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186-143
RECEIVED • • STATE OF ALASKA NOV 2 8 Z017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ALS la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 0 . Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service 2, Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/29/2017 186-143/317-469 ` 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 8/1/1986 50-103-20074-00 4a.Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 352'FSL,556'FWL,Sec 1,T11N,R8E, UM 8/12/1986 KRU 2T-04 , Top of Productive Interval: 9. Ref Elevations: KB:frr it/- 17. Field/Pool(s): 990'FSL, 1377'FWL,Sec 2,T11N,R8E, UM GL:82 BF: Kupurak River Field/Kuparuk Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1057'FSL, 1163'FWL,Sec 2,T11N, R8E, UM surface ADL 25569 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498945 y- 5970332 Zone- 4 8160/6216 - 2667 TPI: x- 494486 y- 5970972 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 494272 y- 5971039 Zone- 4 1765/1708 1550/1518 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)I 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 SCANNED JAN 1 8 2U18 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 Surface 115 Surface 115 24 242 sx CSII 9.625 36 J-55 Surface 3292 Surface 2789 12.25 875 sx AS III,345sx Class G, 100 sx AS I 7 26 J-55 Surface 7556 Surface 5713 8.5 425 sx Class G 5 18 N-80 7353 8157 5559 6213 6.125 122 sx Class G 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): 2 7/8 1484 7185/5433 Perforations Plugged 7755/5873 pcbikxstDa oriV 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. r: Was hydraulic fracturing used during completion? Yes❑ No 0 (oj,ryriti- Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I.-- OA Top Job(Surface) 100 bbls Arctic Set 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A 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 -► L Lo�/ Form 10-407 Revi ed 11/2015 1-- `/2/i 8 CONTINUED ON PAGE 2 U ,� Submit ORIGINIAL only 12K15illi l$ 1e V,6," REDTtiiS • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 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 1550 1518 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. K.44 C- 53S8 lCwp C (gs) 77(e b 583-5 1-ctS6\ oGI3 Kit 2ar (.l,\c" I.v Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical 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. Contact: Jill Simek CD 263-4131 Email: JiII.Simekacop.com , Printed Name: G.L.Alvor _. Title: Alaska Drilling Manager Signature:(t- -P Ls.� =.`°L L• ' Phone: 265-6120 e: I L ( ZS, ` f-+ INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 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 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 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2T-04 Plug and Abandonment November 16, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2T-04, commencing operations on October 21, 2017 and completing the Plug and Abandonment on November 3, 2017. The site was excavated and the wellhead removed. Cement to surface was verified, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. a a a,. +tea 410 8t � a a f ��:` eX Via � -,-9.'„,"4.41,4•,;,-, f , Fry .a.,t „:',1'...,1,1; ,,,,,'...:0;i<err";lifi',,,'',' ' ,",,,l't,,,,,'tri.'774,1-,,y ,fr., 1.,::`V':, ;;' / pis}."; r swt.-.),Yll'ATII•),"" ,'.-- 444:0,..*": 1 illt-,,,,,„‘„,,,,,!'4r:. ,*K`"'' 3 x"+% b si ,� * 4t .(II' � P`�ra T' � si �" N g� ea �� �5ry M ` »y E $ 0 S ., . , t '''''q:.'- :''''''11).' t,-'*„, '"',.".'''''''''t.' • ' .,/..*'` oitit: ' '-iii-tt'4 *VA ''..;) '4. '':'40`• -/-,/A''/` ''' - ''.t '''/ •VO.4it. 411,7,*''''. ' .:.„ ,,',•/' * v, ,,,,. ,,,,, :• • .' .‘,',4,4 4 li r - ' *4 4 I ,.. I ,'"' *, • *#.#0,- g z.,e ' "''' , - f 4;1, ,',- , e As ,4 „ ... , , ...... , _ , .... , ...„, g; r:- - , — . 1111 clopyright2l7. Airights reserved. This photogrphisprovidedtotheAoGccvit h permission to copy for its own use. Copyin g for any other purpose or by any other party sprohlbltedlithout the expressconsent ofconpcoPhilIlpsAlaska Inc. Ie►WELL EVENTS SUMMARY • Date Well Event 11/3/17 Final site pictures taken nd stored in "S" drive. Wellhead Pictures & Repairs (EEF170)\CPF2 Pictures-Copyright!\2T\2T-04 P&A\Pictures\2T-04 Final 11-3-17 10/29/17 P&A Remove water&check cement. Stateman Lou Laubenstein witness good cement and info on marker plate is correct. Weld marker plate- remove stairs and shoring - back fill egress- break down areas that were under cut and bury excavation. PRA (;mmnIata 10/28/17 P&A Remove water and RU to finish cutting wellhead 3.5' below tundra with torch. Cut windows and remove 14'1" of wellhead (6,200 wt) off. Prep stub for marker plate and fill TX 4" pocket with cement. 10/27/17 P&A Finish egress &stage equipment. Remove water and install WACH's cutter. 10/26/17 P&A Initial I/O = 0/0 Quadco excavate to 12' - install shoring -dia egress. 10/21/17 P&A PREP Initial I/O = 0/0 Remove JIC cap on IA and verify 0 psi, reinstall cap. Remove Alemite cap from OA and verify 0 psi, reinstall cap. Final I/O = 0/0 KUP 2T-04 COC►t7CC}F�I tiI{Ips Well Attrib Max Ang D TO AlSOEd,lI C., Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) carwcoHliiiips 501032007400 KUPARUK RIVER UNIT INJ 53.12 3,900.00 8,160.0 ,,, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 27-04,11/27/20178:35:31 AM SSSV:TRDP Last WO: 40.00 8/13/1986 Vertical schematic(actuaQ Annotation Depth(ftKB) End Date Annotation Last Med By End Date oottouriust MARKER PLATE,43.511111Last Tag: 7,920.0 7/14/1998 Rev Reason:P8A WELL,SEE NOTES pproven 11/20/2017 R; CONDUCTO43.5-1150 M CEMENT PLUG,43.5 ftKB' asing rings Cement Plug;43.5 ftKB Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Cement Retainer,224.0 -- CONDUCTOR 16 15.062 43.5 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.525 43.5 3,292.0 2,788.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread Intermediate Casing Cement,, PRODUCTION 7 6.276 43.5 7,555.8 5,712.7 26.00 J-55 BTC 330.0 ftKB Casing Description OD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread Cement Plug;340.0ftKB ill A LINER 5 4.151 7,353.4 8,156.7 6,212.9 18.00 N-80 jLTC Liner Details SAFETY VLV,1,765.1FI , Nominal ID Top(ftKB) Top(TVD))ftKB) Top Incl(-) Item Des Com )in) GAS LIFT;2937.5 1111 7,353 4 It 5,558 9 41.24 HANGER BAKER SIMPLEX LINER HANGER 5.000 Tubing Strings i Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-Post P&A 2 7/81 2.4411 1,484.11 7,776.11 5,890.31 6.50IJ-55 I EUE8rdABMOD Completion Details SURFACE;435-3,202.0 r Nominal ID CEMENT PLUG,43.5-ftKB Top)ftKB) Top(TVD))ftKB) Top Incl(9) Item Des Corn (in) GAS LIFT;5,181.9 1,765.1 1,708.3 30.19 SAFETY VLV CAMCO TRDP-1A-SSA-Camco TRDP-1A SSA(Control 2.312 Line Defeated;Not Locked Out) till 7,159.9 5,4142 41.84 PBR BROWN PBR 2.500 • GAS LIFT;6165.11:1 7,184.6 5,432.6 41.77 PACKER BROWN HB-1 PACKER 2.750 5,488.3 41.61 NIPPLE AVA BPL PORTED.NIPPLE 2.250 Tubing Cut,6,460.0 " 5,490.1 41.61 XO reducing XO reducing,2.875x 2.375,4.78,N-80 2441 7'1 7,716.1 5,840.6 34.64 BLAST RING CARBIDE BLAST RING 1.995 EEE .4 7,754.1 5,872.0 33.95 LOCATOR BAKER LOCATOR 1.995 i:' 7,768.97 775 2 5,884.3 33.68 NIPPLE 5,889 5 33 57 SOS CAMCO D NIPPLE CAMCO SHEAR OUT 1.995 Other In Hole Wireline 0 igP Top(TVD) Top Ind , PBR;7,159.9 1 • 10/29/2017 0.000 CEMENT PLUG;1,484.0 ftKB CEMENT PLUG;43.5 ftKB 1 1 224.0 11/18/2012 PACKER;7,184.7 N 1 INJECTION;7,221.7 11 1 11 • 11 0/9 11• 0.000 1 7,259.2 5,488.3 41.61 SLEEVE-C AVA BPI SLEEVE Set 8/21/94 8/21/1994 SLEEVE-C;7,259.2 NIPPLE;7,259.2 _ _, Shot Dens 11 0lS 4' Top(ftKB) Btm(ftKB) Top(TVD) Btm(TVD)MKB) MKB) Zone Date (shots/ft) Type Com CMT PLUG;7,100.0 . 1 7,756.0 1 1 1 (1 I 7,805.0 7,809.0 1 1 1 PRODUCTION;43.5-7,555.8 7,816.0 7,824.0 5,923.6 5,930.31 1 1 1 7,855.0 5,930.3I 1 4.0 IPERF;7,745.0-7,756.0 _T.y 7,876.0 7,890.0 5,974.0 I 1 1 LOCATOR;7,754.1 g I. 4 Cement Squeezes 7 7 I{ te Com PACKER;7,755.1 1 8,156.0 0 1 f l:f ® CEMENT PLUG 1/17/2012 NIPPLE;7,7889 I ®CEMENT PLUG 1/17/2012 / 7,760.0 8,157.0 5,876.8 6,213.1 Cement Plug 1/17/2012 43.5 224.0 43.5 224.0 Cement Plug 1/18/2012 340.0 1,484.0 340.0 1,457.6 Cement Plug 1/18/2012 SOS;7,775.2 el 330.0 1,000.0 330.0 997.1 Intermediate 1/18/2012 Casing Cement IPERF;7,805.0-7,809.0 :. Mandrel Inserts St tI on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Secs Type Type (in) (psi) Run Date Com IPERF;7,816.0-7,824.0 1 2,937.5 2,567.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 IPERF;7,824.0-7,855.0 2 5,191.9 4,000.0 CAMCO KBMG 1 GAS LIFT DMY BK 1.000 0.0 10/23/1986 3 6,165.1 4,686.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 IPERF;7,876.0-7,80.0 4 6,514.9 4,939.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 5 6,832.7 5,172.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 I I 6 7,120.5 5,384.9 MMH 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/1986 7 7,221.7 5,460.3 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 6/27/1998 Notes:General&Safety CEMENT PLUG;7,755.0/848 LINER,7,353.4-8,156.7-4End Date Annotation Cement Plug;7,760.0 f8<8 407/2009 NOTE:**DRIFT TUBING w/SLINKY"due to possible corkscrewed tubing(WSR 4/17/09) KUP ati 2T-04 ConocoPhillips 111/ Al ska.lnC. r COMLiC lli3ips • 2T-04,.11/27/2017 9:35:31 AM Verticalschematic(g0AInE •••aaat iaiii MARKER PLATE;435 CONDUCTOR;43.5-115.0 E :I —A—A.CEMENT PLUG;43.5 Po(B^ Notes:General&Safety Cement Plug;43.5 1KB. Cement Retainer;224.0 End Date Annotation 11/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/19/2012 NOTE:WELL CEMENTED TO SURFACE AND SUSPENDED 10/13/2017 NOTE:REMOVED TREE,IA VALVE 8 OA VALVE Intemnatliate Casing cement; 330.0 8KB 10/28/2017 NOTE:Remove 14'1"of wellhead(3.5'below tundra) cement Plug;340.0 rine ri ; 10/29/2017 NOTE:Stateman Lou Laudenstein witness good cement and verified marker plate info SAFETY VLV;1,765.17, • i 3 GAS LIFT;2,937.5 :.f ro' SURFACE;43.5J.2920ti CEMENT PLUG;43.5 10(0 ' V., GAS LIFT;5,191.9 7- GAS LIFT;6,165.1 :,- Tubing Cut 6,460.0 ..'- GAS LIFT;6,514.9 GAS LIFT;6,832.7 ti:. ti? : GAS LIFT;7,120.5 PBR;7,159.9 % 1..4�- CEMENT PLUG;1,484.0 8K8.\ ;a; CEMENT PLUG;43.5 rtKB PACKER;7,184.7 INJECTION;7,221.7 NIPPLE;7,259.2 SLEEVE-C;7,259.2,: i i.. g1 4 CMT PLUG;7,100.0 PRODUCTION;43.5-7,555.8 IPERF;7,745.0-7,756.01r- LOCATOR;7,754.1 / I,4 1 1..;1 8 PACKER;7,755.1 1 1 1 t NIPPLE;7,768.9 50S,7,775.2 IPERF,7,805.0-7,809.0 (PERF;7,816.0-7,824.0 IPERF;7,824.0-7,855.0 IPERF;7,876.0-7,890.0 .1 CEMENT PLUG;7,755.0B ` 6K LINER;7,353.4-8,156.7 -: Cement Plug;7,760.09KB • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggi ' c i 1 f<)l t 7 DATE: 10/31/2017 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector KRU 2T-04 CPAI PTD 1861430; Sundry 317-469- 10/30/2017: I arrived on location for the surface inspection of a plug and abandonment on KRU 21-04. The wellhead was removed and all the casing strings where cut 3.5 feet below tundra. The casing stings where full to the top with hard cement at surface and the surface cap was on location with all the proper identification. Everything was in order with their procedure and per the sundry. Attachments: Photos (2) 2017-1030_Surface Abandon KRU 2T-04 11.docx Page 1 of 2 i ! .... _,,,l.".*,,,.... , ,...,. ,„...0:-.... '.1:::...", ''''. .,.. ..,,, , .. ( .. „....,_, ,,.7.-; I r` !i* :t1 _• iy"� N rte;. N . _ 1p U CI to 00 �` * lit . ..fr' - A I Ir''• • ig'. nom'. �i �� 't, • *r ; 7•7.E fr M r I • 4 :' i C En ii si x w i s, •'Q € • n O C) t, ' 13 0 Q >. i111 1 . CD c‘j CO O ,R. ,r L 3 p { OFTFj� • • \�����j�,s� THE STATE Alaska Oil and Gas � ;;, � 1.1of® LAsKA Conservation Commission tistx �== 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F "! Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer SCANNED DEC Q � ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-04 Permit to Drill Number: 186-143 Sundry Number: 317-469 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, Hollis S. French Chair DATED this day of October, 2017. R8Dca L` OCT c 5 2617 • • RECEIVED OCI 0 3 2,017 STATE OF ALASKA / 7/!2 ALASKA OIL AND GAS CONSERVATION COMMISSION 'A CC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory 9 Development 9 186-143 ' 3.Address: Stratigraphic 0 Service 2, 6.API Number: P.O.Box 100360,Anchorage,AK 99510 50-103-20074-00-00 , 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2T-04 Will planned perforations require a spacing exception? Yes 0 No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25569 • Kuparuk River Field/Kuparuk River Oil. 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): 8160 6216 • 0 • 0 . 0 Cemented to surface None Casing Length Size MD TVD Burst Collapse Conductor 83 16 115 115 1640 630 Surface 3260 9.625 3292 2789 3520 2020 Intermediate Production 7528 7 7556 5713 4980 4320 Liner 804 5 8157 6213 10140 10490 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7745-7890 cemented. 5865-5986 cemented 2.875,2.375 J-55,N-80 7262,7776 Packers and SSSV Type: Brown HB-1 packer,Baker DB packer,CAMCO Packers and SSSV MD(ft)and TVD(ft): Brown HB-1 7185 MD,5433 ND Baker DB 7755 TRDP-1A SSA(control line defeated,not locked out) MD,5873 ND SSSV 1765 MD,1708 ND 12.Attachments: Proposal Summary 9 Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service I]" 14.Estimated Date for 15.Well Status after proposed work: 7-Oct-17 Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 9 Abandoned 9, 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.SimeknU conocophiliips.com / Contact Phone: 907-263-4131 Authorized Signature: SDate: 10/ 3// COMMISSION USE ONLY Conditions of approval: ' Commission so that a representative may witness Sundry Number: 317 *I9 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ,LV. Other: .5i`>< 2 Difit"C 2-5-, /zc) fir- Pre 11 a6o+--)cfrYl.rvlcn kw ar e`—i favi <."7" Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: r 0- 4 b 7- RED.7.3 Lam- CCI 2 5 2617 Approved by: APPROVED BY U COMMISSIONER THE COMMISSION Date: t i (1. 1-4 `� 77!& 1x013/17- V77- 10 l/7-/ �- 2�M6rR L G I N Al /� (a>n7 Submit Form and \Q Form 10-403 Revised 4/2017 Approved application is valid for 1 h O h al. Attachments in Duplicate II • -1,-- ConocoPhillips . Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 2 October 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to complete the final plug and abandonment work for the Kuparuk River Unit well 2T-04(PTD#: 186- 143). l Injector 2T-04 was originally drilled in 1986 and completed as a selective completion A and C sand injection well.This well is located in an area where surface subsidence has become an issue. Since 1995,this well has measured a total surface subsidence of 48"which led ConocoPhillips to perform downhole cementing operations in 2009 to isolate the perforations in the well. Additional downhole P&A operations were conducted on the 2T-04 well in January 2012 which resulted in setting of a balanced cement plug in the tubing and tubing x 7"casing annulus from 6460'to 1532'. The tubing was then cut at 1484' and the 7"production casing was perforated at from 1007'to 1012'. The 9.625"x 7"outer annulus was then circulated back to surface through a retainer set at 284'to flush Arctic pack from the annulus. Cement was then squeezed through the retainer and out the perforations at 1007'to 1012' into the outer annulus. This was followed by filling the 7"casing to surface with cement and freeze protecting the 9.625"x 7"annulus with diesel to 1007'. ConocoPhillips now proposes to complete the final P&A of this well by cementing the 9.625"x 7"annulus back to surface,followed by excavation of the cellar,removal of the wellhead and installation of a marker plate. Ifyou have any questions or require any further information,please contact me at 263-4131. Sincerely, 4� 'ime Integrity Engineer k' `I Drilling and Wells • • Kuparuk River Unit 2T-04 Final P&A Procedure Permit to Drill #: 186-143 1. Conduct a pre-job safety meeting to identify and mitigate hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Rig up SLB cementers on 9.625" x 7" annulus valve. 3. Pressure test SLB lines. 4. Perform OA downsqueeze to SC leak depth (leak depth expected at 330ft based on Surface Casing Leak Detect measurement). 5. Shut in well. 6. Clean up cementers to open top tank. RDMO cementers. 7. Remove wellhouse from well, if still in place, remove tree and annulus valves. 8. Excavate cellar to 12' below pad level. Pump or vacuum out any excavation water to holding tank. 9. Place shoring protection over well and access stairs/ladder in accordance with CPAI and OSHA shoring requirements. 10. Notify AOGCC North Slope Inspectors for visual well cutoff and cement to surface in well. PHOTO DOCUMENT 11. Cut off well a minimum of 3' below tundra level per approved techniques utilizing annulus LEL monitoring and window cutting. Expect 7" to move upward about 8" to 16" due to report 48" subsidence of the well. 12. Ensure 7" casing and annuli are full of cement, weld on marker plate. Have AOGCC Inspector witness. PHOTO DOCUMENT 13. Remove excavation shoring equipment. 14. Backfill excavation and mound it 10% to account for settling. PHOTO DOCUMENT FINAL LOCATION CONDITION KUP • 2T-04 COnQcoPhlllipS & , Well Attribut Max Angle&MD TD tsl`fs3.Inc °0- Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) Act Btm(ftKB) .°G,,,,„ Fl010,, 501032007400 KUPARUK RIVER UNIT INJ 53.12 3,900.00 8,160.0 -, Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 21-04,10/3/2017 5:5:56 AM SSSV:TRDP Last WO: 40.00 8/13/1986 Vertical schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 7,920.0 7/14/1998 Rev Reason:WELL SUSPENDED NOTE osborl 10/1/2012 Casing Strings �I s, It, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread pA.`i° , ,+�'*'�'xa; CONDUCTOR 16 15.062 32.0 115.0 115.0 62.50 H-40 WELDED As'z i@a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND).. WtlLen IL..Grade Top Thread °° „ t. - I F„ SURFACE 9 5/8 8.525 31.8 3,292.0 2,788.6 36.00 J-55 BTC .,R,...2 0-1. w r A`°7,` S z CONDUCTOR-32.0-115.0 �y, Casing Description OD(in) ID)in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �ti CEMENT PLUG;320 reKe- `"' ''F'' PRODUCTION 7 6.276 28.0 7,555.8 5,712.7 26.00 J-55 BTC Cement Plug,31.0 ftKB- Casing Description OD(in) ID(in) Top(BOB) Set Depth(ftKB) Set Depth)ND)...Wt/Len(L..Grade Top Thread Cement Retainer,224.0 f,,,.f- LINER 5 4.151 7,353.4 8,156.7 6,212.9 18.00 N-80 LTC Liner Details Nominal ID 9 Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) Intermediate Casing Cement: .;` 7,3534 5,558.9 41.24 HANGER BAKER SIMPLEX LINER HANGER 5.000 330.0 ftKB a ' Cement Plug,340.0 ftKB ` '. Tubing Strings SAFETY VLV;1,765.1 Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Post PBA 'String 27/81 2.4411 1,484.11 7,776 5,890.31 6.50IJ-55 1EUE8rdABMOD ' Completion Details GAS LIFT;2,937.5 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (in) 11; r`44 1,765.1 1,708.3 30.19 SAFETY VLV CAMCO TRDP-1A-SSA-Camco TRDP-1A SSA(Control 2.312 t, °vi Line Defeated;Not Locked Out) SURFACE;31.8-9292.0 o%° 4 7,159.9 5,414.2 41.84 PBR BROWN PBR 2.500 F<'d CEMENT PLUG;32.8 ftKB 7,184.6 5,432.6 41.77 PACKER BROWN HB-1 PACKER 2.750 GAS LIFT;5,191.9 I 7,259.2 5,488.3 41.61 NIPPLE AVA BPL PORTED NIPPLE 2.250 7,261.6 5,490.1 41.61 XO reducing XO reducing,2.875x 2.375,4.7#,N-80 2.441 GAS LIFT;6,165.1 7,716.1 5,840.6 34.64 BLAST RING CARBIDE BLAST RING 1.995 7,754.1 5,872.0 33.95 LOCATOR BAKER LOCATOR 1.995 Tubing Cut;6,460.8 7,755.1 5,872.8 33.93 PACKER BAKER DB PACKER 1.968 _ '7 7,768.9' 5,884.3 33.68 NIPPLE CAMCO D NIPPLE 1.812 GAS LIFT;6,514.9 7,775.2 5,889.5 33.57 SOS CAMCO SHEAR OUT 1.995 .." Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,832.7 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) b 224.0 224.0 0.29 Cement 1/18/2012 Retainer GAS LIFT;7,120.5 ":i �c 6,460.0- 4,900.1 43.46'Tubing Cut 1/16/2012 2.441 PBR;7,159.8 7,100.0' 5,369.6 42.00 CMT PLUG CEMENT PLUG SET IN TUBING;TOC 7100' 10/9/2009 - 0.000 ,yitCEMENT PLUG;1,484.0 ftKB 7259.2 5,488.3 41.61 SLEEVE-C AVA BPI SLEEVE Set 8/21/94 8/21/1994 1.870 CEMENT PLUG;28.0 81(91-3, PACKER;7,184.7 = Perforations&Slots Shot INJECTION;7,221.7t; Dens Top(ND) Btm(TVD) (shoal NIPPLE,7,259.2 l Top(ftKB) Btm(ftKB) )ftKB) (ftKB) Zone Date ft) Type Corn SLEEVE-C,7.259.2" r- 7,745.0 7,756.0 5,864.4 5,873.5 C-4,2T-04 10/23/1986 12.0 IPERF 3 3/8"Schlum HyperJ h. • F, 7,805.0 7,809.0 5,914.4 5,917.7 A-5,2T-04 10/23/1986 1.0 IPERF 3 3/8"Schlum HyperJ ` r4 7,816.0 7,824.0 5,923.6 5,930.3 A-4,A-3,2T- 10/23/1986 1.0 (PERF 3 3/8"Schlum HyperJ CMT PLUG;7,100.0 04 1 ( ', i f 7,824.0 7,855.0 5,930.3 5,956.4 A-3,2T-04 10/23/1986 4.0 (PERF 3 3/8"Schlum HyperJ PRODUCTION;289-7,555.8 7,876.0 7,890.0 5,974.0 5,985.8 A-2,2T-04 10/23/1986 4.0 (PERF 3 3/8"Schlum HyperJ I Cement Squeezes Top)ND) Btm(TVD) IPERF;7,745.0-7,756.0 Top(ftKB) Btm(ftKB) (ftKB) (kKB) Des Start Date Corn 7,755.0 8,156.0 5,872.7 6,2123 CEMENT PLUG 1/17/2012 LOCATOR,7,754.1 32.8 3,292.0 32.8 2,788.6 CEMENT PLUG 1/17/2012 28.0 7,185.0 28.0 5,432.9 CEMENT PLUG 1/17/2012 Cl 32.0 115.0 32.0 115.0 CEMENT PLUG 1/17/2012 PACKER;7,755.1 '' 7,760.0 8,157.0 5,876.8 6,213.1 Cement Plug 1/17!2012 31.0 224.0 31.0 224.0 Cement Plug 1/18/2012 340.0 1,484.0 340.0 1,457.6 Cement Plug 1/18/2012 NIPPLE;7,768.9 '-1 330.0 1,000.0 330.0 997.1 Intermediate 1/18/2012 Casing Cement Mandrel Inserts SOS;7,775.2 St an on Top(TVD) Valve Latch Port Size TRO Run N Top)ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn IPERF;7,805.-7,809.0 �. 1 2,937.5 2,567.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 1 ; 2 5,191.9 4,000.0 CAMCO KBMG 1 GAS LIFT DMY BK 1.000 0.0 10/23/1986 IPERF;7,816.-7,824.0 IPERF;7,824.-7.855.0 , , 3 6,1651 4,686.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 4 6,514.9 4,939.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 .1 IPERF;7,078.0-7,890.0- 1i':71, 5 6,832.7 5,172.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 ' :r 6 7,120.5 5,384.9 MMH 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/1986 7 7,221.7 5,460.3 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 6/27/1998 (s :1 Notes:General&Safety End Date Annotation 4/17/2009 NOTE:'"DRIFT TUBING w/SLINKY"due to possible corkscrewed tubing(WSR 4/17/09) CEMENT PLUG;7,755.0 ftKB 11/30!2010 NOTE:View Schematic w/Alaska Schematic9.0 LINER;7,353A-8,156.7 Cement Plug,7.760.0 ftKB KUP til • 2T-04 ConocoPhillips &' "" Alaska.Inc. ��� Conoco0F1W1Ps 27-04,10/3/2017 5'.50:56 AM Vertical echernenc.:(ectual) i II Notes:General&Safety ' ¢1 z End Date Annotation ``li1 1/19/2012 NOTE:WELL CEMENTED TO SURFACE AND SUSPENDED F u. CONDUCTOR,32.0-115.0 j8a Rv M CEMENT PLUG,32ftKB- - ft 6 KB y Cement Plug;31.0 ft Cement Retainer;224.0 -1 . Intermediate Geeing Cement; 330.0 SIB Cement Plug;340.01168 li SAFETY VLV;1,765.1 ' GAS LIFT;2,937.5 m;. SURFACE;31.8-3,292.0 CEMENT PLUG;32.818(8 ., GAS LIFT;5,191 8 GAS LIFT,6,165.1 -:%110 Tubing Cut;6,460.0 ',J :;:lli GAS LIFT;6,514.9 GAS LIFT;6632.7 .:47 a GAS LIFT;7,120.5 -` P89;7,159.9 .;,. .,te ` a CEMENT PLUG;1,484.01168 CEMENT PLUG;28.0 ft1(B\ ' PACKER;7,184.7 it !i INJECTION;7,221.7 III NIPPLE;7,28.2 �. SLEEVE-C;7,259.21 E7 51 of CMT PLUG;7,100.0 II PRODUCTION;28.67,555.8 (PERF;7,745.0-7,756.0-e IIIIIII1 LOCATOR;7,754.1 1 f F 0 4 r PACKER;7,755.1 I NIPPLE;7,768.9 SOS;7,775.2 IPERF;7,805.0-7,809.0 IPERF;7,816.07,824.0 IPERF;7,824.07,855.0 IPERF;7,876.07,890.0 I ,�` Ap.• r CEMENT PLUG;7,755.0 ftKB LINER;7,353.4-8,158.7 Cement Plug;7,760.011108 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-04 - Oper.Rep: Ian Ives PTD No.: 186-143 Oper.Phone: 659-7043 - Location Verified? Yes Oper.Email: If Verified,How? ter(specify in commei Onshore/Offshore: Onshore Suspension Date: 10/16/09 Date AOGCC Notified: 08/28/10 - Sundry No.: 309-332 Type of Inspection: Initial ' Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 950 Photos Taken? Yes IA 250 ' OA 0 SCANNED AUG 1 4 2015 Condition of Wellhead: Wellhead location verified with a plot plan.The flowline was still attached to the well and the flowline had 2450 psi. IA and OA lines were blinded with gauges.Well had a wooden cellar box that was dry and free of any oil. The wellhouse was removed for dirt work in progress on location. Condition of Surrounding Surface The location looked very good.They were in the process of doing dirt work on the whole pad. 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: "21-04-Current pressure 950 psi completed 8-30-10(all methanol,bled to zero,clearly was thermal in nature)" Attachments: Photos(3) REVIEWED BY: Insp.Supry �) 1Z. Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-04_bn.xlsx . . i OW r r e , • • \Ito. •r oz._ , Ilk I ,, 1 ''$6H— ii,,' iwii, ,,,,' • • 'Aimr111111"ss—AL' : s.. , NI-;-... -17- -- aia‘- Wiwi' 4 .7"`"- ,— z=drrinimfr, - i . ..... 11111 •-•.: „,.._ II- .,, . r: II •-• ,,,, ... i„. • - 4,' 1 r . ,. • . , e e , b. ,041 1 • i Z ' Aissata;.-- ;lit , .,„ . • it, , 1 '. OA im - Z , - . -• „ ... • ..,.. , • _ , '. • ...........; ,:.:.; L,.,: . . • 1 . . , ..._ .ir 114. 111111111.14.., - • ' /1 • Aki ...,.. N ,, ,. ih ...& ma ,, FIT v: , lirx -. , .. ,.,._ . , ... ' '1 '4 ,,:‘ / lam... •••,Za,, '...,'„ Sit 4 ft.: '..:: 1 " ' '','''WI j 4ll'4? ,-mortr,44: ' il ' - ' . it dipt.ollis,,: :•:: • ....... 12„ ;44.,,..".":_,.. ,, . •. , :, . . lot ...,N .,...;-. t Alaftaw, ---,....,,,•••71.1.0t,,, .,.. IP 411111— c) -0 iq il I litiki. - ,.,.'L'i.,s . . ,,. , , .., ar'' 1 —1 ,... ..- -,.... r ......- " .n el — is; virr' i ...._ . ok • • . : 0 ... . • • . I , ..,. . . .• cil ..., = . 0 -4--. . Q Amo tu Q p., . • 1. CL) c/) Co = to 0-1 1-4 (...) ii °°o•%'. ':',: i . . 4 7:3 .9/. • 7 - a) 71) 0 •0 , co ' , • (.4 m < . Lik .. I Crs " CI) ,-4 >..,C) I ma: . N c' . .0 421 *--, W I oo 0 : oo cn o o cu a.) ,--, 0 N . • 0.1 r...\ 4-, cr, -----.,r —. to o cti cn 1-4 0 cv at., • ....-_. . NE c4 co 11111,,,,J. F:• �e } 'a!k �Cf1[1. . Tht•t• .,, t K Ilt o • ♦ 'i~ I CA yy� cv w r„ .+Z`' to 1 ,...i to C> 0 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. /~- /.~-_-_-~J Well History File Identifier RESCAN DIGITAL DATA [] Diskettes, No. [] Other, No/Type [] Color items: [] Grayscale items: [] Poor Quality Originals: Other: TOTAL PAGES: NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHE RYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: &,~' (at the time of scanning) SCANNED BY: ~REN VINCENT SHERYL MARIA LOWELL DATE ReScanned (done) RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: lei General Notes or Comments about this file: PAGES: ~) 6 Quality Checked (done) RevlNOTScanned.wpd ` • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , w ! 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 Ell Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: January 19, 2012 186 - 143 / 311 - 365 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 August 1, 1986 50 103 - 20074 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 352' FSL, 556' FWL, Sec. 1, T11N, RO8E, UM August 12, 1986 2T - 04 Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 990' FSL, 1377' FWL, Sec. 2, T11N, RO8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1057' FSL, 1163' FWL, Sec. 2, T11N, RO8E, 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- 5970332 Zone- 4 8160' MD / 6216' TVD ADL 25569 TPI: x - 494486 y- 5970972 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 494272 y- 5971039 Zone 4 1765' MD / 1708' 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) 1550' MD / 1518' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 32' 115' 32' 115' 24" 242 sx CS II 9.625" 36# J -55 32' 3292' 32' 2789' 12.25" 875 sx AS III, 345 sx Class G, 100 sx AS I 7" 26# J -55 28' 7556' 28' 5713' 8.5" 425 sx Class G 5" 18# N -80 7351' 8155' 5557' 6212' 6.125" 122 sx Class G 24. Open to production or injection? Yes ❑ No El 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) ,� .;2/24 z- 2.875" 1484' -7776' 7185' MD / 5433' TVD perfs isolated: t At /°L' f3 C. _4 r `.t j.:t ) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7745W756' MD 5865' - 5874' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 32 - 6460' 848 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and •• ° • - . • - • • • - • - - • - - -• (Submit separate sheets i f if e e �g it detailed descriptions, chips, s and laboratory an cal results AAC 25.07' . St- escr s, c , p RECEIVED NONE FEB 2 3 2012 RBDMS FEB 2 4 2012 Alaska Oil & Gas Cons. Commission I Form 10 -407 Revised 12/2009 CONTINUED ON REIRSE ARC Iitiiage _ Submtoriginal only yei--16/1 402._ , 7- /2 G 28. GEOLOGIC MARKERS (List all formations and markersOuntered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1550' 1518' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 - 47731 Printed Name . H. Gober Title: Wells Engineering Supervisor z J / l Signature � Phone 263 -4220 Date I 1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 1 2T -04 Pre Rig Well Work DATE, SUMMARY 11/24/10 DRIFTED TUBING WITH 10'x 1" fit DRIFT TO 964' SLM UNABLE TO PAS UE TO POSSIBLE CORKSCREWED TUBING 10/17/11 (RWO) MITT- PASSED; T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; LDS- FUNCTIONAL 10/23/11 (AC EVAL) MITIA- PASSED 11/13/11 DRIFTED TBG TO SSSV @ 1765' RKB w/ KJ & 1.18" SWAGE; TEMPORARILY STUCK, POSSIBLY DUE TO FLAPPER. DRIFTED TO SSSV w/ KJ & 5' x 1" STEM. ERRATIC P/U WEIGHT, MAX OVERPULL 350 LBS. • . onocc hillips Time Log & Summary Wel!view Web Reporting Report Well Name: 2T - 04 Rig Name: NORDIC 3 Job Type: ABANDONMENT Rig Accept: 1/12/2012 5:00:00 PM Rig Release: 1/20/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/12/2012 24 hr Summary Completed Well 2T -202 Program. Release Rig. RDMO. MIRU at 2T -04 Well Slot. 17:00 19:00 2.00 MIRU MOVE DMOB P MIRU Nordic Rig #3. Accept Rig at 17:00 hours. Shuffle rig Mats. Stage needed equipment behind 2T -04 Wellhead before moving in Rig. 19:00 20:00 1.00 MIRU MOVE MOB P Pull off of 2T -202 and move to 2T -04 Well slot. Spot Rig over Wellhead. Shim and level up Rig. 20:00 00:00 4.00 MIRU MOVE RURD P Continue to spot and rig up support equipment. (Note: due to the extreme cold conditions, extra time taken out for Crew to warm up and to discuss any additional cold weather safety precautions). 31/13/2012 Complete Rig -up. Pull BPV w /Lubricator. Monitor Well. ND Tree. NU BOPE. Perform initial BOP Test. 00:00 06:30 6.50 MIRU MOVE RURD P Continue to rig support equipment. Rig up Kill Tank. Berm same. Rig up Hard Lines. Load 244 bbls of 10.5 ppg KWF in Pits. RU Circulating Hoses and PT same 3500 psi 06:30 08:00 1.50 MIRU WHDBO MPSP P PU Lubricator and Pull BPV 08:00 10:00 2.00 MIRU WHDBOOWFF P Initial Tubing Pressure (4) psi. Initial IA Pressure (60) psi. Initial OA Pressure (0) psi. Call DSO, and start bleeding down IA to kill tank to zero. 10:00 11:00 1.00 MIRU WHDBO MPSP P PU Lubricator and Set BPV. Blow down Bleed hoses and treating iron to kill tank. 11:00 12:00 1.00 MIRU WHDBO NUND P PJSM. ND and Inspect Tree. Un -Load Centrilift ESP Spool and Spooling Frame. 12:00 18:00 6.00 MIRU WHDBO NUND P PJSM. NU BOPE 18:00 00:00 6.00 MIRU WHDBO PRTS P Test BOPE per ConcocPhillips requirements at 250/3,500 psi. 01/14/2012 Complete the Initial BOPE Test. Pull Tbg Hanger . Rig up S -Line. Drift Tbg to the top of Cement. 00:00 04:30 4.50 MIRU WHDBO PRTS P Complete the initial BOPE Test. ,e Perform Koomey draw down test. All -t pressure tests recorded on Chart. � (Note: Had one fail /pass. The Top Drive Double Ball Valve had to be replaced). The State's right to witness the test was waived by AOGCC Field Inspector, L. Grimaldi. Page of • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 MIRU WHDBO PULD P Rig down test equipment. Clear and clean floor and drain stack. 05:00 05:30 0.50 COMPZ RPCOM MPSP P PJSM. RU Lubricator and Pull BPV. 05:30 07:00 1.50 COMPZ RPCOM PUTB P PJSM. Crew Change Out. MU landing joint, monitor OA for 15 mins. BOLDS, mark landing joint at rig floor, puh to neutral weight and make another mark and measure distance between the marks (6 -ft total ) hanger started moving up hole at 40k, set slips at 75k and MU TIW valve. 07:00 09:00 2.00 COMPZ RPCOM SLKL P MIRU Slick -line and Load tools to Rig floor. 09:00 09:15 0.25 COMPZ RPCOM PRTS P RU Test Hoses and PT Slick -line Lubricator to 500 psi. S� 09:15 15:00 5.75 COMPZ RPCOM SLKL P Open TIW Valve, RIH with SLick -line rvo Tools to Drift down to top of SSSV. Able to finally get the SSSV Locked out. 15:00 18:00 3.00 0 3,414 COMPZ RPCOM SLKL P MU and RIH with Dummy Drift assembly. Set down at 3400 -ft. Continue to work slick -line down to 3414 -ft. POOH and found trace of shale in and around tools. Continue to trouble shoot tubing. 18:00 00:00 6.00 3,414 6,476 COMPZ RPCOM SLKL P Continue with S -Line operations. RIH with a 2.26" Gauge Ring and Brush. Worked down to 6,476 -ft. RIH with Drive -down Bailer to obtain a bottom sample. Set down at 5,476 -ft. Lost 1,000 -ft of hole. POOH. Recovered 3/4 gal of scale /Injection Powder. Re -load and run back in. Worked down to 5,489 -ft. POOH. Recovered 3/4 gal of scale /Injection Powder. Re -load and RIH. Work down to 5,494 -ft. POOH. Recovered 3/4 gal of Scale /Injection Powder. RIH with Gauge Ring and Brush. Stopped at 5,494 -ft. POOH. Re -tie new Rope Socket. S -Line Crew change -out. PJSM with the on- coming Crew. 01/15/2012 Continue to drift Tubing with Slick Line. Page 2 of 9 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 5,494 5,500 COMPZ RPCOM SLKL P Continue with Slick Line operations. RIH with 2" Drive Down Bailer. Work down to 5,501 -ft. POOH. Recovered 1/2 gal of Scale /Injection Powder. RIH with same and work down to 5,504 -ft. POOH. Recovered 1/2 gals of Scale /Injection Powder. Pick -up the 1.50" Drive Down Bailer. RIH. Work down to 5,510 -ft. POOH. Recovered 1/2 gal of Sale /Injection Powder Pick -up the 1.87" Gauge Ring RIH. Tag up at 5,510 -ft. Clean pick -up. POOH. RIH with 2.00" Bailer. 12:00 13:00 1.00 5,500 6,426 COMPZ RPCOM SLKL P RIH W/ 10' OF 2" DD BAILER WITH MULE BALL BTM, SD A 5512' SLM WORK BAILER MAKEING NO GROUND, PRESSURE TBG TO 2500 PSI, MAKE 6', DUMP PRESSURE TO SHOCK WELL, WORK BAILER AND FALL PAST, PULL THOUGHT BUCKEL WITH OUT EXTRA WEIGHT GAINS, RIH AND TAG BTM @ 6426' SLM, POOH, OOH, 5' OF SCALE IN BAILER 13:00 14:00 1.00 6,426 6 COMPZ RPCOM SLKL P RIH W/ KJ, BLB, 2.26" G.RING. TOOLS FALL FREELY IN HOLE, BRUSH BAD SPOT @ 5500 -5600' SLM, CIH AND TAG @ 6392' SLM, BUSH TBG ON WAY OUT OF HOLE, OOH 14:00 15:00 1.00 6,402 6,392 COMPZ RPCOM SLKL P RIH W/ 10' OF 2" DD BAILER WITH MULE BALL BTM, SD @ 6392' SLM, WORK BAILER TO 6402' SLM, POOH, OOH W/ FULL BAILER OF FINE SCALE 15:00 16:00 1.00 6,400 6,410 COMPZ RPCOM SLKL P RIH W/ 10' OF 2" DD BAILER WITH MULE BALL BTM, SD @, SD @ 6400' SLM WORK BAILER TO 6410' SLM, POOH, OOH W/ FULL BAILER OF SCALE 16:00 17:00 1.00 6,400 6,407 COMPZ RPCOM SLKL P RIH W/ 10' OF 2" DD BAILER WITH MULE FLAPPER BTM, SD @ 6400' SLM, WORK BAILER DN TO 6407' SLM, GETTING STICKY, POOH, OOH W/ FULL BAILER 17:00 18:00 1.00 6,407 6,456 COMPZ RPCOM SLKL P CUT 200' OF WIRE AND REHEAD 18:00 18:30 0.50 6,404 6,407 COMPZ RPCOM SLKL P RIH W/ 2' WB, 2.26" G.RING, SD @ 6404' SLM, WORK G. RING TO 6407' SLM, POOH Page 3 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 6,408 6,445 COMPZ RPCOM SLKL P RIH W/ 10' 1.75" DD BAILER WITH MULE BALL BTM, SD @ 6408' SLM, WORK BAILER DN TO 6416' SLM, BRAKE THROUGH BRIDGE, LOSE SPANGS, TAG BTM @ 6445' SLM, POOH, OOH W/ FULL BAILER OF SCALE, SPANGS LOCKED OPEN 19:30 00:00 4.50 6,456 6,456 COMPZ RPCOM SLKL P Continue to bail Scale /Injection Powder from the 2 7/8" Tubing. Using a 2" and a 1.75" Drive Down Bailers. Also make a run as needed with the Gauge Ring and Bush. Working depth now at 6,456 -ft. 01/16/2012 Continue to drift Tbg w/S -Line. RD S -Lune Unit. RU E -Line Unit and cut or punch Tbg. Circulate Well. Prep for Cementing. 00:00 06:00 6.00 6,456 6,472 COMPZ RPCOM SLKL P Continue to run Drive Down Bailers to clean out Scale /Injection Powder from inside the 2 7/8" Tubing. Also run in with Gauge Ring and Brush as needed. Present depth at 06:00 hrs = 6,468 -ft 06:00 12:00 6.00 6,468 6,480 COMPZ RPCOM SLKL P RIH w/ 1.75" DD Bailer with mule flapper BTM and 2.26" OD gauge ring, SD @ 6,472 -ft SLMD, work bailer down to 6,480 -ft SLMD. Not making much hole, POOH, Bailer full of fine scale. Confer w town engineer, 6,480 -ft is deep enough. 12:00 14:00 2.00 0 0 COMPZ RPCOM SLKL P Call Out E -Line Crew and Equipment. Notify SLB of Tag Depth for cement volume. RD Slick -line equipment and released Crew. Called AOGCC and talk to Bob Noble, he waived witness for tag. 14:00 15:00 1.00 0 0 COMPZ RPCOM SFTY P E -Line Crew and Equipment on location. Hold PJSM and Discuss the hazard for Rigging up E -line and loading tools to the rig floor. 15:00 18:00 3.00 0 0 COMPZ RPCOM ELOG P MIRU E -Line and Load Tools. E -Line Crew Change. 18:00 22:45 4.75 0 COMPZ RPCOM ELOG P PJSM with new Crew. Complete rig -up. Pick -up a 2.250" Jet Cutter /CCL Tool String. Pressure test Lubricator to 1,000 psi. Good. Run in with Jet Cutter. Record a tie -in pass and tie into to the GLM at C � 6,165 -ft. Drop down and position the Cutter at 6,460 -ft. Fire. Good. POOH and park tools inside Lubricator. 22:45 00:00 1.25 COMPZ RPCOM CIRC P Confirm circulations at 3.0 bpm /70 psi with 10.5 lb/gal Brine. Good returns. Call out Cementers and Vac Trucks. Continue to circulate and displace the diesel and wellbore fluids with 10.5 lb/gal Brine. Page 4 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment D1/17/2012 24 hr Summary RD E -Line. RU Cementers. Pump a balanced Abandonment Class G Cement Plug from 6,460 -ft up to 1,700 -ft. RD Cementers. Wait on Cement. PT Cement. RU E -Line. Tag TOC. Cut Tbg above TOC. 00:00 00:30 0.50 6,460 6,460 COMPZ RPCOM CIRC P Complete circulating the Well with 10.5 lb/gal Brine and a final circulating rate /pressure of 4.0 bpm /220 psi. Total volume pumped = 250 bbls. 00:30 01:30 1.00 6,460 6,460 COMPZ RPCOM ELOG P Rig down E -Line equipment and move Logging out of the way to make room for cementing operations. 01:30 04:30 3.00 6,460 6,460 COMPZ RPCOM RURD P Bulk Cement arrive on location. Blow off into Silo. Vac Trucks arrive on Location. Pumping Equipment in route. However, blowing and drifting snow hampers normal travel. 04:30 06:15 1.75 6,460 6,460 COMPZ RPCOM RURD P Pumping Equipment on location. Hold PJSM. MIRU and Spot Equipment. 06:15 07:15 1.00 6,460 6,460 COMPZ CEMEN" CMNT P Start pumping. Pump 10 bbls 80 degf fresh water at 4 bpm @ 800 psi. PT 3000 psi, ok. Batch up 15.8 ppg Class G Cement and strat pumping downhole. Pump 5 bpm at 1550 psi. C1 25 bbls away, 4.6 bpm at 1420 psi, 15.8 ppg. At 50 bbls awy, 4.8 bpm at 1715 psi, 15.7 ppg. At 100 bbls away, 4.6 bpm at 1850 psi, 15.9 ppg. At 150 bbls away, 4.5 bpm at 2040 psi, 15.65 ppg. At 170.3 bbls away. 2.6 bpm at 500 psi, 15.8. End Cement. 07:15 07:30 0.25 6,460 6,460 COMPZ CEMEN" DISP P Pump 2 bbls of FW and follow with 8 bbls of 10.5 ppg Brine. ISIP 0 psi. 07:30 18:00 10.50 6,460 6,460 COMPZ CEMEN WOC P WOC - Notified State via pager at 10:20 AM to inform of upcoming Tag Witness. Return call at 11:26 AM by John Crisp. 18:00 20:00 2.00 6,460 6,460 COMPZ CEMEN" PRTS P PJSM. (Spot E -Line Unit). Pressure test the TOC in the 2 7/8" Tubing at 1,500 psi x 15 minutes. Lost 100 psi. (Note: The Cement sample in the Dog House is still " soft" after 12 hours, WOC). Test the TOC in the 7" x 2 7/8" Annulus at 1,500 psi x 15 minutes. Lost 125 psi. Recorded test on Chart. 20:00 21:00 1.00 6,460 1,532 COMPZ CEMEN" ELOG P PJSM. Rig up E -Line equipment. Pressure test Lubricator at 500 psi. Good. Run in with CCL/Weight Bar /Bull Nose. Tagged the Top of Cement at 1,532 -ft AOGCC Field Inspector, J. Crisp witnessed the tag. POOH and park Tools inside Lubricator. Page 5 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:45 0.75 1,532 1,532 COMPZ CEMEN PRTS P Re- pressure test the 7" x 2 7/8" Annulus as requested by AOGCC Field Inspector to 1,760 psi x 30 minutes. Results = 15 minute /1,650 psi, 30 minutes /1,610 psi. Good Test. Record test on Chart. 21:45 00:00 2.25 1,532 1,484 COMPZ RPCOM ELOG P Lay down Tool String. Pick -up the Jet Cutter. Run in with the 2.250" .IPt Cutter Set down at 1,50Fi - ft Nn further progress. PUH to 1,484 -ft d - LA (6 -ft below a Tubing Collar). Fire f, Cutter. Good. POOH. Set back E -Line Equipment. J1/18/2012 Pull Tbg and Control Line from 1,484 -ft. RU E -Line and Punch Hole in 7" Csg, Circ the 9 5/8" x 7" Annu. Set Cmt Retainer. RU Cementers. Cmt the 9 7/8 x 7" Annulus. Pull out of Cmt Retainer and pump Cmt to surface inside 7" Csg. POOH. RD Cementers. WOC. 00:00 00:30 0.50 1,484 1,484 COMPZ RPCOM CIRC P Circulate bottoms up at 5.0 bpm /160 psi. 00:30 03:45 3.25 1,484 0 COMPZ RPCOM TRIP P PJSM. Pull Tubing Hanger to Floor and lay down same. Rig up Control Line Spooling Unit. Stand back 3 Stands of 2 7/8" Tubing in the Derrick. Begin to single down 2 7/8" Tubing. The SSSV Control Line starting slipping through the Control Line Bands. Run back in hole with 2 Jts of Tubing. Rotate Tubing 20 turns to the right and wrap Control Line around the Tubing. Continue to single down Tubing. Lay down tangled up Control Line. Continue to single down the remaining Tubing. Spool remaining Control Line with no problems. Recovered 45 Jts of 2 7/8" Tubing, a 6 -ft Jet Cut Tubing Stub, Control Line complete, and 22 Bands. Left in 8 Bands on top of the cement top.. NORM recovered Control Line and Bands. Rig down Spooling Unit. Clean floor. 03:45 12:00 8.25 0 0 COMPZ WELLPF ELOG P PJSM. Rig up E -Line. RIH w/ 5 -ft string shot w/ 320 gpf to 1,012.5 -ft and shot from 1,007.5 to 1,012.5 -ft. POOH. Lay down and PU and MU 7 " 2.9" OD Radial torch rch perforator tool f and RIH to 1,010 -ft and fire. Gained 40 psi on OA that was bled to 0 psi. POOH and RD E -Line. Page 6 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 0 0 COMPZ WELLPFCIRC P With blind rams closed break circulation to Open top tank pumping 190 bbls of 150 degree sea water down 7" 26# production casing at 5 bpm at 120 psi thru pert hole at 1,010 -ft, displacing arctic pack from p A 9 5/8" 36# Surface casing by 7" 26# Production casing annulus. Recovered 110 bbls for 190 bbls pumped. 13:30 15:30 2.00 0 224 COMPZ WELLPFTRIP P Held PJSM, PU and RIH w/ 7" Baker 3BB cement retainer to 224 -ft and set. PT at 530 psi on 7" x 2 7/8 Annulus - good test. Bleed off pressure. Un sting from cement retainer and stab back in. Establish circulation rate to verify latch up. 15:30 18:00 2.50 224 224 COMPZ CEMEN' RURD P PJSM. Begin to spot and rig up cement equipment. Rig up Floor. Spot Vac Trucks. 18:00 19:30 1.50 224 224 COMPZ CEMEN" RURD P Continue to rig up. Complete Crew changes with Cementers and Vac Truck drivers. II ' Page 7 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 23:30 4.00 224 0 COMPZ CEMEN" CMNT P PJSM and job review with new Cement Crew. Pump 5 BBIs of fresh water to prime up and warm up Lines. Perform a stall test. Pressure test lines at 2,700 psi. Perform and injection test at 1 bpm /100 psi, 2 bpm /160 psi and at 3 bpm /270 psi. Batch up AS1 Cement. Start Cement at 1.3 bpm /125 psi /15.8 density. 5 bbls away, 3.0 bpm /330 psi /15.8 density. 25 bbls away, 3.0 bpm /310 psi /15.8 density. 50 bbls away, 2.1 bpm /120 psi/ 15.7 density. Divert returns to Cuttings Tank. Blow down return Line to the Open Top Tank. 60 bbls away, 3.0 bpm /400 psi /15.8 density. 75 bbls away Good Cement returns observed at the cuttings Tank. Close in Outer Annulus Valve and begin to squeeze Cement into the Annulus at 1.0 bpm/75 psi Continue to squeeze DA Cement into the Annulus at 1.4 bpm/75 psi /15.8 density. Unable to build any squeeze pressure. End Cement. (Note: A total of 28.3 bbls of extra Cement was pumped into the 9 5/8" x 7" Annulus over the calculated volume from 1,010 -ft back to surface). Un -Sting from the Cement Retainer. Wash up. Bring rig Pump on line and "down flush" the 9 5/8" x 7" Annulus with 33 bbls of 10.5 lb/gal Brine at 2.0 bpm /100 psi and prep Annulus for a Surface Job after the Rig moves off. (Note: Lil Red will Freeze Protect the Annulus). Trip out with 7 Joints of 2 7/8" Tubing and Stinger. Lay down Stinger and trip back in with 7 Joints of 2 7/8" Tubing (open ended). Rig Floor back up to Cement. Start 7" Top Cement at 1.4 bpm /73 psi/15.68 density. Observe good cement returns at the Cutting Tank with 10.5 bbls away. End the 7" Top Cement with 11.2 bbls pumped at 1.0 bpm/75 psi /15.7 density. Final Cement in place at 23:00 hrs. Wash up. Cementers begin rigging down their equipment. Release same. Rig down Floor. Single down 7 Joints of 2 7/8" Tubing. Page 8of9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 COMPZ CEMEN" WOC P Wait on Cement Clean Rig Floor. J1/19/2012 Wait on Cement. Nipple down BOP Stack. Observe cement top and take photo. Install Tubing Hanger. Nipple up Dry-Hole Tree. Pressure test. Secure Cellar. RDMO Nordic Rig 3. 00:00 04:00 4.00 0 0 COMPZ CEMEN P Continue waiting on Cement. Begin to nipple down the Flow Nipple and Nipple down the BOP Stack. Clean out BOPE and open ram doors and inspect. ND BOPE 04:00 09:30 5.50 0 0 COMPZ CEMEN "CMNT P Nipple down Cement Cross. Bucket -Mix Cement to fill up the 7" to the IA Valve. WOC 09:30 10:30 1.00 0 0 COMPZ PLUG FRZP P RU LRS on OA and FP w/ 36 bbls of U� , diesel at 1.3 bpm at 350 psi ICP and C ,iT FCP. RD LRS. 10:30 12:30 2.00 0 0 COMPZ CEMEN" CMNT P Tag cmt at 10 -ft, call out for more bag cement. WOC. Re tag at 6 -ft. Mix and dump more cement filling 7" to IA valve. Take picture of cement in well head. 12:30 14:30 2.00 0 0 COMPZ PLUG NUND P Install Tubing Hanger. Nipple up Tree assembly. DSO verified Tree orientation. 14:30 16:00 1.50 0 0 COMPZ PLUG PRTS P Rig up test equipment. Pressure test the Dry-Hole Tree at 1,500 psi. Good. Rig down test equipment. Dress Tree. 16:00 00:00 8.00 0 0 DEMOB MOVE DMOB P Secure Cellar. Prep Rig and back off Well Slot. Clean up Cellar and Rig footprint area. Release Rig at Midnight Page 9 of 9 -. KUP 2T -04 a ConocoPhillips ell Attributes Max Angle & MD TD Inc Wellbore API/UWI Field Name Well Status Inc! ( °) M D (ftKB) Act Btm (ftKB) LnrncaFreup, {� 501032007400 KUPARUKRIVERUNIT INJ 53.12 3,900.00 8,160.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date "' . SSSV: TRDP Last WO: 40.00 8/13/1986 Well Cones. -2704,2/2012012 9:51:31 AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 7,920.0 7/14/1998 Rev Reason: WELL REVIEW osborl 1/31/2012 Casing Strings mu Casing Description String 0... String ID ... Top (91(8) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 320 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.525 31.8 3,292.0 2,788.6 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 CEMENT 32 -t1s PRODUCTION 7 6.276 28.0 7,555.8 5,713.4 26.00 J -55 BTC PLUG. 32 Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 5 4.151 7,353.4 8,156.7 6,212.9 18.00 N -80 LTC Liner Details SAFETY VLV, .tom Top Depth 1'785 (ND) Top Inc! Noml... T op (kKB) (ftKB) ( °) Item Description Comment ID (in) GAS LIFT, 7,353.4 5,559.0 41.24 HANGER BAKER SIMPLEX LINER HANGER 5.000 2,938 Tubing S trin gs th • Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 7 TUBING - Post P &A 2 7/8 2.441 1,484.1 7,776.1 5,890.3 6.50 J - 55 EUEBrdABMOD CEMENT tion P De Details PLUG. 33 SURFACE. 32 -3,292 (ND) Top Intl Nomi... Top (ftKB) MB) ( °) Item Description Comment ID (!n) GAS LIFT, 1,765.1 1,708.2 30.19 SAFETY VLV CAMCO TRDP -1A -SSA - Camco TRDP -1A SSA (Control Line Defeated; 2.312 I Not Locked Out) GAS LIFT, I 7,160.0 5,414.3 41.84 PBR BROWN PBR 2.500 8,165 1 7,184.7 5,432.7 41.77 PACKER BROWN HE-1 PACKER 2.750 GAS LIFT. a 7,259.2 5,488.4 41.75 NIPPLE AVA BPL PORTED NIPPLE 2.250 8.515 1 7,261.6 5,490.2 41.74 XO reducing XO reducing, 2.875x 2.375, 4.7 #, N -80 2.441 GAS LIFT. 7,716.1 5,840.6 34.64 BLAST RING CARBIDE BLAST RING 1.995 0.833 ■ ■ 7,754.1 5,872.2 33.95 LOCATOR BAKER LOCATOR 1.995 7,755.1 5,873.0 33.93 PACKER BAKER DB PACKER 1.968 GAS LIFT, 7,768.9 5,884.3 33.68 NIPPLE CAMCO D NIPPLE 1.812 7,121 7,775.2 5,889.6 33.57 SOS CAMCO SHEAR OUT 1.995 PBR, 7,150 1 ) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth CEMENT 4�j >~�.� (ND) Top Intl PLUG. 28 PACKER. 7,185 Top (ftKB) (ftKB) ( pion °) Description Comment Run Date ID (in) •� 3_ 7,100.0 5,369.6 42.00 CMT PLUG CEMENT PLUG SET IN TUBING; TOC 7100 10/9/2009 0.000 INJECTION. 7,259.2 5,488.4 41.75 SLEEVE -C AVA BPI SLEEVE Set 8/21/94 8/21/1994 1.870 7,222 Perforations & Slots NIPSLEE PLE, 7,259 Shot 7.259 7,259 Top (ND) 8[m (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (aft,,, Type Comment 7,745.0 7,756.0 5,864.6 5,873.7 C-4, 2T-04 10/23/1986 12.0 IPERF 33/8' Schlum HyperJ CMT PLUG 7,805.0 7,809.0 5,915.0 5,918.3 A-5, 2T-04 10/23/1986 1.0 IPERF 33/8" Schlum HyperJ 7,816.0 7,824.0 5,924.1 5,930.7 A-4, A -3, 2T-04 10/23/1986 1.0 IPERF 33/8" Schlum HyperJ 7.100 7,824.0 7,855.0 5,930.7 5,956.5 A -3, 2T-04 10/23/1986 4.0 IPERF 33/8" Schlum HyperJ 7,876.0 7,890.0 5,974.1 5,985.9 A -2, 2T -04 10/23/1986 4.0 IPERF 33/8" Schlum HyperJ Cement Squeezes PRODUCTION Top Depth Btm Depth 2e - 7.556 (ND) (ND) - Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 7,760.0 8,157.0 5,877.0 6,213.1 Cement Plug 1/17/2012 Start pumping. Pump 10 bbls 80 degf fresh water at 4 bpm @ 800 psi. PT 3000 psi, ok. Batch up 15.8 IPERF, - ppg Class G Cement and strat pumping downhole. 7,745 - 7,758 - - Pump 5 bpm at 1550 psi. 25 bbls away, 4.6 bpm at LOCATOR, 1420 psi, 15.8 ppg. At 50 bbls awy, 4.8 bpm at 1715 7.754 psi, 15.7 ppg. At 11'x) bbls away, 4.6 bpm at 1850 F ` psi, 15.9 ppg. At 150 bbls away, 4.5 bpm at 2040 =_� - psi, 15.65 ppg. At 170.3 bbls away, 2.6 bpm at 500 psi, 15.8. End Cement. Pump 2 bbls of FW and PACKER. 7.755 follow with 8 bbls of 10.5 ppg Brine. ISIP 0 psi. b.1 ./ Notes: General & Safety End Date Annotation NIPPLE, 7.789 4/17/2009 NOTE: **DRIFT TUBING w /SLINKY°' due to possible corkscrewed tubing (WSR 4/17/09) 11/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1/19/2012 NOTE: WELL P &A SOS, 7.775 IPERF, 7.805 -7,809 IPERF, 7,816 -7,824 IPERF, Mandrel Details 7,624 -7.055 Top Depth Top Port (TVD) Intl OD Valve Latch Size TIRO Run Stn Top (ftKB) MKS) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,937.6 Z567.3 51.73 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 7,871 n 2 5,191.9 4,000.0 47.49 CAMCO KBMG 1 GAS LIFT DMY BK 1.000 0.0 10/23/1986 3 6,165.1 4,686.4 43.60 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 4 6,514.9 4,939.9 43.40 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 5 6,832.7 5,172.5 42.77 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/23/1986 , 6 7,120.5 5,384.9 41.94 MMH 1 12 GAS LIFT DMY RK 0.000 0.0 11/13/1986 7 7,221.7 5,460.6 41.96 CAMCO KBMG 1 INJ DMY BK 0.000 0.0 6/27/1998 CEMENT PLUG. 7,755 LINER, 7.353-8,157 -\.,,^ Cement Plug, 7,780 TD. 6.180 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 25, 2012 TO: Regg PI. Supervisor l Z I I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -04 FROM: John Crisp KUPARUK RIV UNIT 2T -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry de)e-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2T - 04 API Well Number: 50 103 - 20074 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr120124100540 Permit Number: 186 - 143 - Inspection Date: 1/17/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -04 ■ Type Inj. N ' TVD IA 0 1760 1650 1610 P.T.D 1861430. TypeTest SPT Test psi OA o 0 0 0 Interval OTHER p/}' P Tubing o 0 0 0 Notes: MIT of permanent abandonment cement plug in production casing x 2 7/8" tubing. TOC was witnessed tagged @ 1532' inside tubing. The TOC was calculated to be @ 1700'. MITIA to verify cement integrity for permanent abandonment. Rig annular preventer use for MITIA.:-- FEB G ic. Wednesday, January 25, 2012 Page 1 of 1 • • SITAITE DEF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ian Toomey Wells Engineer L/� ConocoPhillips Alaska, Inc. �� { "� P.O. Box 100360 = ? l.`t Anchorage, AK 99510 "' ''��' Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -04 Sundry Number: 311 -365 Dear Mr. Toomey: 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 day of November, 2011. Encl. . • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 .) V ANCHORAGE, ALASKA 99510 -0360 A11 aka Oil & Gas Cons. Commission November 17, 2011 Anchorage Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to complete further plug and abandonment work on the suspended Kuparuk Well 2T -04 (PTD 186 -143). 2T -04 was originally drilled in 1986 and completed as a selective completion A and C sand injection well. This well is located in an area where surface subsidence has become an issue. Since 1995, this well has measured a total surface subsidence of 48" which has caused severely corkscrewed tubing. The first indication of corkscrewed tubing was observed as early as August 2004 when coil tubing experienced heavy weight swing while removing an ice plug. The well failed an MIT -OA on 3/27/09 and diagnostic casing tests indicate a leak in the 9 -5/8" surface casing at 330' MD. The well passed a State Witnessed MIT -IA to 2800 psi on 6/1/09 and subsequent diagnostics in 2009 were unable to drift past 1650' SLMD to set a plug. As a precautionary measure it was deemed necessary to bullhead cement from surface to plug the perforations and isolate the reservoir. The A -sand perforations were cemented on 10/9/09 and the estimated top of cement is at 7100' MD, The C -sand perforations were isolated in August 1994 by placing an AVA BPI sleeve in the AVA BPL nipple at 7259' MD and further more by the cement pumped to isolate the A -sand. Following the cement squeeze, the tubing passed as MIT to 2660 psi on 11/3/09 (State Witnessed). Recently, a passing MIT -T was done to 3000 psi on ✓ 10/17/11 and a passing MIT -IA was done to 3000 psi on 10/23/11. The current estimated SBHP is 3088 psi. 2T -04 is in the same fault block as 2T -10 and it is assumed that the pressures are similar. 2T -10 SBHP was obtained on 10/17/11 and measured 3088 psi at 5899' TVD which is an equivalent KWF of 10.5 ppg including a 125 psi overbalance safety margin. The MASP is 2498 psi using a 0.1 psi /ft gradient. The objective of this operation is to perform additional P &A operations up to but not including final surface abandonment. The well will remain suspended until the entire pad is ready for surface abandonment. If you have any questions or require any further information, please contact me at 263 -4693. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Well TATE OF ALASKA it .24.. / / ALASKA OIL AN S CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS ''' :$, 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill f Perforate New Pool r Repair well ( ppr d R oogram Suspend r, Rug Perforations r Perforate r Rill Tubing r �emtnisS10n Operational Shutdown 1 Re -enter Susp. Well r Stimulate r Alter casing r Other: ,;7,1,'1"...— ' '"� k' r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -143 3. Address: Stratigraphic f Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20074 -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 2T -04 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): 8160 6216 8067' 6135' Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 115' 115' SURFACE 3260 9.625 3292' 2789' PRODUCTION 7528 7 7556' 5713' LINER 803 5 8155' 6212' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7745 - 7756, 7805 - 7809, 7816 - 7855, 7876 - 7890 5865 -5874, 5915 -5918, 5924 -5957, 5974 -5986 2.875 / 2.375 J -55 / N -80 7262 / 7776 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN 'HB -1' PACKER MD= 7185 TVD= 5433 PACKER - BAKER 'DB' SBE 2.688" SEAL DIA. 5 FT STROKE. MD= 7755 TVD= 5873 TRDP - CAMCO TRDP -1A SSA MD= 1765 TVD= 1708 12. Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/28/2011 Oil r Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned fl Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4693 Printed Name Ian Toomey Title: Wells Engineer l Signatur- — - Phone: 263 -4693 Date / / - / 7 - (7 1 _ Commission Use Only Sundry Number I - Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test /Mechanical Integrity Test r Location Clearance r Other � .Lt. '.0-4 � ( • le 3 » r s .: HOP c r �- C � s%) - 2'b ,,s,, s,, rte �.. 6 c Subsequent Form Required: Lo — `1 0 7 APPROVED BY C� I Approved b 7 COMMISSIONER THE COMMISSION Date: / 1 12. I V I Form 10 -403 Revised 1/2010 ilt, a.0. R I GINAt NAt BOMS NOV 3 0 uIi . Submit in Duplicate 4 0 itAS( • • 2T -04 Kuparuk Injector Suspend Well (PTD #: 186 -143) Current Status 2T -04 is currently shut in and considered suspended by the AOGCC. The A -sand perforations were cemented on 10/9/09 and the estimated top of cement is at —7100' MD. The C -sand perforations were isolated in August 1994 by placing an AVA BPI sleeve in the AVA BPL nipple at 7259' MD and further more by the cement pumped to isolate the A -sand. Following the cement squeeze, the tubing passed as MIT to 2660 psi on 11/3/09 (State Witnessed). Recently, a passing MIT -T was done to 3000 psi on 10/17/11 and a passing MIT -IA was done to 3000 psi on 10/23/11. The last State Witnessed MIT -IA was done on 6/1/09 to 2800 psi. The OA has a leak at approximately 330'. Scope of Work Complete further plug and abandonment work using Nordic 3. Gain access to the tubing, tag current cement plug in the tubing and fill the tubing and IA with cement. Fill the OA with cement, from as deep as possible, to surface. Leave well suspended until entire pad is abandoned. General Well info MASP: 2498 p- (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure/TVD: - current estimated SBHP is 3088 psi. 2T -04 is in the same fault block as 2T -10 and it is assumed that the pressures are similar. 2T -10 SBHP was obtained on 10/17/11 and measured 3088 psi at 5899' TVD which is an equivalent KWF of 10.5 ppg including a 125 psi overbalance safety margin. Wellhead type /pressure rating: CIW Gen IV, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MIT -T: passed October 17, 2011 MIT -IA: passed on October 23, 2011 MIT -OA: failed on March 27, 2009 (OA leak at —330') Well Type: Injector (Suspended) Estimated Start Date: December 28, 2011 Production Engineer: Mike Balog / Evan Reilly Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey© conocophillips.com) Pre -Rig Work Request 1. Bleed tubing, IA and OA to 0 psi. 2. Set BPV. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Ensure tubing and IA is dead. Set BPV. ND tree. MU blanking plug in lift threads. NU 11" 5M BOP and adapter spool. Pressure test BOP including annular to 250/3500 psi. 3. Pull blanking plug and BPV. Pull tubing to neutral weight. 4. RU slickline and attempt to drift tubing. If able to drift, go to Step #8 • • -- Proposed Procedure Continued-- - 5. If tubing will not drift, RU E -line. Punch holes in tubing as deep as possible. Gravity feed 10.5 ppg brine in IA so that it swaps with the fluid in the tubing. Take returns off the tubing. Continue until tubing is loaded with 10.5 ppg brine. 6. Perform blind backoff as deep as possible. POOH with tubing. 7. Mill 7" casing or cut and pull 7" casing as necessary to get past any bad casing and latch on to the tubing. If the 7" casing is pulled, the tubing head will need to be removed and the BOP stack will be nippled up to the casing head. Due to the surface casing leak, the BOP will be considered a diverter until the 7" casing is removed so that a BOP test can be performed. Any BOP test performed while, 0 14 nippled up to the casing head will be limited to 3000 psi due to the pressure rating of the casin• head. 0 . Once access is gained to the tubing by either drifting or latching on with an overshot, RU slickline and 4- p Tag cement inside tubing (AOGCC to witness). RD slickline. Note: Pressure test of the cement plug in the tubing to 2660 psi was performed on 11/3/09. The pressure test was witnessed by Mr. Lou Grimaldi, AOGCC Inspector. 9. RU E -Line. Perforate tubing above TOC or top packer whatever is higher. ✓ 10. RU Schlumberger cementers. Circulate balanced plug of Class G cement from pert holes to -1700'. vim 11. WOC. PT tubing and IA if possible to 1500 psi (PT of the IA may not be possible if the 7" casing has $4. been milled or removed). Bleed tubing and IA to 0 psi. AOGCC to witness pressure testing. ,f t �. q 12. RU E -Line. Tag TOC (AOGCC to witness). Cut tubing with jet cutter above TOC. RD E -Line. 13. Pick up on tubing to ensure free. Circulate in 10.5 ppg fluid to -1000'. POOH with tubing laying down. 14. RU E -Line. Punch holes in 7 "casing at -1000'. 15. Pump down 7" casing taking returns off the 7 "x9 -5/8" annulus to remove arctic pack. If necessary due to casing holes above 1000', set a cement retainer on drill pipe to facilitate circulation and cementing. 16. RU Schlumberger cementers. Fill 7" casing and OA with ArcticSetl cement to surface. Squeeze surface casing hole at 330' MD. If a cement retainer is set in Step #15, fill 7" casing above the retainer with ArcticSetl cement to surface. 17. ND BOP stack. Install dry hole tree. 18. RDMO Nordic 3. Post -Rig Work request: 1. None Proposed Cement Plug • _ I Existing 15.7 ppg AS1 Cement 2•17•4)4 9 A Surface to - 1,000' MD I 330' MD - Surface Casing Hole � Perforate 7" Casing at 1,000' MD 115' MD Conductor, 16" 62.5 #, H 40 � i Arctic Pack (5 �. p ,,J� 5 e KWF - 10.5 ppg Brine ► 1 L- ♦ 1 Cement Shoe TOC 2,020' MD I , ' i 3,292 MD - Surface Casing, 9 -5/8" 36 #, J -55 1 1,765' MD - SCSSV, Camco TRDP -1A -SSA l(-Z 1- ( Cut the Tubing above TOO Tubing - 2 -7/8" 6.5 #, J -55, EUE 8rd ABMOD IPC / 4--- Cement Plug 15.8 ppg Class G Cement Estimated TOC -1,700' MDT Perforate Tubing above TOC�; I ' -7,100' MD - Estimated Top of Cement I II al I� -- I P 7,185' MD - Brown HB -1 Retrievable Packer w /20' PBR PT / - /y3 i •• 17 7,259' MD - AVA BPL Ported Nipple w /sleeve installed I I I Tubing - 2 -3/8" 4.7 #, N -80, EUE 8rd ABMOD IPC iDE CI. 2 2011 a 7,352' MD - Baker Liner Hanger, 7" 26# X 5" 18# i 7,555' MD - Production Casing, 7" 26 #, J -55 C -Sand f-- 7,755' MD - Baker DB Permanent Packer w /5' SBE 1 I i 10/09/2009 Pumped 8 bbls of 15.8 ppg Class G Cement Estimated TOC -7,100' MD A - Sand ConocoPh i I I i ps 8,155' MD - Liner, 5" 18 #, N -80 I Date: November 28 2011 I Drawn By: Ian Toomey 41111P 2T -04 C i lhps ' - ; { Well Attributes Max Angle & MO TD f'e(€kSI(z? l I1V s - s, �4 Wel!bore APUUWI Field Name Well Status Inc!( MD (ftKB) Act Btm (908) c K. } 501032007400 KUPARUK RIVER UNIT J INJ 53.12 1 3,900.00 1 8,160.0 Comment H2S (ppm) tab An otat o End Date KB Grd (9) Rig Release Date SSSV TROP _ Last WO' 40.00 8/13/1986 _)ArIrtiorPIN.., flat, 1 s*r{+y ' d4e,?9 . 7, (ftKB) �.= B) E , ,d . �.� - __ Annotation !De h ftK6 End Date ( Annotation Last Mod By End Date _ __ Ssh+r'.tel�- .mat. - Last Tag' 1 7,920.0 7/14/1998 Rev Reason PUMP CMT PLUG I Imosbor 1 10/10/2009 ' ,�' "' Casing Strings -. - - Ab., a,,..,12 SN1.Jr..K . . SO/ >,r,: ,, . + e&r.et.� I String OD String ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR, 1 • Case Description (in) (in) Top (ftKB) (1806) (ftKB) (Ibs/R) Grade String Top Thrd 115 CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 1-40 SURFACE 9 5/8 8.525 0.0 3,292.0 2,788.6 36.00 J -55 SAFETY VLV, PRODUCTION 7 6.151 0 0 7,555.0 5,712.8 26.00 J -55 1,765 i I LINER 5 4. 151 7,3520 8,155.0 6,2114 18.00 N -80 Tubin Strings - g g -. GAS LIFE String OD String ID Set Depth Set Depth (TVD) String Wt String 2,938 Tubtmg Description (in) (in) T ftKB _ (ftKB) (ftKB) _(Ibs/ft) Grade String Top Thrd TUBING 27/8 2.441 0.0 7,262.0 5,490.5 6.50 J -55 EUEBrdABMOD TUBING 23/8 1.995 7,262.0 7,776.0 5,890.2 4.70 N-80 EUEBrdABMOD SURFACE. 3,292 ' Other In Hole (All Jewelry: Tubing Run &Retrievable, Fish, etc.) F Top Depth (TVD) T 65 1 0.19 SAFETY Camco TRDP -1A (Control 10/22/1986 2.312 I X I 17 1 5,192 Out) 2,938 2,567.6 51.73 GAS LIFT CAMCO/KBMG /1/DMY /BK! / /Comment STA 1 10/23/1986 2.371 6,165 ` 5,192 4,000.1 47.49 GAS LIFT CAMCO /KBMG/1/DMYBK/ // Comment STA 2 10/23/1986 2.371 6,165 4,686.3 43 60 GAS LIFT CAMCO /KBMG /1/DMYBK/ // Comment: STA 3 10/23/1986 2.371 6,515 4,940.0 43.40 GAS LIFT CAMCO /KBMG /1/DMYBKI// Comment STA 4 10/23/1986 2.371 GAS LIFT, ` 6.515 6,832 5,171.9 42.77 GAS LIFT CAMCO /KBMG/1/DMYBK/ /I Comment STA 5 10/23/1986 2.371 i 7,121 5,385.2 41.94 GAS LIFT MMH/2 7/8 X 1.5/1.5/DMY /RK/ // Comment STA 6 11/13/1986 2.347 7,160 5,414.3 41.84 PBR Brown 10/22/1986 2.500 cns uFT6,83, 2 _- 7,185 5,432.9 41.77 PACKER Brown'HB -t' PACKER 10/22/1986 2.750 7,222 5,460.8 41.96 INJECTION CAMCO /KBMG/1/DMYBK/ / /Comment STA7 6/27/1998 2.371 7,259 5,488.3 41.76 NIPPLE AVA BPL PORTED NIPPLE 10/22/1986 2.250 7,259 5,488.3 41.76 SLEEVE -C AVA BPI SLEEVE Set 8/21/94 8/21/1994 1.870 7,755 5,872.9 33.93 PACKER Baker 'DB' SBE 2.688" seal dia. 5 ft stroke. 10/22/1986 1.968 7,769 5,884.4 33.68 NIPPLE Camco'0' Nipple NO GO 10/22/1986 1.812 7,775 5,889.4 33.57 SOS Camco 10/22/1986 1.995 7,776 5,890.2 33.55 TTL 10/22/1986 1.995 PBR'7'166 -- ; Perforations & Slots -, - -- - Shot ' Top (TVD) Btm (IVO) Deos 64 - T• . MKS) Btm 0193 (9K6) (ftKB) Zone Date (eh -- Type Comment PACKER, 7,185 --- - -- Iftifillfg - r 7,745 7,756 5,864.6 5,873.7 C -4, 21-04 10/23/1986 12.0 IPERF 3 3/8" Schlum Hyper) 1", 7,805 7,809 5,915.0 5,918.3 A-5, 2T -04 10/23/1986 1 0 IPERF 3 3/8" Schlum Hyper) - 7,816 7,824 5,924.1 5,930.7 A -4, A -3, 21-04 10/23/1986. 1 0' IPERF 3 3/8" Schlum Hyper) INJECTION, ____ 7,824 7,855 5,930.7 r) .7 5,956.5 A-3, 2T -04 10/23/1986 4.0 IPERF 3 3/8" Schlum Hype 7.222 � - - -' - __' - - -- - ...- - - -- _ IPERF 3 3/8" Schlum Hyper) E General & Safety TUBING wlSLINKY" due to O � tion 7,876 7 Notes Gene NIPPLE, 7,259 p ndD t Anno SLEEVE - C, \ _._.._ - ___ " 4/17/2009 NOTE DRIF( UB possible corkscrewed tubing(WSR 4 /17/09) 7,259 p t ' • t PRODUCTION, 7,555 IPERF, ],745 -7,756 tea• PACKER,7,755 - -; NIPPLE, 7,769- -.. --- . T.:: SOS, 7,775 --- _ 2@' l TTL, 7,776 IPERF, __,M�. Y` - 7,805-],809 d? - t IPERF.. 7,816 -7,624 IfAV IPERF, ,__ 7,82d -7.855 _ i IPERF, ' -'. 7.876 -7,890 . rrr CEMENT h 4 PLUG, 7,100 . - LINER, 8,155 TD, 8,160 _ ---- ConocoPhillips - - Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ad ft&D NO ( 2 201Q September 19, 2010 Commissioner Dan Seamount'' Alaska Oil and Gas Conservation Commission , 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -04 (PTD 186 -143) 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- 04 (PTD 186 -143). 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 ALASKSL AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air w ell r r P r pug Perforations r S ti mulate r Other Aker Casing r Pull Tubing r Perforate New Pool Waiver Suspended well r r Time Extension inspection r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r � 186 -143 3. Address: 6. API Number: Stratigraphic r Service r � P. 0. Box 100360 9, Anchora a Alaska 99510 50-103-20074-00 7. Property Designatio : 8. Well Name and Number: ADL 25569 2T -04 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 8160 feet Plugs (measured) 7776' true vertical 6216 feet Junk (measured) NONE Effective Depth measured 8067' feet Packer (measured) 7185, 7755 true vertical 6214 feet (true vertucal) 5433, 5873 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 3292 9.625 3292' 2788' PRODUCTION 7555 7 7555' 5713' i 4 . INTERMEDIATE 8155 51/2 8155' 6212' ct Perforation depth: Measured depth: 7745'-7890'- cemented True Vertical Depth: 5864' - 5974 cemented IR V Tubing (size, grade, MD, and TVD) 2.375, N -80, 7776 MD, 5890 TVD Packers & SSSV (type, MD, and TVD) PACKER - BROWN 'HB -1' PACKER @ 7185 MD and 5433 TVD PACKER - BAKER'DB' SBE 2.688" SEAL DIA. 5 FT STROKE. @ 7755 MD and 5873 TVD TRDP - CAMCO TRDP -1A SSA (CONTROL LINE DEFEATED; NOT LOCKED OUT) @ 1765 MD and 1708 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 r Service r 15. Well Status after work:SuspeoAd L2' r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ r WINJ r 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: NA Contact MJ Loveland /Perry Klein Printed Name MJ Loveland/Perry Klein Title Well Integrity Project Supervisor Signature � Phone: 659 -7043 Date RBDMS SEP _2 3 7A Form 104 4 Revised 7/2009 Submit Original Only T-16 4 V 0 r -,I// /" Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riv Unit 2T -04 Field /Pool: Kuparuk River/Kuparuk River Pool_ Permit # (PTD): 186 -143 Sundry 309 -332 API Number: 50103200740000 Operator: ConocoPhillips Date Suspended: 10/16/2009 Surface Location: Section: 35Z 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: Pad or location surface: e0 I?,-L km Location cleanup needed: AA> Pits condition: All - - Surrounding area condition: 6 - Water /fluids on pad: R,O Discoloration, Sheens on pad, pits or water: Samples taken: /jam 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: Af W4 0 7 ' 0 rZ1 rY �Y c516/��► /Ole —A* 7 .4eDS /P �Iff Cellar description, condition, fluids: , W010y9 AJ 1:5061RIWe" FS1" pol k — w Rat Hole: Iv "? Wellhouse or protective barriers: kVJLV A5lKr i> fZ 1 4r �C. u3tXLtC Well identification sign: T t> oW GtIEf 6 14. A.) L Tubing Pressure (or casing if no tubing): / d = 0 O Annulus pressures: Q�+e %uhe e C;' '5'13// a Wellhead Photos taken (# and description): Ll \p2 V IL { ► -mil Work Required: / y47': , RGw - 4( O 7 gC Cif- mg F,, e v 2e2 v 'K1 3a � Operator Rep (name and signature): - OWE AOGCC Inspector:_jU�3y,� Other Observer Inspection Date: AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: WA41 IAKA1 e t--r' KUP 2T -04 ConocoPhiOfips "� Well Attributes Max Angle s MO TD Inc Alaska, Wellbore API /UWI Field Name Well Sfatua Incl ( °) MD (kKB) Act Btm E (11K.) 501032007400 KUPARUK RIVER UNIT INJ 53.12 3,900.00 81 Comment 1125 (ppm) Date Annotation End Date KB-Grtl (k) Rig Release Date ••• Well Con :-2T-0410/1020094:08:19PM SSSV:TRDP Last WO. 40.00 8/13/1986 Schemetic -AOWaI Annotation Depth(ftKB) End Date Annotation Last MOd By End Date Last Tag: 7,920.0 7/14/1998 Rev Reason: PUMP CMT PLUG Imosbor 10/10/2009 Ca sina Strin s String OD String ID Set Depth Set Depth (TVD) String Wt Stri ng CONDUCTOR, Casing Description (in) (in) Top (kKB) (kKB) (ftK6) (IbsM) Grade String Top Thrd 115 CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H 40 SURFACE 9548 8.525 0.0 3,292.0 2,788.6 36.00 J -55 SAFETY VLV, 47 PRODUCTION 7 6.151 0.0 7,555.0 5,712.8 26.00 J -55 1,765 LINER 5 4.151 7,352.0 8,155.0 6,211.4 18.00 N -80 Tubing Strings GAS LIFT, String OD String ID Sal Depth Set Depth (TVD) String Wt String 2,938 Tubing Description (in) (in) Top(kKB) Ik KB) (kKB) (lb.7ft) Grade String Top Third TUBING 27/8 2.441 0.0 7,262.0 5,490.5 6.50J - EUE8rdABMOD SURFACE, TUBING 1 23/81 1.9951 7,2ti2.01 7,776.01 5,890.21 4.7131 1 EUE81dABMOD 3,292 Other In Hole All Jewelry: Tubing Run 8r Retrievable Fish etc. Top Depth GAS LIFT, (TVD) Top Incl 5192 Top (ftKB) (kKB) V) Description Comment Run Data ID (in) 1,765 1,708.1 30.19 SAFETY VLV Cameo TRDP -1A SSA (Control Line Defeated; Not Locked 10/22/1986 2.312 Out) GAS LIFT, 2 ,938 2,567.6 51.73 GAS LIFT CAMCO /KBMG/l /DMY /BK/ // Comment: STA 1 10/23/1986 2.371 6,165 5,192 4,000.1 47.49 GAS LIFT CAMCO /KBMUl /DMY /BK/ / / Comment: STA2 10/23/1986 2.371 6,165 4,686.3 43.60 GAS LIFT CAMCO/KBMG/1 /DMY /BK/ / / Comment: STA3 10/23/1986 2.371 6,515 4,940.0 43.40 GAS LIFT CAMCO/KBMG/1 /DMY /BK/ // Comment: STA 4 10/2311986 2.371 cnse IS a 6,832 5,171.9 42.77 GAS LIFT CAMCO /KBMG11 /DMY /BK // Comment: STA 5 10/23/1986 2.371 7,121 5,385.2 41.94 GAS LIFT MM W2 7/8 X 1.5/1.50MY /RK/// Comment: STA 6 11/13/1986 2.347 7,160 5,414.3 41.84 PBR Brown 10/22/1986 2.500 GAS LIFT, 7,185 5,432.9 41.77 PACKER Brown'H &1' PACKER 10/2211986 2.750 6,832 7,222 5,460.8 41.96 INJECTION CAMCO /KBMG/1 /DMY /BK/ / / Comment: STA7 6/27/1998 2.371 7,259 5,488.3 41.76 NIPPLE AVA BPL PORTED NIPPLE 10/2211986 2.250 7,259 5,488.3 41.76 SLEEVE -C AVA BPI SLEEVE Set 8/21/94 8/21/1994 1.870 7,755 5,872.9 33.93 PACKER Baker'DB' SBE 2.688" seal dia. 5 ft stroke. 10/2211986 1.968 GAS LIFT, 7,121 7,769 5,884.4 33.68 NIPPLE Cameo'D' Nipple NO GO 10/22/1986 1.812 7,775 5,889.4 33.57 SOS Cameo 10122/1986 1.995 7,776 5,890.2 33.56 TTL 10/2211986 1.995 PBR, 7,160 Perforations &Slots Shot Top (TVD) I Bum (TVD) Den. Top (kKB) Bt. (kKB) IkKB) (kKB) Zone Date (ah•.• Type Comment PACKER, 7,185 r - ' 7,745 7,7561 5,864.61 5,873.7 C-0, 2T-04 10/2311986 12.0 IPERF 3 318" Schlum HyperJ r ' 7,805 7,809 5,915.0 6,918.3 A -5, 2T-04 10/23)1986 1.0 IPERF 3 3/8" Schlum Hyper) 7,816 7,824 5,924.1 5,930.7 A4, A-3, 2T-04 10/2311986 1.0 IPERF 3 W' Schlum HyperJ INJECTION, 7,824 7,855 5,930.71 5,956.5 A -3, 2T-04 10/23/1986 4.0 IPERF 3 318" Schlum Hyper) 7,222 7,876 7,890 5,974.1 5,985.9 A -2, 2T-04 10/23/1986 4.0 IPERF 3 3/8" Schlum HyperJ Notes: General & Safe ty NIPPLE, 1,289 End Date Annotation SLEEVE -C, 4117/2009 NOTE: "DRIFT TUBING w /SLINKY" due to possible corkscrewed tubing (WSR 4/17/09) 7,259 PRODUCTION, 7,555 IPERF, 7,745-7,756 PACKER, 7,755 NIPPLE, 7,769 SOS,7,775 TTL, 7,776 IPERF, - 7,805-7,809 IPERF, 7,81 &7,824 IPERF, 7,824 -7,855 IPERF, 7,87 &7,890 CEMENT PLUG, 7,100 LINER, 8,155 TD, 8,160 } + I + + l E 16 +00 0 0 ° o o ° 00 ° o l o I0 + N 0 w + o + + Z Z Z Z Z Z Z I DRILL S 1 -�— I + -}- —{— —}— + E 14 +00 I I I I I I 2{ D OW 71 -1 } T 4 13 0 10 T- OM CC g R F $ R 2 _ - V 2$^ ogo01n4 o o • t + I -}- + + + -}- E 10 +00 — — SCALE 100 I 50 100 LEGEND 0 THERMOSIPHONS 1 "= 100, 8 WELLS IAUxsBTIRY a aesme�, sm. FORM: SSIZE DRAWN: DESIGN: ECM NO: AREA: 2T MODULE: )000( UNIT: 62 AJR — — CC N0 CHECKED: APPROVAL, Co nocoPhillips PLOT PLAN APPROVAL : — — — Alaska,lnc. 1 130 10 Updated Thermosi hon and Well Asbult locations NRB JFC SCALE: DATE: cADD nLENAME: JOB NO: SUB JOB NO DRAWING No: RE PART: REV: V DATE REVISION BY CHK JOB PROJ 1" = 100' 3/13/09 S2T PLT PLN 3/13/09 NSDK 0000 DS2T PLOT PLAN 1 OF 1 1 's C—j I \5 w m r k� j x "�; �jt�'"*3^ . r tea. ,. ..„ y ^!. � :yfrdR "`�• 2Xn V 1 xi.. ,. •PU ilea �. # .arr..r.rr� T -04 PTD 186 -143 c ConocoPhillips Alaska, Inc his hoto is copyrighted b p Y ConocoPhillips Alaska. Inc. and annot be released or published ithout express written consent f Co Alaska 2T -04 PTD 186 -143 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska., Inc. and cannot be released or published , without express written consent of ConocoPhillips Alaska 10 „ ” `' d r J4m y 1 a y Well Name 2T -04 Notes: Start Date 7/112010 Days 123 Bleed History End Date 11/1/2010 -- _ -- - WELL TIME STR -PRES END -PRES DIF -PRES CASING SERVICE Annular Communication Surveillance 2T -04 10/18/2010 20 5 15 INNER PWI 3000 _ - 2T -04 10/18/2010 50 60 -10 INNER PWI _WHP 1 2 2T -04 10/18/2010 20 1 19 OUTER PWI IAP 2T -04 10/16/2010 480 1 479 OUTER PWI OAP ' _WHT ` ` ` `A A i 2T -04 10/112009 100 1 99 INNER PWI 2500 - - r � -- - 1 2T -04 10/15/2009 5/2009 90 1 89 OUTER PWI 2T -04 10/15/2009 400 75 325 INNER PWI 2T -04 6/1/2009 370 300 70 INNER PWI 2000 _ 06 2T -04 4/1/2009 950 400 550 INNER PWI LL G. 1500 -- 0.6g 1000 - - 0.4 500- 0.2 VLa L) Jul-10 Aug -10 Sep -10 Oct -10 - 0.� 0.6 � B a- �BLPD 0.4 0.3 02 0.1 0 i' Jul -10 Aug -10 Sep-10 Oct -10 Date j •L2_ -!o i • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC j 5 2 WELL COMPLETION OR RECOMPLETION REPO T OG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑✓ 1 a s. 20AAC 25.105 20AAC 25.110 Development t` 71 f cploratory ❑ 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.: OctoberV 2009 186 -143 / 309 -332 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 -0360 August 1, 1986 50- 103 - 20074 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached:' 14. Well Name and Number. Surface: 352' FSL, 556' FWL, Sec. 1, TI IN, R8E, UM August 12, 1986 2T -04 Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 990' FSL, 1377' FWL, Sec. 2, T1IN, R8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1057' FSL, 1163' FWL, Sec. 2, T11 N, R8E, UM 8067' MD / 6135' 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-498945 y- 5970332 Zone-4 8160' MD / 6216' TVD ADL 25569 TPI: x-494486 y- 5970972 Zone-4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 494272 - 5971039 Zone-4 SSSV @ 1765' MD / 1708' TVD 2667 18. Directional Survey: Yes ❑ No R/ 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" 242 sx CS II 9 -5/8" 36# J -55 Surf. 3292' Surf. 2789' 12.25" 875 sx AS 111, 345 sx Class G, 100 sx AS 1 7" 26# J -55 Surf. 7556' Surf. 5712' 8.5" 425 sx Class G 5" 18# N -80 7351' 8155' 5557' 6212' 6.125" 1122 sx Class G 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 (MDITVD) 2.875" x 2.375" 7262', 7776' 7185' MD / 5433' TVD, 7755' MD / 5873' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ZVIjG DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 7776' 8 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 ❑✓ 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 r 28. GEOLOGIC MARKERS (List all formations and marker ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1550' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7739' 5858' Base Kuparuk C 7760' 5875' Top Kuparuk A 7799' 5908' Base Kuparuk A 7959' 6043' i N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certi at the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed Name J. Ennis Title: Wells EnOineer Signature Phone 265 -1544 Date oZ 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 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 2 3 2009 REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate ❑ Other AnCh� ge Alter Casing ❑ Pull Tubing [:1 Perforate New Pool ❑ Waiver El Time Extension Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter S spended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill N ber: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 18 43 / 3. Address: Stratigraphic ❑ Service '-J. API Num r: P. 0. Box 100360, Anchorage, Alaska 99510 K-1 03 - 20074 -00 KB Elevation (ft): N Name and Number: R B117' T - Property Designation: Field /Pool(s): ADL 25569 Kuparuk River Fiel ruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8160' _ feet 0� true vertical 6,�� feet P measured) 7776' Effective Depth measured 8067' feet Julk (measured) true vertical 6135' feet Casing Length Size MD TVD Burst Collapse Structural P/ CONDUCTOR 115' 16" 115' ��jl� 115' SURFACE 3292' 9 -5/8" 329 ' �lT 2789' - - PRODUCTION 7555' 7" 7 5¢' 5712' LINER 803' 5" /8dO7816'-7855', 55' 6212' Perforation depth: Measured depth: 7745'- 7756', 780 7876' -7890' � NO Onn true vertical depth: 5865'- 5874', 15' 6918', 5924'- 5957', 5974' -5986' Tubing (size, grade, and measured depth) 2.875" 2.373 ", J -55 & N -80, 7262', 7776' MD. Packers & SSSV (type &measured depth) Br 'FA1�1' pkr, Baker'DB' SBE pkr @ 7185',7755' am TRDP -1A -SSA SSSV @ 1765' 12. Stimulation or cement squeeze sum a Intervals treated (measured) cement plug @ 7776' pump 8 bbls of 15.8 ppg Class G cement Treatment descriptions includ used and final pressure: 13. Representative Daily Average Production or Injection Data f Oil -Bbl Gas -Mcf Water -Bbl Casinq Pressure Tubing Pressure Prior to well operatio SI Subsequent to op ation SI 14. Attachments . Well Class after work: Copies of Lo and Surveys run _ Exploratory El Development ❑ Service Daily Re rt of Well Operations _X Well Status after work: Oil❑ Gas F] WAG GINJU WINJ ❑ WDSPL❑ 17. 1 her y certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -332 Con ct Jim Ennis 26 54 P ' ted Name Jim En Title Wells Engineer Signature Phone: 265 -1544 Date � I uQr!263-4612 0 Pre are b S aron A Form 10 -404 Revised 04/20 .OA /v'Z jre�ubmit On lnly 2T-04 Well Events Summary DATE ~SUMMARY 10/9/09 PUMPED 8 BBLS OF 15.8# CL~ G CEMENT TO SECURE WELL. ESTI~E TOC @ 7100' (TTL @ 7776') . DISPLACED CEMENT WITH 6" OD NERF WIPER, 5 BBLS OF FRESH WATER, AND 40.9 BBLS OF DIESEL. TRAPPED 2380# OF WHP. WILL RETURN FOR MIT-T AT A LATER DATE. 10/12/09 Post cement plug MIT passed. Tested the tubing down to the TOC @~7100' (TTL @ 7776') to 2500 psi. Ready for AOGCC witness test. 10/14/09 BLEED T DOWN TO 0 PSI, TUBING DD TEST - FAILED - WING VALVE LEAK 10/15/09 BLEED TBG TO OPSI. 60MIN. DD TEST- PASSED; BLEED IA & OA TO OPSI. 10/16/09 BLEED IA / OA TO 0 PSI _.,~ KUP ~ ~~~~~~~1p5 ~ Well Attributes A`as~_:' '~: ".. ~ WellboraAPVUWI ~Feldl . ~ 507032007400 ~KUP/ IComment SSSV:TRDP _. wzuc rg zr,-oa,-aaioi _. ... . Srnemat A : ~ n4a~.oc ,, ~.~ . il Annotation IDepih(kK6 CONDUCTOR. tis SAFETV VLV. 1,]65 GAS LIFT. 2.938 SURFACE. 3.292 GAS LIFf. 5.192 GASLIFT.___ _ 6,?65 GAS LIFT, _ 6,832 GAS LIFf, _ 7.121 PBR, 7,160 - 'ACKER. 7,185 - INJECTION, _ ]222 NIPPLE. ].259 SLEEVE-C, ~ ].259 'ACKER. 7,755 NIPPLE. 7,769 sos. zns TTL. 7.7]6 IPERF. 7.805-].809 IPERF. za~s-zaza IPERF,_ _ _ 7.826-7.855 IPERF, 7,876-7,890 CEMENT PLUG.l.100 LINER. 8.155 ~_ TD,8.160 2T-04 Release Data 8/13/1986 1 Date Last Tag~ 7,920.0 ~ 7/14/1998 Rev Reason: PUMP CM i PLUG '. Imosbor . L 70/10/2009 _ -. . C351l1~ $It70 5 String OD String ID Set Depth Sat Depth (ND) j String Wt '~ String CasingDescription (~~) (in) ~ Top(RKB) (ftK6) (ftKe) (Ibs/fl) Grede StringTopThrd ~ ,CONUUCfOR ~ i6 '~, 15.062 0.0 115.0 ll5.0 62.50 H-00 SURFACE . 95/Si 8.525 0.0 3,292A 2,788.6 36.00 J-55 '~ PRODUCTION 7~ fi.751 0.0 /,555.0 5,712.8 26.00 J-55 ~ ~ LWER ~ 5~ 4.751 7,352.0 R,155.0 6,2114 78.00 N-80 • ... , __ ._. . ___ ___- Tubing Strings ~~~ String OD String ID Set Depih Set Depih (ND) String Wt Sir'rng I TuDingDes<ription (in) (in) Top(flK6) (NKB) (HKB~ (Ibs/k) G2de StringTopThM fUBING 21/8 2A41 0.0 7,2620 5,490.S~i 6.SO~iJ-55 EUE8rtlABMOD ~iUBING 23/A 1.995 7,262.0 7,776A 5,8902I 4JO~N-80 EUESrdABMOD ~ Other In Hole All Jewel : Tubin Run $ Retrievable, Fish, etc. 7op Depih ~ (TVD) Top Incl Top (HKB) (ftKe) (°) Description Commant Run Date ID (in) 1,765 1,708.1 30.19 SAFEI Y VW Camm TROP-tA SSA (CoMrol Line Defeated; Not Lceketl 10/22/1986 2.312 Ou[) 2,938 2567.6 5173i GASLIFT CAMCO/KBMG/1/DMY/BK///Commem:STA1 10/23/1956 2.371 5,192 4.000.1 ~ 47.49I GASLIFT CAMCO/KBMG/1/DMY/BK///Comment: STA2 10/23I7986 , 2.371 6,165 4,686.3 '. 4360 GASLIF7 ~iCAMCO/KBMG/1lDMY/BK///CommencSTA3 10/23/19861 2.371 6,515 4,940.0 'i 43.40 GAS LIFT ~~CAMCO/KBMG///DMY/BK/// Commem: STA 4 10/23/1986 2.371 6,832 5,171.9 ~ 4?.77 GASLIF7 ICAMCO/KBMG/1/DMY/BK///Commenc STAS 10/23/1986 2.371 7,121 5,3852 41.94 GAS LIFT IMMhV2 7/8 X t5/t5/DMY/RK/// CommenC STA 6 11/13/1986 2.347 7,160 5414.3 41.84 PBR ''~,grown 10/22/1986 2500 7,185 5,432.9 41.77 PACKER IBrown'HB-1' PACKER 1012Z7986 2J50 7,222 5,460.8 41.96 1NJECTION ~CAMCO/KBMG/1/DMY/BK!//Comment:STA7 fi/27/1998 2.371 7,259 5,488_3 ~ 41J6 NIPPLE ~AVA BPL PORTED N~PPLE 10/22/1986 2250 7,259 5,488_3 41J6 : SLEEVE-C ~AVA BPI SLEEVE Set 8/2V94 I 8/21/1994 1.870 -___ 7,755 5,872.91 __. 33.93 . .. . . PACKER Baker'DB' SBE 2.688" seal dia. 5 R stroke. ____ . 10122/1986 1.968 ~ 7,769 5,884.4~ 33.68'~~ ~ NIPPLE Camco'D'NippleNOGO 10/22l1986 7J15 ._ .. 5.SR9A~ . __.._.. 33.S/ _ __.-+ iS05 ~- ~~~ _--_ Camco 1022/7986 1.995~ 7,776 5.8902~ 3355~I iTL 10l22/1986 1.995 Perfore tions & Slots __ ___ -.._ . ..._. I.__..._ . .._. . snmi ~TOp(TV D~ Btm (TVD) ~Dens Top (ftKB) i Btrn (flK6) ~ (kK6) (flKB) 2one I DMa (sh... Type CommeM 7,745 I 7,756~ 5 864 .6 5,873J~iC -0, 2T-04 i 10/2311986 72.0 IPERF 3 3/8" Schlum HyperJ 7,805 7,809~'~, 5 915 A 5,918.3 A- 5, 2T-04 ' 10/23/1986 1.0 IPERF 3 3/8" Schlum HyperJ 7,816 7,8241~ 5,924 .1 5,9307 A ll, A-3, 27-04 10/23/1986 1.0 IPERF 3 3/8" Schlum HyperJ 7,824 7,855 5,930 J 5,956.5 A- 3, 2T-04 10/2311986 4.0 IPERF 3 3!8" Schlum HyperJ ~ 7,SJ6 7 890 5,974 .1 5,985.9 A- 2, 2T-04 1023/1986 4.0 IPERF 3 3/S" Schlum HyperJ ~,~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,~~, ~Z1r4~I~ DATE: November 05, 2009 P. I. Supervisor ~ 1 FROM: Lou Grimaldi SUBJECT: Wellbore Plug Petroleum Inspector ConocoPhillips Alaska Inc. KRU 2T-04 Kuparuk River Field/Unit PTD #186-143 .~ Tuesday, November 03, 2009; I witnessed the pressure test of a wellbore plug placed to isolate the wellbore from formation on ConocoPhillips Kuparuk River Unit well # 2T-04. The plug had reportedly been down squeezed from surface prior to my arrival. The tubing was pressured up with diesel to 2660 psi. The following pressures were observed during the test; Pretest Initial 15 min. 30 min. 45 min. IA 39 39 39 39 39 OA 10 10 10 10 10 Tubing 0 2660 ~ 2580 2550 ~ 2550 I requested that the tubing pressure test be held an additional 15 minutes as there seemed to be excessive bleed back for the small amount of volume pumped. The / test pressure was bled to zero at the conclusion of this test with approximately the same amount returned as was pumped (.8 Bbl's). The plug has apparent integrity although the negative test should help to confirm this. Ian Ives (KRU DHD) was very helpful with information and background on this well. Ian has a good attitude and seems intent on understanding the differences of our requirements between types of test's, why they are performed and the importance of reliable results. Attachments: None ~~~ ~ ~ 200 Non-Confidential Wellbore Plug KRU 2T-04 11-03-09 LG.doc 1 of 1 • • ,y_c ~ v.:. ~F --' Y 6' i '~ G=' ~~~ i A~~ 4 `ct K ~F ~ ~ ~ ~ ~ ~. ~- y N ~6, ` ,.: , k ~' g { H ~ ~ ° {`^ y - n z ~ Y"`~ t q n S i I'~ 54p ~ ~~ bk~ ~m~ 7$ ~ ~ F tf ~~ 7 !~ G ~ .€ ~ i ~ ~ p k ~ f ~` ,Y ~ u ~ ~ ~ ~ ~ k y ~ ~ SEAN PARNELL, GOVERNOR ~,:~ ~ ~ ~~ ~ ~: ~_~ ~ ~ ~~~ ~ ~ ~ `~~ ~ ~~ ° ~$ ~ ~a~,. ` ~ ~. ~~ > ~ ~-~ ~.r,'~` ~ ~ ~t~~~+ ~~ ~ITi ~~D a~~-.7 ~ 5 ~ 333 W. 7thAVENUE, SUITE 100 -~ c~ CD~S~i RQAii~~ C~~~S`S'I~~ ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 ~«' ~ FAX (907} 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. ,~ + P.O. Box 100360 ~ l ~ ~ ~ Anchorage, AK 99510 ~ ~0 Re: Kuparuk River Field, Kuparuk River Oi1~~~ooT"'27'-04 Sundry Number: 309-332 Dear Mr. Ennis: ~,a ~~~:~r'~~~a.~ :'`~ ~'` ~ ~ 20~~ 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, Cathy P. Foerster Commissioner ~ DATED this~ day of September, 2009 Encl. <~,'. ~ „1~~~.~~~~.~~ ~ STATE OF ALASKA • `, i . 4 _ ` ,'' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR ~~UNDRY APPROVA~.~~ ~ ~ ~i4 ~, ~ ~~~ ~ .. ,= x 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^~ ' Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~eve~opment ^ Exploratory ^ 186-143 • 3. Address: Stratigraphic ~ Service ~. 6. API Number: P. 0. Box 100360, Anchora e, Alaska 99510 50-103-20074-00 • 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-04 ' 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 25569 ' RKB 117' • Kuparuk River Field / Kuparuk River Oil Pool , 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth nnD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8160' . 6216' . 8067' 6135' Casing Length Size MD ND Burst Collapse CONDUCTOR 115' 16" 115' 115' SURFACE 3292' 9-5/8" 3292' 2789' PRODUCTION 7555' 7" 7555' 5712' LI N ER 803' 5" 8155' 6212' Perforation Depth MD (ft): PerForation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7745'-7756', 7805'-7809', 7816'-7855', 7876'-7890' 5865'-5874', 5915'-5918', 5924'-5957', 5974'-5986' 2.87rJ~~ & 2.375~~ J-55 & N-80 7262~, 7776~ Packers and SSSV Type: Packers and SSSV MD (ft) Brown 'HB-1' pkr, Baker'DB' SBE pkr @ 7185', 7755' Camco TRDP -1A-SSA SSSV @ 1765' 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 September 28, 2009 Oil ^ Gas ^ Plugged 0' Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify tha he foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam im Ennis Title: Wells Engineer ! Signature Phone 265-1544 Date ~, j~ ~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3oy- 3,3~-- Plug Integrity ~OP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~0~.~~ .~~3~GCT~t ~o l,~ i ¢hCS,s ~,2tSS~~- T / c-S ~ ~4a.i"~k~~ N'~°~~ e L ~ y E° ~~Q~ Subsequent Form Required: ~ ~~-~~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date. -~' Form ~-403 Revj,b~e~ 06/2~6 ~ ~ ) ~ ~ ~ A L ~ ` ~ ~ r ~ ~ ,^ ~~~ ~ ~, Submit in Dupl~~~ ~( ~~ ~ ~ ~ ~' 9Z3•o~' ~' ~ • Suspend Well Procedure • Well 2T-04 Kuparuk Injector Pump cement plug for well control barrier Network 10258885 Well History: 2T-04 was originally completed as a single selective Kuparuk water injector in 1986 and has been an 'A' sand only injector since September 1994. fn January 1996, the well's service was changed to a WAG injector and it injected gas through March 2009 when it failed an MITOA. The well was then switched to ~ water injection for 17 days and SI. Subsequent diagnostics indicate corkscrewed tubing will not allow access beyond 1650' SLM. The corkscrewed tubing is believed to be the result of well subsidence. The procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover to restore injection or / P&A can occur. TOC for the plug is targeted for 7100' MD. Work accomplished to date: 6/1/09 4 Year State Witnessed MITIA - Passed, (AOGCC - Jeff Jones). Initial T/I/0=2100/370/100. Pressured up IA to 2800 psi with 4.0 bbls of diesel. T/I/0=2100/2800/100, 15 min T/I/0=2100/2670/100, 30 min T/I/0=2100/2640/100. Bled IA down. Final T/I/0=2100/300/100. 5/14/09 IA FL NS, T/I/0= 2000(si)/400/80 4/17/09 ATTEMPT TO DRIFT TBG FOR CALIPER LOG. RUN 1.5" "SLINKY" -TOOL STRING; DRIFT W/ 5' OF 1.75" DD BAILER, STARTED SETTING DOWN @ 1450' SLM," LOST SPANGS", ONLY MADE IT TO 1650' SLM, HEAVY P/U WEIGHT F/ 250 TO 950#s ERRATIC SHAKING ON WAY OUT. JOB SUSPENDED. 4/16/09 TROUBLESHOOT CONTROL LINE ISSUES. ATTEMPT TO BRUSH 8~ FLUSH TBG BUT ONLY GET TO 984' SLM. IN PROGRESS. 4/2/09 T& IC POT/PPPOT - PASSED (WP) 3/31/09 (WP) MIT-IA ( PASSED ), IC-POT ( FAILED ) 3/28/09 SCLD; Initial T/I/0= 3780/1140/20; Rigged up bleed hose to OA and began charging with lift gas; shot OA FL @ 330ft. (600fps) Waited 15min. shot second FL @ same location; Waited 30min. shot third FL @ same location Final T/I/0= 3780/1140/90 3/27/09 MITOA FAILED. Initial T/I/O = 3600/1150/150. Established LLR @ 2 bpm @ 600 psi using 20 bbl diesel. Final T/I/O = 3600/1150/150. Remaining work: 1. RU SLB cementer. Bullhead 50 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, 24 bbls 9.6 ppg brine and 12 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg & IA pressure to zero. Jim Ennis Page 1 9/15/2009 Cont~oPhitlips ; ~ ... ~ , .. , ~ r~~ _.,_ wenoa~ts 2T~4a_ a{~4CZ4oy i ay ~u -m _ . _ __ Stl~ematic. Act 'il ~ . ~ ~..,:.'u~9 CONDUCTOR. 1~5 SAFEN VLV. ___,. t.765 GAS LIFT. 2.938 _ - - _ ,. .. SURFACE. 3.292 GAS LIFT. . . 5.i92 GAS LIFT, 6,165 GASLIFT. ~ 6.515 GASLIFT. .~ ~~ 6,832 '~ GAS LIFT. .. _ . ~ ].12~ ~.:N", PBR. ].160 ti ~ : ~ACK~R. ]. ~85 ~ , i INJECTION, ~ ~.z2z NI SLEEVE-C9 ~ l,259 PRODUCTION, 7,555 IPERF, 7 ]45-7.756 ~ACKER,],]55 NIPPLE, 7,]65 SOS. 7,]]5 TTL. ],T/6 IPERf, 7.805-7.fl09 IPERF, 7,816-1,824 IPERF. 7,824-7,855 IPERF. 7.876-7.890 LINER.8,155- TD, B.160 ~ -- KU P - 2T-04 s Mvc Angle 8 MD ~iTD Field Name WeIIS~a~u 'Prodflnj Type Incl (°) ~MD (ftNB) Act Btrn (%K8) KUPARUK RIVER UNIT INJ '~ 53.12 ' 3,900.00 ~ 8,760.0 H25(ppn) IDate ~'.Mntlion~~.EndDate IKB-Grtl(ft) ~RigReleaseDat ' ILastWO: I 40.00 ' 8/13/1986 ~apih (ftKB) 'End Date MnotaPion End ~Date 7,920.0 7/14/1998 IRevReason:POSSIBLECORKSCREWED78G I 4/2612 0 0 9 1 2 441 (TVD) '~ Top Incl (ftKe) (HKe~ (°) Dascription Comment Run D~ 1,765 1,708.1 ~I, 30.19 SAFETY VLV Camco TRDP-1A SSA (Control Line Deteatr.d; Not Locketl 10/22/1! ~ ~~~ 2,938 2,567.6 51 J3 GAS LIFT CAMCOlKBMGI7IDMY/BK/// Comment: STA 1 10/23/1! 5,192 4,000.1 47.49 GAS LIFT ~ CAMCO/KBMG/71DMY/BK/// Comment: STA 2 1012311! 6,765 4,6863 43.60 GAS LIFT CAMCOlKBMG/1/DMYBK!// Commem: STA 3 10/23/1! fi,575 4,9400 4340 GASLIFT ~CAMCO/KBMG/7/DMY/BK/!/CommeN:STA4 10l23/1! 6,832 5,171.9I 42J7 GAS LIFT I CAMCOIKBMG/7/DMYBK///Commeni: STA 5 10l23/1! 7,121 5,3852~'i 41.94 GAS LIFT MMW2 7/8 X LS/LS1DMYtRK/U CommenC STA 6 11/1311! 7,760 5,4143~~ 41.&4 PBR Brown 10i22/1! 7,785 5,432.9i ~ q7J7 pqCKER Brown'HB-7'PACKER t0i22;1! 986 Perforatio ns 8 Slots _ - ~ --- - - - - -i sno~ _ -- . Top (TVD) Bim (TVD) I ~~, Dans Top(kK6)..Btrn{kK6) (fiK8) (ftKB) i Zone ~i Date (s~.... Type , CommeM _ 7,745~ 7,756 58648 5,873JC-0,2T-64 i10J23/1986 ~ 12.OiIPERF '~.33/S"SchlumHyperJ 1 7,805l 7,809 ~ ~ 5,915.0 5,918.3 A-5, 2T-04 1072311986 i~ 1 0 IPERF - ~ 3 3/8" Schlum HyperJ 7,876I 7,824 ' S,924.1 5,930] A~, A-3, 27-04 10/23/1986 i 1.0 IPERF i 3 3/8" Schlum HyperJ 7,824. 7,855~, 5,930J 5,956.SA-3,2T-04 10l23/1986 401PERF _ ~33/8"SchlumHyperJ 7,876 ~ 7,890. 5.. 74.1 ~ 5.9 5. A- . ' I ' 1// 4.0 IPERF 3 3/8" Schlum HyperJ - ~-- . Notes: Ge ~ neral & Safety _ . _ ~ .. .. _.. __..__ ___ _ _~ End Date Annota tion _ _ 4/1/2009 I NOTE: "DRIFT TUBING w/SLINKY"' tlue ~o possible corksr.rewed tubi ng (WSR 4/17/09)- -__ ~ 7 ks in adva ~~-- om Maunder, PE AOGCC ~~> ~ w~ ~.~~ ~ ~] age ..-- ~T,~ 1 ~'G -/~3 ~ e-c~ G:t~ZSr~ o`~ s~v ec~\ vJ ~ t~ Zs ~~~ ~ ~- 'a- -C~' ~. 2~ ~J~~~ , ~ ~,~~~ -~~ c-F ~bsZ~c.~..~ P ~ ~S s J ~5 -~- ~c.~.~ ~c~.~ c~,~~ c~-c s~J ~c-c~. ~ W~- ~ ~~. ~S ~o ~.~ -~. c~.c-L ~~~ ~ c._cc.~~~~- ~~ `f S ~ p~.~-~~~~-~.\ ~ ~~... ~-~So~~.~~ Y., ~~~~ So~ ~~~ ~~~~s~~~~~~ ~~ `~ ~ S ~lJC~~ ~L V~~C~ ` \ S vS ~~ ~ ~ `~? 1~ ~ ~, a ~ ~v~ ~-~-~5 Ccs_.S~ ,~ c, O -~ ~~~~~ ~-~-t~ ~ t~ ~ ~~ ~ ~ Z~ ~~j ~ ~ ~ ~~~~~~ ~ ~ ~.~.~c.sc `'~`~`c~~c°Q"~~ S ~~~ ~ ~~ ~ ~~- ~ ~` ~~~ ~ co ~~~ ~ ~ c- p c,c~ ~ , , l ~ ~ v..S~~ `~. ~D ~ ~e ~~ a~ o n vJp~ ~ So~~ ! ~~ a~ 9/200 MEMORANDUM TO: Jim Regg ~.r P.I. Supervisor ~~~~ ~~~ ~f ~' t FRO1Vt: 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-04 KUPARUK RIV UNIT 2T-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.LSuprv ~RjZ. Comm Well Name: KUPARUK RIV UNIT 2T-04 Insp Num: mitJJ090608120200 Rel Insp Num: API Well Number: 50-103-20074-00-0o Permit Number: 186-143-0 ~ Inspector Name: Jeff Jones Inspection Date: 6/1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-oa Type Inj. N 'j'am 5433 IA 370 2800 '~ 2670 2640 P.T.D 1861430 TypeTest sPT Test psi lsoo OA loo loo ~ loo loo Interval aYRTST p~F P / Tubing 210o zloo z1oo~ 2100 NOtes• 1 well inspected; 1 exception noted: the tree cap is leaking and was repaired. ., i ~,~ ~C1 t~ Wednesday, June 10, 2009 Page 1 of 1 RE: KRU DS2T Suspected Surface Casing Leaks Page 1 of 3 Regg, James B (DOA) From: NSK Well Integrity Proj (N1878@conocophillips.com] Sent: Monday, April 20, 2009 2:48 PM ~ To: Regg, James B (DOA) ~ t Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: KRU DS2T Suspected Surface Casing Leaks Follow Up Flag: Follow up ~~ ~'Q{ ~~r Ct~ (1; y~ t ~~ - 1~. Flag Status: Green ~ ~.2i,~ 2T_ ~~ ~' ~ t ~ _ ~ I ° Attachments: 2T-11.pdf K,21,t zr - i o ('~~ f~ ~~~ k2c,t 2,- - i i ~ i ~ -- o ? 7 Jim, t `~ -- G~~ ~.t z. - l~ t'~ On 4/19/09 CPAI shut in wells 2T-04, 2T-09, and 2T-15. Additional diagnostics indicate tubing obstructions exist in these wells preventing mechanical secure. On 4/18/09 CPAI shut in well 2T-11. The path forward for 2T-11 will to harvest a SBHP then attempt to secure with a plug in the AVA sleeve at 5801' md. All of the above wells will remain shut in until they can be repaired. We will not be submitting a request for Administrative Approval to continue, water only injection for these wells. These wells will be shut ih long term. Do they need to be carried on the monthly failed injector report? 2T-10 remains online in water only service. We completed a drift, tag, and caliper of the tubing and intend to pursue and AA for continued water injection. 2T-16 remains online in water only service and is scheduled for a drift and tag with subsequent,c~liPer.to follow. If our plans change with regard to 2T-16 I'll inform you immediately. Let me know if you have any questions. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk- Phone (907) 659-7043 Cell Phone (907) 943-1244 Voice Pager 659-7000 x937 ~~~ #~~ ~ ~~` ~ lrt X01 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 03, 2009 3:47 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly 2/23/2010 RE: KRU DS2T Suspected Surface Casing Leaks Page 2 of 3 A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisted of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (OAxForm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom.maunder@alaska.gov; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J oSubject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. 2!23/2010 RE: KRU DS2T Suspected Surface Casing Leaks Page 3 of 3 ~ ~ Y Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf» « File: 2T-04 TIO Plot.pdf» « File: 2T-09 TIO Plot.pdf» « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf» « File: 2T-15 TIO Plot.pdf» « File: 2T-16 TIO Plot .pdf» « File: 2T-02 Wellbore Schematic.pdf» « File: 2T-04 Wellbore Schematic.pdf» « File: 2T-09 Wellbore Schematic.pdf» « File: 2T-10 Wellbore Schematic.pdf» « File: 2T-11 Wellbore Schematic.pdf» « File: 2T-15 Wellbore Schematic.pdf» « File: 2T-16 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 2!23 /2010 KRU 2T-11 Caino~oPhiJli~as Alaska, fnc. 2T-11 API: 501032006500 Well T e: INJ An le TS: 40 d 6330 SSSV Type: TRDP Orig 6/6/1986 Angle @ TD: 40 deg @ 6789 Com lesion: sssv Annular Fluid: Last W/O: Rev Reason: PULL BPC, Set (1 n7-n7a, BPI, TAG FILL OD:3.500) Reference Lo Ref Lo Date: Last U date: 1!29/2007 Last Ta : 6463' TD: 6789 ftK6 Last Ta Date: 1/28/2007 Max Hole An le: 42 de 5400 Gasin Strn -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread Gas LiR CONDUCTOR 16.000 0 110 110 62.50 H-40 andrel/Dummy CASING SUR 9.625 0 2973 2973 36.00 J-55 Valve 1 (sss55sss, . PROD. CASING 7.000 0 6170 5665 26.00 J-55 OD:5.940) LINER 5.000 5976 6789 6789 18.00 L_ -80 _ ___ Tubin Stein -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 5804 5382 9.30 J-55 EUE 8RD AB-MOD PeR 2.375 5804 6394 5838 4.70 N-80 EUE 8RD AB-MOD (5711-5712, 2 875 6394 6396 5839 6.50 . _ _ _ _ Pertorations Summa T _ __ Interval TVD __ __ Zone _ Status Ft SPF Date T e C omment 6331 - 6352 5789 - 5805 C-4 21 12 10/11/1984 IPERF 120 de Ph• 3 3/8" H erJet 6429 - 6435 5864 - 5869 A-4 6 1 10/11!1984 IPERF 180 de Ph• 3 3/8" H erJet ~ 6446 - 6484 5877 - 5906 A-3 38 4 10/11/1984 IPERF 90 de Ph; 3 3/8" H rJet PKR Mandrels/Valves Gas Lift (5725-57zs, St . MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv ~ OD:6.151) Cmnt 1 5665 5274 Otis LBX DMY 1.5 RO-5 0.000 0 6/17/1987 In'ection Mandrels/Valves ~ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO I Date Run Viv Cmnt Injection - 2 5763 5350 CamCO KBUG DMY 1.0 BK 0.000 0 10/12/198 andrel/Dummy Other: IU s e Ui .etc. -COMPLETION valve 2 } De th TVD T e Descrl lion ID (5763-5764, OD:5.313) 1777 1777 SSSV Camco TRDP-IA-SSA Control Line Defeated' Not Locked Out 2.812 5711 5310 PBR Baker 3.000 5725 5320 PKR Baker'FHL' 3.000 5801 5379 NIP AVA BPL PORTED NIPPLE 2.750 5801 5379 SLEEVE-O AVA BPI SLEEVE set 1/28/2007 2.310 SLEEVE-O (saol-58oz, 6373 5822 PKR Baker 'DB' w/ 5' SBE 3.250 oD:z.75o) 6387 5832 NIP Camco 'D' Ni le NO GO 1.812 6395 5838 SOS Camco 2.441 6396 5839 TTL ?•441 -- ! General Notes _ _ Pert (6331.6352) _ _.. _ . _ __-_ Date 'Note 1/27/2 007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM? -- -- i --- ----- PKR I (83736374, j ~ OD:4.151) i NIP i i ~ (63876388, I OD:2.375) I ~ ! I TUBING I (63946396, ' OD:2.875, IDt2.441) ~ ~ ~~ 'i ~ ~ ~ SOS ~ I ~ I i (63956396, OD:2.875) ' Perf .._. _. . _...__ I - . . (64296435) ___ ._...-_- '. 'I i Perf (6446-5484) - ~--- RE: KRU DS2T Suspected Surf Casing Leaks • Page 1 of 2 Regg, James B (DOA) From Sent: To: Cc: Regg, James B (DOA) Friday, April 03, 2009 3:47 PM !~~~~ 4I3I~ 'NSK Problem Well Supv' ,~ __ _ __ C'~ ~ ~~ - X43 Maunder, Thomas E (DOA); NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks This is what we agreed to in phone conversation 3/31/2009. CPAI may continue to inject water only in the listed KRU 2T wells. Please add these 7 wells to the monthly injector integrity report. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~ ~"~`' ~,., ,~ ~:, ~, rg Anchorage, AK 99501 a ~~~~:a~„ ~;~,,,,~„!~ _~i. ~'° ~ ~~' ~~L,y' 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, April 03, 2009 2:47 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: RE: KRU DS2T Suspected Surface Casing Leaks On 04/02/09, the last of a series of diagnostic tests on 7 injectors on Drillsite 2T (2T-02, 2T-04, 2T-09, 2T-10, 2T- 11, 2T-15, and 2T-16) to confirm the existence of 2 barriers was completed. The tests consisTed of MITIA's and positive and negative tubing and inner casing pack off tests. All of the tests, without exception, passed and therefore we are continuing to inject water only and have designated each well as being incapable of conversion to miscible injectant (MI). CPAI plans to continue water only injection and begin drafting applications for administrative approval to continue water only injection with a known surface casing leak (O x orm). Please reply with your concurrence on the proposed plan of action. Martin From: NSK Problem Well Supv Sent: Tuesday, March 31, 2009 6:56 PM To: 'jim.regg@alaska.gov' Cc: 'tom maunder@alaska.gov'; NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK; Lyons, Kelly A; Jackson, Darron B.; Ennis, J J Subject: KRU DS2T Suspected Surface Casing Leaks Jim, Recently CPAI conducted MITOA's on 12 wells on Drillsite 2T as a part of a program investigating subsidence. Of 4/3/2009 RE: KRU DS2T Suspected Surface Casing Leaks Page 2 of 2 • • the 12 wells tested, there were 11 failures, 7 of which are injectors. The second phase of our diagnostics included injecting gas down the OA while using an Echometer to monitor the fluid level. The 7 injectors exhibited fluid levels which could not be depressed below 300' - 348'. We suspect that the reflection is possibly due a hole in surface casing or a mechanical obstruction and is consistent with data collected in the region. We began conducting MITIA's today (3/31/09) on all 11 wells and will follow up with tubing and inner casing packoff tests. Provided we can demonstrate the existence of 2 barriers, CPAI requests permission to continue water only injection in the subject wells (2T-02, 2T-04, 2T-09, 2T-10, 2T-11, 2T-15, and 2T-16) until administrative approval can be obtained within a reasonable amount of time. Attached are 90 day TIO plots and Wellbore schematics. « File: 2T-02 TIO Plot.pdf » « File: 2T-04 TIO Plot.pdf » « File: 2T-09 TIO Plot.pdf » « File: 2T-10 TIO Plot.pdf » « File: 2T-11 TIO Plot.pdf» « File: 2T-15 TIO Plot.pdf » « File: 2T-16 TIO Plot .pdf » « File: 2T-02 Wellbore Schematic.pdf » « File: 2T-04 Wellbore Schematic.pdf » « File: 2T-09 Wellbore Schematic.pdf » « File: 2T-10 Wellbore Schematic.pdf » « File: 2T-11 Wellbore Schematic.pdf » « File: 2T-15 Wellbore Schematic.pdf » « File: 2T-16 Wellbore Schematic.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/3/2009 Well Name ~' " ~ Notes: End Date 41120t7`~ Days 90 Start Date 1/1 X2009 wHP Annular Communicaton Surveillance IAP ----...- _... - ----- ----- __. --- 12 OAP . .- - - --_-- - - -__ __ ____. .. .__ 0 WHT 3500 - - - 100 3000 80 2500 2000 p y Q g '~ 1500 40 1000 20 500 0 0 Jan-09 Feb-09 Mar-09 Apr-09 3000 ! DG~', MGI 2500 ~PWI ' a 2000 '~SWI m 1500 ~BLPD -- ~ LL ~ 1000 500 0 Jan-09 Feb-09 Mar-09 Apr-09 Date • W ConocoPhillips Alaska, Inc. 2T-04 API:~,50103, sssv SSSV Type.' TRDP (nss-nss. - oD:2.87s> ~ A_nnular Fluid:' Reference Log:_ Last Tag: _ 7920 Last Tag Date: 7/14/1 ~ Casing String -ALL ST ~I ~. PBR (71so-7161, OD:2.875) PKR (71as-718x. OD:6.151) SLEEVE-C (7zss-7zso. OD:2.250) Perf (7745-7756) PKR (7755-7756, OD:4.151) NIP (7769-7770, OD:2.375) TUBING (7262-7776, OD:2.375, ID:t.995) Perf (7805-7809) Perf (7816-7824) Perf (7824-7855) Perf (7876-7890) KRU 2T-04 Type_ INJ _ Angle @ TS: ' 34 deg @ 7741 Orig' 8/13/1986 Angle @ TD: 31 deg @ 8160 etion: _ _ i _ W/O: _ __ _ Rev Reason: FCO -TAG Date: Last Update: _ 3/7/2004 TD: 8160 ftK6 angle: , 53 deg @_3900 ~_ Bottom T_ TVD Wt Grade Thread )_ 115 115 62.50 H-40 _ l 3292 _ 2789 ~ 36.00 J-55 __ PROD. CASING 7.000 0 - - - -_ _ _ 7555 __ 5712 26.00 ~_J-55 LINER 5.000 7352 8155 C 6211 18.00 N-80 ~ ubing String -TUBING - - _ -- - - _ _ Size Top Bottom TVD _ ~ Wt Grade_ Thread 2.875 0 7262 _ 5490 - _ 6.50 J-55 EUE 8RD AB-MOD __ _ 2.375 7262 77 76 58 9 0 , . 4.7 0 N-8 0 EUE 8RD AB-MOD _ 'ertorations Summary _ . __ _ . _ . . _ Interval TVD ~ Zon_e _ Sta_tu s ~ Ft SPF Date TypeT Comment 7745 - 7756 5865 - 5874 C -4 _ 111 12 10/23!1984 IPERF 3 3/8" Schlum Hype r) _ _ 7805 - 7809 5914 - 5918 A-5 4 1 10/23/1984 IPERF 3 3/8" Schlum Hype r) 7816 - 7824 5924 - 5930 A-4,A-3 _ _ _ _ 8 1 10/23/1984 IPERF 3 3/8" Schlum Hype r) _ 7824 - 7855 5930 - 5956 A-3 31 4 10/23/1984 IPERF 3 3/8" Schlum Hype __ r) 7876 - 7890 5974 - 5986Y A-2 14 4 ;10/23/1984 IPERF 3 3/8" Schlum Hype rJ____ 3as Lift MandrelsNalves - _ --- -- St MD TVD Man ' - Man Type V Mfr V Type - V OD Latch Port TRO Date Vlv Mfr , _ _ ; I Run i Cm_nt 1 _2938 2568 Camco KBMG DMY 1.0 BK 1 0.000 0 10/23/1986 ;__ _ _ ___ _ 2 5192 4000 Camco KBMG DMY 1.0 BK 0 000 0 10/23/1986 _ 6165 4686 Camco KBMG DMY 1.0 BK 0.000 0 10/23/1986 4 6515 4940 Camco KBMG i DMY 1.0 ' _ BK 0.000 0 10/23/1986 5 6832 5172 Camco KBMG DMY - 1.0 _ BK 0.000 0 10123/1986 ; _ 6 7121 5385 MMH 2 7/8 X_1.5 DMY . 1.5 RK 0.000 0 11/13/198 ' njection MandrelsNalves _ ._ St MD TVD Man Man Type V Mfr V Type ~ V OD ,Latch Port TRO ' Date Vlv Mfr _ _Run_ Cmnt 7 7222 5461 Camco KBMG DMY_ 1.0 BK _ 0.000 0 6/27/1998 . __ ether (plugs, equip., etc.) - JEWELRY _ ___ __ Depth ND Type , Description ID 1765 1708 SSSV Camco TRDP-1A SSA~ Contro _ _ l Line Defeated; Not Locked Out _ 2.312 7160 5414 PBR Brown _ __ ______ ___ _ _ _ _ 2.500 7185 5433 PKR ~ Brown 'HB-1' 2.750 TTL MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg \?~¿;'I:!7 "'/7107 P.I. Supervisor lye ~ DATE: Wednesday, June 06,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-04 KUPARUK RIV UNIT 2T-04 Src: Inspector 2; ló\~ ~ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv$!L Comm Well Name: KUPARUK RIV UNIT 2T-04 API Well Number: 50-103-20074-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603142041 Permit Number: 186-143-0 Inspection Date: 6/2/2007 V' Rei Insp Num: Packer Depth Pretest In itia I 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-04 Type Inj. G TVD 5433 IA 425 2520 2440 2440 P.T.D 1861430 TypeTest SPT Test psi 1500 OA 25 25 25 25 Interval 4YRTST P/F P / Tubing 3600 3600 3600 3600 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. sCANNED JUN 2 0 2007 Wednesday, June 06, 2007 Page I of I ) ,) State of Alaska MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ....;-¡ I· K,a¿rr q 13/0( DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-04 KUPARUK RIV UNIT 2T-04 .~ ~\~ \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2T-04 Insp Num: mitCS050812185938 Rei Insp N urn: API Well Number: 50-103-20074-00-00 Permit Number: 186-143-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weli I 2T -04- IType I~¡l'- ·wTivo-·:5433-¡·niAl··llõö--¡----2ïiQ-- I 2060 .---- 2060---r--·---¡------·-- --.-~--- ·-j-----I--¡-····· -- - -.--j-----.---.--¡-------.f-------... --,----.---..----j-------..--.-.-------I-.----------j,-....-..--- P.T. 11861430 TypeTest SPT. Test psi ¡ 1358.25 I OA 50 I 50 ! 50 . 50 ! --Inte;~~~---:;-;R-;;¡----p;=···-~;--··-----·T~bing 1-·-- 2150"-T---2150 -1"- 2150--T2150-~----'~-'---'- ____. _______._______..___.._. _._____.___ ____.__...L____.._l_______._~....____l._____ ..__---'-.__...._____------'____. __._.._ Notes: Pretest pressures observed for 30+ minutes and found stable. (~E': p ?:~~ 0 ?_ÛJ!.~] >j(;Þ~r.~~\',El" '.JI j Wednesday, August 17, 2005 Page 1 of 1 · . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_X WI to WAG Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 117 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 4926' FNL, 4723' FEL, Sec. 1, T11 N, R8E, UM (asp's 498945, 5970532) 2T-04 At top of productive interval 9. Permit number / approval number 990' FSL, 1377' FWL, Sec. 2, T11 N, R8E, UM 186-143 / At effective depth 10. APl number 50-103-20074 At total depth 11. Field / Pool 4221' FNL, 4116' FEL, Sec. 2, T11 N, R8E, UM (asp's 494272, 5971039) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8160 feet Plugs (measured) true vertical 6216 feet EffectiVe depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 242 sx CS II 115' 115' SUR. CASING 3175' 9-5/8" 875 sx AS m & 345 sx C~ass G w/' 3292' 2789' PROD. CASING 7438' 7" 425 sx Class G 7555' 5712' LINER 803' 5" 122 sx Class G 8155' 6212' Perforation depth: measured 7745-7756; 7805-7809; 7816-7824; 7824-7855; 7876-7890 true vertical 5864-5874; 5914-5918; 5924-5930; 5930-5956; 5974-5986 Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 7262' MD; 2-3/8",4.7#, N-80 Tbg @ 7776' MD. Packers & SSSV (type & measured depth) BAKER 'DB' SBE 2.688" SEAL DIA. 5 FT STROKE. @ 7755' MD; BROWN 'HB-I' @ 7185' MD; CAMCO TRDP-1A SSA (CONTROL LINE DEFEATED; NOT LOCKED OUT) @ 1765' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A 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 1686 2480 Subsequent to operation 1436 600 3672 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? CallJeffSpencer 659-7226 Signed s~--~'~f/r~n~r C ~~/¢¢'~ ~ / ~J~------~ Title Production Engineering Supervisor Date Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2T-04 DESCRIPTION OF WORK COMPLETED SUMMARY MICROFILMED 9/~ 1/00 DO NOT PLACE ANy NEW MATERIAL UN ER THIS PAGE STATE OF ALASKA 0 ~ AI..AoKA OIL AND GAS CONSERVATION COMMI~=kSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown__ Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development "")(-. Exploratory _ Stratigraphic Service .~ ,SP~ 4. Location of well at surface 352' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 990' FSL, 1377' FWL, Sec. 2, T11N, R8E, UM At effective depth 1040' FSL, 1209' FWL, Sec. 2, T11N, R8E, UM At total depth 1057' FSL, 1163' FWL, Sec. 2, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 81 6 0' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-04 9. Permit number/approval number 86-143 / 7-131 10. APl number 5o-103-20074 11. Field/Pool Kuparuk River Oil Pool 6214' feet Cement: 8067'-8160' Effective depth: measured 8 0 6 7' true vertical 6135' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 3260' I 6" 9 5/8" Cemented 7528' 7" 804' 5" measured 7745'-7756', true vertical 5863'-5872', Measured depth True vertical depth 242 Sx CS II 1 15' 1 15' 875 Sx AS III & 3292' 2788' 345 Sx Class G, top job w/100 sx AS I 425 Sx Class G 7756' 571 2' 122 Sx Class G 81 5 5' 621 0' 7805'-7809', 7816'-7824', 7824'-7855', 7876'-7890' 5913'-5917', 5922'-5929', 5929'-5955', 5973'-5985' Tubing (size, grade, and measured depth) 2 7/8" J-55 set at 7278', 2 3/8" N-80 set from 7278' to 7792' Packers and SSSV (type and measured depth) HB-1 Pkr @ 7185', DB Pkr @ 7755', Camco TRDP-1A-SSA @ 1765' 13. Stimulation or cement squeeze summary R EC; E I VED Convert well from A & C Sand production service to A & C Sand injection service Intervals treated (measured) JAN Treatment description including volumes used and final pressure /~bSk~ OJl.~x (~a8 C0ri8, 14. Representative Daily Average Production or Injection Data .:.~s~cJ~0rag~li '~;~' ...... :~..~__. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 369 201 - 0 - 975 309 Subsequent to operation 0 0- 1800 1225 2035 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned "~~~)'~ TitleS~/w.;'~[~ ~, 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 Porcuvine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER J. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 - PHONE: (907) 762-2553 -- --- ;,'~D' - .:. o,-,,~ · ;- -"/':3L A.>'->' ' . ~ ~.""T .- .[.. 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, (Jd~.mes E. Eason 'Director cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 t99t Alaska 0ii .& Gas Cons. Commission Anchorage paper DEI~AI~T~IENT OF NATUI~AL I~ESOUI~CES August 5, 1988 Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99§10-0360 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 IAOGCC) 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, 198B) and the last 2T well release date is the 2T-8 Well IJanuary 16, 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 /XUG - ~ l~BB j'~l{).~I',,'.4 Oil {..: {i;L3 {..",..'li:~. {.',gli:lll[:~.]'21l ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY WELL COMPLETION ZONES TAKING WATER INJECTION BWPD 2B-11 21089 11/19/85 2H-01 20033 03/15/86 2H-04 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 06/16/87 SPINNER FOLLOWUP ARC S 06/05/87 SPINNER FOLLOWUP ARC S 06/07/87 SPINNER FOLLOWUP ARC S 06/13/87 SPINNER INITIAL ARC SS 06/16/87 SURVEY INITIAL A S 06/21/87 SPINNER INITIAL ARC SS 06/16/87 SURVEY INITIAL ARC SS 06/16/87 SURVEY INITIAL ARC SS ARC ARC ARC ARC A ARC A A 3485 1833 59O RECEIVED ff .AUG ,-~, ~' -, i~ .... / Alaska 0il & Gas Cons. Commission Anchorage 50-029 3A-02 21431 3A-04 21433 3A-10 21457 21458 3A-14 21490 04/14/87 /Y-I~ ~ 01/21/87 05/25/87 SPINNER 01/21/87 05/87 SURVEY 01/21/87 05/87 SURVEY 01/21/87 05/27/87 ~ 05/87 SURVEY / · INITIAL ARC SS INITIAL A&C SS INITIAL A S INITIAL ARC SS INITIAL A S ,~-'"~'"~?~ f~ "' ~ . , ARC A A ARC A 2500 1200 1650 RECEIVED c,/I ATTACltMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE II - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 '"'""2B-II ~- 21089 '""-~2.-o1~ 20033 '~'2H-O.,,-''/ 20027 50-103 '"'"J 2T- 04'--''/ 20074 2T-09 20071 "'"~2T- 11 ~ 20075 2T-15 20062 2T-16 20063 50-029 "'"'~3AIO2 ~ 21q31 3A-04 21433 3A-lO 21457 ~ 21458 3A-14 21q90 DATE OF DATE OF DATA TYPE REASON FOR WELL INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION INJECTION SURVEY SURVEY SURVEY 11/19/85 06/16/87 SPINNER FOLLOWUP A&C S 03/15/86 06/05/87 SPINNER FOLLOWUP A&C S 03/15/86 06/07/87 SPINNER FOLLOWUP A&C S 03/30/87 06/13/87 SPINNER INITIAL A&C SS 03/30/87 06/16/87 SURVEY INITIAL A S 03/30/87 06/21/87 SPINNER INITIAL A&C SS 03/30/87 06/16/87 SURVEY INITIAL A&O SS 03/30/87 06/16/87 SURVEY INITIAL A&C SS 01/21/87 05/25/87 SPINNER INITIAL A&C SS 01/21/87 05/87 SURVEY INITIAL A&C SS 01/21/87 05/87 SURVEY INITIAL A S 01/21/87 05/27/87 SPINNER INITIAL A&C SS 04/14/87 05/87 SURVEY INITIAL A S ZONES TAKING WATER A&C A&C A&C A&C A A&C A A A&C A A A&C A INJECTION BWPD 3485 1833 590 2500 1200 1650 RECEIVED AUG a1987 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. · Post Office [,. _. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5961 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3N-9 ~3N-8A ~2T-7 ~2T-4 ~T-15 ~2T-11 CEL 4-7-86 7500-9272 CEL .4-7-86 5100-9272 'CET/CEL 10-29-86 6200-6712 CET/CEL 10-4-86 7350-8160 CET/CEL 10-7-86 6900-7465 CET/CEL 10-11-86 5965-6620 Receipt ~cknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) BPAE Chevron ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan¥ STATE OF ALASKA ALAS.%_OIL AND GAS CONSERVATION COMIL 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other,/~ 2. Name of Operator ARCO Alaska, In¢ 3, Add ross PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 352' FSL, 556' FNL, Sec. 1, T At top of productive interval llN, R8E, UM 5. Datum elevation (DF or KB) RKB 117' 6. Unit or Property name Kuparuk River Unit 7. Well number 2T-4 8. Permit number 990' FSL, 1377' At effective depth 1040' FSL, 1209' At total depth 1057' FSL, 1163' FWL, Sec. 2 FWL, Sec. 2 FWL, Sec. 2 11. Present well condition summary Total depth: measured 8160 true vertical 6214 Effective depth: Casing Structural Conductor Surface X X Xl~a,~~e Production Liner measured 8067 true vertical 6135 Length 80' 3260' , T11N, R8E, UM , T11N, R8E, UM ~ T11N~ R8E~ UM 'MD feet ' TVD feet 'MD feet ' TVD feet Size 16" 9-5/8" 7528' 7" 804' 5" Permit #86-143 9. APl number 50-- 103-20074 10. Pool Kuparuk River 0il Pool Plugs (measured)NOne R E [ E I V E D MAR - 2 1987 Junk (measured) None Naslm 011 & Gas Cons. Commission Cemented Measured depth Allt~h°ra~ue Vertical depth 242 SX CS[I 115' MD 115' TVD 875 SX ASTTZ & 3292' MD 2788' TVD 345 SX Class G Top job w/lO0 SX AS[ 425 SX Class G 7756' MD 5712' TVD 122 SX Class G 7351'-8155' MD 5556' -6210' TVD XgCXf~,~4JO~ ~(pt h: measured 7745'-7756' MD, 7816'-7824' MD, 7876'-7890' MD 7805' -7809' MD, 7824' -7855' MD true vertical 5863'-5872' TVD, 5922'-5929' TVD, 5973' -5985' TVD 5913'-5917' TVD, 5929'-5955' TVD Tubing (size, grade and measured depth) 2-7/8"/2-3/8", J-55, tb9 w/tail @ 7776' Packers and SSSV (type and measured depth) Packers and SSSV (type and measured depth) ,,u-~. rot. r~cT ~ 7z~u . .up r~c~:~' . 7755% & 12.Aftachmen[s uescr,puon summary Of prop~al vv,, vY~ i i viii ~ ~lf.U v ~lly ~1 vHy%~ I,,VlJ ~-~V I~, ~:-~ ~I~: ~IIU W~ ~:l · 13, Estimated date for commencing operat~od 14. If proposal was verbally approved Name of approver ~ ~ ~ I g Date approved 15. I hereby certify that the foregoing is true and.~o~r~c~% ~s~f'~¢~'~ledge Signed /.-Jd~c.--~/ ~) ¢.,-~¢~*~]%'~¢'¢~¢ Title SP. 0potations En9inee~ Date 2/24/87 Commission Use Only Conditions of approval Notify commission so representative may witness / ~ Plug integrity ~ BOP Test ~ Location clearance I Approved by ...... C~OTn mtssi~ n-e-r by order of the commission Date,~ -c~ -2'~ feet Form 10-403 Rev 12-1-85 Submit in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~.~MMISSION 1. Status of Well WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well [] SUSPENDED [] ABANDONED [] SERVICE [] OIL GAS 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 86-143 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 103-20074 9. Unit or Lease Name Kuparuk River Unit 4. Location of well at surface 352' FSL, 556' FWL, Sec. 1, T11N, RaE, UN At Top Producing Interval 990' FSL, 1377' FWL, Sec. 2, T11N, RaE, UM At Total Depth 1057' FSL, 1163' FWL, Sec. 2, T11N, RaE, UM 6. Lease Designation and Serial No. ADL 25569 ALK 2667 10. Well Number 2T -4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions N/A feet MSLI 1 20. Depth where SSSV set I 21. Thickness of Permafrost 1765' feet MDI 1550' (Approx) 5. Elevation in feet (indicate KB, DF, etc.) RKB 117' 17. Total Depth (MD+TVD} D} 8160'MD 6214'TVD 22. Type Electric or Other Logs Run DIL/SFL/SP/Cal, FDC/CNL, GR, CET, GCT 12/23/86* 19. Directional Survey YES [X NO 23. CASING, LINER AND CEMENTING RECORD GRADE TOP SETTING DEPTH MD BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. 16" 62.5# H-40 ~urf 115' 24" 242 sx CS II 9-5/8" 36.0# J-55 ~urf 3292' 12-1/4" 875 sx AS III & 345 sx Class G sx AS I Performed top iob w/101 425 sx Class G 7" 26.0# J-55 ~urf 7556' 8-1/2" 5" 18.0# N-80 7351' 8155' 6-1/8" 122 sx Class G lottom and 25. TUBING RECORD SIZE 2-7/8" 26. DEPTH SET (MD) IPACKER SET (MD) 7776' I 7185' & 7755' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) /AMOUNT& KIND OF MATERIAL USED See attached Adden~Jum, dated 1/13/87, for Fracture data / w/12 spf, 60° phasing w/1 spf, 90° phasing w/1 spf, 90° phasing w/4 spf, 90° phasing w/4 spf, 90° phasing 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 7745'-7756'MD 5863'-5872'TVD 7805'-7809'MD 5913'-5917 'TVD 7816'-7824'MD 5922'-5929'TVD 7824'-7855'MD 5929'-5955'TVD 7876'-7890'MD 5973'-5985'TVD 27. .N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Hours Tested Casing Pressure Date of Test IPRODUCTION FOR IOIL-BBL GAS-MCF TEST PERIOD ]~ CALCULATED , OIL-BBL GAS-MCF 24-HOUR RATE [~ CORE DATA WATER-BBL WATER-BBL ICHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) F-Iow Tubing Press. 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. EB 0 1987 Alaska 0il & Gas Cons. C0mmlssl0n AnchOrage Wel 1 perforated & f. uhi no run 1~1/?~/86. WC2: 09: DAN I CONTINUED ON REVERSE SIDE None *Note: Drilled RR 0~/13/86. Form 1 O-407 Rev. 7-1-80 Submit in duplicate i~/ 29. t~ , 30. ; ~ ,,, ~ .... -' ~ \ , GEOLOGIC MARKE'RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravitv, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7739' 5858' N/A Base Kuparuk C 7760' 5875' Top Kuparuk A 7799' 5908' Base Kuparuk A 7959' 6043' 31. LIST OF ATTACHMENTS Addendum (dated 01/13/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~0 ~/~ ~ Title Associate Engi neet Date /I -- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state-in item .16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement~ lng and the Ioc~iop.:o;[, the. c~menting tool. :' ' Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njectibn~, Shut-in; Other-explain. Item 28' If no cores tal~e~,~ndicate ~'none". Form 10-407 ADDENDUM 12/23/84 2T-4 Frac'd Kuparuk "A" sand perfs 7805'-7809', 7816'-7824', 7824'-7855' & 7876'-7890' in six stages per 12/18/86 procedure using diesel, gel diesel, Musol, 20/40 mesh sand. Press'd ann to 2750 psi w/diesel. Tst Ins to 8000 psi; OK. Pmp'd by Production: Stage 1: 30 bbls diesel w/5% Musol, 2 BPM, 3000 psi Stage 2: 42 bbls diesel, 1.75 BPM, 3000 psi Pmp'd by Drilling Stage 3: 12 bbls gelled diesel pad @ 5 BPM, 2960 psi Stage 4: 12.5 bbls gelled diesel, 10 ppg 20/40 sand @ 5 BPM, 2640 psi Stage 5: 20 bbls gelled diesel flush @ 5 BPM, 2700 psi (inc'd rate to 20 BPM last 5 bbls) Stage 6: 22 bbls gelled diesel, 20 BPM, 6680 psi final press. Pmp'd 2992# 20/40 mesh sand in formation, leaving 576# 20/40 mesh sand in csg. Load to recover 136 bbls of diesel/gelled diesel. Jo~ complete @ 10:09 hrs, 12/23/86. Drilling Shpervisor D'~te SUB-SURFACE DIRECTIONAL SURVEY r~ UIDANCE I'~ ONTINUOUS I"~ OOL Company Well Name Field/Location ARCO ALASKA, INC. 2T-4 (352'FSL & 556'FWL, SEC.1,TllN,R8E,UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No, 72069 Lo{3~ed By: RUBENSTEIN Date · 10/21/86 Computed By: KRUWELL OCT glRECTI,3NAL SURVEY CUST~}MER LISTING ARCO ALASKA~, .,.NC, 2T-4 KUPARUK NORTH SLCPE,ALASKA SURVEY DATE: 21-0CT-86 :_NGINE'ER: RUSENSTEIN METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION ANO AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. gIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 77 OEO 54 MIN WEST GCT DIRECTIONAL SURVEY CUSTOMER LISTING F g R ARCO ALASKA, INC. 2T-4 KUPARUK N~RTH SLOPE~ALASKA SURVEY DATE: 21-0CT-86 ENGINEER: RU]ENSTEIN METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH O~ NORTH 77 DEG 54 MIN WE.ST COMPOTATION DATE: 19-NOV-85 PAGE 1 ARCO ALASKA, INC. 2T-4 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE MEASURED VERTICAL DEPT~ DEPTH SUB-SEA COURSE VERTICAL DEVIATION AZIMUTH DEPTH DEG MIN DEG MIN 0.00 0.00 100.00 100.00 200.00 200.00 300.00 299.99 400,00 ~ 399,99 500.00 499.99 600.00 599.99 700.00 699.93 800.00 799.64 900.00 898.79 -117.00 0 0 N O 0 E -17.00 0 20 N 76 15 E 83.00 0 18 N 68 7 E 182.99 0 16 N 37 46 E 282.99 0 13 N 3 38 W 382,99 0 11 N 67 47 W 482.99 1 0 N 73 15 W 582.93 2 55 N 79 40 W 682,64 5 51 N 82 10 W 781,79 8 37 N 78 25 W 1000.00 997.11 1100.00 1094.41 1200.00 1190.86 1300.00 1286.09 1400.00 1379.97 1500.00 1472.21 1600,00 1562,73 1700,00 1651,58 1800,00 1738,29 1900.00 1822.78 380.11 11 58 N 73 52 W 977.41 14 25 N 77 11 W 1073.86 16 27 N 80 19 W 1169.09 18 59 N 81 39 W 1262.97 21 22 N 80 19 W 1353.21 23 59 N 79 13 W 1445,73 26 10 N 78 44 W 1534.58 28 33 N 78 16 W 1621,29 31 4 N 77 35 W 1703.78 33 38 N 76 53 W 2000,00 1905.17 2100,00 1986,54 2200,00 2066,04 2300.00 2143,29 2400,00 2217,32 2500.00 2287,86 2600.00 2354.82 2700,00 2418,77 2800,00 2481.45 2900.00 2543.51 1788.17 34 58 N 76 11 W 1869.54 36 2! N 75 32 W 1949,04 38 19 N 74 57 W 2026.29 40 42 N 74 47 W 2100,32 43 43 N 75 9 W 2170.86 46 36 N 75 1 W 2237.82 49 11 N 74 14 W 2301.'77 50 55 N 74 1 W 2364,45 51 22 N 74 3 W 2426.51 51 50 N 73 50 W 3000.00 2605.32 3100,00 2667.82 3200,00 2730,49 3300,00 2792,96 3400.00 2855.51 3500.00 2918.38 3600,00 2982.15 3700.00 3046.39 3800.00 3109.99 3900,00 3170,68 2488,32 51 34 N 73 34 w 2550,82 51 11 N 72 32 W 2613.49 51 13 N 72 29 W 2675.96 51 19 N 72 18 W 2738,51 51 18 N 72 30 W 2801.38 50 37 N 72 23 W 2865.15 50 9 N 72 3 W 2929,39 49 57 N 71 26 W 2992.99 51 46 N 64 55 W 3053.68 53 7 N 61 29 W DATE OF SURVEY: 21-CCT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: RUEENSTEiN EVEN 100 FEET DF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COD SECTION SEVERITY NORTH/SSUTH EAS FEET DEG/IO0 FEET FE ROINATES HORIZ. T/WEST DIST. ET FSET DEPARTURE AZIMUTH DEG MIN 0.00 O.O0 0.00 N -0.58 0.64 0.05 N -1.05 0.65 0.25 N -1.34 0.16 0.57 N -1.39 0,20 0.97 N -1.18 0,14 1.24 N -0.37 1.45 1,56 N 2.75 2.22 2.23 N 10,26 3,48 3.38 N 23.15 2.79 5.44 N 0,00 E 0.00 0.60 E 0.60 1.13 E 1.16 1,49 E 1.59 1,63 E 1,90 1.47 E 1.92 0.72 ~c 1.71 2.33 W 3.23 9.76 W 10.33 22,51 W 23.16 N 0 O E N 85 7 E N 77 23 E N 69 3 E N 59 13 ' N 49 59: N 24 41 ~ N 46 13 W N 70 54 W N 76 24 W 41.32 3,38 9,65 N 64,35 1,58 13.16 N 90.73 2.52 20,42 N 121,16 2.28 24.88 N 155.52 3.41 30.28 N 1'94,11 2,74 37,14 N 236.59 2.06 45.31 N 282.43 2.48 54.42 N 332.23 2,45 64,86 N 385.70 2,56 76.63 N 40,19 W 41.33 N 76 30 W 62,56 W 64,37 N 76 22 W 88,*1' W 90,74 N 76 59 W 118.58 W 121.16 N 78 9 W 152.56 W 155.54 N 78 46 W 190.56 W 1'94.15 N 78 58 W 232.25 W 236.63 N 78 57 W 277.18 W 282.47 N 78 53 W 325.87 W 332.26 N 78 44 W 378.04 W 385.72 N 7B 32 W 442.35 0.78 89.83 N 500.43 1.99 104.05 N 561.01 1.SI 119.50 N 624.40 2.97 136.18 N 691.52 2.90 153.58 N 762.30 2.74 171.69 N 836.44 2,58 191.41'N 913,14 0,81 212,53 N 990,87 0.52 233.94 N 1069.11 0.36 255.60 N 433,15 W 442,36 N 78 17 W 489,50 W 500,43 N 77 59 W 548.14 W 561,01 N 77 42 W 60~.40 W 624,43 N 77 24 W 574.31 W 691.58 N 77 10 W 742,82 W 762.40 N 76 59 ~> 814.41 W 836.60 N 76 46 I.. 888.32 W 913,39 N 76 32 W 963,24 W 991,24 N 76 20 W 1038,60 W 1069,59 N 76 10 W 1147,50 0.60 277.64 N 1225,31 0.73 300,09 N 1302,90 0.19 323.40 N 1380.63 0,74 347,05 N 1458,30 0.33 370.60 N 1535.72 0.87 393.97 N 1612.36 0,61 41'7,51 N 1688.58 1,57 441.32 N 1764,71 6,22 469,10 N 18.41.37 1,79 505.66 N 1114.05 W 1148.13 N 76 0 W 1188.82 W 1226.11 N 75 49 W 1263.17 W 1303.92 N 75 38 ~ 1337,60 W 1381.89 N 75 27 W 1411.98 W 1459.81 N 75 17 W 1486.15 W 1537.48 N 75 9 W 1559.49 W 1514.41 Fi 75 0 W 1632,34 W 1690.95 N 74 52 W 1704,24 W 1767,62 N 74 36 W 1774,80 W 1845.43 N 74 5 W COMPUTATION DATE: 19-NOV-86 PAGE 2 ARCO ALASKA, INC. 27-4 KUPARUK N3RTH SLOPE,ALASKA TRUE MEASURED VERTICAL DEPTH DEPTh ~000.00 3230.59 4100.00 3291.37 4200.00 3352.84 4300.00 3414.17 4400.00 3475.37 4500.00 3538.06 4600.00 3602.54 4700.00 3668.39 4500.00 3735.46 4900.00 3802.64 5000.00 3669.77 5100.00 3937.02 5200.00 4004.53 5300.00 4072.08 5400.00 4139.76 5500.00 420~.71 5600.00 4279.23 5700.00 4350.39 5800.00 4421.98 5900.00 4493.86 6000.00 4565.91 6100.00 4638.19 6200.00 4710.63 6300.00 4782.99 6400.00 4855.41 6500.00 4928.04 6600.00 5000.62 6700.00 5073.85 6800.00 5147.23 6900.00 5220.71 7000.00 5294.35 7100..00 5368.46 7200.00 5442.93 ' ~7300.00 5517.61 17400.00 5.592.75 __~L~'~$ 00.00 566a.58 7600.00 5745.59 7700.00 5825.57 780'0.00 5908,72 7900.00 5992.80 INTERPOLATED VA LUES FOR EVeN 100 FEET SUn-SEA COURS~ VERTICAL DEVIATION AZIMUTH DEPTH DEG MIN DEG MIN 3113.59 52 54 N 61 4 W 3174.37 52 16 N 64 9 W 3235.84 52 1 N 67 14 W 3297.17 52 20 N ?0 21 W 3358.37 51 52 N 73 50 W 3421,05 50 26 N 77 3 W 3485,54 49 17 N 80 39 W 3551.39 48 20 N 83 37 W 3618.46 47 38 N 87 19 W 3685.64 47 54 S 89 31 W 3752,77 47 46 S 85 35 3520,02 47 37 S 87 53 3837,53 47 29 S 87 15 3955.08 47 30 S 86 36 4022.76 47 4 S 86 21 4091,71 45 44 $ 87 1 4162,23 4~ 49 S 88 25 4233.39 44 24 S 89 51 4304,98 44 10 S 89 ~8 4376.86 43 57 S 89 33 DATE OF SURVEY: 21-0CT-86 KELLY BUSHING ELEVATION: llT.O0 FT ENGINEER: RUBENSTEIN MEASURED DEPTH VERTIC&L DOGLEG RECTAN S~CTION SEVERITY NORTH/ FE~T DEG/IO0 FEE 1917.95 1.10 544. 1994.40 3.53 581. 2071.56 1.86 613. 214'9.50 3.09 642, 2228.17 2,94 666. 2305.99 3.26 686. 2382.40 2.94 700. 2457,43 2,38 711, 2530.95 3.01 717, 2603.58 1.15 718. W 2675,76 0,58 W 2747,61 0,52 W 2819,03 0,52 W 2890,19 0,47 W 2961.05 !.20 W 3030.86 1.60 W 3099.50 1.28 W 3167,99 0,82 W 3236.28 0.50 W 3304.20 0.40 4448,91 43 48 S 88 56 W 3371,82 0,57 4~2!,19 43 38 S 88 22 W 3439,03 0,49 4593.53 43 35 S 37 42 W 3505.90 0.61 4665,99 43 39 $ 87 0 W 3572,64 0,53 4738,41 43 30 S 86 19 W 3539,12 0,51 4811,04 43 26 S 85 35 N 3705,1~ 0,58 4883,62 43 15 S 85 0 W 3770,95 1,01 4956.85 42 ~'9 S 87 13 W 3836,38 1,50 5030,23 42 ~3 $ 87 58 W 3902,23 0,42 5103.71 42 38 S 87 25 W 3967.92 0.43 5177,35 42 25 S 86 55 W 4033,29 5251,46 42 0 S 86 13 W 4098,00 5325.93 41 44 S 85 33 W 4162.09 5400,61 41 32 S 84 52 W ~4225.72 ',"~288 65 5475,75 40 59 S 84 18.W v 5551.58 ~0 18 S 85 21 W 350~73 5628.59 386~34 N 88.?48 W~7%4i2 53 5708.57¢ 34,:':~',':,,56 N 8131'39 W~,".:'&!'i'~471~96 5791 72~0 33.1~. 7 N 767.~.57 W;~'~'4527'48 5875~8 32,",!',,27 N 74? 5 W)?,',q~:4581.56 0.69 0.58 0.53 0,74 0.95 2,60 5.69 5.14 1.91 2.03 GULAR COORDINATES HORIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN 53 N 1844,79 W 1923,48 N 73 33 W 48 N 1915,06 W 2001,39 N 73 6 W 61 N 1987,09 W 2079,67 N 72 50 W 39 N 2060.62 W 2158,43 N 72 41 59 N 2135,90 W 2237,50 N 72 40 28 N 2211,26 W 2315,31 N 72 94 N 2286,26 W 2391,30 N 72 16 N 2360,81 W 2465,60 N 73 14 N 11 N 2434,72 W 2538,13 N 73 35 W 19 N 250~,77 W 2609,55 N 74 1 W 716,87 N 2582,88 W 2680,51 N 74 29 W 714,58 N 2656.84 W 2751,26 N 74 56 ~ 711,47 N 2730,56 W 2821,72 N 75 23 W 707.51 N 2804.18 W 2892.06 N 75 50 W 702,84 N 2877,65 W 2962,24 N 76 16 W 698,63 N 2949,96 W 3031.56 N 76 40 W 695,67 N 3020.79 W 3099,86 N 77 1 W 694,74 N 3091,04 W 3168,15 N 77 19 W 694,84 N 3160,85 W 3236,32 N 77 36 W 69~,56 N 3230,38 W 3304,20 ~ 77 51 W 593.69 N 3299.72 W 3371.84 N 78 7 W 692.05 N 3368.80 W 3439.15 N 78 23 W 689.72 N 3437.70 W 3506,21 N 78 39 W 686,52 N 3506,64 W 35'73,21 N 73 55 W 682,50 N 3575,49 W 35~0,04 N 79 11 W 677,65 N 3644,05 W 3706.52 N 79 27 .'~ 671,86 N 3712,60 W 3772,90 N 79 44 ~, 667,12 N 3780,53 W 3833.94 N 79 59 W 664,62 N 3848,41 W 3905,38 N 80 12 W 661,89 N 3916,18 W 3971,72 N 30 2~ W 658,56 N 3983,75 W 4037,82 N 80 36 W 654,59 N 4050,78 W 4103.33 N 80 4'9 W 649,80 N 4117,35 W 4168,32 N 81 1 W 644,26 N 4183,62 W 4232,93 N 81 14 W 638,03 N 4249,31 W 4295,95 N 81 27 W 631,61 N 4314,18 W 4360,17 N B1 40 W 629.27 N 4377.89 W 4422,88 N 81 49 W 634,13 N 4437,62 W 4482,70 N gl 52 W 544,91 N 4492.09 W 4538,15 N 81 49 W 658,36 N 4544,52 W 4591.96~ N 81 45 W COMPUTATION D~TE: 19-NOV-SS PA~;E 3 ARCO ALASKA, INC. 2T-4 KUPARUK NORTH SLOPE,ALASKA gATE OF SURVEY: 21-0CT-85 KELLY BUSHING ELEVATION: 117.00 ~T ENGINEER: RUEEtNSTEIN ZNTERPSLATED VALUES FSR EVEN 100 FEET D~ MEASURED DEPTH' TRUE SUB-SEA M~ASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8000.00 6077.67 5960.67 8100.00 6163.00 604~.00 8160.00 6214.20 6097.20 COURSE VERTICAL DsVIATiON AZIMUTH SECTION DEG MIN DEG MIN FEET DOGLE,S RECTA. NGULAR SEVEqlTY NORTH/SOUTH 9EG/IO0 FEET COORDINATES EAST/WEST HORIZ. DEPARTURE gIST. AZIMUTH FEET DEG 31,'"25 N 68.SS53 Wo~Ii,~$'~ 634.11 31, "~2 5 N 68~'i~53 7.80 574.99 0.00 693.77 0.00 705.04 N 4594.70 N 464B.35 N 4672.53 4644.02 N 81 38 W 4694.89 N :~1 30 ~ 4725.42 N 81 25 ,~ COMPUTATION DATE: 19-NOV-86 PAGE ARCO ALASKA, INC. 2T-4 KUPARUK NORTH SLOPE,ALASKA DATE DF SURVEY: 21-0CT-86 KELLY SUSHING ELEVATION: 117.00 FT ENGINEER: RUBENSTEIN TRUE MEASURED VERTICAL DEPTH DEPTH INTERPOLATED VALUE. S FOR EVEN 1000 FEET OF MEASURED DEPT VERTICAL DOGLEG RECTANGULAR CO SECTION SEVERITY NDRTd/S2UTH EA FEET DEG/IO0 FEET F 0.00 0.00 1000.00 997.11 ZO00.O0 1905.17 3000.00 2605.32 4000.00 3230.59 5000.00 3869.77 $000.00 4565.$1 7000.00 5294.'35 8000.00 6077.67 8160.00 6214.20 SUB-SEA COURSE VERTICAL DEVIATION AZIMUT~ DEPTH DEG MIN DEG MZN 0.00 0.00 O.OO N 41.32 3.38 9.65 N 4 442.35 0.78 89.83 N 43 1147.50 0.60 277.54 N 111 1917.95 1.10 544.53 N 184 2575.76 0.58 716.87 N 258 3371.82 0.5'7 693.59 N 329 4033.29 0.69 658.55 N 398 4,534.11 7.80 674.99 N 459 4716.51 O.00 705.04 N 467 -117.00 0 0 N 0 0 E 880.11 11 58 N 75 52 W 1788.17 34 58 N 76 11 W 2488.32 51 34 N 73 34 W 3113.59 52 54 N 61 4 W 3752.77 47 46 S 88 35 W 4448.91 43 48 S 88 56 W 5177.35 42 25 S 86 55 W 5960.67 31 25 N 68 53 W 6097.20 31 25 N 68 53 W OROiNATES HORIZ. DEPARTURE ST/WEST DIST. AZIMUTH EET FEET DEG MIN 0.00 E 0.00 N 0 0 E 0.19 ~ 41.33 N 76 30 W 3.15 W 442.36 N 78 17 W 4.05 W 1148.13 N 76 0 W 4.79 W 1923.48 N 73 33 TM 2.88 W 2680.51 N 74 29,i~ 9.72 W 3371.84 N 78 7 3.75 W 4037.82 N 80 36 ~ 4.70 W 4644.02 N ~1 32 W 2.53 W 4725.42 N ~1 25 N COMPUTATION DATE: 19-NOV-86 PAGE 5 ARCO ALASKA, INC. 27-4 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EV'EN 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -117.'00 17.00 17.00 -100.00 117.00 117.00 0.00 217,00 217.00 100.00 317.01 317.00 200.00 417.01 417,00 300.00 517.01 517,00 400,00 617.01 617.00 500.00 717.09 717.00 600.00 817.47 817.00 700.00 918.45 917.00 800.00 1020.36 1017.00 900.00 1123.34 1117.00 1000.00 1227.30 1217.00 1100.00 1332.77 1317.00 1200.00 1439.92 1417.00 1300.00 1549.28 1517.00 1400.00 1660.81 1617.00 1500.00 1775.19 1717.00 1600.00 1893.08 1817.00 1700.00 2014.44 1917.00 1800.00 2138.00 2017.00 1900.00 2265.59 2117.00 ZO00.O0 2399.56 2217.00 2100.00 2542.88 2317.00 2200.00 2697.20 2417.00 2300.00 2857.15 2517.00 2400.00 3018.74 2817.00 2500.00 3178.47 2717.00 2600.00 3338.34 2817.00 2700.00 3497.82 2917.00 2800.00 3654.25 3017'.00 2900.00 3811.45 3117.00 3000.00 3977.39 3217.00 3100.00 4141.77 3317.00 '3200.00 4304.64 3417.00 3300.00 4466.7'7 3517.00 3400.00 4622.15 3617.00 3500.00 4-772.61 3717.00 3600.00 4921.42 3817.00 3700.00 COURSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MIN FEET OEO/lO0 0 0 N 0 0 E 0.00 O. O0 0 30 N 43 28 E 0.00 0.00 0 19 N 62 44 E -0.66 0.45 0 15 N 54 49 E -1.12 0.30 0 15 N 31 $ E -1.37 0.22 0 12 N 9 48 W -1.37 0.09 0 13 N 65 0 W -1.12 0.40 1 12 N 74 41 ~ -0.04 0.87 3 18 N 80 11 W 3.67 2.51 6 28 N 82 7 W 12.13 3.58 9 28 N 77 35 W 26.09 3.28 12 37 N 75 47 W 45.67 2.80 14 44 N 77 36 W 70.23 1.36 17 9 N 81 24 W 98.60 3.00 1'9 42 N 81 13 W 132.00 2.19 22 23 N 79 55 W 170.42 2.39 25 7 N 78 54 W 214.66 2.03 27 34 N 78 29 W 264.00 2.63 30 27 N 77 43 W 319.51 Z.3i 33 ZT N 76 56 W 381.90 2.57 35 6 N 76 5 W 450.64 1.05 37 7 N 75 18 W 523.13 2.18 39 46 N 74 44 W 602.25 2.58 43 42 N 75 9 W 691.23 2.90 47 43 N 74 40 W 793.71 2.61 50 53 N 74 1 W 910.97 0.85 51 40 N 73 56 W 1035.52 0.55 51 28 N 73 29 W 1162.12 0.66 51 12 N 72 31 W 1286.20 0.07 51 15 N 72 24 W 1410.36 0.44 50 38 N 72 23 W 1534.04 0.88 50 1 N 71 53 W 1553.71 0.33 51 58 N 64 20 W 1773.48 5.02 53 3 N 60 55 W 1900.68 0.76 52 4 N 65 45 W 2026.55 2.62 52 20 N TO 32 W 2153.14 3,04 50 54 N 75 57 W 2280.30 2.81 4'9 2 N 81 26 W 2399.16 2.77 47 42 N 86 13 W 2510.95 3.02 47 53 S 89 14 W 2619.08 0.81 DATE OF SURVEY: 21-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: RUBENSTEIN SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 0.00 N 0.00 E 0.00 N 0 0 E 0.00 N 0.00 E 0.00 N 90 0 E 0.09 N 0.69 E 0.70 N 82 46 E 0.30 N 1.21 E 1.24 N 76 12 0.63 N 1.53 E 1.66 N 67 31 1.03 N 1.62 E 1.92 N 57 31,, 1.26 N 1.42 E 1.90 N 48 1.65 N 0.39 E 1.70 N 13 25 2.39 N 3.24 W 4.03 N 53 33 3.64 N 11.63 W 12.18 N 72 38 W 6.06 N 25.39 W 26.10 N 76 35 W 10.71 N 44.41 W 45.69 N 76 26 W 16.44 N 68.30 W 70.25 N 76 28 W 21.67 N 96.19 W 98.60 N 77 18 W 26.50 N 129.32 W 132.00 N 78 25 W 32.82 N 167.26 W 170.45 N 78 53 W 41.06 N 210.73 W 214.69 N 78 58 W 50.71 N 259.13 W 264.04 N 78 55 W 62.14 N 313.45 W 319.55 N 78 47 ~ 75.77 N 374.33 W 381.92 N 78 33 W 91.82 N 441.19 W 450.65 N 78 14 W 109.77 N 511.48 W 523.13 N 77 53 W 130.33 N 587.99 W 602.26 N 77 30 W 153.51 N 674.02 W 691.28 N 77 10 W 179.89 N 773.18 W 793.83 N 76 54 W 211.93 N 886.23 W 911.22 N 76 33 !~' 246.26 N 1006.25 W 1035.95 N 76 14 I:~ 281.81 N 1128.11 W 1162.78 N 75 58 W 318.36 N 1247.17 W 1287.16 N 75 40 W 356.11 N 1366.06 W 1411.71 N 75 23 W 393.47 N 1484.54 W 1535.80 N 75 9 W 430.38 N 1599.02 W 1655.93 N 74 56 W 473.14 N 1712.34 W 1776.51 N 74 33 W 535.74 N 1829.01 W 1905.86 N 73 40 W 595.38 N 1944.96 W 2034.05 N 72 58 W 643.59 N 2064.09 N 2162.10 N 72 40 W 680.18 N 2186.29 W 2289.66 N 72 43 ~ 703.63 N 2302.82 W 2407.92 N 73 0 W 715.98 N 2414.51 W 2518.43 N 73 28 W 718.00 N 2524.67 W 2624.78 N 7~ 7 W ARCO ALASKA, INC. 27-4 KUPARUK NORTH SLOPE,ALASK~ COMPUTATIDN DATE: 19-NOV-86 INTERPOLATED VALUES FOR ~VEN 100 FEET OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG 5070.31 3917.00 3800.00 47 42 S 88 5 W 5218.46 4017.00 3900.00 47 29 S 87 7 W 5366.45 4117.00 4000.00 47 20 S 86 19 W 5511.90 4217.00 4100.00 45 34 S 87 7 W 5653.18 4317.00 4200.00 44 37 S 89 16 W 5793.05 4417.00 4300.00 44 11 N 89 59 W 5932.13 4517.00 4400.00 43 55 S 89 23 W 6070.70 4617.00 4500.00 43 41 S 83 32 W 6208.80 4717.00 4600.00 43 36 S 87 38 W 5346.99 4817.00 4700.00 43 36 S 86 40 W 6484.80 4917.00 4800.00 43 24 S 85 42 W 6622.44 5017.00 4900.00 43 3 S 85 22 W 6758.82 5117.00 5000.00 42 46 S 88 1 W 6894.95 5217.00 5100.00 42 39 S 87 27 W 7030.64 5317..00 '5200.00 42 14 S 86 45 W 7165.23 5417.00 5300.00 41 50 S 85 47 W 7299.18 5517.00 5400.00 41 32 S 84 52 W 7432.08 5517.00 5500.00 40 ~5 S 84 13 W 7563.14 5717.00 5600.00 39 28 S 88 34 W 7689.46 5817.00 5700.00 35 19 N 82 23 W 7809.88 5917-00 5300.00 33 2 N 76 39 W 7928.64 6017.00 5900.00 32 10 N 72 45 W 8046.09 6117.00 6000.00 31 25 N 68 53 W 8160.00 6214.20 6097.20 31 25 N 68 53 W VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 P AGE 5 DATE OF SURVEY: 21-0CT-86 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: RUSENSTEIN SUB-SEA DEPTH RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST FEET FEET 2726.35 0.83 713.37 N 2534.93 W 2832.18 0.55 710.80 N 2744.15 W 2937.34 0.65 704.45 N 2853.05 W 3039.11 1.77 698.17 N 2958.49 W 3135.95 1.16 694.96 N 3055.21 W 3231.54 0.46 694.83 N 3156.00 W 3325.95 0.42 694.36 N 3252.67 W 3419.36 0.30 692.59 N 3348.58 W 3511.77 0.56 689.46 N 3443.76 W 3603.92 0.47 684.73 N 3539.02 W 3695.13 0.47 3785.61 1.75 3875.10 0.25 3964.61 0.43 4053.21 0.64 4139.87 0.51 4225.20 0.73 4308.63 1.04 4389.80 4.60 4465.84 5.30 678.44 N 3533.64 670.53 N 3727.88 655.56 N 3820.46 662.04 N 3912.77 657.43 N 4004.36 651.54 N .4094.25 644.31 N 4183.07 635.91 N 4270.20 629.35 N 4354.63 633.38 N 4431.53 HORIZ. DIST. FEET DEPARTURE AZIMUTH D:G MIN 2730.32 2834.71 2938.74 3039.75 3136.18 3231.59 3325,96 3419.45 3512.10 3604.65 N 74 48 W N 75 28 W N 76 7 W N 76 43 W N 77 11 N 77 N 77 56 .. N 78 18 W N 78 40 W N 79 2 W 4532.87 1.78 646.i3 N 4497.34 W 4596.82 2.92 652.73 N 4559.19 W 4657.85 0.00 683.65 N 4617.12 W 4716.51 0.00 705.04 N 4672.53 W 3595.43 3787.70 3878. O0 3968.38 4057.97 4145.77 4232.40 4317.29 4399.87 4476.56 N 79 25 W N 79 48 W N 80 7 W N 80 23 W N 80 40 W N 80 57 W N 81 14 N N 81 31 W N 51 46 W N 81 51 W 4543.52 4607.11 4667.46 4725.42 N 81 49 W N 51 43 W N 51 34 W N 81 25 N ARCO ALASKA, INC. 2T-4 KUPARUK NORTH SLaPE,AL~SKA TOP BASE TOP 5~SE PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A COMPUTATION INTERPOLATED VALUES FOR MEASURED DEPTH BELOW K5 7739.00 7760.00 7799.00 7959.00 8067.00 8160.00 DATE: 19-NGV-86 CHOSEN HORIZONS FROM KS 5857.81 5875.30 '5907.88 6042.74 6134.84 6214.~0~ ~RIGIN: TVD P~,3E 7 DATE OF SURVEY: 21-0CT-86 KELLY BUSHING ELEVATION: 117.00 ENGINEER: RUBENSTEIN 352 FSL, 556 SU'B- SE,~ 5740.81 5758.30 5790.88 5925.74 6017.84 6097.20 FWL R~.C NO SURFACE LOCATION AT , SEC 1, TllN, RSE, UM TANGULAR COORDINATES RTH/SOUTH EAST/WEST 637.84 N 4459.26 W 640.17 N 4470.64 W 644.78 N 4491.56 667.69 N 4574.51 WI 687.57 N 4627.29 705.04 N 4672.53 W ,¢-T COMPUTATION DATE: 19-NOV-S6 PAGE 8 ARCO ALASKA, INC. 2T-4 KUPARUK NORTH SLGPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MEASURED DEPTH BELOW KB 7739.00 7760.00 7799°00 7959.00 8067.00 8160.00 SUMMARY FROM KB 5837.81 5875.30 5907.8~ 6042.74 6134.84 6214.20 DATE OF SURVEY: 21-0CT-36 K~LLY BUSHING ELEVATION: 117.00 FT ENGINEER: RUBENSTEIN ORIGIN= 352 TVD SUB-SEA FSL, 556 SU FWL, RECTA NORT RF&CE LOCATION ~T SEC 1, TllN, RBE, NGULAR COORDINATES H/SOUTH EAST/WEST 5740.81 5758.30 5790.88 5925.74 6017.84 6097.20 64 64 66 68 7O 7.84 N 4459.26 W 0.17 N 4470.6, W 4.78 N 4~91.56 W 7.69 N 4574.51 Wi 7.57 N' 4627.29 W' 5.04 N 4672.53 W PINAL MEASURED DEPTH WELL LOCATION TRUE 'VERTICAL DEPTd .AT TD: SU6-SEA VERTICAL DEPTH HORI=ONTAL~ D~PARTURF_ _ DISTANCE AZIMUTH FEET DEG M!N 8160.00 6214.20 6097.20 4725.42 N 81 25 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2T-4 F ! ELD KUPARUK COUNTRY USA RUN DATE LOOOED 21 - OCT - 86 REFERENCE 72069 WELL: 2T-4 (352'FSL & 556'FWL, SEC.1,TllN,R8E,UM) HORIZONTAL PROJECTION NORTH 4000 3000 ~000 ! 000 - 1000 -ZOO0 -9000 SOU~H -4000 -6000 NEST REF 7Z069 SCALE = i/lO00 IN/FT -5000 -4000 -:9000 -ZOO0 - 1000 0 1000 ZOO0 EAST ~% <' -" '" . U,'~ ] 0 f'., :- -'' Alaska WELL: 2T-4 (352'FSL & 556'FWL, SEC.1,TllN,R8E,UM) VERTICAL PROJECTION 102. -2000 - 1000 0 0 1000 ZOO0 9000 4000 5000 6000 ZSZ. PROJECTION ON VERTICAL PLANE 282. - 102. SCALEO IN VERTICAL OEPTH.S HORIZ SCALE = 1/1000 IN/FT ARCO Alaska, Inc. Post Office Box 10036~ Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5855 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals (blueline unless specified otherwise)' 3K-L~5'° FDC Raw 8-12-86 4604-9241 5" FDC Porosity 8-12-86 4604-9241 "~'~2" DIL 8-12-86 1000-9266 2" FDC Raw 8-12-86 4604-9241 ~2" FDC Porosity 8-12-86 4604-9241 ~5" DIL 8-1~-86 1000-9266 ~Cyberlook?/8-12-86 8650-9110 2T-4~~C porosity 8-12-86 7500-8014 "-~2~D~ 8-12-86 7500-8044 '"'~2'~F{3C Raw 8-12-86 7500-8014 ...o~,,~i.F~Dc Porosity 8-12-86 7500-8014 ~F~C(in casing) 8-12-86 '1000-7526 Raw 8-12-86 7500-8014 ~ 5'~/DIL 8-12-86 7500-8044 ~ 5JGR (in casing) 8-12-86 1000-7526 Receipt Acknowledged' Alaska Oil & Gas Gon~. Commission //AI~ Anchorage Date' Distribution' NSK Drilling Rathmell D&M State of Alaska (+ sepia) Vault (film) Johnston (ven. pkg) ARCO AIr, ska. Inc. is a Subsidiary of AllanlicRJchfieldCompany ...... STATE OF ALASKA - ALASKA AND GAS CONSERVATION COMMIS. JN REPORT OF SUNDRY WELL OPERATIONS Operations performed' Operation shutdown ~ Stimulate ~ Plugging ~- Perforate X~ .... Pull tubing Alter Casing ~ Other COMPLETE 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 352' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 990' FSL, 1377' FWL, Sec. 2, T11N, RSE, UM At effective depth 1040' FSL, 1209' FWL, Sec. 2, TllN, RSE, UN At total depth 1057' FSL, 1163' FWL, Sec. 2, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 117' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 9T-~ 8. Approvalnumber 328 9. APInumber 50-- 103-20074 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3260' feet 8160'MD feet 621 4 ' TVD 8067'MD 6135 ' TVD Size Plugs (measured) N o n e feet Junk (measured) feet N o n e Production 7528' Liner 804 ' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Cemented Measured depth 16" 242 sx CS I I 9-5/8" 875 sx AS II I & 345 sx Class G Top job w/lO0 sx AS 7" 425 sx Class O 5" 122 sx Class G 7745' - 7756'MD 7816' 7805' - 7809'MD 7824' 5863' - 5872'TVD 5922' 5913' - 5917'TVD 5929' Wue Verticaldepth 115'MD 115'TVD 3292'MD 2788'TVD 7556'MD 5712'TVD 7351'-8155'MD 5556'-621 - 7824'MD 7876' - 7855'MD - 5929'TVD 5973' - 5955'TVD 2-7/8"/2-3/8", J-55, tbg w/tail ~ 7776' Packers and SSSV(type and measured depth) HB-1 pkr ~ 7185', DB pkr ~ 7755', & TRDP-1A-SSA SSSV ~ 1765' - 7890'MD - 5985'TVD RECEIVED 12. Stimulation or cement squeeze summary N/ Intervals treated (measured) Alaska 0il & Gas Cons. C0mmissi 13. Treatment description including volumes used and final pressbre Anchorage Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcr Water-Bbl Casing P----r-mess~t.~ ~ ~!~'~Jbi~g'Pressu'ie Prior to well operation Subsequent to operation (Compl e~on Well Daily Report of Well Operations ~'~ History) Copies of Logs and Surveys Ruq~ ' .G.~',o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10.404 Rev. 12-1-85 (~ Associate Engineer Title Date / ~__.,.'~, (DAH) SWO/Izl Submit in Duplicate 'TVD )n 14. Attachments ARCO Oil and Gas Company Well History- Initial Report - Daily Inalm¢florl,: 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 .' -~;~:: :~ 'lcounty' parish or borough . ' Alaska ~i/!i!~'.".:{./ . North Slope Borough R~Jd-:-: . .- . ..... /itea~e or Unit '- -~- -KUpam'uk River:- · -' [ ADL 25569 ! Aura. ~r~.O~o. - .... /:' I'rm, ~i:'-:~ j.;..~ A][07t5: :: - -'- I Completion '-:::.:: ~.'?:N°~d~./]~- '- -::_:U'_ --.- kP[ 50-103-20074 0Pe. rator. ~-:-_ .~. _ . : _ -.~_-.~: __ ARCO -ilaska~i- Inc.. I O~te.~'~,-:- ~ - Complete record for each day repoded -. - .. 10/21/86 10/22/86 10/23/86 IState Alaska I Well no. 2T-4 I Hour status If a W.O. 10/18/86 1415 hfs 56.24% 5" lnr @ 8155' - I1.0 ppg Mud 6878', POH w/wet string - Accept. ri~ @ 1415 hfs,. 10/18/86. ND tree, NU & tst BOP~' RIR w/bit & scrpr to 2000', circ out diesel Cap.. RIRw/3~,'DP, CaE. cmt @ 6845', drl cmt to TOL @ 7349', CBU. Tst TOL to 120Opsi; OK, POH. TIM w/4-1/8" bit, tag TOL @ 7349',' drl thru TOB..&Wsh to 7411' GIH w/3½" DP, tag @ 7450' bit plugged, POM;w~ · ~ · - ' ' 5" lnr @ 8155' 11.6 ppg Brine 8061' LC, CO-pits POH w/wet string. MU BHA, GIH on 3½" DP to 7430', wsh & rm f/7430'-8061', tag LC @ 8061', CBU. Tst lnr & csg to 1100 psi ok. Displ well to brine. CO mud pits. 5" lnr @ 8155' 8061' LC, Perf'g 11.6 ppg Brine Clnmud pits. RU Schl, rn CET. Rn gyro, gave bad readings, re-run. RU & peri f/7816'-7824' & 7805'-7809' @ 1SPF/90" phasing, 7876'-7890' & 7824'-7855 @ 4 SPF/90" phasing & 7745'-7756' @ ~ SPF/60" phasing. 5" 1hr ~S~5' 8061' PBTD, Rn 2-7/8" CA 11.6 ppg NaC1/NaBr Fin perf'g 7745'-7756' @ 6 SPF. Att 4.125" & 4.00" gage ring/JB rn; could not enter TOL. TIH w/4-1/8" mill, rm thru lnr top, POOH. Att gage ring/JB rn again; unable to enter TOL. RIH w/DB Pkr, set @ 7771' WLM. RU & rn 2-7/8" CA. RECEI'V"'.__ t.... J. :J 0 U Alaska Oil & 6as Co~s. Comrnissior~ Anchorage The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date I Title Drilling Supervisor 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 biocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Lease or Unit Title IAccounting cost center code State Alaska Field Alaska Kuparuk River North Slope Borough ADL 25569 IWell no. 2T-4 Auth. or W.O. no. AFE AK0715 Completion Nordic 1 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~Date I Complete Date and depth Complete record for each day reported as of 8:00 a.m. 10/24/86 API 50-103-20074 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% Jabandonment of this well IHour . IPrior status if a W.O, 10/18/86 / 1415 hrs. I / 5" f/7351'-8155' 8061' PBTD, RR /H6-'I ~.i~< ~ .Ci' :7i:~' 6.8 ppg Diesel ~ Rn 227 its, 2-7/8", 6.5#, J-55 EUE 8RD AB Mod tbg & ~5 jts, 2-3/8", 4.7#, N-80 EUE 8RD AB Mod tbg w/SSSV @ 1765',*~DB Pkr @ 7755', TT @ 7776'. Tst tbg & ann to 2500 psi; OK. ND BOPE, NU & tst tree to 250/5000 psi. Tst pack-off to 5000 psi. Displ w/diesel. RR @ 1715 hfs, 10/23/86. Aiaska Oil & O.,..s Cons. Con, mission Ar~chora~je Old TD New TD Released rig Date 1715 hrs. Classifications (oil, gas, etc.) Oil I PB Depth 10/23/86 JKind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8061' PBTD 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 ¥:----¥~ : .:~. ~_~-~,- ' ARCO Alaska. Inc. ' _ Post Office ~x 100360-,:--,: : - Anchorage, i-.:-_::-_: -:' ' ' ~ ~' .... -' - Telephone 907 276 1215 - -: ' DATE: 09-10-.86 _ : TRANSMITTAL. # 5753 .--_-' . RE:TURN ~: . Y': .'-- - - :' -' "' ARCOz-u.~.z-~'"'"'"',J.~.,~.,'"'"". :.-'---: _ AT~: Kuparuk Records Clerk ·. .. . _-~ AT() 1119 :: ... '--' '. :_-.:': - :-- ' ". . ' P.O.-Box --)-100360- ::~'_: . · _. - ' 3mchora~e '/- 3~K ~ -.99510-0360 //:__.-_:- - _ . . -: - Transmitted herewith are the following i~ems. :--': :'--' ~ ~ return one signed co~s tr~sm.i~ -. . :i'; -" Open Hole i~s TapeS~~stin~S:~chl' One of each .~ -16. 08_-19-86 Run #1 ~3K-15 08-12-86 Run #1 ~.~ 2T-6 08-21-86 Run #1 2T-4 08-12-86 Run #1 ~2T-5 09-03-86 Run #1 . · . . _- . · . Please acknowledge receipt and .; 0992.5-9606.0'~//~-.~ 'z~',,~eV ~'~,~- ~',~ ~ 0059.0-9071. 0968 0-9302 O~P~l~l~-~~T 0987 5-8235 5 0924 0-8067 0991/0-7694. ~J/~ Receipt AcknoWledged: / L//~~ ~5 1.'9.,~.. Date ARCO ll~lki, Inc. i- · Sul~,~di=ry of AlllnlicRicl'ffilld¢ompinY STATE OF ALASKA ALAb,,A OIL AND GAS CONSERVATION CON,,~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon .~ Suspend ~ Operation Shutdown ~ Re-enter suspended well -- Alter casing feet Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing- Amend order- Perforate '- Other- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 352' FSL, 556' FWL, Sec 1, T11N, R8E, UN At top of productive interval 5. Datum elevation (DF or KB) 117' RKB 6. Unit or Property name Kuparuk River I, Irlil; 7. Well number 2T-4 8. Permit number 86-143 9. APl number 50-- 103-20074 1304' FSL, 1394' At effective depth 1237' FSL, 1167' At total 1237' dF~PLt~h 1101' FWL, Sec. 2, T11N, R8E, UM (Approx) FWL, Sec. 2, T11N, R8E, UM (Approx) FWL, Sec. 2, TI~N, R8E, UN (Approx) 10. Pool ~<uparuk River Oil Pool 11. Present well condit Total depth: Effective depth: ion summary measured 8160 'MD feet true vertical 6168'TVD feet 8067 'MD measured feet 6093 ' TVD true vertical feet Casing Length Conductor 80' Surface 3260' Size 16" 9-5/8" 7" 5" Pr oducti on 7528 ' Liner 804 ' Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Plugs (measured) None Junk (measured) None Cemented Measured depth 242 sx CS II 115'MD 875 sx AS III & 345 sx Class G 3292 'MD Top job w/lO0 sx AS I 425 sx Class G 7556 'MD 122 sx Class G 7351'-8155'MD ., EIVED S E? 0 9 1986 Alaska 0ii & O,.~s C~ns. Co~nrr;ls,~ion Ai~ch.3r.-.:::je True Vertical depth 115'TVD 2788 'TVD 5709 ' TVD 5555 ' -6159 'TVD 12.Attachments Description summary of proposal [] Detailed operations program Well Hi story 13. Estimated date for commencing operation 14. If proposal was verbally approved Name approver Date approved BOP sketch 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~("~//~ :~,LO_f' ,- Title Associate Engineer Commission Use Only (DAM) $A/100 Date Conditions of approval Approved by Notify commission so representative may witness I Approval No. -? ?,' Plug integrity ~ BOP Test ~ Location clearance, _ :~=~ ,' by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Inslructions: 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 Lease parish or borough State Well County. I Alaska Alaska North Slope Borough Field or Unit no. Kuparuk River ADL 25569 2T-4 Auth. or W.O. no. ~T t e AFE AK0715 J Drill Rowan 34 API 50-103-20074 Operator IARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begUnspudded IDate 8/1/86 [Hour 1730 hrs. IPri°rstatusilaW'O' Date and depth as of 8:00 a.m. 56.24% 8~02~86 thru 8/04/86 8/o5/86 8/06/86 8/07/86 Complete record for each day reported 16" @ 115' 3317', (3202'), Cmt 9-5/8" Wt. 9.9, PV 22, YP 21, PH 9.5, WL 6.7, Sol 12 Accept ri~ @ 1230 hrs, 8/1/86. NU diverter sys. Spud well @ 1730 hrs, 8/1/86. Drl to 618', DD & surv 12¼" hole to 3317', 10 std short trip, CBU, POOH. RU & rn 182 jts, 9-5/8" 36#, J-55 BTC csg to 3292'. Prep to cmt. 558', .7*, N84W, 557.99 TVD, 1VS, iN, 1W 1197', 16.6°, N80W, 1188 TVD, 94 VS, 20N, 92W 1657', 27.7*, N78.8W, 1613 TVD, 267 VS, 53N, 262W 2536', 48*, N73.4W, 2309 TVD, 979 VS, 195N, 773W 2944', 51.9', N73.2W, 2572 TVD, 1108 VS, 284N, 1072W 3277', 51.6°, N71.1W, 2778 TVD, 1368 VS, 365N, 1321W 9-5/8" @ 3292' 3791', (474'), Drlg Wt. 9.6, PV 14, YP 7, PH 9, WL 7, Sol 6 Cmt 9-5/8" w/875 sx AS III & 345 sx C1 "G" w/2% S-i, .2% D-46. Displ using rig pmps, bump plug. ND 20". Perform 100 sx AS I top job. NU & tst BOPE. RIH w/8½" BHA, tst csg to 2000 psi. DO cmt & flt equip + 10' new hole to 3327'. Conduct formation tst to 12.7 ppg EMW. Drl 8½" hole to 3791'. 3690', 49.7*, N69.5W, 3040 TVD, 1684 VS, 472N, 1622W 9-5/8" @ 3292' 4702', (911'), Drlg Wt. 9.9, PV 14, YP 14, PH 9, WL 5, Sol 10 Drl & surv 8½" hole to 4702'. 3944', 53.3°, N57.9W, 3198 TVD, 1877 VS, 560N, 1799W 4438', 51.1°, N69.1W, 3500 TVD, 2254 VS, 734N, 2148W 9-5/8" @ 3292' 7037', (2335'), Drlg Wt. 9.8+, PV 14, YP 7, PH 8.5, WL 5.0, Sol 11.4 Drl & surv 8½" hole to 7037'. 4753', 47.8°, N80.7W, 3705.13 TVD, 2492.88 VS, 792.16N, 2379.70W 5539', 45.6°, N88.5W, 4239.71 TVD, 3061.52 VS, 828.21N, 2953.53W 6033', 43.9°, N86.5W, 4590.42 TVD, 3405.95 VS, 852.86N, 3300.48W 6744', 43.1', N86.1W, 5105.05 TVD, 3889.32 VS, 875.63N, 3790.62W ! ' ,r.F_IVFD The above is correct For'for~ preparation and 'distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date~/~.~/~,)~o I Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number aH drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Date and deptll as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25569 Complete record for each day while drilling or workover in progress 8/o8/86 8/09/86 thru 8/11/86 8/12/86 8/13/86 The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IState Alaska IWell no. 2T-4 9-5/8" @ 3292' 7438', (401'), C&C Wt. 11.0, PV 20, YP 10, PH 7.6, WL 5.0, Sol 13 Drl & surv 8½" hole to 7438', lost circ, POH 10 stds & spot LCM pill. POH to 5000', regain circ, POH & chg BHA. RIH, rm thru 3764'-4200' & 5450'-5630', break circ @ 3764', 5000', 5450', 6700'. C&C mud w/full rtns @ 7438'. 7146', 42.1°, S89.7W, 5400.96 TVD, 4157.74 VS, 884.85N, 4062.51W 7" @ 7556' 7660', (217'), Drlg Wt. 11.4, PV 18, YP 7, PH 11.5, WL 6.5, Sol 11 Drl 8½" hole to 7550'; losing fluid. Circ Mica pill, POH 5 stds; well swabbing. RIH, CBU; no gas. RIH to 7550', lower mud wt f/ll.0 ppg - 10.5 ppg, gain full circ. POH, LD DP. RU & rn 185 jts, 7", 26#, J-55 BTC csg w/FC @ 7471', FS @ 7556'. Cmt w/225 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65, followed by 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 2335 hrs, 8/9/86. WOC, ann flowing @ 7 BPH. SI. Open ann, flow slowed dn. NU tbg head. NU BOPE. Instl 3½" rams & tst. RIH, DO flt equip & cmt to 7510', tst csg to 3000 psi; OK. DO cmt & fit equip + 10' new hole. Conduct formation tst to 13.5 ppg EMW; OK. Drl 6-1/8" hole to 7660'. 7500', 40.5°, N90W, 5666.90 TVD, 4386.19 VS, 884.88N, 4296.14W 7" @ 7556' 8043', (383'), Logging Wt. 11.4, PV 14, YP 7, PH 9.5, WL 5.5, Sol 13 Drl 6-1/8" hole to 8043', CBU, short trip, wsh thru bridge @ 7775', POOH. RU Schl & rn DIL/SFL/SP/CAL. 5" @ 8155' 8160' TD, (117'), POH w/lnr tls Wt. 11.4, PV 14, YP 8, PH 9.0, WL 5.8, Sol 13 Rn DIL/GR/SP/SFL/FDC/CNL/CAL f/8043'-7565', cont w/GR to 1000'. RIH, drl to 8160', short trip, CBU, POH. RU & rn 18 jts+ 1 mkr jr, 5", 18#, N-80 lnr. Cmt w/122 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps, bump plug. Release lnr, chaining out of hole @ rept time. (5" FS @ 8155', FC @ 8109', LC @ 8065', Mkr Jt btm @ 7858', TOL E! o 9 **986 O a ~,~/~__~/~.;~ Title Drilling Supervisor 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. Accounting cost center code District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0715 County or Parish Lease or Unit Title North Slope Borough ADL 25569 Drill State Alaska lWell no. 2T-4 Nordic 4 Operator A.R.Co. ARCO Alaska, Inc. Spudded or w.O.spuddedbegun Date Date and depth =Complete record for each day reported as of 8:00 a.m. 8/14/86 API 50-103-20074 W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% Jabandonment of this well IHour I Prior status if a W.O, 8/1/86 ! 1730 hrs. I 5" @ 8155' 8160' TD, 8067' PBTD, RR Wt. 11.4, PV 14, YP 8, PH 9.0, WL 5.8, Sol 13 RIH, spot diesel cap f/2024'-surf, POH, LD DP. adapter & lower vlv. RR @ 1630 hrs, 8/13/86. ND BOPE, NU tbg S Ei-c' 0 9 I,986 Alaska 0il & Ci~s Old TD New TD 8160' TD 8067' PBTD Released rig Date PB Depth JK nd of rig 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 i Gravity Allowable Effective date corrected The above iS correctI J ,5 ~ t{ ii ?., ~ '.'. L'_. ii',', '] : ,." ,.'..'}~ Signa~~ / Date I~,,,~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 1630 hrs. 8/13/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil I S:i'~8;[e Producing method J Official reservoir name(s) Flowing I Kuparuk Sands Potential test data STATE OF ALASKA ' ALASKA OIL 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 X Plugging _% Stimulate- Pull tubing- Amend order-' Perforate '- Other - 2. Name of Operator ARCO Alaska, Inc. 3. Address P, O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 352'FSL, 556'FWL, Sec.1, T11N, R8E, UN 5. Datum elevation (DF or KB) 117'RKB, 82' PAD 6. Unit or Property name Kuparuk River Unit, 7. Well number 2T-4 At top of productive interval At effective depth I. At tgtal depth 8. Permit number 86-143 9. APl number 50-- 103-20074 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 16" S u r fa ce 3 257 ' 9-5/8" feet feet feet feet Plugs (measured) Junk (measured) None None Cemented 200 cf 875 sx AS III & 345 sx Class G & 100 sx AS I Measured depth 115'MD 3292'MD Wue Vertical depth 115'TVD 2801'TVD Perforation depth: measured true vertical RECEIVED AUG l 4 !98 Tubing (size, grade and measured depth) _I Ii Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal 13. Estimated date for commencing operation August 8, 1986 14. If proposal was verbally approved Lonnie Smith Name of approver Date approved 8/8/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-~~ ~,~//Z.A..../ Title Associate Engineer CommisSion Use Only (LWK) SA/097 Date Conditions of approval Notify commission so representative may witness ~ Plug integrity m.. BOP Test © Location clearance Return¢. ~-, ; Approved by Form 10-403 Commissioner J Appr°vaIN°' 3~~ by order of r~) -. the commission Date ~ ~'/'~- ~,Z~" '; Submit in triplicate feet ~~'(,/" 2T-4 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to lost circulation zone encountered above the Kuparuk Sand, ARCO Alaska, Inc., proposes to: 1. Drill 8-1/2" hole to 7555'. 2. Run and cement 7" casing at 7555' with 225 sx 50/50 Poz Lead Slurry followed by 200 sx Class G tail slurry. 3. Drill 6-1/8" hole to original planned TD ~ 8016'MD. 4. Run and cement 5", 18.0#, N-80, LTC production liner from 7355' - 8016'MD with 100 sx Class "G" cement. 5. Complete well as per drilling permit. SA/O97a:tw 08/11/86 July 24, !986 .Telecopy: (907) 276-7542 Mr, J. B. Kewin Regional Drilling Engineer ARCO Alaska, !nc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Re: Kuparuk River Unit 2T-4 ARCO Alaska, Inc. Permit No. 86-143 Sur. Loc. 352'FSL, 556'~, Sec. 1, TllN, R8E, Btmhole Loc. 1366'FSL, ll07'F~.~CL, Sec. 2, TIlN, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The pe~nnit to drill does not indem~ify 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. ~ere a diverter sys~tem is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Cha iz~an of Az=ska Oil and Gas Conservation Co~ission BY OPd)ER OF /~HE-CO~--~[ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. ~,r. Doug L. Lowery .... STATE OF ALASKA ALASKA ,._ .,_ AND GAS CONSERVATION CC...MISSION 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 Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil 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) 352'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit 5tatewide At top of productive interval 8. Well nu .mber Number 1304'FSL, 1394'FWL, Sec.2, T11N, R8E, UM 2T-4 #8088-26-27 At total depth 9. Approximate spud date Amount 1366'FSL, 1107'FWL, Sec.2, T11N, R8E, UM 08/19/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (Me and TVD) property line 801 6 1107' (~ TD feet 2T-3_, 25'~ surface feet 2560 (6082'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle45 0 Maximum surface 1 658 psig At total depth (l'VD) 3336 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ?~1.'~ C--," ~? ~,~ H-&n W¢,l ri Rf~ ' ~,c, , ~,c, , I I c, , I I r~ , 4-?Fill ~-.F _ _ _ 12-1/4"9-5/8" 36.0# J-SS BTC 3317' _~.5' ~5' ~,'~?' ?gO1 ' g75 _~× A~ II I HF-ER~ 345 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 7982' 34' 34' 8016' 6082' 200 sx Class C(minimum HF-ER~ 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 C0[!~ ,~ ~ ~ ~F''"r.i !?~ '"''''' ~ "'~:' ~! ~ il)il. !!ii ~ '~;, / ' Surface ,~ re, ..~.' Intermediate ~ '~;! ~ !~ Production ]~" ~%~ ~*~ ;~'-" ............ Liner ~.~ ~: v.,~ ~ .......... :, ~, Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ,~ Diverter Sketch ',~ Drilling program Drilling fluid program ~ Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ ~~ Regional Drilling Engineer Signed -~' ~ C'r J:;M ¢'...~'~o Title Date mmission Use Only (LWK) PD/PD300 APl number I Approval date I See cover letter Permit Number ','~ C-/Sz-~~ 50-- /'~} - -~o ~'7'-/ 07/24/86 for other requirements Conditions of approval Samples required [] Yes '~ No Mud Icg required [] Yes ~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes ,~ No worki ssur, fo '~2 ; '3M' [] 5M; [] 10M; -~ 15M Required ~~~ , Other: by order of Approved Commissioner the commission Date Form 10-401 Rev. 12-1-85 / Sub~ triplicate KuPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C DE SC R I PT I ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4, TANKO LONER QUICK-CONNECT ASSY. S, TANKO UPPER QUICK-CONNECT ASSY, 6. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES H/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC25.035(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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNNIND DIVERSION, DO NOT SHUT IN NELL UNDER ANY j Al~sk~ Oil & G~s Cons. A;~chors~ge 7 ] I ACCLMJLATOR CAPACZTY TEST 5 4 2 .> 13-5/8" BCP STACIK TEST 1. FIU.. BCP STACX ~ ~ MANIFCLD WITH ARCTIC DIESEL. 2. C~ECX T~T ALL LCX:X E:~ S~ IN ~]_L.~ ARE FLLLY RE-TRAC'FED. ,.~T T-r. ST PLUG IN ~LL.~ WITH R~ING JT A~D R~LIN IN LOC~ SC~. LINE VALVES ADJACENT T0 BCP STAC~. AIL ~ VALVES AJ',D Q-E:KES ~ BE CPEN, 4. PRE~ UP TO 250 PSI AND NCI_D FCR I0 MIN. IN- ~ PRE~ TO 3000 PSI Ahl) HCI_D FCR I0 MIN. BLEED PRE~ TO 0 PSI. 5. CI:x:',_N ANd, I_AR PREVENTE:~ AND ~4'4JAL KILL AhD CHCIKE LIh, E VALVES. O_,_OSE TCP PIPE RAMS AND NCR VALVES Cr~ KILL A/',D (:~-t(:KE LINES. 6. TEST TO 250 PSI AN:) 3000 PSI AS IN STEP 4. 7. C:CI'~I~ TESTING ALL VALVES, LINES, AN:) ~S WITH A 2.3:) PSI LC~ AND 3000 PSI HIC~t. TEST AS IN STEP 4. DO NgT F>F~. ~.9..9J:~ TEST ANY. ~ T]-IAT 1.5 .hQT .A .FU_L C,..OSIh,~ PCISiTIVE SEAL O-K:IKE~ Cr,,LY FLI,i.g~ICIN lEST CI-K:I<~S 'F~iAT DO Ni)'T F-d_LY CLOSE. 8. CF:'EN TCP PIPE RA/v~ AND CLOSE__ BOTTCI~ PIPE ~. TEST BOTTC~ PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. ~ BOTTClvi PIPE RAMS, BACX CUT .~dNNING ,;r AND .lO. CLQSE[ BLIND R41vE; AND TEST TO 2_50 PSI AN:) 3030 PSI. I1. CPEN BLIND R~ AND RETRIEVE TEST PLUG. MAKE SL~ MANIFCLD AIxD LINES AR~ FLLL CF M2N-FREEZING FLUID. SET ALL VALVES IN DRILLING PCISITICI~L TEST STA.M)PIPE VALVES, KFLI Y, K'F'I LY ~S, DRILL' PIPE SAFETY VALVE, AND INSIDE OCP TO ~ PSI ~ 3000 PSI. 13. RECI:RD TEST IhI=~TIC~ CN BLCI~CLrI' ~ TE5' FC~:~, SIGNo AN:) SEN:) TO DRILLING SLPg~ISCR. 14. PERF~ C~E]'.E~BQ:~- rT~. T AFTER NIPPLING UP A~.. '~'~ l-,. '~, ::: ' " ' 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. --~ DE6R$$ER ~ SHALE HUD CLEANER SHAKERS STIR ~ STIR ~.p. STIR TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10+ 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. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih ARCO i ALASKA. .... I'Nl ............ ~ . \__. .... KUP'ARUK FtELD.~--NORTH--SUOPET'-ALASKA ' . .- ~ ~ .................. { -- ~. · .. ~ ~ ;· , . ' : : ~{ " :~ ........ ~ ....... ' -- ~ .......~ ~ .......... * ................ i ................... ~ .................. ~ ...... · ................. ~ ..... .....,~_. ._ : .~ ~ ~ : .... , ........................... ~ i ........ ~ ........... ~ ..... ......... ~ .................. , .......... + ................. ~-r .............. t .......................... .... ..... +~ ....... ~ -~_VD ~ ~500~ _ ~_~500~=0- ........... :::~:::::_~ ~ .{ _ -~ . ~. --~:.:.-:-~_ - ~ ~ ~:-:~}_:.-___ :. :._-_: ::::~_:-_~---:~:-~::~:..:-~ ::--_ .-~_.-::-:.-:.-}-.~ -. ............... ~ .......... ............. ~ ~ . ~ . ; = . . .... i ........ ~ PER. -4~-, ~ ................... , . _ .... ~ ............. ~ . ?, ................... ..... ~ ........ -21 ..... :-~ " ' ~ .... ~ ' ' ~ .... ~ ' ~ ' - ...... ~ ........... ~ .......... ~ ...... : . _ -~ ........ . - . ~ ....... : ........ . --~ :-:~L~: _ ~2~ _~OP UDHU~ SHDS '~ TVD-1TO~_':T~D-~ T99-_ DEP.425 ~ ...... ~ .... ~ ......... ~ -- - ' , ~ ....... : ..... ~ ....... ~ ....... - EOC- - TVD~1858~ T~D-2010--DEP-56~ ......... ~ ....... ~ ..... ~-~ .... ' ........ ~ :- ......... ..... ~ ............... ; ...... ~ - ~ .... ~-~ ~ .... ~ ........ . ~ - }~ .......... ~ ............ ~ ........ ~ ............. - ~ .............. ~ ..................... ..... ~ ...... ' - ToP ~ SAK SHDS-~ TVD-226~---T~D-2584-'DEP"9~4 ...... ~, .... . ~ ..... ~ ........... ~ ....... ... ..... , _~ .... :~ ....~ .....~ ........ ~ ........... ~ ......................... ~ ..... .......... , ......... , .......... * ..... i ................. : ........ i ..... ! , , .... ~-~ ; ~ ' ........... ~-: ~ ......... ~ ...... ' ............ :'~ ...... ~ --' .... ~ ..... i ............. : ..... ' .....~-:--': '" ..... ~__~ -; ....... i- ~ : : i ~ · : _: ............... ~ .......... . ............................ ~_~ . ! ' i ....... ...... ~ .... ~ ; ---4 - · ~ -.- ~ " - : ............ ~ ...... : ..... :- - .... ~ ~' ': ..... - ~ + - "~ .... ;'* ~ K-5~?'TVD=4276'-T.D-5449 DEP-3011 ..... - i=-- "--: - '-; -: i- ':-: :~ -- --- ~~----.. .~ ............ :~--~ ..... :~~ .... ~ .... ~ ...... ; ........... ~ .......... ~ ............ : .... ~ ..... m .....~ ...... ' - - F--; ....... 1 .~m.~ .~~~ ' - ~ ..... : ~-"-'~ ~-: - : ..... ~ ....... . .... :--' -- ~:- - ~ - -t ..... ~- - ~- - ~ ..... ~- -~ ---~ ......... ;--- ~ ......~ -- : ....... ~ ....... ......... L ........... : ................. ~ ............ ~ ...... :_ ..... ~ ....... . ....... : . _~ .... .... ~ .... : :__ 1_:-- ..: ........ ~_ . .~ ........ ~_: ....... : ........ [~~-::~_..:.__ :_;__:..: ..... :_?:_: .... : .... _~__ i ' ' ~ ~ . ~ .... ~_~ ~, ~ . · , ' ' ..... :iL:-'_ ................ :-T/ ZONE C F_TVD-SZ91-__~"Z603 'DEP=4~43 ...... L--~-, ...... :__. ~ ..... TARGET 6NTR T D 5866 T~D: TZIO;DEP ~619 ~ .......... : ....... ~ ....... : -~ ...... : - ................. : -- B/ KUP SNDS ....TVD 5941 T~D ZBtG~-DEP---'4694-i::%&:--~ .................ZD~L ~.. P T,)'_T_ V-_D_6_OS~D~.O]¢' " ~D_E P~E4 B~:L1 .......... h ....... t'-: ......... . .....~ ......... ~ ....... ~ , ~ , , . , : ...... .__ ] ....... : ..... ; ......... ; ..... ................................ ~'---: .... ~--: ........... ~]7 ....... i-: ......I - - .... : ~ ' . ....... ~ ........ ; ............ ~ .......: ; - ' - ....... ~ .........r ........ ~ ............... ; ............. ............. ; .................... ~ : I ....... ~ ........... ~---: ...... , ...... J ......... ; ........... I--: .... 4 ..... ; ............ :_: .... ~ .... :--:_ 7:-:-D::::_:: _~::::::::_:~ ooo-:-':~:.:_:::::~ooo ::::::::::::::::::::::::::: ..... ~ .......... ~ '~ ............ T .... ~ ' ": ..... ~ ........ ~ ....... ~ l-~O-"a-~'''~'-*' *-" ~ ..... ~ - ~ ....... ~ .......... ~ ........ ~ ............... T ...... ~ ........ ! ......... ! .......... ~ ............. ~ _L~: .......... ~,_E ~:!. ~. '~r¢, .... ....... ~ ............. ~ ....... : ....... ~ - ~ ' ~ .... ~ : ' .......... ~ ....... ~ - I~ ~ ~: ~ ~'- ~ ~' ~ ~ ~:'" ~ ~' ~' ~/ .... : ' ' ........ ~ - . ~ - ......... ' ....... ~ ..... ' ; . ~ ~L~:~ ;~ ~.~'.:, ~ ~ ~ ~ ~.~, '~: -- i ..... ~- : .. - )-. - : ..... ~. - - ; ..... L ..... I'D L0¢^1 TVD~$866 1320' SEC'. 1' 2,560 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. If Sincerely, Gruber Associ ate Engineer JG/tw GRU13/L44 Enclosure RECEIVED ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany i i , ~ I~,~; ,~ , I ~ 6 .,, LOC~TE~ IN PROTR~CTE~ LOCATED IN SEC. !~ TIIN~RBE~ U.~. SEC. I~ TIIN~BE~ U.~. ~- ? = 5,970,38~.43 L~T. 70~]9'49.~287'' ~0 - Y = 5,970,~32.65 L~T. ~0~9'46-67~9 ~ - 498,944.93 LON~. ~50~00' 30-807'' ~ = 49~,945.~ LONG. ~50~00' 30.796" ~2' FSL, 556' ~L 06 ~ ~7' P~D ~ 8~.5 L52'FSL, 556' F~L ~" 76.0 3- ~ = ~,970,357.42 ~T. 70~9'48.882B'' ~ = ~ = 5,970,~07.7~ LAT. 70~19'46-4267'' ~ = 498,944.9~ LONG. ~50~00"30.808'' X ~ 498,945. ~0 LON6- ~50~00' 30.80~" 37~' FSL, 556' Y~L 0G = 77' P~D ~ 8~.5 ~27' FSL, 556' F~L 0G ~ 75.9 4- ~ = 5,970,332.46 ~T. 70~9'~.6372" L2- Y ~ 5,970,082.58 L~T. 70~9'46.L79 X = 498,944.84 LONG. ~50~00' 30.809" o X = 498,944.98 LONG. ~50~00 30.804" 352" FSL, 556' ~L OG ~ 77' P~D = 8~.6 "~ ~02' FSL, 556' ~L OG ~ 75.7 5 - ~ = 5,970,307.5~ ~T. 70~9'~.39~9'' ~ ~3 - ~ ~ 5,970,057.59 ~T. 70~9'45.~336" X ~ a~8,944 9~ LONG. LS0~00' 30.808" ~ ~ X = 498,945.08 LONG. ~50~00' ~0.80~" ' ' ~ 77' FSL, 556' F~L 0G ~ ~5.5 P~D ~ 8~.6 327' FSL, 556' FWL OG : 77' PAD : 81.6 LO ~ oD LAT. 70019' 45. ~79" 6 - Y : 5,970,282.50 LAT. 70°19'~.1459'' CO ~ o 14 - Y = 5,970,032.60 X = 498,944.95 LONG.150°00'30 806" ~ ~ ~ ~ X 498,944.91 LONG.150°00'30.806" ' O 302' FSL, 556' FWL OG = 77' PAD : 81.7 ~ ~ ~ ~S 52' FSL, 556' FWL OG = 75.3 PAD = 81.7 ' ~ ~ 15 -'Y = 5,970,007.69 LAT. 70~ !9 ' 45. 4428" 7 - Y = 5,970,257,54 LAT. 70°19 47.9003" ~ O ~ ~ X 498,944.93 LONG. 150°00'30-806" X = 498,944.95 LONG. 150°O0'30-806'' ~ ~ 27' FSL, 556' FWL 0G : 75.2 PAD = 81.6 277' FSL, 556' FWL OG = 77' PAD = 81.6 8 - Y : 5,970,232.63 ~T. 70019'47.6553" ~ ~ ~ 16 - Y : 5,969,982.85 LAT. 70°19'45.1985'' X : 498,944.96 LONG.150°00'30.806'' ~ ~ ~ X : 498,944.88 LONG.150°00'30-807" 252' FSL, 556' FWL OG : 76.9 PAD = 81.6 ~ 2' FSL, 556' FWL 0G = 75.1 PAD : 81.7 9- Y : 5,970.207.62 LAT. 70019'47.4093" c)ej LOCATED mN PROTRACTED x = 498,945.01 LONG.150°00'30.804'' ~ SEC.12, TI I N, RSE, U.M. 227' FSL, 556' FWL 0G : 76.3 PAD : 81.6 17 - Y : 5,969,957.72 LAT. 70~19'44.9514'' X : 498,944.94 LONG. 150000' 30.805" 1. ALL COORDI NATES ARE A.S. R, ZONE 4. ~ ~'' ~ .... [~' ~"' ~ :'~ 2. SECTION LINE DISTANCES ARE TRUE. ~ ~ ~ ~t, ~ 3. HORIZ; POSITIONS BASED ON TEME MON~ ZT-EAST, 2T-WEST ~ 2T-MIDDLE PER LHD~ ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 5 NIg+75, EII+52 PER F.R.B. A ASSOC. 5.0.6. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-3140 rev.~, . CERTIFICATE O~ SURVEYOR; i HEREBY CERTIFY THAT I AM ~ROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ~ ~ ~ MADE BY ME OR UNDER MY SUPERVISION, AND ~.'' THAT fiLL DIMENSIONS AND OTHER DETAILS ~ ~ ." ~ ' ee'~m~ J ~ ARCO Alaska, Inc. ~p./~~ fiURVFYED ...... FOR'. ~ ~ ~.,.~.,-.~...? DR~WN WM U~ILL bl/~ ~/ gUmMug/g~ ¢'~ %' No 6919~ ~ 8SSOG, ~,~u~ ~ F.R.,.e~, AS- BUILT LOCATIONS I. ~..-'-4 .................... ]Jgwe. No. NSK ee-e ~5 Arctic Boulevard, Suite 201. Anchorage. A/aska ~503 /ISSUE N.T.S. (5) BOPE e 11. 12. 13. 14. 15. 16. 17. 18. 19. 20.. 21. 22. 23. 24. 25. 26. 27. 28. 4. (29 thru 3])- For 29. 30. 31. 32. Ge91o~_: Engineering: ~L~ LCS- ' ~..,~ JAL ~_~ rev: 07/18/86 6.011 ~il l°~ted a 'defied' ~ol ....... . '", ;'., ..... - Is "roll lOcated proper ~s~ce rrm ocher rolls .. ........ Is s~f~e~ mde~eated aer~ge 'available ~ ~s ~1 . Is roll to be deviated ~d ~s mllbOre plae ~nelu~d ..... Is opera'or the only affeceed party ............. ~. ....... . ~ pe~t be approved before f~fteen-~y ~it ........... , ~es °perator ~e a brad ~ force ................... ~ .............. Is a c~se~ati~ order needed ' Is a~is~ati~ appr~al needed ................................... Is the lease n~er appropriate ..................................... ~s ~e ~11 ~ve a ~i~e n~ ~d n~er ......................... Is conductor string, provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface .......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............... ' ............. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to _~~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are sUrVey results of seabed conditions presented' Additional requirements ............................................. - INITIAL ' GEO. ' ONIT ON/OFF POOL 6IASS STAndS AREA NO. SHORE . . . .... _ _ = Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady 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. -, . ,,~ ~_ZST.T,N,~ N -' >'~, C '3 !'.,' T = P'i T ,S ~ ~'~ ',i: i S ',",! ~CT: l C J !"...i: ~',:, $' i .:: S T~T: T-Y' LJ3~ !L.r","! 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