s/~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INOIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NUMBER IN SCANNING PREPARATION: %'~ YES NO PAGE COUNT MATCHES ~BREN VINCENT SHERYL MARA LOWELL DATE:/I,~.~ /S'~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERLY BREN VINC~ARIA LOWELL RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd STATE OF ALASKA AUG 1 4 201'3 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ • 'lb.Well Class: I 20AAC 25.105 20AAC 25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 20,2013 • 185-101 /313-153 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 25, 1985 ' 50-029-21356-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1119'FNL,889'FEL,Sec. 14,T12N, R9E, UM July 1, 1985 3C-10 • Top of Productive Horizon: 8.KB(ft above MSL): 82'RKB • 15.Field/Pool(s): 1236'FSL, 1528'FEL,Sec. 12,T12N,R9E,UM ' GL(ft above MSL): 35'AMSL Kuparuk River Field • Total Depth: 9.Plug Back Depth(MD+TVD): 1324'FSL, 1204'FEL,Sec. 12,T12N, R9E,UM 8873'MD/6662'TVD Kupuruk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-528685 y- 5995314 Zone-4 8980'MD/6739'TVD • ' ADL 25629 TPI: x-533314 y- 5997688 Zone-4• 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-533638 y- 5997777 Zone-4 SSSV @ 1977'MD/1812'TVD 2562 18.Directional Survey: Yes ❑ No 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) 1698'MD/1607'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 caliper 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# 1440 35' 116' 35' 116' 24" 213 sx CS II 9.625" 36# _ J-55 35' 4819' 35' 3729' 12.25" 1440 sx AS III,320 sx CI G 7" 26# J-55 39' 8974' 39' 6734' 8.5" 375 sx Class G 4.5" 12.6# L-80 8158' 8873' 6145' 6662' 6.276" 102 sx Class G 24.Open to production or injection? Yes ❑ No Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8202' 8158'MD/6145'TVD 8539'-8551'MD 6419'-6428'TVD 8697'-8742;MD 6534'-6566'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. , 8764'-8789'MD 6582'-6602'TVD Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I'I SCANNED APR 2 8 2014 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO -..,_..„ . Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 1 NONE RBDMS AUG 15 206 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE f1(,B `1/2��Y Submit original only YL F 1/z1 )4 9//rA 4 29. GEOLOGIC MARKERS(List all formations and ma, encountered): 30. FORMATION TESTS NAME MD TVD Well tested? j Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1698' 1607' needed,and submit detailed test information per 20 AAC 25.071. Top Upper Kuparuk Sand 8491' 6383' Base Upper Kuparuk Sand 8548' 6424' Top Lower Kuparuk Sand 8679' 6519' Base Lower Kuparuk Sand 8846' 6641' N/A Formation at total depth: Kuparuk 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32. I hereby certify that the foregoing is true an rrect to the best of my knowledge. Contact: Haibin Guo @ 265-1487 Email: Haibin.GuoCcr�conocophillips.com • Printed Name G.L.Alvord Title: Alaska Drilling Manager III Signature a,/ Phone 265-6120 Date 6 (4(2 013 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 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 KUP 3C-10 ConocoPhiilips 03 Well Attributes 'Max Angle &MDD Act TD OMB) Ino. Wellborn API/UW1 (Field Name Well Status Incl(') conom6Nlups 500292135600 IKUPARUK RIVER UNIT PROD 50.10 I 3,300.00 8,980.0 "" Comment 61 (ppm) Data Annotation End Date KB-Grd(ft) Fig Release Date ••• Wed ConllC'-3Q10 YJ620t37.38'IAMwSSSV:TRDP I_-_2$100 5/14/2012 LastWO:...I._ 5/102013 3459 7/3/1985 Smmlc-riaud_ Annotation DepthMKS) End' DaM�Annotation .._. -. .LaI Last Mod.. End Dato�.. . Last Tag:RKB 8.873.0 5/15/2013 iReV Reason:WORKOVER osbort 5!30/2013 HANGER,24 t 1 Casing Strings Casing Description 'String 0... Sting ID_.Top(ftl(8) Set Depth(f_.Set Depth(TVD)...String Wt..String...String Top Thrd ' ..._.-...-._ .:..=._,..,-......,. ,,,CONDUCTOR 15.062 35.0 11690 _ String Top Thrd SURFACE 9 5/8 8.921 34.9 4,819.4 3,729.1 3600 J-55 BTC Casing Description String 0... String IO_.Top(ORB) Set Dopth(f_.Sot Depth(TVD)...String Wt_String...String Top Thrd I PRODUCTION 7 6.276 38.7 8.972.2 6,734.3 26.00 J-55 BTC -- Casillg Description String 0... String ID_.Top(ttKB) Set Depth(L..Set Depth(TVD)...String WC_String...String Top Thrd SCAB LINER 412 3.958 8,157.7 8,873.0 6,661.9 12.60 L-80 IBTM Liner Details CONDUCTOR, Top Depth I f 35118 (TVD) lop Incl Nomi_. SAFETY vLV, j Top(ft05) (BOB) ('I item Description Comment I ID(in) 1,977 L o] 8,157.7 6,144.7 45.341 PACKER BAKER C-2 ZXP LINER TOP PACKER 4.970 8,176.2 6,157.6 45.05 HANGER BAKER FLEX LOCK HANGER 4.853 8,186.0 6,164.5 44.90 SBE BAKER 80-40 L-80(4.00 ID)SEAL BORE EXTENSION 4.000 Tubing Strings GAS LIFT, Tubing Description String 0... String ID.-Top(108) Set Depth(f_.Set Depth(TVD)...(String Wt..String...String Top Thrd 3.138 TUBING WO 312 2.992 24.2 8,201.8 6,176.1 I 9.30 L-80 8 rd EVE-Mod Completion Details Top Depth SS (ND) Top Incl INoml...' I Top(1tKB) inn) (') (tam Description Comment 1 ID(in) 24.2 24.2 0.34 HANGER TUBING HANGER 2.992 1,976.9 1,811.8 46.181SAFETY VLV CAMCO TRMAXX-CMT-SR-5 SCSSV i 2.812 SURFACE. J 8,115.0 6,114.7 46.01 NIPPLE HES 7C LANDING NIPPLE i 2.813 35-:.,619 8,163.9 6,149.0 45.25 LOCATOR BAKER SEAL LOCATOR 2.990 [ 8,165.1 6,149.9 45.23 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBY 2.990 G . As 170 1 5.170 Perforations&Slots Shot =II Top(ND) Elm(TVD) Dens Top(ftK6)Bim(ROB) IftKB) MKS) Zone Dato Wt.- Type Comment I I♦ 8,539.0 8,551.0 6,419.1 6,427.7 C-1,UNIT B. 7/29/1985 12.0 IPERF 120 deg.phasing;512"Scalloped HJ GAS LIR, 3C-10 6.520 8,697,0 8.742.0 6,533.6 6,566.4 A-4.A-3,3C-10 7/29/1985 4.0 IPERF 90deg phasing;4"Carrier Gun HJ II IIII g: 8,764.0 8,790.0 6.582.4 6,601.4 A-2,3G10 7/29/1985 4.0 IPERF 90 deg.phasing:d"Carrier Gun FIJI! --- Notes:General&Safety End Data Annotation GAS UFT. 7/15/2010 NOTE:View Schematic WI Alaska Schematic9.0 7,500 GAS UFT, 8.055 T MI i NIPS 6.1:5 LOCATOR, 6.164 SEAL ASSY. 1r 1 8165 IPEP,F, 6,539-8.551 I = PERF, 8,6572..90_-- 1 I PEW, Mandrel Details 8764-87990 - Top Depth TopPort _ (TVD) Inc( I I 00( Valve Latch I Size TRO Run 5 N...Top MKS) (fd(B) (') I Make Model lin) Sera Typo Typo 1 (in) (psi) Run Date Com_ 1 3,137.6 2.599.3 49.21 Cameo MMG 1 12 GAS LIFT DMY RK 0.000 0.0 5/29/2013 2 5,169.9 3,995.5 39.45 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.0001 O.Oi5/192013 3 6.520.1 5,007.5 42.71 Cameo MMG 1 1 1/2 GAS LIFT DMY IRK 0.000 0.05/19/2013 4 7,499.9 5,594.7 46.45 Cameo MMG 1 1 1/2 GAS UFT DMY IRK '0.000 0.015/192013 L 5 8,054.9 6,073.5 46.96 Camco MMG 1 12 GAS LIFT DMY IRK 0.000 0.0 5/19/2013 SCAB LINER. e,lsea.ea PRODUCTION. 392.972 TO,0.980 Alk 3C-10 Pre Rig Well Work Summary DATE SUMMARY 4/1/2013 (PRE RWO): MITOA- PASSED. FUNCTION TEST LDS-ALL FUNCTIONED PROPERLY. 4/13/2013 CMIT TXIA TO 3000 ( PASS ); SET CATCHER @ 7564' SLM. PULLED GLV'S @ 7490', 6618', 5406', 3804' & 1997' RKB; SET DV's @ 7490', 6618' RKB. IN PROGRESS. 4/15/2013 SET DV's @ 1997', 3804' &5406' RKB; PULLED CATCHER. IN PROGRESS. 4/16/2013 PULLED CATCHER @ 8420' SLM. PULLED WRP @ 8423' RKB (ELEMENT LEFT DOWNHOLE). PULLED DV @ 8431' RKB. MEASURED BHP @ 8431' RKB: 3169 PSI. IN PROGRESS. 4/17/2013 BRUSH'N FLUSHED SSSV @ 1806' RKB &ATTEMPTED FUNCTION TEST. FLOWTUBE APPARENTLY STUCK IN OPEN POSITION. SET CATCHER. LOCK OUT FLAPPER ONLY ON TRDP-1A-SSA @ 1805' RKB. PULLED CATCHER. DRIFT TO 8547' RKB WITH 10'x 2" BAILER. COMPLETE. 4/22/2013 CUT TUBING WITH 1.69" RCT WITH CUT AT 8360' CCL TO CUT 9'CCL STOP AT 8351'. SHOOT STRING SHOT BEFORE CUT WITH MID SHOT AT 8360' CCL TO MID SHOT 5' CCL STOP AT 8355'. JOB COMPLETE ConocoPhiIIips Time Log & Summary We!Anew Web Reporting Report Well Name: 3C-10 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 5/10/2013 6:00:00 PM Rig Release: 5/20/2013 5:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/10/2013 24 hr Summary R/D on 3C-09.Move rig over well 3C-10. R/U and accept rig @ 18:00 hrs. R/U to kill well. Pull BPV and begin killing well w/10.0 ppg NaBr/NaCI brine. 06:00 07:45 1.75 MIRU MOVE RURD P PJSM, blow down steam,disconnect water,air and steam lines. Remove berms around rig modules and prep pipe shed to move. 07:45 09:00 1.25 MIRU MOVE MOB P Spot rock washer and pipsheds at the corner of pad. Pull power pack away from rig and move to end of pad. 09:00 11:15 2.25 MIRU MOVE MOB P Pull Sub off 3C-09 and crab over to 3C-10.Spot rig over well 3C-10. 11:15 12:00 0.75 MIRU MOVE MOB P Lay matting boards for rig modules. 12:00 14:15 2.25 MIRU MOVE MOB P PJSM, Spot pits, pumps, motors and boiler modules. 14:15 17:00 2.75 MIRU MOVE RURD P R/U berms and plug in modules. Hook up inner connects and test gas monitoring equipment. Hook up and test all communication equipment. Test run conveyors and E-stops. R/U cellar alarm and ground strap. 17:00 18:00 1.00 MIRU MOVE RURD P Work on rig acceptance checklist. Rig accepted @ 18:00 hrs. 18:00 21:00 3.00 MIRU WHDBO RURD P PJSM, R/U circulating lines in cellar. CIO valves and seats on MP#2 and clean out suction manifold. Prep cellar for scaffolding crew and tighten drag chain. 21:00 21:45 0.75 MIRU WHDBO RURD P Rig up scaffolding in cellar. 21:45 23:15 1.50 MIRU WHDBO RURD P Rig up hard line to tiger tank. SIMOPS, pull BPV. Pressure on well, IA=800 PSI and Tubing=900 PSI. 23:15 00:00 0.75 MIRU WHDBO RURD P Rig up circulating lines on tree and blow air though lines. 05/11/2013 Kill well,displaced out diesel w/10.0 ppg brine, lost 75 bbls of fluid while displacing. Circualted out a small amount of gas thought gas buster, OWFF.Set BPV and N/D tree. N/U BOPE and test to 250/4000 PSI. AOGCC rep Bob Noble waived witness of test. 00:00 00:30 0.50 MIRU WHDBO PRTS P PJSM,Test mud pump, choke skid and hard lines to 3500 PSI. Page 1 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 05:00 4.50 MIRU WHDBO KLWL P Kill well.pressure on IA=800 PSI, pressure on tubing=900 PSI. Pump 10.0 ppg brine down tubing taking returns to tiger tank. ICP=1100 PSI, FCP-350 PSI. Kill well @ 2 BPM. Pump 385 bbls of 10.0 ppg brine and shut down with 10.0 ppg brine to surface. Monitor well, observed gas on surface in IA, pump additional 36 bbls @ 2 BPM=350 PSI. Shut down,observed small amount of gas at surface. Lost 75 bbls of 10.0 ppg brine to hole. 05:00 07:15 2.25 MIRU WHDBO CIRC P Rig up to circulate well though gas buster taking returns to mud pits. Circulate gas out of well @ 3 BPM= 680 PSI, lost 50 bbls of hole. Losses while pump—20 BPH. 07:15 09:00 1.75 MIRU WHDBOOWFF P Monitor well,slight flow after 1 hour. Shut in well w/pressure gauge on IA and tubing.observed 2 PSI on IA. Bleed off pressure,observed a small amount of gas. Re-check pressures, O PSI on IA and tubing.SIMOPS, bleed off 1000 PSI on OA. Open well, well on Vac. 09:00 10:00 1.00 MIRU WHDBO SEQP P Blow down circulating lines and rig down.Set BPV and test to 500 PSI. SIMOPS, R/D scaffolding. 10:00 15:00 5.00 MIRU WHDBO NUND P PJSM, N/D tree and adaptor flange. Inspect threads on hanger. Make up plug off tool in BPV, making it a TWC. Nipple up 7-1/16"'X 13-5/8" adapter spool. N/U BOPE, install turnbuckles and riser. 15:00 15:15 0.25 MIRU WHDBO SFTY P Hold PJSM on C/O to rams. Discussed using proper hand placement when removing rams from rack and opening doors. Filled out HRW and HRC. 15:15 17:30 2.25 MIRU WHDBO NUND P Change out top rams f/3'X 6"VBR to 2-7/8"X 5"VBR. 17:30 18:00 0.50 MIRU WHDBO RURD P PJSM, R/U to test BOPE. 18:00 18:15 0.25 MIRU WHDBO SFTY P Hold PJSM on testing BOPE. Discussed working around high pressure testing and keeping non essential personal clean of the area. Page 2 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 00:00 5.75 MIRU WHDBO BOPE P Test BOPE to 250/4000 PSI w/ 2-7/8"and 4"test joints for 5 minutes each.Test annular t/250/3500 PSI w/2-7/8"and 4"test joints. Test#1: Top pipe rams, CV 1, 12,13, 14 and manual kill. Test#2: Upper pipe rams, HCR kill,CV 9 and 11. Test #3: Lower!BOP, CV 5,8, and 10. Test#4: Dart valve, CV 4,6 and 7. Test#5: Floor valve and CV 2. Test #6: HCR choke and 4"kill line demco.(demco valve failed,C/O seat) Test#7: Manual choke and HRC kill. Test#8:Annular preventer and re-test HCR choke. Test#9: Lower pipe rams. Test#10: Blind rams and CV 3.Accumulator test: system pressure=2950 PSI, pressure after closing= 1750 PSI, 200 PSI attained after 49 seconds, full pressure attained after 196 seconds. Nitrogen bottle avg.=2075 PSI.AOGCC rep Bob Noble waived witness of the test. 05/12/2013 Completed BOP test t/250/4000 PSI.AOGCC rep Bob Noble waived witness. Observed gas/crude behind BPV, no pressure on IA. Pull hanger and closed rams,circulate out gas/crude through open choke. Squeeze HiVis pill into formation.OWFF and POOH L/D 2-7/8"tubing. 00:00 04:15 4.25 MIRU WHDBO BOPE P Cont.to test BOPE to 250/4000 PSI for 5 minutes. Install 2-7/8"test joint and test lower rams,top rams and re-test 4"kill line demco to 250/4000 PSI.Test annular to 250/3500 PSI with 2-7/8"test joint.AOGCC rep Bob Noble waived witness of the test. 04:15 04:45 0.50 MIRU WHDBO RURD P RID test equipment and blow down lines. 04:45 06:00 1.25 MIRU WHDBO SEQP P Suck out stack and attempt to pull BPV.Observed gas and crude under the BPV.SIMOPS,fill IA with 8 bbls of 10.0 ppg brine. 06:00 07:00 1.00 8,351 SURPRI RPCOM THGR P M/U landing joint and screw into top drive. BOLD's and pull hanger, hanger pulled @ 80K, 5K over pull. P/U=75K,5/0=60K. 07:00 10:45 3.75 8,351 8,351 SURPRI RPCOM KLWL P Close top rams and pump down tubing thought BPV taking returns out the gas buster. Pump @ 2 BPM=260 PSI, pumped 340 bbls of 10.0 ppg brine followed by 20 bbl HiVis 10.2 ppg brine pill. Chase pill with 28 bbls,closed choke and squeezed 20 bbls into formation @ 1 BPM=350 PSI. 10:45 13:00 2.25 8,351 8,351 SURPRI RPCOM CIRC P Circulate with open choke @ 2 BPM=250 PSI Page 3 of 12 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 13:00 13:30 0.50 8,351 8,325 SURPRI RPCOM PULD P Pull hanger to floor. L/D landing joint and remove BPV. 13:30 14:00 0.50 8,325 8,325 SURPRI RPCOM OWFF P Monitor well,static. 14:00 15:00 1.00 8,325 8,325 SURPRI RPCOM CIRC P R/U and reverse circulate two tubing volumes. 15:00 15:15 0.25 8,325 8,325 SURPRI RPCOM OWFF P Monitor well, static. 15:15 17:30 2.25 8,325 6,650 SURPRI RPCOM PULL P PJSM. POOH laying down 2-7/8"w/ control line. Recovered 32 SS bands 17:30 18:15 0.75 6,650 6,650 SURPRI RPCOM RURD P R/D control line tools and L/D spooler unit. 18:15 00:00 5.75 6,650 521 SURPRI RPCOM PULL P Cont laying down 2-7/8"tubing. Laid down 2 pups, SSSV, 10 GLM's and 255 joints.Actual displacement= 67.32 bbls, Calculated displacement= 17 bbls. Lost a total of 179 bbls of 10.0 ppg brine last 24 hours. 05/13/2013 Cont L/D 2/8"tubing. M/U BHA#1,overshot and RIH. Engage fish @ 8348'.Jar fish free and CBU. POOH w/ 5K drag. L/D fish, recovered OEJ&packer assy. M/U BHA#2, packer mill and RIH to mill DB packer. 00:00 00:15 0.25 521 0 SURPRI RPCOM PULL P PJSM, Cont to L/D 2-7/8"tubing. Actual displacement=3 bbls, Calculated displacement=1 bbl. Laid down a total 2 pups, SSSV, 11 GLM's and 269 joints and 1 cut joint. 00:15 02:15 2.00 0 0 SURPRI RPCOM RURD P R/D tubing equipment,clean and clear rig floor. Strap all 2-7/8"tubing in pipe shed and empty tubing out of shed. Load shed with drill collars and tally. P/U Baker tools from beaver slide. 02:15 04:00 1.75 0 304 SURPRI RPCOM PULD P PJSM, Set wear ring,6.25"ID. M/U BHA#1, overshot as per Baker rep. 04:00 10:45 6.75 304 8,332 SURPRI RPCOM TRIP P RIH picking up 4"drill pipe to 8332'. P/U= 150K, S/O= 100K. P/U 10'pup and single.Actual displacement= 10.1 bbls, Calculated displacement= 51.5 bbls. 10:45 11:00 0.25 8,332 8,348 SURPRI RPCOM FISH P Engage fish @ 8348'. P/U to 180K, 30K over pull and fire jars. P/U to 200K, 50K over pull and fire jars twice,fish pulled free. P/U to 8328' w/5K drag 11:00 12:45 1.75 8,323 8,323 SURPRI RPCOM CIRC P CBU @ 2 BPM=200 PSI staging pump up to 4BPM=300 PSI. Observed gas/crude at bottoms up. Losses while pumping—15 BPH 12:45 14:30 1.75 8,323 8,323 SURPRI RPCOM OWFF P Monitor well to trip tank.Well flowed slighty then began to take fluid. Flowed back 6 bbls into trip tank. 14:30 17:45 3.25 8,323 320 SURPRI RPCOM TRIP P PJSM, L/D single and 10'pup. POOH to 320'.Actual displacement= 64.05 bbls, Calculated displacement=51.5 bbls. Page 4 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 20:30 2.75 320 0 SURPRI RPCOM PULD P Recovered OEJ and packer assy. PJSM, L/D BHA and fish as per Baker rep. Laid down cut joint,OEJ, slick stick, 5 joints,3 GLM and 2 pups.213.75'of fish. Bottom GLM was heavily corroded. 20:30 21:30 1.00 0 0 SURPRI RPCOM PULD P Clean and clear floor. L/D Baker tools. 21:30 22:00 0.50 0 0 SURPRI RPCOM PULD P PJSM, P/U Baker tools from beaver slide. 22:00 23:00 1.00 0 316 SURPRI RPCOM PULD P M/U BHA#2 packer mill as per Baker rep. 23:00 00:00 1.00 316 632 SURPRI RPCOM PULD P RIH picking up pipe f/312'to 632'. P/U=50K, S/O=49K.Actual displacement=2.72 bbls, Calculated displacement=5.61 bbls. Lost 109 bbls to formation last 24 hours,508 bbls total. 05/14/2013 Continue P/U pipe and RIH with BHA#2, mill DB packer and push to 8787'MD, no further. POOH and P/U spear assy,engage fish and jar/pull free. 00:00 04:00 4.00 632 8,523 SURPRI RPCOM TRIP P PJSM-Continue single in hole f 632' MD t/1261'MD. Continue RIH f/ Derrick t/8523'MD, obtain SPR's and milling parameters.Calc disp= 52.5 bbl,Actual=27.8 bbl. P/U= 155k,S/O= 125k 04:00 08:15 4.25 8,523 8,700 SURPRI RPCOM MILL P Wash t/8584'MD,3 bpm @ 275 psi. Mill Packer f/8584'MD t/8587'4 bpm,80 rpm,7-10k TQ. Push Packer to 8700'MD. 08:15 09:15 1.00 8,700 8,700 SURPRI RPCOM CIRC P Circ out gas @ 8700'MD,continue CBU @ 4 bpm @ 500 psi, S/O 125k 09:15 10:00 0.75 8,700 8,787 SURPRI RPCOM FISH P Monitor well, push packer t/8787' MD 3 bpm @ 250 psi, 30 rpm @ 4k TQ. Set 20k WOB with and W/O rotary,5 attempts, push no further. 10:00 11:00 1.00 8,787 8,713 SURPRI RPCOM CIRC P CBU @ 8787'MD,work pipe w/ Rotary 2'above packer, clean up top of packer @ 4 bpm-500 psi. ROT WT=125k,80 rpm, 5k TQ. Circulate out little gas on B/U total of 2500 stks. 11:00 12:00 1.00 8,713 8,713 SURPRI RPCOM OWFF P Monitor well @ 8713'MD, P/U=150k, S/O= 110k, Flowing back slightly. 12:00 12:30 0.50 8,713 8,713 SURPRI RPCOM OWFF P PJSM and continue monitoring well, flowed back 14 bbl total and tapered to zero. 12:30 16:00 3.50 8,713 340 SURPRI RPCOM TRIP P POOH f/8713'MD t/340'MD (Monitor well at collars static)Calc fill=53.51,Actual fill=66.41 bbl. 16:00 17:30 1.50 340 0 SURPRI RPCOM PULD P L/D BHA,clean out junk baskets, L/D tools. 17:30 18:00 0.50 0 0 SURPRI RPCOM PULD P Clean and clear rig floor, P/U tools from beaver slide. 18:00 19:00 1.00 0 304 SURPRI RPCOM PULD P PJSM and M/U BHA#3, Baker Spear assy. Page 5 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:00 3.00 304 8,701 SURPRI RPCOM TRIP P RIH f/304'MD t/8701'MD. Calc disp=53.18 bbl,Actual disp 35.7 bbl. 22:00 22:45 0.75 8,701 8,786 SURPRI RPCOM JAR P P/U single from pipe shed, latch up working stand. RIH f/8701'MD t/ 8786'MD and tag. Establish parameters, P/U=150k,S/O=110k, 1.5 bpm @350 psi.Tag up @ 8786' MD, saw 50 psi increase.Set down 10k, S/D pumps. P/U 10k over, no-go. Set down 10k. P/U 25k over, no go.Cock jars and pull 50k over jar 3X @ 50k over,stage up to 75k over, jar 2X. P/U to 275k(125K over) pulled fish free. 22:45 00:00 1.25 8,786 8,758 SURPRI RPCOM CIRC 'P CBU @ 3 bpm, 1200 psi. Lost 131 bbl to the formation today,639 bbl cummulative total for well. 05/15/2013 POOH with fish, 100%recovery. M/U and RIH w/BHA#4 cleanout assy with string mills and magnets. Ream across perfs and cleanout to 8873'MD. Circ well clean and POOH. 00:00 01:00 1.00 8,758 8,701 SURPRI RPCOM CIRC P Continue CBU X 2 @ 8758'MD,3 bpm @ 1200 psi 01:00 01:45 0.75 8,701 8,701 SURPRI RPCOM OWFF P Monitor well @ 8701'MD, Flow back 3.6 bbl then slight drop. 01:45 07:00 5.25 8,701 304 SURPRI RPCOM TRIP P L/D Single, POOH t/304'MD, OWFF @ Drill collars static-slight drop. Cacl Fill=53.3,Actual Fill= 75.8 bbl 07:00 07:45 0.75 304 0 SURPRI RPCOM PULD P C/O elevators, rack back BHA, L/D fish-Packer and tailpipe assembly. 07:45 08:45 1.00 0 0 SURPRI RPCOM RURD P Clean and clear rig floor, Pick BHA to rig floor. 08:45 10:45 2.00 0 347 SURPRI WELLPF PULD P PJSM and M/U BHA#4 t/347'MD. C/O elevators. 10:45 12:00 1.25 347 1,952 SURPRI WELLPF TRIP P RIH with cleanout assy BHA#4 t/1952'MD, P/U 50k,S/0 50k.Calc Disp=15.4 bbl,Actual Disp=11.4 bbl. 12:00 12:30 0.50 1,952 2,727 SURPRI WELLPF TRIP P PJSM,continue RIH f/1952'MD t/ 2727'MD. 12:30 13:00 0.50 2,727 2,727 SURPRI WELLPF SVRG P Shut down, lubricate rig. 13:00 13:15 0.25 2,727 2,727 SURPRI WELLPF SFTY P PJSM, Cut and slip drilling line. 13:15 14:45 1.50 2,727 2,727 SURPRI WELLPF SLPC P Hang Blocks, slip and cut 65'drilling line. 14:45 17:30 2.75 2,727 8,460 SURPRI WELLPF TRIP P Continue RIH f/2727'MD t/8460' MD. 17:30 20:00 2.50 8,460 8,873 SURPRI WELLPF WASH P Wash and ream f/8460'MD t/8873' MD.60 rpm,4k TQ, 5 bpm @ 700 psi 42%flow. P/U=150k, S/0= 106k. Wash and polished upper, middle and lower perfs with string mills 3 x until no indications on TQ and drag. Washed down to bottom and tagged firm at 8873'.Set down 2k WOM, mnaintained 6k TQ for 5 min. Marked pipe no-go. Page 6 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:30 2.50 8,873 8,870 SURPRI WELLPF CIRC P Rotate 60 rpm and reciprocate string 30', pump hi vis brine sweep down @ 5 bpm-700 psi, increase to 10 bpm-2350 psi as sweep rounded bit to surface.Saw significant sand returns at shakers with small metal shavings on magnets. Decide to pump second sweep to clean well. Mix and pump 3 ppb Flowzan/Brine sweep,circulate clean. Pumped total 6 bottoms up to clean the well. 22:30 00:00 1.50 8,870 8,870 SURPRI WELLPF OWFF P Monitor well,flowed back 10.3 bbl then started dropping. Lost 149 bbl to formation today, 788 bbl cumulative total loss for well. 05/16/2013 POOH and L/D BHA#4. Run 40 arm caliper w/eline. R/U and start running 4.5"liner. 00:00 01:00 1.00 8,870 7,830 SURPRI WELLPF TRIP P PJSM-POOH f/8870'MD U 7830' MD.Calc Fi11=6.4 bbl,Actual fill= 12.4 bbl. 01:00 01:45 0.75 7,830 7,830 SURPRI WELLPFSVRG P Service/lube rig draworks and top drive. C/O link tilt fitting. 01:45 05:00 3.25 7,830 347 SURPRI WELLPF TRIP P Continue POOH f/7830'U 347'MD C/O elevators and monitor well at collars(dropping). Calc fill=48.6 bbl, Actual fill=74.1 bbl. 05:00 06:30 1.50 347 0 SURPRI WELLPF,PULD P L/D BHA#4, L/D 4 3/4"collars. Boot baskets clean,magnets covered with metal pieces and shavings. 06:30 07:30 1.00 0 0 SURPRI WELLPF RURD P Clean and clear rig floor, lower Baker tools from floor. 07:30 10:15 2.75 0 0 SURPRI EVALWE RURD P PJSM-N/D riser and boot flange, N/U wireline shooting flange 10:15 12:00 1.75 0 34 SURPRI EVALWE PULD P PJSM and R/U wireline, M/U 40 arm caliper. 12:00 17:00 5.00 34 8,882 SURPRI EVALWE ELOG P RIH w/wireline HES 40 arm caliper. RIH U 8882'MD, logged out f/8850' to surface.Send data to engineer. 17:00 17:30 0.50 8,882 0 SURPRI EVALWE RURD P PJSM and rig down wireline. 17:30 19:30 2.00 0 0 SURPRI RPCOM RURD P PJSM and N/D shooting flange, N/U riser and boot flange. 19:30 19:45 0.25 0 0 SURPRI RPCOM SFTY P PJSM to R/U and run 4.5"liner on drill pipe. 19:45 21:45 2.00 0 0 SURPRI RPCOM RURD P R/U to run liner 21:45 00:00 2.25 0 630 SURPRI RPCOM RUNL P RIH w/4.5"Liner,test floats(good) Baker Lock everything below landing collar. Install bow spring centralizers every full jt on casing collars, 1 floater below landing jt.Total losses to formation for today=85 bbl, Cumulative loss for well=873 bbl 05/17/2013 RIH w/4.5"scab liner,filling and circulating every 20 stands.Correlate w/eline and cement.Set liner hanger and liner top packer. 00:00 00:45 0.75 630 715 SURPRI RPCOM RUNL P PJSM-Continue RIH w/4.5"liner, Calc disp=2.9 bbp,Actual disp=3.5 bbl. Page 7 of 12 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 02:00 1.25 715 715 SURPRI RPCOM RUNL P M/U SBE, hanger and space out pups for running tool.When lowering/working wiper plug into XO sub/liner pup joint,wiper plug took a little weight, P/U, plug sheared off of running tool. Pull SBE to rig floor, found wiper plug lodged in XO. Removed plug and found it to be damaged. New wiper plug en-route. 02:00 03:00 1.00 715 715 SURPRI RPCOM RUNL T M/U XO's to SBE, RIH to wait on plug. Plug was damaged due shearing w/o the pump down plug being engaged. 03:00 04:00 1.00 715 715 SURPRI RPCOM SVRG T Wait on Liner Wiper Plug from Deadhorse.Work on MP2's, Monitor well on TT, losses @ 5 bph. 04:00 05:00 1.00 715 721 SURPRI RPCOM RUNL P M/U hanger, liner plug w/extensions to SBE 05:00 06:00 1.00 721 816 SURPRI RPCOM RUNL P M/U to stand 4"DPU 754'MD, circulate 1 liner volume @ 4bpm, 100 psi. 06:00 12:00 6.00 816 7,329 SURPRI RPCOM RUNL P M/U marker joint,4.34'pup and resume in hole on 4"DP. Run in hole slowly,filling and circulating out gas @ 1577', 3652',7329'MD. Calc disp=46.4 bbl,Actual disp=8.6 bbl. 12:00 12:30 0.50 7,329 7,329 SURPRI RPCOM CIRC P Continue circulating @ 7329'MD,3 bpm, 175 psi. 12:30 13:30 1.00 7,329 8,840 SURPRI RPCOM RUNL P RIH t/8840'MD, P/U=150k, S/0=90k. P/U single and 10'pup U tag bottom @ 8876'MD. 13:30 15:00 1.50 8,840 8,767 SURPRI RPCOM CIRC P CBU @ 8767'MD,3 bpm,220 psi. 15:00 16:15 1.25 8,767 8,880 SURPRI RPCOM RURD P PJSM and R/U Eline 16:15 17:45 1.50 8,880 8,880 SURPRI EVALWE ELOG P Run GR-Correlation log.Correlated HES 40 Arm caliper log w/marker joint in drill pipe. Pipe needs to move up 6.5 feet for placement of KO joint. 17:45 18:30 0.75 8,880 8,880 SURPRI RPCOM RURD P PJSM and R/D Eline 18:30 19:15 0.75 8,880 8,873 SURPRI RPCOM RURD P PJSM-Pull up 6.5',space out for liner packer setting-mark pipe, R/U cement head. 19:15 21:15 2.00 8,873 8,873 SURPRI CEMEN-CIRCP Circulate at 3 bpm, 300 psi, 32% Flow. R/U to cement liner. Page 8 of 12 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 21:15 22:00 0.75 8,873 8,873 SURPRI CEMEN-CMNT P PJSM, Pump 5 bbl water, PT lines to 3500 psi. Pump 20 bbl 11.5 ppg Mud Push II,21.3 bbl Class G 15.8 ppg Cement chased with 1.5 bbl fresh water to floor. Displaced with 5 bbl water pumped by SLB followed by 90.53 bbl 10.0 ppg brine with rig pumps at 5 bpm-500 psi. Started reciprocating pipe 15'strokes at 400 stks pumped until last 5 bbl. Pumpdown plug hit wiper plug on time at 803 stks, bumped plug on time at 885 stks, pressured up to 3500 at 901 stks and held 5 min.CIP 22:07 hrs. Slack off plus 50K to confirm liner hanger set. 22:00 22:30 0.50 18,873 8,157 SURPRI CEMEN-PACK P R/D Cement lines, RH released 15 turns. 1000 psi and P/U to expose rotating dog sub,flushing liner top w/ pressure drop.Set down and stack 50k setting packer.Saw 24k liner top packer set. Rotate/pickup and restack 60k,verify packer setting x 2. Pump 1/2 bottom up at 7 bpm 1150 psi to clear cement from liner top. 22:30 23:00 0.50 8,157 8,157 SURPRI CEMEN-CIRCP CBU @ 7.5 bpm, 1100 psi,55% flow. Dumped Mud Push and verified some cement returns on shakers. 23:00 23:30 0.50 8,157 8,066 SURPRI CEMEN-RURD P R/D cement head and L/D single to get spacer pups out of SBR. 23:30 00:00 0.50 8,066 8,066 SURPRI CEMEN"CIRC P Circulate another bottom up @ 7.5 bpm, 900 psi,51%flow. P/U=135k, S/O=94k. Total formation losses today=149 bbl, Cummulative formation loss for well=1022 bbl. 05/18/2013 POOH w/liner running tool t/1322'. Set storm packer.CIO tubing spool and 7"packoff.Test VBR's, annular and choke flange. Retrieve storm packer and liner running tool. 00:00 00:30 0.50 8,066 8,066 SURPRI CEMEN-OWFF P PJSM-Monitor well, B/D Top Drive 00:30 00:45 0.25 8,066 7,547 SURPRI CEMEN-TRIP P PJSM-POOH t/7547'MD, P/U= 135k, SIO=94k. Calc fill=2.65 bbl, Actual=3.06 bbl 00:45 02:00 1.25 7,547 7,547 SURPRI CEMEN-PRTS P PJSM-R/U and test casing t/3000 psi, 30 min on chart. 02:00 02:30 0.50 7,547 7,547 SURPRI CEMEN-RURD P R/D test equipment and blow down circ lines. SIMOPS-Bleed off OA to tiger tank,25 psi. 02:30 05:00 2.50 7,547 1,322 SURPRI CEMEN-TRIP P POOH t/1322', 15k SIO weight.Calc fill=35.1 bbl,Actual=37.5 bbl. 05:00 07:00 2.00 1,322 1,402 SURPRI CEMEN'PRTS P PJSM and M/U Storm packer,set @ 80'element depth.Top of tool 67.57', test to 500 psi 5 minutes. 07:00 08:30 1.50 1,402 1,402 SURPRI CEMEN-NUND P PJSM and N/D BOPE and adapter flange. 08:30 10:00 1.50 1,402 1,402 SURPRI CEMEN-NUND P N/D tubing spool&7"packoff. Page 9 of 12 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 1,402 1,402 SURPRI CEMEN-THGR P N/U new Cameron tubing spool&7" packoff. 12:00 13:30 1.50 1,402 1,402 SURPRI CEMEN-THGR P PJSM and continue C/O tubing spool and 7"packoff.Test hanger void 250/3000 psi 30 min. (Witnessed) 13:30 15:30 2.00 1,402 1,402 SURPRI CEMEN-NUND P PJSM N/U drilling spool and BOPE 15:30 17:00 1.50 1,402 1,402 SURPRI CEMEN-SLPC P PJSM-Cut and slip 228'drilling line. 17:00 18:00 1.00 1,402 1,402 SURPRI CEMEN-SVRG P Lubricate rig 18:00 18:45 0.75 1,402 1,402 SURPRI CEMEN-BOPE P PJSM-R/U to test Variable bore rams, annular preventer and choke line flange. 18:45 20:15 1.50 1,402 1,402 SURPRI CEMEN'BOPE P Test upper and lower 2.875"x 5" VBR's t/250/4000 psi,test annular preventer to 250/3500 psi-5 min each charted. 20:15 21:30 1.25 1,402 1,402 SURPRI CEMEN-RURD P R/D test equipment, install 6.3125" ID wear ring. Break down cement head, pup and XO's. 21:30 22:45 1.25 1,402 1,322 SURPRI CEMEN-TRIP P PJSM-R/U and retrieve Storm Packer assy. Lay down same. 22:45 00:00 1.25 1,322 50 SURPRI CEMEN"TRIP P PJSM-POOH t/50'(Liner Running tool)Calc Fill=7.95 bbl,Actual Fill= 8.67 bbl. 05/19/2013 Run 3 1/2"completion,displace to 8.6 ppg NaCI brine w/1.4%Conqor 303A inhibitor. Land and PT Tbg/IA. Set TWC, N/D BOPE. 00:00 00:30 0.50 50 0 SURPRI CEMEN-TRIP P PJSM-POOH w/liner running tool and lay down same. 00:30 01:00 0.50 0 0 SURPRI RPCOM RURD P Clear rig floor and R/U casing equipment. 01:00 01:15 0.25 0 0 SURPRI RPCOM SEQP P Pull wear bushing. 01:15 01:45 0.50 0 0 SURPRI RPCOM RURD P R/U casing/tubing running equipment. 01:45 08:00 6.25 0 6,210 SURPRI RPCOM RCST P PJSM-RIH w/3.5"tubing completion per detail t/6210'MD. 08:00 09:30 1.50 6,210 6,210 SURPRI RPCOM SSSV P M/U SSSV,R/U SLB control line, test t/6000 psi f/10 min. 09:30 12:00 2.50 6,210 7,532 SURPRI RPCOM RCST P Cont'RIH w/3.5"completion per detail t/7532'MD.237 jts,44 SS bands.5/0=67k. Calc Disp=25.2 bbl,Actual Disp=25.2 bbl. 12:00 13:00 1.00 7,532 8,180 SURPRI RPCOM RCST P PJSM and continue RIH w/3 1/2" completion t/8180'MD. 13:00 14:00 1.00 8,209 8,202 SURPRI RPCOM RCST P M/U circ head and break circulation @ 1 bpm, 150 psi. RIH t/8193' observed pressure increase t/250 psi,continue RIH t/8209'tagged no-go. Pressure up to 500 psi, held for 5 min. L/D space out jts, P/U 4.19 and 2.36 pup jts and jt 258.M/U hanger.Total SS bands in the hole-66. Page 10 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 8,202 8,155 SURPRI RPCOM RCST P Terminate control line @ hanger,test t/6000 psi. R/D tubing running equipment. M/U circ head on landing jt, P/U out of SBE. 15:00 16:30 1.50 8,155 8,155 SURPRI RPCOM CIRC P PJSM and displace well to inhibited brine. 16:30 18:15 1.75 8,202 8,202 SURPRI RPCOM HOSO P Land hanger, RILDS,2 lock downs would not seat, BOLDS pull hanger to floor and inspect OK. RIH, land and RILDS OK. 18:15 19:45 1.50 8,202 0 SURPRI RPCOM SEQP P PJSM-Pressure test tubing t/3000 psi 30 min,bleed to 2000 psi and test IA to 3000 psi 30 min. Bleed off tubing and shear out SOV @ 3137'. Sheared out @ 2700 psi differential 300 tbg/3000 IA. Back out landing jt. 19:45 20:15 0.50 0 0 SURPRI RPCOM OWFF P Monitor well f/30 min-SIMOPS B/D choke and kill lines, R/D control line sheave. 20:15 21:30 1.25 0 0 SURPRI WHDBO SEQP P Rinse and vac out stack, Set TWC, test same f/IA,charted 30 min. BID abd R/D lines. 21:30 22:45 1.25 0 0 SURPRI WHDBO NUND P PJSM and N/D BOPE,SIMOPS L/D control line tools and equipment, clean pits, clear rig floor. Prep well head f/NU adapter and tree. 22:45 00:00 1.25 0 0 SURPRI WHDBO NUND P PJSM and N/U adapter flange. 05/20/2013 N/U Tree adapter and tree,test same. Open SOV and freeze protect well w/80 bbl diesel. Move camp to IL, lay down drill pipe and RDMO. Rig release at 17:00 hrs.Complete handover form and place on S drive. 00:00 01:00 1.00 0 0 SURPRI WHDBO SEQP P M/U tree adapter, pressure test void 250/5000 psi(witnessed good). Terminate SSSV control lines in adapter flange. 01:00 02:00 1.00 0 0 SURPRI WHDBO SEQP T N/U tree, adapter misaligned, rotated two hole,tree still misaligned, N/D tree. 02:00 03:00 1.00 0 0 SURPRI WHDBO SEQP T Drain and N/D tree adapter flange, rotate 165 degrees and M/U. Retest void 250/5000 psi(witnessed good) N/U and orient tree correctly. Contacted CPF-3 operator to verify alignment,declined input.Verified alignment with picture f/MIRU. 03:00 04:00 1.00 0 0 SURPRI WHDBO SEQP P R/U and pressure test tree and tubing hanger packoffs to 250/5000 psi-5 min on chart. 04:00 05:00 1.00 0 0 SURPRI WHDBO RURD P R/U t/pump diesel freeze protect, SLB opened SSSV @ 6000 psi on control line. Intsall equalization loop and pressure sensors. 05:00 05:15 0.25 0 0 SURPRI WHDBO SFTY P PJSM-Pumping diesel freeze protect w/Little Red Svcs. Page 11 of 12 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 08:15 3.00 0 0 SURPRI WHDBO FRZP P Pump 80 bbl diesel down IA,take returns out tubing to Rock Washer. Pump 1.1 bpm @ ICP 300 psi in LRS unit, 50 psi at well. FCP at well 200 psi. S/D LRS and open equalization valves f/1.5 hrs until no differential. 08:15 09:00 0.75 0 0 SURPRI WHDBO SEQP P Install BPV and test 5 min at 500 psi w/LRS. 09:00 09:45 0.75 0 0 SURPRI MOVE RURD P R/D Little Red Services and lines from/to tree. 09:45 16:45 7.00 0 0 SURPRI MOVE PULD P Lay down 4"drill pipe.SIMOPS-Rig down camp and move to 1F. 16:45 17:00 0.25 0 0 SURPRI MOVE DMOB P Rig release @ 17:00. Move modules to 1 F-16A.Complete handover form and place on S drive. Page 12 of 12 3C-10 Post Rig Well Work Summary . DATE SUMMARY 5/28/2013 RAN 2.62"x209" OAL DUMMY WHIPSTOCK DRIFT W/ 1 3/4" SAMPLE BAILER AND TAG @ 8789' SLM; SET SLIP STOP CATCHER @ 3230' SLM; PULLED SOV @ 3137' RKB. ( CLOSURE TEST ON SCSSSV VIA OPEN POCKET GOOD). IN PROGRESS. 5/29/2013 SET DV @ 3137' RKB; MITIA TO 2500 PSI ( PASS ); PULLED CATCHER @ 8784' SLM. READY FOR E- LINE. STATE OF ALASKA A. JKA OIL AND GAS CONSERVATION COMb,_ SIGN 44 I' APPLICATION FOR SUNDRY APPROVALS : -, . i ; 20 AAC 25.280 , 1. Type of Request: Abandon E Plug for Redrill N.' rforate New Pool j" Repair w ell W. Change Approved Program J Suspend r Plug Ferforations N / ( \1) Perforate [ — Pull Tubing 1✓ Tore Extension F Operational Shutdow n r Re -enter Susp. Well r Stimulate t Alter casing F Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fi . Exploratory r"" 185 -101 • 3. Address: Stratigraphic (- ` Service r 6. API Numbe P. O. Box 100360, Anchorage, Alaska 99510 50-029-21356-00 - 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No 1++ 3C - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25629 • Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MO (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8980 v 6740 ' 8891' 6674' . 8423' 8547 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 116' 116' SURFACE 4784 9.625 4819' 3729' PRODUCTION 8935 7 8974' 6736' Perforatior4 Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8539 -8551, 8697 -8742, 8764-8790 6419 -6428, 6534 -6566, 6582 -6601 2.875 J -55 8628 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1-SP PACKER MD 8395 TVD= 6314 PACKER - BAKER DB PERMANENT PACKER MD= 8600 TVD= 6463 ' SSSV - CAMCO TRDP -IA -SSA SSSV MD =1806 TVD =1691 - 12. Attachments: Description Summary of Proposal . ry 13. Well Class after proposed work: Detailed Operations Program [_u BOP Sketch [ Exploratory 1 — tratigraphic i Development Service I` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: ( ? 5/1/2013 Oil tV i f r WDSPL E Suspended f y l')J 16. Verbal Approval: Date: WINJ fl > �j IP GINJ f W AG E Abandoned E 0 Commission Representative: GSTOR E SPLUG 1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265 -1487 Email: Haibin.Guo(conocophillios.com Printed Name Haibin Guo Title: Sr. Drilling Engineer Signature l--la/ _)6,M „ - , Phone: 265 - 1487 Date r, .1, _ Z ? _ ? v / Commission Use Only Sundry Number 3_1 Ste+ Conditions of approval: Notify Commission so that a representative may witness s Plug Integrity r BOP Test Imo' Mechanical Integrity Test E Location Clearance I — Other: d3bp ti 7L ?Lc, ?5z O ps i FiriDMS APR 12 203 Al ie>rn a f c phi" p 1 4CC r r t ap p r-o ✓ ri pry' 2,0 "MG 25 9 VLF b //�//3 Spacing Exception Required? Yes 0 No Subsequent Form Required: / h — 46 / - 10' APPROVED BY Approved by: / P9iA COMMISSIONER THE COMMISSION Date: 4 -// - 1.3 Approved application is valid tor 12 months from the date rm te of approval. o d 10/20 's 12) V L SCANNED JUN 1 2 2013 Submit Fo and Attachments in Duplicate z‘3 �) wPti� %rts, THE STATE Alaska Oil and Gas 11,7 °f A Conservation Commission L � GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFA, * ' Anchorage, Alaska 99501 -3572 AL AS Main: 907.279.1433 SCANNED APR 12 1013 Fax: 907.276.7542 Haibin Guo Sr. Drilling Engineer -(01 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C -10 Sundry Number: 313 -153 Dear Mr. Guo: 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, / Cathy . Foerster Chair DATED this day of April, 2013. Encl. STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM ION 4J 1 1 [Q APPLICATION FOR SUNDRY APPROVALS ; 0 AAC 25.280 1. Type of Request: Abandon E Rug for Redrill rforate New Pool j"' ` Repair w ell I✓ Change Approved Program r Suspend V Rug Perforations 'V 1 0 P I- Rill Tubing i∎% Time Extension J" Operational Shutdow n r Re -enter Susp. Well E `7 I Stimulate r Alter casing (" Other: iT" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1r . Exploratory C - " 185 - 101 3. A Stratigraphic - S ervice I — 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21356 - 00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ 3C - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25629 • 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): 8980. 6740 • 8891' 6674' . 8423' 8547' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 116' 116' SURFACE 4784 9.625 4819' 3729' PRODUCTION 8935 7 8974' 6736' PerforatiorS Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8539 -8551, 8697 -8742, 8764 -8790 6419 -6428, 6534 -6566, 6582 -6601 2.875 J -55 8628 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO HRP -1 -SP PACKER MD= 8395 TVD= 6314 PACKER - BAKER DB PERMANENT PACKER MD= 8600 TVD= 6463 ' SSSV - CAMCO TRDP -1A -SSA SSSV MD =1806 TVD =1691 - 12. Attachments: Description Sunmary of Proposal . id 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ( Exploratory ` Stratigraphic E Development • Service E 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: ,� , �1 5/1/2013 Oil P' X11 r ^�G as $ VVDSPL r Suspended TT �f l 16. Verbal Approval: Date: WINJ I~ �� GINJ is WAG E" Abandoned E 6\ Commission Representative: GSTOR i SPLUG i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265 -1487 Email: Haibin.Guo( conocoohiilios.com Printed Name Haibin Guo Title: Sr. Drilling Engineer Signature Phone: 265 -1487 Date 2 _ 2 / ... ,, / ■ Commission Use Only Sundry Number: 3 3_I 53 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 1 - " BOP Test ,1® Mechanical Integrity Test E Location Clearance r O CA ) ther. f3 f - ! f , ?5G0 p $ i FIF3DMS APR 12 20" Spacing Exception Required? Yes 0 No Subsequent Form Required: / h _ Li O a APPROVED BY Approved by: / / 67 )-k-- 1 -1 ( 4 A------ COMMISSIONER THE COMMISSION Date: 4-11- /3 Approved application is valid tor 12 months trom the date of approval. o 0 is d 0/2012) V /--- Submit Form and Attachments in Duplicate new,03 ConocoPhillips Alaska �w P.O. BOX 100360 A 0 `t ANCHORAGE, ALASKA 99510 -0360 March 27, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 3C- 10 (PTD# 185 -101). Producing well 3C -10 was originally completed in July 1985 as a selective 2'/8" gas lift completion. The well was shut in due to excess C sand water production in Dec 2011. Attempts were made to patch the C sand in May 2012. Unfortunately, the lower patch packer was stuck at 8,547' MD in 2-' /s" tubing. Attempts to retrieve the lower packer of the patch assembly failed and the well was shut in since then. The purpose of the workover is to remove the entire 2- tubing completion, pull the upper Camco HRP -1 -SP casing packer. Mill & retrieve the lower Baker DB packer, cleanout to PBTD at +/- 8891' MD, run & cement a 4 '/2" scab liner across the Kuparuk A and C sands. A new 3 'h" gas lift completion will be run to facilitate future Coiled Tubing Drilling(CTD) development. If you have any questions or require any further information, please contact me at 265 -1487. Sincerely, 14 bi Haibin Guo Drilling Engineer CPAI Drilling and Wells • 3C-10 Ri g Workover Pull 2 %" Selective Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & 3 Y2" Tubing (PTD #: 185 -101) Current Status: This well has been shut in since Dec 2011. Patch fish was left in 2 %" tubing at 8,547' RKB. Well is secured with WRP at 8,423' RKB. Catcher was set at 8,410' RKB. Scope of Work: Pull the 2 -7/8" tubing, pull upper casing packer, mill & retrieve the lower Baker DB packer, cleanout to PBTD, run & cement a 4 ' /2" scab liner across the Kuparuk, and run a 3 'h" gas lift completion. The well will be CTD sidetracked after the rig workover. General Well info: Well Type: Producer MPSP: 2,140 psi (Current surface pressure T/I /0= 550/525/480 psi) Reservoir Pressure /TVD: 2,788 psi / 6,571' TVD (8.2 ppg) from Panex gauges on 01/19/12. Wellhead type /pressure rating: Cameron Gen IV, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: CMIT -T x -IA, passed on 01/20/13. Earliest Estimated Start Date: May 01, 2013 Production Engineer: Susan Short / Kenneth Martin / Toon Changklungdee Workover Engineer: Haibin Guo (265 -1487 / Haibin.Guo @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. CMIT T x IA to 3,000 psi. b. Pull catcher sub @ 8,410' RKB. c. Pull WRP plug @ 8,423' RKB. d. Set catcher sub @8,460' RKB. e. Pull 1" GLV from GLM #1 @1,997' RKB, GLM #2 @3,803' RKB, GLM #4 @5,405' RKB, GLM #7 @6,617' RKB, GLM #11 @ 8,337' RKB and GLM #12 @8,431' RKB. f. Dummy off GLM #1, #2, #4, #7 (GLM #3, #5, #6, #8 and #10 have been dummied earlier). Leave pocket GLM #11 and GLM #12 open. g. RIH w/ dual Panex gauges, lightly tag fill, obtain 30 min. SIBHP, pull uphole 100' TVD and obtain 15 min. gradient stop. h. Lock out SSSV. i. RDMO. 2. RU E -line: a. RIH & fire a string shot at 8,360' RKB (in the middle of the first full joint above the PBR). a. RIH with 1- 11/16" RCT. Cut the tubing at 8,360' RKB. b. RDMO. 3. Set BPV within 24 hrs of rig arrival. Proposed Procedure 1. MIRU Doyon141. 2. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. — 4t r~� �A� o(� 7t � 100 ) 96 th' �« cr��c• t Cart- re f4 Mocha/nut( ( ,��/�°f ,e,D /f� I'N f'�4 14 1 we 1f N ><ik ap well ✓oWd /dot 6e 1vst'frcW si /o . / {A11, Ai'Nf- /tom f 64•4444 Cdrr st weeityr Coe a red".!l fiOsV ` yea f Party Frog rk- ;;;-4/, 3C-10 Ri g Workover Pull 2 %" Selective Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & 3 1 /2" Tubing (PTD #: 185 -101) 5. POOH laying down 2 '/8 "" tubing. 6. MU overshot & single in on 4" drill pipe, latch onto tubing stub and jar the OEJ free. POOH standing back drillpipe, lay down fish. 7. MU and RIH overshot latch to slidstick and jar the CAMCO HRP -ISP packer free. POOH standing back drillpipe, lay down fish. 8. MU packer mill, RIH on 4" drill pipe to top of Baker DB Permanent Packer. Commence milling on packer until packer is free to move. POOH mill assembly. 9. MU spear assembly and RIH to latch on the fish. POOH and LD the fish. 10. MU 6 1/4" smooth OD concave junk mill w/ 6 '/s" string mills, cleanout to top of PBTD at 8,891' RKB. POOH standing back drillpipe, lay down milling assy. 11. PU —550' of 4 -1/2" liner (w/ centralizers), 5" x 7" Flex -lock liner hanger, 5" x 7" ZXP liner top packer, HRD running tools, and RIH on drill pipe to —8,300' RKB. 12. RU SLB cementers, establish circulation rate, pump 10 bbl spacer followed by —20 bbls Class G cement, drop wiper plug and chase w/ KWF until plug bumps. Pressure up to 3500 psi to set liner hanger at 8,300' RKB. Slack off 50K lbs to check hanger is set. 13. PU to expose rotating dog sub and slack off 45K lbs. to set ZXP packer. Pick up and reverse circulate cement out of the hole until clean fluid returns. 14. POOH laying down drillpipe, lay down liner running tools. 15. Offload old tbg, load & strap new 3 -1/2 ", 9.3 #, L -80 8rd EUE tbg into pipe shed 16. Single in w/ new 3 -1/2" tubing to just above the SBE. Sting into SBE, space out 7' from fully located, mark pipe and pull out of SBE. 17. Space out w/ pups, MU hanger. Spot 15 bbls 9.0 ppg corrosion inhibited brine in the IA below the bottom GLM. Land the hanger, RILDS. 18. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the tubing pressure to zero quickly to shear the SOV. 19. Pull the landing joint, install two -way check. 20. ND BOPE. 21. NU and test tree. Pull two -way check. 22. Freeze protect through the SOV, set BPV. 23. RDMO Doyon 141. Post -Riz Work 1. Pull BPV. 2. RU Slickline: Pull SOV, run DV. 3. Turn well over to production. 1.--- v KUP • 3C -10 ConocoPhillips $ Well Attributes Max Angle & MD TD .. Alaska. 111,; Wel!bore APUUWI Field Name Well Status !nci (°) MD (ftKB) Act Btm (ftKB) gi 500292135600 KUPARUKRIVERUNIT PROD 50.10 3,300.00 8,980.0 `-"` Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' SSSV: TRDP 100 5/14/2012 Last WO: 34.59 7/3/1985 Well Canfp: - 3C -10 1 /23/2013 8: AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,823.0 2/19/2012 Rev Reason CORRECT TBG TALLY osborl 1/23/2013 Gasin. Strings ` Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • CONDUCTOR 16 15.062 35.0 116.0 116.0 62.50 H - 40 WELDED HANGER, 34 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ SURFACE , 95/8 8.921 34.9 4,819.4 3,729.1 36.00 J -55 BTC Casing Description String 0... String ID ... Top ftKB Set Depth f... Set Depth (TVD) Strip Wt... String String Top Thrd PRODUCTION 7 6.276 38.7 8,973.8 6,735.6 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ...Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 2 7/8 I 2 I 33.7 8 6483 I 6.50 J -55 EUE 8RD Completion Details CONDUCTOR, Top Depth 35-116 (TVD) Top Incl Nomi... SAFETY VLV, L'=.1 L f� Top (RKB) (ftKB) (°) Item Description Comment ID (In) 1.806 33.7 33.7 0.33 HANGER CAMERON TUBING HANGER 2.875 1,805.9 1,690.7 44.51 SAFETY VLV CAMCOTRDP -1ASSA 2.312 GAS LIFT, _ 1,997 8,377.3 6,301.7 43.35 SBR CAMCO OEJ-10 SBR 2.312 GAS LIFT, 8,394.8 6,314.4 43.37 PACKER CAMCO HRP -1 -SP PACKER 2.347 3,804 `-` 8,598.8 6,462.3 43.68 LOCATOR BAKER LOCATOR SUB, 9.45' INSIDE PACKER 2.406 8,599.8 6,463.0 43.68 PACKER BAKER DB PERMANENT PACKER 3.250 ' ' 8,619.5 6,477.3 43.44 NIPPLE CAMCO D LANDING NIPPLE NO GO; 1/3/00 - NO GO @ D PROFILE 2.250 DAMAGED 9/24/06 SURFACE. 1 l 8,626.9 6,482.7 4143 SOS CAMCO SHEAR OUT SUB 2.441 35 -4,819 GAS LIFT, Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 4,910 Top Depth (TVD) Top Inc! GAS LIFT, Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (In) 5,406 I 8,410.0 6,325.4 43.40 CATCHER SET CATCHER ON TOP OF WRP 1/11/2013 0.000 8,423.0 6,334.9 43.41 PLUG WRP 12/25/2012 0.000 GAS LIFT. 5,811 1 1 4 8,547.0 6,424.8 43.60 FISH LOWER ER PACKER 5/18/2012 0.000 GAS 8 LIF ,218 1 . T, Perforations & Slots El ii Shot Top (TVD) Btm (TVD) Dens GAS LIFT, F To p (ftKB) Mtn (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment 6,617 F 8,539.0 8,551.0 6,419.1 6,427.7 C -1, UNIT B, 7/29/1985 12.0 IPERF 120 deg. phasing; 5 1/2" Scalloped 3C -10 HJ GAS LIFT. 7.053 i 8,697.0 8,742.0 6,533.6 6,566.4 A-4, A -3, 3C -10 7/29/1985 4.0 IPERF 90 deg. phasing; 4" Carrier Gun HJ II t�f 8,764.0 8,790.0 6,582.4 6,601.4 A -2, 3C -10 7/29/1985 4.0 IPERF 90 deg. phasing; 4" Carrier Gun HJ II GAS LIFT, - j490 Notes: General & Safety End Date Annotation GAS LIFT, 7,945 7/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 12/9/2011 NOTE: CONFIRMED LEAK @ 8582' RKB w/ ELINE LDL GAS LIFT, 4 8.337 SBR, 8,377 J PACKER. 8.395 - � I i i CATCHER, 8,410 '.4.I' PLUG, 8,423 PRODUCTION, . 8.431 PRODUCTION, 8.499 IPERF, 8,5 39-8,551 FISH. 8,547 PRODUCTION, {_ 8,582 LOCATOR. 8,599 PACKER. 8,600 i l" 1 Mandrel Details w NIPPLE, 8,619 "' Top Depth Top Port ?' 5... (TVD) Intl OD Valve Latch m TRO Run al (e) N... Top (ftKB) (RKB) ( °) Make Model (In) Sery Type Type (in) (psi) Run Date Com... SOS, 8.627 1 1,996.9 1,825.6 46.02 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,356.0 8/3/2011 2 3,803.5 3,031.3 49.42 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,372.0 8/3/2011 3 4,910.3 3,795.8 41.22 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/15/2009 IPERF, 4 5,405.6 4,175.7 40.35 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,356.0 8/3/2011 8,6978,742 5 5,810.6 4,480.7 41.93 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/29/1985 IPERF, C 6 6,215.7 4,781.7 41.01 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/29/1985 8,7848,790 7 6,617.5 5,077.6 41.45 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,381.0 8/3/2011 - 8 7,053.1 5,388.6 47.27 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/15/2009 9 7,489.6 5,687.6 46.43 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,364.0 8/2/2011 PRODUCTION. 398974 * - 10' 7,944.6 5,998.3 47.42 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2008 TD, 8.980 a • KUP 410 3C -10 ConocoPhillips 01 Alaska, Inc w.. KB-Grd (ft) Rig Release Date 34.59 7/3/1985 Well Catnip: - 3C -10, 1/23/2013 8'.30'.00 AM Schematic - Actual • HANGER,34 CONDUCTOR, 35 -116 SAFETY VLV, - o. 1,806 GAS LIFT, 1,997 GAS LIFT,.. 1 '_ 3,804 "`7 Ind I I SURFACE, 1 l 35 -4,819 GAS LIFT, 0,910 GAS LIFT, 5,408 GAS LIFT, 5,811 GAS LIFT, 8,218 08041, GAS LIFT, 7,053 GAS LIFT, 7,490 f ` ` 1 GAS LIFT, 7,945 GAS LIFT, 8,337 f I SBR, 8,377 PACKER, 8,395 CATCHER, 8,410 PLUG, 8,423 PRODUCTION,_ f. 8,431 PRODUCTION, 8,499 IPERF, _ _ 8,539.8,551 FISH, 8,547 PRODUCTION, 8,582 LOCATOR, 8,599 PACKER, 8,600 4a IP Mandrel Details NIPPLE, 8,619 IL Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run N... Top (RKB) (RKB) (°) Make Model (is) Dery Typo Type (in) (psi) Run Date Com... SOS,8,627 'tm""i 11 8,337.1 6,272.4 43.29 MERLA TMPD 1 GAS LIFT OPEN 0.250 0.0 1/10/2013 s 12 8,430.9 6,340.7 43.43 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/23/1999 13 8,498.9 6,390.0 43.53 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/23/1999 IPERF, , 14 8,582.3 6,450.4 43.65 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/3/2011 Ext 8,697-8,742 Pkg IPERF, 8,7648,790 PRODUCTION, 39 -8,974 TD, 8,980 • • 3C -10 Proposed RWO Setup for CTD 6H40shoe @ ■ @ 1166' ' MD 3-1/2" Schlumberger TRMAXX- CMT -SR -5 @ 1800' TVD (2.813" ID) 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 9 -5/8" 36# J -55 shoe @ 4816' MD 3 -1/2" Camco MMG gas lift mandrels @ TBD 3 -1/2" X Nipple (2.813" min ID) Baker ZXP Packer – 8300' RKB Baker Flex Lock Liner Hanger Baker 80 -40 SBE 4 -1/2" 11.6# L -80 Scab Liner 40' KO joint 8605' - R645' PD(_ (reference 7 -14 -85 CET) 4 -1/2" Type 1 Landing Collar @ –8750' RKB 4 -1/2" Float Shoe @ 8850' RKB C -sand perfs 8539' - 8551' MD A -sand perfs 8697' -8742' MD — —_ • 7" 26# J -55 shoe @ • 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. STATE OF ALASKA • $ ALPO OIL AND GAS CONSERVATION COMIIOION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Fbrforations E Perforate f Other rv7 Install Patch After Casing r Pull Tubing r Stimulate Frac r Waiver r" Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j7 Exploratory r- < 185 - 101 3. Address: T ° 6. API Number: 00 Stratigraphic J Service P. O. Box 100360, Anchorage, Alaska 99510 r' 50 029 - 21356 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25629 ' 3C - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8980 feet Plugs (measured) None true vertical 6740 feet Junk (measured) tbg patch @ —8525' Effective Depth measured 8891 feet Packer (measured) 8395, 8578, 8590, 8600 true vertical 6674 feet (true vertucal) 6314, 6447, 6456, 6463 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 116 116 SURFACE 4784 9.625 4816 3727' PRODUCTION 8935 7 8974 6736' RECEIVED JUN 22 2012 Perforation depth: Measured depth: 8539'- 8551', 8697'- 8742', 8764' -8790' True Vertical Depth: 6419'- 6428', 6534'- 6566', 6582' -6601' AOGCC Tubing (size, grade, MD, and TVD) 2.875, J - 55, 8627 MD, 6483 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO HRP -1 -SP PACKER @ 8395 MD and 6314 TVD PACKER - WEATHERFORD ER PACKER @ 8578 MD and 6447 TVD PACKER - WEATHERFORD ER PACKER @ 8590 MD and 6456 TVD PACKER - BAKER DB PERMANENT PACKER @ 8600 MD and 6463 TVD SSSV - CAMCO TRDP -1A -SSA @ 1806 MD and 1691 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: air Mik J ijL 2 4 alZ 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ' Service r.,,„,. Stratigraphic E 16. Well Status after work: ,Oil P Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. 1 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 John Peirce a n. 265 -6471 Printed Name John Peirce Title Wells Engineer ilz Signature 4 IN �, r Phone: 265 6471 Date 6 / ^ i Form 10 04 Revised °? %2(51.1 'lJ Submit Ori ina Only vt SDMS JUN 25 2017 C -Lc. ! f f/a 3C -10 Well Work Summary DATE SUMMARY 1/19/12 TBG OPEN 2.26" TO 8619' RPI , TAG FILL @ 8718' SLM / 8757' RKB, M URED BHP @ 8710' SLM = 2787 psi, DRIFT TBG WITH 2.25" DUMMY PATCH DRIFT UNABLE TO PASS 7575' SLM. IN PROGRESS. 2/4/12 DRIFTED TBG WITH 10' x 2" BAILER TO D NIPPLE, NO PROBLEMS. DRIFT TO SAME WITH 5' x 2.25" BAILER. RAN 7' BROACH ASS'Y WITH 2.25" & 2.22" BROACHES TO UPPER PKR @ 8395' RKB, NO PROBLEMS. IN PROGRESS. 2/5/12 DRIFTED TBG TO SBR WITH 2.25" BROACH, 8' x 2.125" WB & 2.25" x 32" DUMMY (OAL BETWEEN MAX ODs 10.5'). COMPLETE. 2/15/12 PERFORMED FILL CLEAN OUT TO 8892' MD (PBTD) USING GELLED DIESEL. HEAVY AMOUNTS OF FORMATION SAND SEEN IN RETURNS AT RETURNING GE LL S WEEPS. JOB COMPLETE 2/19/12 GAUGE TBG TO 2.27" TO D -NIP @ 8620' RKB, TAG @ 8823' SLM, ATTEMPT TO DRIFT 2.25" DMY PATCH (15.96' OAL) , WORK TOOLS DOWNHOLE f/ 7495' TO 8390' SLM, TAG D -NIP © 8620' RKB, ATTEMPT TO DRIFT 2.25" DMY PATCH (15.3' OAL), SD @ 7495' SLM, DRIFT 2.25" DMY PATCH (11.5' OAL) TO 8590' RKB. RD FOR UNIT MAINTENANCE. 3/5/12 SET WEATHERFORD 2.24" ERP AT 8592', TOOL STUCK AT 8592' AFTER SETTING ERP, WORK WIRELINE TO 2400 LBS WHERE WIRELINE BROKE OFF OF ROPE SOCKET 33.2' OF 2.24" MAX OD TOOLSTRING LEFT DOWNHOLE: 1- 7/16" CABLE HEAD (1.375" FISHING NECK), SWIVEL, 7' WB, ROLLER, 7' WB, ROLLER, CCL, FIRING HEAD, SETTING TOOL, ERP 3/8/12 FISHED ELINE TOOLSTRING FROM 2.24" ER PACKER SET @ 8592' RKB. 5/8/12 SET 13' WEATHERFORD TBG PATCH ACROSS EMPTY CSM @ 8582' RKB, RAN ER TEST TOOL TO UPPER ER PACKER AND UNABLE TO OBTAIN PRESSURE TEST; SET c D &D HOLE FINDER ON TOP OF UPPER ER PACKER @ 8577' RKB TO CONFIRM TBG. 111 V STRING INTEGRITY, PT TBG TO 2000 PSI. JOB COMPLETE P 1 5/15/12 PULLED UPPER PATCH ASS'Y f/ 8543' TO 8525' SLM; UNABLE TO MOVE BEYOND 8525' SLM. IN PROGRESS. 5/16/12 PULLED UPPER PATCH ASS'Y @ 8524' SLM; PKG ELEMENT, SLIP, & 2 PIECES OF SNAP LATCH MISSING DOWN HOLE. ATTEMPTED FISH DEBRIS WITH WIRE GRAB & MAGNET, NO RECOVERY. DRIFTED 5' INTO LOWER ER PACKER WITH 5' x 1.25" STEM, CONFIRMED UNOBSTRUCTED. IN PROGRESS. 5/17/12 JARRED ON ER PACKER 1 HOUR UNTIL PULLING TOOL WOULD NOT STAY ENGAGED. RETRIEVED PULLING TOOL, SLIPS STUCK IN RECESSED POSITION. JARRED ON PACKER 45 MIN, NO SUCCESS. IN PROGRESS. 5/18/12 JARRED ON ER PACKER 2 HOURS UNTIL PULLING TOOL WOULD NOT STAY ENGAGED. ATTEMPTED PULL WITH TTS PULLING TOOL, NO SUCCESS. JO B SUSPENDED. KUP 3C -10 Conoc OA Well Attributes • Max Angle & MD TD A41Shd In+. Wellbore API /UWI Field Name Well Status Inc! 0) MD (ftKB) Act Btm (RKB) Conn inrlR 500292135600 KUPARUK RIVER UNIT PROD 50.10 3,300.00 8,980.0 ' - Comment H25 (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: TRDP 120 12/17/2010 Last WO: 34.59 7/3/1985 Well Conk' - 30 -10, 5/22/2012 11:10:33 AM Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,823.0 2/19/2012 Rev Reason: SET PATCH ASSY ninam 5/22/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ,...,....... CONDUCTOR 16 15062 34.0 116.0 116.0 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 31.5 4,816.0 3,726.6 36.00 J - 55 BTC HANGER, 34 s Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd - 1 PRODUCTION 7 6.276 38.7 8,973.8 6,735.6 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String ... String Top Thrd TUBING 2 7/8 I 2.441 I 33.7 8,627.6 I 6,483.2 I 6 I J - 55 E UE 8RD Completion Details CONDUCTOR, _ Top Depth 34-116 (TVD) Top Intl Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) o SAFETY VLV, 33.7 33.7 0.33 HANGER CAMERON TUBING HANGER 2.875 1,808 1,805.9 1,690.7 44.51 SAFETYVLV CAMCOTRDP - 1A - SSA 2.312 GAS LIFT 1,997 , 8 ,377.3 6 43.35 SBR CAMCO OEJ -10 SBR 2.297 I 8,394.8 6,314.4 43.37 PACKER CAMCO HRP-1-SP PACKER 2.347 T GAS LIFT, ,. 8,598.8 6,462.3 43.68 LOCATOR BAKER LOCATOR SUB, 9.45' INSIDE PACKER 2,441 3,804 ` - - -" 8,599.8 6,463.0 43.68 PACKER BAKER DB PERMANENT PACKER 3250 8,619.5 6,477.3 43.44 NIPPLE CAMCO D LANDING NIPPLE NO GO; 1/3/00 - NO GO @ D PROFILE 2.250 DAMAGED 9/24/06 URFACE, Al 1 l 8,626.9 6,482.7 43.43 SOS CAMCO SHEAR OUT SUB 2.441 32 -4,816 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 4,910 (ND) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) GAS LIFT, 8,578 6,447.3 43.65 PACKER WEATHERFORD ER PACKER 5/8/2012 1.465 5.406 8,580 6,448.9 43.65 PATCH SPACER PIPE, SNAP LATCH SEAL STINGER 5/8/2012 1.320 GAS LIFT, 8,590 6,456.0 43.67 PACKER WEATHERFORD ER PACKER 5/8/2012 1.465 5.811 Perforations & Slots GAS LIFT, Shot 6.216 Top (TVD) Btm (TVD) Dens I II Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ( :h °. Type Comment GAS LIFT. 8,539 8,551 6,419.1 6,427,7 C -1, UNIT B, 7/29/1985 12.0 IPERF 120 deg. phasing; 5 1/2" Scalloped 6,617 3C -10 HJ III GAS LIFT, 8,697 8,742 6,533.6 6,566.4 A-4, A -3, 3C -10 7/29/1985 4.0 IPERF 90 deg. phasing; 4" Carrier Gun HJ II 7,053 8,764 8,790 6,582.4 6,601.4 A -2, 3C -10 7/29/1985 4.0 IPERF 90 deg. phasing; 4" Carrier Gun HJ II III GASLIFT, Notes: General & Safety 7 End Date Annotation III 7/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, _ 12/9/2011 NOTE: CONFIRMED LEAK 8582 RKB w/ ELINE LDL I I I 7,91s @ GAS LIFT. MAP 8,337 /III. SBR, 8,377 INA PACKER, 8,395 PRODUCTION, 8,431 IN PRODUCTION, 8,499 IPERF, 8,5394,551 (''.." ACKER, 8,578 a PATCH, 8,580 -. RODUCTION, N 7 8,582 _ A CKER, 8,590 _ OC • 59 8,599 _ _ ®� PACKER, 8,600 Mandrel Details NIPPLE, 8,619 1µi Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) (1 Make Model (in) Sery Type Type (!n) (psi) Run Date Corn... SOS. 8,627 1 1,996.9 1,825.6 46.02 CAMCO KBMG 1 GAS LIFT GLV BK 0.125 1,356.0 8/3/2011 2 3,803.5 3,031.3 49.42 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,372.0 8/3/2011 3 4,910.3 3,795.8 41.22 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/15/2009 IPERF, 4 5,405.6 4,175.7 40.35 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,356.0 8/3/2011 8,697 - 8,742 5 5,810.6 4,480.7 41.93 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/29/1985 8,7644,78 IPERF, 0 - 6 6,215.7 4,781.7 41.01 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/29/1985 7 6,617.5 5,077.6 41.45 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,381.0 8/3/2011 8 7,053.1 5,388.6 47.27 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/15/2009 9 7,489.6 5,687.6 46.43 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,364.0 8/2/2011 PRODUCTION, 39 10 7,914.6 5,978.0 47.43 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2008 Ilk TD, 8,980 KUP • 3C -10 �► q ConocoPhillips Alaska, Inc. V s{a Conocol49lkps 'd KB-Grd (16) Rig Release Date "' 34.59 7/3/1985 Well Confiq -3C -10 522/201211: 1033 AM Schematic - Actual I 4 HANGER, 34 v CONDUCTOR,_ 34 -116 SAFETY VLV, e� l 1,806 GAS LIFT, 1,997 GAS LIFT, �_ s 3,804 c' SURFACE, 1 L. 32 -4,816 • GAS LIFT, 4,910 GAS LIFT, r .. 5,406 GAS LIFT, 5,811 GAS LIFT, 8,218 r � GAS LIFT, 6,617 GAS LIFT, 7,053 GAS LIFT, 7,490 GAS LIFT, 7,915 GAS LIFT. 8,337 SBR, 8,377 PACKER. 8,395 PRODUCTION, 8,431 PRODUCTION, 8,499 IPERF, 8,539-8,551 PACKER, 8,578 PATCH, 8,580 PRODUCTION, N. 8,582 ?( I{' i PACKER. 8,590 LOCATOR, 8,599 PACKER. 8,600 Mandrel Details NIPPLE, 8,619.L Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top(ftKB) (ft68) (1 Make Model (in) Sery Type Type (in) (ps') Run Date Com... 80S. 8.627 - - { 11 8,337.1 6,272.4 43.29 MERLA TMPD 1 1/2 GAS LIFT OV RK 0.250 0.0 8/2/2011 12 8,430.9 6,340.7 43.43 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/23/1999 13 8,498.9 6,390.0 43.53 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/23/1999 IPERF, , 8,697 -8,742 14 8,582.3' 6,450.4 43.65 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 12/3/2011 EM Pkg IPERF, 8,764-8,790 IPERF. PRODUCTION, 39-8,974' * - TD, 8,980 r lal • Uzi WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3C -10 Run Date: 3/5/2012 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 3C -10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -029 - 21356 -00 JUL26`012 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A OPY 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: 3 �Z Signed: 6.€4 t 213 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 27, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 3C -10 Run Date: 12/21/2011 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 3C -10 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21356 -00 JUL 25 201' 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: 4/\642- Signed: /% i;, • • S- WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 21, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3C -10 Run Date: 12/9/2011 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 3C -10 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21356 -00 Production Profile Log., ��� 1 Color Log 50- 029 - 21356 -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: L lV'2-- Signed: u �' '' • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3C -10 Run Date: 7/24/2011 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 3C -10 Digital Data in LAS format, Digital Log Image file ti 3 (4 l 1 CD Rom 50- 029 - 21356 -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: l 2 l( Signed: , CIO 2� /ygi 1 ° 1 • M WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting: 3C -10 Run Date: 7/16/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3C -10 Digital Data in LAS format, Digital Log Image file 1 Li S6 1 CD Rom 50-029-21356-00 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: • F ) II Signed: Lam )33---10/ STATE OF ALASKA "4.-- ALASKA OIL AND GAS CONSERVATION COMMISSION I.nI• It REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell j Rug Nrforations [ Stimulate [ Other lvf Qr4 c Alter Casing [ Pull Tubing r Perforate New Pool ❑ Waiver ❑ lime Extension ❑ We-1A Change Approved Program 17 Operat. Shutdown C Perforate [ Re -enter Suspended Well ] 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [J Exploratory ❑ — 185 -101 3. Address: 6. API Number: Stratigraphic ] Service j P. O. Box 100360, Anchorage, Alaska 99510 r 50 029 - 21356 - 00 - 06 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025629 ° ` 3C -10 9. Field /Pool(s): J Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8980 feet Plugs (measured) None true vertical 6740 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8395, 8600 true vertical 0 feet (true vertucal) 6314, 6463 Casing Length Size MD ND Burst Collapse CONDUCTOR 82 16 116 116 0 0 SURFACE 4784 9 5/8 4816 3726 0 0 PRODUCTION 8935 7 8974 6735 0 0 ANsifitiD— AUG 162011 Perforation depth: Measured depth: 8539 - 8551, 8697 - 8742, 8764 - 8790 - r ; . - ° \ ( . True Vertical Depth: 6419 -6427, 6533 -6566, 6582 -6601 Tubing (size, grade, MD, and TVD) 2.875, J -55, 8627 MD, 6483 TVD ii'at. > ' ati & 66, t ; a, #tt311j33iUR Packers & SSSV (type, MD, and ND) PACKER - CAMCO HRP -1 -SP PACKER @ 8395 MD and 6314 ND PACKER - BAKER DB PERMANENT PACKER @ 8600 MD and 6463 ND 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory [j Development Jj Service C] Stratigraphic r X 15. Well Status after work: ,i. Oil 1 Gas r VVDSPL Daily Report of Well Operations GSTOR r WIND r WAG r] GINJ [._; 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 NA Contact MJ Loveland /Marti Walters Printed Name MJ Lo land Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date 8/2/11 Q RBDNIS AUG � B 1 • ii 1Of00 Form -.404 Revised 10/2010 � 8 2011 Submit Original Only • • K 3C -10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/24/11 SET WEATHORFORD 2.25" WRP. MID - ELEMENT SET DEPTH 8415.5', CCL STOP DEPTH 8400.5', CCL TO MID- ELEMENT 15'. 07/29/11 T /I /O = 0/0/0 Rig up and purge OA, cooper heat on @ 8:15, up to 470 F, PJSM on location, seal weld BH. 07/31/11 MITOA- passed; Initial T /I /O= Osi /0/30; OA FL @ 100ft. Pressured up OA with 4.5bbls. of diesel T /I /O= 0/0/1800 15min. reading T /I /O= Osi/0/1740 30min. reading T /I /O= Osi/0/1720; Bled down OA. Final T /I /O= Osi /O /80 . • COn ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 20Q9 Mr. Tom Maunder ~ ; : ~~ j ~ Alaska Oil & Gas Commission ;¢~~~`~~'`~~'~ ~l~'` ~ 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~~1a~~~ ~ JIJL 0 7 2Q09 ~~~as~~ C~iI ~ G~~ Cans, Cammission An~ht~r~~~ ~-~~1 '~ ~G"~G~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundty Operations. The cement was pumped June 16~' 8z 26~', 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30~`, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perty Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~f ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operattons (10-404) Kuparuk Fleld Date 7/3I09 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrbsion inhibitor/ sealant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2009 3C-02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6l30l2009 3C-03 50029214150p 1851890 5' 1.0 21" 6/26/2009 5.1 6/30/2009 3C-04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" Na 24" n/a 4.25 6/23/2009 3C-06 500292109600 1840420 6" n/a 6" Na 7.65 6/23/2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6l23/20U9 3C-08 500292139000 1851550 12' 2.00 22" 6/16/2009 3.4 6/23/2009 3C-09 500292135500 1851000 20" Na 20" Na 2.55 6/23/2009 3C-10 500292135600 1851010 30' 4.10 24" 6/16/2009 4.25 6/23/2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3C-13 500292142400 1857980 20" Na 20" Na 2.12 6/23/2009 3C-14A 500292142501 2071750 3' n/a 3' n/a 8.07 6/23l2009 3C-15A 500292142601 2080810 31' 4.40 26" 6/16/2009 2.75 6/23/2009 3C-i6 500292142700 1852010 20" n/a 2Q" n!a 2.12 6l23/2009 3C-17 500292338900 2080590 2'6" n/a 2'6" n/a 8.92 6/23/2009 ~'~' STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ~ Classification of Service Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Name of OPerator 7. Permit Number ARCO Alaska, Inc. 85-101 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21356 4. Location of well at surface 9. Unit or Lease Name 1119' FNL, 889' FEL, Sec.14, T12N, PgE, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 1236'FSL, 1528' FEL, Sec.12, T12N, R9E, UM 3C-10 At Total Depth 11. Field and Pool 1324' FSL, 1204' FEL, Seco12, T12N, 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 82' RKBI ADL 25629 ALK 2562 12. Date.Spudded06/25/85 13. Date T.D. Reached07/01/85 07/03/85'14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsN/A fee, MSL 1 · , 17. Total Depth (MD+TVD) 18. Plug Back DePth (MD+'rvD) 19'. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8980'MD,6739'TVD 8891 'MD,6674'TVD YEb-'X~-} NO []I 1806 feet MD 1700' (approx) . 22. Type EleCtric or Other Logs Run DIL/SFL/SP/GR, Cal, FDC/CNL, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD . _ SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: 52.5# ' H-~,0 5urt 116' 24~" ' 213 sx CS II · _ 9-5/8" 36.0# J-55 Surf 4816' 12-1/4" 1440 sx AS Ill & 320 sx ;lass G 7" 26.0# J-55 Surf ' 8974" 8-1/2" 375 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) 8790' - 8764' w/4 spf, 2-7/8" 8628' 8395' & 8600' 8742' - 8697' 90© phasing . . 26. ACID, FRACTURE', CEMENT SQUEEZE, ETC. 8551' - 8539' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 2~./A PRODUCTION TEST Date First Production I Method of Operation (Flowing,.gas lift, etc.) I Date of Test HOurs TeSted PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, aPparent dips and presence of oil, gas or water. Submit core chips. ~,, .~ r .one c · ,, Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and the well perforated on 7/31/85. WC1/063 Submit in duplicate CONTINUED ON REVERSE SIDE -:. G EOLOGfC:M~B ~- . ~ . . .],!., ..... . .., .. TESTS -~ ~ .~.-~ : ~:.~;:~;~ ~;~i,~: ~'~;~-~' .~ ;-' ~,...... ..~.'~[' ,?... ..,.,., ,. '- 'NAME ..... ~' ": ' ' ' ''~ : -: ': "~ ' ' ~_.lnclude interval tested, pressur'~"data, all fluids r~overed and grav~W, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . .~ ....... . ......... . .' ..~[ ... _ ....... T-op Upper Sand 8~91 ' 6383' N/A 85~8' ~t' ' 6~2~' :" .... ~se Upper Sand ToP Lower Sand ' 8679" -' 6519' -~ ~,-. -..~ - : -- . · Base Lower. Sand '. :88~6, · 66~1, · _. : . , _ - :: ., ., . . ~: ~ · :, :j' _ · ~..~ . ~ - .r .:~.. . . . .. . .' ] .~- - . . . . . ., . . . .. . 31. LIST OF ATTACHMENTS None .... 32. I hereby certify that the foregoin~ i{ {rue and corr~t to the best of mY-Enowl~ge . . : . . ~~ Associate Engineer Date__ Signed // INSTRUCTIONS General: This form is designed for submitting a complete and correct well comPletion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements . given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production 'from more than one interval (multiple completion), so state in item. 16, and in item 24 show the producing intervals fOr only the interval reported in item 27. Submit a separate form for each additional interval to be seParately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-exPlain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 _ RETURN TO:' ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS' CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5421 TRANSMITTED HER/~WITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINALS/ SCHL/ CEMENT <ONE * OF EACH> ~lA-3/ CEMEN~ EVALUATION TOOL -lB-4~ .CEMENT EVALJATION TOOL ~lR-9/ CET LOG ~iR-10~ _CET LOG -ZlR-11/CET/CEL -1R-12" CET LOG X~2A-13- CBL/VDL \2A-13'/ CET/CEL o2U-3--- CEMENT EVALUATION TOOL ~2U-10 / CEMENT EVALUATION TOOL ~2Z-13/ CET LOG ~2Z-14~ CET LOG · ~2Z-15~ CET LOG ~2Z-16-- CET LOG ~3B-4"7. CEMENT EVALUATION TOOL ~3B-12--' CET LOG ~B-12-~ CEMENT EVALUATION LOG W/ AC ~3B-16/CEMENT ~VALUATION TOOL -3C-9'/ CET LOG ~3C-10~ CET LOG . · 05-04-85 RUN #1 7468-8287 05-28-85 KUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN #1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN '#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-8011 05-31-85 RUN #'1 6000-7743 07-14-85 RUN #2 6139-8089 07-0 ~-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 kUN ~1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DIST~ISUTION: BPAE DRILLING*BL %{. PASHER B. CURRIE~ L. JOHNSTON '- ~XXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RATHMELL .... ,.!. : ~ ~' C'~ n s' ,C~3 ~ i~ ~ i o . ~ STATE OF ~~ ~ SOHIO /S~ UNION VAULT/~O*FIL~IS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISb,,JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1119' FNL, 889' FEL, Sec. 14, T12N, R9E, UM At top of productive interval 1236' FNL, 1528' FEL, Sec. 12, T12N, R9E, UM At effective depth 1308' FNL, 1263' FEL, Sec. 12, T12N, R9E, UM At total depth 1324' FNL, 1204' FEL, Sec. 12, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8980 6739 6. Datum elevation (DF or KB) R KB 82 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3C-10 9. Permit number/approval number 85-101 10. APl number 50-029-21356 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 8 8 9 1 true vertical 6674 feet Junk (measured) None feet Casing Length Size Structural Conductor 8 0' I 6" Surface 4 7 8 0' 9 - 5 / 8" Intermediate Production 8 9 3 8' 7" Liner Perforation depth: measured 8359'-8551 ', true vertical 6289'-6427', 8697'-8742', 6534'-6566', Tubing (size, grade, and measured depth) 2-7/8", 6.5#/ft., J-55 @ 8617', Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 213 SxCS II 116' 116' 1440 Sx AS III & 481 6' 3731' 320 Sx Class G 375 Sx Class G 8974' 6736' 8764'-8790' 6582'-66o1' AUG 4 995 ~ ~i[ & Gas Cons. Commission ~-~chorage PKR: Baker DB @ 8589' & Camco HRP-I-SP @ 8384'; SSSV: Camco TRDP-1A-SSA @ 1795' 13. Stimulation or cement squeeze summary Fracture stimulate A Sands Intervals treated (measured) 8697'-8742', 8764'-8790' Treatment description including volumes used and final pressure 9.5 Mlbs 20/40 & 102.1 Mlbs 12/18 ceramic proppant. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 551 849 1 1'070 138 Subsequent to operation 1513 2643 23 1109 146 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 (J~'-ev 06/15/88 Title Wells Superintendent SUBMIT IN DUPLICATE AhCO Alaska, Inc. ~i.. ~...~ .. KUPARUK RIVER UNIT .. ...... WELL SERVICE REPORT .~' K1 (3C-10(W4-6)) WFI ! JOB SC'OPE JOB NUMBER 3C-10 FRAC, FRAC SUPPORT 0620952056.3 DATE DAILY WORK UNIT NUMBER 0 7/0 2/9 5 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE ISLICCESSFUL KEY PERSON SUPERVISOR 4 (~ Yes ONO I(~) Yes O No DS-GAll I=GOS JOHNS FIELD AFC# CC# DALLY COST ACCUM COST Sig.ne~ (~ ./J ESTIMATE 998416 230DS36CL $118,228 $128,087 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Out'et' Ann 500 PSI 2200 PSI 1000 PS! - 750 PSll 150 PS! 200 PSI DAILY SUMMARY ]PUMPED "A" SANDS RE-FRAC, WELL LOOKS TO HAvE A TIP SCREAN OUT AND PACK BACK WITH 7# PPA AND TOTAL OF -:i11' 1,577 # PROP. IN PERES AND 4620# IN WELL BORE. 1114 BBLS OF FLUIDS PUMPED. MAX. WHP 5680 PSI, 3500 PSI ON 17' ANNULI. TIME !LOG ENTRY 0 7: 0 0 MIRU FRAC. EQUIPMENT 0 8:4 5 HELD SAFETY MEETING, DISCUSSED VALUE OF TEAM WORK, EXAMPLE WELL GROUP JUMPING INTO OCEAN TOGETHEP~ - 0 9:1 9 PRESSURE TEST SURFACE LINE TO 8800 PSI. 09:26 PUMPED BREAKDOWN STAGE W/360 BBLS GEL AND 4100# 20/40 LWP SCOUR STAGE. 15 BPM AND 4280 PSi. 1 0:10 PUMPED DATA FRAC AT 175 BBLS FLUIDS AT 5 TO 15 BPM AND 4577 PSI, SD FOR ISIP 2320 PSI 1 1:38 PUMPED 375 BBLS 50# GEL PAD AT 15 BPM AND 4788 PSI. 12:04 PUMPED 2# STAGE OF 20/40 LWP AT 15 BPM AND 4815 PSI7 TOTAL 9500# PROP. RAMP UP TO 5# PPA OF 12/18 LWp AT 15 BPM AND 4692 PSI. 12:07 12:46 RAMP UP TO 7# PPA OF 12/18 LWP, REDUCED PUMP RATE 9 TO 7 BPM , DUE TO TREATING PRESSURE LIMITATIONS. PUMPED 111,577 # AT 4925 PSI. NET PRESSURE ON INCREASE. 13:06 WENT TO FLUSH STAGE, PUMPED 27.7 BBLS GEL, SHUT DOWN FLUSH EARLY DUE TO DECREASED PUMP RATE AND PRESSURE. 13:1 3 SHUT DOWN AND MONITOR WHP. FOR 15 MINUTES 13:35 START RDMO, NOTIFIED DSO TO LEAVE WELL SHUT IN, UNTIL CLEANOUT. ,i SERVICE COMPANY - -SERVICE 'DAILY COST ACCUM TOTAL $o $5o APC $0 $1,2OO A PC-LA B O R $2,000 $2,000 APC-PUMPING $800 $1,700 DOWE LL-STIM U LATION $11 5,428 $115,428 HALLIBURTON $0 $6,561 LITTLE RED HOT OIL $0 $1,148 TOTAL FIELD ESTIMATE :$1 18,228 $128,087 ARCO Alaska, Inc. Post Office Bo.. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-10 Dear Mr. Chatterton' Enclosed is a copy of the 3C-10 Well History to include with the Well Completion Report, dated 8/5/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L102 Enclosure RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanticRichfieldCompany Dally Well History-Initial Report Inlt~ctl~ll: Prepare end submit the "lltlflll Itlt~rf' on the fist Wednesday after · well is spudded or workover operltlOnl are started. Daily wort< prior to Sl~Jddlng ~ould be summarized on the form giving inclusive dates only, DIItrict I County or Pari~h Alaska ]! North Slope Borough Field Lease or Unit Kuparuk River ADL 25629 Auth. or W.O. no. [Title AFE 604895 J Drill State Alaska no, 3C-10 Parker 191 API 029-21356 O~rator ARCO Alaska, Inc. A.R.Co's W.I. Prior statue If · W.O. Spudded or W.O. begun Spudded JDat, 6/25/85 J.our Cate and depth a~ of 8:00 a.m. 6/26/85 6/27/85 6/28/85 6/29/85 thru 7101185 Complete record for each day reported The above ia correct Signature For form preparation and di~{l'ibution, see Procedures Manual, Section 10, Drilling, Page· 86 and 87. 1130 hrs. 56.24% 16" @ 116' 1970'(1860'), WT. 9.8, PV 16, YP 2.2, PH 9.5, WL 12.5, Sol 6 Accept Ri~ @~730 hfs, 6-25-85. NU diverter , Spud @ 1130 hfs, 6-25-85. Drl 12¼" hole to 1970, POOH. Chg BHA, TIH. 16" @ 116 4240'(2270'), Drlg WT. 9.8, PV 32, YP 84, PH 9.5, WL 12, Sol 8 DD & Bury f/1970'-3642'. POOH, LD Dyna Dril, MU new bit, chg BHA to pck hole assy. TIH, work thru tight spots. Drl f/3642'-4240'. 2096', 45.3°, N55.7E, 1904.46 TVD, 651.64 VS, 2833', 47.7°, N60.1E, 2407.5 TVD, 118'~47 VS, 3538'~ 49.5°, N64.7E, 2870.21TVD, 1718.17 VS, 3934', 48.3°, N66.2E, 3130.53 TVD, 2016.47 VS, G & Survey WT. 9.9, PV 10, YP 6, PH 9.0, WL 10.5, Sol 8 Drl to 4836'. POOH, RU & rn 110 its 9-5/8" 36# J-55 HF-ERW BTC csg to 4816' C&C hole, mix & pmp 1440 sx AS III + ½#/sx celloflake @ 12.2 ppg. Followed by 320 sx CL "G" w/2% SI,+ 2% D-46 @ 15.8 ppg. Bmp plug. Full terns throughout Job w/cmO to surface. Tst csg. CIP @ 0530 hrs, 6-28-85. 4238', 46.7~, N68.BE, 3335.91TVD, 2240.21VS, Nl107.41, E1952.18 4800', 44.1~, N68.1E, 3733.8 TVD, 2635.44 VS, N1248.98, E2322.91 N363.8, E547.49 N654.89, g1000.49 N897.11, E1473.90 N1021.10, E1745.33 8200 (~, DRLG & Survey~ WT. 10.3, PV 13, YP 10, PH 10, WL 5.9, Sol 8 ND diverter, MU csg head. NU &tst BOPE. PU BHA, RIH, tst csg to 1500#. DO cmt to +10' new hole. Perform EMW tst; OK. Drl & suiv to 8200'. 5107', 38.3~, N63.7E, 3964.79 TVD, 2837.54 VS, N1331.55, E2507.50 5510', 39.9°, N69E, 4277.54 TVD, 3091.48 VS, N1433.51, E2740.32 6132', 40.8°, N67E, 4751.54 TVD, 3493.19 VS, N1584.34, E3113.71 6883', 44.9°, N61.7E, 5302.51TVD, 4003.23 VS, N1812.98, E3569.64 7959', 46.4°, N69.4E, 6058.00 TVD, 4767 VS, N2110, E4275 RECEIVED SEP26 Number all daily well history forms consecutively Page[no. as they are pral3arad for each well. AR3B-459-1-B ARCO Oil and Gas Company Daily Well History-Final Report Inatrdcliona: Prepare and submit the "Final R~l~elf' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "FI~al Ref3ort" should be submitted also when operations are suspended for an indefinite or appreciable length of lime. On workovers when an official lest ie not required upon completion, rel:~rt completion and representative test data in blocks provided. The "Final R~I~" form may be used lot reporling the entire operation il space is available. Accounting cost center code District Alasl~ I County or Parish Lease or Unit J Well no. Kuparuk River ADL ] 3C- i0 Auth. or W.O. no. [Title AF~. 604895 [ Drill Field North Slope Boroush Stale Alaska Parker 191 AP1 Operator ARCO Alaska, Inc. Spudded or W.O. begun A.R.Co. W.I. 56.24% IOate 6/25/85 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our I Prior status if · W.O. 1130 hrs. Spudded Date and depth as of 8:00 a.m. 7/02/85 7/03/85 7/04/85 thru 7/05/85 Complete record for each day reported 9-5/8" @ 4816' 8980'(780'), POOH to Log WT. 10.3, PV 13, YP 6, PH 9.5, WL 5.8, Sol 9 Drl to 8980'. Short trip. CBU. POOH to log. 8391', 43.1°, N73.4E, 6365 TVD, 5069 VS, N2207.44, E4562.97 8929', 41.1°, NS1.7E, 6762 TVD, 5424 VS, N2295.21, E4915.22 9-5/8" @ 4816' 8980'(0'), Rn'g 7" 26# tag WT. 10.3, PV 13, YP 5, PH 9.5, WL 5.8, Sol 8 RU SOS, log w/DIL/SFL/SP/GR, f/8970'-4816'. Log w/FDC/CNL f/8970'-8300'. RD SOS. TIH, C&C, POH, LD DP. Chg to 7" rams, 7" @ 8974' g~81~- 8980'(0'), RR Rn 215 its 7", 26#, J-55, HF-ERW, BTC, R3 csg . Cma w/375 sx CL "G" blend @ 15.8 ppg. Displ w/10.3 ppg brine. ND BOPE. Set slips, blow dn 7" csg, make cut off, install & tat pckoff to 3000 psi. Release Rig @ 2300 hfs, 7-3-85. Old TD Released rig 2300 hrs. Classilications (oil, gas, etc.) Oil Producing method Flowing Potential test data New TD Date PB Depth 8980' (7-2-85) K~nd of rig 7/3/85 Type completion (single, dual, etc.) Single Olficial reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on teal Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective dale corrected The above is correct Signature Date For form preparation and o¥stribution, see Procedures Manual. Section 10. Drilling. Pages 86 and 87. AR3B-459-3-C Title SEP2 6 Alaska 0il & Gas Cons. Cor,qmiss~r~ Number al~l~RH,~l~li~lltor'/ forms consecutival¥ as they afe'bYIfl~&l,~UClbJ'~ach wel. lPage no. 2 Olvl~lo~ of Atllfltk~lch~leJdComl'lflY ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-10 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not yet received the Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L76 Enclosures Gas 6ons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -- STATE OF ALASKA ALASKA -C_.._AND GAS CONSERVATION CO~ ilSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-101 '3. Address 8. APl Number P. 0o Box 100360, Anchorage, AK 99510 50- 029-21356 4. Location of well at surface 9. Unit or Lease Name C A T 1119' FNL, 889' FEL, Sec.14, T12N, RgE, UM__ Kuparuk River Unit At Top Producing Interval VE~D'r'r !~ 10. Well Number 1236' FSL, 1528' FEL, Sec.12, T12N, RgE, UM ~Surf. ~:~-~i 3C-10 At Total Depth ~ 11. Field and Pool 1324' FSL, 1204' FEL, Sec.12, T12N) RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 82' RKB ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/25/85 07/01/85 07/03/85* N/A feet MS L 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 8980'MD,6739'TVD 8891 'MD,6674'TVD YES []X NO [] 1806 feet MD 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, Cai, FDC/CNL, CET, G~yro 1~3. CASING, LINER AND CEMENTING RECORD ,= , I- SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 213 sx CS II 9-5/8" 36.0# J-55 Surf 4816' 12-1/4" 1440 sx AS Ill & 320 s; Class G 7" 26.0# J-55 Surf 8974' 8-1/2" 300 sx Class 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) 8790' - 8764' w/4 spf, 2-7/8" 8628' 8395' & ~600' 8742' - 8697' 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8551' - 8539' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I · Date of Test Hours Tested PRODUCTION FOR OI L-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-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 ~.. An~., .. Form 10-407 * NOTE: Tubing was run and the wel 1 perforated on 7/31/85. DRH/WC16 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29 ...... ' ~ ~ ' . 30.' . ' ~ 't.. :' : ~EoL'oGII~I~IARKERS '"- ' ...... ' '" ' ' ' ' ' : ' · ' ' : ' ' - :FORMATION TESTS ' NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH . GOR, and time of each phase. Top Upper Sand 8491' 6383' N/A Base Upper Sand 8548' 6424' Top Lower Sand 8679' 6519' Base Lower Sand 8846' 6641' 31. LIST OF ATTACHMENTS ....... ....... , Addendum . 32.-~' I h~reby certif~/"th~t --~' .... J the foregoing is true and correct to the best of my knowledge Signed (~~ ~J..~L~ Title Associate Engineer Date ~'/~ '<~" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well.should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". WELL: 71~5185 3C-10 Rn CET/GR f/8805'-8190, Rn GCT f/PBTD - surf. RETURN TO: ARCO Alaska, Inc?~. Post Offic )x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. DATE: 09-05-85 TRANSMITTAL NO:5332A **CONTINUATION KUPARUK OPEP~ATIONS ENGINEERING RECORDS'CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF HEREWITH ARE THE FOLLOWING ITEMS. . RETU~ ONE SIGNED COPY EVENTS FROM WELL SERVIC 2G-9 ~ PBU 2G-9~'- PBU 08-21-85 2G- 11-" PBU 08-19-85 2G-16 ~-SB}iP 08-19-85 2h-1-~ PBU 08-25-85 2h-l-- ' PBU 08-24-85 2U-l-" 'C' SAND PBU 08-23-85 2U-1'~ END 'C' SAND PBU & ~iISC. 08-24-85 2W-7 -" 'C' SA~D PBU 08-17-85 2W-7-'/ 'C' 'SAND PBU 08-23-85 2W-7/~ 'C' SAND PDU 08-22-85 2X-11 ~ PBU 08-24-85 2X-ll 'C' SAND PBU 08-25-85 2X-11/ 'C' SAND PBU 0~-26-85 3C-5 -'~ BhP & MISC. 08-29-85 3C-7-"~ BHP & F~ISC. 08-3 0-85 3C-8 / BHP & MISC. 08-31-85 3C-9/- BHP & MISC. 08-09-85 3C-10 /'"BHP & MISC. 08-10-85 PLEASE ACKNOWLEDGE OF THIS TRANShITTAL. E REPORTS/PRESSURE DATA 08-22-85 KUPARUK WELL PRESSURE REPORT ENVELOPE FACES: 3C-12/ STATIC 'A' SAND 07-24-85 3C-10~ STATIC 'A' SAND 08-10-85 3C-9 /- STATIC 'A' SAND 08-09-85 2Z-16-- 07-21-85 2Z-15" STATIC' 'A' SAND 07-17-85 2Z-14-' STATIC 07-20-8 5 2Z-13" STATIC 'A' SAND 07-17-85 2X-4~ PBU 08-i 2- 85 2X-4" PBU 08-13-85 2U-1'~ , 08-24-85 2A- 13- STATIC 08- 25- 85 1R-10'~ STATIC 'A' SAND 08-15-85 1R-9 ~ STATIC 'A' SAND 0~-14-85 RECEIPT ACKNO%~LEDGED: DISTRIBUTION: SPAE* DRILLING W. PAS~EE B. CURRIER L. JOHNSTON EXXON CHEVRON* ~OBIL*~ PHILLIPS OIL* ~ & M* NSK CLERK J. RATMMELL* C~CO OTIS OTIS OTIS OTIS OTIS OTIS CA~]CO CAMCO OTIS CAMCO CAI~ICO C~,ICO DATE STATE OF ALASKA* '.':.."~:;:::' · . ' ':>.'U;. SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-8 5 TRANSMITTAL NO: 5214 RETURN TO: AttCO aLASKA, INC. KU PARU K OPEkATIuNb RECORDS CLERK ATU-1115B P.O. SOX 100360 ANCHORi~3E, Ak< 99510 LNGINEEkING TKAN~blITTED RECEIPT AND OPEN hOLE 3C_ 1 O...'--~ 2,, ~ ~5" ~--- =-~--2" , 2 ,i --' "~ 2" HEREWITt~ ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED Ct;PY UF ThIS TttANSMITTAL. FINALS/SCi, L/ONE * OF E~H DIL/SFL-GR .DIL/SFL-GR DEN/NEU-GR DEN/NEU-GR DEN/NEU-GR DEN/NEU-GR CYSERLOOK DIL/SFL-GR - DIL/SFL-GR DEN/NEO DEN/NLU DEN/NEU DEN/NEU CYBERLOOK 3C-9 '-~ CYBERLOOK ~ ~ 5" DIL/SFL-GR , /~'~ --- 2" DIL/SFL-GR 5" DuN/NEO- 2" DEN/NEU-GR ~ ~ 5" DEN/NEU-GR 2" bEN/N~0-GR 3C-1 ~'"° 5'' DIL/SFL-GR - "~2" DIL/SFL-GK ~ 2" DEN/NEU DEN/NEU ""~ 5" DEN/NEU ~ 2" DEN/NEU ~~ CYBERLOOK RECEIPT ACKNOWLEDGED: SPAE B. CURliIER CHEVRON D & bi*DL URIELING*BL L. JOHNSTON MOBIL NSK CLERK*DL RAW RAW POliO 07-02-85 RUN #1 1786-8962 07-02-85 RUN #1 1786-8962 07-02-85 RUN #1 8290-8937 07-02-85 RUN ~1 7468-8937 07-02-85 RUN #1 8290-8937 07-02-85 IiUN ~1 8290-B937 07-02-85 RUN #1 8500-8900 PO RO PORO RAW RAW 06-16-85 RUN #1 3772-7569 06-16-85 RUN #1 3772-7569 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7543 06-16-85 RUN #1 6000-7520 RAW PORO 07-10-85 RUN #1 4500-8279 07-10-8 5 RUN #1 3942-8304 07-10-85 RUN #1 3942-8304 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500-8279 07-10-85 RUN #1 4500-8'279 RAW RA~ PORt; PORO 06-23-85 RUN #1 4473-8854 06-23-85 RUN #1 4473-8854 06-23-85 RUN #1 8100-8828 06-23-85 RUN #1 8100-8828 06-23-85 RUN #1 8100-8828 00-23-85 RUN #1 81U0-8~28 06-23-85 RUN #1 8100-8805 DISTRIBUT ION: SSiOl~ W. PASHER T EXXON SOHIO /SE PHILLIPS OIL UNION J. RATHMELL* BL K.TULIN/VAULT*FILM ARCO Alaska, Inc. is a Subsidiary of At!anticRichfieldCompany ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3C-10 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 3C-10. I have not yet received a copy of the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is run. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer J G/tw GRU11/L38 Enclosure ~'~:':'.~:'::~ C.~ & Gas Cons. Commission An~horage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~, ALASKA (. .AND GAS CONSERVATION CO. AISSION WELL COMRLETION OR RECOMPLETION REI:I'ORT AND LDO 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [-I' ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-101 - 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21356 4. Location of well at surface 9. Unit or Lease Name 1119' FNL, 882' FEL, Sec.14, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3C-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) i 6. Lease Designation and Serial No. Kuparuk River Oil Pool 83' RKBJ ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 1'6. NO. of Completions 06/25/85 07/01/85 07/0:]/85* N/A feet MSL 17. Total Depth (MD+TVD) 18.'Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8980'MD 8891 'MD YES [] NO E~X 1806 feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, Cal, FDC/Cal, CRT 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 116' 24" 213 sx CS II 9-5/8" 36.0# J-55 Surf 4816' 12-1/4" 1440 sx AS Ill & 320 s; Class 7" 26.0# J-55 Surf 8974' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8790' - 8764' w/4 spf, 2-7/8" 8628' 8395' & 8600' 8742' - 8697' 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8551' - 8539' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED~ OtL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c0rr) Press. 24-HOUR RATE 2~. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~": ! ""> /:-"~ 0 ~ ~ · Form 10~,07 Sub~i~i*t in duplicate * NOTE: Tubing was run and the well perforated on 7/31/85. DRH/WC13 Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include ~nterval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEPTH. · ;GOR, and.time of ~ack phase.. , ,. . - .- . . . .... .... '31. LIST OF A~ACHMENTS ._ . None 32. I hereby cert'ify that the foregoing is true and.corr~t t° the best of my know~dge Signed ~ OJ~/~_.,' ¢~~;. Title Associate Engi,eeF Date ~- ,~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. · .: Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this Well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas-Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". , STATE OF ALASKA ~- ALASKA oiL AND GAS CONSERVATION CO. MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: S~a~e of Alaska 'AJasI~a Oq and Gas Ccnservat.;on Commission 3001 Porctmine Drive Receipt of the following material which was transmitted via /4~/~/ is hereby acknowledged: DA TED: Copy sent to sender YES NO _~ STATE OF ALASKA ALASKA uiL AND GAS CONSERVATION CO,..,ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 T~ka 0ii and Cas Consen,at:cn Commission o00~ Porcupine D~ve Receipt of the following material whiCh was transmitted via ~i/ i~ ~~y ~now~g~-. · qUANTITY /.~.~ DESCRIPTION Copy sent to sender YES . NO ~_ SUB. URFACE DIRECTIONAL SURVEY r'~UIDANCE [~]ONTINUOUS ['~OOL ComPany Well Name Field/Location ATLANTIC RICHFIELD COMPANY ! · · 3C-10 ~!119' FNL,. 889' FE.L; S14.., T12N, R~E. UM5 K. UPAR,UKz NORTH SLQPE~ ALASKA _ Job Reference No. 7068[ Loooed By: MCBRIDE Date, x ~,~,~ Comput~ 8~ , ~, ~ ..... ~ - GCT OIR~:CTIONAL SURVEY CUSTOMER L~STING FgR ARCO ALASKA. INC. 3C-10 KUPARUK NORTH SLQPE~ALASKA SU~VE..Y DATE: l~ JUL 85 ENGINEER: MC~RID~ METHODS DF COMPUTATION TO3L L~CATiON' TANGENTIAL AV:RAG':O DEVIATION AND AZIMUTH INTERPOLAT[0N: LINEAR V~RTi'AL SECTION: ~GRIZ. 3~ST. PROJECTED Dh'TO A TARGE[ AZIMUTH ~F NORJH 63 OE~ 5T MIN EAST ARCO AL. AS(A, I. NC. 3,C-10 K, LJPAR~JK N3RTH SL. OPE~ALASKA TRUE SUS-SEA COURSE EASURED VERTICAL '~ERTICAL,DEVIATIDN AZIMUTH DEPTH DEPTh DEPTH DEG M[N DEG MIN COMPUTATION DATE: 25-JUL-,85 PAGE DATE OF' SURVEY: 14 J~'L 8'5 KELLY 6USM[NG ELEVATION: ENGINEER: MCBRIO~ INTERPOLATED VALUES FOR EVEN 10D FEET DF MEASURED DEPTH VERTICAL DOGLEG RECTAhiGULAR C3ORDINATES ,H3RXZ. .DEPARTJRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET OEG/IO0 FEET FEET FEET DES MIN 0.30 0.00 -82.00~ 0 0 N 0 0 E 100.00 100.00 18.00 0 15 S 52 1~ ~ 200.00 200.00 118.00 0 8 N 58 31 E 300.00 300.00 218.00 .0 12 N 76 52 E ~00.00 400.00 318.00 0 18 $ 77 lB E 500.00 500.00 418.00 0 32 N 83 37 E 500.00 599.95 517.95 3 3½ N ~b Z E 700.00 699.4'7 617.47 7 13 N ~5 Z1 E 800.00 797.9~ ?15.~3 12 27 N 47 13 E 900.00 89,5.14 81~.14 14 15 N ,~8 ? E 0.00 0.00 0.00 N 0.00 0.07 0.0~, 0.11 5 0.13 0.51 0.04 0.17 S 0.4Z 0.59 O./i 0.04 $ 0.68 1.00 0.09 0.07 S 1.1~* 1.53 0.86 0.1~ S 1.79 ~.15 5.48 1.4~ N 3.91 13.17 ~.60 8.22 N 10.6~ / 9..51 3.7~ 19.99 N Z3.1 ~' 52.15 1.66 35.7l N ~0.SB I000.00 9'91.60 909.60 16 33 llO0. gO k086.46 100~,.46 20 14 1ZO0.O0 1179.2l 1097.22 23 3 1300.00 1270.74 1188-74 15 2 1~,00.00 13'59.83 1277.83 29 3 1500.00 1~5.36 1,363.36 33 13 1600.00 1527.63 1445.53 35 16 1700.00 1608.38 1526.38 37 44 N 52 53 E 77'.57 4.30 N 58 5~ E 108.98 3.8l N 58 ~ E 146.13 1.24 N 56 55 E 185-14 3.69 N 59 11 E 231'25 4.42 N 59 32 E 282.86 3.96 hi 59 1 E 339.50 0.78 N 56 ~,~ E 39B.16 4.46 N 55 3 E 461.66 3.57 82. OO FT 52..82 N 60.64. E 80.42 N 48 56 E 69.99 N 87.09 E 111.73 N 51 89.25 N 119.0,3 E 148.77 N 53 8 E 111.03 N 152.91 E IB8.9'? N .5~, 0 F. 135.16 N 191.33 E 234.t6 N 5~* 45 E 161.16 N '136.02 E 185.85 N 190.31 N 284.87 E 342.59 N 56 15 22.1.45 hi 334.9,3 E 401.52 N 56 31 E 257.39 N 3B8.05 E 465.65 N 56 26 1900.20 17.57.4'9 1675.49 45 1~ 2OO0.O0 18Z6.94 1744.94 46 0 2100.00 1897.01 1815.01 ~5 1~ 2200.30 1967.46 lS85.~6 45 17 2300.00 Z037.53 1955.53 ~6 0 2400.D0 2105.99 2023.99 ~7 13 2500.00 ~173.61 2091.51 ~7 40 2600.00 Z240.6~ 2158.64 ~8 9 2700.30 2307.52 2225.52 47 56 2800.30 237~.49 2292.49 47 52 2900.00 2~41.63 2359.63 47 58 3000.DO 2508.20 2~26.10 ~8 28 3LO0.OO 2574.15 2492.15 49 3 3Z00.00 !639.30 2557.30 49 33 3300.00 2703.78 2621.78 50 6 3~00.00 2768.05 2685.06 ~9 3~ 3500.00 Z833.04 2751.04 49 31 3600.00 2837.77 2815.77 ~9 40 3700.00 2962.57 2880.57 49 34 3800.30 3027.59 2~45.$9 49 16 3900.D0 3093.07 3011.07 48 5l N 54 2.3 ~ 52'-).62 N 56 5 E 500.77 N 36 2~ f . 571.47 N 56 51 E 7~1.87 N 57 ~ E 812.68 N 57 53 f ~85.11 N 57 58 f 95~.37 N 5~ 5 E 1032.23 N 60 1~ ~ 1105.37 N 50 42 ~ 1180.~0 N 61 35 E 1256.'51 N 02. 55 E 1.329.11 N 53 15 E 140'~,.27 N 03 2~ E 1¢80.13 N 'a3 33 E 1556.56 N 6~ 3Z E 1633.16 N 55 2D E 1709.16 N 55 46 ~ 1785.35 N 66 5 ~. 1~61.~7 N 66 iL ~= ~937-38 N 66 L E 2012.92 3.05 1.02 0.31 0.33 1.85 0.37 0.2~ 1.37 0.33 0.46 1.65 0.50 0.69 0.42 0.55 1.2~ 0.65 0.39 0.23 0.34 0.64 197.65 N 4~.01 f 534.5~ N 56 ~ E 338.40 N 503.29 f 606o4~ N 55 5 E 37'8.04 N 562.60 f 677.8Z N 5,5 6 E 417.05 N 6Z1.89 E 768.79 N 56 9 E 456.01 N 6B1.67 E 810..13 N 56 13 E 495..1I N 7~3.17 E 893.00 N 5~ 19 f 534.25 N 805.59 E 966.6~ N 56 26 ~ 573.20 N 858.76 ~ lOgO.aZ N 5~ 35 620.50 N 933.05 E ZZ~5.03 N 5~ 48 E 647.08 N 997.69 E 1189.16 N 57 2 ~ 683.00 N 1062.5~ E 1263.~0 N 57 15 E 717.52 N 1128.65 E 1337.43 N 5? 33 E 751.5Z N 1195.70 E 1412.26 N 57 50 E 785.50 N 1253.5~, E 1487.80 N 5~ 7 E 819.54 hi 1331.96 E 1563.90 N 58 23 E 853.10 N 1400.82 ~: 1640.15 N 58 39 E 885.27 ~ 1469.70 E 1715.7l N 58 56 E 916.78 N 1539.10 ~ 1791.45 N 5~) 13 E 947.80 N 16~8.6~ e 1861.11 N 59 29 E 978.48 N ~678.15 E 1942.59 N 59 ~5 ~ ~009.07 N 17~7.28 E 20~7.73 N 5'~ 59 E CDMPUTATIDN .GATE: ZS-JUL-85 PAGE ARCD ~LA$[A~ IN':. KUPARUK NDRTH SLO~E~AcASKA. DATE OF: SURVEY: 14 JjL 85 KELLY JaUSMING ELEVATION:* ENGINEER: 8Z. 00 .FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUE-SEA CDURSE VERTICAL DOGLEG RECTANGULAR C~ORDINATES HDRIZ. DEPARTURE EASUREO V~RTICA~ VERTICAL DEVIAT~'~N AZIMUTH SiECTIDN SEVERITY NORTH/SOUTH EAST/WEST D'IST.r '.AZIMUTH DEPT~ DEPTH DEPTH DEG MIN ~OOC.O0 3159.15 3077.15 48 18 4LO0.DO 3226.01 3146.01 ~7 50 4200.00 3293.~7 321 1.~7' ~7 17 ~00.00 3361.70 3179.70 4~00.00 3~30.69 3348.69 4500.~G 350'0.37 3418.37 45 32 ~600.~0 3570.70 3488.?0 45 3 ~700.30 3641.68 3559.68 44 30 4800.~0 3713.23 3631.13 43 53 ~900.00 37~6.65 370~.~5 ~1 25 5000,30 38~3.1~ 378L.1~ 39 29 5L00.30 39~,0.57 3858.57 39 16 5203.00 ~017.84 3935.8~, 39 32 5500.00 ~094.74 4012.74 39 55 5~00.D0 ~1'71.09 4089.09 ~0 5500.~0 ~246.76 4164.76 40 5~00.30 ~322.05 4240.05 41 23 5700.~0 ~395.96 .~31~. 96 41 34 5~00.~0 ~471.71 4389.71 5900.00 ~546.27 446¢.27 41 55 6OO0.O0 6620.61 4538.62 ~I 56 6100.90 ~695.09 4613.09 41 47 6200.30 ~769.67 4687.07 41 4,3 6300.~0 ~8~4.41 4762o~I ~1 4~ 6½00.~0 ~918.43 4835.~3 42 35 6500.D0 ~991.87 4909.87 ~2 52 6500.30 5055.18 4983.[8 42 5~ 6700.30 5138.52 5056.52 42 59 6800.~0 5210.65 5128.66 W4 50 6900o30 52~1.15 5199.[5 ~5 ~2 7000.00 ~351.21 5269.Z1 ~6 21 7100o00 5419.41 5337.~1 47 9 7200.00 5487.60 5~05.60 46 5~ 7500.30 ~556.0~ 5~7~o04 ~6 40 7~00.00 5624.85 55~2.86 ~6 25 7~00.~0 5693.83 5611.83 ~6 27 T60~.DO 5762.56 5680.$6 ~6 37 7700.00 5831.06 5749.06 46 ~5 7800°30 5899.28 5817. Z8 47 9 7~OO.DO 5957.1l 5~85./2 ~7 26 DEG MIN FEET N a5 ~+0 E 2162.26 N 65 29 E 223a.04 N b4 5~ E 2~0'9.14 N ,~4 33 E 2~53.24 N 63 1:~ E 259~.?6 N 63 Z E 2a66.61 N 62 53 E N 62 4~ E 2795.87 N 62 32 E 2.860.14 N al 4L ~ 2923.58 N 6~ ZO E N 62 51 E 3051.98 N 65 l Z E 3117.3~ N 64 4? E 3183.15 N 54 2l 8 3249.39 N 64 1~ ~ 3315.82 N ~4 ~ E 33B2.~5 N 63 4~ E 3~9.33 N 52 59 E 3649.11 N 63 2~ E 3715.34 N 63 IS E 378~.Z0 N ~3 0 ~ 3~52.22 N 62 55 E 3920.18 N 63 25 E 3989.41 N 63 2~ ~ 4060.34 N 6~ 19 E 413Lob9 N 66 ~ E 420½.80 N b6 ~ E 4277.88 N 66 L E 4350.74 N 06 ~ E 4423.24 N 66 5 E 4~95.60 N 66 5 E 4568.20 N ~6 1~ ~ 4640.99 N 66 IZ E 4714.05 N 66 1~ E 4787.~6 DEG/'IO0 FEET FEET F E F:: T DE, G MIN 0.85 0.57 0 .,~5 0.5.5 0.47 0.7~, 0.77 0.42 1.92 3.35 0.36 0.72 O. 2.~3 0.79 0 °2O 0.21 0.26 0.38 0 0.20 0.43 0.69 0.31 0.16 0 0.87 1.40 0.39 .3.15 0.33 0.17 0.22 0.42 0 0.30 0.05 0.2;! 0.38 .I039.77 ~ 1815.7'7 E 2.091.40 N 60 1Z ~ tO70.3T' N 1883.55 ~ 2166.,44~ N 60 23 E 1100.9~ N 1950.73 £ 2239.,96 N 60 33 E 1131.72 N 201.7.0~, E 1312.85 N 60 42 E 1162.44 N 2082.60 E 2385,05 N 60 ~9 E 1193.10 N 21~7.43 E 2456.62 N 60 5~ ~ 1ZZ4.0Z N ZZ[1.4~ E 2527,58 N 61 Z .. / 1255.36 ~ 2274.53 E 2597.9'6 N 61 6 : 1286.89 N 2.336.~7 E 26~7.7a N 61 9 E 1317.80 N 2397.30 ~ 2735.63 N 61 ,LZ E 1347.18 N 2~5~,.62 E 2800.00 N 61 14. g /.376.18 N 2510.85 E 2.863.27 N 61 16 ~ 1~05.91 N 25~6.93 E 2926.73 N 61 17 E 1436.44 N 2623.10 E 2990'.65 N ~1 17 E 1~67.03 ~ 1679.98 E 3055.14 N 61 18 E 1495.25 N 2738.9~ E 3120.51 N 61 22 E 1523.08 N Z798.59 E 3186.20 N 61 26 E 1551.48 N 2858.4.~ E 3252.3~ N 61 30 E L580.25 N 2918.31 E 33~8.69 N 61 33 E 1609.34 N 2978.25 E 33a5.Z~ N 6~ 36 E 1638.73 N 3038.33 E 3452.08 N 61 39 E 1668.28 N 3098.17 E 3518.78 N &/. A,I E 19'~5.34 N 36¢7.9.~ E ,~134.2~ N 6k 55 E 1975.59 N 37t4.56 E 4207.25 N 6L 59 E Z005.25 N 3781.41 E ~,280.20 N 62. 3 E 2034.82 N 38~8o06 E ~352.93 N 62 7 E 2064.22 N 39t~.39 ~ ~25.32 N 61 L1 E 2093.54 N 39~0.60 E ~97.5~ N 62 ~5 E 2113.0~ N 40~6.98 E 4570.05 N b2 19 E 2152.47 N 41L3.61 E ~642.73 N 62 22 6 2181.96. N ~180.52 E 6715.6~ N 62 26 ~ 2211.S~ ~ ~267.77 ~ ~789.00 N 62 29 E [RC0 ALAS(A, INC. 3C-LO ~ORTH SLOPE,ALASKA TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATIGN AZIMUTH C~MPUTATIDN DAT~: ZS-JUL-85, PA'&E ~ DATE OF SURVEY: 14 JJL 85 KELLY BUSHING ELEVATION': INTERPOLATED VALUES FOR EVEN ~OO FEET ~F MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR Cg8RDINAT~S H'DRIZo DEPARTURE SECTION SEVERITY NDRTH~SOUTH EAST/~EST DIST.. AZIMUT~ .JE PT ;t DEPTH DEPTH OEG MIN ~O00.,SO 503~.6! 5952.51 BlO0.O0, 5102.92 6020.32 BZOO.DO 6173.16 6091.16 B~O0.30 52~4.65 6162.55 8~00.00 5317.01 6235.01 8500.00 5389.67 6307.57 8500.00 5451.90 6379.~0 5~00.~0 553~.51 6~5Z.51 8'~0~.00 5607.,~5 6.'5Z5.~3 8900.00 5680.~1 6598.~1 112. O0 PT N 55 25 ~ 4~61.18 N 69 ~$ E 5005.09 N 72 3L E 5.07~.~6 N ?~. 23 E 5142.~9 N 75 15 f 5209.97 N 75 Z E 5277.80 N 7~ 45 E 5Z~5.~1 N 7~ ~1 ~E N 7~ ~ E 5~79.70 N 7~ ~. E 553,3.~3 0.92 2.01 2.01 0.60 0.85 0.65 0 0. O0 0.00 0.00 Z~2.60 N ~955.1~ E 5533-,~4 N 63 ~8 E 8~60o00 5738.80 6656.~0 43 7 D~G MIN FEET DE~/LO0 FEET FEET FEET DEG MIN ~,R£O ~.LASAA, '[NC.. KJPAROK ki3RTH SLDPEtALASKA TRUE SUB-SEA CDURSE EASURED VERTICAL fERTICAL DEVIATIDN AZIMUTH O~PTm DEPTH DEPTH DEG MIN DZG MIN CL~MPUTArTI 3N DATE: 25-JUL-@5 PAGE DATE OF SURVEY: 14, Jjt 85 KELLY BUSHING ELEVATION:' ENGINEER: MCI~RIDE INTERPOLATED VALUES FDR EVEhi lO00 FEET OF MEASURED DEPT VERTICAL OOGLEG RECTANGULAR ,CDORDiNAT~S H~RIZ. DEPARTURE S~ECTION SEVERITY NDRTH/SOU'TH FEET DEGYlO0 FEET .0. O 0 O. O0 -SZ. O0 0 0 lO00.O0 991.60 90~.$0 16 ZO00oO0 1826.94 174~.94 46 0 3000.00, ZSOB.ZO 2416.20 48 18 ~+O00.O0 )159.15 3077.15 5000.00 3863,1,~ 3781.14 39 29 6000,00 ~6Z0.62 ~539..52 7OO0.gO 5351.21 5269.21 ~6 22 ~8,0.00 57.38.80 6656.80 43 0.00 4.30 1.02 0.50 0.85 0 0.20 3.15 0.92 0.00 82. O0 FT 0.00 N 0.00 ~: O.OO N 0 0 E 52.87. ~ 50.6~* E 80.42: N 48 56 338.40 hl 533.2~ E 606.48 N: 55 5 717.57. N 1128.66 E 1337.43 N 1039.77 N 1815.77 f ZO9Z.~.40 N 60 12 E 13~T.1~3 N 2~4,6Z f 2800.00 'N 61 1638.73 N 3038.33 f 345Z.,0~ N 1945.3~ ~ 36~7.98 E 41.3~.:Z6 N 61 22~1,09 N ~3~5.39 E ~86Z.6Z N Z442.60 N 4965.15 ~ 5533.~4 N 63 ~8 E ~RCD ALASKA~ INC. ;g-10 ',UPAR~K IOR"TH SLOPE,ALASKA COMPUTATION DATE: 25-JUL-85 PAGE. 5 DATE OF SURVEY:' 14 JUL 85 KELLY ~USH, IN~ ELEVATION:" .SI.OD ET ENGiNE.ER: MCBRIDE INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUE-SEA COURSE iASURED VERTICAL VERTICAL DEVIA'TI~N AZIMUTH DEPTm OEP'TH DEPTm DEG MIN DEG MiN -82.00 0 '0 N 0 O E 0.00 0 14 $ 51 11 ,f 100.00 0 8 N 61 5T 'E 200,,00 0 11 N 59 49 E 300.00 0 17 S 79 10 E 400.00 0 27 S 87 17 E 500.00 Z 3'7 N 47 3'3 E 500.00 6 28 N ~ ~ E 700.00 11 ~6 N ~7 '7 E 800.00 l~ 5 N ~8 I E 900.00 16 14 0.30 82.00 182.00 282.00 382.30 ~82,.20 582.02 682.60 183.70 68,b.~6 0.00 82.00 122.00 232.00 382.00 5~2.00 682.00 882.00 983.3B 9,~2.00 ,095.Z4 1082.00 1000.00 20 4 203.02 1132.00 llO0.O0 23 5 312.~3 1282.00 1200.00 25 2~ ~25.~7 1382.00 1300.00 30 8 5½4.25 1482.00 l~O0.O0 34 37 566.)4 1582.00 1500.00 36 31 795o25 1682.00 1600.00 41 40 935.11 1782.00 1700.00 ~5 56 078..68 1882.00 1800.00 45 18 :220.68 1982.00 1900.00 ~,5 22 :36~.71 2082.00 2OOO.O0 ~,7 1 '. ~12. ~'6 2132.00 2100.00 ~.7 43 :661.91 2282.00 2100.00 ~7 56 ::lli. 19 2382.00 2.300.00 ~+7 50 :~60.53 Z4:a2. O0 Z~O0.O0 ~6 20 ~111.99 2582.00 ' 2500.00 49 8 i166.07 2682.00 2500.00 ~9 5~ S~21.~6 2782.00 2700.00 ~9 2~ )575.61 2882.00 2800.00 49 ~l )719.'95 2982.00 2900.00 49 30 )883.15 3052.00 3000.00 '*8 58 '034.26 3182.00 3100.00 48 6 ~.183.08 3282.00 3200.00 47 2.3 i329.57 3382.00 3300.00 ~6 31 i,~,73 . T2 '3452.00 3600.00 45 41 ~515.96 35~2.00 3500.00 ~4 58 W756.~3 36,~2. O0 3500.00 ~ 17 ~89&..~5 t782.00 3700.00 ~OZ4.~Z 3882.0'0 3800.00 39 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET 3EG/IO0 FEET FElT FEET DEG 0.00 O.OO 0..00 ~ 0.00 0.04 0.14 0.06 S 0.07 0.26 0.06 0.19 S 0.39 0.53 0.21 0.06 S 0.61 0.92 0.0!i 0.05 S 1.05 l.~O 0.54 0.1~ S 1.65 3.22 5.05 0.78 N 3.2i 11.17 3.75 6.73 N 9.15 25.32 4.73 17.65 N 20.67 48.99 1.31 33.5~ N 38.14 N 51 5~ f 7~.85 N 5,8 4~ E 107.32 3.94 N 58 1 E 147.31 1.21 N 56 59 f 191.37 4.01 N 59 4~ f 243-/4 4.36 N 59 17 E 307.59 2.13 N 57 4~ ~ 37a.38 3.6~ N ~5 a E 458.91 3.~9 N 55 15 E 55~.~3 2.42 N 56 13 E 656.46 0.56 N 56 52 f 75~o~6 h 57 43 E 859.37 N 58 0 E 967.53 N 50 ~ E 1078.16 N O0 4~ E 1188.78 N ,52 35 f 1199.59 N 63 18 f 1413.33 N ~3 33 f 1530.54 N 64 ~ E 1649.48 N 65 ~1 ~ 1766.76 N 06 9 E 188~.25 N 56 { f 2000.12 N 65 ~Z f 2113.44 N 65 23 E 2223.51 N 54 5% E 2330.62 N 64 35 E 2~3~.½5 N 53 47 ~ 2535.60 N 53 9 ~ 263~.23 N a2 53 E 2T28.31 h 62 43 E 2612.38 51.10 ~ 58.36 E 77.55 N 48 ~.6 E 69.13 N 85-66 E 110.08 N 51 5 89.8.8 N 120.03 f 1/-,9.95 N 5,3 l0 E 113.91 N 157.32 E 194.2,3 N 54 5 141.52 N 202.12 E 246.7,~ N 55 0 173.90 N 257.37 ~ 310.61 N 55 57 210.67 N 318.19 E 381.61 N 56 29 E 255.78 N 3~5.77 f 462.87 N 56 27 E 312.14 N 464.5~ E 559.67 N 56' 6 E 369.66 N 550.00 E 662.68 N 55 5 E 0.63 1.06 0.43 0.72 0.45 0.89 0.73 0.63 0.5~ 0.36 4Z5.09 N 634.21 f 763.49 N 5S 10 ~ 481.35 N 7Z1.26 E 867.13 N 5~ 16 E 539.13 N 813.40 E 975.,a5 N, 55 17 E 596.47 N 9~8.51 E 1086.82 N 55 4~ ~" 651.13 N 1004.92 E 11)7.43 N 57 ~ C 704.05 N 1102.39 E 1308.03 N 57 26 E 755.59 N 1203.80 f 1411.29 N 5? 53 f 807.97 N 1308.67 E 1537.99 N 5~ 16 e 860.10 ~ 1415.57 E 1656.38 N 58 ~3 E 909.13 N 1522.1~ E 1772.,97 N 59 9 E 0.40 0.47 0.32 0.7~ 0.69 0.65 0.69 0.38 3.08 0.78 957.03 N 1629.51 E 1889.76 N 59 3~, E 1003.92 N 1735.67 E 1005.10 N 59 57 E 1050.27 N 1839.03 E 2117.80 N 60 16 f 1095.76 N 1939.42 E 2227.56 N 60 32 f 1140.83 N 2036.51 E 2334.28 N 60 4,4 f 1185.04 N 2130.46 E 2437.87 N 60 54 if 1129.00 N 22Z1.5~ E 2538.85 N 6l 2 f 1273.1~, N 2309.77 E 2637.~,1 N 61 8 E 1315.90 N 1393.5~ f 1731.45 N 61 11 E 1~54.2g N 2~8.~0 ~ 2815.51 N' 61 1~ E COMPUTATION DAT~: 25-JUL-B5 ~RCO ALAS<.&, INC, idP,~RUK iDRTH DATE DF SURVEY: 14 JUL 85' JELLY CUSHING ELEVATION: ENGINEER:: MCBRIOE INTERPOLATED VALUES F'DR ]EVEN log FE:ET OF SUB-SEA DEPTH TRUE SUB-SEA £2, URSE :ASUR~.D VERTICAL VERTICAL DEVIATION AZIMUTH DEPTd DEPTH DEPTH DEG MIN D~G MIN i153.5B 3982.00 3900.00 39 2-4 ;263.~0 3082.00 4003.00 39 51 i~,lA. ~2 ~182.00 4100.00 40 46 i546.70 ~282.00 ~200.00 ~1 8 ~5B0.01 ~382.00 ~00.00 ~1 33 ~3.7g ~82.00 4~00.00 ;94~.07 ~582.00 4500.00 ~1 58 ~082.64 ~682.00 4600.00 ~216.52 ~782.00 4700.00 41 40 ~3~.~3 ~882.00 4~80.00 42 aZ.OD N 63 17 iE 3'775.03 N 62 56 E 3867.81 N 63 1L E 3'961.2.7 N 63 2. l ~ 4061.20 N 65 30 E 4164.51 N 66 ~. ~. 4271.90 N 66 ~ E 4378.22 N 66 ~ E 4483.19 N b6 12 ~ 4695.~5 0.58 0.45 2.41 0.67 0.25 0.23 0.13 0.24 0.44, 1.64 1.392.00 hi 25~0.93 E 2.897°24. N 61 17 E- 1451.35 N 2,613.75 E 2980,01 N 6,1 17 E ~71.27 ~ 2686.41 ~ 3064.,66 N 61 18 E 1508.16 N 2,7,66.7,~ E. 3151.0:',9 N 6.1 24 ~ 1545.77 N 2B~6.46 E 3239.10 N 6I 29 E 1584.2~ N 2926.55 E 3327.85 N 6[ 3~ ' ~623.45 N 3007.15 E 3417,39 N 6~ 38 ~663.08 N .308T.6~ E 350T.Oa N 6~ ~1 ~ L702.96 ~ 3157.60 E 3596.36 N. 61 44 ~ 1743.40 { ,326~.~2 ~ 3685.55 N 6~ 4~ E 0.09 1784.75 N 3329.49 i 3777.67 N, 61 48 /~ 0.2,9 1826.67 N 34t2.21 E ,3670..4:~ N 61 50 E 2.49 1869.14 ~t 3495.53 E 3963.B9 N 61 51' E 0.40 1913.85 N 35i14.91 E 40~'3...79 N 61 54 E 1.79 1959.17 N 3677.75 H 4167.0'4 N bi 57 E 0.20 2002.82 E 3775.9~ E 4274.23 N 62 3 E 0.65 2045.9'9 N 3873.1~ E 4360.37 N 62 9 6 0.21 ZOaB.5Z N 39~9.23 ~ 4485.1~ N 62 14 E 0.42 2131.38 N ~065.82 E ~590.60 N 62 20 E 0.31 2174.45 N ~153.50 ~ ~697.12 N 62 25. E 0.53 1.45 2.05 1.67 I .06 0.84 0.00 0.00 0.00 r922.Ol 59,82.00 5'900.00 47 31 3069.50 $082.00 6000.00 46 42 B212.~2 5182.00 6100.00 44 3b ~351.Z6 5282.00 6200.00 43 36 B.48 9. G4 53'~2. O0 6300.00 ~3 29 B627. Y6 6482.00 6~00.00 ~3 3O B765.16 6582.00 6500.00 43 7 B902.~6 56~2.00 6500.00 43 7 B~80.O0 5738.B0 6656.80 43 7 ~½66.33 ~982.00 .AGO0. O0 42 53 :~622.. 94 5082.00 5000.00 42 48 ~759.83 5182,.00 5100.00 44 0 ~:~01.21 5282.00 5200.00 45 11 ?045.01 5382.00 5300.00 47 0 rlgl. BO 5482.00 5400.00 46 54 7337.81 :5582.00 5500.00 46 32 rq, 82.84 5682.00 5600.00 46 2-3 rb28.33 5782.00 5'700.00 4.6 42 r77,~.50 58~2.00 5300.00 ~,7 5 VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ., DEPA'R'TURE SEC'TION SEVERITY NORTH/SOUTH EAST/WEST DIST.: ~:ZIMUT~fl FEET OEL~/IO0 FEET FE~T FEE'I, D, EG ARCO ALAS(A, INC. 3C-lO KUPARJK NORTH SLOPEsALASKA TOP UPP=R SANO BASE UPPER ,SAND TOP LOWER SAND BASF. LO~IER SANE) PSTD TD COMPUTATI3N DAT~: 2..5-JUL-B5 DATE OF SURVEY: L4 JUL 85 KELLY BUSHIN$ ~LeVATiON=' ENGINEER: MCBRIDE B2.O0 FT INTERPOLATED VALUES FOR CHOSEN HO2IZONS MEASURED DE?TH 8491.00 B548.00 86'79.00 ~i8~6.00 8893..00 8980. O0 SURFACE LOCATION .AT ORIGIN: ~119'" ENL, 889' FEL, SEC 14., TI'ZN,.~ RgE,UM TVD RECTANGULAR .COORDINATES FROM K5 SUB-SEA NORTH/SOUTd '~EAS'T./~ES'T 63B3.13 5301 6ale.38 6342.38 6519.23 6437.,23 664~.00 6559.00 6'738. BO 6656.80 235,~,~96 N.. 4,641.,,23. E 2.36~.94 N '4679.,?.7 F. 2388.34 N 4766o, 5e if 2~,Z6.54 N 4906.,~7 E 2~42.50 N Z~gbS,,.~L5 E ~,RCO ~.LAS~A, INC. 3C-10 (,UPARLJK i~RTH SLDPEeALASK~ MA,RKe. R TOP UPPER SAND BAS~. UP~ER SAND T3P LOWER SAND EASE LONER SAND P aT ~ TD COMPUTAI'I2N DAT~.: 25-,JUL-85 PAGE DATE DF SURVEY: 1,4 JdL 85 KELLY 6US~ING ELEVATION: ~2.02 ENGINEER: MCBRIDE 0~:~ ~.~0~000:~: STRAT ZGRAPHIC SUMMARY ME:A SUeR E L1 DEPTH BELOw KB ,SURFACE LOCATION ORIGIN.-- 1,.1,19m FNLe 889~ DELe SEC I*~ T12N TVD RECTANGULAR CDORDIN.&~ES SUB-SEA NO RTH/SOUT~" E~S~"WE S'T 8~91.00 8548.00 8679.00 88~6.00 8891.00 8gBO.O0 6.383.13 be2~.38 651 '9.13 66~.1.D0 6,573.B4 6'138.80 6301.13 6342.38 b437.23 6559.00 6656.80 2354.96 N z~54,1 o'21. Z3,64..9~ N 4,67~m.27 2~8Bo34 N ,67,6 6.,. 54 2¢1B..~3 N 4876.79 2~Z6.5~ N 4,:906 o ~, 7 2~,~2.60 N 4965,. L 5 FINAL WELL LOCATION &'T TO: TRUE SU~-SEA MEASURE] VERTICAL VERTICAL DEPT~ DEPTH DEPTH 8g~iO.Og 6'73g. 80 6656.80 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG M[N 5533.64. N 63 48 E SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3C- 10 F I ELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 14 JUL 8S REFERENCE 00007068! 2:4:3. WELL NAME: 3C- 10 SURFACE LOCATION: '19' FNL, 889' FEL, S14, T12N, 1 , UM VERTICAL PROJECTION -!000 0 0 !000 2000 3000 4000 SO00 GO00 "~T~ ~ ~ ~ ~ ~ ~j I I I I ~ I j j ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ ~ . .... .._: ~ ~_.~ .... ~.~_~..~.._~_~...~..~.....;...~...~.'..x.~...;-~.~- l J ii ~ ~ F' T'FR [ i'T%L..]~ ~..4-Li-~~.4-i-L~.~-~+-k-.-.¥-l---~ i iii -iq-+-f i it +-'-ff-++i i-H-f' ~::i:i~W"~F~T7~44! !ill i liiiilll {ii~iil i li~. i i:i::Ci~[::AMi_ ii ~ : : : ~ : ' : : ' : ~ ' L4 ~-~; ~ ~ ~ 4 ~ ~ ~- ' ~-~-~--?~-~--r"~'"?-?~-".'"~"T'T"~'~'I-~- ~I ~ ~ ~ ~ ~,~'~ ~'. ¢ '-~ ~ ~ ~ ~.~ ~.--~.g.i...~. 4.&i-$....~-i-4-.; ..... i..4-;..;....4 . ,..;....-i-~..;..i.-.4=.~.+-~......+.+.+.+......'-?.+..e- ~~---~?--?~-~--?-?-~--t----~---?-??-,~-w-?-?-%?~ T ............. I ......... , .... ~ , , ~ .... . +.., , , ,_ ._, , , z... ,. ! i 1 .... ;-..i..4...i ...... ~.i...~- -p.~.i...~...--~-4.=~..i- .4-4 -i.=i--.~-+-{-~-..~-.. ,-~-~,--{--{--i-.~--w :--{.--, .-~-!-.~---i. -.i...~..{.,.~ ...... +,..i-?..1,.-, ,.i,..?-,?--i,., ,-T'T%~' ?~ F% ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~_M._ ~& i i i ~4-:-~... ~.~.~i-.,-i.~- ;.i..4...~..,.-~..i.%..;.-- 4-g%.~.---+-~-~-~.-%4..44- --.4.~.-~-:: ~ ~ -~4~4-.~-~-~ ; . ; ,4--~~~--; s s . . -+~q. .......... ~ ~ ~.~. ~ ~'q'-;'-~'"WT'~'"' '"w'7%-~4 ..... f'"~'-7"~-.. ' ~ ~ ....... i'"??q'"?"?"t" 4.4.4-~...l.4-L.~-~. _;.i._L44.4..4.4.4- -L4..&4--~-~4..~-i-~¥+~-q~.~ i ~ !-¥-l--~.-~-+-~-= .fffi-4-?+-t.i.--t-t---ff'-'t"t-f-','"f"?' r"r"""?"t"r'T"r"i'TT'r" ...~.~¢~44 ~ ~4..4.-~4..;...~.~! l! !~ ~',: i: ~i +~+-~--,-i-,ff-hf-t-~---.-?--?f-*rLt-t--'t-"'t'"t-="tt-t"r'~-r' .~4~- i ~ ~~--~4-q f ',ill ~i ~ ~ ~ ~ 'jff'~? ~--ff'--U~'~'"~'""t'~ff'"t"t-~ TW"?"-T'T'T"i-t"%~'T'~- ! 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'...L..4_=!_..L.&..L=g.-.g-.....2=-~--g...g..L..L.-g--.g 4 J...,..-g...l..,;--.; ........... ~...~...~...~...?.;...~...~..4 ............... · '~--~"?'?"~-'~'w~ ..... ~T~'~"T'TTT"?V?'fTTTT"-T'T"~Fi'~ ~ ~ ~ ~: ~,~ ~ i :, ', ,, ~;- · PROJECTION ON VERTICAL PLANE B3. - 243. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/1000 IN/FT 7OOO 83. WELL NAME: 3C- 10 /-"':9' 889' FEL S14, T12N, 1 SURFACE LOCATION: FNL,. , . NORTH !~000 REF 000070681 4OOO lO00 -]000 -~000 SOUTH -9000 -2000 ~EST HORIZONTAL PROJECTION ~{;~LE : 1/lO00 IN/FT , ; ... ~ ~ : : _'. ! :. ~ ~ ~ _: _: : _.. : ~ _.. ... : _: .. .: : ; : : : : : : : : : : ~ : : : : : ~ ~ ~ ~ i. iiii !!ii iiii iiii i'~i'i iiii iiii iiii iiiiiiiii iiii iii~ iiii i~!! ~!l! iiiJ- ii!! !i~! !i!~!ii_i_.L.J..ZL4_~i iiilJ~:i~ i~!~ ii~ ~ ~i] ii~i i~.L~ :~.=q~w :~: iii: ;;z4- .... 4--~-4..,~.~i -~;! !!;'! ~iil '~ ' ! -". -". ; ,~-: i~'':' :;~ ; ~-: ~-,-4-4-i-4- [iii ii~il '-.~iil Hii i,i,!iliiii iii!/ !Iii ~Y"'[Ti i .:Y'Y?" i i i ifil l! :..~ ! ' i :' '::-Vi .: i T'Y'~' :TI-r~..?T-: ~ i i i ~ i '-'?:'I-~-.,I -'..?-'.-~.-?.. ----~.'? ~ :. '-b...w-~-~.-.-r-. ~-w--.~?-~..* ..... :- ........ ~-~bl::-!.~¢.¢.~,~.iH! i! ~>~J~i i ! :ii!!: :' :' , ~ '-' '-': .... ' .... . ~. ~ ~4~ '-4--.~.- ~,-~- ":' :' :- -' ; -: :' ~ ~ -" -: :- ~ ~ -: . ; L~-4- -" -" i- ~ ~ ~ -: -4-4 J - ~ -: -' -i I i i ! i ..~? ~"P.f-r.'%."~t-~?'i~..~.: ~ l ~ i i i i i .k..+-½ i i ~ i ~ ..f i i: ' I i-.t-..'.'- '~-t..: i: i i i i ~ I t-~~-t.'- ~ i ~ 74-%-f- ~- ~.= ."P+- ' .-P+--~.-+--I'--:'.-H'.~--ff ..... i.-+.'---.~.-.'-~ -: .~: .~.. -+-i--i-~ -+-: .+-~:,-++: --.~-.~ -~-f-: +-~--- -~-P: .,~-~--~-..~.-~--~--,--.~-+-H~ ...... ?-i-~,-~" -i-; +-+; '~-' -~-+-~-p~-F.. ~-,..'-----½H.+H-++-----~---~---~--i-.-½~+ .-~-P -+-H--+--H-~--t.-F½~- ~-.~-H--H-:,-b.-~i---' .,:...i ..... i--HH'.--. -H.-.~-P-H'-H"- -~ = = ~ .... ~' ' ~--~- · ~--~-~--~-4-~-w-- · ' ~ ~ : ~ ' ~ ' ~ ~ i .... ~ = · · · ' · '-- '.' .' 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I ............... ! .... ; : : : i : : : : : : : : : : : -: : : : : : : ! : i ! , ~ , · - : : : : : : I ~ ~ , : : : : :l: : : : : , : : ~ : ; : : , i : ' - : : : : : : ] ~ i, [ ..' : : : : . - : : - : : :~..~l~j~~: J - : : : : i · ! i i : J : [ ~ I : ~ i, : : .1- : :~: ~ ! ! ~ : : : : : : : ~ [ :~ ~ t : ~ : : : : .~ : : : : : : : : l~ : : : : : : : : [ i .: .: i : : : : : : : : I · : : : : : : : : : : : : : : : I---?.-.?=-~'HT-T-,~---?.-~...m-~-~-=-?-?--?--~-? .1-~;~...: [ [ [ [ i [ [: ] .1- i"i-~-t-t% i ! t-H--t:-t-'~-:-~'t"'t-t-:-"t'"t'"t-t'" '"t"'t'"?'"H"'t'"t"'t"'t"' .... -l~..': ..... ;-H i. : : ~ ~ : · :'% .... : : : : : ~ : : : : : : l'??':'~-'--?l"~'?? .~-'717----:'"':-'-~"f1"?"71 '-?'T?.--~ :...?.?.~...~.~-~.?,.~?.....?..?._t...?.~,.~._?...?_.!_~...?._?~.?...?_~_?_.~??. _~??..~_ .~..??_?m. ~._ .~..?.?...~_}...~,_? .... ?,~_..._?...t...~l..?...?...?..1 ........l.?...?.~ ...... ~...:..,~ ...... ?.......?...?...?,,.?..?.l.? ....... F4-.i.-..,:'"4..L~,.-bLj..~.g44444-.,~-4.--b4..-;-4444-b~--L-.M-b~4-.::..-¥ ~L~.--b,.'4-L~4-..-.J-..~. i4.4-..LLLLI...~...~..,LL.F:...L.i...-~.-. ~4.4...:;..4...`L-~.~-4...`~-¢...z.-¢-..LJ~-:`-4..4."g-~".L.-`;"4..4..4-`~-~" -.,:--g--~--~4-~.-4--Mg.. -~-~.4--.-;,-~-k.~---. ~g-..~.. ~.-4-..i -.:-..-:...:,..--~ ...L.z.. ,; ,~ ..]...: ~ .4...~ ..... ~..4..~...L..b..L...L..L..I... -~"-~--~---~ i i,/~: ~:I-t;-Ft'T'~'~-FY'I-?'~"Yl-r~?"r~'~-t-?--FrFI'''rF~'~ ......: :-" : I~ :''''~'-''''''''''ll'''''''' ..... ?"?;'"~"'I'"Y'FR ...... ~'":'"~ ....... '"" .............. I: -1000 0 1000 2000 3000 4000 ~000 8000 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL N~IE AND NUMBER Reports and Materials to be received by: ~.~ '-' ~,~-"~.~,~-~-'~ Date Required Date Received Remarks CompletT.ion..~ Report:_~ ...... Samples Mud Log . ' ~ :~ Core Ch~ps , " Core Description . Registered Survey Plat 7 ~~ ,~,~ ~ --~:" ~'I~ Directional Surv Drill stem Test 'Reports Production Wese Reports f . ~: - , ~; . . . ~ . ARCO Alaska, Inc. ~ Post Office Bo.. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 6, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3C-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. I have not yet received the Well History. When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRUIO/LI04 Enclosure RECEIVED AUG 1 6 ~tt5 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA · ALASKA ~ _ AND GAS CONSERVATION CC ~tlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-101 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21356 4. Location of well at surface 9. Unit or Lease Name 1119' FNL, 882' FEL, Sec.14, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 3C-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 83' RKB ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 06/25/85 07/01/85 07/03/85I N/A feet MS L N/A 17, Total Depth (MD+TVD)8980,ND 18. Plug Back Depth (MD+TVD)19. Directional SurveY8891 'MD YES [] NO r-~xx [ 2o, Depth where SSSV setN/A feet MD I21' Thickness °f Permafr°st1700' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/GR, Ca l, FDC/Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 213 sx CS II 9-5/8" 36.0# J-55 Surf 4816' 12-1/4" 1440 sx AS Ill & 320 s; Class G 7,' 26.0# J-55 Surf 8972' 8-1/2,, 300 sx Class G - 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SOUEEZE, ETc. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A --, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OiLRATIO TEST PERIOD ~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 AUG 1 6 Alaska 0il & Gas Cons. C0mm~ssi0n Anchorage Form 10-407 TEMP/WC72 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. , . . . ~ ~ ,- · . , 30~' ' ' ';:' G~oEoGic M~,RKF~R'S .. , ' -~" :: .' ':~ ;. : ..7.-' .~ "FOI~MATION TESTS . .... ' ;,7:: .' .': '" '"~'- "'~' ' '~' :'" '-'~'"" ~ · " ''" :' .' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A . 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct ~o the best of my knowledge Signed ~,{./']~,f)%/~,~-'J ~~-,/~--~ Title Associate Engineer Date .,, INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If n° cores taken, indicate "none" ARCO Alaska, Inc. Post Office Bc -)0360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton- Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) If you have any questions, please Sincerely, Gruber Associate Engineer JG/tw GRU10/L120 Enclosures L1-14 L2-20 call me at 263-4944. RECEIVED AUG ! 1 85 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TRANSHITTAL NO: 5285 ~TURN TO: ARCO ALASKA, INC. KUPAt~UK OPERATIONS ENGINEEkING t~ECOI~DS CLEkK ATO-1115B PoO. BOX 100360 ANCHORAGE, AK 99510 £KANSMITTHD HERE~4ITH ARE THE FOLLOWING IT~4S. ~ ACKNO~¢LEDGE KECEIPT AND RETURN iN BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS 3C-11 06-23.-85 RUN # ONE SIGNED COPY OF THIS TKANSMITTaL. LISYINGS (ONE COPY OF EACH) 1 4427.5-8881.5 REF 970597 ~1 1785.0-8987.5 t~EF #70620 #1 3920.0-8332.5 REF #70642 #1 4617.5-8747.5 t~EF #7U706 #2 3280.0-6803.5 t{~F #70229 ~1 4021.5-8261.5 REF #70641 #1 2190.5-9257.0 REF #70598 %1 3273.0-7270.5 t{EF #70555 #1 2092.0-8415.0 REF #70634 #1 2658.0-6620.0 REF #70562 #1 3876.0-8334.0 REF #70600 #1 4180.0-8538.5 REF #70639 #1 4409.0-9412.5 REF #70661 ~1 3531.5-7534.0 i~EF #70704 3C-10" 07-02-85 RUN 3C-9~' 07-10-85 1{UN ~C-7~ 07-31-85 RUN 3B-14-- 03-20-85 RUN 3B-12-' 07-03-85 RUN 3B-11~' 06-26-85 RUN 3B-10 ~ U6-17-85 RUN 3B-9-'~ 06-10-85 RUN 2Z-15" 06-19-85 RUN 2Z-14~' 06-28-85 RUN /Z-13' 07-05-85 RUN 2Z-12~ 07-20-85 RUN !Z-11'~ 07-27-85 ~UN %N ~OX 2 OF 2: 3PJ~'LN__.HOLE LIS TAPES PLUS 'W-16~/ 01-28-85 RUN # iV-14~/ 05-16-85 ~V- 12~/ 04-22-85 'U-10~ 04-11-85 U-7~ 03-1-9-85 A-13/~ 07-16-85 .R-13'/ 07-27-85 _R-12/-~ 07-20-85 -R-11'~'' 07-13-85 -R-10~'''~ 07-06-~5 R-9// 06-28-85 RUN ~ ~UN ~ ~uN # }(UN 91 ~UN ~1 kUN #1 RUN #1 RUN #1 RUN #1 RUN #1 RUN # l&3 LISTINGS (ONE 1 3116. U-7038. 1 3047.0-7086. 1 3960.0-9265. 1 2972.0-7063. 3594. b-8179. 7649.5-8160. 3940.0-8578. 3935.0-8277. 3810.0-7213. 2991.0-8738. 3991.5-8131. 0045.5-7103. COPY UF 5 REF 5 ~EF 0 REF 0 ~EF 5 ~EF 0 ~F 0 REF 5 REF 5 REF 0 REF 0 kEF EACH) %70436---REVISED ~7U614---tLEVIS~D #70613---HEVISED #70612---kEVISED #70505---REVISED--- #70645 #70702 #70660 ~70643 #70640 #70601 #70509 ECEIPT ACKNO~4LEDGED: PAE · CURRIER ~EVRON & M Dt~IbLING L. JOHNSTON MOBIL NSK CLERK DISTI~IBUTION: W. PASHER EXXON PHILLIPS OIL J. P, ATHMELL DATE: ~ Q? ~ ~J:23 CoDs. Commission STATE OF ALASKA~ ' SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Sta~ b{ Alaska Maska Of? and Gas Conservation Commission RE: Receipt of the following material which was ,~,~:'! transmitted via is hereby acknowledged: QUANTITY DESCRIPTION -- ~,,,o,~ra, e' lan; RECEIVED: DATED: Copy YES sent to sender NO k../ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO,~-..,ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Alask~ Alaska Oil and Oa~. '-' ' ~ozsev,-at, on Commission 3001 Porcupine Drive Anchorage, At~ka 99501 Receipt of the following material which was / transmitted via is hereby acknowledged: Copy YES sent to sender No ~- STATE OF ALASKA ALASKA O,~ AND GAS CONSERVATION COI~..,IlSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~lX~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-101 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21356 4. Location of Well atsurface 1119' FNL, 882' FEL, Sec.14, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 82' RKB I 6. Lease Designation and Serial No. ADL 25629 ALK 2562 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 36-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of July , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 1130 hfs, 06/25/85, Drld 12-1/4" hole to 4836'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8980'TD (7/2/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8891'. Secured well & RR @ 2300 hrs, 713185. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62,5#/ft, H-40 weld conductor set ¢ 116'. Cmtd w/213 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4816'. Cmtd w/1440 sx AS III & 320 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 8972'. Cmtd w/300 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/8970' - 4816' Cal f/8970' - 7300' FDC/Cal f/8970' - 8300' Cal f/4816' - 1810' CET f/8805' - 8190' Gyro f/TD to surface 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED & v~_~ J~t~~ TITLE ....... Associate Engineer DATE ~'/4'~ NOTE--Report~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRH/MR10 Submit in duplicate ARCO Alaska, Inc. Post Office Bo. }360 Anchorage, Alas~<a 99510-0360 Telephone 907 276 1215 June 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the June monthly reports for the following wells' 38-9 3C-11 2V-16 9-33 L2-20 38-10 3C-12 2Z-14 9-34 L2-24 38-11 1R-7 2Z-15 11-8 4-13 38-12 1R-8 2Z-16 11-13 11-5 3C-10 1R-9 4-30 L1-10 11-6 (workover) (workover) (workover) If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU10/L63 Enclosures RECEIVED J U L 1 5 1985 '~as~a Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -'-'- ALASKA C._ AND GAS CONSERVATION COl, _,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well E~ X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well at surface 1 I I 9 ' FNL, 882' FEL, Sec.14, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 83' RKBI ADL 25629 ALK 2562 For the Month of June , 19 85 7. Permit No. 85-101 8. APl Number 50-- 029-21 356 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3C-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1130 hfs, 06/25/85. Drld 12-1/#" hole to 4836'. csg. Drld 8-1/2" hole to 8033' as of 6/30/85. Ran, cmtd & tstd 9-5/8" 13. Casing or liner run and quantities of cement, results of pressure tests 16" 62 5#/ft, U-40, weld conductor set ~ 116' Cmtd w/213 sx CS II 9-5/8" 36 O#/ft J-55 BTC csg w/shoe @ 4816' Cmtd w/1440 sx AS II I & 320 sx Class G 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 6. DST data, perforating data, shows of H2S, miscellaneous data NONE o " C0;i,[lhu¢10R 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED NOTE--Repor&/on¢/ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· ...... TI:'MP/MRR7 Submit in duplicate MEMORANDUM State of Alaska ALASKA OILAND GAS CONSERVATION COI~ISSION DATE: FILE NO: TELEPHONE. NO: SU BJ ECT: July 1, 1985 D.BDF.50 BOPE Test on ARCO's 3C-10, Permit #85-101, Kuparuk River Field. Friday, June 28, 1985: The BOPE test began at 1:00 pm and was cOncluded at 9~00 pm. As the attached BOPE test report shows, there were three failures all of which were repaired or replaced before I departed the location. In summary, I witnessed the BOPE test on ARCO's 3C-10. Attachment t3?-C)OIAf Rev. 10/79) o&b 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ,Inspector ~~~ ~,~L,,I . !~"-"'-~ /~*~"~ Operator' _~~~i~7 Date Well Represent at ive,~/~W Location: Sec //--/ V~_i__~ ~' M L2 Location, General f) ~ Well Sign~' General Housekeeping~Rig ~)~ _ es rw D/6 Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor G~s Detectors ~.~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test P.ressure ~_~0~ 0 ~/~6~asing Set @ ~/~/L ft. ACCUMULATOR SYSTEM Full Charge Pressure ~9~-D psig Pressure After' Closure~~ psig Pump incr. clos. pres. 200 psig -- min~__sec. Full Charge Pressure Attained: ~ min _~'..sec. N2 ~ ~D.~ / ~-0 / ~ ~..~ ~:r'O psig Controls: Master Remote~.~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure_ Choke Manifold~./~Test Pressure3o~ No. Valves /~ No. flanges ~ Adjustable Chokes ~ Hvdrauically op%~ted choke , . Test Time'~:- hrs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: /~/j~"'//~..,~ ~ ~....~07~"~ ,/~/~*~//~ ~~ /~~~ j' ~~~~ Distribution orig. - AO&GCC cc - 0perato? cc - Supervisor ARCO Alaska, Inc Post Office ~,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3C Pad Wel 1 s 1-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L113 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i Y = 5~995~835.15 Lot. = 70°25~58.955'' ~ SEC. l~ WELL I x=528,205.68 Long.-- 149°46°13.622" SEC. 14 596'FNL 1366'FEL N 0 R T H ' Y = 5,995,893.73 Lot. = 70023'59.532" WELL 2 x=528,193.14 Long.=149o46'i$.983' 557' FNL, 1378'FEL Y = 5~995~952.43 Lot. = 70°24'~. II0" WELL 3 x= 528,180.60 Lon~= 149°46'14.343" 478~FNL~ 1390'FEL Y= 5~996~ 011.07 Lot. = 70°24'00.687' ~~ WELL4 X= 52e, 168.12 Long.--149046'14.703'' 420' FNL~ 1402'FEL ~~~~,, ~ ~'~ ~ ~:~,~,o~.~ ~,.: ~oo~'o~.~,~., ~'~ ~ ~ ' ~ WELL 5 X= 52a,520.16 Long.--149°46'04.3~' 346'FNL 1050'FEL Y = 5~996~027.76 L~t. = 70°24'00.837' WELL 6' x= 528,532.83 Long.-' 149°~'~.015" 404' FNL ~ 10~'FEL Y= 5~995~969.11 Let. = 70o24'00.260" WELL 7 x=528,~5.24 Long.--149o46'03.658" 463'FNL ~ 1025' FEL ~ Y= 5~995~910.44 Lat. = 70°23'59.683'' ~ WELL 8 x= 528,557.71 Long.= 149°46'03.Z99" 5~FNL , 1013'FEL ~ '~' " WELL 9 x= 5ze,~7~.s~ Lo,~.= ~ · - ,~ ~ ~,3~ ~ ~O'FNL, 901' FEL WELL 10 x= 528,685.04 Lon~=149°45'59.636" 1119'FNL ~ 889' FEL Y: 5~995~255.22 Lot. = ~°23'53.233' WELL '11 x= 528,697.61 ~ng.= 149°45'59.274" 1177'FNL~ 876'FEL Y = 5~995~196.51 Lot. = 70°23'52.6~'' WELL 12 x= 528,710.19 Long.= 14~45'58.912" pRILL SITE 3'C .c~:,'=.oo' ,~'~.~. ~'~ AS-BUILT CONDUCTOR LOCATIONS ~=5,995,121.33 L~t. = 70°23'51.929" WELL 13 x= 5~e,35e.~o ~,g.= ~49o~'o9.z35· WITHIN SECTION 14~ TI2N~ 'E9E~ U.M.~ ALASKA 1310~FNL~ 1217'FEL NOTE: Y= 5,995,180.01 Lat. C00EDINATES AEE ALASKA STATE PLANE ZONE 4. WELL 14 x= 5ze,3~.63 Long.= 149°46'09.594" 1251'~L ~ 1229' F~ SECTION LINE DISTANCES AEE TEUE. Y= ~995~238.66 L~t. = 7~23'53.084" ,OEiZONTAL POSITION PEK L,D ~ ASS~. MONU~S 19-1 6 19-2. WELL 15 X= 528,~33.07 Long.= 149o46'09.956" VEETICAL POSITION PEK LHD 6 ASSOC. TBM OPI6~ ~ DOC. 125. 1193~FNL~ 1241'FEL eWELL NO. 6 INFOEMATi0N PEK DWi. N0. NSE 9.05.303dl. Y= 5~5~297.32 L~t. = 70°23'55.661" WELL 16 x= 528,320.55 Long. =149° 46'10. 316" 1134' FNL~ 1253' FEL CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND I -- THIS PLAT REPRESENTS A LOCATION SURVEY ~. THAT ALL DIMENSIONS AND OTHER DETAILS ' - ~ I I!~ ' I.~..,;..,....,,..~,.." " SURV ED F · KUP~UK ~ ~ 1nil ~ EY OR. ARCO Alaska, Inc. ,~.,~, .: ~~~~. ifiil" ~'. D~T~ MAY 14, 1985 I '~::~"~" ' ¥. flaaub, ~ ~ SERVICES "'" ,~ ............... ,, ........ ~ May 17, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3C-I0 ARCO Alaska, Inc. Permit No. 85-101 Sur. Loc. lllg'FNL, 882'FEL, Sec. 14, T12N, R9E, UM. Bt~hole Loc. 1313'FSL, l187'FEL, Sec. 12, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A c~ntinuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title !8, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 3C- 10 -2- May 17, 1985 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 thmt the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very trulv~o~rs, ~-~, ~.?× ~ / ~ C. V. Chattert°n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~SSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3C-10 Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Kuparuk 3C-10, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on June 19, 1985. If you have any questions, please call me at 263-4970. Sincerely, JBK/LWK/tw PD/L88 Enclosures RECEIVED 1 ];985 Alaska 0il & Gas Cons. Commission Anchorage RECEIVED 'Cnorage CommiSSion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~'". ALASKA L~,L AND GAS CONSERVATION CO,,,~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL []X REDRILL [] DEEPEN ' [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~ MULTIPLE ZONE"~ ~ ~.Uni, o~,~a~nam~ '~.g ~ ~ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1119' FNL, 882' FEL, Sec.14, T12N, RgE, UH At top of proposed producing interval 1109' FSL, 1607' FEL, Sec.12, T12N, RgE, UN At total depth 1313' FSL, 1187' FEL, Sec.12, T12N, RgE, UH 10. Well number ~¢. 3C-10 ~.~_ 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 83', PAD 48' I ADL 25629 ALK 2562 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1119' @ surface feet 3C-11weII 60' (~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9060' MD, 6798' TVD feet 2560 06/19/85 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 45 o 20. Anticipated pressures 2985 (see 20 AAC 25,035 (c) (2) 3428 psig@ Rf)°F Surface _psig@ 6658 ft. TD (TVD) Proposed Casing, Liner and Cementing Program I Hole i24" i 1 2-1/4" SIZE Casing Weight 16" 62.5# 9-5/8"! 36.0# ' 8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade CouplingI Length H-40 Weld J 80' J-55 BTC J 4671 ' HF-ERW J-55 BTC / 9025' HF-ERW SETTING DEPTH MD TOP TVD 36' I 36' 36' I 36' I 35' I 35' MD BOTTOM TVD 116t 116' 47071 3748' I 90604 6798' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 870 sx Arctic Set III & 300 sx Class G blend 300 sx Class G blend ARCO Alaska, inc., proposes to drill a Kuparuk River Field development well to approximately 9060' MD (6798' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-_5/.8" surfaceQioe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig - · (~'~g~p~ ~0r ann xpected maximum surface pressure is 2985 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-10 will be 60' away from 3C-11 at surface. The~e are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid h r f ha thefo ru ~ ~' --~ ¢/~ ~ ~1~ ~3W~ f~¢ ~~ -23. I e eby certi y t t regoing is t e and correct to the best oF~ kno~ ' ~ ) SIGNED/ ~ ~~~ TITLE Area Drilling Engineer DATE f -- . ~ ~ ¢ · ~ ' · f¢ Cee.ss.on / ' Samples required []YES Permit number APPROVED BY Form 10~401 k (L~) PD/PD88 CONDITIONS OF APPROVAL Mud log required I Directional Survey required I APl number []YES ~ I /~,,~ES []NO I 50- 0~C-~- '-C-' -4 _S'-/~ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 17, 1985 ~.?_~-~~'~ by order of the Commission Submit in triplicate PERMIT TO DRILL 3C-10 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED MAY i 4 ]985 Alaska 0~1 & G:~s C{~ns. t.;omrnission Anchorage -' . -' .. · i i i il i iii i i i i -- iii i · -, ., · · . RECEIVED ~AY I ~ ]B~5 Alaska Oil & Gas Cons. Comm. issior~ Anchorage 5 13-6/8" ~CP STACK l'~$T CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc . i(9 thru 12) 10. ..¥:,:/ .-, . . :~/'/:,/j"o 11. (10 and 12)" 12. (13 thru/21) 13. 14. ].5. 16. 17. 18. 19. 20. 21. YES NO Is the permit fee attached ................... ,... ~ .................... 2. Is well to be located in a defined pool ........................ 3. Is well located proper distance from property line ............. 4. Is well located proper distance from other wells .................... 5 Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .. ............. 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed .... .. . .... , ~'--~ Is administrative approval needed ................................... Is the lease number appropriate Is conductor string provided ...................................... Is enough cement used to circulate on conductor ;nd ;urface . Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive~horizons ..................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in. collapse, tension ;~d burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ..., ......................... REMARKS ! --- I/ (5) BOPE : /:~ '(22 thru 26) 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... W~%q Are necessary diagrams of diverter and BOP equipment attached ........ ~i?' Does BOPE have sufficient pressure rating - Test to ~,~-~:© psig .. '.,~'¥¥ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ' Is the presence of H2S gas probable ................................. ... Additional requirements ............................................. f O mm Geology: Engineering: . rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 roadability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. bis TAPE VERIFTCaTTON LISTI NC., .,VD OlO.gO~ VEPlFiCATiO~ LISTING PA~E ~ ********** Er]F .1 !~NIT TYPE CATE SIZE CODE 000 000 016 065 000 000 005 065 000 000 008 065 0~0 000 002 065 000 000 003 065 000 000 002 065 000 000 007 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 ~VP Oln.HO? v..F.,PlP£CAI'I~i I.~TST'ING I::'AGIg 2 ~ATRTr X $ A N DS?[.IK~E ~**** THTS DAI'~, ~S ~lr]m REF,'~I DEPTH SHIrTW. D .. [3VE~LAYg F'IELD PR.IN'rS ******************************************************************************* * * gCUb!.~,~E.~GER L.nGS ~NC[,UDF. D ,~TTN THTS ~AG~fE?iC TAPE: * nUAL I~)D~CTI~N SPHERIC~Lf~Y F~CUSED LnG (OIL) * DAT.~ AV~II.,ABLE: 4816' TO ~962' * F[)R?~ATION DE~STTY COUPFNSATED ~,[)~ (FDN] * CO~'PF~SATED ~Ef!T~BM [,DG (FDN~ * D~TA ~V~!LA~I,~: 8300' TO 9937' TYPE SIZE ~EPR CRUDE ENTRY' ~ 1 66 0 4 1 66 1 ~ 4 7~ 60 9 4 65 ,lin ,¥p o]n 1'~02 VLnI~,LCAT,[~N bT$'"'ING PAGE,", 4 ~N~ S~RVLCE S~tRV]..CE HNTT APl ;FI,Ii nit. ;R ~AT,I )RHO ~I)N 4RAT ~C~b ~D~' CPS ~C~'L ~D~ CPS IR tnt, GAPI ,ApT APl ~Pl WlI, E 60(; TVPK (?l.,l~S,q ~OP PT nO 000 O0 OHMs: O0 ~20 OH~h~ O0 120 46 nH~ O0 120 44 ~V O0 ale CAPI O0 31o ~API no 3lO O1 TN O0 28n 01, O0 35O O2 O0 356 no 420 Oi no 000 O0 ~9o O0 no 330 31 O0 330 30 O0 310 O1 0 0 0 0 0 0 0 0 0 n 0 0 0 0 0 0 0 0 0 0 0 0 0 n 0 O 0 0 0 0 0 0 COOK 4 1 4 1 4 1 4 1 4 1 4 4 4 1 4 4 4 4 &. 4 PROCESS 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O000000OO00000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00OO000000000 1 6B 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 O0000OO0000000 1 68 00000000000000 I 68 00000000000000 )Ep'.r 8087,5000 .qFLu 'lP '20.7,t~8 ~HOB 9 1777 DRNO qPHI 49141171 2 4531 1'6.r) 20:1562 ,0 ~070 NR~T 440: 5000 VCtUI., 3EPT 8o00.00o0 SFT,U 3.0020 TbP ~,P -14.73,~4 ~R 109.6250 GR ~HOB 2. 3535 DRHO 0.,05~2 NR~T gpHI 47. ~ 6~0 NC~.3L 1~60,0()00 FCNL OEDT 8~00 no0o SFLU SP -lOiS000 GR ~HOB ~ 37B9 DRHO h,lPHI 32 4.7o7 NCNL DEPT 8500 0000 SFI,U SP -22i71~8 ~R RHOB ~ 5137 DRHO NpHI 27,1973 ~CNL 7.7070 IbD 80,4.3~5 ~R 0,05~6 NR~T 2406.0000 FCNb 5,6992 TLD 0,0439 NRAT 2444,0000 FCNh 3,2363 {ED 87 ~125 G~ 0 ~ 146 NRAT 2.4824 IbM 2q. 1562 CALl ~,5176 109,6250 CALl 3,7656 RNRA 528.5000 80:4375 CALl 2, g 336 ~ N R A 851.0000 ~.R 10,1641 16~ 6.8125 CAIi.,I 62,7266 RNRA 074,5000 CR 5.5039 II6~ 80,2500 CAI, I 3.0234 ~N~A 804.5000 mR 3.7188 IBM 87 25 CALl 11, 33, nO00 ~R 2,5469 8,5000 3,6~72 'g99,2 O0 2,6348 9,1016 -999,2500 2,~262 -99g, 500 1~,8516 .51556 2,7 20 "99g, 2500 9, 91 3,03'71 -999,2500 3'7127 g,B 285 'g99,2500 OEPT 8400,0000 ,.qFLU 1..5156 Il, r) 1 .7920 T [.,~ .I ,8174 · ~P Aln,HO? V~I~IOA~'I~N bi'STING PA~ 5 )F-PT ~P ~PHI ~HOB ~}PHI 3EPT 3P ~EPT SP ~HOB 4pH I C)EPT 4 p H I RHOB gPH1 gPHI DEPT SP ~'PH I ~EPT SP ~HOB MPHI DEPT SP RHOB NPHI BgOO nO00 SFLU 44~g7~0 NCNb 8900.0000 SFt. U -2q 4375 ~R -99~!~500 DRHO -09~ ~5nO uCUb 8100 oono SFr. 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On 0000 SFt.d -q9q.2500 ILO -999. ~.500 IbM ~p qgq~50O ~ -q9q,~5~O ~R -99~,~500 CA~I ~HOB iqgq.2500 DRHO -q9q,~500 NRA.]: -999,~500 ~N~A gPN1 -~9g.~5~0 NC~L -~99.~500 FCNL -99g,~500 ~R )EPT !785 0000 SF;~U -99q,2500 ILD -q99,~500 IbM ~P q9q~25~O ~R -99qo2500 ~R -99~,~500 CALl ~HDB -990 ?500 ~HHI] -qgq,~500 ~IR~T -qgq,~500 ~NRA gPMI -Q90~5~0 NCS~h -~9~.~500 FCNL -g99,2500 ~R ~RTC,.N ;0000 TAPE N~l:q~ :06~0 CONTTN[;ATION ~ ~EXT TAPF NAmE ** RF, EL TRAILE~ SE~,'V ?CE NAME DA~E ~5107/16 OR~GTN : CON'T Z N't,~TI, ON NEXT REEL ~tAmE ********** EOB' EOB' EOF 9,2500 -999 2500 52:1875 -999,2500 -q99,2500 -999,2500 52.6875 -99q 2500 -999.[2500 -999 2500 49
