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186-089
• • OF 7'4 6,w I%% sA THE STATE Alaska Oil and Gas T o f LAsKA Conservation Commission 'sem �,- . � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ° ALLs1°Q' Fax: 907.276.7542 www.aogcc.alaska.gov SCANNED DEC 6 $ 2017, Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-13 Permit to Drill Number: 186-089 Sundry Number: 317-468 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, darr- Hollis S. French -tS Chair DATED this l3 day of October, 2017. RBI/7;S �`— a L J cu f? • • • RECEIVED OCT 032017 STATE OF ALASKA D73 10/>7 i7 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGcc APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 , 1.Type of Request: Abandon 1=1. Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development 0 ' 186-089 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,AK 99510 50-103-20067-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2T-13 • Will planned perforations require a spacing exception? Yes ❑ No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25569, Kuparuk River Field/Kuparuk River Oil 1 11. PRESENT WELL CONDITION SUMMARY Total Depth IIID(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7�'0C�8 0 0'0 6)4 ?A 0 0 0 Cemented to surface None Casing Length Size MD TVD Burst Collapse Conductor 72 16 105 105 1640 630 Surface 2944 9.625 2976 2835 3520 2020 Intermediate Production 7495 7 7839 6124 4980 4320 Liner Perforation Depth MD(ft): , Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7392-7414 cmtd,7532-7579 uncmtd 5798-5813,5898-5932 2.875,2.375 J-55,N-80 7262,7776 Packers and SSSV Type: Brown HB-1 packer,Baker 1-B packer,CAMCO Packers and SSSV MD(ft)and TVD(ft): Brown HB-1 7217 MD,5674 TVD Baker 1-B 7450 TRDP-1A SSA(control line defeated,not locked out) MD,55839 TVD SSSV 1765 MD,1708 TVD 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7-Oct-17 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 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 Jill Simek Contact Name: Authorized Title: Staff Well Integrity Engineer Contact Email: JiII.Simek(c conocophilliDs.com • Contact Phone: 907-263-4131 Authorized Signature: INF j•–•),„,,\.c.---. Date: ib)3/1 1- li COMMISSION USE ONLY Conditions of approval: Commission so that a representative may witness Sundry Number: J/7 1/� n Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance UV' (Jy Other: t C o? O f-4--G Z ✓-, / Z 0 FU r 1'1f f 6 J a b 4 r�o`�rn wl rpt r� &i, r l�-tom" rfGv/rY►v,—ri f S Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No V Subsequent Form Required: 1 RPS IS 1--(--CCT 2 F, 2617 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 O 11g It-4 ,- 16/611?_. ,/q%T vim- /o//-�/) S<\ '..).,/ Form 10-403 Revised 4/2017 Approved application is valid for: �4GihNtA iAttachmentss in roval. Submit Form and Duplicate • • Nov ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 2 October 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to complete the final plug and abandonment work for the Kuparuk River Unit well 2T- 13 (PTD#: 186-089). The 2T-13 well was drilled and completed in 1986 as a gas lifted production well and is located in an area where subsurface subsidence has been an issue. Because of the complications in the well due to subsidence,ConocoPhillips performed downhole abandonment operations in 2010 to isolate the perforations in the well and place additional shallower cement plugs as necessary. This work left the well with the following cement plugs in the well: • Perforations squeezed and isolated • Tubing and tubing x casing annulus cemented from 3000'to 1060' • 9.625"x 7"annulus cemented off from 1055'to 344' • Tubing cut at 1090' • 7"casing cut and recovered from 344' • Cement in the 9.625"casing from 344'to surface. ConocoPhillips now proposes to complete the final P&A of this well by excavation of the cellar,removal of the wellhead and installation of a marker plate. / If you have any questions or require any further information,please contact me at 263-4131. Sincerely, i Simek tip 11 Integrity Engineer CPAI Drilling and Wells . • • Kuparuk River Unit 2T-13 Final P&A Procedure Permit to Drill #: 186-089 1. Conduct a pre-job safety meeting to identify and mitigate hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. Remove wellhouse from well, if still in place, remove tree and annulus valves. 3. Excavate cellar to 12' below pad level. Pump or vacuum out any excavation water to holding tank. 4. Place shoring protection over well and access stairs/ladder in accordance with CPAI and OSHA shoring requirements. \- 5. Notify AOGCC North Slope Inspectors for visual well cutoff and cement to surface in well. PHOTO DOCUMENT 6. Cut off well a minimum of 3' below tundra level per approved techniques utilizing annulus LEL monitoring and window cutting. 7. Ensure 9.625" casing and 16" x 9.625" annulus are full of cement, weld on marker plate. Have AOGCC Inspector witness. PHOTO DOCUMENT 8. Remove excavation shoring equipment. 9. Backfill excavation and mound it 10%to account for settling. PHOTO DOCUMENT FINAL LOCATION CONDITION r T`' KUP PD 2T-13 ConocoPhillips Well Attributlir Max Angle. TD Alaska lrv3 j, Wellbore API/UWI Field Name Wellbore Status ncl l°) MD(ftKB) Act Btm(ftKB) corlocv4hitiips 501032006700 KUPARUK RIVER UNIT PROD 50.65 6,200.00 7,868.0 ,..,.,. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2T-13,10/3/20176:02:30 AM SSSV:TRDP Last WO: 41.51 5/13/1986 Verpol 9dlematic;(set al) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 315.0 5/21/2010 Rev Reason:WELL SUSPENDED osborl 9/26/2013 HANGER;21.3 0[610 Casing Strings y' - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 33.0 105.0 105.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 32.1 2,975.7 2,835.0 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen p...Grade Top Thread PRODUCTION 7 6.276. 30.3 7,839.4 6,124.2 26.00 3-55 BUTT Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 21.3 7,472.1 5,855.2 6.50 J-55 EUE8rdABMOD Ei 1� Completion Details u" Top ID Top(ftKB) Top(TVD)(ftKB) Top Incl n Item Des Com (in) 21.3 21.3 0.00 HANGER CAMERON TUBING HANGER 2.875 .h/\CONDUCTOR;33.0-105.0 1,788.3 1,784.5 12.05 SAFETY VLV CAMCO TRDP-1A SSA 2.312 STAGE 3,0.0 ftKB , 7,201.2 5,662.1 45.26 PBR BROWN PBR 2.937 CMT Retainer;259.0 _ . 7,217.4 5,673.5 45.18 PACKER BROWN HB-1 PACKER 2.667 7,363.2 5,776.9 44.33 BLAST RINGs BLAST RINGS(2) 2.441 7,449.0 5,838.6 43.97 SEAL ASSY BAKER SEAL ASSEMBLY 3.000 3 7,450.0 5,839.3 43.96 PACKER BAKER 1-B PERMANENT PACKER 3250 7,454.1 5,842.3 43.96 MILLOUT MILLOUT EXTENSION EXT 2.441 SAFETY VLV;1,788.3 ry 1 Nag 7,463.4 5,848.9 43.93 NIPPLE CAMCO'D'NIPPLE 2.250 GAS LIFT,2,637.9 'ZMItri 7,471.2 5,854.6 43.92 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Corn Run Date ID(in) ` e 299.0 299.0 0.12 CMT Retainer CEMENT 299'TO SURFACE/CEMENT 299'TO 11/15/2010 1.000 1 Il 3015' SURFACE;32.1-2,975.7 �+ Perforations&Slots STAGE 2;299.0 ftKB e Shot Top(TVD) Btm(TVD) Shots/p GAS LIFT;4,921.9 = Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date R) Type Corn 7,392.0 7,414.0 5,797.6 5,813.4 C-4,2T-13 9/3/1986 12.0 5"SOS GAS LIFT;6,3301 7,532.0 7,579.0 5,898.4 5,932.4 A-4,A-3,2T- 9/3/1986 4.0 4"SOS 13 Cement Squeezes GAS LIFT;8,887.9 Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn uM .qw 7,100.0 7,450.0 5,591.0 5,839.3 CEMENT PLUG 1/3/2010 PUMP 21 bbls of 18.8 ppg CLASS G CEMENT, � ESTIMATED 12 bbls BEHIND PIPE WITH GAS LIFT,7,155.6 ,;. ESTIMATED TOC @ 7100'MD. .�,. 299.0 3,015.0 299.0 2,863.3 CEMENT PLUG 11/15/201 0 0.0 299.0 0.0 299.0 CEMENT PLUG 11/16/201 W 0 PBR;7,201.2 Mandrel Inserts PACKER;7,217.4 '. St all on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com Production;7,254.9 T 2,637.9 2,569.6 Camco KBMG 1 GAS LIFT GLV BK 0.250 1,365.0 12/20/1992 Production;7,325.0 F W. 2 4,921.9 4,139.7 Camco KBMG 1 GAS LIFT GLV BK 0.250 1,381.0 12/20/1992 Alki 3 6,330.1 5,063.4 Camco KBMG 1 GAS LIFT GLV BK 0.313 1,552.0 12/20/1992 E: 4 6,867.9 5,428.5 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 4/22/1991 5'SOS;7,392.0-7,414.0 `^T. 5 7,155.6 5,630.0 MMH FMHO 1 1/2 GAS LIFT OV RK 0.250 0.0 3/9/1993 6 7,254.9 5,700.0 Camco KBMG 1 PROD OPEN BEK 1/6/1998 7 7,325.0 5,749.7 Camco KBMG 1 PROD OPEN BK 1/6/1998 8 7.427.3 5,823.0 Camco KBMG 1 PROD OPEN BEK 1/7/1998 Production;7,427.3 r �� Notes:General&Safety • X End Date Annotation SEAL ASSY;7,449.0- 7/20/2007 NOTE:IMPENETRABLE TBG RESTRICTION @ 324,1.52"TOOLS WON'T PASS STAGE 1,7,100.0 ftKB '-"•- PACKER;7.450.0 '- 11/6/2010 NOTE:WELL Suspended,TBG hanger in TBG head w/no TBG below,BPV installed,TBG stub top @1090' • MILLOUT EXT;7,454.1 NIPPLE;7,483.3 SOS;7,471.2 4"SOS;7,532.0-7,579.0 PRODUCTION;30.3-7,839.4 • 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-13 . Oper.Rep: Ian Ives PTD No.: 186-089 Oper.Phone: 659-7043 Location Verified? Yes - Oper.Email: If Verified, How? ter(specify in commei Onshore/Offshore: Onshore Suspension Date: 01/03/10 Date AOGCC Notified: 08/28/10 Sundry No.: 309-399 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 100 Photos Taken? Yes IA 100 OA 10 • AUG 1 4 2015 SCANNED Condition of Wellhead: Wellhead location verified with plot plan.Wellhead looked to be in good working condition.OA was blinded with gauge. • IA has AL line attached but blinded with gauge.Flowline is attached. - Well has wooden cellar box that is dry with no signs of oil.Wellhouse was removed for on-going dirt work. - Condition of Surrounding Surface Surface conditions looked good,they were in the process of doing dirt work. Location: Follow Up Actions none Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry —)((— Comm PLB 08/2010 2010-0829_Suspend_KRU_2T-13_bn.xlsx , ', .. 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' - 0 11111 II f ., f:-. i II i 1 .sis .ybs t N '++ rn ,r 00 O i O N �i O— b0 f s • ."i N c44 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) RESCAN Color items: D Grayscale items: [] Poor Quality Originals: Other: Two-Sided DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~ I NOTES: ORGANIZED BY: ~REN VINCENT SHERYL MARIA LOWELL -- Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~1~ I (at the time of scanning> SCANNED BY: ~ BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; IS~ General Notes or Comments about this file: PAGES: /.~ I Quality Checked (done) RevlNOTScanned.wpd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 lb. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: November 16, 2010 186 - 089 / 310 - 324 3. Address: 6. Date Spudded: 13. API Number. P. O. Box 100360, Anchorage, AK 99510 - 0360 May 5, 1986 50 103 - 20067 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 77' FSL, 556' FWL, Sec. 1, T11N, R8E, UM May 11, 1986 2T - 13 Top of Productive Horizon: 8. KB (ft above MSL): 117' RKB 15. Field /Pool(s): 1327' FNL, 1155' FEL, Sec. 12, T11N, R8E, UM GL (ft above MSL): 61' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1399' FNL, 837' FEL, Sec. 12, T11N, R8E, UM 7754' MD / 6059' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498945 y - 5970058 Zone 4 7868' MD / 6144' TVD ADL 25569 TPI: x - 502514 y - 5968654 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 502832 y - 5968582 Zone 4 1787' MD / 1783' TVD 2667 18. Directional Survey: Yes ❑ No 12 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1550' MD / 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# 1440 Surf. 105' Surf. 105' 24" 225 sx CS II 9.625" 36# J -55 Surf. 2976' Surf. 2835' 12.25" 820 sx AS III, 320 sx Class G 7" 26# J -55 Surf. 7839' Surf. 6124' 8.5" 380 sx Class G, 175 sx AS I 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.875" 7472' 7217' MD / 5673' TVD, 7450' MD / 5839' TVD perfs squeeze off AditiNUP JA 1 2 2.O r 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED sqz perfs est. top of cement 7100' 21 bbls of 15.8 ppg Class G tbg & IA from 1064' -3000' 73 bbls of 15.7 ASI 7" & 7 "x9 -5/8" annulus from 479' -1055' 40 bbls of 15.7 ASI cmt ret. @ 299' squeeze 9 - 5/8" holes 27.5 bbls of 15.7 ASI of 1.5# /bbl cement 27. PRODUCTION TEST surface to cmt ret. @ 299' 17.5 bbls of 15.7 ASI Date First Production Method of Operation (Flowing, gas lift, etc.) abandoned 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) I Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and 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. RECEIVED NONE DEC 2 0 2010 Alaska .Qt & Gas Cons. Cofl' NS!�on Anchorage Form 10 -407 Revised I� M8 DEC 2.2 i CONTINUED ON REVERSE Submit original only 44 /..c.# 6 28. GEOLOGIC MARKERS (List all formations and markers Illintered): 29. ! FORMATION TESTS NAME MD TVD Well tested? ❑ Yes zi No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1550' 1550' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 7391' 5796' Base Kuparuk C 7416' 5814' Top Kuparuk A 7509' 5881' Base Kuparuk A 7700' 6019' N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263 - 4220 Printed Name Howard3ober Title: Wells Engineer /� /� /� Signature 71 "-- Phone 263 - 4220 Date 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 "• KUP 0 2T -13 ConocoPhit i� , Well Attributes Max Angle & MD 1 TD Nash Wellbore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) :J(8 I 501032006700 I KUPARUK RIVER UNIT PROD 50.65 I 6,200 00 L- 7,868 0 conaraPhtlhpt __.. - - ' " "` C K2s Da (p pm) End Date KB Grd (ft) Rig Release Date ]Comment TRDP 30 1/11/2009 Last WO: I 41.51 5/13/1986 Well C fg -23U109,2323 AM -= SU T e,na.s, c ] Ac Annotation Depth (HKB) End Date Annotation Last M.d By End Date Last Tag SLM 315.0 5/21/2010 I Rev Reason WELL SUSPENDED I Imosbor 1213/2010 _. Casing Strings - String OD I String ID Set Depth Set Depth (WO) String Wt String ,_ Casing Description es Bt _ (in) (in) Top (ftKB) (kKB) (Ibs /k) Grade String Top Thrd RANGER, 21 "ell .- e�'r CONDUCTOR 16 15.062 33.0 105.0 105.0 62.50 H-40 . SURFACE 95/8 8.765 32.1 2,985.0 2,841.7 36.00 3 -55 PRODUCTION 7 6.151 344.0 7,839.0 6,123.9 26.00 J -55 Tubing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String ' Tubing Description (in) (in) Top (HKB) (HKB) (61KB) (Ibs/ft) Grade String Top Thrd CONDUCTOR, TUBING 2 /18 2 441 1000.0 7 472 0 5,855.2. 6.50 J -55 EUE8rdABMOD 105 Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) r; ;"`,,, „ s Wi Top Depth I/STAGE 3, 0 '9 f�CMT Retainer, - 1 (TVD) Top Inc! 299N Top ( MKS) ( ° I Description Comment Run Date ID(in) ' 3 21.3 21.3 -0.03 HANGER TUBNG HANGER 9/3/1986 3.500 299.0 299 0 0.12 CMT Retainer CEMENT 299' TO SURFACE / CEMENT 299' TO 3015' 11/15/2010 1.000 1,787.0 1,783.3 12.03 SAFETY VLV Cameo TRDP -1A 9/3/1986 2.312 2,637.0 2 568.3 32.65 GAS LIFT CAMCO /KBMG/1 /GLV/B1(025 /1365 / Comment: STA 1 12/20/1992 2.371 iii - ; • ;I 49210 4139.1 48A9 'GAS LIFT CAMCO /KBMG/1 /GLV /BK/.25 /1381 /Comment STA 2 12/20/1992 2.371 SAFETYI . 6 6,329.0 5,062.8 49.93 GAS UFT 8 67.0 5,429 9 45 61 GAS LIFT CAMCO /KBBMG/ 1/ SJOV/R M 1 Comment Comment S 4 STA 3 4/22/1991 2.371 F Comment STA 4 4/22/1891 2.371 K/ 25// Comment STA 5 3/9/1993 2.347 GAS _v �_ __.__ 2637 - -- 74:157 14un 7201.0 5,6625 4545 PBR Brown _ 9/3/1986 2.500 ' 1 7,217.0 5,673 6 45.34 PACKER Brown 'HB -1' PACKER 9/3/1986 2.441 7,254.0 5,699.5 45.09 PRODUCTION CAMCO /KBMG/11HFCV /BEK // /Comment: OPEN STAB 1/6/1998 2.371 SURFACE. .a. ..,. _._ 2,985 , ' 7,325.0 5,749.71 44.60 PRODUCTION CAMCO /KBMG/1 /OPEN /BK/ / /Comment. OPEN; UNABLE 1/6/1998 2.371 STAGE 2, 299 N „ 7JS r TO SET CV STA 7 �_...,,a _�.. „ _,,.,,,_.� - Z r -70.IP 7,427.0 5,822.9 44.14 PRODUCTION CAMCO/KBMG/1 /HFCV /BEK /// Comment: OPEN STA 8 1/7/1998 2.371 7,450.0 5,839.4 44.05 PACKER Brown '1 -B' PACKER 9/3/1986 3.250 GAS LIFT, K. . 4,921 7,463 0 5,848 7 44 00 NIPPLE Camco'D' Nipple NO GO 9/3/1986 2.250 - 7 7 ,4 4 7 72 1 .0 5,854.5 Brown 9/3/1986 2.441 ��h7 0 5,8552 43 43.96 97 TTL no ELMD TTL available 9/3/1986 2.441 - 61N.6 6,329 perforations &$lots /� /� snot - -- -- '�/ I ry Top (TVD) Btm (TVD) Dens GAS LIFT, ft k Top (ftKB) B (ftK (ftKB) (kKB) Zone Date (nn--- TWO Comment 6,867 7,392.0 7,414.0 5,797 6 5,813.7 C-4, 21-13 9/3/1986 12 0 5" SOS 7,532.0 7579.0 5,899 0 5 932.5 A-4, A -3, 2T -13 9/3/1986 4.0 4" SOS - - - - - - - Notes General & Safety End Date Annotation 7/20/2007 NOTE: IMPENETRABLE TBG RESTRICTION @ 324', 1.52" TOOLS WON'T PASS GAS L , IF 155 ,I` ` 11/6/2010 NOTE: WELL Suspended, TBG hanger In TBG head w /no TBG below, BPV installed, TBG stub top @1090' C t i"tl�1't ,-i.4 M.ti e✓ PBR. 7,201-- _.___.__. / PACKER, 7,217 - -- r �. ,:' 6) 7i60 / ° PRODUCTION,_ 7,254 PRODUCTION, __ _ Sfs s(. R, Cl, M! �s ak 71s @ ? ? CS - = 3 00.:0 ' � 7 "1,6 / S V 7,325 c' -,..1 7' / /. „y 'As. L.7,1 4, 30 en,' `( 7b / s Co os. >54- c-/ ,4...„,e ,..,,,/ /0 A-- /S 5 C-V /0 61 ' . 7,392 -7,414 PRODUCTION, / 7,427 / V G3...'t Sf 3 : i? ,-4 le %s , L 7 ` es, €' To ffs - l oss' . /sit= v STAGE 1, r _ °' - `-.._. ,- „ 4, C �a,4, ..! e / / 0 6 S / S r e - r 1 '7 7 4'5'5 PACKER. 7.450 , , , , . . / ? / 4 5 G A„ ?.r /NS -7‹,-. 4 / 7 f /- /V ss ' NIPPLE, 7,463 -'-- - I r I S fss- S e.-t ! // c i re E.., i & 2 ? ? � ? f•- SOS, 7,471 - -.. .�� / 1-- .,% f TTL. 7,472 -- - - -.._ __ , 17, s 6 c•441 .5 649✓ n/"'^Gr, SA,44 \ 0L.. ` )4 f+f /t`� 4•sos, . � 7,532 -7,579 ' PRODUCTION, TD,7,868 _"- • Conoco ph.11ips Time Log & Summary W 1Mew W & Repart»g Report 1 Well Name: 2T - 13 Rig Name: NORDIC 3 Job Type: ABANDONMENT Rig Accept: Acce t: 10/12/2010 9:30:00 AM Rig Release: 11/16/2010 4:00:00 PM Date . From To Dur S. Depth E. Depth Phase Code Subcode Tx Comment -F-3;1111i111,1,,, 'i 11 10/12/2010 24 hr Summary Move Rig & Spotted Over Well 2T -13. Circulate 9.6 ppg Brine into IA. Set BPV. N/D Tree and Inspected Lifting Threads, & Install Test Dart. NU BOPE and Test. 09:00 09:30 0.50 MIRU MOVE MOB P Move rig from 2T -15 and spot over 2T -13. 09:30 13:30 4.00 MIRU MOVE RURD P RU on well. RU Handy -Berm (containment). Run hardline, spot equipment. Pull BPV. RU circulating lines. Fill pits and blend brine for 9.6 PPG. 13:30 15:30 2.00 COMPZ RPCOM CIRC P PJSM, covered hazards on RU hadlines. Proper line up and good communications w /cellar and rig floor. PT lines to 3500 psi. IA valve stem leaking around bonnet. Fill IA w/9.6 # brine with charge pump. It took 11 bbls to fill. Monitored well for 30 RI min.(t S e 4' 5 . ' 15:30 16:00 0.50 COMPZ WHDBO MPSP P R/D Hosees. . Set BPV / 16:00 19:30 3.50 COMPZ WHDBO NUND P PJSM. N/D Tree. Function LDS. Inspect Lift Threads and Install Test Dart 19:30 23:00 3.50 COMPZ WHDBO NUND P NU BOPE. Bleed Gas Cap From IA. Fill Again With 10.5 bbl of 9.6 ppg Brine. 23:00 00:00 1.00 COMPZ WHDBO BOPE P Rig Up Testing Equipment. Start BOP Test. 250/3500 psi. 10/13/2010 Tested BOP, 240/3500 psi. Pulled BPV. BOLDS and Pull up on Hanger to Neutral Wt. RU and RIH w/ Slickline and Pulled WRP. There was unexpected pressure below the plug. Pull plug to surface. Started Bleeding Down Pressure On Tubing. 00:00 01:00 1.00 COMPZ WHDBO BOPE T Continue with BOP Testing. Had Valve Leaking By. Re -Test. 01:00 02:00 1.00 COMPZ WHDBO BOPE T Still Having Problem getting BOPE to hold Psi. Trouble shooting 02:00 03:00 1.00 COMPZ WHDBO BOPE T Prep to Pull Test Plug and Inspect & Re -set. 03:00 05:30 2.50 COMPZ WHDBO BOPE T Drain Stack and Pulled Dart Valve. Found Bad 0-ring on Valve. Re- Installed.Fill Stack. Worked lockdown screws in and out and tightened. 05:30 10:00 4.50 COMPZ WHDBO BOPE P PT BOPE including annular to 250/3500 psi. Witnessing of test waived by Bob Noble (AOGCC) @ 0720 hrs 10 -13 -2010. - Page 1 of 43 • • 'bate, From To Dar S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 COMPZ WHDBO MPSP P Pull BPV, MU landing jt in hanger threads. MU top drive to landing jt. and set down wt. BOLDS and pull up on hanger to neutral wt 76K including blocks. Fill IA with 14 bbls 9.6 # brine. 11:00 12:30 1.50 COMPZ RPCOM MPSP P PJSM w /HES slickline crew. Discussed hazards of rigging 99 9 up slickline, bringing tools up beaver slide. RU HES slickline. RIH to retrieved WRP @ 121'. Pressure under WRP. Pulled to surface. 12:30 18:00 5.50 COMPZ RPCOM MPSP T 280 psi on tubing. Start bleeding off thru 1/2" needle valve. 18:00 21:00 3.00 COMPZ RPCOM MPSP T Crew Change. PJSM. Have Spill Drill. Continue with Bleed Down. Pressure @ 75 psi While Bleeding. SITP =100 psi. Discussed options w/WO Engineer & Wells Superintendent. Decision was to continue to bleed tubing pressure. 21:00 00:00 3.00 COMPZ RPCOM MPSP T Pressure @ 95 psi While Bleeding. SITP =135 psi. 46 bbls Total return for last 11.5 hour and 54.7 bbl displace from trip tank of 9.6 ppg brine. 10/14/2010 Able to bleed tubing pressure to zero, Lay down slickline fishing string with WRP. Made two attempts to drift tubing with 2.33" O.D gauge ring set down at 338' SLM each time, MU RIH with 1.59" gauge ring and set down at 341' SLM, RDMO Slickline. Rig up re turn line to tubing and attempt to reverse circulate in 9.6# Brine. 00:00 05:00 5.00 0 0 COMPZ RPCOM MPSP T Continue Bleeding Pressure from Tubing. SITP =140 psi / Bleed Psi= 100 psi. 49 bbls Return & 58.8 bbl Displaced to IA. Taking reading every hour. SITP =145 psi / Bleed Psi= 105 psi. 54 bbls Return & 62.8 bbl Displaced to IA. SITP =155 psi / Bleed Psi =110 psi. 57 bbl Bled back & 68.1 bbl Displaced to IA. SITP =160 psi / Bleed Psi =110 psi. 60 bbl Bled back & 78.7 bbl Displaced to IA. SITP =165 psi / Bleed Psi =110 psi. 63 bbl Bled back & 90 bbl Displaced to IA. Page 2 of 43 • • Date From To Dur S. Depth E. Depth Phase Code Subcode l T C omment 1 A1 - ..x _.. 05:00 15:30 10.50 0 0 COMPZ RPCOM MPSP T Continue bleeding p ressure and recording every hour. SITP =170 psi / Bleed PSI =115 PSI 67 bbls Returns & 99.5 bbl Displced to IA SITP =175 psi / Bleed PSI =115 PSI 72 bbls Returns Shut off trip tank to IA SITP =175 psi / Bleed PSI =115 PSI 76 bbls Returns SITP =155 psi / Bleed PSI =105 PSI 80 bbls Returns SITP =135 psi / Bleed PSI= 90 PSI 83 bbls Returns SITP =115 psi / Bleed PSI= 75 PSI 87 bbls Returns SITP= 80 psi / Bleed PSI= 55 PSI 90 bbls Returns SITP= 45 psi / Bleed PSI= 30 PSI 92 bbls Returns SITP= 25 psi / Bleed PSI= 10 PSI 94 bbls Returns SITP= 6 psi / Bleed PSI= 2 PSI 95 bbls Returns Pressure bled off to 0. 108 bbls Returns 15:30 18:30 3.00 0 0 COMPZ RPCOM SLKL T ND Slickline BOP. LD WRP. Stabbed TIW valve and pump out sub. RU slickline BOP and lubricator. RIH w/2.33" drift to 338' worked up and down could not work thru. POOH stood back lubricator, latched onto tubing and pulled 20K more tension on tubing for total of 62K + blocks 35K =total 97K. Rig slickline BOP and lubricator back up and attempt to run 2.33" drift again and only got to 336'. POOH changed drift to 1.56" and RIH to 341' solid set down again. 18:30 19:30 1.00 0 0 COMPZ WHDBO BOPE T Crew Change, PJSM, Hook Up Choke to BOPE and Pressure Test to 250/3500 19:30 00:00 4.50 0 0 COMPZ RPCOM CIRC P Pulled slips and slacked off to 67k neutral weight, Close annular, Bring rig pumps online @ 1 BPM, 70 PSIG. Confirm fluid movement and increase rate to 1.5 BPM, 130 PSIG. Pumped total of 62 BBLS down IA with 6 BBLS returned up tubing. Shut down rig pump and started using charge pump only. 10/15/2010 Continued to load well with 9.6# Brine, Made four attempts to drift tubing with 1.5 ",1.44 ",1.259 ",1.0 ", drifts and were unable to get deeper than 346' SLM, Rig up e-line to cut tubing with RCT. (ON GOING) Pae3of43 • Time Logs `,.,.s _ il ` z' 'ICI Date e = From To d 'Dur S. Depth E. Depth Phase Code Subcoder ,T Comment I„ 00:00 04:30 4.50 0 0 COMPZ RPCOM CIRC P Continue to fill hole with 9.6# brine down 7" CSG with returns up 2 3/8" TBG. Total Pumped down IA 396 bbls / Total Return Up Tubing 52 bbls. 04:30 09:30 5.00 0 0 COMPZ RPCOM CIRC P Continue To fill hole w/ 9.6# brine down IA while taking returns thru tubing while discussing with Workover Team plan forward. Pumped 492 bbls Returns 74 bbls wt =9.3 +. 09:30 14:00 4.50 0 0 COMPZ RPCOM CIRC P Shut down charge pump. Filled trip tank and continue filling hole with trip tank taking returns thru tubing. Rate well taking fluid = approx. 4 BPH returns approx. 1.5 to 2 BPH. Total 9.6 brine in = 508 bbls Total returns = 104 bbls. 9.3 +. 14:00 16:00 2.00 0 0 COMPZ RPCOM SLKL T PJSM w/ HES Slickline crew and rig crew. Good overview of hazards of rigging up slickline, good discussion on job responsibilities. Bring all Slickline equipment to rig floor thru beaver slide. RU lubricator and drift tools. RIH w /1.50" x 5' bailer and stacked out at 343'. POOH changed tools to 1.44" drift and stacked out at 347'. POOH, changed tools to a 1.259 ". Stacked out same spot 347'. POOH. 16:00 18:00 2.00 0 0 COMPZ RPCOM CIRC P Continue to fill hole w /trip tank. Total 9.6# in =512 bbls Total returns 9.3 += 108 bbls. 18:00 19:45 1.75 0 0 COMPZ RPCOM SLKL T Crew Change, Attempt to drift tubing with 5' of 1" stem, Set down at 346' slmd, RDMO slick line, Pressure test tubing to 1000 psi and lost 90 psi in first 5 min with no communication to 7" or 9 5/8" CSG. Take pressure back to 1000# and monitor for an additional 5 min.Lost 30 psi second 5 min, bleed tubing to zero. 19:45 22:30 2.75 0 345 COMPZ RPCOM ELNE T PJSM, MIRU E- Line,RIH with 1 11/16 RCT /Anchor 22:30 00:00 1.50 345 0 COMPZ RPCOM ELNE T Set down with e-line @ 345',Log CCL Pass, Unable to set anchor, POOH with e-line and swap out fingers on anchor assembly 10/16/2010 Made two attempts with RCT to cut tubing. Successful cut made on second attempt at 328', RD E -Line and Circulated bottoms up of 9.6# Brine.Ran in with 6" OD Shoe & Washpipe Extension on drill pipe to 343' for outside cutter drift, Broke thread pin off wash pipe leaving 6" OD shoe in the hole over tubing stub. Confer with town and fishing hand and have Baker build hollow tapper tap to retrieve shoe. Two unsuccessful attempts made at time of report end. I Page 4 of 43 • • Time Logs " Date From To Duc S. Depth E. Depth Phase Code - Subcode N' T Comment x: „, 00:00 01:00 1.00 345 0 COMPZ RPCOM ELNE T Back on well, RIH with RCT /Anchor to 345', Log CCL and attempt to set anchor and cut tubing at 332', Anchor not holding, PUH locate collar with anchor dawgs and located collar at 308', Attempt to cut tubing (315' cut depth).POOH stand back _ e -line 01:00 02:00 1.00 0 0 COMPZ RPCOM ELNE T Pick up on tubing and confirm tubing cut, Tubing not cut, Pick e-line back up with new RCT. 02:00 04:00 2.00 0 328 COMPZ RPCOM ELNE T Tubing set in slips with 74k on weight indicator,On depth with RCT, Set anchor and cut tubing at 328', POOH and stand back e-line, PU landing joint and pull on tubing, tubing free. Continue to rig down e -line 04:00 04:30 0.50 328 328 COMPZ RPCOM CIRC P Screw in head pin and circulate bottoms up 9.6# brine, w/9.6# Brine circulated around and back to surface, monitor well (static). 04:30 05:30 1.00 328 0 COMPZ RPCOM PULL P PJSM. RU control line spooler. POOH laying down 2 7/8" tubing. Recovered 9 jts, 2 7/8" tubing, 1- 21.95' cut off jt and Tubing hanger w /4' xover pup. 05:30 06:30 1.00 0 0 COMPZ RPCOM RURD P RD SLB spooler, RU floor to run DP. Set wear ring. 06:30 09:00 2.50 0 343 COMPZ FISH FISH T MU /RIH w /BHA #1. 6" OD Shoe, 2 -jts (62') 5 3/4" wash pipe, boot basket, oil jars and 6 (4 3/4 ") drill collars on 3 1/2" drill pipe. Tagged tight spot @ 55', worked thru by rotating very slow while RIH. Continued RIH tagged top of 2 7/8" tubing stub @ 339'. Rotate very slow and solid stack out @ 343'. 09:00 10:30 1.50 343 0 COMPZ FISH TRIP T POOH standing back DC's. OOH and discovered that 6" shoe broke and is still in hole. Change BHA. MU 6" OD junk mill, Oil jars and 6- 4 3/4" drill collars. 10:30 11:30 1.00 336 0 COMPZ FISH TRIP T RIH and tag top of 2 7/8" stub to confirm top. Tagged @ 336' (8' lower that SLM cut). POOH, break out and LD BHA #2. 11:30 19:00 7.50 0 0 COMPZ FISH OTHR T Wait on Baker Machine for tools for next run. 19:00 20:00 1.00 0 337 COMPZ FISH TRIP T Baker Tools on location, PU /MU hollow taper tap and run in on drill pipe, Run #1 20:00 20:45 0.75 337 338 COMPZ FISH FISH T Set down @ 337.5', 43k Up /43k Dwn, Puh 1' engage top drive and rotate down, Set down and close bumper sub, Witnessed no torque Page 5 of 4 1 Time Logs " Date Fran ' To ' Dur S. Depth E. Phase " Code 111 Subcode T Comm_e t ' 20:45 21:15 0.50 338 0' COMPZ FISH TRIP T POOH,Check Tap Bottom for marks., No good marks to indicate getting over tubing stub. 21:15 21:42 0.45 0 337 COMPZ FISH TRIP T Discuss with Town Eng., RBIH with same, Run #2 21:42 22:00 0.30 337 0 COMPZ FISH FISH T Set down same depth as before 43k Up /39k Dwn, Work up and down while varying rop's and attempt to work over tubing stub. No -Go 22:00 22:15 0.25 0 337 COMPZ FISH TRIP T POOH check tap bottom for marks.Have welder cut 1 inch hook lip on bottom of tapper tap as discussed with Town Eng. 22:15 23:15 1.00 337 0 COMPZ FISH OTHR T At surface, standback dp and breakout tools, Cut 1" Hook Lip on bottom of tapper tap. 23:15 23:33 0.30 0 337 COMPZ FISH TRIP T PU & RBIH on DP with hook lipped tap to top of tubing stub @ +- 337', Attempt to fish washover shoe. 23:33 00:00 0.45 337 0 COMPZ FISH FISH T Make several attempts while varying ROP's and weights. 43k Up/ 38k Dwn, Work down with torque set a minimum to 340' with 1.5k Torq., PU weight now 50k try to ease up slowly and bleed open jars. 10/17/2010 Made four attempts to fish 6" OD shoe with hollow tapper tap, unable to obtain sufficient bite to retrieve shoe. Perform blind back off of 2 7/8" tubing with 5 7/8' Short Catch Overshot plain bottom. Up wt = 40K Dwn wt = 43KTagged top of 2 7/8" tubing @ 336'. Recovered bottom section of cut off 2 7/8" tubing (9.49'). Left 2 7/8" box looking up. Ran spear and recovered 6" shoe. Made two attempts to screw into 2 7/8" tubing stub once with 3.5 "x2 7/8" XO and once with full joint of 2 7/8" tubing. Unable to locate stub. Rig up slickline to drift thru 3.5" workstring and locate stub. Three runs made with slickline LIB's. 1st lib set down @ 346' SLMD two marks 180° apart, 2nd /3rd lib sat down at 347' SLMD, each had one mark that possibly matched with 2 7/8" Tbg collar. 00:00 00:30 0.50 0 335 COMPZ FISH FISH T Continue to work fish up over stub,Pulled free at 335' with max pull 63k (20k over), POOH check for fish 00:30 01:00 0.50 335 0 COMPZ FISH TRIP T At surface check for fish, No fish appears tap ingaged I.D of shoe .63' (7 1/2 ") 01:00 02:00 1.00 0 338 COMPZ FISH FISH T RBIH with same, Locate fish @ 338', PU and tap down with bumber sub, PU 60k and tap down three more times with bumber sub, PUH 63k (10k over), POOH check for fish 02:00 04:00 2.00 338 0 COMPZ FISH TRIP T At surface, Check for fish. No Fish, Confer with Town Eng., Discussing options of having Baker build new tapper tap. 04:00 06:00 2.00 0 0 COMPZ FISH OTHR T Group concensus to run same tapper tap again. RIH tagged up on shoe same depth @338', PU and tap down with bumper sub 10K, PU to neutral Rotate 1 turn. POOH, check for fish, no fish. Page 6 of 43 • ~ ~Time Cogs Date From To Dur S. Depth E. Depth Phase Code _Subcode . T Comment 06:00 09:00 3.00 0 336 COMPZ FISH FISH T MU 5 3/4" overshot, bumper sub, oil jars. RIH to top of fish @ 336'. Attempt to rotate overshot onto 2 7/8" tubing. Overshot going over tubing 5.5" and hitting on top of shoe not letting overshot swallow tubing enough for engagement. After 4 attempts, POOH and inspect cut lip on overshot to confirm. Cut lip on overshot was hitting top of fish (shoe) not letting the overshot swallow tubing. 09:00 11:00 2.00 0 336 COMPZ FISH FISH T MU 5 7/8" Short Catch Overshot plain bottom. Up wt = 40K Dwn wt = 43KTagged top of 2 7/8" tubing @ 336'. Worked overshot down onto tubing. PU 10K over string wt. Rotate to left to back off. Made 14 rnds w/Torque limit max 3K. Backed off and gained 2K on wt indicator. 11:00 12:00 1.00 336 0 COMPZ FISH FISH T POOH standing back drill pipe, break out BHA. Recovered bottom section of cut off 2 7/8" tubing (9.49'). Left 2 7/8" box looking up. 12:00 13:00 1.00 337 0 COMPZ FISH FISH T MU 5 7/8" bullnose spear. RIH engage 6" OD shoe @ 337'. POOH and LD. Recovered 6" OD x 3.56' shoe. 13:00 16:00 3.00 0 345 COMPZ FISH FISH T Load 3 1/2" tubing in pipe shed. Drift to 2.867" and strap. MU 4 11/16" Overshot on 3 1/2" tubing. RIH attempt to engage 2 7/8" tubing collar @ 346'. Stacked out at 345 +. Rotate and attempt to engage w /cut lip guide but not getting down to top of collar. 16:00 17:00 1.00 345 0 COMPZ FISH TRIP T POOH w/3 1/2" tubing and overshot. 17:00 18:00 1.00 0 345 COMPZ FISH FISH T RBIH with 3 1/2" x 2 7/8" XO on 3.5" Tubing and attempt to screw in. Set down at 345' and screw in by hand. 18:00 18:30 0.50 345 0 COMPZ FISH TRIP T Crew Change,PJSM, PU on tubing and confirm if screwed in 40k Up weight. POOH and pick up 2 7/8" joint, appears to be setting down on damaged 7" 18 :30 19:00 0.50 0 345 COMPZ FISH TRIP T At surface stand back 3.5 ", XO was worn around the bottom three threads with a wear mark 9" up on the outside o.d., PU /MU 2 7/8" joint rbih on 3.5" tbg 19:00 19:45 0.75 345 0 COMPZ FISH FISH T On bottom. MU pup joint and screw in with chain tongs, doesn't appear to be making up to tubing stub, POOH check bottom of 2 3/8" joint 19:45 20:30 0.75 0 0 COMPZ FISH TRIP T At surface, Bottom of 2 3/8" joint threads rounded off. Page 7 of 43 • Time L ogs Date From To :,` Dur S. Depth E_ Depth Phase Code Subcode Corom'en 20:30 23:00 2.50 0 0 COMPZ FISH SLKL T RIH with 3.5" tubing and set down at restriction, PU slickline to find tubing stub. Made three LIB run's, 1st with 2.57 OD to 346' SLMD with two marks on leading edge of LIB 180° apart, 2nd with 2.30" OD to 347' SLMD with 1 mark on leading edge that possibly matches up with 2 7/8" collar, 3rd with 2.25' OD to 347' SLMD with 1 mark on leading edge that matches second run. 23:00 00:00 1.00 0 COMPZ FISH TRIP T RDMO Slick Line , PJSM, Pull /Lay down 3.5" tubing 10/18/2010 Milled with 4 5/8" OD Burn Shoe from 340' to 344'. POOH standing back drill pipe and drill collars. Break out BHA. Cleaned out shoe. Retrieved 2 pieces of casing sliver approx. 2.5' long and 3.5" wide. Measurements indicated pieces to be 9 5/8" casing and 7" casing.Displace tubing and annulus with N2, RIH with camera. Camera shows window in 7" and 9 5/8" casing from 338' -341'. Unable to seen 7/8" tubing stub due to fluid level at 343', Shut down N2, POOH lay down E -Line, Fill hole with 9.6# Brine 00:00 04:30 4.50 0 340 COMPZ FISH MILL T MU & Run in 4 5/8" burnover shoe on DP to open 7" and gain access to tubing, Set @ 340' with burn shoe, PU open bumper sub and begin rotating @ 60 RPM, 3 BPM,60 PSI, 50k Up /48k Dwn Weight 04:30 06:30 2.00 340 344 COMPZ FISH MILL T PU and shut down pumps, RBIH set down at 341'. total depth milled = 1', PU begin milling back down. Continue milling from 341' to 344'. @60 RPM w /2K torque, 3 BPM @ 60 pis (charge pump) 50K up 45 dwn and a48 Rot wt. Drill break for approx. 1' (343' to 344') then drill stopped. Wt on bit 1K to 2K. PU to 335', Shut down pumps and rot. Lowered back down and tagged @ 344' w/ 4 -5K. 06:30 07:30 1.00 344 0 COMPZ FISH TRIP T POOH standing back drill pipe and drill collars. Break out BHA. Cleaned out shoe. Retrieved 2 pieces of casing slivers approx. 2.5' long and 3.5" wide. Measurements indicated pieces to be 9 5/8" casing and 7" casing. 07:30 13:30 6.00 0 351 COMPZ FISH OTHR T Discuss Plan Forward with Engineering and Field Supt. RIH w/ open ended 3 1/2" tubing and tagged up @ 351'. PU 2 ", set slips. Install TIW and head pin. Pump thou tubing and establish circulation to confirm lines open. Test hard lines to 2000 psi. Blow down. Page 8 of 43 • Time Logs Date From To Dur S. Depth E. Depth Phase Code ±2 S T Comment.; 13:30 16:30 3.00 351 351 COMPZ FISH OTHR T PJSM w /SLB, HES and rig crew. RU SLB Nitrogen pumping truck. Pumped 40,000 SCF Nitrogen @ 1500 SCF w /300 psi taking returns to kill tank. Shut down and attempt to bleed pressure down starting at 60 psi. 16:30 17:30 1.00 351 351 COMPZ FISH CIRC T RU to circulate 9.6 # brine to kill well. Tubing pressured up immeditately to 560 psi. Held tight, traced all lines and valves to confirm nothing shut. Bled pressure. Switched around to reverse circulate, pressured up to 560 psi immediately, held for 3 min. and pressure fell off all at once. Reverse circulated 9.6# brine around and killed well. 17:30 18:00 0.50 312 312 COMPZ FISH SFTY T RU E -line and SLB pump unit for Nitrogen. Crew change. PJSM w /SLB, HES and crew. 18:00 20:00 2.00 312 0 COMPZ FISH ELNE T RIH with a -line to drift tubing before camera run.Set down @ 270' with e -line, Standback E -Line, Pull 3.5" tubing and rabbit w/ 2.347 while racking back, Tubing clear RBIH to 312' 20:00 20:30 0.50 312 312 COMPZ FISH ELNE T On bottom with tubing, PU E -Line with Expro camera. 20:30 23:00 2.50 312 312 COMPZ FISH ELNE T On line with N2 @ 500 SCFM, Displace tubing and annulus with N2, RIH with camera. Camera shows window in 7" and 9 5/8" casing from 338' -343'. Unable to see 2 7/8" tubing stub due to fluid level at 343', Shut down N2, POOH lay down E -Line, Fill hole with 9.6# Brine 23:00 00:00 1.00 312 312 COMPZ FISH CIRC T 40bbls 9.6# Brine pump, continue to monitor well until decision made on next run 10/19/2010 Run a 5 1/2" Overshot and set down at 342 -ft. Attempted with a 5" Overshot and set down at same depth. Make -up a 4 11/16" Overshot on a "bent" Pup Joint and also set down at 342 -ft. Attempt to re- orientate several times, Unable to get any deeper to overshot the 2 7/8" Tubing. Run in with the 3 1/2" "bent" Pup Joint and went outside the 7" x 9 5/8" damaged Casing to 350 -ft. Attempted several times to re- orientate to get past damaged Casing. No -Joy. Rig up and run Video Camera to further evaluate damaged Casing area. 00:00 02:00 2.00 312 312 COMPZ FISH OTHR T Continue to monitor well, Confer with workover engineer about video results. Discuss plan forward. 02:00 03:00 1.00 0 0 COMPZ FISH TRIP T Pull and standback 3.5" tubing, PU 5 3/4" Packoff Overshot on drill pipe 03:00 04:00 1.00 0 342 COMPZ FISH FISH T On bottom with 5 3/4" OS packoff /grapple, work down to 342', 3 BPM, 11 RPM, 1.6 Trq, 45k Up /Dwn 04:00 04:30 0.50 342 0 COMPZ FISH TRIP T Unable to get any deeper than 342', TOOH wait for new overshot from Baker. Pag9of43 Time Lags Date From To Dur S. berath' E. beoth Phase Code ` Subcode T Comment - .µ 04:30 05:00 0.50 0 0 COMPZ FISH OTHR T At surface, Stand back drill pipe and break out 5 3/4" Overshot. Set down spinners and pick up Eckels. 05:00 07:30 2.50 0 COMPZ FISH FISH T MU 5" Overshot on 3 1/2" tubing. RIH and tag up @ 342'. Rotate to work down inside 7" approx. 5" no go. POOH standing back tubing. 07:30 09:30 2.00 COMPZ FISH FISH T Sent 10' x 3 1/2" pup jt to welding shop and bent for orienting out of hole into casing. MU 5" Overshot w/ bent pup jt on 3 1/2" tubing. RIH and tagged @ 342'. Attempted to orient overshot into 7" casing to get onto the 2 7/8" tubing. No go. POOH standing back tubing. 09:30 11:30 2.00 COMPZ FISH FISH T MU 4 11/16" Overshot w /bent pup jt. on 3 1/2" tulbing again. RIH and tagged @ 342'. Attempted to orient overshot into 7" casing to get onto the 2 7/8" tubing. No go. POOH standing back tubing. 11:30 13:00 1.50 COMPZ FISH FISH T MU 3 1/2" tubing collar on end of bent pup jt and RIH on 3 1/2" tubing. Tag at 350 (outside of casing). PU and rotate 180 deg lower back and tag at same 350'. Attempt this 8 times with same results, cannot get back inside 7" casing. POOH. 13:00 16:00 3.00 342 COMPZ FISH FISH T Put more bend in the 3 1/2" pup jt. MU and RIH on tubing again. Tag at 343', PU and rotate 180 deg. lower back and tag at 342'. Attempt this 5 more times with same results. PU spaced out w /end of tubing @ 342' and top at rotary table. Prep for video log. 16:00 18:30 2.50 COMPZ FISH ELNE T Rig up E -line and N2 Units. 18:30 19:00 0.50 COMPZ FISH SFTY T PJSM with all Nordic, E -line, and N2 personnel. Also Tool Pusher, Baker Fisherman, and Rig Rep. Discuss hazards with multiple operations going on at same time. Discussed pinch points, pressure, and the need for good communications. Page 10 of 43 • Time Logs .. Date From To Dur S. Depth E. Depth Phase Code _Subcode l' T Comment 19:00 00:00 5.00 344 COMPZ FISH ELNE T Pick up Video Camera and completed making up tool string. Cool down N2 Unit. Pressure test N2 line at 2,500 psi. Good. Displace 9.6 lb/gal Brine in Wellbore with Nitrogen. Run in with Video Camera #1 on E -line down to 342 -ft. End of "Bent Sub" appears to be sitting on the bottom of the 7" x 9 5/8" window. Unable to see top of the 2 7/8" Tubing. Pull back to surface with camera. Blow down N2. Fill Wellbore back up with 9.6 lb/gal Brine (42 bbls to fill and get returns.). Rig down E -Line. Mark and turn pipe. Re- orientate the end of the Bent Joint 90 degs left of previous camera position. Slide down past window to 344 -ft. Rig up E -Line and Video Camera #2. 10/20/2010 Continue to investigate damaged Casing. Set Storm Packer at 50 -ft. ND BOP Stack. NU Hydratight Equipment and control 7" Casing growth. 00:00 06:00 6.00 344 COMPZ FISH ELNE T Prep to Run Video Camera run #2. However, now have E -line Unit Engine problems. Runs for —30 seconds then dies, repeatedly. Check fluid levels and kill switches. Call out Nalco Mechanic and Kuparuk Heavy Equipment Mechanics to trouble shoot and make repairs. Unable to find /correct problem in the field. Prep to swap out Units. 06:00 07:00 1.00 COMPZ FISH ELNE T Swap out E -line units, RU new unit. PJSM w /SLB, HES and rig crew on pumping N2. 07:00 10:00 3.00 COMPZ FISH ELNE T Pumped 1500 SCF of N2 @ 140 psi to evacuate tubing and casing for Video Log. Out of end of 3 1/2" tubing A 340', fluid level at 341'. 10:00 10:30 0.50 COMPZ FISH ELNE T RD E -line and SLB N2 unit. Loaded well with KWF 9.6# brine (14 bbls). 10:30 15:00 4.50 COMPZ WELLPFTRIP T Wait on decision from Engineering. POOH w/ 3 1/2" tubing standing back in derrick. 15:00 15:30 0.50 COMPZ WELLPFCIRC T RU to OA. Pump 9.6 down OA taking returns up 7" casing back to pits. Pumped 20 bbls @ 2 BPM w /60 psi. Shut down monitored well, static. 15:30 19:00 3.50 COMPZ WELLPF PACK T PU / RIH w/ 8 - 4 3/4" drill collars, MU Baker Storm Packer and set @ +/- 50'. Pressure test storm packer to 1000 psi. Page 11 of 43 • Time Lags' ., Date From To Dur S. Depth E. Depth Phase Code Subcode T Co 19:00 20:30 1.50 COMPZ WHDBO NUND T PJSM with Rig Crew. Discuss hand safety, overhead loads, checking equipment before using.. Nipple down BOP Stack and set back on Stump. 20:30 21:30 1.00 COMPZ WHDBO NUND T Rig down Wellhead components. Rig up Hydratight Equipment. 21:30 00:00 2.50 COMPZ WHDBO NUND T PJSM with Rig Crew, Cameron, and Hydratight. Discussed pinch points, keep tools picked up, and working in a small work area. Begin to control 7" Casing growth using Hydratight Equipment. Initial snubbing pressure = 15,000 psi. Continue to control 7" Casing growth. At midnight the 7" Casing growth = 11 inches at 6,000 psi. 10/21/2010 Continue to control 7" Csq growth using Hydratight Equip. Total growth = 22 inches. ND Tubing head. Spear Csg. Land Csg in Slips with 10 K tension. Cut Csg. Install Tbg Head. Test Pack -off. NU BOP Stack. Test BOPE. 00:00 03:30 3.50 COMPZ WHDBO NUND T Continue to allow 7" Casing to grow using Hydratight Equipment. Total Growth = 22 inches with 500 psi. Rig down Hydratight Equipment. Nipple down Tubing Head. 03:30 04:30 1.00 COMPZ WHDBO NUND T Make -up Baker 7" Casing Spear. Spear casing. Stretch casing an additional 2.5 inches. Set Slips with casing in 10K tension. Total casing growth with casing in tension = 24.5 inches. Release and lay down spear. 04:30 12:30 8.00 COMPZ WHDBO NUND T Rig up Wachs Cutter. Cut off 17 1/4" 7" 26# casing. Install packoff . NU tubing head. Install valves and flanges that were removed from tubing head during ND. Pressure test packoff to 3000 psi. 12:30 16:00 3.50 COMPZ WHDBO NUND T NU DSA, & BOPE. Wash out BOPE with swizzel stick. 16:00 20:00 4.00 COMPZ WHDBO BOPE P PT BOPE including annular to 250/3500 psi. The State's right to witness the test was waived by J. Jones. 20:00 00:00 4.00 COMPZ WHDBO BOPE T Number 4 Valve on the Choke Manifold failed during the test. Replace Valve and continue with BOP test. 10/22/2010 Complete BOPE test. Release and lay down Storm Packer. Attempt to overshot the 2 7/8" Tubing Collar. Dress 7" Casing just above the Tubing collar with a 5 1/8" Convex Mill. 00:00 01:30 1.50 COMPZ WHDBO BOPE P Continue with BOPE test at 250/3,500 psi. 01:30 02:30 1.00 COMPZ WHDBO BOPE T Unable to get a test with the lower set of 2 7/8" x 5 1/2" VB Pipe Rams. Change out to 2 7/8 " Pipe Rams. Page 12 0€ 43 • . Time Logs ; Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment IHY 02:30 06:00 3.50 COMPZ WHDBO BOPE P Continue with BOPE test at 250/3,500 psi. 06:00 07:30 1.50 COMPZ WHDBO BOPE P RD test equip. Pull test plug. Set wear ring. 07:30 08:30 1.00 COMPZ WELLPF PACK T MU retrieving tool, RIH latch onto Storm Packer, open equalizer. Pull Storm Packer and LD. Rack back 9 -4 3/4" drill collars. 08:30 11:00 2.50 COMPZ FISH FISH T MU and RIH w/ 4 11/16" Overshot on 3 1/2" tubing. Tagg © 341'. Worked down w /chain tongs to 342'. PU MU top drive and re -tag. Worked down to 345' w /top drive wt. but could not get overshot down to top of tubing stub @ 346'. 11:00 12:00 1.00 COMPZ FISH TRIP T Blow down top drive. POOH and examine overshot. Cut lip on overshot rolled in. 12:00 13:00 1.00 COMPZ FISH FISH T MU, RIH w/ 1 jt of 2 7/8" tubing on 3 1/2" tubing. Tagged top of 2 7/8" collar @ 346'. Attempted to screw back into 2 7/8" collar. No luck. 13:00 13:30 0.50 COMPZ FISH TRIP T POOH and examined end of 2 7/8" jt. Last 1" of threads flattened. 13:30 14:30 1.00 COMPZ FISH TRIP T MU and RIH w/4 11/16" Overshot w /5" guide on 3 1/2" tubing. Tagged @ 342' worked down w /chain tong to 343'. MU top drive worked overshot down to 345' with top drive wt. Could not get any deeper. 14:30 15:00 0.50 COMPZ FISH TRIP T POOH and inspected 5" guide on overshot. Same results, the guide lip was rolled in restricting the ID of the overshot guide. 15:00 20:00 5.00 COMPZ FISH OTHR T Consult with Engineering on plan forward. Ordered tools from Baker Fishing shop and wait on delivery. 20:00 22:00 2.00 0 346 COMPZ FISH TRIP T Make -up 5 1/8" Convex MITI. Trip in. Set down at 340.5 -ft. Bring pump on line at 2.0 bpm /80 psi. Worked passed previous "window area ". Rotate at mim rpms and pushed mill down to 345.0 -ft with out stopping at any spot. Made 5 wiper passes with less resistance on each pass without stopping at any spot. Made 1 pass with no rotation, taking 5 - 10 k down weight. Also taking same over pull weights to pull back through.. Increase rotation to 15 RPMs and rotated back down one time to 345.0. Milled from 345.0 - 345.5 -ft. with fast progress. Stopped making same progress at 345 -5 -ft with 5K weight on Mill. Decided that we could be on top of the 2 7/8" Tubing Collar. Trip out with Mill. Page 9 a of 43 Time Logs Date From To Dur S. Depth E. Depth Phase Code. ' Subcodel Comment 1 , 22:00 23:00 1.00 0 COMPZ FISH TRIP T Lay down the 5 1/8" Mill and inspect same. The side of the Mill still indicates that the 7" Casing remains pinched. The face shows the possible marks made from the 2 7/8" Tubing Collar. Change out floor equipment. 23:00 00:00 1.00 346 COMPZ FISH TRIP T PJSM. Make up a 4 11/16" Overshot. Trip in. Set down lightly at —341.0-ft Work down to 345.5 -ft by using chain Tongs to rotate while lightly setting down weight. Continue to work to get over the Tubing Collar. 10/23/2010 Continue to work 4 11/16" OS to get over fish. Continue to attempt to Mill down to the 2 7/8" Tubing Collar. Fish parted Drill Pipe due to "side- loading ". Recovered Fish. 00:00 02:00 2.00 346 0 COMPZ FISH TRIP T Make up Top Drive and get a little more aggressive. Continue to attempt to get over Tubing Collar. No -Joy. Trip out from 345.5 -ft. Lay down 4 11/16" Overshot. Cut -Lip Guide was rolled over — 1 inch. Discuss options and plan forward with Anchorage Engineer. 02:00 05:00 3.00 0 346 COMPZ FISH FISH T Change over floor equipment. Pick -up the 5 1/8 Convex Mill again and trip in to 345.5 -ft. Continue to Mill down to 345.7 -ft. Made slow progress. Then Mill just stopped further progress Trip out to inspect Mill wear pattern. Mill left in hole, parted 6" up on 1stjt of 3 1/2" drill pipe. 05:00 09:00 4.00 0 0 COMPZ FISH OTHR T Wait on grapples for overshot to fish mill BHA. 09:00 10:30 1.50 0 339 COMPZ FISH FISH T MU 4 11/16" Short Catch Overshot on 3 1/2" DP. RIH attempt to latch onto fish (mill) but could not get overshot to swallow 3 1/2' tube. POOH and inspect guide lip. Gouge marks on cut lip as if not going over a proper angle. Dressed off guide on overshot. 10:30 12:00 1.50 339 0 COMPZ FISH FISH T MU and R11-1w/same 4 11/16' Overshot (redressed). Attempt to latch onto fish with same results. POOH. 12:00 13:00 1.00 0 339 COMPZ FISH FISH T MU 5 7/8" Short Catch Overshot on 3 1/2" drill pipe. RIH tag at same spot 339'. Attempt to work overshot onto fish. No luck. POOH inspect overshot. Appeared to be spinning on beveled end of grapple. Page 14 of 43 • Time Logs. 1 1 11 1 ' Date From To Dur S. Depth E.' Depth Phase Code Subcode T .:= Comment 13:00 14:00 1.00 339 0 COMPZ FISH FISH T Changed out 3 1/2" grapple. Replaced w/3 7/8" grapple in 5 7/8' Shot Catch Overshot. RIH tagged at same spot 339', rotate over fish. PU pulling 10 to 15K overpull until overpull dropped off. POOH w /no fish. Inspect grapple and appears to have grabbed but pulled loose. 14:00 15:00 1.00 0 339 COMPZ FISH FISH T Change back to 4 11/16" overshot w /3- 21/32" grapple. RIH tagged fish @ 335' pushed fish back to original tag @ 339' but could not get overshot over top of fish. POOH Inspect overshot again. No signs of getting over fish. 15:00 16:30 1.50 0 337 COMPZ FISH FISH T MU and RIH w/ 5 7/8" short catch overshot w/3 1/2" grapple and 6 - 4 3/4" Drill Collars on 3 1/2' Drill Pipe. Tag up @335', rotate and worked down to 337' stacked out. PU and dragged for approx. 3'. RIH and tagged again @ 335', rotate and worked down to same 337'. POOH. Did not recover fish. 16:30 18:30 2.00 337 0 COMPZ FISH FISH T Make up and run in with 5 7/8" Short Catch Overshot w/ 3 1/2" Grapple and 1 stand of Drill Pipe, 2 stands of Drill Collars, and 2 JOints of Drill Pipe. Tagged at 339 -ft. Worked to latch Fish. POOH. Recovered fish with much joy! Lay down fish and inspect Mill. Mill shows bad side wear. No wear on face. 18:30 22:30 4.00 0 0 COMPZ FISH OTHR T Discuss options and plan forward between Anchorage Engineer, Baker Fishermen, and Workover Supervisors. Decide to pull 7" casing in more tension. Order out and wait on Baker storm packer. Prep to nipple down BOP Stack. 22:30 23:30 1.00 0 60 COMPZ FISH PACK T Bring storm packer to floor. RIH with Drill Collars. Pick -up Baker storm packer. RIH and set at 60 -ft. 23:30 00:00 0.50 COMPZ WHDBO NUND T Begin to nipple down BOPE. 10/24/2010 ND BOPE. Spear Csa. Pick -uo more on 7" Casing in an attempt to straighten out subsidence buckling. Set Slips. NU Tubing Spool and BOPE. Body test BOP. Run Overshot. Run 5 1/8" Bullnose Mill to 344.9 -ft. Run Convex Mill to 347 -ft. 00:00 01:30 1.50 COMPZ WHDBO NUND T Continue to nipple down BOP Stack and set back on Stump. Nipple down Tubing Spool. Pull Pack -off. 01:30 02:00 0.50 COMPZ WHDBOSFTY T PJSM. Rig Crew, Baker Fisherman, Cameron Wellhead Serviceman, and Workover Supervisor. Discussed the hazards in picking up Casing Spear and the possibility that the damaged 7" Casing could part. Page l5 of 43 • • Time Lags Date From To - Dur ` S. Depth E. Phase Code Subcode T Comment 02:00 03:00 1.00 COMPZ WHDBO NUND T Calculated the 7" casing pick-up p weight (Top of Cement for our calculations was based on other Wells worked over and estimated to be near 2,000 -ft) , Drill Collar weight hung off on the Storm Packer, over pull, and a safety factor margin. A total pick -up weight including 10K over to leave casing set in 10K tenson was field calculated to be 109K. Plant casing spear and set grapple. Pull casing weight off of slips at 66K. Continue to pick -up on 7" Casing in 10K increments until) 109K total string weight was reached. Set Slips with the 7" Casing in 10K tenson. The casing was picked up 16.5" . This figure added to the initial 22" gained from controlling the subsidence compression with Hydratight equipment brings the total casing pick -up to 38.5 ". Release and lay down casing spear. 03:00 08:30 5.50 COMPZ WHDBO NUND T Rig up WACHs cutter and cut off the 7" casing. Install pack -off. Nipple up tubing spool. Test pack -off to 3000 psi. 08:30 10:30 2.00 COMPZ WHDBO NUND T NU DSA, and BOP stack. lnstall riser. Set test plug. 10:30 11:00 0.50 COMPZ WHDBO BOPE T Perform body test on BOP stack. Witnessing waved by Chuck Scheve. 11:00 13:00 2.00 COMPZ FISH PACK T Pull Storm Packer and rack back drill collars. RU rig floor for running tubing. Set wear ring. 13:00 15:00 2.00 0 344 COMPZ FISH FISH T MU RIH w/4 11/16" Overshot w/3 21/32" Grapple. Tagged at 340', worked down with chain tongs to 344'. Took 25.5 bbls to fill hole. MU Top Drive for additional wt. Worked down to 345'. When picking up hanging up and pulling loose w /10K overpull. POOH to inspect overshot. 15:00 21:30 6.50 0 0 COMPZ WELLPF SFTY T Discovered that valve had been left open on wellhead after BOP test. Fluid spilled into cellar. Secure well and clean up spill. Page 16 of 43 • Time La gs , Date From T� Dur S_ Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 COMPZ FISH MILL T Resume planned operations. PJSM. Make up 5 1/8" Bullnose Mill. Trip in. Encountered first tight spot at 337 -ft. Bring Pump on line at 3.0 bpm /60 psi. Work through several tight spots between 337' - 342', 2 3K Torque at slow RPMs. From 342' - 344', 1 - 2K Torque. Made very little progress (if any) at 344 -ft. with 5 - 10K weight on Mill, turning at 60 - 70 rpms. Decided to pull Mill to look at pattern and to inspect the area above the first Drill Pipe Tool Joint. POOH. 10/25/2010 Inspect Bullnose wear pattern. RIH with 5 1/8" Convex Mill to 347 -ft. Run Overshot with 5" Cut -Lip Guide to fish 2 7/8" Tbg Collar. Continue with Mill operations. Develope a new plan forward. Rig up to run Video Camera on E -Line. _ 00:00 01:00 1.00 COMPZ FISH TRIP T Finish POOH. Lay down Bullnose Mill. The side of the Mill had expected light normal wear on the leading edge. The face of the Mill had a 1 1/2" circle pattern in the center of the Mill with the Carbide completely worn away. Also inspected the first Drill Pipe Joint above the Mill. There was a "shined" area —2 -ft long. No sign of any "junk -cut" groves. 01:00 04:30 3.50 COMPZ FISH MILL T PJSM. Pick -up the 5 1/8" (under- gauged) Convex Mill (re -run). Run in and set down at 337.0 -ft. Bring pump on line at 3.0 bpm /60 psi. Work down from 337.0' - 343.5' with slow rotation. Saw a few "bobbles ". Take weight at 343.5 -ft. Increase RPMs to 70. Torque at 1 - 2K. Weight on Mill 5 - 8K. Continue making steady gradual progress down to 345.5 -ft. Observe a "Milling break" down to 347.0 -ft (S -Line top of Tubing tag depth). Took solid weight. Pulled up hole to 335 -ft. Went back down to 347 -ft again with slow rotation with no problems. 04:30 05:00 0.50 COMPZ FISH TRIP T Trip out to look at Mill pattern and inspect Drill Pipe Joint just above the Mill. Lay down Mill. Inspect Convex Mill. Face has a flat wear pattern. The Joint of Drill Pipe just above the Mill had a possible "junk strach" starting. Page 7of43 • • Time Logs Fr Date From To Dur S Depth E. Depth Phase Code Suhcode T ent > 05:00 07:30 2.50 0 351 COMPZ FISH FISH T Make Comm up Overshot with the 5" Cut Lip Guide. RIH on 3 1/2" tubing Tag @ ' k to 350' MU Drive and work down to 350.. 6'. When picking wor up pulls approx. 1 OK over Top wt. and lets go. POOH down to inspect overshot. 342 07:30 10:30 3.00 0 351 COMPZ FISH FISH T Inspect ers Gu has OD polished and lip guide pinched in s lightly . MU 1 jt of 2 7/8" tubing RIH on 3 ov 1/2" hot. drill pipe. ide Tagged @ and 3' u t tagged @ 350', worked down hru. to RIH p 350.5 w ould 1/2 not turn screw and in, 0 overull pick u POOH inspect fell end of 2 7/8" ing tubinpq no she marks, CS no flat threa 10:30 14:00 3.50 0 346 COMPZ FISH FISH T Load d 1" y pi. Change pipe floor over w/ to 3 1/2 Drilll Pipe. MU 4 11/16" Overshot w /5" 3 1/2" Drill dril Guide and RIH on Pipe. @ ' established n. RIH tagged up @ 343', worked down t 346' stacked blish out, could not get circulatio any o deeper. 326 Blow down top drive, POOH. rshot, leading rolled over to inside ove approx. 1/8 " 14:00 16:00 2.00 0 353 COMPZ FISH MILL T MU and RIH w/5 1/8" Bull Nose Mill. Tagged up @ 346' established circulation 3 BPM @ 60 psi Started rotating 50 rpm. Free torque 1 K rotate down no torque less than 1K on bit to 353' Started getting gravel & A5' circul & ate hole Pack. clean. PU POOH. 16:00 20:30 4.50 0 342 COMPZ FISH FISH T RU tools rctic on floor for running 33 1" Hydril MU &RIHw /1 " mule shoe, o 3 jts of 1" Hydril crossing over to 3 1/2" drill pipe. Lightly tagged up at 342 -ft. Pull back up hole and rotate gs re M Shoe. t. Ease back down and tagged at the same 180 de place to with - orientate 2K set-down ule weigh Abort any further aggressive mm tubulars. POOH. Lay dow n the all CS Hydril Tubing. pts 20:30 21:00 0.50 COMPZ TRIP T Run atte in with due 3 1/2 Tubing to 292-ft. e fo a e Vd Camera run. 21:00 23:30 2.50 , COMPZ FISH FISH ELNE T PJS M with Rig -lin Crew , DS, Halco, Baker Rig r Rep. Discuss Hazards associated with Ni and E -line opes conditio ns, safe area, and ha weather nd placement. Rig up N2 Unit. ed Rig up E -Line equipment. Also discus Pick -up Video Camera Tool String. Page 18.of43 • • Time'Logs Date From To Dur S. Depth_ E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 COMPZ FISH ELNE T Cool down N2 Unit. Pressure test line at 2,500 psi. Good. Ease Camera down hole. Bring N2 on line at 500 scfm /240 psi. 10/26/2010 Complete Video Camera run. Cut 7" Casing with MS Cutter. Set Storm Packer. ND BOP. Gas was bubbling from the 7" casin•. NU and shell test BOP. Pull storm •acker. Circulate IA and OA. Set storm •acker. Nipple clown ROP Stack and Tuhinn Spool. Spear ('asing and pull Slips 00:00 01:30 1.50 COMPZ FISH ELNE T Continue downhole with Video Camera and drop out of the end of the 3 1/2" Tubing at 292 -ft. Locate a 7" Casing Collar at 302.1 -ft. Inspect area below the collar at —307 -ft for planned cut. Good. Continue down with Camera. Fluid level at 334 -ft. Increase N2 rate to 700 scfm and attempt to drive fluid deeper. Got down to 337 -ft. Found the top of the first Casing damaged window now at 337 -ft (the top of this damaged area was found at 340 -ft dpmd before the 7" Casing was "stretched "). Attempted to get deeper with Camera. However, fluid level remained at 337 -ft. Camera went "black" when it entered fluid and Tool String took weight just as soon as we tried to run deeper. 01:30 03:00 1.50 COMPZ FISH ELNE T POOH. Rig down N2. Rig down E -Line. 03:00 05:00 2.00 COMPZ WELLPF CUTP T Pick -up Baker MS 5 1/2" Cutter, dressed to cut 7" Casing. Max Blade swing = 8 1/2 ". RIH w/ MS Cutter, 2 stands of Drill Collars, 1 stand of Drill Pipe, plus a single Drill Pipe. Bring pump on at 4.0 bpm /540 psi for base line high pressure. Reduce rate to 2.0 bpm /150 psi. Drop down and locate 7" Collar at 302 -ft (dpmd same as Camera depth). Shut down pump. Drop down to 315 -ft. Pull back up to 307 -ft. Turn Top Drive on to 60 RPMs. Slowly increase pump to 4.0 bpm /540 psi. Begin cut. Increase rate to 4.3 bpm /700 psi. Saw a 200 psi pressure drop. Casing cut in 5 minutes. Continue for 2 extra minutes. Shut down pump. Verify cut. POOH. Lay down MS Cutter All 3 Blades recovered and had expected normal wear. 05:00 07:00 2.00 COMPZ WELLPF PACK T Run in with 8 ea 4 3/4" Drill Collars with Storm Packer & set Packer @ 60'md. 07:00 10:30 3.50 COMPZ WELLPF OTHR T Kickout Tools & Equipment from Rig Floor. Pull Wear Ring. Wait On Plan Forward From Town Engineer. Page 19of4 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T II Comment = 10:30 11:00 0.50 COMPZ WHDBOSFTY T PJSM. Discuss Plan Forward From Town & Hazard Associated with ND of BOPE and Removing of Tubing Head. 11:00 15:30 4.50 COMPZ WHDBO NUND T Bleed Gas From OA. Fill OA With 9.6 brine. ND BOPE and Prep To Pull Tubing Head. Having Gas Readings on 7" Casing. COMPZ WHDBO NUND T NU BOPE to Pull Storm Packer and Fill 7" with 9.6 ppg Brine. 15:30 18:00 2.50 COMPZ WHDBO BOPE T Fill BOP Stack. Function Test. Shell test at 250/3,000 psi. Good test. 18:00 20:30 2.50 COMPZ WELLPF PACK T Release and pull Storm Packer. Inspect same and found formation gravel behind slips. Circulate both the IA and the OA x 3 volumes each at 3.0 bpm /50 psi. Re -run Storm Packer at set at —60 -ft below surface. Test same at 1,000 psi. Good. 20:30 23:30 3.00 COMPZ WHDBO NUND T Nipple down BOP Stack. Nipple down Tubing Spool and remove Packoff. 23:30 00:00 0.50 COMPZ FISH FISH T Pick -up Baker Casing Spear. Plant Spear in 7" Casing. Pull 100K to free Casing at the "cut ". Pull Casing at 55K to a Collar to retrieve Slips. Remove Slips. Run back down with no problems and stack Casing out on the cut -off stump. Release Spear and lay down same. 10/27/2010 •••- •:•• _ , . - -- - -•• ••,. •o• - •.. • •. RIH.with Spear and recover 7" Cut -off Casing Stump. Discuss plan forward. Continue with Fishing Operations. 00:00 04:30 4.50 0 0 COMPZ WHDBO NUND T Nipple up 11" 3K x 13 3/8" 5K Adapter Flange. Nipple up BOP Stack. 04:30 05:00 0.50 0 0 COMPZ WELLPF PACK T Release and lay down Baker Storm Packer. 05:00 05:30 0.50 0 0 COMPZ WELLPF PULL T MU 7" CSG Spear & Engage 7 ". 05:30 06:00 0.50 0 0 COMPZ WELLPFSFTY T PJSM. Discuss Pulling CSG, Pinch point. Slips Trips and Falls.Handling CSG. Unloading CSG 06:00 09:00 3.00 0 0 COMPZ WELLPF PULL T Recover 6 Full Joints of 7" CSG Total 244.89 ft) and Two Cut Joints. Top Cut =5.55 ft and Bottom Cut =27.95 ft. Total 7" CSG Recover 307 feet. Leaving 36' ft Stub Looking Up. Up Wt =45k. Recover Two Centralizer. Joint 2,3 & 5 Was Bent with Dogleg. 09:00 09:30 0.50 0 COMPZ WELLPF PULD T Kick Out 7" CSG. Load DC, DP, and Baker tools 09:30 10:00 0.50 COMPZ WHDBOCIRC P Wash BOP Stack. Page 20 of 43 • Time !',71 s Date Frain To Dur S Depth E. Depth Phase Code Subcode T Comment 10:00 10:30 0 COMPZ WHDBO SFTY P PJSM For BOP Testing. Discuss Fluid Path. Spills, Pinch Points, High Pressure. 10:30 12:00 1.50 COMPZ WHDBO BOPE P Set test Plug. Perform Shell test On BOPE. 250/3000 psi. 12:00 12:30 0.50 COMPZ WHDBO BOPE P BOPE Tested Good. Bleed Down Psi. Pull Test Plug. 12:30 15:30 3.00 COMPZ FISH PULD T Load Pipe Shed w/ 5" Drill Pipe and 6 1/4" Drill Collars. Rack & Tally AII. 15:30 16:00 0.50 COMPZ FISH SFTY T PJSM. Discuss Running Order Of BHA. Pinch Point & Hand Placement. Overhead Loads and Heavy Iron. 16:00 18:00 2.00 0 307 COMPZ FISH PULD T Make up BHA to Spear 7" CSG @ 307' and as follows: 5 3/4" ITCO Spear, Spear Extension, Stop Sub, XO Sub, Bumper Sub, Oil Jar, XO Sub, 6 ea 6 1/4" Drill Collars, Accelerator Jar, 5" Drill Pipe to surface. 18:00 20:00 2.00 307 345 COMPZ FISH FISH T RIH with BHA. Pick up weight = 51 K. Down weight = 55K. (correct weight parameters) Plant Spear in the 7" Casing cut -off Stump at 307 -ft. Picked up to "pop" Jars to set Spear Grapple. However before Jars could unload, Fish came free at 8K over string weight. POOH with BHA and Fish. Lay down recovered Fish. Length = 36.18 -ft. Pin end was mangled and partly missing. 12 inches above the pin end the Joint is severed approx 75% (most likely from parted 9 5/8" Casing. The "milled window" in the 7" Casing body is 5 -ft above the pin end. The bottom of the Joint is bent/bowed approx 30 Degs. 20:00 22:30 2.50 0 0 COMPZ FISH OTHR T Clear and clean Floor. Discuss options and a plan forward with Anchorage Engineer. Rig up Floor to handle 3 1/2" Drill Pipe. 22:30 00:00 1.50 0 COMPZ FISH FISH T PJSM. Make up 5 3/4" Overshot w/3 21/32" Grapple. Start RIH. 10/28/2010 Continue attempting to fish 2 7/8" tubing. Run Video Camera. Begin milling operations w/ 6 1/8" mill trying to re -enter 7" casing.. Page, 21 of 43 • ! Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 342 COMPZ FISH FISH T Continue to run in with 5 3/4" Overshot. Tagged up at 342.0 -ft. Worked Overshot many times in an attempt to make a lucky blind catch on the 2 7/8" Collar. No -Joy. The 2 7/8" Collar appears to be below the top of the 7" Casing and /or the damaged 9 5/8" Casing. Blow down Top Drive. POOH. Lay down Overshot. Inspect overshot. Broke off a small piece of metal from the Cut -Lip Guide. Marks on the outside of Overshot indicates going beside something. 02:00 06:00 4.00 0 0 COMPZ RIGMNTSVRG P Clear and clean Floor. Inspect and service Top Drive. General rig service and maintenance. Kick out Fishing Tools from Pipe Shed not needed anymore. Alert Services needed for Video Camera run in the morning. 06:00 08:00 2.00 0 0 COMPZ FISH OTHR T PJSM. Crew Change Out. Call SLB Pumping Out From Deadhorse. Call HES E -Line. Order Out 1 Load Of Hot Seawter From CPF 1. 08:00 11:00 3.00 0 0 COMPZ FISH CIRC T RIH w/ 3.5" Drill Pipe down to 340' and and Started Circulating @ 4 bpm -60 psi while waiting on Seawater. ( HES E -Line & SLB On Location) 11:00 11:30 0.50 0 0 COMPZ FISH CIRC T Seawater on Location & Unload to Pits. 11:30 12:30 1.00 0 0 COMPZ FISH CIRC T Circulate 150 bbls Hot SeaWater around @ 11 bpm - 120 psi. Monitor Well after Circulating. Blow Down TD, RD Pumping Equipment. Install TIW Valve, Pump - Sub and XOver For E- Line.( SLB Pumping Crew Change Out ) 12:30 13:00 0.50 0 0 COMPZ FISH SFTY T PJSM with HES E -Line, SLB Crew And Expro Video. 13:00 14:00 1.00 0 COMPZ FISH ELNE T MIRU E -Line & Video Equipment. 14:00 16:00 2.00 COMPZ FISH ELNE T PT N2 Treating Iron, 250/2500 psi. Test Look Good, On Line Down DP @ 500 scfm. RIH with E -Line & Expro Video Log down to 340' and and Log Damage area from 310' to 340' md. 16:00 18:00 2.00 COMPZ FISH ELNE T Load Well With 9.6 ppg Brine & Monitor Well For 30 mins. POOH and Download Data.Rig Down SLB N2 Pumper & E -Line Equipment. Page 22 of 43 • • Time L49s „ Date ' From To Dur S. Depth E. Depth Phase Code Subcode TdTHComment 18:00 18:00 0.00 0 342 COMPZ FISH MILL T PJSM. Make up 6 1/8" Concave Junk Mill BHA as follows: 6 1/8" MITI, Bit Sub, 1 ea 4 3/4" Drill Collar, XO Sub, Bumper Sub, Oil Jar, XO Sub, 6 ea 6 1/4" Drill Collars, XO Sub, Acc Jar, 5" Drill Plpe to surface. RIH and tag at 342ft. Up Weight = 54K. Down Weight = 56K. ROTW = 55K. RPMs = 40. Pump Rate = 5.0 bpm /90 psi. Torque = 1 - 1.5K. WOM - 0 - 2K. Begin milling at 20:58 hrs. at 342.0 -ft 10/29/2010 Continue with milling operations. Made an attempt to fish for the 2 7/8" Tubing Collar. Perform weekly BOPE test. Suspend operations to evaluate and improve safety performance. Well secure. 00:00 05:00 5.00 344 0 COMPZ FISH MILL T Continue Milling. Progress at midnight = 342.3 -ft then approximately a 6" milling break. At 01:00 hrs = 343 -ft. At 01:30 hrs = 344.0 -ft 7" Collar depth. Returns so far = Small amount of grey silt/Arctic Pack, with some specks of metal. Continue milling at 344.0 -ft. with no fluid loss. At 03:00 hrs, depth = 344.3 -ft. Returns same. No sign of gravel or coarse sand in returns. Milling is "spongy ". Pull back up hole to 337 -ft. End rotation. Easy back down hole to 339.5 -ft. Then had to rotate to get down to 341.5 -ft with the mill jumping and trying to bind up. We feel that this is the 2 -ft window. Once passed 341.5 -ft rotation was stopped and mill continue down to 344 -ft. (7" Collar depth) with 2K down weight. At 344.3 -ft Tag was solid. POOH to inspect Mill pattern. Mill shows some side wear. The face shows a reasonably good possibility that we are on the 2 7/8" Collar. Lay down Mill. Injury occured to floorhand while breaking out collars. Tongs unlatched from stored position and swung towards well center striking floorhand in the back. 05:00 06:30 1.50 COMPZ FISH PULD T Clean & Clear Rig Floor. Swap Out Floor Equipment. 06:30 08:30 2.00 0 346 COMPZ FISH FISH T PJSM. MU 5 3/4" Overshot on 3.5" TBG. RIH to 343' and and set down same. Was able to rotate and work past tag depth down to 346' md. Made several attempts to work over top of 2 7/8" TBG collar with no success. 08:30 09:30 1.00 346 0 COMPZ FISH TRIP T PJSM. Blow Down T /D. POOH from 344' and and Lay Down BHA. Page 23 of 4 • - . - Time Logs Date From To Dur S. Depth_ E. Dept Phase Code Subcode . T Com 09:30 10:30 1.00 0 0 COMPZ WHDBO CIRC P MU Tools & Wash Out BOP Stack. 10:30 11:30 1.00 0 0 COMPZ WHDBO BOPE P MU & Set Test Plug and Rig Up Testing Equipment. 11:30 18:00 6.50 0 0 COMPZ WHDBO BOPE P PJSM. Testing BOP. Perform weekly BOPE test at 250/3,000 psi.. Good. Perform Koomey draw down test. The State's right to witness the test was waived by B. Noble. Tests were recorded on chart. 18:00 00:00 6.00 0 COMPZ WELLPF TRIP T Secure Well as follows: Run in with 4 3/4" Bull Nose, 3 stands of 3 1/2" Drill Pipe, XO, Double Pin Sub, Test Plug, 1 Joint of 5" Drill Pipe, TIW Valve. Close Pipe Rams. Close OA Valve and install gauge to periodically open and monitor for any pressure build -up. Tubing and IA pressure monitored at choke manifold. Move fluid through circulating system occasionally to prevent any freezing problems. Continue to monitor the general nearby ground area around 2T -13 Well. Decision has been made to cease operations and focus on HSE improvements due to recent spills and injuries. 10/30/2010 Continue to suspend operation to evaluate and improve Safety Performance. Well remains secure. Monitor Well. Monitor General surface conditions in nearby area around 2T -13 Well. Maintain Rig. 00:00 00:00 24.00 COMPZ WELLPF SFTY T Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Schedule Safety Planning sessions for later in the day. Schedule Tap Root Investigation meeting. 10/31/2010 00:00 00:00 24.00 COMPZ WELLPF SFTY T Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Schedule Safety Planning sessions for later in the day. Weekly Safety Meeting & SLT Meeting. Perform Safety Drill & Check Safety Devices. Conduct Hazard Hunts. 11/01/2010 Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Safety Planning sessions continue. Weekly Safety Meeting & SLT. Pag24of43 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T .'Comment 00:00 00:00 24.00 COMPZ WELLPF SFTY T Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Continue to improve on Nordic's commitment to improve safety performance. Perform Safety Drills & Check Safety Devices. Conduct Hazard Hunts. Notify AOGCC on 11/1/2010 @ 1850 PM, that operations are scheduled to resume at 12:00 hrs 11/02/2010. Witnessed was Waived By Bob Noble @ 1855 PM On testing the BOPE. 11/02/2010 Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Continue to improve on Nordic's commitment to improve safety practices. Held Pre -start up inspection and open up well. POOH with 3 1/2" DP kill string. Test Annular and UPR's that were used for shut down at 250 / 3.000 osi. ,PU and MU Milling BHA #41, RIH to 344' and mill to 345'. 00:00 11:30 11.50 COMPZ WELLPF SFTY T Continue to maintain Rig. Continue using the "buddy- system" during environmental walk -a- rounds. Move fluid through circulating lines. Monitor Well pressures at 0 psi. Well remains secure. Continue to improve on Nordic's commitment to improve safety performance. Perform Safety Drills & Check Safety Devices. Conduct Hazard Hunts. 11:30 12:00 0.50 COMPZ WELLPFSFTY T Plan Forward Meeting & Pre -Job Safety meeting. Discuss next Job Task and Hazard Associated With The task. 12:00 13:30 1.50 COMPZ WELLPFSFTY T Perform Walk Thru on Rig Before Starting Normal Rig Operations. Check Circulation System, BOP Control System. Check Valve & Piping. Check for pressure on well & open BOPE. 13:30 14:30 1.00 COMPZ FISH TRIP T POOH and Standback Drill Pipe. 14:30 16:30 2.00 COMPZ WHDBO BOPE P PJSM. M/U & Set test Plug. Functions and test Test VPR's 250/3000 psi. Pull Test Plug. Rig Down Test Equipment. 16:30 18:30 2.00 COMPZ FISH TRIP T PJSM. Rig Up Milling BHA. RIH to 344' Up Wt= 55k / Down Wt= 55k. ROT .55 18:30 00:00 5.50 COMPZ FISH MILL T Milling @ 344' - 345' at 40 rpm's w/ Torque @ 1 -2k. Circulating at 5 bpm @ 80 psi. 11/03/2010 Continue to mill from 345' to 347'. POOH and laydown milling BHA #41. PU and MU BHA #42 -5 3/4" OS assy. POOH and PU Milling BHA. RIH and Mill from 339 -ft. to 345 -ft. Page 26 of 43 l Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode 1 T 1Commerrt 00:00 01:00 1.00 345 347 COMPZ FISH MILL T Continue to mill from 345 -ft to 347-ft. with 1k torque. 01:00 02:30 1.50 347 0 COMPZ FISH TRIP T POOH and lay down BHA #41 - mill face showed signs milling all the way across. 02:30 03:00 0.50 COMPZ FISH OTHR T Clean and clear floor 03:00 03:30 0.50 COMPZ FISH SFTY T Held PJSM on making up BHA #42 03:30 04:30 1.00 0 337 COMPZ FISH TRIP T PU and MU BHA#42 (overshot) and RIH to 337' 43k up wt, 45k do wt. 04:30 06:00 1.50 337 356 COMPZ FISH FISH T Continue to RIH and tag up 353 -ft and continue to work down to 356 -ft - seen pressure increase and unable to engage. Had up to 35k OSW pulls multiple times. 06:00 07:00 1.00 356 0 COMPZ FISH TRIP T POOH to inspect control and grapple - found the cut lip guide to tapered in from 5 3/4" to 5 1/4 ". Inside body of 5 3/4" grapple was untouched from fishing attempt. 07:00 09:30 2.50 0 0 COMPZ FISH OTHR T Discuss Plan Forward with Town Engineer, Wells Supervisor and Baker Fishing Rep. 09:30 11:30 2.00 0 0 COMPZ FISH OTHR T Order Out Equipment & Tools from Baker Fishing Shop. 11:30 12:00 0.50 0 0 COMPZ FISH OTHR T Tools On Location. Un -Load Tool and Load to Rig Floor. 12:00 12:30 0.50 0 0 COMPZ FISH SFTY T PJSM. Discuss Hazard For Making Up BHA. Donnie With BOT Presented the Safety Topic. 12:30 14:45 2.25 0 243 COMPZ FISH PULD T MU Baker BHA #43 - junk mill for milling up 9 -5/8" and 7" casing. Trying to mill past dog leg and find original hole. 14:45 15:00 0.25 243 243 COMPZ FISH SFTY T PJSM. Discuss Milling Operation. Discuss Weather Condition. Discuss Well Control while milling at shallow Depths. Use Buddy System while performing Spill Campion Check List outside and around Cellar. 15:00 15:30 0.50 243 243 COMPZ FISH MILL T Set Parameters. ICP =40 psi, 1K Free Torque, 60 RPM, ROT =55, Up Wt =55k / Down =57K, SPM =106, Rate =5 bpm. Vis -Up Brine for Milling Operations. 15:30 22:45 7.25 243 345 COMPZ FISH MILL T Set Down With Milling Assembly @ 339'md. Start time milling operations from 339 -ft. to 343.5 -ft. Seen drlg break, continue to time mill down to 344.5 -ft. 22:45 23:00 0.25 345 341 COMPZ RIGMNT SVRG P PU from 345 -ft. to 341 -ft. Held HISS, Man rider permit and verbally review procedure on Service of Top drive. Grease wash pipe packing. 23:00 00:00 1.00 341 345 COMPZ FISH MILL T Slide down and Tag up at 344.5 -ft., Continue to milling at same parameters from 344.5 -ft to 345 -ft. Page 26 of 43 • Time Logs Date 1 From To _ Dur S. Depth E. Depth Phase Code Subcode T Comment 11/04/2010 24 hrSummaiv Continue to Mill at 345 -ft. POOH from 345 -ft. Inspect mills. MU Milling BHA #44. RIH w/ BHA #44 to 220 -ft. Slip and cut drill line. RIH to 343 -ft and Begin milling._ Mill down to 355 -ft and exited CSC, , 00:00 01:00 1.00 345 345 COMPZ FISH MILL T Continue to mill at 345 -ft. with 5k WOM and no torque. Not able to make any hole. 01:00 01:30 0.50 345 345 COMPZ FISH SFTY T Held PJSM with crew on tripping DP _ and Breaking down BHA. 01:30 03:00 1.50 345 0 COMPZ FISH TRIP T Blow down Top Drive. POOH and Inspect mills, found possible pattern of 2 7/8 TBG coupling on 3 1/2 Mill nose. and wear on 8.5" OD mill above. 03:00 03:30 0.50 0 0 COMPZ FISH SFTY T Held PJSM with rig crew on Bring tools up Beaver slide, along with _ Breaking down and MU of BHA. 03:30 04:30 1.00 0 0 COMPZ FISH OTHR T Bring Mills for BHA #44 to rig floor 04:30 06:30 2.00 0 244 COMPZ FISH PULD T Break mills and MU BHA #44 and RIH to 200 -ft. 06:30 09:30 3.00 200 200 COMPZ RIGMNT SLPC P Slip & Cut 84' ft of Drilling Line. 09:30 11:00 1.50 200 200 COMPZ RIGMNT SVRG P PJSM. Grease Wash Pipe. P/U 1 Stand of Drill Pipe. (Went on Generator Power @ 10:45 am. Lost Shore Power.) 11:00 15:15 4.25 344 345 COMPZ FISH MILL T TIH to 343' MD. Set Parameters. RPM, 60, ROT 57 / 1k Free Torque, Up wt =55k / Down Wt =57k 105 SPM = 5 BPM/ ICP =250 psi. Starting Milling Depth 343' for milling operations. 15:15 16:00 0.75 345 345 COMPZ FISH MILL T Pump High -Vis Sweep, Seen small amount of Metal shaving @ shaker. Continue with milling operations. 16:00 22:30 6.50 345 355 COMPZ FISH MILL T While milling ahead @ 345'md, Setting 5 to 8k down weight, seen good milling break, set 8 to 10k down weight and seen milling break and milling assembly dropprd to 347' md, continue milling down to 354.5' and 22:30 23:00 0.50 355 355 COMPZ FISH CIRC T Pump hi visc sweep @ 5 bpm @ 250 psi 23:00 23:30 0.50 355 355 COMPZ RIGMNTSVRG P Held PJSM on serviing top drive and filled out LOTO and Man rider permit. Send hand up on service winch and grease wash pipe. Close out man rider and LOTO. 23:30 00:00 0.50 355 355 COMPZ FISH MILL T Begin milling at 354.5 -ft and exited CSG at 355 -ft. Attempt to relocate and restart milling process, but was unable to stay in casing. 11/05/2010 PJSM and POOH and lay down BHA #44, inspect mill, PJSM, PU and RIH w/ BHA #45, Engage fish and pull strain. PT TBG at 800 psi for 15 minutes. RU slick line and RIH, set down at 347 -ft. Continue to work past 347 -ft. 00:00 00:30 0.50 355 355 COMPZ FISH SFTY T Held PJSM on POOH and laying down DC's and mills. Page, 27 of 43 Time Logs Date From To Dur S. Depth L. Depth Phase ' Code Subcode T ''Comment 00:30 01:30 1.00 355 154 COMPZ FISH TRIP T POOH, stand 1 stand of 6.25" DC's. 01:30 03:30 2.00 154 0 COMPZ FISH PULD T Lay down milling BHA #44. Inspect mill for pattern. Showed to milled down side of 7" and 9.625" CSG till locate TBG cplg and jumped off _ exiting CSG strings. 03:30 04:00 0.50 0 0 COMPZ FISH SFTY T Held PJSM on making up 5.75" OS and RIH on DP. 04:00 06:00 2.00 0 COMPZ FISH TRIP T PU and MU 5.75" OD Overshot BHA #45, RIH on 1 stand of 3 1/2 DP, X -O, 5" DP to 345'. 06:00 07:00 1.00 COMPZ FISH OTHR T Discuss Plan Forward with Town Engineer. Crew Change Out. 07:00 08:00 1.00 COMPZ FISH TRIP T PJSM w /Baker & Rig Crew. POOH and Inspect Overshot. Seen Indication marks on the Inside of Grappel. 08:00 11:00 3.00 COMPZ FISH TRIP T PJSM s/ BOT. RIH w/ 5" DP & Overshot. Set Down At 353.40 md, & Set 8k down and Pick up 73k and seen good indication of Latching 2 7/8" . Pressure up on DP x Tubing to 800 psi and held psi for 15 mins. Dispatch Slick -line for Attempt to Drift Inside 2 7/8" TBG. 11:00 12:00 1.00 COMPZ FISH PULD T PJSM. Off Load Baker Tools. Clear Floor of Tripping Hazard. 12:00 12:30 0.50 COMPZ FISH SFTY T PJSM w/ HES & Rig Crew. Discuss Hazard of Loading Slick -line Equipment to Rig Floor. Page 28 of 43 • - • Tune Lags Date From To Dur S. Depth E. Depth Phase Code Subcode ; T Comment 12:30 00:00 11.50 COMPZ FISH SLKL T MIRU Slick -Line. Load Lubricator Section From Unit To Rig Floor. Hoist Up Tools & X -O. MU .125 wire, 15' of 1.5" Stem (5', K -jar, 5', K -jar, 5'), oil jar, K -jar, and SS. RIH w/ 5' of 2" bailer and set down at 346 -ft slm. Unable to get by, POOH and seen 1 small mark. RIH w/ 1.9" LIB to 346 -ft and set down, Tap down lightly, POOH seen slight mark on face. RIH w/ 1.75" OD bailer and set down at 347 -ft, POOH - bailer was empty and no marks. RIH w/ .75" OD prong, set down at 347 -ft. POOH. RIH with 1.73" swage and set down at 347 -ft., beat down, pull bind and pull right out. POOH and had no marks. RIH w/ 3 prong grab and set down at 348 -ft. pull bind and come free, set back down, beat down pull bind and come free. POOH with no marks. RIH w/ 1.73" OD swage and set down at 348 -ft. Beat down many times and unable to get tools to stick. made several more attempts with same result. POOH with swage - no marks. RIH w/ 2.25" OD LIB and set down at 347', beat down several times and POOH with tools. Marks on LIB, looks like rolled TBG. RIH w/ 1.5" Bailer and set down at 347 -ft. POOH and had marks. RIH w/ 1.73" OD swage and set down at 347 -ft attempt to beat down, unable to stick. POOH - No marks. RIH w/ 2.25" OD LIB and set down at 347 -ft. Tap and POOH - had marks of possible rolled TBG. Lay down equipment and back off overshot by 6" and re land in slips at 90k. 11/06/2010 Continue to attempt to work past 347 -ft with 1.73" OD swage. RD slickline. Back off TBG. Circulate 2 hole vol. POOH with fish. Wash BOP stack. Conduct weekly BOP tast, PU and MU BHA #47 and RIH to 131 -ft. 00:00 04:00 4.00 COMPZ FISH SLKL T Continue to attempt to work past 347 -ft. After all attempts no progress was made. RD slick line and load out. 3 Page 29 of 43 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ill Comment 04:00 04:30 0.50 COMPZ FISH BKOF T Pick string up to 75k and work 3 rounds of LH torque into string, Work string from 75k to 50k 3 times. Continue the same process for 8 sessions. Attempt to unscrew 2 7/8 TBG with another 57 rounds of left hand rotation - No torque. PU to 90k and rotate 3 turns to the left - seen weight bleed off on indicator. Drop weight back to 60k and pressure up to 800 psi - rotate to the left 13 rounds and pipe unscrewed. Had 5 -6k gain above fishing string weight of 45k. 04:30 05:00 0.50 COMPZ FISH CIRC T Circulate 100 bbls @ 4 bpm, 250 psi for a calculated back off depth of 2,000 -ft. equal to 2 hole volumes. 05:00 05:30 0.50 COMPZ FISH SFTY T Held PJSM on POOH and laying down fish. 05:30 08:00 2.50 1,090 743 COMPZ FISH TRIP T POOH and release OS. Continue to POOH laying down fish. Upper Section of 2 7/8" TBG was Rolled Over Into Itself, which is why Slick -line was unable to Drift Thru. During Milling Operation, the 2 7/8" TBG had been Shaved Down the Side. 08:00 08:30 0.50 743 743 COMPZ FISH SFTY T PJSM. Discuss Hazard of Pulling and laying down 2 7/8" TBG. Fished 1 Joint of 2 7/8" TBG, 26.06' Long. 08:30 11:00 2.50 743 0 COMPZ FISH TRIP T Change Elevator. Clear Floor Of Tools. Start Pulling 2 7/8" TBG.Pulled a Total of 23 Joints of 2 7/8" Tubing, Total Pulled = 716.82 + 26.06' Fished = 742.88' feet. Recovered 40' of Control Line from BOP stack after drain BOP stack and Had Only 4 Bands.Estimated Top Of 2 7/8" Collar, 1,090' feet. Went on Generator power at 09:30 for CPF 2 Grid 7 11:00 11:15 0.25 COMPZ FISH SFTY T PJSM, On Rigging Up Testing Equipment. 11:15 12:30 1.25 COMPZ WHDBOCIRC P Drain Stack, Wash Out BOPE. Blow Down T /D. 12:30 13:30 1.00 COMPZ WHDBO BOPE P PJSM. Set Test Plug. Clear Rig Floor. 13:30 14:00 0.50 COMPZ WHDBOSFTY P PJSM, on Testing BOPE. ( Back Shore Power ) Page 30 of 43 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 22:30 8.50 COMPZ WHDBO BOPE P Start Weekly BOP Test, 250/3000 psi. Test - LPR's with 2 7/8 Solid rams. Test - Annular and UPR's with 2 7/8, 3 1/2 and 5" Testjts. Draw Test - System 3,000 psi. Close - 1,500 psi 200 psi in 20 seconds. Full - 137 seconds 4 - N bottles at 2,200 psi 22:30 23:00 0.50 COMPZ FISH SFTY T Held Pre Job safety mtg with rig crew on changing out floor equipment and loading Baker tools from Beaver slide. 23:00 23:30 0.50 0 163 COMPZ FISH TRIP T PU and MU Rope Spear BHA #47 and RIH to 131 -ft. 11/07/2010 Continue to RIH w/ Rope spear BHA to 340 -ft, function tool. POOH and recover 200 -ft of .25" control line. Rlh w/ same BHA to 1,080 -ft. Function tool and POOH. Recovered large amount of control line. RIH w/ same to 1,080 -ft and POOH. Had to remove ice from derrick on trip out of hole. At surface recovered no control line. Ran reverse circulating junk basket. Could not get past 355' md. POOH. RIH w/ OS to TOF. Unable to engage TBG collar. POOH and L/D Tools. 00:00 00:30 0.50 163 340 COMPZ FISH TRIP T Continue to RIH w/ BHA #47 to 340 -ft. 45k up wt, 45k do wt. 00:30 01:00 0.50 340 340 COMPZ FISH FISH T Rotate and work rope spear in attempt to catch .25" control line. 01:00 02:00 1.00 340 0 COMPZ FISH TRIP T POOH to spear. 02:00 01:00 -1.00 COMPZ FISH OTHR P Day light savings time 01:00 01:30 0.50 0 0 COMPZ FISH SFTY T Held PJSM with rig crew on removing control line from spear - discussed hazards. 01:30 02:00 0.50 0 0 COMPZ FISH OTHR T Remove control line from spear. Recovered — 200 -ft. of .25" control line. 02:00 02:30 0.50 0 0 COMPZ FISH SFTY T Held PJSM with rig crew on shuffling equipment in pipe shed, Changing out saver sub from 4 1/2 IF to 3 1/2 IF, and resetting Torque values on top drive. 02:30 04:00 1.50 0 0 COMPZ FISH OTHR T Shuffle equipment in pipe shed, Changing out saver sub from 4 1/2 IF to 3 1/2 IF, and resetting Torque values on top drive. 04:00 04:30 0.50 0 241 COMPZ FISH TRIP T RIH with rope spear BHA #48 to 241 -ft 04:30 05:00 0.50 241 1,060 COMPZ FISH FISH T Continue to RIH with BHA #48 from 241 -ft to 1060' Picking up 3 1/2 DP from Pipe shed. Rotate to grab control line. Up wt =50k / down wt =53k. 05:00 08:30 3.50 1,060 0 COMPZ FISH TRIP T PJSM. Crew Change Out. POOH f/1060'. Remove Control Line From Spear. 08:30 08:45 0.25 0 0 COMPZ FISH SFTY T PJSM. Discuss Hazard of M/U BHA and Tripping Hole W /DP. Page 31 of 4 Time Lags Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:15 1.50 0 1,085 COMPZ FISH TRIP T M/U BHA + RIH w/ Spear. Set down @ 348' & 349', Rotate 1/4 and continue in hole w /spear. Rotate every joint from 400' and to 1085' md. 10:15 10:30 0.25 1,085 1,085 COMPZ FISH SFTY P Having Ice Fall From Crown. Stop Operations and inspect derrick. 10:30 12:30 2.00 1,085 1,085 COMPZ FISH SFTY P Blow Down Top Drive. Remove Ice From Derrick. 12:30 14:00 1.50 1,085 0 COMPZ FISH TRIP T PJSM. POOH From 1,080' and 14:00 14:15 0.25 0 0 COMPZ FISH TRIP T POOH. No Control Line Recover. PJSM. 14:15 16:00 1.75 0 355 COMPZ FISH TRIP T MU & RIH w/ a 5 15/16" x 4 1/4" RCJB. Tagged up @ 355' md. Made several attempts to work passed with no success. 16:00 17:00 1.00 355 0 COMPZ FISH TRIP T PJSM. Blow Top Drive. POOH with RCJB. 17:00 17:30 0.50 0 0 COMPZ FISH SFTY T Held PJSM on PU and MU BHA 17:30 20:00 2.50 0 1,090 COMPZ FISH TRIP T RIH w/ BHA #51 (5.75" OD Overshot w/ 3 21/32" grapple w/ type MC) to 1,090 -ft and tag up. 50k up wt, 51k do wt. Attempt to rotate over TOF, circulating at 2 bpm @ 60 psi; 4 bpm @ 90 psi; and 10 bpm @ 300 psi. 20:00 20:45 0.75 1,090 1,090 COMPZ FISH SFTY T Held PJSM with rig crew blowing down Top drive, POOH with DP and changing out 1500 manual tongs with 1200 manual tongs. Had good group Discussion on the hazards in changing out manual tongs and came up with a safer way of do so. Plan on implementing this in to our procedure to share with the other crews, this will remove some unforeseen hazards involved in the process. 20:45 22:00 1.25 1,090 1,090 COMPZ FISH PULD T Blow down Top drive and change out manual tongs. 22:00 22:30 0.50 1,090 0 COMPZ FISH TRIP T POOH from 1,090 -ft to surface - inspect overshot - no fish and had some small markings on cutlip guide. 22:30 23:30 1.00 0 0 COMPZ FISH SFTY T Held PJSM with rig on bringing tools up Beaver slide. Discussed with crew about the hazards involved while installing safety equipment around open hole to keep people from falling through - discussed why hand rails were needed and why they were installed not only for person working the area but also anybody passing by the work area. Nordic Mngt is in the process of designing and fabricating a 4th handrail to be utilized in this area. - Page 32 of 43 • Time Logs' Date From To bur' S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 COMPZ FISH PULD T PU and MU BHA #52 11/08/2010 RIH w/ Shoe and work over to 1,092 -ft. POOH and recover large ball of control line with TBG cplg impression on bottom. RIH w/ OS and engage TBG cplg at 1,090 -ft, PU 10k osw and rotate to right to tighten pipe. Space out and PT TBG to 800 psi. RU Slick line fish control line off of SSSV, install Frac sleeve and tag fill at 3,025 -ft. Lay down slick line as crew was timed out. Observe well for flow - no flow. Continue to monitor well while Slick line crews is laid down for rest 00:00 00:30 0.50 0 1,090 COMPZ FISH TRIP T RIH w/ BHA # 52 (5 3/4" Rotary shoe) to 1,090 -ft. 50k up wt, 51k do wt. 00:30 01:30 1.00 1,090 1,092 COMPZ FISH FISH T Attempt to dry drill over trash into shoe at 45 rpm's establishing circulation @ 4 bpm @ 90 psi. Fell over to 1,092 -ft. 01:30 02:00 0.50 1,092 1,092 COMPZ FISH SFTY T Held PJSM with crew on Blowing down top drive and POOH with fish. 02:00 02:30 0.50 1,092 0 COMPZ FISH TRIP T POOH and break down shoe, recovered ball of control line with impression of TBG cplg in bottom. 02:30 04:00 1.50 0 1,060 COMPZ FISH TRIP T MU 5 3/4 OS and RIH to 1,060 -ft, having to work thru csg damage at 344 -ft and 351 -ft. 04:00 04:15 0.25 1,060 1,060 COMPZ FISH SFTY T Held PJSM with rig crew on elevator operations and loading of slick line lubricator. 04:15 05:00 0.75 1,060 1,091 COMPZ FISH FISH T RIH to 1,091 -ft and engage TBG cplg, PU to 35k osw and attempt to MU 2 7/8 TBG string from backing off. No signs of make up. lower overpull to 15k osw and make 2 rounds to the right w/ 1.5k torque. PU to 85k - 35k osw and attempt to pressure test, unable to get past 640 psi. Slack off and release OS by 1 round and pick back up to 85k. PT to 800 psi - good test. Set slips and prepare to RU slick line. 05:00 05:30 0.50 1,091 1,091 COMPZ WELLPFSFTY P PJSM w/ HES Slick -line & Rig Crew. 05:30 13:00 7.50 1,091 1,091 COMPZ WELLPFSLKL P MIRU SLick -Line Unit & Equipment to perform job tasks. Make up .108" wire and fish .25" control line off of SSSV @ 1,793 -ft 13:00 22:00 9.00 1,091 COMPZ WELLPF SLKL P RIH w/ 2.34" No Go and 8' prong - set down on flapper, pressure up on string to 1,000 psi and appearred to open flapper. POOH and PU TDRP 1A -SSA Frac sleeve and RIH and set. POOH and change over 1.75" Bailer. RIH and pass through sleeve, set down at 3,025 -ft. Bail out dehydrated gray matter on 1st run, pea size gravel on next run. Seen TBG pressure increase from 0 psi to - 350 psi. Lay down slick line equipment - Slick line crew timed out. Page, 33 of 43 • Time Logs Date From To - Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 COMPZ WELLPF OWFF T Open well to choke to monitor pressure and had 0 psi on TBG. Load TBG with 1 bbl of 9.6 ppg KWF to pressure up to 800 psi, Bleed off pressure and setup to monitor well. 11/09/2010 Continue to wait for slick line crew, PU and resume bailing operations. Bail sand and gravel from 3,025 -ft to 3,039-ft. 00:00 06:00 6.00 COMPZ WELLPF OWFF T Continue to observe well for flow _ while HES slick line crew rests. 06:00 18:00 12.00 COMPZ WELLPF SLKL P PU, RIH w/ 1.75" x 10' bailer, tagged up at 3025', making approximately 1' per run. Bailing out grey liquid w /gravel, sand and metal shavings. Made 3 runs with bailer making 3' and 1 run with poker or punch. LD bailer and retied rope socket. Ran back in hole 3 runs and w /same 1.75" bailer and made 1' per run. Total of 6 runs and made total of 6' to 3031'. 18:00 00:00 6.00 COMPZ WELLPF SLKL T Continue to RIH and Bail with 1.75" OD bailer from 3,031 -ft to 3,039 -ft. Recovering small gravel and sand. 11/10/2010 Continue to Bail until bridge is removed or AOGCC says we have sufficient depth. Surge tubing with pressure in attempt to move bridge. No success. RD Slick line and RU e line, perforate tubing above bridge. Establish circulation and RD E line. Change in scope on pumping balanced plug. 00:00 06:00 6.00 COMPZ FISH SLKL T Continue to Bail out 2 7/8 TBG from 3,039 -ft and 3,040 -ft. recovering sand and gravel. Cut off 200 -ft of slick line and rehead. RIH and bail at 3,040 -ft and unable to make hole. PU 1" poker and RIH to 3,040'. POOH 06:00 10:30 4.50 COMPZ FISH SLKL T RIH w /bailer again, bailed to 3042'. While out of hole w /bailer and cut off another 200' of slick line and rehead, pressure up on tubing to 800 psi, dumped pressure to surge and push plug or bridge down hole. Pressure up immediately, attempted this four times with same results. RIH with 1" poker (punch) and tagged at 3039', POOH. RIH with bailer and bailed out to 3040'. 10:30 12:00 1.50 COMPZ FISH SLKL T POOH w/ bailer. R/D HES slickline. 12:00 15:00 3.00 COMPZ FISH ELNE P When HES E -line arrived, spotted equipment. Loaded lubricator and grease head in pipe shed. 15:00 15:30 0.50 COMPZ WELLPFSFTY P PJSM w/ HES E line crew and Nordic 3 rig crew. Discussed hazards and mitigations for rigging up E -line equipment perforating equipment. Page, 34 of 43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:30 3.00 COMPZ WELLPFPERF P Continued rig up u of HES BOP, Lubricator and grease head. MU 5', 1 -3/8" tubing punchers @ 4 spf, RIH and tag up @ 3025', PU and perforated 20' - 4 shots per ft from 3020' to 3015. POOH w/e -line to 1700' (above SSSV). 18:30 19:00 0.50 COMPZ WELLPFCIRC P Established circulation with 3 BPM @ 380 psi. Pumped 5 bbls to fill hole and 5 bbls circulate. 19:00 19:30 0.50 COMPZ WELLPF ELNE P Continued POOH w /tubing puncher 19:30 21:30 2.00 COMPZ WELLPF ELNE P Held PJSM with E line and Rig crew on laying down perf gun and RD E line Pull gun to lubricator, verify fired - RD Eline unit. 21:30 22:00 0.50 COMPZ WELLPFSFTY P Held PJSM on circulating well bore 22:00 23:00 1.00 COMPZ WELLPFCIRC P Pressure test circulation lines at 1,000 psi. Pump 240 bbls of 9.6 ppg at 3 bpm at 360 psi ICP and 470 psi at FCP. through perf holes. Called Town Engineer and discussed concerns of 15.7 ppg balanced cement plug swapping out with 9.6 ppg KWF below TBG perforations prior to plug setting up. Changed scope to swap fluid in annulus from perfs at 3,030 -ft to top of PBR at 7,201 -ft. with 16 ppg polymer Barite mud. Emailed AOGCC in Prudhoe Bay a copy of discussion. 23:00 00:00 1.00 COMPZ WELLPF COND X Weight up returns to 9.6 ppg while waiting on 150 bbls of 16 ppg polymer barite mud to be built in Deadhorse and delivered to rig. 11/11/2010 Wait on 16 ppg mud to be built, delivered and off loaded into rig pits. Pump 58 bbls of 16 ppg Mud, shut down and wait for it to swap, Pressure wouldn't drop past 850 psi. RU HES and 10' of perfs. 00:00 07:30 7.50 COMPZ WELLPF OTHR X Offload rig pits of 9.6 ppg Brine while waiting on 150 bbls of 16 ppg polymer barite mud to be built in Deadhorse and delivered to rig. Load 16 ppg mud in rig pits. 07:30 09:30 2.00 COMPZ WELLPF CIRC XT PJSM. ICP= 400 psi @ @ 3BPM. Pressured up 800 psi slowed pump down to 2 BPM w /500 psi. Pressure came up to 800 psi slowed down pump to 1 BPM w/700 psi pressure built up immediately to 1140 psi. Shut pump down @ 58 bbls. 16 ppg mud. Pressure bled down to 850 psi in 2 hrs. Page, 35 of 43 • • Time Logs Date From To Our S. Depth E. Depth' Phase Code Subcode T Comment 09:30 11:00 1.50 COMPZ WELLPFCIRC XT PJSM discussed change in scope of work & hazards. Open bleeder and dumped pressure attempting to surge and open perfs in 2 7/8" tubing. Pressure back up to 850 psi immediately. Made this attempt four times with no luck surging the heavy 16 • •q mud. 11:00 13:30 2.50 COMPZ WELLPF OTHR XT PJSM. Released overshot from tubing at 1090'. Circulate 9.6 ppg brine around from 1090' to surface displacing the 16 ppg mud. Set back down and re- latched onto the tubing stub at 1090' with the overshot and reset the packoff. 13:30 21:00 7.50 COMPZ WELLPF PERF T Call out HES E -line unit. PJSM w /HES E -line crew and rig crew. RU lubricator, pump in sub and grease head. MU 1st. 5' - 4 SPF tubing punch. RIH and tagged up at 1790' WLM. Attempt to work tubing punch thru obstruction with no luck. Stacking out @ 1790'. POOH and examine end of tubing punch. found to be 2 ". Change out gun with 1.75" and RIH to 3,037 -ft, PU and Shoot from 3,010 to 3,015 -ft. w/ 4 spf 0 Degree Phasing. POOH and hang back lubricator. 21:00 23:00 2.00 CO MPZ WELLPFCIRC T PT lines atb 1,500 psi. Pump 159 bbls of 9.6 ppg brine at 5 bpm at 360 psi. Shut down to dispose of innerfaced brine. 23:00 00:00 1.00 COMPZ WELLPF PERF T PJSM, PU 1.75" OD gun and RIH and shoot from 2 995 -ft to 3 000 -ft. 11/12/2010 RD E line, Circulate 16 ppg mud out of the IA. RU cementers and pump 73 bbl 15.7 ppg balanced plug, Release off 2 7/8 TBG at 1,090 -ft and POOH 200 -ft to 890 -ft. and circulate 2 hole volumes. WOC for 12 hrs. Unable to get 10k slack off. POOH to 871 -ft. CBU and WOC 00:00 02:00 2.00 COMPZ WELLPF PERF T POOH w/ gun and lay down same RD E line. 02:00 05:00 3.00 COMPZ WELLPF CIRC P Pump 50 bbls of 9.6 ppg brine followed by 37 bbl Hi visc sweep followed by 180 bbls of 9.6 ppg at 5 bpm at 370 ICP 620 FCP. Pump 9.6 ppg at 5 bpm at 510 psi ICP and 550 FCP at 122 bbls away slowed pump rate to 3 bpm at 200 psi ICP, continue to circulate at 3 bpm while holding PJSM with SLB cementers. 05:00 06:00 1.00 COMPZ CEMEN" CMNT P RU SLB cementers, pump 10 bbls of fresh water ahead and PT lines at 3,000 psi. Mix and Pump 73 bbls of 15.7 ppg AS1 at 4 bpm at 600 psi ICP and 165 psi. FCP, follow by 5 bbls of 9.6 ppg brine. Page 36 of 43 . . Time Lags Date From To _ [fur S. Depth E. Depth Phase Code Subcode ' T Comment 06:00 07:00 1.00 1,090 890 COMPZ CEMEN P Crew change. PJSM. Release overshot @ 1090'. POOH w/ 2 stands putting overshot @ 890'. Circulate 114 bbls clean 9.6# brine 8BPM w /200 psi to clean hole from any cement around or in DP. SD, blow down top drive. 07:00 18:00 11.00 890 890 COMPZ CEMEN" WOC P WOC 12 hrs from spotting of cement (0600 hrs) for 2000 psi compression _ strength. 18:00 19:00 1.00 COMPZ CEMEN P RIH from 890 -ft and only able to set 1 k down on cmt tag from 1,053 -ft to 1,060 -ft. Pull above to 1,035 -ft and CBU. POOH to 890 -ft. to WOC until 07:00 hrs. Chuck Scheve with AOGCC was on location to witness tag on TOC, will be back at 07:00 hrs. 19:00 00:00 5.00 COMPZ CEMEN" WOC T WOC to cure. 11/13/2010 �\ Continue to WOC, attempt tag, unable to get 10k slack off, POOH to 871 -ft. WOC for add'I 12 hrs., Conduct \{ weekly BOP test while WOC. RD test equip. RIH w/ 6" Mill and tag up at 391 -ft. Made attempts to get into 7" - not successful. POOH and PU 5 3/4" OS RIH to 1,060 -ft, set 10k down. Tag witnessed by Chuck. Scheve - AOGCC. POOH to 1 002 -ft. CBU 2x's RU HES E line and perf orate 7" casing from 1.045 - 1.055 - ft� 00:00 05:00 5.00 COMPZ FISH WOC T Continue to WOC - AS1 requires 48 hr cure for 2,000 psi Compressive strength 05:00 06:00 1.00 890 890 COMPZ FISH TRIP T RIH to 1,056 -ft and attempted to get 10k slack off was only able to set 4k down. POOH to 890 -ft and Circulate 1 hole volume. 06:00 07:00 1.00 890 0 COMPZ FISH TRIP T POOH LD overshot. 07:00 07:30 0.50 0 COMPZ FISH BOPE P Washout BOPE with swizzle stick. 07:30 08:00 0.50 COMPZ FISH OTHR P Load out E -line lubricator and tools. 08:00 10:00 2.00 COMPZ FISH BOPE P Set test plug. Change out lower pipe rams from 2 7/8" to 3 1/2 ". 10:00 14:30 4.50 COMPZ WHDBO BOPE P Test BOPE 250/3000 psi. Witnessing waived by Chuck Scheve. 14:30 16:30 2.00 COMPZ CEMEN T MU 6.0" flat bottom mill on 3 1/2' drill pipe and RIH, tagged up at 344' attempt work thru holes in casing but could not get thru, mill kept going outside casing stacking out at 391'. POOH and inspect mill. 5' above mill was wrapped with 1/4" control line. Cleaned off control line from mill and break down. 16:30 17:00 0.50 0 1,064 COMPZ CEMEN" OTHR P MU 5 3/4" overshot on 3 1/2" drill pipe. RIH and worked thru top of 7" window, continued in hole and hard tagged TOC @ 1064' w /10K down wt. Tag witnessed by AOGCC (Chuck Scheve) @ 1700 hrs. 11 -13 -2010. Page 37 of 43 • • Time Lags Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 1,064 1,002 COMPZ PLUG TRIP P Pulled up hole one stand to 1,002 -ft Circulate 2 bottoms up to clear pipe. 18:00 18:30 0.50 1,002 1,002 COMPZ PLUG SFTY P Held PJSM with Rig crew and Halliburton Eline crew. Discussed _ RU and arming of Perforating gun. 18:30 23:30 5.00 1,002 1,002 COMPZ PLUG PERF P RU E line and RIH w/ 2 - 5 -ft. 2" circ charge (6.5 gram charges and 40 grain cord) 4 spf guns and perforate 7" casing from 1,045 to 1,055 -ft. in 2 runs. 23:30 00:00 0.50 1,002 1,002 COMPZ PLUG SFTY P Held PJSM with Rig crew and Halliburton Eline crew. Discussed RD and off loading of equipment. 11/14/2010 RD E line. RIH w/ 5 3/4" OS to 479 -ft. and double wash cup assy 97 -ft above. RU and circulate 7" x 9 5/8" annulus w/ hot diesel followed by hot Sea water and then swap to cold SW. Pump 50 bbl 15.7 ppg AS1 slurry plug. POOH WOC for 6 hrs. Lay down un- needed Tubulars from derrick and change over floor equipment. 00:00 00:30 0.50 1,002 1,002 COMPZ PLUG RURD P Continue to RD E line and load out same. 00:30 01:00 0.50 1,002 1,002 COMPZ PLUG SFTY P Held PJSM with rig crew on POOH with 3 1/2 DP. 01:00 02:00 1.00 1,002 0 COMPZ PLUG TRIP P POOH with 31 jts of 3 1/2 DP. Remove 5 3/4" OS and recovered 10" of .25" OD control line. 02:00 02:30 0.50 0 0 COMPZ PLUG SFTY P Held PJSM with rig crew on Re- arrange 5" DP and 6.25" DC's in derrick to remove pinch pts when RIH w/ 4 3/4" DC's. Discussed MU and RIH w/ tandem Pack off cup cementing BHA. 02:30 03:15 0.75 0 0 COMPZ PLUG OTHR P Re- arrange 5" DP and 6.25" DC's in derrick to remove pinch pts when RIH w/ 4 3/4" DC's. 03:15 04:00 0.75 0 479 COMPZ PLUG TRIP P PU and MU with Tandem pack off cup assy and RIH to 344 -ft and work into 7" CSG with 49 -ft. in on 2nd stand of 4 3/4" DC's, continue RIH to 459' and seen signs of pack off cups entering 7" CSG stub. Continue to RIH to 479 -ft. OS depth and pack off depth of 373 and 375 -ft. 52k do wt. 04:00 04:30 0.50 479 479 COMPZ PLUG OTHR P RU with 3 1/2 IF x 8rd XO, 8rd FOSV w/ 3 1/2 8rd Pump in sub, 3 1/2 8rd x IF XO, 3 1/2 IF FOSV with 6 -ft 3 1/2 IF pup jt. and MU Top drive in top of DP stub for added wt in case of hydraulicing while pumping occurs. Page, 38 of 43 • • Time Lags . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 479 479 COMPZ PLUG SFTY P Held PJSM with Rig crew and ASRC vacuum truck crew. Discussed Proper PPE, proper valve line up and hazards of possible hydrate recovery while pumping hot fluids, Spills, broaching - periodically checking well bays along with cellars and fluid transfers. Venting gas - shut down Heaters at return tanks and shut down for emptying Open top tank. 05:00 08:30 3.50 479 479 COMPZ PLUG CIRC P Fluid pack lines and PT @ 2,500 psi. Break circulation at .75 bpm @ 340 psi ICP, string wt dropped 35k from 52k and broke over to 70 psi. Air check return lines to open top and kill tank - good. Establish circulation and stage up. .25 bpm @ 370 psi at 32k string wt. .5 bpm @ 470 psi at 32k string wt. with 5 bbls away closed UPR's and taking returns to open top tank at 05:30 hrs. Returns verified at open top tank. Increase pump rate to .75 bpm @ 170 and dropped back to 50 psi. Increase rate to 1 bpm @ 90 psi. Increase rate to 1.5 bpm @ 160 psi with 43k string wt. with 18.5 bbls away. Increase rate to 2 bpm @ 250 psi and string wt of 38k. with 17 bbls diesel away. 60 bbls pumped diesel returning at surface at 2 bpm at 150 psi with 38k string wt. Increase pump rate 06:24 hrs to 3 bpm at 270 psi with 38k string wt. Pumped total of 200 bbls hot 90 deg. diesel, pumped 140 bbls —170 deg Seawater. FCP= 220 psi @ 3 BPM. Shut down to empty returns tank. 08:30 10:30 2.00 479 COMPZ PLUG CIRC P Pump 260 bbls cold seawater @ 3 BPM w /200 psi. 10:30 11:00 0.50 COMPZ CEMEN - SFTY P PJSM w /rig crew, Schlumberger Cement crew, ASRC truck drivers. Covered hazards and mitgations for pumping cement plug. 11:00 12:00 1.00 479 322 COMPZ CEMEN P Pumped 5 bbls fresh water ahead to confirm circulation. SD pressure test lines to 3000 psi. Pumped 40 bbls of AS1 cement @ 3 BPM w/285 psi. W/ 33 bbls away started seeing less weight on indicator. Slowed down to 2 BPM w/187 psi. Displace w/2 bbls fresh wt. SD. Pulled up hole w/ bottom DP to 322' Circulate hole clean at 322'. 12:00 14:00 2.00 322 0 COMPZ PLUG TRIP P POOH, laying down 3 1/2" DP and overshot and tandem cup assy. Page 39 of 4 • • 'Time Lags F Date From To 1, Dur S. Depth E Depth Phase Code Subcode T . Comment 14:00 14:30 0.50 0 0 COMPZ PLUG SFTY P Held PJSM with rig crew on RIH w/ 3 1/2" DP and laying down same. 14:30 15:00 0.50 0 COMPZ PLUG PULD P RIH w/ 3 1/2" DP to 159 -ft and POOH laying down same. 15:00 15:30 0.50 COMPZ PLUG SFTY P Held PJSM with rig crew on changing out elevators and handling equipment for 5" DP 15:30 17:00 1.50 COMPZ PLUG OTHR P Change out handling equipment for 5" DP 17:00 18:00 1.00 COMPZ PLUG TRIP P RIH w/ 4 stands of 5" DP and lay down same 18:00 18:30 0.50 COMPZ PLUG SFTY P Held PJSM with rig crew on RIH w/ 6.25" DC's and lay down the same. 18:30 20:00 1.50 COMPZ PLUG PULD P RIH w/ 2 stands of 6.25" OD DC's and Lay down the same. 20:00 20:30 0.50 COMPZ PLUG SFTY P Held PJSM with rig crew on Changing out floor to 3 1/2 TBG equipment and RIH w/ 3 1/2" TBG and lay down the same. 20:30 21:00 0.50 COMPZ PLUG PULD P Lay down 9 jts of 3 1/2 TBG via _ mouse hole. 21:00 21:30 0.50 COMPZ PLUG SFTY P Held PJSM with crew on offloading pipe shed. 21:30 22:30 1.00 COMPZ PLUG OTHR P Clean and clear pipe shed of 6.25" DC's, 5" DP, 3 1/2 DP and 3 1/2 TBG. 22:30 22:45 0.25 COMPZ PLUG SFTY P Held PJSM with crew on breaking down bumper sub and jars and laying down same. 22:45 23:00 0.25 COMPZ PLUG PULD P Break down bumper sub and jars and lay down same. 23:00 23:30 0.50 COMPZ PLUG SFTY P Held PJSM with rig crew on changing out elevators and handling equipment for 3 1/2" DP 23:30 00:00 0.50 COMPZ PLUG OTHR P Change out 1,500 Manual tongs with 1,200 Manual tongs 11/15/2010 RIH w/ 5 3/4" OS and Taq TOC at 476 -ft. POOH w/ DP and Lay down BHA. PU and MU CMT retainer and RIH to 300 -ft. and set. EST circulation rate. Mix and pump 27 bbls of AS1 cement, unstinq from CMT retainer . and lay 17 bbl balanced plug. POOH laying down DP. Top off well with 1.5 bbls cement. ND BOP Stack and NU TBG Spool. Break down tree for abandonment tree. 00:00 00:30 0.50 COMPZ PLUG SFTY P Held PJSM with Rig crew and Baker hand. Discuss RIH w/ OS to tag cement and POOH 00:30 02:00 1.50 0 0 COMPZ PLUG TRIP P PU and MU 5 3/4" OS and RIH to 476 -ft and tag with 4k down. POOH standing back 2 stands DP and lay down remaining 9 jts. 02:00 02:30 0.50 0 0 COMPZ PLUG SFTY P Held PJSM with rig crew and Baker on PU and MU of cement retainer. Discussed RIH with the same and setting. Page40f43 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 1 ' 1 11 I 02:30 04:00 1.50 0 299 COMPZ PLUG TRIP P PU and MU 9.625" Baker K -1 Cement retainer assy. RIH to 300 -ft. Set Cement retainer at 299 -ft.. PT pump lines to 2,500 psi. - Good Test. Un -sting from Retainer with 40 psi. sting back in and Establish injection rate. .5bpm @50 psi 1.0 bpm @ 70 psi 1.5 bpm @ 90 psi 2.0 bpm @ 120 psi 2.5 bpm @ 150 psi 3.0 bpm @ 180 psi Total Volume pumped = 5.7 bbls. 04:00 04:30 0.50 299 299 COMPZ CEMEN SFTY P Held PJSM with SLB cementers, ASRC, rig crew and Baker hand. Discuss positions and truck placements. Review Pump schedule with all. 04:30 06:00 1.50 299 299 COMPZ CEMEN OTHR P Load trucks with rinsate and spot where needed. RU SLB cementers to rig cement line. Unable to start cement job due to crew change out in the middle of process. 06:00 06:30 0.50 299 299 COMPZ CEMEN SFTY P Crew change. PJSM w /new crew, SLB, and ASRC truck drivers. 06:30 08:30 2.00 299 0 COMPZ CEMEN P Pump 5 bbls fresh water ahead. PT lines to 3,000 psi. Mix and pump 20 bbls 15.7 ppg AS1 w/1.5 #/ bbl Cemnet @ 3 BPM w/ 300 psi. Followed by 7.5 bbls 15.7 ppg AS1. Sting out of cement retainer, PU 2 ft. Shut lower pipe rams. Continue mix and pump another 17.5 bbls of 15.7 ppg AS1 till returns at surface in cellar. Displace with 1.25 bbls of fresh water. RD cementers. Open lower pipe rams. POOH laying down 8 jts of 3 1/2" DP. RU cementers and head pin. PU w /head pin 15 ft above rig floor. Mix and pump 1.5 bbls 15.7 ppg AS1 till cement returns out the OA valve @ .5 BPM @ 100 psi. SD, flush and disconnect all lines. POOH laying down last jt. of DP. 08:30 09:00 0.50 COMPZ PLUG SFTY P PJSM discussing hazards and procedures for ND and cleaning up breaking down 13 5/8 "stack. Open doors to ram cavities and wash out complete stack. Break apart 13 5/8" stack. ND stack off of well. Page 41 of 43 Time Logs • ,, ' ' Date From To lour S. Depth k king E.'Depth P hase Code Subcoce T Comme 09:00 17:30 8.50 COMPZ PLUG NUND mud cro P Open doors to ram cavities and steam out complete stack. Remove all rams. Pre Broke flanges for spl 13 5/ s and stac on skid. ND stack off o well Remove spacer spool. ND Valves • form ss. 17:30 18:00 0.50 COMPZ PLUG OTHR P Recover water from off top of CMT plug located at 16' below Surface CSG flange. Notify SLB cementers - Crew was timed out - unavailable till 03:00 hrs on 11- 16 -10 18:00 18:30 0.50 COMPZ PLUG SFTY P Held PJSM and site assessment with crew on NU TBG spool and tear down of tree. Waiting on SLB cementers Crew was timed out - unavailable till 03:00 hrs on 11 -16 -10 - 18:30 00:00 5 COMPZ PLUG NUND P MU 7 1/16" 5M x 11" 3M TBG spool and tear 11 -16 -10 down tree 5/8 asst'. Waiting on SLB Cementers Crew was timed out unavailable 3M till 03:00 OA hrs on 11 /16/2010 Off load third party equipment and clear pipe shed. Offload pits. RU Cementers and top off 9 thru TBG hanger, taking returns out of OA valve. Cap off with diesel and PT at 5 00 psi to verify 11" flange integritiy and install BPV, NU adapter and abandonment tree. PT at 500 psi for 10 minutes. Dress tree, IA and valves. RDMO Stack 13 5/8" BOPE on skid. Release Nordic Rig P Held Nord M with crew on off loading pipe shed Waiting on SLB Cementers Crew was timed out - unavailable till 03:00 hrs on 11 -16 -10 00:30 02:00 1.50 COMPZ PLUG OTHR P Off load pipe shed of 3 1/2 DP and Baker fishing tools. Waiting on SLB Cementers Crew was timed out unavailable till 03:00 hrs on 11 -16 -10 02:00 02:30 0.50 COMPZ PLUG SFTY P Held PJSM on off loading tools down beaver slide. W ai ti ng on SL Cementers Crew was timed out unavailable till 03: hrs on 11 -16 -10 02:30 out t - 11 -16 -10 unavailable till 03:00 h rs on 04:00 06:00 2.00 COMPZ PLUG NUND P arrived. PJSM SLB Cementers w /SLB covered rigging up Spot . trucks, string out lines and connect 06:00 07:30 1.50 COMPZ PLUG CMNT P SLB Cement Crew change. PJSM w /new crew and e Spot Sucker and string out hoses. Pumped 1.2 bbls of 15.7 ppg ArcticSet 1 Cement filling up void from 16' tSuper o top of Surface Casing Flange. SD washed out lines in celllar and picked up with returns in Super Sucker. page of 43 Time Lo gs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:30 2.00 COMPZ PLUG NUND P Take pictures of cement up to top of Surface Casing flange. NU tubing head w /hanger and BPV installed. NU adapter flange, master valve, and swab valve with tree cap. Fill with diesel and pressure up to 500 psi against cement plug to verify integrity of flanges on the wellhead. Good test. 09:30 12:30 3.00 DEMOB MOVE MOB P Clean and offload pits. PJSM on moving rig. 12:30 13:30 1.00 DEMOB MOVE MOB P Contact DSO, pull off of well, spot rig in middle of pad out of the way. 13:30 16:00 2.50 DEMOB MOVE NUND P PJSM covering hazards of breaking apart 13 5/8" stack and putting on skid. Break apart and load out 13 5/8" stack on skid. Put heat on celllar and clean out, with Super Sucker. Release Nordic 3 rig @ 1600 hrs. 11 -16 -2010. Page 43 of 43 0 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 15, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -13 Run Date: 11/13/2010 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 -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20067 -00 DF- C PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 a 0 klinton.wood Date: n r C 0 t,_ 2 010 Signed: C Anchar e • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 15, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2T -13 Run Date: 11/11/2010 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 -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20067 -00 NIL 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. O �9 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 o f kt tt t o - `� MD Date: n 2010 Signed: AWske Oil & G s i "ClO e • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� � 171 A),0 DATE: November 14, 2010 P.I. Supervisor SUBJECT: Intermediate Plug KRU 2T -13 Conoco Phillips PTD #186 -089 FROM: Chuck Scheve Petroleum Inspector CONFIDENTIAL Section: 1 Township: 11N Range: 8E Meridian: UM - Lease No.: ADL0025569 - Drilling Rig: Nordic 3 Rig Elevation: Total Depth: Operator Rep.: Rick Overstreat Casina/Tubing Data: Casing Removal: Conductor: 133/8 O.D. Shoe@ 105' MD Casing Cut@ Feet Surface: 95/8 O.D. Shoe@ 2976' MD Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: 7" O.D. Shoe@ 7839' MD Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 27/8 O.D. Tail@ 7472' MD Casing Cut@ Feet type Pluq Type Plug Founded on Bottom Top of Cement Mud Weight Pressure (bottom up) of Cement Depth Verified? above plug Test Applied intermediate I balanced 3030' 1064' drill i e to ✓ no Type Plug Founded on: Verified? S W O&D NOV 1 8 2 0 1 0 Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag Casing Stub Retainer No Surface I traveled to the Conoco Phillips KRU 2T -13 location to verify the intermediate cement plug covering the tubing stub in this well. The 2 -7/8" tubing had been perforated at 3030' with the top of the tubing at 1090'. A balanced cement plug had been spotted in the tubing and 7 "casing from 3030' to an estimated top of 1000'. After 36 hrs WOC drillpipe was run in the hole and solid cement tagged at 1064'. Rev.:5 /28/00 by L.R.G. 2010- 1114_P &A_ intermediate _plug_KRU_2T- 13_cs.xls 11/17/2010 • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 10, 2010 2:58 PM To: 'Packer, Brett B' Subject: RE: 2T -13 (PTD #186 -089) Revised Revised Plugging Procedure Brett, Procedure is approved as written below. Most likely as you said things will change in the next day or so. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Packer, Brett B [mailto:J. Brett. Packer@conocophillips.com] Sent: Wednesday, November 10, 2010 1:32 PM To: Schwartz, Guy L (DOA) Subject: 2T -13 (PTD #186 -089) Revised Revised Plugging Procedure Guy, Thanks for stopping by. Below is the revised plan forward as I discussed with you including the free - point determination if we are unable to get circulation, and also including the OA cement plug. We are currently getting rigged up with E -line to perforate the tubing down around 3030' MD. Assuming we can get circulation, we will be ready to pump the first cement plug (Step #3) from 1000' MD - 3030' MD later this evening. I'm sorry for the multiple change of plans, but we are intent on getting this well as secure as possible. I would love to be able to say this is the final plan, but you know how workovers go. Please provide confirmation that the AOGCC approves this revised plan forward. Thanks! Current Status • 2 Va" tubing stub at 1090' MD, tagged fill in tubing at 3040' MD. • 7" casing stub at 350' MD • Hole in the 9 %" casing from —340' -360' MD • Drillpipe is currently latched onto the tubing stub with a packoff overshot. Revised Plan Forward (11/10/2010) 1. RU E -line. RIH w/ tubing punch and punch holes in the 2 %s" tubing at 3030' MD or as deep as possible. 2. Circulate fill from 2 %s" x 7" annulus at max rate. a. If unable to circulate, RIH w/ Halliburton Free Point tools and determine free point of tubing. Punch holes in the tubing above the free point and circulate 2 %s" x 7" annulus at max rate. 11/10/2010 Page 2 of 2 3. RU SLB cementers. Circulate in a balanced plug of 15.7 ppg ArcticSetl cement from 3030' MD to 1000' MD (90' above the top of the tubing stub). Release overshot from tubing stub and POOH two stands. 4. RD cementers. WOC min of 12 hours. RBIH to tag TOC. AOGCC to witness plug tag. POOH standing back 500' drillpipe, laying down the rest. 5. Dummy drift the compromised casing at 350' for the 7" cement retainer prior to punching holes in the 7" casing. a. If unable to drift for the 7" cement retainer, consult Anchorage engineer for plan forward. 6. RU E -line. RIH w/ 2" tubing punch (10' guns, 4 spf). Punch holes in 7" casing above TOC. RDMO E- line. POOH standing back 500' of drillpipe, laying down the rest. 7. RIH w/ 7" cement retainer to set at 500' MD. Displace Arctic Pack from the OA by pumping 200 bbls heated diesel (-90 °F) followed by 150 bbls hot seawater (- 170 °F) followed by 300 bbls cold seawater. 8. RU SLB cementers. Circulate in —36 bbls of 15.7 ppg ArcticSetl cement to fill the 7" casing below the retainer and up the 7" x 9 %" annulus to 400' MD. Sting out of the retainer and lay in an additional 4 bbls cement on top of the retainer in the 7" casing (— 100 ft). POOH standing back 400' of drillpipe, laying down the rest. 9. WOC min of 12 hours. RBIH to tag TOC. AOGCC to witness plug tag. POOH standing back 300' of drillpipe, laying down the rest. 10. RIH w/ 9 %" cement retainer to set at —300' MD. Establish injection through cement retainer. 11. RU SLB cementers. Pump —20 bbls Arctic Setl w/ 1.5 lb/bbl CemNet below retainer. Sting out of retainer. Fill 9 %" casing with cement to surface on top of retainer. POOH. 12. RD cementers. WOC min of 12 hours. ND BOP stack. If cement is more than 5' below original ground level, top off with cement. 13. NU tubing head. NU adapter flange, master valve, and swab valve with a tree cap. Pressure up to 500 psi against cement plug to verify integrity of flanges on the wellhead. 14. RDMO Nordic 3. I. (Brett k-ackr Orang ez Wells Wo*ver Engineer Work# (907) 265 -6845 CefT# (907) 230 -8377 11/10/2010 • Page 1 of Schwartz, Guy L (DOA) From: Packer, Brett B [J. Brett. Packer@conocophillips.com] Sent: Tuesday, November 09, 2010 5:54 PM To: Schwartz, Guy L (DOA) Cc: Nordic 3 Company Man; 'Mike Martin; Gober, Howard; 'Toomey, Ian A' Subject: 2T -13 (PTD #186 -089) Revised Plugging Procedure Guy, I would like to propose another revision to the plugging procedure for 2T -13 based upon the current conditions of the well. As stated before, the perforations were cemented on 1/3/2010 with 21 bbls 15.8 ppg Class G cement with an estimated 12 bbls behind pipe and an estimated TOC in the tubing at 7100'. The cement plug in the tubing was tested to 2500 psi, as witnessed by John Crisp on 1/17/2010. The surface casing is compromised at -340' - 360' and the 7" casing has been pulled to -350'. The tubing stub looking up at us is at a depth of 1090' which we are currently latched onto and rigged up with Slickline bailing fill from within the tubing at a depth of 3025'. We have made multiple bailing runs, gaining only 1' each trip and recovering silty sand and small pebbles, the source which could have only come from the permafrost region where we milled through the 7" and 9 -5/8" casing. We have been bailing in an effort to verify whether this is just a bridge in the tubing or whether the tubing is full of this silty sand and pebbles from the TOC (7100') up to 3025'. If the tubing is indeed full of this muck, this significantly changes our options, as it would be unreasonable to continue to bail 4000' of fill down to the TOC in the tubing at the rate of 1 ft/hr. We will continue to bail fill throughout the night as previously discussed in hopes that this is just a bridge, but if we are faced with the same minimal progress in the morning, I would like to propose the following slight revision to the previous procedure Howard submitted which was approved on 11/8/2010: 1. RU E -line. Perforate tubing at 3000' RKB or as deep as possible. , 2. RU SLB cementers. Circulate in a balanced plug of 15.7 ppg ArcticSet1 cement from 3000' MD to ^.. MD. Release overshot from tubing stub and POOH. ,"" 3. RD cementers. WOC min of 6 hours. RIH with tubing open -ended and tag TOC. AOGCC to witness plug tag. POOH. 4. RIH with 9 -5/8" cement retainer and set at -300' MD. Establish injection through cement retainer. 5. RU SLB cementers. Pump -20 bbls ArcticSet1 cement below retainer. Sting out of retainer. Fill 9 -5/8" cement to surface. POOH. 6. RD cementers. WOC min 6 hours. ND BOP stack. If cement is more than 5' below original ground level, top off with cement. 7. NU tubing head. NU adapter flange, master valve, and swab valve with a tree cap. Pressure up to 500 psi against cement plug to verify integrity of flanges on the wellhead. 8. RDMO Nordic 3. Based on this procedure, we will have a 2,650 ft solid cement plug in the 2 -7/8" tubing and 7" casing from -350' MD down to 3000' MD. We will have a cement retainer set at 300' MD and 20 bbls cement squeezed through the damaged section of 7" and 9 -5/8" casing and a 300' cement plug from the 300' MD to surface in the 9 -5/8" casing above the cement retainer. Please let me know if you have any questions. I would appreciate a confirmation that the AOGCC approves this revised plan forward. Thanks, Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6845 Office 907 - 230 -8377 Cell 11/10/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 08, 2010 4:37 PM To: 'Gober, Howard' Cc: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: RE: 2T -13 (PTD186 -089) Revised Plugging Procedure (latest approved 11- 08 -10) Howard, The below steps are similar to what the original 403 sundry procedure outlined. Some different cement plug depths are proposed but the ultimate goal is still placing an almost solid column of cement from just above the top packer to the surface. The steps below are approved.... I will forward this email to the inspectors so they are aware of the changes. It seems that persistence has paid off in going after access to the tubing and ultimately getting a deep cement plug set. Good work. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Monday, November 08, 2010 4:00 PM To: Schwartz, Guy L (DOA) Cc: 'Mike Martin'; Nordic 3 Company Man; Packer, Brett B Subject: 2T -13 (PTD186 -089) Revised Plugging Procedure Guy, I would like to revise our plugging procedure for 2T -13. We know that the surface casing is compromised at -340' -360'. We also know that the 7" casing has been pulled to -350'. This significantly changes the wellbore so that our plugging procedure needs to be revised. I would like to propose the following procedure for suspending the well: 1. Tag TOC in 2 -7/8" tubing. Pressure test of this plug has previously been witnessed by John Crisp, so we will not call out a AOGCC Inspector for the tag. 2. RU E -line. Perforate tubing above TOC no deeper than 7190' RKB (perfs must be above top packer). 3. RU Schlumberger cementers. Circulate in balanced plug of 15.8 ppg Class G cement with TOC - 3100' MD. This is -100' below the surface casing shoe. 4. RD cementers. WOC to build 2000 psi compressive strength. Pressure test tubing to 1500 psi. Bleed off pressure to 0 psi. IA cannot be pressure tested due to casing holes. AOGCC to witness pressure test. 5. RU E -Line. Tag TOC. Perforate tubing above TOC. 6. RU Schlumberger cementers. Circulate in balanced plug of 15.7 ppg ArcticSet1 cement to -350' MD. Release overshot from tubing stub and POOH. 7. RD cementers. WOC min of 6 hours. RIH with tubing open ended and tag TOC. AOGCC to witness plug tag. POOH. 8. RIH with 9 -5/8" cement retainer and set at -300' MD. Establish injection through cement retainer. 9. RU Schlumberger cementers. Pump -20 bbls ArcticSet1 cement below retainer. Sting out of retainer. Fill 9- 5/8" cement to surface. POOH. 10. RD cementers. WOC min 6 hours. ND BOP stack. If cement is more than 5' below original ground level, top off with cement. NU tubing head. NU adapter flange, master valve, and swab valve with a tree cap. Pressure up to 500 psi against cement plug to verify integrity of flanges on the wellhead. 11. RDMO Nordic 3, 11/8/2010 Page 2 of 2 i Please let me know if you have any questions. I would appreciate a confirmation that the AOGCC approves this revised plan forward. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907 - 263 -4220 Office 907 - 240 -5515 Cell Howard.Gober @conocophillips.com 11/8/2010 • • Page 1 of 1 Regg, James B (DOA) f96_Otcl From: Gober, Howard [ Howard .Gober @conocophillips.com] Sent: Sunday, November 07, 2010 8:29 AM It( L®� �; To: Regg, James B (DOA) Cc: Nordic 3 Toolpusher; Nordic 3 Company Man; Schwartz, Guy L (DOA); CPA Wells Supt; Maunder, Thomas E (DOA); Cawvey, Von Subject: RE: Nordic 3 BOPE Tests 10 -21 -10 and 10 -29 -10 Attachments: RE: 2T -13 Plan Forward Jim, Please see the attached e-mail string documenting a conversation I had with Guy Schwartz and Tom Maunder at the AOGCC office on 10/26/10. At this meeting we specifically discussed that the BOP test pressure would be limited by the working pressure of the casing head which is 3000 psi. Guy discussed i the matter with Commissioner Foerster and she supported our plan as lined out in the attached e-mail. Guy's response to my initial e-mail provided Commission approval to proceed with the revised test pressure. Since we are still nippled up to the casing head, our test pressures continue to be limited to 3000 psi maximum. Please let me know if you would still like a copy of the test charts forwarded to you. I have and will continue to provide periodic updates to Guy Schwartz as we continue in our efforts to properly suspend this challenging well. Please let me know if you have any further questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 8 201 907 - 2634220 office 907 - 240 -5515 cell From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, November 05, 2010 4:18 PM To: Nordic 3 Toolpusher Cc: Brooks, Phoebe L (DOA) Subject: Nordic 3 BOPE Tests 10 -21 -10 and 10 -29 -10 10 -29 -10 BOPE test - Sundry 310 -324 requires test to 3500psi rams /valves; appears you tested to 3000psi? I don't find Commisison approval for change in test pressure. Please send test chart for this test. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 11/8/2010 . • Regg, James B (DOA) Page 1 of 1 From: Schwartz, Guy L (DOA) Sent: Tuesday, October 26, 2010 10:29 AM fIL, e ,4- 4-o 1117 eolu e,.(,;4-� To: Gober, Howard; Nordic 3 Company Man Cc: Cawvey, Von Subject: RE: 2T -13 Plan Forward , Howard, As per our discussion this morning the operational steps forward below are approved. Commission Foerster has been informed and is supportive of additional efforts to properly P & A the well. to I �� Keep me updated as needed should additional approvals be required. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Monday, October 25, 2010 9:09 PM To: Nordic 3 Company Man Cc: Schwartz, Guy L (DOA); Cawvey, Von Subject: 2T -13 Plan Forward Lee, I spoke with Guy Schwartz at the AOGCC. He is ok with us moving forward on the plan to cut and remove the 7" casing down to our problem spot. Here is the game plan as I see it: • Run the video log as planned. Load hole with 9.6 ppg brine. POOH with tubing. • RIH with 5 -1/2" Multi String Cutter (MSC) dressed for 7" casing. Locate casing collar above trouble area (collar should be +/ -300' MD). Cut casing —5' below this collar. POOH with MSC. • RIH with 4 -3/4" drill collars and storm packer. Set storm packer at —50' MD. • ND BOP and ND tubing head. Pull 7" packoff. Spear casing and remove slips. Release spear. • NU BOP to 11" 3M casing head. BOP is a diverter at this point and the break cannot be pressure tested until the 7" casing is pulled out of the hole. • Release storm packer. POOH with storm packer and collars. • Spear casing. POOH laying down casing. • Run test plug in 11" 3M casing head. Pressure test break to 250/3000 psi. Note: Pressure test is limited by the casing head. Pull test plug. • RIH with spear, jars, and collars. Spear 7" casing. Attempt to backoff or pull 7" casing at the next connection. • Develop plan forward depending on results. Looks like we will need a 5 -1/2" multi string cutter and a 7" storm packer from Baker. Please let me know if you have any questions or comments. Thanks, Howard Gober Wells Engineer Office 907 - 263 -4220 Cell 907 - 240 -5515 11/10/2010 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 05, 2010 4:18 PM To: 'nl434 @conocophillips.com' Cc: Brooks, Phoebe L (DOA) Subject: Nordic 3 BOPE Tests 10 -21 -10 and 10 -29 -10 10 -21 -10 BOPE test - were #3 rams (VBR's) that failed 2 -7/8 x 5 -1/2? Size/Type block should show the rams that failed; replacement should be included in Remarks as you did on report 10 -29 -10 BOPE test - Sundry 310 -324 requires test to 3500psi rams /valves; appears you tested to 3000psi? I don't find Commisison approval for change in test pressure. Please send test chart for this test. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 11/5/2010 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION A 1 7 BOPE Test Report Submit to: iim.reggCcaalaska.aov doa .aogcc. Prudhoe. bav()alaska.gov Phoebe. brooks(c alaska.gov Contractor: Nordic Rig No.: 3 DATE: 10/29/10 Rig Rep.: Rice/ Anderson Rig Phone: 659 -7438 Rig Fax: 659 -7566 Operator: Conoco /Phillps Op. Phone: 659 -7446 Op. Fax: 659 -7566 Rep.: Rowell/ Hinkel E -Mail n1433 @conocophillips.com Well Name: KRU 2T -13 - PTD # 1860890 Operation: Drlg: Workover: X Explor.: Test: Initial: Weekly: X Bi- Weekly Test Pressure: Rams: 250/3000 Annular: 250/3000 Valves: 250/3000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13.5 P Pit Level Indicators P P #1 Rams 1 2 7 /8 "by 5.5" FP Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 0 NA HCR Valves 1 3 1/8" P Kill Line Valves 3 3 1/8" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time /Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1600 P Quantity Test Result 200 psi Attained 20 P No. Valves 12 P Full Pressure Attained 124 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @220 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 1 Test Time: 6.5 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: 'im.re alaska. ov Remarks: Upper pipe ram test Failed change out bleeder valve Passed. Annular & VBR,s tested with 5" & 2 7/8" Test Joint [Sundry 310 -324 requires 3500psi test rams /valves, 2500psi annular; email 11/7/10 clarifies Commission approval to test to 3000 psi due to cs head pressure limit abr 11/10/10 24 HOUR NOTICE GIVEN YES X NO Waived By Bob Noble Date 10/28/10 Time 0900 Witness Test start 1130 Finish 0600 Form 10 -424 (Revised 06/2010) 2010- 1029_BOP_Nordic3_KRU 2T- 13.xls • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, November 05, 2010 11:29 AM To: 'Gober, Howard' Cc: Nordic 3 Company Man; CPA Wells Supt; Cawvey, Von; Packer, Brett B; Toomey, Ian (Baker Hughes Centrilift) Subject: RE: 2T -13 (PTD 186 -089) Status Howard, concur with your proposal below. If we indeed have the tubing latched and can make headway toward securing the well the BOP test can be postponed until a more opportune time (adding one day to the 7 day BOP cycle is acceptable). Since we have breached the casing a pressure test of the bottom plug would be very difficult (or impossible on the IA side) . I would think a tag of the cement plug inside the tubing ( if pumped as planned) would be sufficient and due to the shear volume of the planned cement plug would give us confidence that isolation is successful. Of course this assumes the SL drift is successful and the tubing can be punched deep in the wellbore just above the top packer. Thanks for the update... good luck. Guy Schwartz Senior AOGCC P etroleum Engineer�f 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Friday, November 05, 2010 11:08 AM To: Schwartz, Guy L (DOA) Cc: Nordic 3 Company Man; CPA Wells Supt; Cawvey, Von; Packer, Brett B; Toomey, Ian (Baker Hughes Centrilift) Subject: 2T -13 (PTD 186 -089) Status Guy, I wanted to follow up on our phone conversation just a bit ago regarding 2T -13. The rig ran an overshot this morning and all indications are that we have latched on to the tubing. We pressured up on the tubing to 800 psi and it held good (about 40 psi bleed off in 15 min) with no returns up the annulus. Our plan is to rig up slickline and see if we can drift the tubing. If so, we will move forward with the P &A as planned. We are due for a weekly BOP test today. I would like to request that we be allowed to delay the BOP test until either the bottom cement plug is pumped or we release from the tubing whichever comes first. I would anticipate being able to do the BOP test sometime tomorrow (Saturday). Due to the current condition of the well we will not be able to pressure test the bottom plug as proposed in the procedure. I would like to tag the cement plug with either slickline or E -line to verify the cement plug. Please send me a note back confirming that we can delay the BOP test and that we can use a tag of the cement plug instead of a pressure test. Thanks, 11/5/2010 Page 2 of 2 Howard Gober Wells Engineer ConocoPhillips Alaska, Inc 907 - 263 -4220 office 907- 240 -5515 cell 11/5/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, October 26, 2010 10:29 AM To: 'Gober, Howard'; Nordic 3 Company Man Cc: Cawvey, Von Subject: RE: 2T -13 Plan Forward Howard, As per our discussion this morning the operational steps forward below are approved. Commission Foerster has been informed and is supportive of additional efforts to properly P & A the well. Keep me updated as needed should additional approvals be required. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Gober, Howard [mailto: Howard .Gober @conocophillips.com] Sent: Monday, October 25, 2010 9:09 PM To: Nordic 3 Company Man Cc: Schwartz, Guy L (DOA); Cawvey, Von Subject: 2T -13 Plan Forward Lee, I spoke with Guy Schwartz at the AOGCC. He is ok with us moving forward on the plan to cut and remove the 7" casing down to our problem spot. Here is the game plan as I see it: • Run the video log as planned. Load hole with 9.6 ppg brine. POOH with tubing. • RIH with 5 -1/2" Multi String Cutter (MSC) dressed for 7" casing. Locate casing collar above trouble area (collar should be +/ -300' MD). Cut casing -5' below this collar. POOH with MSC. • RIH with 4 -3/4" drill collars and storm packer. Set storm packer at -50' MD. • ND BOP and ND tubing head. Pull 7" packoff. Spear casing and remove slips. Release spear. • NU BOP to 11" 3M casing head. BOP is a diverter at this point and the break cannot be pressure tested until the 7" casing is pulled out of the hole. • Release storm packer. POOH with storm packer and collars. • Spear casing. POOH laying down casing. Run test plug in 11" 3M casing head. Pressure test break to 250/3000 psi. Note: Pressure test is limited by the casing head. Pull test plug. • RIH with spear, jars, and collars. Spear 7" casing. Attempt to backoff or pull 7" casing at the next connection. • Develop plan forward depending on results. Looks like we will need a 5 -1/2" multi string cutter and a 7" storm packer from Baker. Please let me know if you have any questions or comments. Thanks, Howard Gober Wells Engineer Office 907 - 263 -4220 Cell 907 - 240 -5515 10/26/2010 ConocoPhillips a Alaska Calculations Char Subject Vr� l Sheet number t of Fite By Date C� 4 ex t� vk 41� P 1 ''__ LL 1 Zug ` C���tcr 3 47 _tnO_ i I! d- —.1 Qk ,C k clrt.e L Z 4 COn ocoMiiiip5 • Calculations Chai Alaska Subject �� (� Sheet number of File By Date &I D w� c l O tt p OA— f ct wg' 141'df rioa- / recz>,Ie,-e-� C I t 014C z-e> -fO 3 r * - 3 hole- IV I ke F S ec 6 7,41' C ,�- J c--� SGwe an ConocoPhillips Alaska Calculations Char Subject Sheet number of File By Date Vi._ / J J 3 /z u u V `��' `l l '310 34- /66 tz,-Jk- cve.e- ,, f /:e �,, el i 4 ' ` ��� ConocoRhillips Calculations Char! Alaska Subject Sheet number of File By Date � ft ; Yom, i 3 z f2 F,: («e i � 4 Z- 1 [Zo vL w l ev, lee :3` WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 2T -13 Run Date: 10/15/2010 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 -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20067 -00 NOV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood ( �D 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 -2 3535 klinton.wocsi allirty�t� Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: ine hartzer Chest S 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2T -13 Run Date: 10/8/2010 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 -13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20067 -00 N OV 2016 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 oco Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.woolllbt�rtco T 3 Date: " ' Signed: ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 19, 2010 kt 2 2010 Commissioner Dan Seamount "3 M� Alaska Oil and Gas Conservation Commission Aft 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -13 (PTD 186 -089) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required b 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Ku aruk River'Unit well 2T- � Y r r 13 (PTD 186 -089). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List �'�� - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA ALASK* AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon � Repair well Plug Perforations. r Stimulate F Other IT suspended well Alter Casing [! Pull Tubing r Perforate New Pool inspection Waiver � Time Extension Change Approved Program I Operat. Shutdown Perforate I Re -enter Suspended { 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 186 -089 Developmen r Exploratory �� 3. Address: 6. API Number: Stratigraphi r Service P. O. Box 100360, Anchorage, Alaska 99510 50- 103- 20067 -00 7. Property Design ioion: 8. Well Name and Number: ADL 25569 2T -13 9. Field /Pool(s): I- Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 7868 feet Plugs (measured) 7100' Cement true vertical 6145 feet Junk (measured) NONE Effective Depth measured 7754 feet Packer (measured) 7217 & 7450 MD true vertical 8059 feet (true vertucal) 5676 & 5839 TVD Casing Length Size MD TVD Burst Collapse CONDUCTOR 105 16 105 105 SURFACE 2985 9.625 2985 2841 PRODUCTION 7839 7 7839 6123 Perforation depth: Measured depth: 7329' -7579' cemente(II/ z Q 1 True Vertical Depth: 5797' -5932' cemented p p�� fistar? FiM� � � < 'M� VONi► Tubing (size, grade, MD, and TVD) 2.875, J -55, 7472 MD, 5855 TVD Packers & SSSV (type, MD, and TVD) 2 PACKER - BROWN 'HB -1' PACKER @ 7217 MD and 5673 TVD, & 7450' MD and 5839 TVD TRDP - CAMCO TRDP -1A @ 1787 MD and 1783 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: N-1 Copies of Logs and Surveys run Exp loratory (! ` Development r Service r 15. Well Status after work:-SNSpGI)dtc{ Lg -- oil F Gas [_ WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ C WINJ r- SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact MJ Loveland /Perry Klein Printed Name MJ Loveland/Perry Klein Title Well Integrity Project Supervisor Signature Phone: 659 -7043 Date � - /" RBDMIS SEP 2 3 2010A$., Form 10 -404 Revised 7/2009 Submit Original Only Sus Ided Well Site Inspection Form • P P Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riy Unit 2T -13 Field /Pool: Kuparuk River/Kuparuk River Pool Permit # (PTD): 186 -089 Sundry 309 -399 API Number: 50103200670000 Operator: ConocoPhillips Date Suspended: 1/3/2010 77 FSL 556 FWL Sec 1 Tws : T11 N Range: R8E UM Surface Location Section: 9 P 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: 4 Pad or location surface: Location cleanup needed: / 4Wg- Pits condition: - Surrounding area condition: &C;?� Water /fluids on pad: A/p Discoloration, Sheens on pad, pits or water: AAA Samples taken: N - O Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: ��GTa VN' Cellar description, condition, fluids: Rat Hole: A L AOZ . eM L5zj;_',/ Wellhouse or protective barriers: f* rewd/ Rl/Glr Well identification sign: A 0Pj-1A1 dVtt c. F 7. /6/t/ ®/1/ /V GG ./5 Tubing Pressure (or casing if no tubing): -� /l /b 0 J /A® Ill Annulus pressures: P Wellhead Photos taken (# and description): �/ {�/ t� - die . if 110m. Work Required: y U Tb a' caz � >•� -RU - 01: X Operator Rep (name and signature): __140 V AOGCC Inspector: Other Observers: Inspection Date: -<12 , I e AOGCC Notice Date: Time of arrival: Time of Departure: Site access method: Vrlq_, KU P 2T -13 ConocoPhillips v z'-� ll Attributes Max Angle & MD TO Alatilc�l, lnl bore API /l1Nil Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 01032006700 KUPARUK RIVER UNIT PROD 50.65 6,200.00 7,868.0 ment H2S (ppm) Dab Annotation End Date KB-Grd (ft) Rig Release Data ••• well Corti.: - 2T- [35/25120709:39:50 AM V:TRDP 30 1 /11/2009 Last WO: 41.51 5/13/1986 Schemelk -Ac1ud Annotation Depth (kKe) Entl Date Annotation Laat Mod BY End Data Last Tag: SLM 315.0 5121/2010 Rev Reason: Tag TBG restriction, show Cmt Imosbor 5/25/2010 Casing Strings Is " E String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ftKB) (ftKB) (ft(B) (lbeM) Grade String Top Third CONDUCTOR, CONDUCTOR 16 15.062 0.0 105.0 105.0 62.50 H40 105 SURFACE 95/81 8.765 0.01 2,985.0 2,841.7 36.00,155 PRODUCTION 71 6.151 0.01 7,839.0 6,123.9 26.00 J55 SAFETY VLV, 1,767 T Strings String GD I String ID Set Depth Set Depth (TVD) SMng Wt String Tubing Description (in) (in) T Itl(B (ftKB) (ftKB) (IWM) Grade String Top Thrd TUBING 27/8 2.441 0.01 7,472.0 5,855.2 5.50 J -55 EUE8rdABMOD GAS LIFT, Other In Hole All Jewelry: Tubing Run & Retrievable, Fish, etc. 2,637 - Top Depth (TVD) Top Incl Top (ftKB) (ftKB) ( °) Desodptlon Comment Run Date ID (In) 1,787 1,783.3 12.03 SAFETY VLV Camp TRDP-1A 9/311986 2.312 SURFACE, 2,985 2,637 2,568.3 32.65 GAS LIFT CAMCO/KBMG/l /GLV /BK/.2511365/ Comment: STA 1 12120/1992 2.371 4,921 4,139.1 48.49 GAS LIFT CAMCO/KBMG/l /GLV /BK/.2511381/ Comment: STA 2 12120/1992 2.371 6,329 5,062.8 49.93 GAS LIFT CAMCO/KBMG/l /GLV /BK/.31311552/ Comment: STA 3 12/20/1992 2.371 GAS LIFT, 6,867 5,427.9 45.61 GAS LIFT CAMCO/KBMG/1 /DMY /BK/ // Comment: STA 4 4122/1991 2.371 7,100 5,591.0 45.50 CMT Plug CEMENT SQZ & PLUG. PUMP 21 bbls of 18.8 ppg CLASS 1/3/2010 0.000 G CEMENT, ESTIMATED 12 bbis BEHIND PIPE WITH ESTIMATED TOC @ 7100' MD. GAS LIFT, 6,329 7,155 5,629.6 45.37 GAS LIFT MMH/2 7/8 X 1 11211.510WRK/.251/ Comment: STA 5 3/9/1993 2.347 7,201 5,662.5 45.45 PBR Blown 9/311986 2.500 7,217 5,673.6 45.34 PACKER Brown'HB -1' PACKER 9/3/1986 2.441 GAS LIFT, 7,254 5,699.5 45.09 PRODUCTION CAMCO(KBMG/l /HFCV /BEK/ // Comment: OPEN STA 6 1/6/1998 2.371 6,867 7,325 5,749.7 44.60 PRODUCTION CAMCO/KBMG/1 /OPEWBK/ / /Comment: OPEN; UNABLE 1/6/1998 2.371 TO SET CV STA 7 7,427 5,822.9 44.14 PRODUCTION CAMCO/ KBMG /1MFCV /BEK( / / Comment: OPEN STAB 1/7/1998 2.371 7,450 5,839.4 44.05 PACKER Brown'l -B' PACKER 9/3/1986 3.250 7,463 5,848.7 44.00 NIPPLE Cameo'D' Nipple NO GO 9/3/1986 2.250 7,471 5,854.5 43.97 SOS Brown 9/3/1986 2.441 GAS LIFT, 7,472 5,855.2 43.96 TTL no ELMD TTL available 9/3/1986 2.441 7,755 Perforations & Slots Shot Top (TVD) Bt. (TVD) Dens a6R, 7 201 To (ftKB) Bbn (ftKB) (ftKB) (ftKB) Zone Date (sh °• Type Comment 7,392 7,414 5,797.6 5,813.7C-4,2T-13 9/3/1986 12.0 5" SOS 7,532 7,579 5,899.0 5,932.5 A4, A -3, 2T -13 9/311986 4.0 4" SOS Notes: General & Safe End Data I Annotation PACKER, 7,217 7/20/2007 NOTE: IMPENETRABLE TBG RESTRICTION @ 324', 1.52" TOOLS WON'T PASS t PRODUCTION, 7,254 CMT Plug, 7,100 PRODUCTION, 7,325 S SOS, 7,392 -7,414 PRODUCTION, 7,427 L- 1 PACKER, 7,450 1 i NIPPLE, 7,463 1 SOS, ],471 - - -- • TTL, 7,472 4-SOS . 7,532 -7,57 PRODUCTION, 7,839 TD, 7,666 I + + + + I I E 16 +00 0 0 C 0 O o o o ° o ° o N N N CO 0 d N_ Z Z Z Z Z Z 2 DS NORM \ I I + + DRILL SITE 2T I + I + I I E 14 +00 I I AM e _ e r cso + \ E 12 +00 — LLJJ • Oi ISf 18E • • � p � . 2 ppp ■■ T � g 2R2 - .. ••y;nso o ♦ n r 17 53 e9RR R R F q FR Ki3FF F irF A + I 1 E 10 +00 — — — SC � 700 0 50 10o LEGEND O THERMOSIPHONS 1 "= 100' 0 WELLS LOTINBBDRY I ', FORM: BSIZE DRAWN: DESIGN: ECM N0: AREA: 2T MODULE: )000( UNIT: D2 DT CHECKED: AJR APPROVAL CC NO: ConocoPhillips PLOT PLAN — — — Alaska, Inc. 1 130 10 Updated Thermos hon and Wdl Asbultlocations NRB JFC SCALE DATE CADD FILENAME JOB N0: SUB JOB NO DRAWING NO: PART: REV: REV DATE REVISION BY CHK JOB PROD 1" = 100' 3/13/09 S2T PLT PLN 3/13/09 NSDK 1 0000 DS2T PLOT PLAN 1 OF 1 1 1 _.._ /r�►rrry rrrrrir.� ......... . , . iii'* & 1 r 4w it A ti AF- _ �_� � �.. .o IC I I I r 9 2T -13 PTD 186 -089 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska. Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska • STATE OF ALASKA • MAY ~: 0 201a ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~,,,~~I~~gPLETION OR RECOMPLETION REPORT AND LOG. 1a. Well Status: Gas ^ SPLUG ^ Other ^ Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: 1b. Well Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp. usp. or Aband.: January 3, 2010 . Permit to Drill Number: 186-089 / 309-399 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 5, 1986 13. API Number: 50-103-20067-00 4a. Location of Well (Governmental Section): Surface: 77' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 7. Date TD Reached: May 11, 1986 .Well Name and Number: 2T-13 Top of Productive Horizon: 1327' FNL, 1155' FEL, Sec. 12, T11 N, R8E, UM 8. KB (ft above MSL): 117' RKB GL (ft above MSL): 61' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1399' FNL, 837' FEL, Sec. 12, T11 N, R8E, UM 9. Plug Back Depth (MD + TVD): 7754' MD / 6059' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498945 y- 5970058 Zone- 4 10. Total Depth (MD + TVD): 7868' MD / 6144' TVD 16. Property Designation: ADL 25569 TPI: x- 502514 y- 5968654 Zone- 4 Total Depth: x- 502832 - 5968582 Zone- 4 11. SSSV Depth (MD + TVD): 1787' MD / 1783' TVD 17. Land Use Permit: 2667 18. Directional Survey: Yes ^ No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 1550' MD / 1550' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. Re-drill/Lateral Top Window MD/TVD not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE CORD G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE PULLED 16" 62.5# H-40 Surf. 105' Surf. 105' 24" 225 sx CS II 9.625" 36# J-55 Surf. 2976' Surf. 2835' 12.25" 820 sx AS III, 320 sx Class G 7" 26# J-55 Surf. 7839' Surf. 6124' 8.5" 380 sx Class G, 175 sx AS I 24. Open to production or injection? Yes ^ No a If Yes, list each 25. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlrVD) 2_$75" 7472' 7217' MD / 5673' TVD, 7450' MD / 5839' TVD perfs squeeze off III( ~'r ~ ~PetSSED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. A4 ~T'- (A' Ff}ILED "- 5~ ~ Gt ~ ' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED top of cement 7100' 21 bbls of 15.8 ppg Class G `~ ,~a~-<a 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE ~„~ l,''~a+tt~.tc. t"', ,.~~,i~~ s~ '~ 'I[)~~s Form 10-407 Revised 12/2009 RB~MS MAY 10 ZQ CONTINUED ON REVERSE Submit original only X21-`0 ~~~ 28. GEOLOGIC MARKERS (List all formations and markers ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1550' 1550' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 7391' 5796' Base Kuparuk C 7416' 5814' Top Kuparuk A 7509' 5881' Base Kuparuk A 7700' 6019' N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certi t the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Na J. Ennis Title: Wells Engineer ~ ~ 0 ~ 0 ~ -- 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 2T-13 Well Events Summary 'DATE SUMMARY 1/3/10 PUMP 21 bbls OF 15.8 ppg CLAS~CEMENT. ESTIMATED 12 bbl BEHIND ~ WITH A ESTIMATED TOC @ 7100' MD. WELL SHUT IN AND FREEZE PROTECTED. NOTE: WOC 24 hours BEFORE TESTING. 1/12/10 MIT-T (PASSED), MITIA (FAILED) 1/17/10 MITT-PASSED; STATE WITNESSED (JOHN CRISP) '~ 1/25/10 BLEED T, IA & OA. T PRESSURE BLED DOWN 20 PSI IN 1 HOUR. IA PRESSURE REMAINED CONSTANT DURING 1.5 HOUR BLEED. OA PRESSURE BLED TO 0 IN 30 MINS. 2/8/10 ATTEMPT TO BLEED T / IA / OA TO 0 PSI, TUBING AND OA BOTH BLEED TO 0 PSI, IA WILL NOT BLEED DOWN PAST 50 PSI 2/9/10 MONITOR WHP'S POST T, IA & OA BLEED. T/I/0=20/100/0 5/7/10 Well Integrity Group determined that further venting of IA to eliminate slight pressure buildup would not be performed. ~'~ t~ \ Cana~t~Phlfp~ Al~~k~ ~r~C~ sss~ (1787-1788, OD:2.875) Gas Lift Mandrel/Valve 1 (2637-2638, Gas Lik Mandrel/Valve 2 (4921-0922, Gas Lift MandrelNalve 3 (6329-6330, Gas Lik andrel/Dummy Valve 4 (6867868, OD:4.750) Gas Lik MandrelNalve 5 (7155-7156, PBR (7201-7202, OD:2.875 ) PACKER (7217-7218, OD:6.151) Production MandrelNalve 6 (7254-7255, Production Mandrel/Valve 7 (7325-7326, Production MandrelNalve 8 (7427-7428, PACKER ~~ (7450-7451, OD:6.151) NIP (7463-7464, OD:2.875) TUBING (0-7472, OD:2.875, ID:2.441) Ped (7532-7579) KRU 2T-13 • Schwartz, Guy L (DOA) • Page 1 of 1 From: Galiunas, Elizabeth C [Elizabeth.C.Galiunas@conocophillips.com] Sent: Tuesday, May 25, 2010 8:25 AM To: Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj Subject: RE: 2T-13 status (PTD 186-089} Guy, I apologize for the confusion. This well is on the Nordic 3 rig schedule in November for a full P&A. My understanding is that the well is not suspended and will not change status until the rig moves on the well to permanently P&A. We are currently working on the funding for this work and the permits will soon follow. Liz Liz Galiunas Drillsite Petroleum Engineer ConocoPhillips Alaska Office: 907-265-6247 Cell: 907-903-1200 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, May 21, 2010 11:04 AM To: Galiunas, Elizabeth C Subject: 2T-13 status (PTD 186-089) Liz, Do you know the plans for additional securing of 2T-13. It passed MIT-T but failed the MIT-IA after the fullbore cement job. We have it on our suspended status... but technically it has to pass aMIT-IA to before we can grant that status. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 5/26/2010 MEMORANDUM TO: Jim Regg ~ ~~ ,~~~~ ~ o P.I. Supervisor FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 27, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-13 KUPARUK RIV UNIT 2T-13 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~ Comm Well Name: KUPARUK RIV UNIT 2T-13 API Well Number: 50-103-20067-00-00 Inspector Name: John Crisp Insp Num: mitJCr100121090113 Permit Number: 186-089-0 Inspection Date: 1/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-13 Type In~N~ TVD s673 ~ IA 0 0 0 0 P.T.D 1$60890 TypeTest~ sPT Test psi zsoo ~' OA o 0 0 0 Interval oT~R P/F P ~ Tubing ]ozo zszo ~ za9o zaso ' Notes: 1-OIL completion status; MTI'T per sundry 390-399. Estimated cement top @ 7100' MD..5 bbl pumped for test. Verified IA & OA open for test. Pumpe open & applied 4000 psi on tubing retrievable SSSV for tubing test. Wednesday, January 27, 2010 Page 1 of 1. SEAN PARNELL, GOVERNOR Lr I J ALASKA OIL AND GAS y 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION r ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Jim Ennis Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River, Kuparuk River Oil, 2T - Sundry Number: 309-399 200S �i�-ft,AWNED' Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. -( Chair DATED this 07 day of December, 2009 Encl. (A • RECEIVED IV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION D EC 0 1 2009 APPLICATION FOR SUNDRY APPROVA ka Oil &Gag Cons. Conunission 20 AAC 25.280 AnehAPARA 1. Type of Request: Abandon ❑ Suspend Operational Shutdown El Perforate ❑ Re -enter Suspended Well ❑ Repair well •01 Alter casing ❑ p ❑ ty Plug Perforations � � 11y+0 Stimulate ❑ Other ❑ Specify: Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Time Extension ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑� • Exploratory ❑ 86 - 89 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20067 L�} 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 El 2T -13 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADK 25569 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7868' 6144' • 7754' 6059' Casing Length Size MD TVD Burst Collapse CONDUCTOR 105' 16" 105' 105' SURFACE 2976' 9 -5/8" 2976' PRODUCTION 7839' 7" 7839' 6124' Pe ation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7392'- 7414', 7532' -7579' 5798'- 5813', 5898' -5932' 2.875" J -55 7472' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) Brown'HB - 1' pkr and Brown'1 -B' pkr @ 7217' MD / 5673' TVD and 7450' MD / 5839' TVD Camco TRDP -1A SSSV @ 1787'MD / 1783' TVD 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑ ,� 14. Estimated Date for 15. Well Status after proposed work: S4SPvt . Commencing Operations: December 9, 2009 Oil ❑ Gas ❑ WDSPL ❑ -own" ❑� 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned[ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265 -1544 Printed Na a III E niS Title: Wells Engineer q Signature Phone 265 -1544 Date f� 3 0 1 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity W Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ���GC GCr f7tLC� ' - 720C 6 r�55��� l '�u Z Sd� p sZ , Subsequent Form Required: / O• qO 7 APPROVED BY 2J/0 Approved b COMMISSIONER THE COMMISSION Date: 1 r 1 -40� �$v�l 0 � R I � I N A L � /Z • �, � q Submit in Duplicate 0 . Well 2T -13 Kuparuk Producer Pump cement plug for well control barrier Network 10258895 Well History: 2T -13 was originally completed as a single selective Kuparuk producer in 1986. In March, the well failed an MITOA due to a surface casing leak at 342' as indicated by fluid levels. Subsequent diagnostics indicate a failed TIFL and corkscrewed tubing will not allow access beyond 320' SLM. The corkscrewed tubing is believed to be the result of well subsidence. The procedure outlined below will plug the Kuparuk reservoir w/ cement until a workover to restore injection or P &A can occur. TOC for the plug is targeted for 7100' MD. go 4fae4fVaAr-1r' 1phea /leeur� a* r� 7:'•ne� �� � Work accomplished to date: 9/26/09 PUMPED A TOTAL OF 290 BBLS OF SEAWATER TO TUBING. OPENED IA TO TANK AFTER FIRST 20 BBLS, RATE= 1.5 BPM, WHP= 700 PSI. BLEED GAS OFF FROM 100 PSI TO ZERO AND DID NOT SURFACE ANY FLUIDS. CLOSED IA AND CONTINUED PUMPING THE REMAINING 250 BBLS OF SEAWATER AT 3.5 BPM, AVG WHP= 1650 PSI. SHUT DOWN PUMPS, ISIP= 640 PSI, 5 MIN= 350 PSI, 10 MIN= 280 PSI. CONTINUED TO MONITOR PRESSURES FOR 1 HOUR, FINAL WHP= 175 PSI. FREEZE PROTECTED TUBING W/ 15 BBLS DIESEL, PUMPED 50 BBLS DIESEL TO IA. BLED IA TO 0 PSI. LEFT WELL SHUT IN. 9/24/09 OA BLEED, MEASURE GAS RATE AND VOLUME 9/23/09 OA BLEED, MEASURE GAS RATE AND VOLUME 9/22/09 OA BLEED, MEASURE GAS RATE AND VOLUME 9/21/09 BLEED OA, MEASURE GAS RATE AND VOLUME 9/20/09 OA BLEED / MEASURE GAS RATE AND VOLUME 9/19/09 RIG UP 2" DANIELS ORIFICE METER TO OA 9/18/09 TROUBLESHOOT GAS MIGRATION 9/17/09 ATTEMPT TO BLEED IA/OA DOWN 9/16/09 BLEED IA TO FTP & OA TO 0. IN PROGRESS 6/28/09 TIFL - PASSED 5/1/09 RIH WITH 1.75 SWAGE, UNABLE TO WORK PAST 320' SLM. RIH WITH 1.525" GAUGE, UNABLE TO WORK PAST 322' SLM. COMPLETE. 4/27/09 RE -TIFL - PASSED. 4/21/09 RE -TIFL - PASSED 4/20/09 TIFL - INCONCLUSIVE; T POT- PASSED; T PPPOT - PASSD; IC POT - PASSED; IC PPPOT - PASSED 7/20/07 ATTEMPTED WORK 1.52" TOOLS THROUGH RESTRICTION @ 324' WLM, NO SUCCESS. RECOVERED SMALL SAMPLE OF SCALE FROM 324' WLM. 6/25/07 Video Log using lift gas to depress fluid below 116'. Log down with 2 -1/4" camera with centralizers. Sat down at 131'. Picture not real clear but appears to have some scale along entire tubing wall. POOH and change to 1- 11/16" camera with no centralizers. Video clearer with some visible scale on tubing. Set down again at 131' and cannot work passed. No precise evidence as to what is impeding tools. POOH secure well and contact DSO. Remaining work: 1. RU SLB cementer. Bullhead 50 bbls fresh water down tbg at max rate below 2500 psi followed by 100 sx Class 'G' cement w/ additives as shown on attached cement test report. Launch "nerf' cmt plug and displace w/ 5 bbls freshwater and 36 bbls diesel. SI and record SITP. WOC 24 hours. PT cmt plug down tbg to 2500 psi. PT IA to 2500 psi. Equalize tbg & IA across wellhead to allow diesel U -tube & bleed all WHP to zero. Jim Ennis Page 1 11/24/2009 0 0 ConocoPhillips Alaska, Inc. KRU 2T -13 2T -13 API: 501032006700 Well Type: PROD Angle TS: 44 de 7390 SSSV Type: TRDP Orig 5/13/1986 Angle @ TD: 42 deg @ 7868 sssV Completion: (1787-1778, OD:2.875) Annular Fluid: Last W /O: Rev Reason: FOUND TBG RESTRICTION Reference Log: Ref Loci Date: Last Update: 7/22/2007 Last Tag: 7657 TD: 7868 ftKB Gas Lift Last Tag Date: 1/5/1998 Max Hole Angle: 51 deg @ 6200 MandreWalv Casin String - CONDUCTOR 1 (2637 -2638, Description Size Top Bottom TVD Wt Grade I Thread CONDUCTOR 1 16.000 0 105 105 62.50 H -40 Casing String - SURFACE Gas Lift Description I Size I TOD I Bottom I TVD I Wt Grade Thread MandreWalve SUR. CASING 1 9.625 0 2985 1 2842 1 36.00 1 J -55 2 (4921 -4922, Casing String - PRODUCTION Description Size To Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 7839 1 6124 1 26.00 1 J -55 Gas Lift Tubing String - TUBING Mandrel/Valve 3 Size To Bottom TVD Wt Grade Thread 3 (6329 -6330, 2.875 0 7472 5855 6.50 J -55 EUE 8RD AB -MOD Perforations Summary Interval I TVD I Zone Status Ft SPF Date Type Comment Gas Lift 7392 - 7414 1 5798 - 5813 C-4 1 22 12 9/3/1986 5" SOS andreVDu 7532-7579 5898-5932 A-4 A -3 47 4 9/3/1986 4" SOS Valve ve 4 4 - (6867 -6868, Ga Lift Mandrels/Valves 0D:4.750) St MD TVD Man Mir Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt Gas Lift 1 2637 2569 Carrico KBMG GLV 1.0 BK 0.250 1365 2/20/199 Mandrel/Valve 2 4921 4139 Carrico KBMG GLV 1.0 BK 0.250 1381 12/20/199 5 (7155-7156, 3 6329 5063 Carrico KBMG GLV 1.0 BK 0.313 1552 2/2((199 4 6867 5428 Carrico KBMG DMY 1.0 BK 0.000 0 4/22/1991 5 7155 5630 MMH 2 7/8 X 1 OV 1.5 RK 0.250 0 3/9/1993 PBR 112 (7201-7202, Production Mandrels/Valves OD:z.975) St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 6 7254 5699 Carrico KBMG HFCV 1.0 BEK 0.000 0 1/6/1998 Open PACKER 7 7325 5750 Carrico KBMG OPEN 1.0 BK 0.000 0 1/6/1998 1 (7217 -7217, 8 7427 5823 Carrico KBMG HFCV 1.0 BEK 0.000 0 1/7/1998 C, n OD 6.151) 1. O en� Unable to Set CV Other lu s equip., etc. - COMPLETION Depth I TVD I Type Description ID Production 1787 1783 SSSV CamcoTRDP -1A 2.312 Mandrel/Valve 7201 5662 PBR Brown 2.500 6 7217 5673 PACKER Brown 'HB -1' 2.441 (7254 -7255' 7450 5839 PACKER Brown'1 -B' 3.250 7463 5849 NIP Camoo'D'Nipple NO GO 2.250 Production 7471 5854 SOS Brown 2.441 Mandrel/Valve 7472 5855 TTL 2.441 7 General Notes (7325 7326, Date Note 7/20/2007 NOTE: IMPENETRABLE TBG RESTRICTION CcD 324' 1.52" TOOLS WONT PASS Production MandreWalve 8 (7427 -7428, PACKER (7450 -7451, OD:6.151) NIP (7463 -7464, OD:2.875) TUBING (0 -7472, OD:2.875, ID:2.441) Perf (7532 -7579) MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIA -UNDER THIS PAGEL C..y_j.? U b~J U ~ U'%~ U-"'u~ ,.~, u ~.~ DEPT. OF N2kTLTR2kL RESOURCES DIVISION OF OIL AND GAS April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data ,/ WALTER J. HICKEL, GOVERNOR P.O. BOX 107034 ANCHORAGE. ALASKA 99510-7034 PHONE: (907) 762-2553 Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T11N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, (J~,t.mes E. Eason '3Director cc: J. L. Dees, ARCO Alaska Inc. RE( EIVED APR 1 6 199t Alaska 0il & Gas Cons. commission Anchorage '.z....w l;r,r~l ~tj ,)n rdc',,"J:ed paper 5 / C~.,~. DEPART~IENT OF NATURAL RESOURCES August 5, 1988 DIVISION OF OIL AND GAS Jon Wood, Area Landman ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99§10-0360 Dear Mr. Wood: STEVE COWPER, G(~~. P.O. BOX 7034 '-~J~'~-"~---"-'-- I. L~G ASs~ In your July 8 letter and in our August 3 meeting, you requested extended confidentiality for the data from the Kuparuk River Unit "drillsite 2T" wells. You indicated that reports and information from these wells contain significant information relating to the valuation of unleased land in Township ll North, Range 7 East, U.M. This unleased land is currently scheduled to be offered for lease in Sale 70A in September 1989. Following your written request, the August 3 meeting and further review of the well data by my staff, I agree to extend the confidentiality of the data from the ARCO Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, lO, ll, 12, 12A, 13, 14, 15, 16 and 17 wells. The data from these wells will be released after the aforementioned land is offered for lease. In your letter and supporting data, you requested confidentiality for data from a "2T-16A" well. The Alaska Oil and Gas Conservation Commission (AOGCC) has advised the division that they have no record of a "2T-16A" well. The 2T-16 well was side-tracked but no new number was assigned to the well. Therefore, all of the data from the well are filed under 2T-16 at AOGCC. The first 2T well scheduled to be released is the 2T-12 Well (August 6, 1988) and the last 2T well release date is the 2T-8 Well (January 15, 1989). The division is making a special exception to our policy of considering extended confidentiality no sooner than 90 days prior to a release date because it is prudent to, in this case, grant the extension of confidentiality for the 2T wells as a group. By copy of this letter I am requesting that AOGCC keep confidential the data from all of the Kuparuk River Unit 2T wells until fur.ther notice. Sincerely, Eason ames E. i rector cc' C.V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR ARCO Alaska, In, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal ~t 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. lA-5 Static Well Pressure Report 6-8-87 2T-13 PBU Well Pressure Report 7-11-87 2A-11 PBU Well-PressUre-Report 4-16,18-87 2U-13 Pressure Buildup Survey 4-25-87 2C-16 GLM Survey & Temp Gradient Survey 4-13-87 ~ka 0il & Gas COllL~. uulIImlssIJ~, Anchorage Receipt Acknowledged: DISTRIBUTION: BP Chevron MObil SAPC State of Alaska D&M ARCO Alaska. Inc. is a Subsidiary o! AllanticRichlieldCompany Date: Unocal SJ.c, :i'; '. .,' ' ARCO Alaska, Inc. Post Office ,.,,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 RETURN TO: ARCO Alaska, Inc. --Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this-transmittal. 2A-12 CET. 3-8-86 6410-7007 3F-16 CET 1-13-86 7740-8443 2A-lO CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 -- 3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL '2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ~~~'~' BPAE Chevron Unocal Vault (fi~) ~ ~' '' STATE OF ALASKA ~ ALASKA UlL AND GAS CONSERVATION CC/MMISSION ,:,~.-. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 86-89 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20067 4. Location of well 'at surface 9. Unit or Lease Name 77' FSL, 556' FWL, Sec. 1, T11N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1327' FNL, 1155' FEL, Sec. 12, T11N, R8E, UM 2T-13 At Total Depth 11. Field and Pool 1399' FNL, 837' FEL, Sec. 12, T11N, R8E, UM Kuparuk River Field 5. Elevation in feet (indi'cate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 117' RKB ADL 25569 ALK 2667 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 05/05/86 05/11/86 11/23/86* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7868'MD,6144'TVD 7754'MD,6059'TVD YES~ NO []I 1787 feet MD 1550' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/CAL/GR,FDC/CNL, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 16" 62.5# H-40 Surf 105' 24" 225 sx CS II 9-5/8" 36.0# J-55 Surf 2976' 12-1/4" 820 sx AS Ill & 320 sx ;lass G Performed top job w/150 sx AS l 7" 26.0# J-55 Surf 7839' 8-1/2" 380 sx Class (] & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD 73~§~efv-~4~i4el I~[~d nv~r)s p f, 90° phasing SIZ~E~_7/o .... DEPTH7472:SET (MD) PACKER72i 7:, SET/450~(MD) 7532'-7579'MD w/ 4 spf, 90° phasing 5797 '-5812 'TVD "26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5897'-5932'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED S~u di, bached Adden]um, dated i2/i3/86, tor tracture dat 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) J I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE e 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ., : '. *Note: Drilled RR 5/13/86. Tubing was run & well perforated 09/03/86. _. Form 10-407 DAM/WC1:169 Submit in duplicate / Rev. 7-1-80 CONTINUED ON REVERSE SIDE ^ n/' 29. (~. ~ 30. .... :" GEOLOGIC MARKERS FORMATION TESTS '-' . · NAME ,. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GaR, and time of each phase. Top Kuparuk C 739.1.' 5796' N/A Base Kuparuk C 7416' 5814' Top Kuparuk A 7509' 5881' Base Kuparuk A 7700' 6019' 31. LIST OF ATTACHMENTS Addendum (dated 12/13/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ ~ Associate Engineer Signed Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 8/22/86 11/22/86 11/23/86 12/06/86 2T-13 RU Schl, rn 6.1" Gage Ring/JB/Wt Bar, set dn @ 7450', wrk dn to 7460'; unable to get further, POOH. JB full of contaminated cmt chunks. PU 3-3/4" gage ring, RIH, set dn @ 7460', wrk dn to 7585'; unable to get below the base of "A" sand @ 7704', POOH, RD Schl. Pmp 26 bbls diesel & 5% Musol spear. Displ spear w/61 bbls of diesel @ 1.5 BPM, 2350 psi. Frac Kuparuk "A" sand perfs 7804'-7850' in six stages per 11/12/86 procedure using diesel/5% Musol, gelled diesel and 20/40 sand. Press'd ann to 2500 psi w/diesel. Tst Ins to 7500 psi; OK. Stage #1 and #2: Pmp'd above-mentioned spear (11/22/86). Stage #3, 4 & 5: Pmp'd 18 bbls of pad, 17 bbls of 8 ppg 20/40 slurry and flushed w/66.5 bbls of gelled diesel. Pmp'd 16.5 bbls 8 ppg slurry in formation leaving .5 bbls in the wellbore. Load to recover 188 bbls of diesel. Job complete ~ 1500 hfs, 11/23/86. NU BOPE. RIH w/CTU, wsh sand @ 1.75 BPM, 3700 psi f/6500' to +7500, tag fill. Wsh sand f/7500'-7736' CTM, CBU. POOH, displ'g well w/cln diesel. SI well, RD CTU. SUB.$ URFA CE DIRECTIONAL SURVEY ~]UIDANCE ~]ONTINUOUS ~"~ OD L kECElV'~.I) SEP 2 5 Gas Cons. Commissi An~h0r~?'- Company Well Name Field/Location ARCO ALASKA, INC. 2T-13 (77'FSL,556'FWL, SEC 1,TllN,R8E,UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71693 Loc~aed By: FINNELL Date 9/2/86 Computed By: GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. 2T-13 KUPARUK NORTH SLOPE~ALASKA SURVEY DATE: 02-SEP-86 ENGINEER: RUBENSTEIN METHODS OF COMPUTATION TO~L LOCA'TION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 67 DEG z, 1 MIN EAST C~MPUTATION DATE: lO-SEP-85 PAGE 1 ARCO ALASKA, INC. 27-13 KUPARUK NORTH SLOPE,ALASK& TRUE MEASURED VERTICAL DEPTH DEPTH 0.00 0.00 100.00 100.00 200.00 200.00 300.00 300.00 400.00 400.00 ~00.00 500.00 000.00 600.00 700.00 699.99 800.00 799.99 900.00 899.99 1000.00 999.98 1100.00 1099.97 1200.00 1199.96 1300.00 1299.95 1400.00 1399.92 1500.00 1499.83 1600.00 1599.32 1700.00 1697.97 1800.00 1795.91 1900.00 1893.38 2000'.00 1989.68 2100.00 2085.16 2200.00 2179.04 2300.00 2271.29 2400.00 2362.00 ~00.00 2450.92 '.00.00 2537.45 ~,00.00 2821.14 2800.00 2702.01 2900.00 2779.14 3000.00 2852.13 3100.00 2923.45 3200.00 2993.63 3300.00 3062.66 3400.00 3130.83 3500.00 3198.52 3600.00 3265.99 3700.00 3332.78 3800.00 3399,13 3900.00 3465.24 INTERPOLATED VALUES FOR EVEN 100 FEET OF M;ASURE SUB-SEA COURSE VERTICAL DOGLEG RECTAN VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/ DE~TH DEG MIN DEG MIN FEET DEG/iO0 FEE -117.00 0 0 N 0 0 E 0.00 0,00 -17.00 0 1 S 68 35 W 0.03 0.06 83.00 0 5 S 17 10 w 0.02 0,14 183.00 0 7 S 52 34 E 0.15 0.25 283.00 0 10 N 73 9 E 0.34 0.13 383.00 0 17 N 65 40 E 0.63 0.17 483.00 0 22 N 52 39 E 0.96 0.08 582.99 0 27 N 47 21 E 1.36 0.21 682.99 0 24 N 42 42 E 1.62 0.06 782.99 0 30 N 56 42 E 1.93 0.37 882.98 0 42 N 65 21 E 2.66 0.11 982.97 0 49 N 63 7 E 3.54 0.06 1082.96 0 53 N 65 35 E 4.5'4 0.21 1182.95 1 9 N 85 8 E 5.86 0.35 1282.92 1 48 S 78 21 E 8.26 0.48 1382.83 3 27 S 62 41 E 12.43 3.20 1482.32 7 53 S 54 41 E 21.96 4.40 1580.97 10 44 S 54 21 E 37.75 2.84 1678.91 12 13 S 58 11 E 57.53 0.57 1776.38 14 8 S 61 18 E 79.69 3.36 1872.68 16 36 S 63 5 E 106.48 1,35 1968.16 18 27 S 62 36 E 136.07 3.61 2062.04 21 39 S 63 23 E 170.33 2.54 2154.29 23 28 S 64 41 E 208.87 1.39 2245.00 26 22 S 64 33 E 250.86 2.67 2333.92 28 18 S 63 59 E 296.52 3.75 2420.45 31 33 S 62 29 E 346.47 4.30 2504.14 34 36 S 62 27 E 400.94 2.03 2585.01 37 42 S 63 10 5 459.51 3.61 2662.14 41 28 S 63 23 E 522.94 4.37 2735.13 44 2 S 63 39 E 591.11 1.09 2806.45 44 58 S 63 51 E 661.04 1.13 2876.63 45 51 S 64 1 E 732.13 0.94 2945.66 46 44 S 64 12 E 804.33 0.67 3013.83 47 22 S 64 17 5 877.36 0.76 3081.52 47 19 S 64 42 E 950.85 0.51 3148.99 47 52 S 65 3 E 1024.58 0.55 3215.78 48 16 S 65 13 E 1098.93 0.35 3282.13 48 31 S 65 23 E 1173.67 0.27 3348.24 48 39 S 65 27 E 1248.65 0.21 . O. O. O. O. O. O. O. 1. 1. AT~ OF SURVEY: 02-SEP-86 ELLY BUSHING ELEVaTiON: 117.00 FT ENGINEER: RUBENSTEIN D DEPTH GUL&R CODRglNATES HORIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MZN O0 N 0.00 E 0.00 N 0 0 E 04 N 0.05 E 0.07 N 51 49 E 04 S 0.01 E 0.04 S 11 10 E 23 S 0.06 E 0.24 S 15 47 E 24 S 0.27 E 0.36 S 48 38 E 08 S 0.64 E 0.65 S 82 37 E 24 N 1.14 E 1.17 N 77 5~ E 66 N 1.74 E 1.87 N 69 7 E 23 N 2.26 E 2.57 N 61 21 E 76 N 2.81 E 3.32 N 57 58 E 2.22 N 3.78 E 4.38 N 59 37 E 2.79 N 4.97 E 5.70 N 60 39 E 3.41 N 6.31 E 7.17 N 61 38 E 3.89 N 7.93 E 8.83 N 63 51 E 3.69 N 10.44 E 11.07 N 70 30 E 2.25 N 14.36 E 14.53 N 81 5 E 3.00 S 22.51 E 22.70 S 82 24 E 12.72 S 35.59 E 37.79 S 70 20 E 23.79 S 52.43 E 57.57 S 65 35 E 35.14 S 71.72 E 79.86 S 63 53 E 47.54 S 95.58 E 106.75 S 63 33 E 60.99 S 122.05 E 136.44 S 53 26 E 76.90 S 152.55 E 170.84 S 63 14 E 93.64 S 187.35 E 209.44 S 63 26 E 111.56 S 225.38 E 251.48 S 63 39 E 131.46 S 266.56 E 297.22 S 63 44 E 154.07 S 311.28 E 347.33 S 63 40 E 179.45 S 359.75 E 402.02 S 63 29 E 206.29 S 412.05 E 460.80 S 63 24 E 234.89 S 468.87 E 524.42 S 63 23 E 265. 296 · 327. 359. 391 · 422. 454. 485. 516 · 547. 34 S 530.06 E 592.77 S 63 24 E 31 S 592.94 E 662.86 $ 63 26 E 64 S 656.93 E 734.10 S 63 29 E 20 S 722.02 E 806.43 S 63 32 E O0 S 787.91 E 879.59 S 63 36 E 74 S 854,32 E 953.20 S 63 40 E 02 S 921.18 E 1026.99 S 63 45 E 29 S 988.72 E 1101.39 S 63 51 E 53 S 1056.69 E 1176.18 S 63 56 E 73 S 1124.93 E 1251.19 .S 6~ 2 E COMPUTATION DATE: lO-SEP-86 PAGE 2 ARCO ALASKA, INC. 27-13 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 02-$EP-86 KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASUREO DEPTH 117.00 FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZST. AZZMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3531.17 3414.17 48 48 4100.00 3596.93 3479.93 48 57 4200.00 3662.55 3545.55 49 0 4300.00 3728.17 3611.17 48 56 4400.00 3793.88 3676.88 48 52 500.00 3859.76 3742.76 48 41 600.00 3925.78 3808.78 48 39 4700.00 3991.89 3874.89 48 31 ,800.00 4058.14 3941.14 48 33 4900.00 4124.35 4007.35 48 30 S 65 27 E 1323.78 S 65 27 E 1399.06 S 65 29 E 1474.46 S 65 36 E 1549.87 S 65 -8 E 1525.21 S 65 53 E 1700.40 S 65 57 E 1775.47 S 66 4 E 1850.46 S 66 17 E 1925.35 S 66 27 E 2000.27 0.20 0.03 0.16 0.24 0.24 0.09 0.28 0.20 0.24 0.10 578.95 S 1193.33 E 1326.36 S 64 7 E 510.25 S 1261.86 E 1401.67 S 64 11 E 641.58 S 1330.51 E 1477.11 S 64 15 E 672.81 S 1399.20 E 1552.56 S 64 19 E 703.82 S 1467.91 E 1627.92 S 64 23 E 734.59 S I536.56 E 1?03.12 S 64 26 E 765.22 S i605.i3 E I778.20 S 64 30 E 795.74 S 1673.67 E 1853.21 S 64 34 E 826.00 S 1742.20 E 1923.09 S 64 38 E 856.00 S 1810.87 E 2002.99 S 64 ~1 E 5000.00 4190.64 4073.64 48 26 5100.00 425?.00 4140.00 48 25 5200.00 4323.36 4206.36 48 23 5300.00 4389.85 4272.85 48 14 5400.00 4456.45 4339.45 48 16 5500.00 4523.14 4406.14 48 3 5600.00 4589.88 4472.88 48 15 5700.00 4656.29 4539.29 48 35 5800.00 4722.07 4605.07 49 8 5900.00 4787.17 4670.17 49 36 S 66 35 E 2075.13 S 66 46 E 2149.92 S 66 56 E 2224.72 S 67 23 E 2299.42 S 67 47 E 2374.01 S 68 29 E 24~8.52 S 69 29 E 2522.97 S 70 22 E 2597.67 S 71 19 E 2672.88 S 72 27 E 2748.59 0.16 0.20 0.30 0.45 0.33 0.80 0.82 0.76 1.05 1.18 885.83 S 1879.55 E 2077.84 S 64 45 E 915.45 S 1948.24 E 2152.60 S 64 49 E 944.84 S 2017.03 E 2227.36 S 64 54 ~ 973.88 S 2085.85 E 2302.01 S 64 58 E 1002.29 S 2154.82 E 2376.52 S 65 3 E 1030.10 S 2223.95 E 245'0.93 S 65 8 E 1056.81 S 2293.47 f 2525.24 S 65 15 E 1082.41 S 2363.70 E 2599.75 S 65 23 E 1107.19 S 2434.83 E 2674.75 S 65 32 E 1130.82 S 2506.97 E 2750.21 S 65 43 E 6000.00 4851.76 4734.76 49 50 6100.00 4916.03 4?99.03 50 15 6200.00 4979.62 4862.62 50 39 6300.00 5043.01 .926.01 50 29 6400.00 5107.71 4990.71 48 36 ~500.00 5174.26 5057.26 48 17 00.00 5241.13 5124.13 47 10 ..,'00.00 5310.23 5193.23 45 54 6800.00 5379.88 5262.88 45 46 6900.00 5449.79 5332.79 45 36 S 73 33 E 2824.58 S 73 38 E 2900.78 S 73 55 E 2977.53 S 74 27 E 3054.37' S 74 56 E 3130.04 S 75 32 E 3204.03 S 75 40 E 3277.64 S 75 11 E 3349.29 S 75 43 E 3420.39 S 76 25 E 3491.13 0.32 0.59 0.37 1.09 1.48 0.56 2.73 0.47 0.50 0.62 1152.95 S 2580.03 E 2825.93 S 65 55 E 1174.58 S 2653.52 E 2901.87 S 66 7 E 1196,17 S 2727,62 E 29'78.38 S 66 19 E 1217.26 S 2802.02 E 3055.01 S 66 31 E 1237.36 S 2875.57 E 3130.49 S 66 43 E 1256.40 S 2947.74 E 3204.32 S 66 54 E 1274.65 S 3019.82 E 3277.81 S 67 6 E 1293.05 S 3089.71 E 3349.37 S 67 17 E 1311.07 S 3159.17 E 3420.41 S 67 27 E 1328.31 S 3228.56 E 3491.13 S 67 38 E 7000.00 5519.73 5402.73 -45 34 7100.00 5589.79 5472.79 45 30 7200.00 5659.95 5542.95 45 16 7300.00 5730.68 5613.68 44 46 7400.00 5802.09 5685.09 44 5 7500.00 5874.07 5757.07 43 51 7600.00 5946.29 5829.29 43 27 7700.00 6019.41 5902.41 42 13 7800.00 6093.46 5976.46 42 14 7868.00 6143.80 6026.80 42 14 S 77 18 E 3561.69 S 77 38 E 3632.00 S 77 54 E 3702.15 S 77 47 E 3771.73 S 77 10 E 3540.69 S 77 3 E 3909.20 S 77 20 E 3977.41 S 77 2 E 4044.67 S 76 56 E 41II.OI S 76 56 E 4156.i3 0.51 0.24 0.49 0.52 0.70 0.33 0.91 4.34 0.00 0.00 1344.54 S 3298.17 E 3561.70 S 67 49 E 1359.98 S 3367.83 E 3632.05 S 68 0 E 1375.03 S 3437.48 E 3702.30 S 68 11 E 1389.86 S 3506.61 E 3772.00 S 68 22 E 1404.98 S 3574.94 E 3841.12 S 68 32 E 1420.59 S 3642.59 E 3909.80 S 68 41 E 1435.89 S 3710.04 E 3978.21 S 68 50 E 1450.92 S 3776.57 E 4045.70 S 68 59 E 1466.10 S 3842.05 E 4112.28 S 69 6 E 1476.43 S 3886.58 E 4157.57 S 69 11 E COMPUTATION ARCO ALASKA, INC. 2T-13 KUPARUK NDRTH SLOPE,ALASKA DATE: lO-SEP-86 MEASURED DEPTH INTERPDLATED VALUES FOR EVEN 1000 FEET OF 0 1000 2000 3000 4000 000 4000 7000 7868 .00 .00 .00 .00 .00 .00 .00 .00 .00 TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTm DEPTH DEPTH DEG MIN DEG MIN 0.00 -117.00 0 0 N 0 0 999.98 882.98 0 42 N 65 21 1989.68 1872.68 16 36 S 63 5 2852.13 2735.13 44 2 S 63 39 3531.17 3414.17 48 48 S 65 27 4190.64 4073.64 48 26 S 66 35 4851.76 4734.76 49 50 S 73 33 5519.73 5402.73 45 34 S 77 18 6143.80 6026.80 42 14 S 76 56 MEASUR VERTICAL DOGLEG RECTAN SECTION SEVERITY NORTH/ FEET DEG/iO0 FEE 0.00 0.00 O. 2.66 0.11 2. 105.48 1.35 47. 591.11 1.09 265. 1323.78 0.20 578. 2075.13 0.16 855. 2824.58 0.32 1152. 3561.69 0.51 1344. 4156.13 0.00 1476. PAGE 3 ATE OF SURVEY: 02-SEP-86 ELLY BUSHING ELEVATION: 117.00 FT ENGINEER: RUBENSTEIN ED DEPT GULAR COORDINATES HORIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MI~ O0 N 0.00 E 0.00 N 0 0 E 22 N 3.78 E 4.38 N 59 37 E 54 S 95.58 E 106.75 S ,53 33 E 34 S 530.06 E 592.77 S 63 24 E 95 S 1193.33 E 1326.36 S 64 7 E 83 S 1879.55 E 2077.84 S 64 45 E 95 S 2580.03 E 2825.93 S 65 55 E 54 S 3298.17 E 3561.70 S 67 49 E 43 S 3886.58 E 4157.57 S 59 11 E COMPUTATION ARCO ALASKA, INC. 2T-13 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEG MZN DEG MIN 0 17 117 217 317 517 617 717 817 .00 .00 .00 .00 .00 .00 .00 .00 .01 .01 0,00 -117.00 0 0 N 0 0 E 17.00 -100.00 0 20 N 40 25 E 117.00 0.00 0 1 S 56 i W 217.00 100.00 0 5 S 9 31 W 317.00 200.00 0 6 S 65 52 E 417.00 300.00 0 11 N 72 7 E 517.00 400.00 0 18 N 62 34 E 617.00 500.00 0 22 N 55 11 E 717.00 600.00 0 27 N 43 43 E 817.00 700.00 0 24 N 43 19 E 917 1017 1117 1217 1317 1417 1517 1617 1719 1821 .01 .02 .03 .04 .06 .09 .21 .87 .38 .5,2 917.00 800.00 0 32 N 62 5 E 1017.00 900.00 0 43 N 65 13 E 1117.00 1000.00 0 50 N 64 1 E 1217.00 1100.00 0 54 N 56 33 E 1317.00 1200.00 I 12 N 87 16 E 1417.00 1300.00 1 53 S 76 12 E 1517.00 1400.00 4 2 S 60 4 E 1617.00 1500.00 8 33 S 53 44 E 1717.00 1600.00 1i 9 S 55 23 E 1817.00 1700.00 12 23 S 58 27 E 1924 2028 2133 2240 2350 ~461 76 6094 2819 2951 .42 .54 .67 .98 .07 .68 .10 .98 .06 .39 1917.00 1~00.00 14 58 S 62 6 E 2017.00 1900.00 16 53 S 63 12 ; '2117.00 2000.00 19 34 S 62 7 ~ 2217.00 2100.00 22 37 S 64 17 E 2317.00 2200.00 24 51 S 64 50 E 2417.00 2300.00 27 18 S 64 8 E 2517.00 2400.00 30 37 S 62 45 E 2617,00 2500.00 34 28 S 62 25 E 2717.00 2600,00 38 23 S 63 13 E 2817.00 2700.00 43 14 S 63 32 E 3090 3233 3379 3527 3676 3827 3978 4130 4283 4435 .91 .66 .63 .27 .31 .00 .48 .56 .00 .14 2917.00 2.800.00 44 52 S 63 50 E 3017.00 2900.00 46 11 S 64 6 E 3117.00 3000.00 47 12 S 64 15 E 3217.00 3100.00 47 25 S 64 50 E 3317.00 3200.00 48 12 S 65 11 E 3417.00 3300.00 48 35 S 65 25 E 3517.00 3400.00 48 47 S 65 27 E 3617.00 3500.00 48 58 S 65 28 E 3717.00 3600.00 48 58 S 65 35 E 3817.00 3700.00 48 49 S 65 50 E DATE: lO-SEP-86 EVEN 100 F;ET OF PAGE 4 DATE OF SURVEY: OZ-SEP-86 KELLY 5USHING ELEVATZON: 117.00 FT ENGINEER: RUBENSTEIN SUB-SEA DEPTH VERTICAL DOGLEG RECTAN SECTION SEVERITY NORTH/ FEET DEG/IO0 FEE 0.00 0.00 0.02 4.21 0.03 0.10 0.03 0.08 0.18 0.20 0.38 0.15 0.69 0.22 1.02 0.20 1.42 0.17 1.67 0.08 2.03 0.31 2.8O 0.07 3.70 0.11 4.73 0.15 6.17 0.44 8.79 0.81 13.53 3.86 24.46 3.26 41.36 1.93 62.06 1.06 GULAR COCRDINATES HORIZ. SOUTH EAST/WEST DIST. T FEET FEET 0.00 N 0.00 E 0.00 0.03 N 0.03 E 0.04 0.04 N 0.05 E 0.06 0.07 S 0.00 E 0.07 0.24 S 0.09 E 0.26 0.22 S 0.32 E 0.39 0.05 S 0.73 E 0.73 0.31 N 1.23 E 1.27 0.76 N 1.84 E 1.99 1.32 N 2.34 E 2.69 . 2. 2. 3. 3. 3. 1. 4. 14. 26. DEPARTURE AZIMUTH DEG MIN 85.81 3.54 38. 114.69 0.70 51. 147.00 3.08 66. 185.74 2.25 83. 229.27 3.44 102. 278.73 1.56 123. 334.15 2.18 145. 398.11 2.28 178. 471.25 3.64 211. 557.60 2.45 250. N 0 0 E N 48 55 E N 49 28 E S 2 12 E S 21 5 E S 55 31 E S 86 24 E N 75 48 E N 57 31 E N 60 33 E 84 N 2.95 E 3.47 N 58 3 E 31 N 3.97 E 4.59 N 59 52 E 91 N 5.19 E 3.95 N 60 46 E 52 N 6.56 E 7.44 N 61 47 E 92 N 8.28 E 9.16 N 64 40 E 58 N 10.97 E 11.54 N 71 56 E 71 N 15.33 E 15.42 N ~3 37 E 51 S 24.59 E 25.00 S 79 36 E 84 S 38.61 E 41.37 S 68 58 E ZO S 56.33 E 62.13 S 65 3 E 05 S 77.14 E 86.01 26 S 102.94 E 114.99 09 S 131.78 E 147.42 70 S 166.42 E 186.29 35 S 205.82 E 229.86 68 S 250.54 E 279.40 38 S 300.30 E 334.96 13 S 357.23 E 399.18 59 S 422.56 E 472.58 40 S 499.97 E 559.17 634.66 1.03 293.49 756.30 1.03 338.24 862.43 0.77 384.51 970.8~ 0.69 431.28 1081.28 0.33 477.88 1193.90 0.23 524.95 1307.60 0.19 572.23 1422.09 0.15 619.82 1537.07 0.27 667.52 1651.66 0.11 714.65 S 63 44 E S 63 31 E S 63 21 E S 63 18 E S 63 33 E S 63 43 E S 53 42 E S 63 29 E S 63 24 E S 63 23 E S 387.20 E 656.46 S 678.71 E 758.32 S 774.44 E 864.64 S 872.47 E 973.25 S 972.68 E 1083.73 S 1075.09 E 1196.41 S 1178.60 E 1310.17 S 1282.82 E 1424.72 S 1387.53 E 1539.75 S 1492.05 E 1654.37 S 63 26 E S 63 30 E S 63 35 E S 63 41 E S 63 50 E S 63 58 E S 64 6 E $ 64 12 E S 64 18 .E S 64 24 E COMPUTATION DATE: lO-SEP-86 PAGE 5 ARCO ALASKA, INC. DATE OF SURVEY: OZ-SEP-86 2T-13 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN 117.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES MORZZ. DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEPARTURE AZIMUTH DEG MIN 458 473 488 503 ~19 34 ~49 564 579 594 6.72 3917.00 3800.00 7.89 4017.00 3900.00 8.90 4117.00 4000.00 9.73 4217.00 4100.00 0.42 4317.00 4200.00 0.75 4417.00 4300.00 0.82 4517.00 4400.00 0.?7 4617.00 4500.00 2.27 4717.00 4600.00 6.14 4817.00 4700.00 48 39 S 65 57 E 1765.51 0.32 761.16 S 1596.03 E 1768.24 48 29 S 66 8 E 1878.83 0.26 807.23 S 1699.62 E 1881.58 48 30 S 66 27 E I991.95 0.10 852.68 S 1803.24 E I994.68 48 25 S 66 39 E 2104.55 O.1Z 897.62 S 1906.83 E 2107.54 48 24 S 66 55 5 2217.56 0.30 942.04 S 2010.44 E 2220.21 48 13 S 67 34 E 2329.80 0.28 985.50 S 2113.93 E 2332.36 48 4 S 68 23 E 2441.70 0.79 1027.59 S 2217.61 E 2444.12 48 20 S 69 54 E 2553.39 0.74 1067.36 S 2322.02 E 2555.59 49 6 S 71 14 E 2667.05 1.01 1105.30 S 2429.31 E 2668.94 49 46 S 73 7 E 2783.65 1.16 1141.25 S 2540.59 E 2785.14 S 64 30 E S 64 35 E S 54 41 E S 64 47 E S 64 53 E S 65 0 E S 65 8 E S 65 18 E S 65 32 = S 65 48 E 610 625 641 656 670 685 699 713 728 742 1.52 4917.00 4800.00 8.96 5017.00 4900.00 3.99 5117.00 $000.00 4.19 521'7.00 5100.00 9.72 5317.00 5200.00 3.14 5417.00 5300.00 6.10 5517.00 5400.00 8.82 5617.00 5500.00 0.72 5717.00 5600.00 0.73 5817.00 5700.00 50 16 S 73 38 E 2901.94 0.59 1174.91 S 2654.64 E 2903.03 50 39 S 74 13 E 3022.83 0.53 1208.70 S 2771.45 E 3023.56 48 29 S 75 0 E 3140.41 1.16 1240.07 S 2825.67 E 3140.83 47 54 S 75 50 E 3251.45 1.60 1268.18 S 2994.16 E 3251.66 45 52 S 75 14 E 3356.21 0.39 1294.83 S 3096.45 E 3356.28 45 36 S 76 3 E 34~8.04 0.56 1320.36 S 3196.05 E 3458.05 45 34 S 77 17 E 3558.94 0.54 1343.93 5 3295.45 E 3558.95 45 29 S 77 46 E 3659.27 0.29 1365.8'7 S 3394.89 E 3659.35 44 50 S 77 50 E 3758.35 0.37 1387.00 S 3493.32 E 3758.59 44 1 S 77 3 E 3854.90 0.42 1408.20 S 3588.99 E 3855.36 S 66 7 E S 66 26 E S 66 44 E S 67 Z E S 67 18 E S 67 33 E S 67 48 E S 68 5 E S 68 20 E S 58 34 E 755 769 783 786 9.53 5917.00 5800.00 6.74 6017.00 .5900.00 1.80 6117.00 6000.00 8.00 6143.80 6026.80 43 44 S 77 15 E 39w9.87 0.60 1429.76 S 3682.79 42 15 S 77 5 E 4042.50 3.81 1450.43 S 3774.43 42 14 S 76 56 E 4132.11 0.00 1470.93 S 3862.88 42 14 S 76 56 E 4156.13 0.00 1476.43 S 3886.58 E 3950.59 S 65 46 E E 4043.52 S 68 58 E E 4133.46 S 69 9 E E 4157.57 S 69 11 E ARCO ALASKA, INC. 27-I3 KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUP&RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION INTERPOLATED VALUES MEASURED DEPTH BELOW KB 7391.00 7416.00 7509.00 7700.00 7754.00 7868.00 DATE: lO-SEP-86 FOR CHOSEN HORIZONS FROM 5795.63 5813.60 5880.56 6019.41 6059.40 6143.80 ORIGIN: TVD PAGE 6 DATE OF SURVEY: 02-SEP-86 KELLY BUSHING ELEVATION: 117.00 ENGINEER: .RUBENSTEIN 77 FSL, 556 SUB-SEA 5678.53 5696.60 5763.56 5902.41 5942.40 6026.80 SURFACE LOCATION AT FWL, SEC 1, TllN, RSE, UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1403.59 S 3565.84 E 1407.46 S 3585.79 E 1421.99 S 3648.66 E 1450.92 S 3776.57 E 1459.11 S 3811.93 E 1476.43 S 3886.58 E FT COMPUTATION DATe: lO-SEP-86 PAGn 7 ARCO ALASKA, INC, DAT~ OF SURVEY: 02-SEP-86 2T-13 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN 117.00 MARKER MEASURED DEPTH BELCW KB FROM ORIGIN= 77 TVD SUB-SEA FSL, 5r--,6 SU FWL, S RECTA NORT RFA EC NGU H/S CE LOCATION AT 1, TllN, RBE, UM LAR COORDINATES DUTH EAST/WEST TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD 7391.00 5795.63 5678.63 7416.00 5813.60 5696.60 7509.00 5880.56 5763.56 7700.00 6019.41 5902.41 7754.00 6059.40 5942.40 7868.00 6143.50 6026,80 140 140 142 145 145 147 3.5 7.4 1.9 0.9 9.1 6.4 9 S 3568.84 6 S 3585.79 9 S 3648.66 2 S 3776.57 I S 3811.93 3 S 3886.58 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN FT 7868.00 6143.80 6026.80 4157.57 S 69 11 5 SCHLUMBER©ER D T AEC T i ONF:IL SURVE Y COMPANY ARCO ALASKA INC NELL 2T- 13 FIELD KUPARUK COUNTRY USA RUN 1 DATE LOOOEO 02 - SEP - 88 REFERENCE 000071693 WELL: 2T-13 - (77'FSL,556'] ~ SEC 1,TllN,R8E,UM) . {ORIZONTAL PROJECTION NORTH 40DO @000 ZOO0 1000 - ! 000 -2000 -9000 SOUTH -4000 -2000 WEST REF 00007]693 SCALE = ]/]000 IN/FT - 000 0 1000 2000 3000 4000 SO00 6000 EI~T WELL: 2T-13 (77'FSL,556'FWL, S~'~ 1,TllN,R8E,UM) VERTICAL PROJECTION 2~2. -2000 -]000 0 0 ]000 2000 BO00 4000 SO00 6000 112~, PROJECTION ON VERTICAL PLANE 112. - 292, SCALEO IN VERTICAL OEPTHS HORIZ SCALE = 1/ 1000 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATbR,' WF/LL NAME AND NUMBER CONFIDENTIAL INDEFi I'i FLY Reports and Materials to be received by: _,/_,_~-~a.t,_7- ~>_~/ , . Required Date Received Remarks Completion Report y~ , , Well History S amp 1 e s Mud Log ,, Core Chips , , ~ f-~z ...... Core Description , / · Inclination Survey .. OK DireCtional Survey Drill Stem Test Reports Log Run 7e'~ /~- ~0'-~ 0~. .. Digitized Data ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-20-86 TRANSMITTAL ~ 5802 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final~rints: Schl: 2T-~-5" DIL/SFL-GR 2" DIL/SFL-GR ~5". Den/Neu ~2" Den/Neu ~5" Den/Neu 2" Den/Neu ~'--Cyberlook 3N-1~____~5" DIL/$FL-GR 2'~ DIL/SFL-GR ~"5" Den/Neu-GR ~2" Den/Neu-GR ~"~5" Den/Neu-GR ~'"~2'" Den/Neu-GR "'"Cyberlook 3N-1~5" DIL/SFL-GR %'~-2" DIL/SFL-GR "-5" Den/Neu '~'--2" Den/Neu ~'~5" Den/Neu ~2" Den/Neu ~Cyberlook 3N-17~'5'' DIL/SFL-GR ~2" DIL/SFL-GR ~5" Den/Neu ~2" Den/Neu '"'~5" Den/Neu '~-2" Den/Neu ~Cyberlook Open Hole Logs: One * of each (poro) (poro) (raw) (raw) 05-11-86 Run Hi 2978-784~ 05-11-86 Run H1 2978-7844 05-11-86 Run Hi 3340-7818 05-11-86 Run Hi 3340-7818 05-11-86 Run H1 3340-7818 05-11-86 Run Hi 3340-7818 05-11-86 Run #1 7300-7800~ (poro) (poro) (raw) (~,~aw) 05-10-86 Run HI 4319-8498 05-10-86 Run H1 4319-8498 05-10-86 Run Hi 7600-8471 05-10-86 Run HI 7600-8471 05-10-86 Run HI 7600-8471 05-10-86 ..... JL~ ~u~L ~,l 7600-8471 05-10-86 Run Hi 7600-8460 (poro) (poro) (raw) (raw) 05-18-86 Run Hi 4796-9236 05-18-86 Run Hi 4796-9236 05-18-86 Run Hi 8400-9210 05-18-86 Run #1 8400-9210 05-18-86 Run Hi 8400-9210 05-18-86 Run #1 8400-9210 05-18-86 Run H1 8400-9.180 (poro) (poro) (raw) (raw) 05-25-86 Run H1 4607-8998 05-25-86 Run Hi 4607-8998 05-25-86 Run #1 8200-8972 05-25-86 Run HI 8200-8972 05-25-86 Run HI 8200-8972 05-25-86 Run Hi 8200-8972 05-25-86 Run H1 8350-8950 The API#is incorrect on these logs. It should be 50-029-20067. Receipt Acknowledged: ate of AK*bl/se > D & M*bl NSK Files*bl Drilling*bi .-- STATE OF ALASKA ~,~ AL/: .~ OIL AND GAS CONSERVATION CO, ISSION /, , REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown © Stimulate ~ Plugging i-F,, Perforate~ Pull tubing ;~ Alter Casing ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A1 asks, I nc RKB 117 ' Fe¢---~ 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 77' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ?T-I'~ At top of productive interval I 8. Approval number 1327' FNL, 1155' FEL, Sec. 12, T11N, R8E, UM ~ 152 At effective depth 9. APl number 1382' FNL, 912' FEL, Sec. 12, T11N, R8E, UM 501103-20067 At total depth 10. Pool 1399' FNL, 837' FEL, Sec. 12, T11N, R8E, UM Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7868 'MD feet Plugs (measured) None true vertical feet 6144 'MD Effective depth: measured feet Junk (measured) true vertical 7754 'TVD feet None 6059 ' TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 225 sx CSll 105'MD 105'TVD Surface 2944' 9-5/8" 820 sx AS Ill & 320 sx 2976'MD 2834'TVD C1 ass G Top job w/150 sx ASI Production 7809' 7" 380 sx Class G & 7839'MD 6122'TVD 175 sx AS I Perforation depth: measured 7532' - 7579 'MD true vertical 5897' - 59:32'TVD 5797' - 5812'TVDSEP 2 5 196 ; Tubing (size, grade and measured depth) 2 - 7 / 8", J - 55, t bg w / t a i 1 ~ 7472 ' Alaska Oil & Gas Cons. C0mmissir. Packers and SSSV (type and measured depth) Anch0ra? HB-1 pkr ~ 7217', lB pkr (~ 7450', & TRDP-1A SSSV 8 1787' CO I !AI 12. Stimulation or cement squeeze summary ~,~ ~ ~ ~ ~ ~ I nl~e/~als treated (measured) ? !ii i:!~:" (~ Treatment description including volumes used and final pressure~t¢i: ,,. ,,;" 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History, w/Addendum, dated 9-02-86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run :K~: G¥:RO 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge , .~..~ ~;) ~),f,~/ ~ Associate Engineer Signed Title Date · .... · .... ",~ _",_ '-t_ Form 10-404 Rev. 12-1-85 (DAH) $'~O/i 02 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Preoare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" ~hould be submitted also when operations are susgenced for an indefinite or appreciable length of time. On v, orkovers when an official test is not required upon completion, report completion and represen:~d;'e test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is avai!able. Accounting cost center code State Alaska Well no. Kuparuk River ADL 25569 2T-13 District County or Parish Alaska North Slope Borough Field Lease or Unit Auth. or W.O. no_ T t e AFE AK0707 Completion Nordic 1 AP1 50-103-20063 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 8/30/86 Date and depth Complete record for each day reported as of 8:00 a.m. Iotal number of wells (active or inactive on this I cst center prior to plugging and bandonment of this well our Prior status if a W.O. re00 hrs. 8/30/86 thru 9/02/86 9/03/86 9/04/86 7754', PBTD, RU to perf 11.0 ppg NaC1/NaBr Accept rig @ 1600 hrs, 8/30/86. ND tree, NU & tst BOPE. RIH w/6-1/8" bit/scrpr, CO well to FC @ 7755', POOH. RU Schl, rn CET f/7752'-6890'. Rn GCT gyro f/7700'-surf. RU & prepare to perf. 7754', PBTD, Set retrv pkr 11.0 ppg NaC1/NaBr Perf w/4 SPF, 90° phasing f/7532'-7579' & w/5" guns, 12 SPF, 90° phasing f/7392'-7414'. Make gage ring/JB rn to 7500'. RIH & set 1-B pkr @ 7450', RD WL. RU, rn 2-7/8" compl & ind. Prep to set top pkr. SSSV @ 1787', HB-1 pkr @ 7217', 1-B pkr @ 7450', TT @ 7472'. 7754' PBTD RR 6.8 ppg Diesel Shear PBR, re-lnd tbg. Tst ann & pkr to 2500 psi. Tst SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well to diesel. R__R @ 1430 hrs, 9/3/86. ~ECEIVEO SEP 2 5 198L, Alaska 0il & Gas Cons. 60mmissi' Anchoranr Old TD New TD PB Depth Date 7753' PBTD Released rig Kind of r g 1430 hrs. 9'/3/86 Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, duai, etc) Single Official reservoir name('s} Kuparuk Sands Potential test data Well no. Date Resep,'olr Producing Interval Oil or gas Test time Production Od on test Gas per day Pump size, SPM X length Choke size I T P. C.P Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Date ADDENDUM WELL: 8/22/86 2T-13 RU Schl, rn 6.1" gage ring/JB/Wt Bar, set dn @ 7450', wrk dn to 7460'; unable to get further, POOH. JB full of contaminated cmt chunks. PU 3-3/4" gage ring, RIH, set dn @ 7460', wrk dn to 7585'; unable to get below the base of "A" sand @ 7704', POOH, RD Schl. Drilling Supervisor Date MEMO.RA! 'DUM Sta*: of Alaska TO' TH RU' FROM' ALASKA OIL A~ GAS CONSERVATION CO~Mi~SION C. V./C~'terton Chai~. m~n/k_~' /' Lonnie C. Smith ??~ Commissioner John F. Boyle .~ C. Petroleum Engineer Asst DATE' September 5, 1986 FILE NO.' D.JFB. 14 TELEPHONE NO.' . SUBJECT: BOP Test ARCO KRU 2T- 13 Permit No. 86-89 Kuparuk River Field P~.~uKd~Y., August 30, 1986: After the completion of the test on ARCO KRU 2T-5, ~ubject of another report, I remained on location to witness a BOP test on workover Nordic Rig #1. Its purpose is to complete well KRU 2T-13. The test began at 8:30 p.m. and the decision was made to bring in another BOP st%ck at about 12:45 a.m. on August 31. This decision was made because the pipe rams would not function and another BOP st~ck was available. Also, the HCR valve leaked, but was repaired, and there was no blind switch cover on the remote. ~un~ay,.A~gust 31, 1986: The test continued today at 10:30 a.m. and concluded at 3 30 p.m. Prior to the testing, I also observed the nippling up of the replacement BOP stick. During the test I observed 3 failures: !) The remote blind switch cover was not instailed~ 2) the flange below the blind rams leaked and was repaired; 3) the flange around the HCR leaked and was also repaired. Because they had no test joint, I did not test the following: Upper Kelly, Lower Kelly, floor valve, and inside BOP. Both Steve Cameron and Skip Gouchee stated that they are having one made and will test the above and add a remote blind switch cover within 48 hours and notify the Commission. I filled out 2 AOGCC BOP inspection reports which are attached. In summary, in 1~ days I witnessed the BOP test on worker Nordic R±g #~. Attac~hments 02-001 A(Rev 10-84) ..::::~.5" Location;" General~Well Si~ :...i~:~{ .: . . . . . . :'-'t ;:'" Reserve Pit . 'i] :"_ · :-' Mud Systems . .- ..... Trip Tank Pit Gauge . . : - :.. Flow Monitor . :--:i:':i G~s' DeteCtors #-/ Representative Visual Audio -:-.-'~:&-::.':-:~'~::~:-b~t: - ~ ti ' -::-'-:-'---.-91~.~:~.:-~.-7:. .... J : ..:-..- - ... Choke Line VaLves H.C.R. Val Kill Line Valves. Check Valve · . ACCUMULATOR SYSTEM Full Charge PressUre pressure After Closure' . Pump incr. clos. pres. 200 psig, Full Charge PreSsure Attained: ! oc) psig psig . ~ min sec. min sec. N2 psig Controls: Maste~ ~ "Remote ¥~' Blinds switch cover~O .' Kelly and FlOor Safety Valves... ._'-.... . Upper Kelly':'::-''t~:::-- Test Pressure ":;-'"-:":" Lower Kellt'- " . · .~ Ball Type . Inside BOP Choke Manifold _ . Test Pressure Test Pressure Test Pressure Test Pressure No. Valves No. flanges Adjustable Chokes Hvdrauically operated choke Test Results: Failures 3 Test Time Repair or Replacement of failed equipment to be made within d~ys and Inspector/ Co~ission office notified. .- Remarks: ~0 '~~ ~~Tt~ ~0~--~ ~~~. ~ L~~o-'~.~~. Distribution ii UL[II i I ELl cc - Operator. cc - Supe~isor Inspector .:.-. ~. :::~.~:'. ~- Drillin~ ContractorN~ ~b '~ O %i~f-~o~t~o=, s~=~l' ~/~ wen. s~ ' ...:itC?::, . . .....'.. -:~.:. :~ . - ":t'~[,~:~ Ge'~era1 Housekeeping~&,¢ Rig: ~l~t ¢ ReserVe Pit ..-. Mud.SYstems Trip Tank ' 'Pit Gauge Well ~-C<~ k . 'Representative ~-r~ Permit # ~ ~ -- .-. -~//. Casing Set ¢/ ~ Representative - ACC~ATOR SYST~ Full Charge Pressure ~ ¢ O Pressure ~ter Closure' Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: Controls: Master , ~.. Visual Audio ' Flow Monitor ~ '- G~s' :Detectors -~- ' ' :C:'~;s:--,':" :.,~ .-.~-: Remote psig psig psi~ min~00 sec. rain O~ec. Blinds switch cover~l~ · ','Kelly and Floor Safety Valves upper Kelly ::-":~'~-" Test Pressure ~ower Kelly' ' Test Pressure . Ball Type Test Pressure 1'-' Inside BOP Test Pressure Manifold,_~)~ Test Pressu~re No. flanges Blind Rams ~' Choke Line Valves H.C.R. Valve '~,1 Kill Line Valves Test Results: Failures Repair or Replacement of failed equipment .to be made within ______ Adjustable Chokes .~. Hvdrauically operated choke Test Time ~-- . hrs. ~ days and Inspector/ ~ office notified. __ · Remarks :/. /V 0 ~ ~%~, ~': ~ [: ' o~ STATE OF ALASKA ~ ALAS,..-, OIL AND GAS CONSERVATION COM,,..3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend % Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order- Perforate- Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 117' feet 3. Address 6. Unit or Property name P. O. Box 100360 Anehora_oe. AK 9gC, lf} K~,pnr',ll~ Riv~.r Ilni~_ 4. Location of well at surface 7. Well number 77' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-13 At top of productive interval 8. Permit number 1280' FNL, 1418' FEL, Sec. 12, TllN, R8E, UM (Approx) 86-89 At effective depth 9. APl number 1328' FNL, 903' FEL, Sec. 12, T11N, R8E, UM (Approx) 50--103-20063 At total depth 10. Pool 1343' FNL, 827' FEL, Sec. 12, T11N, R8E, UM (Approx) Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 7868 feet Plugs (measured) None true vertical 6148 feet Effective depth: measured feet Junk (measured) 7754 None true vertical feet 6054 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 225 sx CSII 105'MD 105'TVD Surface 2944' 9-5/8" 820 .sx AS Ill & 320 sx 2976'MD 2791 'TVD C1 ass G Top job w/150 sx ASI Production 7809' 7" 380 sx Class G 7839'MD 6127'TVD Perforation depth: measured None true vertical N o n e ~ . . ¥ ~.,.. i. ' _ , Tubing (size, grade and measured depth) None ~- ~t- ~ . .i.,,..¢~.' Packers and SSSV (type and measured depth) No n e 12.Attachments Description summary of proposal [] Detailed operatiOns program ~ BOP sketch 13. Estimated date for commencing operation ~" ~'?, ;'f; fi ~'" ?' ~i ¢":;' ' :' 4;~,:- ..; ¢. \";' "~;I August, 1986 ~;'-~" '~'' '~ 14. N ama of approver I f proposal was verbally ap provedErCt~i ~t:'~?'''~' ?, ";,', '.t~!i~i~id(~ ~'::';" ~- ~ i ~'~~i~ ~J.., '~ '["-~ ~'~' ~' ¢: ~ :'~i ii 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~/~C/ ,.~~., Title Associate Engineer Date // Commission Use Only SA/046 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance, , .~== ....... , by order of ~ Approved by i;~ ; ?,~;;~:'~ ~o ~i~'~_..~.~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough State Alaska Alaska North Slope Borough Field ILeasel or Unit IWell no, Kuparuk River ADL 25~-6~-- 2T-13 I Title Drilling Auth. or W.O. no. AFE AK0804 Rowan 34 API 50-103-20063 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date IHour IPrior status if a W.O. Spudded 5/5/86 I 0600 hrs. I Dete and depth as of 8:00 a.m. 5/04~86 thru 5105186 5/06/86 5/07/86 5/08/86 5/09/86 The above is correct Signature~ ~~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Complete record for each day reported 16" @ 105' Wt. 8.8· PV 14, YP 26, PH 10.5· WL --, Sol 3 Accept ri~ @ 2400 hrs, 5/4/86. NU diverter sys. 16" @ 105' Wt. 9.6· PV 22, YP 21, PH 9.5· WL 9.2, Sol 9.9 2655', (2550')· Drlg · Spud well @ 0600 hrs, 5/5/86. Drl 12¼" hole to 1253' to 2655'. 1503' 2.4° S65 3E 1443 TVD, 4 VS, 2S, 4E 1818' 11.8° S54 3E 1755 TVD 44 VS 25S 38E 2128' 17 1° S61 7E 2055 TVD, 121VS, 64S, 105E · · · · · 2442' 25.9° S64 6E, 2346 TVD, 238 VS, 117S, 209E , mtr drl 9-5/8" @ 2976' Wt. 9.6, PV 19, YP 10, PH 9, WL 12.4· Sol 10 2985', (330'), ND diverter Drl 12¼" hole to 2985', short trip· circ, TOH. RU & rn 74 jts, 36#, J-55 BTC csg w/FS @ 2976', FC @ 2893'. Cmt w/820 sx AS III w/10#/sx Gilsonite, followed by 320 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. Perform 150 sx AS I top job. 'T ~.. 2599' 29.9° S62 4E 2485 TVD 311 VS . · · · , · _ . , ..~ ~ . 2985' 42.4° S63 7E, 2798 TVD, 535 VS ~ ~ i - ,' ,~. /, '~ .'. '. 9-5/8" @ 2976' .j Wt. 8.6, PV 1, YP 4, PH 11.5, WT_. NC, Sol 2.4 3746', (761'), Drlg NU & tst BOPE. TIH to 2893'· tst csg to 2000 psi.' DO flt equip & cmt + 10' new formation to 2995'. Conduct formation tst to 9.1 ppg EMW. Drl & surv 8½" hole to 3746'. 3106'· 45.4°, S66.5E, 2927.83 TVD, 660.59 VS, 304.76S, 588.94E 3618' 48.1° S66 2E, 3277 23 TVD, 1034.37 VS, 461 55S, 928.66E 9-5/8" @ 2976' 6019', (2273'), Drlg Wt. 9.4, PV 12, YP 8, PH 9.5, WL 8.0· Sol 8 Drl & surv 8½" hole to 6019'. 3944'· 48.4°, S66.3E, 3494.31 TVD, 1277.51 VS, 559.50S, 1151.28E 4572'· 48.9°, S69E, 3905.70 TVD, 1751.91 VS, 745.65S, 1587.67E 5225' 48.5°, S67.9E, 4337.13 TVD, 2242.04 VS,~9.27~16S~.~-gQ.~Z, 9.9~.,~ ~'~ ~.~' Io~ bS~ ~ ITM Drilling Supe~isor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended tot an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I State Alaska North Slope Borough Alaska I County or Parish Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE AK0804 Rowan 34 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 5/5/86 5/10/86 thru 5/12/86 Date and depth as of 8:00 a.m. ADL 25569 Drill API 50-103-20063 IWell no. 2T-13 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. 0600 hrs. I 9-5/8" @ 2976' 7868', (1949'), LD BHA Wt. 11, PV 18, YP 6, PH 8.5, WL 6.2, Sol 18 Drl 8½" hole to 6170', tst formation to 10.8 ppg EMW. Drl to 7576', hole swabbing, SI well, CBU w/mud. Inc mud wt to 10.8 ppg, circ thru choke. Inc mud wt to 11.0 ppg, still gas cut to 9.5 ppg. Drl to 7868', short trip, hole swabbing, C&C, POH. RU & log DIL/SFL/SP/GR f/7842'-2868', oont w/GR to 1500'. Log FDC/CNL f/7842'-6950' & 3350'-3550', CAL f/7842'- 2862'. RIH, make cond'g rn, POH, LD BHA. 5970' 49.8° , , S73.4E, 4829.03 TVD, 2800.59 VS, 1112.98S, 2570.49E 6680' 46.1° S76 5E 5299 87 TVD, 3327 12 VS, 1247 92S, 3084 26E .! , ! . , . . . ''' .6o ~/~.i.- .... 7360', 44 , S78.6E, 5776.95 TVD, 3804.43 VS, 1352.25S, 3557.40E 7808', 41°, S78E, 6104.20 TVD, 4104.68 VS, 1412.49S, 3857.24E 7868', 41°, S78E, 6149.48 TVD, 4143.41 VS, 1420.67S, 3895.74E 7" @ 7839' 7868' TD, 7754' PBTD, RR Wt. 11.0, PV 14, YP 5, PH 8.5, WL 6.7, Sol 18 Run 191 jts 7" csg & marker jt w/shoe @ 7839 & FC @ 7754'. Broke circ. @ 2975 & 5500'. RU Dowell. Circ & cond mud. Pumped 10 bbl spacer. Pumped 100 sx Healy/G 50/50 & 280 sx class G w/top 7 bottom plugs. CIP @ 1920 hrs. ND csg equip, PU BOPE. NU tbg head. Tst to 3000 psi. Blow out 120' brine. Pump 30 bbls diesel. Released ri~ @ 0130 hrs. 5/13/86. Old TO Ney/ TO Released rig Date 0130 hrs. Classifications (oil, gas, etc.) Oil 7868' TD PBDepth 5/13/86 IKndOfrig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7754 ' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production 0il on test Gas per day Pump size, SPM X length Choke size T.P, !C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~.~~ J ~ '~ I Signature .~.~ .- Date'~ %~i '~ ~.-.-~ Title For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO AlasKa. Inc. Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone ~07 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 05-27-86 TRANSMITTAL # 5676 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Iape plus Listing: Schl: One copy of each -~--3N-16 ~3N-15 '-'-2T-14 ------2T-13 05-18-86 Run #1 1'990.5-9269.0 '05-10-86- Run #1 2186.5-8523.0 05-03-86 Run #1 7600.0-8215.5 05-11-86 Run #1 1491.0-7878.0 Open Open Open :~ Na.~a 011 & Gas Cons. Commission Anchorage Receipt Acknowledged: ~state~of 'Alaska, ARCO Al·Ilia. Ifac. ,$ · SuDl~cliary of AtllntlcR~claftel~Com~)a,,y Date: ,,/IEMORAN")UM TO: THRU: FROM: Stat,- of Alaska AI~ASKA OIL .-qD GAS CONSERVATION COI~-~ISb~ON Chairman.' v ~, c_. Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector DATE: May 15, 1986 FILE NO.' D. BDF. 41 TELEPHONE NO.: SUBJECT: BOP Test ARCO KRU 3T-13 Permit #86-45 Kuparuk RiVer Field Wednes. day, May 6. 1986: The BOP test began at 12:00 noon and was completed at 3 "00 p.m:, As the attached BOP test report shows, there was one failure which was repaired and tested. In summary, I witnessed the BOP test on ARCO's 3T-13. ~02-001 A(Rev 10-84) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Ins. pector . /~D ~ ~~ Operator Wen V-; Z Location: Sec / T//,~.R~fM l~ Drilling Contractor ~~~ Rig #f~ Location, General,~/~ Well Sign ~ Date ACCUMULATOR SYSTEM General Housekeeping f:)~ Rig Reserve Pit Mud Systems Visual Audio Trip Tank ~-' Pit Gauge z/ Flow Monitor o-' Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Full Charge Pressure_~/~ psig Pressure After Closure/~0 psig Pump incr. clos. pres. 200 psig -- mi~ / sec. Full Charge Pressure Attained: .... ~ mtn~sec. Controls: Master Remote~~ Blinds switch cover ~~ Kelly and Floor Safety Valves Test Pressure Upper Kelly 17 .~p ~ ~ Lower Kelly. / "~~ Ball Type ~ ~ Inside BOP .... Test Results: Failures / Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold ~. Test Pressure No. Valves .... ! No. flanges...~~ Adjustable Chokes / / ~,~5 ~ydrauically operated choke / Test Time 3 hrs. Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Commission office notified. Remarks: /~/;-~z~ .~f~..~.~./. Distribution orig. - AO&GCC cc - Operator cc - Supervisor May 12, 1986 Ms. JoAnn Gruber Associate Engineer- .~RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: KRU 2T-13. Dear Jo~nn: An incorrect A_PI nu~mber (50-103-20063) was assigned this well. The correct AP1 number is 50-103-20067. apologize for an inconvenience this may have caused. Sincerely yours, /John A. Levorsen Senior Petroleum Geologist dlf: 2. J~ CONFIDENTIAL INDEFINIT L' Hay 2, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. -Box 100360 Anchorage, Alaska 99510-0360 Re: 2T-13 ARCO Alaska, Inc. Permit No. 86-89 Sur. Loc. 77;FSL, 556'FI,R~, Sec. 1, TI/N, RgE, ~-f. Btmhole Loc. 1414'F~-~L, 1090'FEL, Sec. 12, TllM, R8E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indem_nifv you from the probable need to obtain additional permits required'~ by law from other governmental agencies prior to commencing operations at the well site. Telecopy: (907) 276-7542 o o aid us in scheduling ~ield work -] .... = - urs prior to comm~.~{~2 ~- -~ , p-ease no~lzy this office 24 ....... ~ ~.~stazlat~on of ~ ~ ..... '~ ~ - ~ ,~woun prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the Surface casing shoe is drilled. 5~ere a diverter system is re uired please also notify this offie~ 9 . q , pq~ipment installktion s~ ~k2-2 ~'~ hours prior to co ~n~n~ ~ ~ u~a~ ~me uo~lssion ~ay witness ' .' be.,..ore drilling below the shoe ~ - test!n o~ the conductor pipe. g Chai~an of Alaska Oil and Gas Conservation Co~ission BY O~DER OF ~E CO~4ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl ~r. Doug L. Lowe_~ · STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C~. JIMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill .~ Redrill ~1 lb. Type of well. Exploratory ~ Stratigraphic Test Re-Entry i~, Deepen[]1 Service ~ Developement Gas [] Single Zone ~ Multiple Zone ~_~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 77'FSL, 556'FWL, Sec.1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1280'FNL, 1418'FEL, Sec.12, T11N, R8E, UM 2T-13 //8088-26-27 At total depth 9. Approximate spud date Amount !1414'FNL, 1090'FEL, Sec.12, T11N, R8E, UM 05/04/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVU) property line 7698 ' MD 1090 feet 2T-14 25'~ surface feet 2560 (6142'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth1 463 feet Maximum hole angle 45 0 Maximum surface 2881 psig At total depth C-VD) 3308 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 12~" 9-5/8" ~6.0# J-%S BT£ 29_~9' .~-~' 35' 2974' 2R21 ' 700 sx AS II I & HF-EI;W 320 ~x Cla~ G 8½" 7" 26.0// J-55 BTC 7664' 34' 34' 7698' 6142' 300 sx Class G HF-ERW 19. To be completed for Redrill, Re-entry, and.Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface rOI ~~ E i ~,. ~" ~' ~ ~ ~' ~?'~, .~ Intermediate Perforation depth: measured'~NU~ ,- Alaska 0il & Gas Cons. Ooln~ true vertical A,qchora§e 20. Attachments Filing fee .~ Property plat [] BOP Sketch~ DiverterSketch Drilling fluid program .,~ Timevs depth plot [] Refraction analysis ~- Seabed report 21. I hereby cer4Tt~ that the foregoing is true and correct to the best of my knowledge / , Regional Drilling Engineer Signed /" Z.,./MC.¥.k.,,? Title Date /'"' ¢'/~; / ' Commission Use Only ( LWK ) PD/'Pd259 · I API number J Appr~)vj~/~)a~e/ J See cover letter PermitNum/~r .~.0:.~¢ 50--/c~--~:~'~. n..o~(~? 86 for other requirements Conditions of approval Samples required ~., Yes ~.~:~Xlo Mud log required ~ Yes '~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~Yes ~ No Required workin~sure, f.~C'0-"CE_ ~2M; ,~ 3M; '~ 5M; © 10M; ~ 15M Other: ,~~./~2~' -'--,. by order of Approved b Commissioner the commission Dat ~si0~ / Sul~'m n triplicate Form 10-401 Rev. 12-1-85 PAD 2T, ~/ELL NO. 1 .- .... i .......... K.U_PAR..UK_ EI__ELD,,_ NORTH___S_LOpE,__ ALASKA ._.-----...-----.'/-J% % ............... .'/~- '- EASTMAN. ~HIPSTOCK-. INC. -'- - - - ..... - ............ -~ - .~ ..... . ........ ~ ...... : - . : . . .~ ........ _~_ i;_-_.' '- ;__!. :;;~_-/_ -- -___7 " ......... - --_2'_; ...... -_ .;:'_-_LLZ_L;_ Z_ _._-_~-. ........................... T_" .................................. ; ............ -- ...... - _ . ...... ; .._: ............. 0 ............. SURF^CIE . . - . . . . _ . · . . . _ _ _7- _.. .. "- -1_ ;--: -~--''- ' - .............. : ..... - _1_000._ - .......... : - - : - - : - - , KOP- TYD=146;3 TMD=i46;3' DEP=Oi _ - ~- . ...... , _ _ ;-73 BASE PERM^FROST- .TYD=1561--TMD~"I 561" DEP=3 -- ; ............ !~1--9 TOP UGNU SNDS-- T:VD=1711 -TMD=1712 DEP=16 ...... ~ ............ .................... - ,- .. .... ~ ........ _,. . - -- 200n I~- -,,~ - -! -BUILD 3 I:)E:I~ ...... 1 ................ ...... ~ ............... "~S- ~ ' "-~ .......... . . _Z_-__L._". ...... _~ ............. I'-- N--'z,~ ....... K-z 1'-2-'---- rVD;~e~-I .... TMD=2~-O77DEP=';39f ............. ......... ~ ..... :~ ...... ~_o.o~_+---,-:- ...... w ............. ~ ......... ,--:--: ....... -:->::: .... ~ .......... -, .... ....................................................... l- __ .........- ~ ' .l--- _ N ' ' - i- AVERAGE 'ANGLE '- ~ "l .... ~N ' - 45 DE6'21' MIN ........... .~ -.-..--.--_._4000 ........ _,. - x/K-5 TVD=4;371 TMD=5179 DEP=21;36 - . _ ' ' 5.0.00 ........................................................ ~ ........... . ..............F~-~ ~/~-C'i \/K~ i'"'~ .................... _ .' .......... - ...... _; ............. -' __: ..... ~ ...... ~__-_ i .... : ................... i':~,-~'~' ',;3. ! ~';qP, ft; -~-. .......... .......... .... .... : ............ ..... ... . ........ : - -- ! - - ' - - ' ' - ,, : '~ .... :~'"'~ /~,, ~3S C;OIS. ~Oi'!Y,i'i!.b~;l[.n'~ " ................. A~.-,,c hor,.'-~ }e .............................. ......... T/--ZONE K'-i-TVD~-587' g:TTMD~7;325-DEP='3662 'N, :: . - ......... TARGET CNTR-' TVD=5896 TMD=F349.DEP=;3680 ;' ' .--'__' . ! .... ". ~l/. KUP SNDS TVD=6001 TMD=?'498'DEP=;3786 :, ~ - - . ----~ .............:D .... (LOI~--PT) TYD=6142--TMD=F698i-DEP=;3928--:: ..... - - :- -' 7000-.. "~ ....~ .... : - ' ' :" ~- - : ' ..... : ........ i .... !__ . I ! ........ 7- "_ ......... . ........... . ......... ?--- ....... ~."- ...... ---.,.. -- . _ o ~ ¢ ' - _'..~,~r~,l'~. ...... '~ ' ".'::. - ooo '- ooo ~ooo' ' ~,ooo~/'~ "-~''' ~'~,..:'.~-~'~'~i ~ :~ ~. ~ ~'' ..... ~ ',:.~ i; '~N:-~.',-:~- · , . _.~ ~.~ ~ ......... ; . HORIZONTAL PROJEC_.T._I,ON' ! '.. SCALE 1 IN. = 1000 FEET PAD 2.- WELL NO' 1~ PROPOSED ' ~ KUPARUK FIELD. NORTH SLOPE. ALASKA EASTHAN ~HIPSTOCK. INC. . ................ 1000 , . ...................... 1000 _ O ~ SURFACE LOCAT[ON~ ZZ'. FSL. 556' F~L SEC. I. T11N. R8E 1 000 _ Z 2000 _ WEST-EAST 0 1 000 I 3000 20OO ! 3000 I .. . 4000 ' ' , ; . S 67 DEG 41 HIN E~ ,, . 3680' (TO TARGET) ; ' . . i ............... , ...... TARGET'C£NTER TVD=S896 THD=?349; DEP.3680~ SOUTH 1397 EAST 3404 . TAROET'LOCAT[ON~ , 1320'IFNL. 1320' FEL ~ SEC. 12. T11N. RSE : TD LOCAI~[ON, ?'1414' FNL. 1090' FEL 112. 1 N, RSE, SEC., T I OOt[ .I I 00[[: O00t 006 I , 009 I 00~; I oo~ ' oo£ ;oo;~ ~Zo~ I , gO,Zg ,9 / , ..: .L:_, .... OOg 001, I 006 ........ i 008 I i ooz 1 O09 I 00~' oo~ ' I 1 ! 000 It 00£ } : oog ¢ ......... 001. ',, .. -'-OOE ..... oo'£ KUP~RUK R I VER UN I T 20" D I VERTER SCHEM~T I C ! 8 8. J 2 ] DE SC R I .P T I ON · 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6, 20" 2000 PSI DRILLING SPOOL N/]O" OUTLETS, 7. 10" HCR'BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DONNNIND DIVERSION. 20"'2000 PSI ANNULAR PREVENTER. APPROVAL OF THIS D IVERTER SYSTEM AS A VARIANCE FROM UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLDN AIR THROUGH DIVERTER LINES EVERY 12 HOURS. · CLOSE ANNULAR PREVENTER IN THE -EVENT THAT AN INFLUX OF NELLBORE FLUIDS' OR GAS 1S DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNNIND DIVERSION, DO NOT SHUT IN NELL UNDER ANY CIRCUMSTANCES. . S ~ 0084002 J .( 5 > > ACCLMJLATOR CAPACITY TEST I. C:HECX ~ FILL A~TCR ~OIR TO'~ LEVEL WlTN NYDRALI_IC FLUID, 2. A~ 'THAT A~TC~ F'f~~ IS 3COO PSI WITH I EOD PSI ~TRF_AM CF' TFE RC. CA.,LATCR. 3. ~VE TI~, TkEN CLOSE ALL UNITS SIMJ_TAAECUSLY AND RECC~ THE TINEE AAD PR~ RE]dAINI~ AF-FER ALL UNITS ARE CLOSED WITH CHAROI~ PLlVP CFF. 4. REC~ ON NADC REPC~T, THE ACC~TABLE LC~ LIMIT IS 45 SEC~ CLOSING TI~E AhO 1200 PSI R~INING PRES~. 13-5/8" BOP STACK TEST I. FILL BCP STACX A~ C~ MANIFOLD WITH ARCTIC DIESEL. 2. Q-EC:X THAT ~ L~ ~ ~ ~N ~~ ~Y ~RA~. ~T ~T ~ IN WI~ ~i~ ~ ~ ~ IN L~ S~. 3. ~ ~ ~ ~ ~~ KILL ~ LI~ V~VES ~~ TO ~ STA~ ~ V~S ~ ~ ~ ~ ~. ~. P~~ ~ TO 2~~~ F~ ~0 ~IN. I~ ~ ~~ T~ ~ ~ F~ ~0 ~IN. BL=WO ~~ TO 0 ~I. 5. ~ ~ PR~~ ~ ~AL KI~ ~ ~E LI~ VALVES. ~E T~ RIRE ~ ~ ~ V~VES ~ KJLL ~ ~E ~ TEST TO 2~ RSI ~~~ IN ST~ 4. 7. ~I~ TESTI~ ALL~VES, LI~S, ~ ~S WIT~ A ~ RSI L~ ~ 3~ PSI HI~. TEST AS ST~ 4. ~ ~T ~~ TEST ~ ~ ~T ~ 8, ~ T~ P]~ ~ ~ ~ ~~ PI~ TEST B¢~ PIPE ~ TO ~ ~I ~ ~ ~I. 9. ~ BO~ PIPE R~, ~ ~ ~I~ ~ .10. ~ ~I~ ~ ~ TEST TO 2~ ~I ~.~ PSI. II. ~ ~I~ R~ ~ ~I~E TEST ~. ~ S~ ~IF~ ~ LI~S ~ ~L. ¢ ~~I~. ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~. 12. TEST ST~I~ VALVES, KB IY, ~lY ~S, PI~ S~ VALVE, ~ I~I~ B~ TO ~ PSI 3~ PSI. 13. RE~ TEST ]~~TI~ ~ ~~ ~ ~ST 14. P~~ ~ETE B~ ~ST ~ NI~I~ ~ ~Y TH~~~ ~I~LY ~~ B~ ~ILY. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out.preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9.' Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel and set packer. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. LWK4/ih S~L E ST'IR, ~'- 5TlR 'f'YP/C~I_ ~UD $'/$T'a::r'l $C. HE'm/:tTtC DRILLING FLUID PROGRAM Spud to 9-5/8" sUrface Casing Density 9.6-9.8 PV 15-30 Drill out to We%ght Up 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. After 200' of departure, there are no well bores within 200' of this proposed well. ~w~5 / ih ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2T Pad (Wells 2 - 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L44 Enclosure ,',, : ; ..~ ~:~ RECEIVED FEE 0 Alack=. Oil & Gao Co,%. au;:,, ..... ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany t/,,, mmma ,-F~ ~ : /'~ . · ~o LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. I, TIIN,R8E~ U.M. SEC. I, TIIN, RSE~ U.M. Z - Y = 5,970,382.43 LAT. 70~19' 49.1287" 10 - Y = 5,970,132.65 ~T. 70019'46.6719" X = 498,944.93 LONG. 150*O0'30.807'' X = 498,945.27 LONG.150000'30.796" 402' FSL, 556' FWL OG = 77' PAD = 81.5 Z52'FSL, 556' FWL OG ' 76.0 PAD - 81.7 3 - Y = 5,970,357.42 ~T. 70~19'48.8828" 11 = Y = 5,970,107.71 ~T. 70019'46.4267.' X = 498,944.91 LONG.150*O0"30.808" X = 498,945.10 LONG.150*O0'30.801" 377' FSL, 556' FWL OG = 77' PAD = 81.5 127' FSL, 556' FWL OG = 75.9 PAD 4 - Y = 5,970,332.46 ~T. 70~19'~.6372" 12 - Y = 5,970,082.58 ~T. 70~19'46.1794 X : 498,944.84 LONG. 150000, 30. 809" .~ X : 498,944.98 LONG. 150'00' 30. 804" 352" FSL 556' ~L OG = 77' PAD = 81 6 ~ 102' FSL, 556' FWL 5- Y = 5,970,307.52 LAT. 70°19'48.3919" '~ 13 - Y : 5,970,057.59 ~T. 70019'45.9336' X = 498,944.91 LONG 150000, 30.808" ~ ~ X = 498,945.08 LONG. 150000' 30.801" ' o 77' FSL, 556' FWL OG - 75.5 PAD = 81.6 327' FSL, 556' FWL OG : 77' PAD : 81.6 CO 6 Y = 5,970 282.50 LAT. 70019'~.1459'' ~ ~ 14 - Y : 5,970,032.60 LAT 70°19'45.~79" - , ~ C~ ~ c> ' . ' ~ ~ X = 498,944.91 LONG. 150~00' 30.806" X = 498,944.95 LONG 150'00 30.806" ~ o ~ 302' FSL, 556' FWL 0G = 77' PAD = 81.7 __ ~ ~ o" 52' FSL, 556' FWL 0G = 75.3 PAD = 81.7 , c3 ~ 15 -'Y = 5,970,007.69 ~T. 70°19'45.4428" 7 - Y = 5,970,257.54 LAT. 70°19 47.9003" ~ 0 ~ ~ X 498,944.93 LONG. 150°O0'30-806'' X = 498,944.95 LONG.150~O0'30.806" ~ ~ 27' FSL, 556' FWL OG = 75.2 PAD = 81.6 277' FSL, 556' FWL OG = 77' PAD = 81.6 = 5,970,232.63 LAT. 70°19'47.6553" ~ ~ 16 - Y = 5,969,982.85 LAT. 70°19'45.1985" 8 Y X = 498,944.96 LONG. 150°00' 30.806" ~ ~ ~ X = 498,944.88 LONG. 150000'30.807`` 252' FSL, 556' FWL 0G = 76.9 PAD = 81.6 ~ 2' FSL, 556' FWL 0G = 75.1 PAD = 81.7 9- Y : 5,970.207.62 LAT.' 70019'47.4093" c~ LOCATED IN PROTRACTED X = 498,945.01 LONG.!50°00'30.804'' ~ SEC.I2, TI I N, R8E, U.M. 227' FSL, 556' FWL OG : 76.3 PAD : 81.6 17 - Y : 5,969,957.72 LAT. 70°19'44.9514'' X : 498,944.94 LONG. 150000, 30. 805" ~'.-. ~--,, ~ NOTES : .... ~ :' .... ~ ': ' '' · - 2. SECTION LINE DISTANCES ARE TRUE.. : ,:. ' .. 3. HORIZ; POSITIONS BASED 0N TEME MON~ ZT-EAST, 2T WE~ &'''2T~'' ~': '': - MIDDLE -P'E:R"LhD& ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ NI9+75, Ell+ 52 PER FR.B. ~ ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX-~140 rev. CERTIFICATE CERTIFy THAT I AM PROPERLY OF SURVEYOR : ~E~EBY REGISTERED AND LICENSED TO ~RACTICE LAND SURVEYING IN THE STATE OF ~LaSKA ~D THAT I THAT A:L DIMENSIONS AND OTHER DETAILS ~ .... ~".- I ~ co~ ~.~'=~.~ -- ~ I: - ......... ~' ) SURVEYED FOR: a~ ARCO AIOSKO, inc. ~~~~.~~.~.~ i~!1~ :~ I~KUPARUK PROJECT ~ ~ m~mm ,) D*TE ~S JAN S~ ............ ~.,~, ,~m~ ¢= ~mm '~ DR*WN W~ U~ILL bl/C ~/ bUl~UUb~V~ f.'~ ', ssn:. I ~,~, AS- BUILT LOCATIONS ~, ..................... ~ IlDWG. No. NSK 86-6 Arctic Boulevard, Suite 201, Anchora e, Alaska 99503/Is~ ..T.~. Fee ,, (2) Loc .~CK LIST FOR NEW WELL PERMITS APPROVE DATE thru 8) (8) (3) Admin ,. (4) Casg (5) BOPE '(9 thru / H :>,' ~,' '(10 and i3') (14 thru 22) Company t'/~ ' Lease & Well No. YES NO 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. _~_~_~ 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8 Can permit be approved before ten-day wait . ~//~--- 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... <¥-~-~ 13. Does the well have a unique name and number ......................... 14. Is conductor string provided ........................................ 15. Will surface casing protect fresh water zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation, proposed ............................ 23. Is a diverter system required .. ...................................... 24. Is the drilling fluid program, schematic and list of equipment adequate~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to 3dDd~O psig .. 27. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 28. Is the presence of H2S gas probable ................................. (29 thru 31) (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31, If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. . Geology: En g%nge, ring: rev: 04/03/86 6.011 -. ...' ': i~;:~, ,, : '! '" "I~'' '"i'."-'"": ",i&'~':' :'~"':'"':"":., -:,. ..... . ,-~ ..... .... .... INITIAL GEO. POOL CLASS STATUS AREA UNIT ON/OFF NO. , SHORE . ,:j~,,,i', :.] ,:i,:',:i. :....;:,~.~":;!.. Well Histo.ry 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 APPENDIXl .. No special'effort has been made to chronologically organize this category of information. LIS' T ~,'PE '~ERIFIC~T'ION;' LISTING VP OlO.H02 VERIFICATID~ LISTIN3 PAGE 1 ~ REEL HEADER ~ ERVICE NAME :EDIT ATE :86/05/1~ RI2IN : ONTINU~TIDN ~ :Ol REVIO~S REEL : OMMENTS :LIBRARY TAPE ~ TAPE HEADER ~* ERVICE NAME :EDIT ATE :86/05/1~ RIGIN :FSIA APE NAME : ONTINUATION ~ :01 REVIOU$ TAPE :. OMMeNT$ :LIBRARY T~PE FILE HEADER 'ILE NA4E :EDIT .001 ,ERVICE NAME 'ERSION # : ~ATE:, [AXIMUMiLE'NGT'H : :ILE TYPE 'REVIDUS"FiLE INFORMATION, RECORDS ~:~: INEM. CONTENTS' UNIT 'TYPE ,. ;N :.. ARCO AL~'SKA, l:.qS. 000 IN : 2T-I 3 ? O00 :N. : KUPARUK 0,00 t A N ~ ':, 8 E 0:0:0 '0 '~: 11,4 000 ;ECT: 1 000 :0~: NORTH SLOPE ODD ;'T ~T~.' ALASKA:' 000 ~EM': C:ONTENT'$' UNIT T. YPE ,:, ~ R :E $: E 0 0 0 CATE SIZE CODE 01'8, 065 ~:0.0, 00:6 065' 0'00'~ : 00:8', 0,65 0:00 OOZ 065 ~,;:,00 00,~' 0'65 800 002 0.65 0~0 012 065 o,oo oo::s :'ATE SZZ"E CODe 000 0,0t' 065 VP OlO.H02 VERIFICATION L~STIN~ PAGE 2 SC~LU'MBERSER ~ ALASKA COMPUTIN~ CEqTER ~ OMPANY : ARCO ALASKA INC ELL = IT-13 IELD = KUPARUK DdNTY : NORT~ SLOPE )ORDUGH TATE =- ALASKA OB NL~MTER AT ACC: UN #ONE~ DATE LOGGED: 1! MAY 85 DP: T HALSTEAD A$ING : 3.525" 3 2@78° - BIT SIZE = B.5" TO 7868' YPE FLJID = WT. ~AT SLAY ENSITY = ll.O LB/~ RM = Z.890 @. 67 DF ISCDSITY : 60.0 ,S RMF = 2.410 ~ 67 DF H = Bo5 RHC = 3o010 @ 67 DF LUID LOSS =.7o2 C3 R~ ATB~T : 1-~35 @ ~.~Z OF AT,IX SANDSTONE, ,~¢ THIS ~ATA '~AS" NOT BEEN DEPTH SHIF'TED - OVERLAYS FIELD PRINTS · VP OlO.H02 VERIFICATID~ LISTIN3 PAGE 3 SCHLUMBERSER LOGS INCLUDED 'WITH THIS MAGNETIC. TAPE: D~ALINDg'CTI]N SPHERICALLY F3CUSED LOG DATA AVAILABLE: )84~' TO ZgTB' F~RMATIOfl DENSITY COMPENSATED LOG CFON) C~MPENSATED NEUTR3N L3G (FDN) DATA AVAILABLE: 7818°-T0 3340 GAMMA RAY IN ~ASING CGR.CNL) DATA AVaILAbLE: 30OD' Tg 1500' DATA FORMAT RECORD ~ NTRY ~LOC~S TYPE SIZE REPR,CDDE ½ I 66 ~ ~ 73 ~" '~ 65 16~ 1 66 0 1 66 ENTRY 0 ! 6O .XIN iAT~M SPECIFICATION BLOCKS ,NEMiSERVICE SERVICE U~IT. API API ~PI ~PI FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS ~'3D ND' CODE ,CO:CTAL) IEP:T FT O0 000 OD O 0 ¢ 1 .,58.000000000000:00 FL~ OIL O~MM O0 220 01 0 0 ~ 1 58:0000000000'0000 LO DIL O~MM O0 ~20 46 0 0 ~, ~ 6~ 0000000000~0.0:0 :LA' OIL ~MM, O0 120 4~' a O & ~ 6a 000000000000,00 ;P OIL MW!. O0 0~0 O! 0 0 4 i 68 000000,00000000 ;R OIL G&PI O0 310 O1 0 0 .4 I $8 00000000000000 VP OlO.H02 VERIFICATI3~ LIS'TINS PAGE 4 R FDN $~PI O0 ALI FDN IN O0 H3B FDN ~/C3 O0 RM3 FDN S?C3 O0 RAT F3N O0 NR~ FDN O0 P,flI FDN PJ O0 C~IL F.'gN CPS O0 CNL: FDN CPS O0 R CflL 2~PI O0 310 01 3 0 280 01 0 0 350 02 0 0 356 01 0 0 420 01 0 0 000 O0 0 0 890 O0 0 0 330 31 0 0 330 30 0 0 310 Ol 0 0 DATA ~'~ EPT 7878'0000 SFLU P -49-0820 GR HOB 2.3948 OR'q] PHI 3~.7656 NCNL EPT: 7800.0000 SFLJ P -18.9539 GR HOB 2-5022 DRHD PHI 36.2793 NCNL EPT 7700o0000: SFLg P -15.7324. 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