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186-097
RECEIVED STATE OF ALASKA NOV 2 8 1017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORIMSOCOG la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned 0 , Suspended ❑ lb.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.: 11/1/2017 186-097/317-178 • 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 5/26/1986 50-103-20065-00 ' 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 127 FSL,556'FWL,Sec 1,T11N,R8E,UM 6/4/1986 KRU 2T-11 Top of Productive Interval: 9. Ref Elevations: KB:41 17. Field/Pool(s): • 1392'FNL, 1238'FWL,Sec 12,T11N,R8E, UM GL:82 BF: Kupurak River Field/Kuparuk Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1684'FNL, 1292'FWL,Sec 12,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- 5970108 Zone- 4 6789/6139 2667 TPI: x- 499628 y- 5968588 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 499682 y- 5968296 Zone- 4 1777/1777 1550/1518 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 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 4 013 P3. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H-40 Surface 115 Surface 115 24 225 sx CSII 9.625 36 J-55 Surface 3292 Surface 2789 12.25 900 sx AS III,285 sx Class G 7 26 J-55 Surface 7556 Surface 5713 8.5 250 sx Class G, 175 sx AS I 5 18 L-80 5961 6789 5503 6139 6.125 115 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): 3 1/2 6391 5725/5321 Perforations Plugged 6368/5818 6/3Ao oc / 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. • ....------77-7----7 Was hydraulic fracturing used during completion? Yes❑ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information 1' ` t ill- DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED Tubing Top Job 1 bbl of cement (.` IA Top Job 0.4 bbls of cement OA Top Job 0.4 bbls of cement 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 �0.• Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407,Reeviiised 11/ vil- /��/I J CONTINUED ON PAGE 2 RBD S L` 1;0\I 1 " 1U1ubmit ORIGINIAL ori Mil. idol 1l �/ • • 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. (L�P 032'1 5�8� c Gssce 5-"Bo, 62C11,41 ?"15 vJIL Formation at total depth: -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 reoort.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 A 263-4131 Email: JiII.Simekacop.com Printed Name: G.L. vord f Title: Alaska Drilling Manager idi Signature: -21A Phone: 265-6120 Date:• ! 1 / / -- t,.;� At-Vv INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 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-11 Plug and Abandonment November 16, 2017 ConocoPhillips Alaska, Inc. performed Plugand Abandonment operations on 2T-11, p P commencing operations on July 8, 2017 and completing the Plug and Abandonment on November 3, 2017. The tree was removed and a cement to job wasperformed to bringcement to surface in tubing P and all annuli. The wellhead was then removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. ,a ,v 17:.$ ''' S} W . 0; . t . � a �y ti LI g Rc '', �, .r . -,. ° r i fi i p" i • • •.:' ,''::. r `r}3 pia r°7;:f'i''''' '''!'''‘:t:t'4::::34101411i:'''''',:ii;' ,:',.:*:::: :>:4;i'7714'"'";:644'4;;;fr;:l::::: .• ,:,, ,,,g,',' � pY yS 4 8 ii �/ :�3R h Y mss ,,zro:::, x5$ , a , ,: t:;,,,,,,,,,' e e' 14 ' �' .� 3'' `'t` re ,as di4ir 1 F` a A f:). „i„,,,, ,,!,,,,,, ,,„.7 :; , 7per.+ kiyt l'er..''14,,,, ii' ,,i':'273.:7,:'t;.,,,,.. , ib) Esi * : \iti Rp� , s'\; lh s ` `Yb zm. 9 Wit;; ��.:, ,- 1 ::::...;,-,„ - „ ,,,,.--..;;,...• - . 00,it 1 111- { ''''''T,„ ,--, „it i 1,, ? yright 2017. All rights reserve eser ed. This photograph is provided to the AO GCC with'>'' perra�ission to copy for its own use. Copying for any other purpose or y any other party is pr€�hib ted without the ii express consent of Corraco hillips Alaska. tnc. P!WELL EVENTS SUMMARY • Date Well Event 11/3/17 Final Site photos taken and placed in the"S"drive folder. Problem Wells& Compliance (ADM040)\Wellhead Pictures & Repairs (EEF170)\CPF2 Pictures- Copyrightl\2T\2T-11 P&A\Pictures\2T-11 Final pics 11-3-17 11/1/17 Remove 4" more of well for a total of 13'10" removed. Top w/cement. Stateman Matt Herrera witness cement and marker plate. Weld marker plate. Remove stairs &shoring. Rury PRA wall 10/31/17 P&A Finish egress& install shoring. RU WACH's cutter and attemp to cut off wellhead -after over 5 hours rigged down and cut off 13'6" of wellhead. Kelp personal on location to keep excavation pumped out. 10/30/17 P&A Excavate to 6' and remove base plate, continue to 12.5' (4' below tundra) and install shoring. Dig egress. 10/29/17 P&A T/I/O = 0/0/0 Excavate to 4' and remove cellar box. 10/21/17 P&A PREP Initial T/I/O = 0/0/0 Remove JIC cap on T and verify 0 psi, reinstall cap. Remove Alemite cap from IA and verify 0 psi, reinstall cap. Remove Alemite cap from OA and verify 0 psi, reinstall cap. Final T/I/O = 0/0/0 10/15/17 (MISC) P&A Prep Initial T/I/O = 0/0+/0+ Bled the IA and OA to 0 psi in 2 sec (gas). Left T, IA and OA open to atmosphere for 6 hr bleed. Final T/I/O = 0/0/0 10/14/17 (MISC) P&A PREP: BLEED IA/OA Initial T/I/O = 0/0+/0+ Bled the IA and OA to 0 psi in 2 sec (gas). Left the T, IA, and OA on an open bleed for 5 hours. Vac out-2 gal of liquid from the T. ' Final T/I/O = 0/0/0 9/30/17 (P&A) BLEED T, IA, & OA TO 0 PSI. FOR P&A. CHECK FOR LEL's (0%) Initial T/I/O= SI 0/8/6 Bled IA to 0 psi. in 5 seconds. Left on open bleed for 1 hr. Bled OA to 0 psi. in 5 seconds. Left on open bleed for 1 hr No LEL'S. Final T/I/O= 0/0/0 8/19/17 Initial T/I/O= SI 0/0+/0+ Left all annuli on open bleed for 10 hrs. Final T/I/O= SI 0/0/0. 8/18/17 (P &A PREP)T TOC @ 8' IA TOC @ SF OA TOC @ SF. Initial T/I/O = SI 0/0+/0+ Bled all annuli to 0 psi and left on open bleed for-7 hours. TTOC @8' TFL@1' IATOC @SFOATOC @SF. 8/17/17 (P&A) CEMENT TOP JOB ON T/I/O (COMPLETE) Initial T/I/O= SI 0/11/1. Bled IA&OA to 0 psi. Removed T flange blind for cement job, Removed IA& OA bull plugs and VR plugs for cement job, Pumped 1 bbls of cement down T taking returns to waste truck Pumped .4 bbls of cement down IA taking returns out companion flange. Pumped .4 bbls of cement down OA taking returns out companion flange. Re-installed all bull plugs and top of T flange blind 8/12/17 (P&A) : T/I/O = si0/0+/0+ 8/11/17 (P&A) : Bled WHP's, 14 111@ 7', OA FL @ 3'1". 8/8/17 (Pre P &A) REMOVED SCAFFOLDING &TREE. INSTALLED BLIND"FLANGE WITH NEEDLE 7/8/17 (TOC) CHECK TOP OF CEMENT IN T-86' IA-23' OA-23' 2" 6/25/17 (Pre P&A)T/I/O = si0/0/4 6/24/17 (Pre P&A) T/I/O = si3/14/48 6/12/17 (Pre P&A) : T/I/O = si1/9/34. 6/6/17 (P&A) T/I/O = SI 2/17/37 5/20/17 (Pre P&A) T/I/O= si 4/22/40 5/19/17 (Pre-P&A) T/I/O = SI 4/22/40, T, IA, and OA FL @ NS. 5/11/17 Received approved Sundry#317-178 for P&A of 2T-11. z KUP 2T-11 ConocoPhillipsZ Well Attribut Max Angle D TD Alaska lm. , Wellbore API/UWI Field Name Wellbore Status Indy) MD(kKB) Act Btm(kKB) CorwcoPhillips 501032006500 KUPARUK RIVER UNIT INJ 1 42.35 5,400.00 6,789.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-11,11/27/201711 58 58AM SSSV:TRDP Last WO: 41.11 6/6/1986 >.:Vertical schema0c(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date °,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,n,,,,,,,,,,,,,,,, Last Tag:SLM 6,436.0 4/24/2009 Rev Reason:P&A WELL SEE NOTES pproven 11/20/2017 MARKER PLATE,46.0 Casing Strings Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 46.0 110.0 110.0 6250 H-40 WELDED Casing Description OD(In) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 46.0 2,973.4 2,973.3 36.00 J-55 BUTT _n_ti CONDUCTOR;48.0-1100 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade 'Top Thread CEMENT PLUG;46.0 ftKB PRODUCTION 7 6.276 46.0 6,170.1 5,665.1 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 5 4.151 5,960.8 6,789.0 6,139.1 18.00 L-80 LTC SAFETY VLV;1,777.5 F Liner Details Nominal ID t Top(kKB) Top(ND)(kKB) Top Incl(°) Item Des Com (in) TOG PUNCHES;2,050.0 ^-i#:„ , 5,960.8 5,503.3° 39.29 SLEEVE BOT SETTING SLEEVE&EXT w/PBR 4.151 5,976.5 5,515.5 39.30 HANGER BOT LINER HANGER 5.000 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...,Wt(Ib/k) Grade Top Connection TUBING 35"x2.325" 31/2 2.992 46.0 6.390.61 5,835.1 9.30 J-55 EUE-8rd CEMENT PLUG;46.01108 @ 5804' l Completion Details Nominal ID SURFACE;16.0.2,9734 Top(ftKB) Top(TVD)(SOB) Top/0010 Item Des Com (in) CMT PLUG;2,900.0 1,777.5 1,777.4 0.58 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 TBG PUNCHES;8297.0 - j 5,711.4 5,309.9 39.03 PBR BAKER PBR 3.000 5,725.1 5,320.6 39.05 PACKER BAKER FHL PACKER 3.000 CEMENT PLUG;2,900.0 ftKB 5,801.0 5,379.5 39.15 SLEEVE AVA BPI SLIDING SLEEVE 2.310 GAS LIFT;8884.e 5,803.9 5,381.8 39.15 XO reducing XO REDUCING 3.5x2.375,4.70#,N-80,1.995 2.375 6,291.5 5,758.8 39.46 BLAST RING 1.995 y 6,365.4 5,815.8 39.80 LOCATOR BAKER LOCATOR 1.995 _ 6,368.1 5,817.9 39.81 PACKER y BAKER DB PACKER 3.250 PBR;5,711.4 .i 6,382.2 5,828.7 39.89 NIPPLE CAMCO D NIPPLE 1.812 PACKER;5,725.1 ' 6,389.9 5,834.6 I 39.93 SOS CAMCO SHEAR OUT 2.441 _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5,763.3 Top(TVD) Top Incl Top(kKB) (ftKB) (°) Des Com Run Date ID(in) 46.0 46.0 0.18 MARKER MARKER PLATE 11/1/2017 PLATE 2,050.0 2,049.9 0.60 TBG 1.38"PUNCH GUN,4 SPF,0 DEG PHASED,1.8 6/6/2012 2.992 SLEEVE-0;5,601.0 PUNCHES GRAM CHARGES SLEEVE;5,801.0 I I 2,900.0 2,899.9 0.27 CMT PLUG PUMPED 15.8 PPG"G"CEMENT INTO TUBING& 9/1/2012 0.000 IA.CEMENTED TO SURFACE,SURFACE OA • DOWN TO 318'. 5,297.0 4,993.9 42.08 TBG 1-3/8"TITAN TBG PUNCH,4 SPF,0 DEG PHASE. 3/24/2012 2.992 CEMENT PLUG;5,800.0 ftKB PUNCHES MEGNETIC DECENTRALIZED 1... �'' 5,600.0 5,223.3 38.83 CMT PLUG PUMPED 23 BBLS 15.8 CEMENT 10/10/2009 0.000 i' 5,801.0 5,379.5 39.15 SLEEVE-C AVA BPI SLEEVE 1/28/2007 2.310 i'I• 14 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shoal Top(kKB) Btm(ftKB) (kKB) (ftKB) Zone Date ft) Type Corn 6,331.0 6,352.0 5,789.3 5,805.5 C-4,2T-11 10/11/1986 12.0 (PERF 120 deg Ph;3 3/8" HyperJet PRODUCTION;48.05,170.1 CMT PLUG;5,800.0 6,429.0 6,435.0 5,864.5 5,869.1 A-4,2T-11 10/11/1986 1.0 IPERF 180 deg Ph;3 3/8" � HyperJet 'I _6,446.0 6,4840 5,877.5 5,906.5 A-3,2T-11 10/11/1986 4.0 (PERF 90 deg Ph;33/8" HyperJet IPERF;8,331.0-6,352.0 ##E Cement Squeezes i Top(TVD) Btm)TVD) Top(kKB) Btm(kKB) (MOB) (ftKB) Des Start Date Corn 5,960.0 6,789.0 5,502.7 6,139.1 CEMENT PLUG 10/10/200 PUMPED 23 BBLS 15.8 CEMENT LOCATOR;6,365.4 t, 9 .. ... 5,600.0 5,960.0 5,223.3 5,502.7 CEMENT PLUG 10/10/200 PACKER;6,368.1 9 it 2,900.0 5,600.0 2,899.9 5,223.3 CEMENT PLUG 5/13/2012 46.0 2,900.0 46.0 2,899.9 CEMENT PLUG 9/1/2012 NIPPLE,6,382.2 « u' 46.0 318.0 46.0 318.0 CEMENT PLUG 9/1/2012 Mandrel Inserts St ati SOS;6,389.9 on Top(TVD) Valve Latch Port Size TRO Run N, Top(kKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 5,664.8 5,273.7 OT IS LBX 1 1/2 GAS LIFT DMY R05 0.000 0.0 6/17/1987 2 5,763.3 5,350.2 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 10/12/1986 IPERF;6,429.06,435 0-. Notes:General&Safety End Date Annotation 1/27/2007 NOTE:CORKSCREWED TUBING FROM 294'SLM TO TBG BOTTOM? 4/24/2009 NOTE:HYDRAULIC PANEL HAD BEEN REMOVED FROM FUNCTIONING SSSV IPERF;6,446.06,484.0 12/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/30/2017 NOTE:Excavate to base plate,cut off base plate,excavate to 126"(4'below tundra) 1 10/31/2017 NOTE:Removed 13'10"of Wellhead(3.5 below tundra) 11/1/2017 NOTE:Stateman Matt Herrera witness cement and marker plate. CEMENT PLUG;5,960.0 ftKB, LINER;5.960.86,789.0 ° • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ' , Ittli1 DATE: 11/4/2017 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Abandonment Petroleum Inspector KRU 2T-11 - CPAI PTD 1860970; Sundry 317-178 11/1/2017: I drove out to Kuparuk Field and met up with Bob Hagberg on KRU 2T-Pad, well KRU 2T-11 and verified their marker plate and well information was correct for installation and the below surface grade compliance. The casing stub was verified at ,r approximately 8-10 feet below grade. Cement was at surface. Information on the marker plate was verified with Sundry 317-178. Attachments: Photos (3) SCANNED 9 <fi,'R 2017-1101_Surface_AbandonKRU_2 T-11_mh.docx Page 1 of_3 0 • Surface Abandonment— KRU 2T-11 (PTD 1860970) Photos by AOGCC Inspector M. Herrera 11/1/2017 • ' ,..,7- , go , ik4 _ .. . . 41110 .r ' •`'halp ri ii.' 01'. 4iii. ,,..:•;,01011..\, ,, •. :. ..,,. , !,..,. ...- _,,,,wr.s.--,,,.1,._.., }:*fir ill, • 4.... • _-ige- • .i. .** . ,::::. , . • •,.......,"...:. ... •.....,.. .4, i..,, ,,..„,....,4-44.1:7-_, • , . w o- fig# 1wk.. . -e) _ �+ k' a k N. 1 ) _ Wil' .+ • . ` 1y1 "c x � .,, J y'i+t" ,r• rr • 4::; •4. ~� 2017-1101 Surface Abandon KRU 2T-11 mh.docx Page 2 of 3 • • ai • ' .i # r� �n°� ' $ r 4"4 x J _ A `1, ) H....., H- 1 •i { t .- _ I ,,,--, 1 i /".. -'-* 11, ...." J ✓ ..i J 10041 r.. !'" r _ - .../ /--- 2017-1101 Surface Abandon K3RU 2T-11 mh.docx Page 3 of 3 • • yOr 7.4 \����y/�'i. THE STATE Alaska Oil and Gas N -4 of Conservation Commission ALAS <:A t z i� 333 West Seventh Avenue " �iiiiV , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 . -..,` Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED M , 2 5 201?'. Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-11 Permit to Drill Number: 186-097 Sundry Number: 317-178 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, pe).....,4„. Cathy . Foerster Chair DATED this I day of May, 2017. RBDMS GL-MAY 1 6 2017 S • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 4 2017 APPLICATION FOR SUNDRY L1LI APPROVALS 1 20 AAC 25.280 CC 1.Type of Request: Abandon �`-j Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: _P&A 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 186-097 A 3.Address: 6.API Number: Stratigraphic 0 Service . P. O. Box 100360,Anchorage,Alaska 99510 50-103-20065-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ KRU 2T-11 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 s Kuparuk River Field/Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,789' 6,139' 0 0 0 Cemented to surface none Casing Length Size MD ND Burst Collapse Conductor 73' 16" 110' 110' Surface 2,941' 10" 2,973' 2,973' Production 6,175' 7" 6,170' 5,665' Liner 828' 5" 6,789' 6,139' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6331-6484-cemented - 5789-5906-cemented 3.5 x 2.345 J-55 6,391' Packers and SSSV Type: PACKER=BAKER FHL PACKER Packers and SSSV MD(ft)and ND(ft): '5725 MD and 5321 ND PACKER=BAKER DB PACKER , 6368 MD amd 5818 tvd SSSV: =CAMCO TRDP . 1778 MD and 1777 ND 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 , 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/21/017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek©cop.com Contact Phone: (907)263-4131 Authorized Signature: '/f &,(t/- Date: 513W' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3r7- C7% Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance I--1% 5 ((? 1 14 Other: FAofv 4o c ,- r 1- ccnGi AOCZ6°C 1A7-) 7-1-17S5 a5 y cif Post Initial Injection MIT Req'd? Yes ❑ No a""-- / Y-'-e- Spacing Exception Required? Yes ❑ No V Subsequent Form Required: Ir —4--U - - RBDMS MAY+A i 1 6 2017 APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date:5-( f....( 7 pia s/ss-)I / vn ��'L[�J(�- re 7/1 5- n , \ ( I A� LL Submit Form and Form 10-403 Revised 4/2017 �pprovd ap I cat A%valid for 12 months from the date of approval. Attachments in Duplicate • • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAY 0 4 2017 , , C C 24 April 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 plug and abandon Kuparuk River Unit well 2T-11 (PTD#: 186-097). Injector 2T-11 was drilled in 1986 and completed as a selective Kuparuk A & C sand well. It was pre- produced for five months, after which commingled A/C water injection began. 2T-11 remained a WAG (water alternating gas) injection well until it was shut-in in April 2009 due to subsidence-induced casing and tubing damage. Subsidence related symptoms, although not diagnosed as such at the time, were first noticed in June 2001 when a desired tag could not reach total depth, due to tight spots in the tubing, restricting deep access. The surface casing leak was diagnosed on March 23, 2009 when the well failed a mechanical integrity test of the outer annulus(MITOA). Based on the overall subsidence issues at drillsite 2T and the condition of the 2T-11 wellbore,the decision was made to secure the perforations with cement, which was completed on October 10,2009. On October 12,2009,a passing mechanical integrity test of the tubing(MITT)to 2500 psi verified the competency of the cement plug. Since then,two additional cement plugs have been pumped,and the well remains suspended with cement to surface. Remaining resources for well 2T-11 are currently being recovered by the CTD laterals out of the injector directly to the north,2T-09. Per this procedure, a P&A will be performed by performing a cement top-off job, if required, followed by excavation and removal of the wellhead. ✓ If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells ConocoPhiiiips 2T-11 P&A Permit to Drill #: 186-097 The objective of the proposed 2T-11 P&A is to excavate 4 feet below original tundra level, remove the wellhead and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document require' 7. Send the casing head w/stub to materials shop. 'hoto document. 8. Weld '/" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2T-11 PTD # 186-097 API # 50-103-20065-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. rhoto document final location condition after all work is completed. Is • i • • Wellbore Schematic: KUP 2T-11 ConocoPhillips i; Well Attributes Max Angle&MD TO 41 d1i_, Wend.APT UWI Reid Name Well Status toll(') 9(8591 Act atm OIKB) Cana +appt 501032006500 KUPARUK RIVER UNIT NJ 4235 5.400.00 6.7890 ,., -" Comment MS Ippon) Date Aotation End Dale KB.lird Ini Rig Release Date 15epOnnry3'::-Z g'MN :edS',1S1nM SSS0:TRDP Lest WO- 41.11 6'6/1086 ndr AnnoleSin Depth MKS) End Dent Annotation Lest Mod...End Oats Last Tag:SL0 6 416 0 4;24,2009 Rev Ranson ADO CEMENTmnem 10/6/2012 Casing Strings Casing Desotpneet Shing O. 'String ID...Top OMB) Set Depth(t...Set Depth tTVD)...String WL..Strntg...Stung Top Red HANGER.26e ' CONDUCTOR 16 15062 3?.0 110.0 1100 6:.50 440 WELDED P Casing Description Stung tl.. String ID..Top MKB) Set Detre II..Set Depth(TVD) Sting Wt. Stro o...Steno Top ihrd SURFACE 95/8 8.765 32.5 29734 29733 3600 755 BUTT Casing Descnpeon Strew 0... String in_.Top(MB) Sat Depth(. Set Depth ROD)..String WI...String...Sting Top flied PRODUCTION 7 6.276 -50 6.1701 5665.1 26.00 J-55 8TC Casing Description thong 0.- String to...Top(thiS) Set Depth 18.. Set Depth(TVD)...Sting Wt..Sung...String Top Red LINER 5 4.151 5960.8 37890 6,139.1 18,00 L-80 LTC Liner Details C(t6KlC1p.4Top Depth 17-110 (TVD) Top Del NomL.. R avi Top 1569) 188591 i`7 nem Descr(ption Comment 10(MI AAS5.960.8 5,503.3 39 29 SLEEVE BOT SETTING SLEEVE 8 EXT eel PBR 4 151 51 SAFETY 41.81 '59765 5,515.5 3930 HANGER BOT LINER HANGER 50 I MG Tubing Strings tubing LMacnplWn Strip Cl... String lD-.1oD(111(61 Set Depth If., Set Depth f1V01_Sting NA...Strom..Meng Top Pet /9511 TUBING S O'e2.3255" 3 1'F 2.932 283 6 390.6 5 835-1 9.30 J-55 EUE-Ord 5804' Coon Details lop Depth MQlT (TAP Top Incl Nenu... PLUG, TOP(NCB) InK91 I') nem Description Comment ID(e) 283 28.3 060 HANGER C1W TUBING HANGER 3.500 SURFACE • 323 en`.. 1,777.5 1,777.4 058 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.812 CLASP UG, 2900"^---�---- 5,711.4 5309.9 3903 PBR BAKER PBR 3.000 TED PUNCHES 1 5.725,1 5,320.6 39.05 PACKER BAKER FHL PACKER 3000 5.297 CEINSD 5,801.0 5,379.4 39.11 SLEEVE AYA BPI SLIDING SLEEVE 2,310 PLUG.2.960 5,803.9 5,381.7 39.11 XO reducing XO REDUCING 3.5x2.375.4.706.6-80,1.995 2.375 IIII CJs Urn6,2915 5.758.8 3940 BLAST RING 1995 5985 it 6,365.4 5.815,7 39.80 LOCATOR BAKER LOCATOR 1.995 6,368.1 5.817.9 3991 PACKER BAKER DB PACKER 3.250 6.382.2 5,8281 3985 NIPPLE CAMCO D NIPPLE 1.812 PBt s7n SIB6.389.9 5.634.6 39.93 SOS CAMCO SHEAR OUT 2.441 tastiete PACK 5,735 ..gnus Other In Hole line retrievable plugs,valves,pumps,fish,etc.) it Top Depth GAS OFT IND) Top Ind 6761 it Top(11558) 711556) ('I Description Comment Run Data ID IIn1 I 2,050 2,949 9 0.71 TBGPUNCHES 1.38"PUNCH GUN,4 SPF,0 DEG PHASED.1.8 GRAM 0/6/2012 2.992 CHARGES G 4F t 2,900 2.899.9 0.27 CMT PLUG PUMPED 15.8 PPG"G"CEMENT INTO TUBING 8 IA. 91112012 0.000 5 aen C CEMENTED TO SURFACE.SURFACE OA DOWN TO 318'. SLEEVE,5101 5,297 4,993.9 42.09 TBG 1'3/8"TITAN TBG PUNCH,4 SPF,0 DEG PHASE. 3'2412012 2.992 PUNCHES MEGNET)C DECENTRALIZED e 5,600 5,2232 38.89 CMT PLUG PUMPED 23BBLS 15.8 CEMENT 10/10/2009 0000 PLYM 5801 533794 39.11 SLEEVE-C AVA BPI SLEEVE 1(26/2007 2.310 6610 Perforations&Slots Shot Tote11001 Bun DVDs Dols Top ITIKBI Bun OMB) mnS) 1CKB1 Zone Oat. IDO... Type Comment 6.331 6,352 5,7833 5,805.4 04.2T-11 10/110986 12.0 IPERF 120 deg Ph,3 3B"HyperJet 5,429 6,435 5,864 9 5.8694 914.21-11 10)1111936 1 0 IPERF -180 deg 55;3 3/8"8750081 6.446 6 434 5.577 7 5,906 5 A-3^_T-11 10'1111906 d 0 IPERF 90 day Ph:.3 3(8"HyperJet PRODUCTION, tau.. CMI'RU6 'S:'General&SaMy 5,999 End Linin Annoninn 172712007 NOTE.CORKSCREWED TUBING FROM 294'SLM TO TOG BOTTOM? 4/:412009 NOTE HYDRAULIC PANEL HAD BEEN REMOVED FROM FUNCTIONING SSSV 4.3384095 12/20010 NOTE:Vmee Schematcau'ANmRg Stlematic9.D I I i 1...q s,aSS PACKEMoteek Tiger ,. I NAME.4asa N I 1 t e Mandrel Details Too Dep01 Top Pon BOW - (TVD) nal 01) Valve Latch Sae TRO sum 6 6298SA35 Sal ToplfdK91 00561 1'1 Mine Model On/ Sent Type Type (del (psi) Pon pate Com... 1 5,661.8 5,273.7 38,97 OTIS LBX 11/2 GAS LIFT DMY R05 0.000 0.0 6/17/1987 2 5,7633 5,350.2 39.10 CAMCO KBUG 1 IOU DMY 855 0.000 00 10/12/1986 IPSO 8.4484.94 - -. • CEMENT PLUG,9981 5,981,9,789\ 18.97ae Is 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-11 • Oper. Rep: Ian Ives PTD No.: 186-097 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ier(specify in commei Onshore/Offshore: Onshore - Suspension Date: 10/10/09 - Date AOGCC Notified: 08/28/10 Sundry No.: 309-339 Type of Inspection: Initial - Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 1205 ' Photos Taken? Yes • IA 250 • OA 20 . SCANNED AUG 1 4 2015 Condition of Wellhead: Wellhead location was verified with the use of a plot plan.Wellhead looked to be in good working condition. IA and OA lines were blinded with gauges.Flowline was attached with 2500 psi.Tree was leaning towards pipe rack. Well had wooden cellar box that was found to be dry and free of any oil.Wellhouse was removed for on-going dirt work. Condition of - Surrounding Surface Surface conditions looked good,there is on-going dirt work. 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: "2T-11 -Current pressure 1250 psi completed 8-30-10(all methanol,bled to zero,clearly was thermal in nature)" Attachments: Photos(3) REVIEWED BY: Insp.Supry ) Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-11_bn.xlsx [ ______________ !Ill - —77 ' - 1 i a ; - ' is • .r..-� 'sem- •r` i "II- , ‘.44. „„„.... ;..,. .• . , . . • . ,. 44.,.. ,,,.. ... , , , . • F : Go ' F .•.! II Ivr . ,. ... u g A , , . ; F.," ,r, :,. ,,,, .. r. _ _ .! 1111 "II 1 L { , _ . 1-1t I , , j pi, U , .. i . N N ■ 0 a l ' z + "R.*fie' O `yW ` Fit t O ' 7 _ gyp�,, C yam_ A` �I dn. O , , ..,„ . . - is `.-; !''j — ..". . . .. ...,... . , ,,,, ..s. 0 , L., . . , ,., L 1 _. ..,,,,,.........,,..... ..,,. . , ,. cA0 \\(.4%,. V)i w Lir oo c4 o - _ `, ` pN0 O TS vD -0Or N .�r O 0 vl O N ` 3 ,,r, Oh CI) P-1 _ :til I ' milk 4 � a C yy y • . . . . . ) 111 7I ..0 .,, �e .... ,,,,. ...„ . if .I ., • DG A iketriivi ':.r.i4 Illirm.:H4eln ''''' . ,. r''''"): '• ,.' r o + / F-' s /It I 1 • O\ PV w ` \ , oNo 0 G N O6> ,—, 00 O co N Pr 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 ~- _0~ ~ Well History File Identifier Organization (done) ,~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [] Maps: ,,~Grayscale items: [] Poor Quality Originals:~ Other, No/Type TOTAL PAGES: ~ NOTES: ORGANIZED BY:~BREN VINCENT SHERYL MARIA LOWELL DATE: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: BEVERLY BREN VINCE~RIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /s/ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd • STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 • 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service El • Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: September 1, 2012 186 - 097 / 312 - 072 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 26, 1986 50 103 - 20065 - 00 `' 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 127 FSL, 556' FWL, Sec. 1, T11N, RO8E, UM June 4, 1986 l6' 2T - 11 ° Top of Productive Horizon: 8. KB (ft above MSL): /1 4 r RKB, 15. Field /Pool(s): 1392' FNL, 1238' FWL, Sec. 12, T11N, RO8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1684' FNL, 1292' FWL, Sec. 12, 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 5970108 • Zone 4 • 6789' MD / 6139' TVD ADL 25569 TPI: x - 499628 y - 5968588 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 499682 y 5968296 Zone 4 ' 1778' MD / 1777' TVD 2667 18. Directional Survey: Yes ❑ No Q 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) • 1520' MD / 1520' 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 37' 110' 37' 110' 24" 225 sx CS II 9.625" 36# J -55 33' 2973' 33' 2973' 12.25" 900 sx AS III, 285 sx Class G 7" 26# J -55 25' 6170' 25' 5665' 8.5" 250 sx Class G, 175 sx AS I 5" 18# L -80 5977' 6789' 5516' 6139' 6.125" 115 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5x2.325" 6391' MD 5725' MD / 5321' TVD, 6368' MD / 5818' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. E' � D Was hydraulic fracturing used during completion? Yes ❑ No ii DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 0 l I 1 2 2012 5350' -6484' 23 bbls 15.8 ppg Class G 2552' -5297' 97 bbls 15.8 ppg Class G AOGCC 0' -2050' 122 bbls 15.7 #ASI 0' -318' in 9.625" x 7" ann. 47 bbls 15.7# AS1 in 9.625" x 7" annulus 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No ra 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 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 BORED LI AR 0 6 2013 $ CMS trig 1 & Form 10-407 Revised 10/2012 ! / � 'R CONTINUED ON REVERSE /2.27.1 Z Submit original only 28. GEOLOGIC MARKERS (List all formations and AIL encountered): 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 1520' 1520' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 6329' 5787' Base Kuparuk C 6356' 5808' Top Kuparuk A 6408' 5848' Base Kuparuk A 6569' 5970' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS te,A d Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 - 4250 Email: Tyson .M.Wiese@conocophillips.com Printed Name H. Gober Title: Wells Enaineerina Supervisor 4 I f Z Signature !A.SS r Phone 263 -4220 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 a KUP 2T -11 e ConocoPhillips 111; Well Attributes Max Angle & MD TD Alaska. k1G Wellbore API /UWI Field Name Well Status Inc( (°) MD (ftKB) Act Btm (MB) cnrl fps 501032006500 KUPARUK RIVER UNIT INJ 42.35 5,400.00 6,789.0 Comment HTS (ppm) Date Annotation End Date KB.Ord (ft) Rig Release Date "' - SSSV: TRDP Last WO: 41.11 6/6/1986 Well Conk' - 2T-11, 10/8/201212 PM Scheme° - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,436.0 4/24/2009 Rev Reason: ADD CEMENT ninam 10/8/2012 Casing Strings Casing Description Strng 0... String ID ... Top MKS) Set Depth (1... Set Depth (TVD) ... String Wt... String . String Top Thrd HANGER, 28 " • CONDUCTOR 16 15062 37.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/ 8 6.765 32 2 2,97 36 J -55 BUTT Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 - 5.0 6,170.1 5,665.1 26.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 5 4.151 5,960.8 6,789.0 6,139.1 18.00 L -80 LTC Liner Details CONDUCTOR, To Depth 37-110 (TVD) Top Inc! Nomi... CEMENT PLUG, 33 Top (RKB) (RKB) (°) Item Description Comment ID (in) 5,960.8 5,503.3 39.29 SLEEVE BOT SETTING SLEEVE & EXT w/ PBR 4.151 SAFETY VLV, ON 5,976.5 5,515.5 39.30 HANGER BOT LINER HANGER 5.000 1.777 "" Tubing Strings ilk TBG @ PUNCHES, 3 Tubing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 2,050 TUBING 3.5'x2.325" 3 1/2 2.992 28.3 6,390.6 5,835.1 9.30 J -55 EUE -8rd @ 5804' Completion Details Top Depth CEMENT (TVD) Top Inc! Nomi... PLUG, 28 Top (RKB) (RKB) (°1 Item Description Comment ID (!n) 28.3 28.3 0.60 HANGER CIW TUBING HANGER 3.500 SURFACE, 32 - 2,973 L.41, 1,777.5 1,777.4 0.58 SAFETY VLV CAMCO TRDP -1A SAFETY VALVE 2.812 GMT P i99000 -- 5,711.4 5,309.9 39.03 PBR BAKER PBR 3.000 PUNCHES 1 5,725.1 5,320.6 39.05 PACKER BAKER FHL PACKER 3.000 5,297 CEMENT I 5,801.0 5,379.4 39.11 SLEEVE AVA BPI SLIDING SLEEVE 2.310 PLUG, 2,900 5,803.9 5,381.7 39.11 XO reducing XO REDUCING 3.5x2.375, 4.70#,N- 80,1.995 2.375 GAS LIFT, illf 6,291.5 5,758.8 39.40 BLAST RING 1.995 5,665 - 6,365.4 5,815.7 39.80 LOCATOR BAKER LOCATOR 1.995 6,368.1 5,817.9 39.81 PACKER BAKER DB PACKER 3.250 a 6,382.2 5,828.7 39.89 NIPPLE CAMCO D NIPPLE 1.812 PBR, 5,711 6,389.9 5,834.6 39.93 SOS CAMCO SHEAR OUT 2.441 PACKER. 5,725 - Other In Hole Wireline retr plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, (TVD) Top loci 5,763 Top (RKB) (RKB) ( ° I Description Comment Run Date ID (in) 2,050 2,049.9 0.71 TBG 1.38" PUNCH GUN, 4 SPF, 0 DEG PHASED, 1.8 GRAM 6/6/2012 2.992 PUNCHES CHARGES 2,900 2,899.9 0.27 CMT PLUG PUMPED 15.8 PPG "G" CEMENT INTO TUBING & IA. 9/1/2012 0.000 SLEEVE - C, CEMENTED TO SURFACE, SURFACE OA DOWN TO 318'. 5.801 SLEEVE, 5,801 5,297 4,993.9 42.09 TBG 1 -3/8" TITAN TBG PUNCH, 4 SPF, 0 DEG PHASE. 3/24/2012 2.992 PUNCHES MEGNETIC DECENTRALIZED Z ... 5,600 5,2232 38.89 CMT PLUG ' PUMPED 23 BBLS 15.8 CEMENT 10/10/2009 0.000 CEMENT 5,801 5,379.4 39.11 SLEEVE -C AVA BPI SLEEVE 1/28/2007 2.310 PLUG, 5,800 Perforations & Slots Shot ' 1 Top (TVD) Btm (TVD) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (.h... Type Comment 6,331 6,352 5,789.3 5,805.4 C-4, 2T -11 10/11/1986 12.0 IPERF 120 deg Ph; 33/8" HyperJet 6,429 6,435 5,864.9 5,869.4 A-4, 2T -11 10/11/1986 1.0 IPERF 180 deg Ph; 33/8" HyperJet 6,446 6,484 5,877.7 5,906.5 A -3 2T -11 10/11/1986 4.0 IPERF 90 deg Ph; 3 3/8" HyperJet PRODUCTION, -5 -6,170 Notes: General & Safety CMT PLUG, • End Date Annotation 5 1/ 1/27/2007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM? 4/24/2009 NOTE: HYDRAULIC PANEL HAD BEEN REMOVED FROM FUNCTIONING SSSV IPERF' - - - -- 6,33143,352 12/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 li il -. -- LOCATOR. 6,365 IS PACKER, 6,368 NIPPLE.6.382 it. 1 I a SOS, 6,390 a Mandrel Details Top Depth Top Pon IPERF, (TVD) Inc' OD Valve Latch Size TRO Run 6,4298.435 Stn Top (RKB) (RKB) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 5,664.8 5,273.7 38.97 OTIS LBX 1 1/2 GAS LIFT DMY R05 0.000 0.0 6/17/1987 2 5,763.3 ' 5,350.2 39.10 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 10/12/1986 IPERF, 6,44643,484 CEMENT PLUG, 5,960 LINER, 5,961.6,789 70, 6,789 • DATE SUMMARY 2T -11 Well Work Summary 3/5/12 WEATHER DELAYED START.IFTED TBG WITH 3' x 1.5" STEM ON 1.SLINKY TOOL STRING TO 5345' SLM. DRIF TO 52' SLM WITH 5' x 2.5" BAILER. D ED TO 192' SLM WITH 5' x 2.25" BAILER. DRIFTED TO 212' SLM WITH 5' x 2" BAILER. COMPLETE. 3/23/12 WEATHER DELAY START DUE TO COLD WEATHER. ATTEMPTED TO PERFORATE TUBING, UNABLE TO GET PAST 281' WITH 1 -3/8" X 5' TUBING PUNCH. SECOND ATTEMPT RAN A 1 -3/8" X 3' TUBING PUNCH. TAGGED AT 5345'. TENSION PROFILE WAS TOO HIGH AT BOTTOM FOR THE SELECTED WEAK POINT DUE TO CORK SCREWED TUBING AND WOULD NOT BE ABLE TO PULL OUT OF WEAK POINT. POOH TO CHANGE WEAK POINT. RESTART IN AM 3/24/12 PERFORATED TUBING FROM A DEPTH OF 5297'- 5303'. TWO PERFORATING RUNS WERE MADE USING 1 -3/8" X 3' TUBING PUNCH GUN LOAD WITH 4 SPF, 0 DEG PHASING, 0.19" EHD. PERFORATED MIDWAY IN THE SECOND JOINT ABOVE TAG DEPTH OF 5355'. 3/24/12 Pumped 100 bbls diesel to tubing taking returns off IA to 2T -12 flowline. Rate was 1.75 BPM and T /I /O pressures were 2400/2000/30 after 60 bbls. Slowed rate to 1.5 BPM and T /I /O pressures were 2250/1950/30 at 100 bbls away. 5/13/12 Pumped 97 bbl of 15.8 ppg "G" cement down the tubing, through the tubing perfs at 5300', taking returns up the IA. Top of cement in the tubing and IA calculated at 2900' Freeze protected the tubing and IA down to 2500' with diesel. t✓ 6/3/12 DRIFT TBG W/ 1.75" S -BLR, SLINKY 1.25" TS TO TAG CEMENT @ 2552' SLM, VERY ERRATIC WEIGHT SWINGS, GET HUNG UP ON FLAPPER, ATTEMPT TO DRIFT 2.85" Z -5 NO -GO, S/D @ 253' SLM, STATE WITNESS MIT -T PASS, POST CEMENT PLUG, PERFORM MIT -IA & OA STEP RATE INJECTION TEST. COMPLETE 6/6/12 PERFORATED 2050' -2053' USING 1.38" TUBING PUNCH GUN, 4 SPF, 0 DEG PHASED, 1.8 GRAM CHARGES. CCL STOP DEPTH AT 2045'. VERIFIED HOLES BY PUMPING DIESEL AT 2 BPM FOR 115 BBLS. ***LEFT IN WELL* ** 34.4' TOOLSTRING AND 1800' 7/32" ELINE * ** 9/1/12 PUMP 122 BBLS OF AS1 15.7# PPG CEMENT DOWN TBG THRU PUNCHED HOLES @ 2050', TAKING RETURNS UP IA TO OPEN TOP TANK. GOOD CEMENT RETURNS AT SURFACE. DOWN OA: PUMP 15.7 AS1 CEMENT, 5 BBLS W/ AGGREGATE, 10 BBLS W/ CemNET, & 32 BBLS NEAT. FLUSH ALL LINES & VALVES CLEAN OF CEMENT. WELL READY FOR MIT'S AFTER 24 HOUR MINIUM SET UP TIME. 9/4/12 (SUB) MITT- IN PROGRESS 9/5/12 MITT- PASSED; MITIA- IN PROGRESS; MITOA- IN PROGRESS 10/8/12 (AC EVAL) IA DD TEST- FAILED DUE TO PSI. INCREASE AND WOULD NOT STABLIZE 10/9/12 (AC EVAL) : IA DDT PASSED, POST P&A. 09 7 11110 21-ci WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 7, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -11 Run Date: 6/6/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20065 -00 SCANNED APR 0 2 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 7 30 V2 Signed: g(1 V 4/ ` • • 7.153'S WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 26, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -11 Run Date: 3/21/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20065 -00 SCANNED APR 0 2 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: - 1 4 /0- Signe d: • • i ,�,. , U 17, AsEA, SEAN PARNELL, �T ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese r } , AI-‹ ', z, =' aw> Wells Engineer / _ 1.".061/7 ConocoPhillips Alaska, Inc. (J P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2T -11 Sundry Number: 312 -072 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2R day of February, uary, 2012. Encl. . STATE OF ALASKA (q 41, f � V • A OIL AND GAS CONSERVATION COMMI�N '` � � � AP FOR SUNDRY APPROVALS 31)- ' /s. a/4141.- 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair w ell r Change Approved R-ogram r A4 4. Suspend V Rug Perforations E Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: Secure Well rk. • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -097 • 3. Address: Stratigraphic f Service r • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20065 -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 -11 . 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): 6789. 6139 • 6690' 6063' 5600' Casing Length Size MD TVD - . Collapse CONDUCTOR 73 16 110' 110' SP _ u SURFACE 2941 9.625" 2973' 2973' PRODUCTION 6175 7 6170' 5665' 4 2032 LINER 828 5" 6789' 6139' FEB [7 ,'Ilaska Qil Gas Cr) , s Commis��0f1 ,__ Anchorage Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubi Gra3 .. - . • 6331'- 6352', 6429'- 6435', 6446-6484' 5789'- 5805', 5865- 5869', 5878' -5907' 3.5 x 2.375 N -80 6390 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 5725 TVD= 5321 PACKER - BAKER DB PACKER MD= 6368 TVD= 5818 SSSV - CAMCO TRDP -IA -SSA MD =1778 TVD= 1777 12. Attachments: Description Summary of Proposal 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: 3/7/2012 • Oil r Gas r WDSPL r Suspended 17 • 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the f going is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name T iese Title: Wells Engineer Signature '05 Phone: 263 -4250 Date f ill - V1 Commission Use Only Sundry Number: 3t2 ( ((�� 572 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test r Mechanical Integrity Test r Location Clearance r �l ynsee c�aV 4:L lam« t C .2 Other: ` / 1 I Subsequent Form Required: / 6 —4 (0 APPROVED BY / / Approved by: COMMISSIONER THE COMMISSION Date 2 // L (/ 1 7 �3Gc Form 10 -403 Revised 1/2010 /� _ 2 /tg //2__ RBDMS MAR 0 2 2012,, - .mit in upa 1; 'ca 1.w nRI PIMAI ' ., zF- • • 2T -11 Fullbore P &A Permit to Drill #: 186 -097 The objective of the proposed 2T -11 Fullbore P&A is to perforate the 3.5" tubing as close to the packer as possible, then cement the tubing, production casing, and surface casing to . further secure the well, until wellhead removal at a later date. Proposed P &A: (further secure, cement to surface) E -line/ Little Red: 1. RIH and detonate 1" Split Shot Cutter at 5,284' KB, or as close to the packer as possible. 2. Pump 105 bbls of Diesel to ensure adequate circ. rate for cementing, and for freeze protect of IA and OA, via jumper line at surface. Pumping: 1. Ensure an approved sundry has been received from AOGCC. 2. Pump 97 bbl of 15.8# cement balanced plug through tubing holes at 5,284', to bring TOC in tubing and IA to 2,900' KB. Perfs below were squeezed off in 2009. Slick Line / Little Red: 1. Nom the slope AOGCC inspector of the upcoming tag and pressure test of the cement plug, providing at least 24 hours of notice to schedule the witness. 2. RIH and Tag TOC at 2,900' KB. Record Results. 3. MIT Tubing to 2,500 psi. MIT -IA to 1,500 psi. Record Results 4. RU LRS to OA and perform a step rate injectivity test. E -line / Little Red: 1. RIH and detonate 1 3/8" Tubing Punch at 2,835' KB, middle of joint #33 of 125. 2. Pump 20 bbls of Diesel through tubing holes to ensure adequate circulation rates. Pumping: 1. Pump 122 bbls of AS1 cement through holes at 2,835' KB, to fill IA and Tubing to surface. When good IA cement returns are at surface, RU on the OA. . 2. Pump 50 bbls of AS1 cement to plug the OA leak @ 318' KB, and bring cement to surface. Use LCM during OA cement job to help plug Surface Casing leak. Little Red: 1. MIT -T with Diesel to 2,500 psi. Record Results 2. MIT -IA with Diesel to 1,500 psi. Record Results. 3. MIT -OA with Diesel to 1,500 psi. Record Results. 4. If cannot get OA cement to surface due to casing leak, plan to perform the final OA cement plug at a later date, when the wellhead is removed. �ev,ou deat f ®1 5,.ferry concerr�f _ No (eferves re vlett necessary �qe y Svs e e U/ fcaw?. - T - 0 9 t welt !� and 7tie pyorecf worK w < �viok c / • )cG r io4 Sir �� � be C i 0 fidermked 7o iP� /4� 00,'7 >44 m We'/ _ 2 T TW 2/22/2012 . KUP 2T -11 Ire Orink GonVc P ili ,- Well Attributes Max Angle & MD TD Wellbore APUUWI Field Name Well Status Ind r) MD (ftKB) Act Btm (ftKB) Alaska. Inc. 501032006500 KUPARUK RIVER UNIT INJ 42.35 5,400.00 6,789.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 41.11 6/6/1986 Well Conflo - 2T -11, 1131/20122: 05: 49 PM Schematic -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,436.0 4/24/2009 Rev Reason: WELL REVIEW osborl 1/31/2012 Casing Strings Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 26 • CONDUCTOR 16 15.062 37.0 110.0 110.0 62.50 H WELDED 9 ' Casing Descript on String 0. String ID . Top (ftKB) Set Depth (L Set Depth (TVD) .. String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 32.5 2,973.4 2,973.3 36.00 J - 55 BUTT Casing Descripti Stri 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTIO 7 6.276 24.9 6,200.0 5,687.6 26.00 J - 55 BTC ° EE Casing Descripti String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 ' k LINER Liner Detai Top De 5 4.151 5,960.8 6,789.0 6,139.1 1800 L -80 LTC #. . Depth CONDUCTOR, (TVD) Top Intl 5004... 37-110 Top (ftKB) (ftKB) ( °) Item Description Comment ID UN 5,960.8 5,503.3 39.29 SETTING BOT Setting SleeveBExt w /PBR 4.151 SAFETY VLV, _ SLEEVE 1,777 5,976.5 5,515.5 39.30 HANGER BOT LINER HANGER 5.000 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3.5 "x2.325" 3 1/2 2.992 28.3 6,390.6 5,835.1 9.30 J -55 EUE -8rd @ 5804' SURFACE. A Completion Details 32.2,973 Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) ( Rem Description Comment ID (in) 28.3 28.3 0.60 HANGER CIW TUBING HANGER 3.500 GAS S LIFT, 665 1,777.5 1,777.4 0.58 SAFETYVLV CAMCOTRDP -1A -SSA 2.812 5,711.4 5,309.9 39.03 PBR BAKER PBR 3.000 IF 5,725.1 5,320.6 39.05 PACKER BAKER FHL PACKER 3.000 PBR, 5,711 5,801.0 5,379.4 39.11 SLEEVE AVA BPI SLIDING SLEEVE 2.310 5,803.9 5,381.7 39.11 XO reducing X0 reducing 3.5x2.375, 4.70#,N- 80,1.995 2.375 PACKER, 5,725 _ 6,291.5 5,758.8 39.40 BLAST RING 1.995 6,365.4 5,815.7 39.80 LOCATOR BAKER LOCATOR 1.995 GAS LIFT. 6,368.1 5,817.9 39.81 PACKER BAKER DB PACKER 3.250 5,763 6,382.2 5,828.7 39.89 NIPPLE CAMCO D NIPPLE 1.812 6,389.9 5,834.6 39.93 SOS CAMCO SHEAR OUT 2.441 SLEEVE -C. Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 5.801 Top Depth SLEEVE. 5,801 (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (In) 5,600.0 5,223.2 38.89 CMT PLUG PUMPED 23 BBLS 15.8 CEMENT 10/10/2009 0.000 5,801.0 5,379.4 39.11 SLEEVE -C AVA BPI SLEEVE 1/28/2007 2.310 CEMENT i r'' t PLUG, 5,600 Pe & Slots ,i„ ., :. Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (886) (ftKB) Zone Date (eh -- Type Comment 1 1 6,331.0 6,352.0 5,789.3 5,805.4 C-4, 2T - 1 0/11/1986 12.0 IPERF 120 deg Ph; 33/8" HyperJet 6,429.0 6,435.0 5,864.9 5,869.4 A-4, 2T -11 10/11/1986 1.0 IPERF 180 deg Ph; 3 3/8" HyperJet 6,446.0 6,484.0 5,877.7 5,906.5 A -3, 2T -11 10/11/1986 4.0 IPERF 90 deg Ph; 3 3/8" HyperJet Notes: General & Safety CMT PLUG, End Date Annotation 5,600 1/27/2007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM? PRODUCTION, 4/24/2009 NOTE: HYDRAULIC PANEL HAD BEEN REMOVED FROM FUNCTIONING SSSV g 12/2/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 IPERF, 6,3316,352 1 LOCATOR, 6,365 PACKER. 6.368 r_ NIPPLE, 6,382 5 ' II 505, 6.390 re IPERF. Mandrel Details 6.4296,435 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 5,664.8 5,273.7 38.97 OTIS LBX 1 1/2 GAS LIFT DMY R05 0.000 0.0 6/17/1987 IPERF, 2 5,763.3 5,350.2 39.10 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 10/12/1986 6,4466,484 - CEMENT PLUG. 5,960 LINER, 5,9616,789 " TD, 6,789 - ` • • 2T -11 Plug & Abandonment (Suspend Well) Current Completion Proposed PRA L J Surface Casing Lead_ - 318' KB on - Ast Cement to sJeaoe 1A - AS1 Comers to Surface • SSSV —1,777' KB I Tubing Hoes — Z 435' KB Top a Class G Cement .. 2400' KS V • 9 VS' 350.1-55 StAace Casing tQ 2.473 KB Tubing Hoes — 5. 254' KB E s. Past Plug TOC in tubing @ 5.353' KS : Ma. ; , Ste. GLV (DMV) — 5.545' KB q gard E: E I asr , �y � � as ru. ,I F3R- 5.7'1' KB ,• rT/� � anta__ L 'J Ni les ....-I . Baker PI-IL Packer- 5,725' KB E it M '. INN (WY: — 5,753' KB :61N3.- Zia maim n » Sliding Sdeem @ 5.901' K8 e e r kl 63 k C 7 264 5f Prod. Casir4 a 6, 170' .B a : C San d Fels: ;.,...: a: 6,33,' -4.352 KB K- n .3 ' Ba DB Pad_e — 8.373' K,8 CamcoD ker NIp r Ie -8,36 KB axes iiii a i ; , E d . w ; A £ard Perfs: g� a m c k 6,422 . 5 n' KB - � ire . _ ' 6,445- 5 -c 4 ' 1 �,. F . k 1'c12 6041036/1310 A a. 7''N 12 -23 -1 f' Liner TO @ 5,764' KB TW 2/22/2012 Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 09, 2011 9:18 AM To: 'Herrmann, Daniel D' Subject: RE: 2T -05, 2T -11 2T -16 Rigless P &A Procedure (PTD 186 -097, PTD 186 -046 , PTD 186 -144) Dan, These three wells all have cement plugs that were pumped fullbore in the last couple of years. It appears that they have all been pressure tested ( witnessed by AOGCC inspectors) after this initial plug was pumped. The wells are officially suspended in our database and the work you are proposing will be additional suspension operations to further secure the wells until final wellhead cutoff and site remediation. The proposed tag depths are very close to the top of the packer and will allow sufficient cement to be circulated to safely abandon the wells. Go ahead a submit 403 sundries with as with the tag depths listed below as circulation points for the cementing ... Regards, Guy Schwartz - ED MAR 0 9 2011 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Herrmann, Daniel D [mailto:JD.Herrmann @conocophillips.com] Sent: Friday, March 04, 2011 4:05 PM To: Schwartz, Guy L (DOA) Subject: 2T -05, 2T -11, 2T -16 Rigless P&A Procedure Guy, We are looking at P &Aing these wells rigless, but before I wrote the procedures for these 3 wells I wanted to check to make sure the State would be ok with it. We are unable to drift to the top of the packer with our slimhole perforating guns, but we are able to get down close to the packer on each of these wells with varying distances from the packer. Our plan would be to perforate and circulate cement down the tubing taking returns up the IA from our perforations to surface. I have attached the wellbore schematics and here are the depths we can drift down to and there distances from the top of the packer. 2T -05: Drift Depth - 6964' SLM Distance from drift to top of packer -172' SLM 2T -11: Drift Depth - 5350' SLM Distance from drift to top of packer - 375' SLM 2T -16: Drift Depth - 7410' SLM Distance from drift to top of packer - 636' SLM Please let me know what questions and concerns you have. 3/9/2011 Page 2 of 2 Cheers, Dan Herrmann Wells Engineer ConocoPhillips Alaska inc. ATO 1586 Office: (907)263 -4619 Cell: (713)703 -5282 jd.herrmann @conocophillips.com 3/9/2011 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 19, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 , .. mn Anchorage, AK 99501 �� A11ChOP Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -11 (PTD 186 -097) 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- 11 (PTD 186 -097). 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, r MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASK* AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Abandon Repair well Plug Perforations r Stimulate Other F Suspended Well 1 Pull Tubing Inpspection Alter Casing � g � Perforate New Pool � Waiver r Time Extension Change Approved Program raj Operat. Shutdown Perforate r Re -enter Suspended 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen r Exploratory [7 ""- 186 -097 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphi Service \ 50- 103 - 20065 -00 7. Property Designation: 8. Well Name and Number: ADL 25569 2T -11 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 6789 feet Plugs (measured) 6394' Cement true vertical 6139 feet ,sunk (measured) NONE Effective Depth measured 6690 feet Packer (measured) 5725 & 6373 true vertical 6063 feet (true vertucal) 5321 & 5821 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110 110 SURFACE 2973 9.625 2973 2973 PRODUCTION 6170 7 6170 6139 n. i k. '._ .� 232010 Perforation depth: Measured depth: 6331'-6484'- Cemented,/ Al; uN Uu GWLC eler*8fW True Vertical Depth: 5789' -5906 - Cemented S A(ICAdfW Tubing (size, grade, MD, and TVD) 2.875, N -80, 6396 MD, 5839 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER'FHL' @ 5725 MD and 5321 TVD CAMCO TRDP - -SSA (CONTROL LINE DEFEATED; NOT LOCKED OUT) @ 1777 MD and 1777 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 F t Development F Service F 15. Well Status after work:S' S�d� Oil r Gas r WDSPL F Daily Report of Well Operations X GSTOR r WAG F GASINJ C WINJ F 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 /Peru KI in Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date 61_111�0_0 7L T Z RBDMIS SEP 913 20 Form 10 -404 Revised 7/2009 Submit Original Only 0 40 K f 01/1�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 -11 Field /Pool: Kuoaruk River /Kuaaruk River Pool Permit # (PTD): 186 -097 Sundry 309 -339 API Number: 50103200650000 Operator: ConocoPhillips Date Suspended: 10/10/2009 Surface Location: Section: 127' FSL, 556 FWL, sec i 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: (1 Q a• jr t Location cleanup needed: #V&7 ✓r- Pits condition: Surrounding area condition: Water /fluids on pad: i110 Discoloration, Sheens on pad, pits or water: �ti Samples taken: AIC> 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: FW 01.101C ld P, 5:5U PA. 05 o K))zP' IX Irr Cellar description, condition, fluids: -PRJ/ V') Vet/ ,� kl twl6 Pz? 1C Rat Hole: ot/0Yya D6t�Rd p Welihouse or protective barriers: P,, )2. ftA Well identification sign: # PAIWIT oW w t& ew $V U fa u--3 I T Tubing Pressure (or casing if no tubing): - �' = /L Annulus pressures: TZ,b",4 /3 / c e2 v 3 0 /o Wellhead Photos taken (# and description): f Work Required: JF r / 'sr taV � Operator Rep (name and signature): AOGCC Inspector: ROD Aft-9 Other Obsery s: 19 - WORI CP1 , Inspection Date: 12ci 1,0 AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: KU P • 2T -11 Conoc(3 t fillips Well Attributes IMax Angle & I TD Inc. Wellbore API /l1Wl Field Name Well Status Incl ( °) MD (kKB) Act Btm (ftKB) 501032006500 KUPARUK RIVER UNIT INJ 42.35 5,400.00 6,789.0 Comment H2S (ppm) Date Annotation Entl Date KB-Grtl (k) Rig Release Date SSSV: TRDP Last WO: 41.11 6/6/1986 Well Cone : -2T -11 10/11f20091:54:18 PM Sd�ematk -AcWal Annotation Depth INKS) End Date Last Mod ay Entl Date Last Tag: SLM 6,436.0 412412009 Rev Reason: CEMENT PLUG Imosbor 10/11/2009 Casing Strings String OD String ID Set Depth Set Depth (ND) String Wt String t Casing Description (in) (in) Top (11I (111 (ftKB) (lbs/ft) Grade String Top Third CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H-40 CONDUCT 110 SURFACE 95(8 8.765 0.0 2,973.0 2,972.9 36.00 J -55 PRODUCTION 7 6.151 0.0 6,170.0 5,665.0 26.00 J -55 LINER 5 4.151 5,976.0 6,789.0 6,139.1 18.00 L-80 SAFETY VLV, � Tubing Strings 1,777 String OD I String ID Set Depth Sat Depth (ND) String Wt String Tubing Description (in) (in) Top (ftKB) (111<8) (ftKB) (lbs/ft) Grade String Top Thrd TUBING 31/21 2.9921 0.0 5,804.0 5,381.7 9.30 J -55 EUE8rdABMOD SURFACE, TUBING 2-3/81 1.995 5,804.0 6,394.0 5,837.7 4.70 N -80 EUE8rdABMOD 2,973 TUBING 1 2718 2.4411 6,394.0 6,396.0 5,839.3 6.50N-80 EUESrdABMOD Other In Hole All Jewelry: Tubinji Run & Retrievable, Fish, etc. Top Depth (ND) Top Incl Top (ftKB) (ftKB) 11 Description Comment Run Date ID (In) 1,777 1,776.9 0.58 SAFETY VLV Camco TRDP- IA-SSA (Control Line Defeated; Not Locked 10/12/1986 2.812 GAS LIFT, Out) 5,665 5,665 5,273.9 38.97 GAS LIFT OTIS/LBX/1.5/DMY /RO -5/ // Comment: STA 1 6117/1987 2.907 5,711 5,309.6 39.03 PBR Baker 10/12/1986 3.000 5,725 5,320.5 39.05 PACKER Baker'FHU 1011211986 3.000 PBR, 5,711 5,763 5,350.0 39.10 INJECTION CAMCO /KBUG/1 /DMY /BK/ // Comment: STA 2 10/1211986 2.875 5,801 5,379.4 39.11 NIPPLE AVA BPL PORTED NIPPLE 10/1211986 2.750 5,801 5,379.4 39.11 SLEEVE -C AVA BPI SLEEVE 1/28/2007 2.310 6,373 5,821.6 39.84 PACKER Baker'DB'w /5'SBE 10/12/1986 3.250 t 1 6,387 5,832.4 39.91 NIPPLE Camoo'D' Nipple NO GO 10/12/1986 1.812 PACKER, 5,725 6,393 5,837.0 39.94 SOS Cameo 10/12/1986 2.441 t i 6,394 5,837.7 39.95 TTL 10/12/1986 2.441 Perforations & Slots Shot INJECTION, Top (ND) - (ND) Done 5,763 Top (ft K13) Bt. (ftKB) I (kKB) (ftKB) Zone Data (sh... Type Comment 6,331 6,352 5,789.3 5,805.4 C-4, 2T -11 10/11/1986 12.0 IPERF 120 deg Ph; 3 318" HyperJet 6,429 6,435 5,864.9 5,869.4 A-4, 2T -11 10/11/1986 1.0 IPERF 180 deg Ph; 3 3/8" HyperJet 6,446 6,4841 5,877.7 5,906.5 A -3, 2T -11 10/11/1986 4.0 IPERF 90 deg Ph; 3 3/8" HyperJet NIPPLE, 5,801 Notes: General & Safe SL 5,801 EE End Data Annotation 5,801 1/27/2007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM? 4/24/2009 NOTE: HYDRAULIC PANEL HAD BEEN REMOVED FROM FUNCTIONING SSSV PRODUCTION, 6,170 IPERF, 6,331 �,352� I PACKER, 6,373 NIPPLE, 6,387 SOS,6,393 TTL, 6,394 IPERF, 6,429-6,435 PERF, CEMENT PLUG, 5,600 LINER, 6,789 TD, 6,789 + + + I I I + + E 16 +00 I °o °o °O I Oo °O lo o 0 N O + D + + N N N < N_ Z 2 2 Z Z Z 2 as NORTH DRILL S 2T I + I + --1-- + I I + E 14 +00 I I �- E 12+00 T-202 — t Ty JY i T-71 1 I ICI Ylel : _ I J - ' 24 9 �T-fE T ♦ � 615 C! F .B R r S$@ .• 2 . T. •� H$O • ♦ N N eR RiiR RI R x a "gg &i3 NF F FA N I 3iii I I II I I + + + I E 10 +00 - - - SCALE • 100 0 50 100 LEGEND O THERMOSIPHONS 1 "= 100' 0 WELLS UNSBUI FORM: BSIZE DRAWN: DESIGN: ECM N D: AREA: 2T MODULE: XXXX UNIT: D2 AJR CC N0: ConocoPhillips PLOT PLAN CHECKED: APPROVAL — — — Alaska,lnc. 1 130 10 1 Thermostphon and Well Asbuilt locations NRB JFC SCALE: DATE: CADD FILENAME JOB N0: SUB JOB NO DRAWING N0: PART: REV REV DATE REVISION BY CHK JOB PROD 1" = 100' 3/13/09 S2T PLT PLN 3/13/09 NSDK 0000 DS2T PLOT PLAN 7 1 1 2T -1 *D 186 -097 ©ConocoPhillips Alaska, Inc c-� This photo is copyrighted by ConocoPhillips Alaska, Inc. and «) cannot be released or published iO without express written consent of ConocoPhillips Alaska CJ 10 W >r •i I , f "W 1F y; ti< y w ti • . � a a 47, r" 2T -11 PTD 186 -097 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska Well Name 2T -11 Notes: Suspended Well Follow -up Start Date 7/1/2010 Days 123 Bleed History End Date 1 1/1/2010 WELL ID TIME STR -PRES END -PRES DIF -PRES CASING SERVICE Annular Communication Surveillance 2T -11 10/18/2010 230 150 80 INNER PWI 3000 WHP - 12 2T -11 10117/2009 50 15 35 INNER PWI i Al n 2T -11 10/1612009 175 50 125 INNER PWI OA D�.�p- 2T -11 10/16/2009 60 1 59 OUTER PWI _ WHCw 2T -11 10/15/2009 780 150 630 INNER PWI 2500 - -- 1 2T -11 5/21/2009 380 300 80 INNER PWI �j u Vt t � 2T -11 4/1/2009 700 475 225 INNER PWI 2T -11 7/6/2008 800 500 300 INNER PWI 2000 - - -_ _ 0 2T -11 6/11/2008 1000 600 400 INNER PWI 2T -11 1212512007 1100 600 500 INNER PWI 2T -11 12/23/2007 750 1300 -550 INNER PWI ILL 2T -11 5/10/2006 1550 1300 250 INNER PWI Q 1500 -- -- - -- - 0.6y 2T -11 5/8/2006 2100 1400 700 INNER PWI 2T -11 5/5/2006 2800 1800 1000 INNER PWI .l /Y 2T -11 12/23/2005 650 400 250 INNER PWI 1000 _ _ 04 2T -11 10/2712005 850 475 375 INNER PWI 2T -11 10/25/2005 1050 700 350 INNER PWI 2T -11 10/23/2005 1005 850 155 INNER PWI 2T -11 6/10/2005 2050 600 1450 INNER PWI 500 - - -- -- - - - -- -- 0.2 2T -11 4/30/2005 800 520 280 OUTER PWI �`- 2T -11 4/16/2005 680 520 160 INNER PWI 2T -11 6125/2004 870 600 270 INNER PWI 0 0 2T -11 519/2004 950 680 270 INNER PWI Jul -10 pug -10 Sep -10 Oct-10 2T -11 4126/2004 1100 780 320 INNER PWI 2T -11 10/2412002 1300 1050 250 INNER PWI o.e �DGI 2T -11 6/10/2002 2000 1650 350 INNER PWI ae �MGI o a.� ��Pwl g 0s„ SWI 0 0s .�BLPD 0.4 0.3 0.2 0.1 0 Jul -10 Aug -10 Sep-10 Oct -10 Date go] �6.L2•!o L~ ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION p~~ 1 ~ ~ppg WELL COMPLETION OR RECOMPLETION REPORT 44~1~,~.C~G „____ 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Plugged ~ Abandoned ~ Suspended 0 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: 1b. s Development ^A49C~n1' ratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 10, 2009 12. Permit to Drill Number: 186-097 / 309-339 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 26, 1986 13. API Number: 50-103-20065-00 4a. Location of Well (Governmental Section): Surface: 12T FSL, 556' FWL, Sec. 1, T11 N, R8E, UM 7. Date TD Reached: June 4, 1986 14. Well Name and Number: 2T-11 Top of Productive Horizon: 1392' FNL, 1238' FWL, Sec. 12, T11 N, R8E, UM 8. KB (ft above MSL): 41' RKB GL (ft above MSL): 82' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1684' FNL, 1292' FWL, Sec. 12, T11 N, R8E, UM 9. Plug Back Depth (MD + TVD): 6690' MD /.6063' Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498945 y- 5970108 Zone- 4 10. Total Depth (MD + TVD): 6789' MD ! 6139' TVD 16. Property Designation: ADL 25569 TPI: x- 499628 y- 5968588 Zone- 4 Total Depth: x- 499682 - 5968296 Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 1777' MD / 1777' TVD 17. Land Use Permit: 2667 18. Directional Survey: Yes ^ No^/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: NIA (ft MSL) 20. Thickness of Permafrost MD/TVD: approx. 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/lateral Top Window MDlTVD not applicable y3, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 225 sx CS II 9-5l8" 36# J-55 Surf. 2973' Surf. 2973' 12.25" 900 sx AS III, 285 sx Class G 7" 26# J-55 Surf. 6170' Surf. 5665' 8.5" 250 sx Class G, 175 sx AS I 5" 18# L-80 5977' 6789' 5516' 6139' 6.125" 115 sx Class G 24. Open to production or injection? Yes ^ No ^ If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD(TVD) 3.5" x 2.375" x 5804', 6394', 6396' 5725' MD / 5321' TVD, 6373' MD / 5822' TVD 2.875" 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 6394' 23 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 Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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 28. GEOLOGIC MARKERS (List all formations and markers countered): 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 - i3ottom 1550' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 6329' S78T Base Kuparuk C 6356' 5808' Top Kuparuk A 6408' 5848' Base Kuparuk A 6569' 5970' N/A Formation at total depth: Kuparuk 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: Jim Ennis @ 265-1544 Printed Na ` J. Ennis Title: Wells Engineer ~ ~ ~ ~ i Signature Phone 265-1544 Date I t ~ Sharon Allsup-Drake V 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 `"' 9 '6! ~~ o--- -- OCT 2 3 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOIk~Q~i~`GasCons.Commission Ar,w6wrene 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter spended Well ^ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Num r: Inc. ConoCOPhilllps Alaska Development ^ Exploratory ^ 186-0 / , 3. Address: Stratigraphic ^ Service Q .API Number' P. O. Box 100360, Anchora e, Alaska 99510 50- 3-20065-00 . KB Elevation (ft): Well Name and Number: RKB 117' 2T 1 Property Designation: .Field/Pool(s): ADL 25569 Kuparuk River Field / K River Oil Pool 11. Present Well Condition Summary: ~~ Total Depth measured 6789' feet _Q true vertical ~ 6139' feet Plugs easured) 6394' Effective Depth measured 6690' feet J k ( easured) true vertical 6063' feet Casing Length ~,TVD Burst Collapse Size MD Structural CONDUCTOR 110' ~ 16" 110' ~ 110' SURFACE 2856' 9-5/8" 2973' ~~ 2973' -.. PRODUCTION 6053' 7" 6170' 5665' LINER 813' 5" 67 ' D~ 6139' 84' ~' ' ' ' ' Perforation depth: Measured depth: -64 , 6 , 6429 -64 -6352 6331 ~~yy g~ nn ~~ N0 ~ ~ ~ 2009 7 ~ ' 5 ' ' true vertical depth: 5878 -590 , 586 - -5805 5789 1~ Tubing (size, grade, and measured depth) 3.5" x 2.3 75", J-55, N-80, 5804', 6394', 6396' MD. Packers &SSSV (type & measured depth) Bake FHL r, Baker'DB' pkr @ 5725', 6373' C co DP-IA-SSA SSSV @ 1777' 12. Stimulation or cement squeeze summ Intervals treated (measured) cement plug @ 6394' pump 23 bbls of 15.8 ppg Class G cement Treatment descriptions includin olumes used and final pressure: 13. Representative Daily Average Prod uction or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operati SI Subsequent to op ration SI 14. Attachments .Well Class after work: Copies of Lo sand Surveys run _ Exploratory ^ Development ^ Service Daily Re rt of Well Operations _X .Well Status after work: Qil^ Gas^ WAG GINJ_I WINJ ^ WDSPL^ 17. I 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: 309-339 co act Jim Ennis @ 265-1544 tinted Name i nis Title Wells Engineer / d Phone: 265-1544 Date V ~ aZa Signature Pre ared b S aron Allsu -Drake 263-4612 ? ~~' 1 Form 10-404 evised 04/2006 ~ ~U`L3~d~j Submit Original Only ~O`z.~~ ~ . 2T-11 Well Events Summary DATE ,SUMMARY 10/10/09 Bullheaded 23 bbl of 15.8 cement down the tubing. Displaced with "nerP' plug followed by 5 bbl of freshwater and 43.5 bbl diesel. TOC ~ 5600 ft(TTL @ 6394'). 10/12/09 Post cement plug MIT passed. Test down the tubing to the TOC @~5600' (TTL @ 6394') to 2500 psi. Ready for AOGCC witnessed 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 10/17/09 BLEED IA & OA TO OPSI. Cono~oPh~lli~s ~-_c;K1i 4no. ... '_.._..._..._WHIConfig.:.T.1,1~i ti.: __ ... Stliema~ic-.AG0. ~CONDUCTOR, .. ~ 1~0 SAFETV VLV. __ _ 1.771 SURFACE, 2.9]3 GASLIFT,_ __. __ 5.665 PBR, 5,'/11 - PAp(ER,S,'/45- - INJECTION. 5,]63 NIP%.E,5.801 SLEEVE~C,~ 5,801 PRODUCTION. ~ ~ 6.' ]0 IPE~F. ~ 6,33".-6.35~ PACKER.6.3]3 s ...1 i NIPP~E.6.38] J~~. ~ KUP Well Attributes WellboreAPl/UWl Fieltll 501032006500 IKUP/ c~me~~ _ SSSV~TRDP Inc 5,665 5.711 5,725 5,763 5,801 5,801 6 484 ~ WellStatus '~Ind K RIVER UNIT INJ ; 4 iY5(pqn) Date MnotationEntlData I ILast WO- I ~~.nd Da~e AnnoGtion 424/2009 Rev Reason: CEMENT PLUG 4.157 BPISIEEVE r'DB' wl 5' SBE co'D' Nipple NO 2T-11 CommeM: STA 1 2T-11 180 deg Ph; 3 3l8" HyperJet 90 deg Ph; 3 3/8" HyperJet MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~~` ~ ~~ i¢~c~. DATE: November 05, 2009 P. I. Supervisor '\ j~ I FROM: Lou Grimaldi SUBJECT: 1/Vellbore Plug Petroleum Inspector ConocoPhillips Alaska Inc. KRU 2T-11 '" Kuparuk River Field/Unit PTD #186-097 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-11. The plugs had reportedly been down squeezed from surface prior to my arrival. The tubing was pressured up with diesel to 2530 psi. The following pressures were observed during the test; Pretest Initial 15 min. 30 min. IA 42 42 42 42 OA 30 30 30 30 Tubing 70 2530 ~ 2500 2490 The test pressure was bled to zero at the conclusion of this test with approximately the same amount returned as was pumped (.85 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 ~ ~~ ~~'is ~ ~ 2009 Non-Confidential Wellbore Plug KRU 2T-11 11-03-09 LG.doc 1 of 1 • ~ ~ ~~ LL~ ~~' ~~~ ~ ~ ~ ~~ ~ ~ ~ n~ ~ ~ ~ " 6 j~:'k d ~ 9~~ ~ ~ .` ~~ ~ ~ ~ ~ ~ ~ ` ~ ~ s " pp F 1 ~ , K f J = ~ . ~. ~.t k ~ < ~ ~. '~. ~ ` ~ a "~ ~ ~, S ~~ ~( '_'}' ~ ~ ~ s d '~ ~ P: fl ~ 1 ~ : ~ ~ '~ ,~°~- g ~ ~ ~ . ~.-~ & ~ i ~ ~,~ ~ ~'~ (. o p ~p-'aq 6 ~~" ~~" ~,~ ~ ~ _ ~ ~~~ ~ s ~. -~ u~~ ~ : ~ ~ ~~d ~ ~ t ~ ~' ~ ~'. ALASSA Du A1~TD ~S CO1~T5ERQA7'I011T CO1~II~IISSI01~ • ~,, ~ SEAN PARNELL, GOVERNOR ~ r,~ ~ 333 W. 7thAVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 '~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 ~~'~,,~~~,1~~ ~y~'"~ ~ ~ ~~~`~ Anchorage, AK 99510 ~ ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-11 ~,/ ~ Sundry Number: 309 339 ~~~~~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroletum 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. ~ ~ ~ 9,~~~, • • ~ ~~ ; ~~._~ ~ STATE OF ALASKA = ALASKA OIL AND GAS CONSERVATION COMMISSION ~..;,,..,:., APPLICATION FOR SUNDRY APPROVAL ~`~~`~ ~ ~ ~ ~~~ ~ 20 AAC 25.280 , , . 1. Type Of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waivef, „~ Other ~ Alter casing ^ Repair well ^ Plug Perforations 0- Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Weli Class: 5. Permit to Drill Number. ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 186-097 • 3. Address: Stratigraphic ~ Service ~. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20065-00 • 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-11 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25569 • RKB 117' Kuparuk River Field / Kuparuk River Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured}: 6789' , 6139' • 6690' 6063' Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 2856' 9-5/8" 2973' 2973' PRODUCTION 6053' 7" 6170' 5665' LI N ER 813' S" 6789' 6139' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6331'-6352', 6429'-6435', 6446'-6484' 5789'-5805', 5865'-5869', 5878'-5907' 3.5" x 2.375" x 2.875" J-55, N-80 5so4', 6394', 63ss' Packers and SSSV Type: Packers and SSSV MD (ft) Baker'FHL' pkr, Baker'DB' pkr @ 5725', 6373' Camco TRDP-1A-SSA SSSV @ 1777' 13. Attachments: Description Summary of Proposal 0 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 ~` Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true d correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Name Jim Enni Title: Wells Engineer Signature Phone 265-1544 Date ~ 7 0 Commission Use Onl f ` Sundry Number: Conditions of approval: Notify Comm~ssion so that a representative may witness 3~~' ,3 3 Plug Integrity ~BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ L~ ~ / ~ Other: ~Q/L~~c.v~ ~h ,OG..I'aY ~i7 c.+• F'h~Sf I ,~ % Subsequent Form Required: ~~ . yo y ~ ~~Yb~~,~ ~~.4 ' k. ' ~ ~ 4 ~J~~ APPROVED BY /- '~S'D Approved by: OMMISSIONER THE COMMISSION Date: / Form 10-403 Revi ed 06/20 6 .~ Submit in Duplicate ~ ~1., !~Q r ~ ~, ~.z~l~b~( ~. ~3 a y ~ ~ ~.~ ~~ • Well 2T-11 Kuparuk Injector ~ Pump cement plug for well control barrier Network 10258892 Well History: 2T-11 was originally completed as a single selective Kuparuk water injector in 1986. In November 1995, the well's service was changed to a WAG injector and it injected gas through May 2006. While on water injection, it failed an MITOA in March 2009 and was subsequently SI. Subsequent diagnostics indicate ~ corkscrewed tubing will not allow drift access beyond 268' 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 5600' MD. ..~- ' Work accomplished to date: 6/1/09 4 Year State Witnessed MITIA - Passed, (AOGCC - Jeff Jones). Initial T/I/0=(si) 950/330/80. Pressured up IA to 1710 psi with 2.3 bbls of diesel. T/I/0=950/1710/85, 15 min T/I/0=950/1620/80, 30 min T/I/0=950/1600/80. Bled IA down. Final T/1/0=(si) 950/300/85. 5/20/09 MITIA - passed; Initial T/I/0= 990/380/90; Initial IA FL @ 120ft. Rigged up LRS to IA and pressured up to 1500psi. with 4.8bbls. of diesel. Start T/I/0= 1000/1500/90; 15min. reading T/1/0= 1000/1420/90; 30min. reading T/I/0= 1000/1390/90; Bled IA to 300psi.10min. fluid; Final T/I/0= 1000/300/90 5l14/09 IA FL @ 240' (600 fps) T/I/0= 1000(si)/350/100 4/24/09 TAGGED @ 6436' SLM WITH 1.25 SLINKY TOOL STRING AND DUMMY DRIFT (ERRATIC PICKUP WEIGHTS, 1300 LBS OFF BOTTOM). MEASURED BHP @ 6440' RKB: 3028 PSI. COMPLETE. NOTE: FOUND NO HYDRAULIC PANEL MAINTAINED ON FUNCTIONING SSSV. 4/18/09 UNABLE TO PAST 268' SLM W/ 5' X 1.5" TOOL STRING. RAN SLINKY TOOL STRING TAGGED @ 6445' SLM W/ 4' OF 1.75"DD BAILER. HEAVY P/U WEIGHTS. RAN 2.79" GAUGE RING TO 2.75" AVA BPL NIPPLE @ 5801' RKB, NO BOBBLING IN WEIGHT IF POOH @ 600 FPM. 4/1/09 T-POT (passed), T-PPPOT (passed), IC-POT (passed), IC-PPPOT (passed), Initial T/1/0= 1900/640/225. Stung into T-PO test port with 650 psi, bled T-PO to 0 psi with no build up in 15 min. Pressured up T-PO to 5000 psi, 15 min 5000 psi, 30 min 5000 psi. Bled T-PO to 0 psi. Stung into IC-PO test port with 0 psi, pressured up IC-PO to 3000 psi, 15 min 3000 psi, 30 min 3000 psi. Bled IC-PO to 0 psi. Final T/I/0=1900/640/225. 3/31/09 MIT-IA ( passed ), IC-POT ( passed ). T/I/0= 1880/700/230. Stung into IC-PO with 700 psi bled to 0 psi, with 0 psi buildup during MIT. Pressured up IA with 6.5 bbls diesel T/I/0= 1880/2700/260. 15 min T/I/0= 1880/2560/260. 30 min T/I/0= 1880/2550/260. Bled IA T/I/0= 1880/475/230. 3/28/09 SCLD; Initial T/I/0= 1680/625/180; Rigged up bleed hose to OA and began charging with lift gas; shot OA FL @ 318ft. (600fps) Waited 15min. shot second FL @ same location; Waited 30min. shot third FL @ same location Final T/I/0= 1680/625/100 3/23/09 2T-11, MITOA - failed, Initial T/I/0= 1450/550/120. Established a LLR of 1.5 bpm @ 400 psi. for a total of 20 bbls pumped. Final T/I/0= 1450/550/140 • Remaining work: 1. RU SLB cementer. Bullhead 60 bbls fresh water down tbg at max rate below 2500 psi followed by 110 sx Class `G' cement w/ additives. Launch "nerf" cmt plug and displace w/ 5 bbls fresh / er, . s.6 ppg brine and 18 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug to 2500 psi. Bleed tbg & IA pressure to zero. 'T~, !/~ CS~Gea~ = ~9 66/S Jim Ennis Page 1 9/17/2009 ConocoPhillips r.l.n~.~i i~lc;. KUP • 2T-11 s _ IMaxAngleBMD 'TD oaia CqNDUCTOR, ~ im snFeTVVLV. -- - ~.~n SURFACE, _ P.973 GAS LIFf, 5,665 PBR. 5.71 t -.. - PACKER, 5,725 INJECTION. ___ _.. 5.I63 NIPPLE,5.801 SLEEVE-C,~_ .. s.eo, PRO~UCTIOV, ~ ~ 6.t1~ IPERF, ~ 633t-6.357 ~ .1 ~ ACKER.6,373 ~- f; ~. I' . , "1 NIPFLE.6,387 ~ C .~ ~ - ~ SOS.6.393 3 ~~ TTL, 6.396 F ~ I IPERF. ~ 6 424-E.435 - IPERf 6,aa6-s.aea " LINER,6.'!69 TD.6.]89 ~----- CONDUCTOR 16 15.062 0.0~ 110.0 62.50 H-00 SURFACE 9 S/8 8.765 0.0 2,973.0 2,972.9 36.00 J-55 PRODUCTION ~~~ ~ 6.157 0.0 6,170.0 5,665A ~ 26.00 J-55 ~~~ ~~ Incl ) Dascription I Comment Run Date ID (ir I.5&SAFETV VLV 'Camco TRDP-IA-SSA (Control Line Defeated; Not Locked 7017~'1986 2.81 Out) L97 GAS LIFT OTIS/LBX/LSiDMY/RO-5/// Comment STA t fi~1'~7987 , 2.9C 5,801 5,379.4 39.11 NIPPLE IAVA BPL PORTED NIPPLE 5,801 53794 39.11 SLEEVE-C IAVA BPI SLEEVE 6,373 5,821.6~ 39.84IPACKER IBaker'DB'w/S'SBE fl~l~'19Sfi Btm 6.429~ 6.435ii 5,864.5 S 869.4 A-0, 2T-11 110/11/1956'I 7.0 IPERF 180 deg Ph; 3 3/8" HyrerJet i 6,44G 6 4&J i, 5.877J 5.906.5 A~3, 2T-11 10/71/7986 ~. 4.0 IPERF 90 deg Ph; 3 3/8" HyperJet Notes: General 8 Safety End Da~e AnnoG~ion ~ 1/27l2007 ~NOTE- CORKSCREWED TUBING FROM 294' SLM TO T8G BOTTOM? 4/242009 NOTE: HYDRAULIC PANEL HALI BEEN REMOVED FROM FUNCTIONING SSSV ~~ i . . .. _._.....___- ~ ~ age 2..,-- 7 ks in advar '`~~ om Maunder, PE AOGCC ~c~,~ \ w c~ ~C~..~C~ Y~ e c~ G:~ZS~~ o~ SCv ecu.~ ~,.) cr ~.~ Zs ~~~ ~ ~-- ~` ~ ~ ~-~'oJ~~~ . ~ c~r~~t~ -~~ c~c ~bS~cl~_sc P ~ ~S sv ~5 -~ 1~v.~ ~w.~ c~,~~ c~-c S~..J ~..c-c~ ~ `-~,X~ ~ ~s. F~S ~O ~~ ~ GC~ V~~ ~ ~rL.~~~~ ~~ `f S ~ p~-r-~-~~~~\ ~, ~~..~-~~o~~~~r, , ~~ .~ ~ So~ ~~ ~ ~~-~~s ~ ~.~e.~,~-~ ~ ~ S ..,JoF--~.-.~~~` ~ s vS ~r~,~ ~~ ~ ~. \ o ~ ~v~ ~-~~S Cs.~.S E ~, c~ O ~ ~ `~~~C ~C ~t`~ t~cQ~`fi `~~P ~ ~~~~~~-~~, ~~~ ~s ~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~~-Z ~ ~ ~c~- ~' w~.` ~ co h~c~ ~ Q ~S ~~`' `~ ` ~ v~~~ ~~. p ~ vJO~ l~ ~ c- p ~,~ ~ , . ~ ~C. ~ `D~ 0 ! ~ Q S ~~ 5( a~ 9/200 MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~~ ~ ~r~(~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska pil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-11 KUPARUK RIV UNIT 2T-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 2T-11 API Well Number: 50-103-20065-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608121554 Permit Number: 186-097-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zT-11 TYPe Inj. N 1'~ ~ 5321 A~ -330 ~ 1710- 1620 1600 -- P.T.D 1860970 TypeTest SPT ~ Test psi ]soo ~ pA so ss ao so Interval aYRTST p~F P ~ Tubing 9so 9so 9so 9so Notes' 2.3 BBLS diesel pumped, 1 well inspected; no exceptions noted. 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 cLDconocophillips.com] Sent: Monday, April 20, 2009 2:48 PM ~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: KRU DS2T Suspected Surface Casing Leaks Follow Up Flag: Follow up 1~2~t ZT- C4 Flag Status: Attachments: Jim, Green 2T-11.pdf ~6-a9 K.2c,~. 27 = v9 I ~ - 1~ 3 ~~ /~- ~In K2c,t Zr - ~ o P ~ ' `~- 09~ 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 in 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 caliper 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 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@conornphillips.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 Subject: KRU D52T 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 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 ~~ C~,n+~c~Ph~llip~s Ata~ska~ 1110. RE: KRU DS2T Suspected Sure Casing Leaks • Page 1 of 2 Regg, James B (DOA) Ki~~°l ~ ~ _ ~ ~ From:... Regg, James B (DOA) _ ~ ~ r ~~ ° 027 Sent: Friday, April 03, 2009 3:47 PM `~~_ Q~~ 3rC? i To: 'NSK Problem Well Supv' Cc: 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 inie~tor intearit 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 (OAx 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 Weil Name '? - t 1 Notes: End Date -i 1'2009 Days 90 Start Date 1 /112009 wHP Annular Communicaton Surveillance IAP - - ---- 2000 OAP WHT 1800 100 1600 -- - - _ _ 1400 -- -- - - 80 1200 - -- __ LL 'a loon - --- - --- - sod soo - - ao soo 400 20 200 -- 0 p Jan-09 Feb-09 Mar-09 Apr-09 4500 ~DGI ~ - ---------__.__ ..__ - - ~MGI 4000 PWI - 3500 ~SWI m a 3000 ~BLPD~ m 2500 - 0 2000 - ~ 1500 - _ 1000 - 500 0 G6 O ~1 i ~ ConocoPhillips Alaska, Inc. sssv - (1777-n7s. OD:3.500) Gas Lift andrel/Dummy Valve 1 (5665-ssss. OD:5.940) PBR (5711-5712. OD:3.500) PKR (5725-5726. OD:6.151) Injection andrel/Dummy Valve 2 (5763-5764, OD:5.313) SLEEVE-O (5801-5802, OD:2.750) Perf (6331352) PKR (6373-6374, OD:4.151) NIP (6387-6388, OD:2.375) TUBING (6394-6396. OD:2.875. ~ 1` ID:2.441) SOS -' (6395-6396, OD:2.875) - Perf (6429-6435) Perf (6446-6484) KRU 2T-11 2T-11 API: 501032006500 Well Type: I IN_J ___ Angle @ TS: 40 deg~a 6330 SSSV Type: TRDP Orig I~ 6/6/1986 I Angle @ TD: 40 deg @ 6789 _ Completion: Annular Fluid:1 __ Last W/O: ~ Rev Reason: _ PULL BPC, Set =-- - B_PI, TAG FILL _ Reference Log:' Ref Log Date: Last U _ate: 1 1/29/2007 Last Tag: 6463' TD: 6789 ftKB Last Tag Date: ,.1/28/2007 C S i _Max Hole Angle: l42 de 5400 _ _ asing tr ng -ALL S_ TR Descn lion ~P _ INGS ND Wt Size To Bottom I P - -- - Grade Thread - - CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING ~ 9.625 0 2973 , 2973 36.00 - I J-55 PROD. CASING _ -- _~ 7.000 __ 0 6170 5665 _ 26.00 i - - J-55 LINER --- bi i S TUB T _ - L 5.000 5976 6789_ 6789 18.00 _ _ -- L-80 n tr o n ING : ~ Size I- ~ _. Bottom TVD Wt Grade ~ - - - Thread 3.500 I 0 -- 5804 5382 ~ 9.30 J-55 EUE 8RD AB-MOD - -- .375 5804 -- - - _ 5838 4.70 ! N-80 EUE 8RD AB-MOD 6394 I _ _ 1 2.875 6394_ P rf i S _ 63__9.6 583.9 6.50 e orat ons ummary Interval TV_D --- Zone Status Ft SPF Date Type Comment _ _ _ _ i _ ; t IPERF 120 deg _- 1 Ph; 3 3/8" HyperJet - 6429 - 6435 5864 - 5869 A-4 I PERF 1_80 deg 4 Ph 3 3/8" HyperJ t e I ~ 38 6446 - 6484 5877 - 5906 A_-3 IPERF 10/11 198 90 deg Ph;- 3 3/8" HyperJet G Lift M l /V d l as an re s a ve 4 - -_ St MD TVD Man Mfr s Man T e V Mfr ~ V T e V OD - Latch Port yp yp TRO I Date Run I Vlv L Cmnt 1 5665_5274 Otis LBX DMY 1.5 RO-5 0.000 0 16/17/1gg7 In'ection Mandr_elsNalv _ es St MD TVD Man Mfr ! Man Type V Mfr V Type '' V OD Latch Port TRO Date Run Vlv - _ - 1 Cmnt 2 5763iL 5350' Camco KBUG DMY 1.0 BK 0.000 0 10/12/1986 ',Other lu s,_ equip., etc __ -- .) -COMPLETION _--__ ---- -Depth _ TVD Ty e~ _____ Description __ _ ID 1777 1777 SSS_V Camco TRDP_-1A-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 6373 _ 5822 PKR _ Baker 'DB' w/ 5' SBE 3.250 _ 6387 5832 NIP ~ Camco 'D' Ni le NO GO 1.812 6395 5838 SOS _ ~ Camco _ _ 2.441 6396 5839 TTL _ _ _ 2.441 General Notes Dat e Note 1% 27/2 007 NOTE: CORKSCREWED TUBING FROM 294' SLM TO TBG BOTTOM ! MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg r¡;(ø' {; /7,1° 7 P.I. Supervisor 1f ..,( c-. DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2I-ll KUPARUK RIV UNIT 2T-11 \q;Ío~ oo.? FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV UNIT 2T-II API Well Number: 50-103-20065-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603143847 Permit Number: 186-097-0 Inspection Date: 6/2/2007 /' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-II Type Inj. W TVD 5320 IA 1250 2350 2300 2300 P.T.D 1860970 TypeTest SPI I Test psi 1500 OA 230 230 230 230 Interval 4YRTST P/F P i/ Tubing 2550 2550 2550 2550 Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ./ NON-CONFIDENTIAL sCANNED JUN· ~ () 2007 Wednesday, June 06, 2007 Page I of 1 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~t6"-- e;q7 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRUI 2T 04118/05 Arend ASRC Well 2T -11 Type Inj P.T.D. 1860970 Type Test Notes: Diagnostic MITIA S P Packer TV.D. Test psi Depth 5320 1500 Tubing Casing Pretest Initial 15 Min. 30 Min. 900 900 900 900 Interval 600 3000 2850 2835 P/F o P Well Type Inj T.V.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.TD. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) SCANNED MAY Ü 2 200~5' MIT Report Form Revised: 05/19/02 MIT KRU 2T-11 04-18-05.xls 4/20/2005 MEMORANDUM TO: Julie Heusser ~t~'~ [-'~ Commissioner THRU: Tom Maunder~L'~ ~ P.I. Supervisor .,~.¢'~,\ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 24, 2001 SUBJECT: Mechanical Integrity Tests Phillips - ~ 2T Pad ~[~'-~/Ol 2T-02, 05, 11, 15, 16 KRU Kuparuk NON- CONFIDENTIAL WellI 2T-02 I Type P.T.D.I1861410 Type Notes: WellJ 2T-05 JType P.-r.D.J1881440 ,type Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ,nj.I ~ I T.v.~. I~ J Tubing 13800 J3800 J3800 J3800 I lntervalJ 4 testI P J TestpsiJ 1438 iCasingj 1950 J 2525J 2525I 2525I P/F I -P testI P I Testpsil 1421 ICasingl 1400 I 2375 I 2375 I 2375I P/F I P P.T.D. J 1860970 Notes: P.T.D.J 1860450 Notes: TypetestI P ITestpsil 1330 ICasingI 1600I 2190I 2190I 2190J P/F I P TypetestI P ITestpsil 1369 ICasingI 750 I 2325 I 23251 23251 P/F I P P.T.D.I 1860460 ITypetestI P ITestpsil 1374 ICasingI 1300I 2490I 2450I 2450I P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to 2T Pad in the Kuparuk river field and witnessed the 4 Year MIT on wells 2T-02, 2T-05, 2T- 11, 2T- 15 and 2%16. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: Attachments: Number of Failures: 0 -- Total Time during tests: 4 hours CC: MIT report form 5/12/00 L.G. MIT KRU 2T Pad 6-24-01 CS.xls 6/25/01 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA L-;' ~'~ ALA.SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown m Stimulate __ Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory _ RKB 117 feet 3. Address Stratigraphic_ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service .~ ~ Kuparuk River Unit 4. Location of well at surface 8. Well number 127' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-11 At top of productive interval 9. Permit number/approval number 1392' FSL, 1238' FWL, Sec. 12, T11N, R8E, UM ~6-97 / 7-133 At effective depth 10. APl number 1620' FSL, 1283' FWL, Sec. 12, T11N, R8E, UM 5o-103-20074 At total depth 11. Field/Pool 1684' FSL, 1292' FWL, ,Sec. 12, T11N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6 7 8 9' feet Plugs (measured) true vertical 6138' feet Cement: 6690'-6789' Effective depth: measured 6 6 9 0' feet Junk (measured) true vertical 6 0 6 3' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 225 Sx CS II 1 1 0' 1 1 0' Surface 2941' 9 5/8" 900 Sx AS III & 2973' 2973' Intermediate 285 Sx Class G Production 61 7 0' 7" 250 Sx Class G & 175 Sx AS I 61 7 0' 5 6 6 5' Liner 81 2' 5" 115 Sx Class G 6 7 8 9' 61 3 8' Perforation depth: measured 6331'-6352' 12 SPF, 120 degree phasing, 6429'-6435' 1/2 SPF, 180 degree phasing, 6446'-6484' 4 SPF, 90 degree phasing true vertical 5789'-5805', 5864'-5869', 5877'-5906' Tubing (size, grade, and measured depth) i~ .... 3 1/2" J-55 set at 5809',23/8" N-80 set from 5809' to 6395' · ,,.C~Jv~[' Packers and SSSV (type and measured depth) FHL Pkr @ 5725', DB Pkr @ 6373', Camco TRDP-1A-SSA @ 1777' 13. Stimulation or cement squeeze summary :~ ~[~.~ Oi! & ~$'lcons, '/' ],Q (i l Convert well from A & C Sand production service to A & C Sand injection service Intervals treated (measured) '~nchoracj8 Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9 8 5 1 1 6 1 - 0 - 1 2 2 5 2 5 6 Subsequent to operation - 0 - - 0 - 6 2 0 0 1 6 5 0 1 2 8 5 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Water Injector ~ Daily Report of Well Operations ~ Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 ' SUBMIT IN DUPLICATE DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER J. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE, ALASKA 99510-7034 PHONE: (90"0 762-2553 . .. _. .. .- - ' ':~ (' t:. '~' , '.~ ;'.,..~ ,. ..... ~ .. · . .,.tc~ .~ " · .,~_.;; i-;:: .. :_.'"' Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kupamk 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 T11N 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, ~:;es E. Eason 'Director cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska Oil & Gas Cons. Commission ~nchoraga .~'.~ u,,r,t.~.,j ,Jr~ r~;c',".::ed paper S t C~.D. CONFIDENTIAL ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF NUMBER NUMBER INITIAL 50-029 INJECTION _..__..__.---- 2B-11 21089 11/19/85 2H-O1 20033 03/15/86 2H-O4 20027 03/15/86 50-103 2T-04 20074 03/30/87 2T-09 20071 03/30/87 27-11 20075 03/30/87 27-15 20062 03/30/87 27-16 20063 03/30/87 50-029 3A-02 21431 01/21/87 3A-04 211;33 01/21/87 3A-10 21~57 01/21/87 ~~ 21458 01/21/87 DATE OF PROFILE/ SURVEY -- 06/16/87 06/05/87 06/07/87 06/15/87 06/16/87 06/21/87 06/16/87 06/16/87 05/25/87 05/87 05/87 05/27/87 05/87 / DATA TYPE REASON FOR WELL ZONES PROFi LE/ PROF I LE/ COMPLET I ON TAKING SURVEY SURVEY WATER SPINNER FOLLOWUP A&C S A&C SPINNER FOLLOWUP A&C S A&C SPINNER FOLLOWUP A&C S A&C SPINNER INITIAL A&C SS A&C SURVEY INITIAL A S A SPINNER INITIAL A&C SS A&C SURVEY INITIAL A&C SS A SURVEY INITIAL A&C SS A SPINNER INITIAL A&C SS A&C SURVEY I N I T I AL A&C SS A SURVEY INITIAL A S A IFs~ INITIAL A&C SS A&C SURVEY INITIAL A S A INJECTION BWPD 3485 1833 590 2500 1200 1650 RECEIVED ,L .' k; / Alaska 0il & Gas Cons. Commission Anchorage c,// ATTACItMENT 1 PAGE 2 CONFIDENTIAL KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 '"X~2B-11 ~ 21089 '"'"",~ 2 tt - 01 ~:.-.'"'" 20033 '"'"~ 2 tl- 04.'-'''/ 20027 50-103 '%'J2T-04 '-"/ 20074 2T-09 20071 "~2T-11 ~ 20075 2T-15 20062 2T-16 20063 50-029 ""~3A-02 ~ 21431 3A-04 21433 3A-10 21457 21 .s8 3A-14 21490 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&C 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 3 1987 Alaska 0il & Gas Cons. Commissiorl Anchorage DEi~XIIT~IIENT OF N~XTUI~AL I~ESOUIICES 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 (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until further notice. Sincerely, ames E. Eason i rector . cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR 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 State of Alaska (+ Sepia) Unocal Vault (film) BPAE Chevron ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK. _ OIL AND GAS CONSERVATION COMb .... SION APPLICATION FOR SUNDRY APPROVALS feet~ 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing El Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] OtherX~ 2. Name of Operator ARCO Alaska, Irc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 127' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1392' FNL, 1238' FWL, Sec. 12, T11N, R8E, UM At effective depth 1620' FNL, 1283' FWL, Sec. 12, T11N, R8E, UM At total depth 1684' FNL, 1292' FWL, Sec. 12, T11N, R8E, UM 11. Present well condition summary Total depth: 5. Datum elevation (DF or KB) RKB 117' (3. Unit or Property name Kuparuk River Unit 7. Well number 2T-11 8. Permit number 86-97 9. APl number '¢ 5o-- 103-200~5 10. Pool Kuparuk River Oil Pool measured 6789' MD feet true vertical 6138' TVD feet Plugs (measured)NOne Effective depth: measured 6690' MD feet true vertical 6063' TVD feet Junk (measured) None Casing Length Size Cemented Measured depth x xx~r)~Yu~p< Conductor 80' 16" 225 SX CSII 110' MD True Vertical depth 110' TVD Surface 2941' 9-5/8" 900 SX ASIII & XXXKq~a~.d<iAte 285 SX Class G 2973' MD Production 6170' 7" 250 SX Class G & Liner 175 SX ASI 6170' MD 81 ' 5" 115 SX Class G 5977'- 6789' MD Perforation depth: measure2'd 6331' - 6352' MD, 6446' - 6484' MD 6429' - 6435' MD, true vertical5789, - 5805' TVD, 5877' - 5906' TVD, 5864' - 5869' TVD, Tubing (size, grade and measured depth) 3-1/2"/2-3/8", J-55/N-80, tbg w/tail @ 6395' Packers and SSSV (type and measured depth) FHL pkr @ 5725', DB pkr @ 6373' & TRDP-1A-SSA SSSV @ 1777' 12.Attachments Description summary of proposal ~ Detailed operations program ,q BOP sketch Convert well from A and C Sand production service to A and C Sand water i 13. Estimated date for commencing operation March 3, 1987 14. If proposal was verbally approved Name of approver 2973' TVD 5665' TVD 5515'-6138'TVD RECEIVEb i;,AR - 2 1987 Alaska Oil & Gas Cons. Commisslor Anchorage 15. I hereby certify that the foregoing is true and c~rrect to the best of my knowledge v,\J?' ~;'-?~.~(."~.~,_¢'.~Title Sr. Operations Engineer Signed :/,</LT(..~.,_d ;;~...) _ ~ Commission Use Only Date 2/24/87 Notify comm4ssion so representative may witness I Approval No. ~ Plug integrity [] BOP Test [] Location clearance I Conditions of approval Form 10-403 Rev 12-1-85 ~.~..-~- - -.~,. · 'Commissioner by order of the commission Date Submit in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CC,v, MISSION ".,WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 86-97 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 103-20065 4. Location of well at surface 9. Unit or Lease Name 127' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1392' FNL, 1238' FWL, Sec. 12, T11N, R8E, UM 2T-11 At Total Depth 11. Field and Pool 1684' FNL, 1292' FWL, Sec. 12, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 117' RKBI ADL 25569 ALK 2667 . 12. Date Spudded 13. Date T.D. Reached /14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/26/86 06/04/86 1 2/05/86* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6789'MD,6138'TVD 6690'MD,6063'TVD YES~ NO []I 1777 feet MD 1550' (Approx) 22. Type Electric or Other Logs Run EPT/PCD/DIL, DIL/FDC/CNL, [~ET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 2973' 12-1/4" 900 sx AS Ill & 285 sx ('.lass G 7" 26.0# J-55 Surf 6170' 8-1/2" 250 sx Class G & 175 sx AS I 5" 18.0# L-80 5977' 6789' 6-1/8" 115 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD n~F~P~[)-5805'TVD, w/12 spf, 60° phasing SIZ~E ........ DEPTH SET (MD) PACKER SET (MD) 6~e{v-a~ ~el ~d ,-o/o"/o-,/2': 6395: 5725" & 6373: 6429'-6435'MD 5864'-5869'TVD, w/1/2 spf, 180° phasing 6446'-6484'MD 5877'-5906'TVD, w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED . S~ ~LL~ui,~d Addu, Ju,,, dar. ed i2/i3/86, for frac~;ure dat' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ' h W~" ~%~ ! ~IJ i~.i~ ',- ?.. ~ ' H , ~Note: Drilled RR 6/06/86. Tubing was run & well perforated 10/12/86. Form 10-407 Rev. 7-1-80 DAM/WC1:172 CONTINUED ON REVERSE SIDE Submit in duplicate~l/// 29. J' . , 30.' .... .... · . , GEOLOGIC MAF],~EI~S . FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6329' 5787' N/A Base Kuparuk C 6356' 5808' Top Kuparuk A 6408' 5848' Base Kuparuk A 6569' 5970' I 31. LIST OF ATTACHMENTS Addendum (dated 12/13/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /~ ~ Associate Engineer Signed ~ ~,/ . Title Date -- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 18, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. " Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ADDENDUM WELL: 6/21/86 12/05/86 2T-11 Arctic Pak w/175 sx AS I, followed by 55 bbls Arctic Pak. Frac "A" sand perfs f/6429'-6435' & 6446'-6484' in five stages per 11/19/86 procedure using Musol, diesel, gelled diesel and 20/40 mesh sand. Press'd ann to 2480 psi w/diesel. Tst ins to 8000 psi; OK. Stage #1 and #2: Pmp'd 30 bbls diesel w/5% Musol, followed by 52 bbls diesel @ 5 BPM. (Pmp'd several days prior to frac job by Production. Well SI until frac.) Stage #3: 30 bbls gelled diesel pad @ 5.7 BPM, 2610 - 2380 psi Stage #4: 22 bbls gelled diesel w/8 ppg 20/40 mesh sand @ 5.7 BPM, 2380 - 3000 psi Stage #5: 51 bbls gelled diesel flush @ 21.2 BPM, 3000 - 3490 psi Pmp'd 6803# 20/40 mesh sand in formation leaving 589# 20/40 mesh sand in csg & tbg above top perf. (Underflushed 2.4 bbls per procedure.) Load to recover 185 bbls of diesel. Job complete ~ 1517 hfs, 12/05/86. 'D~ i%-ling Supervisor CONFIDI N1 ILL INDEFINIT _LY S UB.$ URFA CE DIRECTIONAL SURVEY ~UIDANCE ~'~ONTINUOUS ~-~"~ OOL Company ~co ALASKA, INC. Well Name 2T-11 (127'FSLr556'FWL, SEC 1,TllN,R8E,UM) Fjejd/LocatJorlKUp~J~UKr NORTH SLOPE, ALASKA Job Reference No. 71759 Loaaed By: WEST Date 10/11/86 Computed HALSTEAD .~,~ SCHLUMBERGER '-:~ GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2T-11 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 11-0CT-1986 ENGINEER: WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPCLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 27 DEG 50 MIN EAST SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. 2T-11 KUPARUK NORTH SLOPE,ALASKA SURVEY DATE: 11-0CT-1986 ENGINEER: WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 27 DEG 50 MIN EAST COMPUTATION DATE: 21-0CT-86 PAGE 1 ARCO ALASKAs INC. DATE DF SURVEY: 11-0CT-1986 2T-11 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WEST 117.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET CF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DDGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -117.00 0 0 N 0 0 E 100.00 99.99 -17.01 0 24 S 79 44 E 200.00 199.99 82.99 0 7 N 26 34 E 300.00 299.99 182.99 0 6 N 34 27 E 400.00 399.99 282.99 0 12 S 35 26 W 500.00 499.99 382.99 0 22 S 13 2 E 600.00 599.99 482.99 0 32 S 44 53 E 700.00 699.98 582.98 0 27 N 65 59 E 800.00 799.98 682.98 0 21 N 68 14 E 900.00 899.98 782.98 0 42 S 60 49 E 0.00 0.00 0.00 N 0.00 E 0.42 1.37 0.04 N O.gB E 0.38 0.28 0.30 N 1.37 E 0.29 0.54 0.40 N 1.36 E 0.28 0.52 0.48 N 1.51 E 0.54 0.29 0.15 N 1,43 E 1.31 0.38 0.54 S 1.79 E 1.89 0.24 0.76 S 2.62 E 1.95 0.09 0.47 S 3.28 E 2.51 0.16 0.69 S 4.07 E O. O0 N 0 0 E 0.98 N 87 39 E 1.40 N 77 44 E 1.42 N 73 46 E 1.58 N 72 21 F 1.44 N 84 11 1.87 S 73 13 3.31 S 81 46 E 4-13 S 80 27 E 1000.00 999.97 882.97 1100.00 1099.97 982.9T 1200.00 1199.96 1082.96 1300.00 1299.95 1182.95 1400.00 1399.94 1282.94 1500.00 1499.92 1382.92 1600.00 1599.91 1482.91 1700.00 1699.90 1582.90 1800.00 1799.90 1682.90 1900.00 1899.89 1782.89 0 34' N 79 37 E 0 34 N 88 56 E 0 34 S 84 32 E 0 55 S 56 57 E 0 52 S 36 25 E 1 6 S 30 25 E 0 36 S 38 28 E 0 34 S 36 17 E 0 35 S 14 14 E 0 40 S 11 51 W 3.20 0.25 0.89 S 5.17 E 3.54 0.27 0.78 S 6.10 E 4.07 0.12 0.83 S 7.15 E 5.17 0.09 1.44 S 8.35 E 6.58 0.86' 2.38 S 9.58 E 8.38 0.37 3.99 S 10.40 E 9.88 0.14 5.23 S 11.24 E 10.89 0.16 6.04 S 11.87 E 11.78 2.32 6.79 S 12.38 E 12.89 0.24 8.08 S 12.30 E 5.25 S 80 15 E 6.15 S 82 40 E 7.20 S 83 23 E 8.47 S 80 11 E 9.87 S 76 2 E 11.14 S 69 0 E 12.40 S 65 2 E I3.32 S 63 1 E 14.11 S 61 15 E 14.72 S 56 40 E 2000.00 1999.89 1882.89 2100.00 2099.88 1982.88 2200.00 2199.88 2082.88 2300.00 2299.87 2182.87 2400.00 2399.87 2282.87 2500.00 2499.87 2382.87 2600.00 2599.87 2482.87 2700.00 2699.87 2582.87 2800.00 2799.87 2682.87 2900.00 2899.87 2782.87 0 36 S 20 53 W 0 36 S 29 0 W 0 23 S 39 16 W 0 12 S 51 45 W 0 10 S 73 0 W 0 12 N 42 I E 0 11 N 62 46 E 0 13 N 31 29 E 0 10 N 32 3 E 0 16 N 42 58 E 13.63 0.11 9.08 S 11.98 E 14.29 0.09 10.07 S 11.53 E 14.68 0.27 10.79 S 11.00 E 14.89 0.23 11.21 S 10.66 E 14.91 0.11 11.39 S 10.35 E 14.74 0.25 11.21 S 10.34 E 14.73 0.09 11.02 S 10.67 E 14,67 0.08 10.81 S 10.93 E 14.49 0.07 10.52 S 11.10 E 14.36 0.31 10.24 S 11.36 E 15.04 S 52 50 E 15.31 S 48 50 E 15.41 S 45 32 E 15.47 S 43 32 E 15.39 S 42 16 E 15.25 S 42 41 '- 15.34 S 44 3 15.38 S 45 18 b 15.29 S 46 33 E 15.29 S 47 57 f 3000.00 2999.87 2882.87 0 20 3100.00 3099.87 2982.87 0 30 3200.00 3199.85 3082.85 1 32 3300.00 3299.77 3182.77 3 44 3400.00 3399.05 3282.05 9 16 3500.00 3497.04 3380.04 13 25 3600.00 3593.50 3476.50 16 56 3700.00 3688.43 3571.43 19 28 3800.00 3782.13 3665.13 2i 28 3900.00 3874.37 3757.37 23 58 S 22 46 E 14.74 S 42 40 E 15.35 S 21 24 E 17.16 S 21 26 E 20.87 S 29 35 E 32.48 S 28 1 E 52.28 S 25 44~?. E..... :,78,63 S 23 16i',,,E~ :'~ i-.~Og~. 9'4 0.12 10.54 S 0.61 ll. Og S 1.1g 12.65 S 5.78 16.13 S 4.87 26.62 S 4.48 43.73 S 2.94 67.32 S 2.06 96.00 S 2.82 128.03 S 2.87 163.97 S 11.60 E 15.68 S 47 43 E 11.87 E 16.25 S 46 56 E 12.80 E 17.99 S 45 19 E 14.15 E 21.46 S 41 15 E 19.16 E 32.80 S 35 44 E 29.15 E 52.55 S 33 41 E 40.90 E 78.77 S 31 16 E 53.63 E 109.97 S 29 11 E 67.55 E 144.75 S 27 48 E 81.57 E 183.14 S 26 27 E L, " ' "7 ' c. COMPUTATION DATE: 21-0CT-86 PAGE 2 ARCO ALASKA, INC. DATE OF SURVEY: 11-0CT-1986 27-11 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: WEST 117.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3964.99 3847.99 25 38 4100.00 4054.51 3937.51 27 37 4200.00 4142.33 4025.33 29 16 4300.00 4228.02 4111.02 32 59 4400.00 4310.26 4193.26 36 23 4500.00 4388.85 4271.85 39 36 4600.00 4465,48 4348.48 40 8 4700.00 4541.98 4424.98 40 12 4800.00 4618.18 4501.18 40 31 4900.00 4694.08 4577.08 40 41 S 23 50 E S 26 17 E S 26 38 E S 24 2 E S 21 3 E S 20 29 E S 20 53 E S 21 21E S 21 34 E S 22 6 E 225.07 3.80 269.61 2.31 317.39 2.19 368.87 3.98 425.44 3.57 486.78 2.19 550.53 0.17 614.49 0e47 678.85 0.28 743.59 0.42 203.43 S 96.76 E 225.26 S 25 26 E 243.43 S 116.40 E 269.82 S 25 33 E 286.21 S 137.71 E 317.61 S 25 41 E 332.58 S 160.13 E 369.12 S 25 42 E 385.23 S 181.57 E 425.88 S 25 14 E 443.02 S 203.50 E 487.52 S 24 40 F 503.11 S 226.22 E 551.63 S 24 12 L 563.19 S 249.41 E 615.95 S 23 53 E 623.4'5 S 273.13 E 680.66 S 23 39 E 683.89 S 297.32 E 745.73 S 23 29 E 5000.00 4769.90 4652.90 40 38 5100.00 4845.74 4728.74 40 50 5200.00 4921.09 4804.09 41 22 5300.00 4995.77 4878.77 42 6 5400.00 5069.70 4952.70 42 21 5500.00 5144.84 5027.84 39 30 5600.00 5222.84 5105.84 38 50 5700.00 5300.55 5183.55 39 1 5800.00 5378.20 5261.20 39 9 5900.00 5455.68 5338.68 39 13 S 22 45 E 808.51 S 22 53 E 873.44 S 22 50 E 938.94 S 22 54 E 1005.20 S 23 6 E 1072.29 S 25 4 E 1138.09 S 26 7 E 1200.63 S 26 26 E 1263.53 S 26 53 E i326.54 S 27 6 E 1389.75 0.50 0.41 0.52 0.77 0.42 4.32 0.45 0.39 0.23 0.50 744.17 S 322.20 E 810.93 S 23 24 E 804.22 S 347.52 E 876.10 S 23 22 E 864.79 S 373.09 E 941.84 S 23 20 E 926.06 S 398.96 E 1008.34 S 23 18 E 988.06 S 425.23 E 1075.68 S 23 17 E 1048.40 S 451.87 E 1141.63 S 23 18 E 1104.73 S 479.12 E 1204.15 S 23 26 E 1161.17 S 506.96 E 1267.01 S 23 35 E 1217.47 S 535.28 E 1329.94 S 23 44 E 1273.83 S 563.91 E 1393.07 S 23 52 E 6000.00 5533.05 5416.05 39 20 6100.00 5610.39 5493.39 39 22 6200.00 5687.60 5570.60 39 32 6300.00 5764.79 5647.79 39 27 6400.00 5841.62 5724.62 39 59 6500.00 5918.02 5801.02 40 34 6600.00 5994.05 5877,05 40 14 6700.00 6070.38 5953.38 40 14 6789.00 6138.32 6021.32 40 14 S 27 15 E 1453.10 S 27 14 E 1516.49 S 26 53 E 1580.04 S 19 2 E 1643.38 S 14 12 E 1706.02 S 11 42 E 1768.30 S 7 31 E 1830.05 S ? 31 E 1890.64 S 7 31 E 1944.56 0.50 0.52 1.74 6.22 2.92 1.89 0.00 O. O0 0.00 1330.15 S 592.92 E 1456.32 S 24 I E 1386.50 S 621.97 E 1519.61 S 24 9 E 1442.98 S 651.10 E 1583.08 S 24 17 E 1501.12 S 676.64 E 1646.58 S 24 15 E 1562.60 S 694.36 E 1709.93 S 23 57 E 1625.53 S 708.55 E 1773.25 S 23 33 F 1689.54 S 719.59 E 1836.40 S 23 4 1753.59 S 728.04 E 1898.71 S 22 32 E 1810.59 S 735.57 E 1954.30 S 22 6 E COMPUTATION DATE: 21-0CT-86 PAGE 3. ARCO ALASKA~ INC. 2T-11 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 11-0CT-1986 KELLY BUSHING ELEVATION: llT.O0 FT ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0o00 0.00 -117.00 0 0 1000.00 999.97 882.97 0 34 2000.00 1999,89 1882.89 0 36 3000.00 2999,87 2882.87 0 20 4000°00 3964.99 3847.99 25 38 5000.00 4769.90 4652.90 40 38 6000.00 5533.05 5416.05 39 20 6789.00 6138.32 60Z1o32 40 14 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 79 37 E 3,20 S 20 53 W 13.63 S 22 46 E 14.74 S 23 50 E 225.07 S 22 45 E 808.51 S Z7 15 E 1453.10 S 7 31 E 1944.56 0.00 0.25 0,11 0.12 3.80 0.50 0.50 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.89 S 5.17 E 5.25 S 80 15 E 9.08 S 11.98 E 15.04 S 52 50 E 10.54 S 11.60 E i5.68 S 4? 43 E 203.43 S 96.76 E 225.26 S 25 26 E 744.17 S 322.20 E 810.93 S 23 24 [ 1330.15 S 592.92 E 1456.32 S 24 1 E 1810.59 S 735.57 f 1954.30 S 22 6 E COMPUTATION DATE: 21-0CT-86 PAGE 4 ARCO ALASKA, INC. 27-11 KUPARU'K NORTH SLOPE,ALASKA DATE OF SURVEY: 11-0CT-1986 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -117.00 0 0 N 0 0 E 17.00 17.00 -100.00 0 45 N 69 30 E 117.01 117.00 0.00 0 23 N 71 14 E 217.01 217.00 100.00 0 5 N 14 1 E 317.01 317.00 200,00 0 10 N 52 56 E 417.01 417.00 300.00 0 10 S 36 41 W 517.01 517.00 400.00 0 23 S 17 25 E 617.01 617.00 500.00 0 33 S 49 53 E 717.02 717.00 600.00 0 26 N 65 33 E 817.02 817.00 700.00 0 21 N 68 45 E 917.03 917.00 800.00 1017.03 1017.00 900.00 1117.04 1117.00 1000.00 1217.04 1217.00 1100.00 1317.05 1317.00 1200.00 1417.07 1417.00 1300.00 1517.08 1517.00 1400.00 1617.09 1617.00 1500.00 1717.10 1717.00 1600.00 1817.10 1817.00 1700.00 0 43 S 61 54 E 0 32 N 80 12 E 0 35 S 89 32 E 0 33 S 79 33 E 0 55 S 56 54 E 0 56 S 28 56 E i 3 S 32 26 E 0 36 S 38 54 E 0 32 S 36 14 E 047 S 1 10 E 1917.11 1917.00 1800.00 2017.12 2017.00 1900.00 2117.12 2117.00 2000.00 2217.13 2217.00 2100.00 2317.13 2317.00 2200.00 2417.13 2417.00 2300.00 2517.13 2517.00 2400.00 2617.13 2617.00 2500.00 2717.13 2717.00 2600.00 2817.13 2817.00 2700.00 0 37 S 14 17 W 0 37 S 22 9 W 0 36 S 30 23 W 0 22 S 35 47 W 0 13 S 45 22 W 0 9 S 88 1W 0 12 N 51 17 E 0 11 N 64 3 E 0 13 N 30 21 E 0 10 N 40 10 E 2917.13 2917.00 2800.00 0 17 3017.13 3017.00 2900.00 0 19 3117.13 3117.00 3000.00 0 37 3217.16 3217.00 3100.00 1 38 3317.27 3317.00 3200.00 4 46 3418.21 3417.00 3300.00 10 8 3520.55 3517.00 3400.00 14 12 3624.61 3617.00 3500.00 17 36 3730.36 3717.00 3600.00 20 3 3837.59 3817.00 3700.00 22 24 N 70 33 E S 18 12 E S 40 4 E S 21 ll E S 21 56 E S 30 30 E S 26 48 E S 24 46 E S 23 46 E S 21 26 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 1.56 0.12 N 0.23 E 0.46 0.75 0.05 N 1.09 E 0.35 0.27 0.33 N 1.38 E 0.27 0.34 0.43 N 1.39 E 0.31 0.46 0.43 N 1.47 E 0.65 0.14 0.04 N 1.47 E 1.4'7 0.26 0.65 S 1.91 E 1.90 0.04 0.70 S 2.74 E 1.96 0.11 0.43 S 3.38 E 0.00 N 0 0 E 0.26 N 63 4 E 1.09 N 87 14 E 1.42 N 76 39 E 1.46 N 73 1 E 1.53 N 73 49 1.47 N 88 37 2.02 S 71 13 E 2.83 S 75 36 E 3.41 S 82 39 E 2.69 0.12 0.79 S 4.26 E 3.25 0.17 0.86 S 5.33 E 3.62 0.12 0.78 S 6.28 E 4.16 0.57 0.85 S 7.32 E 5,41 0.06 1.59 S 8.58 E 6.85 0.73 2.61 S 9.73 E 8.71 0.57 4.27 S 10.57 E 10.05 0.09 5.37 S 11.36 E 11.05 0.21 6.18 S 11.97 E 11.98 0.41 7,,00 S 12.39 E 4.34 S 79 31 E 5.40 S 80 51 E 6.33 S 82 53 E 7.37 S 83 24 E 8.72 S 79 28 E 10.07 S 74 59 E 11.40 S 68 0 E 12.56 S 64 41 E 13.47 S 62 41 E 14.23 S 60 30 E 13.04 0.31 8.27 S 12.25 E 13.75 0.10 9.25 S 11.91 E 14.39 0.13 10.23 S 11.43 E 14.73 0.14 10.88 S 10.93 E 14.91 0.19 11.26 S 10.61 E 14.90 0.50 11.41 S 10.31 E 14.72 0.16 11.16 S 10.39 E 14.73 0.09 11.00 S 10.7Z E 14.63 0.05 10.76 S 10.97 E 14.46 0.20 10.47 S 11.13 E 14.79 S 55 58 E 15.09 S 52 9 E 15.34 S 48 10 E 15.43 S 45 7 E 15.47 S 43 17 E 15.37 S 42 5 ~ 15.25 S 42 55 15.36 S 44 16 ~ 15.36 S 45 33 E 15.29 S 46 44 E 14.34 1.47 10.19 S 11.42 E 14.84 0.51 10.64 S 11.64 E 15.52 0.87 11.22 S 11.99 E 17.64 0.53 13.10 S 12.96 E 22.14 6.34 17.32 S 14.61 E 35.54 ~.86 29.26 S 20.70 E 57.20 3.74 48.11 S 31.39 E 85.92 2.96 73.91 S 44.03 E 120.17 1.90 105.42 S 158.70 2.67 141.06 S 15.30 S 48 15 E 15.77 S 47 34 E 16.42 S 46 53 E 18.43 S 44 41 E 22.66 S 40 9 E 35.84 S 35 16 E 57.44 S 33 7 E 86.03 S 30 46 E 57.72 E 120.18 S 28 42 E 72.73 E 158.71 S 27 16 E ARCO ALASKA, INC. 27-11 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 21-0CT-86 PAGE 5 DATE DF SURVEY: 11-0CT-1986 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SD'B-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 3946.88 3917.00 3800.00 25 0 4057.88 4017.00 3900.00 26 36 4171.05 4117.00 4000.00 28 50 4286.90 4217.00 4100.00 32 31 4408.37 4317.00 4200°00 36 41 4536.70 4417.00 4300.00 39 55 4667.32 4517.00 4400.00 40 4 4798.45 4617.00 4500.00 40 31 4930.22 4717.00 4600.00 40 42 5062.06 4817.00 W700.O0 40 40 5194.55 4917.00 4800.00 41 20 5328.66 5017.00 4900.00 42 16 5463.55 5117.00 5000.00 40 57 5592.51 5217.00 5100.00' 38 48 5721.17 5317.00 5200.00 39 1 5850.07 5417.00 5300.00 39 13 5979.27 5517.00 5400.00 39 19 6108.56 5617.00 5500,00 39 23 6238.14 5717.00 5600.00 39 29 6367.85 5817.00 5700.00 3~ 56 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 20 32 E 202.44 S 26 37 E 250.44 S 26 37 E 303.37 S 24 37 E 361.80 S 20 59 E 430,37 S 20 40 E 510.13 S 21 11 E 593.55 S 21 34 E 677.85 S 22 17 E 763.20 S 22 53 E 848.77 6498.65 5917.00 5800.00 40 33 6630.06 6017.00 5900.00 40 14 6761.07 6117.00 6000.00 40 14 6789.00 6138.32 6021.32 40 14 S 22 50 E 935.35 S 22 54 E 1024.38 S 24 2 E 1114.60 S 26 6 E 1195.93 S 26 33 E 1276.85 S 26 54 E i358.18 S 27 16 E 1439,98 S 27 16 E 1521.93 S 24 57 E 1604,32 S 15 21 E 1685.88 S 11 44 E 1767.45 S 7 31 E 1848.27 S 7 31 E 1927.63 S 7 31 E 1944.56 2,39 2.59 0,84 4.32 3.54 0.45 0.60 0.28 0.42 0.38 182.30 S 88.30 E 202.56 S 25 50 E 226.27 S 107.83 E 250.65 S 25 28 E 273.68 S 131.42 E 303.59 S 25 38 E 326.13 S 157.21 E 362,04 S Z5 44 E 389.86 S 183.35 E 430.83 S 25 11 E 465.06 S 211.76 E 511.01 S 24 28 E 543,55 S 241,76 E 594.89 S 23 58 E 622.52 S 272,76 E 679.65 S 23 39 E 702.14 S 304.77 E 765.43 S 23 27 E 781.41 S 337.90 E 851.34 S 23 23 E 0.56 0.45 4,14 0.50 0,39 0.10 0.48 0.38 4.82 1.87 861,47 S 371,69 E 938,23 S 23 20 E 943.80 S 406.46 E 1027.60 S 23 17 E 1027,01 S 442.07 E 1118,11 S 23 17 E 1100.51 S 477.05 E 1199.46 S 23 26 E 1173.09 S 512.90 E 1280,32 S 23 36 E 1245.69 S 549.59 E 1361.54 S 23 48 E 1318.49 S 586.92 E 1443.22 S 23 59 E 1391.33 S 624.46 E 1525,04 S 24 10 E 1464.76 S 661.85 E 1607.35 S 24 18 E 1542.63 S 689.05 E 1689.52 S 24 4 E 1.86 0.00 0.00 0.00 1624.68 S 708.37 E 1772.39 S 23 33 E 1708.79 S 722.13 E 1855.11 S 22 54 E 1792.70 S 733.21 E 1936.84 S 22 14 E 1810.59 S 735.57 E 1954.30 S 22 6 E ARCO ALASKA, INC. 27-11 KUPARUK NORTH SLOPE,ALASKA TOP BASE TOP BASE PBTD TO MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A COMPUTATION DATE: Zl-OCT-86 INTERPOLATED VALUES FOR CHOSEN HORIZONS ORIGIN: MEASURED DEPTH TVD BELOW KB FROM KB PAGE 6 DATE OF, SURVEY: 11-0CT-1986 KELLY BUSHING ELEVA'TION: 117.00 F'T ENGINEER: WEST 127' FSL 556' SUB-SEA 632g.00 5787.15 5670.15 6356.00 5807.91 5690.91 6408.00 5847.76 5730.76 6569.00 5970.42 5853.42 6590.00 6062.75 5945.75 6789.00 6138.32 6021.32 SURFACE LOCATION AT FWL, SEC 1, TllN, R8E, UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1518.71 S 682.23 E 1535.30 S 687.00 E 1567.59 S 695.58 E 1669.68 S 716.72 E 1747.18 S 727.20 E 1810.59 S 735.57 E COMPUTATION DATE: 21-0CT-86 PAGE 7 ARCO ALASKA, INC. 2T-11 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTO TD DATE OF SURVEY: 11-0CT-1986 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: WEST **~,~*~ STRATIGRAPMIC SUMMARY MEASURED DEPTH BELOW K8 SURFACE LOCATION AT ORIGIN: 127' FSL 556' FWL, SEC 1, TllN~ RBE~ UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6329.00 6356.00 6408.00 6569.00 6690.00 6789.00 5787.I5 5670.15 1518.71 S 682.23 E 5807.91 5690.91 1535.30 S 687.00 E 5547.76 5730.76 1567.59 S' 695.58 E 5970.42 5853.42 1669.68 S 716.72 E 6062.75 5945.75 1747.18 S 727.20 E 6138.32 6021.32 1810.59 S 735.57 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6789.00 6138.32 6021.32 1954.30 S 22 6 E SCHLU~BEROER D ]; RECT TONAL SURVEY COMPANY ARCO ALASKA INC HELL 2T-11 FIELD KUPARUK COUNTRY USA RUN 1 OATE LOGOEO 11 - OCT - 86 REFERENCE 0000"7 ! 759 SO0 ] 000 SOO WELL: 2T-11 (127'FSL,556" ~, SEC 1,TllN,R8E,UM) IIZONTAL PROJECTION - 1000 - 500 - 1000 -SO0 0 SO0 ] 000 ] SO0 2000 2S00 WEST EAST -2000 SOUTH ~ WELL,: 2T-11 (127'FSL, 556'FWL qEC 1,TllN,R8E,UM) VEI 'CAL PROJECTION 332, -lO00 -S00 0 0 SOO 1000 1S00 2000 2500 LN~Z..i~;.!' ....... ..... ~-'~.~ '.i",i :., : .~mni.;L ~..ZL;'; ..~.z...ZZ.. 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OPERATOR, WEgL NAME 'AND NUMBER Reports and Materials to be received by:. /--O ~--~7 / Da~e I Required Date Received I Remarks . Completion Report y~..: 1 ~_ ~ ~.__~/ ~~, Well HiSt°ry Samples ~~ ~- ~¢ -*~ ~g Mud Log __ Core Ch~ps C'~re Description R~gistered, Survey Plat :: ~: __::_.: ~~ Inelination Survey Drill Stem Test Reports ~:~" --i---- ~~ ~roduct~on Test Reports ~Y ~':~? Log Run Digitized Data ~~p 7--~ ~- ~ ;~ :_ :~ I~~,. ", , ':. I1~ ~. '~, -. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 17, 1986 Transmittal #5831 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 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. Open Hole Final Logs: 3K--2-~" DIL-SFL-GR 6-19-86 1000-9952 -5" DIL-SFL-GR 6-19-86 1000-9952 ----2" FDC Porosity 6-19-86 8950-9926 ~~c.-5" FDC Porosity 6-19-86 8950-9926 --2" FDC Raw 6-19-86 8950-9928 "5" FDC Raw 6-19-86 8950-9928 ~Cyberlook 6-19-86 9100-9700 3K-1~2" DIL-SFL-GR 6-10-86 4920-8988 ~5" DIL-SFL-GR 6-10-86 4920-8988 .~-2" FDC Porosity 6-10-86 4920-8991 ~5" FDC Porosity 6-10-86 4920-8991 '-2" FDC Raw 6-10-86 4920-8991 '- 5" FDC Raw 6-10-86 4920-8991 ~Cyberlook 6-10-86 8400-8970 2T-11'~2" DIL-SFL-GR 6-5-86 6187-6783 "5" DIL-SFL-GR 6-5-86 6187-6783 ~2" FDC Porosity 6-5-86 6187-6757 ~ '5" FDC Porosity 6-5-86 6187-6757 ~2" FDC Raw 6-5-86 6187-6757 '-5" FDC Raw 6-5-86 6187-6757 ~ Cyberl ook 6-5-86 6187-6783 Receipt Acknowledged: Distribution: NSK Drilling Rathmell Vault (1 film) D & M State ARCO Alaska, Inc. is a SuOsidiary of AtlanticRIchlieldCompany Date: of Alaska(1 bl + 1 se) CONFIDENTIAL " STATE OF ALASKA ALASKA _iL AND GAS CONSERVATION COMMI, .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown :- Stimulate - Plugging -~ Perforate -~ Pull tubing - Alter Casing ~ Other ~ Complete 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaskat Inc RKB 117' Feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 127' FSL, 556' FWL, Sec. 1, T11N, R8E, UH ?T-11 At top of productive interval 8. Approval number 1392' FNL, 1238' FWL, Sec. 12, T11N, R8E, UM 147 ~ ~17 At effective depth 9. APl number 1620' FNL, 1283' FWL, Sec. 12, T11N, R8E, UH 50-- 103-20075 At total depth 10. Pool 1684' FNL, 1292' FWL, Sec. 12, T11N, R8E, UH Kuparuk River 0.il Pool 11. Present well condition summary Total depth: measured 6789 ' kid feet Plugs (measured) None true vertical feet 6138 ' TVD Effective depth: measured feet Junk (measured) true vertical 6690 'ND feet None 6063 ' TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 225 sx CS II 110'MD 110'TVD Surface 2941 ' 9-5/8" 900 sx AS II I & 285 sx Class C 2973 'kiD 2973'TVD Production 6170' 7" 250 sx Class G & 6170'MD 5665'TVD 1 75 sx AS I Liner 812' 5" 115 sx Class G 5977 ' -6789 'ND 5515 '-6138 " Perforation depth: measured 6331 ' - 6352 'MD 6446' - 6484 'MD 6429' - 6435 'MD true vertical 5789' - 5805'TVD 5877' - 5906'TVD 5864' - 5869'TVD Tubing (size, grade and measured depth) ~.. 3-1/2"/2-3/8" J-55/N-80, tbg w/tail ~ 6395' F~#.;''~/'~''.[~-: '. Packers and SSSV (type and measured depth) ~" /..,, FHL pkr ~ 5725', DB pkr @ 6373' & TRDP-1A-SSA SSSV ~ 1777' 12. Stimulation or cement squeeze summary .N/A/;' C'0,%. , In~erva s treated (measured),~.-~;i.,,,.r~ ..... ~';,',,';~;~, .. .... Treatment description including volumes used and final pressure 13.N / A Representative OiI-Bbl DailYGas. Mcf Average Production Water-Bbl or Inject i~~~~l~ Casii, l)rrI''' Prior ,o well operation I Subsequent to operation 14. Attachments (Comp]et'ion We]] History, w/Addendum, dated 7/21/86) Daily Report of Well Operations :~ Copies of Logs and Surveys Run ~ Gyro 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~,~ ~'*,_ Signed Title ~nxt~; .q'~,/~:~ /1-/4'-~/¢_ .. Form 10-404 Rev. 12-1-85 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit ~he "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be suomitted also when operations are suspended for an indefimte or appreciable length of time. On workovers when an official lest is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used Ior reporting the entire operation if space is available. Accounting cost center code Olatflct Alaska Field Kuparuk l~ver Auth. or W.O. no. A~I~ AE0782 County or Parish Lease or Unit Title North Slope Borough ADL 25569 Completion State Alaska IWell no. 2T-11 Nordic 1 O~rator ARCO Alaska, Inc. API 50-103-20065 A.R.Co. w.I. 56.24% Spudded or W.O. begun Date Complete 10/09/86 Date and depth Complete record for each day reported aa of 8:0~ a.m. lO/lO/86 lO/11/86 10112186 Iotal number of wells (active or inactive) on this, DSt center prior to plugging and / bandonrnent of this well our l prior itatul If a W.O. I 1200 hrs. 5" @ 6789'/7" @ 6170' 6690' LC, RIH w/Junk mill Wt. 11.7, PV 17, YP 10, PH 10, Sol -- Accept rig @ 1200 hfs, 10/09/86. ND mster vlv. Stage in hole, tag lnr top @ 5952', CBU, POOH. junk mill. NU & tat BOPE. RIH w/4-1/8" 5" @ 6789'/7" @ 6170' 6690' LC, RR 6.8 ppg Diesel RIH, displ hole w/ll.6 ppg brine. Filter brine, POOH. RU & rn CET f/6620'-5965' WLM. Rn GCT f/6592'-surf. Perf 6446'-6484' @ 4 SPF, 6429'-6435' @ 1/2 SPF & 6331'-6352' @ 12 SPF. Make gage ring/JB rn to PBTD. RIH w/5" pkr, set @ 6373' WLM. RU & rn 184 its, 3½", 9.3#, J-55 8RD AB Mod & 17 its, 2-3/8" 4.7#, N-80 compl w/SSSV @ 1777' & TT @ 6395'. ND BOPE. NU & tat tree to 5000 psi ok. Displ well to diesel. RR @ 1600 hfs, 10/12/86. Old TD Released rig 1600 hrs. Classifications (oil, gas, etc.) Oil INew TD PB Depth 6690 , Date I Kind of rlg 10/12/86 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data ~ell no. I 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 Elfective date corrected ,. The above ia correct f'J~"~L: k = AL For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 6/21/86 2T-11 Arctic Pak w/175 sx AS I, followed by 55 bbls Arctic Pak. Drilling Supervisor Date ARCO Aiast<a.' Inc. Post Office Box 100360 Anchorage. Alasl<a 99510-0360 Tetel~one 907 276 1215 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. return one signed copy of this transmittal. DATE 07-~/-86 TRANSMITTAL # 5702 Please acknowledge receipt and Open Hole LIS Tapes: Schl: One tape plus listing for each 0067.0-2023.5 0995.0-8314.5 1441.5-6812.0 2992.5-9025.0 0994.0-9974.0 ~2T-9 Edit LIS 06-22-86 Run #1 ~21-10 Edit LIS 06-18-86 Run ~1 ~2T-11 Open Hole 06-05-86 Run #2 ~3K-1 Open Hole 06-10-86 Run #1 ~ 3K-2 Edit LIS 06-19-86 Run ~1 Am~m~ Receipt Acknowledged: State of AK ARCO Alaska. Inc. :! · Sul~l,d~lry of Atl·ntlcR~chheldCompany Date: C'ONFIDENTIAL STATE OF ALASKA ALAS,... OIL AND GAS CONSERVATION COMfv~,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation ShutdowrCX:% Re-enter suspended well ¢- Alter casing -" Time extension ~ Change approved program ~ Plugging ~ Stimulate- Pull tubing ~ Amend order-" Perforate- Other - 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage~ AK 99510 Kuparuk River Unjl; 4. Location of well at surface 7. Well number 127'FSL, 556'FWL, Sec.1, T11N, R8E, UM 2T-11 At top of productive interval 8. Permit number 1261'FNL, 1289'FWL, Sec.12, T11N, R8E, UI'4 (approx.) 86-97 At effective depth 9. APl number 1996'FNL, 1110'FWL, Sec.12, T11N, R8E, UM (approx.) 50_103-20065 At ~t~t,¢:~ ¢~.tLh 10. Pool , 1109'F~L, 5ec.12, T11N, ~8E, UN (approx.) Kuparuk ~iver Oil Pool 11. Present well condition summary Total depth: measured 6789 feet Plugs (measured) None true vertical 61 ~7 feet Effective depth: measured 6690 feet Junk (measured) None true vertical feet 6070 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 225 sx CS I1 1lO'MD 110'TVD Surface 2941 ' 9-5/8" 900 sx AS I I I & 2973'MD 2973'TVD 285 sx Class C Production 6170' 7" 250 sx Class G 6170'MD 5670'TVD Liner 812' 5" 115 sx Class G 5977'-6789'MD 5521 '-6147'TVD - Perforation depth: measured None ~-::. ~ /-' ~" ~ '~ ,? ~. true vertical No ne Tubing (size, grade and measured depth) None A~as~<3 0~[ ;~ (:.;..5 L;..;t~3. U None Packers and SSSV (type and measured depth) 12'A[~¢~m~8~S~ory-~....o~ Description summaryof proposal ~ Detailed operations program ~ BOP sketch C0 4 13. Estimated date for commencing operation Augus~ 1986 14. If proposal was verbally approved ~LL ~¢ * E ~ ~.~'-- Name of approver D~fe'~pr6~d - 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~~ Title Associate Engineer Date Gommission ~so Only ( D~H ) Sg/067 Conditions of approval Notify commission so representative may witness [ ApprovalNo. ~ /7 m Plug integrity ~ BOP Test ~ Location clearance ~roved C~? , '. by order of Approved by ~' I ~"~"~ ~, ' ;~J~ ~ ~j~,~, Commissioner the commission Date Form 10-403 Rev 12.1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are slarted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field I County, parish or borough I State Alaska Alaska North Slope Borough ILease °r Unit IWell no. Kuparuk River ADL 25569 2T-11 I Title Drill Auth. or W.O. no. AFE kF0782 Rowan 34 API 50-103-20065 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W,O. begUnspudded IDate 5/26/86 IH°ur 1830 hrs. IPri°rstatusifaW'O' Date and depth as of 8:00 a.m. The above is correct 5/27/86 Complete record for each day reported 5/28/86 5/29/86 5/30/86 5/31/86 thru 6/02/86 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 16" @ 110' 1600', (1490'), Drlg Wt. 9.3, PV 16, YP 12, PH 9.5, WL 11.2, Sol 7.3 Accept rig @ 1200 hrs, 5/26/86. NU diverter sys. 1830 hrs, 5/26/86. Drl 12¼" hole to 1600'. Spud well @ 16" @ 110' 2987', (1387'), Wiper trip Wt. 9.8, PV 20, YP 25, PH 9.5, WL 9.8, Sol 11 Drl to 2811', C&C, POH. RU Schl, log EPT/PCD/DIL to 2230' RIH, wsh f/1676'-2377', drl 12¼" hole to 2987', C&C, POH. log EPT/PCD/DIL f/2980'-surf. RIH f/wiper trip f/9-5/8". RU & 4316' 33.6° S24 7E, 4241TVD, 363 VS, 333S, 148E 5535', 38.7°, S26.2E, 5178 TVD, 1142 VS, 1041S, 473E 6125', 39.7°, S30.5E, 5635 TVD, 1515 VS, 1370S, 560E 9-5/8" @ 2973' 3277', (290'), Rm'g Wt. 8.4+, PV 13, YP 9, PH 10.5, WL 7.6, Sol 9 Tst BOPE. TIH, wsh f/2855'-2892', tst csg to 2000 psi. DO flt equip & cmt + 13' new hole. Conduct formation tst to 12.7 ppg EMW. Drl & surv to 3277', TOH; tight, rm 3 jts. 9-5/8" @ 2973' 6200', (2923'), Prep to rn 7" Wt. 9.7, PV 12, YP 6, PH 9.0, WL 8.4, Sol 14 Raise mud wt to 8.8 ppg, TOH. TIH, wsh 3232'-3277', slide 3277'-4159' bldg angle, TOH, PU turbine. RIH, drl & surv f/4159'-5860', lost circ. Pmp LCM pill, TOH 16 stds, hole not taking proper fill. Att to circ, no rtns. SI & observe. Pmp 10.6 ppg mud in DP, circ @ 4372', balanced mud @ 9.7 ppg. Stage in to 5860', drl to 6200', circ, TOH, LD DP. 3225', 1.6°, S18E, 3225 TVD, 2 VS, 2S, 1E ..... ~-'- 3726' 19 9° S23E, 3714 TVD, 102 VS, 93S 43E -~ ~ .... 't'~ i' '!~":i~ , · , ~ ~. ~ 9-5/8" @ 2973' 2987', (0'), Tst BOPE Wt. 9.8, PV 15, YP 10, PH 9.0, WL 10.2, Sol 11 TIH to 2945', wsh to 2987', circ, TOH. RU & rn 74 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 2973', FC @ 2890'. Cmt w/900 sx AS III & 285 sx C1 "G" w/2% S-1 & .2% D46. Displ using rig pmp, bump plug. ND diverter, NU & tst BOPE. ARCO Oil and Gas Companyv'~' 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 all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheels unlil linal 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 ol oil string until completion. District Field Date and depth 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 6/04/86 6/03/86 State Alaska Well no. 2T-11 7" @ 6170' 6200', (0'), NU BOPE Wt. 9.6+, PV 11, YP 9, PH 9.0, WL 8.1, Sol 12 RU & rn 151 jts, 7", 26~J, J-55 BTC csg w/FS @ 6170'. Cmt w/250 sx C1 "G". Displ using rig pmps, bump plug. Instl pack-off, NU BOPE. 7" @ 6170' 6358', (158'), Drlg Wt. 11.2, PV 14, YP 10, PH 9.5, WL 6.4, Sol 14 NU BOPE. RIH to FC, tst csg to 3500 psi. DO FS + 12' new formation. Conduct formation tst to 12.5 ppg EMW. Drl 6-1/8" hole to 6358'. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 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 lest 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 AK0782 County or Parish Lease or Unit Title North Slope Borough ADL 25569 Drill Slate Alaska [ Well ~_ 1 ]. Rowan 34 Operator ARCO Alaska, Inc. API 50-103-20065 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 5 / 26/86 Date and depth Complete record for each day reported as of 8:00 a.m. 6/05/86 6/06/86 6/07/86 thru 6/09/86 I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our I Prlor status if a W.O. 1830 hrs. 7" @ 6170' 6789', (431'), Logging Wt. 11.7+, PV 23, YP 15, PH 9.5, WL 6.4, Sol 16 Drl & surv 6-1/8" hole to 6789', short trip to 7" csg shoe, C&C, POH. RU Schl, log DIL/FDC/CNL f/6789'-6187'. 5" @ 6789' 6789', (431'), ND BOPE Wt. 11.9, PV 22, YP 17, PH 9.5, WL 6.6, Sol 16 Fin log rn #1, RD Schl. RIH, circ out gas & raise mud wt f/ll.7+ - 11.9 ppg, POH. RU & rn 17 jts, 5", 18#, L-80 lnr. Cmt w/l15 sx C1 "G" w/3% KC1, .9% D-12~, .3% D-13 & .2% D-46. Displ'd cmt w/mud & bump plug. Displ'd 2000' w/diesel. ND BOPE. (TOL @ 5977', LC @ 6690', 5" FC @ 6739', 5" FS @ 6789') 5" @ 6789' 6789' TD, (0'), RR ND BOPE, Inj 30 bbls diesel in 9-5/8" x 7" ann. 6/6/86. Old TD New TD 6789 ' TD Released rig Date 0930 hrs. Classifications (oil, gas, etc.) Oil 6/6/86 RR @ 0930 hrs, CONFIDEhlTIAL i ..... PB Depth 6690' PBTD J K nO of rig Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test lime 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. loaf%/-Z'4D/k~)~ JTitle Drilling Supervisor --- STATE OF ALASKA ALAS,, . OIL AND GAS CONSERVATION COMM,JSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension .'~ Change approved program~l~ Plugging ~ Stimulate '~ Pull tubing ~ Amend order ~, Perforate F~ Other- 2. Name of Operator~ 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 117~i PAD 82~ fe ~t 3. Address 6. Unit or Property name P. O. Box IO0~RO An~hnrnO~' A~ qq~l~ Kuparuk River UniS 4. Location of well at surface 7. Well number 127~FSL~ 556~FWL~ Sec.l~ T11N~ R8E~ UH ?T-11 .. At top of productive interval 8. Permit number 1261~FNL~ 1289~FWL~ Sec.12, T11N~ R8E~ UH 86-97 At effective depth 9. APl number 50-- 1 03 -20065 At total depth 10. Pool I~80~FNL~ I~05~FWL¢ Sec.12~ T11N~ R8E~ UH Kuparuk R~ver 0~1 Pool 11. Present well condition summary Total depth: measured Same as feet Plugs (measured) None feet true vertical approved perm~ =. Effective depth' measured feet Junk (measured) true vertical feet N o n e Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 cf 1150'MD 115'TVD Surface 2938' 9-5/8" 1185 sx 2973'MD 2973'TVD Intermediate 6166' 7" 200 sx 6200'MD 5700'TVD Perforation depth: measuFed None R CE VED true vertical None JUNO 1986 Tubing (size, grade and measured depth) None ~Ka 0~ & Gas Cons. ,'; ~ ~ Packers and SSSV (type and measured depth) None 12.Attachments Description summaryof proposal ~ Detailed operations pro~~ [~ ~l~t 13. Estimated date for commencing operation ~~ ~1 14. If proposal was verbally approved ~ ~ ~ ~ Name of approver H~ ke H~ nder, AOCCC Date approved 6/2/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~~ Title Associ ate Engineer Date ~-~-~ _ Commission Use Only ( HRE ) SA/051 Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity ~ B~PTest:. ~:~cationclearance, / ~ F.,i~ ~ ,. . ? ~:,* ~:~;~ (~.;~i-~¢.~ ~ ~ by order of / Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 2T-11 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to expected bottomhole pressures and inadequate leakoff results, ARCO Alaska, Inc., proposes to alter the well geometry as follows: 1. Drill 8-1/2" hole to 6200'. 2 , Run 7", 26.0#, J-55, BTC casing and cement with a minimum of 200 sx Class "G" cement. 3. Drill 6-1/8" hole to original planned target at 6695'MD/6160'TVD. 4 , Run and cement 5", 18.0#, L-80, LTC production liner from 6000' - 6695'MD. 5. Complete well as per approved Permit to Drill. Any questions can be directed to Mr. Harry Engel at 263-4882. SA/051 a: tw 06/03/86 CONFIDENTIAL May 15, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 2T-11 ARCO Alaska, Inc. Permit No. 86-97 Sur. Loc. 127.'FSL, 556'}~q~, Sec. 1, TllN, R8E, UM. Btmhole Loc. 1480'FNL, 1405'F~., Sec. 12, TllN, R8E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. .To aid us in scheduling field work, please notify this office 24 hours prior to connnencing 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, t-~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. . tru~y~y~ur~s.., Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO3~ISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. L owery - STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C,. AMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory Fi 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 Oi 1 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) 127'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit .Statewide At top of productive interval 8. Well nu .tuber Number 1261'FNL, 1289'FWL, Sec.12, TllN, R8E, UM 2T-11 #8088-26-27 At total depth 9. Approximate spud date Amount 1480'FNL, 1405'FWL~ Sec.12, T11N, R8E, UM 05/20/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthIMDandTVU/ property line 6695 'MD 3800 feet 2T-12 25'@ surface feet 2560 (6160'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure Isee 2o AAC 25.035 (e)(2)) Kickoff depth2960 feet Maximum hole angle 35 0 Maximum surface 1 626 psigAt totaldepth ¢'VD) 3472 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2a.'' !6" E2.5.# H-qO Weld 80' ~5' ~5' !!5' 115' +200 cf 17]~.~, q_r_,/.~,, '~ n.~ I-r~r-, RTP 977¢,' 'A_c,, %c,, ...... ?Rll ' ._o.O. ll .............. ' Rlfl ~,,: Aq II I & HF-ERW 28.5 sx Class 8½" 7" 26.0# J-55 BTC 6661' 34' 34' 6695' 6160' 300 sx Class G HF-ERW 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 Surface ' Intermediate I 1,,, Production · . Liner Perforation depth: measured true vertical .. 20. Attachments Filing fee .~ Property plat .'~ BOP Sketch ~' Diverter Sketch ~ Drilling Program ~ Drilling fluid program '~ Time vs depth plot [] Refraction analysis ? Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoi, Q,g is true and correct to the best of my knowledge Signed //~_,,¢/~,~/~'~:,/x,~'// Title Regional Drilling Engineer Date~/,~' /- ~U~/ ~ "'~'~- Commission Use Only (LWK) PD/PD261 Perm it N u m,~r~C'r / JAPInumber ..~ I Appro~.l/¢~tt~ I See cover letter /" ? 7 50- /:, :. ~ ,> ,:, :'-..~, / 8 6 ¥~, , -_ - for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required ~ Yes ~'xNo Hydrogen sulfide measures D Yes ~ No Directional survey required ~Yes ~ No Required workin~suef~,~ ~ 5M;//~ ~~ [] 10M; ~ 15M Other: by order of Approved by~ E "~ ~ ~'¢/'~~4) Commissioner the commission Date Form 10-401 Rev. 12-1-E 5 Submit in triplicate 6 5 I. (DEC)< AND FILL ACC~TCR RESERVOIR TO'F~ LE-V~ ~ITM MYDRALLiC FLUID. 2. A-S._qLIR~ THAT AC~TC~ PR~5~ IS ~ PSI W]TN I~ PS~ ~T~ a= T~E 3. ~~ Ti~, ~ ~ ~ ~ITS SiXThlY P~~. 13-5/8" BCP STAO< TEST 4 I3 2, I. FILL BCP STACK ArC) C-~ N'ANIF(~ WiTH ARCTIC DIES~. 2. ~ ~T ~ L~ ~ ~~ IN ~~ ~ ~Y ~RA~. ~T ~T ~ ~N ~~ WI~ ~'I~ ~ ~ ~ ~N L~ S~. LI~ V~vEs ~~ ~0 ~ STA~ ~ ~ ~~~~ T~~~ ~~F~ ~O~]N. BLm~ ~~ TO~ L]~ VALVES. ~ T~ P~PE ~ ~ ~ V~VES TEST B~. PIPE ~ ~0 ~ ~I ~ ~ 9. ~ B~ PIPE ~, ~ ~ ~I~ ~ ~ PSI. 11, ~ ~I~ ~ ~ ~I~ ~ST ~. ~ ~UID. ~ ~ VALVES IN ~I~I~ TEST ST~i~ VALVES, ~lY, ~IY ~S, PI~ S~ VALVE, ~ I~I~ B~ TO ~ PSI 3~ PSI. 13. ~~ TEST ]~~T~ ~ ~~ ~ CONFIDENTIAl ! 51c~o84OOl REV. 2 AC~ATOR CAPACITY TEST KUPARUK R I VER UN I T 20" D I VERTER SCHEM/~T I C . · 2. 3. 4, S. $. · DE SC R I PT I ON - 15" CONDUCTOR. TANKO STARTER HEAD. TANKO SAVER SUB. TANKO LONER QUICK-CONNECT ASSY. TANKO UPPER QUICK-CONNECT ASSY. 20" 2000 PSI DRILLIN@ SPOOL N/lO" OUTLETS· 10" HCR'BALL VALVES N/lO' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 03S (b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH DIVERTER LINES EVERY 12 HOURS. -. -3.'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 C I RCUMSTANCES. CONFIDENIJAE INDEFiNII[LY S ] 0084002 RIO GENERAL DRILLING PROCEDUT KUPARUK RIVER FIELD DEVELOPMENT WELLS -. 1o Move in rig. 2. Install Tankco diverter system. 3. Drill 12~" 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 t° provide 100' between plug back total depth and bottom of Kuparuk sands. 10. -Run and cement 7" casing. P_ressure 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. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel and ~et packer. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. CONFIDENTIA L . . . LWK4/ih DRILLING FLUID PROGRAM DenSity Spud to ~.~ = 9-5/8" SUrface Casing 9.6-9.8 pV 15-30 Yp 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7' Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: Triple Tandem Shale Shaker - 2 Mud Cleaners Centrifuge Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. 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. CONFID NTIA INDEFINITELY' . BASE-PERMAFROST TVD=l'561 TOP UGNU SNDS .TVD=1706 ..... ~._-:-.__ ..... sooo ' ' -' .AVERAGE .... ANGLE .................... ..... : ' -- g4- -DEC 58 _ - T/ ZONE C TvD=5806 TMD=6263 DEP=1570 _ . ................ 6000 ' , iT/ ZONE A~ TVD=5876 TMD=6348 DEP=1619 .... ' T--CNTR ...... TVD=SgO1'-TMD=6379 DEP=1'636 - ' . . . i '-- B/ KUP SNDS TVD=Sg96 TMD=6495 DEP=1703. .... ! " : ' ~ - TD (LO0 PT) "TVD=6160 TMD=6695 DEP=1817 '· ! ' ~ - - - ; ...... · i - 0 - 1 000 2000 · . vERTicAL SECTION 3000 . ...... - . _ _ 2000 TOP W SAK SNDS TVD=2271 ........................... ~ ........................ ! ...... 11 000.. , ! . SURFACE [OCATION~ ' ; 127' FSL~ $56' FWL. ; . SEC. I. T11N. R8E ~ ................ ~ .............. ~ ..... 1 000; HORIZONTAL.. PROJECT.]: ON'! SCALE 1 IN. = IO00'FEET , . . . - PAD 2T. WELL NOL 11' :PROPOSED ~ . lOOO 2000 ...... 3000 .._ " WEST4EAST-! '-.-:i :i. :_' t '' ;1000 ~ 2000 '" 13000 . I - ~ · ~ ' - .................................. ....: ......' ;' "! - ; ...... i ................ I ......... L .,.2. _ · . · ,S 27 1636' DEG .50 M! N E (TO .... TARGET) TARGET CENTER TVD-590! , THD-6379 , .... ......... ;.....i .............................. '"*'"i ........ :'"':'" DI~P=1636" ' ' sOU,.' ' ' ! i E/~$T :764 TAROET~ LOCAT ON, '. ......... ~ ~ 1320' FNL. 1320' F~L ' ' ' ; ; ~ SEC. '12, TIIH, RBE 'TTT'¥'~,, .~..,' .............. ~ i , ~ t~~ ',. i,. ~ ~ i . ~1480' ENL., 1405" F~L .~ r , ;SEq~ 12; TI1N. R8E 200 · ~00 i i " ", I ' . . 1 .............. i'--:--- ...................... ~'1 455 · . I . ~oo 5oo .00 ', i~ ooo ] . 2O72 ....... I 500 ! ...',. - ." ~ ._i .... X ..... -: ............ · ~', :~737 i ;, ;, .:..I ' ',; ,... , '.1; !:,., ,.':'!, , '.', , ," ' ,(:o6:.;.,,,; .......... i..." I , 1,,,,_,. , ~1 ,,, .,,, .: , ..L..~...~ ~-i'-i-'i-"4'"l' :'"!-'"~-" '? '"-, ..... J- t""~ ...... 1 ........ .I---.L.-! .............. 4--..-~-.-; .... 1 ......... ,,'. i.. ', , , i I : ' ';'J J ' ' .,'"~.l.J..;-:. J J ; ' ~.,,!,~ ,', ., ,...,,..~_, ,. ,., ,,. ..,.._,. .......... ._.~_.~ .......... :._~,_J.._.._.; ............ :_.....=..'.j_~.-"_;.....~,_%.; .... ,,.: . 1421 i ''J ' I' . ' I .' I ' ? ~.~''~ ! .......~',-' "-T ..... ' ."" ' I ' ' ' !' : ' ' ' ' !!' ' J """- ' ' ' ' i / ~ I J ~ ' i '" t I ; .1 ; ; I.i , ;, ~ ,"t"- ,. -,-.- i ..... ~ ....~ ................... j ..:..~ ..... :..l ...... i , : I 600 oo 100 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 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. Si ncerely, Gruber Associ ate Engineer JG/tw GRU13/L44 Enclosure If CONF]DEN! AL INDEFtN]IEL { RECEIVED Oil & Gas Co;:~. ~,u;:,~ ...... ARCO Alaska. Inc. is s Subsidiary of AttanticRichlieldCompany I I[[[ I ~ ! II [ ~.. , LOCATED IN PROTRACTED LOCATED iN PROTRACTED SEC. I, TIIN,RSE, U.M. SE~. I, TIIN, RSE, U.M. Y = 5,970,38~.43 LAT. 70°19'49.1287'' ~0 - Y : 5,970,132.65 LAT. 70019'46.6719" X = 498,944.93 LO~G.150~O0'30.807" X = 498,945.27 LONG.150~O0'30.796" ~2' FSL, 556' ~L OG = 77' PAD = 81.5 152'FSL, 556' FWL ~ ~ 76.0 PAD · 81.7 - Y ~ 5,970,357.42 ~T. 70~19'48.8828'' 11 ~ Y = 5,970,107.71 LAT. 70°19'46.4267" X = 498,944.91 LONG. 150000"30.808'' X : 498,945.10 LONG. 150000'30~801" 377' FSL, 556' FWL OG : 77' PAD : 81.5 127' FSL, 556' FWL OG ' 75.9 PAD = 81.7 - = ~A ) - = . Y 5,970,332.46 ' ~. 70~19'~.6372" 12 Y 5,970,082 58 ~T. 70°19'46.1794" X : 498,944.84 LONG. 150=00' 30. 809" o X = 498,944.98 LONG. 150°00' 30.804" 352" FSL, 556' ~L OG = 77' PAD : 81.6 '~ 102' FSL, 556' FWL ~ = 75.7 PAD · 81.7 - Y = 5,970,307.52 ~T. 70°19'48.3919'' ~ 13 - Y = 5,970,057.59 ~T. 70°19'45.9336" X : 498,944.91 LONG. 150000, 30.808" ~ ~ X = 498,945.08 LONG. 150000, 30.801" m m ~ l 327 FSL, 556' FWL OG = 77 PAD = 81.6 77 FSL, 556 FWL OG ~ 75.5 PAD ~ 8~.6 - Y : 5,970,282.50 LAT 70°19'~.1459'' ~ 14 - Y = 5,970,032 60 LAT. 70°19'45.6879" X = 498,944.95 LONG.150°DO'30.806'' ~ ~ ~ X = 498,944 91 LONG. 150°O0'30 806" 302' FSL, 556' FWL OG= 77' PAD= 81.7 __ ~ ~ ~ 52' FSL, 556' FWL OG= 75.3 PAD= 81.7 X = 498,944.95 LONG.!50°O0'30.806" ~ ~ ~ X 498,944 93 LONG.150°O0'30.806" 277' FSL, 556' FWL OG = 77' PAD : 81.6 ~ 27' FSL, 556' FWL OG = 75.2 PAD = 81.6 - Y : 5,970,232.63 LAT. 70°19'47.6553''~ 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 OG = 75.1 PAD = B1.7 - Y = 5,970,207.62 LAT. 70o19'47.4093" ~ LOCATED IN PROTRACTED X = 498,945.01 LONG. !50°O0' 30.804'' ~ SEC.12, TI I N, RBE, U.M. 227' FSL, 556' FWL OG = 76.3 PAD : 81.6 17 - Y : 5,969,957.72 LAT. 70o19,44.9514" ,' X = 498,944.94 LONG. 150000. 30.805" 23' FNL, 556' FWL OG : 75.0 PAD : 81.6 SECTION LINE DISTANCES ARE TRUE. HORIZ; POSITIONS BASED ON TEME MON~ 2T-EAST, 2T-WEST ~ 2T-MIDDLE PER LHD& ASSOC. 4. VERT. POSITIONS BASED ON TBM's ~T-6 ~ N 19+75, Eli+ 5Z PER F.R.B. ~ ASSOC. 5.0. G. ELEVATIONS 'INTERPOLATED FROM S/C DRAWING CED- RIXX-5140 rev.~. REGISTERED &ND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~D THAT ~ UF ~/ )) MADE BY ME OR UNDER MY SUPERVISION, AND F ~ ..'~ · -'emimU~ ~ tHAt A', DIMENSIONS AND OTHER DETAILS ~~ ..e ~ ~&,/, / ArE CORRECT p~ . ~ ' 'i I ~ ~ ~UPARUK PROJECT ~ ""~"' .... ~-'~- ~ m~wN w. DRILL SITE 2T CONDUCTOR ~.~ ....... ~a)H~, ~,L~ ~ ~......st, AS- BUILT LOCATIONS I.F.t'.N..'-y7-F~ ..'L~ Arctic Boulevard, Suite 20~, Anchorage, A/aska 99503 [ls~LE N.T.S. llJOe ~. -------- m mm m m m m ITEM (1) Fee .. CHECK LIST FOR NEW WELL PERMITS DATE 2. 3. 4. 5. 6. 7. 8. APP VE 8) (2) Loc (8) (3) Admin ~hru ~-/[.,'/,,~ (10 and 13),'" (4) Casg ~.~,~, (14 thru 22) (23 thz~ ~ (6) OT ER (6) Add: Company .. , YES Is the permit fee attached .......................................... ~ ,. Is well to be located in a defined pool ............................. Is well located proper distance from property line ...... Is well located proper distance from other wells ....... Is sufficient undedicated acreage available in this pool Is well to be deviated and is wellbore plat included ... Is operator the only affected party .................... ,, Can permit be approved before ten-day wait .............. 9, Does operator have a bond in force ................................... 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name and number ......................... Lease & Well No. NO 14. 15. 16. 17. 18. 19. 20. 21. 22. 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 ............................ 23. 24. 25. 26. 29. (29 thru-31) '-~30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented ~.iZ~, ~-/2'~/~ 32. Additional requirements ............................................. 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 ~C~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ............................. ' .... exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. RE2,~CRKS/ 0 ~ 0 Geology: En g~n..e ering: JAL, / rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE~ju, Well Histor~ File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. 996I 9 F_, '"l R f" 60NFIDEN'I'IA[ INDEFINITELY 6. 3 7 ,",,,, 7 i . :; '? I i --.'.~ } }. -' ~ i} P.: 5 ".} 1} 3 :} il} 'i. '$' .'.?. '} 5' -~ 2 'i} o 2.: '3 ,.} -:~ 9 "'. 2 91.3' ) !. ~.} 0, 3' 2'} - }~:}.i :':'} -.) :i' ':., , ? .: ? 3 :'3 ?, - ? '~ 9. l,: ,3 9 -9 '_:;' 9.2 5:1 9 ":~' '? · ! 5 0 '~ · ", -- 5 Z 2 D
