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191-092
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op fiwow. :❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate` 1 ❑ Alter Casing ❑ Change #pp' m �'•R(b1ralri*-(] Plug for Rednil ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCK ❑' 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work:5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑� 191-092 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-029-22193-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25635, ADL 25640 KRU 1 R-26 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,218 feet Plugs measured 4320 feet true vertical 6,976 feet Junk measured None feet Effective Depth measured 10,201 feet Packer measured 9570, 9706 feet true vertical 6,965 feet true vertical 6523, 6614 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 80 feet 16 123' MD 123' TVD SURFACE 5,551 feet 9 5/8 " 5,593' MD 4072' TVD PRODUCTION 10,159 feet 7 10,201' MD 6951' TVD SCAB LINER 355 feet 4 1/2 " 4,606' MD 3503' TVD Perforation depth: Measured depth: 4320-4480 9639-9672 9887-9902 9916-9941 feet True Vertical depth: 3327-3427 6582-6604 6750-6760 6770-6787 feet Tubing (size, grade, measured and true vertical depth) 4.5x3.5x2.875 L-80 9,747' MD 6,642' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER HB RETRIEVABLE 1 9,570' MD 6,523' TVD PACKER - BAKER D PERM. PCKER 9,706' MD 6,614' TVD PACKER - BAKER LINER TOP PCKER 4,431' MD 3,397' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.2as) 15. well Class anter work: Daily Report of Well Operations 121 Exploratory ❑ Development ❑ Service O Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ElGSTOR ElWINJ WAG ElGINJ ❑ SUSP�"7 SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-314 Contact Name: Ryan McLaughlin Authorized Name: James Ohlin er Authorized Title: Staff CTD Engineer contact Email: ryan.mclaughlin@cop.com Authorized Signature: Date:% Contact Phone: (907) 265-6218 JIT -L- 1&115/I9 {;BDMSIIY'gEP 0 5 2019 Form 10-404 Revised 4/2017 0 Submit Original Only 1 R-26 WHIPSTOCK DTTM JOBTYP SUMMARYOPS START 7/10/19 DRILLING SWEPT TBG MULTIPLE TIMES w/ FULL BORE BRUSH, 3.73" G -RING SUPPORT- DWN TO FILL @ 4483' RKB. MADE MULTIPLE ATTEMPTS TO SET CAPITAL 3.81"X LOCK IN TARGET NIP @ 4476' RKB. TRASH CAUSING X LINE TO SHIFT PREMATURELY. UNABLE TO REACH TARGET DEPTH w/ LOCK "RECOVERED SMALL PIECE OF RUBBER IN QUICK CONNECT" PULLED 1" OV @ 4206' RKB. READY FOR CIRC OUT. IN PROGRESS 7/11/19 DRILLING BRUSH & FLUSHED TBG DWN TO X NIP @ 4233' RKB w/ FULL SUPPORT- BORE BRUSH, 3.84" G -RING. MADE MULTIPLE ATTEMPTS TO SET CAPITAL X LOCK @ 4476' RKB, AFTER REACHING TARGET DEPTH WAS UNABLE TO LEAVE LOCK IN PROFILE DUE TO MUD. SET 1" OV (1/4" PORT) @ 4206' RKB. READY FOR COIL. IN PROGRESS 7/11/19 DRILLING TRAVEL TO 1R-26 MIRU SUPPORT - CAPITAL 7/12/19 DRILLING RAN IN HOLE W/ 2.5" JSN PUMPED A 10 BBL GEL SWEEP AND A SUPPORT- 15 BBLS GEL SWEEP HARD TAGGED AT 4482' CTM JET UP AND CAPITAL DOWN SEVERAL TIMES 7/12/19 DRILLING BAILED UNSET CEMENT @ 4421' RKB w/ 3" BAILER, RECOVERED SUPPORT- 1/2 GALLON. DRIFT TBG TO HARD TAG @ 4498' RKB w/ 3.73" G - CAPITAL RING. SET 3.81" X LOCK w/ FLOW THROUGH SUB @ 4476' RKB, CONFIRMED LOCK IS FULLY SET w/ CHECKSET. DRIFT TBG TO X LOCK @ 4476' RKB w/ DMY WHIPSTOCK DRIFT (19'x 3.625") NO ISSUES. READY FOR E -LINE. IN PROGRESS 7/14/19 DRILLING RIH W/ NORTHERN SOLUTIONS WEGDE. SET TOP OF WEDGE @ SUPPORT - 4460' ORIENTATED 0° HS. CCL TO TOW = 14.2, CCL STOP DEPTH = CAPITAL 4445.8', LOG CORRELATED TO TUBING TALLY. 7/15/19 DRILLING Move rig from 1R-101 to 1 R-126. Rig up and start initial BOP test. Rig SIDETRACK accept @ 20:OOpm 7/16/19 DRILLING Complete initial BOPE test, M/U BHA #1. Pressure deploy BHA #1. RIH, SIDETRACK Tie in +10.5'. Displace to milling fluid 7/17/19 DRILLING Complete displacement. Start milling widow. Initial pinch point 4465.5'. SIDETRACK Mill first run to 4472.5. Trip out for second run window BHA. encounter tool problems at surface. Swap out BHA's. Rehead upper NRJ 7/18/19 DRILLING Complete triple string window exit. Mill rathole to 4495. Trip for Build SIDETRACK section BHA 1R-126 Final CTD Schematic opan.a:viamm lam s p^=^°°� \�\� Injector !CTD KOP 4453' MD, 3329'1 65TVD, 51 -Deg Ind! 9-5/6"Supace 36k J-55 ahoy at 5593' Top of 7-cement`9750- via CBL of S-27-91 PERF6 (plugged) asantl 9fi39'-96]2' MO -santl 9867-9902' MD -santl 9916-9941'MD ]-Pmtluation 26k J-55 shoe 10,201' MD ahovethe Weetsak formation T' L9la dont go shallow noogh W vie arN[ pah . BeRgoess izqp cemavaegaeadowab 4R-120 MD' - ID,90]' ��40802-]/0"sbtletl liner:4930'-10,90T MD ' w/3jta ealitl every 1,000' Oapia pvip lisleeve vol'eal core, 4 j0eplaymenl sleeve w/seal hore: 4430' MD ConocoPhillips Alaska, Inc. KUP INJ UNIT WELLNAME 1R-26 WELLBORE 1R-26 1n-2N.YPlA1B]2e'g3AM Last Tag Vatnl xmmusto(xeap Annotation I depth mend End Data wellsre Lazt Miss By .......................... ...................... ............ ... ._............ ......................... .... Last Tag: ELNE 9,018.0 I1R26 jpostojl Last Rev Reason Annotatmn End Date wellWre Last Maa Br Rev Reasons Set Liner Top Packer and Measurea SDHP 8512019 1R-26 bwoMi Casing Strings cxsina Dominion- CONDUCTOR o0(m) to(,.) TQPOURIA sal Depth RUNS) sM ceps lNDd... Wmeo U... Grede To 43 ifi 1506 43.0 123.0 1230 82.58 H-00 WELDED CONDUCTOR, a3.D1Y10 seeing Oeamlptlan SURFACE OD find IO lin) Top RUKB) $et Ceptn(XNo' Se[Depin (ND)... WVLen 6... Grace Top Th. 9518 8.92 42.6 5,583.1 4,0]2.0 38.00 J-55 BTC Gnsupr, 2aaa.o acing Deaaaption PRODUCTION oD Ont IoM) rop fnRel set Depth RUN6) sa oapm lrvoL_wuten 11 Ends Top rhnad ] 6.28 41.9 10,201.0 26.06 JSS BTC -MOO CUIng Oesmiptlon SCAB LINER OD lin) IOlind Top lnKB) $e[Deptn (XNBd Se[DepinlNO)... WVLen (I... Gmae Top Th. 412 4.06 4,251.1 4,606.1 3,5113.1 11.fi0 L40 GASUpr 1.S Liner Details OPPLE. 4.2ES7 sent ASST', 1.11 cemenmb socio wx: agslo a Top then) Top rvommal le Com (in) lND)mKid rap mn l°)#NIPPLENipple 828 4,251.1 3,284.5 51.80 ER=OKB 4,286.7 3,306.6 51.69 Nip0188159 3813 p30.5 3,3960 5136 edg3.958 4,449.5 340].9 51.34 Nipple -3.813 Norman comm same: 4,456.6 3,412.3 51.33edg3.958 C ua CMTsoz; 4a2ooa,aeo.o� 4475.6 3,424.2 51.32 ppl3.813 Tubing Strings be"Nalkx(ME).the Asmsmok 4.4318 Tubing Lima [ion TUBING 4.5" $tang Ma... ID(n) Top (DNB) Set Depth m.. Set DeINM1INOd I... Wf(I"d G2tle Top Connection 4.926 3.96 39.9 4,251.8 3,2850 12.]5 L-80 HYD 503 Completion Details To' Topetime Ineel rop lad Nominal (°I Ihm Dec Co. ID ODI 39.9 39.9 0.88I HANGER Hanger Fra IV11"X41/2"HYD563p1Us4.63pup 3.958 4,232) 3,243.2 51.54 NIPPLE XNipple 3.813"HYD 563 3813 4,249.3 3,283.4 51]9 SEAL ASSY Tieback locator 3.980 WHIPSTOCK 4eem0 Tubing Description TUBING 3.5"x2.845" x29875' I String Ma...Wan)Top Rare a ch(D. Set De US IND) 1... JIM Grace Top Connedon 412 299 9,569.5 9,>46.8 6,641.9 9.30 L-80 ABM -BTC Completion Details X -Lack Nsmmni 4476.0 TaplTV3) Tap YO B) MKB) 9,569.5 6,523.0 Topincl N 1°) Item Nominal Des Com U,(IN 48.08 PACKER BAKER HB RETRIEVABLE PACKER 28 g 9,627.2 8,561.5 48.20 ELAST RINGS CARBIDE BLAST RI NGS 2.992 SoNB LINER:4 M 14 soe.t SNIDCE PLUG-PERNANEINT. 9,6945 =606 7 _76144 47.66 SLEEVE -C CAM CB -1 SL IN SL wMO GO ID; HEE LEEVE 2.750 (OPENED 516114) C4,09 1R -1A SLOrT80 9,]06.0 6,6144 47.63 PACKER BAKER D PERMANENT PACKER 3.250 a 43sz 10.memo0 sIW egamem Unw)', 453]8 A..Q714.0 9,408.6 Q616.9 47.61 SBE BAKER SEAL BORE EXTEN610N 3.250 8,6198 47.59 XO Reducing CROSSOVER 3.5 X2.875 2.875 9,7298 6,6304 47.54 NIPPLE OTIS27/B XN NIPPLE;2313"wre, 5° NO GO ID 2.250 8,746.0 6,6414 47.60 SOS DAKER SH AR OUT SU , I TL Lite ELM, Elms tag 30 ELM 2441 5/5/2006 sreapeaLman's'., ° skb (salla Mnmr); s,49aa Other In Hole (reline (W retrievable lu P s, valves, um fish, etc. 9 PUMPS, ) s5DB.4- Top Top ma gob (blmmtxmr)asza.a� 7..a4,4316 sac (saN4 u^al: r,2os.1- Top fnNB) (ane)KFU 3,3963 r) 51.38 Dea Liner Top Packer (ME) se/ mom Eeker 70"LTP Packer. 4"GS Rearrayidee Profile, DAL 11.42' Run case 8/8/2018 mond 2.360 a am.2� Seal Assembly cemm,n Pleg. 90®9nKa _ 546 (Splha llnx)', San, 4,460.0 34144 51.33 WHIPSTOCK 4-11Z'Northern Solutions lamer Wedge, Set 0 deg HS, wl two PIP tads. 711412019 -7O DD Rani 4,446.0 3,424.4 5133 -Lock Assembly etX-LockB Iowthm aseemblyfor WblpstoCk.37' OAL. 7/122019 0.000 PACNEN: pass 4,659.0 3,534.1 53.91 BRIDG PLUG- PERMANENT 42612019 INJECTION:9023 Perforations & Slots snot rap me8) Sunni Top INO) MIKE)dtKBd ell mingDons Linked Zone Dam le p Co. 4,320.0 44800 3,327.3 3,426.9 4127/2019 12.0 CMTSDZ 51l ° 2spf 9g TD BH 135deg phasing TCP U.S.-c:9e94.s reference log was SLB EMIT 22.19 4,932.8 5,4086 3,696.3 3,9597 lots PACKER; 9,]MO sNE', 9rd8 (Boned L mer) 5,498.3 6,508.4 4,019.8 4,589.7 St.% NIPPLE; AM (Slotted iner) sos: 5.74e.0 61596.0 7,621.8 4,641.4 5,2fi4.8 Blots (Slotted -9'954 Liner) 7708.1 =709.2 5,319.5 8 SItS O (Slotted Liner) .in. b. Loss B I, 8,797.7 9,811) 6,0125 8,685] UNIT D, 113-26 ots (smnea Liner) 8,88.0 9,902.0 6,736.5 6746.7 A -4,1R-26 WWI) 07 8.0 lots (SICUed 2 M'Power narjetHMX, 0deg. ph Liner) PRODUCnox: 41610201/ slar(sblmn tknd; 9,e88s 9,899.5 10,906.3 6,444.9 C -1,1R-26 1/4/1992 10.0 lots (SKUEd Liner) 45"Csg Gun, 80 tleg. ph m.eosa- _ KUP INJ WELLNAME 1R-26 CowcoPhillips Alaska, Inc. HANGER, GNS W6 LIFT', NIPPLE, SURFACE; 42 S6b .tom r SMa(6MW Uw), SA. S.�JAa� sld (Sb Uw) 77DOA- 8 709.2 SLC. C; PACKER; 6RE; 9ery WELLBORE Latch I PORSIae 1 R-26 Run Dab, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPL ION REPORT AND LOG 1a. Well Status: oil E] Gas❑ SPLUG ❑ Other ❑ Abandoned El V Suspended I] 20AAC 25105 20rac 25.110 GINJ ❑ WINJ j] WAGE] WDSPL ❑ No. of Completions: tb. Well Class: Development E] Exploratory E] Service [D Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 6. Date Comp Susp., Or Aband.: 2019 14. Permit to Drill Number / Sundry: 191-092/318-538 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 7/13/1991 15. API Number: 50-029-22193-00-00 4a. Location of Well (Governmental Section): Surface: 394' FNL, 137' FWL, Sec 20, T12N, R10E, UM Top of Productive Interval: 1347' FNL, 1217' FWL, Sec 21, T12N, R10E, UM Total Depth: 1411' FNL, 1696' FWL, Sec 21, T12N, R10E, UM 8. Date TD Reached: 7/21/1991 16. Well Name and Number: KRU 1R-26 9. Ref Elevations: KB:88 GL: 45 BF: 17. Field / Pool(s): Kuparuk River Field/W pa4ww Pool 10. Plug Back Depth MD/rVD: 4659/3534 18. Property Designation: ADL 25635, ADL 25636 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 539830 y- 5990810 Zone- 4 TPI: z- 546198 y- 5969694 Zone- 4 Total Depth: x- 546677 y- 5989833 Zone- 4 11. Total Depth MD/TVD: 1021516973 19. DNR Approval Number: 80-261 12. SSSV Depth MD/TVD: 179911733 1 20. Thickness of Permafrost MD/TVD: 1700/1646 5. Directional or Inclination Survey: Yes ❑ (attached) No E] Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) I 21. Re-drill/Lateral Top Window MD/TVD: 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 evaluat(ga, Ca,Sjitot I aio�ewDelry, and perforation record. Acronyms may be used. Attach a separate page if necessary R E (0.li E V CBL JUN 0 q 2019 AOGCC 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD I HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 43 123 43 123 24 231 sx ASI 9 518 36 J-55 43 5593 43 4072 121/4 1170 sx PFE, 530sx Class G 7 26 J-55 35 10201 35 3503 81/2 250sx Class G 41/2 11.6 L-80 4251 4606 3284 3503 Scab 12 bbls NT -5 24. Open to production or injection? Yes ❑ No El If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perld): /yj pp' CEMENTED 427 TVD.... 4/27/2019 Sys nv 4ko',, ATIONS: 4320-4480 MD and 3327-3 f (1921 SHOTS, 518" shot diameter) GO"Was re 15 VERIFIED 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/IVD) 4.5 4252 4251/3284 . ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes ❑ No R]s Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): SUSPENDED 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 i -L �O/� ��7ONTINUED ON PAGE 2 RBDMS */JUN 04 2019 -10it ORIGINAL only 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MDfrVD, From/To), and summarize lithology and presenceof 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 1700 1646 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 Q TPI - 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, productionpaleontoloaical report. or well test results, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Brian Buck Contact Name: Kyle Hampton Authorized Title: r.^,0F,. UtleArewr Supervisor Contact Email: k le.ham ton co .cem Authorized / Contact Phone: 263-4627 Signature: Date: _3Z°/'? INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 � KUP INJ WELLNAME 7R-26 WELLBORE 1R-26 ConocoP IIIIIpS I' - Well Attributes Max Angle & MO TD IF�e10 Name IW¢IIUOre APYUWI IWNIMee Status riot Pl MD'ttKBI A[IeM i11K81 AI98kA,INC. KIIPARIIN RIVER IIMIT GnNJO'J°l10'inn iui ce e o ast W0: 1R-3,symlae'aatzu4 Last Tag -- Va9[tls[IwnNcle[bYl AnnWNlon pepN laical End Date WNIp IastMW ey ............ ............ ......... _. Last Taff ELNE Inst 9918.0 &2&2014 1R-26 wsbll I Last Rev Reason aw'.3e Anemetion End D. WNIM,e lml Mod 8y evyw, "' ""...... aartm "" Rev Reason: WORKOVERSUSPEND )IA12014 1R-26 posbll Casing Strings Cries rpsedptron CONDUCTOR oo lm) oinl Top llueel 16 15.06 43.0 see Depro(Mel sen Depth (TVDo...aul(L.,enaae TOP Travel 123.0 123.0 62.58 H-40 WELDED Gsi,y Ou[eiplion SURFACE 00 Ban IO pn) Top M.) 9518 8.92 426 .1DepIn BIKE) Sn Depth (Ev D1... tell p_. Grade Top Threat 5,593.1 4,0]20 36.00 J-55 BTC cormucTOR, 43.D+z3o Casing pewrlption PRODUCTION Do (is) ID didTopnlKBl ] 628 M.2 SN Ceptn nlKB) S¢t DepIM1 pV01... WtlLen IL. Grade Top TM1read 10.2010 26.00 J-55 BTC -MOD caslna Description Scab L'mer oDlln) ID lml Top laMe) 4112 4.00 4,251.1 se Deem ryM81 seroevlx lTVDL.. WULen (L. "nae lop Tnreaa 4,606.1 3,503.1 11.60 L-80 TUI,vy-Mrave.ZpdsD Liner Details TOP (hKBI Top OVD)ions) Deeper E) IMm Des enm Numboup (in) 4,251.1 3,2&.5 51.80 FB -R TB -R 5250 nay - Manee. 4.maD 4,2877 3,3066 5169Nipple-% %Nipple 3s13"Sr5693R-2PTp101878159 3813 Nipple -x:4.1 6,430.5 3,396.0 51.38 an em Wedge Wedge ass'y@4434'DKB 3958 S,a Anwn5N:4.1012 Cemb,Ma.. ' 4.315 4,449.5 340]9 51. Nippla -X Nipple-% 3813 Mart 44566 3,612.3 51.IT an em Wedge stay@ 4460' OKs 3,958 Wedge 44756 3,4242 51.32 Nipple -X Nipple -X 3.813 Tubing Strings Tubing Description Tubing 4.5" shrimpMa... ID lin) Tap(.B) tel 4.926 '3 399 4,251.8 Depth miser Depen Me) I-071 dead G- Tap Conneclwn 3,2650 12]5 110 HYD 503 nemata Dere Careen: Completion Details 4,3m0nm CMT5p2; 4,.camna D.a- Top1flKB) )Intel(TvTO f,n[I bre On Com NMln)t 1 39.9 39.9 0.88 Hanger Hanger FMC Gen IV 11" x 41/2" 1475563 plus 4 63 pup 3.958 4,2M7 3,273. 51.54 Nipple-% %Nipple 3813"HVD 563 3.813 4,2493 3,28.41 51.19 latest Assembly Tieback locator 3.986 Tubing Desedplgn TUBING 35"x2.8]5" sWnp Ma... ID gal Tap pMBl 8¢I 41/2 2.99 9,569.5 9]466 DepN la. Sel Cepa RVp)L..Wlpren Gentle Top ConnMium 6841.9 9.30 L40 ABM -BTC Completion Derails Top(TVDI Top(hee) grand Topin[I I°) Item nee Nominal core to pal 9,569.5 6,523.0 46.06 PACKER BAKER HB RETRIEVABLE PACKER 2.890 9,6272 6,551.5 48.20 BIASTRINGS CARBIDE BLAST RINGS (2) 2,992 $694.5 ,607.] 47,66 SLEEVE -C CA 1 SLIDING SLEEVE WN OID;SHI LEEVE ace rear'. 4.ze 14,6w.t (OPENED 5/61 m.heMW-Pu, C deo 9,]08.0 ,6144 4].83 PACKER BAKER D PERMANENT PACKER 3250 9,]09.8 ,616.9 4].61 BE BAKER SEAL BORE EXTENSION 3.250 9.7140 198 47.59 TOReducing CROSSOVER 36 x 2.875 2875 9.729.8 6304 4254 NIPPLE 0TI W8 XN NIPPLE; 2.313"core,225"NO ID 2250 SURFACE', 426a,59J.1- 9.]460 6,6414 4].60 SOS B 51512006 AR OUT SUB, TTL ,Eline 'ELMlag LM 44 21 Cwrtnleks %de.." De„enlpyy;gptppMlg Other In Rule(Wirelins retrievable plugs, valves, pumps, fish, etc.) TOP (rv.) Top Intel Tap pfKB) (hKB fl Des Covea.. Dx rude) 39.9 39.9 0.88 BEV 5/412019 PAc'fERla3a.4 4,6596 3,534.1 53.91 silage Plug- 4l2&2019 Permanent Perforations & Slots INJECTIDN:8813J She, Tep Iran) Bbn DVD) Dens IsMbm ToPMKB) Blustio) 1M�B) (hKB) Llnhatz ne Da@ I Type Com 4,320.0 4,480.01 3.32].3 3,4269 "2712019 120 CMT SO2 5 sD BR %BH 135deg phasing TCP (PERF 9.830.08,l I 1 reference In was SLB EMIT2.2.19 9,639.0 9,672.0 6.!i6g 41 6, 1.5 C -1,1R-28 1/"1992 10.0 (PERF 45" r., Gun, 60 Eeg, ph SLE. -C e..5 ,88/0 9,902.0 I 6]365 1 8,]46.] b4. 1R-28 211&2007 60 RPERF 1/8" ower ndetHM%, 0 tleg. ph 9.160 9,941.0 1 67562 6,]]3.2 A-3, 1R -a 1/4/1992 40 (PERF 4.5" Csg Gun .180 tleg. ph pacced;%sik0 Cement Squeezes SBE.IrDart Top IND) She RVo) T.Chals, Bter Me) mall Ml Des Sart Data Com ,0189 9,050.0 61572 6,n].7 Cement Plug 6/25/2014 Pumped 50' bs ore depth of 90 o cement on NIPPLE;a.nae top of Cement retainer. Squeeze 55 Me of cement below retainer. sos:a.T4¢o 9,05.0 9.6989 QiM Q669.6 Cement Plug 720614 Squreaze 55 DNA of cement below Trainer. 4,UOT 7480.0 3,327. 3,426.9 Rem Ia 412&2019 Arprer swabcutpeawasncementmd use b Cement Squeeze squees ubasNlay in 33bbl 15.Bppg Camenl 4,251.0 4606.0 3,284.5 35030 emente ab Liner K0 19 Pump 10 bbl mud push ppg. Chase veth 12 bbis 15A Mg NTS cement slurry holding 500 psi back pressure an choke manifold. Bump plug and set UP at 4237. Release from packer and and circulate mud RPERF:5,37Debal push and 3 hilt of Cement DW of the hole. CUP at 11:38. Iptsu, 9,ala09.Ard Mandrel Inserts sl ati on N Top calTOauke, (a"8) Make Medor O am Sery Valve--a Type Typ Pertsne fins TRO Run (pati Run Oale Com 1 2,998.0 2,5116.8 Carew KBMG MY RK && 019 PRODJCp0N.3.2-IOdN 0 ConocI3 hillips KUP INJ Alaska, Inc. WELLNAME 1R-26 WELLBORE 7R-26 ,R- EACCC 99a;IZAM Mandrel Inserts VerpJ VAeveeelvcOM 8t ad ._._...... ...........__... _.. aw.39.9 on N TOPMKB) TOP TTSD RMB! Make MetlN OO1in) Sm Valve Type LqG Type Potlbm pnl TRO Run Wil Run Dale Com 21 4,205,0 3,255.5 CamcB KBMG SOV 5132019 Ilea ._...._........... N.�9...9P.9 SOV I Notes: General 8 Safety Ene Ba@ AnnOtallon 102012010 NOTE: View SChemalic wl Alaska Scnemafic9n ]1142014 NOTE: GLV STU K; WAS UNABLE TO RETRIEVE DURING 2014 RWO OCNOucioR; 43.o -1a0 7/172014 NOTE: PISH',COMPRISED OF TUBING/GLMINIPPlESEAL LOCATOR Tldlq-uvMel, 2—.a lu-R—JN,4,0 M NigYv-X',1232.] sul AawmMy, a,za9z cememaa `-' INx, i,zsTB RaniMM Cemm iOy ,aX LMT502; 4,9A.DdJ8IIO,4�,0� 9m lis. 4.MI. toSOS Bret' Plw-v.n48590 S a SURFACE: 42ASM 1� Cvmvm Plw; SAtae. Pimm Plw; 9.�Oftl(9 PACRER9..4 INJECTION: 9..6123 IPERF', 9,W909.BTLO— I SLEEVEL;e.m0.5 PACNEq; 91!8.0 SBE', B.1I8.a NIPPM9,ma SOS', 9148.0 RPERF: 9aSI.O9B32.0� !PERF; 99IB.O9,.10� PRCOUCTION. 152-10,M 0 Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Start Time End Time our (hr) Phase OP Code Activity code rime P-T-X End Depth (flKB) 4/23/2019 4/24/2019 7.50 DEMOB MOVE RURD P Disconnect pit module, move out of 16:30 00:00 way. Pull off well w/ substructure, stage same, set rig mats and herculite. Hange new tree in cellar, stage well head equip. Pull sub over 1 R-26. 4/24/2019 4/2412019 1.50 MIRU MOVE MOB P Position dg over well set rig down. 00:00 01:30 4/24/2019 4/24/2019 2.00 MIRU WHDBOP NUND P NU IA valve, RU to test BPV. 01:30 03:30 **Accept rig at 01:30** 4/24/2019 4/24/2019 1.00 MIRU WHDBOP PRTS P Pressure test BPV with test pump and 03:30 04:30 diesel via IA to 1000psi for 10min. Good test. Observe well for 10min. 4/24/2019 4/24/2019 7.50 MIRU WHDBOP NUND P N/D Tree. NIU BOP and Service Rig 04:30 12:00 4/24/2019 4/24/2019 8.00 MIRU MOVE OTHR X Continue load pipe shed with 3 1/2" 12:00 20:00 HT 38 Drill pipe and strap and tally D.P Prepare to spot pits when 1 R-04 pre rig work is complete. Slick line unit finish up with AOGCC and cut Tubing on 1 R-04 R/D and move, then valve crew to set BPV. 4/24/2019 4/25/2019 4.00 MIRU MOVE RURD P Spot pits, cuttings tanks, berm up. 20:00 00:00 Take on fresh water. 4/25/2019 4/25/2019 2.00 MIRU WHDBOP PRTS P Take on fresh water. Prepare to test 00:00 02:00 ROPE. 4/25/2019 4/25/2019 6.50 MIRU WHDBOP PRTS P Test BOPE. Found blind ram door 02:00 06:30 seal leaking, replace door seal. Test BOPE 250psi/3000psi on 3 1/2" and 4 1/2" test joints. Annular 25012500. 4/25/2019 4/25/2019 3.50 MIRU WHDBOP SEQP P R/D test Equipment and pull FMC 08:30 12:00 BPV, Monitor well 15 mins, All good. R/U 3 1/2 EUE landing joint and Make up to hanger BOLDS Pull hanger to floor and I/d same PUW 47K 4/25/2019 4/25/2019 8.00 MIRU WELCTL PULD P M/U-3 1/2 EUE XO 3 1/2" HT38 and 12:00 20:00 Single in hole w/ 3-1/2" HT 38 D.P, F/ 2224'T/ 9000' and Take diesel returns to cutting box. PUW 150k, SOW 95k. 4/25/2019 4/25/2019 2.50 MIRU WELCTL CIRC P Establish circulation, pump 30bbl high 20:00 22:30 vis pill. Diplace diesel, swap well over to 9.0ppg brine down tubing taking returns to tiger tank. 650psi initial circ press, 2350psi final 7bpm; pumped total of 450bbl, until 9.0 dean fluid in returns. Haul diesel to hydrocarbon recovery. OA pressure built to 1100psi, bled to bleed trailer gas and fluild down to 150ps1. 4/25/2019 4/25/2019 0.50 MIRU WELCTL OWFF P Shut down pumps, observe well 22:30 23:00 30min, no flow. 4/25/2019 4/26/2019 1.00 MIRU WELCTL PULL P POOH LD OP. 23:00 00:00 4/2612019 4/26/2019 6.00 COMPZN RPCOMP PULL P POOH standing back OP, LD 3 1/2" 00:00 06:00 EUE kill string, 72jts 4/26/2019 4/26/2019 2.00 COMPZN WELLPR OTHR P Clean up Rig Floor and service Rig. 06:00 08:00 Install W.R bushing. UD running tool Page 116 Report Printed: 51612019 Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Siad DepM Stmt Time Ed Time our (hr) Phase Op Cade vdy A ' code Time PJA Operetlon (ft End DepVi (RKB) 4/26/2019 4/26/2019 3.00 PRODt WELLPR WAIT T Wait on E-line Stuck behind broke 08:00 11:00 down rig Camp on BP side. 4/26/2019 4/27/2019 13.00 PROD1 WELLPR ELOG P Hold PJSM w/ Pollard E-line and R/U 11:00 00:00 E-line line and RIH w/ CBL-CCL and Log F4600' Usurface. POOH to clean magnet on tool, problem with tool, 4 runs total. LD GR/CCL CBL tool. PU Weatherfor Big Boy CIBP, RIH, tie in GR/CCL to Sib EMIT log dated 2/2/19, set CIBP at 4660' wlm mid element in mid joint. POOH with set tool. 4/27/2019 4/27/2019 2.50 PRODt WELLPR ELOG P RIH w CIBP, set at 4510' wlm mid 00:00 02:30 element. (4509'top of ClBPwlm). POOH. RDMO Pollard eline. 4/27/2019 4/27/2019 1.50 PROD? WELLPR PULD P PU 160ft Halliburton 5-1/8" 12spf 19g 02:30 04:00 RDX BH 135deg phasing TCP perf guns. Check OA, 80psi, bled to bleed trailer, Opal. 4/27/2019 4/27/2019 3.50 PRODt WELLPR TRIP P RIH with guns w/ 3 1/2" HT 38 Work 04:00 07:30 1 1 1 string and Tag up' w/ DPM @ 4494' 4/27/2019 4/27/2019 2.50 PROD1 WELLPR PERF P P/U 29' and Pump down Work string 07:30 10:00 All good Drop Ball and position Guns @ 4320- 4480WIm (4464' RKB) PJSM w/ crew and Pres up to1880 PSI, fire off, Monitor well and CBU @ 3 BBLs min w/ 240 psi Allgood 4/27/2019 4/27/2019 2.50 PROD1 WELLPR TRIP P POOH / Stand Back work string 10:00 12:30 4/27/2019 4/27/2019 2.00 PROD1 WELLPR BHAH P UD Halliburton pert guns and tools. 12:30 14:30 1 1 All shots fired. Cleanup Floor 4/27/2019 4/27/2019 4.50 PROD1 WELLPR SHAH P M/U BHA# 2 W/ Baker 7" casing 14:30 19:00 Scraper RIH on work string, wash last stand to bottom, tag at 4494' RKB. 4/27/2019 4/27/2019 1.00 PROD1 WELLPR CIRC P Circulate two bottoms up, 10bpm, 19:00 20:00 1900psi; no cuttings in returns. 4/27/2019 4/27/2019 3.00 PROD1 WELLPR TRIP P Monitor well, static. Drop 2" rabbit. 20:00 23:00 POOH standing back. Retrieve rabbit on last stand. LD casing scraper. 4/27/2019 4/28/2019 1.00 PROD1 WELLPR TRIP P Prejob safety meeting. PU Archer 23:00 00:00 1 wash tool, RIH on stands. 4/28/2019 4/28/2019 3.50 PROD1 WELLPR TRIP P RIH with Archer tool to 4494'. Filling 00:00 03:30 every 15 stands. 4/28/2019 4/28/2019 4.00 PROD1 WELLPR CIRC P Test tool 1000psi, PU wt 90K, SO 72K, 03:30 07:30 rot 85K, 2800ftibs at 40rpm. Establish circulation parameters: 2bpm 70psi 4bpm 330psi 6bpm 680psi 8bpm 1160psi 9bpm 1450psi 10bpm 1700pSi Pump and wash down through perfs at 9bpm, 1 foot per min. Page 216 Report Printed: 51612019 Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Depth StartTime End Tme Dur (hr) Phase Op Code Activity Code Time P -T -x Operation (ftKB) End Depth tflKB) 4/28/2019 4/28/2019 5.00 PROD1 WELLPR CMNT P Hold PJSM With All crews R/U SLB 0730 12.30 Cement crew and Mix 57 BBIs spacer 12.5 Ib and PT lines U 4000 PSI All good pump spacer cross perf and RIH and pump15.8 lb cement POOH slow and spot 34 bbls cement in and cross pert POOH and 800' and leave 5 bbls cement on top of perf CIP @ 12:30PM 4/28/2019 4/28/2019 2.00 PROD1 WELLPR CIRC P CBU @ high rate Recover 45 bbls 12:30 14:30 spacer and Clean up hole No cement notice @ surface R/D Clean up foor 4/28/2019 4/28/2019 3.00 PROD1 WELLPR TRIP P POOH w/31/2"work-string. LD 14:30 17:30 Archer tool, found bits of metal stuck in top swab cup, otherwise in good shape. 4/28/2019 4/29/2019 6.50 PROD1 WELLPR WOC P WOC 24hrs. Slip and cut. Servicerig. 17:30 00:00 Inspect drawworks, checkladjust brake inspect brake bands. 4/29/2019 4/29/2019 13.00 PRODi CEMENT WOC P WOC. 00:00 13:00 Clean and organize dg. Clean suction and discharge screen on both pumps. Grease choke manifold. Service wash pipe, service pipe skate. 4/29/2019 4/29/2019 1.50 PROD1 CEMENT BHAH P M/U BHA w/ 6 1/8" Rock bit w/2- Boot 13:00 1430 basket string mill, 4 3/4" Oil jar, 6-4 3/4' D.0 1 XO 3 1/2" HT 38 Drill pipe 4/29/2019 4/29/2019 5.00 PROD1 CEMENT TRIP P RIH U 3900' and C&C @ 21bpm w/ 14:30 19.30 250psi, 2x bottoms up, see mud push and cement accross shakers. Wash down f/ 3898' 2bpm. Screen down two shakers to handle flow. Wait on compressive strength f/ 1000 psi on cement 4/29/2019 4/30/2019 4.50 PROD1 CEMENT DRLG P Wash down circ 21bpm tag 15-20k at 19:30 00:00 4004' firm. Drill out firm cement 60rpm 3500ft Ib, 5.5bpm 700psi to 4341'. Getting cement accross shakers. 4/30/2019 4/30/2019 3.50 PROD1 CEMENT DRLG P Continue to wash down through 00:00 03:30 cement 60rpm 3300ftib, 5.5bpm 700psi. Tag CIBP w/2K, PU and pump 15bbl hi vis sweep. CIRC, work pipe up and down, 80rpm, 3500111b, 5.5bpm 700psi until clean. 4/30/2019 4/30/2019 0.50 PROD1 CEMENT PRTS P Close pipe rams, pressure up on 03:30 04:00 wellbore to 930psi. (2.31bbl) Leaking LDS (the one that had been replaced). Bleed off pressure 4/30/2019 4/30/2019 1.50 PRODt CEMENT CIRC T Circ & condition awaiting FMC 04:00 05:30 personnel.Repair LDS on Well head 4/30/2019 4/30/2019 4.50 PROD1 CEMENT PRTS P Test Casing T/ 930 PSI Bleed Down 05:30 10:00 175 PSI in 30 mins OA Build up 400 PSI t 525 PSI Repeat test Test T/ 930 PSI OA 425 PSI Build up U 450 psi in 15 Mins Tubing pres lost 120 psi in 15 mind OA holding solid. Page 316 Report Printed: 5/8/2019 AM, Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Depth Sten Time End Time Wr(hr) Phase Op code Ac&iy Code Time P-T-X OpemUon (flKe) End Depth(0Ka) 4/30/2019 4/30/2079 3.00 PROD1 CEMENT DRLG P RIH and tag CIBP @ 4494 and Drill up 10:00 1300 CIBP @ 5 BBLS min w/ 685 WOB 4- 6K and Push CIBP to 4642 on top of CIBP @ 4644 D.P.M. CBU @ 5 bbls min w/ 650 psi 4/30/2019 4/30/2019 4.00 PROD1 CEMENT TRIP P POOH and L/D BHA 13:00 17:00 4/30/2019 4/30/2019 1.50 PRODt CEMENT PRTS P Pressure test 7" casing and CIBP to 17:00 18:30 1 930 psi. Charted for 10 minutes. 4/30/2019 5/1/2019 5.50 PROD1 CEMENT ELOG P RU E-line and RIH. Perform CBL 18:30 00:00 across cemented perforations from 4465'to 4305'. RD E-line. 5/1/2019 5/1/2019 4.00 PRODII CEMENT PRTS X MU, RIH with test packer. Stop at 00:00 04:00 1000' and presuurs test to 930 psi.All goosd. 5/1/2019 5/1/2019 1.00 PROD1 RIGMNT RGRP XT Service Top Drive break out foot 04:00 05:00 Noitioe the cylinder is not working properly on the break out side 5/1/2019 5/1/2019 1.50 PROD1 EVALWB TRIP X Continue RIH U 4500' 05:00 06:30 5/1/2019 5/1/2019 10.00 PROW EVALWB PRTS X Set Baker PKR @ 4500' and test 7" 06:30 16:30 rasing 1000PSI pumping down D.P 10 mins No Loss and Pump down back side U 930PSI lost 200 psi 10 mins Release PKR POOH T/ 4200' and Set PKR and Test casing T/ 1000 psi 10 mins No loss Release PKR RIH T/ 4434' set pkr and test t/ 1000psi u-tubing Through Prref Back up D.P. / Pull Up hole 32' Retest same POOH tt 4410' retest same /POOH U 4386' retest same' POOH t/ 4418' retest same ,POOH t/ 4386' retest same results, Call Town discuss options All Testing OA stay @ 300 PSI 350 PSI 5/1/2019 5/1/2019 4.50 PROD1 EVALWB TRIP X TOOH with test packer from 4331'to 16:30 21:00 surface. LD BHA and clear rig floor. 5/1/2019 5/1/2019 1.00 PROD1 CASING SHAH P RU Weatherford casing running 21:00 22:00 equipment. 5/1/2019 5/2/2019 2.00 PROD1 CASING BHAH P MU 4-1/2" scab liner with two 22:00 00:00 whipstock wedges and liner top packer. 5/2/2019 5/2/2019 5.00 PROD1 CASING TRIP P Run liner in hole on stands of DP and 00:00 05:00 tag CIBP at 4642'. PU 52'to get liner Ion depth. 5/2/2019 5/2/2019 4.50 PROD1 CEMENT CIRC P RU cement head. Circulate a bottoms 05:00 09:30 up.and space out CBU @ 3 BBLs w/ 380 psi and adjust choke for cement jobHold PJSM w/ crews Page 416 Report Printed: 5/6/2019 Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Imre End Time our h ( r) Phase OP Code Actively Cove Time P -T-% Operetlan Sian Depth (fixe) End Oepm (flKe) 5/2/2019 5/2/2019 3.50 PROW CEMENT CMNT P Pump 3 bbl Fresh water Ahead and 09:30 13:00 test line U 4800 psi All good Mix 10 bbls viscous spacer 12.5 ppg and pump and chase wl 12 bbls NT -5 Cement Sluurry, hold back pres on back side 450-550 psi on choke Manifold All good bump plug and set top of 4 1/2" scab liner @ 4237' PUW104K SOW70K TestPKR 4800 PSI All good Slick off and set 20K on PKR P/U 20K over Allgood check floats 1 bbl Back release PKR Rot 15 Turns to right P/U Pull out slow w/ 500 PSI on D.P string and Circ at high rate and recover 10 bbls Mud push 3 BBIs cement All good CIP @ 11:30 AM 5/2/2019 5/2/2019 1.00 PROD1 CASING CIRC P Continue Circ @ 5 bbls min w/ 400 13:00 14:00 PSI and Finish loading pipe shud w/ 4 1/2" upper completion ,strip same UD Cement Head and R/U T/ UD 3 1/2" work- string 5/2/2019 5/2/2019 5.00 PROD1 RPCOMP PULD P POOH lay down 3 1/2" HT -38 D.P 14:00 19:00 5/2/2019 5/2/2019 1.00 PROD1 CEMENT RURD P Remove wear bushing. Rig down 19:00 20:00 cement head and lay down. 5/2/2019 512/2019 1.00 COMPZN RPCOMP RURD P RU to run 4.5" HYD 563/503 tubing. 20:00 21:00 512/2019 5/2/2019 1.50 COMPZN RPCOMP WAIT T Waitig on TIW Valve (3.5" HT38) xo 21:00 22:30 Tubing (4.5" HYD 563). OD of crossover on location was loo large to strip to bottom incase of a well control event. 5/2/2019 5/2/2019 0.50 COMPZN RPCOMP SVRG P Service the top drive and blocks. 22:30 23:00 5/212019 5/3/2019 1.00 COMPZN RPCOMP SFTY P Pre job safety meeting to run tubing. 23:00 00:00 5/3/2019 5/312019 8.50 COMPZN RPCOMP RCST P Running completion string in hole to 00:00 08:30 1 4238'. 5/3/2019 5/3/2019 3.50 COMPZN RPCOMP CIRC P Tag up TOL @ 4238' seals no go P/U 08:30 12:00 10' and pull seal space out w/ pups Tot joint run 135+2 Pups,M/U FMC Tubing Hanger, RID to displace well T/ 8.6 clean w/ Cl seawater 3 bbls w/ 120 PSI All good land Tubing Hanger RILDS 5/3/2019 5/3/2019 2.00 COMPZN RPCOMP THGR P Pump Down tubing t/ 3000PSI f/ 10 12:00 14:00 mins All good Bleed off to 2000PSI , pressure up on backside 4 1/2" X 7" casing to 3000 PSI 30 mins All good Bleeddown Tubing to 0 and shear the SOV @ 1600 PSI, Bleed off All pres to 0 and check Circ Both ways all good 5/312019 5/32019 2.00 COMPZN WHDBOP NUND P RID landing joint and set FMC BPV 14:00 16:00 and test f/ below 1000PSI All good Bleed down to 0 N/D BOP N/U FMC Tubing Spool adapter and tree. Clean pits and cutttings box. ND BOP and place on stump. 5-3/2019 5/3/2019 5.00 COMPZN WHDBOP NUND P NU tree adapter and tree. Test to 250 16:00 21:00 psi, 5000 psi. Pull BPV and set test pug. 5/3/2019 5/3/2019 2.00 COMPZN WHDBOP FRZP P RU LR and pump 80 bbls diesel FP 21:00 23:00 and let U-tube. Page 5/6 Report Printed: 516/2019 Operations Summary (with Timelog Depths) 1 R-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stars Time End Time Dur(hn Phase Op Code Activity Code Time P-T-X Operation Stan Depth (flKa) End Depth(111) 5/3/2019 5/4/2019 1.00 COMPZN WHDBOP NUND P Set BPV, secure tree and rig release 23:00 00:00 I at Midnight. Page 616 Report Printed: 5/6/2019 Sensor Offset ft l=9�C Description ft O.D. in eight 0b N > -Length ,_CHD-STNDRD 1.05 1.44 2.03 CZ 1 7/16" GO CABLEHEAD r m=f c m =1m;0 m 3 x M 0-1 1.67 3.13 W OC M0 Company CONOCOPHILIPS -ani o 4w_° Well 1R-26 g o m z a C43o3os3 o. o rn w 1 m e n w n N S o ' �" Field KUPARUK c 3 w 3 a o on County NORTH SLOPE , g m o c w 9 2 State ALASKA CountryLISA W W '0 3 w Q b1 0 0 V N n ?C w w ffiN L # 33 n a m 0 N 3 3 S O C '� O w DKO�m z� W 4 2'DO= w o ns o ;a -a D IV= M O KmpNo O --56 °° N O�=N $D�m7 D C 0 N Co W y T O Cl) LA RD z m r x y O T n ."t1 M r o W ;a m 0 _ 0 oSP s m OO G v ..� ? w W C o oy nW aR a > �z m O0 4 ao 0 3 o W m 0 0 3 00 «< Fold Here >>> All Interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any Interpretation, and we shall not, except In the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages, or expenses incurred or sustained by anyone resulting from any Interpretation made by any of our officers, agents or employees. These Interpretations are also subject to our general terms and conditions set out in our current Price Schedule. - Comments SECTOR RADIAL BOND LOG LOGGED 71N 26#AFTER ATTMEPTED CEMENT SQUEEZE 4600' TO SURFACE CORRELATED TO SLB EMIT/GR/CCL 02 -FEB -2019 Sensor Offset ft Schematic Description ft O.D. in eight 0b -Length ,_CHD-STNDRD 1.05 1.44 2.03 1 7/16" GO CABLEHEAD CCL-Loaaina (LoaCCL) 1.67 3.13 5.00 Calibration Report Database File 1r-26cb12.db Dataset Pathname cbll/pass7.4.3 Dataset Creation Tue Apr 30 22:30:312019 3.125in CBL Logging CCL CCL 21.89 CENT-TITAN1687 (middle) 2.92 3.25 18.74 ROLLER CENTRALIZER TEMP 16.22 WVFS8 14.93 WVFS7 14.93 TEKSCBL-TEKSCBLTEMP (POL325) 9.13 2.75 102.00 WVFS6 14.93 TEKCO SECTOR BOND TOOL WITH TEMP WVFS5 14.93 WVFS4 14.93 WVFS3 14.93 WVFS2 14.93 WVFS1 14.93 WVF3FT 14.18 VWF5FT 13.18 WVFSYNC 9.84 WVFTEMP 9.84 WVFCAL 9.84 CENT-TITAN1687 (middle) 2.92 3.25 18.74 ROLLER CENTRALIZER GR-TITAN275 (1) 4.01 2.75 77.00 GR 4.34 Titan 2 3/4 Scintillation Gamma Ray CENT-TITAN1687 (bottom) 2.92 3.25 18.74 ROLLER CENTRALIZER LENTEN 0.00 Dataset: 1r-26 cbl2.db: field/well/cbll/pass7.4.3 Total length: 24.60 it Total weight: 24225 Ib O.D.: 3.25 in Calibration Report Database File 1r-26cb12.db Dataset Pathname cbll/pass7.4.3 Dataset Creation Tue Apr 30 22:30:312019 Gamma Ray Calibration Report Serial Number: 1 Tool Model: TITAN275 Performed: (Not Performed) Calibrator Value: 1.0 GAPI Background Reading: 0.0 cps Calibrator Reading: 1.0 cps Sensitivity: 1.0000 GAPI/cps Segmented Cement Bond Log Calibration Report Serial Number: POL325 Tool Model: TEKSCBLTEMP Calibration Casing Diameter: 7.000 in Calibration Depth: 1073226 ft Master Calibration, performed (Derived): Raw (v) Calibrated (mv) Results Zero Cal Zero Cal Gain Offset 3' 0.117 1.888 1.800 62.165 34.092 -2.188 CAL -0.004 0.466 5' 0.136 1.736 1.800 62.165 37.722 -3.336 SUM S1 0.239 1.386 0.000 100.000 87.230 -20.867 S2 0.197 1.156 0.000 100.000 104.183 -20.474 S3 0.106 0.519 0.000 100.000 242.018 -25.709 S4 0.101 0.231 0.000 100.000 770.676 -77.769 S5 0.160 0.505 0.000 100.000 289.151 46.165 S6 0255 1.202 0.000 100.000 105.556 -26.908 S7 0.271 1.401 0.000 100.000 88.518 -24.008 S8 0.267 1.489 0.000 100.000 81.896 -21.906 Internal Reference Calibration, performed (Not Performed): Raw (v) Calibrated (v) Results Zero Cal Zero Cal Gain Offset CAL 0.000 0.000 -0.004 0.466 1.000 0.000 Air Zero Calibration, performed Thu Mar 08 23:36:44 2018: Raw (v) Calibrated (v) Results Zero Zero Offset 3' 0.000 0.000 0.000 5 0.000 0.000 0.000 SUM S1 0.000 0.000 0.000 S2 0.000 0.000 0.000 S3 0.000 0.000 0.000 S4 0.000 0.000 0-000 S5 0.000 0.000 0.000 S6 0.000 0.000 0.000 S7 0.000 0.000 0.000 S8 0.000 0.000 0.000 Temperature Calibration Report Serial Number: POL325 Tool Model: TEKSCBLTEMP Performed: Fri Sep 02 09:46:15 2011 Reference Reading Low Reference: 0.00 degF 0.00 usec High Reference: 1.00 degF 1.00 usec Gain: 0.33 Offset: 0.00 Delta Spacing 1 CCL 1r-26 cbl2.db . X —tRAD TAMP Dataset Pathname 255 T T (usec) •----------- 155 -27 CCL 3 0 GR (GAPI) 100 CCL 1r-26 cbl2.db . X —tRAD TAMP Dataset Pathname cbI1/pass7.4.3 Presentation Format 1050 Dataset Creation Tue Apr 30 22:30:312019 i Charted by Depth in Feet scaled 1:240 400 T T (usec) 200 — 1 -4-4 - VDL 1200 1 VAD 8 1 3' AMP X 5 -2 3' AMP (mV) 100 0 RAD AVG 300 � 200 3' AMP X 5 -2 (mV) 200 0 RAD MAX 300 e RAD MIN 300 VDL 12001 VAD 8 PPT (uses) 1200 MAIN PASS Database File 1r-26 cbl2.db Dataset Pathname cbI1/pass7.4.3 Presentation Format cdnrad Dataset Creation Tue Apr 30 22:30:312019 Charted by Depth in Feet scaled 1:240 400 T T (usec) 200 -2 3' AMP (mV) 100 0 RAD AVG 300 200 VDL 1200 1 VAD 8 -27 CCL 3 3' AMP X 5 0 RAD MAX 300 200 PPT (usec) 1200 0 GR (GAPI) 100 -2 (mV) 200 ------------------- RAD MIN 300 - 950 -- - ILII TT - -- GR'1 - - - PPT CCL _.. RAD MIN - RAID MAX I - RAD AVG _ t -3' AMP r i 1000 IV Ll MIN 2700 ��Zt a L� mm t f 3250 "Vol m �m ME MON 4550 VDL 12001 VAD 8 PPT (usec) 1200 REPEAT PASS Database File lr-26cbl2.db Dataset Pathname cbll/pass6 00 T T (usec) 200 >7 CCL 3 cdnrad -2 3' AMP (mV) 100 0 RAD AVG 30 3'AMP X 5 -2 (mV) 2010 0 RAD MAX 30 GR (GAPI) 100 RAD MIN" 30 VDL 12001 VAD 8 PPT (usec) 1200 REPEAT PASS Database File lr-26cbl2.db Dataset Pathname cbll/pass6 Presentation Format cdnrad Dataset Creation Tue Apr 30 20:13'21 2019 Charted by Depth in Feet scaled 1240 255 T T (usec) 155 2 3! AMP (mV) 100 0 RAD AVG 300 200 VDL 1200 1 VAD 8 -27 CCL 3 3' AMP X 5 0 RAD MAX 300 200 PPT (usec) 1200 0 GR (GAPI) 100 -2 (mV) 2010 RAD MIN 300 I CCLLMP- - •�—aeRAD MINS it�i �t�fit [464 4400 RAD MAX RAD AVG 3'AMPX5- } 1A, Company CONOCOPHILIPS Well I R•26 1 VAD 8 Id b LE �` M }anti:/-•}4�.: i�� NOM�® �® vY b•`f N•• .u�i 1♦ �. .. i < will M• �MOM ww-BF -go MOM 00-0E f i Mv .11 OPM / 1001 •. • 11 11 -27 CCL 3 /MET 11 11 _ 1 11 1 / • � 11 - Company CONOCOPHILIPS Well I R•26 1 VAD 8 Field KUPARUK County NORTH SLOPE State ALASKA Country USA Sensor ,a;3C �'o Schematic Description Length ft 0. D. in eight Ib CHD-STNDRD 1.05 1.44 2.03 moa ti�m3g-�O�°°��A� CCL-Loaaina (LOGGSCINT) 1.67 3.13 5.00 Company CONOCOPHILIPS �q� 2 ao 3r �m vA,n vac �ru o3 r_r 0� V>4:11 1R-26 Zo paa<s Nmmm 65 Field KUPARUK n 3 3 Dm a County NORTH SLOPE , v ,v<n l3 o a 2 State ALASKA Country USA m �� 'v' v _ , ro -DS M r < O11< O 0 N rp O CD 7 O_ 70 m -n Go G a a 44 0 3 OC� 0 D20p� z _ W y 0 W ;ary Z (n D M O 'dm0tTO r_ Ou_ N 00 OD NZ RIA C� N i m O m W Z r T O 2 co N Oo D Z m r W A -n G) W m o N C O O �E m rrl ro /-� ^' n N w C) W 2z o b 0 r m 3 CO n D mm cox N �TD7 m v o cm° y C m <<< Fold Here >>> All interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretation, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages, or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions set out in our current Price Schedule. Comments SECTOR RADIAL BOND LOG WITH GAMMA RAY AND CCL LOG CORRELATED TO SLB GR/CCL/EMIT LOG 02 FEB 2019 Sensor Offset ft Schematic Description Length ft 0. D. in eight Ib CHD-STNDRD 1.05 1.44 2.03 1 7/16' GO CABLEHEAD CCL-Loaaina (LOGGSCINT) 1.67 3.13 5.00 CCL TEMP WVFS8 WVFS7 WVFS6 WVFS5 WVFS4 WVFS3 WVFS2 WVFS1 WVF3FT WVF5Ff WVFSYNC WVFTEMP WVFCAL �ffl 21.86 16.39 15.09 15.09 15.09 15.09 15.09 15.09 15.09 15.09 14.34 13.34 10.01 10.01 10.01 4.42 1 CBL Logging CCL —CENT -TITAN 1687 (middle) \_TEKSCBL-275TEKCO (POL275) TEKCO SECTOR BOND TOOL WITH TEMP CENT-SDSCENT Centralizer for testing GR-TITAN275 (1) Titan 2 3/4 Seimtion Gamma Ray CENT-SDSCENT Centralizer for testing Dataset: 1r-26 cbl 26apr19.db: field/welUrun3/pass4 Total length: 24.58 It TM.1 w.mhf 9AA 77 1k 2.73 9.13 1 tt 1 4.01 1 rf 2.75 M-#hM 325 1 2.75 1 M3'7.M1 18.74 102.00 20.00 1 77.00 1 I PSKA �_�� P'�F ey v �Rv�G�� 1250 rm 1350 +nrn I 2000 (A - � rt 2050 tHT !- m-7 T T -- GJR f CCL RAD MIN RAD RAD AVG !� 2100 i -- --- k Wil 230 TOC RZE �Zamil ?M I ,)Rrn Alb i v 2800j' I i Got 2850 r zt t "IIt Rs1 e�1A ( MO 3050 3 1 Fes. 3150 3250 D E11 r i f yyj } r 5 e� r 44 1 l y�r I4j Q '-' 1 •11 ,Ars; 1 41 b 3700 3750 3850 IpSK X� y F 4750 650 T T(usec) 150 ------------ -54 CCL 6 0 GR (GAPI) 150 jj 2 AMP 190-2 RAD AVG 200 2 AMP 20-2 RAD MAX 200 -2 RAD MIN 200 VDL 1200 1 TTSFT (usec) 1200 VAD 8 Calibration Report Database File 1r-26 cbl 26apr19.db Dataset Pathname run3/pass4 Dataset Creation Fri Apr 26 19:11:26 2019 Gamma Ray Calibration Report Serial Number: 1 Tool Model: TITAN275 Performed: (Not Performed) Calibrator Value: 1.0 GAPI Background Reading: 0.0 cps Calibrator Reading: 1.0 cps Sensitivity: 1.0000 GAPI/cps Segmented Cement Bond Log Calibration Report Serial Number: POL275 Tool Model: 275TEKCO Calibration Casing Diameter: 7-000 in Calibration Depth: 899.300 ft Master Calibration, performed Fri Apr 26 18:36:06 2019: Raw (v) Calibrated (mv) Results Zero Cal Zero Cal Gain Offset 3' -0.003 1.085 1.800 62.165 55.492 1.940 CAL -0.002 0.963 5- -0.002 1.328 1.800 62.165 45.372 1.907 SUM S1 -0.002 0.483 0.000 100.000 205.948 0.425 S2 -0.002 0.450 0.000 100.000 221.035 0.480 S3 -0.002 0.573 0.000 100.000 173.895 0.399 S4 -0.002 0.708 0.000 100.000 140.833 0.282 S5 -0.002 0.944 0.000 100.000 105.657 0227 S6 -0.002 0.957 0.000 100.000 104.282 0.220 S7 -0.002 0.819 0.000 100.000 121.820 0266 S8 -0.002 0.569 0.000 100.000 175.002 0.382 Internal Reference Calibration, performed Thu Sep 12 02:13:39 2013: Raw (v) Calibrated (v) Results Zero Cal Zero Cal Gain Offset CAL 0.000 0.000 -0.002 0.963 1.000 0.000 Air Zero Calibration, performed Fri Apr 2612:03:14 2019: POL275 Tool Model: Raw (v) Calibrated (v) Results Zero Zero Offset 3 0.000 0.000 0.000 5 0.000 0.000 0.000 SUM S1 0.000 0.000 0.000 S2 0.000 0.000 0.000 S3 0.000 0.000 0.000 S4 0.000 0.000 0.000 S5 0.000 0.000 0.000 S6 0.000 0.000 0.000 S7 0.000 0.000 0.000 S8 0.000 0.000 0.000 Temperature Calibration Report Serial Number: POL275 Tool Model: 275TEKCO Performed: Thu Sep 11 11:48:19 2014 Reference Reading Low Reference: 0.00 degF 0.00 uses High Reference: 1.00 degF 1.00 usec Gain: 0.33 Offset: 0.00 Delta Spacing 1 Company CONOCOPHILIPS Well 1 R-26 Field KUPARUK County NORTH SLOPE State ALASKA Country usA 191092 31 5 57 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. October 16, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure and Packer Setting Records: 1R-26 Run Date: 8/8/2019 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 1R-26 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22193-00 RECEIVED OCT 2 3 2019 AOGCC 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 Fax: 907-273-3535 FRS_ANC@halliburton.com L�zi% Date: L Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 R-26 Permit to Drill Number: 191-092 Sundry Number: 319-314 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 WW W.Oogcc.alaska.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, Daniel T. Seamount, Jr. Commissioner r� DATED this 3 day of July, 2019. RBDMS±� JUL 0 8 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED .JUN 2 8 2013 A^^e1%r 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ V tali n6 shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: Whipstock_ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Stratigraphic ❑ Service„ft, 191-092 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 V '- 50-029-22193-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1R-26 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): 1 ADL 25635, ADL 25636 r 1 Kuparuk River Field / West Sak Oil 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): 10218' 6976' 10201' 6965' 1098 4320' N/A Casing Length Size MD TVD Burst Collapse Conductor 80' 16” 123' 123' Surface 5551' 9-5/8" 5593' 4081' Production 10,166' 7" 10,201' 6965 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4320'-4480', 9639'-9672', 9887'- 3327'-3427', 6582'-6604', 9902', 9916'-9941' 6750'-6760', 6770'-6787' 4-1/2" L-80 4252' Packers and SSSV Type: Baker HIS Retrievable Packer Packers and SSSV MD (ft) and TVD (ft): 9570' MD / 6523' TVD Baker D Permanent Packer 9706' MD / 6614' MD 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hit g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/4/2019 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: James Ohlinger Contact Name: Ryan McLaughlin S� Authorized Title: Staff TD Engjoapr Contact Email: an.mclaU hull CO .Com G Contact Phone: 265-6218 � �/ Authorized Signature: Date: l0 COMMISSION USE ONLY Conditions of approval: Notify Commission so tth t a representative may witness Sundry Number: H Plug Integrity ElBOP Test Ey Mechanical Integrity Test ❑ Location Clearance ❑ Other: OOP ft, z S -OD p s, �1��✓ frhn�la� �r�v«f-r` j`sf ? IBDMS( JUL D 8 2919 Post Initial Injection MIT Req'd? Yes ❑ No Pin Spacing Exception Required? Yes ❑ No Er— Subsequent Form Required: 4 t9 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7/3/17 �y/� // L 9 R I I N//(\y L orm I / SJ4/20117 Approvedpplication is br�1f r t115TrdhTth2 dare of approval. Submit Form and A8 nts in Duplicate �' '�9 WO-fIII(-t Conoc Po hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 27, 2019 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 Application (10-403) to set an Inner Wedge in KRU IR -26 (PTD #191-092) in order to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC. Attached to this application are the following documents: — 10-403 Sundry Application for KRU 1R-26 — Operations Summary in support of the 10-403 sundry application — Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLa g lin ConocoPhillips Alaska Coiled Tubing Drilling Engineer KRU 1R-26 (PTD #191-092) CTD Summary for Sundry Summary of Operations: KRU well 1 R-26 is an injector that was recently worked over to be set up for CTD operations. During the workover, 4-1/2" tubing was installed with tandem wedges to facilitate cutting a window with CTD. Prior to CTD operations E -line will set an inner wedge within the tandem wedge. CDR3-AC will mill a window in the tubing and two strings of casing at 4460' MD. After that the 1 R-1 26L1 lateral will be drilled to the northwest as an unlined pilot hole to de -risk future rotary work in the area, followed by the 1 R-126 lateral to the south targeting the West Sak B -sands. The 1R-126 lateral will be completed with 2-7/8" slotted liner in the lateral and 3-1/2" liner in the build, with a deployment sleeve on top. Pre -CTD Work 1. RU E -Line: Drift, set inner wedge at 4460' MD 2. Prep site for Nabors CDR3-AC rig. Ria Work 1. MIRU Nabors CDR3-AC rig using 2-5/8" coil tubing. NU 7-1/16" BOPE, test. 2. 1 R-1261-1 Lateral (West Sak pilot hole - northeast) a.eMill 3.80" window at 4460' MD b.Drill 4-1/4" bi-center lateral to TD of 7319' MD. c. Set anchored aluminum billet at 4850' MD 3. 1R-126 Lateral (West Sak B -sand -south) a. Kickoff of the aluminum billet at 4850' MD. b. Drill 4-1/4" bi-center lateral to TD of 12,000' MD. c. Run 2-7/8" slotted liner and 3-1/2" solid liner with deployment sleeve from TD up to 4450' MD. 4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Ria Work 5. Return well to production. Page 1 of 1 6/26/2019 is" Contludor 65# H-00 shoe @ 123' MD CTD KOP 4460' MD, 333 SSTVD, 51 -deg inc 9-5/B"Surface 36# J-55 shoe at 5593' Top of 7" cement -875 via CBL of 8-27-91 PERFS (Plugged) C -sand 9639'-9672' MD -sand 9687-9902' MD -sand 9916'-9941' MD 7" Production 26# J-55 shoe @ 10,201' MD 1R-126 Proposed CTD Schematic 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 f � � TRANSMITTAL DATE:i •• TRANSMITTAL#: FIELD BP North Slope L0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. KEGEIVErl 1 1 0 10 Attn: NSK-69 MAY 5 1019 700 G Street Anchoraee.Alaska 99501 onrrrr 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 0 1 Attn: Garrett Brown -Geologist DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Nam Signature Date Please return via e-mail a copy to both Alaska E -Line Services and oq co Phillips Alaska: PTO lql— 0q.2 Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, May 1, 2019 4:57 PM To: Loepp, Victoria T (DOA) Cc: Regg, James B (DOA); Senden, R. Tyler; Eller, J Gary Subject: RE: (EXTERNAL)RE: 1R-26 CBL Update Attachments: 1 R-26 Job Log.docx; 1 R-26 Perf Squeeze Plot Report.pdf; 1 R-26 PWC Washing down.pptx Follow Up Flag: Follow up Flag Status: Flagged Victoria We're preparing to run and cement the 4'/:" liner in place in well 111-26 (PTD 191-092). Our pressure testing indicates there is some leakoff into the squeeze perfs that will be dealt with during the liner cementing operation. Below are some pertinent details. • Calculations suggest the leak is roughly 0.2 gpm (i.e. 35 psi decline every 5 minutes) at 14.2 ppg equivalent mud weight (which exceeds our maximum anticipated injection pressure during injection operation). • We are not certain where in the perforated interval that it is leaking, but a test packer has confirmed that it's definitely within the squeeze interval. The most likely leak point is at the base of the perfs (^'4478' MD) given the signature of the CBL at that depth and that there is a path for leakoff via the shoe of the 9%" surface casing. • We conducted a passing MIT -OA to 1575 psi yesterday. There has been no indication of communication to the OA pressure gauge at surface • We believe the 4'/:" liner cement job will remediate any leakage in these squeeze perfs, and in fact that is one of the reasons it was included in the completion design. We've consulted with our cementing SME in Houston, and he thinks it is the best plan forward to address whatever channel or pathway that exists in the squeeze. He believes this should address the pressure leak and create a sufficient seal, better than another squeeze operation. • We're tentatively planning to increase the cement volume in our liner cementjob, and we'll place thz ce < while holding some back -pressure to help force the cement to plug whatever channel exists. • Overall, we believe that the squeeze cementing operation went as well as it possibly could have, given that we have uncentralized 7" casing inside of 9%" casing. We met today with the Archer representatives who were on- site during the squeeze cementing operation. They attested that the perf-wash phase of the operations went very smoothly, and that there was not substantial material that had to be removed from behind the 7" casing, as we expected. The cementing phase likewise went quite well, and the bond log clearly indicates the positive results of the squeeze behind the 7" casing. I have attached the job details that Archer provided us with from the wash phase and the cementing phase of the squeeze. These include: • Screen shots from the Nabors 7ES RigWatch system during the pert -wash phase of operations. Typically the perf-wash data provides the best indicator of cement success because it shows how well the Barricade tool did at removing debris from behind the casing. In this case, the circulating pressures were very consistent throughout the entire wash and there was little debris across the shakers. We have learned that we need to come up with a better way of capturing the circulating pressure data on Nabors 7ES — a series of screen shots is not the most effective method available to us, but it's all that we have right at this moment. • Schlumberger cementing record • Archer job log Please let us know if we can answer any more questions. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, May 1, 2019 10:56 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Regg, lames B (DOA) <jim.regg@alaska.gov> Subject: [EXTERNAL]RE: 111-26 CBL Update Kyle, Thank you for the CBL results, interpretation and reference schematic. Approval is granted to proceed with running the 4-1/2" liner. Please forward the second CBL interpretation when it becomes available as well as the cement job info. Tha nx, 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. Loepo()alaska.aov 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 Victcna.Loeok)4a1askaagov From: Hampton, Kyle <KVIe.Hampton@conocophillips.com> Sent: Wednesday, May 1, 2019 10:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Eller, J Gary <J.Gary.Eller@conocophillips.com>; Senden, R. James B (DOA) <jim.regg@alaska.gov> Subject: 1R-26 CBL Update Victoria, Tyler <R.Tyler.Senden@conocophillips.com>; Regg, I have attached the post -cement CBL pdf ( 111-26 CBL _2 30APR19), the pre-perf CBL (1R-26 7114 CBL 26APR19), and a couple slide explanation. We are currently waiting to hear back from our Cementing SME for a second interpretation on the CBL, but we feel that it shows cement isolation across the perf interval. The first slide shows the CBL interpretation. The second slide shows a schematic view of the well to provide context with formations and CTD exit points. We are currently gathering all of the information for the cement job and will be sending that over this afternoon. Pending your response, we will be ready to run the 4-1/2" liner this evening and cementing it in place tomorrow morning. Please let us know if you'd like to discuss. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, May 1, 2019 10:35 AM To: Loepp, Victoria T (DOA) Cc: Eller, J Gary; Senden, R. Tyler; Regg, James B (DOA) Subject: 1 R-26 CBL Update Attachments: 1R-26 RWO Update_05012019.pptx; 1R-26 CBL_2 30APR19.pdf; 1R-26 71N CBL 26APR19.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, I have attached the post -cement CBL pdf ( 111-26 CBL_2 30APR19), the pre -pert CBL (1R-26 71N CBL 26APR19), and a couple slide explanation. We are currently waiting to hear back from our Cementing SME for a second interpretation on the CBL, but we feel that it shows cement isolation across the perf interval. The first slide shows the CBL interpretation. The second slide shows a schematic view of the well to provide context with formations and CTD exit points. We are currently gathering all of the information for the cement job and will be sending that over this afternoon. Pending your response, we will be ready to run the 4-1/2" liner this evening and cementing it in place tomorrow morning. Please let us know if you'd like to discuss. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com Perf interval: 4,319' MD - 41477' MD Based on attenuation curve and VDLs, we achieved cement isolation between 4,316' MD and 4,478' MD. We performed a passing MIT -OA to 11575 psi for 20 minutes after the squeeze. LTP: 4,293' MD TOC -4,316' M D KOP 2: 41434' MD KOP 1: 41460' MD _ BOC -4,478' MD — conocoP,urps HO tzr Mo IR -26 Post Squeeze Dyye w CmFl &Sal' S. 35+1155 sDn 'Mn, 4031' TV Ucnc Pack cement 4400'•3500' MO ma COL Ugnu Series N Mudstone confining layer West Sak D sands lest Sak C, B, A sands Up s O at. "M 1R-26 Liner Cementing en3 M FOP (MD) Tey "M at n bio I I.M. LM lea bw wzD 1R-126 CTD ConocoPhnillps 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 BP North Slope L_0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 ECEN 700 G Street R MAY 0 6 NIS Anchorage, Alaska 99501 r.r' 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 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: MM 05 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: / AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 TRANSMITT7LDTRANSMI 191092 WELL NAME 1R-26 3M-26 1R -04 1R-04 �A PI # 50-029-22193-00DWUJ-00077 50.029-22431-00 50.029.21404.02 50-029.21407-00 SERVICE ORDER DWUJ-00078 DWUJ-00079 DWUJ-00080 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER SERVICE WL WL WL WL LE DESCRIPTION .EMIT Caliper EMIT EMIT DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD Color DATE LOGGED 2 -Feb -19 4 -Feb -19 5 -Feb -19 6 -Feb -19 1 1 1 1F-07 50.029-20830-00 E9KH-00003 KUPARUK RIVER WL PPROF FINAL FIELD 9 -Feb -19 1 1B -15A 1R-17 50-029.22465-01 50-029-22212-00 EA77-00001 EA77.00006 KUPARUK RIVER KUPARUK RIVER WL WL PPROF IPROF FINAL FIELD FINAL FIELD 12 -Feb -19 13 -Feb -19 1 1 7 -"-""' j / �� A Transmittal Receipt signature confirms that a package (box, J/ VZOenvelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The 3m Signature Date specific content of the CDs and/or hardcopy prints may or may Vnot have been verified for correctness or quality level atthis return via courier or sign/scan and email a col o Schlumberger and CPAI. point. 3TSPrintCenterpsib.com Tom OsterkamgQconocoohillios com SLB Auditor- 3--W Schlumberger -Private THE STATE °fALASKA 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 1R-26 Permit to Drill Number: 191-092 Sundry Number: 318-538 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 w .aogcc.alaska.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, 6Kj�?�- Cathy P. Foerster Commissioner DATED this a day of February, 2019. ABDMS L C FEB 1 12019 . truv S E 0 V E D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations M Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing El Change Approved Program ❑ Plug for Redhill ❑ Perforate New Pool 0 Re-enter Susp Well [2' Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 191-092 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-22193 � 00—a& Q 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 406B KRU 1R-26 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADg 25635 L Z Ku aruk River Field, West Sak Pool 1L 1. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10218 6976 9050 6189 2393 Oct -24 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 123 123 1640 670 Surface 5551 9-5/8" 5593 4081 3520 2020 Intermediate Production 10166 7" 10201 6965 4320 4980 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 3-1/2", 9.2 ppf (kill string) J-55 2268 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): none none 12. Attachments: Proposal Summary Lal Wellbore schematic L��J 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 ❑ WINJ W 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 Contact Name: Kyle Hampton Authorized Title: Workover Supervisor Contact Email: k le.ham ton Conoco hilli s.com Contact Phone: 907-263-4627 z Authorized Signature: � Date: /z y1'/g COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r "f✓, I Plug Integrity ❑ BOP Test M/ Mechanical Integrity Test El Location Clearance Other: �Up ffS f 30671'r,15-4' U nYfvGciv Pre- t/e'v Post Initial Injection MIT Req'd? Yes ❑ No Er Spacing Exception Required? Yes ❑ No E?' Subsequent Form Required: APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date: 2 1K ABRIR7 Fi 1 t LVW � 2/ �/ 1 Jf Approved EalfdiooRRa �� V Submit Form and rM1f 740 isetl3 O17 applicatiohmQ n n■■ nLe date of approval. Attachments in Duplicate /�R/�1 rr t, B, tz/5%ts 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 a Sundry Application (10-403) to perform workover operations to set up well KRU 1 R-26 (PTD 191-092) for CTD sidetrack in the West Sak formation. The original Kuparuk sand completion has already been plugged in accordance with the requirements of 20 AAC 25.112(c)(1) following a failed workover in 2014, and the well has since been classified as Suspended. Workover operations will prepare 1G-03 for CTD sidetrack into the West Sak formation. Included in this workover summary is ConocoPhillips plans for achieving cement isolation behind the uncemented T' casing adjacent to 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 this application are the following documents: - 10-403 Sundry Application for KRU 1R-26 - Operations Summary in support of the 10-403 Sundry Application - Current well bore schematic - Proposed post-workover schematic - Map of well penetrations in the West Sak formation within a quarter -mile of 1 R-26 - Mechanical review of West Sak penetrations within a quarter -mile of 1 R-26 If you have any questions or require additional information, please contact me at 907-2634172. Sincer J. G ler J Conoco illips Alas Wells Advisor 1R-26 Workover Setup 4'/:" completion in preparation for CTD sidetrack D KOP 4456' MD, 3330' TVD, 52 -deg inc West Sak formation (top 3200' TVD) PWC squeeze perfs: 4320'- 4480' KB (160') Following squeeze, drill out & log, run 4.5", 12.6 ppf, L-80 liner cemented in place with ZXP packer @ 4260' KB. Shoe of liner at '4600' KB. 7" CIBP at 4630' KB KUP INJ 1R-26 CQnQCQPfiilli��/�(/' Well Attributes Merz Angle & MD TD Alaska-I� WellOor-19Z FNMNeme Wellnore SGlue ncll MDIXNB) Atl BM (tt02 500292219300 KUPARUK RIVER UNIT INJ S6.fi5 S,JOO.OD 10,218.0 mml NBSlppnl OMe SSSV: N/A Amwralion EnE DasNBGMIXI NB Reka,p hale Last WO: fi272014 42.99 7124tl991 tR-R, ]/J�A149:rt0f Ax nM n aY oxacksM Wa1,Wq By EM Oa1e Last Tsg:ELNE 9,018.0 NH12014 Rev Reason: WORKOVER/SUSPEND Posb1 7117/2014 ...IIFNGER SB ..._...._ , II sing mgs Gsln9 Descriptbn O Un)Un) ap 9at {X BI Sed Depr NOI... Warren (1... G,aEe op T read CONDUCTOR 16 15.062 43.0 123.0 1230 6258 H 0 WELDED e[Oeptlr BU(61 Sed OepM INP1... WtlLm g... Grtle Top iKreaB (a61p rigbn (in) (nl opt "'"'S59'3 SURFACE 95x8 8.921 42.6 5,593.1 4,U81A 36.007.55 BTC n Gun9 - ml Int Top,rooI Seassornm101 XII%pon'l-l- WULm11..,G2]e Top Tmme PRODUCTION ] 6.276 352 10201.0 6,9645 2600 J-55 BTC -MOD Tubing Strings uang DesnoWhon spm, Ma_.ID(inl Top WS) 3¢I page ln_Bet t1V II_.wgim0 Gm4e Tap eonnemion Tubing Kill sling 312 2,992 39.9 2.26].6 20fi5.3 9.30 J-55 3.5 ELIE BN Completion Details D Top lnnBl Taplrvol lnnel Top trap l•1 uem on Com 0n1 CONOueTOR; 49.wRo 39.9 39.9 0.02 MANGER Tubing hanger Wl pup 3.500 Other In Hole IWireline retrievable plugs, valves, pumps, fish, etc.) Tap RV.) Topina XpinrcB) WE) 19 Dew Gom Run OLe mitral 9,050.0 Still 48.55 RETAINER CEMENTRETAINER fi12312.'4 1.25o 9,241.0 6,316.3 48.30 FISH SEE NOTE: 626120'4 %na.0 6,640.8 4].57 BAND BOF SAND ONPLUG SIfi2014 9,730.0 6,643.5 47.56 PLUG 2.25-K 11 PLUG OAL=22.5') 51620 4 Perforations & Slots shoe Dene TOP RVDI eon RVID) Ishotsn Top WE) Dim MIN I MG) IMeel Zone role 0 Twa Cpm 9,639.0 9,672.0 6,582.3 SS(AA C-1 IR -26 UV1992 10.0 (PERF 4.5 Csg Gun, 60 deg. ph SURFACR42686991-T 9,887.0 9,902D 6.749.8 6,759.9 A4. 1R-26 2/1812007 6.0 RPERF 2118"Power Enagel HMK, 0 deg, ph RETAINER 9tm0 9,916.0 9.941.0 6.769.5 6.786.5 Ad, 1R-26 11411992 4.01PERF 4.5"Csg Gun. 180beg. Ph Cement Squeezes FISH: 9,N10 IND) Mmi1VD) B)IXNB)fi8.8 6, Hera Cement Plug6/2512014 VUMW ou V0013 from depth 019018.0) of cement =9,G6D,G on fop of cement retainer. Squeeze 55 able of Cement tmlmv refainer89.3 6.622.5 Cement Plug 6/2512014 Squeeze 55 pals of cement below retainer. Notes: General & Safety D E; AnmMbn 10Na 10.2 020 Scheatic WAlaska Sc6eme1ka.0 NOTE: View m ]11412014 I NOTE: GLV STUCK; WAS UNABLE TO RETRIEVE DURING 2014 RWO 7/112014 NOTE:FISH; COMPRISED OF TUBINGd3LM/NIPPLEISEAL LOCATOR PACKER; 8.9BD.5 INIECTION:98123 PERF.9.e969,672.0- BLEEYE.C:9@Jf5 PACKER 9,AS0 a.,.,,.. 5^N0: 9.]'G.0 ... N :9,7R8 L...•I FUJG PLW;9i]0.0 505;9]{80 RPERF:98574 ,Y Q - ,.a, PRGOUCTIO N: W2.10,m10 KRU 1R-26: Summary of Workover Plans Prior to CTD Sidetrack into the West Sak Formation Summary of Operations: KRU well 1R-26 (PTD 191-092) is a suspended Kuparuk injector equipped with a 3'/" kill string and 7" production casing. It was suspended in 2014 after an unsuccessful workover rendered the well unusable in the Kuparuk sands completion. The Kuparuk sand completion has already been plugged in accordance with the requirements of 20 AAC 25.112(c)(1), so ConocoPhillips proposes to work over 1 R-26 so that it can be CTD sidetracked in the West Sak formation. This summary only addresses the workover aspects of 1 R-26; a CTD permit to drill (10-401) will be submitted in the near future for 1 R-26. The expected pressure in the West Sak formation is 1572 psi at 3418' 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 2393 psi assuming a gas gradient of 0.1 psi/ft. • Recommended BOP Test Pressure during West Sak workover ops = 3000 psi Workover Operations to Set Up for CTD Sidetrack into the West Sak Formation Note: Well 1R -26's intended service following CTD sidetrack is as a water -only injection well into the West Sak formation. The CTD KOP is tentatively planned at 4456' KB, 3418' TVD. 1. MIRU workover rig onto 1 R-26. NU BOPE, test. 2. Pull 3'/i' kill string 3. MIRU a -line a. (optional) Run CBL from --6000' to surface to evaluate cement behind the 7" casing. Tie into geologic control log and assess the location and condition of the arctic -pack cement with respect to the proposed squeeze location. b. Set CIBP for 7", 26# casing at ±4630' MD as abase for cement. RD a -line. 4. PU and TIH with ±160' of TCP guns (gun OD and shot density TBD). Tag CIBP to correlate depth for squeeze perfs 4320'-4480' MD (i.e. top of the N mudstone to mid West Sak D -sand). 5. Circulate hole full of ±9.0 ppg brine to overbalance anticipated formation pressure 6. Fire TCP guns. 7. Circulate bottoms up, confirming adequate overbalance to formation pressure. Adjust brine weight as needed. 8. TOH, laying down spent TCP guns. 9. PU and TIH with cup -style perfwash & cementing tool 10. Use cup -style wash tool to wash squeeze perfs 4320'-4480', removing old mud, cuttings, and debris from between the 7" casing and the 9%" surface casing. 11. Prepare to pump 15.8 ppg class G cement. Use cup -style placement tool to ensure that cement is circulated through the perfs. Page 1 of 2 11/19/2018 a. Calculated annular volume between the 7" and the 9%" surface casing is only 3.0 bbl for the 160' perforated interval, but be prepared to pump ±20 bbl of cement (i.e. at least 1.5x the 9%" cased hole volume) to adequately squeeze this interval. 12. Pick up out of cement, circulate clean. 13. TOH, lay down cement squeeze assembly. 14. WOC as needed 15. PU drilling BHA with 6%" mill tooth bit. Drill out cement down to bridge plug at 4630' MD. Pressure test squeeze perfs to 14.2 ppg EMW (i.e. 0.74 psi/ft, or 930 psi at surface with 9.0 ppg brine in the hole). 16. MIRU a -line a. Run CBL across the squeeze interval to evaluate quality of the cement squeeze. 17. PU ±330' of 4%", 12.6 ppf, L-80 liner on ZXP liner hanger/packer. Liner will include two outer wedge assemblies spaced out for CTD exits at 4456' MD and 4426' MD. TIH, space out 41/2" liner, putting the outer wedges on depth and the ZXP liner -top packer within 200' MD of the deepest exit point (i.e. no shallower than 4256' MD). 18. Set liner hanger. Cement 4%" liner in place with 15.8 ppg Class G cement. Set ZXP packer, and pressure test IA. Circulate clean and TOH. 19. PU with 4Y2" completion and TIH. Sting seals into sealbore and space out. Circulate hole over to corrosion inhibited brine. Land tubing in tubing hanger. MIT -IA. Set BPV. 20. ND BOPE, NU 4-1/16" tree. RDMO. Page 2 of 2 11/19/2018 WS_U WS_B WS Al WS_B WS_U W5 A4 WS_A3* V CWS_ A3 WS_D 9 o• E WS A2 WS-A2WS_TOP WS_DWS_C P-4 WS IF WS D WS TOP WS D WS D WS_B / 1R-24 - WS_D WS_E D WS_B WS_A S_A2 WS- BASE IR-27 R p1e� 10 11t _D WS_D IR-018L., u' of Q >�?g WS-10 0 >�?g le Q M 4 WS_ a' > > ConocoPhillips 0 Top West Sak iF)cks � OW West Sak Rcks Alaska — 1R-26 Well Trail Amine Well 1 R-26 Top West Sak Pick Suspended and Quartermile Buffer Rugged and Abandoned Q 1R-26 Top WS Qua ten ge Buffer with Nearby WellsN F-, CPA[Lease OW West Sak Picks A0 0.1 0.2 11/26/20181 Miles RRU 1R-26 Workover Setup for West Sak Injection Quarter-MilleReview t/ surface D- Toof surfare Surface Well Name PTD API Wall Top "Edpof Casing Set Udssilicatlon WeI15Wus Oil Poo11MD1 Pool (MD) Sand Oil Pool Cassini Using Set Amaea Wast Cement Operations Summary Mechanical integrity (TVD) Depth (MO) Depth IWO) Saki sewn zsp.. 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In xss -1 w9wWbxluw/w • Ea. �WWn t/ KRU IR -26 Workover Setup for West Sak Injection Quarter -Mile Review Surface Top of D- Top of 6Surta6'e Surface Surface Well Well Casing Set Surface Casing Cement Arctic Pack Narne t PTD API classification Status sand Oil Pool Sand Oil Casing Set Casing Set Casing Set Mechanini Integrity (MO) Pool (TVD) Depth (MD) Depth (TVD) Across Ugnu? Across West Operations Summary Cement Ops Sell? SaSir:lm0aafa39bbliof PNE13.3PP9 OA33bsal=t S5bbl HOMIRL WFlI 4adei9]n1ubbAaf136 pq p .S. Mexl,9/5/83. 33 Eh1. Titpaaud ]/9/13 .19 2.1. Sa 0$¢314dd$ PrMuaer Lia 3,6ga 3,303 0.381 3,BN TgVF TPUE iWl.aenYrelM.<M379samea1 ]IIU InaRannuY. SE dY CMIT-Mb1959pd pauad5/3J/44 . Nole<yrm[bn iii="1851'. MRORfo mp ryl pave lO/iU18 I.SicauMW.,sal. - 96/0":14]YvI5l5 bWIef PFE 13.3 ing lse.5.5bb1 Opal NORMaLWaI kede43Gp169bM1M156pq IK.11. 911W. 31&5.3,55.5 d414 Mn-OprolIVVIS aueE lL19M 1M3 185176 Sa03SI140H0 PrMu<er pmYu<Fy 4,11 3,30 4,Bla 3,885 3flUE TRUE Gondretuans1"eelcb•d19115bb1 -in IN In<yannull, 55.5 001' 10418' TPLWexd ll/3/IS es'entma.nme Fn=u.5p1.. 15W:s..I.IaMef.a3.3PP0 NanuaL.U. 3825 191M] 50039.3315310 Pied.prMUGry 4.513 314% S.571 4,123 TRUE TRUE In dr630.(U2MJ0flS,6.GW. dksN• IviQN15. 50W TFLPWW 3/31/141 fvAreMms,rMPusbacemeMro '160,srs 0asasll E0 Mn-Tfo35CORlpassed9/3/9> zufa<e. W=11.5mFMW. all Mn-Mw35tlIMI Wa-xE8/36M] MRO4so1P03 assNJS 9d/0": 11)Ov1410 bM1oIPFE13.3 pp[ O.43W<n4.SSMI W... Ieadr 530vn98 WjufG l5App3tal6 diesel, 9/33N1. 43bb= MITAWSMa lona-2]14 18-36 191.093 500342219310 llµ SuapeMed 44341 3,393 5,593 4(m 3RUE TRUE 1414' Inryannull. SIMM sur pteMpalpafed10n3/18 WXMWMaeMlreieb,ClM23sxu MI1 ese.M ro.oa<e. aR=32.SMEMW. =1953' S/T: 1397 a a i4B.e bell& PIE 33.111 M-42MI-1.63M] NORN.LLWFLL leade5Ayi31Jbe1 d15.0p1GtaIL diesel. 10/01. 421" TnpalesIMM]0 3R27 ]91 fD3 s09E-22"14D hWucer Iris 5,340 3,530 41.547 a,192 ME ME FWI rNumablrtnoamentrouMa¢. TM IAKino saanuli,6301 Mn-Tsa25EopHpassed5/ A6 MMt ..l29bNl&IS,,6p1PFt. =2138. MRdp M35a3p1IMIIA7A2 Fa=135 FMW. MROAIa1b2 uM 10/1 32 93/ 0":1320ui463WiM PFF13.Sp1 00.31AMICMC65bb1 NOWaLWELL 1R-19 ]91 4 $ON922195M hoduar pIMUCIry 4,051 3,a14 IW2 4,119 TRUE ME lead. I.Ess i01158 11 dleaN. l3/1fi/9f. 338 bbl=113r Mu8annulL 31FLpasled4/14/10 Ma-TIa351gpalpaud5/29/I6 FUA re1wn MIX IKip<avMa']rA bM 651.3160'. MiIse MIs pal W 11/17/13 eMbawlaM. frt•12.Spp4 FMW. am-n-1-1—ued1l.132 111-26i & 111-04i Present Well Condition (generic) a3X maaa MD West Sak formatior (top `3300' TVD) Uncemented ' 11 oeLwe the 9-5)8" r shoe s Arctic Pad cement is well above the West Sak formation 7" C81s don't go shallow enough to see arctic pad cement. gest guess is AP cement goes down to t3000' M0 (I.e. 3500' TVD above WSak) dig' $udau fi4 mae® a IMV TVD 9-5/8" shoe Is below the base of the West Sak FIT to 12.5 poll No CK across 9-5/8" 7" cement extends above the Kuparuk sands which will be abandoned. CBIS in all. 111-26i & 1R-041 (injectors) Post-RWO Condition OV completion in prep for CrD sidetrad Kuparuk Intervals P&A'd Wash -Cement am of 7" annulus interval) eed by 4-1/2" mtedl-mer.' des two 0 lesforfutura._ - rack. 1R -26i & 1R-041 (injectors) West Sak CTD pilot (2019) CTD completion: 2Y" slotted Imer In 4.25" ID hole CFD window nit (3 -string) exit near the top of the WSak sands. rfcb{ ,M..h" ..... ,a. ::..x.n n .la. e ,. ,:.., v xS:Fz , v s ,,,•.Fi, x ,: . SYa .-i 6J� N \� I-IFSIAL F Via, l 'iti c (-ss — 333 West Sevec4n Avenue E41 C OV<Li NOR SEAN PARNT-;I.I. Anchorage Alaska 99O1- 5/2 AoIn 9:7 77°LktaLui 43? Ep AUG 0 12014 Jonathan Coberly Sr. Wells Engineer ConocoPhillips Alaska, Inc. ` J P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-26 Sundry Number: 314-251 Dear Mr. Coberly: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, /04ta4e,__ Cathy P. oerster Chair N-s�- DATED this ‘... day of April, 2014. Encl. • STATE OF ALASKA 1 v E AL :A OIL AND GAS CONSERVATION COMM. ,ON 1 1 'J 4 • APPLICATION FOR SUNDRY APPROVALS DTs 4422.1 11, 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing 17- Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing ri- Other: r- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 191-092 3.Address: 6.API Number: Stratigraphic r Service , P.O. Box 100360,Anchorage,Alaska 99510 50-029-22193-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 171R-26 • 9.Property Designation(Lease Number): / PAO 10.Field/Pool(s): ADL 25635 t o2S(OKuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10218 6976 none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 123' 123' SURFACE 5551 9.625 5593' 4081' PRODUCTION 10166 7 10201' 6965' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9639-9672,9887-9902,9916-9941 ` 6582-6604,6750-6760,6770-6787 3.5 x 2.875 J-55 9747 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HB RETRIEVABLE PACKER " MD=9570 TVD=6536 PACKER-BAKER D PERMANENT PACKER ' MD=9706 TVD=6627 SAFETY VLV-CAMCO TRDP-1A SAFETY VALVE ' MD=1799 TVD=1733 12.Attachments: Description Summary of Proposal F.• 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/15/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WIND r GINJ r WAG J' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.Coberlyconocophillips.com Printed Name Joan Cobert Title: Sr. Wells Engineer Signature 2 Phone:265-1013 Date I/46—/i/ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .- t1— _VS 1 Plug Integrity r BOP Test Mechanical Integrity Test ocation Clearance r RBDM§NAY 8 2014 Other: 0 p -t-E-5 t to 3 5-0 0 p S 1 IL�tC�fe Wj r55rC� /141 T-1 r I'rt cI a f try �t4t 0 i`l r�L.--�i,;-,,)CG ti�t,---) Spacing Exception Required? Yes ❑ No Subsequent Form Required: 7 APPROVED BY Approved by: /31 COMMISSIONER THE COMMISSION Date: 4- u —/ p application is valid for 12 months from the date of approval. Form 10-403(Revised 10/2012) �'� �f ILII I Submit Form and Attachments in Duplicate rl-F4<<9ltit ORIGlNALát • • REC E i . ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 16,2014 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1R-26(PTD# 191-092). Well 1R-26 was drilled in 1991 and completed into the Kuparuk A&C-sand intervals in 1992. The well has no previous workover history. The 1R-26 is selected For a rig workover to setup the wellbore for coil tubing laterals to be drilled following the rig workover. On 3/27/2014 the IC packoff failed positive and negative pressure tests and will be replaced during the rig workover. There is also a known selective leak below the upper packer to the Kuparuk C-sand that does not affect the rig workover. There are no other known integrity issues with this well. The CTD laterals will target 580 MBOE of resource in the Kuparuk A-sand. To setup 1R-26 for the CTD laterals the existing selective completion will be removed, a cemented 4 '/z" liner will be installed across the Kuparuk A&C-sand perforations, and a 3 '/2" injection completion will be installed from the liner to surface. If you have any questions or require any further information, please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, or Imo/ Jonathan Coberly Senior Wells Engineer CPAI Drilling and Wells 1R-26 Rig Workover Remove Selective Completion; Install Cemented Liner & Tubing to Setup for CTD (PTD# 191-092) Current Status: The well is currently awaiting a RWO to setup the well for future CTD development. Scope of Work: Pull the existing injection completion,install a 4 ''h"cemented liner,and install a 3 '/2"injection completion. General Well info: MASP: 2,520 psig(using 0.1 psi/ft gas gradient) V Reservoir pressure/TVD: Kuparuk A&C-Sands—3,196 psig/6,765' TVD (9.1 ppg EMW)measured 11/25/2013. Wellhead type/pressure rating: FMC Gen IV/5,000 psig Tree and Tubing Head Top Flange 3000 psig Casing Head Top Flange Nordic 3 BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT IA—Passed to 3,000 psig on 3/27/2014 MIT OA—Passed to 1,800 psig on 3/27/2014 Well Type: Injector Estimated Start Date: May 15,2014 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Pre-Rig Work: Slickline: 1. RU slickline. Pull DV's from GLM's 2&3. Leave open. RDMO slickline. Other: 1. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU. Pull BPV. Circulate in 9.6 ppg brine to kill the well. No-flow test. 2. Install BPV. ND Tree. Install blanking plug. NU BOPE. Test BOPE to 3,520 psig. Pull the blanking plug. Pull the BPV. No-flow test. 3. MU landing joint. BOLDS. Pull the tubing hanger to the floor. 4. Reverse circulate. No-flow test. RU control line spooler. PU to release from the PBR. If the seal assembly will not pull free, pull the tubing in tension and set it in slips. RU E-line. Cut tubing with RCT. POOH. RDMO E-line. 5. POOH laying down completion. MU storm packer. Set the storm packer. LD setting tool. Bleed the OA pressure. Pressure test the storm packer. Bleed pressures. 6. ND BOPE. NU Hydratight system. BOLDS. ND tubing head using Hydratight system. Replace casing packoff. RILDS. NU new tubing head. Pressure test packoff. NU BOPE. Install test plug. Pressure test the BOPE/casing head flange break. Bleed pressure. 7. Release the storm packer. POOH laying down the tubing and storm packer. 8. RIH on DP with an overshot grapple and fish tubing stub(if tubing was cut previously). 9. RIH on DP and fish the upper packer and upper selective. 10. RIH on DP and mill through the lower packer. Reverse circulate. No-flow test. Chase packer and tubing tail to the top of fill. POOH. RIH on DP and retrieve lower packer if it is unable to be pushed deep enough. 11. RIH with liner assembly to bottom. Set the DP in slips. Close the annular. RU E-line. Log w/CCL/GR logging tool to correlate the liner to the CET log. POOH w/ logging tools. RD E-line. Disengage the annular and remove the slips. Space out the 4 '/Z"R3 liner collars even with production casing collars. 12. RU SLB. Cement liner. Set the liner hanger. Slack off to ensure that the liner hanger is set. Bleed pressure. Release from the liner. Circulate excess cement to surface. PT the liner and liner top packer. Bleed pressure to zero. TOOH laying down DP. 13. Single in with the completion tubing. Engage seal assembly into the SBE until fully located and space out the completion. MU new tubing hanger. Circulate the well over to corrosion inhibited brine. Land the tubing hanger. RILDS. 14. Pressure test the tubing. Pressure test the IA. Shear the SOV. No-flow test. 15. Pull landing joint. Set two way check valve. Test the two way check valve. ND BOPE. NU tree. PT the tree and tubing hanger packoffs. Pull the two way check valve. 16. Freeze protect the well. Set BPV. RDMO. Proposed Post-Rig Work: Slickline 1. RU slickline.Pull BPV. Pull the SOV. Run DV. RD slickline. Other 1. Reset the well houses and flow lines. 2. Turn well over to Operations. $ ConocoPhillips Well: 1R-26 2014 RWO PROPOSED COMPLETION API: 500292219300J L Conductor: PTD: 191-092 16", 62.58#, H-40 Welded to 123' MD Wellhead: FMC Gen IV X-mas Tree: 3-1/2", 5K psi Surface Casing: Lift Threads: 3-1/2"8rd EUE t sv 1— 9.625", 36.0#, J-55 BTC to 5,593' MD' BPV: 3"'IS-A' 3-1/2"Tubing: J Production Casing: •Tubing, 3W, 9.3 ppf, L-80, 7", 26.0#,J-55 BTCM to 10,201'MD 8rd EUE. • SSSV, TRMAXX-CMT-SR-5 w/2.813" j Perforations: DS' profile at-1,800'TVD. ' bk.. MD Zone • 1-5 1-1/2"MMG GLM's as needed 9,639'-9,672' C-1 • 2.813" 'X'Profile Nipple j 9,887'-9,902' A-4 9,916'-9,941' A-3 • 80-40 GBH22 Seal locator 4-1/2" Liner: I— TRMAXX-CMT-SR-5 SSSV • Packer, 5"x7"ZXP w/5.25" ID Tie-back X ♦— 2.813"ID CAMCO'X'Profile Nipple extension • 5"x7" HYD Flex Lock Liner Hanger ZXP Packer w/5.25"ID Tie-back Extension, • 80-40 SBE, 17' _ L` .4_ Flex Lock Liner Hanger,and SBE w/locating •4-1/2" 12.6#L-80 IBTM Tubing (R3) ► seal assembly.(-9,475'RKB) •4-1/2" Landing Collar _�� — f— C-Sand Perforations _ • 4-1/2" 12.6#L-80 IBTM Tubing (R2) ,.7 • 4-1/2" Float Collar 'J i' 1 • 4-1/2" 12.6#L-80 IBTM Tubing (R2) Ir' ``r • 4-1/2" Float Shoe = . ---7/ jC_ 4— A-Sand Perforations t- / (' F— 4 1/2"Landing Collar w/ Wiper Plug Directional: �t_L/I / 11 Max Incline: 56.7°@ 5700' 1 l p C .ii .4 — 4 1/2"Float Collar Max Dogleg: 7.9°@ 1900' l,! 7 f I DLO.7li4 1/2"Float Shoe ; // /7I/ X X Permanent Packer w/Tubing Tail Pushed to Bottom(Top of packer at—10,040'RKB) XN Fill at: 10,039' SLM Last Updated: 15-Apr-14 TD: 10,218' RKB Updated by: J. Coberly • KUP INJ 1 R-26 ConocoPhillips was II Attributes Max Angle&MD TD " v Alaska.Inc. ti' a(bore APi/LNYI Field Name Wellbore Status ncl(') MD(CKB) Act Btm(1969) • Cmroo,„,p, 500292219300 KUPARUK RIVER UNIT INJ 56.65 5,700.00 10,218.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-26,1112712013 9.09;19 AM SSSV:LOCKED OUT _ Last WO: 42.99 7/24/1991 Vemcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,039.0 11/25/2013 Rev Reason:TAG hipshkf 11/27/2013 Casing Strings HANGER;39.9 Casing Description OD(in) ID(in) Top(fCKB) Set Depth(BOB) Set Depth(ND)... Wt/Len(I...Grade Top Thread s``((�� I'lir CONDUCTOR 16 15.062 43.0 123.0 123.0 62.58 H-40 WELDED } Casing Description OD(in) ID(in) Top(COB) Set Depth(f1KB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 42.0 5,593.1 4,081.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(MOB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread PRODUCTION 7 6.276 35.2 10,201.0 6,964.5 26.00 J-55 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(f1KB) Set Depth(ft..Set Depth(TVD)(...Wt(11s/ft) Grade Top Connection TUBING 3.5"x2.875" 3 1/2 2.992 39.9 9,746.8 6,654.9 9.30 J-55 AB MOD-EUE Completion Details `� Nominal ID CONDUCTOR;43.0-123.0 . Top(SOS) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 39.9 39.9 0.02 HANGER FMC GEN IV TUBING HANGER 3.500 1,798.9 1,733.3 31.54 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE-LOCKED OUT Flow 2.812 Tube of SSSV on 5/13/94;Hyd Control Line not Locked SAFETY VLV;1,798.9 741.. Ot 9,517.3 6,500.8 47.99 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 9,555.9 6,526.6 47.99 PBR BAKER PBR 3.000 9,569.5 6,535.7 47.99 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT;3,277.2111 9,627.2 6,574.3 47.89 BLAST RINGS CARBIDE BLAST RINGS(2) 2.992 9,694.6 6,619.6 47.64 SLEEVE-C CAMCO CB-1 SLIDING SLEEVE w/NO GO ID;SHIFTED 2.750 SLEEVE CLOSED 7/5/2008 9,706.0 6,627.3 47.61 PACKER BAKER D PERMANENT PACKER 3.250 9,709.7 6,629.8 47.60 SBE BAKER SEAL BORE EXTENSION 3.250 9,714.0 6,632.7 47.59 XO Reducing CROSSOVER 3.5 x 2.875 2.875 9,729.8 6,643.4 47.57 NIPPLE OTIS 2 7/8 XN NIPPLE;2.313"core,2.25"NO GO ID 2.250 SURFACE;42.0-5,593.1-a 4 9,746.1 6,654.4 47.54 SOS BAKER SHEAR OUT SUB,TTL 9736'ELM,Eline tag 2.441 9930'ELM 5/5/2006 Perforations&Slots GAS LIFT;9,472.8 If i Shot Den Top(ND) Btm(ND) (shots/f Top(BOB) Btm(ftKB) (BOB) (ftKB) Zone Date t) Type Com 9,639.0 9,672.0 6,582.3 6,604.4 C-1,1R-26 1/4/1992 10.0 IPERF 4.5"Csg Gun,60 deg. ^ NIPPLE;9,517.3 YO'f 9,887.0 9,902.0 6,749.8 6,759.9 A-4,1R-26 2/18/2007ph 6.0 RPERF 21/8"Power Enerjet HMX,0 deg.ph 9,916.0 9,941.0 6,769.5 6,786.5 A-3,1R-26 1/4/1992 4.0 IPERF 4.5"Csg Gun.180 deg. ph PBR;9.555.9 Mandrel Inserts PACKER;9,969.5 St lc� a4 C °^ Top(TVD) Valve Latch Port Size TRO Run N° Top(01KB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 3,277.2 2,681.8 CAMCO KBUG- 1 GAS LIFT DMY BK 0.000 0.0 10/28/1992 M INJECTION;9.6123 2 9,472.8 6,471.0 OTIS LB 11/2 GAS LIFT DMY RM 0.000 0.0 4/4/1992 3 9,612.3 6,564.3 OTIS LB 11/2 INJ DMY RM 0.000 0.0 1/4/1992 Notes:General&Safety End Date Annotation 10/23/2006 NOTE:PACKER LEAK @ 9569'HYDRAULIC PORT (PERF;9,639.09,672.0- 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 b SLEEVE-C:9.694.6 PACKER;9,706.0 SBE;9,709.7 NIPPLE;9.729.8 SOS;9.746 1 RPERF;9,887.0-9.902.0 IPERF;9,916.0-9,941.0 PRODUCTION:302-10,201.0 • 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 25, 2011 TO: Jim Regg 9 � � ' � P.I. Supervisor�j 2 5 It SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC 1R-26 FROM: Chuck Scheve KUPARUK RIV UNIT 1R -26 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry --- - 1t 2 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R - 26 API Well Number: 50 029 - 22193 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110522091146 Permit Number: 191 - 092 - Inspection Date: 5/21/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1R -26 . Type Inj. N T 6534 IA 410 1 2150 2100 i 2090 P.T.D1 1910920 - TypeTest SPT Test psi 1 1633 - OA 400 , 440 440 440 Interval 4YRTST ' P/F P - Tubing 1750 I 1775 1775 1750 Notes: Wednesday, May 25, 2011 Page 1 of 1 • `~ • • ConocoPhillips Alaska F.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~, ~ ~ ~ ~ µ. ~' ~ ~~ ~i':~ ~ . M~ w 4 .~~ u - • d ~ ~~ .' ~. SEP ~ ~ 2009 ~l~:~k~ ~e! ~ G~~ C~n~..~o€~~xo~t~ ~n~ha~~~ °l ~' o~ ~- 1 , ~.c~ ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of S~ndry Operations. The cement was puxnped August 15th and 23`d 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ./ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor , ~.._._.Y"___:. D ._.. . .,._'~ ; ~ ~ ~`~ ~ ~ ;; ? C,~g ~ ~ _, r _ d _ .~. ~.~ ~.... . ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 ~ Q ae n Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibkor Corrosion inhibitod sealant date ft bbls ft al 1 R-01 B 50029214040200 2001560 13'7" 2.0 26" 8/15/2U09 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28l2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009 1R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28/2009 1R-08 50029213330000 1850730 8' 1.00 21" S/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8i15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' S.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/152009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" S/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N1A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'4" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15l2009 13.9 SI29J2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8l23/2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1 R-35 50029230500000 2012100 18" N!A 18" N/A 5.3 8/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 S/29/2009. • Page 1 of 1 • Maunder, Thomas E (DOA) From: Peirce, John W [John.W.Peirce@conocophillips.com] Sent: Monday, January 26, 2009 4:25 PM To: Maunder, Thomas E (DOA) Cc: Wilmot, Kelli A Subject: RE: 1R-25 (191-092) Tom, We left the patch setting too( (fish} on top of the 1 R-25 patch when we set the patch. We were unable to release the setting tool after setting the patch, so we ended up having to pump a ball down the coil to get discannected. The setting tool has 0.875" flow through ID, and the patch min 1D is 1.125". It didn't seem like things were going to change much in terms of flow through ID, so we decided ra#her than go back and try fio fish out our setting tool that we should just leave it where it is. Our concern with trying to pull the setting tool is we could unseat the tubing patch in the process of fishing the setting tool. We rather leave it alone as long as the well will take enough injection rate. We can always try to pull the setting tool later if we decide we need to take the risk to get more PWI down the well, but we think we`re only going to be able to get about 500 BWPD down the well into the A sand. 0.875"' ID should be big enough to allow for this PWI rate. We needed 1-Coil to set this patch on depth and had to sefi it while I-Coil was available; although 1 R-25 is down until at least March awaiting the completion of flnw line repair to bring PWi to the well. Regards, ~~ I ~' John Peirce `~'~::t~,$]G w.~.%.~~~~ ., ~"~ ,,~ t;i 265-5471 office From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 26, 2009 10:10 AM To: Peirce, John W Cc: Wilmot, Kelli A Subject: 1R-26 (191-092) John, I am sending this to you since you signed both the 403 and 404. I am reviewing the 404 for the December patching operation. The last report date is 12/18 and at that time work is stopped with a fish in hole. Has any work been done since then? What are the forward plans? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 1 /27/2009 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION SAN ~ ~ 2009 REPORT OF SUNDRY WELL OPE~a~~as Cony r„~..__ 1. Operations Performed: Abandon ^ Repair Well Q Plug Pertorations ^ Stimulate ^ AIIG~~ ~ patch Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development ^ Exploratory ^ 191-092 / - 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22193-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 88', Pad 45' GL 1 R-26 " 8. Property Designation: 10. Field/Pool(s): ADL 25636' Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 10215' ~ feet true vertical 6973' feet Plugs (measured) Effective Depth measured 9695' feet Junk (measured) true vertical 6620' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 123' 123' SURFACE 5553' 9-5/8" 5593' 4080' PRODUCTION 10158' 7" 10201' 6963' Perforation depth: Measured depth: 9639'-9672', 9887'-9902', 9916'-9941' true vertical depth: 6582'-6604', 6750'-6760', 6770'-6787' Tubing (size, grade, and measured depth) 3.5" x 2-7/8", L-80 & J-55, 9714', 9747' MD. Packers &SSSV (type & measured depth) Baker'HB' retrievable pkr, Baker'D' permanent pkr 9569', 9706' Camco TRDP-1A SSSV 1799' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ ° Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^~ - GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-205 contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer a )•~ ~..-- Phone: 265-6471 Date ,~,~ ~~'"C;~~ Signature fi~ ~ ~ "" ~ ti Pre ar b Sharon AI( -Drake 2B3-4612 ~ ~ Form 10-404 Revised 04/2006 ,'~.~~ ~~..;arv ~ ~ ~O~c ~- ~ uo9 ( ja~ Submit Original Only ..~-~/~f `. -'~ KUP • 1 R-26 ~Of1t~C0~'1~~~1~75 ~~ Well Attributes Max Angle & MD TD W ellbora APIIU WI Field Name Well Status Protlllnj Type Inc! (°) 'MD (NKB) Act Bbn (ftK6) ~~`{s~'' `~P ~ 500292219300 KUPARUK RIVER UNIT ,INJ ~PWI 56.65 5,700.00 10.218.0 .. ... Comment H2S (ppm) (Data Annotation IEnd Data IKB-Grd (ft) (Rig Release Dah _. SSSV~ LOCKED OUT ' Last WO 42.99 7/24/7991 .___. ell_Canfg tR-26, 12/$N1(iOE a.6 `.'.44?U - ~ __ ____.. __ __ $tl1~ma7ic Acwal Annotation IiDepth (NKB) End Date (Annotation IEnd Date Last TaD~ SLM 10.049 0 7!162008 Rev Reason: TAG. SET INFLATABLE PAl CH ASSEMBLY 1 212 5 /20 0 8 ~ CANOUCT02 , _..___. _.. ._, ._.___ .__-_ __-__ - 3 36.00 J-55 SURFACE 95/8 8.765 0.0 5.593.0 4,081.3 -~ 26.OOIJ-55 PRODUCTION 7~ 6.151 0.0 10,201.0 6,964.5 sa~lrv,~e 1 799 Tubing Strings ~~ String OD i String ID Set Depth Set Depth (ND) ~ String Wt ' String ~ ~ String Top Thrd Tubing Description (in) (in) Top (NKB) (NKB) (NKB) (Ibs/N) G2da TUBING 3 1/2' 2.992 0.0 9,576.0 6,540.1' 9.30'', J-55 AB MOD EUE 'TUBING 31/2 ~ 2.992 9,576.0 9,714.0 6,632.7 9.30~L-80 iA8 MOD EUE GAS LIFT 3.zn $ TUBING 2718. 2.441 9,714.0 9,747.0 6,655.0. 6.SO~J-55 AB MOD EUE I O ther In Hole All Jewel Tubin Run 8 Retrievable, Fish etc-) _ _ To De M ~ (TVD) Top Inc! SURFACE, ~ TOp (NKB) (flK6) (°) I Description Comment Run Data ID (ir 5.593 7,798,0 1,733.4 31.541 Satery Valve ~Camco'TRDP-1 A' -LOCKED OUT Flow Tube of SSSV on 9/2/1997 2.81 5/13!94; Hyd. Control Line not Locked Out. GnsuFr. i 3,277.0 2,681.7 51.22 GAS LIFT ICAMCO/KBUG-M/1IDMY/BK///Comment: STA 1 10/28/1992 2.92 9.a73 9,473.0 6,471.1 48.00 GAS LIFT OTIS/LB/1.5/DMY/RM/// Comment: STA 2 4/411992 2.85 I 9,517 0 6,500.6 47.991 NIPPLE '~Otis'X' Selective Lantling NIPPLE 1/4/1992 2.81 - 9,556.0 6,526.7 47.99 PBR Baker 1/411992 3.OC 9,569.0 6,535.4 47.99 PACKER Baker'HB' RETRIEVABLE PACKER 1/4!1992 2.SS NIPPLE' 9x17 9,569.0 6,535.4 47.99 PATCH ~ INFLATABLE PATCH ASSEMBLY ~ 9569'-9574 PATCH & 12/18/2008 1.12 - '9584'-9586' w/ANCHOR & BLANK PIPE CONNECTING 'PATCHES (see drawing) -LEFT DISCONNECT ON TOP OF PATCH a~19568' PBR 9 556 ~ ~ ', 9 612.0 6,564.1 47.77 INJECTION OTIS/LB w/Red/1.5/DMY/RM/// Comment STA 3 1/4/1992 2.85 , . I ~ . , 9 695.0 6,619 9 47.63 SLEEVE-C Camco 'CB-1' Sliding; ShiRetl sleeve CLOSE 7/5/2008 9/1/1997 2.7E ~ . 9,706.0 6,627.3 47.61~ IPACKER ~IBaker'D'PERMANENT PACKER 1/4/1992 3.25 9,730.0 6,643.5 47.56 ~ I NIPPLE ~'', Otis 2 7/8"'XN' Nipple. 2.313 core, 2.25" NO GO ID 1/4/1992 2.25 4gCER. 9,569 - - ~ 9,747.0( 6,655.0: 47.54''i TTL TTL 9736' ELM, Ellne tag 9930' E / I, Perforations s i - '~, snot PATCH. 9,569 Top (TVD) Btm (TVD) ~ ~' Dens ~~. Too fft K61 ~. Btm INKBI (NKB( IHKeI Zone Date ~ (sh... HMX, 0 deg. ph INJECTION, _ 9.612 IPERF, 9,639-9.672 ~ACK.=.R.9,706- NIPPLE, 9.730 SOS. 9,766 - TTL, 9,767 IPERF, _ 9,916-9,901 PRODUCTgN, 10,201 TD. 10,218 - 1 R-26 Well Events Summary DATE SUMMARY 5/17/08 RAN EXPRO VIDEO LOG, DIS LACED WELL WITH NITROGEN FOR CL~ VIEW. INSPECTED AREA FROM THE SLIDING SLEEVE AT 9695' TO ABOVE THE UPPER PACKER AT 9569'. 7/5/08 BRUSH AND FLUSH FROM 9525' RKB TO 9625' RKB. CLOSE CB-1 SLIDING SLEEVE AT 9695' RKB. "C" SANDS ARE ISOLATED. COMPLETE. 7/10/08 PERFORM FCO USING SD, SD WITH MI LUBE 776 AND A 2" JSN. CLEAN FRAC AND FINE FORMATION SAND DOWN TO PBTD @ 10124' CTMD, EST. 185' OF RATHOLE., 7/16/08 BRUSHED AND FLUSHED PATCH AREA. TAGGED @ 10049' SLM. RAN 2.74" X 20' DUMMY PATCH TO 6266' WLM, TIGHT SPOT, UNBALE TO PASS. RAN DOUBLE 2.78" BROACHS (OAL 10') TO SAME, WORK TILL ABLE TO PASS. DUMMY DRIFT CONTINUES UNABLE TO PASS RESTRICTION. IN PROGRESS. 7/17/08 ATTEMPTED OPEN UPTIGHT AREA @ 6266' TO 6670' WLM WITH 2.795" BROACH. UNABLE TO PASS WITH 2.72" x 7' DRIFT. SUSPENDED. ~ 7/26/08 GAUGED TBG TO TTL @ 9698' SLM, 9747' RKB LOGGED PDS CALIPER SURVEY FROM 9750' SLM TO SURFACE. TOOL OPENED LATE, NO DATA FOR BOTTOM 700'. RERUN SURVEY FROM 9750' TO 7200'. TOOL FAILURE, NO DATA. IN PROGRESS. 7/27/08 LOGGED PDS CALIPER FROM 9750' TO 7375' SLM TO COMPLETE TBG SURVEY. 9/5/08 RAN 10' X 2.25" TO 9650' SLM. NO OBSTUCTIONS. JOB COMPLETE 12/18/08 SET ONE TRIP INFLATABLE PATCH AT 957' (I-COIL CCL vs. TUBING TALLY) CENTER ELEMENT OF TOP PACKER. UNABLE TO RELEASE FROM SETTING TOOLS, HAD TO DROP 5/8" DISCO BALL AND RELEASE LEAVING DISCO (2" GS FISH NECK),HANDLING PUP, CROSSOVER,AND HYD. RELEASE TOOL IN HOLE (1.93' ). TOP OF FISH AT 9568' I-COIL DEPTH. WELL LEFT SHUT IN AND FREEZE PROTECTED WITH DIESEL FROM 9500' TO SURFACE. (( COMPLETE)) • • >1~i~~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hoie/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~~~ ~~G ~ ~' ~~~$ 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1 ] Caliper Report 26,Ju1-08 1 R-26 1 Report / EDE 2] Caliper Report 25,Ju1-08 3H-26 1 Report / E~ 50-029-22193-00 50-103-20322-00 % ~' ~ - ~} ~ ' ~~~ $ (/ ra/ Signed : (i ~C~'~-!~'--`~~~ Date Print Name: ~y (,~-Pn~)-t ~,~ ~Vl.~{,:~,~~L~ - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8951 FAX: (907)245-88952 EaYNAIL r ~ a ,~,'~~ ,___ ~ _ ~~, WEBSITE . ~ „-- _ ~.;:;n C:\Documenls and Settings\Owner\Desktop\Tiansmit Conoco.doc • Memory Mu~t%Finger Gatip~r Log Results Summary Company: ConocoPhiliips Alaska, inc. Well: 1R-26 Log Date: July 2B, 2008 Field: Kupatuk Log No.: 7252 State: Alaska Run No.: 1 API No.: 50-029-22193-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 Tap Log Intel: Surtace Pipet Use: Tubing Bot Log Intel: 9,697 Ft. {MD) Pipet Desc.: 2.875" 6.5 Ib. J-55 Top Log Intvi: 9,697 Ft. (MD) Pipet Use: Tubing Tail Bot Log Intel: 9,736 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the WLEG @ 9,736' (ELMD). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5"tubing is in good condition, with the exception of a 24°~ wall penetration recorded in the 2.875" tubing tail, in a small section of isolated pitting in joint 309.5 (9,701'). No significant areas of cross-sectional wall loss (> 11%) are recorded. A sere bend restricts the minimum diameter to 2.62" between joints 201 and 202 (6,291'). A 3-D log plot of the caliper recordings across the severe bend between joirrts 201 and 202 is included in this report. The caliper recordings indicate buckling, increasing in severity with depth, from -•4,500' to 9,736'. MAXIMUM RECORDED WALL PENETRATIONS isolated Pitting ( 24%) Jt. 309.5 ~ No other significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 11%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS Severe Bend Minimum I.D. = 2.62" Jt. 201 No other significant I.D. restrictions are recorded. C 9,701 Ft. (MD) 6,291 Ft. (MD) Field Engineer W. McCrossan Analyst: C. Waldrop Witness: C. Fitzpatrick ProACtive Diagnostic Services, Inc. / P.O. Box 1359, Stafford, TX 7?497 Phone: {281) or (888) 565-9085 Fax: {281} 565-1369 E-mail: PDSC~memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 U~ ~ ~g r - c~2 ~ i ~5~f • ~~ PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 R-26 Date : July 26, 2008 Description : Detail of Caliper Recordings Across Severe Bend • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (40.9' - 9698.3') Well: Pipe 2 2.875 in (9698.3' - 9736.1') Field: Company: Country: Survey Date: 1 R-26 Kuparuk ConocoPhillips Alaska, Inc USA July 26, 2008 Approx. Tool Ucviation Approx. Borehole Profile 1 44 1535 GLM 1 3114 46 71 c 6229 -~ a a~ 7778 9303 GLM 2 INJ 1 309.9 9736 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 309.9 50 100 150 a~ E Z 200 ' o 250 300 ' -- • PDS Report Overview ~--. _--~--:.~~_ Body Region Analysis Well: 1 R-26 Survey Date: July 26, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 / 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro > Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 AB MOD EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of "oints anal sed total = 323 pene. 0 181 141 1 0 0 loss 71 251 1 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole J poss pitting comosion corrosion corrosion ible hole Number of ~oints dama ed total = 1 1 0 0 0 0 Damage Profile (% wall) ~ penetration body :ice metal loss body 0 50 100 n GLM 1 l`I A A 7 INJ 1 Bottom of Survey = 309.9 Analysis Overview page 2 ~ ~ PDS REPORT JOINTTABUUITION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1 R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. III „c• t (lnti.) Pen. Body (Ins.) 1'en. %, Metal I ~ „s ~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 41 t? 0.01 5 t? 2.9 PUP 1 44 I ? 0.0 ' 2.90 1.1 68 U 001 4 t? 2. 4 PUP 2 70 U 0 02 ~ > 2.92 3 96 t? 0.03 I t .92 4 1 5 U 0.02 2.93 155 I? 0.03 lU ~ 2.91 6 85 I i 0.01 b <' 2.92 7 216 t) 0.01 5 .92 8 247 t? 0.02 ~) I .93 9 8 t? 0. 2 ~~ 2.93 10 309 t? 0.02 t3 I 2.91 11 33 t? 0.03 12 2.92 12 371 tt 0.02 ~~ 2 13 1 t) 0.02 ~t 2.90 14 431 t? 0. ~ 2.90 15 460 t? 0.0 ii I .90 16 490 n 0.0 I U s 2.93 17 520 a 0.02 '? 1 2.9 551 t? 0.02 f3 2.9 19 582 t? 0.02 ~I _' 2.91 20 614 a 0.01 ~ I 2.90 1 645 U 0.02 9 _' 2.90 2 674 t1 0.03 1 .92 0 u ~ 1 9 24 736 t? 0.01 5 ? 2.92 25 767 t? 0.02 ~? 2.89 6 797 U 0.01 5 I 2.90 27 829 U 0. ~) 1 2.90 28 859 t? 0.03 Il I .90 9 ! -1 I 0 921 t l 0. 1 1 2.9 t ? (, 3 982 t? 0.02 '? _' 2.91 3 1014 t) 1 ~, ' 9 4 1045 U 0.01 ~ 2.90 10 U ~~ ' 6 1106 t) 0.02 '~ I .91 7 u v I 38 1166 U 0.0 I ~ I .90 97 u ~ 40 12 9 u 0.02 ~ I 2.9 4 t? 4 I 42 1292 (? 0. 1 ~ t? .93 4 t) I1 44 135 ~.? 0.03 It) 9 t? ' 46 1414 ~? 0.0 ~) 3 .91 47 43 I 48 1472 0.) 5 2. 3 _ Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft) Pc~n. l Il,tie~~ (Ins.) Pen. Body (Ins.) Pc~n. %> Metal I uss ,, Min. LD. (Ins.) Comments Damage Profile (% wall) 0 50 100 49 1503 t? 0.03 1O 2.91 50 1535 t) 0.01 ~ 2.93 51 1567 a 0.03 10 s 2.91 52 1598 t? 0.0 7 i 2.93 53 16 9 f? 0.01 ? 2.93 54 1 61 a 0.01 s i i 2.94 55 16 3 u 0.02 ti I 2.94 56 1724 t? 0.0 I "~ .93 57 1754 ?) 0.03 t ~ 2.94 57.1 1786 1? 0.01 i 2.91 PUP 57.2 179 u 0 U t? 2.81 Ca TR -ASS 57.3 1805 t ? 0.01 ~t I 2.90 PUP 58 1813 i) 0. 2 ') 2.89 59 1 44 U 0.03 II -I 2.94 60 1875 t? 0.02 ~) i 2.89 61 1907 )? 0.02 ti _' 2. 2 62 1935 t? 0.02 ~~ _' 2.94 63 1966 c? 0.01 ' _' 2.91 64 19 7 i? 0.03 11 ~' 2.9 65 2029 t) 0. 3 1 ; I .93 66 2059 t? 0.0 I Z 2.94 7 2089 t) 0.02 ~) 2.90 68 2120 t? 0.02 8 _' .95 69 2151 t ~ 0.02 ~) _' 2.90 70 180 t ~ .0 9 ~ .90 71 2212 a 0.03 I ~ I 2.94 72 2242 U 0.03 1(t 2.92 73 22 74 U 0.02 1 2 95 74 2306 a 0.03 11 ,' 2.93 75 2336 (1 0.03 13 _' 2.93 7 3 7 u 1 77 2397 t) 0.03 13 Z 2.90 7 4 8 t? I 79 2460 t? 0.03 13 I 2.92 491 u ~ 81 252 n 0.03 1Z ~' 2. 1 8 25 t) 9 i 9 83 2584 t? 0.03 12 ? 2.89 261 t t '> 2. 8 2646 n 0.02 ~~ 2.90 77 a 0. 3 , 87 708 i ? 0.03 1 U 2.90 7 9 t? 0 1l) I 89 2 7 70 t) 0.03 1 1 I 2.90 90 8 1 u 0.0 11 ~ .9 91 2832 U 0.03 13 I 2.91 4 l? I 93 2895 n 0.01 5 I 2 92 9 29 7 ~.? 03 t ' 2 90 95 29 8 ~ 0.01 2.92 Penetration Body Metal Loss Body Page 2 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft.) I'c•n. UFsc~l (In5.) Pen. Body (Ins.) Pen. % ~Ic•tal Luss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 29 9 I ~ 0.03 12 -1 2.90 97 3020 n 0.03 10 .89 98 3051 l1 0.01 5 _' 2.90 99 3083 ~~ 0.02 ~) 2.89 100 3114 a 0.02 ') I 2.88 101 3145 ~ ~ 0.04 15 2.90 102 3176 U 0.02 ~? _' 2.93 103 32 7 U 0.03 13 2.89 10 3239 U 0.02 9 I 2.80 Lt. De its. 104.1 3271 I I 0 U t) N A GLM 1 L tch ~ 4:30 10 32 78 I I 0.03 12 2 2.86 106 3309 U 0.04 14 2.91 107 3340 t) 0.02 7 2.91 108 33 ~~ 0.01 5 -1 2.91 109 3403 ~> 0.03 11 ~' 2.90 110 3434 ~ ~ 0.04 14 2.90 11 1 3465 I I 0.03 1 1 I 2.90 11 496 ~ I 0.0 1 1 I 2 9 113 3527 I I 0.03 I it 2.91 114 3557 U 0.01 4 I I 2.9 115 3588 I~ 0.01 (~ 2.93 116 620 t~ 0.02 ~~ 1 2.88 117 3650 ~ ~ 0.03 1 1 ~ ~ 2.89 118 3682 ~) 0.03 10 I 2.90 119 371 U .03 10 .9 120 3740 U 0.03 1 ~) 2.90 121 3771 n 0.04 15 2.93 1 2 3802 t) 0.03 1 1 I 2.90 123 3833 a 0.03 12 _' 2.93 124 3864 U 0.03 I!1 ~' .90 1 5 9 O ~) ' 1 126 3927 a 0.03 1±1 ? .91 1 7 U 0 9 s 9 128 3986 I I 0.04 1(; I .92 4017 a 0.03 11 13 4049 U 0.03 11 I .91 3 (~ .0 I 1 1 132 41 11 tl 0.03 i 1 I 2.90 13 ~ ~ 0.0 `_) s 9 134 4174 ~~ 0.03 t< _' 2.88 35 4 0 ~I • I 136 4234 ~) 0.03 1 t 2.91 7 7 U 1 4 I 138 4301 n 0.03 13 I 2.90 3 I) 0 1' ' 140 4362 ~ ~ 0.02 9 ~ 2.91 1 4 4 n 0 11 s 142 4425 ~~ 0.03 1O ! 2.91 144 4484 ~ 0.04 i ~ 2.91 Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINTTABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1 R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (FtJ I'"~n. I llxc~~ (In,.) Pen. Body (Ins.) Peen. °i~ "V1c~t,~l f v„ °"> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 1D0 1 5 4515 ~ ~ 0.04 15 I 2.89 Sli ht Bucklin 1 6 4545 ~) 0.0 13 I 2 90 147 4576 ~~ 0.02 3 2. 0 14 4608 O 0.03 1 Z 2.93 149 4639 (I 0.04 14 - .91 1 0 4671 c) 0.03 1._' -1 2.91 Sli ht Bucklin 151 4702 ~ I 0.03 I 1 2.91 152 4733 a 0.01 4 I 2.90 153 4762 (~ 0.0 I U ? .93 154 4794 (~ .02 ~) I 2.91 1 5 48 5 ~~ 0. la 1 0 SI' h uckli 156 4857 (~ .03 13 2.9 t De i s. 157 4888 a .02 t3 2. 2 158 4919 a 0.03 1 U I 2.90 159 4951 (~ 0.03 11 2. 0 160 498 U 0.01 6 I 2.91 Sli ht Buc lin 161 50 3 u 0.01 4 2.92 162 5045 (I 0.03 13 2. 1 163 5076 (~ 0.03 1t1 3 2.91 164 5108 ~I 0. 2 ~) Z 2.89 165 5139 (I 0.03 1O l) 2.94 Sli ht Buc lin 1 6 517 ~) 0.03 11 ~' .90 67 5200 U 0. 3 11 _' 2.92 168 5232 U .03 11 -I .91 1 9 52 3 t~ .03 1 ~) 2.89 170 5294 (I 0.02 ~) I 2. Sli h Bucklin 171 5325 (I 0.0 1Q .91 172 53 c) 0 02 ~) ' 2.88 173 5386 (I 0.03 10 -1 174 5417 O 0.0 t) ~ .90 1 5448 O 1 1 1 176 5478 ~ I 0.01 5 2.90 7 O 178 541 ~ I 0.04 1 5 _' 2.91 7 ) 9 180 5604 (~ 0 03 1O 2.90 Lt. e i Sli t B cklin . 1 5635 ~~ I U ' 182 5666 ~ I 0.02 ') I 2.90 u .03 I I a 184 729 a 0.02 9 4 2.91 1 7 (~ ~ 1 6 5790 a 0.04 I5 1 2.91 7 I 11 ' 188 58 3 (~ 0 0 ~) 2. 9 8 tl 15 G .9 190 5916 (I 0.0 8 ? 2.93 Sli ht ucklin 1 1 (1 i 19 5979 n 0.02 ~) ~ 2.90 1 6011 (I ~) 194 6042 (~ 0.01 ~ 2.92 ® Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINTTABUTATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft.) I'~~n. i lli~<~t (Irn.l Pen. Body (Ins.) P~~n. °'~, M~~t,~l I ~,,, ,~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 195 6074 t ~ 0.03 1 1 .89 Sli ht Bucklin 1 6 6106 ~ ~ 0 02 9 2.94 197 137 a 0.03 1 U 2.91 t. De sits. 198 6167 ! ~ .0 l ~ 2.91 199 6198 i ~ 0.03 1 1 ~ .93 200 6 9 ~ ~ 0.03 1 1 2.92 Sli ht B cklin 01 6261 t~ 002 9 2.62 Severe Ben . 20 6 91 U 0.02 9 .74 Sev e end. 0 6323 a 0.03 i I 2. 0 20 6354 U 0.02 £1 2.93 20 6385 U 1 ~ .89 t. De its. in . 6415 t) 0.02 ~) _' 2.91 207 447 U 0.03 1 U .90 08 478 O .03 11 s 2.9 09 651 t 1 0 03 1 t) I 2.88 21 5 1 U 0.03 1 9 89 Bu klin 211 6572 a 0.03 L~ 2.90 1 6603 a 0.0 I U 2.91 213 634 U 0.03 1 Z 2.9 t De sits. 214 6665 U .0 ti .90 15 696 (1 .02 ~) _' 2. 9 B c lin 2t6 67 6 u 0.03 tU 17 6758 i ~ 0.03 1 l) ! 2. 0 18 6789 a 0.03 1 i i 2.90 19 6821 U .03 11 _' 2.91 2 0 6 52 i~ 0.03 1 1 '~ 2.91 uckl'n 21 688 i ~ 0.0 t~ ~~l 2.9 22 6913 t ~ 0.03 1 t~ 2.90 223 644 U 0.02 ~) 2.90 22 6976 i ~ 0.03 I U -1 1 i1 0. '~ 26 7038 a 0.03 1 t I 90 70 t~ 4 I4 ' 228 7101 U 0.03 II .90 1 i> D ~) ' 30 7164 tt 0.03 13 4 2.92 uckli 1 1 0.0 1;' 4 232 7227 U 0.0 ~) d 2.91 7 t~ .0 1 234 8 cl 0. 4 I4 . 2 7 U 0. ~~ c 2 6 7350 n 0. 2 r3 I 2.93 8 i ~ .01 ~ I 23 7413 i ~ 0.03 L3 .91 4 3 t~ 1" ' 240 473 a 0.0 13 _> .90 Bucklin 41 5 t~~ 0 1 242 753 ~ ~ 0.03 1 Z 5 2.91 4 ~! 0. lU 44 7 95 ~ ! 0.03 1 I 2.91 Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1 R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft.) I'en. I ll,x~l (Ins.) Pen. Body (Ins.) I'en. °io :Metal I ~ ass ~ Min. LD• (InsJ Comments Damage Profile (% wall) 0 50 100 245 7626 U 0.0 14 2.88 B cklin 246 7656 n 0.02 7 ~ 2.91 24 7687 i I 0.03 12 ~ 2.89 48 7717 l) 0.03 1 "3 2 2.90 24 7748 ~~ 0.02 ~~ _' 2.90 250 7778 ll .02 9 ~~ 2.90 ucklin 251 7 09 (~ 0.03 1t1 _' 2.91 252 7839 a 0. 3 11 2.90 253 7869 (~ 0.02 ~~ ~' 2.92 254 7900 U 0.02 ~~ ~' 2.89 Lt. De sits. 255 7930 h 0.0 12 _' .90 Lt. De i s. Bucklin . 256 7960 ii 003 11 _' 2.88 257 7991 i~ 0.03 tU s 2.91 258 80 1 (~ 003 12 ~ .89 9 80 52 U 0.04 5 _' 2.91 260 8082 (1 3 1 _i ? 2.90 ucklin 61 81 13 l) 0.03 1 "~ ; .90 262 8143 (> .0 13 .90 Lt. De s'ts. 263 8173 li 0.03 13 2.91 264 8204 U 0.0 I1 ~' 2.89 65 $ 34 U 0.03 11 ? .90 B cklin 266 8264 a 0.02 9 _' 2.91 267 8295 a 0.04 14 4 2.90 268 8325 U 0 03 1 1 ~ 2.91 69 ci 4 14 ' 90 270 8387 ~~ 0.0 11 ' .9 Bu lin 71 8418 U .0 ~> > 2.90 272 8449 U 0.02 is ~ 2.91 273 8479 U 0.03 Il) 2 2.91 274 8508 a 0.0 Il) 3 2.90 85 U 0 t 1 4 .8 27 569 (t 0.0 I1 -1 2.89 6 0 U 1i 278 8630 i~ 0.0 1 i 2.89 86 1 n .0 1 1 I 280 8691 n .0 i~ 2.8 cklin 87 u 0 1 ~ s 82 753 i ~ 0.03 1 U 4 2.89 8 i~ 0. l~' .9 284 88 6 i 1 0.03 13 3 2.89 847 U 1~ U 286 8877 II 0.02 ~i z 2.90 7 908 i ~ I 1 ~; .87 88 8939 i ~ 0.04 ti 2.88 8969 I 3 1.3 ~' 88 90 8999 ~I 0.03 t~ .' 2.88 ckli (~ 9 ~ 1 292 9060 ~ ~ 0.02 8 2.91 293 9 9 .02 t3 90 294 9122 0.03 I ~ 2. 1 Penetration Body Metal Loss Body Page 6 s • PDS REPORT JOINTTABUTATION SHEET Pipe: 3.5 in 9.3 ppf J-55 AB MOD EUE Well: 1R-26 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 26, 2008 Joint No. Jt. Depth (Ft.) I'en. UI,.~~i i li ~,. i Pen. Body (Ins.) NPfI. °io Metal Less ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 295 9152 t~ 0.02 t~ 3 2.91 Bu klin 96 9182 ~~ 0.03 l? 2.93 297 9211 U 0.0 E3 _' 2.91 29 9242 (~ 0.0 I1 .89 29 9272 U 0.02 ~~ _' 2.91 300 9303 u 3 I1 2.91 Bucklin 30 9334 a 0.01 S _' 2.91 30 93 66 (~ 0.02 ~ ~ 2.92 303 9396 ~? 0.02 .92 304 942 ~ ~ 0.0 2.91 304.1 9459 t i 0.01 ~, ~ i .91 P P Bu klin . 304. 9466 ~~ 0 ~~ U N GL 2 Lath 1:00 304.3 9473 ~ ~ 0.04 14 _' 2.84 PUP 0 94 0 ~ ~ 0.01 ; ! 1 0 .1 951 ~~ 0 U i ~ 3. 1 O 's -N~ le 06 9 12 ~ ~ .02 ti 2.94 Bucklin 30 .1 954 ~~ 0 ~1 U .00 Baker P R 306 9 49 ~ ! 0.0 t3 I 2.96 PUP 3 6.3 9561 i ~ 0 O ~? 2.89 Ba er B aaker 307 9568 ~~ 0. 3 12 5 2.90 307. 9599 ~? 0. 3 13 3 2.86 PUP Bucklin . 307.2 960 U 0 l) U N A In'e lion andrel 1 atch ®12: 0 307. 9614 U 0.03 12 .'. 2.89 UP 08 9620 ~ ~ 0 1 U _' 2.93 6 n 1 " ~ .94 309.1 9681 ~~ 0.0 13 i~ 2.93 PUP Bucklin . 309.2 9688 ~~ 0 ~) i? 2.75 mco CB~1 Slidin SI eve 3 9.3 96 90 l ~ 0.04 I £3 ? .92 PUP 309.4 9697 U 0 U ~l N A 3.5" x 2.875" X-Over 309.5 9698 (~ 0.05 '~ ~ 2.39 UP I olated ittin . 0 97 n I) u 09.7 9707 t~ 0.04 It; 2.35 PUP Bucklin . 7 n u ~! 309.9 9724 u 2 is ~~ 2.35 PUP 0 n ~.) ~~ )Penetration Body Metal Loss Body Page 7 ~ ~ r! ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections Well: 1 R-26 Survey Date: July 26, 2008 Field: Kuparuk Tooi Type: UW MFC 24 No. 214320 / 218183 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 2.875 ins 6.5 opf I-55 AB MOD EUE ___Analyst: C. Waldrop Cross Section for Joint 309.5 at depth 9701.144 ft Too- speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 97 Tool deviation = 48 ° Finger 2 Penetration = 0.052 ins Isolated pitting 0.05 ins = 24% Wall Penetration HIGH SIDE = UP Cross Sections page 1 PDS Report Cross Sections Well: 1R-26 Survey Date: Jul 26 2008 Y Field: Kuparuk Tool Type: UW MFC 24 No. 214320 / 2181 83 Company: Conoco Phil-ips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf I-55 AB MOD EUE Analyst: _ C. Waldrop Cross Section for Joint 201 at depth 6291.31 ft Tool speed = 43 Nominal ID = 2.992 Upset OD = 3.5 Remaining wall area = 100 In upset region Tool deviation = 63 ° Finger 24 Radius = 1.296 ins Ovality Due To Severe Bending Minimum I.D. = 2.62 ins HIGH SIDE = UP • r LJ Cross Sections page 1 ConocoPhillips al~,,.~ ~:~~ SSSV. , ,99 GAS LIFT, 3.zn Sv1sw. 45,593 GAS UF7, 8,473 NIP, 9,517 PBR, 9,556 PKR, 9,569 6V.ECTION, 8,611 N'ERF, 9.638-9.6TI ;AEEVEC, 8,696 PHR.8706 NIP, 9,730 505, 9,746 rn. e.7a 1 t Ion 5113794; Hyd. Cantrd line not Lodcetl Oul I I I • • 6 Q ~ 6 SARAH PAL/N, GOVERNOR CUHSERQg A7I01~ O1rII II55IOH 333 W. 7th AVENUE, SUITE 100 -7aI Aii ~~`~~•~~~1ii~~•~~iiii----777 Dolil~` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John Peirce Wells Group Engineer ~~,ANN~t~ JUN ~. 9 2008 ConocoPhillips Alaska., Inc. PO Box 100360 Anchorage AK 99510 ~ ~ ~ 1 ~~ Re: Kuparuk River FYeld, Kuparuk River Oil Pool, 1 R-26 Sundry Number: 308-205 Dear Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pagerj. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2008 Encl. Q ,~~~~ U 9L/,- G ~ STATE OF ALASKA • ~.t ~(~•.y JUN a ALASKA OIL AND GAS CONSERVATION COMMISSION ~ VVV APPLICATION FOR SUNDRY APPROV -~as~a Oil & Gas ~~;; ,;,1 20 AAC 25.280 ~t1Ch0Y~$ 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ C Repair well ~~lug Perforations ^ Stimulate ^ Time Extension ^ `install t~~i f" ~atch Change approved program ^ Pull Tubing ^ Perforate New Pool ^ \ _ Re-enter Suspended Well ^ ~L:`s , Y~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 191-092 ' 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22193-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS NO ^~ 1R-26 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25636 RKB 88', Pad 45' GL Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Tota~~ p~h (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): rt• ~ •/ ~ 6973' 9695' 6620' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 123' 123' SURFACE 5553' 9-5/8" 5593' 4080' PRODUCTION 10158' 7" 10201' 6963' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9639'-9672', 9887'-9902', 9916'-9941' 6582'-6604', 6750'-6760', 6769'-6787' 3.5" X 2-7/8" J-55 9714', 9747' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER'HB' RETR. ; BAKER'D' PERM. pkr- 9569' ; 9706' Camco TRDP-1A 1799'- 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat June 16, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John P eir c e Title: Wells Group Engineer ,~ ~ + Signature LtJ '-"' Phone 265-6471 Date 6.. Q -+~ Commission Use Onl Co diti f l N tif i i th t C t ti it Sundry Number: 1 / (~ ~ n ons o approva : o y omm on ss so a a represen a ve may w ness 1~ l / Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subse uent Form Re uired: ~~~ ~ ~7 ~~~ ')~~ ~ ~ ~~~~ q q APPROVED BY ~ ~ ~~~ Ap roved b p Y COMMISSIONER THE COMMISSION Date: Form 10-4~3'~2evi~06/20~ y"'~ ~ ~1 ~ p I n ~ / Submit in Duplicate • • 1 R-26 Proposed Tubing Patch Installation Currently 1 R-26 is on PWI at 2400 BWPD with 100% entering the C sand through a leak ~ at the upper packer at 9574' RKB. A tubing patch will be set to isolate this leak and halt all C sand injection. A successful patch will convert 1 R-26 to `A sand only' PWI to provide support to offset A sand producers. A 10/23/06 (PROF with the C sand sliding sleeve closed shows 100% of PWI enters a leak at the upper Packer at 9574' RKB. The leak in the packer appears to be the lower hydraulic setting port near the base of the packer. The packer bore above the leaky port is 4.5' long and is a target landing a top packer of a tubing patch. The PBR is located immediately above the leaky packer, so the only location for the top patch packer is in the packer bore in order to avoid having to use an expansion joint in the patch assembly. A 20' 1-trip tubing patch will be set across the leak. Prior to setting a patch, the C sand sliding sleeve will be closed and a CT FCO will be performed to uncover A sand perforations. E-line will be used to locate the patch top on depth in the middle of the packer bore above the leak. Procedure: Slickline RIH & shift the C-sand Camco `CB-1' Sliding Sleeve closed at 9695' RKB. 2. Brush & flush 3.5" tubing at 9550 - 9600' RKB where a patch will be set. Coil Tubing 3. RIH with nozzle and perform a fill cleanout to as deep as possible to uncover the A sand perforation intervals at 9887 - 9902' and 9916 - 9941' RKB. The last tag was made 1/8/07 at 9695' RKB; 192' fill. E-line Install 20' OAL 1-Trip Retrievable Tubing Patch: 4. RIH with entire retrievable tubing patch straddle assembly consisting from bottom to top of a WLEG, 3-1/2" Straddle Packer, 16' of 2-3/8" spacer pipe, and 3-1/2" Straddle Packer. The tubing patch is run with a setting rod assembly installed inside the tubing patch. The setting tool string assembly consists from bottom to top of a setting rod, setting sleeve, and a setting tool. Log into position and set the top packer element at 9672' RKB, +/-1'.This location is in the middle of the upper 4' of packer bore in the leaky packer. Success of the patch job depends on setting the top packer on depth in a small window. This puts the upper straddle packer element ~2' from the top of the leaky Baker Packer and ~2' above the lower leaky hydraulic setting port of the Packer to complete the tubing patch at 9672 - 9692' RKB seal to seal. POOH. Rig down. JWP 6/10/2008 --.~.... ~ KRU 1 R-26 ~ CuncscoPh~lips Alaska Inc. .. 1 R-26 -- API: 500292219300 Well T e: INJ An le TS: 48 de 9558 SSSV Type: TRDP Orig 7/24/1991 Angle @ TD: 47 deg @ 10218 sssv Com etion: (17ss-18oo, Annular Fiuid: Last W/O: Rev Reason: ADD PERF OD:3.500) Reference Lo Ref Lo Date• Last U ate' 4/1/2007 Gas Lift i ndrel/Dum my Value 1 (32773278, OD:5.391) Gas Lift i ndrel/Dummy Value 2 (9473-9474, OD:5.953) NIP (9517-9518, OD:3.500) PBR (9556-9557, OD:3.500) PKR (9569-9570, OD:6.063) Injection i ndrel/Dummy Value 3 (9612-9613, OD:5.953) TUBING (9576-9714, OD:3.500, ID:2.992) SLEEVE-0 (9695-9696, OD:4.313) PKR (9706-9707, OD:6.063) NIP (9730-9731, OD:2.906) TUBING (97149747, OD:2.875, ID:2.441) SOS (9746-9747, OD:2.875) Perf (9887-9902) Pert (9916.9941) Last Ta : 9695' TD: 10218 ftK6 Last Tag Date: , 1/8/2007 Max Hole Angl e: 57 dec~(a) 5700 -- Casing String -ALL STRINGS _ Descri ion Size To _ Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 123 123 62.58 H-40 SUR. CASING 9.625 0 5593 4081 36.00 J-55 PROD. CASING 7.000 0 10201 6964 26.00 J-55 Tubing String - TllBING .(Tight Spot @ 6200 ', May be Overtorque d Tbg; (SEE WSR 3/25/92)) Size To Bottom TVD Wt Grade Thread 3.500 0 9576 6540 9.30 J-55 AB MOD EUE 3.500 9576 9714 6633 9.30 L-80 AB MOD EUE 2.875 9714 9747 . 6655 _. 6.50 J-55 AB MOD EUE ----- _. _.. Perforations Summary _ ___ _____ Interval TVD Zone Status Ft SPF Date T Comment 9639 - 9672 6582 - 6604 C-1 33 10 1/4/1992 (PERF 4.5" Cs Gun, 60 de h 9887 - 9902 6750 - 6760 A-4 15 6 2/18/2007 EPER 2 1/8" Power Enerjet HMX, 0 de . h 9916 - 9941 6769 - 6787 A-3 25 4 1/4/1992 (PERF 4.5" Cs~Gun. 180 deg. ph Gds Lift Mandrels/Valves _ St MD TVD Man Mfr Man T pe y V Mfr V T ype V OD Latch Port TRO Date Run Vlv Cmnt 1 3277 2682 Camco KBUG-M DMY 1.0 BK 0.000 0 0/28/199 2 9473 6471 Otis LB Otis DMY 1.5 RM 0.000 0 4/4/1992 Injection MandrelsNalves __ __ _ St MD TVD Man Mfr Man T pe y V Mfr V T ype V OD Latch Port TRO Date Run Vlv Cmnt 3 9612 6564 OTIS LB w/Red DMY 1.5 RM 0.000 0 1/4/1992 Other ( plugs equip., etc.) -COMPLETION _ Deprh TVD Type Description I 16 I 1799 1733 SSSV Camco TRDP-1A' -LOCKED OUT Flow Tube of SSSV on 5/13/94; Hyd. 2.812 NIP Otis'X' Selectivt PBR Baker PKR Baker'HB' Retr. 2.250 2.441 . MEMORANDUM TO: '?~ . i!¿¡,lOí Ì'\i1 0. \ '. I Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name: KUPARUK RIV UNIT IR-26 Insp Num: mitRCN0705I0213436 Rei Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Fnday, May 11,2007 SLBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lR-26 KUPARUK RIV UNIT lR-26 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-22193-00-00 Permit Number: 191-092-0 . \~ \ ~ 0 ~ ').-- Reviewed By: P.I. Suprv ~£....... Comm Inspector Name: Bob Noble Inspection Date: 5/912007 Packer Depth Pretest Well lR-26 ITypelnj. i w I TVD 1-- 6535 -IA 1360 I i I -+---------,.-j~-~--------:-- P.T.D' 1910920 ¡TypeTest , SPT i Test psi i 1633,75 1 OA I 690 1 Interva; -4~-RTST P/F P - 7~~---T~bing ì 2150 ' 2150 I ---L..__~,- Initial 2650 i 690 ! 15 Min. 30 Min. 45 Min. 2650 I 2650 i 60 Min. Notes: Friday, May 11, 2007 s<:;ANNED JUN 0 6 2007 :_,_,,_~H_"" 690 2150 690 +----...----- i ----_._----~- ._-~_._-- I _._~_.~--------- 2150 -- Page 1 of 1 Ç) 11/10/06 Sc~luIIIbel'gel' NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth :1 ~~ 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UTC- I Cj I -OCJ d. Field: Kuparuk Well Job# Log Description Date BL Color CD 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE WIDEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE WIDEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22106 1 1J·101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE W/DEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1 R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J·05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11104/06 1 30-07 11416222 INJECTION PROFILE 10/20106 1 2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31106 1 2~-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kr27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk \ ~ \... 0 q a- Scblumbel'gel' NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth v Field: Well Job # Log Description Date BL 1 Y -29 11213739 PRODUCTION PROFILE W/DEFT ~~- ("JC\' 04/28/06 1 3M-25A N/A SHUT IN 8HP I ct'-/ - aG~ 04/23/06 1 2N-303 N/A LDL ,';), 0 - I ¿.,C; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \~1-t13 04/25/06 1 3F-07 N/A INJECTION PROFILE I~":'-- (94,,;,,,- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT IC; "'1-('"7.~ 04/04/06 1 38-15 11213741 INJECTION PROFILE "i(:'{' - C' rl:)' 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT I "{~ - ;;::},.., \ 04/19/06 1 1 A-20 11235356 PRODUCTION LOG W/DEFT q 0 - lir. ';;} 04/26/06 1 1H-18 N/A INJECTION PROFILE ¡Ct '3- f':~Ò 04/24/06 1 1R-12 11213738 PRODUCTION LOG W/DEFT I ~5 -0'1?1 04/27/06 1 1Y-13 11213740 INJECTION PROFILE 1'"6~ - (") \ç' 04/29/06 1 2N-318 11213742 LDL dDO -100 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE I G) '1- -i'C,:?, 05/02/06 1 1G-01 11213744 INJECTION PROFILE ìÝd-- l;(t:> 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT ìC,G -li-I"(- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE j C1 I - ()~ '~ 05/05/06 1 2A-04 11249902 INJECTION PROFILE ì <â,. - Ii'=? 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I 1.f rl - ;)M-h 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE 1"(2,- ';Il'") 05/07/06 1 1G-14 11249904 INJECTION PROFILE ;4<-:(,-¡"{1 05/08/06 1 05/09/06 e Color CD e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: Dan Seamount Commissioner State of Alaska Alaska ~)il and Gas Conservation Commission DA'rE: September 28, 2000 THRU: Blair Wondzell P.I. Supervisor FROM: John Cris-~pp ~[,~ ~_,,_ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1 R Pad 17,18,19a,23,26 Kuparuk River Unit Kuparuk River Field Packer Depth ' Pretest Initial 15 Min. 30 Min. WellI 1R-17 I Typelnj. I G I T.V.D. I 6462 I Tubingl 3700 I3700 I 3700 I ~3700 J lntervalI '4 P.T.D.I 1911140 ITypetestl P .ITestpsil 16'~6 ICasing. I 1500I 2500I 2275I 2200 J P)F I --P' Notes: Pressure stabilized ~ 2200 psi. Monitored for one hour. 'We,,J 1R-18 I Type,,j.I N /T.V.D. 13182 I Tub,.gl I =,o'1=~o I=~o J lntervalJ 4. i P.T.D,.I 1910870 ITypetestI P ITest, psiI 796 I Casingl 900 I 1640 I 1600 I 15901 P/.F I_P Notes: '' we,,I 1R-lea I Type,.j.! s I T.V.D. I 6548 I I I I =~ I lntervaiJ'4 P.T.D.I 1910850 ITypetestl P ITestpsil 1637 ICasi~gI 1110 [ 1940I 1920 I '1920I P/F I .P" Notes: we,,I 1R-23 ITypelnj. I S ] T.V.D. 16713 ]Tubing! 2500 12500 I 2500 I=~°° I'nterva'l'4 P.T.D,I 1911010 ITypetestl P ITestpsil 1678 16asChgl 1100 I 1900 I 1875 I 1850 I P)F J P'" Notes: . we,,! 1R-26-ITypelnj.} S ] .T.V.D. ]6535 I Tubing} 2300 12300 ]2300 12300 I,nterVa,l'i4 P.T.D.I 1910920 ITypetestl P ITestpsil 1634 I CasingI 1220I 1720I 171oI 169oI P/F I P' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details I witnessed MIT's in the Kuparuk River Field on 1R Pad. The pressure on 1R-I7 stabilized @ 2200 test pressure, test was held for one hour. No failures witnessed. .I.T.'s performed: 5_ Attachments: pone Number of Failures: 0 Total Time during tests: 2.5 hrs. cc' MIT report form 5/12/00 L.G. MIT KRU 1Rb 9-28-00jc.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2 2000 P M E E L E W A TE R IA L U N D ER TH IS M A R K ER C:LO~IVtDOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 394' FNL, 137' FWL, Sec. 20, T12N, R10E, UM At top of productive interval 1347' FNL, 1217' FWL, Sec. 21, T12N, At effective depth 1402' FNL, 1627' FWL, Sec. 21, T12N, At total depth 1411' FNL, 1696' FWL, Sec. 21, T12N, R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 1 021 5 feet true vertical 6973 feet Effective depth: measured 1 0 1 2 1 feet true vertical 6909 feet 6. Datum elevation (DF or KB) RKB 88, PAD 45' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1 R-26 9. Permit number/approval number 91-92/94-133 feet 10. APl number 50-029-22193 11. Field/Pool Kuparuk River Field/ OilPool Plugs (measured) None Junk (measured) None ORIGINAL Casing Length Size Structural Conductor 1 2 3' 1 6" Surface 5544' 9 5/8" Intermediate Production 1 01 64' 7" Liner Perforation depth: measured 9639'-9672' true vertical 6581 '-6603' Cemented 331 SX AS I 1170 SX P F E & 530 SX Class G 250 SX Class G Measured depth True vertical depth 123' 123' 5593' 4080' 10201' 6963' , 9887'-9902', 9916'-9941' , 6748'-6758', 6768'-6785' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9575'; 3.5", 9.3#, L-80 @ 9575'-9714'; 2.875, 6.5#, J-55 @ 9714'-9748' Packers and SSSV (type and measured depth) PKR's: Baker HB @ 9569' & Baker D @ 9706'; SSSV: CAMCO TRDP-4A @ 1799', Camco Inj Valve @ 1758' 13. Stimulation or cement squeeze summary Install injection valve Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A RECEIVED OCT - 6 i994 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Da,ta~s[;a 0il & 6as Oon~;. 60mmisslo[ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Allc[~T::~b!pg Pressure x 10000 X 1000 3900 x 10000 X 1000 3900 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ ~----~ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY TIME DESCRIPTION OF WORK _ AT REPORT TIME FIE~ EST: E ~ INCOMPL~ AFC/CC _.¢-~.,,~ _ ACCUMULATED COST LOG ENTRY ~A'],~4/- -~'/4~ [~[~~HIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ITemp' AR3B-7031 Chill Factor oF OF tVisibility miles lWind Vel. 298-3486 REMARKS CONTINUED: SERVICE COMPANY SCA # DAILY ACCUM. TOTAL · ' Aac,hora~c TOTAL FIE~ ESTIMATE ~~ 7. ~~ y~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 995i0-0380 ?elephone 907 27.6 1215 May 19, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action 1 R-26 Variance (sssv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR051995 (w/o atch) AR3B-6003-93 242 2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program. Operation Shutdown __ Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance X Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 394' FNL, 137' FWL, SEC 20, T12N, R10E, UM At top of productive interval 1347' FNL, 1217' FWL, SEC: 21, T12N, R10E, UM At effective depth 1402' FSL, 1627' FWL, SEC 21, T12N, R10E, UM At total depth 1411' FNL, 1696' FWL, SEC 21, T12N, R10E, UM Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 88', PAD 45' GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-26 9. Permit number 91-92 10. APl number 50-029-22193 11. Field/Pool Kuparuk River Field/Oil Pool 12. Casing Length Structural Conductor 1 2 3' Surface 5 5 9 3' Intermediate Production 1 0 2 0 1 ' Liner Perforation depth: I 02 1 5' feet Plugs (measured) 6973' feet None 1 01 21 ' feet Junk (measured) 6 9 0 9' feet None Size Cemented Measured depth True vertical depth 1 6" 331 SX AS I 123' 123' 9-5/8" 1170SxPF E& 5630' 4101' 530 Sx Class G 7" 250 Sx Class G 1 0 21 5' 6 9 7 3' RE(Z£iVF[ measured 9639'-9672', 9887'-9902', 991 6'-9941' true vertical 6581'-6603', 6748'-6758', 6768'-6785' MAY 2 Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 9714' and 2-7/8" J-55 set at 9748' ~,~skaOil&GasCo~-~,~, Packers and SSSV (type and measured depth) Arichorag~; Pkr: Baker HB @ 9569' & Baker D @ 9706'; SSSV: Camco TRDP-4A SSSV @ 1799', Camco Inj. Valve @ 1758' 13. Attachments Description summary of proposal _X Detailed operation program __ nstall spring-controlled sub surface safety valve in injection well. 14. Estimated date for commencing operation ~ 15. Status of well classification as: May 13, 1994 I oi~ __ Gas 16. If proposal was verbally approved May 13,1994 Name of approver Russ Douglass Date approved Service WAG Injector 17. I hereby c~7 that ~J'i'~ foregoing is true and correct to the best of my knowledge. Si~ned "~ Title Sr. Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance __ - ¢ Mechanical Integrity Test _ Subsequent form require 10-.~ (~ BOP sketch Suspended IApproval No. Approved by order of the Commission Form 10-403 Rev 06/15/88 ,.,'~ginal Signed By ~avid W. J~hnston Commissioner Date SUBMIT IN TRIPLICATE Approveci Copy Returned Request for Variance Kuparuk Well 1R-26 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests written Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 1R-26. This injection valve will act as a one-way check valve allowing downward injection of water while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This well failed a closure test on May 13, 1994. After receiving verbal approval from the Commission, the existing SSSV flow tube was locked out, and a CAMCO injection valve with 1" bean was run to 1758' WLM. Subsequently, the well passed the closure test and injection resumed. RECEIVEr f~iAY 2 3 199,~ ,~:.~i~ u~l & Gas Cons. c0~,,,.~,;~.. Anchorage AOGCC Individual Well Geological Materials Inventory PERMIT DATA T 91-092 CBT L 91-092 CDN-LWD L 91-092 CDR-LWD L 91-092 CET L 91-092 INJP L 91-092 MWD-DGR/CNP(MD) L 91-092 MWD-DGR/CNP(TVD) L 91-092 MWD-DGR/EWR/FXE L 91-092 MWD-DGR/EWR/FXE L 91-092 407 R 91-092 DAILY WELL OP R 91-092 SURVEY R 91-092 SWC SUMMARY R 91-092 5024 T DATA_PLUS R1,8500-10092 R1~5591-10218 R1,5591-10218 R1,8500-10113 R1,9500-10050 R1-2~0-5630 R1-2,0-4122 R1-2,0-4122, TVD R1-2,0-5630, MD COMP DATE: 01/05/92 07/13/91-01/05/92 SS DIRECTIONAL 4448-5203 OH-DCR/CDN,5501-10153** Page: Date: 1 12/16/93 DATE_RECVD 09/16/1991 08/06/1991 08/06/1991 09/16/1991 05/06/1993 08/21/1991 08/21/1991 08/21/1991 08/21/1991 03/06/1992 03/06/1992 05/22/1992 08/21/1991 09/13/1991 Are dry ditch samples required? yes ~And rec.~ .e.eTr~yes no Was the well cored?~_7 & description received? yes~ Are well tests required? yes~3.~Received?~ Well is in compliance Comments yes ~ Alaska Oil Gas Conservation Commission 3~i]i Porcupine Drive Anchor~e, Alaska §§SI]1-3~ 92 907-279-1433 The following data is hereby acknowledged as being received: Copy sen~.~.o sender: Yes ~ No / STATE OF ALASKA AI_A~ OIL AND GAS CONSERVATION COMMk:x:,;ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging_ Pull tubing __ Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 394' FNL, 137' FWL, Sec. 21, T12N, R10E, UM At top of productive interval 1347' FNL, 1217' FWL, Sec. 21, T12N, R At effective depth 1402' FNL, 1627' FWL, Sec. 21, T12N, R At total depth 1411' FNL, 1696' FWL, Sec. 21, T12N, R 10E, UM 10E, UM 10E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 88 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-26 9. Permit oum_ber/a@proval number cj1_~2 / ~ 2..- Z.5 ( lO. AP! number 5o-02~)-221~3 11. Field/Pool Kuparuk River Oil Pool 1 021 5 feet Plugs (measured) None 6973 feet 4 feet Effective depth: measured 1 01 21 feet Junk (measured) None true vertical 6909 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 23' 1 6" 331 SX AS I 1 2 3' 1 23' Surface 5544' 9 5/8" 1170 SX PF E & 5593' 4080' Intermediate 530 SX Class G Production 1 01 6 4' 7" 250 SX Class G 1 0 2 01 ' 6 9 6 3' Liner Perforation depth: measured 9639'-9672', true vertical 6581 '-6603', 9887'-9902', 6748'-6758', 9916'-9941' 6768'-6785' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9575'; 3.5", 9.3#, L-SO @ 9575'-9714'; 2.875, 6.5#, J-55 @ 9714'-9748' Packers and SSSV (type and measured depth) PKR's' Baker HB @ 9569' & Baker "D" @ 9706'; SSSV: CAMCO T..,RD).P~, 13. Stimulation or cement squeeze summary ~'~ Convert well from oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A ~as~,~ 0il &/k~o~s 0o~s.. 14. Representative Daily Average Produotiu,, or ,njeotiorl'lJata~'~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 525 480 0 1200 185 Subsequent to operation - 0- -0- 5500 800 2200 15. Attachments Well Schematic Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended __ Service WAG Injector 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C. ~.~. ~ Title Form 10-404 Rev 09/12/90 Date '~'"//~ f~-.~ SUBMIT IN DUPLICATE ~<DgS i':IORi'qZN(~ WELL REPORT FOR 02/17/93 c-m,x-r LLs. TS P.:"TODUCTi(3i',i L*.~ELL STATUS 7" 1. 0 F T P F T T % P P hi P S I P S ! 209 288 ?? 75 i50 1280 300 209 2ii 72 2 45 1200 600 -209 2.-?:'-? ~32 6~} i00 i400 700 ~09 2i2 75 12 20 900 0 ,a ~ i 600 209 ........... ~-~ 40 1380 0 209 2 i '; i '="=' 60 209 2].,5. 37 2 20'9 164 27 0 PQ~ 21 ~ 57 0 209 203 7S 0 60 i480 1050~ 20 1330 500 60 1200 300 60 124.0 200 40 tO00. 150 40 820 300 59 1150 260 50 !200 400 GAS LIFT STATUS IGOR = 6500 ~AS OAS INO OPT OPT · ~ETER VOL RATE GL. READIN¢ MSCF MSCFD ROOTS 0 119 0 1434. 0 705 0 504 0 144.1 0 1422 0 41 0 1041 0 818 0 2089 0 876 0 793 0 1045 0 716 50 0 4 1266 4 6 400 1 4 3'71 1 3 1500 10 0 1500 10 2 837 33 4 746 2 7 678 2 3 2000 6 7 1000 1 8 721 4.8 1032 2.9 976 6.5 SI DA- H M R I S N C[ 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 TOTALS' 13044 13077 INJECTION t~]EL[_ STATUS W Z S E 0 T CFiQ~-{E L N A L E T 7" 10" PSi FTT PSi PS! INdECTION VOLUMES WATER RECMD (~AS [ h.l,] I hi d I N d METER VOl_ RATE VOL READtNO BBLS BWPD MHSCF SI DATA CODE 3 B SW 4 B SW 8 B SW 10 B gi 15 B SW 17 B SW 19 B SW 23 C SW TOTALS' 4.'"3 2 :". 2~- .,?0 ! E;O0~': 1 O0 40 2:}9.J. 7 ]. 24.00.~ ! OO 30 ~'i 47 ~? ! 780'.+ 380 '~r-,,o 21 '7 ! ,' .; ,. o~ ,. -620 ~ w' o.' 209 2!,57 7 l 860 30 100 .~o .... .... ~. ~ ~' i 300 200 I .... 3 S ........ 0 40 ¢: ~r-, '~ i ~:2.-1 -"'-' i 650 4.20 ! ¢:,'-, - _ _ .. '1'-: :_ -'...:¢: 73 400 0 i ,_, ,, ,:: ,, ,: .'~ 6 '~' .5'._,': 0 300 _i. O0 2156 5;D 780 200 ~ 0 4904 2789 O. 000 0000 0 4429 34-91 O. 000 0000 0 2212 3682 O. 000 0000 0 800 1045 0. 000 0000 0 497 821 O. 000 0000 '0 0 0 2.~21 0000 0 O 0 6.497 '0000 0 4286 4421 O. 000 0000 0 1848 2012 0.000 0000 0 383~ 2451 0. 000 0000 0 1115 0 O. 000 0000 0 5806~ 5899 O. 000 0000 29728 26611 8.918 Alaska, Oil a Gas C,0ns. O¢~is.s'to9 WALTER J. HICKEI.., GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 DECEMBER 29, 1992 WATTY STRICKLAND ARCO ALASKA INc. P O BOX 1900360 ANCHORAGE, ALASKA 99510 RE: 91-0114 KUPARUK RIVER UNIT 1R-17 91-0085 ' KUPARUK RIVER UNIT 1R-19RD 91-0092 KUPARUK RIVER UNIT 1R-26 91-0101 KUPARUK RIVER UNIT 1 R-23 DEAR MR. STRICKLAND, OUR FILES INDICATE THAT ARCO ALASKA INC. IS THE OPERATOR FOR THE REFERENCED WELLS. OUR FILES ARE MISSING PAPER WORK FOR THE CONVERSION OF THESE WELLS AS I MENTION DECEMBER 28, 1992 IN A CONVERSATION I HAD WITH VICTORIA FURGENSON. THESE WELLS HAD 403 SUNDRYS SUBMITTED EARLIER IN 1992 TO CONVERT THESE OIL WELLS TO WATER-INJECTORS AND OUR MONTHLY PRODUCTION REPORTS SHOW THESE WELLS WERE CONVERTED IN NOVEMBER AND AOGCC DIDN'T RECEIVE THE 404'S WHEN THE CONVERSION WAS COMPLETED. THIS MATTER NEEDS TO BE ' CORRECTED SO OUR FILE ARE CURRENT AND UP TO DATE. WOULD YOU PLEASE CHECK THIS PROBLEM AND FORWARD THE APPROPRIATE DOCUMENTS TO ME. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN C: ROBERT CRANDALL SR PETR GEOLOGIST STATE OF ALASKA ALAor,A OIL AND GAS CONSERVATION COMMIb,~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon suspend Alter casing _ Repair well_ Change approved program __X_ 2. Name of Operator Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing_ Variance _ Perforate _ Other 5. TyPe of Well: Development _ Exploratory _ Stratigraphic _ Service X ARCO Alaska. Ip6. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 394' FNL, 137' FWL, SEC 20, T12N, R10E, UM At top of productive interval 1347' FNL, 1217' FWL, SEC 21, T12N, R10E, UM At effective depth 1402' FSL, 1627' FWL, SEC 21, T12N, R10E, UM At total depth 1411' FNL, 1696' FWL, SEC 21, T12N, R10E, UM 6. Datum elevation (DF or KB) RKB 88', PAD 45' GL 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-26 9. Permit number ~)1 -~)2 feet 10. APl number 50-029-22193 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 1 021 5' feet Plugs (measured) 6 9 7 3' feet None 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Le n g t h Structural Conductor 1 2 3' Surface 5 5 9 3' Intermediate Production 1 0 2 01 ' Liner Perforation depth: measured 9639'-9672', true vertical 6581 '-6603', 1 0 1 2 1 ' feet Junk (measured) 6 9 0 9' feet None Size Cemented Measured depth True vertical depth 16" 331 SxAS I 123' 123' 9-5/8" 1170SxPF E& 5630' 41 01' 530 Sx Class G o,ass 104 1~ ~': ~V 9887'-9902', 991 6'-9941' 6748'-6758', 6768'-6785' Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 9714' and 2-7/8" J-55 set at 9748' Packers and SSSV (type and measured depth) Camco TRDP-4A i~J~'tsk~ 0il &ua.~"~'" Cons. C0r; SSSV ~ 1799', Baker HB Retr. Pkr ~ 9569' & Baker 35-32 D Perm. Pkr ~ 9706' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ Convert well from oil producer to WAG injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: October. 1992 Oil m Gas _ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned (_.'.(,~, ~ . T..i!!.e' ..E..n.qineer FOR COMMISSION USE ONLY Date c~/~l/O~ ~-' Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form require Approved by order of the Commission Form 10-403 Rev 09/12/90 ©ri~iP,~i Signed By O¢.v!d W, Johnston IApprova__J No. . ~o- '"/'~_~ ..-: ..,,.. SUBMIT IN TRIPLICATE Well 1R-26 Conversion to WAG Injection ARCO Alaska requests approval to convert Well 1R-26 from an oil producer to a WAG injector. This well will be operated as a Class II UlC well in compliance with Area Injection Order No. 2. Water and gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 9639' MDRKB and 9941' MDRKB This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. AR[ ALASKA INC. - KUPARUK , ,LD · we i~, :1 R-26 APl# 50-029-22193-00 Spud Date: 7-13-91 C Sand: CLCGED Completion Date: 1-5-92 ASand: OPEN Maximum HoleAngle: 56.7 deg. @ 5700' MD Original Rig RKB:4 0' All depths are MD-RKB to top of equipment. Well Tree Tree Tree Tree Last Type: WAG INJECTOR Type: FMC GEN IV 5000# Cap Type: Cap Size: Cap O-ring ASN: Workover Date: 1 - 5 - 9 2 Jewelry 1 SSSV: CAMCO TRDP-1A 2.812" ID @ 1799' 2 SLN: OTIS 'X' 2.813" PB ID @ 9517' 3 PBR: BAKER 3.0" ID @ 9556' 4 PKR: BAKER 'HB' RETR. 2.89" ID @ 9569' 5 PKR: BAKER 'D' PERM 3.25" ID @ 9706' 6 XOVER: 3 1/2" X 2 7/8" TUBING @ 9714' 7 NOGO: OTIS 'XN' NIPPLE 2.25" ID @ 9730' 8 SHEAR OUT: BAKER @ 9746' 9 TUBING TAIL: 2 7/8" TUBING @ 9747' Minimum ID:2.25" NOGO Casing and Tubing Pipe Tally Size Weight Grade Top Bottom Description 1 6" 6 5 # H-40 0 123' CASING 9 5/8" 3 6 # J - 5 5 0 5593' CASING 7" 26# J-55 0 1 0200' CASING 3 1/2" 9.3# J-55 0 9575' TUBING 3 1/2" 9.3# L-80 9575' 9714' TUBING 2 7/8" 6.5# J-55 9714' 9748' TUBING Gas Lift Information Depth Stn# Valve Type Sz. Latch Port Sz. AID# Date Run 3251' 1 KBUG-M O/V 1 " BK2 1 6/64" 06-20-92 9473' 2 LB D/V 1.5 RM 04-04-92 9612' 1 LB C, OM 1.5" RM 01-05-92 9695' 2 CAMCO CB-1 SLIDING SLEEVE(Closed) 05-09-92 5 6 7 8,9 Perforation Data Interval SPF Date Zone Comments ~, ,~ '~'-.~ 9639-9672 1 0 1/4/91 C :~',, "~-" ~'~:' '5 .... i'~' ~ ';" t ? 9887-9902 4 1/4/91 A 9916-9941 4 1/4/91 A Comments:Tight spot at 6299' RKB, may be overtorqued tubeing collar. See WSR 3-25-9~? ..... '~,~,,-~.-;~+.'~'~ LAST TAG' 10071' RKB 05-16-92 TD' 10215' PBTD: 10121' LAST REV' 07-9-92sas KRU 1R-26 SIDEWALL CORE SUMMARY PAGE 1 OF 2 COPY FOR STATE OF ALASKA ARCO 1 R-26 APl NO. 50-029-22193 T12N, R10E, SEC. 20, 137' FWL, 394' FNL (Surface) J. T. Eggert 8/1/91 4448'-5203' MD 90 Shot, 80 Rec. (89%) J~ Descri~3tion 4448 4449 4449 445O 4451 4452 4454 4454 4456 4456 4457 4458 4458 4459 4460 4460 4462 4467 4468 4469 4561 4561 4562 4562 4564 4565 4567 4568 4569 4572 4573 .4574 4575 4576 4580 4581 4601 4602 4603 4604 4613 4614 4659 4660 4660 4660 4660. Sandstone, porous, oil saturated Misfired Sandstone, porous, oil saturated Misfired No Core -- Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Misfired Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Mudcake Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Sandstone, porous, oil saturated No Core -- Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated KRU 1R-26 SIDEWALL CORE SUMMARY PAGE 2 OF 2 COPY FOR STATE OF ALASKA ARCO 1 R-26 APl NO. 50-029-22193 T12N, R10E, SEC. 20, 137' FWL, 394' FNL (Surface) J. T. Eggert 8/1/91 4448'-5203' MD 90 Shot, 80 Rec. (89%) ~ Description 4661 4662 4666 4667 4669 4707 4723 4774 4775 4776 4776 4777 4777 4778 4778 4779 4780 4861 4861 .4862 4862 4887 4888 4888 4889 4889 4890 4890 4891 4924 4925 4926 5004 5005 5006 5085 5087 5096 5106 5108 5202 5203 Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated No Core -- Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous Sandstone, porous, oil saturated Claystone Mudcake Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated No Core -- Bullet Empty Sandstone, porous Sandstone, porous, oil saturated Sandstone, porous Sandstone, porous, oil saturated Claystone Mudcake Sandstone, porous ARCO Alaska, Inc. Date: May 22, 1992 Transmittal #: 8442 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Receipt Acknowledged: Sub-Surface Directional 9 - 1 2 - 9 1 Survey Sub-Surface Directional 8 - 2 7- 9 1 Survey '~ ..... Date: D&M State_.9~:.A. asEa~¢(2" copies) 75076 75073 RECEIVED MAY 2 2 1992 Alaska 0il & Gas Cons. Commission Anchorage "~""" -' '""~--' STATE OF ALASKA 0 -~ ~ ~.~ A L :' :~ - AL^~KA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Welt ClassiticatJon of S~rvice Well OIL E~] GAS ~ SUnNeD ~ ABANDO~D ~ SERVICE ~ 2N~~ator 7 PenNer AR~ ~as~, I~ 91-92 3 Addm~ 8 ~1 ~ P.O. ~x 1003~, ~chora~, AK ~510~0 ~-~193 4 L~t~ d we, at sud~e ~: '~:.:~.:.:;:::~ :~:~,,.- -: ~J ~ 9 Un~ or L~ Na~ At T~ P~udng Inte~al ~ ~ ' 1~7' FNL, 1217' ~L, SEC21 T12N, R10E, UM/ : ..... ~,~ ~~~~-'~ 1R-~ At Total D~h ' ~ "~ ~ ~ ~' .- 11 Find and P~I 1411' FNL, 1696' ~L, SEC 21, T12N, R10E, UM KUPARUK RIVER FIELD 5 E~vat~n in f~t 0ndi~te KB, DF, etc.) ~ 6 L~ D~naion and ~1 ~. KUPARUK RIVER OIL POOL RKB ~', PAD 45' GL~ ADL 25~6, ALK 2569 12 D~e ~d~ 13 Dale T.D. R~ 14 D~e Co~.. Su~. ~ ~. J 15 Water D~th, ~ ofls~m 16 ~. of ~l~ns 07/13/91. 07~1 ~1. 1/5~2~ NA f~t MSL 1 17 Tolal D~ (MD+~) 18 Plug ~k ~th ~D+~) 19 Di~l S~ey ~ D~lh where ~V ~t ] 21 Th~e~ ~ ~fmst 10,215' MD, 6973' ~D 10,~21' MD, 6~9' ~D YES ~ ~ ~ 1799' f~ MDJ 1700' ~P~X ~ T~ El~t~ ~ ~her L~s Run CDNICD~G~CET ICBTIG YRO 23 CASI~, UNER AND CEME~I~ RECO~ S~I~ DE~H MD CASI~ SIZE ~. PER ~. GR~ TOP ~ ~LE SI~ CE~~ REC~D AMOU~ PULLED 16' 62.5~ H~ SURF 123' 24' 231 SX ASI 9-5/8' 3~ J-55 SURF 5593' 12-1/4' 1170 SX PF E, ~0 SX CLASS G 7" 2~ d-55 SURF 1~1' 8-1~' :250 SX CLASS G 24 Pe~orMio~ ~n to P~n ~D of T~ a~ ~om a~ 25 ~BI~ RECO~ inte~, s~e and nu~r) SI~ DE~ S~ (MD) PACKER SET (MD) 3-1~',9.~ / 2-7/8' 6.5~ 9705', 9747' 9~9', 9706' ~39' -~72' W/4-1/2' CSG GUN ~ 10 SPF MD 6~1'-~3'~ 9~7' -~2' W/4-1/2' CSG GUN ~ 4 SPF MD 67~'-67~' ~ ~ ACID, F~C~, GEME~ ~UEEZE, ~C ~16' -~1' W/~1/2" C~ GUN ~ 4 SPF MD 67~'-67~' ~ DE~ I~RV~ ~D) AMOU~ & ~ ~ MA~RIAL USED 27 PRODUCTION TEST Date Fimt P~u~n ~th~ d ~rai~ (F~wing, g~ ~, etc.) Date of T~I Ho~ T~I~ PR~UC~ON FOR ~OIUBBL GA~F WATE~BBL CHOKE SI~ CA.OIL RA~O ~ST PE~OD · F~wTub~g C~g P~e C~CU~TED OIL-BBL GA~F WATE~BBL OILG~-API (c~) Pre~. 2~R RA~ * 28 ~RE DATA . ~ ~ ' SEE A~ACHED ADDENDUM ..... Form 10-407 Rev. 7-1-80 Submit in duplicate GE-Ct_OGE) ~ FORN~TION TESTS NAN~ Include interval tested, pressure data, all fluids recoverd and gravity, k~r..AS. DEPTH TRUE VERT. DEPTH GOR, and time of ear phase. KUPARUK C TOP 9558' 6526' NA KUPARUK C BO'FrOM 9674' 6605' KUPARUK A TOP 9867' 6735' KUPARUK A BO'FrOM 10031' 6847' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS, CORE INFORMATION 32. I hereby certify that the f~egoing is true and correct to the best of my knowledge Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 1R-26 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25636 ALK 2569 50-029-22193 91-92 ACCEPT: 07/13/91 SPUD: 07/13/91 RELEASE: 07/23/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5954 WI: 55.252072 07/13/91 ( 1) TD: 300' ( 300) SUPV:KKL 07/14/91 ( 2) TD: 1700' (1400) SUPV:KKL 07/15/91 ( 3) TD: 3938'(2238) SUPV:KKL 07/16/91 ( 4) TD: 5579' (1641) SUPV:KKL 07/17/91 ( 5) TD: 5630'( 51) SUPV:KKL 07/18/91 ( 6) TD: 5630'( SUPV:JRR 0) 07/19/91 ( 7) TD: 8235'(2605) SUPV:JRR DRLG MW: 8.6 VIS: 65 MOVED RIG TO 1R-26. RUN INJ LINE. HOOK UP MUD LINES. ACCEPT RIG 1700 7/12/91. NU 20" HYDRIL AND DIVERTER SYSTEM. PU BHA, MWD, LWD. ORIENT NAVIDRILL. PIN BROKE ON XO FOR SPERRY-SUN COLLAR. WAIT ON XO. LOAD RA SOURCE. DRLD 123'-300' ADT 2.5 HR. DAILY:S65,690 CUM:$65,690 ETD:S65,690 EFC:$1,610,000 DRLG MW: 9.1 VIS: 46 DRLD & SURVEYED 300'-1700'. KICK OFF AT 500'. ADT 19.75 HR. DAILY:S52,194 CUM:$117,884 ETD:S117,884 EFC:$1,610,000 DRLG MW: 9.2 VIS: 42 DRLD 1700'-2198'. ADT 5 HR. CIRC. REPL BLOWER HOSE ON TOP DRIVE MOTOR. POH. PU BIT #2. SERVICE TOP DRIVE. RIH. DRLD 2198'-2231'. ADT .25 HR. TIGHTEN UNION ON MUD LINE. DRLD 2231'-3938'. ADT 10.5 HR. DAILY:S63,909 CUM:$t81,793 ETD:S181,793 EFC:$1,610,000 DRLG MW: 9.4 VIS: 42 DRL 3938'-4051'. ADT 0.75 HR. REPAIR HYDRAULIC CYLINDER ON TOP DRIVE. DRLD 4051'-5579'. ADT 20 HR. DAILY:S71,838 CUM:$253,631 ETD:S253,631 EFC:$1,610,000 RIH TO COND FOR CSG MW: 9.6 VIS: 46 DRLD 5579'-5630'. ADT .75 HR. CIRC. SHORT TRIP TO HWDP. RIH. LOG LWD 3959'- 5630'. CIRC. POH. RU SWS. RIH W/#1 SIDEWALL CORE GUN. WOULD NOT GO PAST WASH OUT AT 2230'. POH & CHANGE CENTR & ADD WEIGHT. RIH. SHOOT CORES. RIH W/#2 GUN SHOOT CORES. 90 CORES 4448'-5203', 3 MISFIRES, 3 NO RECOVERY. RD SWS. MU BHA AND RIH FOR WIPER TRIP FOR CASING. DAILY:S52,410 CUM:$306,041 ETD:S306,041 EFC:$1,610,000 FINISH NU BOP 9-5/8"@ 5593' MW: 9.8 VIS: 42 RIH TO 5630' CIRC. RAN 130 JTS 9-5/8" 36# J55 CSG. FS @ 5593', FC @ 5510'. CMTD W/ 1170 SX E W/ 1/4 PPS FLOCELE, 530 SX G W/ 2% CACL, 1/4 PPS FLOCELE. PLUG DID NOT BUMP. 8 BBL CMT RETURNS. ND DIVERTER. INSTALL 11-3/4" BTC X 11" 3M WELLHEAD. NU BOP. DAILY:S239,539 CUM:$545,580 ETD:S545,580 EFC:$1,610,000 DRLG 8-1/2" HOLE 9-5/8"@ 5593' MW: 9.3 VIS: 37 FIN TEST BOPE. SET WEAR RING. PU & ORIENT BHA & MWD. TIH. TAGGED FIRM CMT @ 5493'. TEST CSG TO 2000 PSI. DRLD CMT, FLOATS, 10' HOLE. LEAKOFF TEST TO 12.5 PPG EMW. DRLD 5640'-8235'. ADT 10 HR. DAILY:S70,054 CUM:$615,634 ETD:S615,634 EFC:$1,610,000 WELL: 1R-26 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 07/20/91 ( 8) TD: 9726' ( 1491) SUPV:JRR 07/21/91 ( 9) TD:10065' ( 339) SUPV:JRR 07/22/91 (10) TD:10215' ( 150) SUPV:JRR 07/23/91 (11) TD:10215' ( SUPV:JRR o) 07/24/91 (12) TD:10121' ( SUPV:JRR o) DRLG 8-1/2" HOLE 9-5/8"@ 5593' MW:10.5 VIS: 40 DRLD 8106'-9470'. ADT 10.25 HRS. CIRC BU. 15 STD SHORT TRIP. DRLD 9470'-9726'. ADT 7.25 HR. DAILY:S89,937 CUM:$705,571 ETD:S705,571 EFC:$1,610,000 DRLG 8-1/2" HOLE 9-5/8"@ 5593' MW:10.4 VIS: 41 DRLD 9726'-9760'. ADT 2 HR. CIRC BU. TOH. CHANGE BIT. TIH. DRLD 9760'-9850'. LOST PARTIAL RETURNS (150 BBL) . SPOT LCM PILL (FINE MICA). MONITOR HOLE. DRLD 9850'-10065'. ADT 5.5 HR. DAILY:S52,142 CUM:$757,713 ETD:S757,713 EFC:$1,610,000 RUN 7" CSG 9-5/8"@ 5593' MW:10.4 VIS: 41 DRLD 10065'-10215'. ADT 6 HR. CIRC BU. 15 STD S~ORT TRIP. CIRC & COND MUD. TOH FOR 7" CSG. UNLOAD LOGGING TOOLS & LD BHA. PULL WEAR RING. RU GBR CSG EQUIP. RUN 7" CSG. CIRC & COND MUD AT 9-5/8" SHOE. RUNNING 7 "CSG. DAILY:S190,052 CUM:$947,765 ETD:S947,765 EFC:$1,610,000 LD DP 7"@10201' MW:10.0 VIS: 36 FINSIH RUN 114 JTS 7" 26# J55 BTC CSG + MARKER JT + 130 JTS 7" 26# J55 BTCMOD CSG. CIRC W/ 50% RETURNS. PMP LCM & CUT MW F/ 10.4 TO 10.2 PPG. CMT W/250 SX G CMT W/ ADDITIVES. DID NOT BUMP PLUG. RECIP THROUGHOUT. HAD FULL RETURNS AT END OF CMT DISPL INTO ANNULUS. SET SLIPS. LD DP FOR INSPECTION. DAILY:S248,077 CUM:$1,195,842 ETD:S1,195,842 EFC:$1,610,000 RELEASE RIG 7"@10201' MW: 0.0 VIS: 0 ND BOP. FINISH CUT 7" CSG & INSTALL UPPER PACKOFF. NU 11"3000X7-1/16"5000 TBG HEAD AND 7-1/16"5000X3"5000 ADAPTOR FLANGE AND 3"5000 VALVE. TEST PACKOFF TO 3000 PSI. INJECT 70 BBL DIESEL IN 9-5/8"X7" ANNULUS. RR 7/23/91 11:00 MOVE TO 1R-24 DAILY:S16,982 CUM:$1,212,824 ETD:S1,212,824 EFC:$1,610,000 SIGNATURE: ~' ~'~' - ' DRILLING SUPERI NTF_~NT~ENT / ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 1R-26 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25636 ALK 2569 50-029-22193 91-92 ACCEPT: 01/03/91 SPUD: RELEASE: 01/05/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5954 WI: 55.252072 01/03/92 (13) TD:10121 PB:10121 SUPV:DB/LH 01/04/92 (14) TD:10121 PB:10121 SUPV:DB/LH RU SWS 7"@10201' MW:10.4 NaCl/Br ACCEPT RIG @ 0130 HRS, 1-3-92. ND DH TREE. NU BOP STACK AND TEST. RU SWS TO PERFORATE. DAILY:S19,536 CUM:$1,232,360 ETD:SO EFC:$2,842,360 POH W/6.05" GR/JB 7"@10201' MW:10.4 NaCl/Br SWS GENERATOR WENT DOWN,WAIT ON GENERATOR, PERFORATE 'A' AND 'C' SANDS AS PER PROCEDURE,CORRELATE DEPTHS TO CBT DATED 8-27-91,TEST LUBRICATOR TO 1500 PSI GUN#l: 9936-9941 AND 9916-9936,4 SPF, 180 DEG, GUN#2:9887-9902,4 SPF, 180 DEG, GUN#3/4:9652-9672,5 SPF, 60 DEG, GUN#5/6:9639-9652,5 SPF, 60 DEG, 82 BBLS FLUID LOST DURING PERF,RUN 6.05" GR/JB TO 10050'WLM, POH DAILY:S29,715 CUM:$1,262,075 ETD:SO EFC:$2,872,075 01/05/92 (15) TD:10121 PB:10121 SUPV:DB/LH RIG RELEASED AT 05:00 7"@10201' MW:10.4 NaCl/Br FPOH W/GR/JB,MU BAKER MODEL D PACKER AND TAILPIPE,RIH AND SET ON W/L AT 9695' WLM, RA_N PACKER SETTING BALL IN PLACE,POH RD SWS,RU TO RUN COMPLETION, RUN COMP AS PER PROCEDURE,MU SSSV AND C-LINE, TEST SAME TO 5000 PSI,CONT RIH W/COMP,STAB INTO PERM PKR, VERIFY POSITION W/500 PSI PUMP PRESS,SPACE OUT COMPLETION, MU HGR MU C-LINE TO HGR, TEST SAME TO 5000 PSI F/15 MIN, OK, RAN 32 SS C-LINE BANDS,LAND HGR, RILDS,PRESS TBG TO 2500 PSI TO SET RETR PKR, HOLD 10 MIN, PRESS ANNULUS TO 1000 PSI,HOLD F/10 MIN, BOLDS,PULL 120K# TO SHEAR PBR, RELAND HGR, RILDS,TEST SSSV W/500 PSI DIFF F/15 MIN,OK, TEST ANNULUS AND TBG TO 2500 PSI F/15 MIN, OK, PRESSURE TBG TO 3000 PSI TO SHEAR SOS,CLOSE SSSV, LD LANDING JT,SET BPV, ND BOPE NU TREE PULL BPV, SET TP,TEST PACKOFF TO 5000 PSI,OK, TEST TREE TO 5000 PSI,OK, PULL TP,OPEN SSSV, DISPLACE ANNULUS WITH 12 BBLS DIESEL, BULLHEAD TBG WITH 4 BBL DIESEL, SECURE WELL, RELEASE RIG AT 05:00 HRS,SITP=500,SICP=0 DAILY:S227,537 CUM:$1,489,612 ETD:SO EFC: $3,099,612 DATE: Alaska Oil & Gas Cons, Commission KRU .1R-28 SIDEWALLS-CORE;.~8UM~ARY., PAGE1 O1=2 COPY FOR STATE OF ALASKA ARCO 1 R-26 APl NO. 50-029-22193 T12N, R10E, SEC. 20, 137' FWL, 394' FNL (Surface) J. T. Eggerl 8/1/91 4448'-5203' MD 90 Shot, 80 Rec. (89%) ~ Description 4448 4449 4449 4450 4451 4452 4454 4454 4456 4456 4457 4458 4458 4459 4460 4460 4462 4467 4468 4469 4561 4561 4562 4562 4564 4565 4567 4568 4569 4572 4573 4574 4575 4576 4580 4581 4601 4602 4603 4604 4613 4614 4659 4660 4660 4660 4660.5 Sandstone, porous, oil saturated Misfired Sandstone, porous, oil saturated Misfired No Core - Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Misfired Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandslone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Mudcake Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Sandstone, porous, oil saturated No Core -- Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated KRU 1R-26 SIDEWALL CORE SUMMARY PAGE2~2 COPY FOR STATE OF ALASKA ARCO 1 R-26 APl NO. 50-029-22193 T12N, R10E, SEC. 20, 137' FWL, 394' FNL (Surface) J. T. Eggert 8/1/91 4448'-5203' MD 90 Shot, 80 Rec. (89%) ~ Descri_~tion 4661 4662 4666 4667 4669 4707 4723 4774 4775 4776 4776 4777 4777 4778 4778 4779 478O 4861 4861 4862 4862 4887 4888 4888 4889 4889 4890 4890 4891 4924 4925 4926 5004 5005 5006 5085 5087 5096 5106 5108 5202 5203 Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated No Core - Bullet Empty Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous Sandstone, porous, oil saturated Claystone Mudcake Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated Sandstone, porous, oil saturated · Sandstone, porous, oil saturated Sandstone, porous, oil saturated Claystone Sandstone, porous, oil saturated No Core - Bullet Empty Sandstone, porous Sandstone, porous, oil saturated Sandstone, porous Sandstone, porous, oil saturated Claystone Mudcai<e Sandstone, porous SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE J~ ONTINUOUS ~ OOL Company ARCO ALASKA, INC. Well Name 1R-26(394' FNL,137' FWL,SEC 20,T12N,R10E) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 75073 Loqqed By: JEFF FORMICA ~EcEIVED Date 27-AUG- 1991 I~.qAR - ~ I~9~. Computed Gas G0ns. fj0mmtss~.o~ R. KRUWELL ~nchora~ SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 27-AUG-1991 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: JEFF FORMICA Averaged deviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 81 DEG 3O MIN EAST COMPUTATION DATE: 5-NOV-91 PAGE 1 ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERT1CAL VERTICAL DEVIATION AZIMUTm DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES, HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DISI. AZIMUT~ FEET DEG/ O0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 70O O0 800 O0 900 O0 0 O0 100 O0 20o O0 300 O0 400 O0 499 99 599 92 699 68 799 13 897 74 -88 O0 12 O0 112 O0 212 OO 312 O0 411 711 809 0 0 N 0 0 E 0 3 N 1557 E 0 1 N 10 30 W 0 1 N 75 58 E 0 6 S 31 27 E 99 1 23 S 77 3~ E 92 2 49 S 75 18 E 68 5 4 S 78 ~ E 13 7 6 S 81 22 E 74 12 24 S 80 19 E 0 O0 -0 03 -0 01 -0 04 -0 04 0 87 4 50, 2 ', 7? 38 !7 0 O0 0 O0 0 O0 0 O0 0 om ; 6.' I 89 : 6' 3 3~ 6 45 0 O0 N 0 15 N 0 ~4 N 0 13 N 0 07 N C, 27 S 4595 7 2i S 0 O0 E 0 O0 W ,0 O1 E 0 02 W 0 03 w 0 84 5 4385 l! 09 E 21 33 E 37 52 E 0 O0 N 0 0 E 0 0 0 0 0 4 38 15 N 1 37 w 14 N 5 45 E 13 N 8 6 W 08 N 27 ~ W 89 S 71 57 E 53 S 75, 6 E 4z S 7.~ 4(; E 82 S 77 52 E 20 S 79 7 E 1000.00 994.21 906.21 17 9 S 78 54 E 64.36 1100.00 1089,43 1001.43 18 19 S 77 0 E 94.84 1200.00 1184.00 1096.00 19 38 S 74 10 E 127.16 1300.00 1277.77 1189.77 20 55 S 73 34 E 161.57 1400.00 1370.98 1282.98 21 17 S 74 4 E 197.45 1500.00 1464.21 1376.21 21 16 S 74 15 E 233.33 1600.00 1556.92 1468.92 23 27 S 75 34 E 270.54 1700.00 1646,98 1558.98 27 21 S 78 28 E 313.82 1800.00 1734.39 1646.39 31 35 S 80 18 E 362.29 1900.00 1815.80 1727.80 39 12 S 84 8 E 420.20 1 93 1 41 1 56 0 80 0 54 0 42 451 2 O5 7 20 7 3O 11.95 S 18.30 S 93 26.48 S 124 36.26 S 157 46.30 S 192 56.20 S 227 66.05 S 263 75.63 S 306 84.71 S 353 92.36 S 411 63 29 E 16 E 94 61 E 127 94 E 162 73 E 198 53 E 234 67 E 271 O0 E 315 66 E 363 06 E 421 64 41 S 79 lg E 94 S 78 53 E 40 S 78 0 E 05 S 77 4 E 21 S 76 29 E 36 S 76 8 E 82 S 75 56 E 21 S 76 7 E 66 S 76 32 E 31 S 77 20 E 2000.00 1889 41 1801 41 45 37 2100.00 1956 2200.00 2021 2300.00 2085 .2400.00 2145 2500.00 2205 2600.00 2265 2700.00 2327 2800.00 2389 2900.00 2452 i87 1868 76 1933 83 1997 90 2057 08 2!17 98 2t77 26 2239 72 2301 04 2364 87 49 36 76 49 21 83 51 3O 90 53 59 08 53 0 98 52 16 26 51 54 72 50 46 04 52 40 S 83 47 E 487.71 S 82 9 E 561.48 S 81 26 E 637.56 S 81 16 E 714 33 S 79 57 E 794 25 S 79 27 E 874 82 S 78 39 E 954 06 S 78 0 E 1032 96 S 77 8 E 1110 87 S 77 38 E 1188 85 4 55 3 30 1 29 4 79 0 85 1 81 0 59 I 28 1 15 2 17 99 15 S 478 31 E 488 48 S 78 17 E 108 119 130 144 158 173 189 2O6 223 25 S 551 32 S 626 66 S 702 Ol S 781 34 S 860 42 S 938 37 S 1016 21 S 1092 42 S 1168 53 E 562 81 E 638 74 E 714 55 E 794 87 E 875 73 E 954 13 E 1033 39 E 1111 67 E 1189 06 S 78 54 E 06 S 79 13 E 78 S 79 28 E 71 S 79 34 E 31 S 79 35 E 62 S 79 32 E 63 S 79 27 E 68 S 79 19 E 83 S 79 11E 3000.00 2512 11 2424 11 53 3 3100.00 2572 3200,00 2633 3300 O0 2695 3400 O0 2757 3500 O0 2818 3600 O0 2877 3700 O0 2937 3800 O0 2999 3900 O0 3061 38 2484 09 2545 57 2607 38 2669 48 2730 47 2789 81 2849 12 2911 09 2973 38 53 7 09 51 32 57 51 23 38 52 5 48 53 15 47 53 48 81 52 17 12 51 58 O9 5O 46 S 77 3 E 1268 60 S 76 15 E 1348 S 75 37 E 1427 S 74 50 E 1504 S 73 59 E 1582 S 76 13 E 1661 S 77 14 E 1741 S 76 45 E 1821 S 76 29 E 1900 S 78 59 E 1978 10 19 80 8O 39 89 38 O8 4O 1 02 0 96 1 65 0 72 0 85 4 62 1 09 0 43 1 05 3 48 240.78 S 1246.71 E 1269 75 S 79 4 E 259.28 S 1324.32 E 1349 278.57 S 1401.41 E 1428 298.44 S 1476.91 E 1506 319 65 S 1552.61 E 1585 340 60 S 1628.94 E 1664 358 72 S 1707.62 E 1744 376 69 S 1785.31 E 1824 395 13 S 1862.13 E 1903 411 60 S 1938.85 E 1982 47 S 78 55 E 83 S 78 45 E 77 S 78 35 E 17 S 78 22 E 16 S 78 11E 89 S 78 8 E 62 S 78 5 E 59 S 78 1 E 06 S 78 I E ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 5-NOV-91 PAGE 2 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3126.09 3038 09 48 33 4100 4200 4300 4400 4500 4600 4700 4800, 4900 O0 3192.46 3104 O0 3257.83 3169 O0 3320.40 3232 O0 3382.60 3294 O0 3445.01 3357 O0 3505.73 3417 O0 3564.74 3476 O0 3623.87 3535 O0 36B3.43 3595 46 48 22 83 5O 31 4O 51 38 60 51 13 O~ 51 34 73 53 43 74 53 47 87 53 37 43 53 13 S 78 54 E 2054 30 S 78 4 E 2129 S 78 12 E 2204 S 79 12 E 2282 S 78 42 E 2360 S 78 12 E 2438 S 79 16 E 2518 S 79 1 E 2598 S 78 37 E 2679 S 78 11 E 2759 O0 53 4,4 66 68 03 7O 26, 47 0 55 0 87 3 03 0 44 1 67 1 40 1 27 0 36 0 69 0 45 426.19 S 2013 42 E 2058.03 S 78 3 E 441.04 S 2086 456.82 S 2160 471.99 S 2237 486.92 S 2314 502.62 S 2390 518.22 S 2468 533.30 S 2547 548.96 S 2626 565.10 S 2705 73 E 2132.83 S 78 4 E 74 E 2208.50 S 78 4 E 25 E 2286.49 S 78 5 E 13 E 2364.78 S 78 7 E 65 E 2442.91 S 78 8 E 55 E 2522.36 S 7~ 9 E 86 E 2603.07 S 7E, ~i E 97 E 2683.72 S 78 ~2 E 66 E 2764.0,4 S 78 12 E 5000.00 3743 23 3655.23 53 26 S 78 2 E 2839.47 5100.00 3802 5200.00 3860 5300.00 3917 5400.00 3972 5500.00 4028 5600.00 4084 5700.00 4139 5800.00 4195 5900.00 4251 55 3714.55 53 49 71 3772.71 55 9 12 3829.12 56 3 90 3884.90 56 3 87 3940.87 56 2 33 3996.33 56 29 16 4051.16 56 39 10 4107.10 55 30 82 4163.82 55 26 S 77 54 E 2919.83 S 80 1 E 3001.07 S 80 28 E 3083.62 S 79 46 E 3166.59 S 79 9 E 3249.41 S 78 57 E 3332.54 S 79 9 E 3416.09 S 80 9 E 3498.92 S 80 58 E 3581.27 0.54 0.84 2.59 0.80 0.52 0.78 1 .04 1 .65 1 .25 0.49 581 73 S 2784.07 E 2844 19 S 78 12 E 598 614 628 642 657 673 689 704 717 42 S 2862.82 E 2924 42 S 2942.57 E 3006 08 S 3024.00 E 3088 39 S 3105.75 E 3171 55 S 3187.23 E 3254 45 S 3268.90 E 3337 38 S 3351.00 E 3421 40 S 3432.51 E 3504 81 S 3513.77 E 3586 70 S 78 12 E 03 S 78 12 E 53 S 78 16 E 49 S 78 19 E 35 S 78 2t E 55 S 78 22 E 17 S 78 23 E 04 S 78 24 E 34 S 78 27 E 6000 O0 4306 57 4220 57 55 23 6100 6200 6300 64O0 6500 6600 6700 6800 6900 O0 4365 37 4277 O0 4422 28 4334 O0 4479 23 4391 O0 4535 98 4447 O0 4593 80 4505 O0 4652.86 4564 O0 4711.86 4623 O0 4770.84 4682 O0 4829.70 4741 37 55 24 28 55 18 23 55 20 98 55 27 80 53 51 86 53 47 86 53 53 84 53 52 70 54 1 S 81 16 E 3663.61 S 81 32 E 3745.91 S 81 46 E 3828.14 S 81 56 E 3910.33 S 82 12 E 3992.67 S 83 42 E 4074.22 S 83 48 E 4154.86 S 83 58 E 4235.52 S 84 3 E 4316.21 S 84 4 E 4396.97 0 27 0 18 0 19 0 37 0 82 0 58 0 29 0 06 0 09 0 32 730.51 S 3595 12 E 3668 59 S 78 31 E 742.80 S 3676 754.78 S 3757 766.45 S 3839 777.84 S 3920 787.84 S 4001 796.61 S 4081 805.24 S 4162 813.66 S 4242 822.04 S 4322 50 E 3750 85 E 3832 22 E 3914 76 E 3997 73 E 4078 95 E 4158 22 E 4239 54 E 4319 95 E 4400 79 S 78 35 E 90 S 78 39 E 97 S 78 43 E 17 S 78 47 E 5,4 S 78 52 E 95 S 78 57 E 4O S 79 3 E 86 S 79 9 E 41 S 79 14 E 7000.00 4888.60 4800 60 53 35 7100.00 4948.52 4860 7200.00 5009.36 4921 7300.00 5072.08 4984 7400.00 5134.90 5046 7500.00 5197.81 5109 7600.00 5260.75 5172 7700.00 5323.57 5235 7800.00 5386.25 5298 7900.00 5448.81 5360 52 53 5 36 51 32 O8 51 4 90 51 4 81 51 0 75 51 1 57 51 9 25 51 13 81 51 20 S 84 32 E 4477 69 S 85 19 E 4557 S 86 25 E 4636 S 86 56 E 4714 S 87 17 E 4791 S 87 36 E 4869 S 88 1 E 4946 S 88 25 E 5023 S 88 53 E 5100 S 89 14 E 5178 6O 74 30 73 O5 29 56 86 20 1 89 0 22 251 0 18 0 56 0 36 0 32 0 28 0 36 0 30 830 22 S 4403 34 E 4480.93 5 79 19 E 837 843 847 851 854 857 860 862 863 13 S 4483 08 S 4562 48 S 4640 43 S 4717 92 S 4795 88 S 4873 30 S 4950 12 S 5028 40 S 5106 10 E 4560.59 S 79 25 E 24 E 4639.48 S 79 32 E O0 E 4716.76 S 79 39 E 70 E 4793.92 S 79 46 E 36 E 4870.97 S 79 53 E O1 E 4947.95 S 80 1 E 78 E 5024.97 S 80 9 E 67 E 5102.04 S 80 16 E 68 E 5179.15 S 80 24 E ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 5-NOV-91 PAGE 3 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN BO00 O0 5511 19 5423 19 51 29 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5573 O0 5637 O0 5701 O0 5765 O0 5829 O0 5894 O0 5959 O0 6024 O0 6089 48 5485 05 5549 19 5613 60 5677 88 5741 09 5806 O0 5871 25 5936 69 6001 48 51 8 05 50 11 19 49 59 60 49 54 88 50 09 49 54 O0 49 20 25 49 15 69 49 4 S 89 34 E 5255 62 S 89 31E 5333 5 87 35 E 5409 5 87 26 E 5485 $ 87 34 E 5562 S 87 44 E 5638 S 87 30 E 5714 S 84 37 E 579O S 84 45 E 5865 S 85 19 E 594~ O6 67 ,98 06 23 44 2"7 93 40 0 33 2 12 0 73 0 24 0 47 0 23 ~ 25 0 66 041 0 39 864 21 S 5184.83 E 5256.36 S 80 32 E 864 866 870 873 876 879 885 892 898 69 S 5263.06 E 5333.62 S 80 40 E 74 S 5340.22 E 5410,10 S 80 47 E 20 S 5416 86 E 5486.31 S 80 52 E 54 S 5493 28 E 5562 30 S 80 58 E 72 S 5569 82 E 5638 40 S 8~ 3 E 82 S 5646 42 E 5714 55 S 8~ 9 E 13 S 5722 29 E 5790 34 S 8i !2 E 20 S 5797 74 E 5865 98 S 8~ 15, 5 75 S 5873 07 E 5941 44 S 8~ 18 E 9000 O0 6155 26 6067 26 48 50 9100 9200 9300 94O0 9500 96O0 9700 9800 9900 O0 6221 O0 6288 O0 6354 O0 6421 O0 6488 O0 6555 O0 6622 O0 6689 O0 6757 54 6133 12 6200 48 6266 22 6333 11 6400 09 6467 18 6534 77 6601 39 6669 54 48 16 12 48 18 48 48 17 22 48 2 11 48 0 09 47 59 18 47 37 77 47 27 39 47 14 S 85 33 E 6016 72 S 85 48 E 6091 S 83 53 E 6165 S 82 6 E 6240 S 81 50 E 6315 S 81 47 E 6389 5 81 56 E 6463 S 82 0 E 6537 S 82 16 E 6611 S 82 36 E 6685 41 85 65 12 45 7O 85 55 21 1 02 0 42 3 79 0 36 0 09 041 018 0 88 041 1 16 904.74 S 5948 33 E 6016 74 S 8~ 2: E 910.43 S 6023 916.53 S 6O97 926.21S 6171 936.68 S 6245 947.32 S 6318 957.86 5 6392 968.24 S 6465 978.38 S 6538 988.17 S 6611 O0 E 6091 42 S 8i 24 E 35 E 6165 85 S 81 27 E 54 E 6240 65 S 81 28 E 27 E 6315 12 S 81 28 E 83 E 6389 45 S 81 28 E 34 E 6463 70 S 81 29 E 76 E 6537.85 S 81 29 E 76 E 6611.55 S 81 29 E 77 E 6685.21 S 81 30 E 10000.00 6825.65 6737.65 46 49 S 82 50 E 6758.27 10100.00 6894.25 6806.25 46 44 S 82 35 E 6831.02 10200.00 6962.78 6874.78 46 44 S 82 35 E 6903.83 10215.00 6973.06 6885.06 46 44 S 82 35 E 6914.75 0.21 0.00 0.00 0.00 997.30 S 6684.28 E 6758.27 S 81 31 E 1006.58 S 6756.45 E 6831.02 S 81 32 E 1016.00 5 6828.66 E 6903.83 S 81 32 E 1017.41 S 6839.49 E 6914.75 S 81 32 E ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 5-NOV-91 PAGE 4 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 994 2000 O0 1889 3O0O O0 2512 4OOO O0 3126 5000 O0 3743 600O O0 4308 7000 OO 488~ 8000 O0 55i~ 9000 O0 6155 21 906.21 17 9 S 78 54 E 64 41 1801.41 45 37 S 83 47 E 487 11 2424.11 53 3 S 77 3 E 1268 09 3038,09 48 33 S 78 54 E 2054 22 3655.23 53 26 S 78 2 E 2839 57 4220.57 55 23 S 81 16 E 3663 6G 480C.6G 53 35 S 84 32 E 4477 19 5423.19 51 29 S 89 34 E 5255 26 6067.26 48 50 S 85 33 E 6016 0 O0 -88.00 0 0 N 0 0 E 0 O0 36 71 6O 30 47 6~ 67 62 72 0 O0 1 93 4 55 1 02 0 55 0 54 0 27 1 89 0 33 1 02 0 O0 N 11 95 S 63 99 15 S 478 240 78 S 1246 426 19 S 2013 581 73 S 2784 730 51 S 3595 83O 22 S 44O3 864 21 S 5184 904 74 S 5948 0 O0 E 0.00 N 0 0 E 29 E 64.41 S 79 19 E 31 E 488.48 S 78 17 E 71 E 1269.75 S 79 4 E 42 E 2058.03 S 78 2 E 07 E 2844.19 S 78 12 E 12 E 3668.59 S 78 31 E 34 E 4480.93 S 79 19 E 83 E 5256.36 S 80 32 E 33 E 6016.74 S 81 21 E 10000.00 6825.65 6737.65 46 49 S 82 50 E 6758,27 0.21 997.30 S 6684.28 E 6758.27 S 8! 31 E 10215.00 6973.06 6885.06 46 44 S 82 35 E 6914.75 0.00 1017.41 S 6839.49 E 6914.75 S 8t 32 E ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 5-NOV-91 PAGE 5 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTm DEPTH DEPTH DEPTH DEG MIN DEG MIN ENGINEER: JEFF FORMICA 0 O0 88 O0 188 O0 288 oo 388 O0 488 O0 588 06 688 28 788 79 890 05 0 0 N 0 0 E 0 3 N 27 45 E 0 1 N 26 7 E 0 1 S 63 30 E 0 5 S 18 1E O0 1 10 S 75 52 E O0 2 37 S 75 16 E OC 4 52 S 77 28 E O0 6 46 S 81 19 E O0 11 45 S 80 24 E -88 O0 O0 O0 O0 O0 0.00 88.00 0 188.00 100 288.00 200 388.00 300 488.00 400 588.00 500 688.00 600 788.00 700 888.00 800 S 79 0 E S 77 2 E S 74 5 E S 73 37 E S 74 5 E S 74 28 E S 76 46 E S 79 1 E S 83 3 E S 83 49 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTN FEET DEG/IO0 FEET FEET FEET DEG MIN 993 51 1098 1204 1310 1418 1525 1634 1746 1864 1997 988.00 900 O0 17 O0 18 18 O0 19 42 O0 21 0 O0 21 14 O0 21 25 O0 25 10 O0 28 36 O0 36 39 O0 45 32 49 1088.00 1000 25 1188.00 1100 95 1288.00 1200 26 1388.00 1300 54 1488.00 1400 12 1588.00 1500 43 1688.00 1600 70 1788.00 1700 97 1888.00 1800 0 O0 -0 03 -0 01 -0 04 -0 05 0 61 3 93 10 36 20 41 36 12 62 47 94 37 128 58 165 44 204 02 242 56 284 53 335 55 398 46 486 25 2148 18 1988.00 1900 O0 49 34 47 2088.00 2000 45 2188.00 2100 O0 2288.00 2200 28 2388.00 2300 81 2488.00 2400 05 2588.00 2500 88 2688.00 2600 80 2788.00 2700 75 2888.00 2800 O0 51 38 O0 53 30 oo 52 20 O0 50 46 O0 53 13 O0 53 12 O0 51 21 O0 52 7 O0 53 30 2303 2471 2636 2797 2959 3126 3287 3449 3617 S 81 33 E S 81 13 E 717 S 79 4O E 851 S 78 28 E 982 S 77 8 E 1108 S 77 28 E 1236 S 76 9 E 1368 S 74 56 E 1495 S 74 21 E 1621 S 77 10 E 1756 598 24 04 95 5O 77 54 86 40 74 14 S 76 19 E 1885 92 3781.95 2988 O0 2900 O0 51 58 O0 3000 O0 3100 O0 3200 O0 33OO O0 34O0 O0 3500 O0 3600 O0 3700 O0 3800 O0 49 33 O0 48 20 O0 51 22 O0 51 10 O0 53 9 O0 53 47 O0 53 12 O0 53 42 O0 55 40 S 78 56 E 2010 S 78 8 E 2123 S 78 50 E 2241 S 78 39 E 2367 S 78 56 E 2494 S 78 51 E 2630 S 78 9 E 2765 S 78 0 E 2900 S 80 38 E 3040 3942.02 3088 4093.29 3188 4247.94 3288 44O8 61 3388 4570 23 3488 4739 37 3588 4907 63 3688 5075 40 3788 5248 08 3888 63 99 72 36 14 43 56 02 64 0 O0 0 O0 0 O9 0 O0 0 14 2 09 1 59 1 . 90 2.46 6.51 0 O0 N 0 t4 N 0 14 N 0 13 N 0 08 N 021 S ~ 02 S £ 60 S 4 38 S 6 87 S 0 O0 E 001 W 001 E 0 02 W 0 04 W 0 59 E 3 82 E 10 09 E 1998 E 35 50 E 0 O0 N 0 0 E 0 0 0 0 0 3 10 20 36 14 N 3 26 W 14 N '5 57 E 14 N 9 22 W 09 N 26 5 W 63 S 69 59 E 96 S 75 5 E 42 S 75 37 E 46 S 77 38 E 16 S 79 3 E 2 2O 1 36 1 33 0 97 0 17 0 95 5 8O 3 8,4 7 8O 4 67 11 58 S 18 26 37 48 58 69 79 89 98 61 43 E 19 S 92 87 S 125 36 S 161 12 S 199 71 S 236 41 S 277 88 S 327 97 S 389 99 S 476 62 51 S 79 19 E 70 E 94 99 E 128 69 E 165 09 E 204 48 E 243 32 E 285 34 E 336 44 E 399 86 E 487 46 S 78 54 E 82 S 77 58 E 95 S 76 59 E 82 S 76 25 E 66 S 76 3 E 87 S 75 57 E 94 S 76 17 E 70 S 77 0 E 03 S 78 16 E 2 43 4 94 1 94 0 36 1 25 0 85 0 67 0 75 2 O8 1 86 113.46 S 587.93 E 598 77 S 79 5 E 131 07 S 705.41 E 717 154 20 S 838 37 E 852 179 07 S 966 65 E 983 205 74 S 1090 33 E 1109 233 69 S 1215 35 E 1237 264 26 S 1344 57 E 1370 295.98 S 1467 77 E 1497 330.42 S 1590 37 E 1624 361.89 S 1721 56 E 1759 48 S 79 28 E 43 S 79 35 E 10 S 79 30 E 57 S 79 19 E 61 S 79 7 E 29 S 78 53 E 32 S 78 36 E 33 S 78 16 E 18 S 78 8 E 0 72 2 69 0 78 1 22 1 18 3 2O 041 0 44 0 49 1 05 391.79 S 1848 31 E 1889 38 S 78 2 E 417.78 S 1970 52 E 2014 440.00 S 2081 82 E 2127 464.25 S 2197 24 E 2245 488.24 S 2320 68 E 2371 513.70 S 2445 07 E 2498 539.40 S 2579 03 E 2634 566.36 S 2711 63 E 2770 594.28 S 2843.42 E 2904 621.03 S 2981,60 E 3045 32 S 78 2 E 81 S 78 4 E 74 S 78 4 E 49 S 78 7 E 45 S 78 8 E 83 S 78 11 E 15 S 78 12 E 86 S 78 12 E 59 S 78 14 E COMPUTATION DATE: 5-NOV-91 PAGE 6 ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLV BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5427 01 3988 O0 3900 00 55 58 5606 5787 5963 6139 6315 6490 6659 6829 6998 65 4088 44 4188 78 4288 BO 4388 41 4488 15 4588 53 4688 12 4788 99 4888 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 56 31 O0 55 34 O0 55 25 O0 55 18 O0 55 23 O0 53 57 O0 53 51 O0 53 54 O0 53 36 S 79 38 E 3188 97 S 78 58 E 3338 07 S 79 58 E 3488 57 S 81 11 E 3633 79 S 81 36 E 3778 65 S 81 59 E 3923 01 S 83 38 E 4066 27 S 83 5`4 E 4202 87 S 84 3 E 4339 7' S 84 3~ E 4476.88 0 65 1 20 1 44 0 23 0 45 0 39 1 33 0 2,4 0 22 1 89 646 39 S 3127.78 E 3193.88 S 78 19 E 674 702 725 747 768 786 801 816 830 51 S 3274.34 E 3343.09 S 78 22 E 60 S 3422.31 E 3493.69 S 78 24 E 96 S 3565 66 E 3638.81 S 78 30 E 61 S 3708 89 E 3783.49 S 78 36 E 23 S 3851 77 E 3927.63 S 78 43 E 96 S 3993 82 E 4070.61 S 78 51 E 77 S 4129 72 E 4206.83 S 79 ~ E 10 S 4265 9m E 4343.30 S 79 10 E 1`4 S 4402 5m E 4480.12 S 79 19 E 7165.35 4988 O0 4900,00 52 22 7325.34 5088 O0 5000.00 51 4 7484.41 5188 O0 5100.00 51 0 7643.35 5288 O0 5200 O0 51 4 7802.79 5388 O0 5300 O0 51 13 7962.79 5488 O0 5400 O0 51 25 8123.05 5588 O0 5500 O0 50 47 8279.47 5688.00 5600 O0 50 2 8434.82 5788.00 5700 O0 50 2 8590.54 5888.00 5800 O0 49 59 S 85 49 E 4609.54 S 87 1 E 4733.93 S 87 32 E 4857.00 S 88 12 E 4979.77 S 88 54 E 5103.02 S 89 28 E 5226.80 S 89 5 E 5350.80 S 87 24 E 5470.33 5 87 35 E 5588.57 S 87 36 E 5707.24 2 88 0 29 0 35 0 35 0 37 0 33 2 48 0 33 0 48 1 01 841 23 S 4535 02 E 4612 38 S 79 29 E 848 53 S 4659 854 40 S 4783 859 O0 S 4906 862 16 S 5030 863 97 S 5155 864 92 S 5280 869 49 S 5401 874.67 S 5519 879.51 S 5639 69 E 4736 25 E 4858 70 E 4981 85 E 5104 73 E 5227 96 E 5351 14 E 5470 91 E 5588 18 E 5707 32 S 79 41 E 96 5 79 52 E 32 S 80 4 E 19 S 80 17 E 62 S 8O 29 E 32 S 80 42 E 68 S 80 51 E 78 S 81 0 E 36 S 81 8 E 8744.47 5988.00 5900 O0 49 16 8897.41 6088.00 6000 9049.54 6188.00 6100 9199.81 6288.00 6200 9350.30 6388.00 6300 9499.84 6488.00 6400 9649.14 6588.00 6500 9797.38 6688.00 6600 9944.94 6788.00 6700 10090.88 6888.00 6800 O0 49 4 O0 48 27 O0 48 18 O0 48 7 O0 48 0 O0 47 55 O0 47 26 O0 46 56 O0 46 44 S 84 38 E 5823 93 S 85 18 E 5939 S 85 39 E 6053 S 83 53 E 6165 S 81 54 E 6278 S 81 47 E 6389 S 81 57 E 6500 S 82 16 E 6609 S 82 55 E 6718 S 82 35 E 6824 0.80 45 0.39 898.60 S 5871 81 0.28 907.61 S 5985 7~ 3.78 916.52 S 6097 14 0.36 931.44 S 6208 33 0.41 947.30 S 6318 19 0.21 962.98 S 6428 62 0.41 978.12 S 6536 10 0.54 992.32 S 6644 38 0.00 1005.72 S 6749 888.30 S 5755 86 E 5824 O0 S 8~ 14 E 12 E 5939 40 E 6053 21 E 6165 66 E 6278 71 E 6389 47 E 6500 85 E 6609 41 E 6718 86 E 6824 49 S 81 18 E 82 S 81 23 E 71 S 81 27 E 14 S 81 28 E 33 S 81 28 E 19 S 81 29 E 62 S 8~ 29 E 10 S 81 30 E 38 S 81 32 E 10215.00 6973.06 6885.06 46 44 S 82 35 E 6914.75 0.00 1017.41 S 6839.49 E 6914.75 S 81 32 E ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA MARKER PAD RKB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING COMPUTATION DATE: 5-NOV-91 PAGE 7 DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 394' FNL & 137' FWL. SEC20 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 44.00 88.00 5593.00 9556.00 9674.00 9867.00 10031.00 10070.90 10121.00 10201.00 44.00 88 O0 4080 46 6525 62 6604 69 6735 O4 6846 91 6874 30 6908 64 6963 46 -44 O0 0 O0 3992 46 6437 62 6516 69 6647 04 6758 91 6786 3O 6820 64 6875 46 0 07 N 0 14 N 672 33 S 953 24 S 965 56 S 985 O0 S 1000 13 S 1003 84 S 1008 56 S 1016 09 S 0 O3 w 0 01 w 3263 17 E 6359 99 E 6446 ?1 E 6587 TI, E 6706 66 E 6735 ~3 E 6771 61 E 6829 38 E TD 10215.00 6973.06 68B5.06 1017.41 S 6839.49 E COMPUTATION DATE: 5-NOV-91 PAGE 8 ARCO ALASKA, INC. 1R-26 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 27-AUG-1991 KELLY BUSHING ELEVATION: 88.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY *~**~*** SURFACE LOCATION = 394' FNL & 137' FWL, SEC20 T12N RIOE MARKER MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST PAD RKB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING 44.00 88 O0 5593 O0 9556 O0 9674 O0 9867 O0 10031 O0 10070 90 10121 O0 10201 O0 44 O0 88 O0 4080 46 6525 62 6604 69 6735 6846 6874 6908 6963 04 91 30 64 46 -44 O0 0 O0 3992 46 6437 62 6516 69 6647 04 6758 91 6786 30 6820 64 6875 46 0 07 N 0 14 N 672 33 S 953 24 S 965 56 S 985 O0 S 1000 13 S 1003 84 $ 1008 56 S 1016 09 S 0 03 W 0 01W 3263 17 E 6359 99 E 6446 71 E 6587 70 E 6706 6£ E 6735 ~3 E 6771 gq E 6829 38 E TD 10215.00 6973.06 6885.06 1017.41 S 6839.49 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10215.00 6973.06 6885.06 6914.75 S 81 32 E DIRECTIONAL SURVEY COMPANY FIF. i.D WELL COUNTRY RUN DATE ~ UNIT ARCO AI.ASKA, INC. 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[...~...~-~.~ ~ ~ : : : : : : : : : : ~ [ : : ~ ~ ~ : ' : : : : : : : : : : [ [ : : : : : : : : : : : : · i : : : : : AO~CC ~EOLO~CAL ~ATE~ALS ~NYENTORY L~ST ,~ form received received date comments no - co~'~lction report 403 yes no ~/ ' ' sundry application 404 yes no repod of sundry application Open required received Cased requi~:~d---';~:~-~ive~l-"~:~'~i~Jdior"~equired received hole Io§ hole Io9 _.__--... Io9 DI~SFL CNL PnOD DLL C"T ~ pRESS' BHC/SL CET ~ '~ SPINNER ....... BHC/AC E~ OTHER DATA LSS PERFflEC Su~cy ~ // 'SSS PACKER " Digital Data CNL FDC RWD ~e~uh~d ~ec~iwd ~AMPLES ~equhed ~eceiwd MWD LDT~CNL ~ ~ ~ ~ ~ d~ ~ilch CYBER , An?ysis N~T ,, ARCO Alaska, inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3Q-03 LIS Tape and Listing 1 -27-92 92095 3 R- 1 2 D LIS Tape and Listing 2 - 4 - 9 2 9 21 1 5 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THiS ONE. THANK YOU. ~/_--/x ~ 1R-17 ~/"/~ 1R-20 ~/..//~ 1R-21 ~,,_/o7' 1R-22 ~,/..../o/ I R-23 'Z/"- ~' $ I R-24 ,~/...-f,z- I R-26 ~/.-/o~- I R-27 f~/- ?~' 1 R-29 - ?/---,~/ I R-1 9 ?/-/.~? 2M-21 ¢/-..i$~..2 M - 1 9 ~ I---~- 1 L-23 ~'/--~'~' I L-24 ¢/-2'° I L-25 ~/--',~'/1 L-26 Receipt LIS Tape and Listing 9 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 9 - 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 0 - 6 - 9 1 9 2 0 2 6 LIS Tape and Listing 9 - 2 4 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 0 - 2 2 - 9 1 9 2 0 2 6 LIS Tape and Listing 7 - 3 0 - 9 1 9 2 0 2 6 LIS Tape and Listing 7 - 1 8 - 9 1 9 2 0 2 6 LIS Tape and Listing 8 - 3 1 - 9 1 9 2 0 2 6 LIS Tape and Listing 8 - 1 4 - 9 1 9 2 0 2 6 LIS Tape and Listing 6 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing I 1 - 1 1 - 9 1 9 2 0 2 6 LIS Tape and Listing 1 1 - 1 7 - 91 9 20 2 6 LIS Tape and Listing 5 - 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 5 - 1 9 - 9 1 9 2 0 2 6 LIS Tape and Listing 5 - 2 6 - 9 1 9 20 2 6 LIS Tape and Listing 6 - 3 - 9 1 9 2 0 2 6 Acknowledged: R-EC--E VE D DISTRIBUTION: Lynn Goettinger FEB 2 8 1992 Alaska Oil & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return o. ne signed copy of this transmittal. { ?~,~I2M-10 Litho-Density & Casing Neutron 11-29-91 7000-7756~ ~ Porosity Data & 12-29-91 7000 - 7669 2M-1 0 Litho-Density & Casing Neutron I 1-29-91 7000-7756 Raw Data & 12-29-91 7000 - 7669 ~3~Q-04 CCN ,./ 1-12-16-92 4517.7-7720 ~oQ,04 CCR ,., 1-12-16-92 4517.7-7720 ~-3Q-03 CE~ ,.2 1-24-27-92 5090-9640 3Q-03 C[~ %} 1-24-27-92 5090-9640 ..~ THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUES-~"']~-~ "'/% I THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG. · ~.THANK YOU. {[-(:'"~/ ~ ~ ' 5-9-'-13--91 ' i 5237'10476 ---% ?/-~? 1L-26(~-~)'~CCN ' 6-3-6-91 5225-10065 ~i[-I]~ 2M-19~/ CEAI '11-17-'91 3835-9250 ~,~ ,~.q 2M-21.v/' CE~ 11-11-91 ' 3914-10599 -t'" .., 1R-17'~ CE~ 9-15.-19-91 5698-10345 q[ ~',~'3' 1R-20/ Q3q 9-9-91 5568-10080 ~[~'~} 1R-21u/, CCN 10-6-11-91 5070-10180 /\ q[~')1R-22 ~/ CCH 9--24-29-91 6001-10813 ~,,,,i 1R-23 '// . C[::N 10-22-91 6330-12188 _~ ~,~ 1 R-24,/ j CDN 7-30/8-5-91 6753-12972 e~..~:>.l R-26 ./ CE~ 7-18-21-91 5591-10218 · ',o¥--1R-27/ CON/ 8-31-91 6547-9250 8-14-91 ~i~/~ 1R-29 ~ CCN// 6042-11368 ~/~' 1L-24 '" ~ '/ 5-19-22-91 5081-9241 cfi :,1L-25 ~'~ CE~ ,/ 5-26-29-91 4978 9352 / RECEIVED FEB 1 1 199 . Alaska 0il & Gas Cons. ~mmission Ancho[age ARCO Alaska, Inc. Date: September 13, 1991 Transmittal Ct: 8223 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. ~[,.¢ -.. 1A-23~ 1A-23,< 1A-23~ 1 A-23~" 1A.23-~,~· A-23 A-23~ 1A-23~ 1A-2 .3-~ (~ i ,.~/"~ .,-1 R- 26--- 1 R-26-~ '- R-2 9-'-'- 2M-25- Please acknowledge receipt and Receipt Cement Bond Log ~ 8 - 2 Acknowledge' - ............ Tracerscan 7- 1 6 - 91 Pulsed Spectral Gamma Log 5 - 1 5 - 91 Pulsed Spectral Gamma Log 5 - 1 5 - 91 Cased Hole Extra Long Spaced 5 - 1 5 - 91 Fuilwave Log Cased Hole Spectra Gamma Log 5 - 1 5 - 91 Cased Hole Fullwave Acoustic Log 5- 1 5- 91 Tracercheck Log 7- 1 6 - 91 Tracercheck Log 7- 1 9 - 91 PSGT..3_.0~,,,~ 5-1 5-91 PSGT 5-15-91 Cement Bond Log 8 - 2 7- 91 Cement Evaluation Log 8 - 2 7 - 91 Cement Evaluation Log 8 - 2 7- 91 Cement Bond Log 8 - 2 7 - 91 Cement Evaluation Log 8 - 28 - 91 8-91 Date' 6900-7300 6800-7350 6800-7350 6800-7350 6800-7350 6800-7350 6900-7300 6900-7300 6900-7300 6900-7300 8500-10092 8500-10113 10000-11198 10000-11178 5990-7334 5990-7314 Drilling State of A!aska(+sepia) NSK RECEIVED SEP 1 6 1991 Alaska 0~1 & Gas Cons. Co~Trniss~o;, AnChorage ARCO Alaska, Inc. Date: September 6, 1991 Transmittal #: 8217 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATOo 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1 R-26 LIS Tape and Listing 8- 1 8- 9 1 74756 Receipt Acknowledged' ~ ..... Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska KUPARUK ENG1NEER~G TRANSMITTAL # 1419 TO: John Boyle STATE FROM: R. M. Brush/l). S. Baxter DATE: August 19, 1991 WELL NAME: KRU 1R-19 and 1R-26 CONFIDENTIAL TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of Blueline and Sepia 1R-24 1R-24 1R-24 1R-24 2' and 5" Dual Gamma Ray, Compensated Neutron Porosity and / Dual Simultaneous Formation Density True Vertical Depth Log ' 2" and 5" Dual Gamma Ray, Compensated Neutron Porosity and Dual Simultaneous Formation Density Measured Depth Log ~/ 2" and 5" Dual Gamma Ray, Electromagnetic Wave Resistivity/and Formation Exposure Time (EWR) True Vertical Depth Log ~ 2" and 5" Dual Gamma Ray Electromagnetic Wave Resistivity and Formation Exporsure Time (EWR) Measured Depth Log v/ One copy of Blueline and Sepia 1R-26 , 1R-26 1R-26 1R-26 2" and 5" Dual Gamma Ray and Compensated Neutron Porosity True Vertical Depth LOg V ' 2" and 5" Dual Gamma Ray and Compensated Nuetron Porosity Measured Depth Log ~ 2" and 5" Dual Gamma Ray, Electromagnetic Wave Resistivity and Formation Exposure Time (EWR) True Vertical Depth Log ~ 2" and 5" Dual Gamma Ray Electromagnetic Wave Resistivity and Formation Exporsure Time (EWR) Measured Depth Log ~' PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1208 P. O. Box 100360 Anchorage, Alaska 9951~[C[[VED RECEIPT ACKNOWLEDGED: tq DATE: AUG 2 1 1991 I' ~J~l~ .0il & Gas Cons. TO: John Boyle State DATE: KUPARUK ENGINEERING TRANSMITTAL # 1418 August 19, 1991 / FROM: R. M. Brush/P./~SS--B. axter W~LL ~AM~: [KRU ~-~9 ~.¢~-26~ ~ CONFIDENTIAL ~'"--i-~-~/ TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of geolgical descriptions of 87 sidewall cores recovered for KRU 1R-19 and 80 sidewall cores recovered on KRU 1R-26 RECEIVED .0il & Gas Cons. PLEASE RETURN RECEIPT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1208 P. O. Box 100360 Anchorage, Alaska 99510 ARCO Alaska, Inc. Date' August 2, 1991 Transmittal #: 8191 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. I~q~1R-26 CDR L..Wb 7/18-21/91 1R-26 C[~ L....W b 7/18-21/91 Receipt Acknowledged' Please acknowledge receipt 5591-10218 5591-10218 Date' - ......... DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA 0IL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 9, 1991 A W HcBride Area Drlg Engr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well No. Kuparuk River Unit 1R-26 Company ARCO Alaska Inc Permit No 91-92 Surf Loc 394'FNL, 137'FWL, Sec 20, T12N, R10E, UM Btmhole Loc 1368'FNL, 1778'FWL, Sec 21, T12N, R10E, UM Dear Mr HcBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determina- tions are made. Sufficent notice must be given to allow for a representative of the Commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Sincerely, BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl STATE OF ALASKA ALASKA OIL AND C-,AS ~SERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [] Redrill D I lb. Type of Well Exploratory [] Stratigraphic Test [~] Development Oil ~r~ Re-Entry D Deepen DI Service [~ Development Gas ~ Single Zone ~ Mulliple Zone Q 2. Name of ~r~or 5. Datum Elev~ion (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 88'~ Pad 45' GL feet Kuparuk River Field 3. Address 6. Pr~eHy Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25636, ALK 2569 4. Lo~tion of well at suda~ 7. Un~ or pr~e~y Name 11. Ty~ Bond (~e 20 AAC 25.025) 394' FNL, 137' FWL, Sec. 20, T12N, R10E, UM Kuparuk River Unit Statewide At top of pr~uctive inte~al (~ TARGET ) 8. Well number Number 1275' FNL, 1120' FWL, Sec. 21, T12N, R10E, UM 1 R-26 ~UG30610 At total depth 9. Approximae spud date Amount 1368' FNL, 1778' FWL, Sec. 21, T12N, R10E, UM 7/1 2/91 $200,000 12. Distance to nearest 13. Distan~ to neare~ well 14. Number of acr~ in pro~dy 15, Pr~s~ d~th (M0 a~ ~0) property line 1R-4 10,199' MD 1,778' ~ TD feet 60' ~ Sudace feet 2560 6,937' TVD feet 16. To be ~mplel~ for deviat~ wells 17. Anticip~ pre~ure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet M~imum hole ~gle 52° Maximum sudace 2444 psig At total depth ~VD) 3300 pslg 18. C~ing pr~r~ Se~in~ Depth size Specifications Top Bottom Quantity of cement Hole C~in~ Weight Grade Couplin~ Length ~ ~D ~ ~D (include sta~e data~ 24" 16" 62.5~ H-40 Weld 80' 43' 43' 123' 123' ~00 CF 12.25" 9.625" 36.0~ J-55 BTC 5619' 43' 43' 5,662' 4,128' 1140 Sx Permafrost E& HF-E~ 530 Sx Class G 8.5" 7" 26.0~ J-55 BTC 10156 43' 43' 10~199' 6~937' 250SxClassG HF-E~ Top 500' above Kuparuk 19. To ~ ~mpleted for R~rill, Re-ent~, and De~en O~rations. Pr~ent well ~ndition summa~ Tolal depth: measured feet Plugs (measured) true ve~ical feet Effective depth: measured feet Junk (measure) true vertical feet C~ing Length Size Cemented Measur~ d~lh True Venial depth Suda~ Intermediate Production d U L, '- 8 Liner . ~ ' Cons, ~01Tt ,~ ' Perforation depth: measured AI~sk~.0il & ~as ~.e ve,ti..~ 'Anchorage Drilling fluid program ~ Time vs depth plot ~ Refra~ion analysis ~ Se~ed report ~ 20 AAC 25.050 requiremenls ~ ~1. I her~y ce~ily lhal Ihe forgoing is lrue ~d ~rr~I lo the besl ol m~ knowl~ Signed ~~~~ Title Area Drillin, En,ineer Date ~!*/~1 / Commi~ion Use Only .umber ~/- ~ 50- O~- ~/~ / other requirements Conditions of ~proval Samples required D Yes ~ No ' ~u~ I;~ r~uired D Yes ~ No Hydrogen sulfide me~ures D Yes ~ No Directional su~ey required ~ Yes D No Requir~ working pre.ute for BOPE ~ 2M ~ 3M D 5M D 1OM D 15M Other: p~~ by order of Ap Commissioner the commission Date //~J DRILLING FLUID PROGRAM (1R-26) Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.6-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% +_ Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System' Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2444 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1 R-26 is 1R-4. As designed, the minimum distance between the two wells would be 60' @ Surface. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or Kuparuk Field well with open annulus used for disposal. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. JUL Oil &. ~,,,~ .... Cons. Oornr¢,ss~o~. Anchoraqe IAE C0 ALASKA, ne. Sfrucfure : Pad 1R Well : 26 Field : Kuporuk River Unif Location : Norfh Slope, Alaska Scale 1 ' 200.00 EcJsf i i > 4000 400 800 1200 1600 2000 2400 2~00 ~200 ~ 4000 ~ 4.~005200 5600 6000 64~0 6~00 7200 I I I I I I I I I I I I I I I I I 1 I I I I I I I I I I 1 I I I I I I I I I J TARGET LOCAIION: J 1 1275' FNL, 1120' FWL SURFACE LOCA~ON: SEC. 21, T12N, RIOE 394' FNL, 137' FWL SEC. 20, T12N, RIOE S 82 DEG E 6525' (TO TARGET) ITD LOCATION: I 1368' FNL. 1778' FWL SEC. 21, T12N. RIOE 0 o o o -. 400 ('~ 2400- - -'~ 28100- 0 - - 3600- _ _ _ I V52~- _ 56~- _ RKB ELEVA~ON: KOP TVD=500 TMO=500 DEP=O BUILD z~, zl.oo 3 OEO / 100 Fl' 27.00 X~.O0 B/ PERMAFROST TVD=1658 TM0=1744 DEP=391 EOC TVO=2000 TMD=2225 DEP=727 Scale 1 ' 200.00 Created by ; rickb FOR: M PR£STRIOGE Dote plotted : 17-Apr-91 jPIot Reference is 26 Version JCoordinotes ore in feet reference slot ~26. JTrue Vertical Depths ore reference wellhead / j--~j~[j EASTMAN J IZZ/JlIC H RISTE NS E N T/ UGNU SANDS TV0=2788 TM0=$498 DEP:1727 AVERAGE ANGLE 51 DEG 45 MIN T/W SAK SANDS 1~VD=3468 T~D=4596 DEP=2590 JUL. B Alaska Oil & Gas Cons. Cot~tssio~' Anchorage K-5 'P/D=5728 TMD=8246 DEP=54-56 TARGET TVD--6413 TMD=g353 OEP:6325 T/ ZONE C TV0=6493 TMD=9482 OEP=6426 T/ ZONE A TVD=6701 TMD:9818 OEP:66go B/ KUP SANDS TVD=6813 TMo=g999 0EP=6832 TO / LOGGING PT TVD=6937 TMO=lO199 DEP=6989 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 ,3200 3600 .4.000 44.004800 5200 5600 6000 6400 6800 7200 Vedlcal Section on 98.01 ozlmufh wlfh reference 0.00 N, 0.00 E from slof #26 50 _ 100 _ 150 _ 200 _ 250 ;300 _ :350 _ 400 _ 450 _ 100 150 200 250 300 350 400 450 500 550 800 I I I I I ;00 I I I I O0 O0 I I I .5O .100 _ 150 _ 2O0 '""-29a0_..~..~ 250 300 _ 350 I I I _ 400 _ 450 100 150 200 250 300 350 400 450 500 550 600 · . · · , , . , , 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 R-26 Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5,662') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole logging while drilling to total depth (10,199') according to directional plan. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install lower production tree assembly. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. 'A!e,s.qa 0il &. GaS Co'n~.;. Anchorage 7 , 6 5 4 t3 13 5/8" 5000BOP STACK ^COUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO3-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 20(X) PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ~.JPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC I I 5 I I 5 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 3 i ' 0 0 ' 2 . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. . 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 2 ) Loc f/~X ~//~/~ / [2 thru8] .... (5) BOPE ~.~.//-~( 7 - c?_ ~ / [23 thru 28] thr[J '31']- (6) Addl le e 3 4 5 6 7 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company /~/~__~ . . YES Is permit fee attached ............................................... Is well to be located in a defined pool ............................... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... ' .... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ .~_ .. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & nkrnber ................................ Is to Is Wil Wil Wi Is Is Is Lease $ Well NO conductor string provided ......................................... ~ ll surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. //f.~ enough cement used to circulate on conductor & surface ............ '~. 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons'. .................... ll all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................... old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to 3©©O psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. REMARKS 0 MO tn--I 9eol ogy' eng i nee r i ng:-. DWd=i~Z:~ MTM,~Z( LCS'~/OKa' .... dH~ rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,,o.=, ~:... /~ ~., '/ ~ ~ ~ //.,co Additional remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX, No special*effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CEMTER * , ****************************** *mm~mmmmemee~mee~mmmemmeme~mm~ * ..... -- SChLUmBERGER *mmmmmmmmmemmmmeememm~mmemmmm* ****************************** CONPANY NA~E t ARCO ALASKA, INC, ~ELL NAME : 1R-26' FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER ~ 50-029'22193 REFERENCE NO : 92026 CORRECTED COPY RECEIVED FEB 2.. 5 19cji. Alas~ 011 & 13~s Cons. C, ommi~ Anchorage bis Taoe Ver].fl. catJon l, isti. nq 5cbl,~,~err~er AlasKa Co~putina Center 2l-JA~!-I992 06:5S PAGE~ F~iC 74756 ARC(~ ALASKA INC,, ~R-26, KUPAPlIK RIVER, 50-029-22193 **** TAPE HEADER SFRVIC~; NA~4E : F~DIT DATF, : g2/ol/2~ OP ICI ~,' : FLIC 'r~Pg ~;A~E : 74756 CO~T!t']UATIO~J ~ : J. PPEVIOUS TAPE CO~E~:T : ARCO ALASKA INC., 1R-26, KUPARUK RIVER, 50-029-2~193 **** WILE HEADER **** FiLF uAME : EDIT .OO1 SERVICE : FLIC VERSIOi~ : DATF : 92/01/~ ~AX REC SIZE : ~(>24 FIL~ TYPE : LO L~ST FILE : CO.~,iPANY NA.~iE: ARCO ALASKA, INC, ~ORE~U(;H: NORTH SLOPE STATE: ALASKA PF.R~4fli,.~ENT DATI)~: ~4SL ELEVATION RA~GE: log 5IS wane Uertficatlon Listlnq ~chlu~r~berqer Alaska Com~'~utin~ Center 71-J~ri-1992 06:56 E:I.~,EVATIO~$ KB: 88 DF: 88 GL: 45 CASIP,IG: 9 5/R" .~6 bB ~ DRILLER DEPTH OF 5591 SIZE: 8.5" TYPF] FLUID I~',i Hr]bE: BARITE MUD DENSITY: 10.4 ~-~ U D RESISTIVITY: FILTRATE RESISTIVITY; 2.~8 M 72 3,13 ~ 72 t~aXI~iU~< TEr~P RECORDED: 1.50 LOGGING DISTRICT: bOGGING ENGINEER: PRUDHOE BAY HUSBANO/TYBUREC TOOl., ¢IUMBER8: RGS042 NDS037 BIT RUN ONE: DRILLED INTERVAL 5630' TO 9764'. GAMMA RAY READING 75FT BEHIND BIT~ RESIST~'VITY ~EADI~G 65F~ BEHIND BIT, DENSITY READING 128FT BE, HligD BlT NEUTRON EADING 135FT BEHIND BIT BIT ~U~q TWO: [~RILLE[) INTERVAL 9764" TO 10218' GAMMA RAY ~EADING 75FT BEHIND Mil. RESISTIViTI READING 65F'~ BEHIND BIT, DENSITY READING 128MT ggHi~.D'q BI%,' ' NEUTRON EADING 13~FT BEHIND BIT. 2.65 DE~ISITY MATRIX, 1.0 FSUID DENSITY. BARITE USED AS MUD ADDITIVE, CD~4 37 STABILIZER OD: 8,375 IN. DRMO READING HIGH (0,5 GM/CC+) OUE TO BARITE SAG IN HOLE, CO~4PUTING CENTER RE{qARK$: tHE CALCULATED DIE,~ECTRIC R~SlSTIVITY CHANNEL (DER) IS ERRONEOUS OvER THE INTERVAL 771~.5' TO 7717,0' PROBABLY DUE TO FIELD COMPUTATION PROBLENS. DENSITY DATA RECALIBRATED JANUARY !992. DE, TM JOB 8TARTEDI 15-JAN-92 ,JOB REFERENCE NO: 92026 LDPtA{'~A: KOHRI~JG PAGE: * ~ILE - EDIT,O , * ARCO ALASKA INC. * KL!PARUK RIVER ',IS Tat~e '~eri. fication 1, istlno ~cblumber<~er hlasKa Compt:t~.r,q Center 2~-JAm-199~ 05:56 1~-26 50-029-~2!,93 MhlN PAgS L%~D !,~G hAT& D~TA SA~PLEP EVERY -.5000 ?PET D~TA INf'LUI)EI'~ - TOOL EXTENGION TOOL TYPE USED ~JAuE LOGGING wgI[,E DRILLING RESISTIVITY/GR 5591' TO 10153' LOGGinG ~HILE DRILLING ~:UTRON/DENSITY 5591' TO 10089' CD~PUTING CENTER RE~ARKS (20-JAN-92): THIS LIBRARY TAPE :-{AS BEEN REVISED TO INCLUDE RECALIBRATED CD~ DENSITY DATA. DATA PRESENTED IS FRO~ 'RHO8 MAX'. TABLE ~'YPE : CONS C~ API~ FL SECT COUN STAT NAT! PDAT EPD EDF TDL ~bI TLI DFT DFP~ rT ~T FT FT FT FT G/C3 ARCO ALASKA INC. KUPA~UK RIVER 50-029-22193 394' FNL & 137' FWL 2O NORTH SLOPE; US A ~SL 0o 1.0218, 10218, 10218, 5630, BARITE MUD i, 0.4: Comp~n~ Name Fiel ame Well Name API Serial Number Field Location Section Township Ran e County State or Province ~ation witness' Name Service Order Number Permanent datum Elevation of Perm. Da Lo~ Measured From ABOVE PERMANENT DATU~ Elevation o~ Kelly BU Elevation of Derrick Elevation of Ground b Total Depth - Driller Total DePth - Logger Bottom LoQ Interval Top LDO Interval Drillin~ Fluid TYpe Orillino Fluid Oensit Drilling Fluid Ph ZONE bis Taoe Yer~icatio~ [,istino ~chlumber<~er A~laska Computim~ Center PAGE: 4 TU:;.;I ~ aLU DEFI TYPE ...................................................... "i ........ .... '""'"'"'"' DFV CP Dr lling FI ¥ scos ZONE Drilling Fluid Loss ZONE ResistiVity of ~ud Sa [)FL F3 ~CST DEGF STE~ DEGF 2.88 72. 72. -999.25 ~50. ~ud Sample Temperatur Resistivity of mud fi ~ud Filtrate Sample T Resistivity of ~ud Ca ZONE Mud Ca~e Sample Tempe ZONE Surface Temperature Bottom Hole Temperatu DEPT De~th Channel Name PEW Pt~otoelectric F'actor TMpH T~er~al Neutron Porosltyf DPOR [')e~sity Porosity Output rom an APplication Pro,ram DP?ti Density Poros£tV ROS~ SS2 RHO DensltV - LDT RNO8 Bulk Density DRMO Delta PMO ATR RGS BHC ATTENUATION RESISTIVITY PSR RGS BHC P~ASE SHIFT RESISTIVITY DER DIELECTRIC RESISTIVITY FRON RGS OC~L Differential CaiiDer ~OPE RATE OF D~ILDING PENETRATION GR Gamma Rav LIS ~tn+, verJflcatien [~ist.i. nq 5cblur~er,er~. A. laska Computfnq Center 06:56 PAGE: ** SET TYPE PE 1 66 0 2 66 0 3 73 5b 4, 66 1 5 66 6 73 7 65 9 65 ~" 11 66 18 17 6~ 13 6b 0 14 65 !5 66 68 16 66 0 66 0 ** SET TYPE - CHAM ** .... .......... ............... .... .--,.-,,,,..,,,,...-..-...... N~ F RVIC.~'E I AP1 AP1 AP1 FILE NUmB NUM PROCE~8 T~ ORDER # LOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) FT O0 000 O0 0 I 1 I 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 PU O0 000 O0 0 1 1 I 4 68 0000000000 PU O0 000 O0 0 I I i 4 68 0000000000 PU O0 000 O0 0 1 ! 1 4 68 0000000000 G/C3 O0 000 O0 O. I i i 4 68 0000000000 G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 G/C3 O0 000 O0 0 1 I I 4 68 0000000000 OH~ O0 OOO O0 0 I 1 1 4 68 0000000000 C) H~ O0 000 O0 0 1 I 1 4 68 0000000000 ~H~ O0 000 O0 0 ! 1 1 4 68 0000000000 IN O0 000 O0 0 1. I 1 4 68 0000000000 F/HR ** DATA ** 10217,500 PEF', i..~!~ D -999.250 Tt?4Pl4, L~ D -999.250 ROS2.L~;D -999,250 RHOB,h~4D -999,250 PSR.Lt~D, -999,250 ,.,ER.b~D[~ ' -999. 250 GR. L~,~D -999. 250 -g99.250 DPOR.LWD -999.250 DRHO.L~D -999.250 DCAL.LWD '999,2'50 '999,250 '999,250 LIS ~ar~ verlficat~ion Listinc~ Scblumter~er AlasKa Computinq Center DEPT. lOOO0,O00 PEF DPN~.I,wD 4,800 ROS2 AT~.I,,~,O 3,254 PSR ROp~.L~D 33.902 GR .L, WD , LwO .Lv~D , L ~ D DEPT. 9900.000 PEF DPHT.[,~D 23.2{~0 R052 ROPE,L~D 45,14~ G~ DEPT. 9800.000 PEF.LWP DPHI,[,~O !0.100 ROS2.LWD ATR,L~D 4.47I PSR.LWD ROPE,[,WD 107.012 GR.LWD DEPT. 9700,000 PEF,LWD DPHI.t,,%~D ~0.000 RO$2.LWD ATR,L~D 4,386 PSR.LWD ROPE.LWD 19.587 GR,LWD DEPT. 9500.000 PEF,LWD Al..L~D 2.672 PSR,LWD ROPE. L;.~D 37.935 GR. DEPT. 9400.000 PEF,LWD DPHI,LWD ~0.700 ~OS2.LND aTR.LWD 1.56i PSR,LWD ROPE.L~D 39,005 GR.LWD DEPT. 9300,000 PEF,LWD I)PHI.L~D 1.4,400 ROS2.L~O ATP.I,WD ~'479 PSR.LWD ROPF.L,~D 83,140 GR.LWD DKPT. 920o. 000 PEF. LWD DP?~]. I.,WD 5. 100 ROS2.5~vD hTR. I'.~D 2,048 PSR, LWD ROPE. LW~ 170. 874 GR. LW~') 21-JA~,i-1992 06:56 -g99.250 TNPH.LWD 999 250 DPOR.LWD -999.250 RHOB.L~D -'999;250 DRNO.L~D -999.250 DFR.L~D -999.250 DCAL.LWD -999.250 -999.250 TNPH.LWD -999 250 DPOR.LWD -99~,250 R~O,.,a,L~D -999~250 DRHO.LWD 2,709 DER.LWO 2.503 DCAL.LWD 91,890 3 425 TNPH,L~O 37,400 DPOR.LWD 2~571 R~OB.LWD 2,571 DRHO.LWD 3.313 DER,LWO 3.288 DCAL.LWD 84.159 2,848 TNPH.LWD 31 700 DPOR,LWD 2,256 ~HOB,LWD 2[266 DRHO.LWD 18,335 DER.LWD 17.677 DCAL,LWD 41.741 3,104 TNPH,LWO 31 300 DPOR.LWD 2,484 RHOB.LWO 2:484 DRHO.bWD 4.6i9 DER.LWD 4.826 DCAb. LWD 76.083 3.309 TNPH,LWD 30.400 DPOR.LWD 2,486 RNOB,LWD 2,486 DRHO,LWD 4.798 DER,LWD -999,250 DCAL.LWD ~5,550 3 719 TNPN,L~D 25.600 DPOR,,LWD 2~604 RHOB,L~D 2.604 DRHO.uWD 4.038 DER'LWD 3.862 DCAL.LWD 64,283 3.626 TNPH,LWD 32.800 DPOR.LWD 2.591 RHOE: LWO 2.541 DRHO.bWD 7 9 · 3 CER,L~D 2..685 DCAL.LWD ~2 ,519 3,509 TNPH..bWD 45.800 DPOR,LWD 2.474 REOB,hWD 2.474 DRHO,LWD 1,759 DER,LWD 1.65~ DCAL, .WDL 1!0.202 3.468 TNPH.LWD 47.500 DPOR.LWD 2'413 RHOB,L'~D 2.413 DRHO.LWD 1,748 DFR.L~O I 620 DCAL.LWD 104.552 ' 3.8~7 TNPH.L~D 49,300 DPOR,LWD 2.566 RHOB,LWD 2.566 DRHO,LWD 2.129 DER,LW~ 2.105 DCAL.LWD 84.824 PAGE) -999250 '999i250 -999 250 -999,250 -999.250 -999.250 4 800 0i031 0 616 23'200 456 ¸00 10,1250 O' 0,510 I0,000 0,026 0.484 2,800 0,025 0'738 6,600 02 '5~3 10,700 00'016 ;517 4 0 0 516 oo !15 27 ils '¥aoe VerJ. ftcation t, istinq 2~.-JAN-1992 06:56 PAGE: ~chlu~berqer AlasKa Co~..out~n,<~ Center 010:.'), O()O PEF, L~i) 3,1[82 TNPM.LNO 41,200 DPOR,LWD 17,200 17.200 ROS2,LwO ~,367 RHOB.bwD 2.]67 DRMO.LND '0,005 2.672 PSR.LWO 2,680 DER.L~ 2.676 DCAL.LWD 0,04~ ]9,531 GR. LWD 136. Ol 2 OEPT. 9000.000 PEF.~WD 3,719 T~PH.bwb 27.600 DPOR,bwD 6,800 DP~I LwD 6,800 ROS2,L~D 2,538 R~OB.LwO 2.538 DRNO.L~D -0.04! ATP:I,>,D 3.928 PSR.LWD 5,6~1 DER,LWi) 5.396 DCAL.LWD 0:20! ROPE.LWD 72,422 GR.LWO 238,579 DEPT. 8900.000 PEF.LW0 3.799 T~!PH.bWD 48.000 DPOR-.LWD 15.~00 DPNI.I. wD ~5,700 ROS2,L~D 2,392 PMOB,LWD ~.392 DRHO,LWD 0,0~4 ~T~.L~D 3.091 PSR.L~ND 3.2~9 i>ER.LND 3.220 DCAL.LWD 0,065 ROP~.L~D 1,41,569 GR.LWD 154,79! DEPT. 8800.000 PEF,LWD 3.357 T~iPH.hW!) 41 000 DPOR.LWD ~5,,300 DPHI.LWD ~5,300 ~OS2,LMD 2,397 R~{OB.LWD 2:397 DRHO.LWD 0,009 ~TR.[,~O 1,870 PSR,LW[) 1 868 DER,L~O 1.827 DCAb. LWD 0,2~0 ROP~.L~'D i95,553 GR,!~WD 146[940 DEPT. 8700.000 PEF.LWD ] 1~3 T~PH,bWO 32,400 DPOR.LWD 13,500 DPHI,LWD 13.500 ROS2,LWD 2[4 8 RHOB,LWD 2 428 DRHO.LWD 0'020 AT~.L~D 2 773 PSR,LWD 2,774 DER,G~O 2:768 DCAL,LWD 0,1t4 ROPE,L~ND i55~184 GR.LWD 82.410 ' DEPT. 8600,000 PEF L~D 2,8~Z7 T.<PH,bWD 38,900 DPOR bWD 15,600 DPMI.[.,~4O t5,600 ROS2$LWD 2'~-3 R}.iOB,hWD 2,393 DRMO:LWD 0,007 ~TP [.., ~ D 1.765 PSR,LWD 1,770 OER.LWD 1.772 DCAL,LWD 0,088 ROP~L>~D 2~ ~,259 GR.LW[) 75,905 DEPT, 8500.000 PEF.LW~ 2.704 TCPM,LWO 35 500 DPOR.LWD I~ 0~0 DPMT.LWD i4,000 ROS2.LWD 2.419 R~0B,L~D 2~419 DRHO.,LWD u ~0u I ATR,L~D 1.884 PSR,L~D 1,955 DER,LWD 1.925 DCAL.LWD 0'000 ROPE.L~D 272,622 GR,LWD 71'164 DEPT, 8400,000 PgF,bwb 2.773 T[ipM.bwt) 36 400 DPOR,LWD DPHI.LWD ~6,100 ROS2,LwD 2.384 RHOB.LWD 2:384 DRHO,LWD 0,007 ATR.L~'D 1,865 PSR,LWD 1.983 DER,LWD I' 929 DCAL.LWD 0,'118 ROP~,L..D'~' 226,731 GR,LWD 88,952 DR~PT . 8300,000 PEF. LWO 2,724 Ti,.~PM , LW D 32. 200 DPOR . LWD 17, '800 DPNI.LWD 17.800 ROS2,LWD 2,357 Rq0B. b~[ 2 357 DRHO.LWD 0,006 ATP.L~.,D 2,2~0 DSR,L~:~D 2,489 DER,LWD 2~ 391 DCAL.LWD 0,108 ROP~. L~D 204,256 GR, LWD 93,451 DI~TPT. 8200,000 PEF, l..WO ~,199 TL~PH,LWD 35,000 DPOR,LWD 10.700 DP~.~I.LWD ~ 0,700 ROS2,LWD 2.473 RMOB,L;{D 2.473 DRMO.LWD 0,0.~5 AT'~,LWD 2.599 PSR,LWD 2,673 DE~,L~O 2.649 DCAL.LWD 0,266 ROPF. L?;:P. 181,747 GR, LkD 102, 163 DFPT. ~t0O.0o0 PEF.Lw0 2,821 T?iPH,LWD 37.500 DPOR.[.,WD 14,000 DP~t I, [,~,,~D 14,000 ROS2,LWD ~.4i9 R~.-{O~, b~ 0 2,419 DRMO.LWD -0,003 A'~ ~'. [., ~ P 2.~5,3 PSR.b~,b 2,562 ROp~, L~.~ 240,912 GR, [.,~[: 90,4z~8 bis Taoe %'eritication [.istJ~q ~chlumbercer ~la$~a Comuutir~c Center 06:56 ~T~,L~.O ~.575 PSR.L~D ROP~.L~O 299.343 i)~PT. 7909.000 PEF.L~O DP~I.L~D 13,700 ~TP.L~D 2.256 PSR.L~O ROPE.I,kD 194.1~.4 GR.LWD D~PT. 7800,000 ~EF,LWO DPHI.L~I) 16.100 ROS2,LWD ATR,LWD ].467 PSR,LW!) ROPE.L~D 289.803 GR.LWD DEPT, 7700 000 PEF..L~D DPHT LWD 14' , ,300 RO$2,b~D ATR.L~D 3.373 DSR,LWD ROP~.[,.~D 234,450 GR~LWD ATR. LWD 3,343 PSR. LWD ROP~. L~O 251. 726 GR. LWD DEPT. 7500,000 PEF,LWD DPHI.LWD ~1,600 RO$2.LWD t L~D 3,b66 PSR,LWD ROPF.L~D 255,166 GR.LWD DEPT, 7400,000 PEF,LWD DPHI.LWD ~5,500 ROS2.I,~D ATR,L~D 2,886 PSR.LWD ROPE.LWD 380.47t GR,LWD DEPT. 7300,000 PEF,LWD DPHI.LWD 18,600 ROS2.LWO AT~,LWl3 3,039 PSR.LWD ROP~.LWD 423,854 GR.LWO DFPT, 7200.000 PEF.LWD ATR,I.,~D 2,525 PSR.L~D ~OPE,L~D 172.]~ G~.L~D DEPT. 7100.000 PEF,L~D DPHT,LWD 21,000 ROS2.LWD ATP.L~D 2,46i PSR,L~D ROPE,Li~D 452,071 GR.LWD 2.890 TNPH.LWD 2.413 RHt~d,LWD 2,454 DFR.L~[> 81,960 2,888 TNP~4.LWD 2.424 RHOB.L~D 2.327 DER,L~D 91,230 2,784 TNPM.b~D 2.385 RMOB.L~D 3,523 DER.LWO 97.533 2,682 TNPM,LWD 2.413 RHOB,LWO 3,382 DER,LWD ~8,530 2,872 TNPM,LWD 2,4i4 RHOB.LWO 3.209 DER,bWO 90,665 3 33~ TNPH. ,LWD 3.889 DER.L~D 78.989 2,744 TNPH,LWD 2,393 RRO~.LWD 2.933 DER,LWD 83.083 2,747 TNPH,L~D 2,343 3.033 95.347 2.788 TNPH,bWD 2,336 RHO8,LWD 2,624 DER,L~D 83,860 2.850 TNPH.bWD 2.304 RHOB.LWD ~,502 DER,LWO 82,~.00 2.811 TNPH, hWD 2,299 RHOB, bb;D 2.303 DER.LWD 97.724 35.200 2.41] 2.488 38 000 2.298 32.900 2.385 3.498 33.700 2.413 3.375 35 300 2:414 3.250 31.600 2 458 3:855 600 2 912 37 400 i343 038 39.300 2,336 2.581 36.300 2.304 2.479 38,900 2 299 21290 DPO~.LWD ORHO.LWD DCAL.LWD DPOR.LWD DRHO.LWD DCAb. LWD DPOR.LWD DRHO.LWD DCAL.LWD DPOR,LWD DRHO.LWD DCAL,hWD DPOR.LWD DRHO.LWD DCAb.LWD DPOR.LWD DRHO*LWD DCAb,LWD DPOR,LWD DRHO,LWD DCAL.LWD DPOR.LWD DRHO,LWD DCAL.LWD DPOR.LWD DRHO.BWD DCAL.LWD DPOR,LWD DRHO.LWD DCAL.bWD DPOR.LWD DRHO,LWD DCAL,LWD 14,400 0,009 0,000 13 700 OiO01 0 266 §:oo 140 !7'0 14~00 0,006 0,259 014 0,268 ,500 1~,005 0,257 6OO 156 19,100 ,058 21 000 0 002 0 000 21,300 g. o, . 46 LIS ~aoe ~,ertfication Listlnq Schl~]~ber~er.. AlasKa Computl~q C_nter'~ ' 2 I-JA{~i-1992 06:56 PAGE: 9 DF?PT. 6qO~,, . ooo P~qF.LWD DPNI. Li,:D 19.300 ROS2.LWD AT~, L<r~) 2. 728 PSR. L~D ROP~. L~':~ 522. 988 GR. L~D DEPT. 6800.000 PEF.LWO DPHT,L~D I7,900 ROS2.L~O ATP.L~D 2.586 PSR.LWD ROPE.[,~O 54:L.750 GR.LWD DEPT. 6'100,000 PEF,LWD DPHI.L~D 22.300 ROS2,LWD ATR.L~;{) 2,358 PSR.LWD RODF.LW[~ 241.955 GR.LWO DEPT. 6600,000 PEF,bWD DDHI.[,.,%~D 23.]00 ROS2.LWO A~fR.'[,¥~iD 2.464 PSR,LWD ROPE.[,~:D 473.744 GR.bWO DEPT. 6500.000 PMF.LWD DPHI.i,WD 20.500 ROS2.LWD ATP.Lv~D 2.617 PSR.LWD ROP~.L~D 466.938 GR.LWD DEPT. 6400.000 PEF LWD DP~'~I,LWD 22,300 ROS2[LWD ATR.L~D 2,642 PSR.LWD ROPM.i~WD 398.952 GR,LWD DKPT. 6300.000 PEF.LWD DPMI.[.,%,~D 18.OO0 ~OS2.LWD ATP.L~O 3.242 PSR.L~D ROPM.L~'D 390.653 GR.LWD DEPT 62o0 000 PEF.LwD D~ 8I. l~;~O 17,900 ROS2.LWD .~TR, L'~ 9 3. 143 PSR.LWD ROP~. I,'~D 358. 958 GR. LWD OMPT. 6i00.00{) PEF,Lwo DPHT.L~D 2i.000 ROS2.b~O AT~,L~D 3,182 PSR,L~D ROPE.L~D 351.670 GR.LWD DEP?~. 6000,O00 PEF,LWD DPHI.L~D 23,100 ROS2.LWD aTR.L~O 2.939 PSR.bWD ROPE.L~D 223.i90 GR.LWD DEPT. 5900.000 PEF.LwO DPHI,Li~D 19.300 ROS2.bWD ~TR.I?~D 3.319 PSR.LWD ROP~.L~D 359.550 ~R.LWD 2.898 TF}PH.LWO 2.331. RHOB.LWD 2.797 DER.LWO 6.241 2.789 TiiPh.bWD 2.355 RHOB.b~O 2,828 DER,L~D 4.0i2 2.809 T~;PH.bWD 2.282 R~!OB.LWD 2.502 DER.LWD 6.874 2.809 T~PH.bWD 2.265 RHOB.LWD 2.757 DER.bWO 0'483 2.814 TI,~PH.LWD ~.311 R.~B,LWD ,789 t> . R DwD 0,563 2,810 TNPH,LWD 2.282 RHOB,LWD 2.758 DER.L~D 3,072 2,851 T~!PH,bWD .354 R~OB'bWD ~,561 DER,bWD 0.284 2.879 Tf~i,PH,bWD 2.354 R~.{OB,LWD 3,409 [)ER.LWD 7.923 2. 975 TNPH,bWO 2,303 RHOB,LWD 3,334 [)ER, bWP 0.725 2.802 T~!PH,bWD 2.268 RiqOB.bWD 3.1.50 DER.-LWD 8,220 2,867 T~,!PH.LWO 2.331 RHOB.LWD 3,326 DER.bWO 1,021 41.300 DPOR.LWD 19.300 2.331 DRRO.LWD -0,002 2.781 DCAL.LWD 0.197 41.700 DPOR.LWD 17,900 2.355 DRHO.LWD 0,007 2.733 DCAL.LWD 0.2]5 45.200 DPOR.LWD 22 ~00 2.282 DRHO.LWD 0:007 2.440 DCAL.LWD 0.000 44.800 DPOR.LWD 20 500 2 31! DRHO,bWD 0:002 2:732 DCAL.LWD 0,129 47 700 DPOR.LWD 22,300 2 708 DCAL.bwD 0 .800 DPOR.LWD ~8,000 4~.354 DRH. O.LWD 0,003 3.429 DCAL,LWD 0,197 ~ ~WD i~:.900 4 700]54 DRMoDPOR: WD ,0t! ]:30]. DCAL,LWD 0'.[50 40.200 DPOR.LWD 21,000 2.303 DRHO.LWD 0,005 3.281 DCAL.LWD 0,000 2 ~00 DPOR.LWD. 23,~ 42~ 68 DRNO.LWD 0,, 3.076 DCAL.LWD 0'010 44.800 DPOR,LWD 19,300 2.33I DRHO.LWD 0,010 3.324 DCAL.LWD 0'195 ~IS Tape verl~lcation blstl, nq ;chlumberqer AlasKa Computin.q Center 21-JAN-1992 06:56 PAGE: 10 580i~.OO~ PEF. LWP 1.416 TNPH. D?~D 46.000 DPOR.LWD 43.2OU ROS2. L~D 1.938 REO~.hWD 1.938 DRHO.LWD 3.059 PSR.[,WD 3.123 DE~.LWD 3.112 DCAL.L~D 5{).752 GR.LWD 72.433 570~.000 PEF. h~P 2.782 TNP~I. bW[) 38 300 DPOR.LWD L~30 ~328 DRHO.LWD lC~.500 ROS2.LWD 2.328 RHOB. ~t~D 3.366 PSR. b~,;D 3.103 DER. . DCAL.SWD 772 GR. [.,~D 82. Ob4 DE.~? 5600 000 PEF. L~,b 1.946 TNPH. LW)) 55.500 DPr)R. LWD DPal. L~O 4~.800 ~OS2.L~D 1.943 RHOB.LWD I 943 DRHO.LWD A~iiP. I,?~D 3.087 PSR.LWD 3.179 I)~R.LWD 3~128 DCAL.LWD RePE. L~[) -999. 250 GR.LWD 68. 269 DEPT. 5501.500 PEF.LWD -999,250 TNPH.LWD -999 250 DPOR LWD DPHI.I..~D -9q9.250 ~OS2.bWD -999.250 RHOS.LWD -999i~50 DRHO:LWD aTR.LWD -999.250 PSR.LWD -999.~50 DER.LWD -999 250 DCAL.LWD ~OPE.b%~D -999.250 GR.LWD -999.250 ~ND OF DATA 43,200 '0 109 0:523 19,500 ,029 ,455 .4.2,800 0'078 1,792 '999 250 '999 250 '999 250 **** FILE TRAILER FILE ~A~E ~ EDIT .001 SERVICE : F~IC V~$!O~ : O01A06 D~T~ : 92t01/21 ~X R~C $1Z~ : I02~ FILE TYPE : bO hAST FILE **** TAPE TRAIbEN **** $~RVICE NAME : EDIT DATE : 92/0!/21 O~IGIN : FLIC TIP~ NAME : 74756 CONTINUATION ~ : i PR~¥100S TAPE : CO~YNT ~ ARCO ALASKA INC., **** REEl,, T~ILER **** D~T~ : g2/91/21 ORIGIN : FLIC REEL ~APE : 74756 COMTINUATIOM ~ PPEVIO/]S REEL 1R'26, KUPARUK RIVER, Iii~C,, IR-26, KUPARUK IRIV'ER, 50-029-22193 50-029-22193
