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195-013
RECEIVE® S STATE OF ALASKAIII fCT 3 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 1a.Well Status: ELL COMPLETION❑MPLETION OR rR❑ECOnMPL❑ETIONndesdee Oil Gas SPLUG 1b.Well Crass 20MC 25.105 20MC 25.»o Development 0 Exploratory ❑ GINJ❑ WINJ ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 10/1/2017 . 195-013/317-180 ' 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 2/14/1995 50-103-20212-00 ' 4a.Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 83'FNL,556'FWL,Sec 12,T11 N, R8E, UM 2/20/1995 KRU 2T-21 • Top of Productive Interval: 9. Ref Elevations: KB: Z3' 17. Field/Pool(s): 1008'FSL, 1574'FWL,Sec 10,T11 N, R8E, UM GL: 82' BF: Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 700'FSL, 1503'FWL,Sec 10,T11 N, R8E,UM surface ADL 25569,ADL 22568 i 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- 498945 y- 5969898 Zone- 4 12821'/6126' 2666 TPI: x- 489406 y- 5965716 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 489335 y- 5965408 Zone- 4 N/A 1462'/1380' 5.Directional or Inclination Survey: Yes H (attached) No Q 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5 H-40 Surface 121 Surface 121' 24" 225 sx AS I 9-5/8" 40 L-80 Surface 4772 Surface 2901 12-1/4" 870 sx AS III,740 sx Class G 7" 26 L-80 Surface 12804 Surface 6115 8-1/2" 275 sx Class G 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number;Date Perfd): 3-1/2" 12268 12245/5755 PERFS PLUGGED 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. 12386-12468 MD,5842-5896 ND Was hydraulic fracturing used during completion? Yes ❑ No ❑✓ Per 20 AAC 25.283(i)(2)attach electronic and printed information 0aNt-9 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED JAN 1 8 2018Surface Top Off Job 2 bbls cement down T am% 6bbls cement down IA 10/o i/17 1 bbls cement down OA ( Surface Top Off Job 1 bbls Portland Type 1 cement into T 1.,,-- 3bbls Portland Type 1 cement into IC 2bbls Portland Type 1 cement into IA 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -. Form 10-407 Revised 5/2017 l V-7-1- I 72/`gONTINUED ON PAGE 2 „ L� @n 2 bmit ORIGINIAL onl • 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: l'€s ❑ No ❑✓ 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 ❑� Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1462 1380 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval information,including reports,per 20 AAC 25.071. Formation @ TPI- N/A N/A Y-mparv.k C— ►238 S25'40 ,te,VPPci:u Formation at total depth: N/A N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,. Authorized Name: Chip Alvord Contact Name: Jill Simek ^h <"J Authorized Title: Drilling Manager Contact Email: Jill.Simek@co Authorized Contact Phone: 263-4131 Signature: _ f Date: /'"'(36,t/Z"r-j 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 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water:Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only KUP PROD • 2T-21 ConocoPhillips t Well Attributes Max Angle&MD TD Al,-til.-I,Il ll:. Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ,-mp,ya,g 501032021200 KUPARUK RIVER UNIT PROD 70.73 11,220.93 12,821.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-21,10/18/20174:08:41 PMSSSV'.NIPPLE Last WO: 5/24/1995 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:TOC 12,201.0 12/2/2010 Rev Reason:P&A WELL,WELDED MARKER pproven 10/18/2017 P&A MARKER PLATE;53 6-II PLATE ON ), + Casing Strings I:1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread- • f CONDUCTOR 16 15.062 53.6 121.0 121.0 62.58 H-40 WELDED M/'CONDUCTOR;83.6-121.0 #.M✓�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • ' $ SURFACE 95/8 8.697 53.6 4,772.4 2,900.9 40.00 L-80 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I.. Grade Top Thread NIPPLE;508.7 ' PRODUCTION 7 6.276 53.6 12,804.0 6,115.1 26.00 L-80 BTC-mod Tubing Strings . Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/rt) Grade •Top Connection GAS LIFT;2,222.0 TUBING 31/2 2.992 53.6 12,267.9 5,768.7 9.30 L-80 EUEABMOD CMT SOZ;53.6+ CMT PLUG;53.6 •r Completion Details I• Nominal ID ,. Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 508.7 507.4 9.32 NIPPLE CAMCO DS NIPPLE NO GO 2.812 CEMENT SW;53.8 1003 12,235.8 5,749.6 53.88 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 12,243.8 5,754.4 53.75 SEAL 'CAMCO KBH-22 Anchor Seal Assy 3.000 SURFACE;53.6-4,772.4- 12,244.7 5,754.9 53.73 PACKER 'BAKER SAB-3 PERMANENT PACKER 3.250 12,258.1 5,762.8 53.43 NIPPLE CAMCO D LANDING NIPPLE 2.750 • • 12,267.2 5,768.3 53.15 SOS 'BAKER Wire Line Entry Shear Out.ELMD TTL @ 12260' 2.992 during PERF on 07/07/2000 GAS LIFT;5,194.3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) CEMENT PLUG;53.6 ftKB CEMENT PLUG;53.6 ftKB. Top(ND) Top Incl Top(ftKB) (ftKB) (") Dos Com Run Dale ID(in) CEMENT PLUG;8,425.0 ftKB 53.6 53.6 1.28 CMT SQZ Pumped 71 bbls'G'cement,followed by 70 bbl'AS1' 10/9/2010 7.000 CEMENT RETAINER;6,994.0 1 ' cement.Bullheaded down the OA and out at the shoe.0.5 bbl diesel cap on OA. 53.6 53.6 1.28 CMT PLUG CIRCULATED 207 BBL OF 15.7 ppg'ARCTIC SET 3/26/2011 0.000 'r 1'DOWN TUBING&UP THE IA;TUBING&IT CEMENTED TO SURFACE GAS LIFT:7,286.5 : 53.6 53.6 128 P&A P&A MARKER PLATE 10/1/2017 0.000 MARKER PLATE GAS LIFT;9,103.4 6,994.0 3,724.8 68.22 CEMENT INFLATABLECEMENTRETAINER 12/25/2010 0.000 RETAINER 12,156.0 5,703.8 56.24 TBG Punches PRE-CTD TUBING PUNCHES 12/4/2010 2.992 GAS LIFT;10,239.9 ! Si 12,245.0 5,755.1 53.73 CEMENT BAKER 2.125"INFLATABLE CEMENT RETAINER, 12/3/2009 0.000 I RETAINER OAL=10',NO ID DUE TO DUAL FLAPPER CHECKS -SET ON 10.2 bbls OF 15.86 CEMENT ill IIII'II TBG Punches,12,156.0 '~wl': Perforations&Slots Shot Dens KS) Top(ftKB) Min(MB) Top(ftKB)) Btm(MB)(TVZone Zon• Date (ah I)) Type Com GAS LIFT;12,190.3 f 12,386.0 12,406.0 5,842.8 5,855.8 C.4,21-21 7/7/2000 4.0 APERF 2 1/2"HSD 12,402.0 12,420.0 5,853.2 5,864.8 C-4,2T-21 6/9/2002 6.0 RPERF 2.5"2506 PJ,60 deg CEMENT PLUG;6,995.0 nKB "..', j+ Phase `i.R • 12,436.0 12,468.0 5,875.2 5,896.0 A-4,A-3,2T- 6/4/1995 6.0 IPERF 2 1/8"Enerjet 90 deg ., 21 ph;oriented+1-45 deg f/lowside NIPPLE;12,235.8 s '. 12,447.0 12,467.0 5,882.3 5,895.4 A-3,2T-21 6/6/1995 4.0 RPERF 2 1/8"Enerjet;180 deg :1: ph;oriented 90 deg left i: &right CEMENT SGZ;7,000.0 ftKB -Ci- a ' Cement Squeezes SEAL;12,243.6 -` Top(TVD) Btrn(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 1f 12,201.0 12,470.0 5,729.3 5,897.3 CEMENT PLUG 12/3/2009 SQUEEZED 10.2 BBLS OF 15.88 CEMENT PACKER;12244.7 ., r 6,425.0 6,994.0 3,517.6 3,724.8 CEMENT PLUG 12/25/201 LAY IN 5 BL ABOVE ICR TO 6425 RKB 0 6,995.0 12,201.0 3,725.2 I 5,729.3 CEMENT PLUG 12/25/201 SET INFLATABLE CEMENT RETAINER&PUMP CEMENT RETAINER;12,245.0 0 CEMENT,SET ICR @ 6994 COIL RKB,PUMPED ?i 190 BL OF 15.8 CLASS G CEMENT,45 BL TO 3.5" 11 TUBING FROM 12201 RKB TO BOTTOM OF ICR NIPPLE;12,258.1 53.6 6,425.0 53.6 3,517.6 CEMENT PLUG 3/26/2011 CIRCULATED 207 BBL OF 15.7 ppg'ARCTIC SET 1' DOWN TUBING&UP THE IA;TUBING&IT CEMENTED TO SURFACE 53.6 6,425.0 53.6 3,517.6 CEMENT PLUG 3/26/2011 CIRCULATED 207 BBL OF 15.7 ppg'ARCTIC SET 1' sos;12,267.2 ^ W DOWN TUBING&UP THE IA;TUBING&IT CEMENTED TO SURFACE Mandrel Inserts APERF;12,386.0-12,406.0 St all on Top(ND) Valve Latch Port Sire TRO Run RPERF;12,402.0-12,420.0 N Top(ftKB) (RKB) Make Model OD(In) Seen Type Type (In) (psi) Run Date Com 1 2,222.0 1,909.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/8/2003 2 5,194.3 3,062.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/2/2010 3 7,286.5 3,834.4 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 10/8/2003 (PERF;12,438.0-12,468.01_ - 4 9,103.4 4,511.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1997 RPERF;12,447.0-12,467.0 5 10,239.9 4,947.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/30/1998 6 12,190.3 5,723.1 CAMCO MMG 11/2 GAS LIFT OPEN RK 0.000 0.0 11/26/2009 CEMENT PLUG;12,201.0 fe(B Notes:General&Safety End Date Annotation 10/17/2003 NOTE:POSSIBLE LEAKS FOUND @ 5808',5590',AND 5398' 10/17/2003 NOTE:TUBING LEAKS FOUND @ 6958',6740',6460',6270,AND 6194' 3/14/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 II 3/26/2010 NOTE:WELL CEMENTED TO SURFACE,ABANDONED 10/1/2017 NOTE:Welded marker plate to the conductor 10/1/2017 NOTE:State Inspector(Jeff Jones)inspected and approved TOC in T,IA,OA,and Conductor PRODUCTION;53.8-12,804.0 KUP PROD O 2T-21 ConocoPhillips 01 ai�5h�1.111I,. ernmGhyll,PC 2T.21,10/18/20174:06:43 PM Verbal!scheme8c(actual) MA MARKER PLATE;53.6 Notes:General&Safety End Date Annotation 10/3/2017 NOTE:AOGCC State witnessed Final site inspection completed by Jeff Jones •,A-AACONDUCTOR;53.6-121.0 ✓`�'� NIPPLE;508.7 • GAS LIFT;2,222.0 V CMT SOZ;53.6 lg` - CMT PLUG:53.6 CEMENT SW;53.6 f8(B SURFACE;53.6-4,772.4-- GAS LIFT;5,194.3 CEMENT PLUG;53.8188, CEMENT PLUG;53.6 fIKB CEMENT PLUG;6,425.018(8 ' — ' CEMENT RETAINER;8,994.0 GAS LIFT;7,286.5 GAS LIFT;9,103.4 111 GAS LIFT;10,239.9 r TBG Punches;12,156 0 f r GAS LIFT;12,190.3 CEMENT PLUG:6,995.011KB ,' NIPPLE;12,235.8 CEMENT SOZ;7,909.0 SEAL;12,243.8 1 IjII PACKER;12,244.7 I I I CEMENT RETAINER;12,245.0 I I NIPPLE;12,258.1 I SOS;12,287.2 APERF:12,386.0-12,406.0 RPERF;12,402.0.12,420.0 (PERF;12,436.0.12,468.0L� RPERF.12,447.0.12,487.0— CEMENT PLUG;12,201.08KB PRODUCTION;53.642,804.0 • • P&A WELL EVENTS SUMMARY Date Well Event 10/1/2017 STATE INSPECTION(Jeff Jones).WELD MARKER PLATE(COMPLETE).REMOVE STAIRS AND SHORING. 9/30/2017 (P&A)CUT AND REMOVE 13'7"OF WELLHEAD. 9/29/2017 RESPOT 400 BBL TANK AND EVACUATE SOLIDS AND FLUID FROM SHORING BOX. 9/28/2017 Excavate,install shoring&stairs. 9/9/2017 (P&A)PUMPED 6 BBLS OF PORTLAND TYPE 1 CEMENT INTO T/I/0 FOR P&A PREP. 8/17/2017 (P&A)CEMENT TOP JOB ON T/I/O(COMPLETE) 8/11/2017 (P&A):BLED WHP'S TO 0 PSI,STRAPPED T TOC @ 400'.STRAPPED IA TOC @ 223'. 7/25/2017 (P&A PREP):CHECK TOP OF CEMENT:T TOC>150'(DID NOT TAG TOC), IA TOC>100'(DID NOT TAG TOC). OA TOC=20'2". • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2T-21 Plug and Abandonment October 4, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2T-21, commencing operations on August 11, 2017 and completing the Plug and Abandonment on October 1, 2017. The tree was removed and a cement top job was performed to bring cement to surface in tubing and all annuli. The wellhead was then removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attach ed. i i \\ ' : 1 ,. ' '4,,,••',2,..liso; _....,-,- ..--,v,,,...**-, i -1,-;-:.,.,,::.",-„f:: : t s •` uxMhem :4 pga t e „ . .��.r� " k ,am' St\ a as 4 94a�^, ,« a; � r� .L.- � • „60N'.,64,,, ,, 4,�p ' '4';*,- 4 t} . •'� „f-,•,,,' , w s� ASF r ----0-., -c s --iv.,'',.,,:., .x ” e1` d • • `. � a: * 4 . o rss ' �9 e ri '1n f. ~ r topsfs �;4;%,,,,,,-,-"4.- - , d,- - > sF c>cthceip"� s witolskaInc se "ps Aa* t ma +�u,7f,:'4 � "x'' , _'. of tt. • �► , Ley �«« �' < ' ,'.,, .4-e' . . .\-, if, /;:::, . -; ' .0" 1.P :-.:- D� ' ! S e Y ' 1 is R #- Y it w r --.-:'tli , ,,,D'Ofia'r . '..-,r. , ,,‘„ .4..- t si,,,i........• , - - r,.-...: .1,\....7.0.-c'.,,,,,- , , . „.•-,,,,;<,:,..,, a ''I'''','.'.,!;40,,'!",.,,,,'",,,,,,,74..1 �� ���� ten. Ir ��� _� s �opyrigrt 2p7. All rights reserved.This "�' photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other puopbse r by any othef party is prohibited without the'express consent of ., w�� �coPhillips Alaska,Inc." Haggerty-Sherrod,ert -Sherrod Ann Northland Staffing Services) From: Simek,Jill Sent: Thursday, October 05, 2017 8:52 AM To: Haggerty-Sherrod,Ann (Northland Staffing Services) Subject: 2T-21 Cementing Info 2T-21 Cementing Info: Surface "Top Off"Job: Pumped 2 bbls of cement down T Pumped 6 bbls of cement down IA Pumped 1 bbls of cement down OA Surface "Top Off"Job: Pumped 1 bbls of Portland Type 1 cement into T Pumped 3 bbls of Portland Type 1 cement into IC Pumped 2 bbls of Portland Type 1 cement into OA Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 1 •V OF T�� IP g � I yyy,,)s THE STATE Alaska Oil and Gas Nof Conservation Commission _; � ALAS�:A r kx �� 333 West Seventh Avenue 010 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 (7 Sj�P Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek SCANNED tVip' f z.. 1.,..., Staff Well Integrity Engineer ` '`' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-21 Permit to Drill Number: 195-013 Sundry Number: 317-180 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, Cathy . Foerster Chair DATED this I( day of May, 2017. RBDMS Lt., MAY 1 6 2017 • !RECEIVED Ii STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 4 2017 APPLICATION FOR SUNDRY APPROVALS ,may. 20 AAC 25.280 1.Type of Request: Abandon Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Plug and Abandon El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development El ' 195-013 '• 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. 0. Box 100360, Anchorage,Alaska 99510 50-103-20212-00 '- 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2T-21 Will planned perforations require a spacing exception? Yes ❑ No (] 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569, ADL 22568 ' 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): 12,821' 6,126' • • 0 . 0 0 Cemented to surface none Casing Length Size MD TVD Burst Collapse Conductor 81' 16" 121' 121' Surface 4,733' 9 5/8 4,772' 2,901' Production 12,769' 7" 12,804' 6,115' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12386-12467-cemented . 5843-5896 cemented 3.500" L-80 12,267' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SAB-3 PERMANENT PACKER ' MD=12245 TVD=5755 12.Attachments: Proposal Summary LI Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 5/21/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 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: JiII.Simek@cop.com r Contact Phone: (907)263-4131 Authorized Signature: fr , Date: 57 3 COMMISSION USE ONLY Conditions of approva. otify Commission so that a representative may witness Sundry Number: SI-7— ‘ 3° Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance EV 4.'1`sF. 5 IVO 114 Other: photo do cV kl,1 tom, a vt of 4-o6c c Vv, 1-1-1 rS5 4 3 Ih of r` eet- J-'rcl • Post Initial Injection MIT Req'd? Yes ❑ No E' Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: //2 —4-/2 7 RBDMS L'-MAY 1 6 2017 ,1 n APPROVED BY Approved by: 0 /' COMMISSIONER THE COMMISSION Date: . '—(/...... / 7 Ii ' 6././i7- Wvi /O// Submit Form and Form 10-403 Revised 4/2017 O n I1ti11t.5 valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 24 April 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk River Unit well 2T-21 (PTD#: 195-013). Producer 2T-21 was drilled in 1995 as an A and C sand selectively completed well. Since the well was drilled it has had issues with slugging, despite multiple new gas lift designs. In 2003,multiple tubing leaks were discovered and the well was shut in. Due to the low oil rate, a workover to replace the tubing was uneconomic. In 2005, additional diagnostics indicated multiple production casing leaks. With severe corrosion,multiple tubing and production casing leaks, and at least 40" of known subsidence(as measured between 1999 and 2009), the wellbore was deemed unsalvageable. The reservoir was cemented on December 7, 2009. Since then, three additional cement plugs have been pumped, and the well remains suspended with cement to surface. Remaining resources for well 2T-21 may be recovered through CTD drilling. 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 Conochips 2T-21 P&A Permit to Drill #: 195-013 The objective of the proposed 2T-21 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 reauired. 7. Send the casing head w/ stub to materials shop. Moto document. 8. Weld %4" 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-21 PTD # 195-013 API # 50-103-20212-00 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. Photo document final location condition atter all work is completed. Is e 4111 Wellbore Schematic: KUP 2T-21 Ph conocoillips t.114 A�Du*es,: Max Angie&MO TO - ft Wellbore AQkUWI Field Name Well Statue Mc,i1 MD 16601 Am Ben 0061 501032021200 KUPARUK RIVER UNIT PROD 7073 11220.93 12 821.0 """ L`aiwrent IMS rppm/ Dain Atalototion End Date 684814(a) RIG Release Date �_,`a.ra .� 'e/^.,.< SSSV:NIPPLE 210 12115/2002 Last WO 512411995 4 ��., L.a Annotation Depth InKB) End Date Annotation Last Mod.,.End Date LOS)Tag TOO 12.201.0 :2212010 Rev Reason.WELL REVIEW Debar 2/6/2012 Cssin strings Cashg 50)IP1bt1 Snag 0-, 5116.910...Top 8861 Set Depth It. Set Dept(TV01 SIm1g WO..Smug..-501119 top rt.d CONDUCTOR 16 15.062 40.0 121.0 1210 0258 H-40 WELDED Casing 0.6009tlon String 0.. Suing ID_Top 10081 Set De{16 p.Set Depth(TVD)..String Wt. Stung..Suing Top Tltrd 000009,98 , I` SURFACE 95'8 8.097 399 4,772.4 2,900.9 4000 L-80 BTC mem•111210500 10119 e... .imp _, op I'- et a pt 1(... -I C t -e .. 111109" tont... trine op C. PRODUCTION 7 6.276 34 6 12 804 0 6.115-1 26.00 L-80 BTC-end R Tubing Strings Tubing Descrlphon Mona D.,. Smog ID...Top IKK61 Set Depth(1.. Set Depth(1051...String Wc..Sting...String Top Thed TUBING 312 2.992 36.5 12.2679 5.766.7 9,30 L-90 EUEABMOD Ct]aAUCTOR4417 Completion Details Tap Depth NIPPLE,599---- gr (TVD) Top loci Mad... Top mKB) 8681 I°) nem Deecriptan Comment ID lin) GAS LIFT36.5 36.5 -1.11 HANGER FMC GEN IV TUBING HANGER 3.500 508.7 507,4 9.45 NIPPLE CAMCO DS NIPPLE NO GO 2.812 CMT 502.19-_ CMTPLO8,59- 12,235.8 5.749.7 54.11 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 12.243 8 5.754.4 53.88 SEAL CAMCO KBH-22 Anchor Seal Assy 3.000 12,244 7 5.754.9 53.84 PACKER BAKER SA8-3 PERMANENT PACKER 3.250 12,258.0 5.782.8 53.43 NIPPLE CAMCO D LANDING NIPPLE 2.750 12.287.2 5.768.3 53.15 SOS BAKER Wee Line Entry Shear Out.ELMS TTL 0 12260 during PERF 2.992 SURFACE. • on 07107)2000 494.772 Other in Hole(Means retrievable plugs,valves,pumps,fish,etc.) Top Dept v. CAS LIFT, ((VD) Top incl 5,190 - Top/168) ita(B) (°) Description Comment Rem Date IO(all CANT en 39.0 39.0 -0.65 CMT SOZ Pumped 71 bbls'G'Cement,followed by 70 bd'AS1' 10)8/2010 7.000 CD034 01f.NT Garment Bullheaded down the OA and out at the shoe.0.5 PLUG,4424 bbl diene! 1 cap on OA. CEMERT 69 J I I 39.0 39.0 -0.65 CMI PLUG CIRCULATED 207 BBL OF 15.7 ppp'ARCTIC SET 1' 3/28/2011 0.000 DOWN TUBING 8 UP THE IA:TUBING 8 IT CEMENTED TO SURFACE GAS t,l 6,994.0 3,724.9 68.29 CEMENT INFLATABLE CEMENT RETAINER 12125/2010 0.000 1,296 It RETAINER 1.: 12,156.0 5,703.9 56.38 TBG PoMAds PRE-CTD TUBING PUNCHES 12412010 2.992 905 LIFT, 12,245.0 5,755.1 53.63 CEMENT BAKER 2.125"INFLATABLE CEMENT RETAINER, 123/2009 0.000 8.15$ RETAINER OAL=101.NO ID DUE TO DUAL FLAPPER CHECKS-SET if E ON 10.2 Ws OF t5.833 CEMENT 0051167 Perforations&Slots ta2ebshot - 11p iT90)eba(1VDI Dens Top 18601 Bim No {Mae dRKBI zona Dale ish_, Type 701111110111 *: 12,3860 12.4069 5.8428 5,8558 C-4.21.21 79712000 4.0 APERF 2 12'HSD Tea Bre14.156 men 12,402 0 12.420 0 5.863 2 5864.8 C-4.2T-21 61812002 6.0 RPERF 2 5'2506 PJ.80409 Phase 12.436 9 12 4680 5,875.2 5,896.D A-4,A'3 2T-21 6/411995 6,0!PERF 2 1/8'EnerIet 90 dog ph;oriented W- 45 deg f/lOwnide I. Cas{LFT, 12,447.0 12.467.0 5,682 3 5.8954 A-3,2T-21 6/6/1995 4.0 RPERF 2 1/8"Enotieo 180 an phi 014111ed L,t59 90 deg loft 8 1gld CEMENT Notes:otGeneral d Safety h 'i�.8,%5 End Dan! Annotation I 10717:20(33 NOTE:TUBING LEAKS FOUND 08958'.6740'.6460'6270,AND 6194' gg 10/1712003 NOTE:POSSIBLE LEAKS FOUND 0)5808'.5590',AND 5398' MPPLE.12394 18 371472010 NOTE:VIEW SCHEMATIC re/Masi.Scheenatio9.0 362672010 NOTE WELL CEMENTED TO SURFACE,ABANDONED iireibt SEAL,12;20( fRt, .+ yg�ar.�. 12k5 .;419 'Art CEMENT RETARIER,-.......................__ 12,215 i NIPPLE 12A.'4 14. SOS,.12,781 APER, 12,MEdtl2,4 - _ WERE, 12.4012,426 Mandrel Detail Top Depth Top Port ITVDI 1103 OD Valve Latch Sae 780 Rat 10,45612 \,,‘,,,,,, Sot Top/14(61 I1K01 i-'1 Main Mind tin) Sere Type Type (ail (psi) Run Date Can... I2,447.1.1,447 '. 1 2,222.0 1,909.3 55.22 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/8/2003 2 5,1943 3,062.0 89.13 CAMCO 0876 1 GAS LIFT DAY BK 0.000 0.0 12/2/2010 3 7,286.5 3,834.4 88,07 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0,010/8/2003 UMW 01012,12:01 4 9,103.4 4,511.9 69.05 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/21997 5 10,239.9 4,947,3 65.84 CAMCO MUG 1 1/2 GAS LIFT DMY RK 0,000 0.0 3/30/1908 6 12.190.3 5,723.1 54.85.CAWCO MMG 1 1/2 GAS LIFT OPEN RK 0.000 0,0 11/26/2009 PRODUCTION, 59-12,401 10,12,821 Is Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning. project. They are available in the original file and viewable by direct inspection. L ~ ~ " ~ 13 File Number of Well History File PAGES TO DELETE Complete RESCAN ^ Color items -Pages: ^ Grayscale, halftones, pictures, graphs, charts - Pages: ^ Poor Quality Original -Pages: ^ Other -Pages: DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type OVERSIZED ^ Logs of various kinds ^ Other COMMENTS: ~~ -~ Scanned by: Bey ^ TO RE-SCAN Notes: Vincent Nathan Lowell Date:[~~~ J~~ ~S~ j. / Y `-i Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /s~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/10/11 Inspector: Bob Noble Operator: CPA Well Name: KRU 2T -21 Oper. Rep: Martin Walters PTD No.: 195 -013 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 12/03/09 Date AOGCC Notified: 09/09/11 Sundry No.: 309 -360 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 50 Photos Taken? Yes IA 20 OA 4 Condition of Wellhead: Wellhead was in good operating condition. The flowline was blinded. The A/L line had been removed. IA and OA were capped with integral flanges. Condition of Surrounding Surface The pad looked to be good clean gravel. The cellar box was dry. Wellhead was inside of a well house. Location: The location was verified with a plot plan. Follow Up Actions I suggested that they remove the integral flanges on the IA and OA and replace them with blind flanges. Needed: Attachments: Photos (2) - REVIEWED BY: Well Schematic > Insp. Supry � - I c47( i KRU 2T pad layout Comm 1 PLB 08/2010 2011- 0910_Suspend_KRU_2T- 21_bn.xls Suspended Well Inspection - KRU 2T -21 PTD 1950130 Photos by AOGCC Inspector B. Noble 9/10/2011 I IF .'i '_ %• . , ,:. II i Of , • :,, It lee -. 0 . . _ , . k1 IOr g 1 t ' t 4 ; >.. k. , mss "' ..., .,ate .,,.. . f r_. _►. r..: i � -. ._ .,. «,.�- �"° fi ... "» ,`"`"+.. �... w... , : ■ • • KU P 2T-21 ,,. ,5 i , Conoco Phillips.. •'',. ' ' ''''' ItIi611 AtIrkr A , - - , , _ - piiAr141 - TO Wei Statue tat, 9) MD (M0) Att Olin (11)03) 501032021200 KUPARUK RIVER UNIT PROD 70.73 11,220.93 12,821.0 CCATVACili H2S (ppm) DAte Annotation End Oat 483.0.d (0) Rig 11.455. 0.19 .., SSSV: NIPPLE 210 12/15/2002 Last WO: 5/24/1995 Last Tag TOC 12,201.0 12/2/2010 Rev Reason' CEMENT pLUO TO SURFACE trnosbor 328/2011 - - DeSInt Strin !s Casing DesetiptIon Wog 0.., 5 ng TO - Top (003( '0.4 Depth (I Set Depth (000) . Stttng W1 . String ,. String Top 0194 CONDUCTOR 16 15.06 40.0 121.0 121.0 62 58 H-40 WELDED Casing Description String 0- String ID -. Top /M01 Set Depth if- Set Depth fTVDS - String Wt- String -. String Top TOrd HANSER M SURFACE 9 5/8 8.697 39.9 4,772.4 2..900.9 40.00 L-80 BTC ri 111 ' 1 - Casing DescrIptlon StrInIM3 OM string ID . Top DIKED Set Depth 44 . Set Depth Trot ... Stang Vet . String _ String Top Thrd PRODUCTION IMIIII 6 151_ 34 6 12 804 0 61151 26.00 L-80 Et:IC-mod ..ri,-,1 T De ob:ng scription String 0. S(4ino10 , Top (MO) Set Oe0h t t Set 0/h (IVO) . 519n4 VeL. String.. Stttng Top . 44 TUBING 3 1/2 2 997 365 12 267 9 5.768 7 9 30 1-80 EUEABMOD CONDUCTOR, 40421 Completion Details 1 4 Top Depth NAAPI.E. WS 4 AL, (900) 90p 4.44 Mute- , ' Top MRS) (MOM (1 Item Descrtption em'eni 10 1191 365 36.5 -1.11 HANGER IX ANGER F GEN IV TUBING HANGF_R 3.500 [ GAS OFT, 2222 i 508.7 507.4 9.45 NIPPLE CALICO DS NIPPLE NO GO 2812 I. CUT 802. 39 t GMT PLUG. SS 12,2368 5,749.7 54.11 NIPPLE CAMCO W.1 SELECTIVE NIPPLE 2812 i , 12,243 1 , . :1 1 .8 5,7544 53.86 SEAL CAMCO 1<81-1.22 Anchor Seal Assy 3.000 . 12,244.7 5,754.9 53.84 PACKER BAKER 3115-3 PERMANENT PACKER 3 250 12258.0 5,762.8 5343 NIPPLE CAMCO 0 LANDING NIPPLE 2.750 , ; 1 ' , ii 12,267.2 5,7683 53.15 SOS BAKER Wee line Entry Shear Out ELMO TTL @ 12260' during P8119' 2.992 A./ ort 07:07/2000 5.0::::118i ______. : .:: 7. Offter In Hole (Wireline retrievable plug's, valves, 4) 0 01 (4s , fish, etc.) .&.t".. Top Depth OAS 10 T, (TV Top Intl 5,104 9 009 4441(5/ tessi 19 poseur/ton Comment 0u/10414 /0(19) 804849 eA. 39.01 39.0 -0.65 CMT St9Z Pumped 711761s II' cement, followed by 701761 I* 109/2010 7.000 PLUG, 34 CEMENT .,L., .. . I 0083808 Bu headed down the OA and 0944 04 the shoe. 0 5 PLUG, 8,425 WI ciesel cap on OA CEMENT RETAMER. %VP 1 39.0 39.0 -0.65 CAT PLUG CIRCULATED 207 BBL OF 15.7 ppg 'ARCTIC SET 1' 3/262011 0.000 8.494 DOWN TUBING & UP THE IA TUBING & IT CEMENTED TO SURFACE .... 6,994.0 3,724.9 68.29 CEMENT INFLATABLE CEMENT RETAJNER 1272572010 0.000 GAS4.,tgi t' RETAINER 12,156.0 5,7019 56.38 480 Punches PRE-CT13 TUBING PUNCHES 12/472010 2.992 GAS 0.403 lk 12,245.0 5,755.1 53.83 CEMENT BAKER 2125' INFLATABLE CEMENT RETAINER, 12/372009 oaaa . . RETAINER OAL=10, 8400 DUE 70 DUAL FLAPPER CHECKS - SET ii ON 10.2 bbls OF 15.84 CEMENT "IOIrT4' 1 Perforations & Slots Shot Top (TVO) Elm (IVO) NOS Top )fti(D) SW (181(9) 44160) 1 8141 4 Zetne Date Ish... Ty, Comment 1111 : es_ ; . 1 .. , 12,386.0 12,406.0 5,842.8 5,8558 C-4, 2T-21 7/7/2000 4.0 APERF 2 1/T H513 T90 Pue;0: 24 . I 12,402.0 12,420.0 5,8532 5, 75, : D.4, - 1 tri 9' 40 RPERF 2.5'2506 PJ, 60 deg Phase 11 12,426.0 12,4680 5,875.2 5696.0 A-4, A4 2T-21 6,/4/1995 6.0 11 2 1/8" Enerjet; 90 deg ph; oriented +L. 45 deg Howskte 12447.0 12,467.0 6882 3 5,895.4 A-3. 2T-21 66/1995 4.0 RPERF 2 1/8*Eneget: 180 deg ph: oriented "str/4 . 90 deg 1eh & light .a,.. . „ CEMEUT /dotes: General & Safety PLUG, 0.945 End Date Anhotg., 1, T0717/2003 NOTE: POSSIBLE LEAKS FOUND @ 5808.5590', AND 5393 10/17/2003 NOTE TUBING LEAKS FOUND tat 6958', 6740, 6460, 6270, AND 6194' tePPLE, 12 2241 ' 2/ "1. NOTE: 1 'o E ' 1 vdAskaSchematIc9.0 SEAL, 42,244 PACKER. 12,24S CEMENT RSIMMER. 12.244 I 5,29(4, 43 IS I 805, 4225? , 42,3 RPERT, 42.402"41420 klaaarelpatafl0 ' ''' :,''::;T,":,''": ' ''',' ' 009 5,959 Top Rort PVC/ Inc) OD Valve Latch Elm TRO Run WULF. 12,43842.483N Stet Top 011(41) (UD) fl Make Model (lo) Sere Type Type Ord (psi) Run Dee Com., ISPERS, 1 2,222.0 1,909.3 5&22 CAMCO KBUG 1 GAS LIFT OW 13K 0.0011 0.01018/2003 12,4414 2,487 2 5,194,3 3,062.0 69.13 CAMCO KBUG 1 GAS LIFT WY BK 0.000 0.0 12)2,12010 3 7.286.6 3,834.4 68,07/2411.400 KBUG - 1 GAS LIFT DMY BTM 0.000 0.0 101312003 CEMENT '' IRMO 12.204 4 9,103.4 4,511.9 69 05 CALICO KBUG 1 GAS LIFT DMY 'BK 0.000 0.0412/1997 5 10,239.9 4,947.3 65.84 CAMCO MMG 11/2 GAS LIFT DMY RIC 0.000 0.0 3930/1998 6 12,100.3 5,7211 54.85 CASCO HMS 1 1/2 GAS Uri OPEN RIC 0000 0 0 11/26/2009 PRO0VOT101A 25.12,554 TO, 12.621 . . , XFRHR P NOTE ---/ ; H. NO SNOW IS TO BE PLACED IN il ANY RESERVE PIT OR LINED PIT. IMIS1 \ i ; i PM ZA 14TR 1 1 RESERVE PIT El PIG 1 PIPELINES PIT — t I I 1 I air " , I , I 1 Ammo F1 la4R ell'In- I WA007 AMY • I MIN - 1 I D Aill 7 ; 0 /%4 , 1. f , ' • 26 21 191' 1 1 1t11 1 1 9 ' ' 15 ' 23g 30 32 .s.: I " "Mus ^),•. ■ , in -':--, ,-- , "et.--. W r. ‘, A6A .,.,:. 6 "Jo p .- ( 1 <:' 2 , / t= 1s) : 37 28 18 — en 22 27 29 31 ... k I FA TO DMA L-75*— 75'-- *- '&---- ' 62.5,-L37S-J41.5".1.2V K V 7", Al I 2 smas j 1 smas [2 sPma 6 gr I 3 sP 6 frg L3 SPACES b 1:.;:; o T25 ens . oars Lem" era ril 1 6,.... 1.....' 1_ 1 1 5 SPACES-. 0 15Jr if 4if MO I r . I larded?: ted Or 1 / : / / 4 &Mg rargat ri rAWA "6":"(1/ Ctle " Ig c FEATURE LOCATION LEGEND 4 I CAUTION 0 EXISTING PRODUCER LEGEND A EXISTING INJECTOR 1 i THIS DRILL SITE IS e corivemo Frrom ,i mon - CLEAN SNOW DUMP AREA. ALL EQUIPMENT. r RESCUE EQUIPMENT CONSIDERED TO BE PRoDucER TO IN.,TCTOR i l .1, • * SCBA LOCATIONS I ABANDONED CONDUCTOR t...........* - ENVIRONMENTAL AREA-NO SNOW DUMPING. AN H AREA '' DESIGNATED SAFE AREA (PRIMARY) X EXISTING CONDUCTOR i 1-- ----j - PowERLINE-WATCH CLEARANCE!!. KODIAK 1 BLOWERS MAY HIT LINES WITH DISCHARGE. ..1.i DESIGNATED SAFE AREA (SECONDARY) ig PARTIAL TREE ii - KODIAK BLOWERS MAY DISCHARGE OVER '' " EVACUATION ROUTES DEPENDING ON WIND .1 I PIPELINES. .. = - NO SNOW DUMPING AREA. I Ak, WINDSOCK r . NDSOCK Cg3 ,7.„.‘ BARRICADE/ESCAPE ROUTE ft -, ! AREA: 2T MODULE:XXXX UNIT: D2 4 LOUNSBURY, INC FIRE EXTINGUISHER 1 AppRov ::, ,: ' , '2" '.. , • ,..4 - • 5 5/01/02 Add Well 39, Rev Per K02013ACS Egginm ; DATE : 11/26/99 cAm FILE:LK622011 4 5/30/01 Add Wells, Update Title 131k, Rev Per K01039ACS ROL , DRAWING NO SHEET: REV: I ; Kv. Mill DATE El .., 1,.., REVISIONS _ • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 10, 2011 Commissioner Dan Seamount Alaska a;I� Alaska Oil and Gas Conservation Commission �`�s tlt1 333 West 7 Avenue, Suite 100 ,,n„g, C0 m oss si a s gC r Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -21 (PTD 195 -013) 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- 21 (PTD 195 -013). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic `4a SF - Location Plot Plan �' - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, Xack i 7 42, F Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA CND GAS CONSERVATION COMMISSI� REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well Rug Perforations St Othe Suspended Well p 9 Inspection Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' Exploratory r r 195 - 013 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20212 - 00 • 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025568 & ADL0025569 • 2T -21 9. Field /Pool(s): o Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 12821 feet Plugs (measured) None true vertical 6126 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 12245 true vertical 0 feet (true vertucal) 5755 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 SURFACE 4733 9 -5/8 4772 2901 PRODUCTION 12769 7 12804 6115 R ECEIVED depth: 12436-12468, 12447 -12467 SE P 1 2f iq Perforation depth: Measured dept 12386 12406, 12402 1242 True Vertical Depth: 5843 -5856, 5853 -5865, 5875 -5896, 5882- 5895 a6k8 01l Gas Cons, Co anchor a mntission Tubing (size, grade, MD, and TVD) 3.5, L - 80, 12268 MD, 5769 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER SAB -3 PERMANENT PACKER @ 12245 MD and 5755 TVD SSSV - CAMCO "DS" NIPPLE @ 509 MD and 507 TVD 11. Stimulation or cement squeeze summary: 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 work: Copies of Logs and Surveys run Exploratory r Development 17 - Service r Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r; WAG ri GINJ r SUSP` 17 SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact MJ Loveland /Martin Walters I Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature /e n7__, �, . ! t Phone: 907 - 659 -7043 Date: 09 -10 -11 RBDMS SEP 14 201f:Cz 7 2 . it Form 10 -404 Revised 10/2010 Submit Original Only Y • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 'Nell Name: Kuparuk River Unit 2T -21 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 195 -013 Sundry 310 -234 API Number: 50103202120000 Operator: ConocoPhillips Date Suspended: 3/25/2011 Surface Location: Section: 83' FNL, 556' FWL, Sec 12 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: Good Pad or location surface: Good gravel pad Location cleanup needed: No Pits condition: NA Surrounding area condition: Good Water /fluids on pad: Rain water on pad Discoloration, Sheens on pad, pits or water: No sheen Samples taken: None Access road condition: Good Photographs taken (# and description): None 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: Good. Cycled SSV, SV, MV, IA valve, and OA valve Cellar description, condition, fluids: 6X6 wooden cellar box with gravel Rat Hole: No Wellhouse or protective barriers: Wellhouse with fiberglass floor. Good Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 50 psi Annulus pressures: IA = 20 psi, OA = 4 psi Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: Replace IA & OA integral flanges /f� /' Operator Rep (name and signature): Martin Walters /d' (GU�� a" AOGCC Inspector: Bob Noble Other Observers: Mouser /Bybee /Greenwood Inspection Date: 9/10/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway Vehicle KUP 2T -21 nocopnips w 1 Attributes M •nqle& MD TD AfJSka �� WellboreAPIIUWI Field No Well Status 15x1(') MD (ftKB) Act Btm (MB) 501032021200 KUPARUK RIVER UNIT PROD 70.73 1 11,220.93 12,821.0 Comment H2S (ppm) Date Annotation End Date KB (8) Rig Release Date •• wea coma - 2a2L3RB(10111.06:]2AM SSSV: NIPPLE 210 12/15/2002 Last WO: 5/24 /1995 SWmate•Aduel Annotation Depth (RIO) End Date Annotation Last Mod ...End Date Last Tag: TOC 12,201.0 12/2/2010 Rev Reason: CEMENT PLUG TO SURFACE Imosbor 3/28/2011 ' - -- - -- Casing Strings Casing Description String 0.., String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 (4 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 38 l SURFACE 95/8 8.697 39.9 4,772.4 2,900.9 40.00 L BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6,151 34.6 12,804.0 6,115.1 26.00 L -80 BTC -nod m r Tubing Strings • Tubing Description String 0... String ID ... Top MB) Set Depth (8... Set Depth (TVD) ... String Wt... 'String ... 'String Top Thrd TUBING 31/2 2.992 36.5 12,267.9 5,768.7 9.30 L -80 EUEABMOD CONDUCTOR. 1 Completion Details _ Top Depth NIPPLE, 509_ Top (ftKB) MKS) Top Item Description Comment ID (in) 1 36.5 36.5 - 1.11 HANGER FMC GEN IV TUBING HANGER 3.500 GAS LIFT. 2,222 f 508.7 507.4 9.45 NIPPLE CAMCO DS NIPPLE NO GO 2.812 CMT SOZ, 39 �. CMT PLUG. 39 12,235.8 5,749.7 54.11 NIPPLE CAMCO W -1 SELECTIVE NIPPLE 2.812 12,243.8 5,754.4 53.86 SEAL CAMCO KBH -22 Anchor Seal Assy 3.000 12,244.7 5,754.9 53.84 PACKER BAKER SAB -3 PERMANENT PACKER ' 3.250 2.755 12,258.0 5,762.8 53.43 NIPPLE CAMCO D LANDING NIPPLE 12,267.2 5,768.3 53.15 SOS BAKER Wire Line Entry Shear Out. ELMD TTL @ 12260' during PERF 2.992 suRFACE, 05 07/07/2000 40.4,772 Other In Hole (WreI(ne retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT. 1TVO) Top Inc( 5,194 Top (MB) (ftKB) (1 Description Comment Run Date ID (In) CEMENT 39.0 39.0 - 0.65 CMT SQZ Pumped 71 bbls'G' cement, followed by 70 bbl'AS1' 10/9/2010 7.000 PLUG. 34 CEMENT cement. Bullheaded down the OA and out at the shoe. 0.5 PLUG. 6.425 1. bbl diesel cap on OA. CEMENT RETAINER. 39.0 39.0 -0.65 CMT PLUG CIRCULATED 207 BBL OF 15.7 ARCTIC SET 1' 3/26/2011 0.000 6 ' DOWN TUBING & UP THE IA; TUBING & IT CEMENTED TO SURFACE GAS LIFT. 6,994.0 3,724.9 68.29 CEMENT INFLATABLE CEMENT RETAINER 12/25/2010 . 0.000 7266 RETAINER IF 12,156.0 5,703.9 56.35 TBG Punches PRE -CTD TUBING PUNCHES 12/4/2010 2.992 GAS °'LIF103 T, I 12 5,755.1 53.83 CEMENT BAKER 2.125" INFLATABLE CEMENT RETAINER, 12/3/2009 0.000 RETAINER OAL =10, NO ID DUE TO DUAL FLAPPER CHECKS - SET a ON 10.2 bbls OF 15 CEMENT GAS LIF40 T. I Perforations & Slots 10,2 shot' SE Top (TVD) Btm (TVD) Dens _ _. Top (ftKB) 888 (9)(13) (R1413) (ftKB) Zone Date (sh... Type _ Comment • 12,386.0 12,406.0 5,842.8 5,855.8 C 2T - 21 7/7/2000 4.0 RPERF 2 1/2" HSD TBG Punches, 12 t hes, t 12,402.0 12,420.0 5,853.2 5,864.8 C-4, 2T -21 6/9/2002 6.0 RPERF 2.5" 2506 PJ, 60 deg Phase E - 12,436.0 12,468.0 5,875.2 5,896.0 A-4, A -3, 2T -21 6/4/1995 6.0 - IPERF 2 1/8" Enerjet; 90 deg ph; oriented +/- 45 deg fADwside GAS LIFT, 12,447.0 12,467.0 5,882.3 5,895.4 A -3, 2T -21 6/6/1995 4.07 2 1/8" Enerjet; 180 deg ph; oriented 12.190 awe.' 90 deg left & right CEMENT Notes: General & Safety PLUG, 6,995 End Date ' Annotation 10/17/2003 NOTE: POSSIBLE LEAKS FOUND @ 5809, 5590', AND 5398' 10/17/2003 NOTE: TUBING LEAKS FOUND @ 6958', 6740', 6460', 6270, AND 6194' NIPPLE, 12,236 12/W2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1 SEAL. 12,244 AIM !e PACKER, 1 r' 12.245 CEMENT RETAINER. ' 12,245 1 II NIPPLE. 12,258 B ._ 1 SOS, 12,267 , - fee' APERF, 12,388 - 12,406 RPERF, 10402 -12.420 Mandrel Details Top Depth Top Port IPERF. (TVD) Inc! OD Valve Latch Size TRO Run 12.436 - 12,468\ Stn Top (MB) (MB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Com... RPERF. 1 Z222.0 1,909.3 56.22 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/8/2003 12,447 - 12,467 _ - 2 5,194.3 3,062,0 69.13 CAMCO KBUG 1 GAS LIFT DMY 13K 0.000 0.0 12/2/2010 3 7,286.5 3,834.4 68.07 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 10/8/2003 CEMENT PLUG, 12.201 4 9,103.4 4,511.9 69.05 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1997 5 10,239.9 4,947.3 65.84 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/30/1998 6 12,190.3 5,723.1 54.85 CAMCO MMG 1 1/2 - GAS LIFT OPEN "IRK 0.000 0.0 11/26/2009 PRODUCTION. 35- 12,804 TD, 12,821 { ���t •11111 <.l•��f0fl•���f 1 1 11• ��11�er�t ralii iirhalMINNIII1 •I•IMIIIMIORf� trnmr -m, �� ■ POWERLINES iI nFRMR II .an NO t. :. :. :. :. :. :. :. :. :. :.1 1 NO SNOW IS TO BE PLACED IN ANY RESERVE PIT OR LINED PIT. r CARD PRA Q 2A HTR HEAT(' I RESERVE PIT PIG I PIPELINES IT ( O PRoo r , 1 L HOD ACCHTIO 0 • .... 15' j 21 1917 13 15142 . 121 1 9 8 7 5 4 3 2 23 N 26 2 30 32N 2,1g1 N N N u � ' : (�pj \ 1174 ®r 0o♦•gacPP•palp 0 ® o 0. 0 Or m u� i 7II v x _ / 3 7 20 18 6 38 ® M 2 2 29 31 ^ ®N F 131 N _ • N — '� ' a a-- 75'�28'�-- a8' —'25" , 50'— '�5' 30'i90'�62- 5'�37.5'i62.5- 1 17.5' 1 25 7 - " II TO DS2A i 75 25 25 25 25 SSPACES) @ SJ L . 5 L $ @2 L3: 56 :,5'S L 3 : i2.5 s 2 0151T i //'` _ 1 �/, FEATURE LOCATION LEGEND C /� n I U I TI O N 0 EXISTING PRODUCER LEGEND 1 ON 1 EXISTING INJECTOR THIS DRILL SITE IS 2A CONVERTED FROM MOM — CLEAN SNOW DUMP AREA, ALL EQUIPMENT. Ii RESCUE EQUIPMENT CONSIDERED TO BE PRODUCER TO INJECTOR I ■∎4. — ENVIRONMENTAL AREA —NO SNOW DUMPING. SCBA LOCATIONS AN H AREA Z ABANDONED CONDUCTOR l 1 1 I DESIGNATED SAFE AREA (PRIMARY) X EXISTING CONDUCTOR -- Ri 1i1, — POWERLINE —WATCH CLEARANCE!!, KODIAK BLOWERS MAY HIT LINES WITH DISCHARGE. 1 I DESIGNATED SAFE AREA (SECONDARY) (Ea PARTIAL TREE r .0 - KODIAK BLOWERS MAY DISCHARGE OVER 1E1 EVACUATION ROUTES DEPENDING ON WIND PIPELINES. F777:71 — NO SNOW DUMPING AREA. r BARRICADE /ESCAPE ROUTE ® AREA: 2T MODULE:XXXX UNIT: 02 A LOUNSBURY, INC ,,r, FIRE EXTINGUISHER APPROVAL: DS2T FACILITY EXPANSION 1 5 5/01/02 Add Well 39, Rev Per K02013ACS MRT SCT DATE: 11/26/99 CADD FILE: LK622011 FEATURE LOCATION ! 4 5/30/01 Add Wells, Update Title Blk, Rev Per K01039ACS ROL MRT DRAWING NO. SHEET: REV: REV. CUST DATE REVISIONS BY CHX Joe PROD CEA -D2TX -3323 001 5 I NO._ _ APP ENGR ENGR • t 6 2T -21 (PTD# 195 -013) © ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska • 0 ,' 2T -21 (PTD# 195 -013) '' ,_ © ConocoPhillips Alaska, Inc. This photo is copyrighted by ti '' ConocoPhillips Alaska, Inc. 4 ` and cannot be released or ,4, ty ,- `` - .. y published without express ,4 -t written consent of p ,0°. * -- ` ConocoPhillips Alaska a Zia '' . t, >04. - .1. --- '14** i * ,p . 40 '' , ..., ' le - .. . - 411# 41464 411° e de 4'4°01'101 ,le.304° ......,:re: % . 4 . 40,414*.4:4$?4 0.4‘4Pote,4$1.#*;1400*°4" 0 4ree.:00,05:;.4 d % x r '10: 1 ? 41$° (0, 40°":"410°:$44#"* vofr w r 4 A rk ' ' ' ''' . - . 411" \ - ', .g ,,,„ "tr. F ar. 0 1 r i ON r , 110/ . r r ,440b ' ." '4/AA ' * '''''5 y_ Aid* "Aill" ' A id . A* Arafiai 400 ax Ailo._ _4_, „6„.. ., ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q . 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aba nd.: cusp., March 25, 2011 • 195 - 013 / 310 - 234 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 14, 1995 50 103 - 20212 - 00 ' 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 83' FNL, 556' FWL, Sec. 12, T11N, R8E, UM • February 20, 1995 2T - 21 - Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field /Pool(s): 1008' FSL, 1574' FWL, Sec. 10, T11N, R8E, UM GL (ft above MSL): 82' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 700' FSL, 1503' FWL, Sec. 10, T11N, R8E, UM surface Kuparuk River 011 Pool • 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498945 • y - 5969898 ' Zone 4 •12821' MD / 6126' TVD • ADL 25569, 25568 TPI: x - 489406 y - 5965716 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 489335 y - 5965408 Zone 4 nipple @ 509' MD / 508' TVD 2666 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1462' MD / 1380' 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 Surf. 121' Surf. 121' 24" 225 sx AS I 9 -5/8" 40# L -80 Surf. 4772' Surf. 2901' 12.25" 870 sx AS III, 740 sx Class G 7" 26# L -80 Surf. 12804' Surf. 6115' 8.5" 275 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) 3.5" 12268' 12244' MD / 5755' TVD perfs squeezed off 12386 MD 5843' - 5865' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12436 12468' MD 5875' - 5896' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 39' 71 bbls Class G cement, 70 bbls AS 1 207 bbls AS 1 c ement retainer @ 6994' and 12245' 10.2 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q • Sidewall Cores Acquired? Yes ❑ No 0 • If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and 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 pe of 5.071. RECEI NONE 'F R 1 ii 1 RBDMS APR 0 8 1011 asks des ��• C® ad' Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only n7,C, r Y /3// A) / -2 G • 29. GEOLOGIC MARKERS (List all formations and markers entered): 30. • 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 1462' 1380' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 12384' 5840' Base Kuparuk C 12426' 5867' Top Kuparuk A 12426' 5867' Base Kuparuk A 12622' 5995' , N/A Formation at total depth: Kuparuk 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. 1 hereby certify that the foregoin. is true and correct to the best of my knowledge. Contact: Dan Herrmann @ 263 - 4619 Printed Name D. ann Title: Wells Engineer Signature t - ��� - Phone 263 - 4619 Date 04/707/ If Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 1---- --.,.., • KU P 2T -21 ConocoPhldIips ' Well Attribul ss Max Angie & MD ITD ( Wellbore APl /UWl I eld Naine Well Status Ind () MD (RKB) Act Bim (ft KB) J T 5010320212(,0 I; 11P41-1K RIVER UNI1 1PROD 70.73 11,220.93 12,821 0 Comment H2S (ppm) Date 'Annotation End Date KB.Grd (ft) Rig Release Date 1- Well C f g 2T - 21, 3282011 8 05 32 AM SSSV. NIPPLE 1___ 210 12/1512002 .Last WO: 5/24/1995 Schematic Actual Annotation '!Depth (RKB) End Date Annotation Last Mod .. End Date Last Tag TOC 1 12,201.0 12/2/2010 Rev Reason: CEMENT PLUG TO SURFACE Imosbor 3/28/2011 ae, Casin Strings e ' .1 Casing Description String 0... String ID ... Top (ftKB) Set Depth f Set Depth (TVD) String Wt... String String Top Thrd g piton 9 9 P( ) P ( -�- P ( ) �� 9 9 ��� 9 CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER, 36 SURFACE 95/8 8 - 697 39.9 4,772.4 2,900.9 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ItKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 , 6.151 346 12,804.0 6,1151 26.00 L -80 BTC mod Tub Strings - � Des cri p tion Tubing _ _ Str rig O. 'String ID . Top (ftK6) Set Depth (f.. Set Depth (TVD) String Wt... String .. String Top Thrtl ' TUBING I 31/2 I 2.992 I 36.5 12,267.9 I 5,768.7 930 L EUEABMOD CTO CONDUR, aoaz, 1 Completion Details i:1 Top Depth NIPPLE, 509 -- 4' l (ND) Top Intl Nomi... Top (ftKB) ( 11 Item Description Comment ID (in) 36.5 36.5 - 1.11 HANGER FMC GEN IV TUBING HANGER 3.500 GAS L FT. 2 , I 222 - -- 0 X. 508.7 507.4 9.45 NIPPLE CAMCO DS NIPPLE NO GO 2.812 CMT SOZ, 39 CMT PLUG, 39 - s} 12,235.8 5,749.7 54-11 NIPPLE CAMCO W -1 SELECTIVE NIPPLE 2.812 w ¢ 12,243.8 5,754.4 53.86 SEAL CAMCO KBH -22 Anchor Seal Assy 3.000 12,244.7 5,754.9 53.84 PACKER BAKER SAB -3 PERMANENT PACKER 3.250 12,258.0 5,762.8 53.43 NIPPLE CAMCO 0 LANDING NIPPLE 2.750 LA /5 12,267.2 5,768.3 53.15 SOS BAKER Wire Line Entry Shear Out E LMD TTL @ 12260' during PERF 2.992 SURFACE, - on 07/07/2000 40.4.77 _ __ - -__. -_._ - " -. __. .. Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) , s, ., -„4 ,- Top Depth (TVD) To Ind G�511994- I A .. , Top MKS) (RKB) Top ) Description Comment Run Date ID (in) CEMENT - 39.0 39.0 - 0.65 CMT SQZ Pumped 71 bbls'G' cement, followed by 70 bbl 'AS1' 10/9/2010 7.000 PLUG, 34 CEMENT cement. Bullheaded down the OA and Out at the shoe. 0.5 PLUG, 6,425 ( .. bbl diesel cap on OA. CEMENT RETAINER, - a 39.0 39.0 -0.65 CMT PLUG CIRCULATED 207 BBL OF 15.7 ppg'ARCTIC SET 1' 3/26/2011 0.000 lc, � s ' DOWN TUBING & UP THE IA; TUBING & IT CEMENTED TO SURFACE Gas LIFT, / 6,994.0 3,724.9 68.29 CEMENT INFLATABLE CEMENT RETAINER 12/25/2010 0.000 7,286 �/ RETAINER 12,156.0 5,703.9 56.38 TBG Punches PRE -CTD TUBING PUNCHES 12/4/2010 2.992 GASUFT, , , , wmny , 12,245.0 5,755.1 53.88 BAKER CEMENT BAKKER 2.125" INFLATABLE CEMENT RETAINER, 12/3/2009 0.000 9 ' 1 � - - 1 - ,✓ RETAINER OAL =10', NO ID DUE TO DUAL FLAPPER CHECKS - SET ON 10.2 bbls OF 15 88 CEMENT GASUFT, Perforation Slots 10.240 c Shot __.. Top (ND) Btm (TVD) Dens Tikii F Top (RKB) Btm (RICE)) (BKB) (ftKB) Zone Date (sh... Type Comment Vi 12,386.0 12,406.0 5,842.8 5,855.8 C-4, 2T -21 7/7/2000 4.0 APERF 2 1/2" HSD TeG Punches, Z`: _ f e 12,402.0 12,420.0 5,853.2 5,864.8 C4, 2T -21 6/9/2002 6.0 RPERF 2.5" 2506 PJ, 60 deg Phase 12,156 - `; u'. ✓ 12,436.0 12,468.0 5,875.2 5,896 -0 A4, A -3, 2T -21 6/4/1995 6.0 IPERF 2 1/8" Enerjet; 90 deg ph; oriented +/- 5,: V. = Y 45 deg f/lowside Gas LIFT _ �_ 12,447.0 12,467.0 5,882.3 5,895.4 A -3, 2T -21 6/6/1995 4.0 RPERF 2 1/8" Enerjet; 180 deg ph oriented 12,190 x - -_ -. 90 deg left & right PLUG, 6,995 Notes: General & Safety CEMENT � End Date Annotation "1 > 10/17/2003 NO'. 0 POSSIBLE LEAKS FOUND @ 5808', 5590', AND 5398' NIPPLE, 12,2% 10/17/2003 NOT 0 TUBING LEAKS FOUND @ 6958', 6740', 6460', 6270, AND 6194' _ - _ ... f 3 12/14/2010 NO' 0 VIEW SCHEMATIC w /Alaska Schematic9.0 SEAL. 12.244 -___._ PA0(ER,__. -_. �/ IJ 12,245 gg?.. {.rr` CEMENT 8 RETAINER, 12,245 . NIPPLE, 12,258 - -- t S00,12,267- 41 10 APERF, 12,386 - 12,406 a• RPERF, °t = a 12,402- 12,420 ._ -._. _.___._. -. -. ..... _._ _... _.._. Mandrel Details Top Depth Top Port ( Intl OD Valve Latch Size TRO Run 12,43&12,468\ ,. r, Stn Top (ftKS! (15K0) 0) Make Model (hr) Sery TYpa TYPe (in) ( Run Date Com... RPERF, f.: , u,,,, _ 1 2,222 0 1,909:3 56.22 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/8/2003 12,447 12,467 s °"` 2 5,194.3 3,062.0 69.13 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/2/2010 ` - 3 7,286.5 3,834.4 68.07 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 10/8/2003 CEMENT PLUG, 12,201 4 9,103.4 4,511.9 69.05 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/2/1997 5 10,239.9 4,947.3 65.84 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/30/1998 6 12,190.3 5,723.1 54.85 CAMCO MMG 1 1/2 GAS LIFT OPEN RK 0.000 0.0 11/26/2009 s PRODUCTION, 35- 12,804 TD, 12,821 2T -21 Well Work Summary DATE SUMMARY 5/21/10 performed pre cement injection tesumped 15 bbls 50 deg F diesel down the aking returns to the formation via the casing leak. 1 bpm @ 1400 psi for 4 bbls, 1 bpm @ 1700 psi for 6 bbls, 0.05 bpm @ 1300 psi for last 5 bbls. 10/9/10 Cemented OA from surface to shoe. Pumped 50 bbl fresh water, 71 bbl "G" cement followed by 70 bbl of "AS1" and flushed with 0.5 bbl of diesel. 10/11/10 TAGGED TOC @ 12201'SLM. PULLED DV © 5194' RKB. READY FOR CTU. 10/13/10 MITOA FAILED 12/2/10 SET DV @ 5194' RKB. TAGGED CEMENT TOP @ 12201' SLM. READY FOR E /L. 12/4/10 PERFORATED TUBING AT A DEPTH FROM 12165'- 12171' USING 2" X 6', 4 SPF, 0 DEG PHASING, MILLENIUM CIRCULATING CHARGES. GUN WAS DECENTRALIZED USING MAGNETIC SUBS ABOVE AND BELOW GUN TO ALIGN PERFORATIONS AGAINST TUBING WALL. 12/25/10 SET INFLATABLE CEMENT RETAINER & PUMP CEMENT, SET ICR @ 6994 COIL RKB, PUMPED 190 BL OF 15.8 CLASS G CEMENT, 45 BL TO 3.5" TUBING FROM 12201 RKB TO BOTTOM OF ICR, LAY IN 5 BL ABOVE ICR TO 6425 RKB , PUMP 139 BL TO IA FROM TOP OF PACKER @ 12244 RKB TO APPROX 7000 RKB, TUBING & IA FP, IN PROGRSS 12/31/10 ECOUNTER CEMENT STRINGERS f/ 3925' TO 4239' SLM, OBTAIN SAMPLE. UNABLE TO CIRCULATE FROM TBG TO IA. TURN WELL OVER TO CTU. 1/28/11 MILLED CEMENT STRINGER FROM TUBING STARTING AT 3500' CTMD DOWN TO 6000' CTMD.LITTLE TO NO MOTOR WORK OBSERVED DURING JOB. ESTABLISHED STEP RATE INJECTION TEST WITH DIESEL (TBG x IA) WITH A MAX RATE OF 3 BPM @ 315 PSIG WHP ACHIEVED. WELL LEFT SHUT IN AND LOADED WITH DIESEL. TURN WELL OVER TO DSO. 3/25/11 CIRCULATED 207 BBL OF 15.7 PPG "AS1" CEMENT DOWN THE TUBING TAKING RETURNS UP THE IA WITH FULL CEMENT RETURNS AT END OF JOB. FINAL PUMP RATE 4.5 BPM @ 1100 PSI WITH 1:1 RETURNS DURING THE ENTIRE JOB. TUBING AND IA WENT ON A VAC AFTER SHUT DOWN. PUMPED 1.5 BBL OF DIESEL DOWN THE TUBING AND IA. 3/29/11 MITT- PASSED; MITIA- IN PROGRESS 3/30/11 MITIA - FAILED • IP WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 17, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -21 Run Date: 12/4/2010 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 -21 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20212 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. ���� 3 Anchorage, Alaska 99518 Office: 907 - 273 -3527 65 *-4- Fax: 907 - 273 -3535 klinton.w h f fin. �s .• 1 � Date: Signed: ,tartsn ''a (S ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 19, 2010 F Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 t+R Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -21 (PTD 195 -013) 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- 21 (PTD 195 -013). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loviand ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon rl Repair well Plug Perforations Stimulate r_1 Other r Suspended Well Pull Tubing Inspections Alter Casing C � g r Perforate New Pool � Waiver (� Time Extension r Change Approved Program f Operat. Shutdown (! Perforate Re -enter Suspended r 2. Operator Name: 4. Current Well Status: 5. Permit Drill Number: ConocoPhillips Alaska, Inc. Developmen r Exploratory 195 -013 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphi r Service F N 50- 103 - 20212 -00 7. Property DesignatioQ: 8. Well Name and Nun*er: ADL 25568 ♦ i 2T -21 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 12821 feet Plugs (measured) 10245 - Cement true vertical 6126 feet Junk (measured) NONE Effective Depth measured 12741 feet Packer (measured) 12244 true vertical 6056 feet (true vertucal) 5754 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121 121 SURFACE 4772 9.625 4772 2900 PRODUCTION 12804 7 12804 6115 Perforation depth: Measured depth: 112386-12467'- Cemented True Vertical Depth: 5842' -5895' -Cemented Sc to 2010 Tubing (size, grade, MD, and TVD) 3.5, L-80,12268 MD, 5769 TVD� Y Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3, PERMANENT PACKER @ 12244 MD and 5754 TVD Nipple - No SSSV 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: N. Copies of Logs and Surveys run Exp loratory r - Develop r Service r Daily Report of Well Operations X 15. Well Status after work:SuSpe+�c�e� Oil Gas WDSPL GSTOR r WAG F GASINJ [7' 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: NIA Contact MJ Loveland /Perry Klein Printed Name MJ Loveland/Perry Klein Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date RBDMS SEP 2 3 2014 Form 10-404 Revised 7/2009 g -Z 7" !-) Submit Original Only • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days inspection to allow witness p s rior to ins Well Name: Kuparuk Riv Unit 2T -21 Field /Pool: Kuparuk RivedKuparuk River Pool Permit # (PTD): 195 -013 Sundry 309 -360 API Number: 50103202120000 Operator: ConocoPhillips Date Suspended: 12/3/2009 Surface Location: Section: 83 FNL, 556 FWL, sec 12 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: (,cY69 Pad or location surface: & ml e !; " (t�j�{/ Location cleanup needed: JVO Pits condition: Surrounding area condition: Water /fluids on pad: "D Discoloration, Sheens on pad, pits or water: ; Samples taken: <NZ Access road condition: -g 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 /valvedescription,condition: ,t40W1,1WC A1 73effXP, G ear, go, ,ap ,oi -P 0 i h _y MJK t .P--, Cellar description, condition, fluids: Rat Hole: N ew r 0`1RO& ? -Jtl&y Wellhouse or protective barriers: LA,) f&g age Well identification sign: 4 fAHju'rjrZ> e W -Ma*„ ,6(441 OV W6&�O s Tubing Pressure (or casing if no tubing): -K lAf Annulus pressures: a / 44, z ,L1 f 12e.2" Wellhead Photos taken (# and description): p/ gGG- �! Ate , TiCo, -® Work Required: 1 G cL�d g-t?wt . e/Zo S / /,,' Operator Rep (name and signature): � AOGCC Inspector: / te r, Other Observer f Inspection Date: * /mac, / 1.0 AOGCC Notice Date: Time of arrival: I Time of Departure: Site access method: 11-F -A CAr KU P 2T -21 ConocoPhillips Well Attributes Max Angle & MD JTD APa�«. =f, 111 Wellbore APl /UWI Field Name Well Statue Incl( °) MD(ftKe) ActBtm(ftKB) 501032021200 KUPARUK RIVER UNIT PROD 70.73 11,220.93 12,821.0 Comment H2S (ppm) jDate Annotation End Date KB -Grd (ft) Rlg Release Dab ••• W."C. :-2T-215/17/20101:53:13PM SSSV:NIPPLE 210 12/1512002 Last WO: 5/24/1995 Schama5c -A. Annotation Depth (ftKB) lEndOate lAnnotation iLast Mod By End Data Last Tag: 12,568.0 2/17/2005 1 Rev Reason: Correct CMT Retainer Set Depth I Imosbor 5/17/2010 Casing Strings Siring OD String ID Set Depth Set Depth (ND) String Wt String Casing Description (in) (in) Top (ftKB) (ftKB) (ftKB) (Its/ft) Grade String Top Thrd CONDUCTOR, CONDUCTOR 16 15.062 0.01 121.0 121.0 62.58 H-40 121 SURFACE 9518 8.697 0.01 4,772.0 2,900.8 40.00 L-80 PRODUCTION 7 6.151 0.01 12,804.0 6,115.1 26.00 L-80 NIPPLE, 5509 Tubing Strings String OD I String ID Set Depth Set Depth (ND) String Wt String Tubing Deacription (in) (in) Top (ftKB) (ftKB) (PIKE) (Ibs/ft) Grade String Top Thrd TUBING 1 3112 2.9921 0.0 1 12,268.0 5,768.81 9.30 1 L -80 ABM -EUE GAS LIFT, Other In Hole All Jewelry: Tubing Run & Retrievable, Fish, etc. 2 222 Top Depth (ND) Top II Top IRKS) (ftKB) (°) Description Comment Run Date ID (In) SURFACE, 509 507.7 9.45 NIPPLE Camoo'DS' Nipple NO GO 5/25/1995 2.812 4,772 2,222 1,909.2 56.22 GAS LIFT CAMCO/KBUG/1 /DMY/BK/// Comment: STA 1 10/8/2003 2.920 5,194 3,061.9 69.12 GAS LIFT CAMCO /KBUG/1 /DMY /BK/ // Comment: EXT PKG STA 2 1018/2003 2.920 7,286 3,834.2 68.07 GAS LIFT CAMCO /KBUG11 /DMY /BTW /1 Comment: STA 3 10/812003 2.920 GAS LIFT, 9.194 9,103 4,511.8 69.05 GAS LIFT CAMCO 1KBUG/1 1DMY /BK1/I Comment: STA 4 41211997 2.920 10,240 4,947.4 65.84 GAS LIFT CAMCO /MMG/1.5/DMY /RK/ // Comment: STA 5 3/3011998 2.920 12,190 5,723.0 54.85 GAS LIFT CAMCO /MMG/1.5 /OPEWRK/ / / Comment: STA 6 1126/2009 2.920 GAS LIFT, 12,236 5,749.8 54.10 NIPPLE Carrico W -1' Selective Landing 5/25/1995 2.812 7,286 12,244 5,754.5 53.86 PACKER Baker SAB-3, PERMANENT PACKER 5/25/1995 4.000 12,245 5,755.1 53.83 CEMENT BAKER 2.125" INFLATABLE CEMENT RETAINER, 1213/2009 0.000 RETAINER 0 1U', NO ID DUE TO DUAL FLAPPER CHECKS - SET ON 10.2 bbls OF 15.8# CEMENT GAS 9i 3 12,2581 5,762.81 53.43 NIPPLE Camco'D' Nipple NO GO 52511995 2.750 12,2671 5,768.2 53.15 SOS Baker 5/2511995 2.992 12,268 5,768.8 53.12 TTL I I ELMD TTL @ 12260' during PERF on 07/072000 525/1995 2.992 GAS 10IZ 3 Perforations & Slots shot Top (ND) St. (ND) Dena Top (ftKB) Bum (ftKB) (ftKB) (ftKB) Zone Date (sh••• Type Comment 12,386 12,406 5,842.8 5,855.8 C-4, 2T -21 7!7/2000 4.0 APERF 212" HSD 12,402 12,420 5,853.2 5,864.8 C-4, 2T -21 6/92002 6.0 RPERF 2.5" 2506 PJ, 60 deg Phase 12,436 12,468 5,875.2 5,896.0 A-4, A-3, 2T -21 614/1995 6.0 IPERF 2 1 /8" Enerjet; 90 deg ph; oriented +/- GAS LIFT, 45 deg fAowside 12,190 12,447 12,467 5,882.3 5,895.4 A3, 2T -21 6/6/1995 4.0 RPERF 2 1/8" Enerjet 180 deg ph; oriented 90 deg left & right Notes: General & Safe End Date Annotation NIPPLE, 12,236 10/17/2003 NOTE: POSSIBLE LEAKS FOUND @ 5808',5590', AND 5398' 10/17/2003 NOTE: TUBING LEAKS FOUND 115958', 6740', 6460', 6270, AND 6194' PACKER, 12,244 CEMENT RETAINER, 12,245 NIPPLE, 12,258 SOS, 12,267 TTL 12,263 APERF, 12,386 - 12,406 RPERF, 12,402- 12,420 PERF, 12,43&12,468 RPERF, 12,447- 12,467 CEMENT PLUG, 10,255 PRODUCTION, 12, 804 TD, 12,821 i + I + II --} II I + II I f I + I + I + E 16 +00 00 I 0 ° o l I 00 ° o l I o0 I °o N O w � + + N N N a _N 2 Z Z Z Z Z 2 D - -- - -- I DRILL S 2T + + I + I + I E 14 +00 + II I E 12 +00 - - I d' I r -ao¢ r31 _ � aJ _ T 4 II'1J a�rl• t16 sib � � •� • � p cpg _ T � — j 4; & $ 27t� - - - w oyinse e ♦ n w A R ' BAi9 & R ri R i5 i5 Ri675F F RA N I I + I I I + II + I —{— —{— I E10 +00 - - - SCALE . 100 0 50 100 LEGEND 0• THERMOSIPHONS 1 "= 100' 0 WELLS T.otJxssum . .eeoetm ac. FORM: BSIZE "� DRAWN: DESIGN: ECM NO. 1/ AREA: 2T MODULE: )OODf UNIT: D2 CHECKED: AJR APPROVAL CC NO: ConocoPhillips PLOT PLAN — — — Alaska, Inc. 1 130 10 Updated Thermosi hon and Well Asbult locations NRB JFC SCALE: DATE: CADD nLENAME: JOB NO: SUB JOB N0: I DRAWING NO: PART: RM REV DATE REVISION BY CHK JOB PROJ 1' = 100' 3/13/09 DS2T PLT PLN 3/13/09 NSDK 1 0000 DS2T PLOT PLAN 1 OF 1 1 V ' i y I m . � � �:' a •. r' a / \ a I I I I � • I �� • 1 I • • •■ • • • r i i i i i iJ J` .«.•r i1i r Ji JV I•JJ! i rii Nii: � i A' �i ! J J ! t !•/•r .� NJir iNiii iNi -v a '_ t NN JirN ..iii i ii i � ✓ ? i ,., A •Mrs iJi i iVW.I MJir M � ' ry� i ��� !i yr•.r JJ.ri.. � i 1 Div _ rr� a • -,, ICY -:. + irr• A . �• .. , rrs.rvs� wr.r .w•..� e- _.. ......•aAr .. .--a .*., ,r.r►w�s� ,r�Mi ri•r•.r�rr•r -mss s^ %'" e.. ^q, . • ... .. „�. e+s* �r.r :twre+ rrr�- ew.ws.t��s rss• -. � Aim I 0 $ 1 291201 (T 1:'02" ' •.r�,�• •�s�� ♦. slur` 1♦ 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-21 Oper.Rep: Ian Ives PTD No.: 195-013 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ler(specify in commei Onshore/Offshore: Onshore Suspension Date: 12/03/09 Date AOGCC Notified: 08/28/10 Sundry No.: 309-360 Type of Inspection: Initial " Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 100 Photos Taken? Yes IA 180 OA 400 SCANNED AUG 1 4 2015 Condition of - Wellhead: Wellhead location was verified with a plot plan,Wellhead looked to be in good working condition with no signs of leaks. Well has flowline attached with 100 psi on F/L. IA has AL line attached but blinded,OA is blinded with gauge. Wellhead has wooden cellar box found to be dry and free of oil.Wellhouse was removed for on-going dirt work. Condition of Surrounding Surface Surface location looked good,dirt work in progress on the pad. • Location: Follow Up Actions None Needed: Attachments: Photos(4) ' REVIEWED BY: Insp.Supry Je)C Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-21_bn.xlsx t `,,\ r�616 . ,i 44 0 1 1 '� ; ' 1, ' u , ---�`",.� /ter. '. :' :.(.a44.4 ,:,;,.,. 3 rkl 404 r' ' ' rqp ii il■■. -- /il '1161'''-1 it ,, ,,,,,,,f. .'' '',...',. .'":-..-;,:k.iiir.,...:(''' 'r''... ' :' '''' 111 Ile , '', ..' w imin. I 11 ' x :; fie. • ,,,, ..,..-7- 1[7,,f,z ' t . 0111111 � '`}t ',,� ��s��ii�� � � 1. ,�� ., ,� ����� 11� ii'll. 1111N ► ���� 1� 111�, 11111N ll � Rj Z \ 0 10 tr ss F 11$0%1"0 -oo ._ -' cl cA .• . 0 '''.. 1:''''7''''''';'''!:"IN A • ,- 1 .. ' M4 4;:z.;;t:,::::,,;',;'''Igillil i. ,' tall la ofD C) V� Q Q w . t 'fir p '1! ►�Y j�Ey{ < < b4 • Film tr. r - iir- i 1 I A AV 4, ..,.,0,•'In .1ii1; .2 f4 i . ir— . s', ,T1 ".• ' . -. ',At.:,...... • - . , _. 72111L ..., 0101i,. N - - F ,,,, v,..., ... . k -,.2 \ yaw . kt, i1 1p. Sibb ') ik'f 1 'IL il I ir- ALIO% , 1 0 0 , :Na 111 / E-1 (NI ,..., 't - ,. • ..., L, , CI) at*, 411111111M—apil .. , gl 2 oo 0 o . - to c cz iiiiiiatln //III Ii; i y' . . ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 /~ ~~ August 1, 2010 ~ `, r ~q ~ ~~ Commissioner Dan Seamount ~~'~~~ Alaska Oil & Gas Commission 333 West 7t" Avenue, Suite 100 s ~m ~~ ~~ 201 Anchorage, AK 99501 ~ ~` Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form.10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have .any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off I/ Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~n ~v n-r own ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date -. -, Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF Na 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • • ~~p~~ 0~ adp~~(Q /.E...~..~o~,.oa Dan Herrmann Wells Engineer % ~ O ConocoPhillips Alaska, Inc. ~~~~~~~-~i~,. ~ ~~ ~~ ~ ~~ ~~~~ ~ ~ ~ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-21 Sundry Number: 310-234 Dear Mr. Herrmann: 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. Please note, this well will be classified as suspended pending receipt and approval of an application, submitted pursuant to Article 2, 20 AAC 25, to abandon the well. 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, Cathy/P. Foerster Commissioner DATED this ~ d y of August, 2010. Encl. STATE OF ALASKA \ALAS~IL AND GAS CONSERVATION COMMISS~ ~~,r~ ~~ APPLICATION FOR SUNDRY APPROVALS ~'~ ~`~ '~ n „ ~ S 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill ~" Perforate New Pool Repair well ~"; Change Approved Program ~"" Suspend ~""~ Rug F~rforations ~; Perforate ~"" Pull Tubing Time Extension ~'""` Operational Shutdow n Re-enter Susp. Well ~ Stimulate ";,; After casing ~- Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ . Exploratory ~'°" 195-013 3. Address: Stratgraphic ~ Service "` 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20212-00• 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ~~, No r`', 2T-21 ' 9. Property Designation: 10. Field/Pool(s): ADL 25569, 25568 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effeaive Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12821 6126 10245' 4949' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121' 121' SURFACE 4772 9.625 4772' 2901' PRODUCTION 12804 7 12804' 6115' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12386'-12420', 12436'-12468' 5843'-5865', 5875'-5896' 3.5 L-80 12268 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER SAB-3, PERMANENT PACKER MD= 12244 TVD= 5754 12. Attachments: Description Sumrery of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program "` BOP Sketch ~ E~loratory ]" Development Service "" 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/11/2010 Oil ~" Gas WDSPL Suspended 16. Verbal Approval: Date: WINJ ~" GINJ WAG ~ Abandoned ` Commission Representative: GSTOR ~~ SPLUG ~ 17. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Dan Herrmann @ 263-4619 Printed Name Dan Herr ann Title: Wells Engineer Signature Phone: 263-4619 Date Q-j~~jq,/(~ mmi i n Sundry Number: 2j 1~ ~ /+~~ / Conditions of approval: Notify Commission so that a representative may witness // Q(,/ Plug Integrity BOP Test ""' Mechanical IntegrityTest """ Location Clearance """ ~~L..~Vi.~.~ Other. ~~~ ~ ~ ~~~~ ~~~~~ ~ ~ ~~ e~• ~9t1'M'tliSSl Subsequent Form Required: ~ ~ - yQ~ ~ftchar~~ APPROVED BY ~~ ~ ~~~~ ~~ Approved by: ~;j/ COMMISSIONER THE COMMISSION C -PV' ` ~f%yG~l~l~^-~ f ~~ Date: '° v ~o ~' ~ Form 10-403 Revised 1/2010 O ~ ~ G nas AUG 0 91010 Submit in Dupl' t~,~/~O I t... ''/ i ~~rt~eciPh~ilips . Y. _t +R Vii. {f1C.. CONDUCTOR, _. 121 NIPPLE. 600 - -- GAS LIFT, ___.- 2 222 SURFACE, 4,J72 GAS LIFT, 6,154 GAS LIFT, J.286 GAS LIFT, 9.103 GAS LIFE, 10,240 GAS LIFT, 121so NIPPLE, 12,236 PACKER, 12.244 CEMENT RETAINER. 12.245 NIPPLE. 12.25a SOS, 12,26] TTL, 12.266 - -- (PERF, 1243612,466 RPERF, _ - 12.44]-12,46] CEMENT PLUG, 10,255 PRODUCTION, 12,804 \ TD, 12,821 -- KUP 2T-21 '~ ~ Well Attribut Wellbore APW WI ~ es Field Name Max Well Status lncl (°) Angle & MD MD (ftKB) ~TD Act Bim (ftKB) I I UK RIVER UNIT 00 KUPAR ~ (PROD ~ 70.73 I 11,22093 ~ 12.8210 Comment , 3 Date H2S (PPrn) An ttlon End Date KB-Grd (ftl IRig Release Da PPLE __. ~SSSV N ( 210 12/15/2002 / Last WO 5/24/1995 M (Annotation Depth (ftKB) End Date Annotation ~ Last Mod By End Date Last Tag: ~ 12,568 0 ~ 2117/2005 (Rev Reason' Correct CMT Retainer Set Depth Imosbor _ 5/17!2010 Casin Strin s String OD String ID _ Set Depth Set Depth (TVD) String Wt Sfring i Casing Description (in) (in) Top (ftKB) (ftKB) (ttK8) (Ibslft) Grade String Top Thr CONDUCTOR 161 15.062 0.0 121.0 121.0 62.58 H-00 6.151 TUBING 3112 29921 O.OI 12268.UI S,/68.8I 9.301 L-iiU 1 At51Vl-tut Other_In Hole ( Top Depth All Jewelry:. Tubin Run 8 Retrievable, Fish, etc.) - _, (FVD) Top Inc! fop (ftKB) (ftKB) (°) Description Comment Run Date ~ ID (in) 509 507.7 9.45 NIPPLE Camco'DS' Nipple NO GO 5/25/1995 8 2,222 1,909.2 56.22 GAS LIFT ~ICAMCO/KBUGl1/DMYlBK///Comment: STA 1 10/812003 ! 2.920 5,194 3,061.91 69.12 GAS LIFT '~CAMCOIKBUGl1/DMY/BK///Comment EXT PKG STA 2 10/8/2003 i 2.920 - __ 7,286 3,834.2 ~'1 68.07 GAS LIFT iCAMCOIKBUG/11DMY18TM///Comment: STA 3 10!8/2003 2.920 9,103 4,5118 69.05 GAS LIFT CAMCO/KBUG/1/DMY/BK///Comment STAR 4/2/1997 2.920 _ 10,240 4,947.4 65.84 GAS UFT -- CAMCO/MMG/LS/DMY/RK//l Comment: STAS ~ - 3/30/1998 2.920 12,190 5,723.0 54.85 GAS LIFT CAMCO/MMG/1.5/OPEN/RK/1/Comment STAB 11/26/2009 2920 12,236 5,749.8 54.10 NIPPLE Camco'W-1' Selective Lantling 5!25/1995 2-812 12,244 5,754.5 53.86! PACKER Baker SAB-3, PERMANENT PACKER 5/25/1995 1 4.000 12,245 5,755.1. 53.83~ CEMENT .BAKER 2.125" INFLATABLE CEMENT RETAINER, 12/3/2009 0.000 1 RETAINER !OAL=10', NO ID DUE TO DUAL FLAPPER CHECKS -SET ION 10 2 bbls OF 15.8f7 CEMENT 12,258 5,762.8 53.43 NIPPLE Camco'D' Nipple NO GO 5/25/1995 2.750 12,267 5,768.2 53.15 SOS Baker 5/25/1995 2.992 12,268 5,768.8 53.12ITTL ___ ELMD TTL ~Ta 12260 during PERF on 07/07/2000 5/25!1995 2.992 Perfora tions & Slots Shot ~ P (7y 1 Dl BL D T Dens Top (ftKB) I BM (ftKB) (ftK j (ftKBI ~ Data (sh~~~ Type I __ -. C mme_M ne Z _ 12,386 1 12 406 5,8428 5 855.8 C-0, 2T-21 7/7/2000 4.0 APERF 2 1/2" HSD _ 12,402 I 11 12,420 5,853.2 5 864.8 C-0, 2T-21 6!9/2002 6 0 RPERF 25" 2506 PJ, 60 deg Phase 12,436 12,468 5,875 2 5,896.0 A-0, A-3, 2T-21 6/4/1995 6.0 (PERF 2 1/8" Enerjet; 90 deq ph; oriented +/- 45 deg f/lowside 12.447 __ I 1 12467' 5,882.3 5,895.4 A-3, 2T-21 6/6/1995 I 4.0 RPERF 21/8" Enerjet; 180 deg ph; orientetl ~, 90 deg left 8 right I I Notes: General -__._.. 8 Safety .__-__ _- __- -_ . __ - __ ' - _-- _ - End D ate Annotat on 10/17/2003 NOTE POSSIBLE LEAKS FOUND ~ 5808' 5590, AND 5398' ' 10/17/2003 - - - NOTE: TUBING LEAKS FOUND ~ 6958', 6740 6460', 6270, AND 6194' Well 2T-21 Proposed Plug and Abandonment 2T-21 is a Kuparuk producer with multiple holes in the tubing between the gas lift mandrels @ 7286' & 5194' RKB. The well also has a couple of production casing leaks around 5435'-5456' RKB & at 5650' RKB. Because of the tubing and production casing leaks, a cement retainer was set @ 12,555' RKB and the perforations were cemented off on 12/03/09. The well was completed with an open surface casing shoe. In order to secure the well for permanent abandonment, cement needs to be bullheaded . down the OA and circulated down the tubing & IA. Proposed Plug 8~ Abandonment Procedure: Cementing Unit 1. Pump 68 bbls of 15.8 ppg class G cement followed by 69 bbls of AS1 cement down the Surface Casing by Production Casing Annulus. Shut-in the well & Allow 24 hours to setup Slickline 2. Pressure test OA to 2500 psi, hold for 15 minutes, then bleed OA to 0 psi. 3. RIH & Tag TOC @ 12,244' RKB 4. Pull DV set @ 12,190' RKB & 5,-194' RKB & leave both pockets open to allow circulating points for cement. Coiled Tubing 5. RIH with inflatable cement retainer (ICR) to 7000' RKB and begin pumping 100 bbls of freshwater gradually building to a pump rate of 2 BPM down the Coiled Tubing w/ the tubing shut in, taking returns up the Tubing X Production Casing annulus to establish a circulation rate. Once a circulation rate has been established, drop setting ball and pressure by gradually stepping pressure up to 2500 psi to shear ball seat; this will position the ICR ~42' below the lowest tubing leak. 6. Pump 184 bbls of 15.8 class G cement, taking returns up the Tubing x Production Casing Annulus. 7. Sting out of ICR, PUH to 5250' RKB while laying in cement from 7000' RKB to 5250' RKB. With nozzle parked at 5250, begin pumping 45 bbls of 15.8 class G cement. Take 1 for 1 returns up the Tubing X Production Csg annulus to a strappable tank. Note: Make sure to closely monitor returns. If returns are still being lost after pumping the 60 bbls of cement, continue pumping until 1 for 1 returns if 1 for 1 returns are not obtained stop pumping @ 68 bbls of cement. 8. Let cement set for 24 hours & perform CMIT on tubing & IA to 2000 psi, bleed Tubing & Tubing X Production Casing annulus to 0 psi. a. If Tubing & Tubing X Production Casing annulus cannot be pressure tested together, pressure test the IA to 2000 psi and record pressure test. Go to step # 9 if the IA pressure tests and the tubing and IA are isolated from each other for tubing punch procedure. E-Line (contingencvl 9. RIH w/ CBL tool & tag TOC, log up to find TOC in the IA, POOH. 10. RIH w/ tubing punches & perforate tubing in first full joint above TOC in the IA. Cementing Unit 11. Begin pumping 50 bbls of freshwater @ 2 BPM down the tubing to establish a circulation rate and pressure, Take Returns up the IA. 12. Pump 60 bbls of AS1 cement followed by 115 bbls of 15.8 class G cement followed by 18 bbls of AS1 cement tail slurry, taking returns up the IA. 13. Leave Tubing & IA Shut in 14. After 24 hours, Pressure test Tubing & IA to 2500 psi for 15 minutes, bleed Tubing & IA to 0 psi. (o G /l5 .~- 19 3 /,~,~c. S • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~;~IVEL~ DEC ~ ~ ?E~D9 WELL COMPLETION OR RECOMPLETION REPOR~6,s.Commissif~fy 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Plugged ^ OAAC 25.1d05^ 20AAC 25.110 ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other ^ No. of Completions: Developments ^ ~>w ~fEx~p oratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 3, 2009 12. Permit to Drill Number: 195-013 / 309-360 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 14, 1995 13. API Number. 50-103-20212-00 4a. Location of Well (Governmental Section): Surface: 83' FNL, 556' FWL, Sec. 12, T11 N, R8E, UM 7. Date TD Reached: February 20, 1995 14. Well Name and Number: 2T-21 Top of Productive Horizon: 1008' FSL, 1574' FWL, Sec. 10, 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: 700' FSL, 1503' FWL, Sec. 10, T11 N, R8E, UM 9. Plug Back Depth (MD + ND): 10245' MD / 4949' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498945 y- 5969898 Zone- 4 10. Total Depth (MD + ND): 12821' MD / 6126' ND 16. Property Designation: ADL 25569, 25568 TPI: x- 489406 y- 5965716 .Zone- 4 Total Depth: x- 489335 - 5965408 Zone- 4 1 L SSSV Depth (MD + ND): nipple @ 509' MD / 508' TVD 17. Land Use Permit: 2666 18. Directional Survey: Yes ^ No ^/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft SL) 20. Thickness of Permafrost MD/TVD: approx. 1380' 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 MD/ND not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 121' Surf. 121' 24" 225 sx AS I 9-5/8" 40# L-80 Surf. 4772' Surf. 2901' 12.25" 870 sx AS III, 740 sx Class G 7" 26# L-80 Surf. 12804' Surf. 6115' 8.5" 275 sx Class G 24. Open to production or injection? Yes ^ No Q If Yes, list each 25. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/ND) 3.5" 12268' 12244' MD / 5755' TVD 12386'-12420' MD 5843'-5865' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12436'-12468' MD 5$75'-5896' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ((~~y 'y 10245' 10.2 bbls 15.8 cement ~ ~~yy (( hh'' (~.1 4~~r ~4~~9't3~ J,~11~ ''" ~ rr.U ii1 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 Q Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+ND 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 7/2009QQDMQ ~C $1 e<~L~I v'ED ON REVERSE Submit original only 28. GEOLOGIC MARKERS (List all formations and marker untered): 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 1380' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 12384' 5840' Base Kuparuk C 12426' 5867 Top Kuparuk A 12426' 5867' Base Kuparuk A 12622' 5995' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed N J. Ennis Title: Wells Engineer ~ 6 a~ Signature Phone 265-1544 Date \\ INSTRUCTIONS Sharon Allsup-Dreke 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 KU P ~ 2T-21 ell Attributes _ (Max Angle & MD _ TD (bore APl/l1Wl 'Field Name Well Status Intl (°) MD (ftK6) Act Btm (ftKB) Sn1nZ~n~t~nn k IPaRIIK PIS/GR IINIT Penn 17!172 11 ~~(1 Q2 1~R71D Comment End Date KB-Grd (ft) H25 (ppn) (DateAnnotation Rig Release Date SSSV: NIPPLE 210 I I 12/15/2002 'Last WO; 524/1995 Annotation 'Depth (ftK6) IEnd D t (Annotation last Mod By _ End Date Last Tag I 12,568.0 2/1 72005 Rev Reason: Pull CR Lock Assy, Set CMT Ret. li Imosbor l 12/4/2009 Casin Strin s Strin OD 9 __ _ Strin ID 9 _ Set De th P ( 1 String Wt Sfring Set Depth ND n Casi D g escri lion P (in~ (in) p ( ) To ftK6 (ftK6) (Ibs/ft) 'I Gmtle (ftK6) String Top Thrd CONDUC TOR 16 15.062 0.0 121.0 6258H~0 121.0 ~- SURFACE ---- 95/8---P,.G97 0.0 4,772.0 2,9008 40.00'L-80 PRODUCTION I 7' fi.1 S1 0.0 12,804.0 6,115.1 26.00'~L-80 ` I Tubing Strings . _ ____ _-_-- __ __ _-- ' String OD String ID Set Depth Set Depth (ND) 'String Wt ~i Sfring ' Tubing Description '~ (in) iin) Top (ftK6) (ftK6) (ftK6) '. (Ibs/ft) it Grade String TOp Thrd TUBING 3 V2 "~ .- 992 9.30iL-80 ,ABM-EUE 0 0 12.268.0 5,765.81 Other I I n Hole (A ll Jewelry: Tubin _ -_ g Run & Retrievable,. Fish, etc.). ~~~ , ' Top Depth (TVD) Top Intl Top (ftK6) (kK6) Descrip ti on (°) Comment___. Run Date ID(ini 509 507.7: 9.45 _ _ _ _ NIPPLE ~ 'Camco'DS'Nipple NO GO 5/25/1995 2.812 2,222 1,909.21 56.22 GAS LIFT ~GAMGO/KBUG/11DMY/BK/// Comment; STA 1 10/8/2003 2.920 5,194 3.061.91 ' 69.12 GAS LIFT 1CAMCOIKBUGl1/DMY/BK/U Comment EXT PKG STA 2 101812003 1 2.920 I 7,286 3,834.2 ~I 68.07 GAS LIFT CAMCO/KBUG/1/DMY/BTM///Comment: STA3 _. 10/8/2003 1 I - - __ 2.920 9,103 ; 4,511.8 69.05 GAS LIFT CAMCOlKBUG/1/DMY/BK///Comment: STA 4 4/2/1997 i _ __ 2.920 10,240 4,947.4 65.84 GAS LIFT CAMCO/MMG/t51DMY/RK/!/Comment: STA 5 3/30/1998 2.920 10,245 4,949.4 65.99 CEMENT BAKER 2.125" INFLATABLE CEMENT RETAINER, 12/3/2009 0.000 RETAINER OAL=10', NO ID DUE TO DUAL FLAPPER CHECKS -SET ON 10.2 bbls OF 15.8# CEMENT 12,190 5,723.0 54.85 GAS LIFT CAMCO/MMG{t5/OPENIRK!!l Comment STAG 11/26/2009 2.920 12,236 5,749.8 54.10 NIPPLE Camco'W-1' Selective Landing 5/25/1995 2.812 12,244 5,754.5 53.86 PACKER Baker SAB-3, PERMANENT PACKER 5/25/1995 4.000 12,258 5,762.8 53.43 NIPPLE Camco'D' Nipple NO GO 5/25/1995 2.750 12,267 5,768.2 53.15'',SOS ~ Baker 5/25/1995 2.992 12268 5,768.8 53.12 I TL ELMD TTL @ 12260'tluring PERT on 07/07/2000 5/25!1995 2.992 I Perfora tions & Slots snot I _ __.. Top (TVD) Btm (TVD1 Dens ~i To ftK6 p ( ) I Btm (ftK6) (ftK6) (HKB) Zone Date (sh-~ Type ! Comment - __ _ - I 12,38fi '. 12.406 5 842.8 S 855.A C d, 2T-21 7/7/2000 4.0 APERF 12 1!2" HSD I 12,402 1 12,420 ____ _ __ 5,853.2 5.864.8 C-4, 2T-21 6!92002 6 0 RPERF X25" 2506 PJ, 60 deg Phase 12,436 ; 12,468 5,875.2 5,896.0 A-0, A-3, 2T-21 6/4!1995 6.0 IPERF ~2 1/8" Enerjet; 90 deg ph; oriented +/- 145 tleg fllowside 12,447 72 467 __ __- A-3, 2T 21 6/6/1995 4 0 RPERF 2 1/8" Enerjet; 180 deg ph; orientetl 5,882.3 5 895 4 1 I 90 deg leN & right Notes:_ General 81 Safety _ Y End Date Annotation 10/17/2003 ~, NOTE POSSIBLE LEAKS FOUND @ SSOS', 5590', AND 5398' .__ _ _._. 10/17/2003 NOTE: TUBING LEAKS FOUND @ 6958', 6740', 6460', 6270, AND 6194' 2T-21 Well Events Summary DATE SUMMARY 11/25/09 PULLED 2.75" CA-2 PLUG @ 12 'RKB. ATTEMPT TO PULL DMY VLV @~90' RKB. IN PROGRESS. 11/26/09 PULLED DMY VLV @ 12190' RKB. SET 2.75" CR LOCK ASSY (CR LOCK,XO & FLUTED EQ SUB/ OAL= 22"). JOB COMPLETE. READY FOR COIL. 12/2/09 TAG CR LOCK ASSEMBLY IN D NIPPLE @ 12,258' RKB, PULLED UP 3' TO 12,255' RKB & FLAGGED PIPE. PULLED CR LOCK ASSEMBLY FROM D NIPPLE @ 12,258' RKB. IN PROGRESS. 12/3/09 SET 2.125" INFLATABLE CEMENT RETAINER(DUAL FLAPPER) @ ESTIMATED 3' ABOVE D NIPPLE @ 12,255' RKB. PUMPED 10.2 BBLS OF 15.8 CEMENT (50 SACKS) THROUGH RETAINER. STING OUT OUT RETAINER AND LOAD TBG 8~ IA W/ 450 BBLS OF 10.5 BRINE. BLEED TBG & IA TO 0 PSI. PUMP 35 BBLS OF DIESEL AND U TUBED AROUND FOR FREEZE PROTECT. JOB COMPLETE. 12/7/09 BLEED T & IA TO 0 PSI, DDT (PASSED ) S ' 7 • • t~% ~ ~,u a ~~. ~ F~ ~ a-~ ~ ~ ~, k `~ ~ p~ f F "i ~ k ;i~r ~ N ~~ ~ h~ E' d C~ ~ 'I @ 3 N ~ Cs ~ L ~ ~ ~,. ,. ~ ~ ~G ' u ' ~ F ~j ~ 1 ~ s ~~~ ~~ k~~ j ~~ ~ ~ ~ C ~ ~ ~'~ M ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ G ~ ~ ~ ,~ SEAN PARNELL, GOVERNOR t ~ f r' ` i ~ ~ ~ r, L r K ~ ~ a~ a ~ ~ t ~ ~ ~ E' ~ ~ ~' ~~-~,~' ~-_,_. _ ,._ t'-r u1. ~.J' ~....:_u' .~s' ~~z;d~ ~. ~;~' ~4.~ 6..~.~; i ~~ ~. 8 ~L~-7~~ ~IL ~D t][t~a7 B~ 333 W. 7th AVENUE, SUITE 100 COrTSE~iVATIOI~T CODIl-IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~~ FAX (907) 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. ~1 P.O. Box 100360 ,,, D r~ Anchorage, AK 99510 ~ ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T-21 Sundry Number: 309-360 Dear Mr. Ennis :~~.~~.~~t~~~ ~Ca`~~ ~ ~~: 20~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the ne~ 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, ~ DATED this? ~day of October, 2009 Daniel T. Seamount, Jr. Chair Encl. ~ .d~ ~,q, t~'~ .~ ~ STATE OF ALASKA IP ALASKA OIL AND GAS CONSERVATION COMMISSION ~tE~EIV~D OCT 2 ~ ZQ~9 APPLICATION FOR SUNDRY APPROVA~aaka0il&GasCons.~ommission 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operationai Shutdown ^ Perforate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Pertorations Q~ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~` Exploratory ^ 195-013 ° 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20212-00 - 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? Y@S ^ NO ~ 2T-21 ' 9. Property Designation: ., ~ ~ t~v 10. KB Elevation (ft): 11. Field/Pool(s): ~~ ~ ` , ADL 25569 ,,~ ~~-- ~=~S(~-~~ ~j c RKB 123' 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): 12821' ~ 6126' • 12258' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 4772' 9-5/8" 4772' 2901' PRODUCTION 12804' 7" 12804' 6115' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12386'-12420', 12436'-12468' S843'-5865', 5875'-5896' 3.5~ L-$0 12268' Packers and SSSV Type: Packers and SSSV MD (ft) Baker SAB-3 pkr @ 12244' Camco 'DS' nipple @ 509' 13. Attachments: Description Summa f Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ~ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat November 4, 2009 Oil ^ Gas ^ Plugged ~' Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that t e foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam m Ennis Title: Wells Engineer Signature ~ Phone 265-1544 Date ~ a Qj ~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness D- ~ Plug Integrity ~BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other:~iV~/~Se/ fe~S ~J~.c,~c/lGs /o3~:u.~ / !`as~r.c,w~e ~Z ~ ~-~- ~i~~-2SS ~a.ca.3 ~o-c.es va ~'L5 I Subsequent Form Required: ~~' ~~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ' 10{3Qy~ 0~006 ~~ ~ Submit in uplica f~J /4•~,~• ~'J ~r`"'~l/'"y~~ f~~, j~ '%`~ ~ ContxoPhillips ':i5r.;1 4i.r, cora~~crva. NIPPLE.509 GAS LIFT, 2.222 SURFACE. s.n2 6AS LIFT, s,i5a GAS LIFf, 7.286 GAS LIFT, 9.t03 GAS LIFT, 10.260 GAS LIFT. 12.190 ~ ` KUP ~ 2T-21 Well Attribut Well~oreAPVUWI es 'FieldName '~WaIlStatus Max Incl(°) Angle 8 MD MD(ftKB) ~TD i AdBtrn(ftKB) ~ 507032021200 ~KUPARUK RIVER UNIT IPROD 7GJ3 I iL220.93 I 12821.0 Cpnment H25 (ppm) ~~Date I,q~ p{ation Ena Data ~KB-Gre (H) ~~Rig Release Date _._. SSSV-NIPPLE i 210 ~ 12;15/2002 I '~.Las1W0: i ~ S/24/1995 _.__.. End Data Mno~a~ion _._ _ Annotati n Dep~h(flKB~ ~ Last Mo0 By j ~ End Date I 9 Last la . ~ I I 12 S68A 2li 7l2005 Rev Reason: RESET PLUG ___ __ ` Imosbor 10/212009 Casin Strin s __.. CasingDescript '~, String OD ~ String ID ion ~ (in) ' (in) Top(RKB) Sat Dapih (ftKB) Set Depth (ND) (ftKB) ~ String Wt ~ String (Ibs/R) II Grade Siring.TopThN CONDUCTOR . 16~ 15.062 0.0 121.0 121.0 , ~ 6258•,H-00 SURFACE 95/8 8.697 0.0 4,772A 2,900.8 40.OO1-80 ~ PROOUCTION I 7I 6.151 0.0 12.804.0 6,115-1, 26.00 L-80 I 9,7 1O,L 12.7 & Retrievable, Fish, etc.) __~ Gomment RunDale __. ID(in) __ ____....___ 'DS' Nipple NO GO 5l25/1995 2.81i )/KBUGl1/DMY/BK///Comment:STA1 10/8/2003 2.92C )iKBUG/t/DMY/6K/// Commem: EXT PKG STA 2 10/8/2003 2 92C )/KBUG/1/DMY/BTMII/ Comment STA 3 10/8/2003 ~ 2.92C )/KBUGl1/DMY/BK/0 Comment STA 4 4l2/1997 292( )/MMG/1.SIDMY/RK/// Comment: STA 5 3/3011998 2.92C )/MMG/t5/DMY/RK///CommentSTA6 3I31/1998 j 2.92( 'W-1' Selective Lantling 5/25/1995 i 281~ '~.ELMD TTL @ 12260' auring PERF on 0//0//2UW .I_.- - .- .. . Shot' . . ~yp) ~ Dens i K8) ~ Zone Date ~(sh~~~ I Type A3, 2T-27 ~6/4/1995 6.0 IPERF 2 1/8" Eneryet; 90 deg ph; onentetl +/- i 45 deg Ulowsitle 2T-21 '~61611995 ~~. 4.0 RPERP 2 1/8" Enepet; 180 deg ph; oriented ~~ :90 aeg left & right _ ~ ~ I Annotation ~ . ... . -- . _ . .. . ~ ~ ~ ~ ~'- ID @ 6958', 6740', 6460', 6270, AND 6194' UND @ 5808', 5590', AND 5398' NIPPLE.12236 PACKER. . _. t2.2M NIPPLE,11,258 ~ PLUG,12,258 - SQS. 12.2fi7 TTL.12268-- APERf, 12.386-1P.406 RPERF. . _ i2aux-iz.a2o. . 12,436-12.468 \ RPERF,_ 12.447~12.467 PRO~UCTION. 12.806 ~ TD. 12.821 t • • ~ell 2T-21 Kuparuk Procedure Pump cement plug for well control barrier Network 10258903 Well History: 2T-21 was originally completed as a single Kuparuk producer in 1995. It was SI in 2003 for a tubing leak, last testing 43 BOPD. Subsequent diagnostics for rig repair identified several tubing holes at 5200'-6500' MD and a 7" casing leak at ~5500' MD. A recent gyro survey indicates this well does not yet have corkscrewed tubing. Due to the well's condition, location on a problematic subsidence drillsite and marginal workover repair options, the procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover to restore production or P&A can occur. Work accomplished to date: 10/6/09 DRIFTED TBG WITH 20' ASS'Y: 10' x 2-1/8" + 10' x 2.25" TO 12250' SLM. NO RESTRICTIONS. COMPLETE. 9/29/09 PULLED C-AZ PLUG BODY @ 12,258' RKB. PERFORMED 30 min SBHPS @ 12,426' RKB= 3154 psi, 152 deg F. 15 min. GRADIENT STOP @ 12,268' RK6=3111 psi. SET 2.75" C-A2 PLUG @ 12,258' RKB. COMPLETE. 9/28/09 UNSUCCESSFUL ATTEMPT TO PULL C-A2 PLUG BODY @ 12,258' RKB. IN PROGRESS. 9/27/09 PULLED EQ PRONG FROM PLUG @ 12,258' RKB. IN PROGRESS. 9/18/09 TROUBLESHOOT GAS MIGRATION 9/16/09 BLEED IA TO FTP & OA TO 0 7/17/09 HOIST GYRODATA LOGGING TOOL FOR DIRECTIONAL SURVEY. DURING DOWNLOG THE TOOL BRIDGED OUT AT 5600'. STOPPED, MADE ONE MORE ATTEMPT. DID NOT GET BELOW 5600'. LOG OUT OF HOLE. 7/9/09 DRIFT w/ 1.84" x 38' TO 12,250' SLM. NO OBSTRUCTION. COMPLETE. 8/2/07 RESERVOIR SATURATION TOOL, SIGMA / BORAX LOG - MAJORITY OF BORAX OBSERVED BETWEEN 5435' AND 5456' WITH POSSIBLE CHANNELING ABOVE AND BELOW. TEMPERATURE AND SIGMA BOREHOLE CONFIRM NO BORAX OR PUMPED FLUIDS BELOW 7300', PACKER AND PLUG DO NOT APPEAR TO BE LEAKING, PUMPED A TOTAL OF 100 BBLS BORAX AND 63 BBLS DIESEL DOWN TUBING TO IA VIA LEAKS RETURNS TO FORMATiON VIA CASING LEAKS, WELL LEFT SHUT !N 7/12/07 LOG TECWELL LEAK DETECT LOG FROM 12250' TO BOTTOM OF SURFACE CASING AT 4750'. Pumping down IA at 3/4 to 1 BPM at 2200 psi. TUBING AND IA PRESSURE TRACKED AND WERE UNABLE TO FIND ANY LEAK SIGNATURE BETWEEN IA AND FORMATION. TTP appears to be holding as no noise was observed at the tbg leak depths as would be expected if the TTP was leaking 7/1/07 LOGGED PDS CALIPER AND MTT FROM 12258' RKB TO SURFACE; GOOD DATA RECOVERED. COMPLETE. 4/7/05 PERFORM LEAK DETECTION LOG USING RST WATERFLOW SENSITIVE TO DOWNFLOW. PUMPED 356 BBL SEAWATER DOWN IA TO FORMATION VIA ONE-WAY IA-FORMATION LEAK DURING LOG. WELL HAS T X IA COMMUNICATION THROUGH SEVERAL KNOWN T X IA LEAKS. RESULTS: RST WATERFLOW LOG 3/7/05 SET 2.75"CA-2 BLANKING PLUG @ 12258' RKB. ATTEMPT PT TBG/IA FAILED. BLED TBG/IA TO 50# HELD. APPEARS TO BE ONE WAY PACKER LEAK. [PRESSURE DATA, LEAK DETECT-PATCH] 2/17/05 TAG FILL @ 12,568" RKB. OBTAINED SMALL SAMPLE OF FRAC SAND/FILL. OBTAINED SBHP PER PROCEDURE. 5/9/04 PRE-RIG MITOA - FAILED, POT-T - PASSED, PPPOT-T - FAILED, POT-IC - PASSED, PPPOT- IC - PASSED, FUNCTION TEST LDS'S - ALL PASSED [ANN COM ISSUES, WH MAINTENANCE] Jim Ennis Page 1 10/23/2009 tv ~ ~ell 2T-21 Kuparuk Procedure Pump cement plug for well control barrier Network 10258903 Remaining work: 1. Bleed tubing & IA pressure to zero to verify casing leaks will not restore welihead pressure. 2. RU slickline. Retrieve 'CA-2' prong & plug body at 12258' MD. Set a gutted SV w/ no ball check in 2.75" 'D' nipple @ 12258' MD for CT depth control. 3. RU 1.75" CTU. RIH w/ BOT 2-1/8" inflatable cement retainer (ICR) w/o spotting valve. Tag SV @ 12258' MD & PUH 3'. Drop ball and set ICR by gradually stepping pressure up to ~2500 psi to shear ball seat. Establish rate into perfs w/ seawater & verify ICR integrity. Bullhead CT volume plus 10 bbls slick seawater down CT at max rate below 4000 psi 4. RU SLB cementer. Bullhead 5 bbls slick fresh water down CT followed by 50 sx Class `G' cement w/ additives. Displace w/ 2 bbls fresh water followed by diesel to ICR. Sting out of ICR & POOH w/ CT. Bleed tbg & IA pressure to zero. Jim Ennis Page 2 10/23/2009 ~ ~ Review of Sundry AppGcation 309-360 ConocoPhillips Alaska, Inc. We112T-21 AOGCC Permit 195-013 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to plug the perforations on this oil producer to secure the well while evaluating future utility. Recommendation: I recommend approval of Sundry Application 309-360 to allow CPAI to perform this operation. Discussion: CPAI proposes to plug the perforations in the subject well to secure the well while they evaluate future utility. The well was originally drilled in 1995 and began producing in June of that year. The well experienced good initial production, peaking at over 2,000 BOPD in July 1995, but oil production began dropping quickly and water production began rising quickly in August 1995. The well produced on a more or less continuous basis until being shut in, due to a tubing leak, during June 2003 and, aside from attempting to flow the well for one day in August 2004, the well has remained shut in. Over the final three years of production the well averaged a little more than 100 BOPD while the water cut was typically in the 80 to 90 percent range. Diagnostic work performed since the well was shut in has revealed numerous tubing leaks and a casing leak. Additionally, CPAI states the well is an drillsite which has experienced subsidence related problems although this well has yet to experience those problems. Conclusion: Due to the fact that the well was a marginal producer prior to being shut in, has multiple mechanical issues, and is located on a pad where subsidence issues may create additional mechanical issues it is prudent to plug the existing perforations and secure the well until CPAI can decide how to proceed with the well. Therefore, I recommend approval of the operator's request David S. Roby ~'r Sr. Reservoir ngineer 'A October 26, 2009 V L. • ~ NO. 4564 Schlumberger -DCS ~~~~'~ ~ ~,•,a - 2525 Gambell Street, Suite 400 Company: Alaska Oil 8~ Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ,' 333 West 7th Ave, Suite 100 %~~~~~ ~~~ ~ ~ ~~Qfi Anchorage, AK 99501 ~/~ ~~ ©`3 ~ Field: Kuparuk VlV Well Job # Log Descripti~~ Date BL Color CD 01 /25/08 2B-13 11996584 PRODUCTION PROFILE gj~ - Jp 01/10108 1 1E-112 11994598 INJECTION PROFILE l)'3. - ~ 01/11/08 1 1J-164L1 12005203 MEM INJECTION•PROFILE c7QS - ~ ~ U~~ 01/22108 1 2M-20 11996596 PRODUCTION PROFILE (~j (~ - V~•( 01/22108 1 1C-170 11970605 USIT ~p 12/02/07 1 2G-06 11994596 PSP MULTI-FINGER CALIPER - 01110108 1 3K-102 11994599 MDT ~ - ~ 01/14/08 1 1J-127 11994603 INJECTION PROFILE (~_~ ~O(o-pL(~ 01/21/08 1 2T-21 11839639 RST ~ 08102/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ~~ . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Ine. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AI< 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report/ EDE 2T - 21 Caliper report 01-JuI..Q7 * * * * * * Reprint w/ Magnetic Thickness Summary* * * * * It:? ð-:'Ol~ sGANNaJ JUL 1 ) 2.0t17 Signed: c--ét . tt" ~ -'-.'. BECEIV' "Erg _." .. l"" -- Date: JUt! 1 Z007 Print Name: {l0 {i:·cJ- ¡ '^ p (lda.lw¿1J¡ -€ (A. 4laska Oil,& Gas Cons, Commission Anchorage PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _Copy- 00 ]DSANC-2OxxIZ _ W ordlDistributioo\TmnsmittaC Sheels\Transmit. OriginaJ,doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. July 1, 2007 7172 1 3.5" 9.3 lb. L-80 Tubing Well: 2T -21 Field: Kuparuk State: Alaska API No.: 50-103-20212-00 Top Log IntvI1.: Surface Bot. Log Intvl1.: 12,251 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This Caliper/MTT data is tied into the Parker GLM 2 @ 6,021 ft. (Driller's Depth). This is the first log of this well with the 24-Arm Multi-finger Caliper (MFC) and 12 Arm Magnetic Thickness Tool (MTT). The caliper records the features of the internal surface of the 3.5" tubing in this well while the Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 7" production casing within the logged interval. The MTT portion ofthis log covers 4,767' to 12,251'. The additional metal volume from the 9-5/8" surface casing above this interval exceeds the MTT's capability to record accurately. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (6,008'), where the readings were assumed to represent undamaged tubing and casing. Inspection ofthe data recorded at this location in the dynamic pass indicates damage in the area of this calibration point. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 7" production casing. INTERPRETATION OF CALIPER lOG RESULTS FOR 3.5" TUBING: This log was run to assess the condition of the 3.5" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing interval logged is in good to poor condition with respect to corrosive penetrations. Wall penetrations in excess of 85%, including holes, probable holes and possible holes, are recorded in 12 joints. Overall, 176 out of the 404 joints logged are recorded with wall penetrations in excess of 20%. The damage appears in the form of Line of Corrosion, General Corrosion and Isolated Pitting. No significant areas of cross-sectional metal loss or I.D. restrictions are recorded throughout the interval logged. Cross-sectional drawings of the most significant events recorded are induded in this report. The distribution of maximum recorded penetrations is íIIustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: HOLE HOLE HOLE HOLE HOLE Jt. Jt. Jt. Jt. Jt. 168 @ 170 @ 172 @ 174 @ 206 @ 5,265 Ft. (MD) 5,334 Ft. (MD) 5,389 Ft. (MD) 5,449 Ft. (MD) 6,453 Ft. (MD) ( 100%) ( 100%) ( 100%) ( 100%) ( 100%) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 0ECE .VE r"""" Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.ccJn\ D ,...<~ Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 JUL 1 I Z007 106-01:3 ~ Oil & Gas Cons. Commission Anchorage I I I I I I . . 3.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 15%) are recorded throughout the interval logged. 3.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the interval logged. INTERPRETATION OF MTTLOG RESULTS: A graph of the average metal loss assessed from the MTT data on a joint-by-joint basis is included in this report. I I I I I I I The MTT log results indicate average overall metal loss generally ranging from 5% to 15% in the interval from joint 154 to 256 (4,750' - 8,050'). The continuation of the trend of average metal loss in the MTT data beyond the general trend of internal damage recorded by the caliper data suggests the presence of significant metal loss unrelated to the internal condition of the tubing. A graph illustrating this interval as well as the correlation between the caliper recordings of the internal condition of the tubing with the MTT recordings is included in this report. The slight increase in average metal thickness (-1 % to 4%) from joint 256 to the bottom of the logged interval appears to be the result of damage in the area ofthe calibration causing an artificially low baseline for undamaged pipe. Significant "tool jerk" is indicated in the MTT data over the interval from 4,750' - 7,150'. Accurate assessment of localized or isolated damage is impaired in this interval, but the average metal loss readings taken while the tool is stopped support the presence of significant metal loss in addition to that recorded by the caliper in this interval. I I Field Engineer: W McCrossan Analyst: J. Thompson/B. Qi Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I I Correlation of Caliper Max. Rec. Pen. to MTI Avg. Recorded Metal Thickness I I I I I I 203 213 .. 41 .c E 223 '" z ... ., 2- 232 I I I I I I I I I I Well: Field: Company: Country: 2T-21 Kuparuk ConocoPhillips Alaska, Inc. USA o 154 Caliper Max. lee. Pen. (mils) 50 100 150 200 250 164 173 183 193 242 252 262 272 282 291 I II Max. Rec< Pen II Max. X-See Wall Loss I Survey Date: Calibration pt. Too!: Tubing: July 01, 2007 Jt. 192 (6,008') UW MFC 24 No. 212330 35" 93 Ib L-80 MTT Avg. Metal....hickness Relative to Calibration pt. (%) -20 -15 -10 -5 ° 5 10 15 20 j ê ::I Z ... ¡: 2- 4 5 62 MTT data indicates interval of significant metal loss unrelated to internal corrosion recorded by caliper. I I Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 3.5 in (4805.8' 12250.9') I I I Decrease I GLM2 175 I 200 I I 225 GLM3 250 ~ ( ) ..D E 275 :J z +' GLM4 c 'õ 300 I I I GlM5 I 350 I 375 GlM6 389.3 -50% I I I Bottom of Survey = 389.3 I Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhíilips Alaska, Inc. USA ]uly01,2007 Increase o Change in Metal Thickness (%) 5468 6248 7029 7818 Õ ¿ ....: 8601 LL .f: ..c ã. ( ) 0 9388 10170 10972 11751 12251 50% I Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (9.4' - 12250.9') I I 50 GLM 1 I 100 150 GLM2 I (¡¡ ..Q E := Z I GLM3 +-' .S -2, I GLM4 300 GLM5 350 GLM6 389.3 0 I I I I Bottom of Su rvey = 389.3 I Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiHips Alaska, Inc. USA Jully01,2007 Approx. Too! Deviation Approx. Borehole Profiie 200 250 50 Damage Profile (% wall) / Tool Deviation (degrees) 13 1546 3115 4680 o 6248 ¿ +-' u... C ..c: ..... Q.. Q,) 7818 0 9388 10972 12251 100 I I PDS Report Overview Body Region Analysis I Well: Field: Company: Country: 2T-21 Kuparuk ConocoPhiUíps Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: NomJD 2.992 ins Jully 01, 2007 UW MFC 24 No. 212330 1.69 24 B. Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread LoBO Nom. Upset 3.5 ins Upper len. 6.0 ins I Penetration ami Metal Loss (% wall) Damage Profile (% wall) I penetration body o o metal loss body 50 penetration body metal loss body 100 400 300 200 100 0 o to 1% I GlM 1 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% I 12 o pene. loss I GlM2 Damage Configuration ( body) I GlM 3 200 150 I 100 GlM4 I 50 GlM5 o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡b~e hote I GlM6 total = 290) o 12 Bottom of Survey = 389.3 I I I Analysis Overview page 2 I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiUips Alaska, ¡nc. USA jully01,2007 I I Joint jt Depth PelL Pen. F'en. ! ,'\/lctal Min. Damag e Profile No. (Ft.) I(:;~~¡~ I Body 1.0. Comments (% w<ill) (Ins.) (Ins.) 0 50 100 .1 9 ( 0.02 2 2.93 PUP 1 13 ¡ 0.02 (] 2.95 2 44 ( 0.01 2.93 3 76 ( 0.02 I 2.95 4 107 n ~ 2.94 5 138 0 2.94 6 170 0 0.D1 2.94 7 201 I 0.D1 2.95 8 233 ) 0.02 2.94 9 264 J 0.03 10 2.94 10 295 J 0.03 I 2.93 11 326 J 0.02 2.94 12 358 0 0.02 2.95 13 389 0 0.01 2.97 14 420 0 0.02 i 2.96 15 452 (] 0.02 7 2.95 15.1 483 0 0 0 2.81 OS Nioole 16 484 0 0.D1 i 2.96 17 515 0 0.D1 2.94 18 546 0 0.02 7 2.94 19 577 0.02 8 2.95 20 609 0.03 11 4 2.95 21 640 0.02 6 2.94 22 671 0.02 5 2.94 23 703 0.D1 2 2.94 24 734 0 0.03 (] 2.95 25 766 0 I 0.ü2 2.96 26 797 0 2.93 27 828 2.94 28 860 0.02 ( 6 2.95 29 891 0.03 1 2.95 30 922 0.03 10 2.96 31 954 0.02 2.94 32 984 (] 0.ü2 9 r¡ 2.95 33 1015 0.02 n 2.97 34 1047 0.03 (] 2.95 35 1078 0.02 2.95 36 1110 0.02 I 2.97 37 1141 0.D1 2.95 38 1172 J 0.03 2.96 39 1203 0 0.02 2.96 40 1235 () 0.02 2.97 41 1266 n 0.03 I 2.96 42 1298 0 0.02 9 2.95 43 1328 0 0.02 2.94 44 1359 0 0.01 2.94 45 1390 0 0.ü2 2.92 46 1422 0 0.ü2 2.95 47 1453 0 0.02 2.92 48 1483 0 0.03 12 6 2.95 Lt Deoosits. I I I I I I I I Body Meal Loss Body Page 1 I I PDS REPORT JOINT TABU ONSH I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiUips Alaska, Inc. USA Juily01,2007 I Joint Jt. Depth PelL Pen. Pen. i i"letal Min. Dam age Profile No. (Ft.) Body !.D. Comments (%wall) (Ias) (Ins.) (Ins.) 0 50 100 49 1514 0.ü1 2.94 50 1546 0.ü2 2.96 51 1577 0.03 OJ 2.95 52 1608 0.ü1 4- 2.94 53 1640 n 0.03 11 I, 2.97 54 1671 0.02 ( II 2.95 55 1703 0.ü1 ¡ H 2.95 56 1734 0.02 ¡ 2.93 57 1766 0.01 2.96 58 1797 0.02 2.96 59 1828 n 0.01 2.95 60 1 RhO 0.ü2 i 2.95 61 1891 W 1 +=f2.95 62 1922 ( 2.94 63 1953 ' 2.95 64 1984 2.96 65 2016 n 0.03 1 2.95 66 2047 n 0.03 I 2.95 67 2076 n 0.03 ? f 2.95 68 2107 0.03 In 4.. 2.94 69 2139 0.02 9 2.97 70 2170 0.ü2 2.96 70.1 2201 0 N/A GLM 1 £latch @ 8:30\ 71 2208 0.02 2.93 72 2239 0.02 7 2.96 73 2270 0.02 I, 2.96 74 2302 0.ü1 I, 2.95 75 2333 0.02 4- 2.95 76 2365 0.03 -iN i 2.95 77 2396 0.03 2.93 78 2426 0.04 1 2.94 Shallow nitlin<>. 79 2457 nO? 0.08 2.94 Isolated nittin<> 80 2489 ( 0.07 ( 2.94 isolated "iHina. 81 2520 n 11\ 0.11 e¡ {¡ 2.95 Isolated nittina 82 2552 0.08 n 2.96 Isolated "ittina. 83 2583 n Iii 0.16 1 2.96 Line corrosion. 84 2614 n 4 0.15 2.95 Line corrosion. 85 2646 In 0.15 2.95 Corrosion. 86 2677 In? 0.10 2.94 Isolated nittinq 87 2708 I 'if; 0.14 ~I 2.95 Line corrosion. 88 2740 HI 0.14 'if;7 2.95 Line corrosion. 89 2771 0 0.13 e¡ B 2.95 Line corrosion. 90 2802 nln 0.08 2.96 Corrosion. 91 2833 I 0.14 2.95 Corrosion. 92 2865 I 0.14 ¡ 2.94 Line corrosion. 93 2896 0.10 2.95 Corrosion. 94 2927 n!"4 0.16 I 2.93 Corrosion. 95 2959 n Ie} 0.12 4- II 2.94 Corrosion. 96 2990 n ffi14 ~ij 2.94 Corrosion. 97 3022 I 07 07 I 2.95 Isolated "iHina. I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiRips Alaska, Ine. USA JullyOl,2007 I Joint Jt. Depth Pen. Pen. Pen, i ¡IAnlal Min. Damage Pro file No. (Ft.) 1(:;~;I;t Body I.D. Comments (%wall) (Ins.) û¡{) (Ins.) 0 50 100 98 3053 0 0.10 2.94 Line corrosion. 99 3085 ( 1 0.16 í i 2.94 Line corrosion. 100 3115 iO( 0.11 2.96 Corrosion. 101 3146 0.16 í 2.92 Corrosion. Lt. Deoosits. 102 3177 (!.f 0.14 2.95 Corrosion. 103 3209 C 0.10 2.95 Corrosion. 104 '240 0.16 0.09 4 2.93 Corrosion. 105 3271 (J 17 ~ 2.93 Corrosion. 106 3302 2.94 Corrosion. 107 3334 2.92 Corrosion. 108 3365 0.14 2.95 Line corrosion. 109 3396 0.16 0.08 'f 2.95 Corrosion. 110 3428 0.08 1 2.93 Corrosion. 111 3459 0.05 1, 2.95 Shallow oittimL 112 3490 0 0.09 2.95 Line corrosion. 113 3522 0.05 0.07 2.95 Line corrosion. 114 3554 0 010 2.95 Corrosion. 115 3585 0.05 2.94 Shallow nittinQ. 116 3616 0.09 2.94 Corrosion. 117 3647 0.05 19 2.94 Shallow oittinQ. 118 3679 0.09 37 2.95 Corrosion. 119 3710 0 0.07 I 2 II 2.96 Corrosion. 120 3742 0 0.05 2.93 Shallow nittim~. 121 3773 0 0.10 2.94 Corrosion. 122 3804 0.08 2.96 Line corrosion. 123 3835 0 17 0.12 2.94 Line corrosion. 124 3866 0.13 , 2.94 Line corrosion. 125 3897 0.06 2.94 Corrosion. 126 3929 0 15 0.09 2.94 Corrosion. 127 3960 0 0.08 2.93 Corrosion. 128 3992 ( 0.14 ( 2.94 Corrosion. 129 4023 ( 0.10 2.95 Corrosion. 130 4055 O( 19 0.10 ( 2.95 Line corrosion. 131 4086 0.12 16 ') 2.95 Line corrosion. 132 4117 O. 17 0:at± 5 2.95 Line corrosion. 133 4148 ( O. 6 2.94 Line corrosion. 134 4180 ( 0.07 5 2.95 Corrosion. 135 4211 0 0.06 4 2.94 Corrosion. 136 4242 o.Ja 0.10 2.93 Corrosion. Lt. Deoosits. 137 4274 ( 0.12 ( 2.94 Line corrosion. 138 4305 ( 0.06 2.93 Corrosion. 139 4337 01 0.10 2.96 Line corrosion. 140 4368 0 0.13 ( 2.95 Line corrosion. 141 4399 O. 0.08 6 2.94 Corrosion. U. Deoosits. 142 4430 0.07 == ( 2.93 Corrosion. 143 4462 ( 0.11 i 2.95 Corrosion. 144 4493 0 16 0.07 2.93 Corrosion. 145 4524 =; 28 2.95 Corrosion. 146 4555 39 2.95 Line corrosion. 147 4587 O. Iß 43 (, 2.93 Line corrosion. I 1 1 1 I I ,I I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Wel!: Field: Company: Country: Survey Date: Kupa ruk ConocoPhiaips Alaska, Ine. USA JullyOl,2007 I Joint Jt. Depth Pen. Pen. Pen., ¡l\¡'Ielal Min. Damage Profile No. (Fl.) 'I Body !.D. Comments (%wall) (Ins.) (Ins.) (Ins.) 0 50 100 148 4618 oos 0.11 1t1 2.95 Line corrosion. 149 4650 0.10 2.96 Line corrosion. 150 4680 0.14 ~4 2.95 Corrosion. 151 4712 0.08 2.94 Corrosion. 152 4744 0.09 2.95 Line corrosion. 153 4775 0.07 2.95 Line corrosion. 154 4806 ~ 2.94 Line corrosion. 155 4837 2.94 Corrosion. 156 4868 o on 0.14 2.93 Corrosion. 157 4900 0011 0.11 ¿ 2.95 Corrosion. 158 4931 nnq 0.15 , 2.92 Corrosion. Ll. Den....sits. 159 4962 0 0.07 51! t 2.94 Corrosion. 160 4994 ~0.1O 'UI 2.92 Line corrosion. 161 5025 0.13 t 2.96 Line corrosion. Ll. Denosits. 162 5056 o 0.11 2.95 Line corrosion. 163 5088 no: 0.12 2.94 Corrosion. It. Denosits. 164 5119 0.1 0.14 ?i± Corrosion. 165 5151 0117 0.08 i1 2. Isolated "ittiner 165.1 5182 {) 0 it N GLM 2 {latch @ 4:00\ 166 5189 {) 0.18 2.88 Line corrosion 167 5219 01: 0.22 "'7 2.94 POSSIBLE HOlE. 168 5250 0 0.25 I 0 2.92 HOLE! 169 5281 Oile¡ 0.19 2.92 Line corrosion. 170 5312 i 0.25 11 2.93 HOLE! 171 5343 0.12 ¿ 2.92 I ine corrosion. Lt. Denosits. 172 5375 0.25 I 12 2.94 HOLE! 173 5405 0.15 2.94 Corrosion. 174 5437 :n 0.25 I 2.94 HOLE! 175 5468 o or, =8ft 2.94 Line corrosion. 176 5497 (:,11 2.93 Line corrosion. 177 5529 00 0.13 , 2.92 I ine corrosion. 178 5560 (I 0.21 t 2.93 Line corrosion. 179 5592 (I 0.13 i 2.94 Line corrosion. 1.1. Dennsits. 180 5622 ¡UF) 0.12 ( 2.93 Line corrosion. U. Denosits. 181 5654 0 0.08 2.92 Line corrosion. 182 5685 (ìJO 0.11 2.93 Line corrosion. 183 5716 0 0.08 2.93 Line corrosion. U. Denosits. 184 5747 0 0.08 2.93 Line corrosion. 185 5778 OHI 0.23 2.94 POSSIBLE HOLE. 186 5810 ( 0.09 I> 2.93 Line corrosion. 187 5841 I 0.09 2.94 Line corrosion. L1. Denosits. 188 5872 0 Jr. 0.11 2.92 Line corrosion. 189 5904 0.14 2.93 Line corrosion. 190 5936 (j )q 0.08 2.93 Line xorrosion. It. Denosits. 191 5967 0.14 2.90 I ine corrosion. L1. Denosits. 192 5999 008~ 2.93 Line corrosion. 193 6030 n Jr, 0.07 2.94 Line corrosion. 194 6061 Oi J(I 0.05 2.93 Line shallow corrosion. 195 6093 ( 0.07 2.94 line corrosion. 196 6124 0 0.12 I 4H 2.95 Corrosion. I I I Body Melat Loss Body Page 4 PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominall.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhinips Alaska, Inc. USA jully01,2007 I joint ji. Depth Per: Pen. Pen. . i\!\etal Min. Damage Profile No. (Ft.) -t Body 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 197 6155 0 0.23 2.93 POSSIBLE HOLE. 198 6186 It 0.11 1 2.95 line corrosion. 199 6218 0 1 0.15 2.93 line corrosion. 200 6248 01 )9 0.25 2.93 PROBABLE HOLE. 201 6279 0 0 0.09 2.91 Line corrosion. 202 6309 ( 0.12 2.93 line corrosion. 203 6341 0 j6 0.20 2.94 Corrosion. 204 6372 0.13 I 2.93 Corrosion. 205 6404 O. 17 0.12 2.96 Corrosion. ,. 206 6435 0.25 1 9 2.92 HOLE! 207 6467 0.09 0.15 ¡:: 2.93 Corrosinn. 208 6496 O)ß 0.Q9 2.94 Shallow nit1ína. 209 6528 ( 0.22 2.92 IBLE HOI E. 210 6559 0 Y: 0.04 2.93 Shallow nitlinQ. 211 6591 ( 0.18 ¡ 2.92 Corrosion. Lt. Denosits. 212 6622 ( 2.93 213 6654 0.06 12 r; 2.93 Isolated nittin". 214 6684 I 0.ü2 2.9'" III. 215 6716 ( 0.24 ( 2.92 I PROBABLE HOLE. 216 6747 0.04 2.93 I Shallow nitlill<:f. 217 6778 0.05 2.95 iUing. 218 6809 0.04 Pi 1 2.93 Shallow nitling. 219 6841 0.03 3 2.95 Shallow oitlin!;!. 220 6872 0.04 16 2.91 Shallow oitlim:r. It. Dennsits. 221 6904 0.03 D 2.96 nittin<> in unset. 222 6935 0.23~ 2.93 POSSIBLE HOLE. III 223 6966 0.04 2.95 Shallow nitling. 224 6997 0.041 2.92 Shallow nitlin!;!. 225 7029 0:&tt it I 2.94 Shallow nitlinQ. 226 7060 O. 2.92 Shallow oitlin!;!. 227 7091 0 0.04 2.96 Shallow Ditlin". 228 7123 0 0.04 2.94 Shallow nitlin". 229 7154 0.11 2.93 Isoiated nittirw 230 7185 { 0.04 2.93 Shallow nitlinll. 231 7216 0.04 2.93 Shallow nit1inQ. 232 7247 0.04 ( 2.94 Shallow nitlinQ. 232.1 7278 0 ( N/A GlM 3 Hatch @ 3:30) 233 7285 0.03 ! 4 2.93 Shallow Ditlim!. 234 7317 0.04 2.94 Shallow nitlin<>. 235 7348 0.04 2.92 Shallow nitlinQ. 236 7380 0.04 2.92 Shallow"itlill". 237 7411 0.04 2.93 Shallow nitlinlZ. 238 7442 0.05 R 2.93 Shallow nitlínQ. 239 7473 ¡ 0.04 I 2 2.92 Shallow Ditlin\!. 240 7504 I 0.04 I 2.93 Shallow nitlinu. 241 7536 I 0.04 2.93 Shallow nitlinQ. 242 7567 í I 2.92 Shallow nittinq. 243 7598 2.91 Shallow oitlin2. 244 7630 í 2.94 Shallow ..ittinll. 245 7661 2 2 2.92 Isolated oittin\!. I I I I I I I Body Metal loss Body Page 5 I I REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiDips Alaska, Ine. USA Jully 01, 2007 I Joint Jt. Depth Pnn. Pen. PelL ¡\/lntal Min. Damage Profile No. (Ft.) (:;~:(~t Body Loss I.D. Comments (%Wiill) (Ins.) (Ins.) 0 50 100 246 7692 0 0.05 19 3 2.94 Shallow oitìimC!. 247 7724 0 0.05 1 2 2.93 Shallow oítlina. 248 7755 0 0.05 ? 2.91 Shallow niuinQ. 249 7786 ¡ 0.04 2.93 Shallow oìtúnQ. U. Denosits. 250 7818 ¡ 0.04 2.93 Shallow oìttin2. 251 7849 0.06 2.92 Isolated oiWnlL 252 7880 0.05 2.92 Shallow oitúna. 253 7911 0.06 2.93 Isolated oittinlL 254 7943 0.04 2.92 Shallow oWinlZ. 255 7974 2.93 Shallow oitfimr. 256 8005 0 H#t 17 2 2.91 Shallow oitfirw. Lt. Dermsits. 257 8037 ¡ I 0.ü3 11 3 2.93 258 8068 ¡ III 2.93 Shallow oit1în2. 259 8100 ¡ a.05 1 : 2.93 ~ 8162 ¡ I 2.94 ¡ 2.91 Shallow oit1îna. 262 8193 2.91 Shallow oitfina. 263 8225 2.91 Shallow nittinQ. 264 8256 0.031 2.91 265 8287 0.ü3 I 2.91 266 8319 0.03 I 2.94 Shallow oitfina. 267 8350 0.03 ¡ 2.92 268 8381 0.04 I 2.93 Shallow oittina. 269 8413 0 I 0.03 1 4 2.92 Shallow oitlim!. 270 8444 0 0.03 1 ¡ 2.94 271 8475 0.05 0.03 2.93 Shallow pit1îna. 272 8507 0 0.ü3 2.94 Shallow nittinQ. Lt. Deoosits. 273 8538 0 0.04 2.91 Shallow nittina. 274 5569 0.ü3 2.93 275 8601 0.ü3 2.92 Shallow oittina. 276 8632 0.03 2.92 Shallow oit1îna. 277 8663 0.ü3 2.91 Shallow oít1îna. 278 8695 0.ü3 2 2.92 279 8726 0 0.04 It 2.91 Shallow oit1îm:!. 280 8758 ¡ 0.03 1 2.92 Shallow nitfin2. 281 8789 ¡ 0.04 ¡ 2.91 Shallow oittin2. Lt. Deoosits. 282 8820 ( 0.04 I 2.90 Shallow oittina. 283 8851 ¡ 0.ü3 1 2.91 284 5881 O. )0 0.03 1 2.92 285 8912 0.05 2¡ 2.91 Shallow pitlíng. Lt. Dermsits. 286 8943 0.04 2.92 Shallow nitlín2. 287 8975 0.04 2.90 Shallow nittimz. 288 9006 0.ü3 2.91 289 9037 0.04 2.90 Shallow DitlÎr1g. Lt. Deoosits. II! 290 9069 0.ü3 2.91 Shallow oitlímr. II! 290.1 9100 0 0 0 N/A GLM 4 (latch @ 9:30) i 291 9105 0.04 2.92 ShaJlow corrosion. 292 9138 0.05 ~ow nit1în2. Lt. Denosits. 293 9169 0.04 Shallow nít1îrnz. Lt. Deoosíts. 294 9200 0.03 2.91 Shallow !Jitting. I I I I I I I I Body Me1alloss Body Page 6 I PDS REPORT JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiUips Alaska, Inc. USA JulfyOl,2oo7 I Joint J1. Depth Pen. Pen. Pen ¡\Aelal Min. Damage P rofile No. (Ft.) Body I.D. Comments (%wal !) (Ins) (Ins.) (Ins.) o 50 100 295 9232 0.04 I 2.92 Shallow nitlÍnQ. 296 9263 ~ ? 2.91 Shallow nitlÍnQ. 297 9295 i 2.90 Isolated nittinQ Lt. Deoosits. 298 9326 0.06 ;> 2.88 Isolated nittinQ. Lt. Denosits. 299 9357 0 is 0.04 ") 2.91 Shallow oittinQ. Lt. Deoosits. 300 9388 0.07 2.91 Isolated nittinQ. 301 9420 0.07 2.89 Isolated nittim!. Lt. Deoosits. 302 9451 O. IB 0.05 2.89 Shallow corrosion. Lt. Deoosits. 303 9483 0 it 2.91 Shallow nittinQ. Lt. Denosits. 304 9514 0 2.88 Shallow corrosion. Lt. Denosits. 305 9545 0 2.91 Isolated oiUinQ. 306 9577 0 2.89 Isolated niUinQ. L1. Deoosits. 307 9608 ( 2.90 Corrosion. Lt. Denn<:its. 308 9640 ( 0.05 2.79 Shallow nittina. Denosits. 309 9671 0.07 2.90 Isolated nittin<r Lt Denosits. 310 9702 ( 0.05 2.91 Shallow nit1inQ. Lt. Denosits. 311 9733 0 )'1 0.06 ;> 2.90 Isolated oittinQ. Lt. Deoosits. 312 <J765 011 0.06 2.90 Corrosion. Lt. Denosits. 313 9796 om) 0.06 2.89 Isolated nittìnIL Lt. Deoosits. 314 9827 0 0.06 2.91 Isolated nittìn2. Lt. Deoosits. 315 9859 0 0.05 2.91 Shallow nit1ina. 316 9890 0 0.05 20 2.89 Isolated nittina Lt. Deoosits. 317 9921 ( 0.05 }9 ) 2.91 Shallow nittinQ. L1. Denosits. 318 9952 0.05 20 ~j 2.91 Shal!ow nit1il1Q. 319 9983 0.04 2.92 Shallow nit1inQ. U. Denosits. 320 10014 0.06 2.93 Isolated nittinIL 321 10046 0.07 2.91 I "'nbted nittinQ. L1. Deoosits. 322 10077 0.07 0.06 2.89 Isolated oittinlL 323 10108 0 0.06 2.92 Isolated nittina 324 10140 0.12 0.07 2 } 2.89 Isolated nittinº L1. Denosits. 325 10170 0.07 j 2.91 Isolated nittinº 326 10201 0 7 0.06 2.91 Isolated nittinQ 326.1 10232 0 7 ;03 111 2.88 PUP Piltìn2. Lt Deoosits. 326.2 10240 I N/A GLM Snatch @ 6:15) 326.3 10242 2.90 PUP III 327 10253 0 2.89 Lt. Denosíts. III 328 10284 on/. 0.05 }. ) 2.91 Sh~lInw nitting. Lt. Denosíts. 329 10316 0.10 0.04 0 2.90 Shallow nit1in2. 330 10348 010 0.04 2.89 Shallow oittin2. It. Deoosits. 331 10379 0 0.07 2.91 Isolated DittinQ. Lt. Deoosits. 332 10410 O.ob I 0.05 2.90 Shallow nit1inQ. Lt. De Dosits. 333 1044 1 0.12 0.05 2.91 Shallow nit1iOQ. U. DeDosits. 334 10473 Ol} 0.08 2.90 Isolated nittinº l1. Denosíts. 335 10504 0.09 0.05 2( ? 2.82 Shallow nit1in2. Lt Dennsits. 336 10535 ~ 0.04 Ii { 2.90 Shallow nit1inQ. 337 10566 0.05 II 2.90 Shallow nit1in2. It. DeDosits. 338 10597 0 0.05 2( 2.92 Isoiated oittìnQ. 339 10629 0.07 ;=Ht 2.91 Isolated oittinlL Lt. DeDosits. 340 10660 0.12 2.91 Isolated nittinQ U. DeDosits. 341 10692 0 0.08 30 2.91 Isolated nittiOQ. L1. Denosits. I I I Body Metal Loss Body Page 7 I I PDS REPORT JOINT TABULATION Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf 1.-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhillips Alaska, Inc. USA Jully01, 2007 I Joint jt. Depth Pen. Pen. PaL ' ¡\¡\etal Min. Damage Profile No. (Ft.) .( Body I.D. Comments (% wall) (Ins.) (Ins.) (Ins.) 0 50 100 342 10723 0.07 0.04 15 3 2.91 Shallow oittim~. I 343 10754 0 0.04 1 1 2.92 Shallow oitlim;~. 344 10785 011 0.04 1 2.87 Shallow nitlinQ. I.t. Denosits. 345 1081 7 0 0.06 t 2.93 Isolated oi WnQ- 346 10848 01t 0.05 I:~ Isolated oittinlL 347 10879 0 0.03 348 10909 010 0.05 Isolated oittim!. 349 10941 1105 0.08 tl 2.91 Isolated oittim!. 350 10972 0 0.06 2 2.91 Isolated oittimL I.t. Deoosits. 351 11003 0 0.04 2.92 Shallow oitlim!. 352 11035 010 0.05 2.92 Shallow nitlinQ. 353 11066 ( 0.06 2.92 Isolated nittin2_ 354 11098 0 t 0.06 ( , 2.91 Isolated nittin2. I.t. Deoosits. 355 11129 ( 0.D3 2.91 Shallow oitlin2. 356 11159 O. 3 0.04 ~ Lt. Deoosits. 357 11189 0 0.06 ,t Isolated oitting. 358 11220 0.10 0.08 i¡ 2.90 Isolated nittÍlw. 359 11252 0.06 2.90 Isolated nittinQ!. It. Deoosits. 360 11283 0.04 2.91 Shallow nitlinQ!. 361 11314 0.04 2.91 Shallow nitlinQ!. 362 11345 0 In 0.05 2.91 Isolated oittin2. 363 11377 0 ;; 0.07 I 2.92 Isolated oittíng. 364 11408 0 0.04 2 2.92 Shallow oitling. I.t. Deoosits. 365 11439 0 0.Q2 9 ¡ 2.92 366 11470 CU2 0.06 I.J! 2.91 Isolated nittinº 367 11502 0 0.06 2 2.92 Isolated pitting. 368 ~ 2.92 Shallow nitun2. 169 0.05 2.91 Isolated nittin2. It. Deoosits. 370 11595 0 0.04 2.92 Shallow oitlin\!. 371 11626 0 0.03 2 2.92 Shallow oitum!. I.t. Deoosits. 372 11658 0 0.D3 1 2.91 Shallow oitum!. 373 11689 0 0.05 2.93 Shallow pitling. It. Denosits. 374 11719 0 0.03 2.93 Shallow nitliml. 375 11751 0 0.02 2.89 376 11781 0 0.02 2.93 377 11812 0 0.04 17 6 2.91 Shallow oitling. 378 11844 0 0.02 q 1 2.88 Lt. Deoosits. 379 11875 0 0.D3 ;; 4 2.93 380 11906 0 0.Q2 2.93 381 11938 n 0.D3 2.93 382 11969 0 0.D3 2.94 383 12000 0 0.05 2.93 Shallow aitlin\!. 384 12031 0 0.04 2.91 Shallow oittim!. 385 12062 0.07 0.04 2.92 Shallow oitun\!. 386 12092 0 0.07 2.93 Isolated oittinlL 387 12123 0.04 b 2.92 Shallow oitlim?:. 388 12154 0.08 2.92 Line corrosion. 388.1 12185 0.04 4 2.90 PUP Shallow oittin2. 388.2 12190 0 N/A GlM 6 (latch @ 8:45) 388.3 12198 o. )[) 0.10 [ 0 2.89 PUP Corrosion. It. Deoosits. I I I I I I I Body Melal Loss Body Page 8 I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhiHips Alaska, Inc. USA juily01,2007 Joint Jt. Depth Min. Damage Profile No. (Ft.) 1.0. Comments (% wall) (Ins.) 0 50 100 389 12204 2.92 389.1 12236 2.81 389.2 12239 4.00 389.3 12251 2.75 I I I I I I I Page 9 - - - - - - - DS Report Cross Sections Well: Field: Company: Country: Tubin : 2T-21 Kuparuk ConocoPhi!lips Alaska, Inc. USA 3.5 ins 9.3 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Jully 01,2007 UW MFC 24 No. 212330 1.69 24 B. i Cross for Joint 168 at depth 5265.1 ft Tool speed'" 43 Nominal ID '" 2.992 Nominal OD '" 3.500 Remaining wall area'" 87 % Tool deviation'" 82 0 Finger 10 Penetration'" 0.414 ins HOLE .25 ins'" 100% Wall Penetration HIGH SIDE'" UP Cross Sections page 1 PDS Report ross Sections Well: Field: Company: Country: Tubin : 2T-21 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Jully 01,2007 UW MFC 24 No. 212330 1.69 24 B. i Cross Section for Joint 172 at depth 5389.08 ft Tool speed'" 43 Nominal 10'" 2.992 Nominal 00 = 3.500 Remaining wall area = 89 % Tool deviation = 83 0 Finger 9 Penetration 0.404 ins HOLE .25 ins'" 100% Wall Penetration HIGH SIDE '" UP Cross Sections page 2 I KRU 2T -21 I API~21200 OD Anole IâJ TS: 50 dAn IâJ 12382 SSSV Type: Nipple Orig 5/24/1995 Angle @ TD: 49 deg @ 12821 NIP (509-510, Comoletion: 00:3.500) Annular Fluid: LastW/O:1 Rev Reason: Set Plua R_"œL~ ~ Last Undate: 31812005 ~12~ 2/17/2005 1221 GasUft . ndrellDummy ription Too Bottom TV!) Grade Valve 1 SURF CASING 0 4772 2900 L-80 (2222-2223, PROD CASING 7,000 0 12804 6114 26,00 L-80 OD:5.390) I 16.000 0 121 121 ITubiria Strino ~ "1"1 IDIMt':! Size ì Ton I Gas Lift 3,500 I 0 I ABM-EUE , ndrelJDummy Valve 2 Interval ND Zone Steros Ft Date Tvœ Comment (5194-5195, 12386 - 12402 5841 - 5852 C-4 16 7fl!2000 APERF 2 1/2" HSD OD:5.390) 12402 - 12406 5852 - 5854 C-4 4 10 619/2002 RPERF 2.5" 2506 PJ, 60 deo Phase TUBING (0-12268, 12406 - 12420 5854 - 5863 C-4 14 6 6/9/2002 RPERF 2.5" 2506 PJ 60 deo Phase OD:3.500, 12436 - 12447 5874 - 5881 A-4,A-3 11 6 6/4/1995 IPERF 2118" Enerjet; 90 deg ph; ID2992) oriented +1- 45 deo fIIowside 12447 - 12467 5881 - 5894 A-3 20 10 6/6/1995 RPERF 2118" Enerjet; 180 deg ph; Gas Lift o ' & riGht . ndrellDummy 12467 - 12468 5894 - 5895 A-3 1 6 6/4/1995 Valve 4 (9103-9104. fIIowside 00:5.390) 8t Man Man Type VMfr V Type fRO Gas Lift Mfr , ndrellDummy T Cameo KBUG DMY 1.0 BK 0.000 0 Valve 5 2"" 3061 Cameo KBUG DMY 1.0 BK 0.000 10240-10241, 00:5.968) --'3 7 3833 Cameo KBUG DMY 1.0 BTM 0,000 0 4 9 4510 Cameo KBUG DMY 1.0 BK 0.000 0 Gas Lift 5 4946 Cameo MMG DMY 1.5 RK 0,000 0 , ndrellDummy 6 121901 5722 Cameo MMG DMY 1.5 RK 0.000 0 13/31/19981 Valve 6 1:::)(1 r"1\\::J 12190-12191, m 00:5.968) Tvne ~ Descrio!Íon 10 NIP NIP 'ioDle NO GO 2.812 12236-12237, NIP Selective Landina 2.812 00:3.500) I 5753 PKR Baker SAB-3, perm. 4.000 5761 NIP Cameo 'D' NiDPle NO GO 2,750 5761 PLUG CA-2 BLANKING PLUG set 3[112005 0.000 5767 SOS Baker 2.992 PKR 5767 TTL 2.992 12244-12245, Nota", 00:6.151) Date .LEAKS FOUND @ 6958', 6740', 6460', 6270, AND 6194' 0/17/2002 POSSIBLE LEAKS FOUND @ 5808', 5590', AND 5398' PLUG 12258-12259, 00:2.750) 80s 12267-12268, 00:3.500) Perf - -- 12386--12400) - ;;;;;; Perf = 124ù2-12420) -- Perf - 12436-12468) - - - - - Perf 12447-12467) - - - - .- -- - = - A I I I I I I I I I I I I I I . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT1 The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 Report / EDE 2T-21 Caliper Report 01..Ju1-07 1) 2) 3) 4) 5) 6) 7) S~Ne.O JUL 1 \) 2007 101;S -013 :;:ì' IS,_;;&:4 RECEIVED Print Name: . ^ íi ¡(¡.-' . U J -l /-- - Q \A f ',~ IÁ'¿ 0i\ (\\.\\;1\( -(i/\ JUL 0 3 Z007 Signed: Date: Alaska Oil & Gas Cons. Commission Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INc., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E~IL: PDSANCHORAGE@MEMORYLOG.COM WEBSlTE: WWW.MEMORYLOG.COM D:\Master _ Copy _ 00 ]DSANC-2Oxx\Z _ WordlDistnòulion\TransmittBC Sheets\Transmit_ Origìna1.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Plpe1 Use: ConocoPhillips Alaska, Inc. July 1, 2007 7172 1 3.5" 9.3 lb. L-80 Tubing Well: 2T -21 Field: Kuparuk State: Alaska API No.: 50-103-20212-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 12,251 Fl (MD) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This log is tied into GLM 6 @ 12,190' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing interval with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing interval logged is in good to poor condition With respect to corrosive penetrations. Wall penetration In excess of 85%, including hole, probable hole and possible hole, is recorded in 12 joints. Overall, 176 out of the 404 joints logged are recorded with wall penetrations in excess of 20%. The damage appears in the form of Line of Corrosion, General Corrosion and Isolated Pitting. No significant areas of cross-sectional metal loss or I.D. restrictions are recorded. Cross-sectional draWings of the most significant events recorded are Included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: HOLE HOLE HOLE HOLE HOLE ( 100%) ( 100%) ( 100%) ( 100%) ( 100%) 168 @ 170 @ 172 @ 174 @ 206 @ 5,265 Ft. (MD) 5,334 Ft. (MD) 5,389 Ft. (MD) 5,449 Ft. (MD) 6,453 Ft. (MD) Jt. Jt. Jt. Jt. Jt. 3.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 15%) are recorded throughout the interval logged. 3.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the interval logged. I Field Engineer: W McCrossan Analyst: J. Thompson/B. Qi Witness: C. Fitzpatrick PmActive Diagnostic Set-vices, Inc. I p,O, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 - ~;¡k / b ;;; (e/-f' IC}~ -Oio I I I I I I I I I I I I I I I I I Bottom of I I 3.5 in Inc. 150 4680 GlM2 .... 200 6248 (\) tt: ...0 E :::J r::: GlM3 Z r::: ~ 250 7818 GLM4 300 9388 GLMS 350 10972 GlM6 389.3 12251 0 50 100 Profile I Too! Deviation GlM 1 == 389.3 WeD: Field: 2T-21 USA 2007 Too! Deviation Borehole Profile 100 3115 13 50 1546 I I PDS Report Overview Region Analysis I Well: Field: Company: Country: 2T-21 Kuparuk Conocof'hmips Alaska, !nc. USA Survey Date: Tool Type: Tool Size: No. of Anal 't: Nom.lD 2.992 ins Jully 01, 2007 UW MFC 24 No. 212330 1.69 24 B.Qi I Tubing: NorROD 3.5 ins Weight 9.3 f Grade & Thread L-80 Nom. Upset 3,5 ins Upper len. 6.0 ins Lower len. 6,0 ins I Penetration and Metallo!>!> ('Yo wall) Damage Profile ('Yo wall) I penetration body o o meta! loss body 50 penetration body metal loss body 100 400 300 200 100 0 o to 1% I I GLM 1 1 to 10% 10 to 20 to 40 to over 20%, 40% 85''10 85% I 12 o I GlM2 Damage Configuration ( body ) I 200 CLM3 150 I 100 ClM4 I 50 GLMS o isolated general line ring hole / poss pitting corrosion corrosion corrosion íbJe hole I GLM6 Bottom of Survey = 389.3 I 12 I I Analysis Overview page 2 I I I I I I I I I I I I I I I I I I I I I .1 1 2 3 4 " 6 7 8 q- 10 11 11 13 14 15 15.1 16 17 18 19 20 21 22 71 24 25 26 ')7 28 29 30 31 32 33 34 3" 36 37 ~á 'N 40 41 42 43 44 45 46 47 48 Join t No. Jt. Depth 9 13 44 76 107 138 170 201 233 264 295 326 358 ( ~89 420 452 483 484 1)15 546 577 609 6Af1 671 7m 734 766 797 R,)R 860 891 922 954- 984- 1015 1047 1078 1110 1141 1172 1203 1235 1266 1298 1328 1359 1390 1422 1453 1483 PDS REPORT JOINT 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Reid: Pen. Pen. I ¡\;It·tal Min. !.D. (Ins.) ? 2.93 ) ±ffij (¡ 2.95 I ') q.<1 2.94 6! 2.94 11 iT , ¡;: I om 2.97 0.0' I (¡ 2.% æ~~ n 0.02 4 2<14 n 0.02 2.95 ~ =i 1 2.95 (o:m' i ~ ) g:g~ Htl J, l!fl 0.01 5 ±~ 0.02 7 2 94 0.02 q 2.95 gggj,; m :; ~ 2M ( 0.03 0 2.95 o 0.02 2.9" ~ i 2.97 2.95 2.96 2.% o 0.02 2.97 0.03 2 ') .96 JMl£ 2.95 JMl£ 2.94 0.01 2.94 0.02 2 92 0.02 tt 2.95 0.02 ') .92 0.0312 ( 2.95 (Ins) (Ins.) ~ om 002 0.02 { os Nino!e Lt. Oef)()<¡.its. ULATION 2T-21 USA Jully01,2007 Comments PUP Alaska, Inc. Profile ¡Of' ..,,,11\ \ ffU VV""¡ o 50 100 Body Metal Loss I I I I I I I I I I I I I I I I I I I REPORT JOINT ULATION SH 3.5 in 9.3 ppf L-80 Well: 2T-21 0.254 in Field: 0.254 in Inc. 2_992 in Country: USA Date: Jufly01,2oo7 Joint .It [)epth Pel]' Pen. Pen. Meid Min. ..~ Profile No. 'I !.D. Comments w ail) (Ins) (Ins.) 0 50 100 49 1514 0.01 (, 2 50 1546 0.02 {, 51 1577 1 0.Q3 '} 6 2.9'1 52 1608 =;± 2.94 53 1640 t 2.97 [jt 1671 2.95 1703 0.D1 t 2.95 56 1734 g= j :J 2.93 I 57 1766 mt 2.96 58 1797 2.96 59 1828 1 (tffi= 60 1860 61 1891 n 0.03 62 1922 0.02 W 63 1953 0.01 64 1984 0.02 +H= 2.96 65 2016 0.Q3 2.95 66 2047 )~ 2.95 67~ ) (, 2.95 68 ) 003 10 4- 2.94 69 2139 0 0.02 9 2.97 70 2170 n 0.02 ~$t ~ 70.1 2201 n ¡: Gt M 1 {latch @ 8:301 71 2208 Ii 72 2239 n 2% 73 2270 11 [5 2.96 74 2302 0.û1 2.95 75 2333 0.02 2.95 76 2365 0.03 10 2.95 77 2396 11. 17 :i= *tm 78 2426 Shallow oitling. 79 2457 isolated pitting. 80 2489 11~ 6 2.94 I selated oiWn<1 81 2520 Oi)g 2.95 Isolated piuifJ2. 82 2552 I 0.08 2.96 Isolated nittinQ:. 83 2563 ¡¡ 0.16 ¡ 1* Line corrosion. 84 2614- I ~ 0.15 line cnrrosion. 85 2646 ¡ 0.15 Corrosion. 86 2677 I 0.10 I 2.94 Isolated oittinl;[. 67 2708 ( 0.14 ¡ I 2.95 Line corrosion. 88 2740 O. 0.14 , , 2.95 Line corrosion. 89 2771 0.13 a 2.95 Line corrosion. 90 2002 010 0.08 2.96 Corrosion. 91 2833 0.14 2.95 Corrosion. 92 2865 0.14 2.94 line corrosion. 93 2896 0.10 2.95 Corrosion. 94 2927 O. 14 0.16 2.93 Corrosion. 95 2959 o. )() 0.12 )) 2.94 Corrosion. 96 2990 o.or, 0.14 2.94 ( orrosion. 97 3022 0 0.07 .2 2.95 Isolated oittinl;[. Body Meld! loss Body .2 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT UiATI SH Wall: Upset WaD: Nomina! I.D.: 3.5 in 93 ppf L-80 0.254 in 0.254 in 2.992 in USA juilyOl,2007 WeD: Field: 2T-21 !nc joint ]t. Depth Pen. Pen. PerL ,\<letal Min. Profile .~ No. r;;::';! W. Comments ('Yo (Ins.) .) 0 50 100 98 3053 0 10 LillP corrosion. 99 3085 ~ 16 ¡ 4 line cor rosío n. 100 '111 t: 0.11 ¡ .96 Corrosion. ~01 3146 J1 2 0.16 ; ~.92 Corrosion. Lt D~$its. 102 3177 O. 0.14 .95 Corrosion. 103 3209 J. 0.10 2,95 CorrosiQn. 104 324.0 'U 2.93 Corrosion. 105 3271 J1HL I 2.93 Corrosion. 106 3302 0 2.94=t== 107 3334 -º- 2.92 . 108 3365 * ....6 2.95 line coHQ$ion. 109 3396 ¡ 2.95 Corrosion. 110 3428 .31 ~ .Co(!:QSion. 111 .3.45 J Shallow.oit!ill&. 112 349i Line corrosion. 113 352 O. i5 2.95 line corrosion. 114 3554 2.95 Corrosion. 115 3585 I 0_05 21 ~ Shallow Plt!iŒ;¡;. 116 3616 J. Jì09 3.s -" CotlILsIon. 117 3647 ( O.JJ5 ShalIQ\ðLp¡tliru¡. 118 3679 I ) 0.09 2.95 Corrosion. 119 3710 .0.07 :'~ 120 3742 I 0.05 121 3773 0.10 122 3804 .1 0.08 0 2.96 . Lkte CQ!:19SÎon. 123 3835 iJ )7 0,12 5 2.94 line corrosion. 124 3866 _0> 13 2,94 ..Line corrosion. 125 3897 0.06 2.94 Corrosion. 126 3929 Jl Q ~ 2.94 Corrosion. 127 3960 J. 5 2.93 Corrosion. 128 3992 0 6 2.94 Corrosion. 129 4.023 0 0.10 " 2.95 Corrosion. 130 4.055 OJ9 0.10 ( 2.95 !ine corrosion. "131 4.086 0.12 2.95 Line corro$ion. 132 4117 -º- lZ 0.07 2.95 Line corro$ion. 133 4148 0.08 ( 2.94 Line ÇQrrosion. "134 4180 0.07 2.95 Corrosion. 135 4211 0.06 2.94 Corrosion. 136 4242 O. Jf) 0.10 2.93 Corrosion. Lt. Deposits. "137 4274 0.12 2.94 line corrosion. 138 4305 ~O.06 2.93 CorrosiQI}. 139 4337 Q !..5 0.10 , ~ line corrosion. 14.0 4368 o. :: 0.13 Line corrosion. 141 4399 (JO'( 0.08 2. Corrosion. It. Deoosits. 142 4430 0.07 ( 2. Corrosion. 143 4462 1 0.11 1 2. Corrosion. 144 4493 ll" Hi 0.07 2.. Corrosion. 145 4524 0.07 2.95 Corrosion. 146 45:'5 0.10 2.95 Une corrosion. 147 4587 O.OB 0.11 6 2.93 Line corrosion. Body Meta! loss Body 3 I I 3.5 in 9.3 0.254 in 0.254 in 2.992 in l-80 Well: Field: 2T-21 I USA 2007 I Joint .It. Depth Pen. Pen. ! Meidl Min. No. w. 116181m1i~oa ~~ne;:::~~: 150 rosion. 151 O. 8 C1ej 2.94 carras. "ion, 152 OJ1Q ¡ ¡ 2. ¡ne mrrosion. 153 477"- 0 ine corrosÎon_ 154 4806 . rosinn. 155 4837 Corrosion. 156 4.AAB 0 )ß Corrosion. ~ h Corrrn;ion. ~ .92 Corrosion ¡ t. Denn<:its. 159 4962 Corrrn;ion. 160 4994 line rnrrosinn. î 61 S(52 5 line mrrosion. ¡ t Dennsits. 162 5056 line mrrrn:iOI1. ..s088 (~ 0.12 Corrosion, It Opnn<õits. 1 ')119 011 I 0.14 165 0.08 Hi5.1 0 166 8 ¡ ine corrosion 167 5219 0 ~2 ¡-,6 I POSS¡RlE HOI f. lœ HOlil ~ 81 0 D9 line corrosion. ~ 12 0011 025- 2.93 I HOlf! 171 5 4':1 2 q? I Line mrrosion. I t np...."..,~its. 172 5375 2.94 HOLE! 173 5405 oiT 2.Q4 Corrosion. 174 5437 OJ 0.25 2.94 HOLE ¡ 175 5468 oor line corroskm 176 5497 0_1 2.93 line corrosion. 177. 0 or ~ Une corrosion. 178 5560 ~ 0.21 line corrosion. 179 551)2 ~ o. n -;;:¡-'2.94 line mrrosion. U. OeOú<;its. 100 5622 O.OB...QJ£ 46 ! 2.93 Une corrosion. U. Del:JOSits. 1 Al 5654 o.Jì.mti 2.92 Une mrrosion. 182 5685 eLIO 0.11 iP Une corrosion. 183 ~ 0 .ine corrosion ¡ t Oeno<:Îts. ~: I 0~)16 ~ine I ¡: HOI f 1860 2.93 line corrosion. 187 5841 f) 2.94 line corrosion. I. t npnnsits. 188 5872 0.06 0.11 189 () ~L 1~ m6 OM 5 191 5967 0:14 ì 192 5999 0.08 193 6030 194 6061 195 60ii3 196 6124 ¡ 0 Comments I I I I I I I I I I Une rnrrooon line xorrosio!1. Lt. DerJO<:Ìts. line corrosion. U. DerJO<:Ìts. ine corrosion. line cor/'OSion. line shallow corrosion. line corrosion. CorrQsion. I tfi 48 2.94 2.93 2.94 2.95 0.12 I 4 I I Inc. ,,:;",. ~ \!?file \ 10 WdllJ o 50 100 I I ONSH I I I 35 in 9.3 0.254 in 0.254 in 2.992 if! l-80 WeD: field: 2T-21 Inc. USA juUy01,2007 I Joint Jt. Deplh Pen Pen. ; Ivlelal Min. Profile No, !.D. Comments 1"/ _IH \ ¡U VY"'''I (Ins.) (Ins.) 0 50 100 197 7 HOLE. 198 199 I 0.1 200 ! 0.25 PROBÁRU: HOLE. 201 line corrosion 202 ~ Ii on 203 341 CorrnsÎnn. 204 637 CorrosÎt>r!. Corrosion. ( HOLF! 207 CU 19 ¡ 0.15 1',1 Corrosion. MOOI' , OM , '," Shallow o¡Uinll. 6526 POS"'IBlE HOLE. 6559 0 Shallow DÎttinll. 2 1 6591 ( It. De!)(}5¡jts. 212 ( 213 I .93 Isolated nittinlL 214 6684 ') ~ 215 /;716 96 ¡ ( PROBABLE HOlE. 216 6747 0.04 .2 2.93 Shallow oitÛnll. 217 677R 0.05 Sh"Unw n¡thOIl. 2H~ 6809 0 0.04 Shailow nitlio2. 219 6841 II '-- Shallow nitlin'" 220 6872 0 Shallow nitlinR. U. Del1OSÎts. i:Ú 6<ID4 0 2.% niltinq in lIO«;pt 222 6935 0 2.93 POSS'S! E HOLE. 223 6966 0.0 16 I 2.95 Shallow nitliluI. 6997 10.04 U ~ Shallow oíttin2:. 7029 I 0.04 "hallow nitlinu. 7060 2.92 Shallow nitlina. 2 7 7091 2.96 I Shallow nitlinQ. 228 7123 ( 2.94 I Shallow nittin2. 229 7154 ( I '''''''"d ni,"no> 230 7185 ) 0 Shallow oitliml. 231 7216 o I Ii Shailow Oitliflll. 232 7247 0 0 (- Shal!ow nitiÌl1!l. 232.1 7278 I::; GlM 311"tch fiill:30ì 233 728'1 Shallow nittirnz. 234 7317 2.Q4 Shallow nitlinŒ. 235 7348 ¡ I Sh.'"" ni"~ 7'1 7380 ( I Shallow òitlirnz. :':11 7411 I ) Shallow oittin«. 231 7442 "".,,,!low nitlin<>'. 239 7473 Shailow oitlinll. 240 7504 , Sh;¡Uow nittil'lQ. 241 0.04 17 'tlin2. 242 7567 0:05 ~ . Shallow oitlinll. 243 7598 != 2.91 . Shallow nitlil1ll. 244 76~O 2.94 "h"¡¡""\AI nitlirnz_ 245 7 hi; 1 ( 2.92 Isolated DÎU:iml. I I I I I I I I I I I 5 I I I I I I I I I I I I I I I I I I I I I I REPORT JOINT TABULATION EET Pipe: BodyWaU: Upset Wall: Nomina! I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 Welt: Field: Company: Country: Survey Date: 2T-21 Kuparuk ConocoPhilips Alaska, Inc. USA Jully 01, 2007 Joint Jt. Depth Pe, Pen. ¡\lÍe la I Min. Damag e Profile No_ (Ft.) 'I Body /.D. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 246 7692 0 0.05 1 1 2.94 Shallow nittinQ. 247 7724 0 0.05 ¡ ? 2.93 Shallow nittin2. 248 7755 1 0.05 I ) 2.91 Shallow nitlin2:. 249 7786 0.04 I 2.93 Shallow nitlinQ. Lt. Deoosits. 250 7818 I 0.04 2.93 Shallow oitlim;y. 251 7849 0.06 2.92 Isolated nittin2. 252 7880 0.05 2.92 Shallow oittim~. 253 7911 ~ ~ lsolatpd nittinq 254 7943 Shallow oÎUínQ. 255 7974 Shallow nitlinl:!. 256 8005 =! 1 2.91 Shallow oitlin¡;y. Lt. Deoosits. 257 8037 'I 2dt1 258 8068 14 2 Shallow oHlin!;!. 259 8100 0.03 2.93 260 8131 0.03 + 2.94 261 8162 0.04 2.91 Shallow oiUinq. 262 8193 0 0.04 ? 2.91 Shallow nÎt1irm. 263 8225 0 ~ 2.91 Shallow nÎtÛm:I. 264 8256 0 1 2.91 265 8287 0 0.03 ¡( 291 266 8319 J 0.03 2.94 Shallow oitûn¡;¡. 267 8350 0.03 2.92 268 8381 0.04 2.93 Shallow oitûm;¡. 269 8413 0.03 4 2.92 Shallow oitûng, ?70 8444 0.03 2.94 271 8475 OOS 0.03 2.93 'tlinll_ 272 8507 0 0.03 2.94 Shallow nitlinll. Lt. Denosits. 273 8538 0 0.04 2.91 Shallow oitiÎnQ. 274 8569 J i= 2.93 275 8601 ) 2.92 Shallow oitlim~. 276 8632 ) 2.92 Shallow niUinQi. 277 8663 ) 0.03 2.91 Shallow oitlirm. ¡II 278 8695 0.01 2.92 279 8726 0.04 1 2.91 Shallow Dit1íng. 280 8758 ( 003 2.92 Shallow Ditling. 281 8789 ( 0.04 2.91 Shallow DÎUing. Lt. DeDosits. 282 8820 ( 0.04 2.90 Shallow nittinQ. i 283 8851 0 0.03 2.91 284 8881 0.00 0.03 2.92 285 8912 0 0.05 2.91 Shallow oitûrm. Lt. Denosits. 286 8943 0 0.04 2.92 Sh~ilow oitûml. 287 8975 0 0.04 1 2.90 Shallow oitûnQ. 288 9006 0.03 1 2.91 289 9037 0.04 1 2.90 Shallow oitûng. Lt. Deoosits. ¡ill! 290 9069 0.03 ¡ 2.91 Shallow oitiÎm¡. ¡ill! 290.1 9100 0 0 N/A GLM 4 (latch @ 9:301 I 291 9105 i 004 ¡ 2.92 Shallow corrosion. 292 9138 () != 19 2.90 Shallow Ditlin!;!. It. Deoosîts. 293 9169 () 17 2.90 Shallow oitlinQ. Lt. Deoosits. 294 9200 () 13 2.91 Shallow oitliml. Body Me!alloss Body Page 6 I JOINT TABU SH EET I I Wall: Upset Wall: Nominall.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 Well: Fie!d: 2T-21 Inc. Country: Date: USA juUy01,2007 I joint jt. Depth F'eil. Pen. Pen. I i\1etal Min. "0' P fofile No. 1.0. Comments 'Of .In \ fU ..""" (Ins) (Ins.) 0 50 100 295 9232 ~ Shallow nitlinl<. ')96 9263 '--- Sha¡f;:;-w hitlin". 297 9295 2.90 Isolated ....itline L1. Deoosits. 'J98 9326 2.88 I Isolated "ittin". It. DeDOSits. tfi9357 0 is 2.G1 I Sha!lnw nitlinº. It Dennsits. '1388 2.91 ! Isolated "iHin" 9420 pï ¡,.nI"~;:¡ "ittin\;! L1. Dems¡ts. 302 9451 m.= Shallow corrosion. It. DeO(¡<;;í¡:"': 303 9483 ShaUow "'itlina. U. Deoosits. 10.1 9514 "1 ?88 I\h"llnw rmrasion. I t. Denn<cits. 30'1 .6 ¡""¡"">d "ittino 306 9577 0.06 Isolatpd ,,¡Wno Lt. Deoosits. .06 2.90 Corrosion. It DennsÎts. 05 Shallow"itlina. De..-.rn:its. isolated nittin2 It Deno<;Íts. 310 2.91 Shallow nitlinlZ. I t. Demsits. 311 9733 '-- I~' II»?J ~~~ It De~Œ 3P 9765 Y. '--- Lt. Deoosits. qn 9796 O. )6 :..-... . U Deoosits 314 9827 7:91 Lt DeoosÎts. 315 9859 005 I 'J .91 Sh low "itlinº. 316 9890 () ~ m¡ 2.R9 ¡"olated nitlina It. f)eno<:its. 317 9921 ¡ OJ 2.91 Shallow nillÍrnl. Lt f}enosits. 318 9952 2 2.91 Shallow nit1h1º ':I1Q 99R'! 1111.1 ') ? q? . . ! t. 320 10014 0.06 2.93 Isolated nittinq 371 10046 2.91 Isolated n¡Uino I t. Der)()<;its. 322 10077 O. 17 289 Isolated nittina 323 10108 0.06 2.92 Isoiaterlnittinº- 324 10140 I 0 12 0.07 ~ '»ored ~tbn~ Lt D.="~ 325 10170~ Isolated nittinR 326 1020 1 0.06 22 i$Dlated oittìnR 326.1 10232 11 6 PUP Piltin<>. Lt. f)e...........it" 326.2 10240 ¡ 0 ) N/A GLM 5 f!atch @ 6:15ì 3263 10242 ( 11 ?90 PUP 327 10253 ( j¡ 1 2.89 Lt. Denosits. 328 102R4 Of if, 11j Y 'J.91 Shallow nitlinl!:!. Lt. Denosits. 329 1031 6 0.10 ~ Shallow oittinQ. 330 10348 010 Shallow "Win". U. Deoosits. 331 10379 0 2.91 Isolated nittinR It. Deoosits. 332 10410 OJ ').90 Sh"l nw ...¡Hino I t. f}enosits 333 1044 1 n 0.0 C 2.91 Shallow nittina. It Deoosits. 334 10471 0 0 :1.90 kol;:¡ted "inino I t. f)eno"its. 335 10504 01 0 !( ~T i Shallow nittinq. U. Der1O';its. 336 1051"\ O. j Shallow nittina 337 10566 0.1 (I ! ¡ Shallow nitlim¡:. Lt. Deoosits, 3':18 1 \ 'I ! soIater! nittino 339 1 0.06 ')'.1 ittìnº It Deoosits. 3An 106 0.06 23 ¡ 'J.91 ¡$Dlated "itnna It f)",nn<cits. 341 10692 I 0.08 30 I 2.91 Isolated nittína Lt, Deno<:its. I I I I I I I I I I I I I I 7 I I I I I I I I I I I I I I I I I I I u Pipe: Body Wall: UpsetWaU: Nominal I.D.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in lAID Well: Field: 2T-21 Inc. USA Jully01,2007 Joint ]t. Depth Pi' Pen. F·en. i'vtelal Min. --ç P rofíle No. ,t !.D. Comments (ins) (ins.) (Ins. ) 0 50 100 342 10723 0.07 0.04 =m 2 ow nitúntl. 341 10754 0 . oitÚntl. 344 10785 2 . oittintl. It. nemsits. 345 10817 I) 0.06 ¡ solated niUirHiI 346 1 í3 0.05 isolated oittinl:!_ ~ 10879 003 1 10909 10 0.05 ¡ 21 Isolated oittina 349 10941 08 2.91 Isolated oittina 350 I 10972 .06 2.91 ! Isoi;¡ted oiUina Lt. Denn<:Îts 351 +:+1003 I) 0.04 7.92 Sh,,¡¡ow oiUinl!. 352 1035 I ~ Shallow nittinli!:. 353 11066 I) isolated nittina 3<4 11098 0.1i Isolated oÎttíntz. It. Demsits. 3"5 11129 0 Shallow nitúrli2. "I 6 11159 Shallow OÎtûn2. It. neo<)<:it". 357 11189 Isolated oittina 358 11220 ? 7.90 !<:niated oittina- "1'19 11252 {] I' 1 2.90 Isolaterl oittina ! f. neno"¡t,,. 360 11283 {] 1 1 2.<ì1 Shallow nitting. 361 11314 {] 0.04 1 I 2-<:11 Shallow oittirn!. 362 11345 0.10 0.05 21 2 2.91 Isolated oiUin2_ 363 11377 0.12 2.92 Isolated oitfin!!.. 364 11408 I) ~ Shallow oitúl1u. U. Dpnnsits. 365 ! 11439 I) %6 ! 11470 nl :) 5!i1 knlafp"¡ nittina 367 11502 {] 2.92 lso!ated oittÎnQ.. 368 11534 ( 2.92 Shallow oit!iml. 369 11565 21 2.91 Isolated oittin2. Lt Deoosits. 370 11595 14 2.92 Shallow oitlinu. 371 11626 0.03 * 2.92 Shallow Ditlin\;!. Lt, Denosits. 372 11658 0.03 2.91 Shallow nitlin\;!. 373 11689 I) 0.05 2.93 Shallow pittin~. Lt, Denosits. 374 1171 q n o.m 2.93 Shallow nitlirnz. 375 11751 ~ 2.89 376 11781 2.93 377 I n812 ( 0.04 2.91 Shallow oitlÍl12. 378 11844 ( 0.02 1 2.88 U. Opnn,,'ts. 379 11875 ( 0.03 (> 4 2.93 380 11906 ( 0.02 ~ 2.93 381 11936 I) ~ 2.93 382 1196 <:1 7.94 383 12000 0.05 2.93 Shallow oíU¡n~. 384 1203 1 =; 14 2.91 Shallow oituml. 385 12062 0. 17 15 2.92 Shallow oittîll2. 386 12092 ( ~ 2h Isolated oittina 387 12123 ( 0.04 2. Shallow [)itlim~. 388 12154 0.08 2.92 line corroc;Îol1. 388.1 12185 0.04 4 2.90 PUP Shallow oiWIl2. 388.2 12190 ( 0 ) ( N/A GLM 6 (latch @ 8:45\ 3883 12198 I). 15 0.10 0 10 2.89 PUP Corrosion. Lt. Deoosits. Body Metal loss 8 I I REPORT 3.5 in 9.3 0.254 in 0.254 in 2.992 in L-80 WeD: Field: I I Wall: UpsetWa": Nominal 1.0.: Joint No. I I 389 389. 389.2 389.3 I I I I I I I I I I I I 9 2T-21 USA )u!ly01,2007 Comments Alaska, Inc. .. - - .. - .. - - - Well: 2T·21 Field: Inc. USA Tubin : 3.5 ins 9.3 l·80 Tool '" 43 NominallO 2.992 Nominal 00 '" 3.500 wall area'" 87 % Tool deviation'" 82 0 10 Penetration'" 0.414 ins HOLE - - - - - - s 01, 2007 UW MFC 24 No. 212330 1.69 24 B. i 1 ft .25 ins'" 100"1" Wall Penetration HIGH SIDE '" UP Cross Sections page 1 - s - - - .. - - .. .. - .. - .. - - .. .. .. - s Well: 2T-21 field: Inc, USA Tubin: 3.5 ins 9.3 f l·80 01,2007 UW MFC 24 Nn 212330 1.69 24 B. i ft Tool 43 Nominal fO = 2.992 Nominal 00 = 3.500 wall area"' 89 % Too! deviation = 83 0 9 Penetration = OA04 ins HOLE .25 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page :2 - s .. - - I KRU 2T ..21 I NIP (509-510. I 00:3.500) I Gas lift I n<lÆlIDummy ValVe 1 (2222-2223, OD:5.390) I Gas lift . ndreilDummy ValVe 2 I (5194-5195, OD:5.300) TUBING «(}'12268, OD:3.500, ID:2.992) 20 Gas lift I n<fr>I¡jlDummy ValVe 4 (9103-9104, I 00:5.390) Gas lift Il'1drêIIDummy ValVe 5 I 10240-10241, 00:5.968) Gas lift .l'1drêIIDummy ValVe 6 I NIP 12236-12237, I 00:3.500) PKR I 12244-12245, 00:6.151) I PLUG 12258-12259, 00:2.750) I SOS 12257-12258, 00:3.500) Perf I 12386-12:406) Perf 12:402:-12:42:0) I Perf 12:436-12468) I Perf 12447-12467} I I Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company' Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I 0/31/O3 Field: Kuparuk Well Job # Log Description Date BL Color CD IY-19 ~ q ~'~-'l(~-c~' PRODUCTION PROFILE/DEFT 10109/03 3A-04 ~ ~7-~'~ INJECTION PROFILE 10111103 3B-03 ~ ~~(~ PRODUCTION PROFILE/DEFT 10H3103 3a-0s '~-~ PRODUCTION PROFILE 10/~4/03 3A-05 1~-~ I PRODUCTION PROFILE 101t5/03 3B-06 ~ ~-~ PRODUCTION PROFILE 10116103 2T-21 1 q~ ~ .LEAK DETECTION LOG 10117103 3B-04 PRODUCTION P.OF LE/DEFT 01 S103 ~E-20 ~ ~ SBHP SURVEY . 10120103 31-1 ~ J~ -O~ LEAK DETECTION LOG 10125103 3G-11 j~~~ PRODUCTION PROFILE 10127103 1B-20 ~-'~ PERF RECORD/STATIC SURVEY 10/30103 ,.~ ~., ~l. ~,~ Please sign and return one copy of this transmi~al t0 Beth at the above address or fax to (907) 561-8347. Thank you. ,';,; ..... ,;; PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 23, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-21 (195-013) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 2T-21. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad SCANNED JUl_ 3 1 2002 RECEIVED JUL 2 4 2002 Alaska 0il & Gas Cons. C;0mmisslor, Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _XX Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 123 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 83' FNL, 4724' FEL, Sec. 12, T11 N, R8E, UM (asp's 498945, 5969901) 2T-21 At top of productive interval 9. Permit number / approval number 1008' FSL, 1574' FWL, Sec. 10, T11 N, R8E, UM (asp's 489404, 5965718) 195-013/ At effective depth 10. APl number 50-103-20212 At total depth 11. Field / Pool 4575' FNL, 3778' FEL, Sec. 10, T11 N, R8E, UM (asp's 489333, 5965410) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12821 feet Plugs (measured) true vertical 6125 feet Effective depth: measured 12545 feet Junk (measured) true vertical 5945 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 225 sx AS 1 121' 121' SURF CASING 4649' 9-5/8" 870 sx AS III & 740 Class G 4772' 2900' PROD CASING 12681' 7" 275 sx Class G 12804' 6114' Perforation depth: measured 12386' - 12406', 12406' - 12424', 12436' - 12468' RECEIVED true vertical 5841' - 5854', 5854' - 5866', 5874' - 5895' JUL £ 4 2002 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12268' MD. Naska 0il & Gas Corls. uo,l,,.,~s~o~ Packers & SSSV (type & measured depth) BAKER SAB-3, PERM. @ 12244' MD. Anchorage CAMCO 'DS' NIPPLE NO GO @ 509' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 126 543 493 - 311 Subsequent to operation 110 908 487 330 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~./Jy~~ Title: Wells Team Leader Date 7/E ~'/~ ~_ Michael Mooney Prepared b~/ Sharon Al/sup-Drake 263.4612 Form 10-404 Rev 06/15/88 · ORIGINAL SCANNED JUL 3 I 2002 SUBMIT IN DUPLICATE Date Comment 2T-21 Event History 06/08/02 06/09/92 06/09/02 UNABLE TO PASS 6220' WLM, IN PROGRESS [TAG] SHOT TWO 2.51N 2506 POWER JETS @ 6 SPF, 60 DEG PHASING. 2 RUNS (8 FT AND 10 FT) TOTAL 18 FT OF GUNS, 122 SHOTS -- PENETRATION 25.2 IN, ENTRANCE 0.32 IN - PERFORATED INTERVAL 12406 - 12424 FT,CORRELATED TO GAMMA RAY ON SWS CDN LOG FINISHED 20 FEB 1995. DRIFTED & TAGGED FILL @ 12,547' WLM W/15'-6" OF 2.55" DUMMY GUN'S & PETROLINE SKATE [TAG] RU ELINE. PERF'D LOWER C4 12406'-12424'. SCANNED JUL 3 1 2002 Page I of I 7/17/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 41' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 83' FNL, 556' FWL, Sec 12, T11 N, R8E, UM 2T-21 At top of productive interval: 9. Permit number/approval number: 1008' FSL, 1574' FWL, Sec 10, T11N, R8E, UM 95-13 At effective depth: 10. APl number: 731' FSL, 1463' FWL, Sec 10, T11N, R8E, UM 50-103-20212-00 At total depth: 11. Field/Pool: 700' FSL, 1387' FWL, Sec 10, T11N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 12821 feet Plugs (measured) None .... ' r ~,~-i'l .... :~,~.,~.,'.. ~ true vertical 6125 feet !...,i 'L ..,' I "~ , ~ , _- Effective Deptl measured 12714 feet Junk (measured) 2 KOT arm springs at 7286 feet true vertical 6055 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 225 Sx AS I 121' 121' Surface 4734' 9-5/8" 870 Sx AS III & 4772' 2900' 740 Sx Class G Production 12767' 7" 275 Sx Class G 12804' 6114' Liner Perforation Depth measured 12436' - 12468' '::i-~,~' Ii ,.~.',~ true vertical 5854' - 5874' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 12268- Packers and SSSV (type and measured depth) Pkr: Baker SAB-3 @ 12244'; SSSV: None, nipple @ 509 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 4/1/98. Intervals treated (measured) 12436' - 12468' Treatment description including volumes used and final pressure Pumped 119950 lbs of 16/20 and 12/18 ceramic proppant into the formation, final pressure = 8900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 231 478 206 1176 326 Subsequent to operation 571 642 1409 1190 327 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __ZX Oil __ZX Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , Signed ~j~/~., Title: Wells Superintendent Date Form 10-404/~ev 06/15/88 SUBMIT IN DUPLICATE~ K1(2T-21(W4-6)) _ JOB SCOPE JOB NUMBER · - 1'-21 FRAC, FRAC SUPPORT 0327981800.3 DATE DAILY WORK UNIT NUMBER 04/01/98 "A" SAND REFRAC '-DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoJ (~) Yes O No DS-GALLEGOS CH~/~IF~Y FIELD AFC# CC# DAILY COST ACCUM COST Sigr'l~d/' /,4:~ /'/ ESTIMATE KD1951 230DS28TL $108,701 $114,024/~.[' /v~ Initial Tbg Press -Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Out~r Ahn ~idal Outer Ann~,/ 925 PSI 1200 PSI 580 PSI 500 PSII - 475 PSI! 60_~g'PS I DALLY SUMMARY ,/ "A" SAND REFRAC SCREENED OUT EARLY. INJECTED 119950 LBS OF PROP IN THE FORMATION W/9.5# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 8900 PSI & F.G. (.78). UNABLE TO FREEZE PROTECT TBG. TIME 06:00 09:00 09:35 11:00 12:30 LOG ENTRY MIRU DOWELL FRAO EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCK. HELD SAFETY MEETING (15 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. SLURRY VOLUME PUMPED 450 BBLS. USED 5657 LBS OF #16/20 PROP FOR SCOURING. MAXIMUM PRESSURE 8900 PSI AND ENDING PRESSURE 3700 PSI. STEPPED RATE DOWN AT THE END OF THE STAGE. S/D AND OBTAINED ISIP OF 1997 PSI W/F.G. @ (.78). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 22 MINS @ 1532 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 225 BBLS. MAXIMUM PRESSURE 5700 PSI AND ENDING PRESSURE 3700 PSI. S/D AND OBTAINED ISIP OF 1951 PSI W/F.G. @ (.77). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 24 MINS @ 1543 PSI. PAD VOLUME = 250 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT EARLY BACK TO SURFACE. PUMPED 150569 LBS OF PROP (22800 LBS OF #16/20 & 127769 LBS OF #12/18). INJECTED 119950 LBS OF PROP IN THE FORMATION W! 9.5# PPA OF #12/18 @ THE PERF'S. LEFT 30619 LBS OF PROP LEFT IN THE WELLBORE AND EST FILL @ SURFACE. EST BHP TO BE 3000 PSI. UNABLE TO FREEZE PROTECT TBG, 14:15 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 15:15 REMOVED TREESAVER ALL CUPS RETURNED). CONTINUED R/D. 16:15 R/D COMPLETED AND ALL WELL SERVICE PERSONNEL LEAVING SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $711.00 APC $6,600.00 $6,600.00 DIESEL $400.00 $400.00 DOW ELL $99,501.99 $99,501.99 HALLIBURTON $0.00 $2,611.77 LI'I-I'LE RED $2,200.00 $4,200.00 TOTAL FIELD ESTIMATE $108,701.99 $114,024.76 ,~ I'ION. WELL SECUt ND NOTIFIED DSO OF STATUS. F' E R M I T D A T A AO,S(.',E Inctividua"i We1 'J Geoio,;:jica'J k'iater"ials Inven-Lor'y T DATA__PLUS Date~ 03/'i9/97 R I..IN D A T l! .... Fi'. 95--~ 0 '13 95-~013 95 .... 013 95 ..... 013 95,-~013 95 ..... 0 i 3 ~-O68 / G C '1 rd D N/D ("J ;S D R/DC D I R S U R V i 0 -.- 6 0 7 -L i0980-'~12780 Ld 0-.~ 126r*0 ', Ar'e dr'y Was t'he Ar'e wei '1 We'l ~ i s C 0 H M E N T {]; DAZ I... Y ditch samples weii eot'ed'? R e c e i v e d '? y_e s n o 't.:ests r"equifed? yes (no , in cornpl'iance ~-,! -, I n "i't i a 'i .-,rlCO Alaska, Inc. Post Office Box 1003bu Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 7, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-21 (Permit No. 95-13) Well Completion Report Dear Mr. Commissioner: Enclosed is a revised well completion report for KRU 2T-21. location has been changed. If there are any questions, please call 265-6206. The bottomhole Sincerely, / Kuparuk Drill Site Development Supervisor RECEIVED SEP 1 2 199§ Alas~. 0il & Gas Cons. Commission 'Anchorage MZ/skad STATE OF ALASKA i ~-.. AL,-,or,,A OIL AND GAS CONSERVATION CON .... bSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~ GAS r~ SUSPENDED ~ ABANDONED [] SERVK;E ~-~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-13 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 , 50-103-20212 4 Location of well at surface! 00~?L~i iL;i"J. ~ 9 Unit or Lease Name i I~"T[~J ~ i i~[,{;31~ ' - Kuparuk River Unit 83' FNL, 556' FWL, Sec. 12, T11", RSE, UM At Top Producing Interval ~~:/~';"~ ~VJ~RtFJ~:~ ~. "~ ~ lO Well Number 700' FSL, 1503' FWL, Soc. 10, TllN, R81=, UM KU~ARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. RKB 41', Pad 82' ADL 25568 ALK 2666 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions Feb. 14, 1995 Feb. 20, 1995 6/4/95 (perf'd)I NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DireclJonal Survey 120 Depth where SSSV set I 21 Thickness of permafrost 12821' M D & 6125' TVD 12714' MD & 6055' TVD YES ~ NO [~I NA feet MD] 1380' ss APPROX 22 Type Electric or Other Logs Run GPJCDR/CDN, GR/CCI_/USIT/CBT/GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 Surf 121' 24" 225 sx ASI 9.625" 40.0# L-80 Surf 4772' 12.25" 870 sx AS III lead, 740 sx Class G tail 7" 26.0# L-80 Surf 12804' 8.5" 275 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 12268' 12245' 12436'-12447'MD 5854'-5860'TVD 6spf 12447' - 12467' MD 5860' - 5873' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 12467' - 12468' MD 5873' - 5874"1-VD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 112436'- 12468' 12MLbs 20/40, 207 Mlbs 12/18, 25MLbs 10/14 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/11/95I FLOWING Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/20/95 18 TEST PERIOD ~ 1369 1585 136 124 1 !58 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press 271 1009 24-HOUR RATE ~ 1825 2113 lSl 24.00 28 CORE DATA Brief description of lithalogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R [ ',' 'ED S EP 1 ?- 1995 Ataska IJit & Gas Cons. Commission Form 10-407 Submit In duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARt(ERS 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 12384' 5840' Base Kuparuk C 12426' 5867' Top Kuparuk A 12426' 5867' Base Kuparuk A 12622' 5995' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- '''-' VED jection, Gas Injection, Shut-in, Other-explain. R i'" '~, ~ [ Item 28: If no cores taken, indicate "none". Form 10-407 S EP ]995 ,Nas~ 0il .& Gas Cons. Commission N~ch0rage Date: 06/16/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-21 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8095 AFE: AK8095 TYPE:DEr AFE EST:$ 1747M/ 2280M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20212 FIELD: KUPARUKRIVER SPUD:02/14/95 START COMP: FINAL: 02/13/95 ( 1) TD: 0'( 0) SUPV: JT 02/14/95 (2) TD: 121'( 0) SUPV:JT 02/15/95 ( 3) TD: 3890'(3769) SUPV:RLM 02/16/95 ( 4) TD: 4783' (893) SUPV: RLM 02/17/95 ( 5) TD: 4793' ( 10) SUPV: RLM 02/18/95 (6) TD: 8355'(3562) SUPV:RLM 02/19/95 ( 7) TD:11520'(3165) SUPV:RLM 02/20/95 (8) TD:12615' (1095) SUPV: RLM 02/21/95 ( 9) TD:12821'(206) SUPV:RLM MW: 0.0 MOVING RIG Moving rig from 2Z to 2T. DAILY:S98,480 CUM:$98,480 PV/YP: 0/ 0 ETD:SO APIWL: O. 0 EFC: $1,845,880 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PU MOTOR AND ORIENT BHA Move rig over 2T-21. Move on location and rig up. Phase 3 conditions exist f/1730 hrs 2/13/95. DAILY:S91,776 CUM:$190,256 ETD:SO EFC:$1,937,656 MW: 10.0 PV/YP: 25/24 APIWL: 8.4 DRILLING Spud well at 0800 hrs. 2/14/95. Directional drill 12.25" hole from 121' to 3890'. DAILY:S87,676 CUM:$277,932 ETD:SO EFC:$2,025,332 MW: 10.1 PV/YP: 19/20 APIWL: 8.8 RUNNING CASING Directional drill 12.25" hole from 3890' to 4783'. Rig up to run 9.625" casing. Run casing. DAILY:S90,077 CUM:$368,009 ETD:SO EFC:$2,115,409 MW: 8.8 PV/YP: 8/ 4 APIWL: 16.8 CIRCULATE Finish running 9.625" casing. Cement casing. CIP @1141 hrs. 2/16/95. Test all BOPE rams, hydril and valves. Test casing to 2000psi. Drill float collar at 4697', cement, float shoe at 4772' and 10' new hole to 4793'. DAILY:S239,462 CUM:$607,471 ETD:SO EFC:$2,354,871 MW: 9.0 PV/YP: 11/ 9 APIWL: 8.2 DRILLING Directional drill 8.5" hole from 4793' to 8355'. DAILY:S76,799 CUM:$684,270 ETD:SO EFC:$2,431,670 MW: 9.3 PV/YP: 14/15 APIWL: 7.2 DRILLING Directional drill 8.5" hole from 8355' to 11520'. DAILY:S79,839 CUM:$764,109 ETD:SO EFC:$2,511,509 MW: 10.6 PV/YP: 17/18 APIWL: 4.8 DRILLING Directional drill 8.5" hole from 11520' to 12615'. DAILY:S118,944 CUM:$883,053 ETD:SO EFC:$2,630,453 MW: 10.8 PV/YP: 22/16 APIWL: 4.4 RIH Directional drill 8.5" hole from 12615' to 12821'. DAILY: $86,662 CUM: $969,715 ETD:SO EFC: $2,717,115 Date: 06/16/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT 02/22/95 (10) TD:12821'( 0) SUPV:JT MW: 10.8 PV/YP: 18/14 APIWL: 4.4 POOH Run in hole with rotary BHA for wiper trip to clean out tight spots and control lost circulation. Wash, ream and work pipe with partial to full returns, adding LCM. CBU at TD. POOH to run casing. DAILY: $96,898 CUM:$1,066,613 ETD:S0 EFC:$2,814,013 02/23/95 (11) TD:12821' ( 0) SUPV:JT MW: 10.8 PV/YP: 22/18 APIWL: 4.0 RUNNING CASING POOH; hole flowed back 70 bbls after circ on bottom. While POOH, hole took 30 bbls over est fill volume. RU to run casing. Held safety meeting. Ran 7" casing. Broke circ at 2000' with no loss. Broke circ at shoe with 23 bbl loss. Attempted to circ at 6700', 8500', and 10,500'; no returns. DAILY:S79,214 CUM:$1,145,827 ETD:SO EFC:$2,893,227 02/24/95 (12) TD:12821' ( 0) SUPV: JT MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 7" casing. LD circ. tool. RU to circ. Attempted to circ. Pumped away 240 bbls. No returns. Cemented with D/S. RD D/S. ND BOPE. Cut off csg. NU wellhead. Freeze protect. Held safety meeting and spill drill. LDDP f/move. DAILY: $244,284 CUM:$1,390,111 ETD:S0 EFC:$3,137,511 REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8095 AREA/CNTY: FIELD: SPUD: RIG: NORDIC WI: 0 % SECURITY: 0 AFE: AK8095' TYPE:DEr AFE EST: $ 0M/ OM STATE: API NUMBER: START COMP: FINAL: 05/22/95 (13) SEAWATER/DIESEL TD:12821' PB:12714' SUPV:JT MOVING NORDIC RIG ~1 Moving rig from lB pad to 2T pad. DAILY: $30,700 CUM: $30,700 ETD:SO MW: 8.5 EFC: $30,700 Date: 06/16/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT 05/23/95 (14) TD:12821' PB:12714' SUPV:JT RUNNING 3-1/2" COMPLETION MW: 0.0 Accept rig 0730 5/22/95. Pressure test 7" casing. Pressure test BOPE. RIH with 3-1/2" completion string. DAILY: $53,225 CUM: $83,925 ETD: $0 EFC: $83,925 05/24/95 (15) SEAWATER/DIESEL TD:12821' PB:12714' SUPV:DEB RIG RELEASED MW: 8.5 Continue running 3-1/2" completion assembly. Run 3-1/2" tubing. Nipple down BOPE. Nipple up tree. Test tree. Test packoff. Secure well. Release rig 0400 5/24/95. DAILY:S162,906 CUM:$246,831 ETD:SO EFC:$246,831 06/04/95 RU SWS. Hold safety meeting. PT lub to 4800%; test OK. Ready to RIH, but SSV has not been pumped open after installation. SSV open; RIH w/gun #1 2-1/8" enerjet w/bh charges, 90 deg 'V' ph, 6 spf, oriented 45/-45 deg. from the lowside to shoot 12456'-12468' per CBL dated 2/26/95. In position at 12452' to shoot 12456'-12468'; pressure tubing to 4800# to shoot interval overbalanced, guns fired; no immedidate pressure response. Watched pressure for 10 mins.; no change, bleed off pressure. POH w/gun %1. At surf w/gun %1; gun did not fire. PT lub to 4800%; test OK. RIH w/gun %2, 2-1/8 enerjet w/bh charges, 90 deg 'V' ph, 6 spf, oriented 45/-45 deg from the lowside to shoot 12448'-12468'. In position at 12444' to shoot 12448'-12468'; pressure tubing to 4800% to shoot interval overbalanced. Guns fired; pressure dropped 200%. After 10 mins pressure is 3300%. Bleed pressure down; POH. At surf w/ gun %2. All shots fired. PT lub to 3000%; test OK. RIH w/ gun #3 2-1/8" enerjet w/bh charges, 90 deg 'V' ph, 6 spf, oriented 45/-45 deg from the lowside to shoot 12436'-12448'. In position at 12432' to shoot 12436'-12448'. Gun fired; POH. At surf w/ gun #3. All shots fired. RDMO. 6/6/95 MIRU SWS e-line unit. Load guns. Notified security of perforating operations. Notified construction and rig crews of radio silence on pad. Held safety meeting. Arm guns. PT lubricator to 4000%. RIH w/12' of 2-1/8" wt bar, 6' 1- 11/16" wt bar, CCL, MPD, 20' 2-1/8" enerjet guns, w/2 spf bh charges, phased 90 deg up from lowside (right). Tie in to CBL log dated 2/25/95. Log across previous perfs. Slight indication of existing perfs, pull wt while pulling back thru existing perfs. Attempt to pressure up tubing w/diesel, pump 5 bbls and tbg pressure increased from 850% to 950%. Shoot guns from 12447-12467' on CDR log. WHP dropped back to 850#. POOH w/guns. On surface at 1445 hrs. all shots fired. MU gun %2 as above (phased 90 deg up from lowside (left). RIH w/same. Tie in and shoot at 2 spf from 12447'-12467' (based on CBL log).POOH. OOH w/guns. ASF. Begin RD SWS. SWS RD. Secure well. End of WellSummary for Well:AK8095 PA~ ~,w~,-** SUR4JE¥ PROGRAM ***,-,w****, DDMPANY ARCO ALAS?~ WELL NA~E 2T-21 LOCATION I I(UPARUI( LOCATION 2 ALASI(A M~Nb'"i'IC I)Y. CLINATION 28,52 GRID CONVER(;B, ICE ANG:LI:. 0,00 DATE: 15-~B-~ ELL NUMBER 0 W~LL tEAI) LOCATION: LAT(N/-S) 0.00 DEP(E/-W) AZIMUTH FEX3M E~]TARY TABLE TO TARGET IS 246,31 0,00 TIE IN FOlNT(TIP) : MP_ASUR~ D~P?H 121,00 TRUE V~? D~PTH .121,00 I~ELINATION 0.00 AZI~TH 0,00 ~TITL!DE(E/-S) 0.00 DEPARTURE(E/-W} 0,00 RECEIVED JUL 0 7 1995 Oil & Gas Cons. Commission .,'. NO, 2I'-21 ,~*********** ANADRII.L *~*~*~*~***~* SL~V~,,' CA~LF~AT IONS .***********.** CIRCULAR ARC M£~OD~*~*~ ME4SUF~D INTERVAL VBF.?IU'$ D;.F'TH ft ft ft t21,00 0,0 121 ..~ 67.5 1~,52 281.30 92.8 281 374,78 ~,5 374,5~ 466,04 91,3 465,07 TARe;ET STATION AZIMU?H ~T!~JDE SECTION tNCLN, N/-S f~ deg d~ fr 0,00' 0,00 0,00 0,04 0,09 0,30 304,29 ~),10 2,19 2,47 ~6,44 .-0,87 8,71 5,70 233,96 -4,72 19,59 8,27 235,50 -Il,lC DF.F'AR?URE DISPLACEMENT .at ft ft O,(X) 0,00 -0,I5 0,18 -2,01 2,19 -7,45 8,81 -!6,52 19,90 AZIMUTH deg 0.00 304,_29 246,64 237,.~. 236,10 DLS d. eg/ lOOft 0,00 0,44 2.56 3,46 2,82 555.21 90,2 ~4,% 646.95 90,7 642,94 737.57 ~,6 730,6~ 827.75 90,2 816,67 919,45 91,7 902.D 33,95 10,30 238,78 52.~ 12.86 241.'92 74,65 16,08 244,08 -3B,14 101,77 18,96 244,07 -50,01 133.98 22,20 243,60 -64.23 -28,75 34,.44 236,62 2,32 -44.60 52.61 237.97 2,91 -64.79 75,18 239,51 3.60 -89,20 102.26 240,72 3,20 -118,12 134,46 241.% 3,54 1010,09 .1101.86 1194,82 12~,3! 1382,47 90.6 985,63 91,8 10&5,27 93,0 1150,89 92.5 12~,67 94,2 1313,52 170,07 24.77 245.~ -79,~ 209,96 26.76 245,81 -95,29 252,58 27,82 247,14 -113.Z? 297.51 2~.~ 247,53 -130.56 346,00 32,50 ~0.92 -147,74 -150.72 170.53 242,11 2,93- -187,04 210,$5 242,77 2,18 -226,12 252,91 243,39 -267,59 297.~ 243,9? -313,02 a4.,13 244,73 3,56 14.77,15 1571,77 1664,09 1758,43 94,7 1~'2,37 94,6 146~.85 92,3 15~2,83 94,3 16!1,52 92.9 I678.25 298,27 2~,71 249.78 -165.38 453,87 37,44 250.!7 -184,45 511,51 40,07 250,29 -203.99 573.85 42,86 249,72 639,70 46.51 250,73 -247.67 -~52,36 398,31 245.47 2.43 -414,70 453,87 246,02 2.89 -%9.08 511,52 246.50 2,86 -527,77 573.87 246,88 2,98 -589,89 639,78 .n/.22 3.96 1944,83 203-~.60 2132.83 2226.01 231A" 92,5 1740.46 92,8 1800,40 94,2 1857.~J 92.2 1910.33 92,3 1959,60 708,00 48,99 250.20 -270.5~ 779.94 51.52 250,10 -2~.06 8~.88 54,10 249.Z7 -~!,14 931.38 56,51 249,36 -348.20 1009.42 59,06 247.5~ -376.~ -654.43 708.16 247.54 -7~,~ 780.20 247.78 -792.64 8~,23 247.94 -&54.31 591.81 248,06 -936,96 1009.9! 248,09 2,72 2,70 2,82 2,58 3,20 24t3,10 ~08,03 2601,91 ~'07,02 3070,24 94,8 cw..,~v 94.9 2049,74 92,9 265B.:b 187,7 2158,25 280,6 2263,54 1091,74 61,6I 247,01 -408,64 1176,~ 64,18 246,55 1261,80 67,23 246,26. -476.13 1435.95 69,07 243.31 -~0,24 1695,53 66,85 242,31 -667,06 -t012,91 1092,22 248,03 -1090,S6 1176,71 247,94 -1169,00 1262,25 247,84 -1326.h6 1436.25 247,47 -1558,00 1695,59 246,76 2,75 2,74 3,25 1,80 0,86 .3348,72 35~5.52 3723,~0 39(~B.46 409,.4,25 278.5 2372.56' 187.8 2442,69 187,3 ~07,78 184.7 2571,77 187,8 2640,10 1951,63 67,09 247,77 -777,15 2125.8I 69,~5 246,45 -844.,93 2301.~? 70,27 247,73 -913,28 2474,5t 69.t8 248,74 -977.51 2649.29 68,14 248.[-8 -1041.45 -1790.24 1951,65 246,53 -1550,71 2125,83 246,58 -2112,46 2301,43 246,62 -:W_.73,~ 2474,58 246,73 -2436,14 2649,41 246.85 1.80 1,23 0.91 0,78 0.58 4280,96 4469,29 465~[).94 4881,01 51~..2,72 184.7 2706,13 188,3 2772,09 221.6 2853.45 190,1 2926, i5 282,7 3032,33 2821,67 69.96 248.37 -1105.03 2997,98 69,03 248.12 -1170,41 2204.08 67.90 247.12 -1248,90 3379,69 67,12 246.07 -1318.&~ 3641,68 68,76 247,68 -1421,54 -2596.49 2821,85 246,~5 -2760.32 2998.21 247,02 -2i50.% 3204.35 247,65 -3112,12 3379,97 247,04 <T053,08 $541,77 247,03 0.99 '0,51 0,66 0,65 0,78 ..d NO.. ************* ANADRILL SURVEY ~LCULA?IONS ************* CIRCULAR ARC 2T-21 MEA~RED INTERVAL V~RTICAL TARGET STATI_nN AZIMUTH LATITUDE DEPAE~URE DISPLACEMENT at AZIMUTH DLS D~PTH D~TH SECTION INCIJ,t, N/-S E/-W deg/ ft ft fr ft deg deg ft ft ft deg lOOft 5444.40 280,7 3132,31 ~?03,92' 69,50 245,87 -1524,97 -3594,07 3504,21 247,01 0,66 5724,16 279,6 32.36,43 4163,54 66,80 247,71 -1627,3 -3832,66 4163,84 246,9? 1,14 6008,58 284.4 33~5,61 4425,60 67.62 248,78 -1724,52 -4076.19 4425,98 247,07 0,45 6284,95 2_76,4 3449.40 4661,91 68,71 248,63 -1617,68 -4315,23 4682,43 247,16 6567,25 282,3 3~2,:il ~' ' ~¥44,o4 68,62 248,69 -1913,35 -4.~0,15 4945,?? 247,24 0,04 6845,13 277.9 3654.74 5202,78 68.04 246,89 -2010.~ -4799.22 5203.50 247.27 0,64 712~,10 284,0 3761,00 546_6,08 68,02 244,27 -2119,80 -5038,99 5466,71 247,18 0,85 7407.99 278.9 ~64.45 5724,92 68,43 244.40 -~1,97 -5272.43 5725.40 247,06 0,15 76&~,75 280,8 396.,o~ 5984,81 67,47 242,53 -2348,22 -b'505,~ 5985,13 246,90 0,70 7971,74 283,0 4076.79 6246,4! 68,12 243.83 -246.6,43 -5739,04 6246.5? 246.74 0,46 824?,67 2,'57,9 41~3,3-~ 6504,17 68,12 244,94 -2577,94 -5971,59 6504,28 246,65 0.37' .8528,92 279,2 4283,96 6763.44 68,34 245,51 -2686,61 -6207,05 6763,52 246,60 0,21 8810,77 281,9 43-,87,44 7025,59 68,58 245,54 -2795,22 -6445,~ 7025,66. 246,~5 0,09 ?0?3.06 282.3 4489.~ 7268,87 69,14 245.66 -2~3,95 -6685,44 7288°?2 246,52 0,20 9372,65 279,6 4591,]3 /"549,15 68,11 244,34 -3014,01 -6921,41 7549,18 246,47 0,57 9653,56 280,? 4694,67 7810,01 68,63 243,19 -3129,44 -7155,63 7810.02 246.38 0,43 9'~,4,98 281.4 4805_.,43 8068,40 65.01 244,30 -.3243,91 -7387,57 8068,41 246,2~ 1,34 10122,16 187,2 4883.93 82~,30 65.41 247.44 -3313,38. -7542.62 8238,30 246.28 1.54 10~7~.27 187,1 4957,4-~ 8410,32 68,2? 246.50 -3380.70 -7700,93 8410.32 246,30 1,61 t0590,93 281,7 5058,14 8673,36 6?,83 246,08 -3486,48 -7941.~ 8673,36 246,30 0,56 10876,79 285.9 5160.61 8940,21 ..48,16 246,83 -3593,'11 -8186,39 8940,21 246,30 0,63 11148,0? 27!,3 5257.27 9193,67 70.10 247,34 -3691,82 -8419,86 9193,67 246,32 0.74 114~,67 272,6 5354.05 9448,46 68,31 246,75 -3791,20 -8654,50 9448,46 246,34 0,69 11582.60 161,9 ~12,61 95?9,42 69,30 245,67 -3652,t0 -8792,63 9599,43 246,34 0,87 11670,00 87,4 5445,26 9680,48 66,84 244,70 -3866,12 -8866.22 9680,48 246,~ 2,?~ 11765,00 95,0 5486,~ 9766,0? 61,?0 246,14 -3921,75 -8944,07 9766,09 246,32 5,38 11859,91 94,9 5531,70 ?849,45 60,?'-? 246,71 -39b"5,09 -9020,48 9849,45 246,32 1,10 11954,95 95,0 b-577.92 9'-732,50 60,82 245+96 -3988,42 -9096,54 9932,50 246,32 0,71 i2049,96 ~5,0 5625,54 10014,71 59,02 245,47 -4022,23 -9171,48 10014,71 246,32 1,94 12145,70 95,7 5576,60 10095,68 56,52 245,.M -4~5,74 -f'245,20 10095,68 246,31 2,62 12240,02 ?4,3 5730,51 10173,07 53,77 246,83 -40~,94 -9316,02 10173,07 246,31 3,09 12335,77 95,7 5789,05 10248,7? 50,83 248,42 -4115,7'~ -9386,06 10246,80 246,32 3,34 I2492,04 I56,3 5669~'25 10..%8,67 49,41 247,22 -4161,05 -9497,10 10~$8,67 246,34 1,08 127!8.10 226,i *)35.71 10540,82 49,82 247,87 -4,~..6,82-9656,24 10540,83 246.36 0.28 THE LAST SLIF;V~ IS PROJP. CTSI) 12821,00 102,? 6102,10 1061%41 ';' 4. ,8,- 247,87 '-4256,44 -9729,07 10619,42 246,37 0,0.., i 'IC OFIL ED lib - SURFACE DIRECTIONAL SURVEY ~'~ UIDANCE ~-~ ONTINUOUS F~ OOL Anchorage Company ARCO ALASKA, INC. WeliName 2T-21 (83' FNL, 556' FWL, SEC 12, Field/LocatiOnKUPaRUK, NORTH SLOPE, ALASKA TllN, R8E) Job Reference No. 95083 Loqqed BV: ORIGINAL Date 27-FEB-1995 Computed By- BAILEY KOHRING SCHLUMBERGER OCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE' 27-FF__.B-95 ENGINEER' BAILEY METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORZZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 66 DEG 18 MIN WEST COMPUTATION DATE: 13-MAR-95 PAGE I arco ALASKA, INC. 2T-2i KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 27-FEB-95 KELLY BUSHING ELEVATION' 122.00 FT , ENGINEER' BAILEY 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. DEPAR'DJRE SECTION SEVERITY NORTH/SOLFFH EAST/WEST DIST. AZI~LFTH FEET DEG/iO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 DO 800 O0 900 O0 0 O0 -122 O0 99 98 -22 199 98 77 299 94 177 399 57 277 498 67 376 597 01 475 694 58 572 790 52 668 884 59 762 0 0 N 0 0 E 02 0 7 N 48 41W 98 0 28 S 80 15 W 94 3 17 S 49 17 W 57 6 12 S 50 39 W 67 9 18 S 54 35 W O1 11 18 S 57 51W 58 14 16 S 60 25 W 52 18 15 S 61 10 W 59 21 30 S 61 4 W 0 O0 -0 09 0 35 2 87 10 94 23 85 41 70 63 40 91 39 125 11 0 O0 0 O0 0 01 0 O4 0 O2 0 O4 0 O2 0 O4 0 O3 0 04 0 O0 N 0 O0 N 0 O1 S 1 36 S 6 81 S 14 88 S 24 90 S 36 11 S 49 77 S 000 E 0 10 E 0 38W 2 54 W 8 96 W 19 51 W 34 61 W 53 39 W 77 97 W 66 0 O0 N 0 0 E 10 S 107 0 0 2 11 24 42 64 92 62 W 126 10 N 88 52 E 38 S 88 36 W 88 S 61 52 W 26 S 52 47 W 54 S 52 4O W 63 S 54 16 W 45 S 55 56 W 50 S 57 27 W 30 S 58 26 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 976 55 O0 1066 O0 1155 O0 1242 O0 1327 O0 1410 O0 1490 O0 1567 O0 1641 O0 1710 854 55 24 35 63 944 50 1033 72 1120 82 1205 54 1288 85 1368 81 1445 20 1519 45 1588 S 62 27 W 63 26 27 S 64 6 W 50 28 22 S 65 6 W 72 30 22 S 65 54 W 82 32 58 S 66 29 W 64 35 0 S 67 18 W 85 38 13 S 67 28 W 81 41 16 S 67 34 W 20 44 35 S 67 28 W 45 47 36 S 67 20 W 164 23 207 59 253 40 302 30 354 80 410 83 470 51 534 33 602 21 674 32 0 O3 0 O1 0 O2 0 O3 0 03 0 03 0 O3 0 O3 0 O3 0 O2 84 77 S 142 15 W 165 50 S 59 11W 104 123 144 165 187 210 234 260 288 24 S 180 94 S 222 19 S 266 38 S 314 33 S 366 25 S 421 71S 480 65 S 543 33 S 6O9 95 W 208 33 W 254 85 W 303 88 W 355 44 W 411 55 W 471 52 W 534 26 W 602 86 W 674 83 S 60 3 W 54 S 60 52 W 31 S 61 37 W 67 S 62 17 W 55 S 62 55 W 07 S 63 3O W 77 S 63 58 W 56 S 64 22 W 58 S 64 42 W 2000 O0 1776 09 1654 09 50 20 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1837 O0 1896 O0 1950 O0 2000 O0 2046 O0 2088 O0 2125 O0 2161 O0 2198 94 1715 13 1774 37 1828 70 1878 81 1924 31 1966 11 2003 45 2039 45 2076 94 53 18 13 55 27 37 58 31 70 60 58 81 63 52 31 67 4 11 68 52 45 68 33 45 68 2 S 67 11W S 66 28 W 828 S 66 12 W 909 S 65 4 W 993 S 63 58 W 1079 S 63 26 W 1168 S 62 50 W 1259 S 62 19 W 1352 S 62 18 W 1445 S 62 16 W 1537 749 74 3O 61 6O 95 59 40 18 11 79 0 O2 0 O2 0 O3 0 O3 0 O4 0 O3 0 O4 0 O0 0 O1 0 O1 317 52 S 679 41 W 749 95 S 64 57 W 348 381 415 453 492 533 576 619 663 35 S 751 09 S 826 70 S 902 02 S 980 35 S 1060 59 S 1141 50 S 1223 84 S 1306 05 S 1388 67 W 828 10 W 909 64 W 993 56 W 1080 09 W 1168 17 W 1259 66 W 1352 12 W 1445 37 W 1538 47 S 65 8 W 77 S 65 14 W 76 S 65 16 W 15 S 65 12 W 85 S 65 5 W 76 S 64 56 W 66 S 64 46 W 74 S 64 37 W 57 S 64 28 W 3000 O0 2236 54 2114 54 67 15 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2275 O0 2316 O0 2356 O0 2396 O0 2435 O0 2472 O0 2508 O0 2542 O0 2578 96 2153 22 2194 64 2234 31 2274 57 2313 43 2350 36 2386 87 2420 17 2456 96 66 29 22 66 1 64 66 35 31 66 26 57 67 54 43 68 31 36 69 42 87 69 38 17 68 58 S 62 11W 1630 O1 S 62 8 W 1721 S 62 8 W 1812 S 64 1W 1904 S 64 33 W 1996 S 64 45 W 2087 S 65 1W 2180 S 66 5 W 2274 S 66 22 W 2368 S 66 4 W 2461 67 96 25 O0 92 85 16 O1 58 0 O1 0 O0 0 O0 0 03 0 O0 0 02 0 O0 0 02 0 O0 0 O1 706 14 S 1470 17 W 1630 96 S 64 21 W 749 791 833 873 912 952 991 1028 1066 08 S 1551 90 S 1632 79 S 1713 35 S 1796 83 S 1879 23 S 1963 11S 2048 74 S 2134 46 S 2220 42 W 1722 33 W 1814 63 W 1905 47 W 1997 52 W 2089 72 W 2182 55 W 2275 54 W 2369 16 W 2453 80 S 64 14 W 28 S 64 7 W 71 S 64 3 W 50 S 64 4 W 47 S 64 6 W 42 S 64 8 W 71 S 64 11W 50 S 64 16 W O1 S 64 21W ARCO ALASKA, INC. 27-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE: 13-MAR-95 PAGE 2 DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT , ENGINEER: BAILEY INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTN DEPTH DEPTH DEG MIN DEG MIN 4000 O0 2614 48 2492.48 68 30 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2651 O0 2689 O0 2725 O0 2761 O0 2797 O0 2834 O0 2871 O0 2910 O0 2949 60 2529.60 67 53 69 2567.69 67 42 85 2603.85 69 30 20 2639.20 69 2 39 2675.39 68 39 15 2712.15 68 10 85 2749.85 67 35 65 2788.65 66 50 66 2827.66 67 9 5000 O0 2988 20 2866 20 67 29 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3026 O0 3062 O0 3098 O0 3133 O0 3168 O0 3203 O0 3242 O0 3281 O0 3320 17 2904 81 2940 33 2976 65 3011 68 3046 86 3081 11 3120 62 3159 71 3198 17 68 1 81 68 57 33 69 18 65 69 18 68 69 33 86 69 5 11 66 36 62 66 49 71 67 10 6000 O0 3359 25 3237 25 67 35 6100 6200 6300 6400 6500 6600 6700 68O0 6900 O0 3397 11 3275 O0 3434 35 3312 O0 3470 91 3348 O0 3507 26 3385 O0 3542 93 3420 O0 3579 13 3457 O0 3615.45 3493 O0 3651.49 3529 O0 3688.56 3566 11 67 56 35 68 21 91 68 32 26 68 57 93 69 11 13 68 35 45 68 49 49 68 35 56 68 8 7000 O0 3725 72 3603 72 68 12 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 3763 O0 3800 O0 3838 O0 3875 O0 3911 O0 3949 O0 3988 O0 4026 O0 4065 26 3641 79 3678 11 3716 10 3753 70 3789 67 3827 59 3866 71 3904 18 3943 26 67 54 79 68 2 11 68 8 10 68 27 70 68 34 67 66 51 59 67 20 71 67 35 18 67 29 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/1OO FEET FEET FEET DEG S 65 48 W 2554 75 S 65 24 W 2647 59 S 65 18 W 2740 04 S 66 10 W 2833 26 S 65 55 W 2926 S 65 30 W 3020 S 65 11W 3113 S 64 50 W 3205 S 64 30 W 3297 S 64 25 W 3389 81 02 01 60 74 76 0 O1 0 O1 0 O2 0 O0 0 O1 0 O0 0 O1 0 O1 0 O1 0 O1 1104 46 S 2305 23 W 2556 15 S 64 24 W 1142 1181 1219 1257 1296 1334 1373 1413 1453 81S 2389 44 S 2473 69 S 2558 65 S 2644 O4 S 2729 82 S 2813 93 S 2897 35 S 2981 10 S 3064 79 W 2648 80 W 2741 82 W 2834 31W 2928 26 W 3021 79 W 3114 74 W 3206 06 W 3299 99 S 64 27 W 44 S 64 28 W 64 S 64 31W 15 S 64 34 W 36 S 64 36 W 35 S 64 37 W 96 S 64 38 W 13 S 64 38 W 11W 3391.21 S 64 38 W S 64 27 W 3481 99 S 64 50 W 3574 S 66 18 W 3667 S 66 20 W 3760 S 66 17 W 3854 S 66 9 W 3948 S 65 58 W 4041 S 67 31W 4134 S 67 29 W 4226 S 67 31W 4318 45 49 97 52 18 79 16 01 03 0 O0 0 02 0 O1 0 O1 0 O0 0 O1 0 03 0 O0 0 O0 0 O0 1492 97 S 3147 33 W 3483.48 S 64 37 W 1532 1571 1608 1646 1683 1722 1758 1793 1828 78 S 3230 04 S 3315 59 S 3401 21S 3486 96 S 3572 11S 3658 36 S 3743 53 S 3827 75 S 3912 83 W 3575.99 S 64 37 W 65 W 3669.02 S 64 39 W 25 W 3762.45 S 64 41 W 91 W 3855 97 S 64 44 W 62 W 3949 60 S 64 46 W 10 W 4043 19 S 64 47 W 07 W 4135 51 S 64 50 W 94 W 4227 28 S 64 54 W 98 W 4319 23 S 64 57 W S 67 35 W 4410 28 S 67 35 W 4502 S 67 31W 4595 S 67 20 W 4688 S 67 48 W 4781 S 67 45 W 4875 S 67 7 W 4968 S 67 10 W 5061 S 66 22 W 5154 S 65 8 W 5247 81 6O 66 8O 19 39 55 82 69 0 O1 0 O0 0 O1 0 O1 0 O0 0 01 0 O0 0 O0 0 O3 0 O0 1864 O1S 3998 25 W 4411 41 S 65 0 W 1899 1934 1970 2006 2041 2077 2113 2150 2188 31S 4083 79 S 4169 50 S 4255 12 S 4341 39 S 4428 32 S 4514 52 S 4599 O1S 4685 52 S 4770 81W 4503 57 W 4596 53 W 4689 60 W 4782 11W 4876 13 W 4969 98 W 5062 82 W 5155 33 W 5248 87 S 65 3 W 60 S 65 6 W 60 S 65 9 W 68 S 65 12 W O1 S 65 15 W 16 S 65 17 W 29 S 65 19 W 53 S 65 21W 40 S 65 21W S 64 40 W 5340 50 S 63 19 W 5433 $ 63 18 W 5525 $ 63 14 W 5618 S 63 11W 5711 S 63 8 W 5804 S 62 8 W 5896 S 61 57 W 5988 S 62 23 W 6080 S 63 41W 6172 10 66 31 O7 O0 31 17 35 53 0 O2 0 O0 0 O1 0 O0 0 oo 0 O1 0 O0 0 O1 0 03 0 O1 2227 77 S 4854 47 W 5341 24 S 65 21W 2268 2310 2352 2393 2435 2478 2521 2565 2606 69 S 4937 36 S 5020 04 S 5103 96 S 5186 97 S 5269 51S 5351 73 S 5432 18 S 5514 54 S 5596 63 W 5433 89 S 65 19 W 42 W 5526 52 S 65 17 W 31W 5619 24 S 65 15 W 22 W 5712 08 S 65 13 W 26 W 5805 09 S 65 11 W 41 W 5897 50 S 65 9 W 75 W 5989 48 S 65 6 W 35 W 6081.79 S 65 3 W 87 W 6174.05 S 65 2 W COMPUTATION DATE: 13-MAR-95 PAGE 3 ARCO ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 27-FF__B-95 KELLY BUSHING ELEVATION' 122.00 FT ENGINEER' BAILEY INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTN DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 4103 06 3981 06 68 2 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4140 O0 4177 O0 4215 O0 4252 O0 4290 O0 4327 O0 4364 O0 4400 O0 4437 11 4018 97 4055 60 4093 99 4130 21 4168 25 4205 28 4242 99 4278 55 4315 11 68 10 97 67 38 60 68 7 99 68 7 21 68 11 25 68 18 28 68 19 99 68 24 55 68 44 S 63 37 W 6264 98 S 63 48 W 6357 S 64 33 W 645O S 64 29 W 6542 S 64 32 W 6635 S 64 34 W 6728 S 64 37 W 6821 S 64 45 W 6914 S 64 41W 7007 S 64 33 W 7100 76 26 87 57 34 19 O4 03 O6 0 O1 0 02 0 O0 0 O0 0 O0 0 O0 0 O0 0 O1 0 O1 0 O1 2647 63 S 5679 79 W 6266 58 S 65 0 W 2688 2728 2768 2808 2848 2888 2928 2967 3007 92 S 5762 99 S 5846 86 S 5930 77 S 6013 65 S 6097 52 S 6181 24 S 6265 93 S 6349 83 S 6433 99 W 6359 42 W 6451 06 W 6544 78 W 6637 58 W 6730 48 W 6823 45 W 6915 58 W 7008 67 W 7102 43 S 64 59 W 98 S 64 59 W 63 S 64 58 W 37 S 64 58 W 18 S 64 58 W 07 S 64 57 W 96 S 64 57 W 98 S 64 57 W 06 S 64 57 W 9000 O0 4473.62 4351 62 69 9 9100 9200 9300 9400 9500 9600 970O 9800 9900 O0 4509.35 4387 O0 4544.97 4422 O0 4580.91 4458 O0 4618.39 4496 O0 4655.43 4533 O0 4691.44 4569 O0 4727.92 4605 O0 4764.83 4642 O0 4803.29 4681 35 69 2 97 69 14 91 68 13 39 67 54 43 68 37 44 68 53 92 68 28 83 68 4 29 66 19 S 64 25 W 7193 28 S 64 23 W 7286 S 64 20 W 7380 S 64 2 W 7473 S 63 49 W 7565 S 63 35 W 7658 S 63 7 W 7751 S 62 17 W 7844 S 61 15 W 7937 S 62 12 W 8029 63 O1 27 90 69 86 78 43 38 0 O0 0 O0 0 O0 0 02 0 O1 0 O1 0 O1 0 O1 0 O1 0 O6 3048 11 S 6517 79 W 7195 32 S 64 56 W 3O88 3128 3169 3210 3251 3293 3335 3379 3424 49 S 6602 90 S 6686 56 S 6770 31S 6853 46 S 6936 26 S 7020 99 S 7102 92 S 7184 26 S 7265 02 W 7288 26 W 7382 25 W 7475 53 W 7568 80 W 7661 2O W 7754 93 W 7847 83 W 7940 79 W 8032 72 S 64 56 W 15 S 64 55 W 46 S 64 55 W 16 S 64 54 W 02 S 64 53 W 28 S 64 52 W 32 S 64 51W 13 S 64 48 W 26 S 64 46 W 10000 O0 4845 28 4723 28 64 45 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 4887 O0 4929 O0 4969 O0 5006 O0 5042 O0 5077 O0 5112 O0 5148 O0 5186 70 4765 44 4807 67 4847 68 4884 60 4920 57 4955 22 4990 64 5026 19 5064 70 65 15 44 65 18 67 67 39 68 68 39 60 69 17 57 69 39 22 69 55 64 67 42 19 68 12 S 63 41W 8120 02 S 65 38 W 8210 S 66 8 W 8301 S 65 45 W 8392 S 65 27 W 8485 S 65 19 W 8579 S 65 15 W 8672 S 65 17 W 8766 S 65 56 W 8859 S 65 46 W 8952 51 38 92 81 12 8O 58 7O 38 0 O1 0 04 0 O1 0 02 0 O0 0 O1 0 O0 0 O0 0 O1 0 O1 3464 73 S 7347 O1 W 8122 99 S 64 45 W 3504 3540 3578 3616 3655 3694 3733 3772 3810 15 S 7428 87 S 7511 14 S 7595 56 S 7679 44 S 7764 63 S 7849 88 S 7934 23 S 8019 13 S 8104 53 W 8213 65 W 8304 26 W 8395 84 W 8488 68 W 8582 78 W 8675 98 W 8769 83 W 8862 41W 8955 53 S 64 45 W 38 S 64 46 W 90 S 64 46 W 78 S 64 47 W 10 S 64 47 W 79 S 64 48 W 59 S 64 48 W 70 S 64 49 W 37 S 64 49 W 11000 O0 5222 91 5100 91 68 44 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 5258 O0 5292 O0 5327 O0 5364 O0 5401 O0 5437 O0 5476 O0 5522 O0 5570 55 5136 74 5170 02 5205 96 5242 83 5279 41 5315 43 5354 16 5400 55 5448 55 69 31 74 70 33 02 68 7 96 67 56 83 68 52 41 68 29 43 65 17 16 61 19 55 61 o S 65 42 W 9045 39 S 65 40 W 9138 S 65 43 W 9232 S 65 52 W 9326 S 65 36 W 9419 S 65 28 W 9512 S 65 8 W 9605 S 64 46 W 9697 S 65 7 W 9786 S 65 19 W 9874 81 78 71 22 17 61 63 51 O1 0 O1 0 0 0 0 0 0 0 0 0 3848 37 S 8189 20 W 9048 37 S 64 50 W O1 '3886 O1 3925 04 3964 02 4002 02 4040 05 4079 07 4119 02 4157 O0 4193 90 S 8274 59 S 8359 28 S 8445 27 S 8529 84 S 8614 83 S 8699 34 S 8782 17 S 8863 69 S 8942 32 W 9141 95 W 9235 55 W 9329 91W 9422 48 W 9515 42 W 96O8 57 W 9700 03 W 9789 56 W 9877 79 S 64 5O W 75 S 64 51 W 67 S 64 51 W 18 S 64 52 W 13 S 64 52 W 59 S 64 52 W 64 S 64 52 W 55 S 64 52 W O7 S 64 53 W COMPUTATION DATE: 13-MAR-95 PAGE 4 ARCO ALASKA, INC. 27-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT , ENGINEER: BAILEY INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH ]-RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERI-rY NORTH/SOLFFH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG 12000 O0 5619 61 5497 61 59 37 12100 1220O 12300 12400 '12500 12600 12700 12800 12821 O0 5671 O0 5727 O0 5786 O0 5850 O0 5915 O0 5980 O0 6046 O0 6111 O0 6124 60 5549 39 5605 90 5664 53 5728 51 5793 87 5858 02 5924 12 5989 79 6002 60 57 0 39 54 45 90 51 50 53 49 41 51 49 22 87 49 8 02 49 23 12 49 23 79 49 23 S 65 14 W 9961 13 S 65 16 W 10046 52 S 65 32 W 10129 49 S 66 19 W 10209 84 S 67 1W 10286 97 S 66 50 W 10362 98 S 66 21W 10438 66 S 66 9 W 10514.51 S 66 9 W 10590.42 S 66 9 W 10606.37 0 02 0 04 0 04 0 05 0 01 0 0 0 0 0 01 O1 O0 O0 O0 4230 14 S 9021 71 W 9964 20 S 64 53 W 4266 4300 4333 4364 4393 4423 4454 4485 4491 11S 9099 91S 9174 94 S 9247 17 S 9318 98 S 9388 93 S 9458 55 S 9527 26 S 9596 71S 9611 17 W10049 50 W10132 76 W10212 72 W10290 64 W10365 14 W10441 54 W10517 97 W10593 55 W10609 61 S 64 53 W 59 S 64 53 W 93 S 64 53 W 02 S 64 54 W 98 S 64 55 W 63 S 64 56 W 46 S 64 57 W 36 S 64 57 W 30 S 64 57 W COMPUTATION DATE: i3-MAR-95 PAGE 5 arco ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT ' ENGINEER: BAILEY INTERPOLATED VALUES FOR EVEN 1OO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEP'~H 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 0 oo 1000 2000 3000 4000 5000 6000 7O0O 8000 9000 0 O0 -122 O0 O0 976 O0 1776 O0 2236 O0 2614 oo 2988 O0 3359 O0 3725 O0 4103 O0 4473 0 0 55 854 09 1654 54 2114 48 2492 20 2866 25 3237 72 3603 06 3981 62 4351 55 24 35 09 50 20 54 67 15 48 68 30 2O 67 29 25 67 35 72 68 12 O6 68 2 62 69 9 N 0 0 E S 62 27 W 164 S 67 11W 749 S 62 11W 1630 S 65 48 W 2554 S 64 27 W 3481 S 67 35 W 4410 S 64 40 W 5340 S 63 37 W 6264 S 64 25 W 7193 0 O0 23 74 O1 75 99 28 5O 98 28 0 O0 0 O3 0 O2 0 01 0 O1 0 O0 0 O1 0 O2 0 O1 0 O0 0 O0 N 84 317 706 1104 1492 1864 2227 2647 3048 77 S 142 52 S 679 14 S 1470 46 S 2305 97 S 3147 O1S 3998 77 S 4854 63 S 5679 11S 6517 15 W 165 41W 749 17 W 1630 23 W 2556 33 W 3483 25 W 4411 47 W 5341 79 W 6266 79 W 7195 0 O0 E 0 O0 N 0 0 E 50 S 59 11W 95 S 64 57 W 96 S 64 21W 15 S 64 24 W 48 S 64 37 W 41 S 65 0 W 24 S 65 21W 58 S 65 0 W 32 S 64 56 W 10000.00 4845.28 4723.28 64 45 11000.00 5222.91 5100.91 68 44 12000.00 5619.61 5497.61 59 37 12821.00 6124.79 6002.79 49 23 S 63 41W 8120.02 S 65 42 W 9045.39 S 65 14 W 9961.13 S 66 9 W 10606.37 0.01 0.01 0.02 0.00 3464.73 S 7347.01W 8122.99 S 64 45 W 3848.37 S 8189.20 W 9048.37 S 64 50 W 4230.14 S 9021.71 W 9964.20 S 64 53 W 4491.71S 9611.55 W10609.30 S 64 57 W ARCO ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE' 13-MAR-95 PAGE 6 DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT , ENGINEER: BAILEY INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEP'll-I 0 O0 122 02 222 02 322 11 422 57 523 67 625 51 728 37 833 24 940 39 1050 25 1022 O0 1162 1276 1393 1513 1639 1773 1917 2073 2246 DEPTH DEPTH DEG 0 O0 -122.00 122 O0 222 O0 322 O0 422 O0 522 O0 622 O0 722 O0 822 O0 922 O0 09 1122 06 1222 07 1322 91 1422 92 1522 27 1622 17 1722 53 1822 63 1922 DEG MIN 0 O0 100 200 300 400 500 600 700 800 0 0 N 0 0 E 0 10 N 75 3 W O0 0 39 S 74 51W O0 4 2 S 49 11W O0 6 45 S 51 27 W O0 9 58 S 55 31W O0 11 52 S 58 20 W O0 15 25 S 60 51 W O0 19 13 S 61 16 W O0 22 53 S 61 21 W 900 O0 25 54 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 0 O0 -0 05 0 56 4 22 13 39 27 74 46 76 70 62 102.01 140.28 S 63 24 W 185.64 O0 27 29 S 64 39 W 235.67 O0 29 43 S 65 44 W 290.30 O0 32 47 S 66 26 W 351.05 O0 35 23 S 67 22 W 418.85 O0 39 18 S 67 27 W 495.47 O0 43 34 S 67 32 W 583.63 O0 47 59 S 67 18 W 687.03 O0 52 39 S 66 44 W 807.16 O0 57 9 S 65 46 W 948.40 0 O0 0 O0 0 O1 0 04 0 O3 0 02 0 O3 0 04 0 O3 0 O3 0 O0 N 0 02 N 0 06 S 2 28 S 8 4O S 17 15 S 27 61S 39 66 S 54 90 S 73.45 S 120 0 O0 E 0 05 E 0 59 W 3 60 W 10 94 W 22 77 W 38 95 W 59 71 W 87 0.00 N 0 0 E 0.05 N 65 21E 0.59 S 84 25 W 4.26 S 57 41W 13.79 S 52 27 W 28.51 S 53 0 W 47.74 S 54 40 W 71.69 S 56 24 W 30 W 103.13 S 57 50 W 96 W 141.52 S 58 44 W 0 02 0 O3 0 O2 0 O3 0 O3 0 03 0 O4 0 03 0 03 0 04 94.53 S 161 24 W 186 91 S 59 37 W 116.40 S 206 139.27 S 255 163 88 S 311 190 43 S 373 219 83 S 444 253 53 S 526 293 23 S 621 339 95 S 732 396 87 S 861 28 W 236 91W 291 44 W 351 83 W 419 61W 495 09 W 583 59 W 687 28 W 807 54 W 948 85 S 60 34 W 35 S 61 27 W 93 S 62 15 W 54 S 63 0 W 99 S 63 41W 99 S 64 16 W 28 S 64 45 W 34 S 65 6 W 56 S 65 16 W 2445 03 2022 O0 1900 O0 62 30 2691 2962 3214 3464 3739 4020 4289 4567 4828 37 2122 18 2222 21 2322 61 2422 61 2522 46 2622 O0 2722 20 2822 96 2922 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 68 53 O0 67 32 O0 65 59 O0 66 57 O0 69 56 O0 68 24 O0 69 31 O0 68 21 O0 66 59 S 63 43 W 1119 59 S 62 20 W 1344 S 62 13 W 1595 S 62 10 W 1825 S 64 33 W 2055 S 66 26 W 2311 S 65 45 W 2573 S 66 10 W 2822 S 65 19 W 3082 S 64 25 W 3324 15 19 91 25 34 77 96 55 36 0 03 0 O0 0 O1 0 O0 0 02 0 O1 0 O1 0 O0 0 O1 0 O1 470 52 S 1016 16 W 1119 81 S 65 9 W 572 689 797 898 1006 1112 1215 1322 1424 76 S 1216 86 S 1439 96 S 1643 83 S 1849 07 S 2082 27 S 2322 52 S 2549 06 S 2786 84 S 3005 53 W 1344 29 W 1596 81W 1827 99 W 2056 60 W 2312 58 W 2575 39 W 2824 12 W 3083 10 W 3325 62 S 64 47 W 07 S 64 23 W 25 S 64 6 W 78 S 64 5 W 87 S 64 13 W 17 S 64 25 W 34 S 64 31 W 88 S 64 37 W 77 S 64 38 W 5088 89 3022 O0 2900 O0 67 56 5367 5648 5903 6166 6441 6718 6989 7256 7528 O0 3122 90 3222 32 3322 64 3422 16 3522 17 3622 99 3722 80 3822 02 3922 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 36O0 O0 3700 O0 3800 O0 69 21 O0 67 18 O0 67 10 O0 68 13 O0 69 5 O0 68 54 O0 68 14 O0 68 5 O0 68 16 S 64 41W 3564 16 S 66 17 W 3823 S 67 1W 4087 S 67 31W 4321 S 67 31W 4564 S 67 51W 4820 S 67 10 W 5078 S 64 49 W 5331 S 63 21W 5578 S 62 56 W 5830 64 19 09 62 22 49 21 27 O1 0 O1 0 O0 0 04 0 O0 0 O1 0 O0 0 O1 0 O1 0 O0 0 02 1528 39 S 3221.52 W 3565 69 S 64 37 W 1633 1740 1829 1922 2020 2120 2223 2334 2447 79 S 3458 64 W 3825 26 S 3699 92 S 3915 93 S 4140 63 S 4377 10 S 4615 80 S 4846 02 S 5067 79 S 5292 72 W 4088 80 W 4322 94 W 4565 19 W 4821 59 W 5079 06 W 5331 50 W 5579 48 W 5831 11 S 64 43 W 57 S 64 49 W 28 S 64 57 W 63 S 65 5 W 08 S 65 13 W 22 S 65 20 W 94 S 65 21W 18 S 65 16 W 13 S 65 11W COMPUTATION DATE: 13-MAR-95 PAGE 7 ARCO ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT , ENGINEER: BAILEY 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 7787 61 4022 O0 3900 O0 67 40 8050 8317 8585 8857 9135 9409 9683 9945 10182 99 4122 13 4222 80 4322 18 4422 42 4522 61 4622 89 4722 26 4822 20 4922 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 68 20 O0 68 2 O0 68 20 O0 68 37 O0 69 6 O0 67 53 O0 68 27 O0 65 0 O0 65 16 10442 32 5022 O0 4900 O0 68 54 10728 10997 11286 11556 11799 12004 12190 12355 12509 19 5122 49 5222 40 5322 71 5422 66 5522 74 5622 61 5722 69 5822 97 5922 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 69 25 O0 68 43 O0 68 42 O0 69 26 O0 61 19 O0 59 31 O0 55 8 O0 50 14 O0 49 20 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET PEG/lO0 FEET FEET FEET DEG MIN S 62 9 W 6068 92 S 63 34 W 6312 S 64 29 W 6558 S 64 36 W 6807 S 64 37 W 7060 S 64 23 W 7319 S 63 47 W 7574 S 62 25 W 7829 S 63 51W 8070 S 66 13 W 8285 27 75 99 18 70 79 83 52 22 0 02 0 01 0 01 0 O0 0 01 0 O0 0 01 0 01 0 02 0 01 2559 83 S 5504 21W 6070 34 S 65 4 W 2668 2775 2882 2990 3102 3214 3329 3442 3534 69 S 5722 71S 5944 86 S 6169 71S 6397 80 S 6631 24 S 6861 04 S 7089 87 S 7302 34 S 7496 19 W 6313 39 W 6560 56 W 6809 63 W 7062 85 W 7321 52 W 7577 65 W 7832 55 W 8073 86 W 8288 90 S 65 0 W 51 S 64 58 W 87 S 64 57 W 16 S 64 57 W 80 S 64 56 W 05 S 64 54 W 35 S 64 51W 45 S 64 45 W 22 S 64 46 W S 65 24 W 8525 25 S 65 27 W 8793 S 65 42 W 9043 S 65 48 W 9314 S 65 23 W 9565 S 65 7 W 9786 S 65 12 W 9965 S 65 24 W 10121 S 67 7 W 10253 S 66 54 W 10370 O3 05 07 16 21 22 8O 07 54 0 01 0 04 0 01 0 06 0 01 0 02 0 01 0 05 0 02 0 01 3632 97 S 7715 71W 8528 23 S 64 47 W 3744 3847 3959 4062 4157 4231 4297 4350 4396 91S 7959 41S 8187 10 S 8434 91S 8662 05 S 8862 85 S 9025 71S 9167 96 S 9287 95 S 9395 O1W 8796 07 W 9046 02 W 9317 67 W 9568 76 W 9789 42 W 9968 51 W10124 50 W10256 59 W10373 03 S 64 48 W 03 S 64 50 W 04 S 64 51W 13 S 64 52 W 26 S 64 52 W 29 S 64 53 W 90 S 64 53 W 14 S 64 54 W 54 S 64 55 W 12663.09 6022.00 5900.00 49 23 12816.72 6122.00 6000.00 49 23 12821.00 6124.79 6002.79 49 23 S 66 9 W 10486.49 S 66 9 W 10603.12 S 66 9 W 10606.37 O. O0 O. O0 O. O0 4443.21S 9501.92 W10489.45 S 64 56 W 4490.39 S 9608.58 W10606.05 S 64 57 W 4491.71S 9611.55 W10609.30 S 64 57 W ARCO ALASKA, INC. 2T-2i KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPLFFATION DATE: 13-MAR-95 PAGE 8 DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 ET , ENGINEER: BAILEY INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER DF TO GL (PARKER 245) GL RKB 9 5/8" CASING TOP KUPARUK C (CDR MD) BASE KUPARUK C (CDR MD) TOP KUPARUK A (CDR MD) BASE KUPARUK A (CDR MD) GCT LAST READING PBTD 7" CASING TD SURFACE LOCATION = 83'FNL A 556'FWL, SEC12 TllN RGE MEASURED DEPTH BELOW KB ]-VD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 41 O0 81 O0 122 O0 4772 O0 12390 O0 12426 O0 12426 O0 12624 O0 12643 66 12714 O0 40 98 80 98 121 98 2899 65 5844 06 5867 37 5867 37 5996 55 6009 35 6055 14 -81 02 -41 O2 -0 02 2777 65 5722 06 5745 5745 5874 5887 5933 37 37 55 35 14 0 07 S 0 03 S 0 02 N 1402 29 S 4361 19 S 4371 91S 4371 91S 4431 24 S 4437 27 S 4458 85 S 0 12 E 0 12 E 0 05 E 2957 80 W 9311 70 W 9336 95 W 9336 95 W 9474 78 W 9488 43 W 9537 26 W 12804.00 12821.00 6113.72 6124.79 5991.72 6002.79 4486.48 S 4491.71S 9599.75 W 9611.55 W COMPUTATION DATE: 13-MAR-95 PAGE 9 arco ALASKA, INC. 2T-21 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-95 KELLY BUSHING ELEVATION: 122.00 FT , ENGINEER: BAILEY **~****~**~ STRATIGRAPHIC SUMMARY MARKER SURFACE LOCATION = 83'FNL & 556'FWL, SEC12 TllN RSE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST DF TO GL (PARKER 245) GL RKB 9 $/8" CASING TOP KUPARUK C (CDR MD) BASE KUPARUK C (CDR MD) TOP KUPARUK A (CDR MD) BASE KUPARUK A (CDR MD) GCT LAST READING PBTD 41 O0 81 O0 122 O0 4772 O0 12390 O0 12426 O0 12426 O0 12624 O0 12643 66 12714 O0 40 98 80 98 121 98 2899 65 5844 06 5867 37 5867 37 5996 55 6009 35 6055 14 -81 02 -41 02 -0 02 2777 65 5722 06 5745 37 5745 37 5874 55 5887 35 5933 14 0 07 S 0 03 S 0 02 N 1402 29 S 4361 19 S 4371 91S 4371 91S 4431 24 S 4437 27 S 4458 85 S 0 12 E 0 12 E 0 05 E 2957 80 W 9311 70 W 9336 95 W 9336 95 W 9474 78 W 9488 43 W 9537 26 W 7" CASING TD 12804.00 12821.00 6113.72 6124.79 5991.72 6002.79 4486.48 S 4491.71S 9599.75 W 9611.55 W FINAL WELL LOCATION AT 70: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12821.00 6124.79 6002.79 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10609.30 S 64 57 W COMPANY ARCO ALASKA, INC. FIELD 2T-21 WELL i' KUPARUK RIVER UNIT COUNTRY USA RUN ONE DATE LOGGED 27-FEB-95 REFERENCE 95083 A interpretations are opinions based on inferences flom elecl~ical or other measurements and we cannot and do not c~uarantee the accuracy or correctness of any interpretations and we shall not, except in the case of gross or wilfull ~egligence on our parr. be liable or responsible for any loss ' costs damages or expenses ~curred or sus. ta. ined by anyone resulting from any interpretation made by any of our officers, agenfs or employees,/nese interpre~a[ions are also subiect to our General Terms and Conditions as set out in our current price Schedule. WELL: (83' 2T- 2~i FNL , 556 ' FWL, SEC 12, 'rWN llN, RNG SE) HORIZONTAL PROJECTION NC~TH 6000 4000 2OOO -2000 -4000 -6OO0 -8000 SOUTH -10000 REF 9S083 SCALE = I / 2000 ~NfF'r ~;..ii .~;..i-..i .... ;..4-..;..~.1.4--~ ...... LI.->---~--L-4 ..... ~---~--~ .... ;-L--i---~ ..... ~---,---~--4 ...... L--~-.4---~ ..... ~ ...... ;---~ ..... ,..-~-.~---~ ...... :---'--.-:.-.-: ...... >.--:...- ............ --.-:-...:.-..:'-. ..... :-: -!->-",-'- !i!'i !"i'i'! .... !i'i'-!--~"~-"~-"'!"i'; ..................... ~-,--~.-~,i!--~.--~--i--i---!--i-.!--.~-.i .... . i--.i.-i ............ ...... ~.-.?--~-.? ...... ~-.-~--~.i-ql-..i.--.i.:---i-.-i.i-.-!.ii.! .... !!-is ! : i-! -: s-! ~- ~ ; : ! t ~-!-: i ' : i-.i i i ~ !'i-i" ~"!-!'i I'i'~"i": I : i"i'"; .... i"i': i .... i'i : ! : :"' :' : ' , . : : - : · ~ I :;~ ~ii.i. ~iii ;-iii~ i;~; ~.;.~ }};: ~0oo i..~ii }.i;.~.,..;...;..;..;.. ;.}..¢...i..}.ii~.. ,~..}i-;i-i, ii} ~ ~i~ !:i! i"!!':.} '~' ~'~'i :.~,~;i " ':~ ~ 'i ":' ': : .... ."~. ~ :! ~ i'i':;, ;ii; .;!..; ;.i.i..! ..... !...i..i..!.[.;..;..i~t;..i;..;..i~;..~'.T;7?..i..; .... !.i-.i.-i-..i;-.-!-.i..i...i...i...i .... i...;.-.i..; .... i..;..i.i..,...;.;...~.; .... i.i:.-, i .... ;.Sk.i..-i.-,- ...... i i i..i.i ..... i.i.-.i ~ ..... ;-i-.~ . }-~0~0.-~ ..... 5 ~ i. -.i-..i.-;---; ;...5.} ..... }---i i.i ; ..... ;.4 ..... i-...~..i ........... i....i...5 ! ...... i ...... -~.!':';': ~;~i.~:~::'~":""':'":'":'":' ':~=:';':'":" nz~°°'1''';':'-'~':IIi:I; ...... .~;:~':'"' ..... !!:"~"~'"; .... ~"~'":"~;,! ...... :5!:;~ ...... .......... :'"~":'"~!i .... ::~;:~ ..... ;""+"+:;. .... :"~-i; .... ,":":'":1-:";";":';;i : ':':: :": :' :::::i':i:': :'::':i"i':i'" : !'::i::;:: :': V::::::":: ]':::":; ':i:' :: : :.'i"i'71': '"i:::!:::i:::i::' :7 :::i:"7 :::T:::'i':'i::: :!:::i:::i:::i":'::i:::!'::!:!: ::"!::::':':;::":7:' t"~: r ; i ~ ' ' -:-~--:---~--I-i-,--:-i--;---:.--:--~--:--:-; ..... I~---i---;-~--i-.:.-:-i.t.-i-i--:.;-I .......... .... :~-.[ ..... ................ :--- ......... I ' -.:- :-;---:-i ..... ?:...:...i.i.!..;...; .... :--i-: .......... : ....... :-:--i ...... }--!--,---;--i ....... ,...i._,..! ....... ~.-.i---: ........... !-.~.--~ ..... ¢",--+ .... [ .... ; ........ t .................. : ,]ii~!-il- · : '- · :: : ::- ' .... :: : :::: : ..... ' . .............. : ........ ~ .... ' ........ . ........ ~'";'-i!'!-:-i---i'-i!:';---: ....... :-?"~'": .......... ~-: .... : ,-~---!-i.-i--~-i--i ::~i-i~.:i!i ,.,.-i ...... i-i-i .... !,-:-:i.-.~---I;i-:-.?.-i-:.;~-".:: ' ~ : ~'; i~i!' ~'i'; tii'i:,'!i~: ;~!; !i';i '!!;;i !'!:';" ii":': i,_; ' . : : ! .: !..!-i ,.:..!.!.-: i..i i . .'..i..: .... i : i. ;.: ~ '.!.}.!..i...i., i.L.:.:.~ i.: : .... !.~.~.~ : ..... . i '':: :'"! ..... !'!'i! ~'!"!i .... !'"i!'~! ~i~i'-!':':"~ i'!i'!'.T'i"!i '!'"! ...... i:'''~ ....................... , ~i.i i.i-..i..ii;..-ii.i.i.i.;.~ .i~.;: ~..;..i i.i~.i.;..i..i..:..i..i..i..: ..... ~.i..;.!..;..;...i;'.i.;..i..~...i..~.: .~.;.! :;i.i;i~ .... -12000 · vNqE ~T - 10000 -8000 -6000 -4000 -2000 0 2000 4000 EAST ,~ELL: (83' 2T-21 FNL, 556'. FWL, SEC 12, TWN liN, RNG 8E) VERTICAL PROJECTIOn, -2000 0 0 2000 4000 6000 8000 10000 12000 · ~ L 'i ~iO'6'oXi';";'";"'! I- . .... ~.. ~ --?~ ......... ~., .......... ~.~...~...~..~..~..~..~.,]~;~~~ ~..~..~.~...k~ ..... ~..~..~..~ ..... ~..~..~.~ ...... ~..~..~: ..... ~..~..~ ..... ~..~..~ ..... / ~. ~-~-~- ~ ~ ~ :~--~-~-.~ .... ~. ~.--; .~... ~..~-.-~. ~; ..... ~-k-:.-; ...... ~--.;-.: 4 ..... ;-.~-..~-.-; ..... ~..-?~..?- ~..~...~...;.-~ 4.. ;..~...~...;.--k~...}...?....~ .......... }.~ ...}...}...~...~ ~..-~-.-}. ~-. ~ ~ ' ~: "~ ......... ~ .......... ~",'" ';'"~"]"?"?"'~"~ "T ...... ;"~ ...... ?"~' .... "'~"~"~"~ '~";'~;?"?'"~"~'"; ..... ~"~ ..... -~ ~'"~ ....... ~"~ .... ~ ; : ': ; '~ ~':'~ 7'~ 'T': i"7"~ ~"~ "~ 'T"7";' ~ ; : ; ~ '~ ; ;' ': ~ ~ ~ '"??"7'~"'~ ~ 7'? ........... ?'T'"f ..... ;"';'"7'?''r'?'':'?''; .... ~'? .... ...... "; '"~ ; :'~ .;. /:~;~ ~... _~ J : : ~8000 : : 12000, ~ ] : ~ : ~ : . ~ ' ~ ~ ; : : · : : : 2 ] 2 : ; ~ . ~ . 2 ] : . =~: :~ .~.-.~ ~--~...~.~..~...~-..~.?..~.~.-~--;. ..~....~ ...... ~ .~ ;~ .~ ~ ................... . ...................... ~. ...... ;. ....... . ...... ~ ..... , , , , . , , . 14000 24~.0 PROJECTION ON VERTICAL PLANE 6G.O- 246.0 SCALED IN VEF:ITICAL DEPTHS HORIZ SCALE = I / 2000 IN/FT ARCO Alaska, Inc. Date' April 7, 1995 Transmittal #: 9222 RETURN TO: ARGO Alaska, Inc. ~,-"~ttn' Bdan Hebert Kuparuk Records Clerk AT©-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-21 Sub-Surface Directional 2/27/95 Survey ,ece, , Acknowledged' ,4/ DISTRIBUTION: ref# 95083 D&M Date' State of Alaska (2 copies) RECEIVED APR 1 I ~995 AJaska 0il & Gas Cons. Commis_s[o_n' Anchorage ) ) ARCO Alaska, Inc. Date: March 24, 1995 RETURN TO: ~~ ~". Transmittal #: 9216 ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk A TO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. q Lf-15~1 R-33 COR Final Print 12/28/94 Q'4- t b ~ 1 R-34 CDR Final Print 1/13/95 'GJ5-' 13 '2T-21 CDR Depth Corrected Feb16-21/95 . c¡~~/3 2T-21 CDN Depth Corrected Feb16~21/95 c¡q-IJfb1R-32 Slim GR MWD Depth Corrected Oec11-14/94 GS--/O2Z-23 CDR Depth Shifted F'eb7-10/95 1 2Z-23 CDN Depth Shifted, Feb7-10/95 , , ~Z-22; CDR Depth Shifted ' Feb1-4/95 Qt¡""/7(2Z-22 ~.N 9~ ~hi~ "~ Feb1-4/95 Acknowledged: /(J ,c/ / ~~ Date: ~: Mr. Vernon E Pringle, Jr. (Geology) DeGloyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon Allsup-Drake OS Development A TO-1205 Erickso nIZuspan NSK Central Files NSK 69 "Larrÿ Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 , \ ,." .. " r . Ref#95009 Ref#95060 Ref#95077 Ref#95077 Ref#95024 Ref#50-029-22544 Ref#50-029-22544 Ref#50-029-22524 Ref#50-029-22524 RECEIVED MAR 3 0 1995 Clifton Posey Ge.61øsItQ Oil & Gas Cons. CommIssIon A TO 1251 Anchorage Sandy Lemke ATO 1336 ,," "'I".r 'I'r"',.",~,<". ARCO Alaska, Inc. RECEIVED MAR I 4 1995 Alaska 0il & 6as Cons. Commission Anchorage Date: March 10, 1995 Transmittal #: 9207 RETURN TO' ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-21 Ultrasonic Imager 2/25/95 1 0980-12780 Corrosion Log USlT 2T-21 Ultrasonic Imager 2/25/95 1 0980-I 2780 Cement Log USlT 2T-21 Cement Bond Log CBTE 2/26/95 1 0980-1 2780 2T-21 Conitnuous Gyro Survey GCT 2/26/95 0-12650 -- ,, ),.~/~ ~ . Receipt Acknowledge' DISTRIBUTION' RECEIVED Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 ALASKA OIL AND GAS CONSERVATION CO~IMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 13, 1995 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 'i ~-812 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2T-21 ARCO Alaska Inc 95-13 83'FNL, 556'FWL, Sec 12, T11N, R8E, UM 922'FSL, 1372'FWL, Sec 10, T11N, R8E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you frgm obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. : Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting~he-Gemmi~$ion_p_etroleum field inspector on the North Slope pager at 659-3607. bu rs..v~e ry tr, uly;-- I _= ~ .l ' ........................ ' David W Johnst?n '~ . ;: lo:; ; i::{ OF TH~~'OMC M|ISION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-'] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry E] Deepen E] Service E] Development Gas E] Single Zone X Multiple Zone r~ 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25568, ALK 2666 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 83' FNL, 556' FWL, Sec. 12, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1042' FSL, 1645' FWL, Sec. 10, T11N, RSE, UM 2T-21 #U-630610 At total depth 9. Approximate spud date Amount 922' FSL, 1372' FWL, Sec. 10, T11N, R8E, UM 2/1 5/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-1 7 12881' MD 922' ~ TD feet 60' ~ 300' MD feet 2560 6134' TVD feet 16. To be competed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 68.2° Max~msur~ace 1 71 3 ps~g At tolaJ depth (TVD) 3 1 50 pslg 18. Casing program Setting DeDth size Specifications Top Bottom QuanlJty of cement Hole Casinc~ Welt, Iht Grade Couplin~ Length MD TVD MD TVD (include sta(:,le data~ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +P00 CF 12.25" 9.625" 36.0# J-55 BTC 4740' 41' 41' 4781' 2893' 810 Sx Arcticset III & HF-ERW 740 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 12840 41' 41' 12881' 6134' 250SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True VerticaJ depth Structural sCu°r~dacU:t°rR E ¢ E IV E D Intermediate Production F EI3 - 8 1995 Liner Perforation depth: measured Aia~k~l. 0il & Gas Cons. Commission true vertical ,J~lchor~ '3 20, Attachments Filing fee X Property piat E] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25,050 requirements X 21. I hereby certify that the f ~regoing is true and correct to the best of my knowledge Signed ~[J~ ~p~r"~)( CommissionTitleuse OnlyDrill Site Development Supv Date ~.(//~ Permit Number I ' I 7'?- Is" c°v"r'"""''°r ~,~--//.5~ 5 0-/~" ~C:::) .~ / ~ other rec~uirements Conditions of approval Sampies required E] Yes ~]~ No - ~udlo~r~quired [] Yes j~ No Hydrogen sulfidemeasures [] Yes ,~ No Directional survey required 1~ Yes E] No Required working pressure forBOPE E] 2M ~L 3M r'~ 5M C~] 1OM F'~ 15M Other:Original Signed By David W. Johnston by order of ~// /~' Approved by Commissioner the commission Date/._,. Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2T-21 . . , . . . , , 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,781')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12,881') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED FEB -8 1995 Alaska Oil & Gas Cons. Commission Anchr~r~,r,e DRILLING FLUID PROGRAM Well 2T-21 Spud to 9-5/8" surface casing . Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,713 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2T-21 is 2T-17. As designed, the minimum distance between the two wells would be 60' @ 300' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 2T-21 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED ICreoted by · jones For: D PETRASH Date plotted : 1-Feb-95 Plot Reference is 21 Version #6. ICoordnates ore in feet reference slot #21. iTrue Ve~lical Depths are reference wellhead. Baker Hughes INTEQ iARC0 ALASKA, Structure : Pad 2T Well : 21 Field : Kuparuk River Unit Location : North Slope, Alaska < - - W e s ± Scale 1 : 250.00 9500 9000 8500 8000 750'07000 6500 6000 5500 5000 4500 4000 3500 ,30002500 2000 1500 1000 500 0 500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I II II TARGET LOCATION: I 1042'FSL, 1645' FWL SEC.10,TllN,RSE TARGET TM0=124-91 DEP=10342 SO~ 4155 TD LOCAI~ON: WES¥ 9471 922' FSL, 1372' FWL SEC 10 TllN 500 1000 ~5oo_ 200Q 2500. - 3000_ 3500_ _ 4000_ - 4500_ - 5000_ 5500_ 6000_ 6500 ESTIMA]I~ RK~ ELEVA'fIO~h 123,' KOP TVD=500 TMD-;.~O DEP-O §.o0 BL~LD 3 OEO / 10<7 ESTIMATED SURFACE LOCATION: 83' FNL, 556' F'WL SEC. 12. 111N, RSE S 66.31 DEG W 103 2' (TO TARGET) B/ PERMAFROST TVD=1503 TMO=1601 0EP=427 +2.O0 T/ UGNU SNDS 3VD=1548 TMD=1660 DEP=464 54..o0 843.00 66.o0 ROG TVD-2073 TMD-2574 DEP=1201 T/ W SAK SNDS 'P¢D=2246 TMD=3039 DEP=1633 B/W SAK SNDSTVD=2673 TMD=4189 DEP=2700 9 5/8" CSG PT TVD=2893 1MD=4781 DEP=3251 K-lO 'fVD=3043 TMD-5185 DEP-3626 RECEIVED FEB -8 1995 Oil & Gas Cons. Commission Anchorage MAXIMUM ANGLE 68.21 DEG K-5 1'VD=4543 TMD=g226 DEP=73T/ BEGIN ANGLEDROP TVD=5418 TMD=11581DEP=g564 68.00 64.00 I:~OP 2 DE:O / lOft ~0.00 TARGET ANGLE TARGET - T/ ZONE C (EOD) TVI)=5883 TMD=Ig491 DEP=10342 ~.o0 r/ZONE ^ m:5~92 TUD:~2*O5 50 DEG T/,U SNr)S m-5~11 TU0-125.5 DEP-~O3~S-- B/ ~<UP SNDS 'm:~OOS TUO:12~Sl D~--10~88 'I'D / ?" CSG PT 'I'VD--8134 t I I I I I I I I I } I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Scale 1 : 250.00 Vedicol Section on 246..51 azimuth with reference 0.00 N, 0.00 E from slot #21 ICreated by : jones IDate plotted : 1-Feb-g5 IPIot Reference is 21 Version #6. iCoordinotes ore in feet reference slot #21, iTrue Vertical Depths are reference wellhead. .... Baker Hughes INTEQ ARCO ALASKA, Structure : Pad 2T Well: 21 Field : Kuparuk River Unit Location : North Slope, Alaska' cO.iO 280 ., ~) 2401 -- 120 120 160 200_ ~ - - W e s f ~o,~ ~: ~o.oo 760 720 680 640 600 560 520 480 440 400 360 D20 280 240 200 160 120 80 40 0 40 80 120 _ 240 " - _ 200 ~0 120 % % % 1500 0 40 0 8O '-'1-- 120 I I V 240 320 RECEIVED 240 280 320 360 FEB - 8 1995 Oil & Gas Cons. Commission Anchorage 36O 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 <-- West Scale,: 20.00 Created by ' jones IDate plotted : 1-Feb--95 Plot Reference is 21 Version #6. ,Coordinates ere in feet reference slot #21. iTrue Vedicol Depths are reference wellhead. Baker Hughes INTEQ --- ARCO ALASKA, Inc. Structure : Pod 2T Well : 21 Field : Kuparuk River Unit Location : North Slope, Alaska 200 ~-- West Sca.e,:So.oo 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 ?00 600 500 400 I I I I I I I I I I I I I I I I I I I I I i I I I I I I I t 1 I I I I I I I I I I I I I J400 ., 200 loo J 700 % 2OO 70o I 3100 RECEIVED / FEB -8 1995 /2° / kl~s~ Oit& Gas Cons. Commission / Anchorage /s~ ~1~ 1600 2600 2500 2400 2500 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1500 1200 11 O0 1000 900 800 700 600 500 400 <-- West ~o,~ ~ · ~o.oo ICreated by · jones iDate plotted : 1-Feb-95 Plot Reference is 21 Version //6. iCoordinates are in feet reference slot //21. True Vertical Depths are reference wellhead. Baker Hughes INTEO --- ARCO ALASKA, I Inc.i Structure : Pad 2T Well : 21 i Field : Kuparuk River Unit Location : North Slope, Alaska J I i V < -- -- W e s f ~oo,e ,: ~o.oo 4300 4200 4100 4000 3900 3800 3700 3600 3500 3400 .33003200 3100 .30002900 2800 2700 2600 2500 2400 2300 2200 2100 I II II II II II II fI II II II I I I I I I I I I I I I I I I I I I I I I I I 600 ,,., ~'~oo % - .~Oo _ 1200 43 4200 4100 40 0 3900 ,3800 3700 ,36 0 3,500 34 0 3,300 3200 3100 .5000 2900 <-- West Alaska Oil & Gas Cons. Commission/%o _-2,oo ~chora¢ ~ - I I I I I I I I I I I I I I 28~ 2700 26~ 2500 24~ 2300 2200 21~ Scale 1 : 50.00 Casing Design / Cement Calculations 6-Feb-95 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2T-21 B 4,781 ft 2,893 ft 12,881 ft 6,134 ft 3,039 ft 12,491 ft 5,883 ft 3150 psi 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 2,893 ft 1,713 psiJ 3,150.0 ppg 5,883 ft 150 psi lO.8 PPgl Surface lead: Top West Sak, TMD = 3,039 ft Design lead bottom 500 ft above the Top of West Sak = 2,539 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 845 cf Excess factor = 85% Cement volume required = 1,563 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 810 sxJ Surface tail' TMD shoe = 4,781 ft (surface TD - 500' above West Sak) * (Annulus area) = 702 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 736 cf Excess factor = 15% Cement volume required = 847 cf Yield for Class G cmt = 1.15 Cement volume required =1 740 sx! RECEIVED FEB-8 1995 Casing Design / Cement Calculations Production tail: 6-Feb-95 TMD = 12,881 ft Top of Target, TMD = 12,491 ft Want TOC 500' above top of target = 11,991 ft 5" casing tail top (100' above C sand) =1 12,881 ft 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 155 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 172 cf Excess factor = 75% Cement volume required = 302 cf Yield for Class G cmt = 1.19 Cement volume required =[ 250 sxJ TENSION - Minimum Design Factors are' T(pb)=l.5 and T(is)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy= Weight of displaced m d,E C E IV E D FEB-8 199§ Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Oil & (}as Cons. Commission 916OOO lb 4,781 ft 40.00 Ib/ft 191240.0 lb 30684.4 lb 160555.6 lb 979O00 lb 4,781 ft 40.00 Ib/ft 191240.0 lb 30684.4 lb 160555.6 lb 6.11 6O400O lb 12,881 ft 26.00 Ib/ft 334906.0 lb 54487.4 lb 280418.6 lb 2.21 667000 lb 12,881 ft 26.00 Ib/ft 334906.0 lb 54487.4 lb 280418.6 lb 2.4] Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAP~;E- Minimvm Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 6.Feb-95 5750 psi 1712.7 psi 3.41 7240 psi 6941 psi 2839 psi 4102 psi 1.81 3090 psi 0.561 Ib/ft 687 psi, 4~! 5410 psi 0.561 Ib/ft 3441 psi 1.6! RECEIVED FEB -8 ]995 A!aska Oil & Gas Cons. Commission Anchora£~ Casing Design / Cement Calculations 6-Feb-95 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burnt 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burnt 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi RECEIVED FEB ;995 Alaska 0il & Gas Cons. Commission Anch0ra,~;~ 7 , 6 13 5/8" 5000 PS'!'c3OP STACK ACCUMULATOR CAPACITY TE~;T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5, OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTFOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 1;~5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 195/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES 6. 195/8"-5000 PS! DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 1;~5/8"-5000 PSI ANNULAR FEB --8 1995 Alaska Oil & Gas Cons. Commission Anchora.~;n .,UPARUK RIVER UNI',i 20" DIVERTER SCHEMATIC 6 ~ 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR C-.-.~S IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2, SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER, DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. RECEIVED FEB -8 1995 Alaska 0ii & Gas Cons. Commission Anchora: ~ DKP 11/9/94 KUPARUK RIVER UN; ,' 20" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSi DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. RECEIVED DKP 11J9/94 FEB -8 1995 Aiaska (Jii & Gas Cons. Commission Anchora '~ WELL PERMIT CHECKLIST COMPANY PROGRAM: exp [] dev~ redrll [] serv [] .///~d ON/O~ s.o~ ~ ~3 ADMINISTRATION ENGINEERING 1. Permit fee attached ................... N 2. Lease number appropriate ............... 3. Unique well name and number .............. Y N 4. Well located in a defined pool .............. Y N 5. Well located proper distance from drlg unit boundary...Y N 6. Well located proper distance from other wells ...... Y N ' 7. Sufficient acreage available in drilling unit ...... Y N 8. If deviated, is wellbore plat included ......... Y N 9. Operator only affected party ............... Y N 10. Operator has appropriate bond in force ......... I N 11. Permit can be issued without conservation order .... ~ N 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27 Conductor string provided ............... ~ N Surface casing protects all known USDWs ......... y~ N CMT vol adequate to circulate on conductor & surf csg. N CMT vol adequate to tie-in long string to surf csg . . . (~ CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... .~ N Adequate tankage or reserve pit ............ N If a re-drill, has a 10-403 for abndnmnt been approved. ~ Adequate wellbore separation proposed ......... .~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate N BOPEs.adequate ..................... N BOPE press rating adequate; test to .~~ psig. N Choke manifold complies w/API RP-53 (May 84) ....... ~ Work will occur without operation shutdown ....... .~ N Is presence of H2S gas probable ............. Y ~ ~A GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y Y' ' /9 31. Data presented on potential overpressure zones ..... Y/N ~ / ~/ 32. Seismic analysis of shallow gas zones .......... / N /(/ {! ~ ~ 33. Seabed condition survey (if off-shore) ........ / Y N 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMI SS I ON: Comments/Instructions: z HOW/)o - A:'tFORMS\cheklist rev 03/94 · . ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. QS-13 RECEIVED MAY 03 199ð ~i$J~, Oil :& Gas Coni. ~ Anchoraøe &~~/~ I I ****************************** * * * ALASKA COMPUTING CENTER * * * ****************************** *---------------------.------* *----.-. SCHLUMBERGER -------* *----------------------------* ****************************** caMPA,NY NAME t~EI!L NAME FIELD NAMr: BOROUGH S 1\A ifF: API NUMBER REFERENCE NO : ARca ALASKA INC. : 21'-21 : KUPARUK RIVER UNIT : NORTH SLOPE : AIJASKA = 50-103-20212 : 95041 f: IS Tape Verification ListlnQ chlumbergpr Alaska Co~putinq Center 17-APR-199515:28 PAGE: 1 **** SERVICE DATE ORIGIN REEf. NAME CONTINUATION # pREVIOUS REEL COr~NENT REEL HEADER **** N~ r-iE :~: D I T : QS/O3/15 : FLIC : 95077 . . . .. : ;\RCO ALASKA **** SERV ICF: DATE ORIGIN TAPE NAME CONTINUATION # pREVIOUS TAPE COMMENT INC., KUPARUK RIVER, 2T-21, 50-103-20212-00 TAPE HEaD~R **** NAME: EDIT : QS/O3/15 : ,""LIC : 95077 : 1 . . : ARCa ALASKA TAPF HEADER Kupðtuk River Unit MwD/~1AD LOGS # wELL NAME: AP I NlH4RER: OPERATOR: LOGGING CfH4PANY: TAPE CREATION DAT~: # JOB DATA \.10B NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: HAN(;E: F'NL: F"SL: FE!,! : F\~L : ELEVATIONCFT FROM KEl.!LY BUSHING: DERRICK Ft,OOR: GROUND LEVEL: # wELt CASING RECORO 1ST STRING 2"ID STRING INC., KUPA~UK RIVER, 2T-21, 50-103-20212-00 2T-21 5010320212 Arco Alaska Inc. SCHLUMBERGER WELL SERVICES t5-MAR-95 8IT RUN 1 _.........."""-- 95077 S t .t, " A,' m,' '°, u r Mth<R ISDN BIT RUN 2 8I'r RUN 3 .-.--"--- -.-..----- 12 It.N 8E 83 556 MSL 0) 121.50 80.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ---~--------- -.-.-.--- -----_w_-- 8.500 9.625 4772.0 IS Taoe verification Listinq chlumberger Alaska Computing Center 3Rt) STRING PRODUCTlnN STRING ¡7-APR-199515:28 PAGE: 2 # RfM13RKS: THE MWD GR DEPTH SHIFTEO TO THE USIT GR DATED FFB 26, 1995. hLL CDR-CDN CURVES SHIFTED WITH THE GR. S # LIS FORMAT DATA LIS FORMAT DATA **** FILE F I L F N .A P,1 E SERVICE VERSION DATE MAX REC SIZE FTLF TYPE LAST FILE HEAOgR **** : ~DIT .001 : F'LIC : 0O1CO1 : QS/O3/15 : 1024 : fJO . . FILF Hr:ADER FILF NU~A8ER: EDITED MERGED ~WD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 # r~It,F SUMMARY LOWG TOOL CODE START DEPTH -------------- ----------- MWD 12754.0 S # BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) # 1 STOP DEPTH --...---...-. 4168.0 ._--------EQUIVALENT UNSHIFTED DEPTH--.~---_.- RASE~r.lINg DEPTH -.---....--....- 88889.0 1,2579.5 12539.'5 12439,0 12391,0 12339.5 1.2262.5 12237.0 12145.0 1.2130,0 12115.0 12090.° 1.2052.0 12016.5 11999.0 1.1-967.5 88885.5 12577.0 12537.0 12436.0 1.2387.0 12334.5 1.2259.5 12232.5 121.38.5 12123.0 12109.0 12084.5 12048.0 12010.5 11993.0 11963.0 IS Tape Verification Listinq chlumberger Alaska ComputlnQ Center 17-APR-199515:28 PAGE: 3 11942.5 1.1921.5 11859.5 11B50.5 11825.0 11749.0 11647.5 1.14)1.0 11357.0 11231.0 100.0 S 11938.0 11915.0 11855.5 1,lB45.5 11820.0 11744.0 11641.0 11426.5 11352.0 1.1225.0 94.0 # MER~gO DATA SOURCE LtDWG TOOTJ COOE .---.--------- BIT RUN NO. MERGE TUP ----------- --------. MERGE .BASE --..--..---- s # RFMARK5: # LIS FORMAT THE ft<\t'¡D GR DEPTH SHIFTED TO THE U5IT GRCH DATED FER 26, 1995. ALL COR-CON CURVES SHIFTED WITH THE GR. THE GRCH COVERED THE INTERV.AL 12684-11042£ A BLOCK SHIFT OF -2.5 FT WAS APPLIED BELOW 12684 roT AND A BLOCK SHIFT OF -6.0 FT WAS APPLIED ABOVE 11642 FT. S DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE.. 64EB ** -------------------------..-..-- TYPE REPR CODE VALUE -------------.-----.....-.---. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 0.5 FT 1,5 0 FT 68 1 0 ---.------.-------------..--.. !IS Tape Verification Listlna ,chlumberg@f Alaska ComputlnQ Center 17-APR-199515:28 PAGE: 4 ** SET TYPl-; - CHAN ** -.-----------.-----------.--------------------.---------------------_.----------------- N 'Hi, F SRRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS to OROER # LO"" TYPE CLASS HOD ~J U M B SAMP FE.LFM CODE (HEX) . ..1...1 -.--.--..---------.---------------------.-----.---------------------------------------- DEPT FT 488076 00 000 00 () 1 1 1 4 68 0000000000 GP M\~T) GAPI 48B078 00 000 00 0 1 1 1 4 68 0000000000 ROP ~"wD FPHR 488078 00 000 00 0 1 1 1 4 68 0000000000 FFT MWD HR 488076 00 000 00 0 1 1 1 4 68 0000000000 RA MwD 0 H t..q~ 48~O7B 00 000 00 0 1 1 1 4 68 0000000000 RP M~'¡O OHMM 488078 00 000 00 0 1 1. 1 4 68 0000000000 DEl< MW1) D H r,H~ 488078 00 000 00 0 1 1 1 4 68 0000000000 VRA M\~D OHMM 488078 00 000 00 0 1 1 1 4 68 0000000000 VRP M vH,) OHrrM 488078 ]0 000 00 0 1 1 1 4 68 0000000000 ~. RfotOA MWD G/C3 488078 00 000 00 0 1 1 1 4 68 0000000000 DRHO ~~WD G/C3 48B078 00 000 00 0 1 1 1 4 68 0000000000 PFF MWO BN/E 488078 00 000 no 0 1 1 1 4 68 0000000000 CALN MWD IN 488078 00 000 00 0 1 1 1 4 68 0000000000 NPHI MwD PU-S 488078 00 000 00 0 1 1 1 4 68 0000000000 NCNT MWD CPS 488078 00 000 00 0 1 1 1 4 68 0000000000 ~"'CNT MWf) CPS 48B078 00 000 00 0 1 ,- 1 4 68 0000000000 GP-CH CET GAPI 488078 00 000 00 0 1 1 1 4 68 0000000000 ._._-_..-------_.----------~--------.-------------.--------------------------.---.----- ** DATA DEPT. RA.MWD YRP.MWD CALN.MWD GRCH.CET DEPT. RA.MWD VRP.MWD CALN.MWD GRCH.CET ** ** 12818.000 -999.250 -999.250 -999.250 .999.250 4634.000 -999.250 -999.250 -999.250 -999.250 END OF DATA ** **** FILE rILE NAME SERVICE VERSION DATF MAX REC SIZE; FILE TYPE LAST FIIJE GR.MWD RP.MWD RHOB.MWD NPHI.MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999;250 -999.250 -999.250 64.515 -999.250 -999.250 -999.250 ROP.MWD DER. MWO DRHO.MWD NCNT.MWD FET.MWD VRA.MWD PEF.MWD FCNT.MWD GR.MWD RP.MWD RHOB.MWD NPHI. MWD -999.250 -999.250 -999.250 -999.250 FET.MWD VRA.MWD PEF.MWD f"CNT. MWO -999.250 -999.250 -999.250 -999.250 ROP.Mwn DER.MWO DRHQ,. MWD NCNT.MWD -999..250 -999.250 -999.250 -999.250 TRAIIJEH **** : EDIT .001 : F"LIC : 0O1.CO1 : 95/03/15 : 1024 . J. 0'... . ..) " " IS Tare Verification ListlnQ chlumberger Alaska Computing Center **** FILE FILE NAME SERVICE VERSION D.ATE MAX REC SIZE FILE TYPE LAST FlfJE Ht~ADER **** : EDIT .002 : FLIC : 0O1.COl : 95/03/15 : 1024 : to . . 2 12820.5 12820.5 # 17~APR-1995 15:28 STOP DEPTH -.----..-- 4640.0 4640.0 20-."EB-95 FAST 2.5 MEMORY 12821.0 4768.0 12756.0 75 49.4 70,1 80TTO~~ ) Toot, TYPE TOOL NUMBER --------. ----------. N!UTRON DENSITY POROSITY IDS 052 COMP DUAL RESISTIVITY RGS 051 FILE HEADER rILg NU~~BER RAW vîWO Curves and log header data for each bit run In separate BTT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 # F'TLE SUMMARY VENDOR TOOL CODE START DEPTH -.-...---------- --------.-. COR CON $ ** LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TO DRILLER. (FT); TOP LOG INTERVAL (FT); BOTTOM LOG INTERVAL (FT): 811 ROTATING5PEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING CTOP TO VENDOR TOOL CODE -....-..---....---. CON COR $ # 80REHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (La/G): MUD VISCOSITY (5): # 8.500 4772.0 l.,SND 10.80 43,00 PAGE: 5 files. IS Tace Verlflcðtion Listinq chlumberger Alaska Computlnq renter 17~APR-1995 15:28 # !4110 PH: MUD CHLOHtDES (PPM): FLUID LOSS eCl): MAXIMUM RECORDED TEMPERATURE CDEGF): RESISTIVITY (QHMM) AT TEMPERATURE (DEGF): Hun AT MEASUPED TEMPERATURE (MT): MUD AT MAX CIRCULATING TFMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUT~ON TOOL MATRIX: MATRIX OENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWP FREQUENCY (HZ): ** # REMARKS: 400 2.670 2.480 0.000 SANDSTONE 2.65 8.500 1.000 PAGE: 6 75,0 75.0 0,0 **************************Run #1****************** - Resistivity measurement 65,05' from bit, Gamma Ray measurement 75å47~ from bit, Density measurement 13. .83' from bit. Neutron measurement 139.12' from bit. - Drilllnq Data from 4772~ to 12821~. - Well TD~D @ 10:00 on 20-Feb-1995 Deviation @ TO 49.82 deg. .. Chloride~: 400 ppm $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE.. 64EB ** -------.-----...---------.-.-- TYPE R€PR CODE VALUE .---.---.--.--.-.------.-.---- 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 9 65 11 66 12 68 0.5 F1' 1,5 15 Tape Verification Listina chlumberger Alaska Computina Center 17~APR-1995 15:28 PAGE: 7 F1.F.P~ CODE 66 155 66 66 66 ** SET TYPE - CHAN ** TYPE --------------.-.------.------ VALUE ** 12820.500 -999.250 -999.250 -999.250 -999.250 4640.000 -999.250 -999.250 -999.250 392..100 ** END OF DATA ** ------------------------------ 13 14 15 16 0 0 F'T 68 1 1 ------------------------------ GR.LWl ATR.LWl DPHI.LWl TNPH.LWl GR.LWl ATR.LWl DPHI.LWl TNPH.LWl --------------------------------------------------------------------------------------- NAMF SFRV UNIT S¡':RVICF. API API API API FIIJE NUMB NUMB SIZE REPR PROCESS TO ORDER j LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) -----.------------------------------------.---.----------------------.-.--------------- DE P 'I' FT 48RO78 00 000 00 0 2 1 1 4 68 0000000000 GR l,W 1 GAPI 48RQ78 00 000 00 0 2 1 1 4 68 0000000000 ROPF LWl F/HR 488078 00 000 00 0 2 1 1 4 68 0000000000 TAB [JW 1 HR 488078 00 000 00 0 2 1 1 4 68 0000000000 TABD T¡W 1 HR 488078 00 000 00 0 2 1 1 4 68 0000000000 ATR [I WI OHMt~ 488078 00 000 00 0 2 1 1 4 68 0000000000 PSR L¡W 1 QHMM 48807B 00 000 00 0 2 1 1 4 68 0000000000 DER IJW1 OHì'<1M 48807B 00 000 00 0 2 t 1 4 68 0000000000 RHOB LWl G/C3 488078 00 000 00 0 '- 1 1 4 68 0000000000 DPHI LINt PU 4S8078 00 000 00 0 2 1 1 4 68 0000000000 DRHO I;W 1 G/C3 488078 00 000 00 0 2 1 1 4 68 0000000000 pEF LWl BN/E 488078 00 000 00 0 2 1 1 4 68 0000000000 OCAl, LW1. IN 488078 00 000 00 0 2 1 1 4 68 0000000000 TNPH t.lW 1 PH 488078 00 000 00 0 2 1 1 4 68 0000000000 HENa. 1.J W 1 CPS 48e078 00 000 00 0 2 1 1 4: 68 0000000000 HEFt' lå¡ 1 CPS 488078 00 aoo 00 0 2 1 1 4 68 0000000000 SN IJW 1, OHMM 488078 00 000 00 0 2 1 1 4 68 0000000000 ..--.-.----.-.-.---------_._._~.._._------_.-------_.-------------..----------..-..---- -999.250 .999.250 -999.250 -999.250 ROPE,.LWl PSR.ttWl DRHO.LWI HENA.LW1 64.515 -999.250 -999.250 -999.250 TAB.[.IW1 DER.LiN! PEF.LWl HEFA.LW1 -999.250 -999.250 -999.250 -999.250 ** DATA DEPT. TABD.LWl HHOB. L'W 1 DCAI¡.L~41 SN.l,Wl DEPT. TAB£).LW1 RHOR.LW1 DCA!t. L W 1 SN.LWl -999.250 -999.250 -999.250 ""999.250 ROPE. l"W 1 PSR.LWl DRHO.liWl HENA.LirJl -999.250 -999.250 -999.250 -999.250 TAB.l,Wi DER.LW1 PEF.LViI HEFA.I.JWl ""999.250 -999.250 -999.250 -999.250 IS Tape verification Listina chlumberger Alaska ComputlnQ Center 17-APR-199515:28 PAGE: 8 **** FILE F'YLE NAYE SERVICE VF.RSION DATE MAX REC SIZ~ FILF: TYPE LAST FILE TRAILER **** : EDIT .002 : FLIC : OOjCOl : 95/03/15 : tO24 : IJO . . **** SERVICE OATF' ORIGIN TAPE NAME CONTINUATION # pREVIOUS TAPE COMMENT TAPE TRAILER **** NAME: F:DIT : 95/03/15 : FLIC : 95077 : t . '" : ARCa ALASKA INC., KUPARUK RIVER, 21-21, 50-103-20212-00 **** REEL TRAILER **** SERVICE NAMg : EDIT DATE : 95/03/15 ORIGIN: FLIC REEL NAME: 95077 CONTINUATION # : pRE:VIOUS REEL .. : COMMENT: ARCa AIJASKA INC., KUPARUK RIVER, 2T-21, 50-103-20212-00
