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Home My WebLink About186-144 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned 2 4 Suspended❑ 1b.Well Class: 20MMC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service Eli Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: c- ConocoPhillips Alaska,Inc. Aband.: 8/25/2017 1864 1$Ic-i4y / ;i -13i-. 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 8/28/1986 50-103-20075-00-00 r 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 327'FSL,556'FWL,Sec 1,T11N,R8E,UM 9/2/1986 KRU 2T-05 Top of Productive Interval: 9. Ref Elevations: KB:4<i i - " 17. Field/Pool(s): 1339'FNL,1291'FWL,Sec 1,T11N,R8E,UM GL:82' BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10.Plug Back Depth MDffVD: 18. Property Designation: 1010'FNL,1319'FWL,Sec 1,T11N,R8E,UM SURFACE ADL 25569 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 498945 y-499678 Zone- 4 7676/6065 ALK 2667 TPI: x- 499678 y- 5973921 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 499778 y- 5974250 Zone- 4 1807/1801 2107/2085 5. Directional or Inclination Survey: Yes ❑ (attached) No 2 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A RECEIVED SEP 152017 AOGCC 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 32 115 32 115 24 240 sx CS II 9 5/8 36 J-55 32 3010 32 2792 12.25 760 sx AS III,320 sx Class G 7 26 J-55 32 7670 32 6060 8.5 525 sx Class G, 175 sx AS I 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): 3.5 7157 736/5682 ALL PERFS PLUGGED *4-' 4 4-' )C.)-'0P 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. i,a ` ' `'( Was hydraulic fracturing used during completion? Yes❑ No ❑ �g \ /. .I c7)(ZS/�-" Per 20 AAC 25.283(i)(2)attach electronic and printed information Sr ".,mai JAN ` u` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED /4. TOP OFF JOB 3.75 bbls 15.7ppg ARCTIC Set 1 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-407 Revised 5/2017 V Ti- "J Z/1 e CONTINUED ON PAGE 2 Submit ORIGINIAL only -P l/Io// tie. 'Wo- RE3D S I SEP 2 1 2017 G • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No El If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface if yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information,including reports,per 20 AAC 25.071. Formation @ TPI- Formation at total depth: N/A k'-u era J N 31. List of Attachments: Daily Operations Summary,Schematic, PM Photos Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ^ �/ Authorized Name: G.L.Alvord Contact Name: Jill Simek `rr / Authorized Title: Alaska Drilling Manager Contact Email: Jill.Simek@cop. Authorized //p� Contact Phone: 263-4131 Signature: l — ,'L_ Date: �I'(442-19 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 la: 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 1 b: 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 • • Y NOTICE 10-407 SUNDR ConocoPhillips Well 2T-05 Plug and Abandonment • August 30, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2T-05, commencing operations on July 23, 2017 and completing the Plug and Abandonment on August 252017. The tree was removed and a cement top job was performed to bring cement to surface in tubing and all annuli. The wellhead was then removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. rt The field Well Service Repois attached. x -';-2,,''',-•",, ,,,,: ,'' * , erg ` 'r t l'it• "'.-.4-;;;,*,c.'41-•..,..!!!:$,-'1*;-,A,,,• ,/* . . m 00, �, , .�' 1 i ,pV� s ,� M �a.".t 44 4 F • • 0 Wig „E$4;ne4; 'F. • .�, PIIVELL EVENTS SUMMARY • Date Well Event 8/25/17 Took final site clearance pictures-Stateman Chuck Scheve Waived opportunity to witness. Sent pictures and info to town engineer Jill Simek to finalize P&A . 8/24/17 (P&A) STATE INSPECTION (CHUCK SCHEVE). WELD MARKER PLATE (COMPLETE). REMOVE STAIRS AND SHORING. State Inspector(Chuck Scheve) inspected and approved TOC in T, IA, OA, and Conductor. Welded marker plate to the conductor. Removed the shoring and stairs from the excavation. R&P began backfilling excavation. 8/23/17 (P&A) TOP-OFF CEMENT (COMPLETE) Topped off T and conductor with 3 gal of Portland Type 1 cement. Prepped the conductor for welding the marker plate. 8/22/17 (P&A)CUT and REMOVED 13'4"WELLHEAD. COMPLETE. Rigged up crane to well head. Cut windows in conductor. Cleaned out cement and welded threadolet to SC then drilled out for N2 purge. Cut windows in SC, cleaned out diesel saturated cement. Welded threadolet for N2 purge of PC. ****Note****While cutting windows in PC well rose causing partial seperation of conductor and complete seperation of SC. Well was observeved to be leaning to the left side that was still connected by the remaining conductor. Decision made to relieve the stress remaining on•conductor to correct the lean/stress on wellhead. Completed cut on PC, cleaned out cement surrounding the Tubing and welded threadolet and drained —6 gallon of fluids from Tubing. Cleaned out bad cement from remaining wellbore and topped off with fresh cement. Prepped remaining wellbore for marker plate weld to be completed tomorrow post AOGCC inspection of P&A cement top-off. 8/21/17 (P&A) SET STAIRS AND SUMP FOR EXCAVATION, SCAFFOLD INSTALL (COMPLETE) Dewatered —5' of water that filled excavation over night. R&P excavated egress for stairs. Installed stairs. Signed off excavation (H2S-0 ppm, CO- 0 ppm, o2-20.9%, LEL- 0%) and installed sump for dewatering throughout P&A. (180 bbls pumped total) Called scaffold and they arrived to build half scaffold on backside of well. Drilled and tapped one 1/2" hold on front side of conductor. 8/20/17 (P &A) P &A IN PROGRESS. Initial T/I/O = Unable to access due to excavation. Roads and Pads excavated down to 12'. Bed excavation with pea gravel. Dewatered excavation during digging process. Lounsbury surveyors on location to verify height in relation to the tundra. Rigged up and set shoring box. Backfilled around shoring box for compliance. Return in the morning to excavate egress and set stairs. 8/19/17 (P&A) EXCAVATE DOWN TO 15'. (IN PROGRESS) Initial T/I/O= SI 0/0/0. Pulled Control line jewelry and replaced with alemite fitting. Civil crew pulled well house and floors neighboring 2T-05 in case of sluffage. Wells group sucked cellar dry prior to starting excavation digging. Will return to suck more water. Roads and pads dug down to 4' before hitting contaminated soil @ 7 o'clock position of excavation Regrouped with a plan of dewatering cellar and separating contaminated soil into a truck and clean soil on a pile on the pad. Continued excavating down to —8' exposing base plate. Decision made to leave base plate due to danger of sluffage, water inflow and confined space. Will return tomorrow to continue. 8/18/17, (P &A PREP) T TOC @2" IA TOC @ SF OA TOC @ 10". Initial T/I/O = SI 0/0/0 PIWII annuli on open bleed —7 hrs. • TTOC @16' 2' TFL@2' IATOC @SFOATOC @10". T FUV—6 gallons OA FUV—1 gallon. 8/17/17 (P&A) CEMENT TOP JOB ON T/I/O (COMPLETE) Initial T/I/O= SI 0/9/1. Bled IA& OA to 0 psi. Removed T flange blind for cement job, Removed IA& OA bull plugs and VR plugs for cement job, Pumped 1 bbls of cement down T taking returns to waste truck. Pumped 0.75 bbls of cement down IA taking returns out companion flange. Pumped 2 bbls of cement down OA taking returns out companion flange. Re-installed all bull plugs and top of T flange blind. 8/12/17 (P&A) : Bled WHP's to 0 psi. Initial T/I/O = siVac/8/0+. Bled IA& OA to 0 psi (gas) & held T, IA& OA on open bleed for 7.6 hours. Final T/I/O = si0/0/0. 8/8/17 (Pre P &A) REMOVED SCAFFOLDING &TREE. INSTALLED BLIND FLANGE WITH NEEDLE VALVE. REMOVED IA GATE VALVE INSTALLED FLANGE WITH NEEDLE VALVE.REMOVED OA GATE VALVE &VR PLUG INSTALLED 2" PLUG WITH NEEDLE VALVE. Initial T/I/O = SI 1/21/1 Bled T to 0 psi instantly. Bled IA to 0 psi 2 minutes. Bled OA to 0 psi instantly. Left on open bleed 1 hour. Vac truck evacuated fluids from tree. Removed scaffolding. Removed tree and replaced with blind flange and needle valve. T FL @ 4'. Removed IA gate valve and replaced with flange and needle valve. Removed OA VR plug and replaced with 2" plug and needle valve. Removed OA gate valve and replaced with 2' plug and needle valve. Final T/I/O = SI 0/0/0 7/23/17 (Pre P&A) TBG TOC 207' IA TOC 20' 6" OA TOC 82' 6". Initial T/I/O = SI 0/30/0+. Bled IA to 0 psi in 3 minutes (gas) placed all annuli on open bleed for 1 hour. Strapped TOC in tbg © 207'. Removed IA jewelry and strapped IA TOC @ 20' 6" IA FL @ 5'. Repeated with same results.Replaced IA jewelry. Removed OA VR plug and strapped OA TOC @ 82' 6" OA FL @ SF. Replaced OA VR plug. Final T/I/O = SI 0/0/0. KUP imi 2T-05 'Con©coPhillips Well Attribuillir Max Angle TD Alaska Inc rev Wellbore APVUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) LonoccVhillips 501032007500 KUPARUK RIVER UNIT INJ 46.75 3,100.00 7,676.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-05,9/14/20172.16.14 PM SSSV:TRDP Last WO: 40.00 9/5/1986 Vertical schematic{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,260.0 5/19/2009 Rev Reason'P&A WELL pproven 9/11/2017 Casing Strings a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread „,,, CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H-40 _WELDED .;*;;, ,,Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I.._Grade Top Thread SURFACE 9 5/8 8.921 32.0 3,010.4 2,792.2 36.00 J-55 ETC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread _A-h CONDUCTOR;32.0.1150 A' PRODUCTION 7 6.276 32.0 7,669.5 6,060.3 26.00 J-55 BTC Tubing Strings CEMENT;32.0 ftKB -Tubing Description String Ma...11)(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibtft) Grade Top Connection CEMENT;32.0 TUBING 31/2 2.992 32.0 7,157.2 5,697.1 9.30 J-55 EUE-8rd Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 1,807.3 1,801.8 13.97 SAFETY VLV CAMCO TRDP-1A SSA control line defeated:not locked 2.812 out SAFETY VLV;1,807.3 7,122.2 5,672.4 44.94 PBR BAKER PBR 2.991 7,136.0 5,682.1' 44.98 PACKER BAKER FHL PACKER 2.991 7,148.9 5,691.2 45.02 NIPPLE CAMCO D NIPPLE NO GO PROFILE 2.750 (PERF;2,448.0-2,450 0-. h� 7,156 4 5,696.5 45.04 SOS CAMCO SHEAR OUT 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl (PERF;2,480.0.2,492.0�. `^ Top(ftKB)- (ftKB) C) Des Com Run Date ID(in) '.") 32.0 32.0 0.05 CEMENT CEMENTED TUBING,IA&OA TO SURFACE w/ 5/11/2012 0.000 -.- 15.7 PPG ARTICSET 1,OA CEMENTED DOWN TO ' CASING LEAK @ 300'. {!:� 2,900.0 2,716.2 46.30 CEMENT PUMPED 15.8 PPG"G"CEMENT DOWN THE 3/25/2012 0.000 IPERF;2,675.0-2,678.0 .:.'. TUBING,UP THE IA.TOP OF CEMENT IN 'rte ' TUBING AND IA @ 2900' 7,157.0 5,696.9 45.05 CEMENT PUMP 8.6 BBLS OF 15.8 PPG CLASS'G'CEMENT, 5/23/2009 0.000 ALL PERFS COVERED IPERF;2,700.0-2,703.0 Perforations&Slots Shot CEMENT;32.01KB, Dens CEMENT;32.0 ftKB Top(ND) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 2,448.0 2,450.0 2,379.7 2,381.3 A-2,2T-05 4/9/2012 3.0 IPERF '1.375"HSC Loaded,0 Deg Phased 2,490.0 2,492.0 2,413.3 2,414.9 4/9/2012 3.0 IPERF '1.375"HSC Loaded,0 Deg Phased 2,675.0 2,678.0 2,555.0 2,557.2 A-2,2T-05 4/6/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased SURFACE,32.0.3,010.4 2,700.0 2,703.0 2,573.5 2,575.7 4/6/2012 3.0 IPERF 1.375"HSC Loaded,0 CEMENT;2,900.0 Deg Phased 6,927.0 6,930.0 5,533.6 5,535.7 3/22/2012 4.0 IPERF 1-3/8"Titan Tbg Punch, IPERF;6,927.0-6,930.0 0 Deg Phasing, Decentralized IPERF;6,930.66,933.0 6,930.0 6,933.0 5,535.7 5,537.9 3/21/2012 4.0 IPERF 1-3/8"Titan Tbg Punch, 0 Deg Phasing, Decentralized 7,234.0 7,249.0 5,751.3 5,761.8 A-4,A-3,2T- 10/16/1986 1.0 IPERF 4"HyperJet II;90 deg. GAS LIFT;7,076.2 05 Ph 7,249.0 7,274.0 5,761.8 5,779.5 A-3,21-05 10/16/1986 4.0 IPERF 4"HyperJet II;90 deg. Ph 7,308.0 7,332.0 5,803.4 5,820.4 A-2,2T-05 9/3/2002 6.0 APERF 2.5"HSD PJ/2506 PJ,60 Deg Random orientation Illt B to low side PBR;7,122.2 2 Ft' Cement Squeezes Top(ND) Btm(ND)' PACKER,7,136.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,157.0 7,332.0 5,696.9 5,820.4 Cement Plug 5/23/2009 2,900.0 7,157.0 2,716.2 5,696.9 CEMENT 3/25/2012 Pumped 15.8 PPG G Cemenrt 2,900.0 7,157.0 2,716.2 5,696.9'CEMENT 3/25/2012 NIPPLE;7,146.9 - 32.0 2,900.0 32.0 2,716.2 CEMENT 5/11/2012 32.0 300.0 32.0 300.0 CEMENT 5/11/2012 32.0 2,900.0 32.0 2,716.2 CEMENT 5/11/2012 SOS 7,156 4 CEMENT,2.9000ftKBMandrel Inserts CEMENT;2,900.0 ftKB y St ab on Top(ND) Valve Latch Port See TRO Run N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,076.2 5,639.7 OTIS LBX 1 1/2 GAS LIFT DMY RO5 0.000 0.0 11/11/1986 Notes:General&Safety IPERF;7,234.0-7,249.0.E End Date Annotation CEMENT,7,157.0 .r5/23/2009 NOTE:P&A well due to Production&Surface CSG leaks&corkscrewed TBG IPERF;7,249.0.7,274.0--. 5/11/2012 NOTE WELL CEMENTED TO SURFACE;SUSPENDED 8/22/2017 NOTE:P&A-REMOVED 13'4"OF WELLHEAD 8/24/2017 NOTE:P&A-WELD MARKER PLATE BELOW ORIGINAL TUNDREA GRADE APERF.7308.0-73320- . Cement Plug,7.157 0(IKB - I PRODUCTION;32.0-7,669.5 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, /' 17 DATE: August 24, 2017 P. I. Supervisor FROM: Chuck Scheve, SUBJECT: Surface Abandonment Petroleum Inspector ConocoPhillips Alaska Inc. KRU 2T-05 - PTD 1861440; Sundry 317-177 Thursday, August 24, 2017: I traveled to Conoco Phillips' Kuparuk River Unit 2T pad location to inspect the casing cut off and abandonment of well 2T-05. All casing strings were cut off at approximately 5 feet below original ground level and all were found to be full of cement. A '/2-inch thick marker plate was welded ' to the conductor casing with the required information bead welded to it. SUMMARY: I inspected the casing cut off depth, and the P&A marker plate on the KRU 2T-05 well and found all to be in order. Photos attached. Attachments: Photos (2) SCANNED 1 - 311 Vit; ?) 2017-0824 Surface_Abandon_KRU_2T-05_cs.docx Page 1 of 2 • 0 Surface Abandonment— KRU 2T-05 (PTD 1861440) Photos by AOGCC Inspector C. Scheve 8/24/2017 � t� AI*441(.10„, � � Q , • x„ f 44t t r,) ,gj>wT s `,` _�.. • mss". 416r1 1 , ..-11,,, ,4446 oil ei .it, ....,c, . , . . _ . . , .. , 44, v-,.., ::-- - - . ' - .ii,... 4.0,-..,‘, .c4iit. " ,' 'IrtMfF71 :tit it eft i, fr ,71,..;' 1 yar p, 'a #, .,�, , _„ ` . - :, . 2()17-0824 Surface Abandon KRU 2T-05 cs.docx Page 2 of 2 ID OF Tit 94."I//77s THE STATE Alaska Oil and Gas ti ►:._' �, of LAsKA Conservation Commission __ A k =__ _-- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFA +`� Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer %AWNEDA:`; ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-05 Permit to Drill Number: 186-144 Sundry Number: 317-177 Dear Ms. Simek: 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, P9g,,c4, Cathy . Foerster Chair DATED this Ay of May, 2017. RBDMS L AY 1 6 21117 S . • RECEIVED STATE OF ALASKA MAY Q 4 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon u 40 Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: P and A_U 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 186-144 3.Address: Stratigraphic ❑ Service 0 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20075-00 ` 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2T-05 . Will planned perforations require a spacing exception? Yes 1=1No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 • Kuparuk River Field/Kuparuk River 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): 7,676' 6,065' 0 • 0 - 0 Cemented to surface None Casing Length Size MD TVD Burst Collapse Conductor 83' 16" 115' 115' Surface 2,978' 9 5/8 3,010' 2,792' Production 7,639' 7" 7,670' 6,060' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7324-7332 • 5751-5820 3.500" J-55 7,157' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER MD=7136 TVD=5682 . SAFETY VLV-CAMCO TRDP-1A SSA control line defeated'not locked nit MD=1807 TVD=1802 • 12.Attachments: Proposal Summary 12.1 Wellbore schematic L'I 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service D 14.Estimated Date for 5/21/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 2 , 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek@cop.com Authorized Signature: Date: 613/ itContact Phone: (907)263-4131 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31fy "«7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance HS -- Sit 'I I� Other: /`�hofo � oGv.-1---) Gih CI 4-0cs ' c Wi 'fel � 5S 01_,..5 � cl/ caft'� Post Initial Injection MIT Req'd? Yes ❑ No nn Spacing Exception Required? Yes ❑ No VSubsequent Form Required: j b — ¢0 7— RBDMS 1)— KAY 1 6 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ,�'..1 I_/7 kT'7- 'iru3 s '/7 VrL 5//c 17-- ORIGINAL 7- L Form 10-403 Revised 4/2017 ORIpproved isvalidSubmit Form and / ppapplication for 12 months from the date of approval. Attachments in Duplicate • RECEIVED ConocoPhillips ConocoPhillips Alaska MAY 0 4 2017 P.O. BOX 100360 AOGC ANCHORAGE,ALASKA 99510-0360 24 April 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: J ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk River Unit well 2T-05 (PTD#: 186-144). Injector 2T-05 was drilled in 1986 and completed as a single A sand well. The well pre-produced from November 1986 to March 1988 before conversion to water and miscible gas injection. Subsidence related symptoms were first noticed in December 2005 when the well failed a mechanical integrity test of the outer annulus(MITOA); subsequent rigless diagnostics in 2009 were unable to drift for a plug and a gyro survey could only be run to 126'MD.Based on the overall subsidence issues at drillsite 2T and the condition of the 2T-05 wellbore, the decision was made to secure the perforations with cement, which was completed on May 23,2009. Since then,two additional cement plugs were pumped,and the well remains suspended with cement to surface. Remaining resources for well 2T-05 are currently being recovered by the CTD laterals out of the injector directly to the south,2T-09. Per this procedure, a P&A will be performed by performing a cement top-off job, if required, followed by excavation and removal of the wellhead. / If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells • ConocchMips 2T-05 P&A Permit to Drill #: 186-144 The objective of the proposed 2T-05 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document renuired 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld %" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2T-05 PTD # 186-144 API # 50-103-20075-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Pnoto document final location condition after all work is completed. Js • • Wellbore Schematic: KUP INJ 2T-05 ConocoPhillipsi well Attributes Max Angle It MD TD Al ;,iii)It Wal no a API•UW Feld Nana Wa dd*Shun r CI I"I MD dreb1 ALI Bun MAIM 501032007500 KUPARUK RNER UNIT INJ 46.76 3.100.00 7,676.0 ••• Comment MMS wpm) Date AneotM9n End Date 054041III RID Release Date 9999. 3999 - SSSV.TRDP Last WO: 40.00 9/5:1986 Annotation Depth IREBI Eno Date Annotation Lama Mod by End Date Last Tag:SLM 7260.0 5/192059 Re.Reason:UPDATE CEMENT DATA 0360/1 10262012 wAN�ER aA iII1� `abasing S9nngs t mare Desarytion OD pal ID{III Top:56(01 Set Depth 11001 Set Depth(TOD)., WILen(,.,G,ade Top Thread 'l "" 1 CONDUCTOR 16 15.062 32.0 115.0 1150 62.501140 WELDED 1. d' Cn$03 Desem/ton co 90) ID/M) Top(NADI bee Depth TAW Set Dep.(TVD)• Wt/Len(1,,Grade Top Tweed �3',. SURFACE 9 5/8 8 921 32 0 3.010 4 2792 36 00 J-55 8TC Casing Description OD(91 ID lel p 110E Set 05Mh IP06/ Se Depth(1001..00Len 11...C 100 110101) PRODUCTION 7 5.276 Ta 3304 7,569.5 L 050 2c 00 40767610 53 8TC Tubing Strings t 74 T(ElI,0 n,n,, Top 1106) 5.1 Deptu 1..Set D+p.IT401...AI(IA'PI [Grade TINT C,onner�bn `' I TUBING r:phun s.•D M.i_ 2.9921 18.31 7.157 51 5 9701 c 30IJ-55 EUE-8M Completion Details NV/CONDUCTOR:92L11.0 Mammal is Top MED) Top ITVO)ilIKBI Top Mei I') hem Des Uonl (Dl) CFMENT:un NAP 28.3 28.3 0.04 HANGER CIVJ TUBING HANGER 3.500 CEMENT:32b I 1,807.2 1.801.6 13.97 SAFETY VLV CAMCO TROP-1A SSA control line defeated-not locked 7,122.1 5,672out 2 1)1).91)PBR BAKER PBR 2.872 2.951 SAFETY WV.,.eo>.t '` 7.133.6 5,682.0 44.98 PACKER BAKER FHL PACKER 2.991 I f 7,148.7 5,691.1 4502 NIPPLE -CAMCO O NIPPLE NO GO PROFILE 2-750 7,156.2 5,696.4 45.04 SOS CAMCO SHEAR OUT 2.992 PERFt„ada.(0- 1• Otefuintfp4�:(Wks**r*td.lrlbb: ,WNer,pumps,fish,stn:) I i ,v Top 10011) Top Mel.. 9999 Tap)0(61 (hoe) I°1 Dp Goon Run Data '10 O)101 32 D 32.0 0.05 CEMENT CEMENTED TUBING,IA A 0A TO SURFACE 00 5:11/2012 0 000 WERF:1.100 0a 1920 1_::I 15 7 PPG ARTICSET 1,OA CEMENTED DOWN TO 1 CASING LEAK(0 300'. I 2,9000 2,7162 46.30 CEMENT PUMPED 158 PPG'G"CEMENT DOWN THE 30612012 0.000 TUBING.UP THEW.TOP OF CEMENT IN TUBING 1 AND L6 tfp 2900' WERE.2.N5➢9,a]9➢-� 1 7 157 0 5 6969 45 05 CEMENT PUMP R 6 BBLS OF 15.8 PPG CLASS 73'CEMENT, 5!13.2009 D 000 ALL PERF 5 COVERED 1 Perforations&Slots ,PERF'.2]0003,TW• 1_, cans Tap a.D1 Dem!TVD) Islwha C£MENT tDa1hB -Top(11th 33.7409 {8611) 7108) zone Dare I Type Com 2,4480 2.450.0 23797 2,3813 A-2,21-05 4/92012 30 WERE 1.375'HSC 1 044e0,0 Deg Phased 2,4908 2,492.0 2,413.3 2,414,9 4/92012 3.0(PERF 1.375'HOC Loaded,0 Deg Phased 2,6750 2,6780 2,5550 2.5572 A-2.21-05 4/62012 3.D PERF 1.375'HSC Loaded,0 Deg Phased 2.700,0 2,7030 2,5735 2,575 7 416/2012 30 PERF 1 375'HSC Loaded.0 SURFACE 003.3410.1-. A Deg Phased 5EAxOT.t0900 6,927-0 6,930.0 5,633.6 5,535.7 322/2012 4.0(PERF 1-3/8'Titan Tbg Punch, 0 Deg Phasing, MEAT.3.0005t01P0--. Decentralized 6,9300 6,933.0 5,635.7 5,537.9 321/2012 40(PERF 1-3/8'Tilen Tbg Punch, WE1F,e,000.14Aga➢ 0 Deg Phasing, Decentralized 7,234 8 7,249 0 5,7513 5,7618 A-4.A-3,21- 10/160986 1 0 PERF 4'HyperJet II;90 deg. 05 Ph DAD Lel:TOW. 7,249.0 7,274M 57618 5,7795 A-3,21-05 10/16/1986 4.0 PERE 4'HyperJelll:90 deg. Ph 7.300.0 7,332.0 5,803 4 5,8204 A-2,2T-05 9/3/2002 6 0 APERF 2.5"HSD PJ/25135 PJ. 60 Deg Random onentation to Ion side PPR,7.12.2.1 r a Cement Squeezes 4 ■ Top(TM Nor ITVD) AMARA:TO. lop 11061 BUe MALT SINAI MAP) Dos Start Dad 4,111 ' 7.107 0 7,332.0 5,696 9 5,820 4 Cement Plug 0232009 2,900.0 7,157 0 2,716.2 5,696.9 CEMENT 312512012 Pumped 15 8 PPG G Contend 2,900 0 7,157.0 2,716 2 5,696.9 CEMENT 3252012 5101,111450 30.0 2,900.0 30.0 2,716.2 CEMENT 5/102012 320 3000 32.D 3000 CEMENT 5/1/2012 Mandrel Inserts 305:71501 St -A=y- a000feP Mi Top{1Y00 Vans Latch Pod51ee TRO Run M Tug 111 01 IRKS) Mee Medn OD IM) Ser. Type Ty. 0m mon Ron Date Com ,� 7,076.8 1,6396 OTLS 066 112 GAS LIFT 0680 1205 0000 00 11111:1986 Nom(,Gsneosi aa Safety Fed nate 50001 01 6232009 NOTE KA wen due to Production A S0TIeCe CSG Maks A 00,600rened TAG mER F:],1/943]44041,_, c MENx:7la]d 61112072 NOTE WELL CEMENTED TO SURFACE,SUSPENDED MERE,T24aITT,]748- . ✓b APERE,7,SDeA743tD C4mnMrhas STS]➢M6 PRODUCTION.904-7 Mb Js STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T-05 • Oper.Rep: Ian Ives PTD No.: 186-144 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ier(specify in commei Onshore/Offshore: Onshore Suspension Date: 05/23/09 Date AOGCC Notified: 08/28/10 Sundry No.: 309-179 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 800 Photos Taken? Yes IA 400 OA 50 : scOVAED AUG 1 4 2015 Condition of _ Wellhead: Wellhead verified with use of plot plan. Wellhead looked to be in go condition-no leaks IA and OA were blinded with gauges. The flow line was still attached.The flowline pressure was 900 psi.The wellhead was leaning back towards the pipe rack. The well had a wooden cellar box that was dry with no signs of oil.The wellhouse was removed for on going dirt work. Condition of Surrounding Surface The surface around the well was in good condition,dirt work was in progress. Location: Follow Up Actions I ask CPA to find out why the wellhead pressure was so high. I received and email from CPA MJ Loveland on 8/30/10 telling me- Needed: "21-05-Current pressure 800 psi attempted 8-30-10,appears to be communicating from flowline,only bled down to 300 psi for - now,valve crew plans to service valves tonight and we'll try again" Attachments: Photos(3) REVIEWED BY: Insp.Supry _ r� Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-05_bn.xlsx 1 0 - o L' k�. I Ill% t irA yid MO , 21. 1 4 , -• ; 1 1 pArA llir S l4 , ,,,,,...,„,,... :, „A„:„,„: a � i1 : 1 ''.�IISMII ! \ r '4 0 � ) l'. '; IA ' :1 ft . (4610 ip f. a Z. p ° o ' lit 47 f y i ,� d • NI rn I:4 0 IMP= ... ,Liii , , , _.1 ., i ... w . .., .. 0 = • 0 At - ' ;) . ,..., ... , .. AH IN ooNO It Fr -9 'aa om�O a rn ,• ou vNar) pVelialia ' ND ,C vaaoo i 4 k� n y - t \` r • 4 g ' ` Ii: t. ` ... . • o (0', a 9h vM .+{yi. �I a) CT N N w b O N Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) XII/Two -Sided III IIIIIIIIIII VIII 0 Rescan Needed III IIIIIIIII) III III RESCAN DIGITAL DATA OVERSIZED (Scannable) • Color items: ❑ Diskettes, No. ❑ Maps: • Grayscale items: ❑ Other, No/Type ❑ Other items scannable by large scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) f7 Other; ❑ Logs of various kinds ❑ Other TOTAL PAGES: � � NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Pro Proofing III IIIIIIIIIII V III III IIIIIIIIII III III 11 Staff Proof Y PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanned (done) 1111111111111111111 PAGES: &d (at the time of scanning) n SCANNED BY: BEVERLY REN VINCENT SHERYL MARIA LOWELL DATE: / D , !!/ . Q �L /s/ ReScanned (done) IIIIIIIIIIIIIIIIIII RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) IIIIIIIIIIIIIIII�I PAGES: �V Rev1NOTScanned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended Q 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑., Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 11,2012 186-144/312-073 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 August 28, 1986 ' 50-103-20075-00 -wog 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 327'FSL,556'FWL,Sec. 1,T11N, R8E,UM September 2, 1986 " 2T-05 Top of Productive Horizon: 8. KB(ft above MSL): 41'RKB 15.Field/Pool(s): 1339'FNL, 1291'FWL,Sec. 1,T11 N,R8E,UM GL(ft above.MSL): 82'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1010'FNL, 1319'FWL,Sec. 1,T11 N, R8E,UM surface Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498945 y- 5970308 Zone-4 7670'MD/6060'TVD ADL 25569 TPI: x-499678 y- 5973921 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-499778 y- 5974250 Zone-4 SSSV @ 1807'MD/1801'TVD 2667 18.Directional Survey: Yes ❑ No 0 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 2107'MD/2085'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD CBL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE . AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 240 sx CS II 9-5/8" 36# J-55 Surf. 3010' Surf. 2792' 12.25" 760 sx AS III,320 sx Class G 7" 26# J-55 Surf. 7670' Surf. 6060' 8.5" 525 sx Class G,175 sx AS I 24.Open to production or injection? Yes ❑ No Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 7157' 7136'MD/5682'TVD all perfs cemented off 1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. FlE C E I V E D Was hydraulic fracturing used during completion? Yes U No❑ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED OCT 2 9 2012 cement plug @ 7126'-7332' 8.6 bbls 15.8 ppg Class G cement plug @ 2687'-7126' 149 bbls 15.8 ppg Class G AOGC C cement plug @ 0'-2687' 95 bbls 15.7 ppg AS 1 cement plug @ 0'-300' (OA) 55 bbls 15.7 ppg AS 1 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE satin') APR 2 9 2014 1R&'g ivi S OCT 2 9 2012 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE /J . ,a/ Submit original only 29. GEOLOGIC MARKERS(List all formations and rr, s encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑✓ No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 2107 2085 needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7201' 5727' Base Kuparuk C 7214' 5737' Top Kuparuk A 7214' 5737' Base Kuparuk A 7400' 5868' N/A Formation at total depth: Kuparuk 31. LIST OF ATTACHMENTS rk _W_,! ‘b-'��-YL (1 , Summary of Daily Operations,schematic � 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson.M.Wiese@concophillips.com Printed Nam Gober Title: Wells Engineering Supervisor Signature Phone 263-4220 Date fC/Z �Z. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23:If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 2T-05 Well Work Summary DATE SUMMARY 1/29/12 DkIFTED TBG TO 6960' SLM 6'x 1.5" ON 1.25" SLINKY T/S FOR E-L..1E TUBING PUNCH. DRIFTED TBG TO 1023' SLM WITH 5'x 2.5" BAILER. COMPLETE. 3/21/12 PERFORATED TUBING AT 6930'-6933' USING 1-3/8"X 3'TUBING PUNCH GUN LOAD WITH 4 SPF, 0 DEG PHASING, 0.19" EHD, MAGNETIC DECENTRALIZED. LRS ESTABLISHED A PUMP RATE AT LESS THAN 0.5 BPM AT 2500 PSI DOWN TUBING. WILL RETURN TOMORROW TO RE-PERFORATE IN ORDER TO OBTAIN A HIGHER PUMP RATE. 3/22/12 PERFORATED TUBING AT 6927'-6930' USING 1-3/8"X 3'TUBING PUNCH GUN LOAD WITH 4 SPF, 0 DEG PHASING, 0.19" EHD, MAGNETIC DECENTRALIZED. LRS ESTABLISHED A PUMP RATE OF 2 BPM AT 600 PSI DOWN TUBING. RIGGED DOWN AND TURNED WELL OVER TO DSO. 3/25/12 Circulated 149 bbl of 15.8 ppg "G"cement down the tubing, through the tubing punch at 6927' -6933' i and up the IA. Calculated top of cement in the tubing and the IA—2900'. Diesel from 2500'to surface Y0 in the tubing and IA. �� n 3/31/12 MIT TBG/CMT PLUG 1500 PSI, PASSED. 4/ 4/2/12 TAGGED CEMENT @ 2687' SLM WITH 1.65"SWEDGE. MIT TBG AND MIT IA 1500 PSI, BOTH �( PASSED. STATE OG AK WITNESS: LOU GRIMALDI. READY FOR E/L&OA INJ TEST. illA)1 4/6/12 TAG BOTTOM AT 2716'. PERFORATE TUBING AT 2700'-2703'AND 2675'-2678' USING 1.375" HSC LOADED 3 SPF, 0 DEGREE PHASED, ORIENTED 15 DEG OFF OF LOW SIDE. PRESSURE UP ON TUBING TO 2500 PSI, UNABLE TO CIRCULATE FLUID UP THROUGH IA. J`.G•(1/ 4/9/12 PERFORMED CEMENT BOND LOG FROM 2703'TO 2300', ESTIMATED TOC 2512'. PERFORATED 2490' -2492'AND 2448' -2450', LRS PUMPED 20 BBL DIESEL AT 2 BPM @ 1000 PSI DOWN TUBING TAKING RETURNS UP IA. 5/11/12 Pumped 15.7 ppg AS1 cement to surface in the tubing, IA and OA. Circulated 95 bbl of 15.7 ppg AS1 down the tubing, taking returns up the IA. Bullheaded 55 bbl of 15.7 ppg AS1 down the OA. 5/20/12 (SUB) : MIT-T PASSED TO 1500 PSI, MIT-IA FAILED TO 1500 PSI, IA FL @ 40', 760 PSI DECREASE IN 10 MINS, LLR TOO SMALL TO MEASURE ON TANK STRAP, MIT-OA FAILED TO 1500 PSI, OA FL @ 40', PRESSURE WAS FALLING QUICKLY WHEN ACTIVITY WAS NOTICED IN CONDUCTOR, POSSIBLE CASING SWELL, CONDUCTOR WAS SUBMERGED BY CELLAR WATER. 6/1/12 MITIA(FAILED) @ 1500 PSI, T-PO (PASSED) NEG. TEST, IC-PO (PASSED) NEG. TEST, IA DD TEST(PASSED) notKUP 2T-05 P CMI ti k *We"- Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Incl(1 MD(ftKB) Act Btm(MKB) a,,,;. 501032007500 KUPARUK RIVER UNIT INJ 46.75 3,100.00 7,676.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(M) Rig Release Date "' SSSV:TRDP Last WO: 40.00 9/5/1986 Well Config:-2T-05,101262012 10.07'.04 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,260.0 5/19/2009 Rev Reason:UPDATE CEMENT DATA osborl 10/26/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)... String Wt...String... String Top Thrd ". CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H-40 WELDED 1175 77.70 ',:° %y , Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd ° SURFACE 9 5/8 8.921 32.0 3,010.4 2,792.2 36.00 J-55 BTC ',. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String..String Top Thrd PRODUCTION 7 6.276 30.4 7,669.5 6,060.3 26.00 J-55 BTC t Tubing Strings ii�,„i', Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd TUBING 31/2 2.992 28.3 7,157.0 5,697.0 9.30 J-55 EUE-8rd Completion Details Top Depth CONDUCTOR, (ND) Top Incl Noml... 32-115 Top(ftKB) (MKB) ('( Born Description Comment ID(In) 28.3 28.3 0.08 HANGER CIW TUBING HANGER 3.500 CEMENT,32 CEMENT.32 1,807.2 1,801.6 13.97 SAFETY VLV CAMCO TRDP-1A SSA control line defeated:not locked out 2.812 7,122.1 5,672.4 45.18 PBR BAKER PBR 2.991 7,135.8 5,682.0 45.18 PACKER BAKER FHL PACKER 2.991 SAFETY VLV, .,_ 7,148.7 5,691.2 45.18 NIPPLE CAMCO D NIPPLE NO GO PROFILE 2.750 1,e07 7,156.2 5,696.4 45.18 SOS CAMCO SHEAR OUT 2.992 I II Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) (PERF, _= = Top Depth 2.448-2,450 = _ (ND) Top Incl ! Top(MKB) (MKB) ("I Description Comment Run Date ID(in) 32.0 32.0 0.08 CEMENT CEMENTED TUBING,IA 8 OA TO SURFACE w/15.7 PPG 5/11/2012 0.000 ARTICSET 1,OA CEMENTED DOWN TO CASING LEAK PERF, 2,490-2,492 @ 300'' 2,900.0 2,716.2 46.30 CEMENT PUMPED 15.8 PPG"G"CEMENT DOWN THE TUBING,UP 3/25/2012 0.000 THE IA.TOP OF CEMENT IN TUBING AND IA @ 2900' TI IPERF, a" = _ 7,157.0 5,697.0 45.18 CEMENT PUMP 8.6 BBLS OF 15.8 PPG CLASS'G'CEMENT,ALL 5/23/2009 0.000 2,675-2,678 PER FS COVERED I _ Perforations&Slots IPERF, Shot 2,700.2,703 _ = Top(ND) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (9h-. Type Comment 2,448.0 2,450.0 2,379.3 2,380.9 A-2,21-05 4/9/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased CEMENT,30 2,490.0 2,492.0 2,413.3 2,414.9 4/9/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased 2,675.0 2,678.0 2,554.9 2,5572 A-2,2T-05 4/6/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased 2,700.0 2,703.0 2,572.9 2,575.1 4/6/2012 3.0 IPERF 1.375"HSC Loaded,0 Deg Phased 6,927.0 6,930.0 5,533.4' 5,535.5 3/22/2012 4.0 IPERF 1-3/8"Titan Tbg Punch,0 Deg Phasing,Decentralized 6,930.0 6,933.0 5,535.5 5,537.7 3/21/2012 - 4.0 IPERF 1-3/8"Titan Tbg Punch,0 Deg SURFACE, 32FACft . 6. Phasing,Decentralized CEMENT, 7,234.0 7,249.0 5,751.3 5,761.8 A-4,A-3,2T-05 10/16/1986 1.0 IPERF 4"HyperJet II;90 deg.Ph 2,900 IPERF, 7,249.0 7,274.0 5,761.8 5,779.5 A-3,2T-05 10/16/1986 4.0 IPERF 4"HyperJet II;90 deg.Ph 6,927.6,930 - 7,308.0 7,332.0 5,803.8 5,820.6 A-2,2T-05 9/3/2002 6.0 APERF 2.5"HSD PJ/2506 PJ,60 Deg IPERF, - Random orientation to low side 6.930-6.933 Notes:General&Safety II End Date Annotation 5/23/2009 NOTE:P&A well due to Production&Surface CSG leaks&corkscrewed TBG GAS7IFT, 076 5/11/2012 NOTE:WELL CEMENTED TO SURFACE;SUSPENDED 086 7,122 IIII PACKER,7,136 e,rs- NIPPLE,7,149 K. SOS,7,156 CEMENT, 2,900 CEMENT. 2.900 IPERF, 7.234-7.249 Mandrel Details CEMENT, Top Depth Top 7,157 p Port (PERF, -_-_ (ND) Incl OD Valve Latch Size TRO Run 7.249-7.274 - Stn Top(ftKB) (ftKB) (") Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 7,076.0 5,639.6 44.80 OTIS LBX 1 1/2 GAS LIFT DMY R05 0.000 0.0 11/11/1986 APERF. 7,308-7,332 Cement Plug. ..... -` 7,157 PRODUCTION. 30-7,870 TD,7,676 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, October 04, 2012 11:25 AM To: 'Wiese, Tyson M' Subject: RE: 2T and 2M P &As to Surface (PTD 186 -144) Tyson, Thanks for the run down on 2T -05. My assessment is as follows: The reservoir has been isolated as proven by the passing MIT -T done on 5/19/09 and also by the witnessed MIT -IA on 4/2/12. This satisfies the regulations as laid out by 20 AAC 25.112. Normally, the surface plugs are never tested but are only visually checked when cut off of the casing occurs. The pressure tests you are performing at surface are not required to meet any regulations and as you point out are indicating a very shallow leak in the casing near surface. If the other wells have a witnessed /charted pressure test of the lower plug holding they meet suspend regulations also. So in a nutshell ... submit the 10-407 's for the wells . They will be accepted as suspended. Regards, Guy Schwartz APR 1i 7 Z013 Senior Petroleum Engineer �� AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wiese, Tyson M [mailto: Tyson .M.Wiese @conocophillips.com] Sent: Thursday, October 04, 2012 9:12 AM To: Schwartz, Guy L (DOA) Subject: 2T and 2M P&As to Surface Guy, I had a question regarding the sundry status for the 2T and 2M fullbore P &A work we have completed. Below are the details; 2T -05 (Sundry #312 -073) is the example I will use, but the issue is the same for 2T -11, 2T -16, and 2M -23, with failing MIT -IA's at surface (TOC is at/near surface) 5/19/09: Reservoir was isolated with a cement squeeze and a passing MIT -T was obtained. MIT -OA and MIT -IA failed due to leaks above. 1/29/12: Drifted tubing to ensure tubing punch would get down as close to the top packer as possible to allow for a fullbore P&A job. 3/22/12: Perforated tubing to allow cement to be circulated up to base of permafrost. 3/25/12: Cemented Tubing and IA from packer @ 7,135' KB to 2,687' KB using Class G cement. 4/2/12: State witnessed MIT -T and MIT -IA passed with TOC @ 2,687'. The production leak was covered with cement and now has a passing pressure test. 4/9/12: More tubing holes shot to allow cement to be circulated to surface. 5/11/12: Cemented T /IA from 2,687' to surface, and in the OA from 300' to surface with AS1 cement. 5/20/12: MIT -T Passed. MIT -IA failed. MIT -OA failed. 6/1/12: A second MIT -IA was performed and failed. An IA Draw Down test was performed which passed. 8/19/12: Bleed down OA in prep for top job (58" of cement approx measured with string line). No build up in 30 min. T /I /OA = 0 / 0 / 0. We have disconnected all paths of communication from the wellhead /tree (flow lines, gas lift lines, etc) and are still unable to obtain a passing MIT -IA at surface, possibly due to a small shallow thread leak in 10/4/2012 • • Page 2of2 the first joint casing. The plan forward is to perform a small volume top job on the OA (58" of cement approx) to see if we can obtain a passing MIT -OA and MIT -IA. Finally to the question, I apologize for the long winded description above: With the passing MIT -T and MIT -IA with TOC @ 2,687' , and the passing Tubing /IA/OA drawdown tests @ surface, is that sufficient to close out this sundry and not open another until it is time for the final surface P &A? Section 20 AAC 25.112 (g) states that "except for surface plugs, the operator shall record the location and integrity of cement plug, " In this case the cement is to surface but due to a near surface leak, we are unable to obtain a passing MIT -IA. I did not want to send in these 10-407 forms until I had a chance to run this by you to confirm that we are meeting all of the requirements for this well suspend sundry. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 Cell:1- 907 - 230 -5388 10/4/2012 2.■5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: 2T -05 Run Date: 3/21/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -05 Digital Data (LAS), Digital Log file 1 CD Rom 50- 103 - 20075 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Signed: ' Date: Y J' \4 l2, gn WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 10, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log/Perforation Record/Tubing Punch: 2T -05 Run Date: 4/6/2012 & 4/09/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -05 Data in LAS format, Digital Log Image files 1 CD Rom 50- 103 - 20075 -00 Cement Bond Log 1 Color Log 50 -103- 20075 -00 SLAMED MAY 1 4 202 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com J �} �'Z Signed: Date: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ' � t 4 1611 DATE: April 2, 2012 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector KRU 2T -05 PTD 1861440 Conoco Phillips Alaska Inc. Kuparuk River Field Monday, April 2 2012; I witnessed the verification of plug integrity for Plug and Abandonment in C.P.A.I.'s Kuparuk River Unit well 2T -05i in the Kuparuk River Field. I travelled this morning to 2T pad and witnessed the wireline tag at 2687' (2712' RKB corrected). This was above the anticipated height of 2900'. Little Red services was rigged up on the tubing which in turn was pressure tested to 1550 psi fell to 1486 psi (non - linear) in thirty minutes. The iron was rigged over to the Inner Annulus which was pressure tested to 1530 psi and fell to 1445 psi (non - linear) in thirty minutes. I left location at this time. Attachments: none Algae) APR 1 7 LiZ 2012- 0402_Wellbore _Plug_KRU 2T-05_1g 1 of 1 • • q rr col g\_,As[KKA SEAN PARNELL, GOVERNOR �1 ALASKA OIL AND &As 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese t,� Wells Engineer �,� ConocoPhillips Alaska, Inc. 114 P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -05 Sundry Number: 312 -073 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2 ? day of February, 2012. Encl. STATE OF ALASKA , �y�, • • AL OA OIL AND GAS CONSERVATION COMMON lrt °"' t�r y • 1 APPLICATION FOR SUNDRY APPROVALS 2' !/` .i. 0111 20 AAC 25.280 1. Type of Request: ebandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r :41 XSuspend y Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate Al ter casing g r Other: Secure Well F7, 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -144 • 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20075 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J 2T -05 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25569 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7670 • 6060 • 7584' 5999' 7157' {''' Casing Length Size MD TVD I I F fit. C E I e ,se CONDUCTOR 83 16 115' 115' v SURFACE 2978 9.625 3010' 2792' rai 2 4 2012 PRODUCTION 7639 7 7670' 6060' / laeka nil fi, (;ae l Commiss" n Anchc rage i Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7234'- 7274', 7308' -7332' 5751'- 5780', 5804' -5821' 3.5 J -55 7157 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 7136 TVD= 5682 SSSV - CAMCO TRDP -1A SSA MD= 1807 TVD= 1802 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch re Exploratory r Development r Service F; • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/7/2012 ' Oil r Gas r WDSPL r Suspended I✓ • 16. Verbal Approval: Date: WINJ i ' GINJ r WAG r Abandoned r Commission Representative: GSTOR f' SPLUG r 17. 1 hereby certify that the for oing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name SOn iese Title: Wells Engineer > Signature Phone: 263 -4250 Date 3/ 2 Commission Use Only Sundry Number: ( /-0-13 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity I'V BOP Test r Mechanical Integrity Test r Location Clearance r Other: NI a 4 " : C7 :�ih 5 •CS ini ;c- e- . Subsequent Form Required: /o D 7 APPROVED BY Approved by: A � COMMISSIONER THE COMMISSION Date: 25 111 Form 10 -403 Revised 1/2010 " deo, MAR 0 2 2012 Submit in Duplicate � 'a• I� 4',Z— .77 V • i 2T -05 Fullbore P &A Permit to Drill #: 186 -144 The objective of the proposed 2T -05 Fullbore P&A is to perforate the 3.5" tubing as close to the packer as possible, then cement the tubing, production casing, and surface casing to ,/ further secure the well, until wellhead removal at a later date. Proposed P &A: (further secure, cement to surface) E -line/ Little Red: 1. RIH and detonate 1" Split Shot Cutter at 6,950' KB, or as close to the packer as possible. 2. Pump 100 bbls of Diesel to ensure adequate circ. rate for cementing, and for freeze protect of IA and OA via jumper at surface. Pumping: 1. Ensure an approved sundry has been received from AOGCC. 2. Pump 149 bbl of 15.8# cement balanced plug through tubing holes at 6,950', to • bring TOC in tubing and IA to 2,900' KB Perfs below were squeezed off in 2 009. . Bl X y060 i of r buts Slick Line / Little Red: 1. Notify the slope AOGCC inspector of the upcoming tag and pressure test of the cement plug, providing at least 24 hours notice to schedule the witness. 2. RIH and Tag TOC at 2,900' KB. Record Results. 3. MIT Tubing to 2,500 psi. MIT -IA to 1,500 psi. Record Results/ 4. RU to OA and perform step rate injectivity test. E -line / Little Red: 1. RIH and detonate 1 3/8" tubing punch at 2,850' KB. 2. Pump 25 bbls of Diesel through tubing holes to ensure adequate circulation rates. Pumping: 1. Pump 133 bbls of AS1 cement through holes at 2,850' KB, to fill IA and Tubing to . surface. When good IA cement returns are at surface, RU on the OA. 2. Pump 50 bbls of AS1 cement down the OA to bring cement to surface. Use LCM during OA cement job to help plug the Surface Casing Leak @ 300' KB. Little Red: 1. MIT -T with Diesel to 2,500 psi. Record Results 2. MIT -IA with Diesel to 1,500 psi. Record Results. K- 3. MIT -OA with Diesel to 1.500 psi. Record Results. 4. If cannot get OA cement to surface due to the casing leak, plan to perform the final OA cement plug at a later date, when the wellhead is removed. p o re fen/ et fev'cw necessce T*l$ w8/! He eeeworf/ iws for ,4, y C 045 dercit ..f. ft'opfol worK wall /h.ke The well Mee . s ?�u k/e!l 5 I,�N�e 7r0 h 07 1) , +etoy(kod To fepiu ce n �ecr yT lv if 6y fr /he a &n/on $t a F 14 Well gi 1 2/22/2012 E KU P • 2T -05 Conoc /$ Well Attributes Max Angle & MD TD Alasha,Irv; Wellbore APUUWI Field Name Well Status Intl (°) MD (ftKB) Act Btm (ftKB) carwmwlops 501032007500 KUPARUK RIVER UNIT INJ 46.75 3,100.00 7,676.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 40.00 9/5/1986 Well Conlg - 27-05, 1 /32 01 1 0'.07'.31 AM schematic - 2 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,260.0 5/19/2009 Rev Reason: WELL REVIEW osborl 1/31/2012 Casing Strings - -- /— - - -- Casing Description String 0... Stang ID ... Top (ftKB) S e t Depth (i .. Set Depth (ND) .. Str ng Wt.. Str ng ... Stang Top Thrd CONDUCTOR 16 15.062 32.0 1150 115.0 62.50 H - 40 WELDED HANGER, 2e Casing Description String 0... Stang ID ... Top (ftKB) S Depth (t.. Set Depth (ND) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.765 32.0 3,010.4 2,7922 36.00 J BTC Casing Description String 0... String ID ... Top (ftKB) S Depth (f... Set Depth (TVD) _. String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 30.4 7,669.5 6,060.3 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID... Top (ftKB) S Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 28.3 7,157.0 5,697.0 9.30 J -55 EUE -8rd Completion Details To Deplh (ND) Top Intl Nomi... - Top (ftKB) (RKB) C) ftem Descri Co mmen t ID ( In) 32-115 28.3 28.3 0.08 HANGER CIW TUBING HANGER 3.5 00 CONDUCTOR. 1,807.2 1,801,6 13.97 SAFETY VLV CAMCO TRDP -1A SSA control li defeated: not locked out 2.812 7,122.1 5,672.4 45.18 - PBR BAKER PBR 2.991 7,135.8 5,682.0 45.18 PACKER BAKER FHL PACKER 2.991 7,148 5,691 45.18 NIPPLE CAMCO D NIPPLE NO GO PRO 2.750 77771:7111142256352878......27821 ,156.2 5,696.4 45.18 SOS CAMCO SHEAR OUT 2.992 SAFETY VLV. J Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 1.807 1 Top Depth (TVD) Top Intl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (In) 7,157.0 5,697.0 45.18 CEMENT PUMP 8.6 BBLS OF 15.8 PPG CLASS 'G' CEMENT, ALL 5/23/2009 0.000 PLUG PERFS COVERED Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm )RKB) MB) (ftKB) Zone Date (ah -• Type Comment 7,234.0 7,249.0 5,751.3 5,761.8 A-4, A -3, 2T -05 10/16/1986 1.0 IPERF 4" HyperJet II; 90 deg. Ph 7,249.0 7,274.0 5,761.8 5,779.5 A -3, 2T -05 10/16/1986 4.0 IPERF 4" HyperJet II; 90 deg. Ph SURFACE. . ' 7,308.0 7,332.0 5,803.8 5,820.6 A -2, 2T-05 9/3/2002 6.0 APERF 2.5" HSD PJ /2506 PJ, 60 Deg 32 - 3,010 Random orientation to low side Notes: General & Safety End Date Annotation GAS LIFT 5/23/2009 NOTE: P&A well due to Production & Surface CSG leaks & corkscrewed TBG 7 076 1 l PBR, 7,122 J PACKER 7,136 -4fSZFARFAri C- NIPPLE. 7,149 SOS, 7,156 \ IPERF, 7.234 -7,249 CEMENT PLUG, 7,157 IPERF, 7.249 -7.274 Mandrel Details Top Depth Top Port APERF. (ND) Inc! OD Valve Latch Size TRO Run 7,308-7,332 Stn Top (RKB) )RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... cameraPlug, 1 7,076.0 5,639.6 44.80 OTIS LBX 1 1/2 GAS LIFT DMY R05 0.000 0.0 11/11/1986 PRODUCTION. 30 -7,670 , TO, 7.676 0 • 2T -05 Plug & Abandonment (Suspend Well) Cierrent Cnmptetinn Proposed PRA ; !f '' / ' , /'-'` OA - AS', WC' Plug 'to Leak • Surfa eCasngLea's -30.i K - IA -AS1 Ceme:to ;S •rf =c: • joy • '/ �J;}i� - l 8.1i KB d� /7 r elf Tubir l+oes -3.8 %' S 0, f - cp of Class G Cerrs �}'= rn 9 2P,# `6 Surface Casing 2ca_C' KB A x CA Leak be:aee. Packv a-d Su,^fa =e C s ng 2h r i MT -IA failed, nth n: p-ess. vim. > etween IA, and C .; Last ag i 6,85: B i subside -o issues '3 1' 4 7:/ -` 1, ;- Tubing Spit- 8.g5:• KB GLV - 7,07 5' K6 PBR - 7,122• KB r =_s - CC from Pert Soueeze -7,126 KB • Baker R L Paler-7.136' KB - _. ®' : Can: 'D' Nipple - 7,141 KB 3.5' 'lib -g Tail ggi 7. 157' KB , a... ,,-:. ::r; A Sand Perfs: .. , 7, 7.222' KB 7,30E -7,322' KB 7 Prod Casng TO 0 7,878' KB TN 02 -14-12 TW 2/22/2012 Well Details — 2T -05 Exam le . w: REE is u Conoco Phillips to yOU and me Current Comuletion SCI' @ 300' KB — SSSV - 1,807 KB • 9 5/8" 36# J -55 Surface Casing @ 3,010' KB IA leak between packer and Surface Casing Shoe. Depth not known. IA and OA did not •- - - -- MIT -T Passed 05/29/09 track, indicating leak below shoe. Last Tag @ 6,960' KB (TOG) GLV - 7,076' KB PBR – 7,122' KB Baker FHL Packer – 7,136' KB 0 :I% Option 1 Diagram g I NCIDENT -FREE ConocoPhillips II S Up to yore and me SCL @300'KB , Option 1: 0 1.) Fluid Swap OA to Heavy Brine (displace diesel up OA, but may push some out the leak). 2.) Shoot holes @ 6,950' KB. IA leak. IA and OA did 3.) Cement Tubing and IA with Class not track, indicating leak below surface shoe. G cement to 2,900' KB. 0 4.) Shoot holes @ 2,850' KB 5.)Cement Tubing and IA to Surface with AS 1 cement. 6.) Bullhead Cement down OA and _, cement to surface (CemNET lead to plug SCL) 0 ...... ,. Option 1 Diagram _ rrc1nE ConomPhi J „ it's up to you and ate 4 SCL @300' KB ► Option 1: • 1.) Fluid Swap OA to Heavy Brine (displace diesel up OA). 2.) Shoot holes @ 6,950' KB. 3.) Cement Tubing and IA with Class IA leak. IA and OA did G cement to 2,900' KB. not track, indicating leak below surface shoe. 4.) Shoot holes @ 2,850' KB • i, 1:-. 5.)Cement Tubing and IA to Surface with AS 1 cement. 6.) Bullhead Cement down OA and cement to surface (CemNET lead to plug SCL) 0 i 0 3 Option 1 Diagram INCIDENT-FREE conocophiuips «s up to you and me SCL @ 300' KB • Op 1.) Fluid tion 1: Swap OA to Heavy Brine (displace diesel up OA). 2.) Shoot holes @ 6,950' KB. 3.) Cement Tubing and IA with Class IA leak. IA and OA did • G cement to 2,900' KB. not track, indicating leak below surface shoe. 4.) Shoot holes @ 2,850' KB • 5.)Cement Tubing and IA to Surface with AS 1 cement. 6.) Bullhead Cement down OA and cement to surface (CemNET lead to plug SCL) O s. Option 1 Diagram INCIDENT -FREE' ConocoPhilhps S up to you and me Option 1: • 1.) Fluid Swap OA to Heavy Brine (displace diesel up OA). 2.) Shoot holes @ 6,950' KB. 3.) Cement Tubing and IA with Class IA leak. IA and OA did G cement to 2,900' KB. not track, indicating leak • below surface shoe. 4.) Shoot holes @ 2,850' KB • � yam .._ .. Y 5.)Cement Tubing and IA to Surface with AS 1 cement. .. 6.) Bullhead Cement down OA and cement to surface (CemNET lead to _ = plug SCL) OS' Option 1 Diagram I rci '' - •E p g Ws Up trim! me ConocoPhillips p , SCL @300'KB Option 1: • 1.) Fluid Swap OA to Heavy Brine (displace diesel up OA). 2.) Shoot holes @ 6,950' KB. 3.) Cement Tubing and IA with Class IA leak. IA and OA did G cement to 2,900' KB. not track, indicating leak below surface shoe. 4.) Shoot holes @ 2,850' KB • . 5.)Cement Tubing and IA to Surface `. ...'' with AS1 cement. . ? , 'W ,. . * - 6.) Bullhead Cement down OA and � cement to surface (CemNET lead to - - plug SCL) r 0 i Option 1 Diagram INCITE T_ ConocoPhillips It S U{7 to you and me SCL @300' KB Option 1: • ` 1.) Fluid Swap OA to Heavy Brine (displace diesel up OA). 2.) Shoot holes @ 6,950' KB. A "� �` 2 3.) Cement Tubing and IA with Class IA leak. IA and OA did * 1.,....,,,„t Shoot holes @ 2,850' KB ` � ' i , -�. �A ,A G cement to 2,900' KB. not track, indicating leak ,�'4 ` ��' below surface shoe. 0 ' .0 +�t �1t ' , , _' ._ :` ` . - = `sr • R ' . 1°: k' 5.)Cement Tubing and IA to Surface .. ,1=. x"} with AS 1 cement. 6 »N " elt k' ? . . 10 ' 6.) Bullhead Cement down OA and ''�* cement to surface (CemNET lead to plug SCL) &wens Follow u p Items ConocoPhillips t1 rrri • • Plan to fluid swap in heavy brine in the OA, in an effort to reduce the amount of diesel that will be bullheaded through the surface casing leak @ 300 ft during bullhead cement job. • Previous 2009 Brinker Platelet job pumped 78 bbls of Diesel through SCL • Will not be able to remove all Arctic Pack from the OA. Arctic Pack will remain in OA from approx. 300 ft (casing • leak) — 2,034 ft (Surface Shoe TOC) Page l of 2 . • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 9:18 AM To: ' Herrmann, Daniel D' Subject: RE T -05, T -11, 2T -16 Rigless P &A Procedure (PTD 186 -097, PTD 186 -046 , PTD 186 -144) Dan, These three wells all have cement plugs that were pumped fullbore in the last couple of years. It appears that they have all been pressure tested ( witnessed by AOGCC inspectors) after this initial plug was pumped. The wells are officially suspended in our database and the work you are proposing will be additional suspension operations to further secure the wells until final wellhead cutoff and site remediation. The proposed tag depths are very close to the top of the packer and will allow sufficient cement to be circulated to safely abandon the wells. Go ahead a submit 403 sundries with as with the tag depths listed below as circulation points for the cementing ... Regards, tiNet) mAR Guy Schwartz Senior Petroleum Engineer t AOGCC 793 -1226 (office) 444 -3433 (cell) From: Herrmann, Daniel D [mailto:JD.Herrmann @conocophillips.com] Sent: Friday, March 04, 2011 4:05 PM To: Schwartz, Guy L (DOA) Subject: 2T -05, 2T -11, 2T -16 Rigless P&A Procedure Guy, We are looking at P &Aing these wells rigless, but before I wrote the procedures for these 3 wells I wanted to check to make sure the State would be ok with it. We are unable to drift to the to p packer the acker with our slimhole perforating guns, but we are able to get down close to the packer on each of these wells with varying distances from the packer. Our plan would be to perforate and circulate cement down the tubing taking returns up the IA from our perforations to surface. r the depths have attached the wellbore schematics and here are the we can drift down to and there distances from t p the top of the packer. 2T -05: Drift Depth - 6964' SLM Distance from drift to top of packer -172' SLM 2T -11: Drift Depth - 5350' SLM Distance from drift to top of packer - 375' SLM 2T -16: Drift Depth - 7410' SLM Distance from drift to top of packer - 636' SLM Please let me know what questions and concerns you have. 3/9/2011 Page 2 of 2 • • Cheers, Dan Herrmann Wells Engineer 1 ConocoPhillips Alaska Inc. AT O 1586 Office: (907)263 -4619 Cell: (713)703 -5282 jd.herrmann @conocophillips.com 3/9/2011 4 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 19, 2010 , RU L. J CEP 2 3 2010 Commissioner Dan Seamount r g .r 10 & iW Wa Cr0sewn Alaska Oil and Gas Conservation Commission A00 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -05 (PTD 186 -144) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2T- 05 (PTD 186 -144). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F Repair well r Plug Perforations r Stimulate r- Other F Suspended Well Alter Casing ull Tubing Inspection g � g � Perforate New Pool (� Waiver � Time Extension Change Approved Program 17, Operat. Shutdown Perforate l Re -enter Suspended 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen I Exploratory \ 186 -144 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphi Service '- 50- 103 - 20075 -00 7. Property Design%tjgn: 8. Well Name and Number: ADL 25569 2T -05 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7676 feet Plugs (measured) 7157'- Cement true vertical 6065 feet Junk (measured) NONE Effective Depth measured 7584 feet Packer (measured) 7136 true vertical 5999 feet (true vertucal) 5682 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 SURFACE 3010 9.625 3010 2792 PRODUCTION 7669 7 7669 6060 Perforation depth: Measured depth: 7324' -7332 - cemented True Vertical Depth: 5751'-5820'- Cemented S E 1' 2 3 2010 Tubing (size, grade, MD, and TVD) 3.5, J -55, 7157 MD, 5697 TVD InGhem Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 7136 MD and 5682 TVD CAMCO TRDP -1A -SSA (CONTROL LINE DEFEATED; NOT LOCKED OUT) @ 1807 MD and 1801 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development [ Service 15. Well Status after work: 5USpeA E1i Oil F Gas r WDSPL Daily Report of Well Operations x GSTOR F WAG r GASINJ h WINJ SPLUG r 16. 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: N/A Contact MJ Loveland /Perry Klein Printed Name MJ Lovel nd /P rr Klein / Title Well Integrity Project Supervisor Signature / Phone: 659 -7043 Date �-(• 27. /o ��Q�S S d EP IC Form 10 -404 Revised 7/2009 Submit Original Only Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riv Unit 2T -05 Field /Pool: Kuaaruk River /Kuparuk River Pool Permit # (PTD): 186 -144 Sundry 309 -179 API Number: 50103200750000 Operator: ConocoPhillips Date Suspended: 5/23/2009 Surface Location: Section: 327' FSL, 556 FWL, sec 1 Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: (1 Pad or location surface: f 0cp 6 (Z* f_. _ V)m y\ Location cleanup needed: /t /a Pits condition: &/,7 Surrounding area condition: Water /fluids on pad: ' M Discoloration, Sheens on pad, pits or water: /t/P Samples taken: AID Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: /�t/ Cellar description, condition, fluids: P, twoo in! o/ _ geog folg: A " I Rat Hole: r_ �.--9 0; Wellhouse or protective barriers: A lta A7xifa c,-9AV tt i�t Well identification sign: �' / P LL 6(-3 E A' / / 1" Tubing Pressure (or casing if no tubing): i Z) _ 4100 0 0 9 Annulus pressures: /� fd 31-' s ° y 3 iv Wellhead Photos taken (# and description): , r Work Required: - IC> /g Operator Rep (name and signature): / Jr_yr� �-- AOGCC Inspector: Other Observe A?t O.R **C"L9r 2 Inspection Date: 9 1 12-q // 0 AOGCC Notice Date: Time of arrival: r Time of Departure: Site access method: /fie r e, �, KU P 2T -05 C0110C0�1j��jPS . ` W ell Attributes Max Angle & MD TD Inc Alaska, Welltwre API /UWI Field Name Well Statue Incl ( °) MD (kKB) Act Btm (ftKB) Aff 501032007500 KUPARUKRIVERUNIT INJ 46.75 3,100.00 7,676.0 Comment H2S (pqn) Dab Annotation End Dete KE1 (k) Rig Release Date ,•• Weil Conti: -2T -055/25"200911.02:42 AM SSSV: TRDP LastWO: 40.00 915/1986 Schemer. - Amel Annotation Depth (ftKB) End Date Annotation Last Mod ay Entl Date Last Tag: SLM 7,260.0 5/19/2009 Rev Reason: P&A WELL Imosbor 5/25/2009 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (inl (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top 7hrd CONDUCTOR 161 15.062 0.0 115.0 115.0 62.50 H-40 SURFACE 9 &81 8.765 0.01 3,010.0 2,792.0 36.00 J -55 PRODUCTION 1 71 6.151 0.01 7,669.0 6,060.0 26.001J-55 CONDUCTOR, 115 Tubing Strings String OD Sling ID Set Depth Set Depth (TVD) String Wt String Tubing Description (In) IIn) Top (ftKB) (kKB) (ftKB ) (ItuRt) Gmtle Sling lop Third TUBING 31/2 1 2.992 0.01 7,157.0 5,697.0 9.30 J -55 EUE8rdABMOD Other In Hole All Jewelry: Tubing Run & Retrievable, Fish etc. SAFETY VLV, Top Depth 1,607 O (TVD) Top Ind Top (kKB) (ftKB) (°) Deuription Comment Run Date ID (in) 1,807 1,801.4 13.96 SAFETY VLV CamoO TRDP -1ASSA (Control Line Defeated; Not Locked 10/16/1986 2.812 Out) 7,076 5,639.6 44.80 GAS LIFT OTIS/LBX/1.5/DMY /RO -5/ // Comment: STA 1 11/11/1986 2.907 7,122 5,672.3 45.18 PBR Baker 10/1611986 2.991 suRF3 010 7,136 5,682.2 45.18 PACKER Baker FHL packer 1011611986 2.991 7,149 5,691.3 45.18 NIPPLE Camco'D'NippleNOGO 10/1611986 2.750 7,156 5,696.3 45.18 SOS Camoo 10116/1986 2.992 7,157 5,697.0 45.18 TTL 10/1611986 2.992 GAS LIFT, 7,157 5,697.0 45.18 CEMENT PUMP 8.6 BBLS OF 15.8 PPG CLASS'G' CEMENT, ALL 5/2312009 0.000 7,076 -- - PLUG PERFS COVERED Perforations & Slots Shot Top (TVD) Btm (TVD) Dons Top (kKB) Btm (ftKB) (ftKB) (ftKB) Zone Data (sh..• Type Comment 7,234 7,249 5,751.3 5,761.8 A-4, A -3, 2T -05 10/1611986 1.0 IPERF 4" HyperJet 11; 90 deg. Ph 7,249 7,274 5,761.8 5,779.5 A-3, 2T -05 10/16/1986 4.0 IPERF 4" HyperJet 11; 90 deg. Ph PBR, 7,122 7,308 7,332 5,803.8 5,820.6 A -2, 2T -05 9/3/2002 6.0 APERF 2.5" HSD PJ /2506 PJ, 60 Deg Random orientation to low side Notes: General & Safe End Data I Annotation 5/23/2009 NOTE: P &A well due to Production & Surface CSG leaks & corkscrewed TBG t 1 PACKER, 7,136 ( 3 NIPPLE, 7,149 SOS, 7,156 TTL, 7,157 IPERF, 7,234 -7,249 CEMENT PLUG, 7,157 IPERF, 7.249 -7,274 APERF, 7,308 -7,332 I PRODUCTION, 7,669 TD, 7,676 I + + I + + E 16 +00 0 00 00 0 0 loo °o a + v o + + Z Z Z Z Z Z Z D NORTH - -- - -- I DRILL S 2T II + + + + E 14 +00 TT 41 ACM \ m - s fsD k E 12 +00 - LJ - � T -J7 13 615 n + i 002 T- 44 $R>g>S A r;I 1pAY F f F R F � 73 F F F F N +II + I + II I E 10 +00 — — — SCALE 100 0 50 100 LEGEND O THERMOSIPHONS i"= 100, IN WELLS LoutasBUSx •.eeoo� ac. FORM: BSIZE s DRAWN. DESIGN: ECM NO: `/ AREA: 2T MODULE:l00fX UNIT: D2 CHECKED: APPROVAL' APPROVAL' CC N0: ConocoPhillips PLOT PLAN — — Alaska, Inc. 1 130 10 Updated Thermosi hon and Well Aabult locations NRB JFC �AtE DATE: CARD FILENAME* JOB N0: SUB JOB NO DRAWING NO: PART REV: REV DATE REVISION BY CHK JOB PROD 1" = 100' 3/13/09 S2T PLT PLN 3/13/09 NSDK 0000 DS2T PLOT PLAN 1 OF 1 1 r� G' C s 3 ?y 2 ki i 1 { s a y , A 4 : t�. 3 e T -05 PTD 186 -144 ©ConocoPhillips Alaska, Inc This photo is copyrighted bye° ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhilli s Alaska " 2T -05 PTD 186.144 t « Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent .s of con000Philli s Alaska s r < W 4,. v a a C. E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OR .1 5 2009 WELL COMPLETION OR RECOMPLETION REP 1a. Well Status: oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: e •k4 ❑ 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 23, 2009 186 - 144 / 309 - 179 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 August 28, 1986 50 103 - 20075 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 327' FSL, 556' FWL, Sec. 1, T11N, R8E, UM September 2, 1986 2T -05 Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1339' FNL, 1291' FWL, Sec. 1, T11 N, R8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1010' FNL, 1319' FWL, Sec. 1, T11 N, R8E, UM 7584' MD / 5999' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x y - 5970308 Zone 7670' MD / 6060' TVD ADL 25569 TPI: x y - 5973921 Zone 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 499778 - 5974250 Zone SSSV @ 1807' MD / 1801 TVD 2667 18. Directional Survey: Yes ❑ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) approx. 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H -40 Surf. 115' Surf. 115' 24" 240 sx CS II 9 -5/8" 36# J -55 Surf. 3010' Surf. 2792' 12.25" 760 sx AS 111, 320 sx Class G 7" 26# J -55 Surf. 7670' Surf. 6060' 8.5" 525 sx Class G, 175 sx AS I 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7157' 7136' MD / 5682' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. "w ANNE ' ( 7 2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED AA y _ _ 11 009 �I cement plug @ 7157' 8.6 bbls 15.8 ppg Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME li n formations MD TVD Well tested? ❑Yes ❑ No If yes, list intervals and tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1550' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7201' 5727' Base Kuparuk C 7214' 5737' Top Kuparuk A 7214' 5737' Base Kuparuk A 7400' 5868' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed Na J. Ennis Title: Wells Engineer / y Signature Phone 265 -1544 Date o2 1,1 Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 7/2009 ' STATE OF ALASKA RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 l 2009 REPORT OF SUNDRY WELL OPERATIONS Oil & Gas Cons, r 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑✓ • Stimulate ❑ Other ? nc lN rage Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time E #nsion ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 186 -144 / 3. Address: Strati ra hic Service g p ❑ ❑, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20075 - 00 7. KB Elevation (ft): 9. Well Name and Number: RKB 117 2T - 8. Property Designation: 10, i /Pool(s): ADL 25569 Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Q\ Total Depth measured 7670' 1 feet true vertical 6060' - feet Plugs (measured) 7157' Effective Depth measured 7584' feet Junk (measured) true vertical 5999' feet Casing Length Size M TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' SURFACE 3010' 9 -5/8" 10' 2792' PRODUCTION 7670' 7" 7670' 6060' A Perforation depth: Measured depth: 7234' -7274' 30 ' -7332' p true vertical depth: 5751' -57 0 04'- 5821' J it a Tubing (size, grade, and measured depth) 3.5 ", J 7 P57' MD. Packers & SSSV (type & measured depth) ak HL pkr @ 7136' co TRDP - IA - SSA SSSV @ 1807' 12. Stimulation or cement squeeze su CcS�•� �I'-r Intervals treated (measured) cement plug @ 7157' `7 pump 8.6 bbls of 15.8 ppg Class G cement to cover all perfs Treatment descriptions includ umes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure I Tubing Pressure Prior to well operatio Si Subsequent to op ation 1733 14. Attachments 15. Well Class after work: Copies of Log and Surveys run _ Exploratory ❑ Development El Service E ` Daily Repo of Well Operations _X 16. Well Status after work: plugged ❑� Oil❑ Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 hereb certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -179 Conta Ennis @ 265 -1544 Prin d Nam Ennis Title Wells Engineer ( ' O Si nature Phone: 265 -1544 Date �p qq f�! Pre red b aron AlI - D 2 e , 26 33 - 612 4 ', .i. l 9F kLVVV • tai y Y•~• 4 j* Form 10-4 evised 04/2006 ;�� a a 1 Submit Original Only 2T-05 Well Events Summary DATE SUMMARYOPS 4/30/09 GAUGED TBG TO 2.785" TO D PPLE Ca~ 7125' SLM, 7149' RKB. P/U W~ 100 LBS. COMPLETE. 5/19/09 ATTEMPT TO LOAD IA PRE MITIA - UNSUCCESSFUL 5/19/09 TAGGED AND MEASURED BHP @ 7260' RKB: 4700 PSI. ATTEMPTED SET 2.75 CA-2 PLUG~ UNABLE TO WORK PAST 1016' SLM. DRIFTED TBG WITH 10' x 1.75" OD DUMMY TO 7200' SLM WITH NO PROBLEMS. JOB SUSPENDED. 5/21/09 ATTEMPTED DRIFT TBG WITH 17' x 1.75" DRIFT. SPEED OF 210 FPM REQ'D TO PASS RESTRICTION @ 321'. TOOLS STOPPED @ 950' SLM. DRIFTED WITH 15' x 1.75" DRIFT TO 1020' SLM. DRIFTED TBG TO D NIPPLE Ca~ 7149' RKB WITH CAMCO 2.75" A-2 STANQING VALVE. COMPLETE. 5/22/09 LOGGED A GYRO SURVEY FROM SURFACE TO 126'. UNABLE TO FALL PAST 138' DESPITE MULTIPLE ATTEMPTS. 5/23/09 COMPLETED P&A WITH 8.6 BBLS OF 15.8 PPG CLASS G CEMENT. DISPLACED CEMENT WITH 2" OD FOAM WIPER, 5 BBLS OF FRESHWATER, 39 BBLS OF INHIBITED 9.6 PPG BRINE AND FREEZE PROTECTED WITH 18 BBLS OF DIESEL. ESTIMATE 4 BBLS SQUEEZED INTO PERFORATIONS.WELL LEFT SI WITH 1940# OF WHP. WILL RETURN IN AM FOR 2500# PRESSURE TEST. 5/24/09 SUCCESSFUL MIT OF THE TUBING TO 2500#. TUBING BLED DOWN 10# DURING THE FIRST 15 MINS. AND 0# DURING THE 2ND 15 MINS. NO CHANGE ON THE IA AND OA. 5/28/09 STATE WITNESSED MIT-T ~ ~~.~ Cont~toPhillips ` on ,.:,,~,~- , ••• Wx11Conlg. -2TU5.S . .. . ... -~_ _ "' .u,. a. ~~s _ __ SGiei^a:ic-A~:u~.~l , CONDUCTOR, 115 SAFETV VLV SURFACE, 3,010 PeR. ~.~zz ~ACKCR. ].136- NIPPLE.I.'.A9 -- SOS. 7 158 TTL,7,157 IPERF, 1.236-1.2651. CEMENT PLUG.7.157 IPERF, _ _ 7.2/9-7.2I6 APERF, 3 ],308-],332 -~~ PRODUCTION, ] 669 ~ TD,],6]6 KUP ~ ---- 5 FieldName ~ iWellStatus IKUPARUKRIVERUNIT iINJ I,H2S(ppm) ~..Date IMnotationlEndData i Last WO. ! epth(RKB) iEntlDate Mnotation 7.260.0 '~, 5/79l2009 IRev Reason: P8A WELI Rvol rov~~d (ftK8) (ftK6) (°) 1.807 1.801.4 13.96 7,076 5,639.6I 44.80 7.122 5,672.3 ~ 45.18 ~.iae s,ssz.z~ as.ia 7,749 5,691.3 45.18 7,156 5,696.3 45.15 7.157 5.697.Oi 45_18 2T-05 kK6) IAct Btrn (ftK6) 3,t00D0 7,6760 3rd (ft) I Rig Relaase Dat 40_00 9/5/1986 Mod By I End Date Imosbor ~, 5l2512009 Comment TROP-1ASSA (Control Line Deteated; Not Lc 3X/1.S/DMYIRO-S/// CommenC STA 1 HL packer ~ ~~ ~ Top (ftK6) Bbn (RKB) Top(TVD) (ftK6) Bim(TVD) (NKB) Zone I ! Date SAot Dens (sh-~ I ~~, Type CommaM 7,234 7,249 5,751.3 S,J61.8 A-0, A3, 2T-05 10/1611986 ~ 1 A~,IPERF 4" HyperJet II; 90 deg. Ph 7,249 7,274 ~~ 5,761.8 SJ79.5 A-3, 2T-05 10/76/1986~ 4.O~IPERF 4" HyperJet II; 90 deg. Ph 7, 308 7,332 ~', 5,803.8 _ _...._- 5,820 6 A-2, 2T-05 __ 9/32002 6 0 APERF 2.5" HSD PJ/2506 PJ, 60 Deg 'I , , ! . i .. _ .. .... ._._ . _. _. . Rantlom orieNation to low side . _ . . __. -_. . _- ~ Notes: Ge Entl Date neral & Safet y -- ---_ _. __ _ Annotation ~5/23/2009 NOl E~ P&A well d~e to Production 8 Surtace CSG leaks 8 corkscrewed TBG MEMORANDUM To: Jim Regg ~j t< i P.I. Supervisor l ~ ~ ~G J FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-OS KUPARUK RIV UNIT 2T-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~~- Comm Well Name: KUPARUK RIV UNIT 2T-OS API Well Number: 50-103-20075-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608120729 Permit Number: 186-144-0 ;, Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T 2T-OS Type Inj. ~ N-_ TVD 5682 '~ IA 1140 1260 ~ P. D 1861440 TypeTest sPT j Test psi 1500 / OA 60 - ~_-~ - - ~- ~ ~ - Interval axRTST p~F F ~ Tubing lsoo Notes: Pumped 10 BBLS diesel; IA did not pressure up. y~ ,~ r J-,' 4 . Wednesday, June 10, 2009 Page I of 1 MEMORANDUM TO: Jim Regg ~ P.L Supervisor ~~ e~ :~ ~(Z~~l FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 08, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-OS KUPARUK RIV iJNIT 2T-Os Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Jam" ~~-' Comm Well Name: KUPARUK RIV UNIT 2T-OS API Well Number: s0-103-2007s-00-00 Inspector Name: John Crisp Insp Num: mitJCr0906021s4309 Permit Number: 186-]44-0 Inspection Date: s/28/2009 Rel Insp Num: Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. - - Well aT-os Type Inj. N~ Tarp P.T.D~ts6laao TypeTest SPT Test psi s6s2 zsoo IA~ Viso i Ilso Op ~o +-,zo ~ Ilso 7o nos ~ zo Interval oT~R p/F' P Tubing I6oo zsoo ~ 2aso zaao Notes' TJ &cement plug perforation test..3 bbl's pumped for test. 1 ~~ ~. y i ~,, ~ ~.. p e t - w~'iaai/`L'+~Y Li:inksu'+" - .L ~,:-ll L~... Monday, June 08, 2009 Page 1 of 1 • ,, - ,~ ~ ~~ 4 '~ ~ ~ k ` SARAH PALIN, GOVERNOR ALA58A OII. A1~TD GA5 s 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COM1~II551O1Q.. ~'~-- - ANCHORAGE, ALASKA 99501-3539 r PHONE (907) 279-1433 ~ FAX (907) 276-7542 Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ; ~~~.~ ~~'~~' ~ ;1 ~~~~ 1~~ Anchorage, Alaska 99510 ~ ~, `~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-05 Well Sundry Number: 309-179 Dear Ennis: 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 (pagers . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this ~ day of May, 2009 Encl. u U Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Thursday, May 21, 2009 2:38 PM To: Maunder, Thomas E (DOA) Subject: 403 for 2T-05 (PTD 186-144) Attachments: 20090521170238 001.PDF ~» Z0090521170238_0 O1.PDF (230 KB... Tom, Sharon is sending over the attached 403 this afternoon. With holiday weekend approaching and needing to get this cement pumped, I thought a preview via email was appropriate. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 1 • • age T ks in adva om Maunder, PE AOGCC ~c~,~ ~ `N ~ ~G,~CG ~ e-~ ~v~S~ O~ SCU ec-r~~ v.1 cr t~ `~s- ~ ~ ~ P ~ ~S SJ ~5 ~ ~c,.~ ~~ ~~~ c~-c S~cJ ~c-r~. ~ Wcz- ~ ~S. `f S ~ ~-~~ ~~~-~~c~tt s~S ~~~ ~~ ~~~ o ~ ~~~~~~~~ ~~~ ~s ~~~ A ~ ~ ~~ ~ ~~~~ ~c. ~ ~~~ ~ ~ ~~~ ~ ~ ~~~ P SS ~ ~ ~ I cr ~ ~ v..Sc~ ~~ ~D ~ ©t~ ©1 v~JO ~ l9- ~P~ ~Q©S ~ ~ . i 1~ S ~ p G~ y (ate 29/200 ~ ~ ~~~~ STATE OF ALASKA ~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~a APPLICATI~,O~-~j FOR SUNDRY APPROVAL ~ r.(~'~rv 1 20 AAC 25.280 ~4.sC:~~I~D MAY 2 1 2009 ~fnc4~ ftel B. C..,, n 1. Type of Request: Abandon ^ Sus ~ Operational Shutdown ^ Perforate ^ Waiver~ Other nC ~~~ Alter casing ^ Repair well ^ Plug Perforations Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 186-144 ' 3. Address: Stratigraphic ^ Service ^/ - 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20075-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 2T-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25569. RKB 117' - Kuparuk River Field /Kuparuk River Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7670' ~ 6060' - 7584' 5999' Casing Length Site MD ND Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 3010' 9-5/8" 3010' 2792' PRODUCTION 7670' 7" 7670' 6060' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7234'-7274', 7308'-7332' 5751'-5780', 5804'-5821' 3.5" J-55 7157' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FHL pkr @ 7136' Camco TRDP-1A-SSA SSSV @ 1807' 13. Attachments: Description Summary of Proposal ~ 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 May 23, 2009 Oil ^ Gas ^ Plugged ~ ~ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true d correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Name Jim Enni Title: Wells Engineer Signature ~ Phone 265-1544 q Date ,5 .2 I 0 / Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness .3D f-~ ~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ `` Other: CO~tGC~ ~~5~~~ ~ W\~~~SS Q~SS`1C'f ~c S~ n`~ ~ 4~iA ~ ~ b /~O~ Subsequent Form Required: y~~~ vu, , APPROVED BY 2 ~~ S'T Approved by: COMMISSIONER THE COMMISSION i Date: Form 10-403 Revis~d 06/2006 ,~ :- Submit in Duplicate Suspend Well Procedure Well 2T-05 Kuparuk Injector Pump cement plug for well control barrier Network ? Well History: 2T-05 was originally completed as a single Kuparuk water injector in 1986. In 2008, a suspected surface casing leak repair @ 300' was unsuccessfully attempted using Brinker platelets. On 5/19/09, a production casing leak was identified while preparing for an MITIA. The well was SI and an attempt to set a plug in the 2.75" `D' nipple was unsuccessful due to corkscrewed tubing. The corkscrewed tubing is believed to be the result of well subsidence. The procedure outlined below will suspend the Kuparuk reservoir w! cement until a workover can occur. ' Work accomplished to date: 5/19/09 TAGGED AND MEASURED BHP @ 7260' RKB: 4700 PSI. ATTEMPTED SET 2.75 CA-2 PLUG; UNABLE TO WORK PAST 1016' SLM. DRIFTED TBG WITH 10' x 1.75" OD DUMMY TO 7200' SLM WITH NO PROBLEMS. JOB SUSPENDED. 5/19J09 ATTEMPT TO LOAD IA PRE MITIA -UNSUCCESSFUL. SI INJECTION. 4/30109 GAUGED TBG TO 2.785" ON SLINKY TOOLSTRING TO D NIPPLE @ 7125' SLM, 7149' RKB. P/U WGT 1100 LBS. COMPLETE. 2/1/09 BRINKER PLATELETS SC REPAIR- UNSUCCESSFUL 10/31/08 OA LLR FOR BRINKER PLATELETS 10/27/08 OA LLR 1 BPM @ 210 PSI, 1.5 BPM @ 220 PSI, 2 BPM @ 225 PSI (BRINKER PLATELET ) 4/17/08 T-POT -PASSED, T-PPPOT -PASSED, OA NFT -PASSED 2/15/07 ATTEMPTED TO CLEAN OUT WELL. JOB ABORTED DUE TO EXCESSIVE PICK UP WEIGHTS. PUMPED 200 BBLS OF SLICK DIESEL WITH MI LUBE 776 FRICTION REDUCER STILL WITHOUT SUCCESS. MAX DEPTH ACHIEVED WAS 5750' CTMD W/ 22,000# P/U WT AND A RIH WT OF -7400#. 2/6/07 TAGGED @ 7245' RKB, EST. 87' FILL. 2/5/07 TAGGED SSSV @ 1807' RKB, EXCERISED SAME. IN PROGRESS. "**"" NOTE: SSSV CONTROL LINE REMOVED AT SURFACE, THOUGH VALVE IS NOT LOCKED OPEN """"" Remaining work: RU SLB cementer. Bullhead 40 bbls fresh water down tbg at max rate below 2500 psi followed by 40 sx Class `G' cement w/ additives. Launch "nerf" cmt plug and displace w/ 5 bbls fresh water, 39 bbls 9.6 ppg brine and 18 bbls diesel- SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg pressure to zero. . ~ I v~1~SS ~SSSJ~c~S~ ~j-~-~ aka t Jim Ennis Page 1 5/21/2009 ° Conoco`Phillips CONDUCTOR,~ 115 SAFETY VLV, 1,807 SURFACE.- _._ 3.010 GAS LIFT. PBR, 7,122 PACKER.7.136- NIPPLE, ].149 SOS, 7.166 TTL. 7.157 IPERF, 7.234-7,269 IPERF, ] 24&],274 APERF, 7,3067.332 _- PRODUCTION, ],669 TD, 7,67fi KUP , ( 2T-05 s -----_ (Field Nama Max A -_ Wall Status Inc! (°) ngle & MD MD (kKB) TD ~, Act Bim (flK6) KUPARUK RIVER UNIT ( INJ 46.75 I 3,100.00 i 7,676.0 ~M25 (ppm) Date 'Annotation /End Date KB-Grtl (N) (Rig Release Dat Last WO' 40.00 i 9!5/1986 i epth IftK61 Entl Date (Annotation I Last Motl By 'End Date 6.151 Inc Comment ontrol Line Defeats 4/Comment: STA 1 7,14 1. 46.78'NIPPIE Camco '0'Nipple NO GO 70/16/15 7,156 5,696.3 45.18 SOS Camco .._ _- c 70!16/1_ 7,157 _ 5,697 0'i I 45.18TTL - __.__ _ _.. _ __-_ 10/16/75 _ rtora tions & Slots -_. _____I ( Shot _. Top (TVD) Btm [rVD) Dens (ftKe) Btm (ftKB) ~~. (ftKB) ((iK8) Zone Date (sh... Type C«nmerd 7,234 _ 7,249 - 5,751.3 5,761.8'~AA, A-3, 2T-OS 10{16/1986 1.0 IERF 4" HyperJet II; 90 deg. Ph 7,249 7,274 5,761.8 5,779.SA-3, 2T-OS 10/16/1986 4.0 IPERF 4" HyperJet II; 90 deg. Ph 7,308 7,332 5,803.8 6,820.6~A-2, 2T-05 9/3/2002 6.0 APERF 2.5" HSD PJ/2506 PJ, 60 [ Random orientation to low 2.991 2T-OS (PTD 186-144) Report off~iled MITIA • Page 1 of 1 ~ Regg, James B (DOA) From: Rogers, Brent A [Brent.A.Rogers@conocophillips.com] Sent: Wednesday, May 20, 2009 10:35 AM '\~~ ~~ ~'~ ~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2T-05 (PTD 186-144) Report of failed MITIA Attachments: 2T-05 90 day TIO.jpg; 2T-05 schematic.pdf Jim, Tom Kuparuk water injector 2T-05 (PTD 186-144) failed an MITIA on 05/19/09 while attempting to load for upcoming summer MIT's. The TIO prior to the load was 2500/800/100. The well was immediately SI and freeze protected. The current plan forward is to secure the well with a plug below the packer. `"- Attached is a schematic and a 90 day TIO piot. Piease let me know if you have any questions. w '-~^ #~a~; ~~;~~ .. ._ i`tl~~~i Brent Rogers/Martin Walters ConocoPhillips Alaska Inc. Problem Well Supervisor Office: 907-659-7224 Pager: 907-659-7000 pgr 909 Cell: 907 943-1999/1720 «2T-05 90 day TIO.jpg» «2T-05 schematic.pdf» 8/6/2009 KRU 2T-OS PTD 186-144 5/20/2009 TIO Pressures • u • • C~~a~~c~~l~~l~~pr~ A;1~~k~, ~r~~. KRU 2T-05 . ~4 `., ".~ ' ~ .. ~ ~ ,1~~5'.a~ .~~"a..,~_.: ~I ~, , , ~'~ ,.'ri "i~`~~ "L .'~ e~ i~il Iilh~y 'Y..~':- , .=. I~ i k~ i~ E~~~ ~ hS_~ ~~ APL 501032007500 Well T e. INJ An le TS: 45 de 7201 SSSV Type: TRDP see note Orig 9/5l1986 Angle @ TD: 45 deg @ 7676 Com letion: Annular Fluid: Last W/O: Rev Reason: TAG FILL sssv ~ieo~-isos Reference Lo : Ref Lo Date: Last U date: 2/13/2007 , OD:3.500) Last Ta : 7245' TD: 7676 ftKB TUBING Last Ta Date: 2/6/2007 Max Hole An le: 47 de 3100 (0-7157 ~ i i ~ ;is ' ' ' ' ~ ~ ` - ~ OD:3.50Q `--. - ' ~~~. ~ ~ ~ ` ~~ii: ~ ~~ ~ ~s~ ~ 3~, ei ~.~i 7r`~ ~°.: . P ~ ~ . . ~~ ~ ~ - . ..a. ;ti Et , s, ~~ ,a .._ ~ '~ : ~~ " .`- uy- ~ --= lo:z.9s2) Descri tion Siz e To Bottom N D ~ Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 3010 2792 36.00 J-55 PROD. CASING 7.000 0 7669 6060 2 6.00 J-55 ~~~ ~~~~.~ ~~ ~~ '~' # k~4 k 7 _ ~ e ~ i l ~'ii.~; " 5di { =ti~ ~~4J Ii~~~~ ~ 4 ~!E~ i4F~t ~~ ~~~~`=~i"~~~ ii ~~'.~' Gas ~in Size To Bottom ND Wt Grad e Thread andreuDummy ~~ 3.500 0 7157 5697 9.30 J-55 EUE 8RD AB-MOD Valve t ar M - ~~ ii ~ ~ __ (~~~ - r~, ~~6' ~ba ~ 3 i~ ~3 .~ ~~ ~~: ~~ ~L~ ~'~~ ~ "~"" ~ ( h~ ~ ~r p'~ ^`~ ~+ ~ ~, r ~ ~~'6. _ ~_ €~+.~t i~~ (7078-7077~ oo:5 sao) ~ ~ _ . _ 2one Status Ft SPF Date Interval TVD T e Comment . 7234 - 7249 5751 - 5762 A-4,A-3 15 1 10/16/1986 IPERF 4" H erJet II• 90 de . Ph 7249 - 7274 5762 - 5779 A-3 25 4 10/16/1986 IPERF 4" H erJet II~ 90 de . Ph 7308 - 7332 5803 - 5820 A-2 24 6 9/3/2002 APERF 2.5" HSD PJ/2506 PJ, 60 Deg Random orientation to low side ~ ~~~~ ° - ~r~n~~ ` ~ _ : ~~ , a ~„ ~ ~ „ ) (~ ~~ .~ N E ~ .-! ~;, ,~ ~ ~ ~~ ~ ~ T a _ ` " .-c p ~ iinr,. i3k~ `4 :'-?t ~ :i. .~ . ~ ~i , ~ i.~ I li r = ~? ,. r=; , ~ PBR St MD TV D Man Mfr Man Type V Mfr V Type V OD Latc h Port TRO Date Run Vlv (~~22a~2s, Cmnt OD:3.500) 1 7076 5640 Otis LBX DMY 1.5 RO-5 0.000 0 11/11/198 PROD. CASING ~ ~ 5 ° ~1~~ I = ~ ~1 . - ~ , ~a ih=~ ~~.~ _ a= '~ ° ti ~: p i ~ ~ '"~, '~d ~G°t~~~~ r~~:~ , ~ ~ (oasss, De th ND T e~ ~ D escri tion ID o~:~.ooo, 1807 1801 SSSV Camco TRDP-IA-SSA Control Line Defeated~ Not Locked Out 2.812 wr.zs.oo~ 7~22 5672 PBR Baker 2.991 7136 5682 PKR Baker FHL 2.991 7149 5691 NIP Camco'D' Ni le NO GO 2.750 7156 5696 SOS Camco 2.992 PKR 7157 5697 TT'L 2.992 (7136-7137, OD:6.151) I I NIP I ~~ (7149-7150, ~. OD:3.500) 'i ~ SOS (7156-7157, -+'i~-~ ~~ OD:3.500) ~ ~~~ TTL (7157-7158, '~~~ OD:3.500) PeR (7234-7249) ....._....__ Pert ._ ._. ..--- ~ (7249-7274) _... - --- Pert .._-- _ - _--- . (7308J332) . _-- ~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Sunday, May 03, 2009 5:57 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E(DOA); NSK Well Integrity Proj Subject: FW: 2T-05 (PTD 186-144) Attachments: 2T-05 TIO.png; 2T-05.pdf Jim, Given the recent history of subsidence on 2T pad, I assume that this well will also need an AA. It is our intent to leave the well online until the AA is approved. Piease let me know if this is not acceptable. MJ Loveland Well Integrity Project Supervisor ConocoPhiliips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: NSK Well Integrity Proj Sent: Tuesday, February 17, 2009 4:57 AM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2T-05 (PTD 186-144) Jim, ConocoPhillips is currently in the process of testing a new technology (Brinker Platelets) for leak repair. During the first phase of our campaign we queried our data base for wells that have a failing MITOA. Injection well 2T-05 (PTD 186-144) was one of the wells that the query found. It failed a diagnostic MITOA back in December 2005. At that time, the leak was suspected to be a casing shoe leak. Diagnostics conducted for the Brinker Platelet job indicated an anomaty at 300' that might be a surface casing leak. However due to recent subsidence issues on 2T/2A we can not confirm that it is a leak point or an anomaly in the casing from subsidence. The IA and tubing operate with in normal guidelines with no indication of integrity issues. The platelet job in this welt (Sundry 309-010) did not repair the failing MITOA. It also did not give us any indication as to where the leak is located. We thought that if it were a corrosion leak (vs. shoe leak) we would see a pressure change with the platelets, and did not. In the past and as a precedence we have not reported shoe leaks (as they are not casing leaks per se'). Since this in an unusual case we are unsure as how to proceed. Does this well require monthly reporting and an AA? A TIO plot and a schematic are attached. Please Advise. 8/6/2009 FW: 2T-OS (PTD 186-144) • • Thank you MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «2T-05 TIO.png» «2T-05.pdf» Page 2 of 2 8/6/2009 KRU 2T-OS PTD l 86-144 5/3/2009 TIO Pressures CH~KE FTP F~-r i~P T/l!O Plot - 2T-05 oAP . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ -_--,..,. 200 ~ 2000 ~ ..........................................................................~.....................................~ _-r-a 150 1500 ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ._. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . d 1000 ~- ...........................................................................~.................................... a. E a~ 100 ~ ~ 0 t v 50 500 0 01-Dec-08 01-Jan-09 Date 01-Feb-09 0 ~ KRU 2T-OS PTD 186-144 2/ 18/2009 TIO Pressures CH~KE FTP Frr i~P T11/0 Plot - 2T-05 ~~P . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~,_~..~•~.r 2~0 2U~0 ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 150 Q 1500 ................................................................................................................ E ~ - _," - `~ ~`-,~..,----~~',.-_` ~_ - - -- -_ - - _ -- ---- _ _ _ t ~ _ `"~` 100 ~ ~ 0 .................... .................................... '1000 ....................................................... t c~ 50 50U ........................................................................ . 0 ~ a ' ~ ~ ~ ~ ~- ~ ~ 0 01-Dec-08 01-Jan-09 01-Feb-U9 Date ~ ~ . ~ ~ +~c~~c~~vP~till~~s A~~~~a, ~~~. KRU 2T-05 ~~~ rr"ir'IiII~~ ~2 •tF,.i.'.I~'';~ ti.iihA.,~ r.~'llr~: I ~~1~.~:.~1~~C8~~-_7$~`~ ~ ~~ult~ii ~ r ~ {~~~i`M1 ~~d(':.=x~Wll~l~r~~~~ API. 501032007500 Well T e. INJ An le TS. 45 de 7201 SSSV Type: TRDP see note Orig 9/5/1986 Angle @ TD: 45 deg @ 7676 Com letion: Annular Fluid: Last W/O: Rev Reason: TAG FILL sssv ~ieo~-ieoa Reference Lo : Ref Lo Date: Last U date: 2/13/2007 , OD:3.500) last Ta : 7245' TD: 7676 ftKB TUBING Last Ta Date: 2/6/2007 Max Hoie An le: 47 de 31 00 ODO3.500, ~ ~~~~- ~~~ r .' ~ ~~~ ~°:. ~ - ~~N ~;?~+ ~, ~~IIS`~ _ -1 ~ ~~ k f~ ' , .~ ~ _ ~ , a~.:: , ~,x ~:,G „j; ID:2.ss2) Descri tion Siz e To Bottom TV D Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 3010 2792 36.00 J-55 PROD. CASING 7.000 0 7669 606 0 26.00 J-55 ~~ Ff ~y~j ~~ ~M[ ~~ ~~~~ ~~i"i ~ ` Q L~ ~ s~ r~- ~ ~~ -a-s" ~~ ~ ~ ~ ~ ~, ~fi~ _ i i- '~i '~ ` ' ; ~i~; ~ ~ _ ~ s ~;h~ "~ ~ _ ~ ~ ~; ~ - ~ i„'"~ . Gas Lift . ; ~ Size To Bottom = 5 y ,. ~_ ND W t ~ t Grade Thread andreUDummy 3.500 0 7157 5697 9.30 J-55 EUE 8RD AB-MOD Valva 1 „ ~ y o~ , , ~~ ~ v..:~:~ ," i~ :~ P i~i ~ ~~~~~ ` r ciI °~".t~ ~G~~m";~ {;~ e- ~'~ ~~" w~.F~~,+ ~,"~,~ `~'~ iiM ,. : ~ ~ (7076-7077~ oD:5.s4o) ~"~ h. , . Interval TVD Zone ~ Status Ft SPF Date .. . Comment ~~T e 7234 - 7249 5751 - 5762 A-4 A-3 15 1 10/16/1986 IPERF 4" H erJet II~ 90 de . Ph 7249 - 7274 5762 - 5779 A-3 25 4 10/16/1986 IPERF 4" H erJet II• 90 de . Ph 7308 - 7332 5803 - 5820 A-2 24 6 9/3/2002 APERF 2.5" HSD PJ/2506 PJ, 60 Deg Random orientation to low side N ~'' ~ " ~. ~~~f ~i` ~ ~ ~ ~~_ ~ 3~ t 7Id I~ ~"; ~"< + ,,;E . ` ~ f ` >~ ~ ~ w~ a ~ ~ a. ° ~~ ~~r~ ~ PBR St MD TV D Man Mfr M an Type V Mfr V Type V OD Latc Port h TRO Date Run Vlv ~~izzaizs, Cmnt OD:3.500) 1 7076 5640 Otis LBX DMY 1.5 RO-5 0.000 0 11/11/198 PROD. CASING ~Fl m ,- ~~ - ~ = -- '~. ? `~~~° ~ ,~ ~ -"~k r ~ t `~ ~.. i ? ~ ,..~i _ ~ ~ - ~,.,~n.~~ ~4~~~ ,h ~ . ~ ~;w (oasss, De th ND T e Descri tion ID OD:7.000, 1gQ7 1801 SSSV Camco TRDP-IA-SSA Control Line Defeated~ Not Locked Out 2.812 wr.zs.oo~ 7122 5672 PBR Baker 2.991 7136 5682 PKR Baker FHL 2.991 7149 5691 NIP Camco'D' Ni le NO GO 2.750 7156 5696 SOS Camco 2.992 P R 7157 5697 TTL 992 2 K . (7136-7137, ~ OD:6.151) NIP (7149-7150, OD:3.500) II SOS (7156-7157, ~ .' _ . OD:3.500) '~.;`,-~~ TTL (7157-7158, OD3.500) I Pert ( I (7234-7249) ___...... ... i ; ~ ,' Perf -- - -- (7249-7274) -- - ( ...-._ Perf .:_ -:. .....- (7308-7332) ~ • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 r.~. February 7, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 7,,~~~~ p~pp~~ p~ ~Y. n r, ^~ ~b ~ Dear Mr. Maunder: ~~~~ ~' ;:,~~a~ssio~a >.a«~ p~ ` Please find the enclosed 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we112T-OS (PTD 186-144, Sundry 309-010). The report records the unsuccessful surface casing repair attempt with Brinker Platelets. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, .~ ~' ~'~-'~' G2-~- ('-'"'"`ems-"/~ MJ Loveland Well Integrity Project Supervisor `mil • • STATE OF ALASKA ~~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSI(~~S~B ~. GaS ~©pg. REPORT OF SUNDRY WELL OPERATIOI~A__ . Commie;„w t. operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Ot a ^Q Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ . Chan e A roved Pro ram OA repair w/ g pp g ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ platelets 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 186-144 3. Address: Stretigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20075-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 117' 2T-05 8. Property Designation: 10. FieldlPool(s): ADL 25569 ALK 2667 Kuparuk River Field /Kuparuk Oil Pool e 11. Present Well Condition Summary: Total Depth measured 7676' feet true vertical 6065' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 2893' 9-5/8" 3010' 2792' PRODUCTION 7552' 7" 7669' 3030' Perforation depth: Measured depth: 7234-7274, 7308-7332 true vertical depth: 5751-5779, 5803-5820 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7157' MD. Packers &SSSV (type & measured depth) pkr= BAKER FHL pkr= 7136' SSSV= TRDP 1A SSA SSSV Locked out SSSV= 1807' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: See enClOSed dally report Of Well OperatlOllS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A 2900 1050 2400 Subsequent to operation N/A N/A 2900 1050 2400 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-010 contact Perry Klein/ MJ Loveland Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature ~,...~~ ~~ ~ °'~ ~ ~ Phone 659- 7043 Date ~y `~- Form 10-404 Revised 04/200' ~ ~ ~ ~ ~` P ~` ~~ Submit Orig~ OnIY~ /_/ ~ r~~~ 2T-05 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/01/09 Brinker Platelets SC re air- Unsuccessful; Rigged up LRS to the platelet skid and started pumping diesel down the OA and established a LLR of 4bbls. per min. @ 260psi. 23.4bbls. pumped; Loaded batch #1 100 - 8mm cube light platelets and pumped at a rate of 2bbls. per min. @ 200psi. 15bbls. pumped; Loaded batch #2 100 - 10mm cube heavy platelets and pumped at a rate of 2bbls. per min. @ 200psi. 13.9bbls. pumped; Loaded batch #3 100 - 15mm with 1/2" core heavy round platelets and pumped at a rate of 2bbls. per min. @ 200psi. 17bbls. pumped; Loaded batch #4 100 - 25mm x10mm disc platelets and pumped at a rate of 2bbls. per min. @ 200psi. 17.7bbls. Rigged down LRS and platelet skid. Final T/I/0= 2375/1025/20 Summary Platelets failed to repair leaking OA. Leak Depth is unknown. i ~PLATELETS° Overview & Case Studies Produet ®roervi~w Platelets° are an innovative means of sealing leaks in fluid flow applications such as pipelines, umbilicals and other items of system infrastructure. Platelets° are free floating, discrete particles which are injected into a system which has a known or suspected defect. The Platelets° are transported downstream with the flow in the system and when they reach a leak fluid forces entrain them into it thus providing a seal. This unique and innovative concept is based on the method the human body uses to heal wounds and can be optimised for a wide variety of fluid flow applications. ` Since Platelets° are deployed remotely they are a cost effective alternative to other remedial techniques such as clamps and wraps since direct access to the leak site, and therefore vessel intervention, is not required. Platelets° can be deployed in response to an emergency loss of containment incident but are most effectively incorporated as part of an ongoing integrity management programme to remove unnecessary system downtime. Platelet° material is selected depending upon the conditions within the system, such as pressure, temperature, fluid type, predicted leak geometry etc. but generally polymeric and elastomeric materials have the required characteristics for Oil & Gas applications. In all instances Platelets° are entirely inert and are therefore a low risk solution as they will have no negative effect. on system infrastructure or indeed the carrier fluid. Platelets° can be introduced into a pipeline in a number of ways such as via pig launchers or by pumping through teeing points on the line; in all deployments to-date it has been possible to utilise existing infrastructure for injection and no modifications to the system have been required. Platelets° -The Facts • Remote deployment - no requirement for vessel intervention or access to leak site. • No requirement to shut-down, deployed whilst system operational. • Adaptability for variety of leak scenarios: corrosion pitting, fitting failures, hairline cracks, 6 o'clock grooves. • Emergency response or effective component of ongoing integrity management programme. • Temperature <_ 90°C, Pressure <_ 3,000 psi • (leak/ OPipeline = 1/20. ~~ ~ SARAH PALfN, GOVERNOR ALASSA OII, A1~TD GAS 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COM1~iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ~~~~,~ ~~~ ~ ~~~~ P.O, Box 1003Fi0 Anchorage, Alaska 99510 ~I . ~, Lr i (~' Re: Kuparuk River Field, Kuparuk Oil Pool, 2T-05 Well Sundry Number: 309-010 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 1~~ day of January, 2009 Encl. ConocoPhillips ~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 8, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: C~ ~~~i ,~,~ ~~® ~~ ~~2 ''~ia~t;a ail ~~~ ~uti ... ~~~h ~~ns ~'am~1~si~~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 2T-OS (PTD 186-144) Brinker Platelet OA job. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ,~ ~%~ ~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ,~ ~ EC~IVE~ 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ JAN ~ 3 ZOOS APPLICATION FOR SUNDRY APPROVAL ``~ 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waive nC~i'ag~ Other Q Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved r ram 9 pP P o9 ^ Pull Tubing ^ Perforate New Pool ^ OA repair w/ Re-enter Suspended Well ^ Platelets 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. development ^ Exploratory ^ 186-144 3. Address: Stratigraphic ^ Service Q ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20075-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO^ 2T-05 • 9. Property Designation: ,(D S'~6g DL - 3' a9 10. KB Elevation (ft): 11. Field/Pool(s): Z / ADL ALK 2667 ~ 1• ~ RKB 117' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7676' ~ 6065' Casing Length Size MD ND Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 2893' 9-5/8" 3010' 2792' PRODUCTION 7552' 7" 7669' 3030' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7234-7274,7308-7332 5751-5779,5803-5820 3-1/2" J-55 7157' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER FHL pkr= 7136' SSSV= TRDP 1A SSA SSSV Locked out SSSV= 1807' 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 Operations: January 2z, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/ MJ Loveland Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature ~---~/ Phone 659- 7043 Date ~ , ~., Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance 11~ ^ V J(~~,~5 ~`~~'. i y,E~ ~~ Other: ,~~ ti Subsequent Form Required: L` ice. APPROVED BY l// ~J ~ Approved by: COMMISSIONER THE COMMISSION cv / Date: Form 10-403 Revised 06/2006 ~~ ~ ~ ~ ~< Submit' p i e . ~~_ t ~~` t ~ ~ ~ ~ ~F~ ,f~N 2 Q ?004 .,~.~` "~1~3~0~' • ConocoPhillips Alaska, Inc. Kuparuk Well 2T-05 (PTD 186-144) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 8, 2009 This application for Sundry approval for Kuparuk we112T-OS is for the application of platelets to the production casing by surface casing annulus. Kuparuk River Unit we112T-OS (PTD 186-144) was drilled and completed in April 1986 as a development well and subsequently converted to an injector. Historic MITOA testing indicates a surface casing shoe leak. However, given that the depth of the leak is unknown there is a possibility that the leak is a very deep surface casing leak. This well is included in an experimental 10 well campaign to test new Brinker Platelet technology. Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak (at the shoe or in the casing) with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications and within the operating conditions of the well. Each partial is individually sized to fit the predicted leak geometry. With approval, application of the platelets will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Krt1 £(1/01 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-05 KUPARUK RIV UNIT 2T-05 \ fl:, V \ 4-Y" FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed B~ P.I. Suprv ..:JE>£-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-05 API Well Number: 50-103-20075-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603142310 Permit Number: 186-144-0 Inspection Date: 6/2/2007 ./ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-05 Type Inj. G TVD I 5682 IA I 1550 I 2970 2930 2930 P.T.D 1861440 TypeTest SPT Test psi I 1500 OA 240 I 240 240 240 ! Interval 4YRTST P/F P :/ Tubing 3600 I 3600 3600 3600 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. / sCANNED JUN Z () 2007 _..t~~,!·..1tI,' Wednesday, June 06, 2007 Page I of 1 ') ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~~ s~:~r~isor~11 1'{ .-"-fo5" DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-05 KUPARUK RIV UNIT 2T-05 ; \ \,V \; \'''\ . \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ......J~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-05 Insp Num: rnitCS050812190234 Rei Insp Num: API Well Number: 50-103-20075-00-00 Permit Number: 186-144-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -",-;(1'- 2Ì~05-TTyp~ Inj~T-wlTVD--T----5682-!-IAIJ-85o¡- 24SÖ---.¡!----235-Õ¡- 2350 ¡_______U_¡___ ~~;i¡~61::~~eTe;;;SPTJ Te;! pSILI4205~~~~[,'o:00=+ ';070 ± :~~f~:~+:~]--- -:~ Notes: Pretest pressures observed for 30+ minutes and found stable_ :){,;l'\!¡\t~lr:.}) ·S E p. ?' D~; Wednesday, August 17, 2005 Page 1 of 1 Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 ~ Anchorage, AK 99510-0360 ConocoPh ¡IIi pS Phone: 907-263-4574 December 17,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2T-05 (APD # 186-144) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 2T-05. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M.J;{~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 0 5 2004 Alaska Oil & Gas Cons Com' . . miSSIOn Anchorage SCÁ~!\IE[) JAW 2 {j 2004 0 R \ G \ N A L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance 0 Annular Disp. D Alter Casing D Repair Well D Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change Approved Program 0 Pull Tubing D Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 186-144/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20075-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 117' 2T-05 8. Property Designation: 10. Field/Pool(s): ADL 25569 1 ALK 2667 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7676' feet true vertical 6065' feet Plugs (measured) Effective Depth measured 7559' feet Junk (measured) true vertical 5982' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 2893' 9-5/8" 3010' 2792' PROD. CASING 7552' 7" 7669' 6060' Perforation depth: Measured depth: 7234'-7274',7308'-7332' true vertical depth: 5751'-5779', 5803'-5820' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7157' MD. R E C E IVE D Packers & SSSV (type & measured depth) pkr= BAKER FHL pkr= 7136' JAN 0 5 2004 sssv= sssv SSSV= 1807' 12. Stimulation or cement squeeze summary: AlaSka un ðt bas lJons. I,OmmlSSIUlI Intervals treated (measured) 7890' Anchorage Treatment descriptions including volumes used and final pressure: 720 bbls seawater 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation n/a -- Subsequent to operation n/a 1937 - - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJ0 WINJ D WDSPLD 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: Contact Mike Mooney @ 263-4574 Printed Name Mike f\¡~ooney Title Wells Group Team Leader ./ Signature J J t . J Phone Date 12/ Z. Z/O..::3 fell ;:;ìf) HI ¿ '\ Prem:m:~d hv Sharon AII.c:un-Drak~ 263-4612 v t. ~ Form 10-404 Re\Osed 2/2003 . 0 RIG I N A L IBIIs ÐtL sJür ~ i &E ConocoPhillips Alaska, Inc. KRU 2T -05 2T-O5 API: 501032007500 Well Tvce: INJ Angle (â) TS: 45 deQ (â) 7201 SSSV Type: TRDP see note Orig 9/5/1986 Angle @ TD: 45 deg @ 7676 SSSV Completion: (1807-1808, Annular Fluid: Last W/O: Rev Reason: PERFS bv ImO 00:3.500) Reference Loa: Ref Loa Date: Last Update: 11/5/2002 Last Taa: 7559 TD: 7676 ftKB ., Last Taa Date: 8/30/2002 Max Hole AnQle: 47 dea (â) 3100 ... Casina Strina - ALL STRINGS . DescriDtion Size TOD Bottom TVD Wt Grade Thread ,.' CONDUCTOR 16.000 0 115 115 62.50 H-40 , SUR. CASING 9.625 0 3010 2792 36.00 J-5S ~ PROD. CASING 7.000 0 7669 6060 26.00 J-5S Gas Lift ;;>:' TubinaStrina -TUBING mdrellOummy" Size I TOD I Bottom I TVD I Wt I Grade I Thread Valve 1 3.500 I 0 I 7157 I 5697 I 9.30 I J-55 I EUE 8RD AB-MOD [1076-7077, ...:....-_....",.1!1 PeJforationsSummarv ...',... ..:..: ... ...."" ',:.. ,'::>. '..:... .~..:......., " 00:5.940) Interval TVD Zone Status Ft SPF Date Type Comment 7234 - 7249 5751 - 5762 A-4 A-3 15 1 10/16/1986 IPERF 4" HvperJet II' 90 deo. Ph 7249 - 7274 5762 - 5779 A-3 25 4 10/16/1986 IPERF 4" HvperJet II' 90 dea. Ph ...: .. 7308 - 7332 5803 - 5820 A-2 24 6 9/3/2002 APERF 2.5" HSD PJ/2506 PJ, 60 Deg Random orientation to .... low side PBR .,'.,:.',.. [1122-7123, St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv 00:3.500) Mfr TvDe Run Cmnt ...1 1 7076 5640 Otis LBX DMY 1.5 RO-5 0.000 0 1/11/198 Other(oluas;eauip..etc. -JEWELRY.. ....... .,. . .. .. . ..: Depth TVD TVDe Description I D 1807 1801 SSSV Cameo TRDP-1A-SSA (Control Line Defeated; Not Locked Out) 2.812 7122 5672 PBR Baker 2.991 7136 5682 PKR Baker FHL 2.991 - 7149 5691 NIP Cameo 'D' Niccle NO GO 2.750 PKR 7156 5696 SOS Cameo 2.992 (7136-7137, 7157 5697 TTL 2.992 00:6.151) GeneraINotes... ... '. ... Date Note 5/14/2000 Control line appears to have ice plug uphigh, will not take fluid. WATCH OUT. Suggest lockout SSSV. See WSR. lHES) ~ NIP (7149-7150, 00:3.500) TUBING (0-7157, 00:3.500, 10:2.992) SOS (7156-7157, 00:3.500) . Perf - - - - -- (7234-7249) - - - - -- - -- - -- ;;;;; ;; ;;; ;;;;; Perf - -- [1249-7274) - - - - -- -- -- -- -- == == Perf - -- (7308-7332) - - - - -- -- -- -- ----,- -- 2T -05 Event H ¡story Date Comment 11/22/03 PUMP HPBD TO INCREASE INJECTION RATE INTO THE A SAND. PUMPED 720 BBLS OF 50 DEG SEAWATER @ MAX RATE POSSIBLE (9 BPM AVERAGE) @ 4000 PSI. PUMP 4 STAGES WITH 15 MIN SHUT DOWNS IN BETWEEN STAGES. [HPBD] Page 1 of 1 12/12/2003 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 1, 2002 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-05 (186-044) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 2T-05. If there are any questions, please contact me at 263-4574. Sincerely, tlV[. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED oCT 0 9 2002 Oil & An~,h0mge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging_ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Conoco Phillips Alaska, Inc. 3. Address P. ©. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4951' FNL, 4723' FEL, Sec. 1, T11 N, R8E, UM At top of productive interval 1339' FNL, 1291' FWL, Sec. 1, TllN, R8E, UM At effective depth At total depth 1004' FNL, 3956' FEL, Sec. 1, T11N, R8E, UM Perforate _XX Other_ 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 498945, 5970308) (asp's 499709, 5974255) 6. Datum elevation (DF or KB feet) RKB 117 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2T-05 9. Permit number / approval number 186-144 / 10. APl number 50-103-20075 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 115' 16" SUR. CASING 2978' 9-5/8" PROD. CASING 7639' 7670 feet Plugs (measured) 6060 feet 7559 feet Junk (measured) 5982 feet Cemented 240 sx cs II 760 sx AS Ill, 320 sx Class G 525 sx Class G, 175 sx AS 1 Measured Depth 115' 3010' 7669' True verticalDepth 115' 2792' 6060' Perforation depth: measured 7234' - 7274', 7308' - 7332' RECEIVEr' true vertical 5751' - 5779', 5803' - 5820' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7157' MD. Packers & SSSV (type & measured depth) BAKER FHL @ 7136' MD. OCT 0 '2002 0il & CAMCO TRDP-1A-SSA (CONTROL LINE DEFEATED; NOT LOCKED OUT) @ 1807' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl N/A N/A Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil __ Gas __ Suspended __ Service_XX Water Injector WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ Title: Wells Team Leader Michael Mooney . ,~ LUUL Form 10-404 Rev 06/15/88 · Questions? Call Mike Mooney 263-4574 Date /~,/'/~ 2~ Prepared b~y Sharon AIIsup~Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 2T-05 Event History O8/26/O2 08/30/02 O9/O3/O2 PERFORMED A FCO TO 7558.7' CTMD. RETURNS 1-1+ ALL DAY. RETURNED WELL TO INJECTION. FINE SAND AND CARBOLITE ABLENTY IN RETURNS. GOOD GEL SWEEPS. SONIC PICK UP TOOLS BY SCHLUMBERGER TEST DAY. [FCO] DRIFT TBG W/23' X 2.63" HCDG, TAGGED FILL @ 7559' RKB EST. 285' RAT HOLE.NO PROBLEMS PASSING THROUGH SSSV, COMPLETE [TAG] PERFORATED: 7308'- 7332', 6 SPF POWERJET ALL SHOTS FIRED. WELL HANDED BACK OVER TO FACILITIES. [PERF] 2002 Page 1 of I 9/30/2002 '" STATE OFALASKA 3 ~ ! I.~ ~ .r~ A t ~ OIL AND GAS ~SERVATION COMMIS,~ION ~ ~'~ - REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development "'X'- Exploratory _ Stratigraphic Service X 4. Location of well at surface 327' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1339' FNL, 1291' FWL, Sec. 1, T11N, R8E, UM At effective depth 1069' FNL, 1313' FWL, Sec. 1, T11N, R8E, UM At total depth 1010' FNL, 1319' FWL, Sec. 1, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7670' 6060' feet feet 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-05 9. Permit number/approval number 86-144 / ~-170 10. APl number 5o-103-20075 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Cement: 7584'-7670' feet Effective depth' measured 7 5 8 4' true vertical 5999' feet feet Junk (measured) None Casing Length Structural Conductor 8 0' Surface 2 9 7 8' Intermediate Production 76 3 9' Liner Perforation depth: measured 7234'-7249' 7249'-7274' true vertical 5751 '-5762', Size Cemented 1 6" 240 Sx CS II 9 5/8" 760 Sx AS III & 320 Sx Class G 7" 525 Sx Class G 1 SPF, 90 degree phasing 4 SPF, 90 degree phasing 5762'-5779' Measured depth 115' 3010' 7670' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 7157' Packers and SSSV (type and measured depth) FHL Pkr %~ 7136', Camco TRDP-1A-SSA ~ 1807' 13. Stimulation or cement squeeze summary Convert well from A & C Sand production service to A & C Sand injection service Intervals treated (measured) True vertical depth 115' 2792' 6060' RECEIVED JAN 1 4 ]991 Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1311 4058 0 - 1050 225 Subsequent to operation - 0 - - 0 - 3200 1325 2040 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data . ..i,.%: WALTER J. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (907) 762-2553 · !'.3 - ..... - :'.:~.- .-- . ,5:. Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in Ti 1N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, ~.mes E. Eason XDirector cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 t99t Alaska 0il .& Gas Cons. commission gnch'orage ~z~..d¢ p'r,nt,eu r)t~ r~.~c'ic:ed paper DEI~Xi~T~IEN'I' OF N~XTUI~AL I~ESOUI~CES August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 STEVE COWPER, Dear Mr. Wood' In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ames E. Eason i rector . cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR RECEIV[ D AUG - 5 1 J88 A_ lasl;'.4 IL'il L': {.~.::.; L'::~m..,.: .......... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. T.vpe of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension r-q.; Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska: Inc. 3. Address P.O. Box 100360~ Anchorage~ Alaska 99510 4. Location of well at surface 327' FSL, 556' FWL, Sec, 1, T11N, R8E, UH 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-05 feet At top of productive interval 1339' FNL, 129].' At effective depth 1069' FNL, 1313' At total depth 1010' FNL~ 1319' FWL, Sec. 11. Present well condition summary Total depth: measured true vertical FWL, Sec. FWL, Sec. 1, T11N, R8E, UM 1, T11N, R8E, UM 1~ T11N, R8E~ UM 7670' 6060' feet feet Plugs (measured) 8. Permit number 86-144 9. APl number 50- 103-20075 lO. · P°dKuparuk River Oil Pool Effective depth: measured 7584' feet true vertical 5999' feet Junk (measured) Casing Length Size Cemented Conductor 80 ' 16" Surface 2978' 9-5/8" Production 7639 ' 7" ~(~,~KXXXX 7234'-7274' MD Perforation depth: measured true vertical 5751'-5779' TVD Measured depth True Vertical depth 240 Sx C.S. II 760 Sx A.S. III & 320 Sx Class G 525 Sx Class G & 115' 115' 3010' 2792' 7670' 6060' INDEFIi' ilfEL'Y'''' , Tubing (size, grade and measured depth) ""' 3 ]./2", J.-55, tbg w/tail @ 7157.! Packers and SSSV (type and measured depth) FHL Packer @ 7136' MD & TRDP - ].A-SSA SSSV @ 1807' MB 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Convert well from production service to water in,~ection service. 13. Estimated date for commencing operation 03/30/88 14. If proposal was verbally approved Approved by Name of approver Z- .~'/"1, [//- Date approved 2 ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~(~ ~ ~~.~..? Title ~_ '~, ~g~(,~. ~~,._,~ ~ Date Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity D BOP Test O Location clearanceI ~ ~'/ ~ Mech~ica~ k-~-~- ~ Approved Copy Returne~~j ' 0BIGIN~ SIG~D BY ~ ~/¢_ ~~ :~' LONNIE C. SMITH by order of ' Gommissionor tho commission Dato ~ Form 10-403 Rev 12-1-85 ~¢4 Submit in triplicate STATE OF ALASKA wELL ALASKA'OIL AND GAS CONSERVATION COMMISSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-144 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20075 4. Location of well at surface 9. Unit or Lease Name 327' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1339' FNL, 1291' FWL, Sec. 1, T11N, R8E~ UM 2T-5 At Total Depth 11. Field and Pool 1010' FNL, 1319' FWL, Sec. 1, TllN, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 117' ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/28/86 09/02/86 1 2/16/86* N/A feet MSL 1 17. TotaIDepth(MD+TVD) 18.Plug Back Depth (MD+TVD)19. D~.~ctionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7670'MD 6060'TVD 7584'MD 5999'TVD YES L¢~ NO [] 1807' feetMD 1550' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL/FDC/CNL, Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 240 sx CS II I 9-5/8" 36.0# J-55 Surf 3010' 12-1/4" 760 sx AS Ill & 320 sxI, Class G 7" 26.0# J-55 Surf 7670' 8-1/2" 525 sx Class G & 175 St AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7157' 7136' 7234'- 7249'MD w/1 spf, 90° phasing 7249'- 7274'MD w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 5751 '- 5761 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5761'- 5779'TVD See attached Adder~um., dated 1/13/87 for Fracture. dat-.a. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE sIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure cALCULATEDi~ O~L-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ¢%*Note: Brilled RR 9-05-86. Well perforated & tubing run 10/16/86. // Form 10407 WC1:182 :DAN I ~,ljiG~I0fB~i] Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE fJ~¢" GEOLOGIC MARKERS :FORMATION TESTS . .~- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7201' 5727' N/A Base Kuparuk C 7214' 5737' Top Kuparuk A 7214' 5737' Base Kuparuk A -- 7400' 5868' 31. LIST OF ATTACHMENTS Addendums (dated 11/15/86 & 1/1:~/~7) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~ ~'~_~ ~J~/,L~, Title Associate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct.well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the.~?menting tool. Item 27: Method 'of Opera~ion: Flowing, Gas Lift,.'R.~d Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-i~, (~t~e-r-explain. ~ .".;~ ': Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 9/14/86 10/11/86 2T-5 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak & tst; OK. Rn CBL f/6178' WLM - 3278' WLM. Rn gyro f/6178' - surf. Supervi~ ADDENDUM 10/11/86 12/16/86 2T-5 Rn CBL f/6178' WLM - 3278' WLM. Rn gyro f/6178' - surf. Frac'd "A" sand perfs 7234'-7249' (1SPF) & 7249'-7274' (4 SPF) in 6 stages per 11/26/86 procedure using gelled diesel, 100 mesh & 20/40 Carbo-lite prop. Press'd ann to 2000 psi w/diesel. Tst ins to 8200 psi; OK. Pmp'd 30 bbls 5% Musol, followed by 63 bbls cln diesel @ 2100 psi, 2 BPM. Stage 1: Pmp'd 78 bbls gelled diesel pad @ 20 BPM, 4660 - 3100 psi Stage 2: 20 bbls 100 mesh @ 20.3 BPM, 3160 psi Stage 3: Pmp'd 70 bbls gelled diesel spacer @ 20.4 BPM, 3100 psi Stage 4: 22 bbls gelled diesel w/3 ppg 20/40 Carbo-lite @ 20 BPM, 3100 psi Stage 5: 33 bbls gelled diesel w/ 8 ppg 20/40 Carbo-lite @ 20 BPM, 3100 - 4000 psi Stage 6: 62 bbls gelled diesel flush @ 20 BPM, f/4000 - 6130 psi Total sand in formation: 800# 100 mesh & ±13,000# 20/40 Carbo-lite prop leaving approx 1000# Carbo-lite in csg. Load to recover 285 bbls of gelled diesel, 30 bbls 5% Musol & 63 bbls cln diesel. Job complete @ 1725 hfs, 12/16/86. Drilling Supervisor Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 October 22, 1986 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60070 Well: 2T-5 Field: Kuparuk, Alaska Operator: E. Sellers Survey Date: October 12, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co., Exxon, and Arco as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARRFi ALA~KA~ INC. KLIF'ARUK A L A :-'-'; K A S..i:F' E:'R R'~ ..... Fi;Llbl 1~4 E L I_. :5;I..IR V F Y I NIS li:;:F'i M P A N Y A N CH OIR A G E "' "'- ..... f-~ L ~--.~ .":, I'-.. A V E R T I C A L S EiC T I O N C A I_ C: U L A T E D A L O N F:i C L L]'.~;IJ R E TRUE ~,UB-SEA MEASLIF(ED VERT I CAL VERT I CAL D E: F' T FI ...... 1:) E 1.5 ]"H D E P TFI C:F.~MPUTA]"I ON DATE OC:TOBER 14~ 1986 DATE OF SLIRVEY OL.T~BER 1"' BU.:,.=, i]YRO.'-]i-:nP I i" oL RVEY ,_lOB NUMBER AK-BO-60(~7~D::: F'AGE J. 19.86 KEI._LY B II~:;H'[NI] ELEV. = l17.A~-~ F"F -- "' . , "i -- ~7 ............................................ ' " ~ OF'ERATOR-E. SE:LLERS _.ULIR._~E COLIRSE DOG-LEG INCLINATION DIRECI'ION SEVERITY D E G M I N I"~ E". 3 R E E S ]:) E G / 100 T O T L REF:TANGULAR COORD I " N A T .:: :?~! ~:. ::~::: ~E R T I I-: A L NORI'H/SOI_ITH EAF;T/WEST .'_--.;E C T I ON 0 0. ('-~ () ---'1 ]. '7 ,, '00 0 0 Iq 0. (} E 0.00 0.00 0. (")0 .......................... 0. ()() :200 200.00 8:3.00 0 1_ 5 N 1_ 4- ,, 6'.-.':~ E 0, ()9 0, 4'-',_-, N 0. :14 :300 :3()C), 00. 18::-:. 00 0 15 N 1:3, 10 [ii: 0, 02 0.91 N 0.24 E 0, 94 /.I-()0 400. OCi ........ ........... :i2?-'.!j~i::'"i:i~i .................... i~:i ...... !i]'~:, .......... '~ ':70. '.Si':i 'i!!E ........ ~(::i'-j"'i:i'2i: ............................. ![':"!.:~Zi:--I~ ............................ ~-~)-~ :3'7 -~'.' ................................ 1` ~ ............... :38 !!5 C) (':) 50 (_), 0 () ::ii: 8 :::':. () 0 () 15 hi ::-':'.-:), 6'.:.; E 0, () F.: 1,71 N ("), .59 E:; 1, '7'::) 400 .... ....~'=;'::)9... , '::~9... 4-82 , '::~'").... (") ........ 2:3 I',i.=~': , ::.:.:C).. E (3_, .16 .,..".:'. (')::::... N 1 . (-)c) .... .F.: :2, ":"::',:......, 700 ...................................... '/,'-}9. '~":) .... '-':~:~::t,'' ;-59 ..................... i'i' ..... ':~i;:i ....... N 4.,:,' -~',5E ...... (; :' i"~' .................. ~:.:4 '~i::,.. :,/ ................................................................ N 1_. 64 E:: 2:, 86 8 C) 0 799 9 F,' 6,::,'-' ~.-'-' ':~:: '-',:, A 44 N :':~ 8 60 E C) '-"-' ..,'.:, 3 4.1. 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L :.:.';LIRVFYING COMF'ANY ~LN..(2.!:'J2=~[:L,'::!.!'.~J:~:. a L ;"'~'.~; 1'::: a COMF'UTATION DATE OCTOBER 14, 1..oc, F' A G E 4 ':' ' OCTOBER` 12 []ATE OF ._,URVEY ~ 1 ~,_,E ,JOB NUMBER AK-BO-~,OO..Tf);:'?:~:.::.!.:: I<EL_I_Y BI..ISHING ELEV. = 117.00 FT. ~':' F:' E R A T'O R-- E. :--; E L. L.. E R S ' '1_- I I ' I NTERF JLATE£ "~'Pii~ljD~'i:~i'-iL'iJ~-~'~'~i ...... 10iS6"-~:E'~."T OF MEASLIRED £ EF TH M E A :.:.~; U R E D I rt--I ]"RUE V E I::: 'T I I:": A I._. D E F' '1" H oLIB-._,E~ V E R T I C A L .... D E F']"H ......... TOTAL R i_:i: C 'T' A N G U L ,;4 [i~ ....... c o o R I]I N A'1- E S ........ ill-i::,- T'V I", N 0 R T' H / '..--.; 0 I._1 "1" H E F/S T / W E ::; -I- D I F:: F' E R E N C E V [..:' R T I C A l_ C 0 R R E C: '1' I 0 N 1000 '.;~'.:}'.;~. 97 88'Z':,, 'F~7 ..5. '77 N :B. 80 E 0.03 O. 03 '2 0 0 0 19 8 6 ".~i 8 6';.-~ :2 0 ':~ 9 E "-" ' ..... 7._ 1 75 1:24.4,6 hi 1 . :z5 1 ':' :d 1 . . ,~ ~ ,, ... ,..! ,..l mm :B ()00 :2-784. '? 4 2667. '.-.-/4 6:3 ?. ? 1 N ]. 74. '?'F.) E '2 :l 5.0/:, :2:01.81 4. 0 () () :3490.6, 50o0 41 t-)'?. 74 /_-, 000 4.887. :E: 7000 5584. 7670 6060.00 :B:3'7:3,, d: 6 I :::64.8'7 N ::~ !'_::?. 52 E 50'?. :B4 :2'!;~4.. 2:::i: ,, . I:::~ ,"', c:.~ .... . . ... 40 :ii!: 2 74 204.1 8':'.:' N ..... : ..... 2 :.'-!: E ::: (') () 26 ':.'."'? 0 'il) 2 THE: F:AI....E:I..II_A]'IOIq F'ROIZ:EDURE:S ARE BASED ON I"FIIE L.I::.';IE OF ]"FIIREE I]IME:NSIL-.INAI_. RADII...It-] OF CL.IRVA'TI_IRE MEI"HOD. ARCO AI_A.-,I-...A, Ki_IPARI_IK AL. ASI<A MEASIJRE.'.D ~' TH .1.17 iF: .1. 7 ::ii: 1 7 4.17 51 '7 6 .1. '7 '71 '7 '.:..:.' 'I 7 10:1. 7 1117 1217 1:-]17 141 '7 1517 1618 1720 18:2 :'2: I NC. :.:.'i; F' E.' R F:;.: Y ..... S I...I N W E t.... I._ A N C I--I 0 R A I"~ E A L. A :--; I< A ::-:;LIR VliE Y I NG C ri MF'A N Y L-:OMF'LITATI (:IN DATE OC'TOBER 14, 1986 F'A G E 5 DATE OF ,.,LIRVEY oCTOBER 12., 198/_-, ,_lOB NUMBER AK-BO-60070 I<ELL. Y BLISHING EL. EV, = 117.00 F']", OF'ERAI':'OR--E. :_:;EL~LEI-RS ................................... 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'.:.;' ;l E 0. (") 4 ,[:i,. 0 .1, ................. · ~'] . 0 (') 1 1117 OO .1. ~"~ ()() OO '7 :::/~, N ,l .... 4 [il (), ()5 .... ':"'.6'7 N =; :30 E 0.06 0.01 i :2 i 7'. O0 .............. i."~ .- ii 1.5.: 17, C,O 1 ..:.'-',r..~,- O' ....... O,h '.:.:'. 9,':_:: N ~'., 1 '7 E 0.0'7 ,r:~ 01 .1. 417 ¢]0 1:300 ()0 1 ":' '" =' = .:,..., N 6 '"' =' E 0. I I 0. ('~:':: ,, _ . ~, · ,:', ._1 ... .1.._':; ~ ""~/oo. -' :[ ........ 4 o o 77]n n ............................................. i'?~]'-F;] ........ ih .................................. Y":755_;'"'-~ ............................ n..-7 ............................ 3 :[ o ,, ::'-.i ........................................................................ o 1 ,:'::, 17., C,,[") 1 !":': ()(") ,. C, 0 :32.2 i;:" N '7.5 () E 1.25;' ("`,. i.-) :i:: 1 '717,, ,o C, 16 00., 0 (') 5'2.25".' hi ::i:. 86 E :3.2:3 fi:. () 0 18 i :2 .... ,¢i6 ............. i'?'iSO"L"iSi"5' .................................................................................................................................................................................................................................................................... 7.5. '76 N i .1.. 4.4- E 6.0,':, .-.'-':' '7o ':"' ARIz~o AI. ASKA, INC. KLIF'ARUK A L A S K A M E A '.=_: U R E D COMPUTATION ELATE C'CTOBER 14., 1 'F.,,'86 F:'A O E DATE OF SURVEY FICTaBER 1'=' ,JOB NUMBER AK-BO-60070 KEL[.~Y Bu::'.-.3H.!~.r3 .E.L..E%/,. ........ ..=.. ...... !.!.7.......~;!!;! FT. 0 F'E R A'r 0 R- E, :::'; E/.. l_ E R S Z NTER~D.~ED VALJE.:::, FOR EVEN 10o FEET 01= ::,UB-._,EA DEF'TH · 'I"RUE SUB-SEA ]"OTAI.. vER TiC AL_ VERT I ,]:AL_ "i'~'~-_{~i:'i=ANO'i...li;~'AR ' i]: O ,.'.) F;: I] I NATE'.;ii ............. i;i'6-ETVI:-, DEP]"H DEF']'H IqOF~'FH / SC,_ITH EA'.=.;]" / WEST DIFFERENCE . VER'T I ;:::Al_ L-: 0 R R E r:: T l' 0 N 1 'F¢ :2 ./.-, :2032 2142 2254 :2: ::ii: 71 24?4 275'.:.~ 2901 :3 () 4/=, :L:: 1 ?2 :3:L:::35 :;;:'017 ,, ()0 1 ?0,::;,. OC) 1:36. O0 N 2:3 ,, '.:;'4 E 9117 O0 20()() O0 :[79:30 N ":'~ 87 E · ~-, ~ . · N ~ .,..i ,_ ~, :2 2 :[ %1 6o ......... :,"..i!-fiiiii~i';:"~ii'?) ................................. ~,'.:f",~?~'"~F..~""i'~i .................. 2i.i:/:'ii' 2i: ~ [ii: 2 :L:: 1 '7. C)() 22 C)(;). 0 () 288 ' 44 1'4 d, 2.. 52 E 2417. ,:])0 2:3 (),:"). 0 () :.'-.': 58. 10 1'4 7 ?. '76 E :3 7. :::c) 1. 2: /- "-] 54.71 16. '?1 '7'7.8:3 :2..'::3. 1 1 ':::'/-, 17 0(") 2.~;()(') O0 ~-':'"'": '.'.'"~ ._,z....,. N 124 41 IE 14:2: 4.(':, '-' =' 0:2: -- -- ,~ ......... · ,~.... ".. ~ · .. .,~l ,_1 # 2'. 717 .00 .,.'.-,/-,. C).. (').. 00 621 . 7:3 N 1 ._."] .._,':'. 76 ._ 1 ,:::, 4.. 4:3 42 .04 ' 2 .................... :::i' :1 ?Z ] "i~) i') ~!~;' '?' C)('). ~:'i (') ........................ :~]?:;, ...,.. '-:=.:'..,.. ;i;' "-iq. .......... i :':_ ,,,~; "' ("i. ........ 2::'" '::" ' ................................ ..,.~!'" ...C=;';5-... -2.:','?-i_. .... .................................................................................................................................... 4'=.., . 2(').._ 2 ? 17. C) 0 :2:8 ()(). () 0 8 :;ii:::.:.',. C)7 N 2 .1. 6.47 ]:: :2:'75. C)'7 45.44- :30:1. 7. C)() 2'F'('.)O. ()C) '..'::":7.-.:C). 76 N :;2: 4'7. :2:4 Z :31 8.24 4:2:. 17 :_=:617 :}'.:217. O0 3100. O0 11 (')'..i;'. 69' N :}.': 11.44 E 400, 74 40, 96, '-' .~- c4"', .... ,r)'-, '- .=, 7._ 7 :::: :31 '7 C) 0 0 0 4 N 1 4 4 0.7 4 4 0.0 C) ....· _ .~ ¢_) 0 C) 1.~:,..:,, :;-'-: 4 . ""._. (.)' _ .::-i:;~:;~'~2:: .......... :.::,.4".t'?-/6'i"i ................ !i~ii'!~YiXi"/'6'6 ................................. ~[=f-~;;:¥'.-"g;f-'-iq ........................... !?_:rE.' 'g'~i'--.g ................ ~,-~,.:.-, ' ' i-_:]- ................... :}':..'7'".-:-['4-T ................................................................................... 4-0:3 '7 :':: ........................ .":; .1. '7 ("~ 0 :3400 C)(') 1 :::: ::::':). 8:3 iq :3 '? 7 4. :F:'- ~" '-',:. (.)'. 1 '::".._, 40 .2 '7 417:=: :3617 ~' 0 () :3.50 (). 00 1485. () 2 N 428.64 = 561 · 6 L=: 41.5:2: .............................4._:~?"~;}-1 .... ........................................................ :37 ~ 7.00 ........... :~;7:'''~.=, =,(.)c), ............ 0o;:' '- ~ 57:a 2':..) N .~._,o. ~ ~ "=,~, =_-- ..... %-ei:~"::'"i'a .......................................... ~'o"f's? ........ ARCO ALASKA, 2T-5 KLIF'ARLIK . AL. ASKA I NC:. SF.'ERRY--SL.IN WF.L.L. SURVEYING COMF'ANY ANCHORAGE A L A'.:.:K A COMPUTATION DATE OCTOBER 14, ~986 . . PAGE 7 · DATE OF SURVEY oCTOBER 1° ~, 1986 dOB NUMBER AK-BO-6OOZO. K EL l.. Y BI._I'.:~:H I NI".~ E L. E V, = 1 1 7, 0 0 F' T, r.]F'EF~ATOR'E. SELL_ER:--; M E A :i.:.'; I_1R I.'.-.-. D I:' "'TH INTERPOLATED'"VALLiES' FOR "E(,'EN' 1'0© FEET" OF' · TRLIE ~LIB-.= EA TOTAL VIL:;RT'i C-AE' VERT I CAL.. ' ..... -i:.;~'i?.'!:i:'~-"ii~'i~ii]l[~.'~i~:;~ ...... ,~'.iOOF(~i '~ N'it~"i'E:iii; M ]E, -- "I* V [~ -- VER]"I CAL DE:F:'TH DEF"I"H NORTH / S(]U]"H EAST/WEST [:, I FF:ERE;.NCE: CORREC]' I ON 4._, ;¢,:, :'-':'.-'.;' 1 7 0 0 3 8 o 0 0 0 17 6 5,6 6 N 1 '2 8:3 E 6 81 0 5 :':: 9 0 5 4 7 :':: '7 4 017 ......... (')(') :3':.) ¢) 0 0 0 1,:,'-'._, =',:,''''',_~:'-~'"" N ...,'"-..:,'-' c, ''"' . '-'~. ('J E 7 2'_ ¢)_. 0 5 :3. ? . O0 '~' "' 2 ~' ,-1. 2 ....... ?; ::::'::~, 5 6 E 8 ¢)::::, 0 8 ~.. ·, (.~ ..'., 1 '7. (')(') 4 :[ 0 (") 0 0 2 0 5'?..z,' .... 7 N ........... ,.1- 5. ", ..... ,." !::; .1. 7 (") 4:317 0 (".~ 4 "::' ()(') (') 0 ".:' 16 2, 7 3 hi 61:3 .':=;/-, E :::: F; '-':, 7.5 4 .~'; / '"' !5 4 6 ]~ 4._~ 17,0 0 4 4 0 0 ,0 0 2:3 6 '? . P'~_ 4 N 6 ...P'~ ._~, 6:3 E '.*T,',q 4 .... ] 4 5, ,_,c::.. ] · '-;/-, ¢)/-, ,.1. ¢;, 1. 7 0 0 -1. !::; (') (') 0 0 2 4 7:3, 7 4 N 6 7 2 8 2 E ,:),-, o 9/., 4 5 4 5 ....... . - . - ,, . .':. 0 :: . .... . ,':'"' ,":.'-", ..................... .;'*;~: ': "7:;*'* ~ :'7:: ................. -' '-'-" ........ .::,' "':: .................. ]' *:'.'YE:: ............ *. ·, 7.-, ... 4 71 7 0 0 4/-, (")(') (")C, .,.. ,_, 7,:-,,., ;-' N /., ,-., 7./-, .,-. [-. 1 ( ).-, .-,./-, ] 4 5 /- % ........ . ...... . .... · 5 :iii:'.:.') 7 '"1-81 '7.0 0 ,-1. 7 0 0.0('-.~ 2 6 8:3.0'7 hi 6'? !;). '? 4 [ii: 1 ()8C), '7 5 4 5, 14 6 () 4-:3 4';".;' ]. 7.0 0 4 8 00. () 0 2 7 8 8.0 0 Iq 71 (). (".) 7E 1 ]. 2,"_-,. 0/:, 4 .~.:.;. 2:1 · 61:=::=: ~;('i'1'}' ()n ......... ;~"~or~','i:i'il ............. "~.;~i'()':¥,'"':~]:~'"'N 71,..-.~. 4'?E 1171.48 4._. 41 6 ....... :':: 3:3 '::~ 117.00 F:i ¢} () ('~. 0 () 2 F) 97.66 N 725. ......:,'"'-' E 1216 . ~.- '- 44.75 64 '77 .._~':~.._";' 17 .00. 51 () (). ¢:~ 0 :.3102 .10 N '? 2 ?. 9"-) E 12/-, ('~. 90 44. ~'_-,o ./..:,6 21 5:317. () 0 5 2 0 (), () 0 :3 2 () 4.5 !? N '7:3 2..,.:, 8 E 1 3 0 4.12 4 :.".3.2'2 6 7 6:3 5,.1.1 '7 ,, ~:) () 5:3 (:) C). 0 0 :3 :'3 ()5, :31 N 7:3 :]ii:. 5 6 E 13 4 6.41 4 2.2 9 ....... 6'F/0 4 5 5 ]. '7.0 0 5 4 00, 0 0 :3 4 () 5.2::2: Iq 7 2:2.5 7 E:' ]. :2:,L=: 7.4 9 41.0 ? ................................................7044 ._, <:,~- ;":]............. 7. UU;" ': ........... '~._,._i-:.:,":jC U. -':~: ...... C) U:'"': ................................. ._., ._, U .:, .:=5~-"'::':~'"'";~.~'~:: ,:~ ................................... N 7.:,U"-""::-'B':5'. ,:,.: ................ E 1427 . '--¢.-o'--'-' 4(:). 49 ARC:O ALA'.--~KA~ IN~i'~ .,1'-':_:!=1F' ~F~ L_!K .......................... AI_A'.SI<A F:F'E:RRY--.F-i;L.IN WE:I_..I... S:LIF;:t,'EY I NG L-.:OMF:'ANY ~ N C.: H 0 R ~-} C.~ [-'.: A I... A :-q I-':: ~-:~ F'~IG[:.E L:-.: L. JMFIJT/-IT I ON DATE OCTOBER 14, 1986 DATE OF SURVEY OCTOBER 12, 1986 ,..lOB NLI.i'!.BER AI<-BO-6OO~EI~.;i:i ,:' ~.' .: :: :.. KELLY BLISH! N!3.. E..L.~.V..... ......... -...-5. ....... U_.7......!:!C.!. F'"I', O.F'E:RP.~TC~R-F...E ~. i.:-.;.E.-'!~.-..LER.~i SUB~.SEA TOTAL V E R T I C Pt L. R E C: T r:'~ Iq G U I.... ~4 R C: 0 0 R D I N A T E ,.s; DEF'TH NF~R"I" H / S C~ L,I-I"H E:_'AST/WE:S1" TRUE Mr:: nii:.iu Fdii!: D O'F:'. F:"Fi' E "'1" H D E: F'"I' H '7G:2:~) ":"-' ............ · _,,:, 17 C)() 57 O0 00 :::7 ()4 2("~ N 740 48 E 7469 5'P 1 '7. C)O 5800, OC~ :380:3.6S? N 748.54 E 7609 60 :[ 7,, C)() 59()(:). 0C) :3'P() 1.44 N 758. 'P'P E '76 '70 6 () 60 ,, 00 5'P 4:3. C)0 :394:3.4:3 N '7 ~ :3.4:3 E MD-TVD VERT ! CAI, ......................................................... D I F:' F' E R E I',1 C: E is: 0 R R E: C: T I 0 hi 1469 . z.., 41.27 1= · .,11 . 17 4I . PIP]':' 1 .... ... 46 41.3£) 1...,=";/ .... .-..'. 70 40.2:2: 1 ~."-, 1 (-). C)0 17. :3 () 'tHE C:AL C.:ULA'FION F'ROC:EDURES L..:,E A L..INEAR INIERFuLAT!Ciiq' BE'~:'~E'E'~ ........................................................................................................................................................................................... THE NE:AREST 20 FO0"I' MD (FROM RADTU:$; 01-': CURVATLIF~E) F'OINTS ARCO AI_A::;KA~ INC. 2]'--5 KLIF'ARUK AL_ASKA '.:'.i:PEF~:F~Y--SUIq WE:[..[... ~:-.,I..IRVE. k I NG F:F~MF'ANY A N C H (] R A G E A L A S I< A F:OMF'LITATION DATE OCTOBER 14, 1986 I NTERPOLATE[.I Vr~Lu~'i:]:: 'F'OF~""SFi'Ec I AL sURVEY "F'i~i-i i~iTi~.; ............... F' A G E 9 DATE OF z, URVEY OCTOBER 12, 1986 ,_lOB NUMBER A1.(-BO-60070.: :: KELLY BL.I:E;HING ELEV,. ....... '.T,-, .... !....,!....7,.~00 F'T, O PER A T OR- E. :--; E I.. L. E R.'_:; M [.:- A :..-'S.; I..I I:? Iii..'. D 1' .... "'TH ,, 7201 7.'.-.: 14. 7214 74 c:, 0 750 0 / ...' ,:::, 4 TRUE ."-];LIB-SEA VI::!:R T I CAll' VERT I F':AI .... D E F:' -r' H I.] E P '1" H TOTAL i]ilii.l[..i';'-iF;: .... i.:'_'!o01:~:j[.".l'![ N'A":iz-F-_-,.ii!; NC~F;tTH/SOU'TH E.:.A S-I" / NE S;'F MARI..'::ER 5619.55 3623.34 N 735.53 E BASE 1.(UF'ARLIK C · ,,". 1 = . .,-, .-,6.z..-,. '-, ~ N 7._',._,.._,..:, E TOF' KLIF'ARUK A 5750.75 :3754.8'.:.) N '744.26 E B A S E KI...I F'A R I._11.( A 58:21. '7'7 3:iii', 24. '!98 N 75 (). ',:32 E :!:';U R V E Y D E P TI--I TOTAL. DEPTH DRIEL. ER "."T :_--;TRAY I GRAPH I C SLIMMARY DERIVED IJ'._--;ING DII DEPTH?-; AND SPERRY SLIN SURVEY DATA ................... M A R K [ii R .............................. M E A :_:; I..I IR EI] D [.--. P T I--t ......................... '1' V D .................... BKB ........................................... BKB SUB-SEA T(]F' KUF--'ARI...IK C BA::!;F I<I._IF:'ARUK (": TOP KUI:'"ARI...IK A BASE KLIPARLIK A P LIJG BACK T'D l' H I C K N E S 5_ VERT I CAL 7214. 57:36 ":' =~ ._,c-,~--' j. 9 . =',. =', u .._1 ...I . ~ .... '7214 5'7 ::ii: 6,. '.!:_:; 5 56:1. 9..55 7400 P]:::67.7.5 =" ~''- ". ........ 7.,(). 75 7..N ....... :::: 4 !=; 99 :R . ,_,/. ,._,o '=5._ '""c, '-',::, 1.68 ,:,7..4 89N 744 2AE .:. o,::,.: .... ,.:, N 7._, 7.0'7 E 1 ) F'R01"I I.... I I',IEA R Iii[ X 'T'IR A F' 0 L. A'T' I Obi BEI_ O W I'.lE E P E:.".:;'I" S T A 1" I Olxl. 2) ~ ...... ' ......' ...'-'MI- LllI:.F;: Pf;~'C)GI:~:AM ]. '"SF. iER~'Y- [)ATA CALCUL~TION AND INTERPOLATION BY RAD!LtS OF CURVATURE I) ATE OF SL.IRVEY OC'f'OBER 12, ].'78/3 C 0 FII::' LIT A 'T' I 0 hi .[)A T E ............ KELLY..SU, i~.~:',I.Nt3 ELEV. = 117. O0 FT ..:.;:i' '.'. '&¢;:r: ?i:i;"i:!:::i;!i}~i!~.::~:~:~!;(i. ..... .......................................................................................................................................................... SCqLE ;- L ~NCH Td ~.000.00 '/ Ku.mqRdK '7670 , /. / -ECCC. ! ! i ~/ / / 1 ~000.0 qsco qLqsKq. !NC. OCTOBER 12. i986 C, CC $CRLE ;- t iNCH TO i500.00 / tSO0. O KdPqRdK qBco RLflSKR. 2T-5 OCTOBER 12, qK-Oe-OO07C ~988 &~CC. CC %. ,% "~ 7670 ] I I --- - .. ----:---.-....-.--........ -----.... " .' ( ( ',~ Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: /- {s- fJ''Z ate , Required Date Received Remarks Completion Report Well History Samples ~ ~ ~- Mud Log ~ "~\ . Core Chips ~ . Core Description . J ~ ,¡¡ ~ Registèred Survey Plat ~ lhclination Survey ~ ; ~ * ~- Do,,' ° 1 ~4 1rett10na Survey þ','( {I. ,. Drill Stem Test Reports Production Test Log Run Digitized Data .-- . ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE December 31, 1986 TRANSMITTAL #5864 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Final Prints: (1 blueline copy unless otherwise Specified) 2T-5 ~ 5" DIL-SFL-GR 9-3-86 3014-7670 ~5" FDC Raw 9-3-86 3014-7645 '-2" DIL-SFL-GR 9-3-86 3014-7670 '~ 2" FDC Raw 9-3-86 3014-7645 ~'5" FDC Porosity 9-3-86 3014-7645 ~2" FDC Porosity 9-3-86 3014-7645 ~Cyberlook 9-3-86 3014-7635 2T-3 2T-2 ~5" DIL-SFL-GR 9-12-86 3178-7889 ~h2" FDC Raw 9-12-86 3178-7863 "~2" FDC Porosity 9-12-86 3178-7863 ~'~2" DIL-SFL-GR 9-12-86 3178-7889 5" FDC Raw 9-12-86 3178-7863 ~5" FDC Porosity 9-12-86 3178-7863 Cyberlook 9-12-86 7350-7850 ~Cyberlook 9-26-86 8300-8670 x~2" DIL-SFL 9-26-86 3561-8778 2" FDC Raw 9-26-86 3898-8752 ~'2" FDC Porosity 9-26-86 3898-8752 ~5" FDC Raw 9-26-86 3898-8752 '~5" FDC Porosity 9-26-86 3898-8752 5" DIL-SFL 9-26-86 3561-8778 Receipt Acknowledged: DISTIBUTION' NSK' Drilling Rathmell D&M State of Alaska (+Sepia) Vault (film) L. Johnston (vendor package) ARCO Alalka. Inc. il a Subsidiary of AtlanhcRichlieldCompan¥ ...... STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMMI;. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging Alter Casing ~ Other ,_~ Complete Perforatey,~ Pull tubing - 2. Name of Operator ARCO Ala~k,~, Ir~; 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 327' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1339' FNL, 1291' FWL, Sec. 1, T11N, R8E, UM At effective depth 1069' FNL, 1313' FWL, Sec. 1, T11N, R8E, UM At total depth 1010' FNL, 1319' FWL, Sec. 1, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-5 8. Approval number 9. APl number 50-- 103-20075 10. Pool Kuparuk River 0il Feet Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2978' Production 7639' 7670'MD 6060'TVD 7584 'MD 5999 ' TVD Size feet feet feet feet 1 6" 9 -5/8" 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 240 sx CS II 760 sx AS Ill & 320 sx Class G 525 sx Class G & 175 sx AS I True Vertical depth 115 'MD 115'TVD 3010'MD 2792'TVD 7670'MD 6060'TVD Perforation depth: measured _ 7234' - 7274 'MD true vertical 5751' - 5779'TVD Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 7157' Packers and SSSV (type and measured depth) FHL pkr ~ 7136' & TRDP-1A-SSA SSSV ~ 1807' 12. Stimulation or cement squeeze summary Inte~v/a~s treated (measured) Treatment description including volumes used and final pressure /\ Afl .~,~. ' 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History, w/Addendum, dated 9/23/86) Daily Report of Well Operations ~. Copies of Logs and Surveys Run ~{; Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ';gned 10-404 Rev. 12-1-85 Title Associate Engineer [UAM) 5WU/ll~ Date ll-l~-gb, Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25569 Auth. or W.O. no. ~Title AFE AK0723 I Completion COSt center code Alaska JWell no. 2T-5 Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun API 50-103-20075 Complete Date and depth as of 8:00 a.m. IA.R.Co. W.I. 56.24% IDate 10/15/86 Complete record for each day reported 10/16/86 10/17/86 I'Total number of wells (active or inactive) on this ,cost center prior to plugging and I iabandonment of this well I Hour Prior status if a W.O. 1700 hrs. 7" @ 7670' 7584' FC, Rn 3½" CA 11.0 ppg brine Accept ri~ @ 1700 hfs, 10/15/86. ND tree, NU & tst BOPE. RU Schl, perf 7249'-7274' @ 4 SPF & 7234'-7249' @ 1 SPF, RD Schl. RU & begin rn'g 3½" compl. 7" @ 7669' 7584' FC, RR 11.0 ppg brine Fin rn'g 228 its, 3½", 9.3#, J-55 EUE 8RD AB Mod tbg w/SSSV @ 1807', FHL Pkr @ 7136', TT @ 7157'. Tst ann to 2500 psi, tst SSSV; OK. ND BOPE, NU & tst tree; OK. Displ well w/diesel. RR @ 1515 hrs, 10/16/86. Old TD I New TD PB Depth Released rigI Date Kind of rig 1515 hrs. 10/16/86 Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7584' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected . The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 9/14/86 2T-5 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak & tst; OK. Drilling Supervisor STATE OF ALASKA :' ALASKA ,.,,L AND GAS CONSERVATION COMMI$._ .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown~ Re-enter suspended well - Alter casing - Time extension ~ Change approved program ~ Plugging ~ Stimulate ? Pull tubing- Amend order- Perforate ' Other-' 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchoraae. AK 99510-0360 k',,p~,-,,k. I~iv~:r Ilnif 4. Location of well at surface 7. Well number 327' FSL, 556' FWL, Sec. 1, TllN, R8E, UM 2T-5 At top of productive interval 8. Permit number 1406' FNL, 1302' FWL, Sec. 1, TllN, RSE, UM (Approx.) 86-144 At effective depth 9. APl number 1061~ FNL~ 1313~ FWL~ Sec. 1~ TllN~ RSE~ UH (Approx.) 50-- 103-20075 At total depth 10. Pool 1001~ FNL, 1316~ F~L~ Sec. 1~ T11N¢ RSE~ UH (Approx.) Kuparuk R~ver 0~1 Pool 11. Present well condition summary Total depth: measured 7670'HD feet Plugs (measured) None true vertical 6058 'TVD feet 7584 'MD feet JUnk (measured) Effective depth: measured 5997 'TVD None true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 240 sx ~ II 115'MD 115'TVD Surface 2978' 9-5/8" 760 sx AS Ill & 320 sx Class G 3010'MD 2806'TVD Production 7639' 7" 525 sx Class G 7670'MD 6058'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None ~.,~v~ Oil ~, ~ Cons.' ......... Packers and SSSV (type and measured depth) None 12.Attachments DeScription summa~ of proposal ~ Detailed Well History~V~ ~[~-,'' <~-~ v 13' Estimated date f°r c°mmencing °perati°n0ctober, 1986 NDE,~ ~ ~ ~ ~1-~ ~'',~ Y 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ ~~ Title Associate Engineer Date ~-~-~ _ Commission Use Only (DAM) SA/117 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test D Location clearanceI '~--~-~ ~- by order of Approved by .... ......... ~ :" ''~'~: Commissioner the co~mission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company,~, Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough I State Alaska ILease North Slope Borough I I Alaska Field or Unit Well no. Kuparuk River ADL 25569 2T-5 Auth. or W.O. no, T tie AFE AK0723 Spudded Rowan 34 API 50-103-20075 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Hour Prior sta us if a W.O. Spudded 8/28/86 1630 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 8/29/86 8/30/86 thru 9/02/86 9/03/86 9/04/86 16" @ 115' 1473', (1358'), Drlg Wt. 9.8, PV 32, YP 28, PH 8.5, WL 9.5, Sol 10.9 Accept rig @ 1200 hrs, 8/28/86. NU diverter sys. 1630 hrs, 8/28/86. Drl 12¼" hole to 1473'. Spud well @ 9-5/8" @ 3010' 7044', (5571'), RIH Wt. 10.6, PV 20, YP 10, PH 9.0, WL 4.8, Sol 13 Drl 12¼" hole to 3030', short trip, C&C, POOH. RU & rn 75 jts, 9-5/8", 36#, J-55 BTC csg w/ FC @ 2928', FS @ 3010'. Cmt w/760 sx AS III & 320 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE. R!H w/8½" BHA, DO cmt & flt equip + 10' new formation. Conduct formation tst to 12.8 ppg EMW. Drl & surv 8½" hole to 7044', POOH to 2700', repair generator #3, fin POOH. ppg & cont RIH. 432', .35°, N52.1E, 432 TVD, 1312', 1.1°, N34.7E, 1312 TVD, 2098', 23.6°, N14.2E, 2078 TVD, 2538', 38.2°, N12.7E, 2454 TVD, 2965', 46.6°, N16.1E, 2768 TVD, 3324', 45.6°, N17.5E, 3016 TVD, 4089', 45.4° 4916', 46.8° 5417', 46.7° 6969', 44.9° Chg BHA, RIH, rn LOT to 11.45 .67 VS, .62N, .30E 11.57 VS, 10.46N, 6.48E 167.49 VS, 164N, 35E 393.44 VS, 384N, 84E 682 VS, 663N, 159E 940 VS, 911N, 234E , N17.4E, 3557 TVD, 1478 VS, 1428N, 396E , N13.6E, 4141 TVD, 2062 VS, 1989N, 561E , N10E, 4485 TVD, 2427 VS, 2346N, 635E , NO.7E, 5557 TVD, 3539 VS, 3462N, 735E The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 9-5/8" @ 3010' 7670', (626'), C&C Wt. 10.9, PV 22, YP 11, PH 8.5, WL 4.8, Sol 18 RIH to 6980', wsh 60' to btm, drl 8½" hole to 7080'. Raise mud wt f/10.6 - 10.9 ppg, drl to 7670', 10 std short trip, circ gas cut mud & inc mud wt to 11.1 ppg. 9-5/8" @ 3010' 7670', (0'), POOH, LD DP Wt. 11.2, PV 24, YP 9, PH 8.5, WL 5.2, Sol 20 Circ, raise mud wt to 11.2 ppg, 5 std short trip, CBU, TOH. RU Schl, rn DIL/GR/SP/SFL/FDC/CNL f/7670'-7000' & 3650'-3350'; CAL f/7670'-3015', RD Schl. Make cond'g rn, circ; lost 270 bbls & mud cut to 9.6 ppg. Spot 10% diesel pill, TOH 15 stds; well stable. POOH, LD DP. Title ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after aUo,,vable has been assigned or wel! is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indel[nite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0723 County or Parish Lease or Unit Title North Slope Borough ADL 25569 Drill Rowan 34 AP1 50-103-20075 Operator State Alaska IWoII no. 2T-5 A.R.Co. W.I. 56.24% ARCO Alaska, Inc. Spudded or W.O. begun Date SPudded 8/28/86 Date and depth Complete record for each day reported as of 8:00 a.m. I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well our Prior status if a W.O. 1630 hrs. 9/05/86 7670' TD, RR Wt. 11.2, PV 23, YP 11, PH 8.0, WL 4.8, Sol 18 ~0t-- RU & rn 187 jts, 7", 26#, J-55 BTC + 1 mkr jt to ~. Cmt w/350 sx 50/50 Pozz & 175 sx class G tail. Displ w/Il ppg brine, bump plug. Instl pack-off & master vlv, tst to 3000 psi. RR @ 0300 hrs, 9/5/86. Move rig to 2T-3. Old TD New TD 7670' TD PB Depth Released rig Date Kind of rig 0300 hrs. 9/5/86 Rotary Classifications {oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sig~~__~ Dale For form preparati .... d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ~ ;;~..;-::'.-:":::-?..-~: :,'-:--'; :~:,~-?~ _:. :: j-:-: Anchorage. Alaska 99510-0360 . ._'--:/_J~::.-_- :: ~ -' :__- -_::- : _:~' -:::Telephone 907 276 1215 . DATE 09-10-.86 .eco'r ~ _. ':--'---- -'-. A~ 1119 ~'-~ - ' '- --'-~.-~' ~-'~.-~ .--' P, O, BOX~ 100360-.-.'~' '. ' --~:-~:'~-: ~chorage -- ~ 99510-0360 ~'~:::?--.-_ -~ ~ "'--.. . :: .' ..- · :' _--_ --_ - . _ .- :.:-;~J::-'-:_" Tr~s~tted' herewi~ 'are ~e following items, Please acknowledge receipt ~d ~:~T~_"-"-:. rerun, one signed~~ ~c°p~is tr~smi tal: ' .';. Open· Hole-:~~stin~~chl: One of each ~3 -16.. 08~19-86 Run ~1 0059.0-9071 .- ~3K-15 ... 08-12-86 Run ~1 0968,0-9302 ' ~.2T-6 · 08-21-86 Run ~1 0987,5-8235 ' : ~ ~2T-4 08-12-86 Run ~1 0924, 0-8067 .. ~2T-5 09-03-86 Run ~1 0991/0-7694, ~3/~~_~g~/_~ -- 7~~g~ . _ .. . " . -. Receipt ACknowledged: / k..//' ~/'~ ~5 1'0~C' ate: ~ / Alaska Oil & Gas Cons. Comm!ssicn ARCO Alaska, Inc. ~s a Subsidiary of Atla~ticRic~lJel~Compsny MEMORAI"OUM THRU: Stat of Alaska AI~A~K~OI~,~..-~-~o GAS CONSERVATION CO~-GiioSION C. V/~,'~erton DATE: September 5, Chai~ F~tENO.: D.JFB.II TELEPHONE NO.' SUBJECT: BOP Test ARCO KRU 2T-5 FROM' Lonnie C. Smith ~'/>-M Commissioner ~ 1986 John F. Boyle ~=~ Petroleum Engineer Asst Permit No. 86-144 Kuparuk River Field Saturday, August 30, 1986: I traveled this date from ARCO CPF-1 to Rowan Rig '#34 to witness a BOP test. The test commenced at 6:00 p.m. and concluded at 7:30 p.m. There were no failures, and I filled out an AOGCC BOP inspection rePort which is attached. In summary, i witnessed the BOP test on ARCO KRU 2T-5, Rowan Rig #34. Attacb~nent ~ -_~';i ~: .... . ~~~'.: V'~ :~' ~ --! ~ ~'e~:~'~:': ....... /¢~5!~'~ L'ocatSon~: ~enerhl --~-' G:;heral'Housekeep'ing- 0 ~ Rig 0 ~, .: . .,: >:: . - _ ' -.. Mud Systems Visual Audio :",:,~ Trip Tank ~' ' < ../ Pit Gauge '' .... '-' Flow Monitor .... ..~. Detectors - wen Representative ~0 0 qg/~ casin§ Set- @ 3010' "ft.' :resentative ~ ~ ACCUMULATOR SYST-~M Full Charge. Pressure 30 0 O Pressure 'A~ter CloSurel[ ~ O 0 psig psig Pump incr" clos. pres. 200 psig, . (~ min sec. Full ChargePressure Attained: ~' min~- sec. Controls: Master ~ · ' Remote d~ Blinds switch cover ... '" KellY'and Floor Safety Valves UpPer .KellY'S+'_ Test Pressu~e ~ ~ ~ ~' ~ I : ~ LoWer Kelly'~-'o ~ Test Pressure 30 0 O Ball Type x~O~ Test Pressure Inside BOP~Ok Test Pressure Choke Manifol~k No. /¢ ~00 ~. ~0~ Te~t Pressure ~0 ~ ~0 -_ Test Results: Failures · ':~_ . Repair or Replacement of-failed equipment to be made within . · ~ Commission office notified. No. flanges Adjustable Chokes ~ - 0 Hvdrauicall¥ operated choke TeSt Time / hrs. -~) ~/~' days and Inspector/ ._ = Distribution orig. - AO&GCC' cc - Operator .- cc Supervisor IND[I:INI'I'ELY July 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Te!ecopy: (907) 276-7542 Re: Kupar,uk River Unit 2T-5 ARCO Alaska, Inc. Permit No. 86-144 Sec 1 TllN R8E UM Sur. Loc. 327tFSL, 556'~., · , , , · Btmhole Loc. !093'FNL, 1368'FI'P~, Sec. !, TllN, RSE, ~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to Commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where ~ diverter system is required, please also notify this o=zzce 24 hours prior to commencing e~uipment installati°n so that the Commission may witness testing b~fo~e drilling below the shoe of the conductor pipe. Ver~y~Druly~urs, x Chai~an of Alaska Oil and Gas Conservation Co~ission BY OPCDER OF THE CO~-.~.fISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section ~/o encl. Department of Environmental Conservation w/o encl. Mz-. Doug L. Lowery STATE OF ALASKA · _ ALASKA ...- AND GAS CONSERVATION CE,,,~MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen©1 Service [] Developement Gas ~ Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet ~uparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 327'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit ~tatewide At top of productive interval 8. Well nu .tuber Number 1406'FNL, 1302'FWL, Sec.1, TllN, R8E, UM 2T-5 #8088-26-27 At total depth 9. Approximate spud date Amount 1093'FNL, 1368'FWL, Sec.1, TllN, R8E, UM 08/28/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 7645 'MD 1093' ~ TD feet 2T-4 25'(~ surfacefeet 2560 (6060'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth1438 feet Maximum hole angle46 0 Maximum surface I 664 psig At total depth dVD) 3325 psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ?4" 1~" ~9 ~ N-&~ W~l ~ R~ ~ ~ ~ ~ ~ 11 ~ ~ I I ~ ~ ~200 cf 12-1/4"9-5/8" ~6.O~ ,l-55 RTC 2935~ ~ ~' 2970' 2Rll ' 760 sx HF-ERW 320 ~x Class G blend 8-1/2" 7" 26.0¢ J-55 BTC 7611' 34' 34' 7645' 6060' 200 sx Class G(minimum HF-ERW TOC 50~' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~~ ~r~ ~ ~ RECFIVED Surface ~ ~ ~' ;i ;~ ",~ ~ Intermediate Production ii , ~_~,;~ ~}:~ ~ ~ ~ ~ 1:: ~,~ ~a ~ ~ ~L Alaska 0it & Gas Cons. Oommissio~ Liner Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch ~. Drilling program Drilling fluid program ~Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ g Regional Drilling Engineer Signed - ~~ ~ ¢r~¢--- Title Date ~ ~ommission Use Only (LWK) PD/PD301 APl number ~., ¢- I Approval date I See cover letter Permit Number -~ ~-/- 50-/~';~-'~¢~'/~i 07/24/86~ for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ¢, No Hydrogen sulfide measures ~ Yes ~ No ~i~ectional survey required ~Yes ~ No Required workin~surefor~e~M;~ A~; ~ SM; Q 10M; ~ 15M Other: ~ ~~~~~ ~ by order of Approved by k ~ ~* k ~~~~ Comm,ss,oner the commission Date Form 10-401 Rev. -85 Subrfi 'iplicate KuPARUK R I VER UN I T 20" D I VERTER SCHEMF~T I C DESCRIPTION 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. G. 20" 2000 PSI DRILLINQ SPOOL N/IO" OUTLETS. 7. 10" HCR BALL VALVES N/lO" S DIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF HELLBORE FLUIDS OR ~AS IS DETECTED. OPEN ,_. ~DONN"IND DIVERSION. t,~ .$ ~NOT SHUT IN NELL "~ ~.,~ s~'s'O~DER ~NY C ] RCUHST~NCES, J l i 5 4 > ~!A~AM #~ 15-5J,. 5,?,CO .:Si ~SRR,~ ~C~ STACX 1. 16" - 2CCO PSI TAN<CO STARTINS HE. AD 2. I1 · - 3,000 PSI CA,SINI3 FE. AD 3. I1' - 30CO PSI X 13-5/8" - ,SCCO PSI ~AC~R 4. 13r-5./8" - ~ PSI PIP~ 5. 1~-.5/8" - ECXDC) PSI DRILLING SPOCL K/CHCi<E AJ~) KILL LI~ES 6. 13--5,/8" - 5CO0 PSI ~ RAI,4 W/PIPE P, AN~ QN TCP, '7. 13-5/8" - 5OCO PSI ANAJLAR AC~LATOR CAPACITY TEST I. C~ECX A.N) FILL A~TCR ~OIR TO'~ LE'VEL WITH I-h'CI:L~I. LIC FLUID. 2. ~ THAT A~TCt~ PR~~ IS ~ PSI WITH 1500 PSI DClN'~TREAM CF ~ I:~C~.LATCI~. 3. ~VE TIN~, T1-EN CLOSE ALL UNITS SII~ULTASE~Y ALL L.NITS ARE CLOSED WITH a--IARGING ~ CFF. 4. RECCR~ ON NADC I:Fr_PCRT, ~ ACCEPTABLE LC:~ LIMIT IS 45 SECCt~DS CLOSING TI~ AN:) 12CO PSI RE},~AINING P~E~. 13-5/8" BOP STACX TEST 1. FILL BC::P STACX AN) ~ MANIFCLD WITH ARCTIC 2.. Q-ECX THAT ALL L~ ~ ~ IN ~t~_LJ-F_AD FULLY R>E-I'RA~. SEAT TEST PLUG IN 1A~]_LJf_AD WITH R~ING JT ~ RUN IN L~ LIthE VALVES ADJACENT TO BC~ STACX, ALL OTI-ER VALVES AN) ~ SI-EM_D BE CPEN. 4. PRE~ UP TO 250 PSI Ab, D HCLD FOR 10 MIN. IN- ~ PI:~E~ TO 3000 PSI AN) HCLD FOR I0 MIN. BLEED PRE~ TO 0 PSI. 5. CPF_N Ah, N.J~AR PREVF_,NTE,~ AN) ~W'4JAL K~LL ~ C4CKE LII~E VALVES. Q..OSE TCP PIPE RAN'S AJ'~D HC2 VALVES ON K,ILL Ab, D COKE LINES. 6. TEST TO 250 PSI AN) 3000 PSI AS IN STEP 2, CCNTIN.~ TESTING ALL VALVES, LINES, AAD C-K3<ES . WITH A 2..50 PSI LC~ AND 3000 PSI HI~, TEST AS IN STEP .4, DO N3T ~L>F. F~_~J:~ TEST ~ ~ THaT .NOT .A FU_L Q_OSj.h~ PCSiTIVE SEAL ~ ONLY FLA'NCT1GW TES'r Q-KiI~$ I-r-~AT DO ND1 FLLLY Q_QSE. 8, CP~N TCP PIPE RA~ AN:) CLOSE BOTTC~ PIPE RAMS, TEST BOTTQM PIPE RAM~ TO 2.~ PSI AN:) 3000 PSI. 9, CPEN BOT'FC~ PIPE RAN6, BAG< CUT. RtNNING JT AND .i0, CLQSE BLIt~D RAMS AND TEST TO 250 PSI A~D II ~ BLIN3 RAM~ AND RETRIEVE TEST PLUG. MAKE SURE MANIFQLD A~D LINES ARE FLLL CF NC]W-FREEZING- FLUID. SE'T ALL VALVES IN DRILLING POSITION. . TF.~J STRIPE VALVES, Kr~ ~ Y, ~ LY ~S, ~I~ .,~ S~ VALVE, ~ I~I~ B~ TO ~ PSI ~ 3~ PSI ........... RE~ ~ST I~~TI~ ~ ~~ ~l~ ,c~m F~, SI~, ~ ~ TO ~I~I~ ~I~. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS DE~kSSER i' MUD CLEANER $11R .~. CLEANER STIR _ .~. STIR TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casin~ Density 9.6-9.8 PV 15-30 YP 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10-+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight. Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid Practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. LWK5 / ih Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well of this proposed well. PAD 2't WELL .NOt 5' PRDPOSED-; .... KUPARUK ' FI: ELD.'-' NORTH ....................... , - _ ............ !-- . ; - _--::- ........ - ......................... ~ ............... ? .......... i : -' ~ _ __ _:.._'~._ _ _j ....... ~ ....... .... ~ ~ __ _:.'.._ i '-' ':' . , _- ' _ .... .... T- - ? .... '- - ' ~ ........ '" .................. ~' .... '" ~ ' , __ ........... .' '..--'; ';---: .................... ; . _.~ ........ ,i ....... ........ !-~ .................... ~! ................... ~ - ...... ' _ _ ~ ............ 1-- -- ..... '..- ......... ; -- - , ......... ~ .......... 1' ............ · ......... , ........ ' --- ......... ' -~ ..... F- .... . ' ........ ~ _ - . .... .: ........... - 'r ........... , .................. : ................... ~ ~ i ......... : - : -- ~" ................. ~ ....... j ....... KOP -TYD"'1 4:38' THD'" 4.:38 DEP'"O i - ,--_ '3 ~--BASE-'PERHAFROS~VD~156_1~THD-=-156-1'~EP~4 ' . .... TOP UGNU SNDS-iTVD=I-?06 TIeD-l?07 DEP-19 ......... 9 -'i .... - .... ~--- -_': .......i ............... ! ............. ' ............... :' - - 21:_ TOP-~/ SAK-'-SNDS-'-TVD-22Z::I THD-2300'-DEP-191 - 2?:-' ~ - ~ _ ; ...... .: : :.--____ --3~__-- -- '~'1~; 12:--:'TVD"2611 'TMD"2701'----THD'403-- _ ooO Eoc s/.' - --~ --TVD-2811 THD"2970':DEp-583---:-:''- i ............. l ...... ,' -----~--: .... --i ..... i .- ..... :' :-- ~ .... ' ...... .:- ..... ! ............ : " ' i ..... ~ ....... !--: ..... : ...... .......... -- .. ......... ~.__ __;~__ - _ f------ ,._-____ , ........... ~ ............ ~ -- . ......... ! - : ...... }' - ' ; - -! ................. ' ...... : - " .......... i .... i ..... : J ..... : '--: .......... ~ :-' ---i-----'-:-- ~,:-: '- -- --- ~ .... -:__~:-.-;:_ L-:':. :-_:._ i. . !-'_ .. '~' _: .... -" --'---::-:'45 pEg 58:--~]:.N.--::-:-_:: , . ~ , , 6000_2 ........ ~ .............. ?i ...... _.:'~ ...... ~. ....... =-~ ..... ~, ......... . ~'.~__ ,.~: ............. .~., ,t'"~ ~ ~-~~., _ ~-- ........... T/-ZONE A; TVD-$Z99 ~Tt'ID-Z2ZO-DEP-:3674 .... ~ ........ : ....~ ...... : ',g~ ~ ....... ~ - ......... TARGET CNTR_. TVD-5836;THD=Z]2:3!:-DEP=3Z! : .......... ' ' - '~ ' ~ BJ-KUP--SN DS---TV.D-~,S92it--THD"-Z445 i-DEP-:3800 ; . ............. TD_ .(LOG _P~:I:3 .... T..VD_ 6060__._THD Z645,~DEP. 3944_?~- - i . - .... = '-- = - i- ~ .... ~:': i ..... -. b~,s..~"_'. ..... ' , : ~ ~ ~ L -. -t- ....- ,-., r. ~.. ~_. ~J ~,~ _, _~ ....... ~. ....... -:- .... 7000':' ........ ~: ......... i ......... ~: ........ ~;~-, '~, : ~'-- ~- ..... ~, ............. - .. ~. .... ~"~' ......... ~. ............ ,:' -' .......... i .......... I ................. I_ ' i · · · j · : , · j · D : - ..... ~1 000 ........ ~000--~ ......... '~000 ...... :-~ .............. ~- - '- ........ ~ ...... : TARGET LOCAT{ION ( -~- 1320' FNL. I;~' FWt. ......... i - ......... ~c. ~. T~_~E_-.:' _-'7'--~ .... ' - ................. r ......... 4 ..... ~ : i ' ~ " .. :--~~---,-.I- . ~.- ,~ .... ' ] ' ~ . , - i ~ ................. ~ ................ 1 ................~ ...... ........... ' .... ~ ~ ............... i ..... : ............. ~ ........ ...... ~ .... :::::_~f .'~64 ........ ~ ......... .......... : ........ - . . --:-:-: ~;- ..... : .... -:-,--~- ,f ~ ,._~_...~,-.,i .- .__,_-~ ,,.~;: 4..-, . ~.~ ' ,: ~_" ..... ; .... ~ ..... 7~- :-t -~'~ '-: -: :'! : i , · -"'"',.' i":' -r . .7 ' i : f , ~ . :+ ¢ t- · ..... ~ , ' : . ~ , i.~ , , . : , i , ' : .~- : -' ' . ' . ..... ' .~ ~ , . j - ~ ..... ~ ' - ~-' · ~-~~ : ~-' ~" : .' '= : ' : ~ I . : ~ .... ; -" : ~ ..... ~'~ --~ .......... t--- ', :~' , ' ¢ ~ : : ' , '~ /~ '= ' . . - ! , ~ ~ ' . -- ~ : . .... ~,. ~ . i - ' . ~ ~ : i : . ~ '-; . ~ - ' ~ : ~ '. '. . ~ ' ' ~ ~ ~--~; ~'~. ~ .~z.~.s~ ~ . , .., ,..-. , .) . ,. ~. ~~~-~.~,,~.,~,~,~ . ........ ; ......~ _~ ...... ~ ; ---_2 __ i_:~ :~ ' [' _ ':.I' _-- ~ : :.'--L ~. ~ : :~&~'~~~E.F~ ..... :~ ....... ~-:--~--- ;,~-:-- ~--:¥[ :. ~ ,:~T~ :~ ---,~ '-:-~ :---'.-~:--: -~-:-, ::':~-'- ' -4-4-~~~' -' ~-~;~?~.:~-~'~ ~ ~:-~,.~ ~'' ' - ~ .--:-- --- ~:-'-: ,-- ~~~~-~3~:i-:2:~~~-~RGET3~':-:--:- ~ ~; -:-'-~ ':~ 2oo ... , , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2- 17) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure If RECEIVED FFB 0 P Al,,, .... Oil & G-as Con,;;. ~,~;:,, ......... ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany Ti2N ~ ~ 'N ~ -- d ~T~IS ~ ~ ~ ~ ' ,~:' VEY~ ~~ Lsu" % 1 -- , / ~1~ LOOATED IN PROTRAOTED LOOATED IN PROTRACTED SEC. I~ TIIN~R8E~ U.M. SEC. I ~ TIIN~RSE~ U.M. 2 - Y ' 5,970,382.43 LAT. 70~tg'49.~287" t0 - Y = 5,gT0,t32.65 LAT. 70"tg'46.67~9" X ' 498,g44.g3 L0~6.~50~00'30.807" X ~ 498,945.27 L0f16.tS0~00'30.796" ~2' FSL, 55~' F~L 06 ~ 77' PAD - 8Z.S ZS2'FSL, 556' F~L 06 ' 76.0 PAD - 8Z.7 3 - Y ' 5,970,357.42 ~T. 70~9'48.8828" ~ = Y = 5,970,t07.Tt LAT. 70~19 ' 46. 4267'' X ~ 498,944.g~ LON6.~50~00"30.808" X : 498,945.~0 LON6.tS0~00'30.80~" 377' FSL, 556' F~L 06 : 77' PAD = 8~.5 t27' FSL, 556' F~L 06 ' 75.9 PAD ' 8t.7 4 - Y = 5,970,332.46 LAT. 70~g'48.6372" ~ Z2 - Y : 5,g70,082.58 ~T. X ~ 498,944.84 L0flG. tS0=00'30.80g" o X ~ 498,g44.98 L0f16.~50~0030.804" 352" FSL 556' F~L 06 ' 77' PAD ~ 8t 6 '~ ~02' FSL, 556' FYL 06 , · 5 - Y = 5,970,307.52 LAT. 70~g'48.39~g" '~ ~3 - Y - 5,970,057.59 ~T. 70~tg'~S.9336 X : 498,g44.gt LON6.~50~00'30,808" ~o~ X77,: FSL,498'945'08556' F~L 327' FSL, 556' FWL OG = 77' PAD = 81.6 LO 6 - Y = 5,970,282.50 LAT. 70°19'~ 1459" ~ ~ 14 - Y : 5 970,032.60 LAT 70°19'45 6879' X = 498,944.95 LONG. 150°00' 30. 806'' ~ ~ ~ X = 498,944.91 LONG. !50~00' 30.806' 302' FSL, 556' FWL OG = 77' PAD = 81.7 ' ~ ~ o~' 52' FSL, 556' FWL OG = 75.3 PAD : 81.7 ' ~ ~ 15 -'Y = 5,970,007.69 LAT. 70019'45.4428" 7 - Y : 5,970,257.54 LAT. 70°19 47.9003" ~ ~ ~ ~ X 498,944.93 LONG. 150oO0'30.806" X = 498,944.95 LONG. 150000'30.806'' ~ ~ 27' FSL, 556' FWL OG = 75 2 PAD = 81 6 277' FSL 556' FWL OG : 77' PAD = 81.6 ~ · · 8 - Y = 5,970,232.63 LAT. 70019'47.6553" .~ 16 - Y : 5,969,982.85 LAT. 70°19'45.1985'' X : 498,944.96 LONG.150°O0'30.806'' ~ ~ ~ X : 498,944.88 LONG.150°O0'30.807" 252' FSL, 556' FWL OG = 76.9 PAD : 81.6 ~ 2' FSL, 556' FWL OG : 75.1 PAD : 81.7 ~ LOCATED ~N PROTRACTED 9 - Y = 5,970.207.62 LAT. 70019'47.4093" X = 498,945.01 LONG. !50~O0 ' 30. 804'' ~ SEC.;2, T~I N~ ~8~, U.~. 227' FSL, 556' FWL OG = 76.3 PAD : 81.6 17 - Y = 5,969,957.72 LAT. 70°19'44.9514" X = 498,944.94 LONG. 150000. 30. 805" 5. HORIZ; POSITIONS BASED ON TEaR MON~ 2T-EAST, 2T-WE I ~ ASSOC. 4. VERT. POSITIONS BASED O~ TB~'~ 2T-6 B N 19+75~ Eli+ 5~ PER F.R.B. B ASSOC. 5.0.6. ELEVATIONS INTERPOLATED FROM S/C DRA~I~6 CED- RIXX-5140 rev. REGISTERED AND LICENSED TO PR&CTICE LAND SURVEYING IN THE STATE OF ALASK~ ~D THAT I ~ MADE BY ME OR UNDER MY SUPERVISION AND ~ __. I ~ THAT ALL DIMENSIONS AND OTHER DETAILS ~ --m~,~ SURVEYED KOR: ~ ARCO Alosko, lnc. ~.F~~ ffSSflfi, ~,~ ~ ~......~, AS- BUILT LOCATIONS *. '-' ' ilDwG No NSK 86-6 Arctic Boulevard, Suire 201, Anchorage, Alaska 99503 Jloo. ~.s~LE N.T.S. CHECK LIST FOR NEW WELL PERMITS Conpany lJóI- (A Lease & Well NJ. J(y[ ~ '-T-..r- ITEM APPROVE DATE . YES NO J:(J1.l"Ji\1.'Wj (1) Fee ~ 1-ï..-l-lf~ 1. Is the pennit fee attached .......................................... 0 - (2) Loc <~ 7-1..(-3<.0 2. Is well to be located in a defmo ed pool............................. i~ (~8) ,3. Is well located proper distance fran property line.................. ,<- --- 4. Is well located proper distance fran other wells .................... ---- 5. Is sufficient undE;dicated a:reage available ~ this pool ............ = ...... 6. Is well to be devl.ated and 1.S wellbore plat 1.ncluded ................ ~ < :::= ' 4Ø- 0! '/ 7. Is opera~or the only affected p~rty ........:........................ Z!;;: = .. , . J. ? '.).1. $é::' 8. Can pernn.t be approved before f1.fteen-day wal.t ...................... ~ --- I' .1 I ° () ~ I,. I-- (3) Admin -//-- ---/ ?~Ì/f-t~ 9. Does operator have a bond ill force .................................. C1-- :z:- ~ 13) 10. Is a conservation order needed ...................................... ~ ~ ~ ilJ ¡./- ri h L/ %i. 11. Is adninistrati ve approval needed................................... - ~ - ~) 12. Is the lease number appropriate ..................................... ~ . ¡:¡:: L.L.J 13. Does the well have a unique name and nunber ......................... ~ ¿ ~ W~ Casg ~:t~ i~~-S*¿ ~ ... -(T4tliiû 2 ) 14. Is conductor string provided............... ......................... d£.. (~ ~ ~ 15. Will surface casing protec~ fresh water zones....................... tIItL = c.......> ì 16. Is enough cement used to cl.rculate on conductor and surface......... ¿' 8 17. Will cerœnt tie in surface and intennediate or production strings... I = ~ 18. Will cerœnt cover all known productive horizons..................... . ~ ~ 19. Will all casing give adequate safety in collapse, tension and burst.. .. ..... --- ~ 20. Is this well to be kicked off from an existing wellbore. . . . . . . . . . . .. --- p ~ ~ 21. Is old wellbore abandonment I?rocedure included on 10-403 ............ ...' ,. '. --- ~ A I . - ~ ~ ~ 22. Is adequate wellbore separatl.on proposed.. . . . . . . . . . . . . . . . . . . . . . . . . ... --- }<IJR~ JJ./.JIl, .."fÆ/E RI:;MJ4/ftk.s (5) BOPE 1fI.r1.' k 'I-rift !2J - 1'-Jtfiru. 23. Is a di verter sys tern required. . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . .. ¥..' 24. Is the drilling fluid program sch~~tic æ1dlist of equipment adequate~ --- 25. Are necessary diagr~ and descriptions of diverter and BOPE att~ched."" ' DitJI£JltE1l '¡L<¡~~Y~Rl4~~ ~.~. ... fA IE'.. ~+-~. . 26. Does BOPEhavesuf~l.cient pressure rating ... Test to ,,~Oøø pSlg ..¡I/IL - 27. Does the choke mat1l.fold comply w/API RP-53 (May 84).................. ---' HJ $,.ÌJ*:.tJ::~ 28. Is the presence of H2S gas probable................................. ---- L ,w" ,,.-"';'1 ,( "- For exploratory and Stratigraphic wells : " (6) OTHER ~A 29. Are data presented on potential overpressure zones? ................. --- ( 9 thru 31) 30. Are seismic analysis data presented on shallow gas zones............ - 31. If an offshore loc., are survey results of seabed conditions presented = = (6) Add: ~. 7~~.~~ 32. Additional requirements ............................................. --- ~ ~OlO : ~r~: Additional Renarks: ~~'~* '~i~~-~ WWB,. .,.... ...,LCS .. Bm INITIAL.... G EO. .. UNIT ON/OW *'~ -. /:::)<~':¡' . -... ,Ii... .,. . .,..-...~ :.,..;t ~. ' ,\~ _°1 . WVA MIM . HJH;m POOL ClASS STAWS AREA NO. SHORE - @? - &,," .." 'i',' ,- -. .-} t JAL /'-- - ¿¡~ 'I c) ~ r) ~ \ -.." J rr V ) II G ò 0 N rev: 07/18/86 6.011 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. oo ;~ .... $CHLUFt8 ERGER .... LiS TAPE V'ER~FIC~TZgN LI STIN.~ VP 010.H02 VERZFICATZCN LiSTiNG PAGE I '" REEL H=AD,=R ...... ERVTCE NAME :EDIT ATE ;85/09/10 RIGiN : EEL N~ME :152675 ONTZNUATION ~ :01 R=V"'OUS,. ~.REEL : .'3MMENTS :LIBRARY TAPE :"' TAPE Hr-AD=R ..... ERVICE N,~ME :EDIT ,ATE :86t09/10 RIGZN :FSZA APE NAME : ,ONTZNU,ATZDN ,~ :Ol IREVIBUS TAPE : O~MENTS :LIBRARY TAPE ..............,..,.....,. ;',: X: ;k ;:: x: ;:: E 0 ~-, :;:~. FiLE HEADER :I:LE NAME :EDIT ;ERVICE NAME 'E,RSiON ,~ : )ATE : tAX'!MU~ LENGTH :~LE TYPE : 'REVIOUS FILE .001 1024 INFORMATION RECORDS-,--,- ~NEM C3NTENTS 'N : ARCO ALASKA iN : 2T-5 :N : KUPARUK ', ,A N G: BE ;ECT: 'OUN: NORTH SLOPE ;TAT: &LASKA INEM CONTENTS iNC,. >RES: E ~.ENTS ...... UNiT UNIT TYPE 000 000 000 000 000 000 000 000 TYPE 000 CATE 000 000 000 000 000 000 000 000 CATE 000 SiZE 018 0O4 0O8 002 OO4 OOZ 012 006 SiZE 001 CODE 065 065 O55 065 O65 065 055 065 CODE 065 VERiFICATiON LISTtN~ P~GE 2 SCHLUMBERGER ALASKA COMPUTING CENTER ~OMOANY : ARCO ~LASKA INC .~ELL = 2T-5 :~ELO = KUPARUK ;DUNTY = NORTH SLOPE BOROUGH ~T~T6 = ALASKA J~B NUMBER AT ACC: 71694 ~UN ~1., OA'TE LOGGED: 03-SEPT'-1986 .DP: RICK KRUWELL ]ASING : 9.825" @ 3010' - BIT SIZE : 8.5" 1'0 7670' ,YDE FLUID = WEIGHTED NATIVE CLAY )ENSITY = 11.2 LB/G RM = 3.21 @ 66 OF ~ISCDSITY = 42 S RMF = 2.51 @ 61 OF ~d = 8.3 RMC = 2.62 @ 72 DF :LUiD LOSS : ¢.8 C3 RM AT ~HT = 1.66 @ 1'38 DF qATRZX SANDSTONE I:~: THIS O~TA HAS NOT ~EEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS VP 0"~ ~.O.H02 V:RIFIC~TI,SN~. LISTING PaGE 3 '~: SCHLUMBERGER LOGS ZNCLUD[D WITH THIS M~GNETZC TAPE; ~:~ ~,~ DUAL ~N~U'CT~ON SPHERICALLY ~OCUSED L~G (D~L) ~:~ '~: DAT~ AV&IL~BLE: 7670' TO 3014' ~:~ FORMATION DENSITY COMPENSATED LOG (FDN) ~:: CCMPENSATED NEUTRON 'LOG (FDN) =:~ ~',~ DAT~ AVAILABLE: 7645' 7.0 3014' ~',~ =',: GAMMA R~Y IN CASING (GR.CSG) ~1~ ~,~ '"-,- DATA FDRMAT RECORD.~..~. 'NTRY B'LO'CK S TYPE SiZE REPR C~DE ENTRY 2 I 66 0 ~ 1 66 1 $ 4 73 60 $ 4 65 .1 IN ,I 6. I 66 1 0 ! 66 0 ATUM SPECIFICATION BLOCKS .VP 010.HOZ VERIFICATION LISTING PAGE ]NEM SERVZCE iD iE pT ~=LU DTL :LD DZL 'LN DZ L ;P DIL ;R OiL ;R FDN : A L ! F O N ',HOB PON )RHO PON IRA, T FON ]NRA FDN fPHZ FDN ~CNL FON :CNL FDN ;R CSG SERVICE UNIT AP1 AP ORDER ~ LOG TYP FT O0 O0 OHMM O0 22 3HMM 00 12 gHMM O0 12 MV O0 O1 GAPi O0 31 GAPi O0 31 IN O0 28 G/C3 O0 35 G/C3 O0 35 O0 42 O0 O0 PU O0 89 CPS O0 33 CPS O0 33 GAPI OO 31 t AP1 AP1 FiLE E CLASS MOD NO. 0 O0 0 0 0 O1 0 0 0 46 O 0 0 44 O 0 0 O1 0 0 O1 0 0 0 O1 0 0 O1 0 0 0 02 0 O 6 O1 0 0 0 O1 O 0 0 O0 0 0 0 O0 0 0 0 31 O 0 0 30 0 0 0 O1 0 0 SIZE SmL 1 1 1 1 1 1 1 1 1 1 1 1 1 REPR CODE 68 68 68 68 68 68 68 68 .68 68 68 68 68 68 68 P ( O0000000 00000000 00000000 000:00000 OOO00000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 ~GC OCT 000 000 000 000 000 000 000 DO0 000 000 000 000 000 000 000 000 ESS ,aL ) 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 000 :;:: O A T a ...... )EPT ;P ~HOB tPHI 7694.5000 SFLU -60.5000 GR 2.3945 gRHD 37.8418 NCNL )EPT :HO '5 IPHZ 7600.0000 SFLU -42.3438 GR 2.4961 DRHD 32.7148 NCNL ;EPT !PHI 7500.0000 SFLU -56.4375 GR 2.4453 ORHO 32.6172 NCNL ]EPT ~HOB IPHi 7400.0000 SFLU -43.5000 GR 2.4355 DRH3 43.7500 NCNL )EPT ;P ',H3B iPHI 7300.0000 SFLU -52.4375 GR 2.4395 DRH8 33.6914 NCNL )EPT tPHI 7200.0000 SFLU -56.8437 GR 2.4707 DRHg 31.1035 NCNL )EPT ;P 7100.0000 SFLU -55. 6~50~ GR 2.6540 ILD 109.4375 GR 0.0684 NRAT 1899.0000 FCNL 3.8563 ILO 103.3125 GR 0.0322 NRAT 2194.0000 FCNL 2.7995 ILO 102.81.25 GR 0.0059 NR~T 2168.0000 FCNL 2.8847 ILO 107.6250 GR 0.0259 NRAT 1854.0000 FCNL ~.8617 ILO 91.3125 GR 0.021,5 NRAT 2238.0000 FCNL 3.8487 ILO 124.0000 ,OR 0.0132 NRAT 2204.0000 FCNL 110. 2669 iLO OOOO GR 2.5942 109.4375 3.1816 570.5000 3.3582 103.3125 2.9434 718.0000 2.7345 102.8125 2.9238 698.0000 3.0566 107.6250 3.5410 539.0000 4.7253 91.3125 2.9941 733.0000 3.0695 124.0000 2.8513 729.0000 2.&900 110.0000 ILM CALI RNRA GR ILM CALI RNRA GR ILM CALl RNRA GR ILM CALl RNRA GR ILM CALl RNRA GR ILM CALl RNR~ GR ILM CALI 2.52 8.17 3.32 -999.25 . 3. -999. . 8. 3. -999. . 8. 3. -999. 8. 3. -999. . 9. 3. -999. . 45 77 O5 25 85 63 10 25 09 62 43 25 74 57 05 25 29 07 02 25 51 65 43 97 81 O0 64 34 47 O0 58 28 55 O0 38 5O 95 O0 38 1'9 27 O0 13 81 15 O0 25 ,53 .VP 010,H02 VSR!FICATilON LISTING PAGE 5 ~PHI )EPT ;P I PHI )EPT ;P )EPT ~PHi )EPT ;P ~HO6 iPH l )EPT ;P ~PHi }E P'T ;P iP H ~' )E PT iPHi' )=PT ;P ~HO5 ;EPT ;P ~HCB ,~PHI )FPT ;P ~HO8 ,~PHI )--PT 2.5'762 CRHO ~5.7520 NCNL 7000.0000 SFLU -51.2813 GR 2.3457 DRHO 41.2109 NCNL 6900.0000 SFLU -51.8125 GR -999,2500 DRHO -999.2500 NCNL 6800.0000 SFLU -46.7813 GR -999.2500 DRHO -999.2500 NCNL 6700.0000 SFLU -.56.8125 GR '-999.2500 DRHO -9'99.2500 NCNL 6600.0000 SFLU -54.2813 GR -999.2500 DRH3 -999,2500 NCNL 6500.0000 SFLU -64.8125 GR -999.2500 DRHO -999.2500 NCNL 6400.0000 SFLU -68.5625 GR -999.2500 DRHO -999.2500 NCNL 6300.0000 SFLU -66.0625 GR -999.2500 DRHO -999.2500 NCNL 6200.0000 SFLU -54.6563 GR -999.2500 DRHO -999.2500 NCNL 6100.0000 SFLU -45.3438 GR -999.2500 DRH3 -999.2500 NCNL 6000. 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OlO.MO2 VERIFICATIBN LISTING P~G~ ? ),-' P T ~HO8 ~P'H I )EPT )E PT ;P IPHI )EPT ;P ~PHi )EPT IPHI )EPT ;P IPHI >E P'T ;P ~PHi )EPT ;P JPHI )EPT ~HOB 4PHi ) E PT ~P qPHI qPHl 4900.0000 S:LU -28,7188 GR -999,2500 DRHD · -999,Z500 NCNL 4800.0000 SFLU -30.7344 GR -999.2500 9RHO -999.2500 NCNL 4700.0000 SFLU -34.2500 GR -999.2500 DRHO --999.2500 NCNL 4600,0000 SFLU -35,7500 GR .-999.2500 DRHO -9'99.2500 NCNL 4500.0000 SPLU -34.718~ GR ,-999,2500 DR~O -999.2500 NCNL 4400,0000 SFLU -41,7500 GR -999,2500 DRH3 -999,2500 NCNL 4300.0000 SFLU -39.7500 GR -999.2500 DRHO -999,2500 NCNL 4ZO0.O000 SFLU -39,9687 GR -999,2500 DRHO -999,2500 NCNL 4100,0000 SFLU -41.7188 GR -999,2500 ORHO -999.2500 NCNL 4000.0000 SFLU -43.9687 GR -999.2500 ORHO -999.2500 NCNL 3900.0000 SFLO -47.7813 GR -999,2500 DRHO -999.2500 NCNL 3,0606 itD 102.0000 GR -999.2500 NRAT -999.2500 FCNL 2.5415 iLD 105.3750 GR -999,2500 NRAT -999.2500 FCNL 3.3561 iLD 88.5000 GR -999.2500 NRAT -999.2500 FCNL 1,9992 iLD 96,6250 .GR -999,2500 NRAT -999,2500 FCNL 2,9177 ILD 89.5000 GR -999.2500 NRAT -99'9.2500 FCNL 2,6992 ILO 105,8125 GR -999.2500 NRAT -999,2500 FCNL 2.6150 iLO 91,5625 GR -999,2500 NR~T -999.2500 FCNL 2,6782 ILO 87.2500 GR -999,2500 NRAT -999,2500 FCNL 3,0166 ILD 83,1875 GR -999,2500 NRAT -999,2500 FCNL 2.6613 iLD 93,6875 GR -999.2500 NRAT -999.2500 FCNL 2.8374 ILO 94.3750 GR -999.2500 NRAT -999.2500 FCNL 3.3963 ILM 102,0000 CALl -999,2500 RNRA -9'99,2500 GR 2,5843 ILM 105,3750 CALl -999.2500 RNRA -9S9,2300 GR 3.0'739 ILM 88,5000 CALl -999,2500 RNRA -99'9,.2500 GR 2,2735 ILM 96,6250 CALl -999,2500 RNRA -999,2500 GR 3.0992 ILM 89.5000 CALl -999.2500 RNRA -999.2500 GR 2,7953 ILM 105,8125 CALl -999,2500 RNRA -9'99,2500 GR 2,8980 ILM 91.5625 CALl -999,2500 RNRA -999.2500 GR 2.8855 ILM 87,2500 CALl -999.2500 RNRA -999,2500 GR 3.5691 ILM 83.1875 CALi -9'99.2500 RNRA -999.2500 GR 2.9822 ILM 93.6875 CALl -999,2500 RNR& -999.2500 GR 3.1293 ILM 94,3750 CALl -999.2500 RNRA -999.2500 GR 3,3996 8.7734 -999,2500 -999.2500 2,5469 8,7031 -999.2500 -999.2500 2.9792 8.7734 -999.2500 -999.2500 2,2066 9.2813 -999.2500 -999,2500 3.0273 8.9844 -999.2500 .-999.2500 2,7669 9,0938 -999.2500 -999,2500 2.8368 9,0156 -999.2500 -999.2500 2,7518 9.2734 -'999.2500 -999.2500 3.3342 9.1484 -999.2500 -999.2500 2.8673 8.9453 -999.2500 -999.2500 2.9976 9.5156 -999.2500 -999.2500 . 'R TFIC~,TISN LiSTiNG PAG~ >3 VP 01.0 HO2 VE ~. 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