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183-155
STATE OF ALASKA ALASKA Oil ANTI rAC Cr1kLCFRX/ATInni rnnnnn1cC1nK1 - - .- -_..-_.......-v WELL COMPLETION OR RECOMPL TION REPORT AND LOG ' la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned EnQ Suspended 20A C25.105 �20MC 25 110 GINJ❑ WIND❑ WAG❑ WDSPL❑ No. of Completions: i_ ," 1b. Well Class: Development ❑ Exploratory Service R] Stratigraphic Test E] 14. Permit to Drill Number/ Sundry: 183.1551318.,36Tµ(- 15. API Number: 50-029-21031-00-00 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Date Comp., ", 1r band J+ 8/18/2019 7. pudded: 10/29/1983 4a. Location of Well (Governmental Section): Surface: 367' FSL, 428' FWL, Sec 29, T12N, R10E, UM Top of Productive Interval: 1679' FNL, 3993' FEL, Sec 30, T12N, R10E, UM Total Depth: 1437' FNL, 4308' FEL, Sec 30, T12N, R10E, UM 8. Date TO Reached: 11/6/1983 16. Well Name and Number: KRU 1G-16 9. Ref Elevations: KB:97 GL: BF: 17. Field / Pool(s): A4'p" rrx Kuparuk River FieIdNV &t'%'"il Pool :31r 10. Plug Back Depth MD/TVD: 4220/3378 18. Property Designation: ADL 25640 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540208 y- 5981014 Zone- 4 TPI: x- 535758 y- 5984225 Zone- 4 Total Depth: x- 535441 y- 5984465 Zone- 4 11. Total Depth UD -[TVD : 9225/6816 19. DNR Approval Number: ALK 2571 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1500/1390 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/FVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD VD SETTING DEPTH T FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16 62.6 H-40 40 114 40 114 124 212sx CS II 103/4 45.5 J -55/L-8 37 2642 37 2250 131/2 1050sx Permafrost E, 7 26 J-55 34 9216 34 6810 81/2 1200sx Class G, 24. Open to production or injection? Yes ❑ No If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SQUEEZED @: us �� 4188-0208 MD and 3356-3370 TVD ..... 8/8/2019 �( 7E b VE IFIE �/° 145;,V 25. TUBING RECORD SIZE DEPTH SET (MD)PACKER SET (MD/rVD) 4.5 4100 4021/3243 6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes El No ❑� Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4188 -4208 -SQUEEZE 15 bbls 15.8 ppg Class G 27. 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10407 Revised 5/2017 t-tL- "`'�'3/( CONTINUED ON PAGE 2 Submit ORIGINIAL only /o�k n 3BDMSI��AUG 2 2 2019 �_ �fl. (-r 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored (MDfrVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No M If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1500 1390 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - N/A Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey core analysis, rialeontoloaical report or.Qduction orwell test resul1g,r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ty Senden Contact Name: Gary Eller AuthorizeTitle: Wells Su ervisor Contact Email: J.Ga om .Eller Authorize Contact Phone: 263-4172 Signature: �� Date: 8 `J.l INT UCTIONS General: This for d the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each -407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only ConocoPhillips Alaska, ITT, KUP INJ UNIT WELLIJAME 1G-16 WELLBORE 113-16 1U18, 801211811 /]'. W AM Last Tag Vemul memo". (ecWap Annotation capin IHKB)Ene Gab Lasi Moe By ...... .....FuicEe;ais""" .._....................._. Last Tag RKB(Est J' of Fill) 9,00].0 3If ", 6 urnmS, Last Rev Reason Annotation Ene pe4 WeII4o,e {est Mae By Rev Reason'. Per CTDSIBetrack Perp 820"019 IG -16 Tansan8 Casing Strings Laame Deserter on 100 (in) m(in) Top dKID bet"spin Tokel set0apth II I_. -ren 8.. Gratla Top Tnraea CONDUCTOR 16 1506 400 1140 114.0 63.00 H40 WELDED LONpVLTOP', a0.611d0 Casing descrlmem Op (in) ID (in) Top(fll(BI Bet Japan OURED fist Depth nVD)... 45 g... Glee Top TFr4tl SURFACE 10314 9.95 36.9 2,641.6 2,250.0 45.60 ohn BUTT SURFACE; W 9,26n a_ A Casing Dezc,lption OD tin, Ippn) Topmene, -,arm MS.) .GoRh INDI... Wllaep Q_Grade Tap Thread PRODUCTION ] 628 343 9,210 6,810.0 26.00 J-55 BTC Tubing Strings INJ; Zen-41/2"COMPLETION Tubing Jascrlpronsnmg ma... Ip (In) ITPMKJD flet Depth In_ sea Depth (I L.. w klieg Greaa Top Connection 412 3.96 313 4,1002 3,296.9 12.60 1 L-80 jIBTM Completion Details IID39aB3 Top (WO) Topmot Nominal Top LIMB) (1111B) PI Ihm Des Co. IDdn 31.3 31.3 030 HANGER Cameron 71/16"x41/2" CXS Tubing hanger, Vam FJL 3.BDD PACKER U.all1 2,963.5 2,492.8 4180 NJ GLM Cam. 412"x1"KBG-2, DUmmy SNG2083bi 3.830 79882 7221.3 47.67 INJ GLM Cong. 4112"xi'KBG-2, Dummy She 20836-19 3.830 NRPLE: a.ga9.a 7021.2 3,2435 4763 PACKER Packer Baker 7"x41I2'FP 53 ProtlUtllpn 3.830 4,09.4 3,255.8 4758 NIPPLE 3010 MULE sxOE: a.Wa.6 wwpsixK.4.1mo CMT 50 Z: 4,188 .61, 39.o 4,0989 3,2960 4743 MULE SHOE WLEGNBnhern So on 1 4.000 Tum"a DmcrlpGon scone TUBING -1988 312 2.991 REMAINING 5,20".081 8,856 ]M (n 85196to (ND 11. (blKl 920 Gmee JSS Top Correction Top Cor ABMOD BRIDGE PLUG PERMANENT, Completion Details a P9] JET CUT; 5.36]0 amenllluv7.c M(B Z9 Top(ND) Top Nominal Top (Dead (ryKBI E°Incl Ihm Rea Co. to (in) 6281.7 6064.4 39.59 INJ 2.907 Denver 7 ance.0 SKe8,3245 CEMENTfl ETANEN, Rep. 6,0974 39.25 5BR OTIS TSD SBR 2.813 Demons Pnp; 4,381 o eve 633].5 61075 39.12 PACKER OTIS RRH PACKER 2.900 8,376.5 6,13].9 38.751NJ 2.897 INJ; 8.391] $449.1 6,194.6 3823 INJ 2.897 LMT6@Je,A568.3N.p 8,521.5 6,251) 3783 INJ 2897 8,559.6 6,281.8 3766 BLAST JTS 5TEEL BLAST JOINTS (OAL=58.55') 2.992 aBRl B.B 8,fi44.5 BS,IP3 3730 PACKER OTIS RH PACKER 2900 PACKER; 8,3375 8,65].1 6,359.3 37.25 INJ 2,907 J 8,6724 6,3714 37.19 BLAST TS BLAST JOINTS (DAL =79.43') 2-92 Ix, BMS 8,7889 6,4647 36.18 INJ 2.907 8,829.1 64972 36D7 SEAL ASSY OT IS SEAL ASSEMBLY 2.90g INJ; e.1 8,6297 6,4978 36.07 PACKER OTIS WD PERMANENT PACKER 4.000 8,833.6 6,500.9 36.07 SBE SEAL BORE EXTENSION 3.000 8,846.8 6,511.4 36.07 NIPPLE CAMCO D NIPPLE NO GO y50 IN, B, 5315 8,856.1 6,519.1 36.07 SOS HEAR UB,ELMD TL@8844 uring ,PRO on 2.875 1112fi12006 Other In Hole (VYireline retrievable plugs, valves, pumps, fish, etc.) mERP 8,557O358a.0------ Too( D) Top Incl RESP: &See.Ga.naO- Top DKBl d1KBI V) Des Com Run Dat Dled 4,188.0 3,356A 47.25 WHIPSTOCK Baker Hughes Defta Retrievable Whipstock, Orlented 8/112010 DODO H5, GAL 18' IPESr gsazaBsee.o_ RESP; Saba MAI 42192 3,3776 4747 BRID LUG &1212019 PERMANENT 5,20003,983.753.82 JET CUT Jet Cut 6IB12o19 2.992 PAmN', 8,260.0 60476 39 ]2 C PENT3.5" FH Cement Retainer 5,2]12019 0.000 RETAINER Plsx; e.eas.o PACKER: e.e4a.5 8,fi33.0 6,340.1 3].34 PATCH 21 S' ubing Patch; Set across EAKIN Middle KR 729/1996 23]5 864$' on 729196 INJ; OEM .1 8,845.0 6,349.6 Pony Tail Pans Plugging Leak in PKR@86457/4119950.000 Downhole Camera run 714195 CMT SOZ: B,fiBTDa8R0 , 6,8467 6 ,511.5 360] REDUCER AVA NIPPLE REDUCER 7/1211996 2250 Perforations & Slots Prer;D,amni snot Dena TagalogMXKB BTop Bim INDI all marat( ) DIKED B) steel Linkwl Zone Cape TYFa Com 4,188.0 4,2080 3,356A 3,370.0 88219 60 CMT SOZ PERF GUN: 2" POWERFLO6SPF BIG Irv]: B]c8.9 HOLE CHARGES REAL A66Y; BBN I PACI(ER, 8 BN] ,3150 8 8,320.0 6,090.1 6,093.9 N1112019 4.0 CMTSOZ 1.56"Tubing Punch F, Ode g. 6BE; B4O9a6 8,55].0 8,583.0 669.8 6284.5 74, 1G-18 1117/1984 12.0 IPERF SOB; 120 tleg pH 8,5690 8,576.0 6289.3 6,284.8 C4, iG-16 1/1711984 12.0 (PERF SOS; 120 deg pH NIPPLE, eawa 8,582.0 8,588.0 6,299.6 6,304.3 C4, iG-18 T17 1984 12.0 PERF SOS 120 tleg pH SEDucsq; Be a.] 8,602.0 ITSI 6,315 111 .4 6,318.6 C-0, 1G-16 7/1984 120 IPERF SOS; 120 tleg pH sps; .. gbi ----------------- 8,6670 8,672.0 6,3671 6,371.1 Fi, JG- 18 3/1112019 4.0 CMT SOZ "Tubing Punch4 PF, 0 tleg. 8,670.0 8,7420 6,3685 6,427.0 -1, UNIT B, 111]/1984 120 [PERE SOS 120 tleg pH 1G-16 APER1,R.,G.d4A 8,954.0 9,"14.0 65982 8,646) A-0,Aa, 1G-16 &1071984D5 APERF DA BarKone II; 90 deg pH Cement Squeezes TOP (NDI Star mol Top(XKB) Btm(XKB) (RKBI (HKBI Dm Sbn Date Lom 8,2610 8,954.0 6,0484 6,598.2 CEMENT PLUG WDI2019 1868 F15.BP LASSG EMENT BULLHEADED BELOW RETAINER PRODUCTION:3s.ie,316o� ✓ KUP INJ WELLNAME 1G-16 WELLBORE 1G-16 CanowPhiflips Alaska.1Dc. 1G.1s.1911"On M Cement Squeezes vatiral W.mapo (aatlW) Top IWO) Binl mm TopmKBI BErmR.) /Blue /MBI Grs Start dab Com ........................_............._......... ..... .......... Ru+cER:su_ ],808.0 8,338.0 570].9 6,10].9 CEMENTPLUG 52]2019 1 BL OF 53P CLA5SG EMENT CIRCULATED UP IA ]700.0 8,260. 5,628.5 6,04].6 CEMENTPLUG 512]12019 BBL OF 100- —EOci CEMEN7oNTffp— OF RETAINER. CLEANED OUT DOWN TO ]]00' Mandrel Inserts sl no h�CONOVCTORI80.0-11)0 �, Tap ("G) Valve Lel[II Porte- TRORun Top I%3 12.49 Mahe Madel OB 6n) Sery type Type Pnl IPsll Run Bah Lam 2,963.5 2,492.8 Camco KBG-2 1 INJ GLV BK 0.188 1,4140 8/1912019 2 3,9882 3,2213 Cam. KBG-2 1 INJ OV BK 0.313 00 811912019 sDRRACE ae.a26a�e— 3 8,281] 6,0644 OTIS ICBX INJ 4 8,376.5 6,1379 OTIS WB INJ Iw;x,eeas 5 8,449.1 6,194.6 OTIS WB INJ 6 8,521.5 62517 OTIS WB INJ me; s,988.z ] 8,69.1 6,359.3 OTIS LBX INJ 8 8788.9 6,464] OTIS LBX INJ PACKER4m11 Notes: General & Safety Ena Oah AnnohBon 102312008 NOTE STA 6 bas possible pocket damage due to nose cone emded OR NIPPLE4WR4 7112019 NOTE: View SChemallC Wl Alaska 50emadcl 0.0 MULE SHOE: 4,008 WRIPSTOCK;d1e80 cou SOL 0e9.G4,G 0 BRIDGE PLUG PERMANENT, 4.2182 JET CUT; S... eemem Pilo, 7,]..O W Gement PLp;],...B CEMENTRETaNER;SGG0 GE -1 PLg; B2610BOB INJ: S.R.T CMT SUE: 8.315.08.3A.0 SBR: Ba245 PACRER', 8 W 5 I.. 0,3)85 NJ;B4W 1 NJ; B.15 IPERF:8EuJD 85Sa.o� PERF;S,•AS.GaMO� /PERF, 8, SEZOLS .591 IPERP;BancOa.606.0� PATCR;a,6a3.0 FI6R', %wo PACREP, 88 N.5 NJ;8S5]1 CMTSOE;8,65].0$6R0 IPERF, 9,6 08,1420 INJ; B,]e89 SEALA95V; BBH1 PALKER;8az9.] BBE: BSB9.6 REOVCER;BBIB.T 505;8856.1 APERF; 8Ba40B0140� PRODUCTION, 31.39,2180 1G-16 PLUG FOR RE -DRILL DTTM JOBTYP SUMMARYOPS START 6/10/19 RECOMPLETION Completed 1G-03 and Move Rig T/ 1G-16 6/11/19 RECOMPLETION Lubricate out BPV. Kill well with 9.8 PPG brine. Set BPV. N/D tree, install blanking plug. N/U stack. Performed between well maintenance on stack. Begin BOP test. 6/12/19 RECOMPLETION Test BOP, Pull BPV, Pull tubing, eline set CIBP @ 4220 MD 6/13/19 RECOMPLETION ND BOP, swap tubing head, NU BOP. Run 4 1/2" completion, land. NDNU. 6/22/19 DRILLING LRS ATTEMPT TO SET PACKER BY PRESSURING UP TBG SUPPORT- MULTIPLE TIMES; LRS RU TO IA TO CONFIRM PACKER NOT CAPITAL SET. IN PROGRESS. 6/23/19 DRILLING LRS SET PACKER, PERFORM MIT -IA TO 2500 (PASS); PULLED SUPPORT- DV @ 2963' RKB; LRS PUMP 88 BBLS DWN IA UP TBG FOR FP; CAPITAL SET DMY @ 2963' RKB; PULLED BALL & ROD & RHC @ 4039' RKB. JOB COMPLETE. 7/10/19 ANNCOMM (PRE -CTD) SV, MV, SSV VALVE TESTS PASSED, IC POT PASSED, IA DDT COMPLETE, OA DDT PASSED, INSTALL IC PO EP JEWELRY COMPLETE, REMOVE IA COMPANION BLEEDER VALVE AND INSTALL ALEMITE COMPLETE. 8/8/19 ANNCOMM RIH W/ 2.0" POWERFLOW GUN. PERFORATED INTERVAL: ✓ 4188'- 4208', CCL TO TOP SHOT = 3.3', CCLSTOP DEPTH = 4148.7', LOG CORRELATED TO DRESSER ACOUSTIC CBL DATED 11-13-83. 8/11/19 ANNCOMM RIH W/ BAKER WHIPSTOCK. WHIPSTOCK SET @ 4188', WHIPSTOCK ORIENATION = 4° LOHS, CCL TO TOP OF WHIPSTOCK = 14.1', CCL STOP DEPTH = 4173.9' 8/18/19 ANNCOMM RIH TO TAG WHIPSTOCK AT 4183' CTMD, LAY IN 15 BBLS OF 15.8 PPG CLASS G CEMENT, WELL TAKES 5 HESITATION SQUEEZES BEFORE HOLDING A SOLID 870 PSI, SQUEEZED 9.5 BBLS BEHIND PIPE, CONTAMINATE DOWN TO TARGET CEMENT TOP AT 4178' CTMD, F/P TUBING TO TOC, TRAP 1170 WHP AT SURFACE, READY FOR S/L, JOB IN PROGRESS. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 0 9 2019 WELL COMPLETION OR RECOMPL5TIQN REPORT AN 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Me Suspended M 20MC 25.105 20MC 25.110 - GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service [D • Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date CompSusp or Aband.: 6/7/2019 14. Permit to Drill Number/ Sundry: - 183-155/318-537 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 10/29/1983 15. API Number: 50-029.21031-00-00 ' 4a. Location of Well (Governmental Section): Surface: 367' FSL, 428' FWL, Sec 29, T12N, R10E, UM Top of Productive Interval: 1679' FNL, 3993' FEL, Sec 30, T12N, R10E, UM Total Depth: 1437' FNL, 4308' FEL, Sec 30, T12N, R10E, UM 6. Date TO Reached: 11/6/1983 16. Well Name and Number: KRU 1G-16 9. Ref Elevations: KB:97 GL: BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10. Plug Back Depth MD/TVD: 7703/5631 18, Property Designation: ADL 25640 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540208 y- 5981014 Zone- 4 TPI: x- 535758 y- 5984225 Zone- 4 Total Depth: x- 535441 y- 5984465 Zone- 4 11. Total Depth MD/TVD: • 9225/6816 ' 19. DNR Approval Number: ALK 2571 12. SSSV Depth MDfTVD: NIA 20. Thickness of Permafrost MD/TVD: 1500/1390 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: NIA 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER SETTING DEPTH MD SETTING DEPTH TVD FT GRADE TOP BOTTOM TOP BOTTOM AMOUNT HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 40 114 40 114 24 212sx CS II 103/4 45.5 J -551L-8 37 2642 37 2250 131/2 1050sx Permafrost E, 7 26 34 9216 34 6810 8 1/2 1200sx Class G, 24. Open to production or injection? Yes ❑ No E] If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Pend): p4.5x3.5 PERFORATIONS PLUGGED BACK: 505 (� 8557-9014 MD and 6280-6647 TVD ..... 5/27/2019 +� �12�Pr D TE 11, 1�. V RI IED 1 _02!�_ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 8857 4021/3243 8337/6107 6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No E] Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7703-9018 37 bbls 15.8ppg Class G 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Form 10-407 Revised 5/2017 VT% ial�.3�� 9 CONTINUED ON PAGE 2 RBDMSA�!/ JUL 1 1 201Qubmit ORIGINIAL only �o/y .&�:o'"�6f.. 28. CORE DATA Conventional Core(s): Yes ❑ No 0 • Sidewall Cores: Yes [:1 No j] If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1500 1390 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - N/A Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaicalr r well test results, per 20 AAC 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ty Senden Contact Name: Gary Eller Authorize i e A Wells Su ervisor Contact Email: J.Ga .Eller co .com Authorize Contact Phone: 263-4172 Signature: Date:? INSTRUCTIONS General: This fo nd the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each -407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports raga ing samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: 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 ib: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange 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 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only 1G-16 PLUG FOR RE -DRILL DTTMSTAR' JOBTYP 5/26/19 DRILLING SUPPORT CAPITAL 5/27/19 DRILLING SUPPORT CAPITAL SUMMARYOPS RIH AND TAG TOP OF PATCH @ 8624' CTMD (8633' RKB). GET CORRECTION AND PULL UP TO RETAINER SET DEPTH. PAINT RED/WHITE/BLUE FLAG. INJECT 20 BBLS DIESEL DOWN IA TO VERIFY COMMUNICATION. LAY DOWN FOR NIGHT. JOB IN PROGRESS. RIH WITH CEMENT RETAINER TO 8260' RKB. DROP BALL, WITH 9.3 BBLS AWAY, COIL PRESSURED UP. STACK 4K DOWN ON RETAINER SHOWING RETAINER IS SET. PRESSURED UP ON TOP OF RETAINER TO 1500 PSI, HOLDING GOOD. PERFORM INJECTIVITY TEST THROUGH RETAINER. BULLHEAD 18 BBLS OF 15.8 PPG CLASS G CEMENT BELOW THE RETAINER TO FORMATION. OPENED UP IA AND CIRCULATED 14 BBLS OF CEMENT UP THE IA TAKING 1:1 RETURNS. PULLED OUT OF RETAINER AND LAYED IN 5 BBLS OF CEMENT ON TOP OF RETAINER. CLEANED OUT DOWN TO 7700' RKB. READY FOR SLICKLINE IN 24 - 48 HOURS. 6/7/19 DRILLING STATE WITNESS TAG @ 7703' RKB (GOOD CEMENT SAMPLE). SUPPORT MITT & MITIA TO 2200 (PASS). GAUGED TBG TO 2.77" DOWN TO 5531' RKB. JOB COMPLETE & READY FOR JET CUT. CAPITAL KUP INJ WELLNAME 110-16 WELLBORE 1G-16 CO/fin /� (, � Well Attributes Max Angle & MD TD f1°COPiI)�i5 FieNNama phal reAPVGWI Wellbore5alus ncl(°f MGIXK9) AH.1.'HIS KUPARUK RIVER UNIT 500292103100 INJ 459 fi00000 up9Fn 12-16;77 1912PpM Last Tag Wo whereas, Annotation peplh(XKB) 1 red 01 Wellbore Up,MM By ....._...._. ................_...........__.__...... ... ................... ............ Last Tag: FOR (Est.7 of Fill) 90070 3x612019 1G -i6 zembaej Last Rev Reason Penetration End Data gun test Moa By Rev Reason: FP, Pulled Ball&Rod Pulled RHC 6232019 iGi6 JM1ansen8 Casing Strings easing Donlan Do (in) mNJ Top MCI see Depth PIKE) Set Dead, TTVDI VWLen(u.. Grade TOp thread CONDUCTOR 16 1506 40.0 114.0 1140 63.00 RAD WELDED �h CGNOUCiOR; 40.0.1110 Caping Descnplon 0o (in) IG iln) Top (XKB) 6atoeplM1 (XXB) SN Gepih tTato... WVLen(I...Grade Top Thread SURFACE 10314 9.95 36.9 2,641.6 2,250.0 45.50 J-55 BUTT Casing 0escrlptlan 00(In) IO pn) Top (XNB) Set Oeptheom) Set DepN(rvo)... WVLan(I-Vanede Top Thread PRODUCTION 7 628 343 9,2160 6,810.0 26.00 J-55 BTC 6URFACE"ne-Z,ere- Tubing Strings MergM; R,was Tubing Oescnption 6111'0 Ma... ID (in Top ( -He) JR., Depth (X.. get Gepth (ND)(...Wt(gano Grade Tap Bonne ion D' 18 4112 396 31.3 4,1002 3,296.9 12.60 L-80 /BTM Completion Details Manan: z Top (INCH Top ma xommal TER DUKE) (ttKa) V) Mem Das cam man) 31.3 31.31 030 111.rl Cameron 71/16'x41/2" CXS Tubing hanger, Vam FJL 3900 Pi s,VL1 4,0212 3,243.5 4]63 Packer Packer Baker ]"x412"FP S-3Produnion 3.830 4,039.43,2 558 4]58 Nipple -X 3.610 4,098.9 3,296.0 4].43 Muleshoe WLEG NoMem Solutions 4.000 Tubing Oesariplion 61tlng Ma... Tubing -1988 312 Remainin0 lO pn) 2.99 Tep (XKB) 5,200.0 Sel OaptM1 (X.. 8,856.] SN Depai (NO)(...Wt(INX) 6,5196 920 Grade J-55 Top Oonnecfian EVE8IMBMOD MJe Gtm:<.asen sons Plrq-Pemuna'; 7183 Jet ce, dando Completion Details. Pop(WID) Top Incl Nominal lep DIIIB) (XKB) I') lam Des Com to (in) 8,324.5 5,0974 39.25SBR OTIS TSD SBR 2.83 cemad Plu&7,]D3HORKM c.nem PNg;�maoxKe 8,3375 6,10].5 39.12 PACKER OTIS RED PACKER 2.900 Cement vl�; Baal oxo 559.6 6,28L8 3766 BST JTS STEEL BLAST JOINTS 2 11,LA092 8,644.5 6,349.3 37.30 PACKER OTIS RH PACKER 2.900 JTS M.mN: amt ] 8,672.4 6,371.4 37.19 W7ST STEEL BI -AST JOINTS (OAL=]9.43') 2.992 8JCTl .49].2 35.07 SEAL ASSY OTIS SEAL ASSEMBLY 2.960 can SDR: A315 GJEOM 0 8,8293 64978 3607 PACKER OTIS WD PERMANENT PACKER 4.000 sea: a.szas 8,833.6 6,500.9 36.07 SBE SEAL BORE EXTENSION 3000 8,846.6 6,511.4 36.0] NIPPLE CAMCOD NIPPLE NO GO 2.750 PACKER'. asws 8.856.1 8,519.1 36.01 SOS DTIP SHEAR UT SUB, ELMD L 8844 during R Fon 2.875 /1262066 IrvJwnorv'. a.mas Other In Hole (Wireline retrievable plugs, valves, pumps, tisk, eta) rap(rv0) Top ma Irvaamlorv: e.aaed Top (EKE) goal (•) a_ Com Run dee 10 (in) 4,2192 3,3776 4747 Bridge Plug- 61122019 Permanent 5,200.0 3,983.] 53.82 Jet Cut Jet Cut 6/82019 2.992 INJECTION: 8x15 8,280.0 6,047.6 39.72 Cement WET 35' FH Cement Retainer 51272019 0.060 Retainer .833.0 6,340.1 37.34 PATCH 2. or Tubing Patch;Be across LEAKING Mi die PKR@ 7291199fi 2.375 8645 an 729/96 maaF; e,6noasa3a- 8,645.0 .349.6 3729 FISH Pony Tail Pens lugging Leak in PK 5' 7/4/1995 0.000 /PERF, URAIJEeI DGWnlmle Camera lDo TAM mERP; e.ssi.0a.sae.o- 8,8467 6,511.5 36.07 REDUCER AVA NIPPLE REDUCER 1/1211996 2.250 Perforations & Slots IPexP,a.oa,mxD_ she vanx; p633.0 Den Top oftKu Dun /TVD) Iahoblrt Tap IMKB) Blm(XK9) (XKB) Linked Zane ) TS Com SIG 8,315.0 8,320.0 8,090.1 6,0839 3I11I2019 4.0 CMT 502 1.56"Tubing Punch4 SPF. 201 "PH ;Aeaso 0 deg. PAcxva, asps 75570 8,5630 6,279.8 6,284.5 G4, 113 16 1I17/1884 120 (PERF SOS; 120 deg pH 8,569.0 8,5]6.0 6,289.3 6,294.8 C<, 1G-16 1/1711984120 ]PERF §0S 120 deg pH INJECTION. e.and 8,5820 .588.0 6,2996 6,304.3 CA, iG-i6 111711984 12.0 /PERF SOS; 120 deg pH e,eD CMTfiRSE8.66]6R 8,602.0 .608.0 6,3154 6,318.6 Ga, iG-16 111]/1984 12.0 /PERE SUS 120 deg pH 8,667.0 8,6]2.0 6,3671 .3]1.1 C-1, iG-16 3/112019 40 CMT BUZ 1. 6" ubing Punch 0 deg. IVERF 6,aTo.oa,74zo� 8,670,0 8,]42.0 6,3695 6,4270 -1, UNIT B, 111711984 12.0 IPERF SOS; 120 deg PH iG-16 .954.0 I 9,0140 I .596.2 66467 A4,A-3,12-16 8I10I1984 OS APERF DA BarKone II; 90 deg IN Cement Squeezes INJECTION, anee top (TVD) Otm(rvo) 6Y lase , a,.I PACKER;aem.1 Top (Po(B) Btm (flKB) (XKB) (XKB) Oes Earl DataCam 8,2610 8,9540 11,048.4 6,5982 Cement Plug 5222019 188FLSOF lS8PPGCLASSGCEMENT BULLHEADED BELOW RETAINER she, esaae ],808.0 8,338.0 5,7079 6,1079 Cement Plug 52]2019 WBILSO 5. PPG CIA G MENT CIRCULATED UP IA wPPLE:9,Me.6 REDUCER, ea<e.T 77000 6,260.0 5,6285 6,04].6 Cement Plug 5272019 5BBL O 5. PPG CLASSG CEMENT ON TOP OF RETAINER. CLEANED OUT DOWN TO ]]00' Mandrel Inserts 606', B,B56t 61 all To Top N Tap Mi (XNB) Make Model Valve ball Pail Size TRO Run 00 (In) Sery Type Tmg (in) loan Run Data Com APERFAAMne,014.0- 1 2,963.5 2492.8 Camco KBG2 1 INJ DMY BK 0.000 0.0 6232019 2 3,9882 3,221.) Camro KBG-2 1 umm BK &1312019 I Notes; General & Safety Em! Data annoaXon 10 232008 NOTE'. STA 6 Has possible pocket damage due to nose cane eroded off PRODDCTION;.Lea2t0 a- KUP INJ WELLNAME 1G-16 WELLBORE 1G-16 ConocoPhillips''^'' Alaska, Irtc. 12416, 1/8O319124B42 Pm Notes: General B Safety vaMnlcn.mtictx6Nl) EOE oae Anno tion ................. .............Ha�513- ............... 0I21Y010 NOTE: View Schematic wl Alaska Schemalic0.0 �`�` corv0uciod, a--onila.0 SURFACE; S^ MJC41 S� MaMmi, MenCnl: J.866.2 Pockm', a.@t l MI Yca; 0... BMa. PI. -Parma am; 4,218.2 Jrt CN; E... Carom PING 7 M0 role C. P4. 1,6080 rota Came I RId1, 8,2630 C=t P, 6,2610 RMB Mmdnl', 11.11 CMi 8QC. B.el 500... SBR: 6.324.5 PPCMER', SI INJECTION; 6,3185 INJECTION; 11448.1 INJECTION; 8,521.5 IPERF, 8.55108.553.0 IPERF: B566.C8.516.0� IPERF. 8.562.6 ,�O� IPERF: 8,032086080 PATCH; 8,6230 FISH: e.695.0 PACKER; 6.6W.5 INJECTION; 86511 CMT SOL 11.10868 0 I PERF; B B]0.MN20� INJECTIO N; 81688 .F ASSY', 6..1 PPCKER: 8JM7 SBE', arM6 NIPPLE; 8046.6 REDUCER; 8,0481 608; 86581 APERF; 6,85468.O14C- PRODUCTION: 34392160 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 1 TRANSMITTAL DATE: * TRANSMITTAL #: Kuparuk BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 aco Phillips Alaska Inc. Ixt: E1VE� 1 1 0 0 : NSK-69 C G Street JUL 17 2019 forage, Alaska 99501 A nom. _ AOGCC 0 1 0 1 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 1 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 '' Date Please return via e-mail a copy to both Alaska E -Line Services and Cohog6 Phillips Alaska: 183155 WELL LOG TRANSMITTAL #905736979 30 92 7 To: Alaska Oil and Gas Conservation Comm. June 26, 2019 Arm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 ��++ Anchorage, Alaska 99501 RECEIVED JUN 2 7 2039 RE: Jet Cutter Record: 1G-16 AOGCC Run Date: 6/8/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1G-16 Digital Data in LAS format, Digital Log Image file 50-029-21031-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: '"/ Signed: MEMORANDUM TO: Jim Regg�Q�f bI(�1i9 P.I. Supervisor li f FROM: Matt Herrera Petroleum Inspector Section: 29 Township: Drilling Rig: HWL# 774 Rig Elevation: Operator Rep: Jake Fame Casing/Tubing Data (depths are MD): Conductor: 16" O.D. Shoe@ Surface: 10 3/4" O.D. Shoe@ Intermediate: Feet O.D. Shoe@ Production: 7" - O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 31/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 7, 2019 SUBJECT: Well Bore Plug & Abandonment KRU 1G-16 CPAI PTD 1831550; Sundry 318-537 12N Range: 10E - Meridian: UM ' 31.2 ft Total Depth: 9216 ft MD Lease No.: ADL 25640 Suspend: P&A: X - 114 - Feet 2642 - Feet Feet 9216 - Feet Feet 8857 Feet Casinq Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing -1 Retainer 8260 ft MD 7703 ft MD ' 15.8 ppg - Wireline tag 120 120 iri [E & uY'11i�Zr ul"111t. u11 j z mn Tubing 2260 2220 2210 IA 1100 1080 1080 P ✓ OA 120 120 120 Initial 15 min 30 min 45 min Result Tubing 570 - 570 570 IA 2235 - 2170 2150 P ✓ OA 250 240 240 - Remarks: KRU 1G-16 is scheduled for a reservoir abandonment and redrill. Cement retainer was set by E -Line and approx. 37 BBL's of 15.8 ppg cement pumped by CTU. Cement taggged with Haliburton Slickline Unit and MIT -T and MIT -IA conducted afterwards Both Tubing and IA Inital integrity tests failed with > 10% loss in 30 Minute but passed retests. ✓ Attachments: NONE � rev. 11-28-18 2019-0607_P I ug_Verification_KRU_1 G-16_mh PTo /5? -/5-57 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, May 31, 2019 8:58 AM To: Hayes, James C Subject: KRU 1G-16 (PTD 183-155, Sundry 318-539) Set packer post rig approval Follow Up Flag: Follow up Flag Status: Completed James, This modification is approved. Please include this approval with the original approved sundry. Understand the risk that if the packer doesn't set or the tubing test or IA pressure test fails the rig will have to return. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(o)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or vicloria.Loeoo €i alaska.clov From: Hayes, James C<James.C.Hayes@conocophillips.com> Sent: Thursday, May 30, 2019 12:01 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: KRU 1G-16 (PTD 183-155) RWO Change Victoria, I would like to request a change to my 1G-16 sundry that was submitted. On 111-01 we were allowed to set the tubing packer post rig and then freeze protect the well. I would like to do the same on 1G-16 as we did on IR -01. Would you be fine with this modification request? Thanks, James Hayes C: +1918.914.9609 From: Ward, Dusty K <Dustv.Ward@conocophillips.com> Sent: Monday, April 8, 2019 3:20 PM To: Loepp, Victoria T (DOA) <victoria Loepp@alaska.aov> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Senden, R. Tyler<R.Tyler.Senden@conocophillips.com> Subject: 1R-01 Workover Steps being moved to Post -Rig Victoria, Hope this finds you well. On the RWO coming up on the 1R-01 producer (approved sundry attached), we'd plan to tweak our order of operations slightly and move: - The corrosion inhibited fluid circulation step and - The actual setting and testing of the packer step to Post -Rig operations. The following shows the above changes with strikethrough portions moved to red 'Post-Workover Operations...' steps: Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1 R-01 B's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 3690' MD, 3387' TVD. 1. MIRU workover rig onto 1R -01B. NU BOPE, test. 2. Pull old 3%" tubing down to the cut at ±4700' KB 3. MIRU a -line a. (optional) Run CBL from 4600' to surface to evaluate cement behind the 7" casing. Tie into the Schlumberger EMIT log run in Jan/Feb 2019. b. Set CIBP for 7", 26# casing at ±3720' MD as a base for cement. RD a -line. 4. PU 4'/z', 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Land tubing in tubing hanger and pressure up tubing to set paGke . Packer depth tentatively planned at ±3500' MD. MIT -IA- Set BPV. 5. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation 1. Pull BPV 2. Circulate hole over to corrosion inhibited brine. 3. Pressure up tubing to set packer. Pressure test tubing. 4. Pressure Test IA. 5. MIRU a -line. Tie into Schlumberger EMIT log run in Jan/Feb 2019. Tag CIBP at 3720' MD. Perf for squeeze 3640'-3710' KB (70'). 6. Set 4'/z' x 7" thru-tubing whipstock at 3690' MD with high -side orientation. RDMO a -line. 7. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to —3580' and apply squeeze pressure. a. a C lculated volume of 130' of 7" casing is only 5 bbl, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 3690' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 3690' MD. Thanks for your time! Please let me know if you have any questions/comments or need anything else. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 WELL LOG TRANSMITTAL 4905545795 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 1G-16 Run Date: 3/11/2019 103155 30 72 5 April 30, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.- Fanny f: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1G-16 Digital Data in LAS format, Digital Log Image file 50-029-21031-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com .e: 0 5 08`i Signed: RECEIVED MAY 0 8 2019 AOGCC THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Brian Buck Workover Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1G-16 Permit to Drill Number: 183-155 Sundry Number: 318-539 Dear Mr. Buck: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, *7)0; ,f-' Cathy P. Foerster Commissioner DATED this � y of February, 2019. BBDMSY' f b 1 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on AAC 25 ovn EEEI WE DO DEC 0 5 2018 Arc Zs 1. Type of Request: Abandon ❑ Plug Perforation:.. _ � Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate Pull Tubing ❑� Change Approved Program ElPlug E❑ for Redrill ❑ Perforate New Pool EDRe-enterSusp Well IJ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service 183-155 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21031 00 —00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1G-16 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): wc5 f sa, k ADL 25640 ' Ku aruk River Field, Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9225 6817 5200 3984 2348 cement to 7800' MD cut tbg 5200' MD Casing Length Size MD TVD Burst Collapse Structural Conductor 114 16" 114 114 1640 670 Surface 2642 10-3/4" 2642 2250 3580 2090 Intermediate Production 9216 7" 9216 6810 4320 4980 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8557'-9014' MD (gross, sgz'd) 6280'-6647' (gross, sced) 3-1/2", 9.2 ppf J-55 8857 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Camco TRDP-1A SCSSV, Otis RRH packer SCSSV: 1840' MD, 1642' TVD. RRH packer: 8338' MD, 6108' TVD 12. Attachments: Proposal Summary EJ Wellbore schematic ED 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/1/2019 OIL 4Z—V'N WINJ ❑ WDSPL ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Brian Buck James Hayes Contact Name: Authorized Title: Workover Supervisor Contact Email: James.C.Ha es cclrlocoiphillips.corn Contact Phone: 907-265-6927 Authorized Signature: ^ /� � Date: / 2 '/ ZD/:, COMMISS ON USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I ' Plug Integrity ❑ BOP Test ["f Mechanical Integrity Test ❑ Location Clearance ❑ Other: COP tcst ro 3v00 p'5 --r5 /I- y -k ki t, I er r- .0 r-ek<ek-�tt-6-k— ye j -o jgvoarj, 7 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No E/ Subsequent Form Required: APPROVED BY Approved by: �..., COMMISSIONER THE COMMISSION Date: ROMS-az- FEB 14 0019'/ 1 1� � A Submit Form and Form 10-403 Revised 4/2017 Approved applicatio r or (nom" he date of approval.Attachments in Duplicate ,l R gt6 9-,x.P. tf fsll8 1G-16 Workover Setup 4%" gas lift completion in preparation for CTD sidetrack. I I I Packer @ —4000' r MD. CTD KOP 4188' MD. 3259' SSTVD, 47 deg inc West Salk formation (top "'3200' TVD) RWO will set a 7" CIBP and run new 4%" completion. Post-RWO will perf, set whipstock, and squeeze via CT. Squeeze perfs: 4140'-4210' KB (80') KUP INJ 113-16 ConocoPhillips wen Attributes Max AngleB MD TD W.0 WeIIWreAPIIUWI FINtl Name WNIMxe SIMui ntl l•1 MD(XKSI AGI BIm IXKBI A'y15XL, 1"i. SOU292103100 KUFARUK RIVER UNIT 54.52 500060 8,2250 Comment X33 (ppm) Mn�Aion EnG- --me Rig RM-- S6SVLOCKEDOUT Last WO: 01611988 41.W 111811983 1846.34 60118 9 3 2'.121. Last Tag Vedingeme-boundutoMn,aMbnDean ("buff End Laid MW By Laa Tag: RKO 9,010 0 111192011 ims. HANGER; 3u Last Rev Reason Annofdlon LasIMM Dy low= Rev Reason: Slid DV 3282018 )baleen' Casing Strings Caie, Instrument Iol.N T.,Iwgl 3d Oepin IXK3) Sel Depin GVDI-� WVLen B._Gak, 11Tn. looks) CONDUCTOR 16 15.W0 40.0 114.0 fl4.0 63.00 K40 WELDED CaNnB OahnlPlbn Wlin) IDlln) iOp IXKRI 3e, Depa IXK31 Bet Pepin ITVp)... WNlen P... DIa4 TOP TnImf SURFACE 10 W4 9950 38.9 2,641.6 T,250.0 45.50 -55 BUTT Comg Oaulplbn Ce lint ID(Inl Tep (IIKBI Bel -IM IXKBI Bal DNI'ITV%.., WVLen 16.. DMe mW cONDUCT0R;400tJ40 lips PRODUCTION > 82]8 343 9,215.0 6, M'0 2800155 BTC 34FEnvLv:1,6A.T Tubing Strings toeing Oe -ht ion string Ma... mint Top IXKe) 3elttptn X..3M Illh(TVD 6_ Wt Montt Gla]a Top Cwne6wn TUBING 3112 2.992 312 8,856 6,51`96 9.20 JY55 EUEBNPBMOD Completion Details Top NVD) Topp"Naminal Top IXKBI IXKBI PI 1km Om Dam tO(in) 312 31.2 0.30 HANGER MCEVOY GEN II HANGER 3.500 SURFACE: w9-28416 1,839.6 1,842.3 41.44 SAFETY VLV CAMCO TRDP-1`A SAFETY VALVE (LOCKED OUT 521195) 2.813 8,3245 8,09)4 39.25 SBR OTIS TSD SBR 2.813 OM LIFT: emina 8,33].6 6,10].5 39.12 PACKER OTIS RRH PACKER 2.900 8,559.6 6.2819 37.66 BLASI STEEL BI MINTS (01=5855') 2.992 8,8448 8,3498 3].30 PACKER OTIS RH PACKER 2.900 ask: is. I 8,8]25 0,3]1.5 37.19 BLAST JTS STEEL BLAST LOWS (DAL =]9.43') 2.992 pPEKFR:a3t]6 8829.1 6,49].3 36.D7 SEAL A68Y OTIS SEAL ASSEMBLY 2900 ceicXER; 8.3561 n 8,829.8 669].0 36.07 PACKER OTIS WD PERMANENT PACKER 4000 Ru4(Raff,peaeU 8.833.6 6500.9 360] SBE SEAL BORE EXTENSION 3.000 8848.] 8.511.5 3607 NIPPLE CAMCO O NIPPLE NO GO 2750 B.e.2 6,519.1 36.07 SOS OTIS SHEAR OUT SUB, ELMD TTL BB44 dung WROF an 28]5 INECTWeV68 1112612006 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (WD) T,P;hd Tnp II (am (') Des Com Run Dale IOIIn) WEC1I011; 8.x91 6.356.1 6,121.9 38.95 CATCHER 2.79"x35" AVASTYLECATCHER 51181201] 0000 0,359.0 8124.2 38.92 PLUG IRBP) 2.72' RBP(PACKER CPP35113 I ED VLV 51182017 0000 CPE0350008 DAL OF RBP=10.7]' ) 8.8330 8.340.1 37M PATCH 216' Tubing PI 30 acFBas LEAKING Middle PKR Q 7129!1996 2.375 INJECTION:8,5216 Bfi45' On ]29196 0,645.0 6,349.6 37.29 FISH Pony Tail Pana Plugging Leak in PKR8843 71411995 0.000 Downnole Camem had 714195 8.846.7 6.511.5 36.0] REDUCER AVA NIPPLE REDUCER 71121996 2.250 IPERF:8557085630- Perforatbns S Slob Shot IFERF:BBW.OeS760-^° 1,110) BoII Ia'amx, Topless) Mn(IIKBI MKB) (flee) Zona Gas 1 Type Com IPER1.e3ez.ba.dwo- 8,557.0 8,5630 6.279.8 6,2845 Ci, 1G-18 1117119M 12.0 IPERF 505: 12D on PH 8,569.0 8,576.0 6.289.3 6.2948 CJ, 1G-16 1117/19M 120 IPERF SOS: 120 on PH IPERF', 66eB0e,edi 8,582.0 8,5880 6.2996 6.304.3 C-4, 1G-16 1/1711004 120 IPERF SOS: 120 deg PH 8.602.0 8,6060 6,3154 6.318.6 CA, 1G-16 111711984 1201PERF 506:12001 8,600 8,7420 8,3695 8, 4270 CLUNRB, IG 111711984 120 IPERF SOS: 120 deg pH PATLX;BA3a0 -16 8,9540 9,014.0 6,5982 6646.] A -4,A ,IG -16 SAW1984 05 APERF DA Barron 11: 90 deg PH FI Mandrelinserls PNCxER;0; 8.6a4.6 pithe SI at INJECTION;9,B5/1 on iop(TVDI Valw Ia4A PoX Sne TRORun N Top(XKB) (ft"d Make MMN Wird Swv Teed Type (in) (Psg Run Dale COm ,2 LB ,0844 OTIS USX 112 IQAS LIFT DMY RM 0000 00 W2612018 2 8,3766 6137.9 OTIS WB 1 INI DW BK- 0000 0.0 10211988 BROK EN IPERF;emoaa.743n- 3 8.449.1 8.1947 OTIS WB i INJ DMY BK 0.000 0.0 11/11997 4 8,521.6 6,2518 OTIS M 1 INJ HFCV BK 0.188 0.0 111192011 5 8.657.2 6.359.3 OTIS LBX 1112 INI MAY RM 0000 00 1118/1997 8 8,7889 6,464.8 OTIS LBX t 112 INJ HFCV RM 0.250 0.0 11/1912011 wJEcnomre.lee.9 Notes: General & Safely End Dapper I Anlglatlon eFA Aesv: e.ema 1012320m NOTE.STAB has possible pocket damage due to now wne eroded o0 ..R:e,.a 9212010 NOTE: VIew6G)edwic W1A1a6ka60nematlL90 am 68331 NIP M.GB] REOUCFR:8.8,846.7 503; fiAw3 APERF6954.690110- PRODUCTmN;Mle.2160- KRU 1G-16: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1G-16 (PTD 183-155) is a Kuparuk injector equipped with 3'/" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1G-16 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1G-16; a CTD permit to drill (10-401) will be submitted in the near future for 1G-16. The Kuparuk sand formation pressure in 1G-16 is 2860 psi at 8500' MD, 6235' TVD, as measured on 5/18/17. For the plugging operations the maximum potential surface pressure is 2234 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1544 psi at 3356' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2348 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3000 psi • Recommended BOP Test Pressure during West Sak Wer ops = 3000 psi Kuparuk Sand Plugging Operations 1. RU Slickline: a. MIT: IA to 2500 psi b. Pull catcher sub and retrievable bridge plug at 8356' KB x c. Drift tubing out the tubing tail at 8856' KB. (Last tag = 9018' KB on 11/19/11) ( d. Pull dummy valve from mandrel at 8449' KB 2. RU E -line: J 00 a. Tie in with CCL t64ubing tally of 3/5/88. v b. Pump down the tubing. If fluids are not freely going into the perfs, punch holes into the 3%' tubing, adjacent to the C -sand to allow injection into the perfs. c. Punch holes in the 31/2" tubinb at —8315' KB, above the upper production packer. Perf in the lower half o the full joint immediately above the packer to leave room for the cement retain in the same joint. d. Bullhead 105 bbl diesel down IA to nfirm that the tubing punches are clear to the perfs. Diesel will serve as an I freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3'/z" a ulus e. Set 3Y:" cement retainer at —8300' KB, beloly the GLM at 8282' KB but above the tubing punches. \) 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing Page 1 of 11/15/2018 b. RIH with CT. Sting into cement retainer at 8300' KB and establish injection into C -sand and A -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. i. This procedure calls for pumping a minimum of 37 bbl of cement to plug the 1 G-16 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.$ ppg cement through the retainer into the C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 18 bbl of cement is expected just to fill the tubulars, but the inten#ion is to pump sufficient cement to see at least a 300 psi .in increase IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum 4,14 bbl of 15.8 ppg cement into the IA, which is J� l sufficient to place a 500"• lug of cement in the IA. 0� yt i. 500' of 15.8 ppg cement will add -175 psi hydrostatic pressure over diesel at the 1 G -16i clination of ±400. f. Sting out of the cement retai r and shut-in returns on the IA. Begin taking returns on the tubing. Lay in bl (minimum) of cement inside the 3.5" tubing, which is sufficient for0' plug of cement. g. Continue to POH while switching ver to PowerVis to contaminate any leftover cement. Remain at 200' a ove calculated top of cement in the tubing until PowerVis turns the corner, an then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. Tag top of cement. Pressure test cement plug to 2000 psi via tubing and IA separately. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3'/", 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±5200' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Salk Formation Note: Well 1 G-1 6's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 4188' KB, 3356' TVD. 1. MIRU workover rig onto 1G-16. NU BOPE, test. t ✓� 2. Pull old 3%" tubing down to the cut at ±5200' KB 3. MIRU a -line a. (optional) Run CBL from -4800' to surface to evaluate cement behind the 7" casing. Tie into the original CBL from 10-3-82 and look to see if there are /- any meaningful changes in the new log. Page 2 of 3 11/15/2018 b. Set CIBP for 7", 26# casing at±4220' MD as abase for cement. RD a -line. 4. Nipple down BOPE and McEvoy Gen 3 tubing tubing head. Replace the old tubing head with a Cameron Gen 4 tubing head. Pressure test IC seals. NU BOP and retest as needed. 5. PU with 4'/", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger and pressure up tubing to set packer. Packer depth tentatively planned at ±4000' MD. MIT -W Set BPV. 6. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation J� y� 1. Pull BPV /] f7 2. MIRU a -line. Tie into CBL of 11/13/83. Tag CIBP at 4220' MD. Perffor squeeze 4140'-4210' KB (70'). 3. Set 4'/:" x 7" thru-tubing whipstock at 4188' MD with high -side orientation. RDMO e - line. 4. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to -4100' and apply squeeze pressure. a. Calculated volume of 120' of 7" casing is only 4.5, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 5. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 4188' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 4188' MD. Page 3 of 3 11/15/2018 KRU 16-03 Workover Setup for West Sak Injection Quarter -Mile Review Surface Top of D -Top of D- Surface Surface Surface Well Well Well Casing Set Surface Casing Cement Arctic Pack PTD API sand Oil Pool Sand Oil Casing Set Casing Set Casing Set Mechanical Integrity Name Classification Status (MD) Pool (TVD) Depth (MD) Depth (TVD) Across Ugnu7 Across West Operations Summary Cement Ops Saki 1na/a:um M la» pWl& WIN lag oA:clbbI mtanlm 11,010 wF3L Op81e�a250vla1 bbIIW15.)gaPK tlhaal'WA/B1. R>Vacer Mn-LLro3000psl pass& l]-3538 1`343 MUM 5"0 MWD3 Na. Inle[tM1e 3,191 %x5 Z. 2,316 FYXrewmse:Reelob Mc383u tCBL mbl-winca Mn-0Rta 1BD]Wl Oaitetl 11-]5.18 emeMw[ul1u. Herc[bmtatbn Fn=annuli. CBLsIII— tram W15W'MD Uspp9EMW.. 163/4': 13[Ou1MSbNl&3 IIJUI an:ai pblcmtei}]apl WMBFR�WFLLINOp OP9kad.2W.(41W)d15.7MPF{ 8kM'1/39M'al Ed= Mrt-0Ata 18DJ psi OassM 3/8/19 3GG6 mow 5 Z330.4M3N IM Inlma:e a,COF 3,3x3 3.309 ]-150 .4. r. Into tall. PaNN rftumseaLeloll. no[vnut BY'inaB annuli. Mn-Mb3WJpYpnsetl 3/&18 bW)d. ..nd[M:hIZ(MIAe bdlal5]ppi mU wpsbdla .S 18.]pq. m•13.5 {p9EMW. MSOMMt,101bd TaXaaJWWFUWSIMTdA 1WV:2M=&P E13A0MIe + OW0, 11/9/83, WW. Mn-WW2540P WSa 22/2/18 IG -16 183-155 SD 2103140 INertw LT51 s, 31333 31613 ],2i0 n,f. Iptl[ 25UnalSdpq PFL tall. GaMrtdms 1G3TIna8almu11,3W Mndpb]BD]psl Wssetl t3/ylB relob,4rc]35 pp1®mentbwrlan. b61=2141'. CBLSM1mn ft,Wg [atlm FIT=]25009EMW. ea 111 1ontlLbB'- A$. ]-5.F-UIL 891:1:1 ]pp9lwtlt]bbbl of tNr[�atl MORMUWEII IG -1) 199462 SODM32935M PrNuzr prWu[Iry 3,529 3,Y3 6.38] 3,933 TRUE TRUE 15.B ppg W1. 89pblumeirtrosYrtxe. MrtFAAWD3pal Pawetl1V19/OB lOT•ISA EMW. rtaAb25tl1 tll 1] �k §k B {{¥) zof` THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ty Senden Wells Supervisor ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-16 Permit to Drill Number: 183-155 Sundry Number: 318-537 Dear Mr. Senden: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w W w. oogcc.o laska.gov Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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 P. oerster Commissioner DATED this F day of February, 2019. NMI FEB 1 12018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ECENED �8�I9.A aid 1. Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑� 183-155 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-21031 —GO -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1 G-16 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25640 ' Ku aruk River Field, Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9225 6817 9018 6650 2234 n/a n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 114 16" 114 114 1640 670 Surface 2642 10-3/4" 2642 2250 3580 2090 Intermediate Production 9216 7" 9216 6810 4320 4980 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8557'-9014' MD (gross) 6280'-6647'(gross) 3-1/2", 9.2 ppf J-55 8857 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Camco TRDP-1A SCSSV, Otis RRH packer SCSSV: 1840' MD, 1642' TVD. RRH packer: 8338' MD, 6108' TVD 12. Attachments: Proposal Summary Ld Wellbore schematic la 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/15/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑� GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ty Senden Contact Name: James Hayes Authorized Title: IIs Supe isor Contact Email: James.C.Haves(cDconocophillios.com Contact Phone: 907-265-6927 Authorized Signature.Date: COMMItSKIN USE ONLY Conditions of approval: Notify Cofission so that a representative may witness Sundry Number: 1 - Plug Integrity Ell� BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req d? Yes ❑ No Er Spacing Exception Required? Yes ❑ No Subsequent Form Required: ! D -- 4 0 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: R13dMS,L� FEB�12001 q ®D I Submit Form and Form 10-403 Revised 4/2017 Approved application a f n r t e date of approval. Attachments in Duplicate .Il(AA,f `s!.r6,&1Ws/ip ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Sundry Applications (10-403s) to plug for re -drill the KRU 1 G-16 (PTD# 183-155) and to perform workover operations to set the well up for CTD sidetrack in the West Sak formation. The plugging of the existing KRU 1 G-16 completion in the Kuparuk Sands is in accordance with the requirements of 20 AAC 25.112(c)(1). Following plugging, workover operations will prepare 1G-16 for CTD sidetrack into the West Sak formation. Later, a Permit to Drill (10-401) application will be submitted for the planned West Sak lateral to be drilled with Nabors CDR3-AC in mid -2019. Attached to the plugging application are the following documents: - 10-403 Sundry Application for KRU 1G-16 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed plugging schematic of the Kuparuk sands completion Attached to the workover application are the following documents: - 10-403 Sundry Application for KRU 1G-16 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic If you have any questions or require additional information, please contact me at 907-263-4172. %erConoPIIIps Wells Advisor KUP INJ 1G-16 C0 oc@P111ll1ps '- Well Attributes Max Angle &MD TO wet ,W.APnuwl Fido Name wenbore Status nfJC MOlnl<8) 4cr 81m IXN8) A"dSka, Inc. 500292103100 NUPARUK RNER UNR INJ 54.52 5,OD000 9.135.0 '710Ene pate "pusuIH) BIg R1ZWI9Ogle ent H29 fas"d Ogle Ad1t 7n SSSV:LOOKED OUT Last VA: 31611988 41.00 11/0/-. 1Gu'oQd N1a99:12PM Last Tag e nu x AnndAbn Dzpn (XKBI Ene OMe IUIMW Oy ..._. .. Lasl Taff RKB 90180 iV191201t nine. HANGEa: 6,3 Last Rev Reason nabinn E,dr LaeIMM By Rev Reason, Set OV 3/26/2Ute transmit Casing Strings Caaim.,ipnon OD lint 1Otml Top 1X801 se Coln ln881 m,1 repairlrvpl. wvlon ll._Gratle top rnrraa CONDUCTOR 18 15060 40.0 1140 1140 8300 H-40 WELDED Casing Description -Bnl "m TOP IXKeI SeLCpNIXKBI 8e1 DepIn IND)... WVLm 11... Grsi TDp mr. SURFACE 103/ 9.950 36.9 2,6416 22500 45.50155 BUTT Casing DescNplbn Op llnl I011n) Top 1X1(81 541 DePin IXKB, Set DeplI11TVD1... WflLen fl._Gra]e TopTn- cONDUC'foR.4D4na0 PROOVCTON ] 8.2)8 34.3 9,2180 6810.0 26.00 J-55 BTC BAFBTrvLv r,4wT Tubing Strings Tubing Ca6cripti0n Strinp Ma.. ID9p Tap IXKB) Bet DM1n IX.. 5e1 CepM (Troll-. w101YX) GraBe Top CannMion TUBING 3112 2.992 }11 8,856.) 6,5198 920J-55 EUEBmABMOD Complegon Details Top (Win Top lwl Nmo nor Top matte; IXKB) fl Item Dn Com ID IIA) 31.2 31.2 0.30 HANGER MCEVOY GEN II HANGER 3500 SURFACE', 36S26tl a- 1,839.6 1,842.3 41A4 SAFETY VLV CAMCO TREE A SAFETY VALVE (LOCKED OUT W21 195) 2.813 8,324.5 6,0974 3915 SBR OTIS TSD SBR 2.013 GAB LIFT: afters 0,337.6 6,107.5 39.12 PACKER OTISFIRE! PACKER 2.900 0,559.6 6.281.9 37,66 BLAST JTS STEEL BLAST JOINTS (DAL =51155) 2.992 8.644.6 6,349.3 37.30 PACKER OTIS RH PACKER 2900 88R:e,3t45 8,6725 6,371.5 37.19 BLASTJTS STEEL BLAST JOINTS (OAL=]943) 2992 PALKFR,433)8 0.829.1 6,497.3 36.07 SEAL ASSY OTIS SEAL ASSEMBLY Mad CAmHBR: 4354r 0.829.8 6,497.8 36.07 PACKER OTIS WO PERMANENT PACKER 4000 RUO ReP):4 0 88336 6.500.9 36.07 SBE SEAL BORE EXTENSION SAW .846.] 6.511.5 3807 NIPPLE CAMCO D NIPPLE NO GO 2750 8,8562 8.519.1 3807 505 OTISSHEAROUTSUB, ELMDTTL®8844dudnglPR0Fon 2.875 INJECTION', 8.3766 1126/2006 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) To, (,or Topincl Top1XKe) IXKB) M Do. Co. Run 0m 10 (in) INECRON:4419I 8358.1 6,121.9 38.95 CATCHER 2.79"x35- AVA STYLE CATCHER 51IW2017 9000 83590 8.124.2 3092 PLUG(RBP) 2.72" RBP(PACKER CGP35113 I EO VLV SMOI2017 0.000 CPE0350008 SAL OF REP =IDT7'1 5,6330 8340.1 3734 PATCH 21,5' Tubing Palch: Sea across LEAKING Middle PKR @ 712911996 2375 INJECTION', Bern B 01145' on 71tiSA 6 8,645.0 6,349.6 37,29 FISH No, Tail Pada Plugging Leak in PKR a 8645' 7/4/1995 0.000 Casemate Camera mn 714,95 8,848.7 6,511.5 MIT REDUCER AVA NIPPLE REDUCER )11211996 2.250 IPERE:B,S)DLeN30- Perforations IS Slots Shot PERF,$Me 0dS160- Dena Top (Won Bim UVD) (sh. T.10"On m.( ..I RKB/ (nKBI &ne Cye 1 Type Com 510 85530 8.279.0 6,2845 G4, IG -16 111)/1984 12.0 /PERF SOS; 120 deg pH rPEaF:e58208.5W0� ,5690 8,5760 6,209.3 6.294.8 C-4, 1G16 1117/1984 12.0 (PERE S0S, 120 deg pH IPERF,S, D "MO- 8,5820 8,5880 8.299.6 6.304.3 C-4, 1G16 1/1]11984 120 PERE S0S; 120 deg pH 8,6020 8 11 8.3154 6.3186 C-4 1G-16 111711984 1201PERF S0S; 120 deg PH 88]0.0 87420 93895 6427D1UNIT ,iG 11711984 120 (PERF 505; 120 deg pH PATCH.86330 -16 9,0140 6,598.2 6646] A -4,A -031G.16 811011984 0.5 APERF Uftrfoone Il; 90 deg pH Fol -8.954.0 Mandrel Inserts K. b. a PACKER:9.fiu.5 an an IrvJECTION', e.MT.t on Top M) Valve blcn N Te RKB) MW Opllnl Bert/ TYPe Rod She TRO Re IPSO Run Date Co. 28181 SX 0,281.0 6,O644 OTIS LB% 1112 GAS LIFT OR41' RM M 0ond.0 It 0011 00 328/2018 2 0.3 88 8.1318 OTIS 6413 1 INI DMV BK- 0.000 0.0 10219M BROK EN /PERF',%67OOL5.7420� 3 BM91 6.194] OTIS WB 1 INI MY BK 0.000 0.0 1121997 4 0.5216 6,251.0 OTIS 6413 1 INJ HFCV SK 0.188 00 11/1912011 5 8,657.2 6.359.3 OTIS LEX 11/2 INI MY RM 0.000 00 1118/199) 6 8,788.9 6,464.8 OTIS lO% 1112 INJ HFCV RM 0.250 00 11119/2011 INJECTION:8M.8 Notes: General & Safety End!!!Annoomon BFALASSY:e.edal 1042 312 0 28 NOTE: STA B has passible pocket damage due to nose cone eroded off PACKElpset9b 91112010 NOTE:Vlew Scnenospewl Alaska5chematic9.0 MI :88317 NIPPLE "0",7 REDUCER:8A467 SOS:4B:53 MERF:48 otabm4.0- PRODUCTION: 34393180 1G-16 Present Well Condition 114' MD ® 2642' MD, Arctic Pack cement '2050'-2605'via CBL 13- 13-83 PERPS C-sand8557'-M3' MD C -Sand 8589-8678' MD C -send 8582'-8588' MD C -sand 8802'-9808' MD C -sand 8670'-8742' MD -sand 8954'-9014' MD ' 26%J55 shoe ® 9216' MD J\JIL\\ 11 13f83) Et 6000' (CBL of BCSSV : mandrel at 8282' A packer M 8338- & RSP at 8356' mandrels at 6377, 8447 & patch at 8633 (2.375" ID) RH packer at 8646 lion mandrels at 8657' & 8789' WD packer at 8830' ople (2.76" ID) at 884T mote reducer to 2.25" ID tail at 8866 - IG -16 Kuparuk P&A Proposal CTD KOP 41 88'MD, 3259 SSTVD, 47 deg Inc (1) Pull RBP & catcher (2) Open mandrels and/or Ig punches adjacent to 0 -sand parts (3) Open mandrel or tag punch above top packer (4) Cmt retainer set above top tag punch (5) Cmt bullheaded thm retainer into all open parts (6) Cmt circulated up IA above top packer (7) Cmt on top of ressbar in 3 t/2" tbg (8) Tubing but above TOC at -5200V MD KRU 1G-16: Summary of Plugging & Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1G-16 (PTD 183-155) is a Kuparuk injector equipped with 3%:" tubing and 7" production casing. ConocoPhillips proposes to plug the existing Kuparuk A and C sand completion and work over 1 G-16 so that it can be CTD sidetracked in the West Sak formation. This summary only covers the plugging and workover aspects of 1 G-16; a CTD permit to drill (10-401) will be submitted in the near future for 1G-16. The Kuparuk sand formation pressure in 1 G-16 is 2860 psi at 8500' MD, 6235' TVD, as measured on 5/18/17. For the plugging operations the maximum potential surface pressure is 2234 psi assuming a gas gradient of 0.1 psi/ft. The workover operations shall be conducted after the Kuparuk sands have been plugged. The expected pressure in the West Sak formation is 1544 psi at 3356' TVD (i.e. 0.46 psi/ft gradient, which is original formation pressure). The maximum potential West Sak formation pressure assumes an 0.8 psi/ft gradient, which equates to a maximum potential surface pressure of 2348 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during Kuparuk Sand plugging ops = 3000 psi • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi S rnnGuf. VOW lays Jccrt 54tr SiPiGt �Oly. ✓ Kuparuk Sand Pluoginp Operations 1 1. RU Slickline: .�a �'/q/vrQci / e e0�ay {rdM Y� l°'?'r►+ �G a. MIT -IA to 2500 psi f; al i. b. Pull catcher sub and retrievable bridge plug at 8356' KB c. Drift tubing out the tubing tail at 8856' KB. (Last tag = 9018' KB on 11/19/11) d. Pull dummy valve from mandrel at 8449' KB 2. RU E -line: a. Tie in with CCL to tubing tally of 3/5/88. b. Pump down the tubing. If fluids are not freely going into the perfs, punch holes into the 3Y2" tubing adjacent to the C -sand to allow injection into the perfs. c. Punch holes in the 3'/i' tubing at -8315' KB, above the upper production packer. Perf in the lower half of the full joint immediately above the packer to leave room for the cement retainer in the same joint. d. Bullhead 105 bbl diesel down IA to confirm that the tubing punches are clear to the perfs. Diesel will serve as an IA freeze protect fluid after cementing. i. 105 bbl = 4000' in the 7" x 3'/z" annulus e. Set 3'/" cement retainer at -8300' KB, below the GLM at 8282' KB but above the tubing punches. 3. RU Service Coil and cementing unit: a. RU to take returns off the IA and the tubing Page 1 of 3 11/15/2018 b. RIH with CT. Sting into cement retainer at 8300' KB and establish injection into C -sand and A -sand perfs with seawater. Monitor IA pressure to establish a baseline injection pressure. c. Prepare to pump 15.8 ppg class G cement. i. This procedure calls for pumping a minimum of 37 bbl of cement to plug the 1 G-16 Kuparuk Sands completion, but we will blend cement on the fly in the event more cement is needed. d. Pump 15.8 ppg cement through the retainer into the C -sand perfs. Monitor pressure on IA continuously while pumping cement into the perfs. i. A minimum of 18 bbl of cement is expected just to fill the tubulars, but the intention is to pump sufficient cement to see at least a 300 psi increase in IA pressure. e. Once IA pressure has built to 300+ psi over baseline injection pressure, open up the IA to allow cement to enter the IA. Maintain 1:1 returns on the IA. Circulate a minimum of 14 bbl of 15.8 ppg cement into the IA, which is sufficient to place a 500' plug of cement in the IA. i. 500' of 15.8 ppg cement will add -175 psi hydrostatic pressure over diesel at the 1G-16 inclination of ±400 . f. Sting out of the cement retainer and shut-in returns on the IA. Begin taking returns on the tubing. Lay in 5 bbl (minimum) of cement inside the 3.5" tubing, which is sufficient for a 500' plug of cement. g. Continue to POH while switching over to PowerVis to contaminate any leftover cement. Remain at 200' above calculated top of cement in the tubing until PowerVis turns the corner, and then POH while cleaning up any residual cement. 4. Slickline: a. After cement has had minimum of 24 hours to cure, RIH with slickline bailer. f`5 Tag top of cement. Pressure test cement plug to 2000 psi via tubing and IA r separately. Provide 24-hour notice for the AOGCC to witness this operation. 5. E -line: a. RIH with jet cutter for 3'/z', 9.3 ppf, J-55 tubing. Tie in with CCL. Jet cut the tubing mid -joint at ±5200' KB (i.e. -1000' deeper than the eventual CTD sidetrack depth). 6. Set BPV, prepare for workover rig Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1G -16's intended service following CTD sidetrack is as a development oil well in the West Sak formation. The CTD KOP is tentatively planned at 4188' KB, 3356' nr,VJ TVD. �vrid 1. MIRU workover rig onto 1G-16. NU BOPE, test. 2. Pull old 3'/" tubing down to the cut at ±5200' KB 3. MIRU e -line a. (optional) Run CBL from -4800' to surface to evaluate cement behind the 7" casing. Tie into the original CBL from 10-3-82 and look to see if there are any meaningful changes in the new log. Page 2 of 3 11/15/2018 b. Set CIBP for T', 26# casing at ±4220' MD as a base for cement. RD a -line. 4. Nipple down BOPE and McEvoy Gen 3 tubing tubing head. Replace the old tubing head with a Cameron Gen 4 tubing head. Pressure test IC seals. NU BOP and retest as needed. 5. PU with 4'/", 12.6 ppf, L-80 completion and TIH. Completion will include hydraulic set packer and gas lift mandrels. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger and pressure up tubing to set packer. Packer depth tentatively planned at ±4000' MD. MIT -IA. Set BPV. 6. ND BOPE, NU 4-1/16" tree. RDMO workover rig. Post-Workover Operations to Set Up for CTD Sidetrack into the West Salk Formation 1. Pull BPV 2. MIRU a -line. Tie into CBL of 11/13/83. Tag CIBP at 4220' MD. Perffor squeeze 4140'-4210' KB (70'). 3. Set 4'/" x 7" thru-tubing whipstock at 4188' MD with high -side orientation. RDMO e - line. 4. MIRU coiled tubing unit. Lay in 15.8 ppg class G cement from TOWS to —4100' and apply squeeze pressure. a. Calculated volume of 120' of 7" casing is only 4.5, but be prepared to pump at least 15 bbl of cement to adequately squeeze this interval. 5. Once target squeeze pressure is achieved, contaminate and circulate out green cement down to the TOWS at 4188' MD. Maintain overbalance the entire time. POH, trap sufficient surface pressure to maintain overbalance. RDMO, allowing time for cement to cure. a. The intention is for coiled tubing to leave cement nodes over the perfs. CTD will drill out any cement nodes inside the 7" casing when they go to perform their window exit at 4188' MD. Page 3 of 3 11/15/2018 Ima~ ect Well History File' C, 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. J ~.~__- /~'~_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: n Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: ~.: ~, , NOTES: [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT(~ MARIA LOWEU. DATE:'7~(~., /SI Project Proofing .. BY: BEVERLY BREN~:C~SHERYL MARIA LOWELl_ Scanning Preparation BY: BEVERLY BR~/NC SHERYL Production Scanning Stage I BY: Stage 2 MARIA LOWELL DATE: IS/ PAGE COUNT~IATCHES NUMBER IN SCANNING PREPARATION: YES BEVERLY BREN VINCENT SHERYL LOWELL DATE: ~_ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WEREFOUND: NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wlxI • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 15, 2011 TO: Jim Regg P.I. Supervisor r' / 2 1/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1G -16 FROM: Bob Noble KUPARUK RIV UNIT IG -16 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry \1 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1G - 16 API Well Number: 50 029 - 21031 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN111202142638 Permit Number: 183 - 155 - Inspection Date: 12/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1G-16 Type Inj. W 'TVD 6107 IA 800 2985 - 2945 2936 P.T.D 1831550 TypeTest SPT Test psi 1526.75 O o 0 0 0 Interval 4YRTST - P/F P Tubing 1250 1260 1260 1260 Notes: Thursday, December 15, 2011 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, December 13, 2011 P.I. Superv ' C 1Z� Z ZI f( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IG -16 FROM: John Crisp KUPARUK RIV UNIT IG -16 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1G - 16 API Well Number: 50 029 - 21031 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr1 1 1 1250945 1 5 Permit Number: 183 - 155 - 0 Inspection Date: 11/19/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1G -16 'Type Inj. N - TVD 6107 - IA 570 1060 - 1130 - P.T.D 1831550 'TypeTest SPT Test psi 1526 • OA o 0 0 0 Interval 'WPM p/F F Tubing o 0 0 0 Notes: Attempted test with no success. Fluid level was supposed to be at 30'. Fluid level not accurate. Pumped 11 bbls into IA & stopped test. No ✓ operator report, 5 QED FEB 1 C X Tuesday, December 13, 2011 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Q ( P.I. Supervisor ')~ et¿tl 7 t 1( ¡) 7 DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-16 KUPARUK RIV UNIT 10-16 Src: Inspector \~y\s5 Reviewed By: P.I. Suprv ,JI5e.-- Comm FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV tJNIT 10-16 API Well Number: 50-029-21031-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070714194304 Permit Number: 183-155-0 Inspection Date: 7/14/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -W:"T [Type Inj. I N vi IA T ~~ 10-16 TVD 6108 980 2460 2430 2420 ,,~ -. I I -~ P.T.D! 1831550 ''""!"'vT\eTest ì SPT Test psi 2460 í OA 30 30 I 30 30 ! I J. J î' i___ 1 ~- ~ 4YRTST P ¡/ Tubing 1810 1810 I 1810 1810 I Interval P/F -l..-. Notes: SCANNED AUG 0 6 2007 Friday, July 20, 2007 Page 1 of 1 Û ¡U--~. . ..--.-..-- . ."...,.,..,==~-......,--.--~~- ~ 01/02/07 Scblumbel'gel' NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~NED JAN 0 8 2007 UJ(L 1~3-IS6- Field: Kuparuk Well Color CD Job# Log Description Date .' BL ,.... ~.. ~......,. ¡.,'f¥""". #...~ 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1D-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 12/06106 Scblumbergep NO. 4061 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth '';f·, .",.>",:~ ,1,/\1,,", 0;. ~<~':;¡~;l) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 {; Field: Kuparuk . UI C- I is'3 -II ~S Well Job# Log Description Date BL Color CD 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1R-20 11486085 LOL 11/28/06 1 10-05 11486086 INJECTION PROFILE 11/29/06 1 1 0-03 N/A SBHP 11/25/06 1 1 0-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1 R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1E-04 11477639 INJECTION PROFILE 12/04/06 1 . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10/31/05 Schlumbergep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil &. Gas Cons Comm Anchorage, AK 99503-2838 SCANNED NOV 2 3 2.005 Attn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk - Well Job# Log Description Date BL Color CD 1 R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 ./ 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 "-' 2C-04 11022934 INJECTION PROFILE 10/14/05 1 ~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10/26/05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1E-170 11015750 USIT 10/19/05 1 1J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: ~ rw DATE: /t It) t}.V 2.... ~ tJ 1- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12 3 -/) S- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: July 4, 2003 Commissioner ,<"3~ Mechanical Integrity Tests THRU: Jim Regg '\~,,¢'~'~ "~/~'l tc~'sUBJECT: Conoco/Phillips P.I. Supervisor Kuparuk River Field 1G Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I We., le-02 I Type,nj.I S I T.V.D. 15883 I Tubingl 775I~oo I~ooI~oo ]lntervall 4 I P.T.D. 1821380 ITypetestl P ITestpsil 2000 ICasingI 1280I 2250 I 2250I 2260I P/F I P I Notes: Pretest OA psi. 720 OA psi. during test 780 1BBL pumped for test I Wall[ 1G-03 I Typelnj. I S I T.V.D. 15992 I Tubing 12500 I 2500 12500 12500 I Interval[ 4 I P.T.D.I 1821490 ITypetestI P ITestpsil 2000 I CasingI 1700I 3180 I 3140I 3120I P/F I P I Notes: Pretest OA psi. 880 OA psi. during test 980 2BBL pumped for test I we,.I 1e-o9 I Type,nj.I e I T.V.D. I~ I Tubingl=~ I,~I~ I~ I,nterva, I 4I ,P.T.D.I 1831240 ITypetestl P ITestpsil 2000 I Casingl 425 12O5O12OOO12OOOI P/F I PI Notes: Pretest OA psi. & psi. during test was 0 4 BBL pumped I WellI 1G-14 ITypelnj.I S I T.V.D. I~ I Tubingl 1030 I 1030 I 1030 11030 Ilntervall 4 I P.T.D.I 1831410 ITypetestl P ITestpsiI 2500 I Casingl 1900 I 2650 I 2650 I 2650I P/FI P I Notes: OA psi. 1040 1.5 BBL pumped I WellI 1G-16I TY, ,,i.I s I T.V.D. I 6108 ]Tubing 12950 12950 12950 12950 I lntervall 4 P.T.D.I 1831550 ITypetestl P ITestpsil 2000 I CasingI 1500I 2360 I 2360 I 2360 I P/F I P Notes: OA psi. 400 1 BBL pumped Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S - SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R- Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D-- Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. ~CANNE[:' AUG 0 1 2003 2003-0704_M IT_KRU_I G-16_jc.xls 7/17/20O3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU/1G 07/04/03 Arend/Brake- APC John Crisp P.T.D. Notes: Typel~ Type Test WellllG-03 I Type Inj P.T.D. I182'1490 TypeTest Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I T.V.D. I s~83 I Tub,ng I S001 ~001 S001 ~001 'nto~'I ~ I Test psiI 1500 ]CasingI 1280] 22501 22501 22601 P/F OA 720 780 780 780 T.V.D. ] 5992 ]Tubing ] 2500] 2500] 2500] 2500],nterva,] 4 TestpsiI 1500 I Casing I 1580] 31801 31401 31201 P/F I P OA 860 980 980 980 P.T.D. I1831240 Type Test TestpsiI 1572 I Casing I 4251 20501 20001 20001 P/F Notes: OA 0 0 0 0 P.T.D. I1831410 Type Test TestpsiI 1537 I Casing I 19001 26601 26601 26601 P/F Notes: OA 1000 1040 1040 1040 we'II1G'16I vPe'"i I II~°s I Tubing I 2os°l ~os°l ~os°l ~os°l IntervalI ~ P.T.D.]1831550 TypeTest Test psiI 1527 I Casing I 15201 23601 23601 23601 P/F Notes: OA 350 400 400 400 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0704_MIT_K RU_I G-16.xls 7/1 1/2003 STATE Of ALASKA ~ OIL AND GAS CONSERVATION coMJ~;~ir~ssION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 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 367' FSL, 428' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1679' FNL, 3993' FEL, Sec. 30, T12N, R10E, UM At effective depth 1470' FNL, 4265' FEL, Sec. 30, T12N, R10E, UM At total depth 1437' FNL, 4308' FEL, Sec. 30, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 9 2 2 5' feet 6 81 6' feet Plugs (measured) 6. Datum elevation (DF or KB) 97' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-16 In!ection 9. Permit number/approval number 8-54/8-635 10. APl number 5o-029-21031 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 9134' true vertical 6743' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8557'-8563', 6279-6284', Length Size 8O' 16" 2604' 10 3/4" 9183' 7" measured 8569'-8576', true vertical 6289'-6294', Cemented Measured depth True vertical depth 212 Sx CS II 1 14' I 14' 1050 Sx PF E & 2339' 2221' 250 Sx PFC 1200 Sx Class G & 9 21 6' 6 8 0 9' 250 Sx PFC 8582'-8588', 6299'-6304', 8602'-8606', 8670'-8742', 8954'-9014' 6315'-6319', 6369'-6427', 6598'-6646' Tubing (size, grade, and measured depth) 3 1/2", J-55 tub w/tail @ 8857' Packers and SSSV (type and measured depth) RRH pkr @ 8338', RH pkr @ 8645', WD pkr @ 8830', TRDP 13. Stimulation or cement squeeze summary -- Intervals treated (measured) Treatment description including volumes used and final pressure Conver niec,on 14. Reoresentative Daily Average Produmion or I~~~---- ----- ---~ ~-~ ..... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- 0 - 5800 780 2475 Subsequent to operation -0- 0 - 5500 - 0 - 251 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil _ Gas Suspended Service WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned //'~'~.-'/f-./~l ~ ~ Form t'0-404 Re~/ 05/17/89 Sr. Operations Engineer Date SUBMIT I~1DOPLICATE Sundry Notice Well 1G-16 No BOP will be used for the proposed work. No workover fluids are required. The estimated BHP is 3600 psig. '-' STATE OF ALASKA ~.~, ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~L GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P. 0, Box 100360, Anchorager AK 99510 50- 029-21031 4. Location of well at surface 9. Unit or Lease Name 367' FSL, 428' FWL, Sec.29, T12N, R10E, UM Kuparuk River Uni~; At Top Producing Interval 10. Well Number 1679' FNL, 3993' FEL, Sec.30, T12N, R10E, UM 1G-16 At Total Depth 11. Field and Pool 1437' FNL~ 4308' FEL, Sec.30, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool 97' RKBI ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1 0/29/83 1 1/06/83 01/17/84*I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set 121.Thickness of Permafrost 9225'MD~6816'TVD 9134'MD~6743'TVD YES~j~ NO [] 1~40' feetMD 1500' (Apprn×~ 22. Type Electric or Other Logs Run DI L/SFL/FDC/CNL/GR/SP/Cal , CBL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~;" 62 ~# H-4~ S,,rf !!4' ?." 2!2 sx CS Ii 10-~/4" 45.5#/55.5~ .I-Rr~/I-RO .~,,rf 2639' !3-!/2' !050 SX PF E & 250 sx P.~ C 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) Perforated w/12 spf, 120° phasing 3-!/2" 8857' 8338', ~5':5', 8557' - 8563' MD/6279' - 6284' TVD 8569' - 8576' MD/6289' - 6294' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8582' - 8588' MD/6299' - 6304' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8602' - 8606' MD/6315' - 6319' TVD N/^ 8670' - 8742' MD/6369' - 6427' TVD 8954' - 9014' MD/6598' - 6646' TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure' CALCULATED.k, OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE * NOTE: Workover performed 3/6/88. Form 10-407 Submit in duplicate ~// Rev. 7-1-80 CONTINUED ON REVE]~I~I~I~I~104 GEOLOGiC MARKERS " . ' ' :' :.!' i' ~ '. .~ :' '.'./-:~ -.,FORMATION TESTs - . ' .i' "-' '. ' . . = , _ · ~':'-~ J, - ~.~-t '- :-'" . : ..... ., , . ~'-. · ' '- --.' - · -.' ' ; . . ~ - -.r;,.'~ ; .... . .~' ' ~ .:;~. ~ . NAM E I nclu de interval tested; pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8557' 6279' N/A Base Upper Sand 8728' 6415' ~ . . Top Lower 5and 8934' 6581' Base Lower Sand 9074' 6694' · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~,/-~-~J Title A$$oeiaf.~. Ennin~_~_r- Date ~'/4-~ 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 STATE OF ALASKA ALf.-,,,KA OIL AND GAS CONSERVATION COi.,,~ilSSION APPLICATION FOR SUNDRY APPROVALS feet I~. Type of Request: Abandon Suspend . ' Operation Shutdown. ~ Re-enter suspended well .~ Alter casing El TIme extension Change approved program Plugging '~ Stimulate .~. Pull tubing Amend order f Perforate [' Other 2 Name of Operator ARCO Alaska, Inc. 3 Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 367' FSL, 428 FWL, Sec. 29, T12N, RIOE, UN ~t6tC~,of odu t'v ,pt I FI~'Ic, §~3 e¢~, Sec. 30, T12N, RIOE, UM At effective depth 1470' FNL, 4265 FEL, Sec. 30, T12N, RIOE, UM At total depth 1437' FNL, 4308' FEL, Sec. 30, T12N, RIOE, UM 5. Datum elevation (DF or KB) RKB 97 6. Unit or Property name Kuparuk River Unit 7. Well number 1G-16 p Se' r mPe~r ~ i t#~u_r~ Ne r 9. APl number 50-- 029-21031 10. Pool Kuparuk River Oil Pool · Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9225' MD feet Plugs (measured) None feet 6816' TVD 9134' MD feet Junk (measured) None 6743' TVD feet Casing Length Structural Size Cemented Measured depth True Vertical depth Conductor 80' Surface 2604' Intermediate Production 9183' Liner Perforation depth: measured true vertical 16" 10-3/4" 212 SX CS 11 1050 SX PF E & 250 SX PFC 7" 1200 SX Class G 250 SX PFC 8557'-8563', 8569'-8576', 8582'-8588', 8602'-8606', 8670'-8742', 8954'-9014' 6279'-6284', 6289'-6294', 6299'-6304', 6315'-6319, 6369'-6427', 6598'-6646' 114' MD 114' TVD 2339' MD 2221' TVD 9216' MD 6809' TVD Tubing(size, grade and measured depth) 3-1/2", J-55 tbg w/tail @ 8857' Packers and SSSV(type and measured depth) RRH pkr ¢ 8338', RH pkr @ 8645', WD pkr @ 8830'~ & TRDP SSSV @ 1840' 12.Attachments Description summaw of proposal ~ Detailed operations program ~ Convert from water injection to WAG BOP sketch 13. Estimated date for commencing operation Au gu s t/September 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the~best of my knowledge - Commission Use Only Date Conditions of approval Notify commission so representative may witness F'., Plug Integrity [] BOP Test ~ Location clearance Approved Copy ORIGINAL SIGNED BY Approved by LONNIE O. SMITH Commissioner by order of the commission Date Form 10-403 Rev 124-85 Submit in triplicate STATE OF ALASKA ALA~..._~., OIL AND GAS CONSERVATION COk,,..._..SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other~ Workover 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 367' FSL, 428' FWL, Sec.29, T12N, R10E, UM At top of productive interval 1679' FNL, 3993' FEL, Sec.30, T12N, R10E, UM 5. Datum elevation (DF or KB) RKB 97 ' 6..U. nit or Property. name ~uparuk River Unit 7. Well number 1C-16 8. Approval number 8-54 9. APl number 50-- 029-21031 10. Pool Kuparuk River Oil Pool At effective depth 1470' FNL, 4265' At total depth 1437' FNL;, 4308' 11. Present well condit Total depth: Effective depth: FEL, 5ec.30, T12N, RIOE, UM FEL~ Sec.30~ T12N~ R10E~ UM ion summary measured 9225 'MD feet true vertical 6816 'TVD feet measured 9134 'MD feet true vertical 6743 ' TVD feet Plugs (measured) None Junk (measured) None Feet Casing Conductor Surface Production Length Size Cemented Measured depth 80' 16" 212 sx CS II 114'MD 2604' 10-3/4" 1050 sx PF E & 2639'MD 250 sx PFC 9183' 7" 1200 sx Class G & 9216'MD 250 sx PFC True Vertical depth 114'TVD 2221'TVD 6809'TVD Perforation depth: measured true vertical 8557'-8563', 8569'-8576', 8582'-8588', 8602'-8606', 8670'-8742', 8954'-9014' 6279'-6284', 6289'-6294', 6299'-6304', 6315'-6319', 6369'-6427', 6598'-6646' Tubing (size, grade and measured depth) 3-1/2", J-55 tbg w/tail @ 8857' Packers and SSSV (type and measured depth) RRH pkr ~ 8338', RH pkr ~ 8645', WD pkr @ 8830', & TRDP SSSV ~ 1840' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure C0mmlss,u,, Oil & C~as'Cons. Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Well Histor,~_) Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engi neet (Dani) SW03/59 Date Submit in Duplicate ' I '" :::"':~~iiira"d Gal Company ,r Well History - Initial Report~-~. Dally! InebuoUonl: Prepare and submit the "Initial RlpoH" on the first Wednesday after a well is spudded or workover operations are star~ed. Dally work prl0r to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O, no. AK3145 Operator ARCO Spudded or W.O. begun ACCEPT Date and der)th as of 8:00 a.m. 02/17/88 ( TD: 9225 PB: 9134 SUPV:SC o2/18/88 ( TD: 9225 PB: 9134 SUPV:GC 02/19/88 ( TD: 9225 PB: 9134 SUPV:GC 02/20/88 ( TD: 9225 PB: 9134 SUPV:GC 02/21/88 ( TD: 9225 PB: 9134 SUPV:GC 02/22/88 ( TD: 9225 PB: 9134 SUPV:GC ICounty. parish or borough NORTH SLOPE BOROUGH Lease or Unit ADL: 25640 Title WORKOVER API: 50-029-21031 IDate 02/17/88 IH°ur 1500 Complete record for each day reported NORDIC I ]Sta~;~ 1G-16 [Well no. IARCO W.I. 56.0000 Prior status if a W.O. KILLING WELL MW:11.3 NaC1 MOVE RIG FROM 1G-9 TO 1G-16. ACCEPT RIG @ 1500 HRS 2/16/88. RU WIRELINE. RIH TO PULL DUMMY FROM 8330'. COULD NOT FIND ANY DUMMY. RD WIRELINE. RU TO KILL WELL. PUMPING BRIDGESAL PILL AND 11.3 PPG BRINE. DAILY:S105,352 CUM:$105,352 ETD:S105,352 EFC:$365,000 CIRC/DISPLACE WELL MW:11.3 NaC1 WELL TAKING 25 BPH. ATTEMPTED TO CIRC W/ 8.6 SEAWATER. NO GOOD. PUMPED 6 BBLS BRIDGESAL PILL. SQZ W/ 150 PSI OVER. CIRC WELL W/ 8.6 PPG. REC'V 211BBLS 11.3 PPG NACL/BR. FORM PRESS 650 PSI. CUT WT TO 10.9 PPG. (84-109 PSI OVER BALANCE). CIRC 10.9 PPG NABR AROUND W/ 0 LOSS. DAILY:S39,300 CUM:$144,652 ETD:S144,652 EFC:$365,000 WORKING ON SLICK STICK MW:10.8 NaCl/NaBr CIRCULATED 10.9 PPG. FLUID LOSS @ 24 BPH. PUMPED 50 BBSL CLEAN BRIDGE PILL. MAX SQUEEZE PRESSURE = 425 PSI ON THE CASING. CIRC. 10.7 PPG. WELL FLOWING SLIGHTLY. PUMPED 10.8 PPG. WELL STATIC. SET BPV. ND TREE. NU BOPE & TESTED TO 3000 PSI. ATTEMPTED TO SHEAR SBR. DAILY:S40,064 CUM:$184,716 ETD:SIS4,716 EFC:$365,000 POH/CHANGING COLLARS MW:10.8 NaCl/NaBr CONTINUED ATTEMPTING TO SHEAR SBR-UNSUCCESSFUL. RIH WITH 400 GR STRING SHOT. SHOT AT TOP OF SBR WITH 125K UP. NO RESULTS. RIH WITH CHEM. CUTTER. CUT @ 8346' (10' BELOW BOTTOM GLM) WITH 110K UP. SEPARATED. LD TUBING HANGER. POH 2 STDS. RIH AND SET BAKER PKR & STORM VALVE BELOW TUBING HEAD. CHANGED TO 5000# HEAD. NU BOPE & TESTED TO 3500 PSI. PULLED BAKER PKR & LD. POOH. CHG OUT COLLARS TO AB-MOD, 8RD. LD SSSV. DAILY: $47,969 CUM: $232,685 ETD: $232,685 EFC:$365,000 POH WITH FTA #1 MW:10.8 NaC1/NaBr POH AND CHANGED OUT COLLARS. PU FTA · @ 8349'. ATTEMPT TO ~. SBR FREE WITH 108[ OVER PU W~. NO RESULTS ROTATED, ATTEMPTED TO RELEASE PKR - NO RESULTS. RELEASED GRAPPLE AND POH DAILY:S30,303 CUM:$262,988 ETD:S262,988 EFC:$365,000 TIH W/FTA [3 MW:10.8 NaCl/NaBr POH WITH FTA [1. TIH WITH FTA ~2. PUMPED AND SQUEEZED 50 BBLS POLYMER VIS PILL. WASHED TO TOP OF SBR - 1-1/2 FILL. CBU. POOH. MU FTA ~3 AND TIH. DAILY:S27,715 CUM:$290,703 ETD:S290,703 EFC:$365,000 The above Is correct F'or form preparation I~d distribution, see Procedures Manu~, 8action 10, Drilling, Pages 88 and'8?. I Date~.~/~-- '~c~ ITM ARCO 011 and Gas Company "'~aily Well History--interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Rel3ort official or representative test on "Final" form. f) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field KUPARUK RI~ Date and depth as of 8:00 a,m. I County or Parish Alaska, Inc. I NORTH SLOPE BOROUGH I Lease or Unit ~R UNIT I 1G-16 Complete record for each day while drilling or workover in progress 02/23/88 ( TD: 9225 PB: 9134 SUPV:GC 02/24/88 ( TD: 9225 PB: 9134 SUPV:GC 02/25/88 ( TD: 9225 PB: 9134 SUPV:SC 02/26/88 ( TD: 9225 PB: 9134 SUPV:SC 02/27/88 ( TD: 9225 PB: 9134 SUPV:SC 02/28/88 ( TD: 9225 PB: 9134 SUPV:SC 02/29/88 ( TD: 9225 PB: 9134 SUPV:SC NORDIC 1 ¸o) L1) 1.2) [3) J Statez~.( CIRC. OUT GAS BELOW PKR MW:10.8 NaCl/NaBr CONTINUED TIH WITH FTA #3. TAGGED @ 8349'. ENGAGED FISH & JARRED SBR FREE. CIRCULATE BOTTOMS UP. POH & LD SBR & CUT JT. SBR PINNED WITH 4 SCREWS. PU FTA #4. TIH. TAGGED @ 8374'. WASHED OVER & TAGGED PKR @ 8396'. ENGAGED & JARRED FREE. CIRCULATE BOTTOMS UP. DAILY:S50,946 CUM:$341,649 ETD:S341,649 EFC:$365,000 W/O WIRELINE TO CUT TBG MW:10.8 NaCl/NaBr FINISHED CIRC. POOH & LD RRH PKR AND CUT TAIL PIPE. MU FTA #5. TIH WITH 3-1/2" TUBING. TAGGED FISH @ 8530'. ENGAGED & WORKED PIPE 46K OVER P/U. NO MOVEMENT. ORDERED W/L TO CUT BELOW BLAST JOINT. DAILY:S51,006 CUM:$392,655 ETD:S392,655 EFC:$365,000 BAILING SAND FROM TBG MW:10.8 NaCl/NaBr RIG UP TUBING CUTTER. CANNOT GET BELOW 8667'. RIG DOWN E-LINE. RU SLICK LINE UNIT. BAIL SAND FROM INSIDE TUBING. DAILY:S25,300 CUM:$417,955 ETD:S417,955 EFC:$365,000 RU ARCTIC CTU MW:10.8 NaCl/NaBr BAILED OUT SAND TO 8711'. WAITED ON ARCTIC COIL TUBING UNIT (3.5 HRS). RIG UP ARCTIC COIL TUBING UNIT ON RIG FLOOR. DAILY:S48,431 CUM:$466,386 ETD:S466,386 EFC:$365,000 RU DRESSER W/L MW:10.8 NaCl/NaBr RU COIL TUBING. CLEAN OUT WELL. RD COIL TUBING. RU DRESSER WIRELINE UNIT. DAILY:S52,943 CUM:$519,329 ETD:S519,329 EFC:$365,000 POOH W/ BLAST RINGS MW:10.8 NaC1/NaBr RIH W/ SLICKLINE TO PUSH FISH TO TD. FOUND NOTHING STUCK IN TUBING. RU WIRE LINE. CUT TUBING AGAIN AT 8765'. TUBING FREE. CIRC BOTTOMS UP. POOH W/ BLAST RINGS. DAILY:S74,393 CUM:$593,722 ETD:S593,722 EFC:$365,000 POOH W/ TUBING MW:10.8 NaCl/NaBr LD BLAST RINGS. RIH W/ OVERSHOT WITHOUT GRAPPLE ON 3-1/2" TUBING. RU SL. RIH CAN'T REACH FISH IN TAILPIPE. WORK TO GET OVERSHOT ON TUBING STUB. NO GOOD. RD SLICK LINE. POOH W/ TUBING AND OVERSHOT. DAILY:S27,640 CUM:$621,362 ETD:S621,362 EFC:$365,000 IWell no. The above is correct For form p,,/e~p~ration and distribution see Proce{¥res Manual Section 10, Drilling, P~l~es 86 and 87 IDale I Title ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History--Interim Instruction-,: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drJJJ stem fesls sequentially. Atlach description of all cores. Work performed by Producing Section will be reported on "interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District i County or Parish IState ~ORTH S,,oPE ARCO Alaskar Inc. ILease or UnitBOROUGH I I 1G-16 Field KUPARUK RIVER UNIT Well no. Date and dapth as of 8:00 a.m. 03/01/88 ( TD: 9225 PB: 9134 SUPV:SC O3/02/88 ( TD: 9225 PB: 9134 SUPV:SC 03/03/88 ( TD: 9225 PB: 9134 SUPV:JC 03/04/88 ( TD: 9225 PB: 9134 SUPV:JC 03/05/88 ( TD: 9225 PB: 9134 SUPV:JC 03/06/88 ( TD: 9225 PB: 9134 SUPV:JC Complete record for each day while drilling or workover in progress NORDIC 1 .4) .5) .6) L7) LB) /9) POOH W/ FISH MW:10.8 NaCl/NaBr POOH W/ TUBING. RIH W/ DP, OVERSHOT AND JARS. LATCH FISH. JAR LOOSE. CIRC. STUCK AGAIN. JAR LOOSE. POOH W/ FISH. DAILY:S73,600 CUM:$694,962 ETD:S694,962 EFC:$365,000 RIH TO LATCH FISH MW:10.8 NaCl/NaBr POOH W/ FISH. LD SEAL ASSY, 1 JT, GLM, CUT OFF PIECE. RIH W/ GUIDE SHOE AND DP. REVERSE SAND FROM TOP OF PKR. POOH. RU SLICKLINE. RIH W/ 5-3/8" IMPRESSION BLOCK. CAN SEE TOP OF FISHING NECK ON DRESSER TOOL. RIH. LATCH FISH. JAR. STUCK OVERSHOT. RIH LATCH FISH. JAR. STUCK OVERSHOT. RIH ONE MORE TIME. DAILY:S25,545 CUM:$720,507 ETD:S720,507 EFC:$365,000 CBU MW:10.8 NaCl/NaBr 3 TRIPS W/ W/L RET TOOLS. NO GOOD. RIH W/ TRI-STATE SUCKER ROD OVERSHOT. LATCHED AND JARRED. NO GOOD. POOH. CUT LINE. MADE 2 RUNS. COULD'NOT LATCH FISHING NECK. RD CAMCO. MU FTA # 8. TIH. MILLED AND REAMED TIGHT SPOTS AT 8661' TO 8662'. MILLED PKR AT 8820' - 8822'. CIRC BTM UP. DAILY:S36,642 CUM:$757,149 ETD:S757,149 EFC:$365,000 RIH W/ 6-1/8" BIT MW:10.8 NaCl/NaBr FIN CIRC. POOH W/ MILL SHOE. PU FTA ~ 9. TIH. LATCHED PKR AT 9082' POOH AND MU BHA # 10. TIH. DAILY:S87,587 CUM:$844,736 ETD:S844,736 EFC:$365,000 GR/JB RUN MW:10.8 NaCl/NaBr CONTINUED TIH WITH BHA ~10. WASHED FILL F/9100'-9108'. HARD @ 9108' CIRC. BOTTOMS UP. POOH LDDP & BHA gl0. RU DA. RIH W/6.00" GR & JB. TAGGED @ 8640'. FINE MARKS 3~0'. TIH WITH 5.75" GR & JB. DID NOT TOUCH @ 8640'. TAGGED TD @ 9107' WLM. POOH - SAW NOTHING @ 8640'. DAILY:S57,580 CUM:$902,316 ETD:S902,316 EFC:$365,000 ND BOPE MW:10.8 NaCl/NaBr RIH WITH 'WD' PKR ON WIRELINE. SET @ 8816' WLM. RAN 3-1/2" COMPLETION ASSY WITH TAIL @ 8857', SSSV @ 1840', 'RRH' PKR @ 8338', 'WD' PKR @ 8830'. SPACED OUT. LANDED HANGER. PRESSURED TO 2500 PSI - SET ?KRS. SOS FAILED EARLY @ 2500 PSI. RU OTIS. SET STANDING VALVE @ 'D' NIPPLE 8846.67' PRESSURED UP TO 2500 PSI & TESTED TUBING. TESTED ANNULUS & SSSV. SHEARED SBR. LANDED HANGER. RETRIEVED STANDING VALVE. SET BPV & ND BOPE. RH PKR @ 8645' DAILY:S114,457 CUM:$1,016,773 ETD:S1,016,773 EFC:$365,000 The above is correct For form prfl4~aration and distribution see Procedl~r,,bs Manual Section 10, Drilling, Pa/g~s 86 and 87 Dale I/itle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructlona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data Jn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO Alaska, Inc. NORTH SLOPE BOROUGH AK Lease or Unit IWell no. Field KUPARUK RIVER FIELD I ADL: 25640 1G-16 ITitleAuth. or W.O. no. I WORKOVER Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 03/07/88 ( TD: 9225 PB: 9134 SUPV:JC API: 50-029-21031 IA.R.Co. W.I. rrotal number of wells (active °r inactive) °n thisI Icost center prior to plugging and 56. 0000 labandonment of this well 02116188 / 150o Complete record for each day reported NORDIC 1 RELEASED RIG MW: 0.0 DIESEL ND BOPE. NU MCEVOY 5K GEN II TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. ANNULUS 0 PSI, TUBING 250 PSI. SECURED WELL AND RELEASED RIG @ 1200 fiRS, 3/6/88. DAILY:S18,334 CUM:$1,035,107 ETD:S1,035,107 EFC:$365,000 Old TD I New TD Released rig J Date Classifications (o11, gas, etc.) Producing method PB Depth Knd of rg Type completion (single, dual, etc.) Official reservoir name(s) Potential lest data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature~ Date JTme ~X~ATE EN~,NEE~ For forr/~reparation and distribution, see i~rdg'edures Manual, Section tO, Drilling, Pagee 86 and 87. STATE OF ALASKA ALAbwA OIL AND GAS CONSERVATION COM...~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown C Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~. Other .~ Workover 2. Name of Operator 5. Datum elevation (DF or KB)- ARCO Alaska, Inc. RKB 97' Feet 3. Address 6. ~nit or Property name P.0. Box 100360, Anchorage, AK 99510-0360 ~uparuk River Unit 4. Location of well at surface 367' FSL, 428' FWL, Sec.29, T12N, RIOE, UM At top of productive interval 1679' FNL, 3993' FEL, 5ec.30, 1'12N, R10E, UM 7. Well number 1G-16 8. Approval number 8-54 9. APl number 50-- 029-21031 At effective depth 1470' FNL, 4265' FEL, Sec.30, T12N, At total depth 1437' FNL~ 4308' FEL~ 5ec.30a T12N~ 11. Present well condition summary Total depth: measured 9225 true vertical 6816 RIOE, UM RIOEa UM 10. Pool Kuparuk River 0il Pool 'MD ' TVD feet feet Plugs (measured) None Effective depth: measured 9134 'MD true vertical 6743 ' TVD feet feet Junk (measured) None Casing Length Size Conductor 80 ' 16" Surface 2604 ' 10-3/4" Producti on 9183 ' 7" Cemented Measured depth 212 sx CS I! 114'MD 1050 sx PF E & 2639'MD 250 sx PFC 1200 sx Class G & 9216'MD 250 sx PFC True Vertical depth 114 'TVD 2221 'TVD 6809 ' TVD Perforation depth: measured 8557'-8563', 8569'-8576', 8582'-8588', 8602'-8606', 8670'-8742', 8954'-9014' 6279'-6284', 6289'-6294', 6299'-6304', true vertical 6315'-6319', 6369'-6427', 6598'-6646' Tubing (size, grade and measured depth) 3-1/2", J-55 tbg w/tail ~ 8857' Packers and SSSV (type and measured depth) RRH pkr @.8338', RH pkr ~ 8645', WD pkr ~ 8830' 12. Stimulation or cement squeeze summary , & TRDP SSSV @ 1840' N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 Histor,~) Daily Report of Well Operations Copies of Logs and Surveys Run Q 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~/J4/R_./ ~iL//,ULJt Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) 5W03/59 Date Submit in Duplicate pany~ ~- Well History- initial R~~ Daily~ I~ and a,,,,mtt tho "lnlUal Report' on the .flr~. Wednetday aftef a well ie spudded or workover operetione are ettrted. Dally wo~ IDr~or to I~tlddlflg should bo eummeflzeo on th(, form giving inclusive cietee only. Olstdct ] ~ounly. parian or borough ~RCO ~aaka, Znc. [ NORTH S~P~ BOROUGH Field ILea~ or Unit ~~ RZ~R FZ~ I ~L: 25640 Au~. or W.O. no. ITM ~145 I WO~O~ ~I: 50-029-21031 ~CO 1G-16 IWell no. IDle IHour ACCEPT 02/17/88 1500 IAI~CO w.i. 56.0000 Prior status if a W.O. Spudded or W.O. begun Date and deplh- as of 8:00 a.m. 02/17/88 ( TI:)= 9225 PB: 9134 SUPV:SC 02/18/88 ( TD: 9225 PB: 9134 SUPV:GC 02/19/88 ( I"D: 9225 PB: 9134 SUPV:GC 02/20/88 ( TD: 9225 PB: 9134 SUPV:GC 02/21/88 ( TD: 9225 PB: 9134 SUPV:GC 02/22/88 ( TD: 9225 PB: 9134 SUPV:GC Complete reoord for each day reported NORDIC 1 KILLING WELL MW:11.3 NaC1 MOVE RIG FROM 1G-9 TO 1G-16. ACCEPT RIG ~ 1500 HRS 2/16/88. RU WIRELINE. RIH TO PULL DUMMY FROM 8330'. COULD NOT FIND ANY DUMMY. RD WIRELINE. RU TO KILL WELL. PUMPING BRIDGESAL PILL AND 11.3 PPG BRINE. DAILY:S105,352 CUM:$105,352 ETD:S105,352 EFC:$365,000 CIRC/DISPLACE WELL MW:11.3 NaC1 WELL TAKING 25 BPH. ATTEMPTED TO CIRC W/ 8.6 SEAWATER. NO GOOD. PUMPED 6 BBLS BRIDGESAL PILL. SQZ W/ 150 PSI OVER. CIRC WELL W/ 8.6 PPG. REC'V 211BBLS 11.3 PPG NACL/BR. FORM PRESS 650 PSI. CUT WT TO 10.9 PPG. (84-109 PSI OVER BALANCE). CIRC 10.9 PPG NABR AROUND W/ 0 LOSS. DAILY:S39,300 CUM:$144,652 ETD:S144,652 EFC:$365,000 WORKING ON SLICK STICK MW:10.8 NaC1/NaBr CIRCULATED 10.9 PPG. FLUID LOSS @ 24 BPH. PUMPED 50 BBSL CLEAN BRIDGE PILL. MAX SQUEEZE PRESSURE = 425 PSI ON THE CASING. CIRC. 10.7 PPG. WELL FLOWING SLIGHTLY. PUMPED 10.8 PPG. WELL STATIC. SET BPV. ND TREE. NU BOPE & TESTED TO 3000 PSI. ATTEMPTED TO SHEAR SBR. DAILY:S40,064 CUM:$184,716 ETD:S184,716 EFC:$365,000 POX/CHANGING COLLARS MW:10.8 NaCl/NaBr CONTINUED ATTEMPTING TO SHEAR SBR-UNSUCCESSFUL. RIH WITH 400 GR STRING SHOT. SHOT AT TOP OF SBR WITH 125K UP. NO RESULTS. RIH WITH CHEM. CUTTER. CUT @ 8346' (10' BELOW BOTTOM GLM) WITH 110K UP. SEPARATED. LD TUBING HANGER. POH 2 STDS. RIH AND SET BAKER PKR & STORM VALVE BELOW TUBING HEAD. CHANGED TO 5000~ HEAD. NU BOPE & TESTED TO 3500 PSI. PULLED BAKER PKR & LD. POOH. CHG OUT COLLARS TO AB-MOD, 8RD. LD SSSV. DAILY:S47,969 CUM:$232,685 ETD:S232,685 EFC:$365,000 POH WITH FTA #1 MW:10.8 NaCl/NaBr POH AND CHARGED OUT COLLARS. PU FTA ~1. TIH. LATCHED FISH @ 8349'. ATTEMPT TO J~R SBR FREE WITH 108K OVER PU ~T. NO RESULTS. ROTATED, ATTEMPTED TO RELEASE PKR - NO RESULTS. RELEASED GRAPPLE AND POH. DAILY:S30,303 CUM:$262,988 ETD:S262,988 EFC:$365,000 TIH W/FTA 93 MW:10.8 NaCl/NaBr POH WITH FTA 91. TIH WITH FTA t2. PUMPED AND SQUEEZED 50 BBLS POLYMER VIS PILL. WASHED TO TOP OF SBR - 1-1/2 FILL. CBU. POOH. MU FTA ~3 AND TIH. DAILY:S27,715 CUM:$290,703 ETD:S290,TM EFC:$365,000 The above Ii correct F'or form prepirltl dlltdbutlo~, m Prog~duml Manudlg, Section 10, Ddlllft~, Peg# M afters?. ARCO Oil and Gas Company '~-~Daily Well History--Interim Inltn~ctlenl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem testa sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. I) Submit "lnlarlm" sheets when filled out but not less frequently than even/30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting Of oil string until completion. District Field KUP~.RflK Dete and deptl~ as of 8:00 a.m. I County or Parish I NORT[~ BOROUGH ARCO Alaska. Inc. ILeasa or Unit SLOPE I rRR UNIT I 1G-l~ Complete record for each day while drilling or workover in progress 02/23/88 ( TD: 9225 PB: 9134 SUPV:GC 02/24/88 ( TD: 9225 PB: 9134 SUPV:GC 02/25/88 ( TD: 9225 PB: 9134 SUPV:SC 02/26/88 ( TD: 9225 PB: 9134 SUPV:SC 02/27/88 ( TD: 9225 PB: 9134 SUPV:SC 02/28/88 ( TD: 9225 PB: 9134 SUPV:SC 02/29/88 ( TD: 9225 PB: 9134 SUPV:SC StateAK NORDIC IWell no. CIRC. OUT GAS BELOW PKR MW:10.8 NaCl/NaBr CONTINUED TIH WITH FTA #3. TAGGED @ 8349'. ENGAGED FISH & JARRED SBR FREE. CIRCULATE BOTTOMS UP. POH & LD SBR & CUT JT. SBR PINNED WITH 4 SCREWS. PU FTA #4. TIH. TAGGED @ 8374'. WASHED OVER & TAGGED PKR @ 8396'. ENGAGED & JARRED FREE. CIRCULATE BOTTOMS UP. DAILY:S50,946 CUM:$341,649 ETD:S341,649 EFC:$365,000 8) W/O WIRELINE TO CUT TBG MW:10.8 NaC1/NaBr FINISHED CIRC. POOH & LD RRH PKR AND CUT TAIL PIPE. MU FTA 95. TIH WITH 3-1/2" TUBING. TAGGED FISH @ 8530'. ENGAGED & WORKED PIPE 46K OVER P/U. NO MOVEMENT. ORDERED W/L TO CUT BELOW BLAST JOINT. DAILY:S51,006 CUM:$392,655 ETD:S392,655 EFC:$365,000 BAILING SAND FROM TBG MW:10.8 NaCl/NaBr RIG UP TUBING CUTTER. CANNOT GET BELOW 8667'. RIG DOWN E-LINE. RU SLICK LINE UNIT. BAIL SAND FROM INSIDE TUBING. DAILY:S25,300 CUM:$417,955 ETD:S417,955 EFC:$365,000 LO) RU ARCTIC CTU MW:10.8 NaCl/NaBr BAILED OUT SAND TO 8711' WAITED ON ARCTIC COIL TUBING UNIT (3.5 HRS). RIG UP ARCTIC COIL TUBING UNIT ON RIG FLOOR. DAILY:S48,431 CUM:$466,386 ETD:S466,386 EFC:$365,000 L1) RU DRESSER W/L RU COIL TUBING. CLEAN OUT WELL. DRESSER WIRELINE UNIT. MW:10.8 NaCl/NaBr RD COIL TUBING. RU L2) .3) DAILY: $52,943 CUM: $519,329 ETD: $519,329 EFC:$365,000 POOH W/ BLAST RINGS MW:10.8 NaCl/NaBr RIH W/ SLICKLINE TO PUSH FISH TO TD. FOUND NOTHING STUCK IN TUBING. RU WIRE LINE. CUT TUBING AGAIN AT 8765'. TUBING FREE. CIRC BOTTOMS UP. POOH W/ BLAST RINGS. DAILY:S74,393 CUM: $593,722 ETD:S593,722 EFC: $365,00,0~ POOH W/ TUBING ~:10.8 NaCl/NaBr LD BLAST RINGS. RIH W/ O~RSHOT WITHOUT G~PLE ON 3-1/2" TUBING. RU SL. RIH C~'T REACH FISH IN TAILPIPE. WORK TO GET O~RSHOT ON TUBING STUB. NO GOOD. RD SLICK LINE. POOH W/ TUBING ~D O~RSHOT. DAILY: $27,640 CUM: $621,362 ETD: $621,362 EFC:$365,000 The above is correct For form p/~p~retion and dlstribulion see Proce~lCres Manual Section 10, Drilling, Pl~les 86 and 87 Dale ITitle I j-l-: ASSOOIATE EN(~INEER ARCO 011 and Gas Company Daily Well History--Interim InetllJctione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. AlteCh description of sir cores. Work performed by Producing Section will he reported on "Interim" sheets until final completion. ReDort official or representative lest on "Final" form. 1) Submit "lnterll~l" sheets when filled out but not less frequently than every 30 days. or on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date end deDIh as of 8:00 a.m. County or Parish ~ NORTH SLOPE ARCO Alaskat Inc. [Lease or Unit BOROUGH I KUPARUK RIVER UNIT ~ 1G-16 'Complete record for each day while drilling or workover in progress 03/01/88 ( TD: 9225 PB: 9134 SUPV:SC 03/02/88 ( TD: 9225 PB: 9134 SUPV:SC 03/03/88 ( TD: 9225 PB: 9134 SUPV:JC 03/04/88 ( TD= 9225 PB= 9134 SUPV:JC 03/05/88 ( TD: 9225 PB: 9134 SUPV:JC 03/06/88 ( TD: 9225 PB: 9134 SUPV:JC IState ~ NORDIC i 5) L6) [7) 18) L9) POOH W/ FISH MW:10.8 NaCl/NaBr POOH W/ TUBING. RIH W/ DP, OVERSHOT AND JARS. LATCH FISH. JAR LOOSE. CIRC. STUCK AGAIN. JAR LOOSE. POOH W/ FISH. DAILY:S73,600 CUM:$694,962 ETD:S694,962 EFC:$365,000 RIH TO LATCH FISH MW:10.8 NaCl/NaBr POOH W/ FISH. LD SEAL ASSY, 1 JT, GLM, CUT OFF PIECE. RIH W/ GUIDE SHOE AND DP. REVERSE SAND FROM TOP OF PKR. POOH. RU SLICKLINE. RIH W/ 5-3/8" IMPRESSION BLOCK. CAN SEE TOP OF FISHING NECK ON DRESSER TOOL. RIH. LATCH FISH. JAR. STUCK OVERSHOT. RIH LATCH FISH. JAR. STUCK OVERSHOT. RIH ONE MORE TIME. DAILY:S25,545 CUM:$720,507 ETD:S720,507 EFC:$365,000 CBU MW:10.8 NaCl/NaBr 3 TRIPS W/ W/L RET TOOLS. NO GOOD. RIH W/ TRI-STATE SUCKER ROD OVERSHOT. LATCHED AND JARRED. NO GOOD. POOH. CUT LINE. MADE 2 RUNS. COULD NOT LATCH FISHING NECK. RD CAMCO. MU FTA 9 8. TIH. MILLED AND REAMED TIGHT SPOTS AT 8661' TO 8662'. MILLED PKR AT 8820' - 8822' CIRC BTM UP. DAILY:S36,642 CUM:$757,149 ETD:S757,149 EFC:$365,000 RIH W/ 6-1/8" BIT MW:10.8 NaCl/NaBr FIN CIRC. POOH W/ MILL SHOE. PU FTA 9 9. TIH. I.J%TCHED PKR AT 9082' POOH AND MU BHA 9 10. TIH. DAILY:S87,587 CUM:$844,736 ETD:S844,736 EFC:$365,000 GR/JB RUN MW:10.8 NaC1/NaBr CONTINUED TIH WITH BHA ~10. WASHED FILL F/9100'-9108' HARD @ 9108' CIRC. BOTTOMS UP. POOH LDDP &-BHA ~10. RU DA. RIH W/6.00" GR & JB. TAGGED @ 8640' . FINE MARKS 360'. TIH WITH 5.75" GR & JB. DID NOT TOUCH @ 8640'. TAGGED TD @ 9107' WLM. POOH - SAW NOTHING @ 8640'. DAILY:S57,580 CUM:$902,316 ETD:S902,316 EFC:$365,000 ND BOPE MW:10.8 NaCl/NaBr RIH WITH 'WD' PKR ON WIRELINE. SET @ 8816' WLM. RAN 3-1/2" COMPLETION ASSY WITH TAIL @ 8857', SSSV @ 1840', 'RRH' PKR @ 8338', 'WD' PKR @ 8830'. SPACED OUT. LANDED HANGER. PRESSURED TO 2500 PSI - SET PKRS. SOS FAILED EARLY @ 2500 PSI. RU OTIS. SET STANDING VALVE @ 'D' NIPPLE 8846.67'. PRESSURED UP TO 2500 PSI & TESTED TUBING. TESTED ANNULUS & SSSV. SHEARED SBR. LANDED HANGER. RETRIEVED STANDING VALVE. SET BPV & ND BOPE. RH PKR @ 8645'. DAILY:S114,457 CUM:$1,016,773 ETD:S1,016,773 EFC:$365,000 IWell no. The above is correct For form pre. ration and dlelribution see Proced~r.~e Manual Section tO, Drilling, Pa~a 86 and 87 ASSOCIATE ENGINEER ~ ARCO Oil and Gas Company · Daily Well History-Final Report |,11tllJollo~ll: Prepare and suDmlf the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Re~ert*° should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish I State ARCO Alaska, Inc. I NORTH SLOPE BOROUGH JLease or Unit IWell no. Field KUPARUK RIVER FIELD ITitle.ADL: 25640 1G-16 I Auth. or W.O. no. I I WO~KOVER API: 50-029-21031 OperatOr J A.R.Co. W.I. ARCO I 56.0000 Spudded or W.O. begun Date ACCEPT 02/16/88 Dale and depth aa of 8:00 a.m. Old TD 03/07/88 ( 2 TD: 9225 PB= 9134 SUPV:JC Released rig Classifications (oil, gas, etc.) Producing method Complete record for each day reported NORDIC I Iotal number of wells (active or inactive) on this~ DSt center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 1500 FRS RELEASED RIG MW: 0.0 DIESEL ND BOPE. NU MCEVOY 5K GEN II TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. ANNULUS 0 PSI, TUBING 250 PSI. SECURED WELL AND RELEASED RIG @ 1200 FRS, 3/6/88. DAILY:S18,334 CUM:$1,035,107 ETD:S1,035,107 EFC:$365,000 New TD J PB Depth Date I Kind of rig Type completion (single. dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X lenglh Choke size T.P. C.P. Water % GOR Gravity Allowable Elfective date corrected The above II correct For forq(~reparatlon end distribution, see I~rd~duree Manual, Section t0, Drilling, Pegel 88 and 87. Date ITitle ARCO Alaska, Inc, Date: April 20, 1988 Transmittal #: 7146 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ Kuparuk Well Pressure Report 2 - 8 - 8 8 Static 'C' Sand '"---~1 9 Kuparuk Well Pressure Report 2 - 3 - 8 8 'A' Sand ~'--~1 G-09 Kuparuk Well Pressure Report 2 - 3 - 8 8 Static 'C' Sand -'~ 1 G-09 Kuparuk Well Pressure Report 2- 3- 8 8 Static Both Sands '~ 2C-04 Kuparuk Well Pressure Report I 2-1 3-87 'A' Sand "~3 H - 0 5 Post-Frac Report 4 - 6 - 8 8 AIIo Frac 10 3 H 0 2 Post-Frac Report 4 - 6 - 8 8 AIIo Frac 10 H-03 Post-Frac Report 4 - 6 - 8 8 AIIo Frac 10 H 0 7 Treatment Report 4 - 1 3- 8 8 ~ 1 Y- 1 4 Pulse Test 3 - 1 I - 8 8 'A' & 'C' Sands -- Anch0rsge Receipt Acknowledged: DISTRIBUTION: D & M :ijj~~~ Date: Chevron Mobil SAPC Unocal ARCO Alaska,, Subs~dia~ of Atlantic Richfield C~iS~any WELL /'~ -/~ CONTRACTOR WELL SERVICE REPORT FIELD · DISTRICT- STATE OPERATIO~N AT REPORT TIME IDAY~; j DATE J 3-zo-~ REMARKS ~lqo I $5o ..7..-A.~.~o ~- ~ c_-slc~t r-J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1988 Transmittal #: 7O94 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-8 ~ 3H-9 3A-6 3A-15 3A-15 Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Data Frac Pressures BHP Data Worksheet Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) 12-23-88 Static 2-8-88 Static 'C' Sand 1-15-88 1-3-88 #94225 1-15-88 Static 'A' Sand 1-15-88 Static 'C' Sand HAPPY VALENTINE'S DAY Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska - Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a Subsfdiary of AllanlicRichlieldCompany STATE OF ALASKA ALASK.,~.~OIL AND GAS CONSERVATION COMM.,-~,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of R(~quest: Abandon ~ Suspend ~q Operation Shutdown Q Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing ,/~Amend order F-q_,, Perforate ~ Otherx 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska~ Inc. KB 97' 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit feet 4. Location of well at surface 367' FSL, 428' FWL, 5ec.29, T12N, RIOE, UM At top of productive interval 1679' FNL, 3993' FEL, Sec.30, T12N, RIOE, UM At effective depth 1470' FNL, 4265' FEL, Sec.30, T12N, RIOE, UM At total depth 1437' FNL, 4308' FEL, Sec.30, T12N R10E UN 11. Present well condition summary Total depth: measured 9225 'ND feet Plugs (measured) true vertical 681 6 ' TVD feet 7. Well number 8. Permit number 9. APl number 50-- 10. Pool aruk River Oil Pool None Effective depth: measured 91 34 ' MD feet true vertical feet 6743 ' TVD Casing Length Size - Conductor 114' Surface 2604 ' Production 9183' 1 6" 1 0-3/4" 7 '; Junk (measured) None Cemented Measured depth 212 sx CS Ii 1050 sx PF E & 250 sx PFC 1200 sx Class G ~ 250 sx PFC 114'MD 2639'MD 9216'MD ~ue Verticaldepth 114'TVD 2221'TVD 6809'TVD Perforation depth: measured 8557 ' -8563 ' 8670'-8742' true vertical 6279'-6284' 6369 ' -6427 ' Tubing (size, grade and measured depth) 3-1/2" J-55 @ 8851' Packers and SSSV (type and measured depth) "RRH" 12.Attachmen!,s~ Description summary of proposal ;- , 8569'-8576' , 8954'-9014' , 6289'-6294' , 6598'-6646' , 8582'-8588' , 6299'-6304' Detailed operations program [] , 8602'-8606' , 6315'-6319' , RECEi ~ ,,,-:, ~s~,a Oil & BOP sketch 13. Estimated date for commencing operation February 10, 1988 14. If proposal was verbally approved Name of approver Date approved ORIGINAL SIGNED BY Approved by Form 10-403 Rev ll~J~F- C,. $~iTH 15. I herebyf'certify~-,that the-/f°reg°ing is true and correct to the best of my knowledge Signed [/~'l_ ['i''i''i/'" ~'''/'!// /'~''''' ' Title Associate Enq~n~r Commission Use Only ( JWR ) SA3/43 Conditions'Gf approval Notify commission so representative may witness I Approval No. ',~ Plug integrity [] BOP Test [] Location clearanceI &pproved Copy Return~i ~ L;OmmlSsloner by order of / the commission Date,~-- Submit in triplicate~/ 1G-16 KUPARUK WORKOVER COUPLING AND WELLHEAD CHANGE OUT AND RECOMPLETION PRELIMINARY PROCEDURE Pre-Rig Arrival Operations: 1) Bullhead diesel to perforations. 2) Set positive plug in "D" nipple and test same. Bleed pressure off. 3) Pull gas lift valve from first mandrel above retrievable packer. 4) Test wellbore to 1000 psi, bleed tubing and annulus pressure. 5) Cut tubing with chemical cutter between GLM //2 and top of carbide blast rings. Rig Operations: 1) MIRU workover rig. 2) Kill well. 3) ND tree. NU BOPE and test same. 4) Pull tubing free from packer. POH 2 stands. 5) PU storm packer and NU same into tubing string. 6) GIH and set storm packer directly below tubing spool. same and test to 500 psi. POH. RECEIVEg Release from 7) NU BOPE, change out wellhead to 5000 psi equipment. NU BOPE. 8) GIH and latch storm packer. POH with same. 9) Finish POH with tubing. LD GLMs and change out couplings to AB-Mod whi 1 e POH. 10) GIH with DP and POH with retrievable packer. POH. 11) GIH wi~h-tubing and POH with carbide blast rings and permanent packer seal assembly (cut tubing above GLM //1 if unable to POH). 12) Run triple packer completion assembly. 13) -ND BOPE. NU tree. 1G-16 KUPARUK WORKOVER PRELIMINARY PROCEDURE (cont'd) 14) Displace well to diesel. 15) Release rig. TOTP. Workover fluid: NaCl/NaBr BHP : 3000 psi @ 6300'TVD Anticipated start date' ~ ~FLxOX~ GPAD2/1G-16 12/28/87 ANNULAR PREVENTER PIPE RAMS 4 BLIND RAMS 5 TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 10-3/4" 2. 11"-;5000 PSI STARTING HEAD 3. 11"-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1 / 16"- $000 PSI PIPE RAMS $. 7-1/16" - $000 PSI BLIND RAMS 6. 7-1 / 16"- $000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PS! DOWNSTREAM OF THE REGULATOR. ;5. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK-AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED'. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO ;5000 PSI AND HOLD FOR 10 MINUTES. 8, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH ;5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO ;5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11, TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. dULY 28, 1986 Mr. C..V.' Chat rton May 27, 1986 --~ Page 2 KUPARUK · ATTACHMENT RIVER UNIT INJECTION INJECTION Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 1A-13 2/4/83 10/17/83 lA- 14 2/22/83 4 / 11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 · - 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 1E-23 1E-27 1E-30 1 Number Wel 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Date of Initial Injection Date of Injection Profile ~__x~'-~ 10/25/85 12/20/85 1G-6 7/28/84 9/23/84 1G-9 9/15/84 9/23/84 1G- i4 8/24/84 9/22/84 ~1G-16 8/24/84 9/22/84 .Well Number Date of Initial Injection Date of Injec-tion Profile 1F-10 8/13/84 10/30/84 1F- 11 8/12/84 9/24/84 1F- 13 8/16/84 9/25/84 1F-15 8/16/84 9/26/84 -. ARCO Alaska,~.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 21, 1984 Mr. C. V. 'Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent following wells at the Kuparuk River Well Action 1F-2 Fracture 1F-10 Convers i on 1F-11 Convers i on 1 F-13 Convers i on 1F-1 5 Convers ion 1G-3 Fracture 1G-4 ' Fracture 1G-5 Fracture 1G-6 Fracture 1G-6 Convers i on 1G-9 Conver s i on 1G-14 Convers i on 1G-16 Convers i on 2C-7 Fracture If you have any questions, please call notices on the Field' Date Performed 8/23/84 8/13/84 8/12/84 8/16/84 8/16/84 8/10/84 8/30/84 8/10/84 8/12/84 8/28/84 8/24/84 8/24/84 8/24/84 8/14/84 me at 263-4253. Kuparuk Operations Coordinator MLL / kmc Attachment (Duplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, In :c~.: O!i~ci-~,--_ ,c~' 3f, 5 Anchorage. Alaska 99510 Telephone 907 277 ,5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 8/17/84 Transmittal No: 4691 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CH FINALS/Schlumberger 1G-16~ CBL Variable Density 5/29/84 8800 - 9050 Run 1 2A-lA CBL " " GCT 6/02/84 5895 - 7502 " 2A-2~ CBL " . " GCT 6/02/84 5291 - 6544 " 2A-3"'1 '~' CBL " " CIS 6/01/84 4948 - 7092 " 2A-4'/ CBL " " 6/01/84 6750 - 8018 " 2A-3j CBL " " CRS/RTS/DDL 6/15/84 6583 - 7081 Run 2 & 3 2A-5 "- CBL " " 6/03/84 7695 - 8938 Run 1 2A.-6 CBL " " 6/03/84 6995 - 8078 " 2A-7 ~ CBL " " GCT 6/03/84 6895 - 7823- " 2A-lA ~J' Gyro Cont. Tool "CBL/VDL" 6/02/84 60 - 7454 " 2A-2 f " " " " " 6/04/84 60 -. 8060 " 2A-3/~ " " " " " 6/02/84 60.5 - 7050 " 2A-4~r " '" " " " 6/02/84 60.5 - 8003 " 2A-6 / " " " " " 6/04/84 60 - 8060 " 2A-7 " " " " " 6/04/84 Surf - 7805 " /cat Receipt Acknowledged: B. Adams D & M F.G. Baker Drilling P. Baxter DISTRIBUTION oeo ogw W.~. Pasher BPAE 'Mobil Chevron NSK Operations G. Phillips Phillips Oil J.J. Rathmell R&D State of Alaska Sohio Union Well Files -' STATE OF ALASKA ALAS'F~ OIL AND GAS CONSERVATION'C'0M MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 367' FSL, 428' FWL, SEC. 29 T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 97' (RKB) 12. 7. Permit No. 83-155 8. APl Number 50- 029-21 031 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1(3-16 11. Field and Pool KUPARUK RIVER FIELD J6. Lease Designation and Serial No. KUPARUK R I VER O I L ADL 25640, ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate Stimulate Repair Well Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation [] Abandonment [] Change Plans [] . Repairs Made [] Other [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On August 24, 1984, Kuparuk well to a water injector well. No being injected into both the "A" 1G-16 was converted from a producer downhole changes were made and water and "C" sands. is 14. I hereby certify that the foregoing is true and correct to the best of mKYL~o~gk Signed ~/~j_~~~/4~--~ j TitleOPE RAT ! ONS COORD I N AT OR The space below for Commission use 9/18/84 Date ~ ~ ~. Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Posl Office~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 25, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are notices .of intention to convert the following Kuparuk wells from producer to water injection: 1F-10, 1F-11 1F-13, 1F-15 1G-6, 1G-9, ~G-14, 1G-16 If you have any questions, please call me at 263-4253, Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JUL 2 i91 4 " ~ Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanlJcRichlieldCompany STATE OF ALASKA ALASKA,._..L AND GAS CONSERVATION C,,,..~iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-155 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 031 4. Location of Well SURFACE .LOCATION: 367' FSL, 428' FWL, SEC. 29 T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 97' (RKB) 6. Lease Designation and Serial No. ADL 25640, ALK 2571 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-16 11. Field and Pool KUPARUK RIVER F ! ELD KUPARUK RIVER O I L- POOL Check Appropriate Box -I~0 Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 1G-16 be converted from a producer to a water injection well. Currently the well produces from both the "A" and "C" sands. Downhole equipment will be unaltered and water injected into both sands. ANT! C I PATED START DATE AUgust 16, 1984 J U L 2 5 Oil & Gas Cons. Commission Anchorage 14.1 hereby certify that the foregoing~js~rue and correct ,o the best of m~/O~:)~~ S,~.ed .//~,/~~. T it,eOPERAT ! ONS cOORD I NATOR The space below for Commission use Date 7/25/84 Conditions of Approval, if any: Approved by BRIGiNAL B! L'ANilI£ C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent notices on the wells at the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 6/10/84 1F-3 Fracture 6/11 / 84 1F-5 Fracture 6/12/84 1F-9 Perforate 6 ! 16 ! 84 1F-9 Fracture 6/19/84 1F-1 0 Perforate 6/1 4/84 1F-1 0 Fracture 6/18/84 1F-11 Perforate 6/19/84 1F-1 3 Per forate 6/19 / 84 1F-1 4 Perforate 6/22/84 1F-1 4 Fracture 6/23/84 1F-15 Perforate 6/1 7/84 1F-15 Fracture 6/21 !84 1 F-16 Perforate 6/19/84 1G-7 Choke 5 / 4/84 1G-1 0 Per forate 5 ! 29 ! 84 1G-1 0 Fracture 5/30 / 84 1G-12 Per forate 5 / 29 ! 84 1G-1 2 Fracture 5/31/84 RECEIVED JUL 0 .~, Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA~OIL AND GAS CONSERVATION C~CYMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCAT I ON: 367 ' T12N, R10E, UM FSL, 428' FWL, SEC. 29 5. Elevation in feet (indicate KB, DF, etc.) 97 ' (RKB) 12. 7. Permit No. 83-155 8. APl Number 50- 029-21031 I 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1G-16 11. Field and Pool KUPARUK RIVER F i ELD 6. Lease Designation and Serial No. KU PARUK R ! VER O ! L ADL 25640, ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 11, 1984, the "A" sands of Kuparuk well 1G-16 were perforated for production. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD). 8954' - 9014' (4 SPF) RECEIVED JUL o 198 0ii E Gas Cons. Commissi0n Anchorage 14. I hereby certify that the foregoing is true add correct to the best of my knowledge. Signed ~~~J~~ Title K UPARUK The space below for Commission use OPERAT i ONS COORD I NATOR Date 6~28/84 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in DuPlicate June 29, 1984 1G-15 Perforate 5/27/84 1G-15 Fracture 6/9/84 1G-16 Perforate 6/11/84 1G-16 Fracture 6/13/84 2C-1 Fracture 5/19/84 2C-2 Fracture 5/20/84 2C-3 Fracture 5/21/84 2C-4 Fracture 5/22/84 2C-5 Fracture 5/23/84 2C-6 Fracture 5/25/84 CPF-2 Perforate 6/23/84 3C-6 Fracture 5/19/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) ARCO Alaska, Inc. ,....~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent notices on the wells at the Kuparuk River Field: Well Action Date Performed 1F-1 Fracture 6/10/84 1F-3 Fracture 6/11/84 1F-5 Fracture 6/1 2/84 1F-9 Perforate 6/16/84 1F-9 Fracture 6/19/84 1F-10 Perforate 6/14/84 1F-1 0 Fracture 6/1 8/84 1F-11 Perforate 6/19/84 1F-1 3 Perforate 6/19 / 84 1F-1 4 Perforate 6/22/84 1F-1 4 Fracture 6/23/84 1F-15 Perforate 6/17/84 1F-1 5 Fracture 6/21/84 1 F-16 Per forate 6 ! 19 / 84 1G-7 Choke 5/4!84 1G-1 0 Perforate 5/29/84 1G-1 0 Fracture 5/30/84 1G-1 2 Perforate 5/29/84 1G-1 2 Fracture 5/31/84 ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany RECEIVED JUL 0 ,1984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA~IL AND GAS CONSERVATION C0-'MMISSION SUNQRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL r'3[ OTHER [] . 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 83-155 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 031 367~ FSL, 428~ FWL, SEC. 29 UM 4. Location of Well SURFACE LOCATION: T12N, R10E., 9. Unit or Lease Name KUPARUK RIVER UN IT 10. Well Number 1G-16 1 1. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KUPARUK R I VER O I L 97' (RKB) I ADL 25640 ALK 2571 PQOI 12. Check Appropriate Box To Indicate Nature ~f Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ]~ Abandonment [] Repair Well [] Change Plans [] . Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On June 13, 1984, the "A" sands of Kuparuk well 1G-16 were hydraulically fractured and propped to improve production. The treatment consisted of 200 BBLS of gelled diesel as pad and carrying .fluid and 4,000 & 3,800 LBS of 20/40 & 16/20 sand, respectively, as proppant. Prior to pumping, equipment and sand was tagged with R.A. tracer performance. lines were tested to 5000 psi. The to aid determination of job RECEIVED JUL 0 3 984 Alaska Oil & Gas Cons. Commission Anchorage I 6/28/8q ! 14. I hereby certify th, at the foregoing i_s true and correct to the best of my knowledge. Signed . Title OPERAT IONS COORD i NATOR The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate June 29, 1984 1G-15 Perforate 5/27/84 1G-15 Fracture 6/9/84 1G-16 Perforate 6/11/84 1G-16 Fracture 6/13/84 2C-1 Fracture 5/19/84 2C-2 Fracture 5/20/84 2C-3 Fracture 5/21/84 2C-4 Fracture 5/22/84 2C-5 Fracture 5/23/84 2C-6 Fracture 5/25/84 CPF-2 Perforate 6/23/84 3C-6 Fracture 5/19/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) Well Name: Transmittal # KUPARUK ENGINEERING~_~ DISTRIBUTION NSK Operations Blueline Dr ill ing Bluel ine Geolbgy /Ken ~ Film S ta~ e- 0 f ~ /~?:'~ ~:.-'.~Blu el ~e"'& 'S ep ia ~ Sign & return the attached copy as receipt of~.~ata.//, Re turn to: ARCO A~S~, ~NC ATO-1115B P.0. Box 100360 Anchorage, AK 99510 ARCO Alaska, Ir Post Offic'e-'Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 14, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached are notices of intention to stimulate Kuparuk wells. 1C;-10 1C;-12 1G-14 1G-15 1G-16 3C-6 the following v questions, please /~Mik/a L. Laue rKuparuk Operations Coordinator ~Lk/kmc Attachment (In Triplicate) call me at 263-4253. RECEIVED MAY Alaska Oil & Ge--s Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichfieldCompany STATE OF ALASKA ALASL~OIL AND GAS CONSERVATION ~_JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. 0. ROX 100360, 4. Location of Well SURFACE LOCAT IO1'1' T12N, R10E, ANCHORAGE, AI_A._C, KA 9951 0 367' FSL, 428' FWL, SEC. llM 29 5. Elevation in feet (indicate KB, DF, etc.) 97' (RKB1) 6. Lease Designation and Serial No. ADL 25640, ALK 2571 OTHER 7. Permit No. 83-155 8. APl Number 50- 029-?_1d31 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-16 11. Field and Pool KUPARUK RIVER F! ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 f.or each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to hydraulically fracture the "A" sand to improve production. Lines and fracturing equipment will be pressure tested to 5000 psi. Treatment will use gelled diesel to carry 20/40 sand as proppant. Expected treatment volumes: Diesel 18 300 gallons Proppant 20i40 sand 21,000 lbs. Expected start date' 5/24/84 RECE!VFD MAY ! Alaska 0il & ~s Corns. Commission 14. I he~ng STil~:~a~e bellow f.~r Commission use is true and correct to the best of my knowledge. Title KUPARUK OPEI~ IONS CO014_D I NAI O~ Date 5/14/84 Conditions of Approval, if any: Approved by Approved Copy Re)urne, d By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1430 and "Subsequent Reports" in Duplicate STATEOFALASKA - ' '% ALAS~_.,~.;IL AND GAS CONSERVATION-~...~-~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL¥~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21031 4. Location of well at surface 'FT'/:-'~T::%:,-?;--(- 9. Unit or Lease Name 367' FSL, 428' FWL, Sec. 29, T12N, R10E, UN !L~).,,/\7.'?,~:",2~ Kuparuk River Unit At Top Producing Interval~_ I 10. Well Number 1679' FNL, 3993' FEL, Sec.30, T12N, R10E, UM ISurL ~ ~ 1G-16 AtTotal Depth ! ~'H' ~' ' ] 11. Fieldand Pool 1437' FNL, 4308' FEL, Sec. 30, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 97' RKBI ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/29/83 11/06/83 01/1 7/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9225'MD,6816'TVD 9134'MD,6743'TVD YES I~ NO []I 2092 feet MD 1500' (Approx.) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP/Cal, CBL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 114' 24" 212 sx CS II 10-3/4" 45. 5#/55. 5~ J-55/L-80 Surf 2639' 13-1/2" 1050 sx Permafrost E & ~50 sx Permafrost C 7" 26.0# J-55 Surf 9216' 8-1/2" 1200 sx Class G & 250 s~ Permafrost C 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) 8742' - 8723' 3-1/2" 8851' 8393' & 8822' 8722' - 8703' 8702' - 8683' 12 spf, 120~ phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8682' - 8670' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8606' - 8602' N/A 8588' - 8582' 8563' - 8557' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF ' WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 (:RUS/WC24 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · , . . .. . ' - '. '~' ' ' ' ' ~' :'1 . ~ - - - ' ;~. '' - :-' -- GEOLOGIC MARKERS.. ' - .... : -'..,. ,.'..';:: ."..' ! ,-':FbI~MA'~:ION?EslTS' .: ::~.! :;:.. t:?..;:;~. . NAME Include interval tested, pressure data, all fluids recovered and gravity,. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Upper Sand 8557' 6279' N/A Base Upper Sand 8728' 6415' Top Lower Sand 8934' 6581' ..... ~ _ Base Lower Sand 9074' 6694' . . 31. LIST OF ATTACHMENTS Drilling History, Completion Summary, GYroscopic Survey ~2 ¢opie~) 32. I hereby certify that the foregoing is true and correct to the best of my I~nowledge ......... · ' "~ ~',~1, - ~ 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". 1G-16 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1430 hfs, 10/29/83. Drld 13-1/2" hole to 2658'. Ran 63 its 10-3/4" 45.5# & 55.5# J-55 & L-80 BTC csg w/shoe @ 2639. Cmtd 10-3/4" csg w/1050 sx Permafrost "E" & 250 sx Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20"hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW. Cont drlg 8½" hole to 9200' . Ran logs DIL/SFL/FDC/CNL/GR/SP/CAL f/9175' to 2639'. Cont drlg 8½" hole to 9225TD as of 11/6/83. Ran 231 jts 7" 26# J-55 HF. ERW BTC csg w/shoe @ 9216. Cmtd w/1200 sx class "G" cmt. Arctic pack w/250 sx permafrost "C" cmt and 104 bbls arctic pack. Instld 7" packoff & tstd ~ 3000 psi - ok. Displ fluid from top of well. ND stack. NU tree. Secured well and released rig ~ 1630 hfs on 11/8/83. HI LL/DH59 12/18/83 1G-16 COMPLETION SUMMARY RU Dresser-Atlas. Ran CBL/GR/CCL f/8842' - 1800'. Ran gyro f/8800' - surface. RD Dresser-Atlas. Secured well. Accepted rig @ 0930 hrs, 01/13/84. ND lower tree assembly. NU BOPE & tstd - ok. Perforated the following intervals w/12 spf, 120° phasing' 8742' - 8723 8722' - 8703 8702' - 8683 8682' - 8670 8606' - 8602 8588' - 8557 TIH w/gauge ring/JB. RIH w/WD pkr & set @ 8822'. Ran 3-1/2" completion assy w/tail @ 8851" pkr @ 8393' & SSSV @ 2092'. Tstd tbg hanger & packoffs - ok. Set RRH pkr. Installed BPV. ND BOPE. NU tree & tstd to 3000 psi - ok. Retrieved "C" lock in SSSV @ 2092'. Pulled dummy valve @ 8330' Disp well w/diesel & Kuparuk crude oil. Reset dummy in GLM #8 @ 8330'. T~td tbg to 3000 psi - ok. Set BPV. Secured well & released rig @ 1400' hrs, 01/17/84. GRU5/CS16'tw ~f~ ~:~.'~,~:,'~~~-~.~-~-? ........................................................................................................... KLIPARUK ~:-.)c:':~ ~ ~" NOVENBE~ 17, 1983 dOB NLINBER ~K-BO-30124 ALASKA ~ KELLY BUSHING ELEV. = 97.00 FT. ~.~.~.~ ..... ~ .......... . ....... ~ ......... . .... .~. .......... ~...:~. ................. ~........,~.~.,~.:.~.~¥:...~..,~..,..~.~:, .~..~..~ ........................................... , ................. ~ .......... ~ .......... . ..................... ~ ................. ~ .......................................................................................................................... . ............. : ........ HE~SURED VERTICAL VERTICAL INCLIN~YION: DIRECYION SEVERITY RECTANGULAR COORDIN~YES VERTICAL DEPYH DEPYH DEPYH DEG HI N DEGREES DEG/100~ NORTH/SOUTH E~SY/~ESY SECT I . . ~2~h~!~i ~:?:~[i?:~?:~i[~E~:=::~?:~[~:~::i~:=~i[~ ~[[i~? ........... ~'"'.~*'~?.' ~='='=~ ...... ~,m~'='~:':'~::=~=~ .............. ~=*¥~===~¥*~'~ ................. ~=='~"==~==~:~:=:=~ ...................... ' ......................... ~ ..................... ~ .......... ~="=~"=~ .......................... ~='*':=~**='*=~'~ ................................................................................................................................. ":'. .................... .................................................. -" ": ~:~.~`~`~¥.:~.'.~`~:`~`~:~:~:~¥~:¥~~:~:`~=~:~.~*~?¥~:~::~'~::¥~ ~:~:..:..,::,:,~ :,: ~,,~::,:,~,~:~:~:~::~:~:::~=.::~:~:~ ................. ~ .......... ~:::~.~:~=~:::::~.:~:~:~:.::~:~:~.~::¥:~ ...................... ~::::,~::~.=~ .................. ~: :~:~:~:::¥:=~:~:~:~:?~:::::::::::::::::::::::::::::::::::::::::: ............................ ,:: .......................................... :::~:?~::~::~*i~iiii~?:~i?:~:~::::~.~.i:::~.~::::~x~::f~p*:~::::~:~i~ii~:i~::ii~ ::,,...:::i~=~::?.:,?,:::::, "~:~x~:[~?'"':::!i~i:~:~:?'":ii~!::i~iii:':'"~::~::"""K~:i:::t~:~ ~:~ i~ ::""::~:~:~" ':!i'"~+i~i~:i~:~:~:~:i::~:::.x~::::~ :'" ~?" :::::::::::::::::::::::::::::::::::::::::::::::::: :i · [~[~?? ,.:~;!~!!:ii~ii~[i::~i~h~:!~:'.:i::i:~::~:~T~: :300 299.98 202.98 0 26 S 54.89 W 0.78 2.65 S 1.16 E -'2.50 400 399,93 302.93 2 ~5 ~ N,'68.19.W 2.38 ,. . 2,04 8 1,25 W -0.19 450 449'8~ _ 352,83 .', '4 2~._ . N_z~6'.60 W '.. 3.65. _..._. 0~. ~ ..... ,.~ .. ~.,~.~..,9Z2~...~,~...,~, ......... ~m~.~.,.=~? ......... ~:. ............ ~.~..'--'~-..=,~.~.,;;~.~..~; .~-: .... ~,~, d-'==. ~' .%.~-~i ."~-..:~x~' ~. - ; ,:-~..,..~%~ .... , ..... .'.' ~..~..~ ' .... ~'.~.' ..... ~tt,==.~'~.'~'-?.;.~"'"r~· .~=~"'~ .. . . ~ ....... ...~... -- ' . ~ ~, ~50 "647.'66 550.66 ' : 12 ~ 17 N 60.10 W 3,81' . ' 1~.45 N ~o.77 W 30.56 ~,.,, 700 69~.36 5'~9.~, ~:6 ',13 ',48~ : ' N 58; 60,, W,. 3.09 , , 18..~ 21,~,~ N ' ' 38.47~. = W . 41,..~79 ,~ 8o0 79~.~7 6~5. c,Z 18 '34 N 57'.89 W ' 4.77 , ~.8~ N ~.'1~ W ~~ ~:~ ~ x ...... .'.," ~ ~ ' ,~;;.~+ ' ~~ ~ T~..;:~:;~:~:.~fcm:~z~~'~'~'~ ............ -- .:'~: ~ ........... --- ~ ~- ~ ' ~" .'.~+' '.'"',.~..' '..'. '+ ' ,' '..~ ..... ~.~,..~x+...,::-:?~:~::'" :,::.';~;.~:;'"',:. '.'..u,: ..... :? '~'"' '~'~'""~ '~ "~' ~. i ~ .~ · ....... ~ ... ~ ........ ~ ............... ,...~..,..~.~....~ ............. ~ ~,.~ ..... .~ ' ~ ~.:::'. ~;~ ......... ¥~:::::::~'.::'"'.::~."'.'" ,x?.:~:i: :, '.:' ::::::::::::::::::::::::::::::::::: :':v.x:y,::':::x:x::~x:~:?.' ~." '.:,'.' '.??'.?.~:~! "~ ~ 10oo 9,77.11 ~0,11 ~ ~ 15:~ N 5~.69 N , 1.66 76. yo N 1~4,~._, W 14._..7,.~ ~ 1100 1066;41 9~9.41 ~ 28 ';"13 N 54~19 W' 2.~9 103.42 N, 160.73 W 190.77 , .. ~ .~., ,~,,, ~ ~ __ ,- , ,.,. .~,.~,~.~,,. 1110.02 olc~.0~ ~0 18 .. N~,~.8~ W 4,~Q 1~ ~. 1~o.64 W _~ ~ ~,~., 1 1 50 ..~'..~.;~ ............................................... i~..~.~. ~,.~ .... :::~ ...... ~[!~'~:"".i:!' ~/ '" ~%.> ~ :~ =~>' <:~:~ "~:~' · ...... i~" :~ Y~:i: ':' ::~::~:~ll~'.~::t: .l~ ....... ~i~¥'~ ~..~:t:: .:'.::~. ~;:' ' ~' :::;:..:' ........... ~.:::~:~i i~'~' :'~.?.:i:!~ ':ii:i: ' ....... ~ ........ ~ ............... ~ ........ '~.~ ~':".:;~' ': ........ 1350 1275. y9 ,, 1178.99 37 24 : N,,,56" 19 .W : 4. ~,0 17... o.I N ,, ~.7.,. 1~ W .,.6.4., 1400 :, 1314,'97" 1'~'~17.97 40~ ,7 N 55,69,, W 5.46 , ~197 ...... 04 N 2'~9 1~ W ~,._,7 73 1450 1352.84 84 ' 558.61 624.99~ 0 0 0 · ' SPERR¥-~;UN WELL KLIPARUK NOVEMBER 17 ALASKA KELLY BUSHING ELEV. : 97.00 FT. MEASURED VERTICAL VERTICAL INCLINATION DI'RECTION SEVERITY. RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG, MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECTION 2300 1989.87 1892.87 40 43 N 54.30 W ' 0.14 540.08 N 785.64 W 952.92 ·" ' ~,7o 11 N 838 46 W 1018 O0 · ~' '{ 1968.79 , 40 28 N 54.19, W 0.27 ~40 ) 20~5,.79 ... .... 2~00 2141'~5 2044.e5 ' ' 40 '1~.: N 54.10 W 0.15 616.06 N . 89o. .... ....... ................. . .................................. ........ ............. ......... ...... ...... .... ........ ~.., :~..:~.~..-:...,>..x .......... ,,, .'* .... , ' ' ~.'.' .~ .. ' > ~.. ~.:- .~ ..:.. ~q~...~. . ~ ' ~'.g.' .: ~:~:.'. ...... . .. ~ ........... ~: *:.~..'.~.* ........................... *~>..~...~.:....:~ .... ' ...... ~ .................. ~ .... ~ ................. ~.~;~z~:8~:.~i~~~~,~:~:~~¢}~j~ ~¢~;~ ..................... *~:."":~e~:.'::,?':..~. ...... ....... ~:~}~ ~:,.~:,:,~ .,ir".~".'.'? ....... v ':~i,::. "?"~m~:'~:.:~' ? :,-~.'~,:"~ '~~. ~ ..~' ~..~,~:~..~: ~j~ ..... .~'~ *' ::'~~..m~;~?. :~¢~~.~~.~:.:.~:.:.:.:.:~'".~¢ '. ':"~r ~:~:~,?'".~"~:..~..~. ·. ~' '~ ~, ': .............................. ~j¢~,~:~g~..~.~.~,l..~.,.,..,.~...,.~[~..:: ..~. ~:~.. ? :~ :,.~ ~:~;~i~:~¢~i~.g..~.~.~.,.,,~.~':~:.. ~ ....... :~: :' · ~., ' o.* . , : ~ 76~. 54 N 1102.61 W 134:~ 62 ~00 2445.20 ~.:,48 20 41 41 N 54.10 W 0.' '~' -. 7.:000 ~519.76 2422'.76 .' .' 4~ 52. "'.N 54.10 W '..' 0.18 ' ' '~= '-'"'-' ' '-'::' _9 , ,': _o~. ' : ' , 3100 ~.;:.,9C-~. ~7 ~.4.6.87 4-'- ...E~ N 54. c W ~~.. ?:, ..... ~,~,~ -'.~'.:,~.~..- ;: :.,~.; ~;.'~:~ ~:~ :.:~,:..x~,. . .: ~,' · ~' ':~ :. ~ .... "., . :3S00 2884,, 89 2787, 89 45 10 N 51,60 W 1, 45 807.62 N 1156. o~ W 1410 26 847.04~N 1210. ~ W ~. .~ 1~7.40 !. - ~:~.¢.~ ~..~..?.,,?. i ~. - .~ ~:~ :~?;~s~:~.:..:~..~:~:~ ........ :...~.:.~: .... '~ '. '~:~ ~ '~" ~::~::" :::' ':::~: .:: .~<n~:::,5 ::~::::~' ::~:.' :~.. ::. ,;s '~:'~ ~ ' ~0 . . ~ W 1 ~-~-." . L~600 2955.28 '2858.28 45 ~ 20 ~:..N '50 69 W ,0',66 . 1057 '~" N' 1484 :~o .--.o._-.. ' i~700 :7,40~. 05 2928 .05. ' 46...'10 N 49 6~. W 1.1[~ . 11o._-~, 1._. N 1J._-~..~. ~~~. ~ .~'¥' .~ ~r~TM:~:':*~ "'. '.~?~:" :~, ~:~ '7" .~ '~:~::~:~:~:":'~~{~i~ ~' *~ '~ ~' ~' '~''~* ~' *' ......*~ "?:' ~:~:~'~:~'*":" .... :~:~:' ~'~i~)~i~)~}~~;q ~" ~:u:?:~?:~!~""~:??'':'::, ~~:~:' ~":~ ":'* ~[~::' '~":::-~4~:*'~"'""~:~:~~ ............ 4100 3296, , .38 31'99,...38 ', 47', 26' N 49.10 W , 0.25 4200 3364,15 ~3267.15 47 13 :'N 51,80 W o O0 0 ' W 1294.9(} N 1762.62 W 2187.14 1341.71 N 1819.31 W 226¢]. o4 4,..-00. ' ,..-431. ~4 .L~,:.,,-4, ~,4. , ....48. ,. 0 N ._.5. . ~. 6 ~' 1._-._-,5. :. 0._ N 187._-,. o4 W ~,~ =.4. ~.[s'~ ~t~: ~,~[~' .~¢: ::' :~. :.: ............ : :':' ":'>~'~ ¢": .: : ~ ..... ~: :: ~ ~ ~'.? :.~. ~..~.:...~ ........ <...p.. .... :........~ '.kLq:::.-~g ..... . ...:. :~:.>> · .. .,. .. v ...~.... 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'~[~:~:~:::: ':~ t~f~':~ ~::' .~}}~:g~:~; '.: ~;::~: :.:¢}:~:~:~¢~:~>~,~:~,:' ":::::::: :': ::':~r~*~:::~:~:.:..x.:~*~:.~..:.>~ · ~ .m~':*~.~ ::::..S: ::: :::. :::,....:.:::::.:. : :.:.:..: ' .:.:::::::::.:.:.':~.:...>:': ...... :.' ~."..:. :. ":':':':': ?:':':':"':':':':"':':':::':':".::':':::::':::~.'~:: :::::::::::::::::::::::::::::::::::::::::::::::::::::::: . 4700 ' 3686.97 3589.97..~.:.:. '.51 :' , :¢0"60 :"': 15f. 1.93 N : 21:30.94 W 2642.07 ' 4800 3748,00'.'::: 3651.00":;.: N 2195.87 W 2721.27 900 3807.7Cq ........~710.7o 44 N 55.10 W .-.'. O- ~4 16,_,~. ~t., N --~; ,, ...... , ........... ~:,_,,~..~.,.[L...~ ................... ~.- :~.,~.,. ...... ;-::~-~--.--,-x?-~-,~s~ ~ ........ < '.>~'s' ~ * ~'*' ~ ~:' - .~<~;~ ~ ..... ~ ~ ~ =-; '~*~ . q~, ' ' ' ' ~ ' ~. ~ ~ ~ '.:~8~:~ :'. .x.. ~ ~>~:.~.~' .~:~:.::~:::~:~;~::~k::.-x.m.:::::::::.: :::::::::::::::::::::::::::::::::::::::::::::: .~..~ ...................... , ................... ~...~.,.~,.,~.,..~...~. ~.,.~.~ ........ ~>.,~,~.~ ........ ~.~ ........... ~.....~~,.~,~...,~ .,. ~ .., ................ ~ ~ ~ .......... · .................... ~t.,,~,~ ......... ............................................. , ................. ........ ............ . ...... ............. .... .... ....... . ..... ......... ..... ................................................ . ................ ======================================================================= ~¢~ .~;~{~,~. ~,~.~:, c~:..~. ~.., ::~ . .:,~ ~ ~;~.. .~ ..... , ~ .~. ,~: ~.~ ~¥:x>~. ,...~:~..~..~ ..~::~>g:~,~. ,:.. :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::============================================================== x..~:.. 8x.~..,.:~.:...:,. ...... ~.,.:...'..:~& .:: .:,..~:.~:~.:.;~.:.;.:~..:.,~'.:.~:.>~,.. ~qq.~'-"~'~...;.~. '.,:;.:~:.>..~.q~.~...:q~. ~.~.'.~y.'.'~'"'.~..'~ ~ .:~fi~ T~,'~'.. ' :.'.~v.~*~'~4 ~'"x:~:~ ~ x ~>~.'~ .~'~.~".~exe~'"'~'~i ' ~'. ',~<:'~<~q~';'::'~8:":':'" : ' '~ ~ ~ ~<. >~ ~ ~.:::~:.:~. ~.:..:~ :.:.~:..:.x.:.:.:.:.:.A.:..:. +x.;..:.>>.....:.;.:.:.;.:<.:;..:.:.x.:,.:. ,; ........ :...x...-:....:: .;.:.:..:.. ::,.:.;.: .:-.. '.:.:...:.. ~:,::..::,::~:~::,. ............ ~ ........ ,~....,~.~,~,~ · ,,.~.,~.** ..... ¥~..:~,~,~..~, ...... ~. , .... ~.. ~ . ~. ~.~ ,~ .~ ......... ~ ~ ..... :.~. :. ~::~,~,~.~g~....~..~ .~,...::~ ............ , ......................... ~ ............... ~ .................. , ............................. ~ ....................................................................................... : ................................ ~Y-.~l IN W~I L '3URUEY I NG ~.AHPANV ~. ~ ~.~- ~ ~.~ ~" ~ ~ ,~AA~_~.'_~ NOVEMBER 17, 1983 dOB NUMBER AK-BO-30124 KELLY BUSHING ELEV. = 97.00 FT. ALASKA n ~ ~ , ~ - APERAT_R-MC~?L IR~ ~ MEASURED VERTICAL VERTICAL INCLINATION , DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/100 NORTH/SOUTH EAST/WEST SECTION (' .~..~ ........................................ ~ ....... ,~.~,~,..~E~ ........ ~....~.~...;~ ...... ~ ................ ~..~.~ ............................ ~.~ ......................................................... ~,_..~.....~.~...~.~ ..................................... ~ ............. ~.~.~ ................ ?..~...~,~......~ ............................................ ...~ ....... ~ .............. , ............................. .......................................... ~.~ ................. ~ ~ ...... ~..~....~,,~ ............ ~.L~...~.~ .......................... ~ ......... ~ ........ . .~,~...~.~ ....... . ................ ,.~ ........... ~.~.~ .............. ~ ....... ~ .... ~ ~ ............................................ ~ ..... . .................... ~ ....................... ~.~..~ ............... . ........... . ¢, ~ ~._, 27 , ~.36 N 2527.44 N '-' '-'~ 5300 4042.38 ~ 3945.38 53 34 "N 55,60 W 0 41 1"' "' · . , ._-~ ~, 71 5400 4101..73 4004.73 53 36 N 55;39 W O. 17 1883.95 N 2593.76 W · ....~ ...................... ~ ----~ : . ~' --'~-' . ~' , " . . 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DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/100, NORTH/SOUTH EAST/WEST SECTION , , 8300.. 60~7,62 5~80,62' '. . '. 2~' 2~ ' N 51,80 W 0,58 3135, 08 N 42~5, 8400 6155, 32 6058.32 ' 38-'. ~ 32,',"'~',~' N".~1.80 W , , 0.~5 3174.01 N 4345.42 W 5381.16 ~Suo 62J~2~.87 ,61~.87, ~' ' 37'. 557 .:,'~ N"" ~ o · ~ ~.- . 51.60 H ,', 0.63 3~1~.~6 N ..... 4._~:~3 ~' "=:~:~'=:':~:~'"m""" ......... "'~"'~=~" ~" '.~ ~'. ':.~ ~ .... : ~*~' '~F..'~' ~:':" : .~ .:'"~; ~' ~i~ ...... ~':"~'~'"~F'(&'''~'%,... ,.:~ ,:.:...~:~.~.,~,.~....:.~::.. , ,,. , .:..,~.,,..~, .~::.:..~,,.::: ...... ...~. ~......, ~ ,'.~: >~ ~ > 8800 6472'86 ] :~" 6375,86 ',N 52,69 W,.:"]': 1.05 , ,3224.01 N , 8900' 0,,00,,. a359'69 'N ' 4583.69 W 5683.10 9000 N ' .-,c. - - ~ ': .~.. . ~ .:':~ , HORIZONT~L'D~SPL~CEMENT':.."',.':~874,42.~: ~EET ~T NORTH ~2' DEG..42 MIN. 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'.~ $ '.~,~ :~.':., :.'.:.~.~ TRUE SUB"SEA T:OTAL MEASURED 'VERTICAL VERT~:CAL REcTaNGULAR COORDINATES HD-TVD DEPTH DEPTH' DEPTH NORTH/$OUT~ ~,.~.~*,~,LII~: '":':, :"::~-~?:~'~" ~ ::' ' ' i'''''~ '~ . - · -., '3 ' ~, ~ ~ ' 3000 2519.76 2422.76,. 807.62 N .1156.59 W ,' 480,.24 40A~] ~ 3228.91 3131.91' 1246'52 N""i~'~1706~88'W, ~' ~71.09 ~ ~,':..:.:~::~. ~....::~.,,,,.,,,..:.:...:..,,?.?,:.~..~,.~:~.?...'?~,.:,::.:..'. :. ~ : ':.: ., :.......,.:~,:.~..~,:-.::~:. ... ...::.,,:.. . .:~ ..:...~:.., ...::.~?~..,?: .~..~..:.:.....,.::.:.~....×,,'.::.:...:.::,,::.:~ ...::........,~...:~: ,.: ,.,.:::...::::...:::..,,::.: ~:~:~:~.?~'~!;~,~:.~.~:.'~'~:!~ ~':~i~'~'~:~::~:!~:i:i~:i:!~:i~!i!:ii:~;i:!"' '" ~ i ~":! ::':' '~'~' .... ~,~~;~k~, '~.~ ' "'! ~'~'"~:~ .... ' ~" , ~- ~_.'~, .... . · , , . 8000 5849 56 ~,7~.5~ 3014.53 N : .4142.84 W .2150.44 · ',. 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' .... :.. :.::.:x::.:: ======================================== ............. ~~ ~.~ ~]~.,,~.~ ...... ~,~(~:~::~:~::,:~;~.,~::~:~:~:~,~:~:~:~:~:::~: :~:: :~ :~ :~: ~:,~ ~: ~: ~:~¥ :::~,::~::::~:: ::~ ................... ~ ....................................... ~ ......... . .' , , DERIVED USING DIL DEPTHS AND SPERRY SUN SURVEY DATA TOP OF uPPER SAND 8557 ;6278.89 6181 . 89 3234.11N 4421 . 35.1~" BASE ~F U~PER SA'ND ' 8728 . 64 ~ ~. 89 6317.89 ~:~.. :~-, {.~5N' 4.-,{-~Z=' -, '~ :~:~:~''' ::::::::::::::::::::::::::: ' '::':" ' :~: ~::(" '~'~:~'~:~:~::" ":'" ":" ':~:E::~'> .~t. ':c'~', ,((:;:~:~' ::' ':"' '?'¢:::::?(: ::::::::::::::::::::::::::::::::::::::::::::: ====================================================================================== ................................ .:~: .::~:~: ...~::~¥~:~:~ ..... . ..... ~~...~% ,..::~ ........ ~:..... ........... ~:~::~ .... · .................. . ..... ~:~¥:.~ ........... ~;~ ......... ~ ...................... ~ ::::::::::::::::::::::::::::::::::::?::':': :':EE~i:::)?:::':'::::x+:~:E:~s".~.. ... E~%~E~E:F~:~:~:::E~?~E~(~E(~:~K<~(~:~1:~Kc~s~ ~:~E~E~;~E~F:~H:~:~:E~E~¢~]~p~:~E~8>~E~i~E~E~:~:E~:::~:~::~:~:~:~:~:~E:~(~E~:~::~.:~E:~E~ PBTD 9134 , '6742.82 6645.82 '~ '~' ~ 44._.. 17N 46~3.29W TOTAL DEPTH' DRILLER ~25 .'6816",37. ~' 671'~.37 3475.64N 4735.90W ~, , .~ ,% , ,,, . .,.. OF' SI ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-.E~)-30124 Well: ~lG-16 (SEC 29 TllN R10E) ~uparuk Field North Slope, Alaska Survey Date: November 13, 1983 _Operator: McGuire Scale: 1" = 1000' TRUE NORTH 9225 .. 367 FSL 428 ~,.~ ~ HOBIZONTRL -3OO0. O0 -2000. O0 -I 000. O0 0.00 -1000. O0 PBOJECTIO-N 0.00 1500.00 ARCO _Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30124 Well: ~lG-16 (SEC 29 Ti-tN R10E) !<uparuk Field North Slope, Alaska Survey Date: November 13, I983 Operator: McGuire Scale: 1" = 1500' 3000.00 4500.00 6000.00 5874.43 @ N 53° 43'W 9225 7500.00 ~bo. oo ~obo. oo 45b0~ oo ~0~0. oo VEBTICRL PROJECTION Sugge: form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. ' ' 'Operator; We~ Name a~d Reports and Materials to be received by: ~ ~e -~'- ~ Required Date Received Remarks - Completion . Report , Yes · _Well.Hist°ry. .. . . . yes " O/f , Mud. Log /~W--P ,,, _ Core Chips ........ . co~ .~_s~Uo~ ' __ ~gistered Survey ~:::~i>N " ' Inclination, Surve7 ~~ .... Directi°nal Survey ~q ~/ Drill. Stem. Test, Reports, _/~" ,~~'e. - --"--' ' · Logs Run. Yes l--~,O-" ~y" ._ Digitized, Data X ~ , , , ,, ~ _ KUPARUK ENGINEERING Well Name: Transmittal DISTRIBUTION NSK Operat ions Dr il 1 ing Geolbzy te of AK Blueline Blueline Film Blueline & Sepia~ return the a{tach~ //~y .as r~eipt o f ~da t Return to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 STATE OF ALASKA ALASKA--~IL AND GAS CONSERVATION C~_~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~X OTHER [] 2. Name of Operator. 7. Permit No. ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21031 4. Location of Well Surface: 367' FSL, 428' FWL, Sec.29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 97 ' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1(:;-16 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~, Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). RU Dresser-Atlas. Ran CBL/GR/CCL f/8842' - 1800'. Ran gyro f/8800' - surface. RD Dresser-Atlas. Secured well. Accepted rig ~ 0930 hrs, 01/13/84. ND lower tree assembly. NU BOPE & tstd - ok. Perf'd the following intervals w/12 spf, 120° phasing: 8742' - 8723' 8722' - 8703' 8702' - 8683' 8682' - 8670' 8606' - 8602' 8588' - 8582' 8563' - 8557' TIH w/gauge ring/JB. RIH w/WD pkr & set ~ 8822' SSSV @ 2092'. Tstd tbg hanger & packoffs - ok. RECE ¥ED A:'.:}~,~,C'''' u'''', · Ran 3-1/2" completion assy w/tail ~ 8851', pkr @ 8393~ & Set RRH pkr. Installed BPV. ND BOPE. NU tree & tstd to 3000 psi - ok. Retrieved "C" lock in SSSV @ 2092'. Pulled dummy ~ 8330'. Disp w/diesel & Kuparuk crude oil Reset dummy in GLM #8 @ 8330'. Tstd tbg to 3000 psi - ok. Set BPV. Secured Well & released rig @ 1400 hfs, 01/17/84. 14. I hereby ce~Ff~y that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer Signed Title The spacep, o~ZZor C~7fmission use Conditions of Approval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRUS/SN77 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In{' Post Office~'ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 1G-16 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG:tw GRU6/L01 Enclosure FEB i 5 i984 C0mml$ol0~ AI~R~ 0i! & Gas Cons. Anch0rago ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc.: Post Office 15'Trx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 30, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1G-16 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU5/L147'tw Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany KUPARUK ENGINEERING TRANSMITTAL # 2~ ~ ~ ~ 'TO' .~-- FROM: D. Fay Allison / WELL NAME' Transmitted herewith are the following- '- S SEPIA F FILM T TAPE PC PHOTOCOPY PLEASE NOTE' BLUELINE, - , - , - , - ~/~'LEASE RETURN RECEIPT TO' ARCO ALASKA, INC. '<-~I--~/'~'~A~;~O ATTH- D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 Alaska Oil & Gas Cons. ~mmi~ion ANCHORAGE, AK. 99510 Anchorage ARCO Alaska, Inc. Post Office B'b'-~360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached are sundry notices for wells' 1G-9 fracture 1G-9 perforate 1G-10 perforate 1G-11 perforate 1G-12 perforate 1G-13 perforate 1G-14 perforate 1G-15 perforate 1G-16 perforate action on the fo1 lowing If you have any questions, please call me at 263-4527. Charles K. House ~' Kuparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) AR;.:() ,~,h']_<k~ ~r,c. is a sub.,~dlary of AllanticRichlieldCompany STATE OF ALASKA ALASKA'~IL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER EX 2. Name of Operator ARCO ALASKA~ INC, 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 367' FSL, 428' FWL, SEC. 29 T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 97 ' (RKB) 12. 7. Permit No. 83-155 8. APl Number 50-- 029-21031 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 16-16 11. Field and Pool KUPARUK 6. Lease Designation and Serial No. KU PARUK ADL 25640, ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate the following depths in the Kuparuk "A" sand: 8954' - 8964' and 8975' - 9007'. All perforating will be conducted with 4 SPF through-tubing guns. A 3000 psi lubricator will be used on al 1 wirel ine work. Lubricator will be pressure tested prior to doing the work. All circulated and flowed fluids will be diverted to tankage on location. Expected start date' Subsequent Work Beported o. ,JAN 0 5 1984 14. I hereby certify6th~t the for~egoing is t[ue and correct to the best of my knowledge. Signed ~'.-i~'f~../ _ , (~,~ _ Title KUPARUK The space below for Commission use 0 P E RAT I ON S C O0 RD ! NATO R Date /~-/~'~"~ f~/ Conditions of Approval, if any: BT tS~l[ t;;. S~,tlll~ By Order of Approved by COMMISSIONER the Commission ·: i?eturnec~' Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In( Post office~-E-~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 1F-16 ~lG-16-' 2F-13 2V-1 2F-14 2V-2 Thank you. Sincerely, win lng Engineer JBK/SHi:ih Alaska 0it & Gas Cons. Cornmissiort ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ~ . STATE ~::~,~ ALASKA HL' ALASKAr~AND GAS CONSERVATION C .c. vl ss ONoPERATIO MONT Y REPORT OF DRILLING AND WORKOVER · Drilling well [~]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-029-21031 9. Unit or Lease Name 367' FSL, 428' FWL, Sec. 29, T12N, R10E,UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 61' 97' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 10. Well No. 1G-16 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool November 83 For the Month of , 19I 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks _ Spudded well ~ 1430 hfs, 10/2.__9/83. Drld 13-1/2" hole to 2658'. Ran cmtd & tstd 10-3/4" csg. Contd drlg 8½" hole 9200: Ran logs. Cent drlg 8½" hole to 9225TD. Ran, cmt, and tstd 7" csg. Performed Arctic Pack. Displ . fluid from top of well. Secured well and released rig ~ 1630 hrs. on 11/8/83. · . 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45.5# & 55.5#, J-55, L-80 BTC csg w/shoe (~ 2639'. and 250 sx Permafrost "C". Cmtd w/1050 sx Permafrost 7" 26# J-55 HFERW BTC csg w/shoe ~ 9216, cmtd w/1200 sx class "G" cmt. I! E II 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/FDC/CNL/GR/SP/CAL f/9175' to 2639'. 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo~/n t~is~//~)'is require~ for each calendar month, r~r~l-ess-o; ;h'e's;a~'u~ o~ ~;e;~;i~s: and must be filed in/duplicate with the Alaska Oil and Gas C¢6nservatioCCCommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 1G-16 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well ~ 1430 hfs, 10/29/83. Drld 13-1/2" hole to 2658'. Ran 63 its 10-3/4" 45.5# & 55.5# J-55 & L-80 BTC csg w/shoe ~ 2639. Cmtd 10-3/4" csg w/lO50 sx Permafrost "E" & 250 sx Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20"hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd cs§ to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form to 12.5 ppg EMW. Cont drlg 8½" hole to 9200'. Ran logs DIL/SFL/FDC/CNL/GR/SP/CAL f/9175' to 2639'. Cont drlg 8½" hole to 9225TD as of 11/6/83. Ran 231 jts 7" 26# J-55 HF. ERW BTC csg w/shoe ~ 9216. Cmtd w/1200 sx class "G" cmt. Arctic pack w/250 sx permafrost "C" cmt and 104 bbls arctic pack. Instld 7" packoff & tstd @ 3000 psi - ok. Displ fluid from top of well. ND stack. NU tree. Secured well and released rig ~ 1630 hfs on 11/8/83. HILL/DH59 12/18/83 TO: DATE: 1-PvNN.%4 I'FTAL ~ Transmitted herewi tlm are the roi Ic~wir. g- FT~,;I: D.W. Bose/Shelby J. ~aatthews' · . PLEASE E: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PFEIFOCOPY' ~Je l l ,--"IF- !.~..,/' ---I ~7oI l~j 6B1 RECE ! PT AC.t~O,"A_[3:~FJ): LEASE P,E-RJt%N RECEI PT TO: ' ~ ' ' r~ ' STATE OF ALASKA ~/~' ALASKA q,..,.--AND GAS cONSERVATION CC~,411sSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21031 367' FSL, 428' FWL, Sec. 29, T12N, RIOE,UM 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) PAD 61 ' 97' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1G-16 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. 0ctobe r ,198:~ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1430 hfs, 10/29/83. Drld 13-1/2" hole to 2658'. csg. R IH to tst 10-3/4" tsg as of 10/31/83. Ran cmtd & tstd 10-3/4" 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45.5# & 55.5#, J-55, L-80 BTC csg w/shoe ~ 2639'. and 250 sx Permafrost "C". Cmtd w/lO50 sx Perma.frost "E 14. Coring resume and brief description N/A 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~N~,/~'~,~' 'TITLE Arum I~r~l l~nm I~nm~n~rDATE ///~//~,~ NOTE Reeler' fl~s~f~rt~n ~ ~or~"is r'~eeq-uired fo~-each calendar month rega;b'le~s-of-t~e's'ta't~s"o~f o~;;t;(~r~ -and must be filed in ' duplicate with the Alaska Oil an~~Ga~'s Conser~on Commission by the 15th of the succeedil~g month, unless otherwise directed.' Form 10-404 Submit in duplicate 1G-16 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well ~ 1430 hfs, 10/29/83. Drld 13-1/2" hole to 2658'. Ran 63 jts 10-3/4" 45.5# & 55.5# J-55 & L-80 BTC csg w/shoe @ 2639. Cmtd 10-3/4" csg w/1050 sx Permafrost "E" & 250 sx Permafrost "C". Bumped plug w/1500 psi - floats held - ok. ND 20"hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. RIH to test 10-3/4" csg as of 10/31/83. HILL/DH58 11/16/83 ARCO Alaska, Inc Post Office"~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 18, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 1F-13 1G-12 1F-14 1G-13 1F-15 1G-14 1F-16 1G-15 ~G-16 Thank you. Sincerely, wl~~ Engineer A~~~t Drilling JBK/SHi:ih ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany MEMORANDUM StatS'of Alaska ALASKA 0I~L AND GAS CONSERVATION CO~-~%ISSION TO: C. rton DATE: November 4, /~.~ / FILE NO: 108A:G3 THRU: Lonnie C. Core, is s io~er L~ TELEPHONE NO: [~ou: Edgar W. S~pple, Poeroloum inspector' 1983 Witness BOPE Test on ARCO' s Kuparuk 1G-16, Sec. 29, T12N,R10E,U.M., Permit No. 83-155, Doyan 9. Monda , October 31~ 1983: I traveled this date from Rowan 34 (subject of another report) to ARCO's Kuparuk 1G-16, Doyan 9. The drilling contractor was in the process of finishing the hole. The BOPE test commenced at 7:45 pm and was concluded at 9:00 pm. There were no failures. I filled out the A.O.G.C.C. BOPE inspection report ~gnich is attached to this report. In surmnary, T witnessed the BOPE test on ARCO's KuoarUk IG-16 Doyan 9. At tachment 02*O01A(Rev, ]0/79) O&G # 4 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COblMISSION B.O.P.E. Inspection Report Inspector Operator /~/~, Well / ~ -/ Location: Sec Drilling Contractor Rig # f Representative Permit # 8.~ ~.~ /~/C Casing Set @ .~g~ ft. .. Representative ~' ~ ~A4~ ~ ~J_' Location, General Well sign General Housekeeping Reserve pit Rig BOPE Stack Annular P e~nter. Pipe~ms . Test Pres .sure ACCUHULATOR S'YSTEM Full Charge Pressure ~.~./~ ps.ig ' PressUre After Closure /~ psig 200 psig Above Precharge Attained: O min_~_~2_sec Full Charge Pressure Attained: ~ mil ~Osec Controls: Master ~ Remote ~ Blinds switch cover>~ Kelly and Floor Safety Valves - Upper Kelly ~;/~ e~st Pressure Blind .game Choke Line Valves H.C.R. Valve Kill Line Valves Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves /~ · NO. 'flanges ~__~. Adjustable Chokes ~lydrauically operated choke g9/1'~ Pres sure ~)/~ Test Pressure 0 /~ Test Pressure Test Pressure Test Results: Failures ~ 0 ~ Test Time / hrs./-g',~4,~_.~.j) ,,~. __ 'Repair or Replacement of failed equipment to be made within days Inspector/Commission office notified. Remarks: · . Distribution -... orig - AO&GCC '".... cc - Operator ~ ,,.c c - Supervisor Inspector ARCO Alaska, Inc. Post Office "~rX 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 28, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-16 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on December 10, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU5L12:tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA-~.!L AND GAS CONSERVATION C~._;MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER[~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-155 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21031 4. Location of Well Surface: 367' FSL, 428' FWL, Sec.29, T12N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) 97 ' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1G-16 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other '~[ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, RePort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: December 10, 1983 TA,~ ?,-o/~o~ ~.l Subsequent Wor]~ Repo~eo~ ~ ~ .. · ,-' ~.d '~ '" '~'~ AlasKa. 0il & Gas Cons:. Commissio~ &nchorage 14. I hereby certif,~hat the foregoing is true and correct tO the best of my knowledge. Signed Title The space b ssion use Condition¢ Appro~ i~ Date Approved by Approved Copy Returned //-2. ~¢3 By Order of COMMISSIONER the Commission Date Form 10-403 GRUS/SN12 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate October 26, 1983 Mr. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit 1G-16 ARCO Alaska, Inc. Permit No. 83-155 Sur. Loc. 367'FSL, 428'Ft~, Sec. 2.0, T12~, R!OE, UM. Btmhole Loc. 1068'FNL, 593'F~L, Sec. 30, T12N, RIOE, L~I. D e ar Mr. Kewin .. Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional murvey 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 dtpmeter surveys. ~ny rivers in Alaska and their drainage systems hav~ 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 commencin~ 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 18, 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. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Kew~m Kuparuk River Unit 1G-16 -2- October 26, t983 prevention equipment $o that a representative of the commission. may be present to witness testing of the equipment before the surface casing shoe is drilled. W~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. ~/!truly yo~urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Comm_.i~sion be.. 6..H/A Enclosure cc: Department of Fish & Game, Habitat Section w/o enct. Department of Environmental Conservation w/o encI. ARCO Alaska, Inc. Post Office B'o~'x~i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 24, 1983 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1G-16 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1G-16, along with a $100 application fee. o Diagrams showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. ° An analysis of the 1G-16/1G-1, 1G-16/1G-2, 1G-16/1G-3, and 1G-16/1G-6 well bore crossings. ° A diagram and description of the surface hole diverter system. ° A diagram and description of the BOP equipment. Since we estimate spudding this well on October 30, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Si rely, .. ~rea D~q~lling E gine ?,~r~ JBK/JG5/LO3:tw Attachments (i[~'~ ~ ~ ~'~ ~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA Oi'L~AN D GAS CONSERVATION COM~YISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.0O5 EXPLORATORY [] SERVICE [] STRATIGRAPHIC DEVELOPMENT OIL [~( SINGLE ZONE DEVELOPMENT GAS [] MULTIPLE ZONE [] 9. Umt or lease name Kuparuk R~ver 10.1G_16Well number 1 b. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 367' FSL, 428' FWL, 5ec.29, T12N, RIOE, UN At top of proposed producing interval 1427' FNL, 1030' FWL, Sec. 30, T12N, RIOE, UM At total depth 1068' FNL, 593' FWL, Sec. 30, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 97', PAD 61' ADL 25640 ALK 2571 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed 1G-2 well 95' @ 1494'TVD feet 18. Approximate spud date 10/30~83 2671 . psig@ 80°F Surface 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 593' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9391' MD, 6885' TVD fe~t 2459+ 19. If deviated (see 20 AAC 25.050) 1 20. Anticipated pressures KICK OFF POINT 300 feet. MAXIMUM HOLE ANGLE 47 Ol (see 20 AAC 25.035 (c) (2) 3069 psig@ 67b, 7 ft. TD (TVD) , SIZE Hole I Casing Weight 4" 16" 65# ~3-1/2" 10-3/4" 45.5# ~3-1/2" 10-3/4" 55.5# 8-1/2" 7" 26# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER Grade I Coupling H-40 /Weld J-SS/HF-FRW BTC E-80 / J-SS / BTcl / I Length SETTING DEPTH MD TOP TVD 80' 36' I 36' I 2161' 35' 35' I 400' 2196' ~1924' I 33' I 33' 9358' MD BOTTOM TVD 116'I 116' 2196'11924' 2596'12200' 9391'16885' I I QUANTITY OF CEMENT (include stage data) ± 250 cf 877 sx Permafrost E 250 sx Permafrost C 597 sx Class G extended 356 sx Class G neat Est. TOC= 2596' ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development we]l to approximately 9391' MD (6885' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2671 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The cement will be brought 500' above the top of the sha]lowest hydrocarbon zone or to the 10-3/4" shoe. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Completion operations with the workover rig will be covered under a separate sundry notice. 1G-16 will be 95' away from 1G-2 at 1494' TVD.There are no closer wellbores. Reserve pit fluids will be disposed of by pumping them down the 7" x 10-3/4" annu]us of this wel]. The 7" x lO-3/4"~nnulus will be left with a non-freezi.ng fluid during any interruptions in the disposal . process. //_~,. _~/~,/~~,~ / ~/_~ SIGNED TITLE Area Drilling Engineer DATE _ The space belo/~i"C~r~s~se ' CONDITIONS OF APPROVAL Samples required I--lYES Permit number APPROVED BY~ Form 10-401 Mud log required I-lYES Approval date Directional Survey required APl number /d~YES [[]NO 50-- 0 %'~~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 26, 1983 by order of the Commission Submit in triplicate ARCO ALASKAr. I. NC. P AD 1 - WELL' NO.' ...... PROPOSED .... K U.__P. ARUK_...F I E_L__.D__,_,...~_O__R.TH 'EASTt'IAH WHIPSTOCI(,-. [NC.:. "i-' · _ ........ : .......... - ............................. .. : ..... L ..... ~_. ' .... ~ ............ ~.. ' KOP , . ..~ ..................... ............. i ......... . _; ............ .....--4. ..... : . ... '.;~' ........... ~ ...... ~ ., ........ ' '' I. · . ';., .............. ' i (:::: ' . ...... i : ' ~ ! ~ .... · . . , ~. , :i ..... ............. . ' ; , ; :;13 I ':! - - ( ! ,.- r~A,..,_= ~ ,.,,=,.,_.~__~" ~-"'~;:7''-'"'*''''-~- r-. -'^V' · ........ ~ '1- ....... · ........ -- ...... - - ..... ' ............. L ......... . . . : ....................... ~. .... ..... ; ....... ~ .... ; . . ..... · ..... : .......... ~ ~. K-5' T V D'=-51:-4?r~:' T HD~87-O-; DEP~ 31 ......................... .. .~ ......... : . ,; .' "~.:. BA'81E.-_"KLfl?_-:S~_~¥~]~ --" .6Z_~.:/'] - T ~i D_=_ ~i_9:k -- TD-' (-L-Oe,13-tN~-~T-)- ·- ..... ; ........ .... , 1 .................... 0 .... ~1_000-: · . ' ......~ ............... . . - _ . .... ........ ~. ...................... ...........: ..-- ............... ..................................................... - ........... ~OOQ 1000. 1 000 , I 3'1 ...... 5'0.0- SoO _ . ; ; · . 1:6b-I -_ t - -T i KUPARUK-E-I ELD~,--NORTH- SLOPE ~: EAST~'IAI~ WH-[P-S-TOCK.--I:N~ ~ ; . ; , ~ '~'~' -- ~ - i . 1 ~00 . ...... 1.!2QO_ · . . ...... i'.I_QQ- 1200 '~--11-00 .... : iooo-- ;-'-900 ---~ 800 ...... 700-- ~ ..... 8'00 I i ; I I I I , ....... : ............. -'-ARCO-- AL--ASKA-, t NC--. ~ ............. ~ - ............ '.i: .... :._:_:_:~-.~-L- .... _~ ---~._:_~.._o__._: ......... :~ ........ :- --~;: ..... .- · _ ............ r--. _ ............. _ .~-::--,: ~:: _ :__--_-? . . . , . . _ ............. ~ ..... ~ ~ j; ......... _ ...... · : . '~.:'.'.': ;- i:::_-_ _:-_::-:~_: :-- _-;_? _-:- : ~_:-_ ........... --._: :--__-~__ -;: :.-.-;::__; ..... . ...... _ ~!~ ......... . ........... ! ......... -___; ........ ~ .'_ ;:_ .. _~ ................ :~ ...................... ~ ..... ._ _ . ._ : ..... ~ ...... - _,_ ................. · ............... . ........ 4- ' ........... ~ .... ~ .................. 1 ......... : ...... ~ ........ ,4- i- ............. "-- ......~ ............... : ............... -- ' . i : ANALYSIS OF 1G-16/1G-2 WELLBORE CROSSINGS NOTE: Refer to the attached proximity maps and computer generated wellbore distance analyses. The proposed well, 1G-16, will cross four different existing wellbores. As indicated in the attached wellbore distance analysis, the nearest completed well will be 1G-2 with a minimum distance of 95' at 1494' TVD. These minimum distance calculations are based on the theoretical direction of 1G-16 versus the completed gyros on 1G-1, 1G-2, 1G-3, and 1G-6. The following procedures will be used to drill Well 1G-16: 1) The KOP for this well has been decreased to 300' MD, to increase the minimum distance between 1G-16 and 1G-2 to 95'. 2) This well will be drilled with a 5o_+ lead to the left (as most wells are drilled). Because 1G-16 will be above the other four wells, this 5°+ lead will increase the minimum distances between wellbores in all cases. 3) A Teleco MWD surface readout system will monitor the progress of the well. Surveys will be taken and plotted at maximum distances of 300' or less if minimum distance calculations indicate the necessity. 4) Well 1G-2 will be shut-in if calculations show that a distance between wellbores of 50' or less is to occur. If 1G-2 is shut-in, casing and tubing pressures would be monitored until a safe crossing is evident. In addition to the above precautions, the on-site rig personnel and supervimrs will continuously monitor all parameters as the intervals of interest are drilled. TJB:tw GRU5/PDOla RANGE (TVD) MINIMUM FROM TO DISTANCE 250.00 ,;50,00 538,656 550.00 750.00 497.779 650.00 850,00 478.575 '750,00 950,00 456,645 850,00 1050.00 432.587 950.00 1t50,00 407,53~ J050,O0 t250,00 383,246 t250,00 t450.00 343.005 i750.O0 i950.00 344.428 i850,00 2050,00 i950.00 2i50.00 408,689 2050~00 2250.00 455,i70 2150.00 2350.00 507,640 2250.00 ~4o0 O0 564 2i6 2~50,00 2550,00 2450.00 2650.00 685.604 ~ ~.>0. O0 749 2550,00 ~-~ · 2650, O0 2850. O0 2750, O0 2950, O0 879.8i 7 2850.00 3050.00 2950~00 3i50,00 t0t3.t92 3050,~0 3250,00 ~080,208 3250,00 3450.00 i2t4.5i? 3350,00' 3550.00 3450,00 3650.00 i349,748 3550,00 ~750,00 3650,00 3850,e0 i49i,t36 3750,00 3950,00 i564.637 3850.00 4050~00 t639.i4t 3950,00 4i50,00 i7i4,572 4050~00 4250.00 4~50.00 4350,00 4250.00 4450.00 4250,00 4550,00 2029.085 4450,00 4650~00 2i09.259 4550,00 4750.00 2t90.i50 4650,00 4850~00 4750,00 4950,00 4850,00 5050,00 4950,00 5~50.00 5050.00 5250.00 260t.207 5t50,00 5350.00 2684~666 5250,00 5450.00 2768~845 5350,00 5550~00 2853,464 5450,00 5650.00 2938,274 5550.00 5750.00 3023,725 RANGE (TYD) FROM 5650.00 5750~00 5850.00 5950,00 6050.00 6i50.00 6250,00 0300.00 6450,00 6_,o0.00 6650.00 ~750.00 6850.00 6950,00 TO 5850.00 5950,00 6050.00 6t50,00 6250.00 6350~00 6450,00 6550,00 6650.00 6850,00 6950,00 7050~00 7i50.00 WELL BORE DISTANCE A XSIS iG-i6 MD TVD 250,0 250~0 549,8 549.0 649,8 647~7 749,8 745~5 849.8 842.i 949.8 937.i i049,8 i030.4 tt49.8 ti2i,8 t249,8 i2iO,8 t349,8 i297,4 t 449.8 i38i .2 i60~,? i504.9 J650.2 i540.1 i750,2 i614.3 i850,~ i685, 5 t95e.2 i754.5 205e.2 i82~.4 2t50,2 t892,4 2250,2 i96t,3 2350,2 2030,5 2450,2 2099,3 2550,2 2i68.2 2850.2 2237.2 2750,2 2306,2 2850,2 2375,i 2950,2 2444,i ~050,2 25t3.0 3t50,2 - . 2582,0 3250.2 265t,0 3350,2 27t9,9 3450,2 2788,9 3550,2 2857,9 3650.2 2926.8 3750.2 2995.8 3850.2 3064.7 3950,2 3i33.? 4050,2 3202,7 41-50,2 327t,6 4250,~~ 3~40 . 6 4350.2 3409.5 4450,2 3478,5 4550,2 3547,5 4650,2 ~6t6,4 4750,2 3685,4 4850,2 3754.4 4950,2 3823.3 5050,2 3892,3 5t50,2 396i.2 5250,2 4030~2 5350~2 4099,2 5450,2 4~68,~ 5550,2 4237.i WELL BORE DISTANCE ANALYSIS MINIMUM DISTANCE 3t09.55i 3t95.535 3282.040 3369.035 3543,556 363t,553 37i9.823 3808.205 3896.858 4~75.480 4254.7i5 iG-tz MD I'VD 5650.2 5~0,~ ,~ 4375.0 5850,~ 4444.0 =~ ~ 45t2,9 6050,2 458i.9 6i50,2 4650,9 6250.2 47i9~8 6350.2 4788,8 6450.2 4857.7 6550.2 4926.7 6650.2 4995~7 6750,2 5064,6 6850,2 5i33.6 6950 o 5202 1)$ G-i GYRO SURVEY MD TVD 250,0 250,0 650.4 650,4 747,S 747.3 843.4 843.S 938.7 938.7 ti2i.9 ii2i,9 t2i0.2 i2iO.i i296.9 t296.9 i384.8 i384,7 tstO.? t5t0.9 t5i~,9 i546,i i546.0 i620.3 i620,3 i67i.4 i69i.3 i759.8 i759.7 i829.7 i829.6 i970.3 i970.2 204t.4 204i.3 ~i80 5 2t80 2250,0 2249,8 232t.i 2320,9 239i,4 239i,2 2466.8 2466.6 2544.5 2544.3 262i.i .... 2620.8 2693.~ 2692.6 2770,~ 2769.8 2800.0 2799.5 2858.6 2857.7 2900.0 2898,9 29t9.5 29i8.t.-. 298~.6 3000.0 3025.4 3082,4 3i06,6 3i60.9 3200,0 3250,0 3300.0 3333.6 3385.9 3405.9 3455,5 3500.0 35ii.3 3559.8 2997,t- 302i,7 3077,0 3i00,4 3i89,7 3237,0 3284,4 33i5.9 3365.0 SS83,Z .. 3429.6 S470.9 S525.5 3562.2 DS G-i GYRO SURVEY MD TVD 3657.0 36i3,5 3700,0 3652.2 3700 0 3652 ~ 374t,4 3688.9 3785.2 3727.7 3800.0 3740~8 3809~0 ~748.7 3850.8 3785,J 389~7 3822~5 3900.0 3827~9 3905,~ 3832~S 3944,5 3866~0 3982·0 3898~0 4000~0 39t3 3 WELL BORE DISTANCE ANALYSIS RANGE (TVD) MINIMUM FROM TO DI£TANCE 250.00 450,00 660.t72 350.00 550.00 643.977 450.00 650.00 625.482 550.00 750.00 594.920 650.00 850.00 552.587 750.00 950.00 497.9i8 850.00 t050.00 435.520 950.00 ~t50.00 367.023 ~050.00 1250.00 294.9t7 t150.00 1350.00 221.f7t 450.00 t650.00 ... 94.96t t550.00 1750,00 94,96t i750.00 2050.00 2150.00 2250.00 2350.00 2450.00 2550.00 2650.00 2750.00 2856.00 3450.00 3550.00 3650~00 3850~00 3950.00 4050.00 425O.00 4350.00 -- -~ 4450.00 4550.00 4650.00 - 4750.00 4850,00 - 4950,00 5050,00 - 5150.00 5250,00 - 5350.00 5450.00 - 5550.00 RANGE FROM 5650.00 5750~00 _. 5850.00 5950.00 -- 6050.00 6250.00 6350.00 _- s 6450.00 6550,00 t 950, ee t 74.3e9 0_,0.00 · :..~t50 · 00 342,564 2250. O0 429.835 245~,~ 6~4.7~2 255~. O~ 692. t 85 265~. ~0 779. 888 275~.~0 867.792 ;8~.~ 955.924 2950. O0 ~ ~44. 248 3J 5O.O0 J~.t .496 3350, ~0 ~ 399.40S 345~. ~ ~ 488. 554 355~, 88 ~ 577,995 365~, ~ ~ 667. 748 3750,8~ t 757,559 385~, ~ J 847. 784 3958, ~ ~ 938,-2~ 4 485~, ~ 2~28,685 425~, ~ 22~ ~, 244 ~ ~ 234 4558,~8 2483,38~ 465~, ~ ~5 , 4,6~7 475~.-~ 2666,2J9 485~.~ 2757,869 495~,8~ 2849,54J 5J 5~. ~ 3~33,846 525~, ~ 3~ 26, ~ 26 535~,8~ 32J8.459 545~.8~ 33tJ,~89 5550.~8 565~,0~ 3496,432 575~, 8~ 3589,284 t6-i6 MD TVD 250.0 25(:,,0 549.8 549,0 649,8 647.7 749,8 745,5 849.8 842, 949.8 937, t 049,8 t 030,4 ti49.8 tt2t.8 i249,8 t2i0,8 1349,8 i297,4 t449,8 t38t.2 ~549.8 i462. t589,6 1493,7 t589 r ~ t 493.7 t650,2 t 540, i t750.2 i6i4.3 t850.2 t685.5 t 950.2 t754,5 2e5e, 2 t 823,4 2t50.2 t892,4 2250,2 i 96t . 2350,2 2030.3 2450,2 .-'09..3 2550.2 2i68.2 2650. -~ ~'~ ~' 2750,2 2306,2 2850.2 2375. 295~.2 - 2444. 3050,2 25i 3, 3150,2 2582,0 325~. 2 265t .O 3350.2 2719,9 345~,2 2788,9 3550,2 2857,9 3650,2 2926,8 375~, 2 2995,8 3850,2 3064,7 3950.2 3t 33.7 4850.~ 4t 5G.~ 3271 .6 4250.2 SS4e.6 4358.2 3489,5 4450·~ ~ 3478 ..) 4550.2 3547.5 465~ ~ 2 ~&~ 6.4 475~.2 S&85.4 485~.2 S754.4 4~5~.2 ~82~.~ 5~59 ~ ~8~~ 5~ 58.2 - ~6~ .2 5259.2 5~50.2 49~.2 545~. 2 4~ 68, 5558.~ 42~7. DS G-2 GYRO ~URVEY MD TVD 250,0 250,0- 569.5 569.~ ~ 693.4 693,9 857,4 854,5 996.-'.2 982,3 i!39,8 ii2t .6 t244,7'-' i 2t 6. '-" t 334.4 ! 294.8 i4t0,2 t360,2 i472,3 14i2,7 i 5~5.9 i 465,9 !590,6 t5tt .t t6t5,".-- t53t · t 16t5,..-'" t53t . 1 t644,5 t554.7 i690,6 t59t,8 t738,3 t629,9 t780,i t663,3 t840.'2 t7tt,6 i885.5 t748.t i942.~ i793.~ i 989. I i 830.3 2035.5 t866,4 208t.6 t90t.9 2t25.4 t935.2 2t70.7 t969.2 22tl.3 t999,5 2~55 9 2032 0 2300.0 2064.3 234t.0 2093.5 2384.4 2t24.4 24tf.7 2t43.6 2454.7 2t73.4 2497.7 2203.2 25t7.6 22t6.8 2559.8 ~o45.6~_ 2600.0 2273,I 2628.~ 2292.~ 2670.3 232t.t 2700,0 2341,4 2736,7 2366,5 2777.S 2394.3' 2800,0 2409,9 2827,7 2428,7 n°67 6 2455.8 2900,e 2477,9 290t,6 2478,9 2940,2 2504,8 2977 7 n~n°,9 seee.o 2544.8 3022,7 2559.9 3059,8 2584,5 3096.9 2609.t 3100,e. 26tt,2 (TVD) TO 6250,00 6450.uu 6550.00 6650,00 6750'00 WELL BORE DISTANCE ANALYSIS MINIMUM DISTANCE 3682.399 3775,526 3868.660 396t.969 4055,574 4t49.238 4242.906 4336.6{3 4430.555 4o~4 i t6-t6 MD TVD 5650.2 4306.0 ~o0.o 4375.0 5850.2 4444,0 5950,2 4512.9 6050.2 458i~9 6t50.2 4650.9 6250.~ ~ a7t~=8, . 6350.2 4788,8 6450.2 4857~'? 6550 2 4~,'z ~ DS G-2 GYRO SURVEY MD TVD 3t 28.9 2630.3 3t 64. t 2653.6 3200.0 2677,4 3200.0 32t3.3 2686.i ¢~40,9 2708 t 3SOO.O 2742.8 3306~6 2747.i S340.2 2768.7 RANGE (TVD) FROM 250.00 650.00 t250,00 t350,e¢ t45o.80 t650.ee t750.00 t85¢.e¢ 2t5¢.ee 2350.ee .2450.00 2550.00 TO 450.0¢ 550.00 650.00 850.00 t250.00 t35o.oo t450.00 t550.00 t650.00 t750.00 1850.00 1950.00 2050.00 2150.00 2250.00 2350.00 2450.00 2550.00 2A50.00 2750.0¢ WELL BORE DISTANCE ANALY?,I$ MINIMUM DISTANCE 779,547 766.4it 754,468 738.449 718,929 695.8!2 669.270 640.335 6¢9.5t3 576.693 542.769 508.349 472.574 435.366 365.7¢5 336.870 3t2.846 293,601 278,538 267.446 26t.099 ?$9.R99 259.873 i6-t6 MD 250.0 549.8 649.8 749.8 849.8 949.8 t¢49.8 i149.8 1249.8 t349,8 1449.8 t549.8 1649.8 t749.8 i849.8 t949.8 2049,8 2t49.8 2249.8 2349.8 2449.8 2549.8 26t2,7 TVD 250.0 549.0 647,,7 745.5 842. t 937. t tt2t .8 t2t0.8 1297 · 4 138t .2 t 462, t t539.8 t6t4,t t 685.2 I 754.2 1823.2 i 892. i t96t ,t 2099. ¢ 2t68.0 2202,4 22t I ,3 DS G-'S GYRO .'.Ur,.VEt' MD 250.3 545.7 649.2 747 843.0 945,3 104t.0 it29.7 i223.8 i3i2.5 1489,t t583.6 t680,9 t770.7 i856.2 i943.7 2034.¢ 2i28.5 2322.3 24t6.8 9469,~ 2473.8 TVD 250.3 545.7 649,2 747.3 843.0 945.3- i04t.0 it29.4 i3i¢.7 i376.4 i482.3 i572.2 i663.3 t746.5 i824.8 i904.0 i984.6 2067.5 2i5i.4 23i0.4 2357.t-t 2650.00 2750.00 2850.00 2950.00 3250.00 S350.00 3450.00 3550.00 ~650.00 3750.00 3850.00 3950.00 4050.00 4i50.00 4250.00 4350.00 4450.00 4550.00 4650.00 4750.00 4850.00 4950.00 5050.00 5i50.00 5250.00 5350.00 5450.00 5550.00 2850.00 2950.00 3050.00 3t50.00 3250,00 3350.00 3450.00 3550.00 3650.00 3750.00 _ 3850.00 3950.00 4050.00 4i50.00 4350.00 4450.00 4550.00 4650.00 4750.00 4850.00 4950.00 5050.00 5i50.00 5250.00 5350.00 5450.00 5550.00 5650.00 5750.00 · .i' RANGE (TVD) FROM 5650.00 5750.00 5850.00 5950.00 6050.00 6t50.00 6250.00 6350.00 6450.0O 6550.00 6650.00 6750.00 TO 5850.00 5950.00 6050.00 6t50.00 6250.00 6350.00 6450.00 6550.00 6650.00 6750.00 6850.00 6950.00 260.942 267.288 275.600 290.550 309.245 330.5i2 353.289 377.i'04 40t.258 424.936 448.429 475.045 508.45~ 548.564 594.476 645.579 700.80t 758.16~ 8t6.352 875.576 935.3t8 995.257 1055.t34 ttt4.937 tt74.479 t234.041 t293.763 t353.648 t4t3.522 t470.76t 2675,2 2775,2 2850.2 2950.2 3050.2 3250.2 3350.2 · 5450.2 3550.2 3650,2 3750.2 3850.2 3950.2 4050.2 4i50.2 4250.2 4350.2 4450.2 4550.2 4650.2 4750.2 4850.2 4950.2- 5050.2 -5i50.2 5250.2 5350.2 5450.2 5550.2 2254.4 2323.4 2375.i 2444.i 25i3.0 2582.0 265i,0 27i9.9 2788.9 2857,9 2926.8 2995.8 3064.7 3t33,7 3202,7 327t.6 3340.6 3409,5 3478.5 3547.5 36i6.4 3685.4 3754.4 -3823,3 3892.3 396t.2 4030.2 4099.2 4t68,t 4237.1 WELL BORE DISTANCE ANALYSIS MINIMUM -DISTANCE t520.07t i 568. 955 i 6 i 7,630 t666.ti5 i 7 i 4. 574 i ?62 ~ 378 i 8 i 0. 295 i°~° t 905'. 579 t 95 t . 989 i 997.67 l ":' 4"':' "'t ~0 .... 4 2087. 250 iG-i6 MD TVD 5650.2 4306.0 5750.2 4375,0 5850.2 4444.0 5950.~ ~ 45i2.,0 6050.2 458f.9 6t50.2 4650.9 6250.2 47t9.8 6350.2 4788,8 6450.2 4857.7 6550,2 4926.7 6650.2 4995,7 6750.2 5064.6 6850.2 5t33.6 2534.0 2627,7 2696.t- 2790.2 2885.2 2982,0 3080.5 3i79.7 3280.9 3384,8 3487,i 3554..7 36i9.i 3680.i 374i.0 3795.3 3850.0 - 3923,4-. · 4¢74,6 4t5t,2 4235.5 4406.2 4484,4 4566.8 4~44.9 4724.6 4819.5 5068.7 2406.I 2482.0 2536,9 26i2.0 2687.2 2838.9 29i4, t 2989.2 3064.3 3t36.0 3i82.-9. 3228.2 327i.9 33i6.2 3355.9 3448.4 3503.0 3556.t 36i0.3 3669.9 3729.3 · 3790.0 3844.9 3902.6 3957.2 4012.9 4079.2 4255,8 DS G-3 GYRO SURVEY MD TVD 5i68.7 4526.5 5260.2 439i.1 5353.t 4457.0 5444 t 4_~t.8 5540.2 4590.3 56~2.0 4655.8 57t8.4 47t7,6 58i6.4- 4788.1 5924.2 4866.5 6028.9 4943.8 6t32.0 5020.8 6234.0 -- 5097.5 6332.4 5i7f.9 RANGE (TVD) FROM .450,00 650,00 750.00 850,00 950.,00 t050,00 tt50.00 t250.00 t350~0~ t450.80 t55e.oe J650.00 TO. 750.00 ~so.oe 950,00 t050,00 J150,00 t250.00 t350,00 1450.00 t550.00 1650,00 t750,00 t850.00 WELL MINIMUM DISTANCE 752.0;4 744.929 737.906 724 702 70< 677,t44 649.245 620.664 592.779 566.944 545,4t6 530.352 ~22.42t 52t,434 52t.434 ....... Y$I$ oORE DIo,ANC: t6-f6 MD TVD 549.8 549.0 649 8 '~ 7 749.8 745.5 849.8 842.1 949 8 ~ ~ t049.8 i030.4 t449.8 tt2t.8 t249.8 t2i0.8 1349.8 t297.4 1449.8 i38t.2 i549.8 i462.i t649.8 t539.8 i700.0 i577.9 iTeo.o i577.9 DS G-6 GYRO MD 254~ 545 = 668,4 798.0 958.~ t077.3 tt86.7 i293.4 t395.3 i495,3 t589.8 t679.7 ~774.6 1825.8 4825.8 SURVEY TVD 254,0 545.S 668.3 797~7 956~5 t072,9 1t79.3 t282.4 i380.t i475.I t564.I t648.t I736.o i783.0 t783.0 I 750 ~ O0 1850.00 I 950. O0 2050.00 2 t 50. O0 2250.00 2350.00 2450.00 ~.'~550 · O0 2650,00 2750,00 2850,00 2950,00 3050.00 3150.00 3250,00 3350 ..O0 3450, O0 3550,00 3650,00 3750,00 3850,00 · 3950,00 4050,00 4 t 50. O0 4250.00 4350,00 4450.00 455.0.00 , 4650,00 4750,00 485o,o0 4950,00 5050.00 5 t 50. O0 5250,00 5350,00 5450.00 '_ , ':: .: '5 , ' t-'~ :.,:.( :-;_ ~. :..:!. .)::: :?,:.8 .... .::, :i,, :: .':,': RANGE FROM 5650,00 5750.00 5850.00 5950,00 6050,00 6t50,00 6250.00 6350.00 6,;50.00 6550.00 6650.00 t950,00 523,762 t750.2 t6t4,3 2050.00 535,5~9 t 850.2 4685,5 2t50,00 557,t24 t950,2 t754,5 2250,00 585.24t 2050.2 1823.4 ~'~="~.00 6t9 638 2t50 ~ t892,4 2450.00 659,795 2250.2 t96t '~5~0, O0 705 806 o'==.~ .:.-~ <0..,0.,3 2650. O0 756. t t t 2450.2 2099,3 2750,00 808,677 2550,2 2168,2 2850,00 862 · 872 2650.2 2237,2 2950,00 9t8.796 2750,2 2306,2 3050. O0 975,702 2850,2 2375, t 3t50.00 403t .736 2950,2 2444,t 3250.00 1088.t95 3050,2 2513,0 3350. O0 I I 46,203 3t 50,2 · - 2582,0 3450,00 1205,69t ~250,2 265t,0 3550,00 t266,458 3350,,9 27t9,,° 3650,00 t328.2t4 3450.2 2788,9 3750,00 I 390,565 3550,2 2857,9 3850, O0 t 453. 240 3650,2 2926.8 5950,00 t5t6,2t4 3750,2 2995,8 4050,00 t 579. 653 5850,2 3064,7 4t50,00 t643.747 3950,2 3t33,7 4250,00 t 708,290 4050,2 ~202,7 4350. oe t 773. t 79 4t 50.2 327t . 6 4450.00 t838. 367 4250.2 3340.6 4550. OO t 903., 953 4350.2 ;3409.5 4650.00 1970,065 4450 , 2 5478.5 4750.00 2036.668 4550,2 3547,5 4850.00 2t03.802 4650.2 3616.4 4950.00 2t7t .452 4750.2 3685.4 5050.00 2239.538 4850.2 3754.4 5150.00 2308· 074 4950 ,,=° 3823, 5250, O0 2376. 870 5050.2 3892.3 5350.00 2445.9t0 5150.2 396t .2 5450.00 25t5.407 5250.2 4030.2 _~550. O0 2585 ,20t _5350,2 4099, 5650.00 2655,296 5450,2 4t68.t 5750,00 2725,600 5550,2 4237, (TVD) TO 5850.00 5950.00 6050,00 6150.00 6250,00 6350.00 6450,00 6550.00 6650.00 6750,00 6850,00 WELL MINIMUM DISTANCE 2796.t2t 2866.883 2937.803 3008.795 5079.822 3150.902 3222,053 3293,254 3364.396 3435.347 3506.023 BORE DISTANCE ANALYSIS t6-t6 MD 5650,°= 5750.2 5850.2 5950.2 6050,2 6t50,2 6250.2 6350.2 6450 ~ 6550 ~ 6650,2 t862.1 f946.t 2037.9 21.~ ~ 2207,0 2269.9 234~.4 2430.9 2607.0 267t.9 28t9.t 29t6.8 2983.2 3060.9 3J37.t 32t3.7 3280.5 3363.7 3452.0 3535.2 3607,8 3675.0 3752.7 3834.8 3907.8 3977.0 4044.t 4t08.6 4t76.6 4237.5 4300.4 4368.7 4438.7 4500,0 4566.0 4625.8 4693.4 4760.2 i8i6.i i89i.9 i973.0 2049.8 2ii6.4 2t67.7 2225.7 2298.1 237i,9 2438.2 2486.6 2590,3 2655,3 2699.0 2749,7- 2799.t 2848,5 289t.6 2945.t 300t.3 3053,9:.: 3099.5 3J4J.4 3~89.3 3239.3 3283.3 -3324.9 3365.4 3404,2 3445,4 3482,4 3520.5 356t.9 3604.5 364~.9 3682.4 37t9.2 376t.t 3802.5 DS 6-6 GYRO SURVEY TVD MD TVD 4'306.0 482t.5 3840,7 4375.0 4889.5 3883.0 4444.0 4956,2 3924,9 45t2.9 5028,5 3970,5 458t,9 5096,5 40f3,6 4650.9 5i66.4 4058,t 47i°,.8 ~,.~=~ 5 4t03,4 4788.8 53f2.5 415i,0 4857,7 5381.2 4i94.6 4926.7 5464.8 4247.8 .:.~.7 ~57.4 4307.0 .® 1 6" CondUctor 1. 16" Bradenhead. · 2. 16" x 20" 2000 ps~'~doub!e studded adapter. " ~ w/lO" side outlets. 3. 20 2000 psi drilling s~, 4. lO" ball valves, hyraulically actuated, w/lO" lines to 'reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20"-bell ~ipp3-e.' ' ' - Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3, Close. annular preventer in the event that gas or fluid flow to surface· is -detected. If necessary, manually over- ride and close ball valve to upwind di verter I i r.e. D~o. not. Shu_____Et i__En -wel 1 -under any, circmstances. C ~'"NULRR PREVENTOR - BL I ND 8 PiPE RRMS 7 DRILLING SPOOL PZPE RR,"IS "5 T. BG HD 3 CSG HD 1 2_0'00 r'_--'.' x ;.,., -- T IC" 3000 ~i x ~3-5/$: 5£30 FSi adapter spool 5 I~ 5/8" 5000 PqT pipe 6. 13--5/8" 5000-'PS1 drilling and kill line~ o 7. 13-5/8" 5000 PS! pipe ra~.s- - 8. 13-5/$" 5000 PSi.blind r-~ -- 9. 13-5/8" 5000 PSI ~nr-.Jlar . 4. 5. 6. 7. 8. .. w/choke o . · ACCI~'~I_~TOK C.~:~$-£ITT T_ST ~d[~ ~ FILL A~t~TOS ~1I~ ~'~ ~;T~ SYD~b~I~ ~I~ 1500 PSI ~W~q ~ OFF. ~ O~ IA~C R~P~- ~LL BOP STA~ ~ ~N S~S I~ ~. lO MII~ES. B~D TO ~0 ~1. TO. ~ PSI. ~gl TOP 5~ OF PiPE IN~.~E PP. ESSU?~ TO 3~ ~ ~2:g H!I~T~. B~ED TO II. ~j( BO~ S~ OF PIPE ~. ~ ~lD lEST lO B~ED TO lE~O PSI. ~ ~;IFOLD ~qD M~ ~ ~ ~t~l. 15. P~ TEST [NF~T!~ T~T FOPJq SIGN YI~. o . -. · o _. - . .:7 . PHASE II AS BUILT WELLS 9 thru 16 29 PHASE 1 EXISTING WELLS ! thru 8 DRILL mITE I G CONDUCTOR A,.,.~3 UI LT LOCATIONS WELL 9 Y = 5,981,095.182- ×: 540,558,976 4 44' FSL Lat. 70°21'33.3989" Long. ,149° 40' 14.036" 780 FWL WELL I0 WELL Ii Y = 5,981,034.771 X 540,572.18 6 386' FSL Y: 5,980~976.130 Lat. 70o21'32.8237" Long. 149040' 13.66Cf 793' FWL Lat. 70°21'32-246P-'' X: ,540,585.500 327 FSL Long. 149°40'13.279" I 806 FWL ; WELL 12 Y: 5,980,917. 67G X = 540,598.709 268' FSL Lat. 70°21 '31.6706" Long. 149°40' 12.902" 818 ' FWL Lat. 70°21'30.9105 Long. 149°40'23.18:5'' 466' FWL WELL Y: 5,980,838.480 540,247.544 I 191 FSL WELL 14 Y: 5,~80,896.9t9 Lot. 70°21'31.4858'' X= 540,234.224 Long. 149040'23.563'' 250' FSL 454'FWL WELL 15 WELL 16 Y = 5,980,955.661 X: 540,22Q.882 30 9' FS L Y: 5,981,014.002 Lat. 70°21 '32.06447." Long. 149°40'2-5.9:44' 441' FWL Lat. 70021'32.6388'' ! Long. 149°40'24.313'' - X: 540, 207. 93 2 I 367' FSL 428 · . , FWL 31 NOTE:BASIS OF ELEV. IS TBM 1--6 SOUTH PER LHD 8~ ASSOC. NOTE: DS iA T. 12N ;RIOE. UMIAT MER I": I mi., BASIS OF LOCATION IS MONUMENT' IG MIDDLE AND IG SOUTH AS SET BY L.H.D. 8~ ASSOC. LOCATED IN PROTRACTED SECTION 29, TOWN 12 N., RANGE IOE., UMIAT MERIDIAN. Th~s Surve, 33 34 CPF I >IT C I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, AND THAT TI-LIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF: IIIiiiiii .M jJ)t ii. irltl-li i I i ARCO Alaska, Inc. Kuparuk Project DRILL SITE I-G CONDUCTOR' AS BUILT LOCATIONS date' AUG 14, t983 scale' I": 300' drawn by ' E.H. dwg. no. '9.05.107.11d 2_ CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc '"f / _~ ~ ~ (,,'2 thru 8) (3) Admin thru l l) (4) Casg (12 thru 20) (5> BOPE (21 thru 24) ® 10. 11. YES NO the permit fee attached 1. Is ......................................... 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 well bore plat included ....... "i_ 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait .................... bond in force :', ..... Does operator have a .................................. ' Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production strings }i. Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required .... Are necessary diagrams of Does BOPE have sufficient pressure rating -Test to ~rg~D psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ... ........................................... REMARKS Additional Remarks: o Geology: Engineering: HWK ~ LCS~__~ BEW WVA,,, rev: 12/06/82 INITIAL GEO. UNIT ON/OFF .... POOL CLASS STATUS AREA N.O,. SHORE, Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. ~mmmm~mmm,m~m~mmmmmmm~ TAPE VERIFi~CA, TI;O~ ~ISTING bVP O]O,H02 VER)FICATION LISTING PAGE ORIGIN : REEL NAME 11)5056 CONTiNUATiON ~ PREVIOUS REEL COMMENTS {LIBRARY TAPE H ~ SERV'ICF NA~E :,EDIT DATE :8)/11/23 ORIGTN lO000 TAPE NAME :873.1 ONTINUATION ~ 101 ,REViOU$ TAPE { COMMENTi {L~BRARY TAPE ** FILE HEADER ~IL~ NAME lEgIT .001 SERVICE NA~E VERSION # DATE l ~AXlMUM L~NDTH I 1024 FILE TYPE PREVIOUS rILE ** INFOR~AT'ION RECORDS MNEN CONTENTS CN ) ARCO ALASKA WN I 1G-16 FN { KUPARUK RANG{ i0E TOWN{ 12N SECTI 29 STATI SKA CTRY3 USA COMMENTS 000 0 0 ~) 065 000 0~0 ~ 065 000 000 004 065 000 000 004 065 O0 0 065 00~ 000 0 ~ 065 000 O0 000 000 006 065 000 000 O04 065 COMPANY ~' ~TZC RZCHF~EbDCO:#PAN¥ WEb[, ,~ 6 FI£LD a RUK BOREHOI,~E COMPENSATED bOg IBHC)LoG FORNAT'tON DENSIT¥1COM:PZNS~TED COMPENSATED NEUTRON LOG (FDN) ENTRY 9 ,lin OATU~ SPECZFXCATZON BbOCK$ ~"D O:'~'~E~~ LOG D~PT FT 0 0 0 0 Ib~ DXL OH~ ? 0 0 0 ILD DIL OHM~ ? ~ 46 0 DIL ~ 0 0 , i ° FON U 4~ 68 0 DR'HO rDN G/C3 42 4~ 0 iN 42 3 0 NRAT FDN 42 ! 0 RNR~ FON 4 0 0 GR FDN GRPI 42 3! 32 0 DEPT 9163,0000 SFLU 2,59:38 IL~ SP -2'6,0000 GR 91 ' 3~25 NPH! RHOB NCNb lvo .000o rCNb, NRA~ rILE N:~. o o 0 0 ! 0 , , DRHO SAMPLE 8,$000 bVP 010.H02 VERIFICA?ION 5~S?~NG P~GE 4 SP -2_~'0000 RHOB 2,4:121 NRAT 2.9277 ,U '"9:):; · Ri.lOB ,4B05 NC~t. NRAT .0742 RNRA Or. PT 8600,0000 SIP ..2~,5000 RHOB r" 4551 NRAT 2.5840 8F~U SF~U ~CNb RNPA SFLU RNRA. SFbU GR NCNb RNRA 8FLU NCNb RNRA 8rbU NCNb RNRA DEP? 8500,0000 BP. -25. 0000 4727 7500 SP ! , RHO'B ~,2715 NRA? ,8359 OEPT 8300,0000 SP -22,0000 RHOB -999,2500 NRAT -999,2500 DEPT 8200,0000 SP -25.0000 RHOB ;999,2500 NRAT 999.2500 DEPT 8100 0000 SP -tB,O000 RHOB '999.2500 NRAT -999.2500 oooo t5,0625 lb,~ 76,.5000 NPH,T 2S5~.0000 rcNb ,,1465 GR 8'~ 1094 937S 217~: 0000 3!64 6 I: b M OR rCNb GR FCNb 01~ GR . 0 FCNB ,~680 ?$00 ~! '999, [ ~$000 ~¢~! " .2500 rCNb -99~,2500 GR 241,,4648 IbM ,5000 NPH! · GE 8457 't,ooo''/5' 3 44'. 2,~059 iO9,?SO0 ZbD DRHO CAb,! RHO CAb! bD ~RHO CAb:l: lbo DRHO CAb! DRHO '.50 CAbl -999, I00o 174 0 2578 lbo '50 CAb! !5~0 D,RNO 5000 4 7 9' 9O -999, O0 10,5625 2,1602 ,.999,2~i00 10,3594 D~PT 8000 0000 8FLU SP -31 0000 GR RHOB -999 2500 NCNb NEAT -999 2500 R~RA DgPT 7,~.0000 ~FbU 8P ,0000 RNO~ -999,2.500 NCNb NRAT -999,2500 RNRA 7900 0000 DEPT 7 R~ ?600 -999 2500 DEPT 75~~.. 0000 SP ,2500 NRAT '9 DEPT 7400.0000 .RHOB ' ~ ,2SO0 NRAT '999.2500 7300 0000 '~0 9375 -999 2500 -999 2500 7200 0000 ooo "999 2500 DEP~ 7[00.00 Se -25.25 g RHOB ~999, "R,T 999.~I~0 0 DEPT 7000,0000 SP -24.~I00 RHOB -999, O0 DEPT RHOB NRRT t).t~PT NRAT DEP? NRAT DEPT SP RHOB NRA? SF[,U RNRA ,8FL U RNRA 2,9102 6250 ~0 :00 O0 9 NCN RNRA -99 NCNt, -999. O0 RNRA -999, O0 SFbU ¢~t094 ~NL i875 999.2500 ~bU 2.8086 96,3750 NCNb -999,2500 RNRA -999,2500 SFLU ~!.8525 NCNb .2500 ! M I' M NPH! FCNL NPHi FCNL NPHI FCNb 999 ~ '99~ 2500 2500 "999 2500 .,2656 -9~ ,2500 -9 .,~'500 ,t875 999e2500 -999., 2500 IL:D DRHO IbD DRHO CALl DRHO CALl CALl DRHO lbD DRHO CAt,l DRHO CALl DRHO CAbi .99}, 7:6 l !; 0 I .99 I . 2,2285 -99'9.250'Q 9,9687 ,9,85,4 -99~,2500 ,8984 SP RHOB aP,, NRAT SP. R,HOB DF, P? RA? DEPT P/RA? DE:PT NRA? DEP? DEP? SP, RHOB OgPT SP RHOB ~RA? DEPT RHOB NRAT DEPT SP -999.2500 RNPA 6900 0000 SFLU 2500 OR 2500 NCNb 2500 Rr~R~ 6:80'0,0000 8rL, U -24,7500 GR · 999,2500 NCNb =999,2500 RNRA SFLU GR NRA 6500 0000 ~]bU -gg~ 2500 NCNL -999 ~,250:0 .RNRA .oo o° 9'9 ,2500 NCN[~ -999~2500 RNRA 6300,.~ FLU -999.2500 NCI~b "999.2500 RHeA 6200,0000 8Ft, U -29.5000 OR -999,2500 NC~'L -999,2500 RNRA 610~,0000 SFLU 3 , 0000 GR -999,2500 NCNL ~999,2500 RNRA 6000,0000 8FLU -34.~000 GR ,,999. 500 NCNb -999,2500 RNRA 5900,0000 SFLU -3%,5000 GR !',, ! $ T I: N G ,.999.2500 2999 oo 99~ O0 3,0 84 -¢99, 500 "999, 500 -999.,2500 -999, '999, '999~ O0 '999.2500 '999.2500 '99 .2500 '999.2500 91, 50 GR I N I~H]: rent,, NPH! FCNL OR ! bM ! N GR GR NPXI OR PNI. CNL NPH! FCNL GR NPH! . -999 .99} °o ,9727 : ,8 '99 t05,0~25 5OO 9~, 000 3 3379 . ~: HO C~t,l CAbI I:bD DRH:O DRHO DRHO R O A I DRHO CAI,,I ILD DRHO 6 '999,,2580 tO,O? ! .99~'039t t0,3'5:00 .2500 ,4648 10.9932 -99 , t t, '99 , tO,$ 05 3.3770 -999,2500 5¥P 010,~0~ VE~IFIC~TIO~ LISTinG PAGE ~HOB -999.25~ NCNb ~EPT 5800,0000 SFLU ~P -32 2500 RHOB ~9'9~ ' ,2500 NCNb NRAT "999.2500 DEPT 5700.0000 SP -34,5000 ~HOB -g99.2500 NCNb RAT -999.~500 500 NRAT 999..500 RNRA 0 0 S,P RHOB 99 NCnb NRA.? RN~A DE:PT SFL, U SP. GR ~RAT RNRA OEPT RHOB NRALT OEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB OEPT SP RHOB NRAT DEPT 5300 )000 -37 ~500 -999 ~500 "99'9 ~500 5200.0000 -40.5000 -999.2500 "999.2500 51.00.0000 . 39. 0000 ~999.2500 999.~500 5~00,0000 . 38,5000 999.2500 -999.2500 4900 0000 '46.5000 m999.2500 4800,0000 OR NCNb RNRA SFLU GR NCNb RNRA NCNb RNRA 8FbU GR SFLU GR NCNb RNRA 8FLU ~' 40 oo 9"9' :2:500 6 ~ O, : ,.999 O0 04'8125 999,2500 99~ 2500 4,0273 4,0000 .-999.2S00 999,25o0 3,1973 86,3125 "999,2500 2.7773 -99 . -999. 6 i055 . 999, '999,2500 3,5449 FCNL NPH! FCNL GR CNL OR NPH! GR NPH! NPH! FCNL I~M NPH FCN~ N N! r~Nb NPN! FCNb GR -999, $0 ..!9~ 00 91 SO '999, -999 - 9979 84 '5 · CALl DRHO CAb! CAL~ CAbi t6 -9 DRHO ' CA:b! lO1, 9375 :" ~:RHO .,9:9~:,93.55 bD ~2~00 -999.,~500 CALl 104'I25 . ~,t7'58 bO 999:,2500 ~RHO -999'2500 ~14.0000 -999.. ~CAL!DR"O . 3'0898 ILO 999.2 DRHO 0 CALX ~00,]750 . 5,9062 96, 50 4,1953 !LD 10,828! 0 ? 8 '9gg, O0 ' 999;::2500 12,1562 . 4, 3,4{i9 Il', '999,2500 6,3125 "999 4,6094 8P NRA? DEPT SP RHO~ NRA'T RHOB NRA? NRAT O£PT SP RHOB NRAT DF. PT RHOB NRA? DE,PT BP RHOB NRAT D~PT SP RHOB NRAT DEPT SP RHOB NRAT DEPT RHOB NRAT 86 4200. 0000 -79,7500 4100,0000 ,,5'7,5000 2,2949 3,5742 4000 0000 '2500 '6i ' 97 3900,0000 ,0000 '6~,4902 ,2187 3800,0000 ',,7J,2500 3,1562 .757g RNRA RNRA SFLU GR NCNb RNBA SlrbU GR N N R~RbA SFLU GR NCNb RNRA 8rbU NCNb RNRA 217t: ,0 4;,i 20 221'40 0:000 4492 6.1992 84et875 2128,0000 4o,t680 6.7969 0 4258 ! 0 4531 51 ' 3438 '0 0 NPH! IPCNh GR NPH:I: FCNL, :IbM NPH! rCNL, NPH! GR NPH! FCNb GR ' 6,902{ 3g,7949 510,2500 B4,1675 4375 7813 P,8203 )',697 lt,,84{7 440B242 57&,,O000 5i"03438 DRHO CAb]: 11 AL, 4 DRHO CAb! CAbl o °o: CAb:l: [,VP 010,H02 VBRIFICATION DEPT 3600.0000 Srb. U SP '72,2500 GR RHOB 2',1719 NCNb NEAT 3,2109 RNRA ~s~PT ]..800. 0000 8F[,U · . 0,0000 GR RHOB 2,0508 NCNb NEAT 3 ,:60i 6 RNRA DEPT 3~00.,00~0 SrhU RHOB , 68: M:CNb NRAT , 58 RMRA NRAT , RNRA DEPT 3200.0000 ~HPoB -6 .00001 ,?0i2 RNRA SP 25 RHOB 1426 NEAT 3: 2 86'7 NCNb RNRA SFLU GR NCNb RNRA 8FLU GR NCNb RN~A 8FLu ER NCNb. RNRA DEPT 3000.0000 SP ,,,58,2500 DEPT 2900,0000 SP -48,5000 RHOB 2.0938 NRA? 4.i602 DEPT 2800.0000 SP -58,5000 MRA? 38 27oo.oooo sr u Sp "05 .0000 GR RHOB 2.0488 NCNb NEAT 4,1719 RNRA · ,?0~! ,g6¢ I M :. GR IbM NP'.Hi 2~04 4:i'Ot6 FCNI~ .1250 ~PHI rcl~,c ER 0703 GR 0 FCNL 4R GR 4,6367 5000 NPH! 7,402; IbM 54 187 . NPH! 00 rCNb 6,5586 , FCN~ ER .0000 ' i 8 ? 5 6 56 625 54 7 82,I250 482,7500 68,9{75 S,2148 .51+ 6 62,5000 !i 't484 ,6270 .0000 754.1875 !484 IT, D DRHO CAt,! CALl · XLD DR'#O CALl L.D RHO CAb'/ XbD DRHO CALl DRHD CALX :I:LD I)RI'IO CALl PAGI~ X :0; 3 10, ,~984 ~,P420 10.?i{8 LVP OiO,H02 VERIFICATION ,LISTING PAGE {0 ' t0'0 I~M NPH! FILE NAME M{ED]'T ,,001 8ER¥ICE NA YERSION # DATE i MAXIMUM LENGTH i 1024 FILE TYPE -0 10 TRAILER ~ NAME {EDYT ORZGIN lO00? TAPE NAME {8731 ~NTINUATION , 101 X, TAP~.NA,E I COMMENTS ,LIBRARY TAPE ** REEL TRAILER ERV! NAME {EDIT 3/1.1/ ORIGIN { REEL NAM~ {I35056 CONTZNUATION ~ {01 NEXT REEL NAME COMMENTS ILIBRARY TAPE
