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Home My WebLink About188-121 Ima ect Well History File Cover~ e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /~_~_ / ~;~/ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No, [] Maps: 1:3 Grayscale items: [] Other, No/Type [] Other items scannable by D Poor Quality Originals: large scanner OVERSIZED (Non-Scannable) [3 Other: NOTES: [] Logs of various kinds [3 Other BY: BEVERLY. BREN VINCENT SHERYL MARIA LOWELl, DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: Is~ Scanning Preparation ~ x 30 = BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /SI Production Scanning Stage Stage 2 PAGE COUNT FROM SCANNED FILE: '~? PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: NO BEVERLY BRE' VINCEN~MARIA LOWELL DATE;~/'~,~)~'/ ~ IF NO IN STAGE 1, PAGE(S] DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION ~S REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned(individua, page[specia, a~tenrion]scanningco~p,e~ed) IIIIIIIIIIIIIIIIII RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or COmments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd • w\� �j/j-.s THE STATE Alaska Oil and Gas �'�' �f�Ll`1S� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Titov Anchorage, Alaska 99501-3572 A Main: 907.279.1433 Fax: 907.276.7542 Mike Callahan Drilling Engineer ConocoPhillips Alaska, Inc. MAY 1 6 2014 P.O. Box 100360 ( �-- Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-02 Sundry Number: 313-643 Dear Mr. Callahan: 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, p9,Cathy P. F erste Chair DATED this3D day of December, 2013. Encl. 4 STATE OF ALASKA 4\ 1,4:(GRECEIVED AL A OIL AND GAS CONSERVATION COMM__SON o DEC 2 0 2013 APPLICATION FOR SUNDRY APPROVALS OY.S tilso I( 3 20 AAC 25.280 AOGCC 1.Type of Request: Abandon Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r After casing r Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developrrent (�, _ 188-121• 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20101-00 , 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P" • 2K-02 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 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): 7770 6390 35' 35' 35',903',6347' 730' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3369 9.625" 3404' 2941' PRODUCTION 6499 7 7217' 5952' LINER 810 5" 7768' 6388' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7403'-7454',7488'-7524' . 6101'-6141',6168'-6196' 3.5 J-55 6347 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HB PACKER MD=6915 TVD=5716 • SSSV-CAMCO TRDP-1A MD=1231 TVD=1189' 12.Attachments: Description Summary of Proposal (d, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r- Exploratory r Stratigraphic r Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/15/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned 17, Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Callahan @ 263-4180 Email: Mike.Callahan@conocophillips.com Printed Name Mike Callahan Title: Drilling Engineer Signature Phone:263-4180 Date /02 //A/&/3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 V3—Ca.`E 3 Plug Integrity Pf BOP Test r Mechanical Integrity Test r Location CIearance ir- RBDM MAY 0 9 2014 Other o�d� L2Sp 'G {` ays" /r lCGt1 c d P 6 0 docurn erg Grrfof ��St� aroot weldeGe ppictfi ._ Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: ,+d ,--- 4—ll i 7 APPROVED BY Approved by: p COMMISSIONER THE COMMISSION Date: /Z - ✓ 43 Approved application Is valid for 12 monthps�tro�m�t e date of approval. Form 10-403(Revised 10/2012) pRIGINAL �l u ��y`r /3 Submit Form and Attachments in Duplicate (/t--F-d2/Z4 II RECEIVED 1PV DEC 2 0 2013 ConocoPhillips AOGCC December 19, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to plug and abandon the Kuparuk Producer 2K-02 (PTD: 188-121). Well 2K-02 was originally completed in 1989 as a Kuparuk producer. Most recently, the well was suspended in March of 2013 (Sundry Number 313-152) after a failed workover attempt due to subsidence induced failures in surface and intermediate casing at -700'. The well was cemented to surface by Nordic 3 on 3/25/2013. The objective of this workover is to permanently plug and abandon the suspended 2K- 02 well and back-fill the surface hole to ground level. This work is in preparation for the upcoming 2K-29 well, which will be drilled from a surface location 5 feet away from the 2K-02 surface location. If you have any questions or require any further information, please contact me at 263- 4180 or Mike.Callahan@conocophillips.com. Sincerely, Mike Callahan Drilling Engineer CPAI Drilling and Wells 2K-02 Wellhead Excavation / Final P&A Procedure 1. Remove well house. 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the production tree in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. Use Hydratight equipment to control any potential casing growth. Ver fy that cement is At surface in all strings. Add cement as required. 6. Send the casing head w/ stub to mat�als shop for repair/redress. Photo document. 7. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Drill 1/8" weep hole in the cover plate. Photo Document. / fF ConocoPhillips 2K-02 PTD #: 188-121 API #: 50-10320101-00 8. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. RDMO. 9. Report the final P&A has been completed to the AOGCC and any other agencies required. Ph v io n cu (- I v G � v Cd /Z cJ L t- tivr o r- G`, is Co iM r�� , t KUP 2K-02 e e ConocoPhillips g I Well Attributes Max Angle&MD TD AidSl(2 Inc; Wellbore APIIUWI Field Name Well Status Inc?(°) MD(RKB) Act Btm(RKB) ca..LJ7weps I 501032010100 KUPARUKRIVERUNIT PROD 39.47 2,600.00 7,770.0 Comment 1125(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:LOCKED OUT 60 10/28/2011 Last WO: 40.09 6/22/1989 Well Conrg:-2K-02,424/20139:5326AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,495.0 8/3/2012 Rev Reason:SUSPEND WELL osborl 4/24/2013 p Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 1150 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVO)...String wt..String...String Top Thrd CONDUCTOR. SURFACE 95/8 8.921 35.0 3,404.1 2,941.4 3600 J-55 BTC 36-115 : Casing Description String 0... String ID...Top(ftKB) Set Depth(f.Set Depth(ND)...String Wt...String...String Top Thrd. CMT Retainer, ; s "7 r PRODUCTION 7 6.276 718.0 7,216.6 5,952.3 2600 J-55 BTC 650 ,:: J y.;, Casing Description String 0... String ID...Top(ftKB) Set Depth(f.,.Set Depth(ND)...String Wt...String...String Top Thrd `I* LINER 5 4276 6057.9 7,768.0 6,388.2 18.00 L-80 LTC-8RD Squeeze,652 Liner Details Top Depth CSG CUT,718 (ND) Top Incl Komi... Top(ftKB) MKS) (°) Item Description Comment ID(In) 6,957.9 5,750.3 38.77 TIEBACK BAKER/BROWN TIEBACK SLEEVE 5250 FISH'730 6,965.2 5,756.0 38.76PACKOFF BAKERBROWNPACKOFF 4250 9-5/8 Balanced 6,971.6 5,760.9 38.76 TIEBACK BROWN TIEBACK SLEEVE 5.250 Plu0g,35 Cement Plug, - gp3 • `I 6,978.9 5,766.7 38.76 HANGER BROWN HMC LINER HANGER 5250 SAND PLUG, 1116 1 Tubing Strings _ SAFETY VLV, i Tubing Description String O... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd 7'237 � TUBING Post WO 3 12 2.992 1,230.7 6,347.0 5,273.4 9.30 J-55 EUESrdABMOD Attempt 2013 Completion Details Top Depth (TVD) Top Incl Nomi... GAS2,101 :e0Top(ftKB) (RKB) (°) Rem Description Comment 10(In) „t-. 1,230.7 1,188.7 30.54 SAFETY VLV CAMCO TRDP-1A SSA SAFETY VALVE(LOCKED OUT 9/3096) 2812 A j .. P Tubing DescriptionString 0... String ID...Top(ftKB) SDepth(L..Set Depth(ND)...String Wt..String...String Top Thrd . y TUBING TAIL Iet 31/2 I 2.992 I 6,900.8 I 6,985.1 5,771.5 ill i , oCompletion Details �' Top Depth CMT SOZ,35 ki (TVD) Top Incl Noml... SURFACE, Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 35-3,404 6,900.8 5,705.8 38.78 PBR BAKER 80-40 PBR w/4"SEAL BORE,10'STROKE 2.992 GAS LIFT, 6,914.5 5,716.4 38.78'PACKER BAKER HB PACKER 2.892 3,644 6,951.8 5,745.6 38.77 NIPPLE OTIS 2.812"XN NIPPLE w/2.75"NO GO 2.750 GAS LIFT. L Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) 4,354 Top Depth r IT (TVD) Top Incl To ftKB (MB) (.1 Dascri 'on Comment Run Date ID(in) GAS LIFT, _ 650.0 648.2 11.78 CMT Retainer 3/24/2013 1.500 4,745 718.0 714.1 13.32 CSG CUT CUT 7"CSG 32/2013 6.000 730.0 725.9 13.73 FISH OLD COMPLETION TUBING IN CEMENT 3/24/2013 2.992 GAS LIFT. 0 1,116.0 1,088.0 26.56 SAND PLUG Pump 2,300 lb 20/40 sand plug 3/2/2013 0.000 5,136 W If Perforations&Slots GAS LIFT, _ A 0 Shot 5.533 j G Top(ND) Btm(TVD) Dens '., Top(ftKB)Btm(ftKB) (MB) (RKB) ' Zone Date (oft- Type Comment 7,403.0 7,454.0 6,100.6 6,140.8 C-4,2K-02 3/19/1991 6.0 APERF 7,488.0 7,524.0 6,167.6 6,196.0 A-4,2K-02 11/16/1989' 4.0 IPERF -180deg.Phasing;27/8-Casing GAS5,In32ILL s Guns la 1 Cement Squeezes Top Depth Btm Depth (ND) (TVD) Top(ftKB)Btm(ftKB) (RKB) (ftKB) L Description Start Date Comment GASLIF._ 35.0 903.0 35.0 891.9 CMT PLUG 3/24/2013 9-5/8 Balanced cement plug 5.3oTs 651.5 652.0 649.7 650.2 CMT SOZ 3/24/2013 Abanadonment squeeze 903.0 1,116.0 891.9 1,088.0 CMT PLUG 3/2/2013 Ur 6,347.0 6,900.8 5,273.4 5,705.8 CMT PLUG 2/26/2013 Barrier from production zone-tested at 3,000 psi and Cement Pkg. NFT 6,347 PBR.6.901 -,. % End IfItQ nv+Frscs!; .. • // EDaterta Annotation _ PACKER,6,91410292010 NOTE:View Schematic w/Alaska Schematic9.0 i 7/12/2012 NOTE:OBSTRUCTIONS @ 692,713',8 719'SLM NIPPLE.6952-- j 3/26/2013 NOTE:SUSPEND WELL FOR FUTURE P&A i% 3 y / 0 Mandrel Details Top Depth Top Port 7 j S... (ND) Incl OD Valve Latch Size TRO Run // 1 N...Top(ftKB) MKS) 1°) Make Model (in) Semi Type Type (in) (psi) Run Date Com... PRODUCTION, 1 2,100.9 1,892.7 38.19 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,252.0 6/152000 77818-7,217217 j 2 3,644.2 3,143.2 35.02 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,295.0 6/15/2000 • APERF, 3 4,354.4 3,715.9 38.18 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,393.0 6/15/2000 7'403-7'454 4 4,745.1 4,021.9 38.56 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 6/15/2000 (PERF, 5 5,136.3 4,328.3 38.37 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/23/1996 7,486-7,524 6 5,532.6 4,637.9 38.51 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/10/1995 7 5,931.8 4,950.4 38.80 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 1221/1995 8 6,305.4 5,240.6 38.07 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 1222/1995 LINER. 6,958-7,768 TD,7,770 RECEIVED STATE OF ALASKA APR 2 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDA CC la.Well Status: Oil El Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended 2 , lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other E} No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 25,2013 t 188-121 /313-104,313-152 - 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 June 4, 1989 50-103-20101-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 271'FSL,94'FEL,Sec.2,T1ON,R8E,UM June 20, 1989 2K-02 • Top of Productive Horizon: 8. KB(ft above MSL): 154'RKB 15.Field/Pool(s): 1455' FNL,1544'FEL,Sec.2,T1ON,R8E,UM GL(ft above MSL): 114'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1430'FNL, 1709'FEL,Sec.2,T1ON,R8E,UM surface Kuparuk Oil Pool , 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498310 y- 5938575 Zone-4 / 7770'MD/6390'TVD • ADL 25588 . TPI: x-496859 y- 5942129 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-496694 y- 5942154 Zone-4 SSSV @ 1231'MD/1189'ND 2674 18.Directional Survey: Yes ❑ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1600'MD/1494'ND 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MDTTVD Caliper/CCL not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 179 sx AS III 9.625" 36# J-55 35' 3404' 35' 2941' 12.25" 880 sx AS III,450 sx Class G 7" 26# J-55 718' 7217' 33' 5952' 8.5" 357 sx Class G 5" 18# L-80 6958' 7768' 5750' 6388' 6.125" liner 24.Open to production or injection? Yes ❑ No Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 6303' 6915'MD/5716'ND perfs isolated 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 350'of cement plug from 6303'-6653' Was hydraulic fracturing used during completion? Yes❑ No❑✓ DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement plug 6303'-6653' 14 bbls 15.8#Class G SCANNED PR 40!`f cement plug 903'-1116' 7.6 bbls of 15.8#Class AS I 3L U! cement plug 650'-903' .5 bbl of 15.8#Class AS I _ cement plug surface-650' 54 bbls of 15.8#Class ASI 27. PRODUCTION TEST 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) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑✓ Sidewall Cores Acquired? Yes ❑ No Q 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 RBDMS APR 28 1013 /r c..7_,,-.< ti ' Form 10-407 Revised 10/2012 CONTINUED ON REVERSE / ol Submit original only I/. /' 1 /,. I ,. 0 i//_�../-•- I 1I 29. GEOLOGIC MARKERS(List all formations and me. encountered): 30. FORMATION TESTS NAME MD TVD Well tested? U Yes Q 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 1600' 1494' needed,and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263-4773 Email: Howard.Gober@conocoDhillips.com Printed Name T-1,4 Howard Gober '— Title: Wells Engineering Supervisor Signature Phone 263-4220 Date .a/t!3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 2K-02 Well Work Summary • DATE SUMMARY 11/21/2012 LOAD IA AND TUBING WITH 150 AND 80 BBLS OF DIESEL RESPECTIVELY. JOB COMPLETE 11/25/2012 (AC EVAL) RIG WORK, T FL @ SURFACE, IA FL @ SURFACE. 12/13/2012 PUMPED 140 BBLS 12.2 BRINE DOWN IA @ 1.3 BPM, 1500 PSI. FINAL IA PRESSURE AT 400 PSI. 12/14/2012 PUMPED 140 BBLS 12.2 BRINE DOWN IA @ 1.5 BPM, PUMPED 70 BBLS 12.2 BRINE DOWN TUBING @ 1.5 BPM, IA @ 100 PSI, WING APPEARS TO BE LEAKING BY, 200 PSI ON TUBING WITH GAS, SHUT MASTER VALVE AND CALLED VALVE CREW TO SERVICE WING. 12/16/2012 (PRE-RWO) : RIG WORK T POT(PASSED), T PPPOT(PASSED), IC PPPOT(FAILED), FT T LDS (T LDS @ 7 O'CLOCK POSITION WOULD NOT FUNCTION, GLAND NUT FUNCTIONED PROPERLY, THE LDS DID NOT ROTATE WITH THE GLAND NUT, ALL OTHER T LDS FUNCTIONED PROPERLY). 12/20/2012 (PRE-RWO): BLEED T& IA GAS CAPS. 1/11/2013 Verified no ice plug present in tubing nor IA by bullheading 5-bbl diesel down tubing each. Job complete. ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2K-02 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/19/2013 9:00:00 PM Rig Release: 3/26/2013 3:30:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/19/2013 24 hr Summary Rig&Camp Move from 2N-304 to 2K-02. 16:00 00:00 8.00 MIRU MOVE MOB P Move Camp,followed by rig from 2N pad to 2Kpad. 02/20/2013 Continue with Rig move from 2N 304 to 2K-02.Crew change at 2M pad.Arrive on location,install secondary containment and spot rig. Rig up Kill tank&cuttings tank. Rig accept @ 21:00 HRS 00:00 16:00 16.00 MIRU MOVE MOB P Continue moving rig from 2N pad. Stopped for crew change at 2M pad. Continue with rig move.Arrive on 2K location at 16:00 hrs. 16:00 21:00 5.00 MIRU MOVE MOB P PJSM-Discuss cold weather/wind chill. Lay down containment under rig and cellar. Install DSA behind rig. Spot rig over well.Spot Cutting tank. 21:00 00:00 3.00 MIRU MOVE RURD P **Rig Accept @ 21:00 hrs*** Continue with rig up,Warm up cellar, fluid lines and hydraulics on rig. Rig up Kill line to Kill tank. Load FMC lubricator onto rig. 02/21/2013 Held Pre-spud with Crews. Loaded 700 bbls of 14.2 KWF&bringing 3.5"DP into pipe shed. Tested all surface lines, Pulled BPV&VR plug. Bled down gas cap IA 550 psi&set up to kill well pumping 14.2#KWM down IA via OV @ 5299'while trying to recover 12.2#brine from well. Start=SPR 680 psi @/bpm/300 psi on tubing/OA 350psi Finish=IA 0/Tubing 0/OA 460 psi.Total bbls pumped 503,total bbls lost to formation 112. 12.2#Brine unuseable. 00:00 01:00 1.00 0 0 MIRU MOVE SFTY P Pre-spud meeting with Cody Crew. Waiting on SW-truck broke down due to cold temperatures. 01:00 04:00 3.00 0 0 MIRU MOVE SEQP P Start loading 235 joints of 3.5 DP into shed. Rigging up VR plug lubricator to pull VR plug. 04:00 06:00 2.00 0 0 SURPRI RPCOM PRTS P Trucks arrived on location.Take on heated SW,circulate the rig and pump 40 bbls to the Kill tank.Test hard line to 2500 psi. 06:00 10:00 4.00 0 0 SURPRI WHDBO MPSP P Test lubricator to 2000 psi for 5 mins. ok left 1500 psi on lubicator&Pull BPV 1000 psi on tubing. 1350 psi on IA, 340 psi on OA. Page 1 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:00 16:00 6.00 0 0 SURPRI WELCTL CIRC P load 350 bbls of 14.2 water base mud in pits,mix up 30 bbl 12.2 mud sweep.wait on remaing 350 bbls of 14.2 mud to arrive on location. MI mud plant backing up on orders. continue to load drill pipe in to pipe shed.tested gas alarms in shaker area Good test. 16:00 18:30 2.50 0 0 SURPRI WELCTI KLWL P opened up IA to choke pressure decreased to 550 psi. Bled down IA to 0 psi. Established SPR @ 680 psi @ 1 BPM circulating reverse thru GLM @ 5299 w/.25 orfice.pumped 10 bbls fresh water then swich to 12.2 brine vis.mud sweep.pumped 35 BBLs. @ 2 BPM @ 700 psi IA pressure and 300 tubing.with 72 bbls total pumped brine to surface. Blew kill tank line dry with air and continued circulation with 14.2 mud. 18:30 22:00 3.50 0 0 SURPRI WELCTI KLWL P Continue with well kill process pumping 14.2#KWM down IA @ 2 bpm 630 psi,choke 300 psi/OA 440 psi. Pump 30 bbls sweep followed by 14.2 KWF,attempted to recover 12.2 brine from well-cannot save fluid mixed with hydrocarbons average weight 10.3#.Continue with Kill process-started to get sweep back after 283 bbls pumped. Returns roughly 40%pumping 2 bpm. Signs of KWM returns to surface @ 383 bbls pumped, 13.8#90% returns. 448 bbls pumped-#14+KWM returns to surface 1:1 returns, pumping @ 2 bpm 600 psi on IA/ choke 0 psi wide open. Final Values=Total pumped 503 bbls/Losses 112 bbls to formation/ IA pressure"0"/choke pressure"0 OA 460 psi. 22:00 23:30 1.50 0 0 SURPRI WELCTI OWFF P 30 minute no-flow test-Good well on slight vac. Monitor for another 30 minutes to determine loss rate.Took 1.5-2 bbls to fill tubing after 1 hour of static test. Continue loading 3.5"DP into pipe shed. 23:30 00:00 0.50 0 0 SURPRI RPCOM KLWL P Rig down Cellar hoses, prep for setting BPV. 02/22/2013 Set BPV, ND tree,erosion on tubing hanger lift threads, NUBOP's. Set 3.5"5M WRBP @ 600'due to Plug profile damage in the hanger. Replaced hanger retention screws&packing gland nuts in order to test BOPE stack. 00:00 00:30 0.50 0 0 SURPRI WHDBO SEQP P Set BPV Page 2 of 30 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:30 03:00 2.50 SURPRI WHDBO RTWH P ND Tree 03:00 03:30 0.50 SURPRI WHDBO OTHR P Inspecting lift threads on the tubing hanger noticed pitted threads on one side. 03:30 08:00 4.50 SURPRI WHDBO NUND P NU BOP stack and hook up lines 08:00 09:00 1.00 SURPRI WHDBO MPSP P removed test plug and install double check plug do to damage noticed in hanger. 09:00 09:30 0.50 SURPRI WHDBO MPSP P filled BOPE with fresh water to begin blind ram and check valve test hanger retention screw packing was leaking @ 2500 psi. bled off preesure. 09:30 11:30 2.00 SURPRI WHDBO MPSP T empty out BOPE stack to replace packing gland on hanger.wait on FMC service hand. 11:30 12:30 1.00 SURPRI WHDBO MPSP T replaced leaking packing gland and remainin 2 others as well.all 4 retention bolts replaced. 12:30 13:30 1.00 SURPRI WHDBO MPSP T FMC hand had gotten new information that the plug profile in the hanger was bad. Pulled double check from hanger.installed test jt in hanger with FOSV. 13:30 17:00 3.50 SURPRI WHDBO MPSP X Call out HES eline to set WRBP in tubinng. 17:00 19:00 2.00 SURPRI WHDBO MPSP X pre job with HES: Rig up HES to set Weatherford 3.5"5M WRBP @ 600 ft.above tubing damage @ 690 ft. 19:00 21:00 2.00 SURPRI WHDBO MPSP X Pooh with eline and RD HES 21:00 21:30 0.50 SURPRI WHDBO BOPE P Prep Cellar and rig floor for BOPE test. PJSM for BOP testing. 21:30 00:00 2.50 SURPRI WHDBO BOPE T Start BOPE test 250/4800 psi. ***State waived witness by John Crisp.*** Shell test Stack-New Gland nut started to leak while coming up to high shell test. Bleed off pressure, tighten nut.Gland nut held until 4800 psi was reached then started to leak again. Bleed off&drain stack. Pulled Gland nut to inspect. Installed new Glan nut,seals and packing. Fill Stack&test-passed. 02/23/2013 Complete BOPE test 250/4850 psi. Fish WRBP, P/U baker 3.5 ITCO Spear. Pull hanger free 65K,Worked tubing and pulled 3.5"seal assembly free 140K.Circulate 518 bbls of 14.2 KWF. RIH with SL to drift tubing with 2.80"&2.70"drift,tagged same spot @ 686'. Reverse Circulated @ 4bpm due to well balance. 00:00 05:00 5.00 0 0 SURPRI WHDBO BOPE P Start BOPE test 250/4800psi. Annular 250/3500,using 2 7/8"& 3.5"test joints.****State test Waived by John Crisp** Page 3of30 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode ` T Comment 05:00 10:00 5.00 0 0 SURPRI WHDBO PACK X Spot Slick line and rig up SL equipment on rig floor. Held PJSM tested lubicator to 500 psi. RIH with WRBP retieving tool to 600 ft worked plug free and let equalize.no pressure in tubing. POOH with plug and RD HES Slick Line. 10:00 12:30 2.50 0 6,915 SURPRI FISH FISH P PJSM with Baker Fishing.Made up 3.5 IF ITCO spear with 2.933 graple, packoff dressed for 3.5-9.3#tubing. Engaged spear in hanger and picked up on tubing hanger free at 65,000 lbs.worked seals and tubing up to 102 K with out Bliock weight 140 K with seals pulled free.pulled out of PBR. 12:30 13:30 1.00 6,915 6,915 SURPRI WELCTI CIRC P pumped 62 BBLs 14.2 mud @ 2BPM @ 1200 psi down tubing to balance out well 13:30 14:00 0.50 6,915 6,850 SURPRI FISH FISH P removed spear from hanger laid down hanger and 4 ft 3.5 8rd pup jt 14:00 20:00 6.00 6,850 6,850 SURPRI WELCTI CIRC P Circulated well with 14.2 mud 1.5 hole volume=415 bbls convetional @ 2BPM 380 psi FCP. Monitored for flow 15 miins tubing began to flow continue to circulate.Total loss of 160 bbls of KWF,32 bbls downhole &80bbl due to X-link of 12.2 in the annulus.Order another 175 bbls. Circulate addional 103 bbls,2 bpm 430 psi. 14.1#KWF around, lost 2 bbls to formation. Flow check,no pit gain. Loss of 1 bbl for 60 minute no flow while rigging up SL. 20:00 22:30 2.50 6,850 6,850 SURPRI RPCOM GRJB P Rig up SI with 2.80"gauge ring cannot drift past 686' POOH install 2.70"drift(WRBP OD). tagged up in the same spot. Rig down SL.Total losses of 3 bbl. Built up 50 psi.on tubing while running Slick line. 22:30 00:00 1.50 6,850 6,850 SURPRI WELCTI CIRC P Rig up and circulate#14.1+down the tubing-start 2 bpm @ 615 psi. Finish after tubing volume 2 bpm 405 psi.Shut in and pressure built up to 100 psi on tubing/backside is zero. No losses or gains during circulation. Well acting like it is out of balance. Line up to reverse circ @ 4 bpm 630 psi-increased to 980 FCP.Annular volume pumped.started to get 14.5# KWM back. 02/24/2013 P/U weight 95K,TOOH with old 3 1/2"completion string up to Joint#33(1034')of pipe.SSSV would not pull through restriction @ 720'.Max Pull 110K. Down weight 55K.Try to work string with no luck. P/U New 3 1/2" tubing,TIH,sting into PBR. R/U Slick line and could not drift past 714'with 2.80"&1 11/16"Drift. Rig down SL. Page 4 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 6,850 6,850 SURPRI WELCTI CIRC P 175 bbl of new 14.2#KWF arrived on location.Continue reverse circ. 14.5# KWM coming back pumping 4 bpm @ 950 psi.Stop pumping-Monitor well for 30 minutes-No flow. 01:00 05:30 4.50 6,850 5,780 SURPRI RPCOM TRIP P PJSM for tripping pipe-start tripping pipe. P/U weight 93K Down weight 75K.Joint#13 the SSSV line pulled tight.tried to work free,drain stack to inspect.Worked it free. Fill stack. Joint#22 first joint of corkscrew tubing. P/U weight 95-100K. Started pulling heavy on joint#33. max. P/U 110K.( 1034'of tubing OOH/SSSV roughly 730'from surface) P/U new joint of 3.5"-rotated 1/4 turn try to P/U-over pull in the same spot. 05:30 14:00 8.50 5,780 5,780 SURPRI RPCOM CIRC X Cut SSSV line, installed 2 bands and folded over the line.Sit with new joint across the stack for circulation, monitor well. Wait on Scope change while circ well. 14:00 16:30 2.50 5,780 5,780 SURPRI RPCOM CIRC X Loaded 3.5"8 round pipe,drift,strap &tally. 16:30 18:30 2.00 5,780 6,888 SURPRI RPCOM TRIP X Start P/U pipe RIH to PBR. Lightly stung into while circulating 1/2 bpm. Located with pressure build @ 6877' Bleed off pressure RIH to No-go @ 6888'.-P/U weight 105K/Down weight 55K. 18:30 20:00 1.50 6,888 6,870 SURPRI RPCOM CIRC X Pull out PBR and circluate B/U at 6 bpm,2050 psi. First B/U had 14.9# mud coming back.Circ additional B/U with#14.1 around. 20:00 21:00 1.00 6,870 6,887 SURPRI RPCOM HOSO X TIH and located while pumping 1 bpm,pressure increase @ 6877'- Bleed pressure and TIH to 6887'(1-2 ft off locator). Up 105K/Dwn 55K. Pull string in tension for SL run. 21:00 00:00 3.00 6,887 SURPRI RPCOM GRJB X PJSM-rig up SL with 2.80"guage ring. Made it down to 712',multiple attempts to drift past. No luck, toolstring sticky coming out of tight spot. POOH for 1-11/16"drift. RIH with 1 11/16"drift tagged up 714' made it two feet deeper than first run. POOH call town. 02/25/2013 Circulate 14.2#KWF -perform no flow test for 30 minutes. P/U 7"storm packer,set packer @ 100'.Test to 1000 psi/15 minutes. ND BOP's. Decision made for Cement job, NU BOP'S test to 5000psi. RIH to 6780' 100' above PBR,Circulate,wait on Cement. 00:00 01:30 1.50 6,888 6,888 SURPRI RPCOM SLKL X Rig down SL. Page 5 of 30 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:30 03:00 1.50 6,888 6,870 SURPRI RPCOM CIRC X Pull out of PBR,Max up 105K& Circulte B/U.6 bpm @ 1200 psi with 14.2#Mud. Flow check for 30 minutes.Good-no flow. 03:00 03:30 0.50 6,870 6,550 SURPRI RPCOM TRIP X TOOH 300'to install storm packer. 03:30 05:30 2.00 6,650 6,750 SURPRI RPCOM PULD X P/U storm packer-RIH 100'to set 7" packer. 05:30 06:00 0.50 6,750 100 SURPRI RPCOM PRTS X Test/chart Storm packer to 1000 psi for 15 minutes. 06:00 11:30 5.50 100 0 SURPRI WHDBO NUND X ND BOPE stand by on orders NU BOPE 11:30 13:00 1.50 0 0 SURPRI RPCOM BOPE X test cavity on BOPE to 250/5000 psi 13:00 15:00 2.00 100 0 SURPRI RPCOM PULL X release and pull Storm packer 15:00 21:00 6.00 0 6,871 SURPRI RPCOM CIRC X PJSM-RIH from 6577'down to 6878' -Locate PBR, P/U 7ft and circulate to condition the well @ 4bpm 870 psi. 21:00 00:00 3.00 6,871 6,780 SURPRI RPCOM CIRC X ASRC trucks arrived on location,set up pits for cement job&mix up rinsate pill. P/U and lay down 3 joints.#34,33,32-100'off the packer. 02/26/2013 Pump 13.4 bbl balanced Cement plug,WOC for 12 hrs, RIH and tag cmt @ 6,303-ft. CBU, Pressure test Cement plug @ 1,500 psi for 15 minutes-passed,conduct 30 minute NFT-passed. POOH laying down 9 jts-cork screwed TBG. RIH and set Storm packer 112-ft center of elements. POOH w/setting tool. 00:00 02:00 2.00 6,780 6,780 SURPRI RPCOM COND X Wait on Cementers.Condition mud in pits from 13.9+to 14.2#. 02:00 04:00 2.00 6,780 6,780 SURPRI RPCOM SEQP X Start Circulating KWF around @ 5 bpm/1260 psi.SLB cement crew arrived. PJSM-rig up for cement job. Take on water and mix up Mud Push Spacer. 04:00 06:00 2.00 6,780 6,780 SURPRI RPCOM CMNT X PJSM-Pumping Balanced Cement Job.Presure test surface lines to 3000 psi.Cement set up time started @ 04:50. 15 bbl Mud Push (drop 1/4 foam ball) 14bbls 15.8#Class G Cement Pump Mud Push 8.5 bbls Displace with rig 48 bbls Cement in place @ 05:50.TTOC @ 6460 ft. 06:00 06:30 0.50 6,780 SURPRI RPCOM CMNT X RD Schlumberger. 06:30 07:30 1.00 SURPRI RPCOM CMNT X pulled 19 jts 3.5"9.3#N-80 8rd tubing tail @6195 ft. 07:30 09:00 1.50 SURPRI RPCOM CMNT X reverse circulated 80 bbls mud stiil balled up continue to circulate.sent a total of 124 bbls of bad mud to cutting tanks.total reversed 234 BBLs. 09:00 09:30 0.50 SURPRI RPCOM CMNT X SWI and record pressures on 30 minute SI.TBG.0 PSI, IA 0 PSI,OA 0 PSI Page 6 of 30 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 09:30 18:00 8.50 SURPRI RPCOM CMNT X wait on cement 18:00 21:30 3.50 SURPRI RPCOM CMNT X Tagged cement @ 6,303-ft CBU to condition hole volume,pressure tested to 1500 PSI .test waived By John Crisp AOGCC @ 1600 hrs. 21:30 22:00 0.50 COMPZ RPCOM TRIP X POOH laying down from 6,303-ft to 5,987-ft(TBG was was severely cork screwed-This was new tubing that was RIH on 2-24-13) 22:00 00:00 2.00 COMPZ RPCOM PULD X PU,MU Baker storm packer assy and RIH to 112-ft center of element with Top @ 100-ft. Seal assy mule shoe @ 6,188-ft. 02/27/2013 PT storm packer to 500 psi. PJSM, ND BOPE and set back. ND TBG spool w/hydro tight. Spear 7"csg and re land w/100k in slips. Cut stub and NU TBG spool and BOPE. Test pack off and Shell test BOPE. Release storm,acker and POOH. Lay down strom packer. 00:00 00:30 0.50 COMPZ RPCOM PRTS X Pressure test Baker Storm Packer at 500 psi for 15 minutes-good test. 00:30 02:30 2.00 COMPZ WHDBO NUND X Drain stack,ND BOPE and rack back. 02:30 11:00 8.50 COMPZ WHDBO OWFF X Prepare to ND FMC TBG Spool- slight blow on OA-check with Quad monitor-high LEL-standby and monitor well. Continue to monitor OA still venting gas monitor IA checking ever 30 mins for acceptable LEL.4 PPM @ 10:30 am 11:00 12:00 1.00 COMPZ WHDBO NUND X PJSM RU Hydro-Tight. Let 7"csg. grow(9.5") 12:00 12:30 0.50 COMPZ WHDBO NUND X RD PESI Hydro-Tight 12:30 14:30 2.00 COMPZ WHDBO RTWH X removed 7"tubing spool and packing /slip rings 14:30 16:30 2.00 COMPZ WHDBO RTWH X made up 4 1/2"ITCO spear W/6.22 grqaple and speared Casing. pulled csg. up to 50K over string.total Growth =21..5"re-landed csg with 16:30 17:30 1.00 COMPZ WHDBO RTWH X cut casing with Wach cutter install tubing spool. 17:30 18:00 0.50 COMPZ WHDBO PRTS X Test tubing spool to 250/3000 psi 15 min 18:00 21:30 3.50 COMPZ WHDBO NUND X NU 11"Class III BOPE 21:30 22:30 1.00 COMPZ WHDBO BOPE X Set test plug and Shell Test BOP @ 250/5,000 psi. Pull test plug. 22:30 00:00 1.50 COMPZ RPCOM PACK X PJSM, RIH to 100-ft and engage storm packer,check for flow, release storm packer and NFT. POOH and lay down storm packer. 02/28/2013 POOH to 714-ft with SSSV,pull 15k OSW-attempt to work thru, parted @ 5k OSW-lost 50k string wt. Continue to POOH laying down de-completion. RIH w/3 1/2 DP and set down @ 717-ft. POOH and set test plug. Change out LPR's from VBR's to 7"CBR's. Open and inspect ram cavities Conduct weekly BOP Test w/3 1/2 Test jt. Page 7 of 30 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 04:00 4.00 COMPZ RPCOM PULL X continue to pull out of hole with production tubing string.Got SSSV to damage at 710 ft.valve hung up with 15K over worked back down and pulled back up string parted with 5 k over string.continued out of hole recovered top sub on SSSV pin pulled.Cap.tubing was also balled up do tubing rotation from damage. Some cap tubing in BOPE. 04:00 08:00 4.00 COMPZ RPCOM FISH X wait on spear and scope change orders 08:00 10:30 2.50 COMPZ RPCOM FISH X PJSM made up BOT wire rope spear RIH to 90 ft no recovery. RIH to-700 feet 10:30 11:30 1.00 COMPZ RPCOM FISH X POOH with spear recovered approx 50 of cap.tubing. 11:30 13:30 2.00 COMPZ RPCOM TRIP X RIH with 3.5 IF drill pipe with bull nose.tagged solid at 717 ft csg. damage 13:30 14:00 0.50 COMPZ RPCOM TRIP X POOH with drill pipe 14:00 15:30 1.50 COMPZ RPCOM TRIP X RIH w/3 1/2 8rd de-completion from derrick to 378-ft. POOH laying down the same. 15:30 17:00 1.50 COMPZ RPCOM OTHR XT Waiting for 2 7/8 HT PAC to arrive from Dead Horse-Clean and organize rig. 17:00 18:00 1.00 COMPZ WHDBO OTHR X Pull wear ring and install FMC test plug. RILDS in preparation of changing LPR's to 7"and conducting weekly BOP test due on 3-2-13. 18:00 21:30 3.50 COMPZ WHDBO OTHR X PJSM,Change out LPR's from 2-7/8 x 5"VBR's to 7"Solids. Open Blind and UPR's ram doors and inspect cavities. Close doors and secure. 21:30 00:00 2.50 COMPZ WHDBO BOPE X Conduct weekly BOP test @ 250/ 5,000 psi on rams and 250/3,500 psi on Annuular. Test with 3-1/2 Test joint. Notice was given @ 07:30 hrs on 2-28-13 and Right to witness was waived by Chuck Scheve @ 07:40 hrs on 2-28-13. 03/01/2013 Continue to conduct weekly BOP test with 2-7/8 and 7"test jts. Change out VBR packers. Re-test-good test. PU and RIH w/2-7/8 HT PAC dp to 714-ft and set down. POOH and 2-7/8 wire grab mules jt to 734-ft and No-go cross over @ 717-ft, POOH and recovered 20-ft of control line. Close blind rams and PT cmt plug at 1,500 psi-good test. RIH w/BHA#7 Page 8 of 30 • Time Logs — - Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 00:00 13:30 13.50 COMPZ WHDBO BOPE X Continue to conduct weekly BOP test @ 250/5,000 psi on rams and 250/3,500 psi on Annular. Test with 2-7/8 Test joint-VBR's failed, Continue to test w/7"Test jt. Change out 2-7/8 x 5"VBR's in UPR's and test w/2-7/8 test jt installed and tested cement valves on mud cross. Notice was given @ 07:30 hrs on 2-28-13 and Right to witness was waived by Chuck Scheve @ 07:40 hrs on 2-28-13. 13:30 15:30 2.00 COMPZ RPCOM TRIP X PJSM.Made up HT PAC bit sub on 2 7/8"HT PAC and pick up/RIH with 29jts 2 7/8"HT and 6 jts 3.5 IF DP tagged @ 714 ft.put 15K down wt.on tubing did not push thru.bad csg area. 15:30 17:30 2.00 COMPZ RPCOM TRIP X POOH with D/P and bit sub. 17:30 19:30 2.00 COMPZ RPCOM FISH X made up 2 7/8"X 15 ft poor boy wire rope spear and RIH to 734 ft work spear-Cross over no-go @ 717-ft 19:30 20:30 1.00 COMPZ RPCOM TRIP X POOH w/BHA#6 and recover 20-ft 20:30 21:30 1.00 COMPZ RPCOM OTHR X Clean and clear floor,offload pipeshed 21:30 23:30 2.00 COMPZ RPCOM PRTS X PJSM,PT 7"CSG against balanced cmt plug @ 1,500 psi 22:00 hrs 1,586 psi 22:15 hrs 1,573 psi 22:30 hrs 1,567 psi 22:45 hrs 1,563 psi 23:00 hrs 1,561 psi 23:15 hrs 1,561 psi 23:30 00:00 0.50 COMPZ RPCOM TRIP X PJSM,RIH w/BHA#7 03/02/2013 Continue to RIH w/BHA#6 to 734-ft, POOH and recovered no fish. PU and RIH w/23 jts of 2 7/8 8rd and follow w/3 1/2 DP to 1,231-ft. PU to 1,214-ft. Prep for spotting sand plug. Pull 7"CSG packoff. BOP's NU and Tested. 00:00 01:30 1.50 COMPZ RPCOM TRIP X Continue to RIH w/BHA#6 to 734-ft and No-go on cross over sub @ 717-ft. Work wire grab, POOH w/no recovery. 01:30 02:30 1.00 COMPZ RPCOM OTHR X Tally and Drift 2-7/8 EUE 8rd tubing 02:30 03:45 1.25 COMPZ RPCOM PULD X PU and RIH w/BHA#7(Taper String)having to screw in Top drive for push wt.to 1,231-ft and tag up 17-ft in on DP jt#16. 35/45k do wt, 50k up wt. POOH to 1,214-ft and set in slips. 1,231-ft+5,216-ft Fish= tail @ 6,357-ft. 03:45 04:00 0.25 COMPZ RPCOM OTHR X Prep for RU of Schlumberger to pump sand pill. Page 9 of 30 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 04:00 08:00 4.00 COMPZ RPCOM CIRC X Circulating and conditioning hole w/ 154 bbls of WBM at 4 bpm @ 320 psi,circulating 14.1 ppg in 13.5/ 14.0+ppg out. 08:00 11:00 3.00 COMPZ RPCOM OTHR X Rig up Schlumberger to spott 100 ft- 2300 lbs of 20/40 sand from 1231 to 1131 +/-.plug in place @ 10:20 AM RD Schlumberger. 11:00 13:00 2.00 COMPZ RPCOM TRIP X POOH standing back D/P. laid down 2 7/8 8rd. 16 jts bent. 13:00 15:00 2.00 COMPZ WHDBO MPSP X PJSM with BOT picked up Baker G packer RIH set paker @ 87 ft C/E 15:00 15:30 0.50 COMPZ WHDBO PRTS X test packer to 1500 psi for 15 minutes. 15:30 16:00 0.50 COMPZ WHDBO OWFF X Conduct NFT-Good test had no flow 16:00 18:00 2.00 COMPZ WHDBO NUND X ND BOPE and FMC tbg Spool and pull 7"FMC pack off ring 18:00 23:00 5.00 COMPZ WHDBO NUND X NU 11"3M x 11"5M DSA and 11" 5M Class III Bope Stack 23:00 23:30 0.50 COMPZ WHDBO BOPE X PJSM,Test BOP Breaks @ 250/ 1,500 psi 23:30 00:00 0.50 COMPZ WHDBO MPSP X PJSM,MU and RIH w/BHA#10 Model"L"Retrieving head 03/03/2013 RBP was pulled f/87-ft. Begin milling out tight spot in 7"casing @ 720-ft,breeched 7"CSG at 721-ft. Circulate out Arctic Pack to open top tank, POOH w/Milling assy. Discuss options with Town engineers. Prep rig to change over to Sea water. RIH w/2 7/8 mule shoe jt and attempt to pass by 722-ft Unsuccessful. POOH. Load pits with sea water. RIH w/bull nose slotted bent jt to 1,116-ft,Attempt to CBU-no luck. Pull high and WO cementers. 00:00 00:30 0.50 COMPZ WHDBO MPSP X Engage and release RBP at 87-ft and POOH. Lay down RBP. 00:30 01:30 1.00 COMPZ RPCOM OTHR X Load Milling BHA in Pipe shed 01:30 02:30 1.00 COMPZ RPCOM PULD X PJSM, PU,MU and RIH w/BHA#11 (milling Assy) to 220-ft 02:30 04:00 1.50 COMPZ RPCOM TRIP X RIH w/BHA#11 from 220-ft to 720-ft and tag up. 04:00 04:30 0.50 COMPZ RPCOM MILL X Gather parameters:Circulating @ 5 bpm @ 430 psi Rotating @ 80 rpms w/1,400 ft/lbs. 51k up wt, 53k do wt,51k Rot wt. Begin milling from 720-ft to 721-ft,breeched 7"casing and arctic surfaced. 04:30 07:30 3.00 COMPZ RPCOM CIRC X Divert Arctic pack OA fluids to open top tank and displace annulus with 14.1 ppg WBM 07:30 08:30 1.00 COMPZ FISH MILL X continue milling operations from 721 ft to 22 lost circulation. Pulled up to 670 ft.Scope change. 08:30 16:00 7.50 COMPZ RPCOM OTHR X Held conference call with town engineers. Change over pit system from mud over to Sea water. Clean pits. Wait on cementers. 16:00 18:00 2.00 COMPZ RPCOM TRIP X PJSM,MU BHA#12,Tag up @ 722-ft. Attempt to work through -no success. POOH. Page 10 of 30 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 21:30 3.50 COMPZ RPCOM OTHR X Fix suction valves in pits 2 and 3. Load pits with 526 bbls of sea water. Gather compnents for BHA#13 (Cement String). 21:30 23:00 1.50 COMPZ RPCOM TRIP X RIH w/BHA#13(Bull Nosed,bent jt cement string)to 722-ft,set down 10k, rotate string 1/2 turn and able to pass by to 1,116-ft. PU to 1,087-ft. 23:00 00:00 1.00 COMPZ RPCOM CIRC X RU to circulate thru cement line. Attempt to circulate while reciprocating, Pumped 145 bbls @ 4 bpm @ 310 psi,fluid level rose to flowline and fell back. Check adjacent well cellars-no fluid. 03/04/2013 Con't to Circ @ 4 bpm @ 310 psi w/57 bbls lost. WO Cementers,mix and pump 8 bbl AS balanced cement plug. POOH to surface,WOC-Tag TOC @ 903-ft. Attempt to Circulate-high losses, POOH to 630-ft and Attempt to circulate-have returns. POOH. PT Line to kill tank and cement line. 00:00 00:30 0.50 COMPZ RPCOM CIRC X Continue to circulate @ 4 bpm @ 310 psi-lost 57 bbls. PU to 1,087-ft and blow down circulation system. 00:30 02:30 2.00 COMPZ RPCOM OTHR X Wait for cementers to arrive 02:30 07:30 5.00 COMPZ CEMEN-CMNT X RU Schlumberger, Held PJSM w/ Nordic,MI,ASRC,SLB. Flood treating lines-frozen line found on rig. Re-route and flood lines, PT at 3,000 psi-Good test. Blend 14.5 ppg Mud push and pump 11 bbls, mix and pump 7.6 bbls of 15.7 ppg AS1 slurry,followed by 5.1 bbls of 14.5 ppg mud push.Cement in place @ 07:10 hrs RD Schlumberger. 07:30 08:00 0.50 COMPZ CEMEN-TRIPX Pooh to 700 ft 08:00 16:00 8.00 COMPZ RPCOM PLUG X wait on cement 16:00 16:30 0.50 COMPZ RPCOM PLUG X RIH tagged TOC at 903 ft. Setdown 15k 16:30 17:00 0.50 COMPZ RPCOM CIRC X Attempt to circulate from 898-ft @ 8 bpm at 400 psi-had no returns w/ 112 bbls pumped. 17:00 17:30 0.50 COMPZ RPCOM TRIP X POOH with drill pipe to 2-7/8 8rd tbg to 635-ft 17:30 19:30 2.00 COMPZ RPCOM CIRC X Install FOSV and head pin. Circulate 492 bbls @ 5 bpm @ 130 psi w/ good returns-total losses to permafrost=29.5 bbls of sea water. 19:30 20:00 0.50 COMPZ RPCOM OWFF X NFT well- Static 20:00 20:30 0.50 COMPZ RPCOM OTHR X Change over floor equipment 20:30 22:00 1.50 COMPZ RPCOM PULD X PJSM, POOH laying down 2-7/8 from 635-ft, break off snozzlator and clean out cement. MU snozzlator for next BHA. Page 11 of 30 • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 COMPZ WELCTL PRTS X Pump 9.6 ppg brine to kill tanks and fluid pack lines. PT at 250/5,000 psi -good test. Blow down lines to kill tank with air. PT cement line at 250/5,000 psi-due to hose removal for thawing ice blockage found during AS1 balance plug at 05:30 hrs on 3-4-13. Blow down cement line with air. 03/05/2013 PU,MU and RIH w/BHA#14, unable to get past 728-ft-attempt to work down-unsuccessful. POOH. RIH w/BHA#15, unable to get past 722-ft. POOH. PU and RIH w/BHA#16 to 752-ft-mill depth 720-ft. Mill down to 751-ft Bull nose depth of 783-ft. 00:00 01:30 1.50 0 0 COMPZ RPCOM OTHR X Change over floor equipment 01:30 02:30 1.00 0 313 COMPZ RPCOM PULD X Attempt to work bull nosed bent jt into wellbore-successful,continue to RIH picking up milling BHA to 313-ft. 02:30 04:30 2.00 313 728 COMPZ RPCOM TRIP X Trip in w/BHA#14 to 722-ft and attempt to work around the corner- Unable to get past 728-ft 04:30 05:30 1.00 728 313 COMPZ RPCOM TRIP X PU 6-ft and seen 5k over pull, continue to POOH to 313-ft 05:30 07:00 1.50 313 0 COMPZ RPCOM PULD X POOH laying down BHA f/313-ft, bull nosed bent joint showed ring at 6-ft from bull nose,recovered formation off of the same 6-ft. 07:00 08:00 1.00 0 0 COMPZ RPCOM OTHR X Bending and slotting 10-ft x 2-7/8 pup joint 3"off center in 4-ft. 08:00 10:30 2.50 0 722 COMPZ RPCOM PULD X PJSM. MU BHA#15. Tag at 716'. Work to 722'-attemt to pull through tight spot. 10:30 11:30 1.00 722 0 COMPZ RPCOM TRIP X PJSM. POOH with BHA#15 from 722' 11:30 12:30 1.00 0 0 COMPZ RPCOM PULD X LD BHA#15. Load MU BHA#16 with modified 2-7/8"EUE Joint with Bend 12:30 16:30 4.00 0 753 COMPZ RPCOM MILL X RIH with BHA#16 and tag up-10k# down at 720'RKB Mill Depth with bottom of BHA at 753'-753'RKB. PU wt 47k#,down 50k#. Rotate at 60-70 rpm,600 ft-lb, pumping 7.6 bpm at 240 psi. Work through—0.5' trouble spot(-1.5 hours)with 1-2k# WOB and 700-900 ft-lbs in and see some metal over the shakers. No fluid losses. Able to dry drift through after working. Page 12 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 00:00 7.50 753 783 COMPZ RPCOM MILL X Fall through,make connection,and wash down to 725 RKB mill depth. Tag up. Pull up, bring on pumps 1.9 bpm at 140 psi and tag again and pressure jumps to 900 psi. Pick up and start rotating at 60-70 rpm and tag down and pressure climbs again. Pull up a stand, RBIH and able to start slow milling again @ 725-ft to 751-ft with 1-2k#WOB and bullnose depth of 783-ft. 03/06/2013 Continue to work mill to 785-ft, POOH to increase mill diameter and found to have lost 28-ft bull nose jt in the hole,cut 4-ft below tool jt. PU and RIH w/5-1/2"OD mill w/3 1/2 IF bull nose bent jt to 750-ft-Not able to make any hole. POOH,Change lengthen bottom of BHA and re-run 5.5"OD mill to 750-ft. POOH, RIH w/ 4-11/16 OS and attempt to recover 2-7/8 TBG stub-no success. RIH w/Bull nose on 3 1/2 DP to 750-ft and change hole over to Fresh water, PU to 717-ft and RU E-Line for video camera run. 00:00 02:30 2.50 753 786 COMPZ RPCOM MILL X Continue to mill from 751-ft mill depth to 753-ft w/bull nose at 785-ft. Circulating at 1.9 bpm at 140 psi and rotating at 60-70 rpm.with 1-2k# WOB. Kick out rotary and PU to 715-ft(mill depth)with no over pull. Slide through tight spot at 722-ft with mill w/5k slack off wt,continue to slide in the hole to 754-ft mill depth, 786-ft bull nose depth and 3 1/2 IF tool joint(5.10"OD)hanging up at 722-ft-set 25k down weight. PU off tight spot at 722-ft and POOH to 724-ft bull nose depth. 02:30 03:30 1.00 724 0 COMPZ RPCOM TRIP X PJSM,POOH from 724-ft to 5-3/16" OD mill cross over sub and 4.10-ft of 2-7/8"TBG stub. Leaving 28-ft of 2-7/8 bent jt in the hole. 03:30 04:30 1.00 0 0 COMPZ RPCOM OTHR XT Gather equipment for BHA#17 04:30 05:00 0.50 0 143 COMPZ RPCOM PULD XT PJSM, PU, MU and RIH w/BHA#17 (5.5"OD String mill w/3-1/2 IF Bull nosed Bent jt)to 142.96 05:00 06:00 1.00 143 750 COMPZ RPCOM TRIP XT RIH w/BHA#17 to 750-ft w/Mill at 717-ft. Gather Parameters, returned coal and formation over the shakers. 06:00 07:30 1.50 750 750 COMPZ RPCOM MILL XT Tag at 7050'RKB at bottom of BHA. Down 50k#, up 47k#(mill at 718' RKB). Mill at 48k#,Circ 3 bpm at 320 psi,rotating 70 rpm. 1-5k# WOB and no progress after 1 hour. 07:30 09:00 1.50 750 0 COMPZ RPCOM TRIP XT PJSM, BDTD, Offload Baker Tools, POOH, LD BHA#17. Noted some rub marks on bottom nose, nothing on mill. 09:00 11:00 2.00 0 750 COMPZ RPCOM MILL XT PJSM, PU, MU and RIH w/BHA#18 (5.5"OD String mill w/15'of 3-1/2 IF DP with 32'- 2-7/8"Bent Joint Below). RIH and tag at 750'RKB at BHA-with mill depth at 701'RKB. Page 13 of 30 Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 11:00 12:00 1.00 750 0 COMPZ RPCOM TRIP XT PJSM, POOH with BHA#18 and LD BHA. 12:00 15:30 3.50 0 0 COMPZ RPCOM OTHR XT Wait on Overshot Drift from BOT. Clean,service,and organize Rig. 15:30 16:00 0.50 0 0 COMPZ RPCOM PULD XT PJSM,MU BHA#19, Bowl 2-7/8" GR Overshot with 4-11/16"OD. 16:00 19:00 3.00 0 750 COMPZ RPCOM TRIP XT RIH with BHA#17 and tag at 750' RKB. Attempt to engage fish, Circulate 72 bbls @ 126 gpm @ 130 psi with no losses. POOH to 694-ft 45k up wt.and BDTD. 19:00 19:30 0.50 694 694 COMPZ RPCOM OWFF XT Monitor well for flow. 19:30 20:30 1.00 694 0 COMPZ RPCOM TRIP XT PJSM, POOH from 694-ft to OS,no fish. Teatr down OS and had no signs of engagement. 20:30 22:00 1.50 0 0 COMPZ RPCOM SFTY XT Re-rack 4-3/4"OD drill collars in derrick to remove pinch points for employees handling tubulars in derrick and on floor. 22:00 23:00 1.00 0 717 COMPZ RPCOM TRIP XT RIH w/3 1/2 Drill pipe w/bull nose to 751-ft. Set down, PU,2-ft and circulate 50 bbls of fresh water to change hole over. POOH to 717-ft for RU of Video log. 23:00 00:00 1.00 717 717 COMPZ EVALWE ELNE XT PJSM, RU E-Line unit 03/07/2013 Continue to RU E-Line and RIH w/1-11/16"OD Video camera to 722-ft. POOH and RIH w/40 ARM caliper to 750-ft, POOH. RD Eline. PU and RIH w/MSC to 718-ft and cut 7"casing 7-ft below CSG Collar at 711-ft. POOH,Spear CSG and PU off slips. ND BOPE. 00:00 02:00 2.00 717 717 COMPZ EVALWE ELNE XT Continue to RU E-Line. 02:00 06:00 4.00 717 717 COMPZ EVALWE SFTY XT Held PJSM with"New"E-Line crew coming on tour. RIH w/Camera to 712-ft ELM. Bring LRS on at.5 bpm @ 200 psi,pump 15 bbls for clarity, drop out of TBG tail and see partial picture increase rate to.75 bpm picture some. Increased to 1 bpm able to see mill marks 717-ft and TBG stub @ 722-ft. Close annular and bull head 32 bbls, unable to go into side track area. FP pump lines w/meth, POOH to surface and standby with E-Line and LRS. Bleed off annular pressure and open annular. 06:00 08:00 2.00 717 717 COMPZ EVALWE ELOG XT PJSM, RD Eline 08:00 08:30 0.50 717 717 COMPZ RPCOM CIRC XT Swap Well to 8.6 ppg SW 08:30 09:00 0.50 717 0 COMPZ RPCOM TRIP XT PJSM, POOH from 717'with BHA #20. 09:00 10:30 1.50 0 0 COMPZ RPCOM OTHR XT Wait on 40-arm Caliper 10:30 12:00 1.50 0 0 COMPZ EVALWE ELOG XT PJSM,MU HES 40-arm Caliper/ CCL. RIH with Eline and log from 750'to surface. 12:00 13:00 1.00 0 0 COMPZ EVALWE ELOG X RD HES Eline Page 14 of 30 Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 13:00 14:30 1.50 0 0 COMPZ RPCOM OTHR XT Process Eline Log,Wait on Plan Forward 14:30 15:30 1.00 0 0 COMPZ RPCOM PULD XT PJSM, Load Tools, MU BHA#21 7" Casing Spear and attempt to pull Casing. Pick up 195k#including Blocks and no pull. 15:30 16:00 0.50 0 0 COMPZ RPCOM PULD XT MU BHA#22 Baker Multi-String Casing Cutter(5.5"OD) 16:00 17:00 1.00 0 718 COMPZ RPCOM TRIP XT RIH with Cutter to 680'. Up 46k#, Down 48k#. 17:00 17:30 0.50 718 718 COMPZ RPCOM CPBO XT Locate Caing Collars at 711'and 672.5'RKB depth and cut 7"Casing at 718'(7'below collar at 711'). Free spin 1100 ft-lbs at 70 rpm, Pumping 2-3 bpm at 200-300 psi. Working 1100-1400 ft-lbs while working through cut. Good cut indication after 16 minutes. 17:30 18:00 0.50 718 718 COMPZ RPCOM OWFF XT Monitor well for flow 18:00 20:30 2.50 718 0 COMPZ RPCOM TRIP XT PJSM. POOH from 718'with BHA #22. 20:30 22:30 2.00 0 0 COMPZ RPCOM OTHR XT Add 1-2"plug valve to OA divertor line, Pump 9.6 ppg brine to kill tank and pressure test @ 250/5,000 psi. Blow down hard line. Offload tubulars not needed and load casing equipment. 22:30 23:30 1.00 0 29 COMPZ RPCOM FISH XT PU BHA#23(7"CSG Spear), Engage csg and Pull for 1-ft @ 55k. 23:30 00:00 0.50 29 29 COMPZ WHDBO NUND XT PJSM, Nipple down BOP at 11"3M casing head 03/08/2013 Continue to ND BOPE and PU Stack. Pull E-Slips. Set BOP down on 11"3M CSG Head and NU. Flood test BOP stack. RU Casing Equipment. POOH laying down 7",26#,J-55 BTC casing. Wash BOP and install test plug. Open doors and inspect Ram cavities. Conduct weekly BOPE test @ 250/3,000 psi with 2-7/8, 3-1/2,and 7"Test joints. Annular element failed -change out element and piston seals. 00:00 03:30 3.50 29 29 COMPZ WHDBO HOSO XT Continue to ND and pull 11"x 7" E-slips. RU GBR Casing equipment. 03:30 06:00 2.50 718 0 COMPZ RPCOM PULL XT PJSM, POOH w/Casing from 718-ft, lay down spear and 16.23-ft cut landing jt. Continue to POOH laying down 17-7"casing joints,7.23-ft of cut stub. 06:00 07:30 1.50 0 0 COMPZ RPCOM PULD XT PJSM,Offload 7"Casing,Offload GBR Equipment,Clean and Clear Floor 07:30 09:00 1.50 0 0 COMPZ WHDBO BOPE XT PJSM,Wash out BOP Stack, Grease Valves,Set Test Plug and RU to test. 09:00 15:30 6.50 0 0 COMPZ WHDBO BOPE XT PJSM,Test BOPE 250/3000 psi. Notice was given to AOGCC for weekly BOP Test @ 02:30 hrs on 3-8-13, Right to witness was waived by Lou Grimaldi @ 7:39 hrs on 3-8-13. Page 15 of 30 • Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T Comment 15:30 00:00 8.50 0 0 COMPZ WHDBO BOPE XT Held PJSM on removing Cap on 11" 5M GKA Hydril annular and replacing annular element. RU and remove cap. Pull element(not in bad shape -small tears in 2 places-pictures in well file)and piston seal rings. Re-install cap, rough make-up, remove and dress threads. Utilize Crew to loaded 8--6-1/4"OD XH Drill collars, Rotary shoe,9-5/8" Casing scraper,6-1/4"OD Bumper sub and fishing jars for warm up. 03/09/2013 Continue to Change out element and piston seals. Finish conducting weekly BOPE test. 00:00 06:00 6.00 0 0 COMPZ WHDBO BOPE XT Continue to change out element(not in bad shape-small tears in 2 places-pictures in well file)and piston seal rings. Re-install cap, rough make-up, remove and dress threads. This element was in place since 11-5-12 Utilize Crew to loaded Rotary shoe, 9-5/8"Casing scraper,6-1/4"OD Bumper sub and fishing jars for warm up. RU 1,500 Folley Tongs. 06:00 09:30 3.50 0 0 COMPZ WHDBO BOPE XT Begin testing-3-1/2 EUE 8rd FOSV. Complete BOPE Test. Drawdown Test. System pressure:2900 psi, after close 1900 psi. 200 psi attain- 16 sec. Pressure up to system pressure 86 sec. 4 Nitrogen bottle average 2000 psi. note:3-1/2 EUE 8rd FOSV was torn down and cleaned up and re-tested. 09:30 12:00 2.50 0 0 COMPZ RPCOM PULD XT RD Test Equipment, Prep to run BHA#24,Changeout Floor Equipment 12:00 13:00 1.00 0 0 COMPZ RPCOM CIRC XT PJSM. MU BHA#24, 9-5/8"Casing Scraper. 13:00 15:00 2.00 0 716 COMPZ RPCOM TRIP XT RIH to 716'RKB. Up 62k#, Down 63k#. No issues with scraper. Slight overpull off bottom. 15:00 15:30 0.50 716 716 COMPZ RPCOM CIRC XT Circulate 2 bottoms up until clean at 5 bpm-80 psi. Monitor well,static. BDTD. 15:30 16:30 1.00 716 0 COMPZ RPCOM TRIP XT PJSM. POOH with BHA#24 and LD Casing Scraper 16:30 21:00 4.50 0 0 COMPZ RPCOM OTHR XT PJSM. Load, Rack,Tally and Drift 7"casing 21:00 21:15 0.25 0 0 COMPZ RPCOM SFTY XT Held PJSM on RU of casing tongs, preparation for running in hole w/ Wash over shoe and 7"casing li Page 16 of 30 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:15 00:00 2.75 0 653 COMPZ RPCOM PUTB XT PU 1jt of 8-1/8"Baker TSWP amd MU 8.5"OD x 6.25"ID Rotary Shoe. RIH,Change over equipment. Start RIH w/7",26#,TC-Il Casing to joint #15 653-ft. 52k Dn,53k Up. 03/10/2013 Con't to RIH w/BHA 24,tag up and gather parameters. Begin milling with light wt. Mill frrom 715-ft to 718.5-ft. Located 7"csg stub at 718-ft. 00:00 01:30 1.50 653 715 COMPZ RPCOM PUTB XT Continue to PU and RIH w/BHA#24 (1jt of 8-1/8"Baker TSWP amd MU 8.5"OD x 6.25"ID Rotary Shoe) from 653-ft.to 695-ft. Mouse jt#17 and MU to Top Drive, PU and screw into stump. RIH and tag up with 5k SO wt.at 715-ft-18-ft in with 55k Dn,55k Up. 01:30 12:00 10.50 715 716 COMPZ RPCOM MILL XT Gather Parameters: Circulate at 244 gpm @ 77 psi, ROT wt @ 53K with 800 ft/lbs free torque. SPR: Pump 1 @ 16 spm @ 68 psi, 43 spm @ 70 psi/Pump 2 @ 22 spm @ 69 psi,43 spm @ 70 psi Begin milling at 715-ft w/500 lbs WOM,Circulating @ 6bpm @ 74 psi at 70 rpms.53k#up,53k#down. 12:00 16:00 4.00 716 716 COMPZ RPCOM MILL XT Contiue milling ahead from 715.72 at 70 rpm with 300-900 ft-lbs of torque. WOB 500#pumping at 6 bpm at 80 psi. 16:00 21:00 5.00 716 718 COMPZ RPCOM MILL XT Drop through from 716.34'to 716.8 and progress down with same parameters to 718' 21:00 00:00 3.00 718 719 COMPZ RPCOM MILL XT Milling on the 7"casing stub from 718-ft to 718.5-ft 03/11/2013 Continue to mill from 718.5 to 720-ft, RU for camera run,(found"S"pipe design for Top Drive entry needs to be reconfigured). RIH w/camera with out the ability to move pipe in sequence with camera rigged up. RIH and evaluated milling results,showed to have cut window in 9-5/8 and slabbing 7". RD E-Line and continue to mill to 725-ft. 00:00 02:00 2.00 719 719 COMPZ RPCOM MILL XT Continue to mill on 7"Casing stub from 718.5-ft to 719.0-FT 02:00 06:30 4.50 719 720 COMPZ RPCOM MILL XT Continue to mill on 7"Casing stub from 719-ft to 720-FT 06:30 06:45 0.25 720 719 COMPZ RPCOM TRIP XT Pull up 1-ft to 719-ft and prepare for eline video log 06:45 14:30 7.75 719 719 COMPZ RPCOM ELOG XT Entended PJSM. Attempt to rig up entry sub on top of top drive. Top Drive Compensator Bushings had to be loosened and moved to remove Gooseneck 10-02 cap. Once removed, unable to connect S Pipe due position of cowscock.Make 10-02 cap back up and rig up conventionally. Determined S Pipe needs to be reconfigured. 14:30 19:00 4.50 719 719 COMPZ RPCOM ELNE XT PJSM. Re-rig Sheeve. Rig up HES Pump-in-sub and Duel Packoff on top of DP pup. Page 17 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 22:00 3.00 719 719 COMPZ RPCOM ELNE XT Start Circulating 175 bbls of Fresh Water @ 5 bpm @ 70 psi. Run video log and seen 2 sections of slabbed casing inside wash pipe, indications are that we remove hard dogleg bend as intended. POOH and RD E-line unit. 22:00 00:00 2.00 715 719 COMPZ RPCOM MILL XT Screw in w/Top Drive to 3 1/2 IF pup jt on milling assy. PU to 715-ft, Change hole over to milling fluid and set parameters. Begin rotating back down to 719-ft setdown in 3 points at various depths working shoe back down to 719-ft 03/12/2013 Continue to mill down to 721', POOH for BHA/Mill inspection. P/U new milling assembly, RIH and tagged up early @ 716'.Continue milling down to 725.Circulate well over to filtered fresh water for downhole video run. 00:00 08:00 8.00 719 720 COMPZ RPCOM MILL XT Continue to mill down to 719-ft to 725-ft w/500 lbs WOM,Circulating @ 254 gpm @ 80 psi,while rotating @ 70 rpm's w/800 ft/lbs free torque. Slight metal returns over shakers. 08:00 09:30 1.50 720 721 COMPZ RPCOM MILL XT Torque starts slowly falling off and ROP dropping off. Pick up a foot and try again. ROP down,discuss with town and POOH to check BHA. 09:30 10:00 0.50 721 721 COMPZ RPCOM OTHR XT RU Casing Tongs and Blow Down Top Drive. 10:00 13:00 3.00 721 0 COMPZ RPCOM TRIP XT RD XO pup Joint, PJSM, POOH Laying Down 7"Casing. 13:00 14:00 1.00 0 0 COMPZ RPCOM PULD XT On Surface. Changeout Rotary Mill. Not much wear noted and pictures in Rig Folder. MU New Mill. 14:00 19:30 5.50 0 722 COMPZ RPCOM MILL XT RIH with BHA#25 8-5/8"x6-5/8"ID Rough OD Burn Shoe. Lose ground and start milling at 716.5'. Increase Torque 1500-2000 ft-lb and WOB to 3000-5000# 19:30 22:30 3.00 722 725 COMPZ RPCOM MILL XT Begin losing string weight and torque,Continue time milling, Returns had light shale for 1.5ft, scale and light metal fillings.Call out water and Eline for camera run. Continue time milling-6 bpm,80 psi,WOB 2-3K,800-1000 torque. 1:1 returns-scale and light metal shavings. Stall @ 724.8'-No overpull during P/U 55K up to 723' 22:30 00:00 1.50 725 725 COMPZ RPCOM MILL XT Work string back down to 725'with light motor work.TD reached, circulate fresh water around starting at 2 bpm,working up to 5 bpm. 03/13/2013 R/U Eline and ran multiple camera runs while moving the work string to different depths to try and identify DH conditions.Assess the DHV runs,decision made to mill ahead additional 3-5ft. R/D Eline and mill ahead @ 1 FPH. Page 18 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 725 725 COMPZ RPCOM ELOG XT PJSM-R/U E-line with Side entry sub and Down hole Video Log. RIH to 680'. 03:00 08:00 5.00 725 725 COMPZ RPCOM ELOG XT Tighten&grease pack off sub on side entry sub.Start pumping fresh water @ 2bpm, increase to 4 bpm. Pump 120 bbls, DHV getting clearer, start logging. Good image of piece of metal chunk up inside the burn over shoe @ 719'. P/U on string 5'- P/U weight 58K. Log back down with DHV to max depth of 721'. Good image of damaged/milled metal debris. P/U on string additional 15ft and log down again. Log from 706-717'. Video shows two distict hole sections at 714'Video depth. (**"Note'-All eline depths are referenced to Nordic 3 RKB,so 4' needs to be added to match Nordic 3 depths corrected back to ORKB) 08:00 12:00 4.00 725 725 COMPZ RPCOM OTHR XT Video Logs posted and reviewed with town wells group and plan formulated to fish piece of slabbed casing. 12:00 13:30 1.50 725 725 COMPZ RPCOM PULD XT PJSM. Load,tally and strap 7"pups for spaceout. 13:30 15:30 2.00 725 724 COMPZ RPCOM ELOG XT PJSM. RIH with current mill string BHA#25 and take video,prior to spacing out 7"casing,to determine how slab would re-enter mill assembly. Make it down to 724.5' with BHA#25 without working very hard or rotating. Start pumping fresh water down mill string at 3 bpm at 100 psi and take video. Find slabbed casing balled up in bottom of mill assembly. Attempt to RIH another 0.5'while watching on video, stacking addition 10k. Not much change. Pull up 1'and take video, pull up 2'and video,and 3'and video. These videos showing cut slab of casing balled up and section of casing it appears to be slabbed from. Pull up 6'with mill assembly and log out of shoe. This showed some spiraling and what looks to be a cut window. RBIH to 724'and bullhead some fluid to see flow path. BDTD. Video logs posted in well folder. 15:30 18:30 3.00 724 724 COMPZ RPCOM OTHR XT Video Logs posted and reviewed with town. Page 19 of 30 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 18:30 21:15 2.75 724 724 COMPZ RPCOM CIRC XT Set up the rig floor for handling 7" pup.Well out of balance with Fresh &Sea water.Circulate well over to milling fluid. Lost 8 bbls to formation during fluid swap.Well balanced with milling fluid, no flow check. Make up 7"pup. 21:15 23:15 2.00 724 726 COMPZ RPCOM MILL XT P/U to 723', P/U weight 58K-set free spin parameters.6 bpm @ 105 psi, 1500 free spin @ 70 rpm.Wash down to 724.50'. Begin milling-6 bpm @ 110 psi, WOB 1-2K, 1500-1750 @ 70 rpm, 54K string weight,milling roughly 1 FPH.Good metal debris/chunks coming back for the first foot then frac/sand beads,clay formation returns in second foot with light metal shavings.90%formation 10% metal. 726.68'-hard stall 5200 torque-P/U weight 56K. 23:15 00:00 0.75 726 726 COMPZ RPCOM MILL XT Mill down slowly-Started taking weight 726.24'.6 bpm,90 psi,70 rpm, 1300#/ft torque,WOB 1-2K, string weight 55K,milling 1 FPH. Returns look like 60%clay, 30% metal shavings.Call town to discuss. Plan to mill additional 1ft-camera run if samples don't improve. 03/14/2013 Continue with DHV logs.Clear indication of the previous sidetrack @ 718'HS out the 9 5/8"then rolling over to lowside,shaving the 9 5/8"casing down to a depth of 725'.TOOH sideways with 7"milling assembly.Jet BOPE stack and prepare for weekly BOPE test. 00:00 01:00 1.00 726 728 COMPZ RPCOM MILL XT Continue milling down to 727.80'. No improvements on samples,mostly light clay/sand mix with trace metal shavings. 01:00 03:00 2.00 728 728 COMPZ RPCOM CIRC XT Rig down 7"Pup and circulate well over to filtered water. 03:00 05:00 2.00 728 728 COMPZ RPCOM ELOG XT PJSM-R/U ELINE for DHV log. 05:00 13:00 8.00 728 708 COMPZ RPCOM ELOG XT Start logging DHV. Pick up mill 5', 10', 15',and 20'and log HES Downhole Video at each interval. Pumping Freshwater at 3 bpm at 80 psi. Logs posted to Nordic 3 rig folder. Blow down top drive and wait on orders. 13:00 15:00 2.00 708 708 COMPZ RPCOM ELOG XT PJSM. Rig Down HES eline. Prepare to Trip 7"Casing 15:00 16:00 1.00 708 708 COMPZ RPCOM CIRC XT Circulate well over to Milling Fluid. Lost 14 bbls during fluid swap. 16:00 19:00 3.00 708 37 COMPZ RPCOM TRIP XT PJSM.Start pulling out of hole laying down 7". LD BHA#25 19:00 21:30 2.50 37 0 COMPZ RPCOM PULD XT PJSM-Lay Down BHA#26-clear rig floor and remove BHA from rig. 21:30 22:30 1.00 0 0 COMPZ WHDBO CIRC XT Jet&flush BOPE stack. Page 20 of 30 Time Logs Date From To Dur S.Death E. Death Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 COMPZ WHDBO MPSP XT Run in test plug. Fill stack,test plug leaking by. Pull test plug. 03/15/2013 Complete BOPE test 250/3000 psi.Make up and RIH with 7"string with 8.5"Sodscallop Shoe down to 718'. R/U Eline for final camera run,good images of milled casing for proper space out/milling.Mix up new Milling mud. 00:00 01:30 1.50 0 0 COMPZ WHDBO MPSP XT Inspect test plug,wrong size. Locate correct test plug and install. 01:30 02:30 1.00 0 0 COMPZ WHDBO BOPE XT Fill stack and test plug.Surface valve leaking on test pump, repair. 02:30 07:30 5.00 0 0 COMPZ WHDBO BOPE XT Start BOPE test 250/3000 psi. State test waived witnessed by Jeff Jones. 07:30 08:30 1.00 0 0 COMPZ RPCOM PULD XT PJSM with GBR and Baker. RU Casing Tongs and Floor Equipment 08:30 10:00 1.50 0 693 COMPZ RPCOM TRIP XT RIH with 7"Casing on BHA#27 to 693 10:00 10:30 0.50 693 693 COMPZ RPCOM PULD XT Kick out Baker Tools 10:30 13:00 2.50 693 693 COMPZ RPCOM OTHR XT Confering with Town Engineer 13:00 14:00 1.00 693 693 COMPZ RPCOM PULD XT RD Casing Tongs and RU Floor Equipment 14:00 16:00 2.00 693 693 COMPZ RPCOM ELOG XT PJSM with HES Eline. RU 15'and 6' DP Pups on stump. RU Eline. 16:00 18:00 2.00 693 718 COMPZ RPCOM ELOG XT RIH with HES Video to Baker Shoe depth at 714'. Start pumping clean Fresh Water at 3 bpm at 70 psi. Once clean start moving pipe and logging video. Stop pipe at 718'and log out of Shoe. Obtain clear video of planned drill out point. Video posted in well log folder on s drive. 18:00 20:00 2.00 718 718 COMPZ RPCOM ELOG XT POOH and RD Eline 20:00 00:00 4.00 718 718 COMPZ RPCOM CIRC XT Mix up new Milling fluid prior to swapping over well.Mi Engineer recommended mud swap.Continue rigging up MWD shack and equipment. 03/16/2013 NDBOP's,set 7"casing to a set depth of 718'. NUBOP's,test 250/3000psi. P/U BHA#28 with 6"Mill, 1.5 degree bent motor and MWD tools. Prior to milling on bottom MWD tool failed. POOH for BHA change. 00:00 02:00 2.00 718 718 COMPZ RPCOM CIRC XT Complete mixing up new mud,circ out fresh water with new mud.Total losses of 13 bbls.30 minute static test. 02:00 09:30 7.50 718 718 COMPZ RPCOM NUND XT PJSM-Begin ND BOP stack. 7"Casing in position of previous camera run. Set slips and hang 7" casing.Cut 2.99'of joint number 16. 09:30 11:30 2.00 0 0 COMPZ RPCOM PULD XT PJSM for picking up RBP. MU plug BHA, RIH&set @ 50'. 11:30 12:00 0.50 0 0 COMPZ RPCOM BOPE XT RU for shell test.Test 250/3000 psi &charted. Good test. 12:00 12:30 0.50 0 0 COMPZ RPCOM TRIP XT RIH, retrieve RBP @ 50'. 12:30 13:00 0.50 0 0 COMPZ RPCOM PULD XT PJSM, Lay down RBP. Page 21 of 30 • Time Logs Date From To Dur S.Death E.Depth Phase Code Subcode T Comment 13:00 16:00 3.00 0 195 COMPZ RPCOM PULD XT PJSM,pick up milling BHA#28. Round Nose Mill with Sperry Sun Tools 16:00 18:00 2.00 195 698 COMPZ RPCOM TRIP XT TIH while scribing HS 18:00 20:00 2.00 698 720 COMPZ RPCOM TRIP XT Crew change-pick up pump rates to 5 bpm while working string to test MWD tools. Not getting a consistant reading or pulse. Bring down pumps and start dry tagging to check orientation while MWD troubleshoot surface equipment. Lightly stacking while rolling pump @ 1 bpm. Saw light pressure increases: 718'-HS-scribe only no MWD. 724.7'-LOHS 724.23-ROHS 20:00 21:00 1.00 720 195 COMPZ RPCOM TRIP XT Decision made to TOOH to swap out MWD tools. 21:00 23:00 2.00 195 0 COMPZ RPCOM PULD XT PJSM for laying down BHA. Break off Bit,lay down internal components of MWD tool. Replace and re-test BHA without mill. Pump 5 bpm @ 400 psi using pump#2. Low reading,might be due to low surface pressure. Modify pressure sensor equipment with successful test. 23:00 00:00 1.00 0 195 COMPZ RPCOM PULD XT P/U BHA#29 03/17/2013 Milled from 718'down to 722', 30 degrees ROHS rolling to HS. POOH and installed BHA#30 with a 6 1/8" string mill, bent sub and mule shoe. RIH,no luck entering, R/U DHV. 00:00 01:30 1.50 195 710 COMPZ RPCOM TRIP XT TIH while scribing HS orientation. 01:30 03:00 1.50 710 718 COMPZ RPCOM MILL XT Start pumping,Good indication from MWD tool. Bring pumps down to locate top of damaged casing @ lbpm(dry tag). 10 ROHS-tagged 725'-P/U 12 LOHS-Tagged 726' 24 LOHS-tagged 726' 30 ROHS-tagged 718'-found top of damaged casing. P/U to start milling. 03:00 05:30 2.50 718 720 COMPZ RPCOM MILL XT Start milling-free spin 6 bpm @ 680 psi, 53K weight 30 ROHS 718'-Milling 1 FPH,6 bpm @ 810 psi,72 RPM,WOB 2-3K,50K string weight.30 ROHS.Metal shavings with light formation in samples. 719'-Milling 1 FPH,6 bpm,@ 790 psi,72 RPM,WOB 2K,50-51 K String weight-30 ROHS,Metal shavings with light formation/cement. 720'-Stop pumping try to drift down and tagged @ 724'-P/U to 719' Reactive torque moved us to straight HS. Page 22 of 30 Time Logs Date From To Dur S. Death E. D-.th Phase Code Subcode T Comment 05:30 09:00 3.50 720 720 COMPZ RPCOM MILL XT Start milling HS @ 719'. Continue milling again down to 722',with diminishing work. Very little metal over shakers and decide to POOH and log video. 09:00 10:00 1.00 720 720 COMPZ RPCOM PULD XT Load Dutch Riser and discuss options with town. Plan on running Bent DP BHA and log video through BHA to orient. 10:00 12:00 2.00 720 720 COMPZ RPCOM PULD XT PJSM w/Baker and RD BHA#29. POOH and LD 12:00 13:00 1.00 720 720 COMPZ RPCOM PULD XT Prepare to make up BHA#30 with Mule shoe, Bent DP with String Mills. 13:00 15:30 2.50 720 720 COMPZ RPCOM ELOG XT PJSM with Baker. MU BHA#30 and RIH to 717' 15:30 17:00 1.50 720 720 COMPZ RPCOM ELOG XT PJSM with HES. RU Downhole Video through Side Door Entry Sub. 17:00 22:30 5.50 720 720 COMPZ RPCOM ELOG XT RIH to 700'with Eline and circulate clean Freshwater down DP at 3 bopm at 80 psi until clean. RIH with DP BHA#30 to tag at 728'and circulate clean FW taking returns. Pull DP back into 7"Shoe,start Bullheading fluid and run Video log out to tag. Able to get picture of mill work done on previous run but very murky picture.Try to clean up OH section,ordered additional water truck.Cannot see bottom of mule shoe for orientation. 22:30 23:30 1.00 720 720 COMPZ RPCOM ELOG XT Blow down top drive,wait on fresh water truck. 23:30 00:00 0.50 720 720 COMPZ RPCOM'ELOG XT Hook up truck,prepare to start pumping. 03/18/2013 Ran DHV logs,video indicated first milling run was unsuccessfull. POOH for BHA change. P/U and start milling with a 2.2 AKO motor&5 7/8"Bell mill. Light to no motor work detected, POOH for BHA change. P/U 3.0 AKO motor with same milling assembly.Good indication of motor and begin milling from 718'down to 721'. 00:00 01:30 1.50 720 720 COMPZ RPCOM ELNE XT Log OH section with DHV. Murky video but better than earlier. Shows no sign of prior milling work.Cannot see through bottom of mule shoe, too murky, need to pull BHA up into 7"to get a decent DHV log. 01:30 03:00 1.50 720 720 COMPZ RPCOM ELOG XT RD Eline 03:00 04:30 1.50 720 720 COMPZ RPCOM TRIP XT Try to locate damaged 7"with Mule shoe and milling string. No luck with multiple attempts. 04:30 06:30 2.00 720 720 COMPZ RPCOM TRIP XT PJSM,Swap out to milling fluid, POOH with Eline from 728'. LD BHA 06:30 10:00 3.50 720 720 COMPZ RPCOM OTHR XT Wait on Order and Montior Well on Trip Tank Page 23 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T ` Comment 10:00 12:45 2.75 720 720 COMPZ RPCOM MILL XT PJSM with Sperry and BOT. MU BHA#31,Set Motor angle at 2.12 deg. Orient DD direction on floor and RIH to 718'scribing in the hole. Up 55k,down 54k#. Strokes per minuter 200,GPM 220,presure 700 psi. Pulse test MWD and orient hoigh side. 12:45 14:00 1.25 720 720 COMPZ RPCOM MILL XT Correct MWD. Start working at 718' at 235 gpm at 775-800 psi. Not getting much WOB,but feels like metal on bit. Continue RIH to 725' and stack down 3-5k#WOB with pump pressure up to 900 psi. To 728.5'at 100 deg R solid set down 10k#. 14:00 16:00 2.00 720 720 COMPZ RPCOM MILL XT Pull up to 715'and try and orient to 0 degrees and try again back to 728'. Same action. Pull up again and try to slide with pumps off. Saw bobble at 720'and continue to slide in hole. Set down 12k#at 729'. Pull up and try multiple angle's with the pumpd off. -180 deg,45 right,45 left,20 left. Still in rathole. Discuss with town. 16:00 17:30 1.50 720 720 COMPZ RPCOM TRIP XT TOOH and to change motor angle to 3 deg.Mill had indication of metal work,OD guage on tapered part down to 5-5/8"with inside wear on the cup. 17:30 19:30 2.00 720 720 COMPZ RPCOM TRIP XT P/U BHA with 3.0 AKO, Bell Milled guage 5-5/8". Pad to center 6.25" had to lightly push first 30ft of BHA down into 7".Continue to scribe and TIH. 19:30 00:00 4.50 720 720 COMPZ RPCOM MILL XT Tag Top of damaged 7"@ 717.5'HS -P/U and drift to TD. P/U and set milling parameters. Free spin-5.5 bpm,780 psi, 10 degrees ROHS, string weight 50K. Begin milling from 717.5'-5.7 bpm, 900-1050 psi,WOB 2-3K,good motor work, 10 ROHS. Continue milling down 3 ft..Motor work started to fall off.Stop pumps and drift down to TD to ensure we didn't side track. Hard Tagged @ 725', P/U and drift again to TD 728'.Set down 5-8K. P/U and begin milling from 720'. 03/19/2013 Continue milling with new 5 7/8"bell mill&3.0 AKO motor down to 726'. Dry tag down to 728', POOH for BHA inspection. R/U Eline for DHV logs.Good indication of milling runs down to 720'.Murky video below that. ,Work mule shoe string down to 731'. R/U DHV log. 00:00 01:00 1.00 720 720 COMPZ RPCOM MILL XT Continue to try and mill from 720.5', made roughly 1/2 ft in past 2 hours due to falling off the top of fish or worn bit. Page 24 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 03:30 2.50 720 720 COMPZ RPCOM TRIP XT POOH from 721.7'for bit change. Inspect BHA at surface and found mill worn down.Concave section of mill rung out,outer mill guage roughly 5 1/2"OD. Install new mill and TIH. 03:30 11:30 8.00 720 729 COMPZ RPCOM MILL XT Start milling from 720.5'-5.5 bpm, 980 psi,WOB 3-4 K, String weight 52K. Milling 1 FPH. Good motor work.Mill string jumps off&wants to work down the pipe along the outside. P/U and time mill from 723 ft with 3-4K on mill able to set down 10k @ 726'. able to rotate off and drop down to 729 FT with soild tag as well. 11:30 13:00 1.50 729 720 COMPZ RPCOM CIRC XT turn hole over to fresh water 260 BBLS 13:00 14:30 1.50 720 0 COMPZ RPCOM TRIP XT POOH with BHA#33 14:30 16:00 1.50 0 720 COMPZ RPCOM TRIP XT RIH with bit sub and drill pipe to 708 ft. BHA#34 16:00 20:00 4.00 720 720 COMPZ RPCOM ELNE XT PJSM&RU HES Eline to DHV while pumping fresh water. @ 1/2-3 BPM bull heading. Good clean video down to 720', murky view beyond that point. Rig down&stand by E-line 20:00 22:30 2.50 720 731 COMPZ RPCOM TRIP XT Work Mule shoe into Cased hole/OH section.Tagged @ 726'--rolled into Cased hole possibly,worked string down to 730'. Lots of fill&40/20 sand rolling over the skakers. Continue to makehole while pumping 5 bpm,. 22:30 00:00 1.50 731 731 COMPZ RPCOM ELOG XT Space out with Pups in order to cycle pipe with Eline, R/U eline for DHV logs. 03/20/2013 Continue with DHV logs from 727'up to 719'. POOH for BHA#35 with 3.0 AKO and new 5 7/8"Bell Mill.Mill down to 728', POOH for BHA#36. 00:00 05:00 5.00 731 731 COMPZ RPCOM ELOG XT DH video log from 727',725',723, 721'-Good clear DHV of milling progress. DHV log indicates good solid ledge at 726'. 05:00 07:00 2.00 731 720 COMPZ RPCOM FLOG XT RD Eline. 07:00 08:30 1.50 720 720 COMPZ RPCOM CIRC XT turned hole over to vis.sea water for milling operations with 180 bbls to good vis. Pull two stands,circ well again.Good Static. 08:30 11:00 2.50 0 724 COMPZ RPCOM TRIP XT PJSM make up 5 7/8"bell mill with 2 degree MWD motor RIH( BHA 35) tagged @ 724+ft 11:00 17:30 6.50 724 728 COMPZ RPCOM MILL XT oriented mill on @ 724+ft continue milling operations to 728 ft. attempted to slide mill into 7"casing stub with out success. Got back old KWM stringers to surface. Page 25 of 30 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:00 2.50 725 710 COMPZ RPCOM CIRC XT circulate hole clean with 90 bbls @ 5 BPM, gained 5 bbls,- flow check- circ B/U 2 bpm @ 190 psi.Gained 1/2 bbl. in 30 minutes no flow. 20:00 22:30 2.50 710 0 COMPZ RPCOM TRIP XT Circ B/U @ 2bpm-Shut in,zero pressure, No Flow. POOH.Check on second stand.Good- Continue to POOH 22:30 00:00 1.50 0 0 COMPZ RPCOM PULD XT Lay down BHA#36&P/U BHA#37 03/21/2013 P/U BHA#36 with 5 1/4"Bullnose mill and bent sub.Tried to re-entry 7",jetted down to 744', possible OH jetting. Pull BHA 36, run BHA 37,38&39'with no luck. R/U DHV log. 00:00 00:30 0.50 255 720 COMPZ RPCOM TRIP XT TIH 00:30 02:30 2.00 720 728 COMPZ RPCOM TRIP XT Start working the pipe in entry area. Min.pump rate,set down @ 725, then 728', move down to 730'tag. P/U and try multiple times. Feel we have entered the 7" by staying HS @ 725'and rolling 15 degrees to ROHS as lowering BHA. Increase pumps to 5 bpm. 100%sand rolling over the shakers, no formation. 02:30 04:00 1.50 728 744 COMPZ RPCOM MILL XT Work pipe down to 735 with no rotation,stacking 8K weight then getting weight back to zero pumping 5 bpm. 100%sand across the shakers.Slowly roll pipe @ 5 rpm. No shale or clay,Wiper up to 731' every 5ft. 04:00 05:00 1.00 744 720 COMPZ RPCOM MILL XT Started to get scale or coal chunks over the shakers.80%sand, no shale or clay formation. P/U to 720'. Rotate 180 degrees of HS and tag at 730'then slid down to 744'.Might have stayed in the OH, POOH to inspect/change BHA. 05:00 07:30 2.50 720 COMPZ RPCOM CIRC XT P/U one stand. Blow down top drive. Flow check, circ B/U-well annulas wanting to flow continue to circulate well 4 hloe volumes.monitor well for 30 minws 07:30 08:30 1.00 COMPZ RPCOM TRIP XT pooh with BHA 36 08:30 09:30 1.00 COMPZ RPCOM TRIP XT Rih with BHA#37 09:30 13:30 4.00 COMPZ RPCOM MILL XT attempt to work in 5 1/4"bull nose mill into 7"stump.tag depth with mill @ 730.5 ft and 732 ft with 10Kon mill. 13:30 14:30 1.00 COMPZ RPCOM TRIP XT POOH with BHA#37 14:30 18:30 4.00 COMPZ RPCOM TRIP XT RIH with BHA#38 mule shoe 2 degree bent 3.5 IF jt,5 3/8"string mill.atempted to work in 7"csg. stump @ 728.with out success worked down along side of stump to 736 ft while circulating @ 5 BPM. Page 26 of 30 • I _ Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:30 21:00 2.50 COMPZ RPCOM TRIP XT POOH&P/U BHA#39. 21:00 23:00 2.00 COMPZ RPCOM TRIP XT Start tagging up @ 725',turning HS and finding the OH section we hit last night.Just pumping we started to get 100%sand back again. RIH 745'total depth,feels like off section. P/U and space out for camera run.Static test no flow. 23:00 00:00 1.00 COMPZ RPCOM ELOG XT PJSM-R/U Eline. 03/22/2013 Ran DHV,could not get a clear DH picture pumping fresh water, pumped total of 350 bbls of water. R/D Eline -Pipe pulled Heavy While POOH from 725'-Sand/Fill fell in around BHA.Worked pipe free up to 560'. POOH.Set RBP perform a weekly BOPE test 250/3000 psi.Witnessed by Jeff Turkington. 00:00 04:00 4.00 720 714 COMPZ RPCOM ELOG XT Try to DHV log from 735'-circ 2 X B/U with fresh water, no luck on video outside the DS,clean fluid to surface, Bullhead 60 bbls. P/U DS to 719'-try again,clean returns to surface.-murky video outside the DS. P/U to 714'.Try again with same rates,clean returns,very fuzzy video, well fluids not cleaning up downhole. 04:00 07:00 3.00 714 720 COMPZ RPCOM ELOG XT R/D Eline,flow check prior to POOH. 07:00 12:18 5.30 720 COMPZ RPCOM TRIP XT began trip out of hole with BHA 39 pulling 20 K over attemted to circulate well.pressured up to 2000 psi. rotated pipe up pulling free with 5 K over and 1500 on tourge. pulled out of fill at 565 ft.still unable to circulate. pooh. BHA pluged from jars down. cleared sand from BHA. 12:18 13:18 1.00 COMPZ RPCOM CIRC XT PJSM RIH to 295 ft turned hole over to VIS sea water 24 BBLS. 13:18 14:18 1.00 COMPZ RPCOM TRIP XT POOH with drill pipe and rinsed out BOP. 14:18 15:18 1.00 COMPZ RPCOM PACK XT PJSM made up 7"RBP RIH to 110 ft Center of element set plug and tested to 500 psi for 5 min. POOH. 15:18 22:30 7.20 COMPZ RPCOM BOPE XT Begin BOPE test 250 low,3000 psi high.State test witnessed by Jeff Turkington. 22:30 00:00 1.50 COMPZ RPCOM BOPE XT RIH and pull RBP. 03/23/2013 RIH down to 730',try to re-enter 7"milled string with no luck.Sand returns to surface from 680'. POOH, Backload tools, ND BOP's, remove emergency slips&pack offs, ND BOP's. 00:00 02:30 2.50 0 212 COMPZ RPCOM PULD XT PJSM P/U BHA#39 with 2 7/8 mule shoe bent joint,string mill,jars& circ sub.TIH 02:30 03:15 0.75 212 680 COMPZ RPCOM FCO XT Found top of sand @ 680'-start cleaning down to 718', circ 2X B/U, sand returns over shakers. Page 27 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:15 07:15 4.00 680 730 COMPZ RPCOM CIRC XT Begin to work string and make attempts to re-enter milled casing while pumping 5.5 bpm of new milling fluid,pump pressure 180 psi.OH cleaning up,making multiple attempts,most tags occuring @ 730' &735'. Lower pump rate to 2.5-3.0 bpm.Good tag @ 728'.Continue trying. Unsuccessful in getting into 7"CSG.stump @ 728 ft. 07:15 08:00 0.75 730 COMPZ RPCOM TRIP XT POOH wit 5 3/4"sting mill and 2 7/8" 8rd bent jt. 08:00 13:30 5.50 COMPZ RPCOM OTHR XT Standby wait on orders for next step. 13:30 18:30 5.00 COMPZ PLUG TRIP XT RIH and lay down DC's, Pac 2 7/8 tubing, load out BOT tools,MWD motor. Prep rig floor for pulling 7" casing. 18:30 23:00 4.50 COMPZ PLUG PULL XT ND BOPE stack,spear 7"casing, P/U weight 62K-pull up 30ft to remove emergency slips, weight drag increased to 77K. Slips removed, ND BOP's and rig up casing handling equipment. 23:00 00:00 1.00 COMPZ PLUG PULL XT PJSM-begin pulling 7"casing. 03/24/2013 Pull 7"casing show from 720', Placement of retainer and cement waived by Chuck Sheve AOGCC @ 07:20 hrs. Run 9 5/8"40#cement retainer down to 650'. Pumped a total 54 bbls of 15.7#AS-1 Cement in three stages from 650'to surface. 00:00 01:30 1.50 0 0 COMPZ PLUG PULL XT Continue pulling and laying down 7" casing. 01:30 04:00 2.50 0 0 COMPZ PLUG MPSP XT R/D 7"floor equipment. Unload pipe shed,set test plug,test stack 250/3000 psi. Remove test plug. 04:00 06:00 2.00 0 COMPZ PLUG TRIP XT P/U Bullnose and DS to RIH and tag sand top.Tag TOS @ 704'.TOOH laying down Drill collars. 06:00 08:00 2.00 COMPZ PLUG PACK XT setting of retainer and cement placement waived by Chuck Sheve AOGCC @ 07:20 hrs PJSM picked up 9 5/8"41#BOT cement retainer RIH set packer @ 650 ft.pulled 50 K over and 15 K down to insure positive set. release from plug. Page 28 of 30 r Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08:00 15:30 7.50 COMPZ PLUG CMNT XT Wait on/RU Schlumberger to pump cement below retainer. PJSM. PT lines to 3500 PSI good. Est injection rate with 5 bbls of sea water well pressure up to 2300 psi. @ 1 BPM. same @ 1/4 BPM.spotted cement above retainer stab into reatiner down squeezed 1/2 bbl of AS-1 cement below in 45 mins. Unstung from retainer spotted 10 bbls of AS-1 cement above retainer.TOC @ 521 ft POOH to 450 ft. revesed out with 12 BBLs of sea water.Cement in place@15:30hrs 15:30 17:30 2.00 COMPZ PLUG TRIP XT lay down 3.5 IF drill pipe and PAC. 17:30 21:00 3.50 COMPZ PLUG OTHR XT Change over to 8rd equipment. Install VBR in lower rams for surface cement, rig up iron in cellar to cuttings. 21:00 23:00 2.00 COMPZ PLUG TRIP XT TIH to 515'with 3.5"tubing. Up String weight 37K/Down 36K Rig up cement line/manifold on rig floor. 23:00 23:30 0.50 COMPZ PLUG SFTY XT PJSM for cement job. Stage#2-24 bbls of cement. 23:30 00:00 0.50 COMPZ PLUG CMNT XT Hook up vac trucks,test lines&start blending. 03/25/2013 Continue to pump Cement in three stages from 650'to surface. Lay down and offload tubulars from rig. Clean and Prep 11"5M BOPE for storage. ND BOPE. NU tree and test. 00:00 01:30 1.50 515 210 COMPZ PLUG CMNT XT 515'-Pump 5 bbls fresh/24 bbls of 15.7#AS-1, 1/2 bbls fresh @ 5 bpm, start pressure 200 psi,finish 80 psi. Estimated TOC-210' Flush 10 bbls fresh to pits across the top. Rig down hard line on rig floor. Pull 10 joints of 3.5"-P/U string weight 39K,dry pipe. 01:30 03:00 1.50 210 0 COMPZ PLUG CMNT XT Start pumping third stage.Close lower VBR,take returns to cuttings tank,pump 5 bbls fresh,20 bbls of 15.7#AS-1 cement returns to surface,pump additional 10 bbls of flush across the top to the stack. Clean up leak from Cutting box. estimated 30 gallon spill. 03:00 05:00 2.00 0 0 COMPZ PLUG CIRC XT POOH slowly with last 7 joints, layed down.Clean up rig floor,breaking down 2 7/8"pipe from derrick. 05:00 14:00 9.00 0 COMPZ PLUG NUND XT Pull Mousehole and prepare to ND 11"5M BOP.Clean out and ND stack 14:00 16:30 2.50 COMPZ PLUG CMNT XT TOC 8-ft below casing head, mix and dump 30±Gallons of cement for topping off to 2-ft below casing flange. 16:30 23:30 7.00 COMPZ PLUG NUND XT NU TBG head, install TBG Hanger, NU adapter and Tree. Page 29 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 COMPZ PLUG PRTS XT Attempt to PT against TOC at 1,500 psi, lost 1,250 psi in 20 minutes. 03/26/2013 Continue to test tree at 250/3,000 psi. Pull TWC. Pull off well. Prep cellar and location for release of rig. 00:00 01:00 1.00 COMPZ PLUG PRTS XT Install TWC,and Test Tree @ 250/3,000 psi-good test. Pull TWC 01:00 03:30 2.50 COMPZ MOVE OTHR XT Prep and pull rig off well. Clean and clear cellar area in preparation for rig release. Release Nordic Rig 3 @ 03:30 hrs. Page 30 of 30 • mow o jj� s9 THE STATE T Alas 1 S o f l 1 LAs,��1 1 Conservation v1 1 Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue wR' '�,;,, ;i; �, Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Ian Toomey p p� 20 19- I Wells Engineer scoN E ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -02 Sundry Number: 313 -152 Dear Mr. Toomey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of April, 2013. Encl. STATE OF ALASKA r : ,17$ 4 A OIL AND GAS CONSERVATION COM SI Lt '1 • APPLICATION FOR SUNDRY APPROVALS { 20 AAC 25.280 1. Type of Request: Abandon r --- Rug for Redrill r Perforate New Pool F Repair w ell r" Change Approved Program [ Suspend ., • Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown i• Re -enter Susp. Well r Stimulate I""' Alter casing I Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l✓ , Exploratory r 188 - 121 • 3. Address: 6 . API Number: Stratigraphic (-- Service 1 - - P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20101 - 00 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes I' No I+#7 2K - - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25588 Kuparuk River Field / Kuparuk River Oil Pool v 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): 7770 ' 6390 surface Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3369 9.625 3404' 2941' PRODUCTION 7184 7 7217' 5952' LINER 810 5 7768' 6388' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7403' - 7454', 7488' - 7524' 6101' 6141', 6168' - 6196' 3.5 J - 55 6985 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB PACKER MD =6915 TVD =5716 SSSV - CAMCO TRDP -1A MD =1785 TVD =1641 12. Attachments: Description Summary of Proposal jv • 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch I-- Exploratory E Stratigraphic r Development l✓ . Service E` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/23/2013 Oil I Gas r WDSPL Cm Suspended Imo' 16. Verbal Approval: Date: 3/23/2013 WINJ r GINJ WAG r Abandoned E Commission Representative: Victoria Ferguson GSTOR I SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4773 Email: lan.A.Toomev(conocoohilliDs.com Printed Name Ian Toomey Title: Wells Engineer Signature _ ,_ d`�' Phone: 263 -4773 Date 3 -a 7- / Commission Use Only Sundry Number: 3)31 52.... Conditions of approval: Notify Commission so that a representative may witness Plug Integrity I- BOP Test f Mechanical Integrity Test E Location Clearance r Other: RBDMS APR 10 201 `4 ' , Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: /0 — a v APPROVED BY Approved by: ppro cd application is vaRaVai� 1 �rlN�nths from th 1 val. Date: 0 '"-- Y ro O rflerGetN3/A1 . s 2 ` Submit Form and Attachments in Duplicate � 4 / 5//3 %fib /„ �\ • • I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 March 25, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk Well 2K-02 (PTD 188 -121). Nordic 3 was accepted on 2K -02 on 2/20/13 at 21:00 hours and the well was successfully killed with 14.2# KWM. While POOH with the completion the SCSSSV tagged up at —730' RKB. We attempted to drift for a plug but were unable drift past 714' SLD with 1- 11/16" tool string. We made the decision to pump a 350' balanced cement plug to isolate the reservoir. The balanced cement plug was PT to 1500 psi (charted) and tagged at 6303' RKB with 15k down (the test was waived by John Crisp at 16:00 hours on 2/26/13). We pulled the casing in 50k tension (total casing growth 21 -1/2 ") and attempted to POOH with the completion. The SCSSSV tagged at 710' RKB and parted. We were unable to get 2 -7/8" HT PAC DP but could get 2 -7/8" tubing thru (tubing would come back bent) and tagged the SCSSSV at 1231' RKB. Prior to any milling operations we re -PT the cement plug to 1500 psi and placed a 100' sand plug on top of the SCSSSV. RIH with milling BHA tagged up at 720' RBK and milled to 721'RKB where we breached the 7" casing continued to mill to 722' RKB where we breached the 9 -5/8" casing and lost circulation. In order to comply with our internal barrier policy we pumped a —200' cement plug. Tagged the cement plug at 903' RKB (did not request to be witnessed and unable to PT due to a hole in the 9 -5/8" casing). The 7" casing was cut at 718' RKB and pulled from the well. We then began milling and ended sidetracking below the 9 -5/8" casing. We were unable to regain access to the 7" casing and were given verbal approval by Victoria Ferguson on March 23 2013 to perform P &A operation up to but not including final surface abandonment. The well will remain suspended until the entire pad is ready for surface abandonment. We request that the 350' cement plug (6303' — 6653' RKB) satisfies the requirement of 20 AAC 25.112 (c) (1) (C). We set a cement retainer at —650' RKB set down 15k to confirm the cement retainer is set and to comply with 20 AAC 25.112 (g) (1). We only pumped —1/2 bbls of ArcticSET 1 below the cement retainer in 45 minutes due to high squeeze pressure. Then we un -sting from the cement retainer and fill the 9 -5/8" casing with ArcticSET 1 cement to surface. We request that this satisfies the requirements of 20 AAC 25.112 (c) (2) (B) since freshwater is not present in the area. If you have any questions or require any further information, please contact me at 263 -4693. Sincerely, Ian Toomey Wells Engineer CPAI Drilling and Well • • 2K -02 Kuparuk Producer Suspend Well (PTD #: 188 -121) Current Status Nordic 3 released from well 2K -02 on March 26 2013 at 03:30 hours. Scope of Work We set a cement retainer at -650' RKB set down 15k to confirm the cement retainer is set. We only pumped —1/2 bbls of ArcticSET 1 below the cement retainer in 45 minutes due to high squeeze pressure. Then we un -sting from the cement retainer and fill the 9 -5/8" casing with ArcticSET 1 cement to surface. General Well info MASP: 3787 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) MD (6160' TVD) calculated on 1/8/13 using a SITP 840 psi, Reservoir pressure/TVD: 4400 psi at 7478' ( ) g p P p FL @ 463' MD with the well loaded with 12.2 ppg brine. The well was killed using 14.2 ppg water based mud which includes a 125 psi safety factor. The well was losing —1 bbls per hour prior to cement plug. Wellhead type /pressure rating: FMC Gen IV, 11" 5K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: TIFL: failed August 29, 2012 MIT -IA: Unable to install a plug and there is an OV in GLM #4 MIT -OA: Passed on August 19, 2012 to 1800 psi Well Type: Producer Estimated Start Date: Rig accepted February 20, 2013 at 21:00 hours Production Engineer: Deanna Van Dam / Mike Balog Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Proposed Procedure 1. Notify AOGCC of P &A operations for right to witness. (Victoria Ferguson from the AOGCC gave verbal approval to proceed with P &A operations on March 23 2. ND BOP and pull 7" packoffs. NU BOP. BOP cannot be test at this point. 3. Speared 7" casing and POOH sideways. 4. Install test plug. PT BOP body to 250/3000 psi. Pull test plug upon successful PT. 5. PU and RIH with 9 -5/8" cement retainer on 3 -1/2" IF DP and set at —650' RKB. Set down 15K to confirm cement retainer is set. 6. RU Schlumberger cementer. Established an injection rate of 23000 psi at 1 BPM. We only pumped —1/2 bbls of ArcticSET 1 below the cement retainer in 45 minutes due to high squeeze pressure. Pulled out of cement retainer and pump —10 bbls of AS1 on top of the cement retainer. POOH laying down DP and cement retainer running tool. 7. RIH with 3 -1/2" tubing to TOC. Filled the 9 -5/8" casing with AS1 cement from the TOC to surface. 8. RD Schlumberger cementers. 9. ND BOP. 10. Cement was 8' below original ground level, topped off with cement. NU tubing head and install tubing hanger. NU adapter flange, master valve, swab valve, and tree cap. 11. RDMO Nordic 3. Post -Rig Work request: 1. None .. . • • • ConocoPhi lips ArcticSet1 2 K -02 ii Cement P &A Conductor Shoe -115' RKB • t - =� : : 9 -5/8" Cement Retainer at 650' Sidetrack -718' - 728' RKB _ Cut 7" casing at 718' RKB • Permafrost g , r cticS e : . : 11 Cem nt Fish - 28' of 2 -7/8" tubing I 81 .• I :: Tagged TOC 903' RKB -200' Set 15K1 Arctic Pack Cement Plug -100' Sand — Ir. Tagged SCSSSV 1231" RKB -1600' MD • 1 1 Estimated TOC -2087' MD • UGNU • -2430' MD 1 ' West Sak Surface Casing Shoe - 3404' RKB _• I - -3360' MD 9 -5/8" 36# J -55 I II Marginal Cement to 4760' MD —10.- 14.2# Mud Tagged TOC 6303' RKB (Good Cement _ PT to 1500 psi TOC 6400' RKB ( -350' Set 15K1 Cement Plug Bottom of Cement Plug -6653' RKB 14.2# Mud u e :1 i 1 J L u0 Production Casing Shoe - 7217' RKB d 7" 26# J -55 C-Sand Perforation 14.2# 7403' - 7454' RKB Mud : 0 N A -Sand Perforation 7488' - 7524' RKB 5" Liner Shoe - 7768' RKB Date: March 20°, 2013 I Drawn By: Ian Toomey KUP • 2K -02 r ' • Conoccf [ �hiHips , .i Well Attributes Max Angle & MD TD Alaska, I nc. i.° `1811- Wellbore API /UWI Field Name Well Status Inci (°) MD (ftKB) Act Btm (6908) Lorncoat+ilkps 501032010100 KUPARUK RIVER UNIT PROD 39.47 2,600.00 7,770.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' _ SSSV: LOCKED OUT 60 10/28/2011 Last WO: 40.09 6/22/1989 Well Confiq: -26 -02, 8/15/20126: 07: 49 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,495.0 8/3/2012 Rev Reason: TAG ninam 8/15/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 31 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED ;> Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 P SURFACE 95/8 8.921 35.0 3,404.1 2,941.4 36.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 7,216.6 5,952.3 26.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 5 4276 6,957.9 7,768.0 6,388,2 18.00 L - 80 LTC - 8RD CONDUCTOR, 36 -115 Liner Details --iL Top Depth (TVD) Top Incl Nomi... Top (ftKB) (RKB) ( °) Item Description Comment ID (in) SAFETY VW, { ...:.• I 6,957.9 5,750.3 38.77 TIEBACK BAKER/BROWN TIEBACK SLEEVE 5.250 1,785 6,965.2 5,756.0 38.76 PACKOFF BAKER/BROWN PACKOFF 4.250 6,971.6 5,760.9 38.76 TIEBACK BROWN TIEBACK SLEEVE 5.250 6,978.9 5,766.7 38.76 HANGER BROWN HMC LINER HANGER 5.250 GAS LIFT, 2,655 Tubing Strings L_,_'= Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ' TUBING 31/2 2.992 31.1 6,985.1 5,771.5 9.30 J -55 EUE8rdABMOD Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) ( °) Item Description Comment ID (in) SURFACE, 31.1 31.1 0.23 HANGER FMC GEN IV TUBING HANGER 3.500 35 -3,404 1,784.5 1,640.6 37.21 SAFETY VLV CAMCO TRDP -1A SSA SAFETY VALVE (LOCKED OUT 9/30/96) 2.812 6,900.8 5,705.8 38.78 PBR BAKER 80-40 PBR w /4" SEAL BORE 2.992 GAS LIFT. 4,198 6,914.5 5,716.5 38.78 PACKER BAKER HB PACKER 2.892 I 6,951.9 5,745.6 38.77 NIPPLE OTIS 2.812' XN NIPPLE w/2.75" NO GO 2.750 GAS LIFT, 4,908 _ Perforations & Slots Shot Top (TVD) Btm (TVD) Dens GAS LIFT, c 51 Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (ah... Type Comment 5,299 7,403 7,454 6,100.6 6,140.8 C-4, 2K -02 3/19/1991 6.0 APERF 7,488 7,524 6,167.6 6,196.0 A-4, 2K -02 11/16/1989 4.0 IPERF 180 deg. Phasing; 27/8" Casing GAS LIFT, Guns 5,690 Notes: General & Safety End Date Annotation GAS LIFT, .4 10/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8,088 7/12/2012 NOTE: OBSTRUCTIONS @ 692, 713', & 719' SLM H GAS LIFT, 6,486 IIII IIII III GAS LIFT, ['. 6,859 PBR, 6,901 ....- = PACKER, 6,915 _ ` NIPPLE. 6,952 MR 9 1 Mandrel Details Top Depth Top Port PRODUCTION, 4 (TVD) Incl OD Valve Latch Size TRO Run 337,217 Stn Top (MB) (ftKB) (°) Make Model (in) Sery Type Type fn) (Pei) Run Date Com... 1 2,654.7 2,328.3 37.09 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,252.0 6/15/2000 7,403 -74 • • 2 4,198.0 3,592.7 37.92 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,295.0 6/15/2000 3 4,908.2 4,149.4 38.63 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,393.0 6/15/2000 IPERF, • 4 5,298.9 4,455.6 38.60 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 6/15/2000 7,488 -7,524 5 5,690.1 4,761.3 38.35 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/23/1996 6 6,086.4 5,070.4 39.33 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/10/1995 7 6,485.7 5,382.4 38.43 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 12/21/1995 8 6,859.2 5,673.4 38.80 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 12/22/1995 LINER, 6,958-7.768N TD, 7,770 V of 7•4 • • \ %%y 6. THE STATE Alaska Oil and Gas - 0 1 L SKA. Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue LA OF"�mr�,+ S p. Anchorage, Alaska 99501 -3572 Main: 907.279.1433 SCANNED MAR 18 2013 Fax: 907.276.7542 Ian Toomey Wells Engineer ConocoPhillips Alaska, Inc. �, ,/ �. P.O. Box 100360 1 6 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -02 Sundry Number: 313 -104 Dear Mr. Toomey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this lday of March, 2013. Encl. 4 .. KtUtlVI U STATE OF ALASKA Y ,,(7J • AL(A OIL AND GAS CONSERVATION COMMON '3' FEB 2 8 2013 ' APPLICATION FOR SUNDRY APPROVALS /� �e 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Plug for Redrill I Perforate New Pool r" Repair w ell E■;•■ • Change Approved Program E""` Suspend E Plug Perforations r Perforate E Pull Tubing Id , Time Extension [ Operational Shutdow n r Re -enter Susp. Well E`" Stimulate (- Alter casing Jd • Other: i "m 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development j • Exploratory r 188 - 121 • 3. Address: Stratigraphic r Service E 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20101 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes E No E✓ 2K - 02 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25588. 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): • 7770 6390 none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3369 9.625 3404' 2941' PRODUCTION 7184 7 7217' 5952' LINER 810 5 7768' 6388' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 7403' 7454', 7488' - 7524' - 6101' 6141', 6168' - 6196' 3.5 J - 55 7768 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB PACKER • MD= 6915 TVD= 5716 SSSV - CAMCO TRDP -1A SSA s MD =1785 TVD =1641 12. Attachments: Description Summary of Proposal • I:7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch E Exploratory r Stratigraphic r Development Iv • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/11/2013 Oil Iw• • Gas r WDSPL [ Suspended E`"` 16. Verbal Approval: Date: WINJ 1 GINJ r WAG r Abandoned E Commission Representative: GSTOR r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: lan Toomey @ 263 -4773 Email: lan.A.Toorney@conocophillips.com Printed Name lan Toomey Title: Wells Engineer Signature — Phone: 263 -4773 Date .2 2 7 - /3 Commission Use Only Sundry Number: �j ( 3 !d (( Conditions of approval: Notify Commission so that a representative may witness ✓✓ ` I Plug Integrity BOP Test i t '' ' s Mechanical Integrity Test I Location Clearance 1 - Other: , 3 v P is 7 to '---.00 63 r s I RBDMS MAR 12 2w ``v Spacing Exception Required? Yes ❑ No I/ Subsequent Form Required: j ) ° 4 U O APP R O VED BY Approved by: j A pproved application is va�f Wal Yntiths from t h T CN�l�tg l val. Date: 3 -/1 ' 3 O fn d ]� /Z +t 2) / t— / Submit Form and Attachments in Duplicate � / j " 1 1 L 3 1 113 � 2,/ - � �� • • • �.' RECEIVED Conoco Phillips FEB 2 8 2013 Alaska AOGCC BOX 100360 AOGCC ANCHORAGE, ALASKA 99510 -0360 26 February 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2K -02 (PTD 188 -121). Well 2K -02 was originally completed in 1989 as a single 3.5" gas lift well producing from the A -sands. In 1991 the C -sand was perforated, making it a single A and C sand producer. The well has produced continually since then, and the C -sand accounts for the majority of the production. While well 2K -02 was shut -in during June and July of 2012, high IA pressure was noted. Attempts to drift the well were largely unsuccessful with obstructions encountered at around 700'. The rig workover plan was to pull the entire completion, run diagnostics on the 7" casing to determine if subsidence was an issue or not, re- perforate the existing A -sand, and run a new 2 -7/8" x 3 -1/2" selective completion. During the RWO we successfully pulled the seal free from the PBR and TOOH 1000' but the SCSSSV was unable to pass an obstruction in the 7" casing at —700'. We TIH with 1000' of new 3 -1/2" tubing and attempted to drift for a plug but were unable to get past our problem area at 700'. In order to proceed forward with ND BOP stack, ND the tubing head, and pulling the 7" casing in tension to hopefully remove the obstruction at 700' we decided it was necessary to pump a balance cement plug to provide a second barrier. A —350' cement plug was pumped, with the bottom of the plug —100' above the PBR in the 7" casing. Our plan forward is to tag the cement plug and PT to 1500 psi once the cement has had sufficient time to cure. Pull the remaining tubing from the well. Perform a full subsidence repair; cut & pull the 7" casing above the TOC in the 7" x 9 -5/8" annulus, re- install new 7" casing, and circulate cement into the 7" x 9- 5/8" annulus. Mill the 7" cement plug, fish the existing packer, re- perforate the existing A -sand, and a new 2 -7/8" x 3 -1/2" selective completion. If you have any questions or require any further information, please contact me at 263 -4773 Sincerely, -- Ian Toomey Wells Engineer CPAI Drilling and Wells • 2K -02 Kuparuk Producer Rig Workover (PTD #: 188 -121) Current Status The rig workover plan was to pull the entire completion, run diagnostics on the 7" casing to determine if subsidence was an issue or not, re- perforate the existing A -sand, and run a new 2 -7/8" x 3 -1/2" selective completion. During the RWO we successfully pulled the seal free from the PBR and TOOH 1000' but the SCSSSV was unable to pass an obstruction in the 7" casing at —700'. We TIH with 1000' of new 3 -1/2" tubing and attempted to drift for a plug but were unable to get past our problem area at 700'. In order to proceed forward with ND BOP stack, ND the tubing head, and pulling the 7" casing in tension to hopefully remove the obstruction at 700' we decided it was necessary to pump a balance cement plug to provide a second barrier. A —350' cement plug was pumped, with the bottom of the plug -100' above the PBR in the 7" casing. Scope of Work Our plan forward is to tag the cement plug and PT to 1500 psi once the cement has had sufficient time to cure. Pull the remaining tubing from the well. Perform a full subsidence repair; cut & pull the 7" casing above the TOC in the 7" x 9 -5/8" annulus, re- install new 7" casing, and circulate cement into the 7" x 9 -5/8" annulus. Mill the 7" cement plug, fish the existing packer, re- perforate the existing A -sand, and a new 2 -7/8" x 3 -1/2" selective completion. General Well info MASP: 3787 psi (utilizing 0.1 psi/ft gas gradient and SBHP listed below) Reservoir pressure /TVD: 4400 psi at 7478' MD (6160' TVD) calculated on 1/8/13 using a SITP 840 psi, FL @ 463' MD with the well loaded with 12.2 ppg brine. The well was killed using 14.2 ppg water based mud which includes a 125 psi safety factor. The well was losing —1 bbls per hour prior to cement plug. Wellhead type /pressure rating: FMC Gen IV, 11" 5K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: TIFL: failed August 29, 2012 MIT -IA: Unable to install a plug and there is an OV in GLM #4 MIT -OA: Passed on August 19, 2012 to 1800 psi Well Type: Producer Estimated Start Date: Rig accepted February 19, 2013 at 21:00 hours Production Engineer: Deanna Van Dam / Mike Balog Workover Engineer: Ian Toomey (263 - 4773 / Ian.A.Toomey@ conocophillips.com) Proposed Procedure (once cement plug has cured) 1. Notify AOGCC to witness PT and tag of cement plug. 2. PT the cement plug to 1500 psi for 30 minutes and record on chart recorder. Drawdown test to 0 psi. 3. RIH with 3 -1/2" tubing and lightly tag TOC at —6465' RKB. 4. POOH 3 stands. MU storm packer. RIH and set storm packer at —100' RKB. PT to 1500 psi for 10 minutes and drawdown test to 0 psi. 5. ND BOP stack, ND tubing head. Spear 7" casing and pull in tension. Cut off 7" casing growth. Tack weld slips to casing, install pack -offs, and re -land. 6. NU tubing head, NU 11" 5M BOP. PT tubing head break to 250/3000 psi. Install test plug in tubing head and PT BOP to 250/5000 psi. . • -- Proposed Procedure Continued- - 7 . RIH and retrieve storm packer. POOH laying down remaining completion. 8. RU E -Line. RIH with 7" casing evaluation logs including CBL and POOH. Based on the 7" x9 -5/8" cement top, determine the depth of the 7" collar to back -off following the casing cut. RIH and fire string shot across that collar. POOH and RD E -Line. 9. MU, RIH and set RBP below the TOC. Pressure test to 1500 psi and drawdown test to 0 psi. Dump sand on top of RBP. 10. ND BOP stack, ND tubing head and pull packoff. NU 11" 5M BOP on 11" 3M casing head and PT 250/1500 psi (testing against surface casing). 11. Swap well over to 8.6 ppg seawater. 12. Cut the 7" casing above the TOC. Circulate out Arctic Pack from the 7" x 9 -5/8" annulus with heated diesel followed by heated seawater. 13. Spear 7" casing and POOH sideways. 14. Run 9 -5/8" casing scraper to the top of the 7" stub and circulate clean. 15. Run back off tool and back off casing stub. 16. Run tandem string mills to gauge the 9 -5/8" casing for the ES cementer. 17. Spear and recover backed off 7" casing stub. 18. RIH with new 7" casing and Halliburton ES cementer. Screw into top of 7" casing. Pressure test casing. 19. Open ES cementer and pump cement into the 7" x 9 -5/8" annulus to surface (see attached cement detail). Close ES cementer. 20. WOC. ND BOP, pull casing in tension and land in slips. Cut off excess 7" casing and install packoffs. NU new tubing head. 21. NU 11" 5M BOP and test break to 250/5000 psi. 22. Drill out cement. Pressure test casing to 2500 psi for 30 minutes and record and test chart. Continue down until tag up on top of sand, dry drill to break up debris. Circulate well clean. 23. RIH with wash shoe, boot baskets, magnets, etc. and circulate out sand on top of RBP. 24. Swap well back to 14.2 ppg water based mud. 25. RIH with RBP retrieving tool, release RBP, and POOH. 26. Drill out 7" cement plug and circulate well clean. 27. RIH with cleanout assembly to cleanup remaining solids and debris off the PBR/packer assembly. 28. RIH with spear, spear the PBR, and release the packer. POOH with packer assembly. 29. RIH with 5 -1/2" and 7" casing scrapers. POOH 30. RU E -line. Run caliper log on the 5" liner and 7" casing to surface. 31. RIH with perforating guns and re- perforate the existing A -sand interval (7488' — 7524' RKB). 32. Run gauge ring to ensure the packer will pass the existing C -sand perforations. MU 5" packer assembly with plug installed in the `D' nipple profile, RIH, and set the packer at 7470' RKB. POOH and RD E -line. 33. RIH with 5" test packer and set below the C -sand perforation. PT below the test packer to 2500 ps. Release the test packer, PU above the C -sand perforation and set the test packer. PT the backside 2000 psi to test the integrity of the 5" liner and 7" casing (a 2500 psi test + hydrostatic pressure of 14.2 ppg mud is greater than 80% burst of 7" J -55 casing). POOH. • • —Proposed Procedure Continued 34. PU, MU and RIH with 7" FHL packer and selective completion. Engage anchor seal assembly and overpull to confirm anchor is engaged. Pressure up and set 7" FHL packer. PT the IA to 1500 psi to confirm the packer is set. Shear PBR and POOH. 35. RIH with new 3 -1/2" tubing completion. Sting into PBR, mark the pipe, PU and reverse circulate out 14.2 ppg mud with 8.6 ppg seawater. Load the tubing and IA with 8.6 ppg corrosion inhibited seawater. 36. Space out and land 3 -1/2" completion. RILDS. PT tubing and IA to 2500 psi for 30 minutes and record on chart recorder. 37. Set BPV. Shear SOV. Pressure up on the IA to 1000 psi to test BPV from below. Bleed IA to 0 psi. 38. ND BOP. NU tree, pull BPV, set tree test plug, and PT to 5000 psi. 39. Pull tree test plug. Freeze protect well. Set BPV. 40. RDMO Nordic 3. Post -Rig Work request: 1. Pull BPV 2. RU slickline: set catcher sub on top of plug in the `D' nipple, pull SOV in GLM #5, run GLD, pull catcher sub and pull plug in the `D' nipple. RD slickline. 3. Return to production. i KU P • 2K-02 Conoc a Well Attributes Max Angle & MD TD Ai 1 h<i {tu, Wellbore API /UWI Field Name Well Status Inc/ ( °) MD (ftKB) Act Btm (ftKB) .,..`i1.dlp.s 501032010100 KUPARUK RIVER UNIT PROD 39.47 2,600.00 7,770.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Wet cones'. - 2K - oz , 8/15.2012 607:49 AM SSSV: LOCKED OUT 60 10/28/2011 Last WO: 40.09 6/22/1989 Schematic - Actual Annotation Depth /ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,495.0 8/3/2012 Rev Reason: TAG ninam 8/15/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String .. String Top Thrd j HANGER, 31 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 3,404.1 2,941.4 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 7,216.6 5,952.3 26.00 J - 55 BTC . Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 5 4.276 6,957.9 7,768.0 6,388.2 18.00 L - 80 LTC - 8RD CONDUCTOR, 36-11 Liner Details Top Depth (TVD) Top Intl Nomi... Top (ftKB) M(TVD) ( °) Item Description Comment ID (in) SAFETY VLV, j co, I 6,957.9 5,750.3 38.77 TIEBACK BAKER/BROWN TIEBACK SLEEVE 5.250 1,785 6,965.2 5,756.0 38.76 PACKOFF BAKER/BROWN PACKOFF 4.250 6,971.6 5,760.9 38.76 TIEBACK BROWN TIEBACK SLEEVE 5.250 6,978.9 5,766.7 38.76 HANGER BROWN HMC LINER HANGER 5.250 GAS LIFT, r 2,655 Tubing Strings [ - � Tubing D31.1 escription 31.1 String 0.23 0... HANGER String ID ... Top FM (ftKB) GEN IV Set Depth TUBING (f... Set HANG Depth (TVD)... String Wt... String ... String Top Thrd TUBING 31/2 2.992 3 6,985.1 5,771.5 9.30 J -55 EUE8rdABMOD Completion Details Top Depth (ND) Top Intl Nomi... SURFACE. J l Top (ftKB) (11K8) (1 Item Description Comment ID (in) 3.500 _ 35 3,404 1,784.5 1,640.6 37.21 SAFETY VLV CAMCO TRDP -1A SSA SAFETY VALVE (LOCKED OUT 9/30/96) 2.812 {` / 6,900.8 5,705.8 38.78 PBR BAKER 80-40 PBR w /4" SEAL BORE 2.992 GAS LIFT, 1'.' 4.198 6,914.5 5,716.5 38.78 PACKER BAKER HB PACKER 2.892 6,951.9 5,745.6 38.77 NIPPLE OTIS 2.812" XN NIPPLE w/2.75" NO GO 2.750 mo GAS LIFT. t - Perforations & Slots ' r Shot i Top (ND) Btm (ND) Dens GAS LIFT, r Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date 1 Type Comment 5,299 - 7,403 7,454 6,100.6 6,140.8 C -4, 2K -02 3/19/1991 6.0 APERF 7,488 7,524 6,167.6 6,196.0 A-4, 2K -02 11/16/1989 4.0 IPERF 180 deg. Phasing; 27/8" Casing GAS LIFT, Guns 5,690 r Notes: General & Safety � End Date Annotation GAS LIFT. 10/29/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6 ' 7/12/2012 NOTE: OBSTRUCTIONS @ 692, 713, & 719' SLM • GAS LIFT, _ X t.. 6,486 E a GAS LIFT, 6,859 PBR. 6,901 - -- -� PACKER, 6,915- - NIPPLE, 6,952 l I i j Mandrel Details Top Depth Top Port PRODUCTION. (TVD) Intl OD Valve Latch Size TRO Run 33 -7,2t7 Stn Top (ftKB) (RKB) (1 Make Model (in) Sery Type Type ON (psi) Run Date Corn... 1 2,654.7 2,328.3 37,09 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,252.0 6/15/2000 APERF, 7,403 - 7,454 II 2 4,198.0 3,592.7 37.92 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,295.0 6/15/2000 3 4,908.2 4,149.4 38.63 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,393.0 6/15/2000 IPERE, ® 4 5,298.9 4,455.6 38.60 MERLA TMPD 1 GAS LIFT OV BK 0.250 0.0 6/15/2000 7,488 - 7,524 5 5,690.1 4,761.3 38.35 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/23/1996 6 6,086.4 5,070.4 39.33 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/10/1995 7 6,485.7 5,382.4 38.43 CAMCO MMG -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/21/1995 8 6,859.2 5,673.4 38.80 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 12/22/1995 LINER, 6,958 -7,768 IL TD, 7,770 • • 0C Illi S Well: 2K -02 2013 RWO PROPOSED COMPLETION API: 501032010100 Conductor: PTD: 181 -088 16 ", 62.5 #, H -40 to 115' Wellhead: FMC Gen IV 2.813" 'DS' 0. NIP X -mas Tree: 3 -1/8 ", 5K psi Nipple Surface Casing: Lift Threads: 3 -1/2" 8rd EUE 9.625 ", 36.0 #, J -55 to 3404' BPV: 3" 'ISA' Proposed 2 -7/8" Selective Completion J Production Casing: 7 ", 26.0 #, J -55, 33' - 7216' • Tubing, 3'W, 9.3 ppf, L -80, 8rd EUE. j Production Liner: • Packer, Baker 'FHL' 3'/2' x 7" 5 ", 18.0 #, L -80, 6,958' - 7768' • Tubing, 2 -7/8 ", 6.5 ppf, L -80, 8rd J EUE. Perforations: • Sliding Sleeve, Baker CMU w/ 2.312" 'X' MD Zone profile. • Weatherford 2 -7/8" x 5" UltraPak Packer 7403' 7454' Kuparuk C-4 • Nipple, 2.25" 'D' w /plug installed 7488' 7524' Kuparuk A-4 J 4 4— PBR at XXXX' \ , Gas Lift Mandrels: Type MD TVD X g 4- Baker FHL Retrievable Packer at XXXX'. MMG, 1 -1/2" 2864' 2500' MMG, 1 -1/2" 4335' 3700' --- MMG, 1 -1/2" 5420' 4550' 4— 2 -7/8" to 3 -1/2" crossover MMG, 1 -1/2" 6241' 5191' MMG, 1 -1/2" 6754' 5591' 1 E Baker/Brown Tieback Sleeve, 5.75" OD, 5.25" ID A ■ Directional: — 3 — ♦—• Carbide Blast Rings Max Incline: 39.5° at 6000' f Max Dogleg: 4.7° at 700' Boo — Baker Sliding Sleeve 5" UltraPak Packer NIP 4— 2.25" 'D' Nipple 4-- PBTD 7678' MD Last Updated: 20- Feb -13 Updated by: MLC • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~AI~N~~ AUG ~ ~ 208 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, Julyl0,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date • 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 02/16/07 Schlumbepgel' NO. 4142 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth c,r/!"~\N. ED rEB 2 1 2007 to,.jJ't:JN'A Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I tr - 19 I Field: Kuparuk Well Job# Date Color CD Log Description BL 10-111, 11638816 INJECTION PROFILE 01/24/07 1 1H-19 . 11663824 INJECTION PROFILE 01/25/07 1 2T -30 . 11663825 PRODUCTION PROFILE 01/26/07 1 2K-02 11663829 PRODUCTION PROFILE 01/30/07 1 3J-02 11632653 INJECTION PROFILE 01/30/07 1 3J-08 11632657 INJECTION PROFILE 02/03/07 1 2M-OS· 11632658 SBHP SURVEY 02/04/07 1 1A-19· 11632660 PRODUCTION PROFILE 02/05107 1 3J-04 . 11628963 INJECTION PROFILE 02/08/07 1 1C-09 . 11638818 INJECTION PROFILE 02/09/07 1 2M-26 11638819 INJECTION PROFILE 02/10/07 1 10-03 11628967 PRODUCTION PROFILE 02/11/07 1 1C-20 N/A RSTIWFL 02/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ¡/¡ . . Schlumbepger NO. 3231 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 0/06/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL RDr.f- p:3 ( J 1 E-119 10884033 SCMT 1 0/04/04 19'0 - 0:3 tf !1L-09 10802915 PRODUCTION PROFILE W/DEFT 07/26/04 1 /7'5- {)~r J2V-14 10884026 PRODUCTION PROFILE W/DEFT 09/27/04 1 / 88>- I;)"" I . 2K-02 10884027 PRODUCTION PROFILE W/DEFT 09/28/04 1 / qr, - (tf'dJ 3J-17 10884031 PRODUCTION PROFILE 10102/04 1 /~5 - ;2.23 . 3A-07 10884030 INJECTION PROFILE 10/01/04 1 /80 -{)S7] 1E-04 10884023 INJECTION PROFILE 09/24/04 1 1 E-11 10884024 INJECTION PROFILE 09/25/04 1 / YJ.. - 05/ J 2H-12 10884022 PRODUCTION PROFILE 09/23/04 1 ! ~5 - ~ ~ '2.. - R" -kL Kuparuk ~ Color CD 1 ~ DATE: 1'~( SCANNED NOV {} 5 2004 Please sign and retur 0 e copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000 E E C:LORPaMFILM. DOC PI~ E W M A.T ER IA L U N D ER TH IS M A R K ER STATE OF ALASKA A~ OIL AND GAS CONSERVATION C, OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address Stimulate ~( Plugging Perforate _ Repair well O t h e r P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory I Stratigraphic Sorvice feet feet 4. Location of well at surface 271' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1455' FNL, 1544' FEL, Sec. 2, T10N, R8E, UM At effective depth 1455' FNL, 1544' FEL, Sec. 2, T10N, R8E, UM At total depth 1430' FNL, 1709' FEL~ Sec. 2~ T10N, R8E, UM 12. Present well condition summary Total Depth: measured 7 7 7 0' true vertical 6 3 8 9 Plugs (measured) None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-02 9. Permit number/approval number 08-121 10. APl number 5o-103-20101 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 75 06' true vertical 61 8 0' feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 115' 3404' 115' 16" 3404' 9 5/8" 721 7' 796' measured 7403'-7454', 7488'-7524', true vertical ,, 179 Sx AS III 880 Sx AS III & 450 Sx Class G 357 Sx Class G 2.125" Gun @ 6 SPF 2.875" Gun @ 4 SPF 7217' 6972'-7768' 6099-6140', 6167'-6196' Tubing (size, grade, and measured depth) 3.5" J-55 set at 6985' Packers and SSSV (type and measured depth) Brown HB @ 6915', Camco TRDP-1A-SSA @ 1785' 13. Stimulation or cement squeeze summary Stimulate C Sand during scale inhibitor squeeze. Intervals treated (measured) 7403'-7454', 7488'-7524' Treatment description including volumes used and final pressure True vertical depth 115' 2941' 6031' 5760'-6387' RECEIVED MAR - 4 t992 Alaska Oil & Gas Cons. comrnissioO Anchorage Pumped 26 bbl diesel pre-flush with I drum SS-8603, following by 100 bbls seawater with 5 drums S-289 and 5 drums S-256. 14. Displace with 950 bbls of seawater. Final WHTP -- 1100 psi. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 236 Service Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 17. 908.¢f'',~ 822 1409 1250 , 2994 -/:":" 2670 1409 1300 1 !6; Status of well classification as: __ ~ .- ' Water Injector m X Oil X Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. 261 Si~lned Form 10-404 Rev 09/12/90 Title ~/ Z) ~/.5 ~,'le(~ ~' Date ~-'/[ d f~- SUBMIT IN DUPLICATE .,RCO Alaska, Inc... Subsidiary of Atlantic Richfield Company REMARKS I FIELD - DISTRICT - STATE WELL SERVICE REPORT !}<'o~.uk. P,~uer P;~.lcl OPERATION ATf~.._O,~.~ ii~f e .~/R~PORT TIN1E OqOo 0~o !~lSo ~o~o I SOc~ k. iN, AR - 4 ~992 Aiaska OiJ & Gas Cons. Commission ,Anchora.oe J-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK kflotl J Signed STATE OF ALASKA f'-'~ 0 ~ ALAo¢~ OIL AND GAS CONSERVATION COMMIEkSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate m Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 271' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1455' FNL, 1544' FEL, Sec. 2, T10N, R8E, UM At effective depth 1455' FNL, 1544' FEL, Sec. 2, T10N, R8E, UM At total depth 1430' FNL, 1709' FEL~ Sec. 2, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 7770' true vertical 6389 feet Plugs (measured) feet None Effective depth: measured 7 5 0 6' feet Junk (measured) true vertical 6180' feet None Casing Length Size Cemented Structural Conductor 1 1 5' 1 6" 179 Sx AS III Surface 3404' 9 5/8" 880 Sx AS III & Intermediate 450 Sx Class G Production 721 7' 7" 357 Sx Class G Liner 7 96' 5" Perforation depth: measured 7488'-7524', 2.875" Gun @ 4 SPF true vertical 6167'-6196' Tubing (size, grade, and measured depth) 3.5" J-55 set at 6985' 3ackers and SSSV (type and measured depth) Brown HB @ 6915', Camco TRDP-1A-SSA @ 1785' 13. Stimulation or cement squeeze summary Perforate C Sand from 7403'-7454' @ 6 SPF and 0°F Intervals treated (measured) Treatment description including volumes used and final pressure 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-02 feet 9. Permit number/approval number 88-121 10. APl number S0-103-201 01 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3404' 2941' 7217' 6031' 6972'-7768' 5760'-6387' RECEIVED MAR - 4 3992 Anchorage 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Reoresentative Daily Averaoe Production or Injection Data - OiI-Bbl Gas-Md Water-Bbl Casing Pressure 760 1423 0 1300 665 ~- 901 653 800 16. Status of well classification as: Water Injector ~ Oil ~ Gas Suspended Service Tubing Pressure 33O 278 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C(~ , ~ Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ,~RCO Alaska, Inc.~ Subsidiary of Atlantic Ricl~ftelcl Company WELL SERVICE REPORT IP~.~ ! I FIELD - DISTRICT- STATE DAYS REMARKS C_C_: AK 35"/9 Ei,-J'C' Iq, lqO. ~o RECE[V O Alaska Oil & Gas Cons. F"I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W'ather [Temp' ! Chill F'ct°r I VisibilitylWind V'l'R.port 'Fi1 'F mile. ADDENDUM WELL 2K-2 4/8190 Frac Kuparuk "A" sand perfs 7488'-7524' 180 deg oriented 160 deg ccw in ten stages as follows. Stage 1: Prop 100 bbls YF240 Gel water prepad @ 20 bpm 6020-4660 psi 45 bbls YF240 Gel water prepad @ 15 bpm 4200-4600 psi 30 bbls YF240 Gel water prepad @ 10 bpm 4045-4560 psi Stage 2:70 bbls slick diesel flush @ 20 bbm 5410-4340 psi Stage 3:250 bbls YF240 pad @ 20 bpm 4420-4625 psi Stage 4: Stage 5: Stage 6: Stage 7: Stage 8: Stage 9: Stage 23 bbls YF240 w/2 ppg 16/20 Carbolite @ 20 bpm 4625-4490 psi 26 bbls YF240w/4 ppg 16/20 Carbolite @ 20 bpm 4490-4210 psi 24 bbls YF240 w/6 ppg 16/20 Carbolite @ 20 bpm 4210-4125 psi 30 bbls YF240 w/8 ppg 16/20 Carbolite @ 20 bpm 4125-4130 psi 14 bbls YF240 w/9 ppg 16/20 Carbolite @ 20 bpm 4130-4320 psi 10 bbls YF240 w/10 ppg 16/20 Carbolite @ 20 bpm 4320-4330 psi 10:67 bbls slick diesel flush @ 20-19 bpm 4330-5100-5200 psi Fluid to recover: 688 bbls Sand in zone: 34,076 lbs Sand in csE.. 652 lbs Avg pressure: 4400 psi D~ervisor ~ --- Date /~"~' STATEOF ALASKA U j-~ ~G j j~ ~ ALASKA ulL AND GAS CONSERVATION COMMISSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~m mmm ~E,,~E~,iEii mm m m~m,m~m 'm~m ~ ! mm-- --, -m- ~.-/ 1. Status of Well Classification of Service Well / OIL ~ GAS [] SUSPENDED ~ ABANDONED ~ SERVICE [] , . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-121 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20101 4. Location of well at surface 9. Unit or Lease Name 271' FSL, 94' FEL, Sec. 2, T10N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1455' FNL, 1544' FEL, Sec. 2, T10N, ESE, UM 2K-2 At Total Depth 11. Field and Pool 14:30' FNL, 1709' FEL, Sec. 2, T10N, RBE, UM Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 154' RKB ADL:25588 ALK: 2674 Kuparuk 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 06/04/89 6/20/89 11/17/89I --- feet MSL 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+7¥D) 19. D~z~ionalSurvey { 20. Depth where SSSV set ] 21. Thickness of Permafrost 7770'MD&6389'TVD 7676'HD&6315'TVD YES I~J NO [] 1785' feet MD --- 22. Type Electric or Other Logs Run DIL/GR/SP/SFL~ FDC/CNL/CAL; CET; Gyro 23. CASING, LINER AND CEMENTING RECORD ,,, SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" Surf 115' -- 17C~ .~x A.q III 9-5/8" 36# J-55 Surf 3404' 12-1/4" 880 sx AK III. 450 .~> £1a.~s O, . 7" 26# J-55 Surf 7217' 8-~," ~57 sx £1a.~.~ o. 5" 18# 1-80 6972 ' 7768 ' 6-1/8" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7,488'-7,524' MD 3¥',9.3#,J-55 6,985' 6,915' 6,167'-6,196' TVD w/2-7/8", 14 gm, 4 spf, 180° ph' 160° CCW 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. from hi gh si de DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .... 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS'OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATEDml~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chiDs. RECE{VED JAN 2 q 1990 Alaska.011 & Gas Cons. ~mmissl0.[~ · wc 1 / 3 0 "~,~,k'..~ ~0h0r .a~. ) Form 10407 Submit in duplicate J Rev. 7-1-80 CONTINUED ON REVERSE SIDE . . . , GEOLOGIC MARKERS F(~RMATION TESTS · NAME TOPS Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Kuparuk C 7,404' 6,101' None Kuparuk A 7,460' 6,145' · 31. LIST OF ATTACHMENTS Gyro 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _ I Signed ,.'~ Title Area Drillir~g Engr. 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 (G L) 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 ARCO Oil and Gas Company ~ Well History - Initial Report - DailY- instructions: Prepa~*e and stJbmit the "Initial Report" on the f~rst Wednesday after a well is spudded or workover ope~at!ons a~e started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District JCounty, parish or borough ARCO ALASKA INC. I NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT I ADL: 25588 ALK: 2674 Auth, or W.O. no, ITitle AK3579 I COMPLETIONS State AK 2K-2 Iwe,. ,o. Operator ARCO Spudded or W.O. begun IDate IHour SPUD I 06/04/89 I 05:30 Complete record for each day reported NORDIC ~1 Date and depth as of 8:00 a,m. 11/09/89 (21) TD: 7770 PB: 7768 SUPV:DB 11/10/89 (22) TD: 7770 PB: 7768 SUPV:DB 11/11/89 (23) TD: 7770 PB: 7768 SUPV:DB 11/12/89 (24) TD: 7770 PB: 7768 SUPV:DB 11/13/89 (25) TD: 7770 PB: 7768 SUPV:DB The abov/~e correct /% For form prepare~"~ and dlstrlbutlo~_____.~ see Procedures [Vlantllal, Section 10~ Drilling, Pages 88,,,ea~d 87. MOVE & RACK DRIL~,.COLLARS. 5"@ 7770' MW: 0.0 WBM MOVE RIG FROM 2K-7, ACCEPT RIG AT 0300 11/9/89, ND DRYHOLE TREE, NU BOPE, TEST BOPE TO 3000 PSI, MOVE & RACK 4-3/4" DRILL COLL;LRS DAILY:S20,540 CUM:$!,677,541 ETD:S1,677,541 EFC:$693,600 IARCO W.I. 55.8533 Prior statue if a W.O. TIH 5"@ 7770' MW: 0.0 WBM CONT. RACK 3-1/4" DRILL COLLARS, PU AND TIH W/ 4-1/8" BIT, 5" SCRAPER, 3-1/4 DCS ON 3-1/2" DRILL PIPE, STOP AT 2086', DISPLACE BRINE WITH 64 BBLS WATER, FOLLOWED BY 80 BBLs MUD, TIH TO 3672, CIRC & COND MUD, CONT. TIH TO 6532, CIRC. & COND. MUD, CONT. TIH DAILY:S110,709 CUM:$1,788,250 ETD:S1,788,250 EFC:$693,600 PREP TO FILTER BRINE 5"@ 7770' MW: 0.0 NaCl CONT. TIH, TAG FILL AT 6962, CIRC. & COND. MUD, DRILL CMT F/6962-6993, (TOL AT 6973), CBU, TEST CSG & LINER TO 3000 PSI - OK, DRILL CMT & LD COLLAR F/6993-7676, CBU, TEST CSG & LINER TO 3000 PSI - OK, RU AND REVERSE CIRC. 80 BBLS WATER FOLLOWED BY 11.1 PPG BRINE, PREP TO FILTER BRINE DAILY:S26,552 CUM:$1,814,802 ETD:S1,814,802 EFC:$693,600 LOG W/ GCT GYRO 5"@ 7770' MW: 0.0 NaC1 REVERSE CIRC. AND FILTER BRINE, TOH LD BHA, RU SWS, TIH w/cBT, TOOL SHORTED OUT, TOH, TIH W/ 2ND CBT, TOOL STOPPED AT 7600, TOH, CLEAN TOOL, TIH LOG FROM 7646 WLM TO ABOVE TOL, TOH, TIH W/ GCT GYRO DAILY:S33,461 CUM:$1,848,263 ETD:S1,848,263 EFC:$693,600 WASH & REAM FILL 5"@ 7770' MW: 0.0 NaC1 CONT. LOGGING W/ GCT GYRO, TOH, RD SWS, PU AND TIH W/ 6-1/8" BIT, 7" CSG SCRAPER, 4-3/4" DCS ON 3-1/2" DP, WASH AND REAM F/6925-6973(TOL) TO CLEAN CMT SHEATH ABOVE LINER, TOH, PU 4-1/8" BIT, 5" CSG SCRAPER, AND TIH, WASH AND REAM FILL F/7648-7676 DAILY:S56,687 CUM:$1,904,950 ETD:S1,904,950 EFC:$693,600 RE£E VED JAN 2 4 1990 Alaska 0il & Gas Cons. Commisslo~ .i t'ti ]~J iui ca'~_J'g .. AR3B-459-1-D INumberall dally well hlmo~/ forme consecutively no. es they a~.e prepared roi' each wall. ~1Page I ARCO Oil and Gas~Company 4> Daily Well History--Interim Instructions: This form is used during ddillng or workover ope~'ation¢ If (estiog. f'Orhlg, or perfora',m:, show formation nrlme in ,hmchbin(] work ~mrformr,,t. Number all drill s~m tests sequentially. Attach d~Jscription of aH cores Wor~; perfo'med by ProdtJC;~g completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when hlled out but not less frequently than every 30 (Jays. or (2) On Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish IState ARCO ALASFu~ INC. I NORTH SLOPE I AK Field JLease or Unit JWell no. KUPARUK RIVER UNIT J ADL: 25588 ALK: 2674 2K-2 Date and depth as of 8:00 a.m. 11/14/89 (26) TD: 7770 PB: 7768 SUPV:DB 11/15/89 (27) TD: 7770 PB: 7768 SUPV:DB 11/16/89 ( 28] TD: 7770 PB: 7768 SUPV:DB 'Complete record for each day while drilling or workover in progress NORDIC #1 TIH W/LINER PACKER 5"@ 7770' MW: 0.0 NaCl CONT. CIRC. OUT FILL, REVERSE CIRC. AND FILTER BRINE, TOH, PU 5-3/16 MILL, TIH, POLISH OUT LINER TIEBACK STEM (6 TIMES AT 30RPM), TOH, PU BAKER JM TIEBACK PACKER AND TIH DAILY:S31,147 CUM:$1,936,097 ETD:S1,936,097 EFC:$693,600 RIH W/ PERF GUN ~ 1 5"@ 7770' MW: 0.0 NaC1 CUT & SLIP 50' DRLG LINE. SERVICE RIG. CONT. RIH W/ BAKER' TIEBACK ASSY. STAB INTO 5" LNR. TEST SEALS TO 10000 PSI, OK. SET BAKER JM TIEBACK PACKER. TEST SAME. TEST LINER AND CASING TO 3000 PSI. OK. POOH. LDDP. RU SOS. MU PERF GUNS. RIH W/ GUN # 1. DAILY:S46,231 CUM:$1,982,328 ETD:S1,982,328 EFC:$693,600 TIH W/ SLICKLINE F/SV 5"@ 7770' MW: 0.0 NaCl PERFORATE 7504-7524 AND 7488-7504 AT 4 SPF, RD SWS, RU & RUN 3-1/2" COMPLETION ASSEMBLY, TEST CONTROL LINE, LAND TBG, RU SLICKLINE, RIH AND SET SV AT XN NIPPLE, POH, PRESSURE UP TBG AND SET PKR (TBG TEST OK TO 3000 PSI), PBR SHEARED DURING TEST, BLEED PRESS, PU AND CONFIRM'PBR SHEARED, RELAND TBG, RILDS, TEST ANNULUS TO 2500 - OK, CLOSE SSSV, BLEED TBG PRESS, SSSV OK, BLEED PRESS, OPEN SSSV, RIH W/ SLICKLINE TO RETRIEVE SV DAILY:S12,700 CUM:$2,178,615 ETD:S2,178,615 EFC:$693,600 The above,~,,tco r rect For form preparation d distribution ~ sst ~11 ~~reM~ia°~n¢8S7 e c t, 0n 10. I AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO ~JII and Gas Company Daily Well History-Final Report Instructions: P~-epare and submit Ihs "Final Report" on .the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" shoulc~ be submitted also when operations are suspended for an indefinile or appreciable length of time. On workovers when an official test is required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used tor reporting the entire operation ~f space is available. District iCounty or Parish Field ARCO ALASKA INC. LeaseN~)~"i]{ SLOPE Auth. or WEO3B[%RUK RIVER UNIT IT t e ADL: 25588 ALK: 2674 I AK3579 COMPLET IONS IAccounting cost center code State AK J Well no. I 2K-2 Operator Spudded o~begun Date and as of 8:00 a.m. 11/17/89 (29) TD: 7770 PB: 7676 SUPV:DB A.R.Co. W.I. Date55.8533 'rcotal number of wells (active or inactive) on this~ Dst center prior to plugging and J labandonment of this well JHour IPrlor status if a W.O, Complete record for each day reported06/04/89 05:30 NORDIC #1 RIG RELEASED ~ 5"@ 7770' MW: 0.0 NaC1 POH W/ SV, RD SLICKLINE, SET BPV, ND BOPE, NU TREE, PULL BPV, SET TEST PLUG, TEST TREE AND PACKOFF TO 5000 PSI, PULL TEST PLUG, REVERSE CIRC. 5 BBLS DIESEL BULLHEAD 2 BBLS DIESEL ( CV HOLDING), RELEASE RIG AT 1400 11/16/89 DAILY:S12,700 CUM:$2,178,615 ETD:S2,178,615 EFC:$693,600 Old TD J New TD I · Released rig Date Classifications (oil, gas, etc,) PB Depth Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval lOll or gas Test time Production Oil on test Gas per day . Pump size, SPM X length · Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Ls,.-correct S'gnat~.~.~ ~ l Dar;//////~/~' d:) I"~ ~ ~ · ". . . 4_) i ~ For form preparat'~and dmtr~buhon, g see Procedures I~a~,r,r~al, Section 10, Drilling, Pages 8b-"~nd 87. INumber ell daily well history forms consecutively I Page no. ~ Jas they are prepared for each well. I I AR3B-459-3-C Olvl,~ el AtlentlcRlehfleldCompa~y O~IGINAL SUB. SURFACE DIRECTIONAL SURVEY MED F~ONTINUOUS ~-]OOL RECEIVED JAN 2 6 19~0 Gas Cons° ~ch0ra~ ComPany ~ ARCO ALASKA~ I,,NC. , , Well Name 2K-2 (271',, FSL, 94' FEL,,, SEC 2, TION,, R8E, UM) FleldlLocation KUPAR, UK~ NORTH SLOPE, ALASKA , Job Reference No. 73546 SARBER Date 12-NOV-89 Computed SINES SCHLUMBERGER GC'T DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2K - 2 KUPARUK Ng~TH SLOPEr ALASKA SURVEY DATE: 1Z-NOV-lO8 ENGINEER: G. SARBER METHDgS OF C3MPUTATION TOOL LOCATION: TANGeNTIaL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: MORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 20 DEG 5Z MIN WEST ARCO ALASKA INC. 2K - 2 KUPARUK NORTH SLOPEr ALASKA COMMUTATION DATE: 16-NOV-89 PAGE DATE OF SURVEY: 12-NDV-198 KELLY BUSHING ELEVATION= 154.00 FT ENGINEER: G. S~RBER INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -154.00 0 0 N 0 0 E 100.00 100.00 -54.00 0 20 N 23 12 E 200.00 199.99 45.99 0 30 N 11 14 E 300.00 299.99 145.99 0 28 N 0 53 E 400.00 399.98 245.98 1 8 N 8 ¢ W 500.00 499.80 345.80 5 22 N 14 0 W 600.00 598.98 444.98 8 50 N 12 51 W 700.00 697.10 543.10 13 13 N 12 35 W 800.00 793.82 639.82 16 6 N 16 I W 900-00 889.02 735.02 19 30 N 18 43 W VERTICAL DDGLEG RECTANGULAR COORDIN&TES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1000.00 982.41 828.41 22 18 1100.00 1073.65 919.65 26 4 1200.00 1162.18 1008.18 29 5 1300.00 1248.23 1094.23 32 7 1400.00 1331.83 1177.83 34 25 1500.00 1413.38 1259.38 3~ 12 1600.00 1493.46 1339.46 37 13 1700.00 1573.04 1419.04 37 13 1800.00 1652.71 1498.71 37 12 1900.00 1732.38 1578.38 37 5 0.00 0.00 0.00 N 0.00 E 0.37 0.00 0.55 N 0.40 E 0.98 0.10 1.29 N 0.65 E 1.74 0.21 2.14 N 0.72 E 2.93 1.83 3.29 N 0.67 E :2.44 3.64 8.75 N 0.73 W 20.93 3.57 21.02 N 3.62 W 39.~9 3.57 39.74 N 7.74 W 65.07 3.35 64.30 N 14.02 W 95.56 3.57 93.41 N 23.23 W 2000.00 1812.35 1658.35 36 47 2100.00 1891.75 1737.75 38 12 2200.00 1970.51 1816.51 37 34 2300.00 2050.07 1896.07 37 7 2400.00 2129.92 1975.92 37 5 2500.00 2208.52 2054.52 39 25 2600.00 2285.54 2131.54 39 28 2700.00 2364.15 2210.15 36 56 2800.00 2444.30 2290.30 36. 36 2900.00 2524.80 2370.60 36 3 N 20 20 W 131.26 N 20 34 W 172.15 N 13 59 W 218.61 N 17 1Z W 269.45 N 17 0 W 324.19 N 17 38 W 381.94 N 18 12 W 441.76 N 17 54 W 502.25 N 17 13 W 562.58 N 16 31 W 622.87 3000.00 2605.99 2451.99 35 24 3100.00 2687.88 2533.98 34 35 3200.00 2770.56 2616.56 33 51 3300.00 2854.01 2700.01 33 7 3400.00 2938.00 2784.00 32 39 3500.00 3022.18 2868.18 32 49 3600.00 3106.05 2952.05 33 14 3700.00 3188.82 3034.82 35 3 3800.00 3270.59 3116.59 35 7 3900.00 3352.30 3198.30 35 19 N 15 57 W 682.71 N 15 40 W 743.25 N 15 5 W 804.50 N 14 53 W 864.85 N 15 2 W 924.72 N 19 55 W 986.38 N 20 51 W 1050.16 N 20 5~_ W 1111.95 N Z0 31 W 1171.74 N Z0 3 W 1231.07 N 19 45 W 1289.45 N 19 1Z W 1346.82 N 18 5? W 1403.03 N 19 13 W 1458.10 N 19 15 W 1512.36 N 19 36 W 1566.33 N 19 45 W 1620.77 N ZO 5 W 1676.87 N 20 32 W 1734.43 N 20 42 W 1792.08 0.00 N 0 0 E 0.68 N 35 54 E 1.45 N 26 42 E 2.26 N 18 36 E 3.35 N 11 27 E '-~ 8.78 N 4 46 W 21.33 N 9 46 W 40.48 N 11 0 W 65.81 N 12 18 W 96.26 N 13 57 W 3.43 3.87 2.86 2.87 2.53 1.36 0.46 0.52 0.49 0.51 127.04 N 35.23 W 131.84 N 15 29 W 155.30 N 49.67 W 172.60 N 16 43 W 209.04 N 65.37 W 219.02 N 17 Z1 W 257.42 N 81.17 W 269.92 N 17 30 W 309.91 N 97.16 W 324.78 N 17 24 W 365.15 N 114.40 W 382-65 N 17 23 W 422.12 N 132.86 W 442.53 N 17 28 W 479.67 N 151.71 W 503.09 N 17 33 W 537.29 N 169.94 W 563.53 N 17 33 W 595.12 N 187.48 W 623.95 N 17 29 W 0.83 0.98 0.98 0.21 1.42 2.97 0.91 1.15 0.26 0 652.77 N 204.27 W 683.98 N 17 22 W 711.26 N 220.80 W 744.74 N 17 14 W 770.67 N 237.17 W 806.34 N 17 6 W 829.19 N 252.81 W 866.87 N 16 57 W 887.38 N 268.24 W 927.04 N 16 49 W 946.38 N 286.57 W 988.82 N 16 50 W 1006.04 N 309.11 W 1052.46 N 17 4 W 1063.78 N 331.13 W 1114.12 N 17 17 W 1119.72 N 352.25 W 1173.82 N 17 27 W 1175.35 N 372.85 W 1233.08 N 17 36 W 0.61 0.92 0.81 0.61 0.45 0.27 0.91 0.70 0.39 0.35 1230.26 N 392.72 W 1291.42 N 1T 42 W 1294.35 N 411.86 W 1348.78 N 17 46 W 1337.54 N 430.18 W 1405.01 N 17 49 W 1389.60 N 448.20 W 1460.10 N 17 52 W 1440.86 N 466.06 W 1514.36 N 17 55 W 1491.76 N 484.06 W 1568.33 N 17 58 W 1543.03 N 502.39 W 1622.76 N 18 2 W 1595.79 N 521.50 W 1678.84 N 18 5 W 1649.76 N 541.49 W 1736.36 N 18 10 W 1703.71 N 561.83 W 1793.96 N 18 15 W 'ARCO ALASKA INC. 2K - 2 KUPARUK NORTH SLOPEr ALASKA COMPUTATION OATE: 16-NOV-89 PAGE 2 DATE OF SURVEY: 12-NOV-IDB KELLY 5USHING ELEVATION: 154.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF.MEASUREO DEPTH TRUE SUB'SEA COURSE VERTZCAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVFRITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET OEG MIN 4000.00 3433.74 3279.74 35 37 4100.00 3514.69 3360.69 36 31 4200.00 3594.13 3440.13 37 56 4300.00 3672.93 3518.93 38 5 4400.00 3751.52 3597.52 38 15 4500.00 3829.97 3675.97 38 23 4600.00 3908.22 3754.22 38 34 4700.00 3986.41 3832.41 38 32 4800.00 4064.63 3910.63 38 34 4900.00 4142.72 3988.72 38 40 5000.00 4221.10 4067.10 38 8 5100.00 4299.66 4145.66 38 18 5200.00 4378.04 4224.04 38 28 5300.00 4456.29 4302.29 38 35 5400.00 4534.32 4380.32 38 44 5500.00 4612.28 4458.28 38 46 5600.00 4690.46 4536.46 38 27 5700.00 4768.80 4614.80 38 21 5800.00 4847.23 4693.23 38 29 5900.00 4925.46 4771.46 38 41 6000.00 5003.25 4849.25 39 3 6100.00 5080.78 4926.78 39 19 6200.00 5158.07 5004.07 39 15 6300.00 5236.34 5082.'34 38 4 6400.00 5315.16 5161.16 38 2 6'500.00 5393.59 5239.59 38 29 6600.00 5471.63 5317.63 38 52 6700.00 5549.29 5395.29 38 59 6800.00 5627.09 5473.09 38 55 6900.00 5704.86 5550.86 38 47 7000.00 5782.78 5628.78 38 45 7100.00 5860.75 5706.75 38 3~? 7200.00 5939.03 5785.08 38 20 7300.00 6018.03 5864.03 37 25 7400.00 6097.61 5943.61 37 21 7500.00 6176.65 6022.$5 38 0 7600.00 6255.33 6101.33 38 0 7700.00 6334.11 6180.11 38 0 7760.00 6381.38 6227.38 38 0 N '20 40 W 1850.11 N 20 20 W 19OB.B2 N 20 0 W 1969.55 N 19 36 W 2031.11 N 19 22' W 2092.93 N t9 22 W 2154.92 N 19 23 W 2217.16 N 19 23 W 2279.48 N 19 21 W 2341.77 N 19 44 W 2404.21 N 13 10 W 2466.29 N 23 18 W 2528.11 N 23 23 W 2590.15 N 23 23 W 2552.36 N 23 24 W 2714.83 N 24 16 W 2777.39 N Z7 50 W 2839.43 N 28 2 W 2901.11 N 29 6 W 2962.66 N 28 17 W 3024.44 N 28 27 W 3086.75 N 28 51 W 3149.32 N 29 20 W 3212.12 N 30 35 W 3273.55 N 30 37 W 3334.21 N 30 33 W 3395.35 N 30 35 W 3457.00 N 30 55 W 351'9.06 N 31 27 W 3580.85 N 31 26 W 3642.64 N 31 58 W 3704.21 N 31 44 W 3765.69 N 31 55 W 3826.72 N 31 50 W 3886.97 N 29 29 W 3946.61 N 28 28 W 4007.26 N 27 47 W 4068.47 N 27 47 W 4129.61 N 27 47 W 4166.29 0.41 2.05 0.33 0.39 0.12 0.22 0.10 0.09 0.26 1.19 0.84 0.18 0.28 0.38 0.08 2.36 0.19 0.42 0.74 0.41 0.52 1.28 0.31 1.31 0.41 0.66 0.77 0.70 0.80 4.21 0.16 I .18 0.99 1.14 1.76 0.00 0.00 0.00 1757.98 N 5~32.35 W 1851.93 N 18 19 W 1812.96 N 602.96 W 1910.60 N 18 23 W 1869.98 N 623.88 W 1971.30 N 18 27 W 1927.91 N 644.73 W 2032.86 N 18 29 W 1986.21 N 665.35 W 2094.69 N 18 31 W ~ 2044.72 N 685.90 W 2156.70 N 18 32 W 2103.45 N 706.58 W 2218.95 N 18 34 W 2162.26 N 7!7.27 W 2281.29 N lCJ 35 W 2221.03 N 747.95 W 2343.59 N 18 36 W 2279.93 N 768.73 W 2406.04 N 13 37 W 2337.69 N 791.48 W 2468.05 N 18 42 W 2394.54 N 815.94 W 2529.73 N 13 48 W 2451.54 N 840.57 W 2591.64 N 18 55 W 2508.69.) N 865.30 W 2653.73 N 19 1 W 2566.08 N 8'90.13 W 2716.08 N 19 7 W 2623.48 N 915.21 W 2778.53 N 19 13 W 2679.28 N 942.98 W 2840.38 N 19 23 W 2734.18 N 972.12 W 2901.86 N 19 34 W 2788.91 N 1001.33 W 2963.23 N 19 45 W 2843.81 N 1030.76 W 3024.86 N 19 55 W 2899.12 N 1060.60 W 3087.03 N 20 5 W 2954.54 N 1090.88 W 3149.49 N 20 15 W 3010.01 N 1121.68 W 3212.21 N 20 26 W 3063.83 N 1152.93 W 3273.58 N 20 37 W 3116.83 N 1184.21 W 3334.21 N 20 48 W 3170.22 N 1215.80 W 3395.36 N 20 58 W 32Z4.07 N 1247.60 W 3457.04 N 21 9 W 3278.21 N 1279.81 W 3519.17 N 21 19 W 3331.91 N 1312.42 W 3581.07 N 21 29 W 3385.51 N 1345.2T W 3643.00 N 21 40 W 3438.87 N 1378.14 W 3704.74 N 21 50 W 3492.10 N 1411.11 W 3766.43 N 22 0 W 3544.91 N 1443.92 W 3827.70 N 22 9 W 3597.04 N 1476.29 W 3888.21 N 22 18 W 3649.02 N 1507.37 W 3948.10 N ZZ 26 W 3702.66 N 1536.93 W 4008.97 N 22 32 W 3757.01 N 1566.18 W 4070.39 N 22 37 W 3811.49 N 1594.90 W 4131.73 N 2Z 42 W 3844.18 N 1612.14 W 4168.54 N 22 45 W ARCO ALASKA INC. 2K - 2 KUPARUK NORTH SLOPE· ALASKA COMPUTATION DATE: 16-NOV-BO PA~E 3 DATE OF SURVEY: 12-NOV-lO8 KELLY BUSHING ELEVATION: 15~.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DEG MIN 0.00 0.00 -15~.00 0 0 1000.00 982.41 82B.41 22 18 2000o00 1812.35 1658.35 36 47 3000°00 2605.99 2451.99 35 24 4000.00 3433.74 3279.74 35 37 5000.00 4221.10 4067.10 38 8 6000.00 5003.25 4849.25 39 3 7000.00 5782.78 5628.T8 38 45 7760°00 6381.38 6227.38 38 0 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN N 0 0 ~i O.OO N ZO 20 W 131.26 N 15 57 W 682.71 N 19 45 W 1289.45 N ZO 40 W 1850.11 N Z3 10 W 2466.Z9 N 28 27 W 3086.75 N 31 58 W 3704.21 N 27 47 W 4166.29 0.00 3.43 0.83 0.61 0 0.84 0 .~1 4.21 0.00 0.00 N 0.00 E 0.00 N 0 0 E 127.04 N 35.23 W 131.84 N 15 29 W 652.77 N 204.27 W 683.g8 N 17 Z2 W 1230.26 N 3gZ.72 W 1291.42 N 17 42 W 1757.98 N 532.35 W 1851.93 N 18 19 W 2337.69 N 791.48 W Z468.05 N 18 42 W 2899.12 N 1050.60 W 3087.03 N 20 5 W 3438.87 N 13'78.14 W 3704.74 N 21 50 W 3844.18 N 1612.14 W 4168.54 N 22 ~5 W ARCO ALASKA INC. 2K - 2 KUPARUK NORTH SLOPE, ALASKA C3MPUTATION DATE: 15-NOV-89 PA~E 4 DATE gF SURVSY: 12-NOV-198 KELLY 5USHING ELEVATZDN: 154.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 ~EET OF SUB-SEA DEPTH TRUE SUB-SEA COURS~ tEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0o00 0.00 -154.00 0 0 N 0 0 E 154.00 154.00 0.00 0 28 N 19 6 E 254.01 254.00 100.00 0 28 N 3 37 E 35¢.0! 354.00 200.00 0 34 N I 30 W 454.06 454.00 300.00 3 29 N 15 7 W 554.56 554.00 400.00 7 31 N 13 ? W 655.88 654.00 500.00 11 22 N 12 15 W 758.68 754.00 600.00 14 51 N 14 32 W 862.99 854.00 700.30 18 17. N 17 52 W 969.39 954.00 800.00 21 26 N 19 57 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. &ZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 1078.23 1054.00 900.00 25 14 1190.65 115¢.00 lOOO.O0 28 50 1306.82 1254.00 1100.00 32 18 1426.97 1354.00 1200.00 34 57 1550.55 1454.00 1300.00 36 50 1676.09 1554.00 1400.00 37 16 1801.62 1654.00 1500.00 37 12 1927.08 1754.00 1600.00 36 58 2052.19 1854.00 1700.00 37 27 2179.12 1954.00 1800.00 37 49 0.00 0.00 0.00 N 0.00 E 0.56 0.23 0.91 N 0.56 c 1.39 0.00 1.75 N 0.71 ~ 2.19 0.72 2.61 N 0.72 E 4.86 5.31 5.Z7 N 0.17 E 14.53 3.03 14.73 N 2.16 W 30.57 4.76 30.54 N 5.72 W 54.10 3.00 53.67 N 11.11 W 83.62 3.57 82.06 N 19.47 W 119.87 2.41 116.35 N 2304.93 2054.00 1900.00 37 6 2430°30 2154.00 2000.00 37 36 2559.06 2254.00 2100.00 39 43 2687.27 Z354.00 2200.00 37 10 2812.08 2454.00 2300.00 36 35 2936.06 2554.00 2400.00 35 48 3058.75 2654.00 2500.00 34 56 31B0.04 2754.00 2600.00 34 1 3299.98 2854.00 2700.00 33 7 3419.00 2954.00 2800.00 32 35 N ZO 46 W 162.79 N 19 ~ W 214.09 N 17 7 W 273.08 N 17 10 W 339.52 N 17 57 W 412.00 N 18 3 W 487.79 N 17 12 W 563.56 N 16 21 W 539.12 N 15 46 W 714.04 N 15 13 W 791.87 3537.90 3054.00 2900.00 32 55 3657.67 3154.00 3000.00 34 18 3779.71 3254.00 3100.00 35 3902.08 3354.00 3200.00 35 19 4024.93 3454.00 3300.00 35 43 4149.24 3554.00 3400.00 37 31 4275.96 3654.00 3500.00 38 1 4403.16 3754.00 3600.00 38 15 4530.69 3854.00 3700.00 38 28 4658.56 3954~. O0 3800.00 38 33 N 14 52 W 867.81 N 15 58 W 943.02 N 20 55 W 102~,.06 N 20 53 W 1104.27 N 20 29 W 1178.95 N 19 54 W 1252.22 N 19 25 W 1323.279 N 18 55 W 1391.89 N 19 13 W 1458.09 N 19 21 W 1522.61 N 19 39 W 1586.90 N 19 55 W 1652.80 N JO 27 W 1722.76 N 20 42 W 1793.29 N 2.0 3'~) W 1864.64 N 20 8 W 1938.47 N 19 41 W 2016.30 N 19 22 W 2094.89 N 19 24 W 2173.99 N 19 23 W 2253.67 0.00 N 0 0 E 1.06 N 30 43 E 1.89 N 21 56 E 2.71 N 15 24 E 5.27 N I 52 E 14.89 N 8 ZO W 31.07 N 10 35 W 5z+.BO N 11 4,1 W ~4.34 N 13 20 W 31.30 W 120.49 N 15 3 W 3.90 2.77 2.69 I .58 I .23 0.42 0.49 0.56 2.21 1.32 156.54 N 46.35 W 163.26 N 16 29 W 204.76 N 63.90 W 214.49 N 17 19 W 260.90 N 82.26 W 273.56 N 17 29 W 324.59 N 101.68 W 340.14 N 17 23 W 3'93.80 N 1.23.60 W 412.74 N'17 25 W 465.91 N 147.24 W 488.62 N 17 32 W 538.23 N 170.23 W 564.51 N 17 33 W 610.76 N 192.09 W 640.26 N 17 27 W 683.02 N 212.85 W 715.42 N 17 18 W 758.33 N 233.82 W 793.56 N 17 8 W 0.23 3.81 0.54 2.16 0.30 0.62 0.93 0.91 0.61 0.68 832.06 N 253.57 W 869.84 N 16 56 W 905.09 N 273.16. W 945.41 N 16 47 W 981.66 N 299.80 W 1026.4.2 N 16 58 W 1056.60 N 328.39 W 1106.46 N 17 15 W 1126.47 N 354.78 W 1181.01 N 17 28 W 1195.24 N 380.08 W 1254.22 N 17 38 W 1262.15 N 404.08 W 1325.25 N 17 45 W 1326.99 N 4~6.57 W 1393.87 N 17 ~,9 W 1389.59 N 448.20 W 1460.09 N 17 52 W 1450.54 N 469.45 W 1524.61 N 17 56 W 0.25 2.54 0.43 0.36 0.46 1.51 0.28 0.12 0.32 0.14 1511.16 N 490.97 W 1588.89 N 17 59 W 1573.15 N 513.27 W 1654.78 N 18 4 W 1638.83 N 537.41 W 1724.69 N 18 9 W 1704.84 N 562.26 W 1795.16 N 19 15 W 1771.58 N 587.48 W 1866.45 N 19 20 W 1840.79 N 613.21 W 1940.26 N 18 25 W 1913.96 N 639.75 W 2018.05 N 18 28 W 1988.06 N 666.00 W 2096.65 N 18 31 W 2062.72 N 692.23 W 2175.77 N 18 33 W 2137.89 N 718.70 W 2255.46 N 18 34 W ARCO ALASKA INC. 2K - 2 KUPARUK NORTH SLOPEr ALASKA COMPUTATION D~TE: 16-NOV-89 PAGE 5 DATE OF SURVEY: 12-NOV-198 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: G. SAR~ER INTERPQLA'TED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURS6 MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 4786.41 4054.00 3900.00 38 32 491¢.45 4154.00 4000.00 38 38 5041o85 4254.00 4100.00 38 13 5169.30 4354.00 4200.00 38 25 5297.08 4454.00 4300.00 38 35 5425.23 4554.00 4400.00 38 45 5553.42 4654.00 4500.00 38 30 5681.12 4754.00 4600.00 38 24 5808.65 4854.00 4700.00 38 29 5936.63 4954.00 4800.00 38 55 6065.42 5054.00 4900.00 39 10 6194.75 5154.00 5000.00 39 21 6322.43 5254.00 5100.00 38 2 6449.45 5354.00 5200.00 38 23 6577.37 5456.00 5300.00 38 48 6706.06 5554.00 5400.00 38 57 6834.60 5654.00 5500.00 38 55 6963.02 5754.00 5600.00 38 45 7091.36 5854.00 5700.00 38 33 7219.00 5954.00 5800.00 38 9 7345.21 6054.00 5900.00 37 13 7471.24 6154.00 6000.00 38 5 7595.31 6254.00 6100.00 37 57 7760.00 6381.38 6227.38 38 0 N 19 22 W 2333.30 N 20 0 W 2413.24 N 23 18 W 24,92.13 N 23 23 W 2571.08 N 23 23 W 2,650.54 N 23 2'~ W 2730.61 N 26 56 W 2810.64 N 28 0 W 2889.4~8 N 28 7 W 2968.00 N 28 18 W 3047.21 N 28 43 W 3127.64 N 29 15 W 3208.85 N 30 32 W 3287.18 N 30 3 7 W 3364.38 N 30 33 W 3443.00 N 30 59 W 3522.81 N 31 31 W 3602.22 N 31 35 W 3681.40 N 31 43 W 3760.41 N 31 55 W 3838.27 N 31 9 W 3913.87 N 28 38 W 3989.70 N 27 50 W 4067.44 N 27 47 W 4166.29 0.13 1.94 0.29 0.20 0.39 0.08 2.27 0.19 0.42 0 0.42 0.91 0.51 0.46 0.30 0.72 I .29 1.06 0.29 1 2.36 0.71 2.88 0.00 2213.04 N 745.14 W 2335.12 N 18 36 W 2288.44 N 771.78 W 2415.08 N 18 38 W 2361.46 N 801.69 W 2493.83 N 18 45 W 2434.02 N 832.99 W 2572.61 N 18 53 W 2507.02 N 864.57 W 2651.91 N 19 I W '. 2580.57 N 896.41 W Z731.83 N 19 9 W 2935.36 N 10~0.35 W 3127.85 N 20 12 W 3007.13 N 1120.05 W 3208.95 N 20 25 W 3075.74 N 1159.96 W 3287.20 N 20 39 W 3143.16 N 1199.81 W 3364.38 N 20 53 W 3211.84 N 1240.38 W 3443.03 N 21 6 W 3281.48 N 1281.77 W 3522.93 N 21 20 W 3350.45 N 1323.77 W 3602.48 N 21 33 W 3419.11 N 1365.94 W 3681.86 N 21 46 W 3487.52 N 1408.28 W 3761.12 N 21 59 W 3554.89 N 1450.14 W 3839.29 N 22 11 W 3620.35 N 1490.67 W 3915.23 N 22 22 W 3687.09 N 1528.45 W 3991.34 N 22 30 W 3756.10 N 1565.70 W 4069.36 N 22 37 W 3844.18 N 1612.14 W 4168.54 N ZZ 45 W ARCO ALASKA 2K - 2 KUPARUK NORTH SLOPEr INCo ALASKA H~RKER 9 5/8" CSG. m-B-T-B 7" CSG. TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A GCT LAST READING BASE KUPARUK A TD 5" LINER COMPUT/~TI ON DATE: 16-NOV-89 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 6 1Z-NOV-lg8 154.00 FT G. SARBER INTERPOLATED MEASURED DEmTH ~ELOW KB 3404.00 7217.00 7404.00 7460.00 7460.00 7600.00 7604°00 7760.00 7760.00 VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = TVD FROM KB 2941.37 5756.33 5952.43 6100.79 6145.15 6145.15 6255.33 6258.48 6381.38 6381.38 CAT SURFACE), SECZ, TION, RSE R~CTANGUL SU8-SEA NORTH/SO 2787.37 1442.g0 5602.33 3420.70 5798.43 3553.84 5946.79 3651.13 5991.15 3681.02 5991.15 3681.02 6101.33 3757.01 6104.48 3759.19 6227.38 384~.18 6227.38 3844.18 AR COORDINATES UTH EAST/WEST N 466.78 W N 1366.92 W N 1449.49 W N 1508.57 W N 1525.13 W N 1525.13 W N 1566.18 W N 1567.33 W N 1612.1~ g N 1612.14 W 'ARCO ALASKA 2K - 2 KUPARUK NORTH SLOPE INC. ALASKA MARKER 9 5/8" CSGo PBTD 7" CSG. TOP KUPARUK EASE KUPARUK TOP KUPARUK BASE KUPARUK TD 5" LINER C C A A COMPUTATION OATE: 16-NOV-S9 ***~*~,~ ~ STRATIGRAPHIC SUMM~RY SURFACE LOCATION = MEASURED DEPTH TVD BELOW KB FROM KB KELLY CAT SURFACE) SUB-SEA 3404.00 29~,1.37 2787. ~7 6966.00 5756.33 5602.33 7217.00 5952.43 5798.43 7404. OD 6100.79 5946.79 7450.00 6145.15 5991.15 7460.00 6145.15 5991.1 5 7604.00 625'3.48 6104.48 7760°00 6381.38 6227.38 7760°00 6381.38 6227.38 DATE BUSHING SECZ, REC NO OF SURVEY: ELEVATION: ENGINEER: PAGE 7 12-N~V-198 I54.00 FT O. SARBER TI~N~ RSE TANGULAR COBRD RTH/SOUTH EAS IN~TES T/WEST 44Z.90 N 466.78 W 420.70 N 1366.92 W 553.84 N 1449.49 W 651.13 N 1508.57 W 681.02 N 1525.13 W 681.02 N 1525.13 W 759.19 N 1567.33 W 844.18 N 1612.14 W 844.18 N 1612.14 W FINAL MEASURED DEPTH 7760.00 WELL LOCATION TRUE VERTICAL DEPTH 6381.38 AT TO: SUB-SEA VERTICAL DEPTH 6227.38 HgR!Z~NTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4168.54 N 22 45 SCHLUMBERGER O ~ REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC. WELL 2K- 2 FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 12 - NOV - 89 REFERENCE 73S46 WELL ' (271 ' 2K-2 FSL, 94' FEL, SEC 2, TION, R8E, UM) ,IZONTAL PROJECTION NORTH 6000 REF 7~46 SCALE : 1/I000 IN/F !'"T": "~ -'?'"'r : ...... · : : ~ : ' : ~ · : ~ ........... .k.-:...-...-~--~..;. ;.--~ .......................................... '-t ............... ..... ........ ...~...L.~.~..-j..-.~...~...~...~.--..~.-+.-~ ............ !'-! 's~ ~'"~ t '~ .... T'"' '"I ..... ~' ? ...... t" r : . i ~ : . ~ . ! ......... ~ .............. , .............. ~.- ...... ', .................... : . . , : , · ~ . ..: .... t..~...~.......~ ........ ,....,..-,....r-.,..-~.-~..-~ ......... t ~-? 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T"r'T'-~'"~"T'T'] .~ ..... L..~ ........ ~..L..~ ........ :.4 .................. ~ ........... ,.~..~ ........... : ......... i ....................................... ~ .............. SOUTH -2000 '"T-"F"~'"T"]''T''?''~ ................ r"'"'/"~ ; ' ' ~ ' I : ' ' _ , nnn ~nnn qnAA 400Q -4000 -~000 -2000 - ] 000 0 1000 EAST NEST WELL · (271 ' 2K-2 FSL, ~ "--'"~VERTICAL PROJECTION 94' FEL, SEC 2, TION, R8E, UM) -2000 - !000 0 0 1000 2000 3000 4000 5000 RO00 340. PROJECTION ON VERTICAL PLANE 940. - 160. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/1oo0 IN/FT ARCO Alaska, Inc. Date: October 20, 1989 Transmittal #: 7579 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File 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. 2K-02 CBLog 1 1 -1 2-89 7400-7636 2Z-18 TMD 08-27-89 5950-6100 Receipt Acknowledged: DISTRIBUTION: Date' _R.E_C.E_ I V E D Nov2V1989 Alaska Oil & Gas Cons. Commissio? Anchorage Drilling NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: July 7, 1989 Transmittal #: 7512 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 2 K - 0 2 OH EDIT Tape and Listing 6 - 3 0 - 8 9 # 7 3 3 8 2 Receipt Acknowledged: ~.sl~.~ 0il & (~as Cons. ........................... Date: ............ DISTRIBUTION: State of Alaska Lynn Goettinger ARCO Alaska, Inc. Date: July 7, 1989 Transmittal #: 7507 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 2 K - 02 2" Dual Induction - SFL 6 - 1 9 - 8 9 I 000 - 771 8 2K-02 5" Dual Induction - SFL 6-19-89 1000-7718 2K-02 2" & 5" Raw FDC 6-19-89 7236-7692 2K-02 2"& 5" Porosity FDC 6-1 9-89 7236-7692 2K-02 Cyberlook 6-1 9-89 7250-7650 Gas Cons. Comm;ss!o[~ ~qchora[le Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: State of Alaska(+sepia) NSK D&M Franzen Drilling STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 271' FSL, 94' FEL, Sec. 2, TION, R8E, UM At top of productive interval 1313' FNL, 1514' FEL, Sec. 2, TION, R8E, UM (Approx) At effective depth 1546' FNL, 1383' FEL, Sec. 2, TION, R8E, UM (Approx) At total depth 1114' FNL~ 1629' FEL~ Sec. 12. Present well condition summary Total depth: measured true vertical 2~ TION;, R8E~ UM (Approx) 7770' MD feet 6379' TVD feet 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ Plugs (measured) None 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-2 9. Permit number 88-121 10. APl number 50-- 103-20101 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured true vertical 6966' MD feet Junk (measured) None 5747 ' TVD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3363' 7182' measured None true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured depth 16" 179 sx AS I I 9-5/8" 880 sx AS III, 450 sx C1 G 7" 375 sx Class G 115' MD 3404 ' MD 7217' MD 5II None None 130 sx Class G 7768' MD RECEIVED JU L, - 5 i989 Naska 0il & Gas Cons. Commission Anchorage feet True vertical depth 115' TVD 2939' TVD 5943 ' TVD 6378 ' TVD Date ~//'2.. ~/~' Date SUBMIT IN TRIPLICATE ~" 13. Attachments Description summary of proposal __ Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation September 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ '~~~ k./ Title Area Drilling Engineer / FOR COMMISSION USE ONLY (TWM) 5A1/8 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commission Commissioner JApproval No. Approved Oopy Returned '¢-- Form 10-403 Rev 06/15/88 APPLICATION FOR SUNDRY APPROVALS 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 Istat~.K Field [Lease or Unit ~('[]P~]~ I~TV]~.I~ rJl~lT'l~ ~F~T. '~RR AT.W ~"/~_ Auth. or W.O. no, [Title a~'~Tq DRILLING IWell no. Operator I^RCO W.I. Spudded or W.O. begun [Date [Hour .~pnn 0~_/04/"_9 Date and depth Complete record for each day reported as of 8:00 a.m. F)C~YC~kT I 4 06/04/89 ( TD: 180'( SUPV:ZR 06/05/89 ( TD: 2625' ( 2 SUPV:ZR 06/06/89 ( TD: 3424'( SUPV:ZR 06/07/89 ( TD: 3950'( SUPV:ZR 06/08/89 ( TD: 6690'( 2 SUPV:ZR 06/09/89 ( TD: 7266'( SUPV:ZR '' llYr~}"~atus if a W.O. .) .80) :) ,45) ~) '99) ) 26) ) 40) ) 76) DRILLING SURFACE HOLE MW: 0.0 VIS: ACCEPT RIG 0230 6-4-89,NU DIVERTER, RISER, FLOWLINE,PU BHA, TEST DIVERTER FOR LEAKS, SPUD IN AND DRILL TO 180'.SPUD AT 0530,6-4-89. DAILY=S25,620 CUM=$25,620 ETD=S25,620 EFC~$693,600 DRILLING SURFACE HOLE MW: 9.4 VIS: 52 DRILL 180-1575,CBU AND PUMP SWEEP PILL, SHORT TRIP TO KOP,TIGHT, SAW COAL AND WOOD, CIRC AND DROP SINGLE SHOT, TOH TIGHT AT 1407-1501,CHG OUT BHA, PU BENT HOUSING NAVI,TIH AND DRILL AHEAD. DAILY:S63,552 CUM:$89,172 ETD:S89,172 EFC=$693,600 RUNNING 9-5/8" CASING. MW: 9.4 VIS: 66 DRILLED FROM 2,625' TO 3,424'. ADT-4HRS. CIRCOLATE AND CONDITION HOLE. SHORT TRIP TO KOP (400'). TIGHT GOING IN AT 1,596'. WASHED FROM 1,596' TO 1,682'. ALSO WASHED FROM 1,975' TO 2,208'. CIRULATE AND CONDITION HOLE. PUMPED DRY JOB AND POOH. L/D BHA.(TOOK 54 BBL TO FILL HOLE.) R/U AND RUN 9-5/8" CASING. HIT VERY TIGHT SPOT W/JT 957 ~ 2,209'. PUMP THRU. MAIN DRIVE CHAIN ON DRAW WORKS BROKE. REPAIRED IT WHILE CIRCULATING EVERY HALF HOUR WITH FULL RETURNS. CONT'D TO RUN 9-5/8" CSG AND CONT'D TO HIT TIGHT SPOTS THRU JT 9 66. ALL CLEAR PAST %66. DAILY=$95,085 CUM=$184,257 ETD:S184,257 EFC=$693,600 DRILLING 8-1/2" HOLE 9-5/8"% 3404' MW: 8.7 VIS: 31 RIG UP AND CIRC 9-5/8" CSG, PUMP 80 BBLS WATER, 880 SX ASIII,450 SX G CEMENT, DISPLACE AND BUMP PLUG, FLOATS HELD, TEST CSG TO 2000 PSI,FULL RETURNS,NO CEMENT TO SURFACE,RD DIVERTER, DO TOP JOB WITH 105 SX AS I,NO BOP STACK AND TEST SAME, SET WEAR RING, PU AND ORIENT BHA, CUT DRILL LINE, TIH, DRILL OUT FLOAT COLLAR, TEST CSG TO 2000,DRILL OUT SHOE AND 10' HOLE, TEST FORMATION TO 12.5 PPG EMW, NO LEAK OFF, DRILL AHEAD IN 8-1/2" HOLE. DAILY:S121,067 CUM~$305,324 ETD=S305,324 EFC=$693,600 DRILLING 8-1/2" HOLE 9-5/8"~ 3404' MW: 9.3 VIS: 32 DRILL 8-1/2" HOLE 3950-6690. DAILY=S47,717 CUM~$353,041 ETD:S353,041 EFC=$693,600 9-5/8"@ 3404' MW:10.2 VIS: 40 DRILL 6690-7266, TOH FOR BIT~PU ROCK BIT AND ROTARY BHA, TIH, REAM 7236-7266,CIRC AND HOLE PACKING OFF, TRIP BACK TO SHOE,APPEAR TO BE SWABBING IN FLUID ALTHOUGH KUPARUK NOT OPEN YET, CBU AT SHOE, NO LOSSES, TIH 10 STANDS,CBU, LOST 30 The above is correct AR3B-459-1 -D d{~ ~-~ ~8. S O0]~S. f'"~r"~Tt~c'c~;~"" Number all dally well hlsto~ forms con,cutively iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. .District J ICounty or Parish J SfateAK ARCO ALASKA INC. I NORTH SLOPE Field ~Lease or Unit KUPARUK RIVER UNIT [ 2K-2 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 06/10/89 ( TD: 7468'( SUPV:ZR 06/11/89 ( TD: 7468'( SUPV:ZR 06/12/89 ( TD= 7468'( SUPV=ZR 06/13/89 ( TD: 7468'( SUPV:ZR 06/14/89 ( TD: 7468'( SUPV:ZR 7) 202) 8) 0) a) 0) O) O) 1) O) The above is correct Signa For form prepauj~o~ and distributio~ see Procedures Iki.~ual Section 10, Drilling, Pages 86 and 87 CIRC OUT GAS COT MUD 9-5/8"8 3404' MW:10.5 VIS= 39 TIH, CIRC & CHK FOR FLOW, SPOT LCM PILL, TOH ABOVE PILL 8 STDS,CIRC & CHK FOR FLOW, TIH TO BTM, CIRC & CHK FOR FLOW, INC PUMP RATE TO DRLG RATE,DRILL 7266- 7468,DRILLING BRK IN A SAND,FLOW ON CONNECTIONS,GAS CUT MUD,SI WELL, NO PRES ON DP,35-409 SICP,CIRC & WT UP TO 10.4,TREAT MUD W/ LCM, RAISE WT TO 10.5,CONTINUE CIRC AND MOVING PIPE, RAISE WT TO 10.6,WELL STABLE,NO PRESSURE ON DP OR CSG. DAILY:S58,062 CUM:$466,727 ETD:S466,727 EFC=$693,600 CIRCULATING ON BOTTOM 9-5/8"@ 3404' MW=10.7 ViS: 41 CIRC & WT UP TO 10.6,MONITOR WELL,WT UP TO 10.8,CIRC OUT 9.2 MUD,HOLE TAKING FLUID, SPOT LCM PILL, FILL HOLE FR BACK SIDE,HOLE GIVING AND TAKING FLUID, PUMP LCM PILL, RETURNS STILL GAS CUT, HOLE TAKES FLUID AT HIGHER PUMP RATES,CONTINUE PUMPING LCM PILLS,MONITOR WELL,CIRC 10.7 IN,GETTING 10.7 OUT, CONTINUE TRYING TO STABILIZE FOR SHORT TRIP. DAILY:S76,304 CUM:$543,031 ETD:S543,031 EFC:$693,600 CIRC GAS CUT MUD 9-5/8"8 3404' MW=11.0 ViS= 43 CIRC AND BUILD VOLUME. PUMP LCM PILL. MONITOR WELL. PUMP AND SPOT LCM PILL. POOH 10 STDS. TOOK 18 BBL GAIN. TIH GAIN 20 BBLS. CIRC AND MIX LCM PILL. WEIGHT UP TO 10.9 PPG. CIRC. LOST RETURNS. MIXED AND PUMPED SUPER LCM PILL. PARTIAL RETURNS. CIRC AND MONITOR WELL. DAILY:S66,440 CUM=$609,471 ETD=S609,477 EFC:$693,594 TOH TO SET CMT PLUG 9-5/8"@ 3404' MW:11.1 VIS: 44 PUMP LCM PILL, CIRC & MONITOR WELL, LOST RETURNS, SHORT TRIP 20 STDS, TIH, LOST RETURNS,CIRC & MONITOR, PUMP LCM PILLS, KEEP HOLE FULL ON BACKSIDE,TOH 47 STDS, SWAB WELL IN,MONITOR WELL 450' ABOVE SHOE, SPIN BHA TO CLEAN STAB'S,WELL FLOWING, TIH 36 STDS,ATTEMPT TO CIRC,NO RETURNS,MONITOR WELL,HOLE STABLE 11 STDS OFF BTM, TOH TO SET CEMENT PLUG, AT BHA AT REPORT TIME,HOLE APPEARS STABLE ON TOH, STDS BREAKING WET OR DRY ERRATICALLY. DAILY:S68,142 CUM:$677,613 ETD:S677,613 EFC=$693,600 TOH FOR BIT TO DRL CMT 9-5/8"@ 3404' MW:10.8 VIS= 46 PU MULE SHOE, TIH TO BTM, CIRC & MONITOR WELL, HOLE STABLE, SPOT BALANCED CMT PLUG 170 SX NEAT G, TOH 9 STDS,CIRC W/ NO RETURNS,FILL BACKSIDE, TOH TO SHOE, HOLE STAYED FULL, COND MUD ON SURFACE & MONITOR WELL, CIRC 11.1 MUD,LOST RETURNS, FIL BACKSIDE,CONTINUE LOSING MUD, TIH,MIX MUD & LCM, TIH & TAG HARD CMT @ 7133,PULL i STD, GAINED& THEN LOST MUD, PUMP LCM PILL, MONITOR, STILL LOSING, SHUT DOWN PUMP HOLE STABLE,PULL TO SHOE, EST TOTAL MUD LOSS TO DATE APPROX 2000 BBLS. Wall no, AR3B-459-2-B P,~,~ F/, :), (~a.s (10i~S, Oorp. t'r~iSSiOli [Number all daily well history , .... ~ as they are prepared for each well. consecutively r .. L., ... ~,~ ~ I IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. County or Parish IState ARCO ALASKA INC. NORTH SLOPE I AK Lease or Unit KUPAROK RIVER UNIT 2K-2 Complete record for each day while drilling or workover in progress DO¥ON 14 HARD CMT & 7133,-u''~ ~ ~' $1D GAinED & iHE~ ~u~---~ hub,~u- ~m PILL, MONITOR, STILL LOSING, SHUT DOWN PUMP,HOLE STABLE,PULL TO SHOE, EST TOTAL MUD LOSS TO DATE APPROX 2000 BBLS. -DAILY:S149,142 CUM:$826,755 ETD:S826,755 EFC:$693,600 06/15/89 ( TD= 7468'( SUPV:ZR 06/16/89 ( TD: 7235'( SUPV:ZR 06/17/89 ( TD: 7235'( SUPV:ZR 06/18/89 ( TD: 7375'( SUPV:ZR 06/19/89 ( TD: 7590'( SUPV:ZR L2) JWell no. L3) CIRCULATE ON BOTTOM 9-5/8"g 3404' MW:10.8 VIS: 43 TOH W/ OPEN ENDED DP,MU BIT & BHA, TIH TO SHOE, COULDN'T CIRC, BIT PLUGGED,TOH, WELL FLOWING, TIH TO SHOE,CIRC OUT GAS CUT MUD,STAGE IN 20 STDS,CIRC & REAM BRIDGE AT 5247-5300,GAS CUT MUD,STAGE IN 10 STDS,WELL FLOWING, CONT TO CIRC GAS CUT MUD, TIH TO 7014,CIRC 10.8 IN, 10.2 TO 10.6 OUT,WASH TO 7152, TAG PLUG AT 7152,LOST 49 BBLS MUD, DRILL CMT TO 7235,CIRC 10.8 IN,10.8 OUT, PREPARE TO TOH FOR 7" INTERMEDIATE CASING.PROBLEM ZONE IS LIKELY COLVILLE AND/OR FAULT. DAILY:S125,332 CUM:$952,087 ETD:S952,087 EFC:$693,600 L4) O) 7"8 7217' MW:10.8 VIS: 43 CIRC 10.8 IN, 10.8 OUT W/ 60 % RETURNS,PULL 5 STDS,WELL FLOWING, TIH, INC MW TO 10.9 PPG, STABILIZE WELL, PULL TO SHOE, WELL STILL FLOWING, INC MW TO 11.0 PPG, TOH KEEPING HOLE FULL, RU & RUN 185 JTS 7" CSG, LOST PARTIAL RETURNS WHILE RUN- NING PIPE,CIRC AT SHOE, RUN IN TO BTM, RU DS,CIRC W/ 20% RETURNS,PUMP 10 BBLS WATER, 250 SX 12.5 PPG G, 125 SX 15.8 PPG G, DISPLACE W/ MUD AND RIG PUMPS,BUMP PLUG TO 3000 PSI,FLOATS OK, PARTIAL RETURNS DURING JOB,PREP TO ARTIC PAK ANNUL. DAILY:S168,462 CUM:$1,120,549 ETD:S1,120,549 EFC:$693,600 LS) 140) RIH W/ CMT BOND LOGS 7"8 7217' MW:10.7 VIS: 44 ARCTIC PACK 7" X 9-5/8" ANNULUS,WO ARCTIC PACK, BLEED OFF ANNULUS & MONITOR, ND BOP,SET SLIPS ON 7",CUT CSG, INSTALL PACKOFF,NU BOP STACK, TEST TO 3000,CHG OUT RAMS AND KELLY TO 3-1/2",PULL TEST PLUG & INSTALL WEAR BUSHING, LD STABS, STD BACK MONELS, LD 5" DP,RU SCHLUMBERGER, RIH W/ CET, CBT BOND LOGS. DAILY:S98,798 CUM:$1,219,347 ETD:S1,219,347 EFC:$693,600 ,6) 215) DRILLING 6-1/8" HOLE 7"@ 7217' MW:11.0 VIS: 51 RUN CET/CBT BOND LOGS ON 7" CSG, RD SOS,PU & MU BHA, PU 3-1/2" DP OFF RACK, TIH, TAG FLOAT COLLAR, TEST CSG TO 2000,CLEAN OUT TO 7245,CIRC & COND MUD,WT UP TO 11.0 PPG, EVEN OUT SYSTEM, RUN LEAK OFF TEST TO 12.5 EMW, DRILL AHEAD TO 7375. DAILY:S55,951 CUM:$1,275,298 ETD:S1,275,298 EFC:$693,600 For form prepalCa~on and distribu~ see Procedure~l~lanual Section 10, Drilling, Pages S'6 and 87 DRILLING 6-1/8" HOLE 7"8 7217' MW:11.1 VIS: 54 DRILL SLIM HOLE 7375-7425,FLOW INCREASE,PU,CHK FOR FLOW, NO FLOW, GAS CUT MUD, WT UP TO 11.1 PPG, DRILL 7425-7476, DRLG BRK, NO FLOW, CBU,DRILL 7476-7513,CIRC, DROP SINGLE SHOT, TOH, C~G BIT. TIH. REAM 60' TO BTM. DRILL 7520-7590. DAILY:~81,987 CUM:~1,357,285 ETD:$1.357,Z85 EFC:$693.600 AR3B-459-2-B Number all daily well history torms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formalion name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish IState ARCO ALASKA INC. NORTH SLOPE I AK Field Lease or Unit KOPAROK RIVER UNIT 2K-2 Complete record for each day while drilling or workover in progress DOYON 14 Date and deptll as of 8:00 a.m. 06/20/89 ( TD= 7720'( SUPV:ZR 06/21/89 ( TD: 7770 PB: SUPV:ZR 06/22/89 ( TD: 7770 PB: SUPV:ZR 17) 130) 18) 19) TIH TO DRILL RATHOLE 7"@ 7217' MW:ll.1 VIS: 51 DRILL 7590-7720,CBU,PUMP DRY JOB, TOH, RU SCHLUMBERGER, LOG W/ TRIPLE COMBO,RD SCHLUMBERGER, TIH W/ BIT TO DRILL 50' OF RATHOLE AND CONDITION FOR LINER. DAILY:S50,755 CUM:$1,408,040 ETD:S1,408,040 EFC:$693,600 TOH AFTER LINER CMTG 5"@ 7770' MW:11.1WBM TIH FOR WIPER TRIP AND TO DRILL RATHOLE,CBU, TRIP GAS CUT MUD TO 10.0,DRILL 7720-7770,CIRC & COND, DROP SINGLE SHOT, STRAP OUT, LD BHA, RU CSG CREWS TO RUN 5" LINER,RUN 5" LINER W/ BAKER(BROWN) }{MC HYDRAULIC SET HGR, DRIFT DP ON TIH, RUN PIPE @ I MIN PER STAND, RU CMTG HEAD & CIRC, RU DOWELL,TEST LINES,MIX & PUMP 10 BBLS SPACER 3000 & 130 SX G W/ ADDITIVES(27 BBLS},DROP DART, DISPLACE W/ MUD, DID NOT BUMP PLUG, DID NOT SET HANGER, SET LINER ON BOTTOM, RELEASE FROM SET- TING SLEEVE W/ SETTING TOOL, PULL 10 STANDS,REVERSE OUT DP VOLUME, TOH. DAILY:S133,545 CUM:$1,541,585 ETD:S1,541,585 EFC:$693,600 ND BOP STACK 5"@ 7770' MW:11.1WBM FINISH TOH, LD LINER RUNNING TOOLS,PU BIT & BHA, SLIP LINE,STD BACK BHA, WOC, TIH TO 6711,WASH & REAM 6711-6762,TAG CMT 6762,REAM TO 6766, CBU, TEST 5" LINER LAP TO 2500 FOR 30 MIN,OK, PUMP DRY JOB,SET BACK KELLY, TOH LDDP,LEAVE 2000' DP IN DERRICK, LD BHA, TIH TO 2000',DISPLACE W/ 11.1 PPG BRINE,TOH LDDP, SPOT 50' DIESEL CAP,LD 4-1/4" KELLY, PULL WEAR BUSHING,ND BOP STACK. DAILY:S70,016 CUM:$1,611,601 ETD:S1,611,601 EFC:$693,600 JWell no. The above is correct AR3B-459-2-B INumber all daily well history forms consecutively lPage no. as they are prepared for each well. I 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 aisc when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish I State Field ILease orUnit I Well no. Auth. or W.O. no. [Title ~_W_? 5 7 9 J rYll TT.T, TN~. Operator Spudded or W.-~.~'~e-~gn Date and depth as of 8:00 a.m. 06/23/89 ( 2 TD: 7770 PB: SUPV:ZR I A.R.Co. W.I. rrotal number of wells (active or inactive) on this, Icost center prior to plugging and I ~,~bandonment of this well Date ............... PTI6r-sTatus if a W.O. Complete record for each day reported RIG RELEASED 5"@ 7770' MW:11.1 WBM FINISH ND BOP STACK, PULL WEAR RING, NU MASTER VALVE,CLEAN PITS,RELEASE RIG 1200 HRS,6-22-89. DAILY:S45,400 CUM:$1,657,001 ETD:S1,657,001 EFC:$693,600 Old TD New TD PB Depth Released rig Date IK nd of r g I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval OII or gasTest time Production Oil on t'eet 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 Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forme consecutively I Page no. as they are prepared for each well. 1 Division of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: June 30, 1989 Transmittal #: 7502 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 2 K - 0 2 Cement Evaluation Log 6 - 1 7 - 8 9 4 0 0 0 - 7 0 2 6 2 K - 0 2 Cement Bond Log 6 - 1 7 - 9 0 4 0 0 0 - 7 0 4 9 Receipt Acknowledged: Anchorage DISTRIBUTION: NSK D r illi ng State of Alaska(+sepia) MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~¢IlSSION / TO: Lonni e C. Smi t b/?- ~-?¥~; ( DATE: June 1, 1989 / Conani ss ioner FILE NO: ~). HRH. 0 3 9 TELEPHONE NO: THRU: Michael T. Minder ~~/~' Sr. Petroleum Engineer SUBJECT BOP Test AAI KRU CPF-2K-3 Permit No. 88-120 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector//;i?!~ Monday, May 29, 1989, Stand by to test BOP AAI KRU 2K-3. Tuesday, May 30, 1989, I witnessed the BOP Test on AAI KRU CPF 2K-3. T~=~re no ]~z~-'~. I filled out an AOGCC Field report which is at t ached. In summary, I witnessed the BOP test on AAI KRU CPF-2K-3. The tests were satisfactorily. Attachment 02-001A (Rev. 8~85) Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COf~IISSION B.O.P.E. Inspection Report Operator../~.~ Location: Sec ~ T/~ Drilling Contractor ~D Location, General h Uell Sign General Housekeeping,,// Rig Represencative£/3/Yl/ic £ · ACC~LATOR SYST~ Full Charge Pressure _~ ~ psig Reserve Pit F/ Pressure After Closure Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE S tack Annular Preventer Pipe Rams ,, Blind Rams Visual Audio Test Pressure "' Upper Kelly .,~ ~:f ~ " Lower Kelly. Ball Type Pump incr. clos. pres. 200 psig --~ min~ ..sec. Full Charge Pressure Attained: X min/~ .sec. Controls: Master ~ 1~ Remote ~/,&)/ Blinds switch cover~%y _Kelly and Floor ~afety Valves . ' Test Pressure ~~ TeSt Pressure .~~ ~ · s ' Test Pressure ~~ Inside BOP Test Pressure Choke Line Valves It.C.R. Valve Kill Line Valves Check Valve · Test Results: Failures Repair or Replacement of failed equipment to be made within . Commission office notified. Choke Manifold Test Pressure...?/~'~ No. Valy.es ½~ ' No. flanges ~ Adjustable Chokes ~b,~c Hydrauically operated choke Test Time / hrs. day~ and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspend __ Operation shutdown m Re-enter suspended well M · Alter casing __ Repair well __ Plugging m Time extension ~ Stimulate ~ Change approved program J,/' Pull tubing ~ Variance ~ Perforate ~ Other 2. Name of Operator 5. Type of Well: Development __1~ ARCO A1 aska, I nc. Exploratory__ 3. Address Stratigraphic_ P. 0. Box 100360, Anchorage, AK 99510-0360 Service__ 4. Location of well at surface 271' FSL, 94'FEL, Sec. At top of productive interval 1320'FNL, 1500'FEL, Sec. At effective depth 2, TION, R8E, UM 2, TION, R8E, UM At total depth 1143'FNL, 1567'FEL, Sec. 2, TION, R8E, UM 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 3340' 7749' measured true vertical hds hug spudded feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 154' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-2 9. Permit number 88-121 10. APl number 50-- 103-20101 11. Field/Pool Kuparuk River 0il Pool MAY ! feet Junk (measured) feet Alaska 0il & Gas Cer~. 60~i'i~ais$ Anchorage Size Cemented Measured depth True vertical depth 9-5/8" To surface 3376'MD 2930'TVD 500 ' above 7784 'MD 6422 ' TVD Kuparuk This sundry request revises the target for subject well resulting in revised casing setting depths and directional plan. 13. Attachments Description summary of proposal Revised Birectional Plan Detailed operations program BOP sketch 14. Estimated date for commencing operation June 1, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ Title Area Drilling Engineer Signed -'~ ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date ~-/1 b~//,~ '~ (TWM) SAI/1 No. ¢) _. Approveo Copy ' - Plug integrity ~ BOP Test ~ Location clearance ~ ,'¢o Mechanical Integrity Test __ Subsequent form required 10- ~:iig4NAL SIGNED ~Y CONNIE C. SMITH Approved by order of the Commission Returned Commissioner Date ..'.'.¥'-~/2¢''' 0¢'~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 ~ ARCO ALASKA, !ne. Pad 2K. Wel I No~ 2 Revisecl Proposal Kuparuk Field. North Slope. Alaska RKB ELEYAT[ON, 154' 1000 2000 KOP TVD=400 TMD=400 DEP=O 3 g 15 21 27 33 BUILD 3 OEO PER 100 FT B/ PERMAFROST TVD--!424 TMD=1481 DEP=298 T/ UGNU SNDS TVD=1544 TMD=1627 DEP=381 EOC TVD=1565 THD--1653 DEP-397 T/ W SAK SNDS TVD=2163 TMD=2408 DEP=857 3000 4000 5OOO B/ W SAK SNDS TVD=2730 TMD=3123 DEP=1294 9 5/8= CS(~ PT TVD=2930 TMD=3376 DEP=1448 K-lO TVD=3174 TMD=3684 DEP=1635 K-5 TVD=4530 TMD=5395 DEP=2680 AVERAGE ANGLE 37 DEG 36 HI N 6OOO 7000, / ZONE C TVD=6084 TMD=7356 DEP=3876 T/ ZONE A TVD=6142 TMD=7430 DEP=3921 ITARGT CENTR TVD=6177 TMD=7474 DEP=3948 B/ KUP SNDS TVD=6264 TMD=7584 DEP=4015 TD (LOG PT) TVD=6422 TMD=7784 DEP=4137 I I 0 1000 2000 3000 VERTICAL SECTION I I 4000 5000 HOR I Z'""/T AL SCALE 1 IN. PROJECTION -'- 1000 FEEl' ARCO ALASKA. Pad 2K. Well No, 2 Kuparuk Field. North Revised Slope, Pro[osel Alas 4000 TD LOCATION t !14,3' FNL. 1567' FEL SEC, 2. T1ON. RSE ~000 z 2000 I c :z: 1000 1000 ;~000 2000 I WEST-EAST 1 000 1000 I TARGET LOCATION, 1320' FNL. 1500' FEL SEC. 2. TION. RSE TARGET CENTER TVDm6177 TMD=7474 DEP-3948 NORTH 3689 WEST 1406 RECEIVFr:, MAY 1 6 i9S~ ) SURFACE SURFACE LOCAT ! ON t 271' FSL. 94' FEL SEC. 2, TION. RSE N 20 DEG 52 MI N W 7948' (TO TARGET) ARCO Alaska, Inc. Post Office Bo~ lu~0360 ^nchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat - 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the any questions, please call me at 263-4618. Sincerely, subject wells. If you have D. Martin Engineering Aide DM' hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & Gas Cons. C0mmissim] Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany N.TS. SECTION SECTION · t9 WELLS 1'12 ARE LOCATED IN SECTION 2, T. I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13'24 ARE LOCATED IN SECTION II,T. ION., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED SECTION CORNER Notes: VICI ~]THI$ .RURVEY ITY MAP T ION I. COORDINATES ARE ASP. ZONE 4. SECTION 12 RECEIVED DEC 1 1988 ?. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S,L. 4. O.G. ELEVATIONS FROM CED- RIXX-3311, re~4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY & ASSOCIATES. 6. REFERENCE FIELD BOOK: L 88-40, pgs. 55,56, 58,59, 65 I~ 66. Well ASP's AiasYa uii & ~',,;~:s Cons,. ~j~q,m;~cm;:= DiSt. Dist. O.G. Pad .... No. 'Y' 'X' I_~I;~/D~Ei~ LONGITUDE F.S.L. F.E.L, Elev. Elev. .,. I 5,938,600.18 498,310.17 70°14'36.519" 150°00'49.133'' 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70° 14.' 36.029" 150°00'49.128'' 246' 113.8 4 5,938,525.46 498,310.06 70°14' 35.784" 150°00'49.136'' 222' 113.8 5 5,938,500.19 498,310.1Z 70o14' 35.536" 150°00'49.134" 196' 113.8 6 5,938,475.14 498,310.33 70 °14' 35.289'' 150° 00'49.1Z8'' 171' 113.8 7 5~938,450.36 498,310.36 70°14'35.046'' 150°00'49.127" 146' 113.8 8 5,938,425.30 498,310.18 70° 14' 34. 799'' 150 °00' 49.132'' 121' 113.8 9 5,938,400.3,0 498,309.98 70°14'34,55:5'' 150°00'49.137" 96' 113.8 ii OI I0 5,938,375.19 498,510.14 70° 144J 34.306 150°00,49.133" 71' 113.9 I I 5~938,350.22 498,310.14 70°1 34.061 " 150o0 49.133" 46' 113.9 12 5,938,525.20 498,310.17 70014' 33.815" 150°00'49.131" 21' 94' 113.9 118.5 FN.L. 13 5,938,235.31 498,310.37 70° 14' 32.930" 150°00'49.125" 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70o14'32.683" 150°00'49.151" 94' 113.7 15 5,938,185.12 498,310.16 70°14' 32.4~7'' 150° 00' 49.131" 119' 113.8 16 5,938, 160.11 498,310.20 70°14' $2. 191'' 150° 00' 49. 130'' ~44' 113.8 17 5,938, 135.21 498,310.18 70014' 31.946" 150°00'49.130" 169' 113.9 i 18 5,938, 110.19 498,310.29 70014' 31.700" 150°00'49.127'' 194' 114.0 t9 5,938,085.~0 498,310.27 70014' 31.454" 150°00'49.127'' 2 19' 114.0 20 5,938,060.14 498,310.22 70°14' 31.207'' 150° 00'49.128'' 244' 114.1 21 5,9 38,055.16 498,310.16 70014'30.962" 150° 00'49. 130'' 269' ~I 114.0 22 5,938,010.40 498,510.19 70°14'30.718'' t50°00'49.129" 294' 94' 114.0 23 5,937,985.32 498,310.13 70 °14' 30.471'' 150° 00'49. 130'' 319' 95' 114.0 24 51937~960.29 498,310.08 70o14'30.225'' 150°00'49.132" 344' 95' I 113.9 118.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING INTHE''P/49 STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER ZO~ 1988. 'f~ ".. IS- 6299 ..." .~-~ L". · ·.... · 4,, AR O Alaska, Inc. DRILL SITE 2. K CONDUCTOR AS-BUILTS October 19, 1988 Telecopy No. (907) 276-7542 J B Kewin Regional Drilling Engineer ARCO Alaska,' Inc P O Box 100360 Anchorage, A~K 99510-0360 Re: Kuparuk River Unit 2K-2 ARCO Alaska, Inc Permit # 88-121 Surf Loc 275'FSL, 90'FEL, Sec 2, T10N, RSE, UM Bt~hole Loc 1894'FNL, 1381'FEL, Sec 2, T10N, RSE, UM Dear Mr Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by· law from other govern- mental agencies prior to co~encing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. W"nare a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver%:~ruty your, s, . f, : ...:- /. :~...' .,:., / Chai~an AlaSka Oil and Gas Conservation Co~ismion BY O~ER OF THE COMMISSION Ene!osure~ Department of Fish & Game, Habitat Section - w/o encl Department o£ Environmental Conservation - w/o encl STATE OF ALASKA ~'" ALASKA O,,_ AND GAS CONSERVATION CO~,,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ,~k Redrill [Z]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenJ-11 Service ~ Developement Gas [] Single Zone,l~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 136',PAD 101 'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface__ ,, 7. Unit or property Name 11. Type Bond Isee 20 AAC 25.025) 275'ESL, 90'FEL,Sec.2,TION,RSE,UM~/--~ppF'OY...~ Kuparuk River Unit Statewide At top of productive interval (@ target) 8. Well nu.mber Number 2040 ' FNL, 1:320' FEL,Sec. 2 , T10N,RSE,UM 2K-2 #8088-26-27 At total depth 9. Approximate spud date Amount 1894'FNL,1381 ' FEL,Sec. 2,TION,RSE, UN 11/08/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depthtMOandTVD~ property line 2K-1 7342'MD 1894' ~ TD feet 25' ~ surface feet 2560 6416'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 400 feet Maximum hole angle 320 Maximum surface 1 724 psig At total depth CTVD) 2908 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) Zbr;; lb" bZ..b~ H-~-U Weld 80 ~55 55' 115 115' +200 # cf i2-i/4:' -3-5/8"36.0# J-~) o/~. .~'i~3 .~) 5.~' ~;zzu Z~lZ' I~)u sx A5 ill & HF-ERI/ 4uu sx 61ass G 8-1/2' 7" 26.0# J-55 BTC 7308 34 34' 7342 6416' -IF-ER~ 200 sx Cl'ass G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Top of G 500' above Present well condition summary Kupa r uk -Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor - Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ;~ BOP Sketch ~ Diverter Sketch ,I~ Drilling program Drilling fluid program ~,, Time vs depth plot [] Refraction analysis ~ Seabed report ~. 20 AAC 25.050 requirements Signed / /~..,~_/'~._z///.,)~,~.~.¢¢~~ Title Regional Drilling Engineer Date/'¢-?-~',¢¢' '/ ~'"'/ - ' ' CommissionUseOnly~C/~(TEH, PD3/022~'~ PermitNum~er I APInumber I Approvaldatb ISoocovorlettor ¢0¢-/.~../ 50-- /O ,~--- ~-..O/O/) I 10/19/88 for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required D Yes ~No Hydrogen sulfide measures [] Yes ~ No D, irectional survey required /~"Yes [] No Required work~,~yo~~/,~~3M; [] SM; I-q 10M; Fq'-15M by orderof Other: Approved by ~,~', L~~ Commissioner the commission Date / GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to loggilng point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack'and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. MUD CLEANER SHALE .,~SHAKERSI' STI STIR ~ STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 ~pight Up to TD 10.3 PV 15-30 5-15 9-13 yp 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 " 5-12 Filtrate API 20 10-20 plt 9-I0 9.5-I0.5 9.5-10.5 % Solids 10± 4-7 9-12 DrillingFluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. L~X~/ih *' "'" KUPARU · K RIVER UNIT 20' DIVERTER SCHEI'IATIC III I. 16' COI4XJCTO~. 2. FI'lC SLII)-OI Mil) STAIITINI ~ ,,3. FI'lC OlVF,.qTtR AS~'ILY MTIi ~ ~.,1/16' 200Q IzS! SAIL VN.VEI S. 10' HCg BALL V&LVESIWtO° ~ ~ A SINeLE VALV~ ~ AUTCI~TICd4LL¥ ~ Rf"IOTELY Ct3~11~ TOAGglVl I~ OIV~I~ 6. 20'20Q0~~~. 4 ARCO ALASKA, INC.. REQiASI~ APt:)ftOV~ OF THIS OlVF, RTER SYS~ AS ,4 VARIAI~ FR~'~2OA.4C2S.O3S(b) M^!~tT£NANC£ & OPERATION 2e . UPON tNITI&L INSTALLAI'IC}N. CLOS~ PREV~ITR ,~ CLOSE ANNULAR PI~VENT~R AND ~I,,0~ AIR TI. IR~ DIVERT'ER LINES EVERY 12 HOUI~. CLO~E ANNULAR DI:~rV[NI'~R IN THE EVENT TI. IA T iNFLUX OF WELLBOI~ FLUIOS OR GAS IS OF, TECTT, D'- OPEN APPROPI:IIAI'[ VALVE TO ACHIEVE ~~K DIVERSION. DO NOT SHUT IN WFLL UNDI:R ANY CIRCIJIISTANCIrS 7 mi 6 5 ! I DIA~ #1 I;~-5/8' 5000 PSI ~ ~ STACK 4. 13-~J/8' - 5000 PSI PIPE RAI4) 5. 13-5/8' - 5000 1:"31 DRILI. IN~ ~ W~)-IOKE AM) KILL. LIliES 6. )~-5/8' - 5000 P'~JI C~LI)LE ~m~ VVPIPE RAk~ ON TCP. 7. 13.-5/87 - 5000 PSI AI~NJt. AR A(;~TCR CApACI~ TEST I. O.~a( ~ FILL AO3.MA. ATCR RE--IR TO I:q~PER LEVEL WITH HYI]Ui.LIC B. UID. 2. ~ THAT ACO. M.I. ATCR PRESSt,I~ I$ )(X)O I:~I MII'H 1500 PSI [X~¥~STRF. AM (~F TI-~ REGLLATCR. 3. ~ TII~.,.. ~ ~ ALL. UNZl~ SIM. I.T~~Y AbO EEC~ ~ TII~ AbO I~ EE~INING AFTEE AU. LI~T$ ~ ~ WITH 04ARGING PLM~ CFF. 4. RI~ ON ~ I~E]:~RTo TI.~ Aca3~A~LE LOYdER LIMIT I$ 45 ~ECCN~ CLOSING TII~ ~ 1200 PSI RI3wIAZNZMG I;~-5/8' BOP STACK TEST I. FILL BCP STACK ~ 043~ ~FCLD WITH AI~'TIC 2. ~ ~T ~L L~ ~ ~~ IN ~L~ ~ ~LY ~T~~ ~T TEST ~ ZN ~L~ ~ ~1~ JT ~ ~ INL~ ~~ 3. ~ ~ ~~ ~ ~ KILL ~ ~ LZ~ V~ ~~ TO ~ ST~ ~ 4. ~~ ~ lO ~ ~I ~~DF~ I0 ~ ~ ~~ TO ~~I ~~DF~ I0 ~ED ~~ TO 0 ~Z. LZ~ V~& ~ T~ PI~ ~ ~ ~ & ~ TO~I ~~~1 ~ IN~4. 7. ~Z~ ~I~ ~ V~ LI~ ~ ~S ~ A ~~I L~~~~I HI~. ~ST ~ IN 8. o:rr.N TCP PIPE RAKE3 AF~ CLO3E BOTTOM TEST 133TTOM PIPE I~gV6 TO 250 PSI ~ I~ ~ ~I~~ ~~T TOPAZ II, ~ ~I~ ~ ~ ~]~ ~T ~~D ~LI~ ~ F~ ~ PZ~ ~~ V~ ~ Z~Z~ ~ TO F~ SZ~ ~~TO ~ZLL~ ~E~Y ~~ F~~Y ~TE 51 (X)84001 ARCO ALASKA, !ne. Ped 2K. Well No, 2 Propoeed Kuperuk Field. North Slope. Alaeke RKB £LEVAT[O#~ 136' KOP TVD-400 TMD-400 DEP-O 3 9 BUILD 3 DEO PER 1 O0 FT I 000 ~ $ 21 2000 27 EOC TVD-1401 TtqD=1453 DEP-283 B/ PERI~AFROST TVD-1406 THD=1460 DEP-286 T/ UGNU SNDS TVD-1526 THD-1600 DEP-360 T/ 14 SAK SNDS TVD=2145 TlflD=2327 DEP-741 3000 4000 K-12 TVD=2712 TtID=2993 DEP-1090 9 5/8' CSG PT TVD=2912 TlflD=3228 DEP=1213 K-IO~ TVD=3156 THD=3514 DEP=1363 K-5 TVD=4512 THD=5106 DEP-2197 5000 6000 7000 l I AVERAGE ANGLE :31 DEG 36 HIN ' I ..... I 000 2000 3000 VERTICAL SECTION T/ ZONE C TVD-6072 TlflD=6938 DEP=$156 T/ ZONE A TVD-6124 TlflD=6999 DEP=3188 ", TARGET CNTR TVD=6159 TlflD-7040 DEP=3:i B/ KUP SNDS TVD=6246 TlflD=7142 DEP=~ TD (LOG PT) TVD=6416 TMD=7342 DEP=~ 4000 H,'~"'~ ZONTAL PROJECT ! SCALE 1 IN. = 1000 FEET ARCO ALASKA. !ne. P,d 2K. Well No, 2 Propo.ed Kuperuk Field. North Slope. Aleeke 4000 3000 _ z 2000 _ I :z: 1 000 . 1000 3000 2O00 TARGET CENTER TVD-6 ! $9 TPID-?040 DEP-3210 NORTH 2965 I~EST 1230 WEST-EAST 1000 0 TD LOOAT[ON ' 1894' FNL. 1381' FEL SEC. 2. TION. RSE 1000 I TARGET LOCAT[ONt 2040' FNL. 1320' FEL SEC. 2. TION. RgE SURFACE LOCATION, 275' FSL. gO' FEL SEC, 2. TION. R8E N 22 DEG 32 MI N 14 3210' (TO TARGET) 550 . 500 . I 450. I I 400. 350 :300 ..~ 250 _ 200 . 1 50. 250 200 1 50 1 O0 50 ~ I I ~1 400 ",t, soo '"' L400 "",,1200 '""4 300 300 \ \ ~'\1 200 \ \ \I 100 \ ~ 1000 ~ 900 , 6eo ~Uoo '~soo, soo ~ 1 ;~00 "Looo X'~oo sod ~.q ~~ ~01 O0 ~ 9 o~t~ ~. 0 t 1800 I I I I I I ~700 I I I I 4 1600 I I I I t I I 800 147.00 000 1 O0 I I I I I I I I I I I I I I 50 250 200 1 50 1 O0 50 0 50 - 55( .50( .45( 40( 35( 30( .25( .20( .15C ITEM APPROVE 'DATE (1) Fee F./~-_ ./c3//,~/~f i. (2 thru 8) (5) BOPE , u,~'~/~- '~".$3~ (23 thru 28) (6) p, Tmm 4 ?c (29 th Geology: Engineering: LCS ~' BEW rev: 08/11/88 ½.0ii Company ,~ r~.-_o " YES Is the permit fee attached .......................................... Lease & Well No. ~ PC~ NO 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. Mm 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 fifteen-day-wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. '22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is adeq wellbore paration proposed ' uate se ........................... 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ,~o~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .... ~ ............. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. ? INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: 0 ~-,]. 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 APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. -,- &L~SKA COMPUTING CENTER * SCHLUMBERGER COMPANY NAME : ARCO ALASKA, W[LL N4M:E : 2K-2 FIELO NA':qE ' KUPARUK BOROUGH ,: NORTH SLOPE STAT~ : AL.~SKA API .NUMBER : 50-1013-20101. REFERENCE NO : '73]82 I NC o ALASKA COMPUTING CENTER ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. NELL NAME : ~Z:r_LD NAME : KUPARUK BOROUGH : NORTH 'SLOPE 'STATE : ALASKA · AP! NUMBER : REFERENCE NO : '73382 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ALASK~ COMPUTING CENTER ~O-JUN-lg$9 13:39 PAGE: · ~'~-' REEL HEADER '~ ~ SERVICE NA~E : ED IT DATE : ORIGIN : FLIC REEL NAME : '?3382 CONTINUATICN ~ : PREVIOUS RE EL COMMENT : &RCO ALASK4 INC., · -,-~-~ T &P E HE ~D~R ,,-,~- ..... SERVICE N4~E ' EDiT DATE : ORIGIN : :LIC TAPE NA~E : 733~2 CONTINUATICN ~ : 1 PREVIOUS T~PE : COMMENT .' ARrO.~ ALASKA INC., KUPA~UK KUPA~UK 2K-2, aPI 2K-2, ~PI .~5 O- 10 ~-20101 ,~50-I03-20101 ~ FILE HE~DER ~:-'~ ~;~'- FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001~32 DATE : 89/05/30 MAX REC S IZ~ : 1096 FILE 'TYPE : t~ LAST FILE : COMPANY NAME: ARCO ALASKA, WELL: 2K-2 FIELD:' KUPARUK BOROUGH: NO RT~.q SLOPE STATE: ALASK~ API NUMBER: 50-10.3-20101 INC. LOCATION: 271' FSL & 9¢' FEL S:EC'TION: 2 TOWNSHIP: 1ON PERMANENT D~TUM' !MSL ELEVATION: 0.0 'RANGE: 8E .IS TAPE VERIFICATION LISTING ;CHLUM~ERGER ALASKA COMPUTING CENTER 30-JUN-t989 13:39 LOG MEASURED FROM RKP 154 ABOVE PERMANENT D4TUM ELEVATIONS KB: 154 DF: 153 GL: 113 DATE LOGGEG: lO-JUN-89 RUN NUMBER: ONE TO DRILLER: T720 TO LOGGER: 7726 CASING: 7" @ C~ILLER DEPTH O~ 7216 ~ND LOGGER DEPTH OF 7236 BIT SIZE: 6 I/~" @ DRILLER DEPT~ De 7720 TYPE FLUID iN HOLE: DISPERSED POLYMER DENSITY: 11.1 VISCOSITY: 53 PH: 10 FLUIO LOSS: 3.0 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2.25 @ 75 2.15 @ 75 2.63 @ 75 TIME CIRCULATION ENDED: 19:30 19-JUN TIME LOGGER CN BOTTOM: 00:30 ZO-JUN M~XIMUM TEM~ RECORDED: 150 LOGGING DISTRICT: LOGGING ENGINEER' WITNESS: PRUDHOE B~Y TINKHAM L OWEN/D IXON/P'E~K/RENK E TOOL NUMBERS: DIS 2140 PGS 508 SGC 2626 NLM 1378 ~IC 2191 CNC 12~8 IEM 1347 FIELD REM ARKS: NO S'TANDDFFS AND 2' HDL'E KINDER USED ON DIT. MATRIX DENSITY : 2.65 G/C3 , FLUID DENSITY = 1.00 G/C3 CNL M~TR]K = S~N~ , HOLE CORRECTION = CALIPER CE,~NT PLUG SET )ETWEEN T" CASING AND TOP OF KUPARUK BEFOR.E DRILLING CUT WITH 5 1/8" BIT. PAGE: DATE JOB STZ),RTED: 30-JUN.-89 JOB REFERENCE NO: 73382 LDP/ANA: J. KOHRING .IS TAPE VERIFiC~&TICN LISTING ;CHLUM6ERGER ALASKA COMPUTING CENTER 30-JUN-1989 13:39 PAGE: 50-103-20101 M&IN P,~SS LOG DATA SAMPLED EVERY -.5000 FEET D,&Ta INCLUDED - TOOL EXTENS ION TO_rtL TYPE USED NAME DIT-D .DIL DUAL INDUCTION SFL 7718' TO 7235' FDC .FDC FORMATION D'ENSITY 7692' TO 7236' CNT-A/D/H .CNL COMPENSATED NEUTRON 7676' TO 7236' CNT-A/D/H .CSG CASING CNL 7314' TO 6T09' CNT-A/D/H .CSG CASIN,~ GAMMa PAY T396' TO 1000' TABLE TYPE : TUN I CN FN WN APIN FL SECT TOWN R A N G COUN STAT NATI ENGI WITN SON EPO FT LMF: APO ~T E K.E iFT EDF FT EGL FT TDD FT BLI FT IL I FT TCS TLAB CONS V~LU DEFI ARCO &LASKA~ INC. COMPANY NAME KUP~RUK FIELD NAME 2~-2 WELL NAME 50-103-20101 ~PI SERIAL NUMBER 271' FSL [ 94' FEL FIELD LOCATION 2 SECTION 1ON TOWNSHIP BE RANGE NORTH SLOPE COUNTY ALASKA STATE OR PROVINCE US~ NATION TINKH~M LOWiEN/DIXON/PEAK/RENKE 549127 MSL O. 154. 154. 153. 113. 7 72 0. 7718. 1000. i9:30 19-JUN 00:30 20-JUN ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM BOTTOM LOG INTERVAL TOP LOG INTERVAL TIME CIRCULATION STOPPED TIME LOGGER .AT BOTTOM .-- .IS 'TAPE VERIFICATION LIST'ING ;CHLUMBERGER ~LASK,~ COMPUTING CENTER TABLE TYPE : CURV DEFI 30-JUN-1989 13:.39 DEPT ILO ILM SFLU S~ GR TENS DPH~ RHOB DRHO FFDC NFDC CALI GR TENS NPHI TNPH TNRA NPCR RCNT RCFT CNTC CFTC G~ CALI TENS NDHI TNPH TNRA NPOR RCNT RCFT CNTC CFTC GR CALI TENS DEPTH CHANNEL N~ME IL-DEEP RESISTZVITY IL-M EDIU.M RESISTIVITY SFL UNAVERAGEO SPONTANEOUS POTENTIAL GAMMA R~Y TENSION DENSITY ~OROSITY SULK CENSITY DELTA RHC FA:R FDC COUNT R~TE NE.~R FDC COUNT RATE CALIPER ,GAMMA RAY TENSION NEUTRON POROSITY THERMAL NEUTRON PORDSI'TY CALIBRATED THERMAL NEUYRON R~TIO NEUTRON POROSITY OUTPUT FROM AN ~PPLICATION PROGRAM RAW CORRECTED NEAR THERMAL C'DIJNTS RAW CORRECTED F~R THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS ,G A M M A R A Y CALIPER T:ENSION NEUTRON POROSITY THERMAL NEUTRON PORCST-T'Y CALIBRATED THERM,~L NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM ~N APP.LZCATIDN PROGRAM RAW CORRECTED NEaR THERMAL COUNTS RA~ CORR:CTED~ FAR, THERMAL COUNTS CORRECTED NEaR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY CALIPER TENSION PAGE: ~-'~: DATA FORMAT :SPECIFICATION RECORD SET TYPE - 6~EB '~'~-~. TYPE REPD CODE V :~LU E I 66 0 2 66 0 3 73 14 8 ,IS TAPE VERIFICATION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 30-JUN-1989 13:39 PAGE: TYPE REPR COPE V~LUE 4 66 5 66 6 73 ? 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 9 14 65 =T 15 66 16 66 1 0 66 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVIC5 API AP1 ~Pl aP1 FILE NUN5 NUMB SIZE REPR I0 ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE DEFT FT 549127 O0 ILD DIL CHMM 549127 07 ILM OIL OHMM 549127 07 SFLU DIL DHMM 549127 SP OIL MV 549127 O? GR OIL G~P! 549127 07 TENS OIL L8 54912? 07 DPHI FDC PU 549127 07 RHOB FDC G./C3 549127 07 DRHg FDC G/C,3 549127 07 FFDC FDC :CPS 5491 27 07 NFDC FDC CPS 549127 07 CALI FDC IN 5.49127 07 GR FDC GAPI 5491Z? 0'7 TENS FOC LB 549127 07 NPHI CNL PU 549127 07 TNPH CNL PU 549127 07 TNRA CNL 549127 07 NPOR CNL PU 549127 07 RCNT CNL CPS 54912? 07 RCFT CNL CPS 5491Z7 0'7 CNTC CNL C:PS 549! 27 CFTC CNL CPS 549127 07 GR CNL GAPI 549127 07 CALI CNL IN 549127 0'7 TENS CNL L8 549127 07 NPHI CSG PU 549127 07 TNPH CSG PU 549127 07 TNRA CSG 5491 27 07 NPGR CSG ~U 549127 07 RCNT CSG CPS 549127 07 RCFT CSG CPS .549127 07 OOO 00 0 1 1 1 4 6 8 120 46 0 1 1 1 4 68 120 44 0 1 1 1 4 6~ 220 01 0 1 1 1 4 68 010 O1 0 I 1 1 4 68 310 O1 0 I 1 1 4 68 635 21 0 1 1 1 4 68 635 21 0 1 1 1 4 6 B 350 02 0 1 1 1 4 6,8 356 O1 0 1 1 1 4 68 354 02 0 1 1 I 4 68 354 O1 0 1 1 1 4 68 280 O1 0 1 .1 1 4 68 310 O! 0 I I I 4 68 63 5 2 '1 0 1 1 1 4 6 8 890 O0 0 1 1 1 4 68 890 O0 0 1 I 1 4 68 420 O! 0 1 1 1' 4 68 890 O0 0 1 ! I 4 68 4,20 01 0 1 1 1 ,4 68 420 01 0 1 1 1 ,~ 68 07 420 O! 0 1 1 1 4 68 420 O1 0 ! 1 1 4 68 310 O1 0 1 1 1 4 68 280 Ol 0 1 1 1 4 68 6:35 21 0 1 1 1 4 68 890 O0 0 1 1 1 4 68 890 00 0 1 1 1 ,4 68 420 O1 0 1 1 1 4 68 890 O0 0 I 1 ! 4 68 420 01 0 1 1 1 4 68 420 O1 0 1 1 1 4 68 PROCESS (HEX) 0000000000 0000000000 0000000000 O0000000iO0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000000'00 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS TAPE VERIFZC6TION LISTING iCHLUMSERGER ALASK.~ CO~4PUTING CENTER ~O-JUN-1989 13:39 PAGE: NAME SERV UNIT SERVICE API ,aPl ID ORDER # LOG TYPE AP1 CLASS CNTC CSG CPS 549127 07 420 CFTC CSG CPS 549127 07 420 GR CSG GAPI 549127 07 310 CALl CSG IN 549127 O? 280 TENS CSG LB 549127 07 635 O1 01 Ol O1 21 ~PI PILE NUMB NUMB HO0 NUMB S~MP ELSM ---- 0 1 1 0 I 1 0 I I 1 0 I 1 0 i I 1 ---- SIZE REPR CODE PROCESS (HEX) 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000009000 DATA D:PT~ . 77'~1. 500 ILO.OIL SP. OIL - 23.0 O0 GR. ElL RHOB.FDC 2.461 ORHO.FDC CALI.FDC 6.273 GR.FDC TNPH.CNL 41.816 TNRA.CNL RCFT.CNL 578.899 CNTC.CNL CALI.CNL 6.2'73 TENS.CML TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG -'999.250 DEP'T. 7700.000 ILD.DIL SP.DIL -25.000 GR.CIL RHOB.FDC 2.484 ORHO.FOC CALI.FDC 6.293 GR.FDC TNPH. CNL ~1.800 TNRA.CNL RCFT.CNL 578.899 CNTC.CNL C~LI.CNL 6.293 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.C.SG TENS.CS~ -999.250 DEPT. 7600,0100 ILD.D.IL SP.DIL -29,500 ~R.DIL RHOB. FDC 2.442 DRHO.FOC CALI.FDC 6.547 GR.FOC TNPH.CNL 30.9,37 TNRA.CNL RCFT.CNL 967.265 CNTC.CNL CALI.CNL ~.547 'TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG .-999.250 CFTC.CSG TENS.CSG -999.250 DEPT. 7500.000 !LD.DIL SP.OIL -37,500 GR.DIL RHOB.FOC 2.278 ORHC.FDC CALI.FDC 6.371 GR.FDC TNPH.CNL 26.406 TNRA.CNL RCFT.CNL 1532.470 CNTC.CNL CALI.CNL 6.371 TENS.CML TNRA.CSG -999.250 NPOP.C~SG 2.660 ILM.DIL 124.000 TENS.OIL 0.008 FFDC.FDC 124.000 TENS.FDC 3.3~9 NPOR.CNL 2190.345 CFTC.CNL 3084.000 NPHI.CSG -999.250 RCNT.CSG -999.250 GR.CSG 2.376 ILM.DIL 124.000 TENS.OIL 0.026 FFDC.FDC 124.000 TENS.FDC 3.389 NPOR.CNL 2190.3~5 CFTC.CNL ~604.000 NPHI.CSG -999.250 qCNT.CSG -'999.250 GR.CSG 3.034 3084.000 %56.000 3084.000 41.816 656.557 -999.250 --'999.250 -999.250 Z.435 4604.000 450.250 4604.000 41.800 656.557 -999.250 -999.250 -999.250 5.277 ILM.DIL 5.404 105.250 TENS.DIL 4624.000 -0.003 FFOC.FDC 464.500 105.250 TENS.FDC 4624.000 2.845 NPOR.CNL 32.984 2939.023 CFTC.CNL 1108.326 4624.000 NPHI.CSG -999.250 -999. 250 ~CNT.CSG -999.250 - 999. 250 GR. C SG -99 9. 250 23.149 ILM. DIL ~7.781 TENS.DIL 0.000 FFOC.FDC ~7.781 TENS.FDC 2.378 NPOR.CNL 4055.~54 CFTC.CNL 4605.000 NPHI.CSG -999.250 ,RCNT.CSG 30.426 4608.000 700.500 4608. 000 26.099 1728.392 -999.2.5'0 .-999.250 SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C.~LI.CSG SFLU.DIL OPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG 3.566 11.479 565.500 43.921 21~,3. 531 124.000 -999.250 -999.250 -999.250 2.705 10.083 43.899 2143.531 124.000 -999.250 -999.250 -999.250 6.862 12. 608 553.500 33.6~4 2730.446 105.2'50 -999.250 -999.250 -999.2 50 46.729 22.555 631.500 26.730 4004.486 47.781 -999.250 -999.250 .IS T~PE VERIFICATION LISTING ~CHLUNBERGER ~LASK& CgMPUTIN~ CENTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG -999.250 DEPT. 7400.000 ILO.OIL SP.DIL -33.500 GR.DIL RHOB.FOC 2.478 ORHO.FDC CALI.FDC 6.941 GR.FDC TNPH.CNL 36.678 TN~A.CNL RCFT.CNL 660.391 CNTC.CNL CALI.CNL 6.941 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CF'TC.CSG TENS.CSG -999.250 DEPT. 7300.000 ILO.OIL SP.DIL -47.000 GR.CIL RHOB.FDC 2,112 ORHO.FDC CALI.FDC 7,090 GR.FOC TNPH.CNL 47,496 TNR~.CNL RCFT.CNL 418.0~0 CNTC.CNL CALI.CNL 7,090 TENS.CNL TNRA.CSG 4,030 NPOR.CSG CNTC.CSG 1801.713 CFTC.CSG TENS.CSt 4280.000 DEP'T. 7200. OOO ILD.DIL SP.OIL -84,000 GR.D[L RHOB.FDC 2.158 DRHO.FgC CALI.FOC 6.359 GR.FDC TNPH.CNL 44.807 TNR~.CNL RCFT.CNL 403.779 CN'TC.CNL CALI.CNL 6.3 59 TENS.CNL TNRA. C,SG 3,700 NPOR.CSG CNTC.CSG 1560.870 CF'TC.CSG TENS. CSG 4232. OOO DEPT. 7100.000 !LD.DIL SP.DIL ,-999,250 GR.DZL RHOS.FDC '-999.250 DRHO.FDC CALI.FDC -999,250 GR,FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999,250 T~NS.CNL TNR~.CSG 4.0'?5 NPOR.CSG CNTC.CSG 1530.236 CFTC.CSG TE~S.CSG 4204.000 OEPT. 7000.000 ILD.DZL SP.DIL -999,250 GR.OIL RHDB.FDC -9~9,250 ORHD.~DC CALI.FDC -999.250 GR.FDC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999,250 CNTC,CNL CALI.CNL -999.250 TENS.CNL TNR~.CSG 4,258 NPOR.CS~ 30-JUN-1989 13:39 - 999. 250 GR.CSG -999. 250 2. 559 ILM. D IL 142.500 TENS.OIL 0.049 ~FDC.FOC 142.~00 TENS.FDC 3. 989 NPOR.CNL 2179.366 CFTC.CNL 458,4.000 NPHI.CSG -999.250 RCNT.CSG -999.250 GR.CSG 2.122 ILM.DIL 84.259 TENS.DIL -O. O0~ FFDC.FOC S4.250 TENS.FDC 3.764 NPOR.CNL 1778.333 CFTC.CNL 4~72.000 NPHI.CSG 49.~52 RCNT.CSG ~72.091 GR.CSG !9.172 ILM.DIL I00. 500 TENS.DIL -0.41~ FFDC.FDC 100.500 'TENS. FDC 3.733 NPOR.CNL 1502.661 CFTC.CNL 4'380.000 NPHI.CSG -999,250 RCNT. CSG 419.432 GR.CSG 2.516 4584.000 483.000 4584.000 3T.OP1 716.412 -~99.250 -999.250 -999.250 2.170 4~72.000 1032.000 4472.000 48.249 478.648 55.809 1.753.716 119.563 2000.000 4380.000 336.500 4380.000 43.938 425.777 41.~75 1505.849 112.875 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFOC.FOC -999.250 -999.250 'TENS. F'gC -999.250 -999.250 NPgR.CNL -999.250 '-999..250 CFTC.CNL -999,250 -999.2150 NPHI.CSG 48.709 -999..250 RCNT.CSG 1,485,450 372.524 GR.CSG 109.125 -999.250 ILM.DIL -999,250 -999,250 TENS.DI[ -999.250 -999.259 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999. 250 NPOR.CNL -999.250 '-999.1250 CFTC.CNL -999.250 '-999.250 NPHI.CSG 52.049 -999.250 RCNT.CSG 1455.319 C&LI.CSG SFLU.DIL DPHI.FDC NFEC.FDC NPFI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.OIL DPHI.FDC NmDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.mDC NPHI.CNL RCNT.CNL GR.CN[ TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: -999,250 2.531 10.428 613.500 37.680 2113.086 142.500 -999.250 -999.250 -999.250 2.339 32.5'39 687.000 49.880 1715.522 84.250 49.561 379.219 2.340 2000.000 29,813 219.500 50.120 1496.549 100,500 -999.250 377.725 2.3~0 -999,250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 326.294 2.326 -999,250 -999,250 -999.250 -999.250 -999,250 -999.2,50 -999.250 317.044 ,IS TAPE VERZmICATION LISTING ,CHLUMBERGER ~LASK~ COMPUTING CENTER CNTC.CSG 1516.664 CFTC.CSG TENS.CSG 4148. OOO 30-JUN-1989 13:39 361.604 3R.CSG 73.500 DEPT. 6900.000 ILO.OIL -999.250 ILM.DIL -999.250 SP.DIL -999.250 GR.DIL -999. Z53 TENS.DIL -999.250 RHOB.FDC -999.250 DRHO.FDC -'999.250 FFOC.FOC -999.250 CALI.FDC -999.250 GR.FDC -999.!50 TENS.FDC --999.250 TNPH.CNL -9'99.250 TNRA.CNL -99'.9.250 NPDR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 NPHI.CSG 38.853 TNRA.CSG 3.534 NPOR.CSG -999.250 RCNT.CSG 1759.668 CNTC.CSG 1776.499 CFTC.CSG 507.817 GR.CSG 77.750 TENS. CS; 4! 08.0 O0 CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG DEPT. 6800.000 ILO.OIL -999.250 ILM.DIL -999.250 SFLU.DIL SP.DIL -999.250 GR.~IL -999.250 TENS.OIL -999.250 DPHI.FDC RHGB.FDC -999,250 DRHO.FDC -999,250 FFDC.FDC -999.250 NFEC.FDC CALI.~DC -999.250 GR.FDC -999.250 'TENS.FOC -999.250 NPHI.CNL TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCN~T.CNL RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 GR.CNL CALI.CNL -999.2.50 TENS.CNL -999.250 NPHI.CSG 36.200 TNPH.CSG TNR&.CSG 3.388 NPOR.CSG -999.250 RCNT.CSG 1841.905 RCFT.CSG CNTC.CSG 1869.853 CFTC.CSG 556.106 GR.CSG 69.688 CALI.CSG TENS.CSG ~054.000 DEPT. 6700.000 ILO.OIL -999.250 ILM.DIL -999.250 SP.DIL -9'99.250 GR.DIL -999.250 TENS.OIL -999.250 RHOB.FDC -999.250 DRHO.FDC -999.250 FFDC.FDC -999. ~-50 CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CN'TC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 NPHI.CSG 54.624 TNRA.CSG 4.399 NPDR.CSG -999.250 RCNT.CSG 1415.749 CNTC.CSG 1488.935 CFTC.CSG 355.031 GR.CSG 68.063 TENS.CSG 3990.000 DEPT. 66,30.000 ILO.OIL -999,250 ILM.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS.OIL -999.250 RHO3.FDC -999.250 DRHO.FDC -999.2.50 ,=FOC. FDC -999.250 CALI.FDC -999.250 GR.FDC -999,250 TENS.FOC -999,250 TNPH.CNL -999,250 TNRA.CNL -999.250 NPOR.CNL -999,250 RCFT.CNL -999.250 CNTC.CNL -999,250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS,CNL -999,250 NPHI.CSG -999.Z50 TNRA.CSG -999.250 NPgR,CSG -999.250 RCNT.CSG -999.250 CNTC.CS; --999.250 CFTC.CSG -999.250 GR.CSG 76.438 T ~NS. CSG 4164.0 00 DEPT. 6500.000 ILO.OIL -999.250 ILM.DIL -999.250 SP.OIL -999.250 GR .EIL -~99.250 TENS.OIL -999.250 RH~B.FDC -999,250 DRHO.FDC -99:9.25D FFDC.FDC --999,250 CALI.FDC -999.250 GR.FDC -999.250 'TENS.FDC -999.250 'TNPH. CNL -999.250 TN.RA .CNL -999. 250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL '-999.250 CALI.CNL -999.250 TENS.CNL -999.250 NPHI.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -99'9.250 SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GRoCNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.gIL DPHI.FDC NFCC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH..CSG RCFT.CSG PAGE: 2.334 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 476.414 2.338 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99,250 48 8. 278 2.334 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 285.239 2.367 -999.250 -999.250 -999,250 -999. 250 -999.250 -999 °250 -9'99. 250 -999.250 -999.250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999,250 .-999,250 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKa, CgMPUTING CSNTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG ~090.000 DEPT. 6400.000 ILD.gIL SP.DIL -999.250 GR.DIL RHOB. FDC -999.2 50 DRHO.F DC CALI.~DC -999.2 50 GR. =OC TNPH. CNL -999.250 TNRA. CNL RCFT.CNL -999.250 CNTC.CNL CALZ.CNL -999.250 TENS.CNL TNR~.CSG -999.2 50 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG ~070.000 DEPT. 6300.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.~DC CALI. FDC -999.250 GR.. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL '-9'99.250 TENS.CNL TNRA.CSG -'999. 250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG ~000.000 DEPT. 6200.000 ILD.DIL SP. OIL -999.250 GR. OIL RHO~. FDC -999. 250 DRHO. FOC CALI. FDC -9'99. 250 GR. FOC TNPH. CNL -999.250 TNRA.CNL RC'FT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG ]3954. 000 DEPT. 6100. 000 ILD. DIL SP.gIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FOC C ALI.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALZ.CNL -999.2!50 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999°250 CFTC.CSG TENS.CSG 3.890. 000 DEPT. 6000.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR. FDC TNPH.CNL -9'99.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 'TENS.CNL TNR~.CSG -999. 250 NPOR.CSG 30-JUN-1989 13:39 -999. 250 GR.CSG 87.$25 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFOC.FOC -999.250 -999.250 TENS.FDC -999.250 -999. 250 NPgR.CNL -999.250 -)99.250 CFTC.CNL -999.250 -99'9.250 NPHI.CSG -999.250 -999.~50 RCNT.CSG -999.250 -999.250 GR.CSG 77.000 -999.250 ILMoDIL -999.250 -999. 259 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -99'9.250 -999.250 NPOR.CNL -~999.Z50 -999. 250 CFTC.CNL -999. 250 -999.25.0 NPHI.CSG -~99.250 -~99.250 RCNT.CSG -999.250 -999.250 G'R.CSG 66.125 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 65.875 -999.250 ILM. DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.259 TENS.FDC -999.250 -999.1Z50 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 55.250 -999.250 ILM.DIL - 999. 250 TENS.DIL -999. 250 FFDC. FDC -999.250 TENS.FgC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 NPHI.CSG -~99.250 RCNT.CSG -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 --999. 250 -999.250 CALI.CSG S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG R'CF'T.CSG C~Li.CSG SFLU.DIL DPHI.FDC NFDC.EDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.mDC N FDiC. FDC NPHi. CNL RCNT. CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE': -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999..250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2!50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS T~PE VERIFICATION LISTING CHLUMBERGER ~LASK~ COMPUTING CENTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3850.000 D~PT. 5900.000 ILO.OIL SP.DIL -999.250 OR.OIL RHOB.FDC -999.250 9RHO.FDC CALI. FDC -999.2 50 ~R. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999,250 CFTC.CSG TENS.CSG '37 94. 000 DEPT. 5800.000 ILD.CIL SP.DIL -999.250 §R.DIL RHOB. FDC -999.2 50 DR HO. ~OC CALI. FDC -999.2 50 G~,. FOC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999,250 CNTC.CNL C~LI.CNL -9'99,250 TENS.CNL TNRA.CSG -999,250 NFOR.CSG CNTC.CSG -999,250 CFTC.CSG TENS.CSG 3720.000 DEPT. 5700.090 ILO.OIL SP.DIL -999.250 OR.OIL RHOB. FDC -999.2 50 ORHO. CALI. ?gO -99 9. 250 GR. FOC TNPH.CNL -999,250 TN R r-,,. C NL RCFT. CNL -9 99. Z 50 CNTC. CNL CALI.CNL -999.250 TENS.CNL TNR&.CSG -999.250 NPDR.CSG CNTC.CSG -999.250 CFTC.CSG T =_NS. CSG 3700. 0 O0 DEPT. 5600.0 DO ILO.OIL SP. OIL -999.2 50 .GR. Bit RHOB.FDC -999,250 DRHO.FOC CALl. FDC -9'99.2'50 GR.. FDC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999,250 CNTC.CNL CALI.CNL ,-999,250 TENS,CNL TNRA.CSG -999. 250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3640.000 DEPT. 5500.000 ILO.OIL SP.DIL -999.250 OR.OIL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -999.2 50 GR. FOC TNPH.CNL -999. 250 TN,,qA. CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 'TENSoCNL TNRA.CSG -999.2,50 NPO~.CSG 30-JUN-1989 13:39 -999.250 GR.CSG 62.750 -999.250 !LM.DIL -999.250 -999.250 TENS.OIL -999.250 -~99.250 FFOC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999,250 -999.250 RCNT.CSG -999,250 -999.25~ GR.CSG 90.063 -999.250 ILN.DIL -999.250 -999.250 TENS.OIL -999.250 -99'9.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -'999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999,250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999,250 GR.CSG 8~.750 999 2:0 ILM 0'" - . ..... . ~.t -999.250 -99'9.250 TENS.OIL -999.250 -999. 250 FFOC.FCJC -999.250 -999.250 T~NS.FDC -999.250 -999.2:50 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -99~.250 RCNT,C:SG -999,250 -999. 250 GR. CSG 112. 250 -99'9. 250 ILM.DIL -'999.250 -~99.250 TENS.OIL -999.250 -999.250 FFOC.FOC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL .-999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999,250 -999. 250 GR.CSG 9~.250 -999.250 ItM.O'It -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 'TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 NPHI.CSG -999.250 RCNT.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CALI.CSG SFLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSS CALI.CSG SFLU.OIL DPHI.FDC NmDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.OIL OPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFToCSG PAGE: 10 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1-999.250 .-999 o 2/50 -999.250 -999.250 -999.250 -999.250 -999.250 -999 °250 -999.250 -999.2:50 -999.250 -999.250 -999..250 -999.250 -9'99. 250 -999.250 .IS T~PE VERIFICATION LISTING ;CHLUFBERGER ~LASK4 CO?4PUTING CENTER CNTC,CSG -999,250 CFTC,CSG TENS,CSG 3604,000 DEPT, 5400,000 ILD,OIL SD,OIL -999,250 GR,DIL RHOB.FDC -999,250 ORHO,FDC C ~LI, FDC -999, Z 50 Gq, FDC TNPH,CNL -999,250 TNRA.CNL RCFT, CNL -999,2 50 CNTC , CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999,250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3540.000 DEPT, 5300,000 ILD,OIL SP, OIL -999,250 GR. DIL RHOB,FDC -999,250 DRHO,FDC C ALI, FDC -999,250 GR, FDC TNPH. CNL -999,2 50 TN RA, C NL RCFT,CNL -999,250 CNTC,CNL CALI,CNL -999,250 TENS,CNL TNRA,CSG -999,250 NPDR,CSG CNTC,CSG -999,250 CFTC.CSG TENS, CSG 3490,000 DEPT, 5200,000 ILD, SP,DIL -999,250 GR,DIL RHGB,FDC -999,250 gRHO,FOC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT,CNL -999,250 CNTC,CNL CALIoCNL -999,250 TENS,CNL TNRA.CSG -9'99.250 NPOR.CSG CNTC,CSG -999. 250 CFTC,CSG TENS,CSG 3434,000 DEPT, 5100,000 ILD,DIL SP,DIL --999,250 GR,DIL RHOS. FDC -999.250 9RHD.FDC CAL]., FDC -999, 250 GR, FOC TNPH.CNL -999. 250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI,CNL -999.250 TENS,CNL TNRA,CSG -999,250 NPOR,CSG CNTC,CSG -999,250 CFTC,CSG TENS.CSG 33'74,000 DEPT, 50OO,OOO !LD,DIL SP,DIL -999.250 GR,OIL RHOB,FDC -9'99,250 DRHO.FOC C~LI, FDC -999,250 GR, FDC TNPH.CNL -999,250 T~RA,CNL RCFT,CNL -999,250 CNTC,CNL CALI,CNL -999,250 TENS,CNL TNRA,CSG -999,250 NPOR,CSG 30-JUN-19B9 13:39 -999, Z$O GR,C SG 6 5,500 -q. 99.250 ILM, DIL -999,250 -:~99,250 TENS,DIL - ;~9 9, Z50 -999.2.~0 FFDC.FDC -'999.250 -999.250 TENS.FOC -999.250 -'~99. Z5O NPOR.CNL -999.250 -999.250 CFTC.CNL -~99.~50 -999.250 NPHI.CSG -99'-). 250 -999,250 RCNT,CSG -999,250 -999.250 GR.CSG 76.750 -999,250 ILM,OIL -999,250 -999,250 TENS,DIL -999,250 -999.250 ~FDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.25'~ NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 74.063 -999.250 ILM,DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.Z50 -999.2:50 TENS.FDC -999.250 -999.250 NPOR.CNL -'999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.Z50 -999, 250 RCNT.CSG -999,250 -999. 250 GR,CSG 78. 313 -999.250 ILM.DIL -999.Z50 -999.250 TENS.DiL -999.250 -999.250 FFOC.FDC -999.250 -'999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999,250 GR, CSG 77,188 -999,250 ILM,DZL -999,250 TENS,DIL -999,250 FFDC, FOC -999.250 TENS.FDC -999.259 NPOR,CNL -999.250 CFTC,CNL -999. Z50 NPHI.CSG -999,250 RCNT,CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CALI.CSG SFLU.DIL DPHI.FDC NFGC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC N~DC.FOC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI,CSG SFLU,OIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT,CNL GR,CNL TNFH,CSG RCFT,CSG C~LI,CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT,CNL GR,CNL TNPH,CSG RCFT,CSG P~GE: 11 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 -999,250 -999.250 -999.250 -9'99,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,2~0 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 '-999,250 -9'99,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .-999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 .-999.250 -999.250 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ~LASK~ COMPUTING CENTER C NTC. CSG -9'99.2 50 CF TC.C SG TENS.CSG 3320.000 DEPT. 4900.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHD.FDC C ~LI.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LZ.CNL -9 99.2 50 TENS .CML T NR A.CSG -999.2 50 NF OR.C SG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3274.000 DEPT. 4800.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.2]50 DRHO.FDC C ALI . FDC -999 . 250 GR . F DC TNPH. CNL -999.250 TNRA. CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG 'TENS" C, . . ~,S ,~ 3210 000 DEPT. 4700.0 O0 ! LD. DIL SP. OIL -999.2 50 GR.DIL RHOS.FDC -999.250 DRHO.FDC C ALI. FDC -999.250 GR. FDC T NPH. CNL -999.2 50 TNRA. CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL '-999.250 TENS.CNL TNRA.CSG -999. 250 NFOR,CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3'1:B4. 000 DEPT. 4600,000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.F'DC CALI.FD£ '-999.2 50 GR. FlOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALIoCNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENSoCSG 3120.000 DEPT. 4500.000 ILO.OiL SP. OIL -999.250 GR..OiL RHOB.FDC -'999.250 ORHO.FOC DALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999,250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG 30-,JUN- 1989 13:39 -999. 250 GR.CSG 85.250 -999.250 ILM.DIL -999.250 -999.250 TENS.DZL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -399.250 -999.250 CFTC.CNL -999.250 - .999. 250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.25~ GR.CSG 54.875 -999. 250 ILM.DIL -999.250 -~99.250 TENS.DIL -999.250 -999.~50 ~FDCoFDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999. 250 -999. 259 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -'~99.250 GR.CSG 67.975 -999.250 ILM.DIL -999.250 -999.250 TENS.D~L -999.250 -999.Z50 FFDC.FOC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -'999.250 CFTC.CNL '-999.250 -999.250 NPHI.CSG -999.250 '-999.250 RCNT.CSG -999.250 '-999.250 GR.CSG 88.500 -999.250 ILM. DIL -999.250 -999.,250 TENS.DIL -999.250 -999,250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999. 250 NPHI.CSG -999.250 -999. 250 RCNT.CSG -999.250 -999.2~0 GR. C SG 6z,. 125 -959.Z50 ILM.DIL -999.Z50 -999.250 TENS.DIL -999.250 -99'9.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.Z50 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 C~LI.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL Gq.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFGC.FDC NPH!.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSS SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCN'T.CNL GR.CNL TNPH.CSG RCFT.CSG C~L.I.CSG SFLU.DZL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCF'T.CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9 '99.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 '-999.250 -999.250 '-999.250 -999.250 -999.250 12 .IS TAPE VERIFIC,&'TZON LISTINS ;CHLUMBERGER ~LASK~ COMPUTINg3 CENTSR CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3090.000 DEPT. 4400.000 ILO.OIL SD.OIL -999.250 GR.EIL RHOB. FDC -999.2 50 DRHO. FgC CALi. FDC -999. 250 GR. F]C TNP H. CNL -9 39.2 50 TN RA. C NL RCFT.CNL -999.250 CNTC.CNL CALl .CNL -999.250 TENS. CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 3010.000 DEPT. 4300.000 ILO.OIL SP.DIL -999.250 GR.~IL RHOB. FDC -999.250 DRHG.FDC CAL[. FDC -999 . 2 50 GR . F,~C TNPH. CNL -939.250 TN RA. CNL RCFT.CNL -999.250 CNTC.CNL CALI. CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNYC.CSG -999.250 CFTC.CSG TENS. CSG 2970.0 O0 DEPT. 4200.000 ILO.OiL SP. OIL -999.2 50 GR. OIL RHOB.FDC -999.250 DRHC.FOC CALIo FDC -999.250 GR. FDC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNR~oCSG -999,250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2950.000 DEPT. 4100.000 !LO.OIL SP. OIL -999. 250 G~. DIL RHOB.FDC -999,250 DRHO.FDC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 T~R~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL 1-9'99.2,50 TENS.CNL TNR~.CSG -999,250 NPDR.CSG CNTC.CSG -999.250 CFTC.CSG TENS. CSG 29,20. 000 DEPT. 4000. 000 ILO, OIL SP.OIL ,-999,250 GR.DIL RHOB.FDC -999,250 ~RHD,FDC CALI. FDC -999 . 2 50 GR . FOC TNPH.CNL -999.250 TN~.CNL RCFToCNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 MPOR.CSG 30-JUN-19B9 13:39 -999.250 5R.CSG 65.250 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -399.250 CFTC.CNL -999.250 -999. 250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999. 250 GR.CSG 73.938 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FOC -'999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CN[ -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR. C SG 72. 063 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFOC.FDC -999.250 -999.250 TENS.FgC '-999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC,CNL -999,250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 G~.CSG 54.594 -~99.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFOC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.C NL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999. 250 GR. CSG 6 3. 344 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 ~FDC.FDC -999.250 -999. 250 TENS. FDC -999. 250 -99'9.250 NPDR.CNL -999.250 -'999.250 CFTC.CNL -999.250 -999. 250 NPHI,CSG -999.250 -999. 250 ~CNT.CSG -999.250 C~LI.CSG SFLU.DIL DPHI.FDC Nm~C.FOC NPHI.CNL RCNT.CNL GR.CNL TNPH.CS~ RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC N~DC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.~DC NFDC.FOC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCEToCSG C&LI.CSG SFLU.DIL DPHI.FOC N~DC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.,250 -999,250 -999.250 -999.2.50 -999,250 -999.250 -999.250 -999.250 -999.250 13 .IS TAPE VERIFZCAT!ON LISTING ;CHLUMBERGER ~L~SK~ COMPUTING CENT:_R CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2854.000 DEF'T. 3900.000 ILD.CiL SP.DIL -999.250 GR.DZL RHOB.FDC -999.250 DRHO.FDC C~LI.FDC -999.250 GR.PDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNR~.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.C,SG TENS.CSG 2800.000 DEPT. 3800.000 ILD.DIL SP.OIL -999.250 GR.CIL RHOE.FDC -999.250 ORHG.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C&LI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2774.00~ DEPT. 3700.000 ILO.OIL SP.OiL -999.250 GR.DIL RHO~.~DC -999.250 DRHO.FOC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TN~A.CN[ RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPDR.CSG CNTCoCSG -999.250 CFTC.CSG TENS.CSG 2700.000 DEPT. 3600.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 ORHO.FDC CALI. FDC -999.250 GR . FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNR,~.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2_6'70. 000 DEPT. 3500.000 ILD.DIL SP.DIL -999.2E0 GR.DIL RH05. FDC -999.250 DRHO. FDC C A:LI . FDC -999 . 250 GR. FDC TNPH.CNL '-999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999' 250 NPOR.CSG 30-JUN-t989 13:39 -999.250 GR.CSG 73.000 -999.250 ILM.OiL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.!50 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 56.500 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FOC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CF'TC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 58.719 -999.250 ILM.DIL -999.250 TENS.DIL -999.250 ~FDC.FDC -999.250 TENS.FDC -999.250 NPOR.CN[ -999.250 CFTC.CNL -999.250 NPHI.CSG -999.2~0 RCNT.CSG -999,250 GR.CSG -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 78,563 -999.!50 ILM.DIL -999.250 -999.25D TENS.DIL -999.250 -999.250 FFDC.FOC -999.250 -'999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999,250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999. ]2,50 GR. CSG 66,938 -999.250 ILM.DIL -999,250 TENS.DIL -999.250 FFDC.FOC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 NPHI.CSG · -999.250 RCNT.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999,250 C&LI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL PCNT.CNL G~.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC N:DC.~DC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.:CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999. 250 -999.250 -999,250 -999.250 -999.250 14 .IS TAPE VERIFICATION LISTING iCHLUMSERGER ~LASK.~ COMPUTING CENTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2624.000 DEPT. 3400.0 O0 ILO. 0 IL SP.DIL -999.250 GR.DZL RHOB. FDC -9 99.2 50 OR HO. FDC CALZ.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2564.000 DEPT. 3300.000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB. FDC -9 99.250 DRHO. FDC C,ALI . FDC -999.2 50 GR . FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.230 CNTC.CNL CALI.CNL -999. 250 TENS.CNL TNR~.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2494.000 DEPT. 3200.000 ILD.DZL SP.DIL -999.2 !50 GR. tlL RHOB.FDC -999.250 DRHO.FOC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG ,2470. 000 DEFT. 3100.000 ILD.OIL SP.DIL -999.250 GR.DZL RHOB.FDC -999.250 gRHO,FDC CALT. FDC -999.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2.50 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NFOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2404. 000 DEPT. 3000. 000 ILO. DZL SP. OIL -9'99.2 50 gR. DIL RHOB.FDC -999.250 DRHO.FDC CALI. FOC -999. 250 GR. FOC TNPH.CNL -$99.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999. 250 NPOR.CSG 30-JUN-1989 13:39 -999. 250 GR.C SG 70. 625 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.250 ~FDC.FDC -99).250 -999.250 TENS,FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL --999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -)99.250 -999. 250 GR.CSG 31.84~ -999.250 ILM.DZL -999.250 -999. 250 TENS.D[L -999.250 -999.250 .~FOC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 - 999. 250 GR. CSG 31,672 -999.250 ILM.DIL -999.250 -)99..250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 --999. 250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999. 250 GR.CSG 36.938 -999.250 ILM.D[L -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FgC -999.250 -999,250 NPOR.CNL -999,250 -999.250 CFTC.CNL -999..250 -999.250 NPHI.CSG -999.250 -999. 250 RCNT.CSG -999.250 -999. 250 GR.CSG 31.922 -999.250 ILM.DZL -999.250 -999.250 TENS,DIL --999.250 -999.2,50 FFOC.FOC -999,250 -999.250 'TENS.FDC -999.250 -999.250 NPDR.CNL --999.250 -999. 250 CFTC.CNL -999.250 -999. 250 NPHI.CSG -999.2.50 -999.250 ~CNT.CSG -999.250 C ,~ L I. C S G SFLU.DIL DPHI.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALZ.CSG S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT,CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC..FDC NPHI.CNL RCN'T.CNL GR.CNL TNPH.CSG RCF'T.CSG CALI.CSG S~LU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TNPH.CSG RCFT.CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 -999.250 -9'99. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25.0 -9'99.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999. Z 50 -999.250 -999.250 15 ,IS TAPE VERIFICATION LISTING CHLUMBERGER ~LASK~ COMPU'TING CENTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2350. 000 39-JUN-1999 13:39 -999.250 GR.CSG 30.984 DEPT. 2900.000 ILD.DIL -999.250 IL~.OIL -999.250 SP.DIL -999.250 GR.~IL -999.250 TENS.DIL -999.250 RHOB.FDC -9'99.250 DRHO.FDC -999.250 ~=FDC. FDC -999.250 CALI.FDC -999.2.50 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.259 CFTC.CML -999.250 CALI.CNL -999.250 TENS.CML -999.250 NPHI.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSS -999.250 CFTC.CSG -999.250 GR.CSG 30.844 TENS.CSG 2250.000 DEPT. 2800.000 ILD.DIL -999.250 ILM.CIL -999.250 SP.OIL -999.250 GR.DIL -999.250 TENS.DIL -999.250 RHOB.FDC -999.250 DRHO.FOC -999.!50 FFOC.FOC -999.250 C~LI.FDC -999.250 GR.FDC -999. 250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -'999.250 RCFT.CNL -999.250 CNTC.CNt -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -99~9. 250 NPHI.CSG -999.250 TNRA.CSG -9'99.250 NP'OR.CSG -~99.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 28.719 TENS.CSG 2190.000 DEPT. 2700.000 ILO.DIL -999.250 ILM.DIL -999.250 SP.OIL -999.2.50 GR.DIL -999.250 TENS.DIL -999.250 RHOB.FDC -999.250 DRH~.FDC -99'9.250 FFOC.FDC -999.250 CALI.FDC -999.250 GR.FDC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPSR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 C,~LI.CNL -999.250 TENS.CML -999. 250 NPHI.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CNTC.CSG -999.250 CFTC.CSG -999.250 GR.CSG 38.125 T EMS. CSG 2110. 0 O0 DEPT. 26 00.0 O0 ILO. 0 IL SP. OIL -999.2 50 GP. OIL RHOB. FDC -999. 250 DRHO. FDC CALI. FDC -999.250 GR. FDC TNPH. CNL -999.2 50 TNRA. CNL RCFT.,CNL -999.250 CNTC.CNL CALI.CNL -9'99.250 TENS.CNL TNRA.CSG -999.250 NPDR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 2035.000 -999.250 !LM.DIL -999.,250 TENS.D!L -999.250 FFOC.FDC -9'99.1250 TENS.FDC -99'9.250 NPOR.CNL -999.250 CFTC.:CNL -999.250 NPHZ.CSG -999.250 RCNT.CiSG -999.250 GR.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -:999.250 -999.250 -999.250 25.703 DEPT. 2500.000 ILD.OIL -999.250 ILM. DIL -999.250 SP.DIL -999.250 GR.gIL -999.250 TENS.DIL -999.250 RHGB.FDC -999.250 ORH~.FDC -99'9.250 FFDC.FDC -999.250 CALI.FDC -999.250 GR.FOC -999.250 TENS.FOC -999.250 TNPH.CNL -999.250 'TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALZ.CNL '-999.250 TENS.CNL -999.250 NPHI.CSG -999.250 TNRA.CSG -999.250 NPOR.CSG -999.250 RCNT.CSG -999.250 CALI.CSG SFLU.DIL DPHI.mDC NF~C.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FOC NFDC.FDC NPHI .CML RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: 16 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25C -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 - 999..250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ,-999.250 -999.250 -999.250 -999.250 -999.250 -999-250 ,-999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING ~CHLUMBERGER ~LASKA COMPUTING CENTER CNTC.CSG -999.250 C~TC.CSG TENS.CSG 1990.000 DEPT. 2400.000 ILD.CIL SP.DIL -999.250 GR. C,'IL RHO~. FDC -999.250 DRHD. FOC CALI.FDC -gg9.250 GR. FDC TNPH.CNL -999.250 TKRA.CNL RCFT.CNL -999.25C CNTC.CNL CALI.CNL -999.250 TENS.CML TNR~.CSG -999.250 NPOR.CSG CNTC.CSG -999,250 CFTC.CSG TENS.CSG 1950.000 DEPT. 2300.000 ILD.DIL SP.DIL -999.250 GR.~IL RHOB.FDC -999.250 DRHD.F~C CALI. FDC -999.250 GR. F DC TNPH. CNL -999.250 TNRA. CNL RCFT. CNL -999.2 50 CN'TC, CNL C~LI.CNL -999,250 TENS.CML TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 1930.000 DEPT. 2200. 000 ILD.OIL SP.OIL -999.250 GR.DIL RHOB. FDC -999.250 DRHO.FDC C ALI. FDC -999o 2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999,250 TENS.CNL TNRA.CSG '-999.,250 NPgR.CSG CNTC,CSG -999,250 CFTC.CSG TENS.CSG 1~75. 000 DEPT. 2100- 0 O0 ILO. DIL SP.DIL -999.250 GR.~IL RHOE.FDC -999.250 DRHO.FDC CALI. FDC -999,. 250 GR. FDC TNPM.CNL ,-9'99,250 TNRA.CNL RCFT.CNL -999,250 CNTC.CNL CALI,CNL -999,250 TENS.CML TNRA.CSG '-999.250 NPOR-CSG CNTC.CSG -999,250 CFTC.CSG TENS.CSG 1835.000 DEPT. .2000. 000 ILD.B IL SP.DIL -999.250 GR.DIL RHOE.FDC -999.250 DRHO.FgC CALl. FDC -999.250 GR. FDC TNPH.CNL '-999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA,.CSG -999.250 NPg~.CSG 3 O-JUN-1989 13:39 -999. 250 GR.CSG 21. -9'99.250 ILM.DIL -999.250 -999.250 TENS.DZL -999.250 -999. 250 FFDC. FDC -999. 250 -999.250 TENS.FDC -999.250 -999.2.50 NPOR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 25.703 -999.250 ILM.OIL -999.250 -999.~50 TENS.DIL -999.250 -999.250 FFDC.FDC -999,250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999,250 -999..250 CFTC.CNL -999.250 -999. 250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 27.281 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999,250 FFDC.FDC -999.250 -9'99.250 TENS.FDC -99:9.250 -999.250 NPOR.CNL -999.250 -999. 250 CFTC,CNL -999.250 -999,250 N~HI.CSG -999,250 -999. 250 RCNT.CSG -999.250 - 999. 250 GR. CSG 14. 508 -999.250 ILM.DIL -999.250 -999. 250 TENS.DIL -999.250 -999. 150 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -'999.250 -999. 250 NPHI.CSG -999.250 -999.250 ~CNT.CSG -999.250 -999. Z5O GR. C SG 21.3'75 -999.250 ILM.DIL '-999.250 TENS.DIL -999.250 FFDC. FDC -999. 250 TENS. FDC -999..250 NPOR.CNL -999.2,,'50 CF~TC.CNL -999.250 NPHI.CSG -999.2:5'0 RCNT.CSG -999.250 -999.250 -999.2.50 -999.250 -999. 250 -999.250 -999.250 -999.250 C,&L~,CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT .CSG CALI .CSG SFLU.DIL DPHI .FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT. CSG CALI.CSG SFLU.DIL DPHI,FDC NFDC,FDC NPHI .CNL RCNT .CNL GR,CNL TNPH,CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR .CNL TNPH.CSG RCFT .CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: -999.250 ~999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.250 -9'99. 250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2 50 17 .IS TAPE VERIFIC4TION LISTING ;CHLUMBERGER ~LASK~ CO~P'UTING CENTER CNTC.CSG -999.250 CFTC.CSG TENS.CSG 1775.000 DEPT. 1900.000 ILD.gIL SP.DIL -999.250 GR.BIL RHOB. ~DC -9 99.2 50 ORHO. CALI. FDC -999.2 50 GR. ~DC TNPH.CNL -999. 250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999. 250 TENS.CNL T NRA. CSG -999.2 50 NP OR .C SG CNTC.CSG -999. 250 CFTC.CSG TENS.CSG I730.000 DEPT. 1800.000 ILD.DiL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -999.250 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999. 250 NPOR.CSG £NTC.CSG -999,.250 CFTC.CSG TENS. CSG 16 55. 000 DEPT. 1700.0 O0 ILD. E'IL SP. DIL -999.250 GR. ~IL RHOB.FDC -999.250 ORHO.FDC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -9'99.250 CNTC.CNL CALI.CNL -999. 250 TENS.CNL ~NRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CFTC.CSG T~NS. CSG If 10.0 O0 OEPT. 1600. 000 ILO. CIL SP. OIL -999. 250 GR. DIt RHOB.FDC -999.250 DRHO.FOC C ALI. FDC '-9 99.2 50 GR. FOC INPHoCNL --999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -9'99.250 CFTC.CSG TENS.CSG 1555. 000 DEPT. 1500. 000 ILO. DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 ORHO.FOC CALI. FDC -999. 250 GR. FDC TNPH.CNL -999.250 'TNR~.CNL RCFT.CNL -9'99.250 CNTC.CNL C,~LI.CNL -999.250 TENS.CNL TNRA.CSG -999. 250 NPOR.CSG 30-JUN-1959 13:39 - 999. 250 GR.C SG 3 5. 969 -999. 250 ILM.RIL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPDR.CNL -999.250 -999. 250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 17.141 -999. 250 ILM.DIL -999.250 -999. 250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -99'9.250 TENS.FDC -999.250 -999.250 NPDR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -'999. 250 GR. CSG 2 5.313 -999. 250 ILM.D!L -999.250 -999.250 TENS.DIt -999.250 -999.250 FFDC.~DC -999.250 -99!).250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CN[ -999.250 -999.250 NPHI.C~SG -999.250 -999.250 RCNT.CSG -999.250 -999. 250 GR.CSG 22. 906 -999.250 ILM.DIt -999.250 -999.250 TENS.DIL -999.250 -999. 250 ~FDC.FDC -999.250 -999. 250 'TENS. FDC -999. 250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.C]SG -999.250 - 999. 250 GR.CSG 1 7.625 -999.250 ILM.O!L -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FOC -999.250 -999.250 TENS.F~C -'999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.25:0 NPHI.CSG -999.250 '-999.25~ RCNT.CSG -999.250 CALI.CSG SmLU.DIL DPHI.FDC NFgC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCET.CNL GR.CNL TNPH.CSG RCF'T.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~II.CSG SFLU.DIt DPHI.FDC NFDC.FDC NPHI.CNL RC~'T.CNL GR.CNL TNPH.CSG RCFT.CSG CAL!.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: 18 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2150 -999.250 -999.2!50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.25'0 -999.250 -999. 250 -999.250 -99'9.250 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 .IS T~PE VERIF!C~TIgN LTST!NG ;CHLUMBERGER AL~SK~ COMPUTING CENTER, CNTC.CSG -999.250 CFTC.CSG TENS.CSG 1550.000 DEPT. 1400.0 O0 ILD. D iL SP.DIL -999.250 GR.DZL RHDS.~DC -999.250 DRHO.FDC CALI. FOC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.2.50 TENS.CNL TNRA.CSG -999.250 NPgR.CSG CNTC.CSG -999.250 CFTC.CSG TENS.CSG 1495.000 DEPT. 1300.000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FgC C ALI.FDC -999.250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALZ.CNL -999.250 TENS.CNL TNR.&.CSG -999.250 NPgR.CSG CNTC.CSG -999.250 CFTC.CSG TEN.S.CSG 1460. 000 DEPT. 1200. 000 ILO. OIL SP.OIL -999.250 GR.DIL RHOB.FDC -999.250 DRHG.FDC CALI. FDC -999. 250 GR. FgC TNPH.CNL -9'99.250 TNRA.CNL RCFT.CNL -999,250 CNTC.CNL CALI.CNL -999.250 'TENS.CNL TNRA.CSG -999,250 NPOR.CSG CNTC,CSG -999.250 CFTC,CSG TEN S. CSG 1405.0 O0 DEPT. 1100o000 ILD.DIL SP.DIL -999.250 GR.gIL RHDB.FDC -999.250 DRHD.FOC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 'TNRA.CNL RCFT.~CNL -999.250 CNTC.CNL CALIoCNL -999.250 TENS.CNL TNRA.CSG -999.250 NPOR.CSG CNTC.CSG -999.250 CF'TC.CSG TENS.CSG 1325. OOO DEPT. 1000. 500 ltD. DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 gRHD.FOC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL TNRA.CS~ -999.250 NPOR.CSG 3O-JUN-19~9 13:39 -999.250 GR.CSG 27.556 -999.250 ILM.DiL -999.250 -999.250 TENS.OIL -999.250 -999.250 :FDC.FOC -99'9.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 NPHI.CSG -99'9.250 -999.250 RCNT.CSG -999.250 -999.250 ~R.CSG 20.094 -999.250 IL~4.DIL -999.250 -999. 250 TENS.DIL -999.250 -999.250 ~FDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999. 250 NPDR. CNL -999.250 -999.250 CFTC.CNL -999.250 -999. 250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 -999.250 GR.CSG 21.625 -999.250 ILM.DIL -999.250 · -999.250 TENS.OIL -999.250 -999.25.0 FFDC.FOC -999.250 -999.250 'TENS.FDC -999.250 -999.250 NPDR.CNL -999.250 -999. 250 CFTC.CNL -99 9. 250 -999.2,50 NPHI,CSG -999.250 -999.250 ~CNT.CSG -'999.250 -999. 250 GR. CSG 1 7.375 -999.!50 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFOC,FDC -999.250 -999. 250 TENS,FDC -999.250 -9~99.~50 NPOR.CNL -999.250 -999.250 CFTC,CNL -999.250 -999.250 NPHI.CSG -999.250 -999.250 RCNT.CSG -999.250 - 999. 250 GR.C SG 13. 977 -'999.250 ItM. gIt · -999.250 TENS.OIL -999.250 FFDC.FDC -999.1250 TENS.FDC -999.250 NPOR,CNL -999.250 CFTC.CNL -999.250 NPHI.CSG -999. 250 RCNT.CSG -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -'999. 250 -999.250 CALI.CSG SFLU.DIL DPHI.FDC NFCC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC N=DC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG CALI.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TNPH.CSG RCFT.CSG C~LI.CSG SFLU.DIL DPHI.FDC NFOC.FOC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT,CSG CALI.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TNPH.CSG RCFT.CSG PAGE: -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.2,50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 19 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ~LASK& COMPUTING CENTER ~-O-JUN-1989 13:59 PAGE: 20 CNTC.CSG -999.250 CFTC.CSG TENS.CSG 1290.000 -999.250 GR. C SG 14.797 C~LI.CSG -999.250 :ND OF DATA '~ * ~- ~-' FILE TRAILER FILE NAME : EDIT .~01 SERVICE : FLIC VERSION : O01A02 DATE : ~9/06/30 M~X REC SIZE : 1096 FILE TYPE : LO L~ST FILE : ~-.~-~ ~- FIL~,_ HE ~ C'E R '~'-~'~- ~..-.. FILE :NAME ' EDIT .002 SERVICE : FL!C VERSION : 001A02 DATE : 99/06/30 MAX REC SIZ,5 : 1096 FILE TYPE : LO L A S T F ! LE : FILE - ~D~T.O02 A2CO AL.~SK~, INC. KUPARUK 2K-2 50-103-20101 MAIN PASS L~OG D~TA DATA SAMPLED EVERY -.1000 FEET D~TA INCLUDED - TOOL EXTENSION TOOL TYPE US:ED NAME FDC . FDH CNT'-A/D/H .CNH FOR~'~ATI ON DENSITY COMPENSATED NEUTRON 7692' TO 72~,6' 7676' TO 7236' IS TAPE VERIFIC.~TZDN LISTING CHLUMBERGER ~LASK~ COMPUTING CENTER 30-3UN-1989 13:39 PAGE: 21 TABLE TYPE : CONS CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI ENGI WITN SON PDST EPD LMF APl] EKB EOF EGL TOD TUNI FT FT ~T FT FT FT VALU ARCO ALASKa, INC. KUPARUK 2K-Z 50-103-20101 271' eSL & 94' ,=EL 2 ION 85 NORTH SLOPE USA TtNKH~M LOWEN/DIXON/PEAK/RENK E 549127 MSL O. RKB 154. 154. 153. 113. 7'720. DEFI COMPANY NAME FIELD NAME WELL NAME ~PI SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYP5 : CURV DEFI DEPT DPHI RHOB DRHO FFDC NFDC CALI GR TENS N PHI TNPH TNRA NPOR R CNT RCFT CNTC CFTC GR C ALI DEPTH CHANNEL NAME DENSITY ~OROSITY SULK DENSITY DELTA RHC FAR FCC COUNT 'R~TE NEAF( FDC COUNT RATE CALIPER GA'AP, A ~Y TENSION NEUTRON P~qCS!TY THER~,~L NEUTRON gORCSI'TY CALIbRaTeD THER~.~L N~U'T~ON NEUTRON gOROSITY OUTPUT FROK ~N APPLICATION PROGRAM RAW CORRECTED NEaR THE'R~AL COUNTS RAW CORRECTED ~AR THERMAL COUNTS CORRECTEg NE~R THERMAL COUNTS COR~SC'TEO FAR THERMAL COUNTS GAMMA RAY CALIPER IS TAPE VERIFICATION LISTING CHLU~3ERGER ~LA.SK~ '-O~FUT'r r_ ,., .... No CENTER 30-JUN-1989 13:39 PAGE: 22 TENS DEFI TENSION DATA FORMAT. SP:CIFICATT£N. RECORD SET TYPE - 6~,E6 ~:~ TYPE: P:PP,_ ,, CODE VALUE 1 56 0 2 66 0 3 73 80 4 66 5 66 6 73 ? 65 B 68 0.099 9 65, FT 11 66 13 12 68 1~ 66 0 14 65 FT 15 66 68 16 66 1 0 66 ~'.-~ SET 'TYPE - CHAN ** NAME SERV UNIT SERVICE AP! ~PI AP~ ~PI ~ILE NUMB NUMB SIZE REPR IO ORO:ER ~ LOG TYPE CLASS MOD NUmB SAMP ELEM CODE DEP'T FT 549127 O0 DPHI FDH PU 549127 07 RHOS FDH G/C3 549127 07 DRHD ~DH G/C3 549127 07 FFDC FDH CPS 5491 27 07 NFDC FDH CPS 549127 07 CALI FDH IN 549127 07 GR FOH GAPI 5491127 07 TENS FDH LB 549127 07 NPHI CNH PU 549127 07 TNPH CNH PU 549127 OT 'TNRA CNH 549127 07 NPOR CNH PU 549127 OT RCNT CNH CPS 5491,27 07 RC'FT CNH CPS 5491~7 07 CNTC CNH CPS 549127 OT CFTC CNH CPS 549127 07 GR CNH GAPI 54912'? 07 OOO O0 0 2 t 1 4 68 63 5 2 1 0 2 I 1 ,4 68 350 OZ 0 2 1 1 4 68 '356 01 0 2 1 1 4 68 354 0 2 0 ,2 i 1 ,4 68 354 01 0 2 I 1 4 68 280 O1 0 2 1 1 4 6~ 310 O1 0 2 1 1 4 68 635 21 0 2 1 1 4 68 890 Og 0 2 1 1 4 68 890 O0 0 2 1 1 4 68 420 01 0 2 1 1 4 68 890 O0 0 2 I 1 4 68 420 01 0 2 1 1 4 68 ,420 O! 0 2 1 1 4 68 420 01 0 2 1 1 4 68 420 O1 0 2 1 1 4 68 310 O1 0 2 1 1 4 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0,000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O00000OO00 0000000000 0000000000 0000000000 0000000000 0000000000 IS TAPE VERZFZC~TZC-N LISTING CHLUMBERGER ALASK/~ COMPUTING CENTER 30-JUN-19~9 13:39 PAGE: 23 NAME SERV UNIT SERVICE IO OROER e LOG TYPE ---- C~L! CNH IN 5/,9127 07 280 TENS CNH LB 5/,91 27 07 635 API CLASS M 0 O mILF NUMB NUMB SAMo O! 0 2 1 2! 0 2 1 NUmB CLEM 1 SIZE REPR COD5 PROCESS CHEX) 4 68 0000000000 0000000000 DEPT. 77~.200 DPHI.FDH FFDC.FDH 552.000 NFOC.FDH TENS.FDH 2270.000 NPHI.CNH NPO~.CNH 35.324 RCNT.CNH CFTC.CNH 713.557 GR.CNH DEPT. 7700.000 DPHI.FDH FFDC.FDH 534.000 NFDC.FDH TENS.FDH ~848.000 NPHI.CNH NPCR.CNH 37.053 RCNT.CNH CFTC.CNH 703.979 GR.CNH DEPT. 7600. O O0 DPHI.FDH FFDC.FDH 4B4.250 NFDC.FOH TENS.FDH 4608.000 NPHI.CNH NPOR.CNH 31.833 RCNT.CNH CFTC.CNH 1121.971 ~R.CNH DEPT. 7500.000 OPHI.FDH FFDC.FDH 7tl.500 NFOC.FOH TENS.FDH 4552.'000 NPHI.CNH NPOR.CNH 25.2t8 RCNT.CNH CFTC.CNH 1711.697 GR.CNH DEP'T. 7400.000 DPHI.FDH FFDC.FDH 450.000 NFOC.FDH TENS.~DH ~704.000 NPHI.CNH NPOR.:CNH 134.858 RCNT.CNH CFTC. CNH 763.1 !55 GR.CNH DEPT. 7300.000 DPHI.FDH FFDC.FDH 1075.000 NFDC.FDH TENS.FDH 4512.000 NPHI.CNH NPOR.CNH 50.800 RCNT.CNH CFTC.CNH 475.770 GR.CNH DEPT. 7200.000 9PHI.FDH FFDC.FDH 293.500 NFOC.FOH TENS.FDH 4324.000 NPHI.CNH NPOR.CNH 46.647 R£NT.CNH ~CFTC.CNH 413.242 GR,.CNH 14. 628. 36. 2034. 117. 14. 612. 36. 2096. 117. t0. 609. 31. 2863. 89. 22. 642. 2'7. 4002. 38. 10. ]35, 2097. 124. 34. 665. 54. 1B43. 97. 219. 47. 1,445. 90. 38 ~ SO0 342 660 563 219 50O 805 575 563 805 500 76'7 908 938 551 500 011 721 281 420 000 320 702 000 382 000 310 768 375 748 )_5O 71~ 679 R, 13 RHgB.FgH CALI.FgH TNPH.CNH RCFT.CNH CALI.CNH RHOB.FDH CAL~.FDH TNPH.CNH RCFT.CNH CALI.CNH RHOB.FOH CALI.FOH TNPH.CNH RCFToCNH CALI.CNH RHOB.FgH CALI.FDH 'TNPH.CNH RCFT.CNH CALI.CNH RHgB.FgH CALI.FDH TNPH.CNH RCFT.CNH CALI,CNH RHOB.FDH CALI.FDH 'TNPH.CNH RCFT.CNH CALI,CNH RHOB.FDH CALI .FOH TNPH.CNH RCFToCNH CALI.CNH 3 62 3 62 3 98 2 160 3 ,66 4 40 4 37 2.413 5.645 5.324 9.156 5.645 2.415 5.680 7.805 9.156 5.680 2.472 6.250 1.105 1.235 6.250 2.278 6.270 5. 894 0.890 6.270 2.,47B 6.930 4.577 4.877 6.930 2.083 6.992 9.433 8.908 6.992 2.242 6.258 6.968 1.579 6. 258 DRHO.FDH GR.FDH TNR~.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FOH GR.FDH TNR~.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CN'TC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH 0.038 117.563 2.965 2079. 096 2270.000 0.028 117.563 2.965 2163.301 4848.000 0.044 89.938 2.706 2970.294 4608.000 0.007 38.281 2. 390 3950,292 45 52.0 O0 ,0.029 134.000 2.959 2218.294 4704.000 -0.021 97. 375 4.000 1830.011 4512. 000 -0.390 90.813 3.596 1512.623 4324.000 IS TAPE VERIFIC&TIDN LISTING CHLUM~ERG;R ~LASKA COMPUTING CENTER 30-JUN-1989 13:39 ~AGE: 24 DEPT. 7193.100 DPHI.~DH FFDC.FDH 3!0.000 NFOC.FDH TENS.FDH 4312.000 NFHI.CNH NPOR.CNH 53.328 RCNT.CNH CFTC.CNH 394.305 GP.CNH 26.881 RHOB.FOH 218.750 CALI.FDH 55.B3B TNPH.CNH 1570.57~ RCFT.CNH 129.375 CALI.CNH 2.206 6.250 52.423 337.415 5.250 D~HO.FDH GR.FDH TNRA .CNH CNTC.CNH TENS.CNH -0.403 128.375 4.039 1576.405 4312.000 END OF DaTA ~-~- :~-' F IL E TR ~I LE R :~-' FILE NAME : EDIT .002 SERVICE : ~LIC VERSION : O0~A~2 DATE : 89/05/30 M~X R~C SIZe. : 1096 FILE 'TYPE : LO LAST FILE : "'"'"'"' TAPE 'rR,~IL¢ R '"""'"'"' SERVICE N:~ME : EDIT DATE : O~IGIN .'. ~LIC TAPE NAME : 73382 CONTINU~TION P~REVIDUS TAPE : COMMENT : ~RCO ALASK INC. , 'KUPARUK 2K.-2, ~PI :~50-103-201.01 ~ ~-'~ -~ REEL TRAILE9 ~-;~ SERVICE N~E : EDIT DATE : 'B9/05/30 ORIGIN : :LIC REEL NA,¥~E : 73382 CONTINUATION ~ PREVIOUS REEL COMMENT : ARCO ~LASK~ INC.~ KUPARUK 2K-2, ~50-103-20