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186-174
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan.activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) ~ Two-Sided D/Color items: Grayscale items: [] Poor Quality Originals: DIGITAL DATA D Diskettes, No. D Other, No/Type TOTAL PAGES: ~"~'jltl NOTES: ORGANIZED BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds m Other Project Proofing [] Staff Proof By: Date: PROOFED BY: Scanned (done) PAGES: SCANNED BY, BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ (at the time of scanning) BEVERLY BREN VINCE~RIA LOWELL RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd ~ ~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 7 2010 wF~ i ~nnnpi FT~ON OR RECOMPLETION REP~R~aR~.1,,,~!~,,;ccinn 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned Suspended L ~ 0 1b. Well Cla~ merft"n /~f 3~}@ Exploratory ^ lo D 20AAC 25.105 20AAC 25.11 eve p GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: Service ^ StratigraphicTest^ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: May 21, 2010 186-174 / 310-093 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 October 17, 1986 50-029-21656-01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: R9E, UM T13N Sec. 35 317' FWL Surface: 1234' FSL October 20, 1986 3K-09A , , , , Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field/Pool(s): 1325' FSL, 2199' FWL, Sec. 35, T13N, R9E, UM GL (ft above MSL): Kuparuk River Field , Total Depth: 9. Plug Back Depth (MD + ND): 1334' FSL, 2445' FWL, Sec. 35, T13N, R9E, UM 7033' MD ! 6511' ND Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + ND): 16. Property Designation: , Surface: x- 529306 y- 6008229 Zone- 4 7580' MD ! 6980' TVD ADL 25519 TPI: x- 531187 y- 6008327 Zone- 4 11. SSSV Depth (MD + ND): 17. Land Use Permit: , Total Depth: x- 531433 - 6008337 Zone- 4 2183' MD / 2183' ND 2555 18. Directional Survey: Yes ^ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700' MD / 1700' 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 MD/TVD GR/Res not applicable 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD PULLED CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 1540# Poleset 9.625" 36# J-55 Surf. 3172' Surf. 3169' 12.25" 1400 sx AS IV, 125 sx Class G 7" 26# J-55 Surf. 7559' Surf. 6962' 8.5" 91 o sx Class G, 175 sx AS I roduction or injection? Yes ^ No O If Yes, list each to 24 O 25. TUBING RECORD pen p . Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MDlTVD) 3 5 6940' 6936' MD /6431' ND I ~ 0 0~'~ ~~ 9'-7297' MD 6723'-6739' /1 ~'T ~~i 7310 26' MD 6750'-67 TVD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. ~~ 7333'-733 D 67 - 769' ND 1` ~J DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7339'-7339' MD 74'-6774' ND 7033' 25 bbls of 17 ppg cement 7344'-7344' 67 779' TVD ~~ ~ ~~~ ~ ~~ 7348'-7 2' MD 6782'-67 D 73 -7363' MD 6791'-6795' N 2 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (core) Press. psi 24-Hour Rate -> 2g, CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. '~ -'"~%~~ ,...,:;.. i.~ _ .s ~ j~~ NONE Form 10-407 Revised 12/2009Hg MAY 2 ~' ,~~ CONTINUED ON REVERSE J~~~~„~ ~,~y°~°~ ~"'y 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes Q No If yes, list intervals and formations tested, Pemlafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7108' 6581' Base Kuparuk C 7146' 6613' Top Kuparuk A 7260' 6710' Base Kuparuk A 7401' 6831' N!A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James hlinger @ 265-1102 ~O. s~,,T~/<O Printed Name V. C wv Title: Alaska Wells Manaoer ~~Z~~~© Signature lr tr"r Phone 265-6306 Date 'vG~ na....~.... A11...... l1.«.Le 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 12/2009 3K-09A Well Events Summary DATE •SUMMARY 4/11/10 TAG @ 7398' SLM w/10'x 2" DD BAILER, SAMPLE OF FRAC SAND. PERFO 30 MIN SBHP @ 7340' RKB=3089 PSI, 162 DEG F; 15 MIN GRADIENT STOP @ 7222' = 3053 PSI. SET 2.81" CAT SV @ 6983' RKB, PULL OV @ 6839' RKB & GLVs @ 5586' & 3532' RKB, IN PROGRESS. 4/12/10 PULL GLV @ 2396' RKB, SET DVs @ 2396', 3532' & 5586' RKB, CIRC. 243 BBLS DIESEL DOWN TBG UP IA, ATTEMPT 2500PSI CMIT, FAILED, IN PROGRESS, 4/13/10 CMIT TO 2500 PSI; PASSED. SET DV @ 6839' RKB; MITT TO 2500 PSI, PASSED. PULL SV @ 6972' RKB. COMPLETE. 4/15/10 PERFORMED PERFORATIONS- MIDDLE OF FIRST FULL JOINT ABOVE TUBING TAIL. CORRELATED TO K1 MARKER ON SCHLUMBERGER CBL LOG DATED 14-NOV-86. PERFORATED 7035' - 7037'; 2-INCH BH HSD GUNS, 6SPF, 60 DEG. 4/17/10 (PRE-CTD) T- POT-PASSED; T- PPPOT-FAILED; IC- POT-PASSED; IC PPPOT-PASSED; MITOA-PASSED; PT SV-PASSED; MV-PASSED; SSV-PASSED; DD TEST SV-PASSED; MV-PASSED; SSV-PASSED; SSSV-PASSED 4/19/10 TAGGED @ 7390' SLM. LOG CALIPER f/ 7380' - 6300' SLM. DATA NOT GOOD, CALIPER ARMS STUCK IN DUE TO VISCOUS /TAR-LIKE COATING. 4/20/10 MIRU; RD FOR SAFETY STAND DOWN. IN PROGRESS. 4/21/10 BRUSHED & FLUSHED TBG f/ 6500' - 7370' SLM. LOGGED CALIPER SURVEY f/ 7360' - 6500' SLM. RECOVERED DATA GOOD. COMPLETE. 4/22/10 MILL 2.75" XN NIPPLE @ 6983' RKB TO 2.80". WELL READY FOR SLICKLINE TO DRIFT NIPPLE & SET FRAC SLEEVE. IN PROGRESS. 4/23/10 MILL TIGHT COLLAR @ 57' CTMD W/ 2.87" JUNK MILL. DRIFT DRY TO SSSV @ 2183' RKB. TURN WELL OVER TO SLICKLINE, IN PROGRESS. 4/23/10 GAUGED TBG TO 2.79" THRU XN TO 7100' SLM. ATTMEPTED DRIFT FOR FRAC SLEEVE; TIGHT COLLAR @ 41' SLM. RD FOR CTU. 4/23/10 GAUGED TBG TO 2.86" TO SSSV. SET 3.5" TRMAXX-5E FRAC SLEEVE IN SSSV @ 2183' RKB (OAL=80", MIN ID=2.30"). COMPLETE. 4/24/10 LOAD WELL WITH HEATED SEAWATER. LAY IN 25 BBLS OF 17 PPG CEMENT & PERFORM HESITATION SQZ UP TO 2000 PSI, HELD FOR 1 HOUR. CLEAN OUT E R O T 70 3' R B. ELL FREEZE PROTECTED W/ DIESEL TO 2500' RKB. ALLOW 72 HOURS FOR CEMENT TO CURE PRIOR TO TAG & PT. IN PROGRESS. 4/27/10 MIT TBG 1635 PSI, GOOD TEST. TAGGED CEMENT @ 7010' SLM. PULLED FRAC SLEEVE @ 2153' SLM-2183' RKB. COMPLETE. 5/16/10 Complete reel & injector swap. Move rig from 1 Q to 3K - 09. Spot rig & equipment.. 5/17/10 Spotted Rig & Equipment. Function Tested Injector. 6 hr Weather Hold (Phase 3 Condition ) Rigged Inner Reel Iron. Stab Pipe in Injector, Rebuilt Stuffing Box. 5/18/10 Complete BOPE Test, Performed slack Mgmt. M/U BHA, RIH to mill pilot hole 5/19/10 Complete Pilot hole to 7250, Run Dummy WS to 7240 5/20/10 Completed dummy run, set whipstock @7200, Milled window TOW=7201, BOW=7206.5 . 5/21/10 Complete Window, Drill Build from 7215 to 7385, RIH with lateral BHA, Tool Failure, POOH 5/22/10 RIH with BHA#7 Drill Ahead to 8150, Lost 286BIs to hole ~OF1C-Ct~~'11~~I~JS I -;tea r1(; 2,183 GAS LIFT 2,396 SURFACE,- __ _ oa,nz GAS LIFT, _ - 3,533 GAS LIFT. _. 4,607 GAS LIFT, -_ __ 5,586 GAS LIfT, __- 6,307 GAS LIFT. 6,839 NIPPLE. 6.888 LOCATOR, 6.928 ~_ PBR, 6,922 - SEALASSV, 6,528 ~ SEPL ASSY. 6.935 PACKER. 6,936 -- 6.946 NIPPLE. 6,984 -- TBG PUNCHES, 7,935 WLEG, 7,049- IPERF, 7.284 -- RPERF. 7 279-7.297 \ IPERF. 7.zfis IPERF, 7,292 -- - - IPERF. 7,294 IPERF, 7,315 ~ " RPERF, - -: -- 7.310-7.326 IPERF. 7,325- -- --V IPERF, 7.333 IPERF,]335- IPERf. 7.344-- IPERF,-.-. • 7,346-7,352 , IPERF, 7 359-7.363 FISH. ],400- - cemenlsoz. 7,033 FISH. 7,473 --- ---- PRODUCTION, 0-7,559 TD (3K-o5a), - 7.560 KUP ~ 3K-09A __- Max A ngle 8 MD STD s - Fieltl Name - Well Status Intl (°) ( MD (ft KB) Act Bim (HKB) IKUPARUK RIVER UNIT PROD ~ 37.33 1 4,675.00 7,SSD.O H25 (ppm) Date (Annotation 'End Date 'KB-Grd (H) (Rig Release Date 120 I 2/23/2009 ,last WO: ~ 9/5/2008 I 39.90 10/17/7986 e pth (HKB) (End Date ( Annotation 'Las/ Motl .../End Date nnnr~mn Last Tag: SLM ~ 7,390.0 4/19/2010 (Rev Reason' Pun rRAC alv, t,m I ai,lc, ~ ey ~ v Strin s in C g g as ~__ __ rig ... String To 'Casing Description String 0... (String ID ... Top (ftK6) Set Depth (t... Sat Dep[h (ND) ... String Wt... Stri p 15.062 0.0 110.0 1100 62.50 H-00 (CONDUCTOR 16 ~ Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt...String ... String Top Thnl 36.00 J-55 ( ~ h O 6 5 R String TOp Thrd String _. ND)...,String WL.. (f... Set Dept 9D ... TOp (HKB) Set Depth 0... Sirin ng Descri tion Str9 Casi p g g PRODUCTION 7 ~ 6.151 00 7,559.0 26.00--JSS I _ ____ , _._ (Tubing Strings - ' _ _ _ - String Top Thrd 'Tubing Description Shing 0... iSring ID ._ Top (HKB) Sel Depih (f... Set Depih (ND) ... String Wt.. String ... EUE 8 d r TUBING 3 1/2 2.992 0.0 6,940.4 6 434 6 9.30 L-80 Com letion Details Top Depth Nom ~~~~ (ND) Top Intl Top (ftK6) (HKB) (°) Ilem Description Comment ' ID (in) 500 3 0.0 0.0 0 00. HANGER ) 3.5" Gen V Tubing Hanger EUE Srtl Motl (Pup jt 3.66 . 2,183.3 2,183.3 1.24 Satery Valve 3.5" TRMAXX-SE SCSSV wl 2.812" X Profile EUE 8rd Mad - 2 812 __ 6,888.0 6,3900, 31.54 NIPPLE 3.5"XNipple w/2.813"prof le 2.813 G,423.7 31231LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.030 6,424 0 31.23SEAL ASSY ( 6,927.9 Baker 80-40 PBR w/Seal Assembly O.D. 4.01" LD. 2.99 2.990 ription 'String O._ String ID ... T g op (HKB) Set Depth (f... Set Depih (ND) ...'String Wt... String ... String Top 1 Thn1 1/2 2.992 TUBING O 9 1 6,921.6 7,050.0 6,528.1 9-30 - L-80 EUE - - S 1 1 rd __ COmpletlOn Details To oe th - I - Nomi... (ND) ~ 7op Intl (kKB) (HKB) (°) Item Description To Comment ID (in) p 6,921-6I G 418.7 31.87•PBR (Baker PBR Polish Bore Receptacle (6 Pins 40,000 Ib Shear) 4.000 6,935 0 6 430.0 31.25 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE Srd Box Up) 3.000 ~ 6,935.9( 6,430.8. 3725 PACKER Baker 7" x 4-5" SA63 Retainer Protluction Packer (LTC Box Down) 3.250 6,946.4. 6,439.7( 3128 XO-Reducing Crossover 45" LTC Box x 3.5" EUE Srd Pin 3500 ( 6,983.8. 6.471.6 31.09 NIPPLE 2.813"'XN' Nipple -Milled to 2.80 4/222010 2.800 7 049 6,527 4'. 31.59 WLEG Wireline Entry Guide 4.18" O-D. 2.992 Other In Hole Wireline retrievable lu s, valves, um s fish, etc. Top Deplh op (HKB) T (TVD) (ftK6) Top Intl (°) Description Comment Run Date ID (in) __ 7 035 6,515 4 31.71 TBG TUBING PUNCHES w! i" BH HSD GUNS, 6 spf, 60 deg 4/15/2010 2.992 PUNCHES phase 7 400 FISH 1 112" OV 1 S" OV LOST 2/24/2006 2/24/2006 7,873 ~ FIS H 1.1/2" DV & TG Latch Dropped to Rathole 1 2116/7986 _ 12/16!1986 Perfora -- tions & Slots ~ __ _ Shot - op (HKB) T Top (TVD) Btm (ftK6) (HKB) Bim (ND) (HKBj Zone Dens Dale (s h... i Type _ Comment _ 7,279 7,297 6,723 4 6,738 7 A-3, 3K-09A 9/27/1987 8.0 RPERF 2 1/8"Silver Jet, 60 ph 7,284 ' 7 284 6,727.7 6,727.7 1 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8"EnerJet, 0 deg ph 7,289 7,289 6,731.9 6,731.9 IA-3, 3K-09A 12/14/19861 1 0 IPERF 2 1/8" EnerJet, 0 deg ph 7,292 7,292 6,734.5 6,734.5 ,A-3, 3K-09A 12/14/198611 1.0 IPERF 2 1/8"EnerJet, 0 deg ph _- 7,294 7,294 6 736.2 6,7362 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 118" EnerJet, 0 deg ph - - 7,310 7,326 6,749.8 6.763 4 ~A-2, 3K-09A 9/27/1987 8.0 RPERF 2 1!8" Silver Jet, 60 ph 7,31 5 7,315 6,754 0 6,754.0 A-2, 3K-09A 1 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,32 5 7,325 6,762.5 6,762.5 A-2, 3K-09A 12114/1986 1.0 IPERF 2 i/8" EnerJet, 0 deg ph 7,33 3' 7,333 6,769.3 6,769.3 A-2, 3K-09A 1 12/14/1986 1.O .IPERF 2 118" EnerJet, 0 deg ph 7,33 9( 7,339 6,774 4 6,774.4 A-2, 3K-09A 12/1411986 1.0 IPERF 2 118" EnerJet, 0 deg ph 7,34 4 7,344 6,778.7 6,778.7 A-2, 3K-09A (12/14(7986' 1.0 IPERF 2 1l8" EnerJet, 0 deg ph 7,348 7,352 6,782-1 A-2, 3K-09A 12114/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,359 7,363 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph Notes: General 8r Safety _ - End Date Annotation _ 9/2012008 (NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 _ - M i ndrel Details - - --- Top Depth Top Port (TVD) Intl OD Valve Latch Slze TRO Run (HKB( (°I Make Model Onl Sore Type Type l~nl (psi) Run Date Com... Stn' Top (ftKg) 1 2,396.3 2,396.2 2.10,CAMCOIMMG 1 1/2 GAS LIFT 'DMY RK 0 000 0.0 4/13/2010 2 3,532.7 3,523.811.53CAMC0`MMG 11/2 GAS LIFT (DMY RK 0.000 0.04/13/2010 -- 3 4,606.5 4,510.4 37.11'CAMCOMMG 1 112 GAS LIFT DMY RK 0.000 0.0 9/2/2008 4 5,586 4 5,305.4 34.86 CAMCO MMG 1 1l2 GAS LIFT DMY RK 0.000 0.0 4/13/2010 5 6,307.0 5,900.3 33.83 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/212008 6 6,839.0 6,348.4 32.17 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/13/2010 ,,. PROACTIVE DIACINOSTIC SERVICES INC. • I/~f~LL LL7~ TRANS~t/1/TTAL LJ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 21 Apr-10 3K-09A 1 Report / EDE 50-029-21656-01 2) ~99~~ Signed Print Name; Date : _ a~ •~~ n~_ .D A PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88982 E-MAIL : pdsanchorag~memorvlog com WEBSITE : WWW.memorvloa.com C:\Documenls and Settvigs\Diane Williams\Desktop\Transmit_Conoco.docx WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3K-09A Run Date: 4/15/2010 Apri123, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-09A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21656-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b arreto@halliburton. com ? ~~'! T ~~ ° - a>` ~ ~ ~ (o - 1 ~~( Date: ~r~ ~.~ ~~ )1 ~(? 1~~~~- Signed: • Memory Multi-~=roger Caliper ,~ Log Results Summary << - _ Company. _ _ __ ConocoPhillips Alaska, Inc. Well: 3K-09A Log Date: Apri121, 2010 Field: Kuparuk Log No.: 10628 State: Alaska Run No.: 1 API No.: 50-029-21656-01 Pipet Desc.: 3.5" 9.3 Ib L-80 Top Log Intvll.: 6,539 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 7,049 Ft. (MD) Pipet Desc.: 7" 26 Ib. J-55 Top Log Intvl1.: 7,049 Ft. (MD) Pipet Use: Production Casing Bot. Log Intvl1.: 7,385 Ft. {MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the WLEG @ T,049' (Drillers Depth). This log was run to assess the condition of the tubing and production casing with respect to corrosive and mechanical damage prior to CTD sidetrack operations. 3-D log plots of the caliper recordings across the 3.5" tubing and 7" production casing logged are included in this report. The caliper recordings indicate the 3.5" tubing lagged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 7" production casing logged appears to be in fair condition with respect to corrosive and mechanical damage. A maximum recorded wall penetration of 39°h is recorded in an area of corrosion in joint 2 (7,103'), where the caliper also recorded 24%cross-sectional wail loss. No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the production casing logged. 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 19%) are recorded throughout the tubing logged. 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS No significant LD. restrictions are recorded throughout the tubing logg~~ ~ ,~~~ ~ ' ~ i-J „~ ~~~ ? ~ ~ 7" CASING -MAXIMUM RECORDED WALL PENETRATIONS Corrosion (39%) Jt. 2 ~ 7,103 Ft. (MD) Corrosion (25°r6) Jt. 1 Cam, 7,063 Ft. (MD} Gorrosion (25%) Jt. 3 @ 7,178 Ft. (MD) Corrosion (25%) Jt. 4 C~ 7,221 Ft. (MD} Corrosion (22%) Jt. 4.1 ~ 7,238 Ft. (MD) C ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail; PDS u memorylog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: (907) 659-2314 f~sCo-(~-L( I°JCo(oc~ • 7" CASING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Corrosion (24%) Jt. 2 7,103 Ft. (MO) No other significant areas of cross-sectional wall loss {> 14%) are recorded throughout the production casing logged. 7" CASING -MAXIMUM RECORDED iD RESTRICTIONS No significant E.D. restrictions are recorded throughout the production casing logged. Field Engineer: G. Etherton Analyst: C. Lucasan / C. Waldrop Witness: C. Kennedy ProActive Diagnostic Services, Inc. ! P,~, Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (28] } 565-1369 E-mall: PD5!amemoryiog.com Prudhoe Bay Fiefd Office Phone: (907) 659-2307 Fax; (907) 659-2314 PDS Muftifinger Caliper 3D Log Plot ~~ ~ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3K-09A Date : April 21, 2010 Description : Detaii of Caliper Recordings Across 3.5" Tubing Logged. Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-0 Log Image Map 1ft:400ft'0 100 2.5 3.5 0° 0° 90° 180° 270°~ 0° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. (ins.) 2.5 3.5 f 6550 _ Joiirt 201 - -- I _ _.. . . ~. ;~ : - - I I i _ y ~. - _.. ::, v . __ Joirrt202 --~_ I _ + _ „ ., : . 6600 ..~_- - Joirrt 203 ~, .°^-^^- i Joiee ao4 6650 ~ - ~~ = ._ - ', oirrt 205 , _ _ - ~ _ I ~_ ~.~ ..... - . :; -- ~~ ~~ - _ ' 6700 _ _.~,_ _ _ ,. JoirK206 ~ ! ; i I -- II _ -..... _ _ "_ _~ - - wrt' ? i oi~rt 207 I i I _ _- -+ ~_,...., ,,, ,. - ' 6750 ~.._ ~ _ - --w~' .: _. i Joint 2os 'i I I ._ "' I '°~ - __~::. • Joint 209 6800 Pup Jt GLM fi Pup Jt. Joint 210 6850 X-Nippkt Joint 211 6900 Baker PBR Baker KBN-22 Seal Assembly Baker 7"x4.5" SAB Packer P°p'~' 6950 Joint 212 XN-Nipple Joint 213 7000 - - d I I - ~ --I - + ..t _ - __ Joint 214 - ii t Perforations i L rt - ~i,- - w~G 7050 ^_- -•- T' Production Casing ` Nominal I.D. (ins.) :..................................................: 2.5 3.5 Min. I.D. (ins.) 2.5 3.5 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map , 1ft:400R 0 100 2.5 3.5 0° 0° 90° 180° 270° 0° • • PDS Multifinger Caliper 3D Log Plot ~-, _,~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3K-09A Date : April 21, 2010 Description : Detail of Caliper Recordings Across 7" Production Casing Logged. Max. I.D. 3-0 180° 1ft:3001t ~ 0 100 ~ 6 7 Min. I.D. (fns.) 6 7 Nominal I.D. (ins.) 6 7` 0° ss"Tubing 7040 ~ ~: :; -.. ._ _ 7050 ~,~_ ~ 7060 j I I Jant ~ j c i 7070 j orros on 25% W all ~ Penetration 7 080 i 7090 i fs ~~ ' ~ -. 7100 : - Jolnt2 i' ' Corrosion i 7110 39% Wall I Penetration I j 2a^~ 7120 j CrossSedional I Wall Loss 1 0 ~ I 3 7 e 7140 7150 Joints Corrosion 71 n^~ wan 60 Penetration 4 q 7170 I i .: I .; : : , __ -- _ _ i 7180 71 ! 90 , Joint4 Co o ion 7200 i rr s <, 25% wan ? 4. Penetration 7210 • PDS Report Overview ~-~~ ___ s.,. Body Region Analysis Well: 3K•09A Survey Date: April Z1, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8rd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metai Loss (% wall) penetration body metal loss body 20 10 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 17 pene. 0 10 6 0 0 1 loss 2 14 1 0 0 0 Damage Configuration (body ) 10 0 isolated general tine ring hole/poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 6 4 2 0 0 0 Damage Profile (% wall) ~ penetration body .metal loss body 0 50 100 ZO1 ti i GLM 6 Bottom of Survey = 214.1 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 3K-09A Kuparuk ConocoPhillips Alaska, Inc. USA April 21, 2010 Joint No. Jt. Depth (Ft.) I'Ern. t llisc i (In..) Pen. Body (Ins.) Pc n. % Vle~tal I <~ss %, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 lOD 201 653 i t O.OZ ~> <' ,92 02 656 i) 0.01 (> ~ 2.96 2 3 600 U 0.01 t Z 2.91 204 6632 ~:~ 0. 1 (~ 2.95 205 6663 (? 0. 3 ! ~ 2.91 Shallow ittin . 206 6696 U 0.02 ~i i 2.97 207 672 ~? D.0 ~) .95 208 6758 +? 0.05 19 2.94 Shallo corro io . 209 6791 U 0.03 13 1 2.93 Sh Ilow it in 209.1 68 2 (? 0. 3 13 4 2.94 Shall w ittin . 209.2 6831 ~? D U U N A GLM 6 Latch ~ 7:00 209.3 6838 i? 0.02 ~) 0 2.91 PUP 210 6847 ~? 0.02 9 I 2.96 210.1 6877 ~? 0 U i) 2. 1 X-Ni le 211 6880 ~.? 0.03 1 ; 2.93 Shallow corrosion. 211.1 6913 ~) 0 tl a 4.00 Baker PBR 211.2 6919 U 0 i) i.? 3.00 Baker KBH-22 Anchor Seal Assembl 211.3 6932 (? 0 t1 (? 3. 5 Baker 7 0" x 4.5" SA Packer 211.4 6946 U 0.04 15 ~~ 2.93 PUP Shallow ittin . 12 6950 ~? 0.0 7 ~ 2.93 12.1 6982 i? 0 t) U 2.75 XN-N' 13 6984 ~ ~ 0.01 6 2. 1 214 7016 0.36 ! ' 2.91 Perforations 214.1 7049 0 N A WL C _ Penetration Body Metal Loss Body Page 1 PDS Report Overview ~--4:. _ 5.,. Body Region Analysis Well: 3K•09A Survey Date: April 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.1D Nom. Upset Upper len. Lower len. 7 ins 26 f -55 6.276 ins 7 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%walf) ~ penetration body metal loss body 10 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% umber of joints analysed (total = 9) pene. 0 0 1 5 0 3 loss 0 0 5 4 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 6 0 6 0 0 0 Damage Profile (% wall) ~ penetration body ; _ metal loss body 0 50 1 Bottom of Survey = 7 100 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf J-55 Weil: Body Wall: 0.362 in Field: Upset Wall: Q362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: iLATION SHEET 3K-09A Kuparuk ConocoPhillips Alaska, Inc. USA April 21, 2010 Joint No. Jt. Depth (Ft.) I'~.~n. Upx~l (Intl Pen. Body (Ins.) I'en. % :b1clal loss ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 7050 O.Ut1 9 > . ~1 6.25 Corrosion. 2 7093 l).OfS 0.14 3~l _'~ 6.30 Cor osion. 7137 O 0.09 ?'i t, 6.26 Corrosion. 4 7180 t).t)~ 0.09 Z5 1~ 6.3 Corrosion. 4.1 7 3 O.U i 0.08 ' ~ I ,1 6.33 arker oint. Corrosion. 4. 7 42 0.116 0.07 2U I ~ 6. 4 ark r int. Co rosin 5 726 U.ll9 0.74 1t)l) tt3 6.09 Perforations. Sli ht Oval Defo mation. 6 7305 tr.'1 ~ 0. lt)0 'it 6. 3 erf ra~o s 7 7347 LLUS 0.6 1U0 ?_' 6. 5 Perf rati ns Penetration Body Metal Loss Body Page 1 ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ PDS Report Cross Sections Well: 3K-09A Survey Date: April 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 7 ins 26 f J-55 Anal st: C. Lucasan Cross Section for Joint 2 at depth 7102.9 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 76 Tool deviation = 29 ° Finger 1 Penetration = 0.14 ins Corrosion 0.14 ins = 39% Wall Penetration / 24% Cross-sectional Wall Loss HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections -,,. Well: 3K-09A Survey Date: April 21, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.b9 Country: USA No. of Fingers: 24 Tubin 7 ins 26 f J-55 Anal st: C. Lucasan Cross Section for Joint 1 at depth 7062.91 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 86 Tool deviation = 28 ° Finger 1 Penetration = 0.097 ins Corrosion 0.09 ins = 25% Wall Penetration HIGH SIDE = UP • • Cross Sections page 2 ~,,, ~ ~-\ ~ KUP ~ 3K-09A ConOCOPhillips II Attributes An Ie 8 MD TD .,I ,,._-.., ,. Wellbore APl 1 FINd Name ell Status Incl11 ND IMCB) AQ etm gtKB 500292165601 KUPARUK RIVER UNIT PROD 37.33 4,675.00 7.580.0 Cammmt M251ppm) Date Amala[ian Ertl Date KB-Grd Q[) Rlg Release Dale SSSV: TRDP 135 1/12/2008 Lasl WO: 9/5/2008 39 90 10!17/1986 wane ne : -3 -o tvzsrzoos o:o a37 Arn . mema[c-Actual Amotatlan Depm (IUtB) Ertl Date Amatatlan last motl ... 6q Date Last Tag: SLM 7.397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 Casin Strin s HANGER, _ Casing Deudptlon Smng 0.. . String ID ... Top (IIKB) S et Depth If... SM Depth (ND) ... Smrg WL.. Smng... Smng Top Thrtl CONDUCTOR i6 15.062 0.0 110.0 110.0 62.50 H~0 coNWC1oR, Ca51ng Descriptlan Smng 0.. . S[mg W ... Top (ttl<0 S et Deem rc... Set Depth (ND) ... Smng N2.. 9ring ... mng Top lhrtl alto SURFACE 95/8 8.697 0.0 3,172.0 3,169.4 36.00 135 Caslrg Descriptlon Smng 0.. . String ID ... Top INtB) S et Depth (t... Bet Depm (ND) ... S[rirg N2., Smrg... Smng lop Thrd sarery vawe. o 2183 PRODUCTION 7 6.151 0.0 7.559.0 26.00 J-55 Tubin Strin s Gtu uFr. 7L6irg Description Smn90... String ro... Top gtKH) Bet Depm m... Set Depth (TVD)... Smng NIL.. Smng... Smng TOp 7tIN TUBING 31/2 2.992 0.0 6,940.4 6,434.6 9.30 L-80 EUE Brd 2396 COm letion Details rap Deem (ND) Top InrJ NomL.. suRFACE 1 T I~B) 19 tt emDesc on Cammenv IDgn) . . 0.3,n2 0.0 0.0 0.00 H ANGER 3.5" Gen V Tubing Hanger EUE Brd Mod (Pup j13.66') 3.500 cast iFr 2,183.3 2,183.3 1.24 S afety Valve 3.5" TRMAXX3E SCSSV w/ 2.812" X Profile EUE Brd Mod 2.812 3533 6.888.0 6,390.0 31.54 N IPPLE 3.5"X Nipple w/2.813"gofile 2.813 6,927.6 6,423.7 31.23 L OCATOR Baker 3.5" Locator O.D. 4.54" i. D. 3.99" 3.030 cAS uFr. a Sol 6.927.9 6,424.0 31.23 S EAL ASSV Baker 800 PBR w/Seal A-asembly O.D. 4.01" LD. 2.99 2.990 Turing Description Smng 0... String ID ... Top ptl(B) Set Depm (f... SA Depth (TVD) ... String Wt.. Smng... Smng Top Thrtl TUBING Original 3 1/2 2.992 6,921.6 7,050.0 6,528.1 9.30 L-80 EUE Srtl GAS uFT. Com letion Details 6 586 Tpp p~m IND) T ap InG Noml... Top ntKB) 1~8) (°) tt em Descriptlon Cammert ID pn) G,v uFr s?ni 6,921.6 6 418.7 31.87 P BR Baker PBR Polsh Bore Receptade (6 Rns 40.000 Ib Shear) 4.000 6,935.0 6,430.0 31.25 S EAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE Brd Box Up) 3.000 Ga 6,935.9 6,430.8 31.25 P ACKER Baker 7" x 4.5" SAB3 Retainer Production Packer (L C Box Down) 3.250 s es' 6,946.4 6,439.7 31.28 X O-Retlucing Gossover 4.5" LTC Box x3.5" EUE Brd Pin 3.500 I 6,983.8 6,471.6 31.09 N IPPLE 2.813"'XN' Nipple (2.75" No-Go) 2.750 II NIPPLE, 6 666 7,049.1 6.527.4 31.59 W LEG Wnekne Entry Guide 4.18" O.D. 2.992 Other I n Hole ireline retrievabl e lu s valves u s fish etc. Top Deem INW T op ktcl Top (ttKBI ~) (°) Descriptlon Comlllenlt Run Date ID (try LocAroR 7.400 F ISH 1 1/2" OV 1.5" OV LOST 2/24/2006 2/24/2006 PeR. c.eiz sEnL Assv 7,473 F ISH 1 1/2" DV &TG Latch Dropped to Rathole 12/16/1986 12/16/1986 , sEr~L Assn Perforations 8 S lots 6,935 Bllaf Top (TVD) Bim ITID) Def15 PACKER.6936 Top (ItlB) Btin IRKB) INCB) ~B) Zane Date (sh.. TYPe Comment 7,279 7,297 6,723.4 6,738.7 A-3. 3K-09A 9/27/1987 8.0 RPERF 21/8" Silver Jet, 60 ph 7,284 7,284 6,727.7 6,727.7 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,289 7,289 6,731.9 6,731.9 A-3, 3K-09A 12/74/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph xoaaa s 3as 7,292 7.292 6,734.5 6.734.5 A-3, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,294 7,294 6,736.2 6,736.2 A-3.3K-09A 1274/1986 1.0 IPERF 2 1!8" EnerJet. 0 deg ph 7,310 7,326 6,749.8 6,763.4 A-2, 3K-09A 9/27/1987 8.0 RPERF 21/8" Silver Jet, 60 ph NIPPLE s 9aa 7,315 7,315 6,754.0 6,754.0 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph , 7,325 7,325 6,762.5 6,762.5 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 118" EnerJet, 0 deg ph 7.333 7,333 6,769.3 6,769.3 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet.O deg ph wLEC, ] oas 7,339 7,339 6,7744 6.774.4 A-2. 3K-09A 72/14/1986 1.D IPERF 2 1/8" EnerJet, 0 deg ph 7,344 7,344 6.778.7 6.778.7 A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1!8" EnerJet, 0 deg ph 7.348 7.352 6.782.1 A-2, 3K-09A 72/14/1986 7.0 IPERF 2 1/8" EnerJet, 0 deg ph IPERF, ] zsa 7.359 7.363 A-2, 3K-09A 12/74/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph ].z,¢i zsF; Notes: l3eneral8 Safe IPERF, ],299 End Dale Amotatlon IPERF. ] 292 9/20/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 IPERF, 7,294 IPERF, 7 ~ 15 RPERF, ],310.1 326 IPERF, 7 325 IPERF. 7 333 IPERF, ] 339 IPERF ] Sad Mandrel Details , Top Dee m Top Pon (TVD) Intl OD Valve latch Slze TRO RUI IPERF. Sm T INKBI (°) Make Nbdel Ilnl Sav Type Type Onl (pall Rut Date Cam.. 7,3aa-7,3sz 1 2.396.3 2.396. 2 2.10 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1.346.0 9/28/2008 2 3.532.7 3,523. 8 77.53 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,327.0 9/28/2008 mERF, ],353] 363 3 4,606.5 4,510. 4 37.71 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 4 5,586.4 5,305. 4 34.86 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,307.0 9/28/2008 5 6,307.0 5,900. 3 33.83 CAMCO MMG 1 1!2 GAS LIFT DMY RK 0.000 0.0 9/2/2008 FISH. 7,400 6 6,839.0 6,348. 4 32.17 CAMCO MMG 1 1Y2 GAS LIFT OV RK 0.188 0.0 9/27/2008 FISH. 7 473 PRODVCTION, 0.7 559 TD (3K-094), 7 580 ~_ ~~ C oPhi111 v~a"3 1/2" Comn etion Tubin Detail Well: oa1:~. 3K-09A 9/2t2~°$ onoc ps Alaska, Me. Rig: Doyon 15 Jt N b Depth um er Joints Weil Equip tion and Comments age 1 Length Tops T op ofi Strin or Top of Flan e Jts 211 to 211 1 Jt U er LDS Ori final Do on 9 RKB 35.00' 3.5" Gen V Tubin Han er EUE 8rd Mod (Pup jt 3.66' 3 5" 9 3 # 35.00 4.23 35.Oo s . . L80 EUE 8rd Mod Pu Jt 1 3 " 31.$4 39.23 Jts 145 to 21 6s Jts - .5 9.3 # L80 EUE 8rd Mod Space out Pu 4.09' 3.5" 9.3 # L80 EUE 8rd Mod Tb 3.5" 9,3 # L80 EUE 8rd Mod Pu Jt 4.09 2098.05 10.13 71.07 75.16 2173.21 3.5" TRMAXX-5E SGSSV w/ 2.813" X Profile EUE 8rd Mod 4.38 2183.34 3.5" 9.3 # L$0 EUE 8rd Mod Pu Jt 10.05 2187.72 Jts 139 to 14 6 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 190.41 2197,77 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.15 23ss.1$ 3.5" x 1.5" MMG GLM #1 w/ Dumm + RK Latch, EUE 8rd Mod s,s1 z3ss.33 3.5" 9.3 # L80 EUE $rd Mad Pu Jt 8.14 2405.24 Jts 104 to 13 35 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 1111.21 2413.38 3.5" 9.3 # L$0 EUE 8rd Mod Pu Jt 8.13 3524.59 3.5" x 1.5" MMG GLM #2 w/ Dumm + RK Latch, EUE 8rd Mod $.91 3532.72 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt - s.os 3541.63 Jts 71 to 103 33 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 1048.68 3549.72 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.12 459s.4o 3.5" x 1.5" MMG GLM #3 w/ Dumm + RK Latch, EUE 8rd Mod 8.91 46os.52 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.15 4&15.43 Jts 41 to 70 30 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 954.63 4623.58 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.1s 5578.21 3.5" x 1.5" MMG GLM #4 wl Dumm + RK Latch, EUE 8rd Mod 8.92 55ss.39 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.18 5595.31 Jts 19 to 40 22 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 695.39 5603.49 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.13 6298.88 3.5" x 1.5" MMG GLM #5 wl Dumm + RK Latch, EUE 8rd Mod 8.41 6307.01 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.13 6315.42 Jts 3 to 18 16 Jts 3.5" 9.3 # L80 EUE 8rd Mod Tb 507.36 8323.55 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt 8.13 6830.91 3.5" x 1.5" MMG GLM #6 w/ DCR-1 Shear Valve + RKP latch s.9o 6839.04 3.5" 9.3 # L80 EUE 8rd Mod Pu Jt $.11 s$a7.94 Jts 2 to 2 1 Jts 3.5" 9.3 # L80 EUE 8rd Mod 31.91 6856.05 3.5" X Ni pfe w/ 2.813" rofiie 1.68 8887.98 Jts 1 to 1 1 Jts 3.5" 9.3 # L80 EUE 8rd Mod T 31.90 6889.64 Remarks: *** S ace out From Fult Located is 0.95' *** up Wt 125 K Ali Measurments are as per Tubin Tatiie. Found PBR to 7.88' Dee with #ubin ~n Wt 12o K Total of 71 Bands used to Clam SCSSV Control line elodc Wt 7o K GLM #6 is 1500 PSl Casin to Tubin Shear Supervisors: Mike Thornton /Steve Shultz ~ f .x Number Joints Well Equipment Description and Comments Length Tops Page 2 3.5" 9.3 # L80 EUE 8rd Mad Pu Jt s.o~ 6921.54 Baker 3,5" Locator O.D. 4.51" t. D, 3.03" 32 B k 80 . s927.s1 a er -40 PBR w/Seal Assembl O.D. 4.00" I.D. 2.99 12 45 6927 93 BOttom of Tail =_» . . 6940 38 . 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.3$ 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 6940.38 Remarks: Bottom Depth of String:---------______> 6940.38 Supervisors: Mike Thornton / Sfeve ShuHz Application for Sundry to Plug Perforations KRU 3K-09A 3K-09A Sundry (10-403) ~~ Engineer: James Ohlinger r~ '~~~'~~, .. ~ ~ `"~ ~ ~~ ' ~ 7~{ ~.? c f <9 CT Drilling Engineer (907) 265-1102 The anticipated spud date for Nabors CDR-2AC to drill a CTD A-sand quadrilateral from we113K- 09A is April/May 2010. Summary of Operations: The 3K-09A original A-sand perforations will be cemented off prior to CTD drilling although A- sandproduction will be replaced by the laterals drilled in the immediate vicinity. This will be a pilot hale with 2 whipstocks exiting the 7" casing providing 4 laterals. Approximately 7,900 feet of total hole will be drilled and the productive intervals will be completed with slotted liners. Pre-RIE Wark • Slickline: Dummy perf gun drift. Obtain SBHP. Dummy GLVs, MIT-IA. • E-line: Run GR/CCL jewelry log /tie-in log (K1 Marker to Tubing Tail). Shoot holes in the 3%2" tubing below the Baker SAB3 Packer from 7033' to 7035' RKB. • Coil: Mill out the XN-nipple at 6984' RKB to 2.80" with alert-hand motor. • Coil: Lay in cement plug from PBTD plug to 7033' RKB. • Slickline: Tag top of cement, pressure test cement plug. ~„/~~ ~`3~ / e • Prepare wellsite for rig arrival. J~ .y ^ ~ ~ Rig Work ~ ~~~~ ~~ r~ 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. 3. Set top of whipstock at 7,200' MD. s~~~~~ 3jo- d`73 s. 3K-09B Sidetrack a. Drill a 2.70" x 3" bi-center lateral to a TD of 9,975' MD b. Run the 23/8" slotted liner from TD to 8,200' MD. An aluminum liner top billet will be placed at 8,200' MD. 6. 3K-09BL1 Lateral a. Kick off of the aluminum liner top billet at 8,200' MD b. Drill a 2.70" x 3" bi-center lateral to a TD of 10,050' MD c. Run the 23/8" slotted liner from TD to7,195' MD, into the pilot hole inside the 7" casing Page 2 of 4 3/31/2010 1'7"D ~ ~ Application for Sundry to Plug Perforations KRU 3K-09A 7. Set top of whipstock at 7,150' MD. s. Mi112.80" window at 7,150'. 9. 3K-09BL2 Sidetrack a. Drill a 2.70" x 3" bi-center lateral to a TD of 9,075' MD b. Run the 23/8" slotted liner from TD to 7,700' MD. An aluminum liner top billet will be placed at 7,700' MD. 10. 3K-09BL2-O1 Lateral a. Kick off of the aluminum liner top billet at 7,700' MD b. Drill a 2.70" x 3" bi-center lateral to a TD of 9,075' MD c. Run the 23/8" slotted liner from TD to 6,970' MD, inside the 3-1/2" tubing tail of the motherbore. Post-Rig Work 1. Install GLV's 2. Obtain SBHP 3. Produce to system Reservoir Pressure 3K-12 is the closest offset well injecting in the A-sand interval and had a static bottom hole pressure of 3584 psi (10.3 ppg EMW). 3K-12 has been flowing back for several months to bring the reservoir pressure down. 3K-OS has been shut in since October `09 from injecting water and it measured 4564 ps (13.2 ppg EMW, Feb. ' 10). Similar pressures are expected as the laterals are drilled. The most recent static bottom hole pressure reading in 3K-09 was 2065 psi (6.0 ppg EMW). The 3K-09 has been shut-in for 5 months to allow the reservoir pressure to build up high enough to drill without excessive losses and to mitigate high differential pressure at fault crossings. Page 3 of 4 3!31/2010 • Application for Sundry to Plug Perforations KRU 3K-09A 3K-09B + Proposed CTD Sidetrack 16" 62# H-40 shoe @ 110' MD 9-5/8" 36# J-55 shoe @ 3172' MD Packer to Tubing Tail = 104' Tubing Tail to Top of Whipstock = 100' A3 -sand pens 7279' ~ y -7297 MD F~ A2 -sand peels 7310' - 7326' MD 7333' ~ ~4t' 7339' 7344' ~.r'~ 7348' - 7352' PBTD @ 7410' 7359' - 7363' 11122109 9.3# L-80 EUE Sb Tubing to surface ID = 2.992" Camco MMG gas lift mandrels @ 2396' 3533' 4607' 5586' 6307' 6839' X Nipple @ 6886' MD (2.613" profile) PBR @ 6922' MD (4" ID) KBH-22 Anchor Seal Assembty @ 6935' MD (3.0" SA83 Packer @ 6936' MD (4.0" ID) 'XN' Nipple @ 6984' MD (2.75" min ID) @ 7049' MD I Tail @ 7050' MD 7" 26# J-55 shoe @ 7559' MD Page 4 of 4 3/31/2010 • ~ K UP 3K-09A ~, ConoeoPhillips ~ w 1 S MBX Ankle & MD I I D Ai +~~...{ i'1: i5 P r e I etus Ac ~ ) 00 92 6560 KUPARUK RIVER UNIT PROD 580.0 P H2S ) t n T dD Da te IRi9 G ... wencone -3K osq t nsi2 oos1 3 7A SSSVeTRD i 135 WO L 1/12/2008 ~Last 9/5/2008 I 0/17/1986 39.90 ~_ g: - , l - _ Schematic-Act M_ _- o:o3: . ual P ( ) Annotation De th ftKB End Date _ Last Mod ... (End Date ~ Annotation Last Tag: SLM 7,397.0 11/22/2009 Rev Reason: TAG Imosbor 11/26/2009 :,,.I~ ;i,l a Casing Strings Casing Description String O .I String ID ... Top (ftKB) Set Depth (f Set Depth AND) ... String Wt .String .. i String Top Thrd _ CONDUCTOR I 2 16 06 I 0.0 110.0 1 110.0 62.50 H-40 CONDUCTOR, __ _ ~ Casing Description I 0 String O Stnn g Top (ftKB ) iSet Depth (TVD) Set De th f String Wt String '. String Top Thrd _ avo SUR ACE 69 7 9 /8 I !. 0.0 3,169.4 3,172 0 P 36.00 J-55 9 Casin Descr lion - P 0 1 9 Strm 'Sfrin 0... g (Top (ftKB) i Set Depth (f ~ ~ Depth (TVD) ... __ _-- St 2 0 ... ~St -- Stnng Top Thrd Safe Valve, b _ -__ ~ PRODUCTION 7 ! 6.151 ~ ', 0.0 7,559.0 J55 1 fi 2.183 ------------ Tubin Strin s _i_ ~ _ -----~ i g g Tubing Description String 0... IStnng ID - Top (ftKB) - Set Depth (f... Set Depth (TVD) - _- - String Wt.. String String Top Thrd cns uFT, _ ( TUBING 3 1!2 i 2 992 ', 0.0 ~ 6,940.4 6 434 6 9.30 L-80 EUE 8rd ~. _. - _ 2,396 Completion Det _____. _ _ ails ___ ._. _ ___ - - ___ ~ -Top Depth- - T-- -_ _ (TVD) Top Incl I Nomi... ~ (ftK6) Top (ftK6) (°) ;Item Description ~ Comment ID (in) SURFACE, a3,n2 - -- _ 0 0 0 1 E P 6 1 8 2,183. 3 2,183. 3 1 .24 Safety Valve e EUE 8 3 5 TRMAXXSE S SSV 2 8 2" X Prot d Mod _ 0 - - GAS LIFT, 3,533 3 6,888.0. 6,390.0, 31.54 NIPPLE 8 3 1 11. - 3.5 X Nlpple w 2.8 3 p of e 6,927.6.. 6,423.7, 31.23,LOCATOR ,Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.030 GAS LIFT, 6,927.9 ~~ 6,424.0 31.23 ~ SEAL ASSY - - ~.. Baker 80-40 PBR w/Seal Assembly O.D. 4.01" LD. 2.99 - ~ 2.990 ~ aso7 Tubin Descri lion g p 'Strip 0... -.Strip ID ... g g ~ p ( ) p ( Set Depth (TVD) String Wt . (String ... ,.String Top Thrd ',To ftK6 Set-De th f...' TUBING Original 3 1/2 2.992 6,921.6 7,050.0 ~ 6,528.1 9.30 L-80 EUE 8rd Gns55~ Com letion Det P ails _ - ~ Top Depth -- - - (TVD) ~;. Top Incl '~ Nomi... Top (ftKB) ftK6 Item Description ) 3 Comment ID (in) cns uFT, _ 6,921.6 6,418.7 1 87~ PBR Baker PBR Polish Bore Receptacle (6 Pins 40,000 Ib Shear) 4.000 6,307 ~ 6,935.0 6,430.0 31.25' SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5" EUE 8rd Box Up) 3.000 ,- ' 6,935.9 6,430.8 31.2511 PACKER Baker 7" x 4.5" SA63 Retainer Production Packer (LTC Box Down) 3.250 GAS LIFT, s,63s -- 6,946.4 6,439.7 31.28 XO-Reducing ~ _ - - _ _.. Crossover 4 5" LTC Box x 3.5" EUE 8rd Pin _ __ 3.500 ~ 6,983.8 6,471.6. -31.09 NIPPLE 1 2.813"'XN' Nipple (2.75" No-Go) - 2.750 NIPPLE. 6:686 ~~ 7,049.1 6,527.4 - _ -- 31.59 WLEG ..___. -_-__- Wireline Ent Guide 4 18" O.D. _- -_._~ __-_-__ ry - __.__.. 2.992', ~-- Other In Hole (W T th ireline retrievab ~ - le plugs, valves, pumps, fish, etc. To ncl ~ ~ Top (ftK8)y ( KB) ; , - Descnption_ Run Date ~_ ID (in) L_ _ _ _ __ _ Comment - _ _ LocaroR - ' 7,400 ( I FISH 1 1/2" OV 1 5 OV LOST 2/24/2006 12/24/2006 ssza PeR, s,9zz - ~- - -- -- 7,473 FISH 1 1/2" DV & TG Latch Dropped to Rathole 12/16/1986 f 12/16/1986 ~ - SEALASSY, :. _ -- - - - -- .. 6,928 ~'-_- sEALASSV, PerfOratl011S $r SIOtS - __ _-_- -___ 6:935 ____. _ __- _ _ Shot ~ ~ ~ Top (TVD) Btm (TVD) Dens PACKER, 6,936 - - To ftKB P ( ) ( ) ' elm ftKB ( ) (ftK8) Zone Date sh ( Type Comment - ,279 , _ _ _ _ 6,738.7 A-3, 3K-09A 9/27/1987 8 0 -- RPERF 2 1/8" Sllver Jet, 60 ph . - 6,727.7 A-3, 3K-09A 1 ! 12/14/19861 1 0 - - IPERF 2 1/8" EnerJet, 0 deg ph _ _ 7,289- 7,289 6,731.9 A-3, 3K-09A 1, 6,731.9 12/14/1986 1.0 - IPERF ',2.1/8" EnerJet, 0 deg ph X0.Reducing, 6,946 NIPPLE, 6,984 WLEG, 7,049 IPERF, 7,284 ---_ RPERF, 7,279-7,297 ~~, IPERF, 7,289 IPERF, 7,292 IPERF, 7,294 7,292, 7,2921 6,734.51 6,734.5iA-3, 3K-09A , --L 12/14/19861 _ - 1.0 IPERF _ lit 1/8" EnerJet, 0 deg ph 0 , 6 736 2 A-3, 3K-09F, ~ 12/14/1986 IPERF 1 0 j 2 il8" EnerJet, 0 deg ph 7,31 7 3 6' 6,749.8 -II-- 6,763 4 A-2, 3K-09A 19/27/1987 8 01 RPERF - 2 1/8" Silver Jet, 60 ph 7,315 7,315' 6,754.0 6,754.0 A-2, 3K-09A - 12/14/1986 1.011PERF ( -- 2 1/8" EnerJet, 0 deg ph 7,3251 ' I 7,325', 6,762.5 6,762.5 A-2, 3K-09A -- 12/14/1986 IPERF 1.01, i~2 1/8" EnerJet, 0 deg ph ,, 7,333 I 7,33311 6,769.3 A-2, 3K-09A 6 769.3 12/14/1986 - 1.0 IPERF ~-- 2 1/8" EnerJet, 0 deg ph I 4 1 6 774 4+A-2, 3K-09A - 12/14/1986 - 1 0 IPERF - 2 1/8" EnerJet, 0 deg ph - 7,344 1 7,34 1 6,778.7 6 778 7,A-2 3K-09A 12/14/1986 1 0 IPERF 2 1/8" EnerJet, O deg ph 1 6,782.1 ~ 1 OIPERF 2 1/8" EnerJet, 0 deg ph 7,359', 7,363 iA-2, 3K-09A .12/14/1986 ', 1.O IPERF 2 1/8" EnerJet, 0 deg ph IPERF, 7,315 RPERF, 7,310.7,326 IPERF, 7,325 6 SEAN PARNELL, GOVERNOR James Ohlinger Coiled Tubing Drilling Engineer ConocoPhillips Alaska, Inc. ~" APrt ~ ;~: ~Q1~ P.O. Box 100360 Anchorage, AK 99510 ~~ ~. Re: Kuparuk River Field, Kuparuk River Oil Pool, 3K-09A Sundry Number: 310-093 Dear Mr. Ohlinger: 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 pxovided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair s DATED this ` day of March, 2010. Encl. STATE OF ALA~KA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 IRECEI1lEl~ IMAR~~2010 1. Type of Request: Abandon j""`" Rug for Redrill ~:~~I~rforate New Pool Repairwell ~""° Suspend ~"" Rug Perforations ~` • Perforate "" Pull Tubing ~'"` '~~~xtension '°" Operational Shutdow n Re-enter Susp. Well ~" Stimulate Aker casing ~ Other: ~"` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory j"""' 186-174 ' 3. Address: Stratigraphic Service "°°, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21656-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ~ No 3K-09A 9. Property Designation: 10. Field/Pool(s): ADL 25519, ~~~~. ~• ~~ Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Deptn MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7580 6980 7400', 7473' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110' 110' SURFACE 3172 9.625 3172' 3169' PRODUCTION 7559 7 7559' 6962' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7279'-7297', 7310'-7326', 7333'-7363' 6723'-6739', 6750'-6763', 6769'-6795' 3.5" L-80 7050' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -BAKER 7" X 4.5" SAB3 RETAINER PRODUCTION PACKER MD= 6936 ND= 6431 Safety Valve - 3.5" TRMAXX-SE SCSSV w/ 2.812" X Profile EUE 8rd Mod M0= 2183 ND= 2183 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory ~ Development ~ Service ~"" 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: e~j~~s ~?!,~ c`S~ 3/31/2010 F'lu 3 Oil ~ Gas "° WDSPL ~ 16. Verbal Approval: Date: WINJ ~"' GINJ ~ WAG ~ Abandoned ~"` Commission Representative: GSTOR ~ SPLUG ®" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Printed Name James Ohlinger Title: Coiled Tubing Drilling Engineer Signature Phone: 265-1102 Date 3~0'l~o//O C mi i n nl Sundry Number: ~1 ~ ,_,•, Conditions of approval: Notify Commission that a representative may witness ` BOP Test _ Mechanical Integrity Test Location Clearance [" Plug Integrity "` 2 ~C~ I~ ~5 t `" ~ `~ ~~ ~ ~ S ~ Other: ~,- - - / Subsequent Form Required: / ~ ' APPROVED BY .•~ ~ ~ ~ ~ D ! Approved by: COMMISSIONER THE COMMISSION Date: 3 Z~ ~ a Form 10-40 evTs~~iTZ/ ~ ~' 20~ ~ Q ~ G ~ N ~ L Submit in Duplicate Application for Sundry to Plug Perforations KRU 3K-09A 3K-09A Sundry (10-403) Engineer: James Ohlinger CT Drilling Engineer (907) 265-1102 The anticipated spud date for Nabors CDR-2AC to drill a CTD A-sand quadrilateral from well 3K- 09A is April/May 2010. Summary of Oaerations: The 3K-09A original A-sand perforations will be cemented off prior to CTD drilling although A- sand production will be replaced by the laterals drilled in the immediate vicinity. This will be a pilot hole with 2 whipstocks exiting the 7" casing providing 4 laterals. Approximately 7,900 feet of total hole will be drilled and the productive intervals will be completed with slotted liners. Pre-Rid Work • Slickline: Dummy perf gun drift. Obtain SBHP. Dummy GLVs, MIT-IA. • E-line: Run GR/CCL jewelry log /tie-in log (K1 Marker to Tubing Tail). Shoot holes in the 3%2" tubing below the Baker SAB3 Packer from 7033' to 7035' RKB. • ' Coil: Mill out the XN-nipple at 6984' RKB to 2.80" with alert-hand motor. • Coil: Lay in cement plug from PBTD plug to 7033' RKB. • Slickline: Tag top of cement, pressure test cement plug. ~ 3d3D,Crr • Prepare wellsitne for rig arrQival. ~''~ ~ '~ u- ~ Tv// ` ~ ~ n /~ o (~ r ~ ~ Pr ~a '~ ~"~..~ ~ ,~~~ C,> ~~ p S C a c jC / la~..~.~~-~' ~ 1 ~+--.r.~C?~ j ((( ~ ` /~~`~ c©~~~. ~' ~~r od ~~St~, ~ ~~ ~~ ~- ~~~ ~~Q~~ ,~e ^., ~~~~~ Page 2 of 2 3/26/2010 ~- ~C}~lt)Ct~~`"11 ~ ~ 1 - Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 25, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a sundry to plug the perforations in the A sands of Kuparuk Well 3K-09A (PTD# 186-174) utilizing cement. The plugging is being done as part of the pre-rig preparation for upcoming coiled tubing drilling (CTD) operations. The work is scheduled to begin in April/May 2010. The CTD objective will be to drill an A-sand quadrilateral producer. Permit to Drill applications for those laterals have been submitted separately. Attached to this Sundry application is an outline of job operations (including those of the CTD project). If you have any questions or require additional information please contact me at my office 907-265-1102. Sincerely, ~-'~~ . James Ohlinger Coiled Tubing Drilling Engineer 3K-09B + 9.3# L-80 EUE 8rd Tubing to surface ID = 2.992" 16" 62# H-40 shoe @110'MD 9-5/8" 36# ,155 shoe ~ 3172' MD 1/2" Camco MMG gas lift mandrels Q 2396' 3533' 4607' 5586' 6307' 68 39' X Nipple Q 6888' MD (2.813" profile) Packer to Tubing Tail = 104' Tubing Tail to Top of Whipstocks 100' 7200' A3 -sand perfs 7279' -7297' MD AZ -sand perfs 7310' -7326' MD 7333' 7339' 7344' 7348'-7352' 7359'-7363' Proposed CTD Sidetrack P BT D ~ 7410' 11122/09 Perts for Cement 7033' - 7035' South Laterals KOP - 8200' T' 26# .155 shoe @ 7559' MD Baker PBR @ 6922' MD (4" ID) Baker KBH-22 Anchor Seal Assemby ~ 6935' MD (3.0" ID) Baker SAB3 Packer @ 6936' MD (4.0" ID) 2.813"'XN' Nipple @ 6984' MD (2.75" min ID) @ 7049' MD Tail @ 7050' MD KOP - 7700' ff ~ ii. ~_ •°-- •9075' WP03 ,~ . -- ~_. KUP 3K-09A , ~f~110CU~'11~f1~5 } } Well Attributes -- Ma1c An91e b MD - - ~'~-- _ ' . Wellbore APUUWI _ Field Name Well SWtua Incl (°) i MD (RKB) Act Bt (11KB) ~ ."~ 500292165601 KUPARUK RIVER UNIT PROD 37.33 ~ 4,675.00 7,580.0 -~- ~~~~~ Comment H331ppm) Date Annotation End Date iKB-Grd IR) Rig Release Date 3K-0BA 11@8/2008 70 03 °°° WNI C 37 AM SSSV: TRDP ~ 135 1112/200 8 Last WO: 9/5/2008 ~ 39.90 10/17/1986 : on - Sdem Nb-AduN Annotation Dep th (RKB) Entl Date Annotation Laat MO d ...End Date Y Last Tag: SLM ~ 7 Casin StTin s ,397.0 11222009 Rev Reaso n: TAG ~ Imosb - or 1112612009 - HANGER, 0 Casing Descdption String 0... Siring ID ... Top (RKB) _ jSet Depth (t._ Set Depth (ND) StnngWt.. St i g ... String Top Thrd CONDUCTOR 16 15.062 0 0 j 110.0 110.0 62 50 H-00 CONDUCTOR, Casing Description String 0... Stdrg ID ... Top IRKS) ilSet Depth (f._ Set Depth (ND) ... Stnng WL..1St ing ... String Top Thrd Otto SURFACE 95/8 8.697 0.0 ~ 3,172.0 3,169.4 36.00 j J-55 Casing Description String 0... String ID ... Top IPo(B) Set Depth (f._ Set Depth (TVD) ... String WL.. String ... String Top Thrd sarery valve, PRODUCTION 7 6.151 0.0 7.559.0 26.00 '~~ J-55 Tubing Str}ngs _ ' Tubing Descr ption St ng 0... ,String ID ... Top (RKB) Set D pth (f .. Set Depth (ND) String Wt.. St ing ... Stnng Top Thrd GAS UFT TUBING 3112 j 2.992 0.0 69404 6,434.6 ~ 9.30 L-80 EUE Srd 2'3~ Com letbn l~tails -- _ - _ _ Top Depth INDI Top Incl Nomi... Top (RKB) (RKB) (°) Item Description Comment ID (in) suR~ o~ 0.0 0.0 0.00 HANGER 3.5" Gen V Tubing Hanger EUE Srd Mod (Pup jt 3.66') 3.500 GAS LIFT, 3,533 GAS LIFT, 4,607 GAS LIFT, 5,588 GAB LIFT, 8,3W GAB LIFT, 6,839 NIPPLE, 6,688 LOCATOR, 6,9ze PBR, 6,922 SEALASBY, 8,928 SEALASBY, 8,935 PACKER, 6,938 x0-Retluoing, 8,948 NIPPLE, 6,984 WLEG, 7,00.9 IPERF, 7,284-~ - RPERF, -- 7,279-7,297 ~-_,- IPERF, 7,289 IPERF, 7,292 = IPERF, 7,294 IPERF, 7,375 ~ RPEft F, '. 7,3147,326 "'IPERF, 7,325 IPERF, 7,333 IPERF, 7,339 IPERF. 7.344 IPERF, 7,348-7,352 _ IPERF, 7,3547,363 FISH, 7,400 FISH, 7,473 ~'iRODUCTION, 47,559 TO (3K-09A), 7,580 6,927.6 6,423.7 31.23 LOCATOR Baker 3.5" Locator O.D. 4.54" I. D. 3.99" 3.D30 6,927.9 6,424.0 31.23 SEAL ASSY Baker 80-40 PBR wlSeal Assembly O.D. 4.01" I.D. 2.99 2.990 Tubing Descriptlon String 0 ... String ID . .. T op (RKB) Set Depth If... Set Depth (ND) ... String Wt... String ~~~ String Top Thrd TUBING Original 3 1/2 2.992 6.921.6 7,050.0 6,528.1 9.30 L-80 EUE Srd Com ietion Details - _ _.-_ _-, Top DeptT _ _... ___. _... (ND) Top InU ~ Nomi._ lop (RKB) (RKB) (°) ~ Rem Descripti on i Comment ID (in) 6,921.6 6,418.7 31.87 PBR Baker PBR Polish Bae Receptacle (6 Pins 40,000 Ib Shear) j 4.000 7" x 7,049.1 6,527.4 31.59 WLEG Wireline Emry GUide 4.18"O.D. 2.9921 -- Ctherin Hole reline retrievable lu a .valves um a fish etc. _ ' lop Depth ITVDI lop Intl Top (RKB) (RKB) (°) Deseripton ~ CommeM Run Date ID (in) 7,400 FISH ~ 1 tl2" OV 1.5" OV LOST 2242006 2242006 7,473 (FISH ;1 1l2" DV 8 TG Latch Dropped to Rathole 121611986 1216/1986 Perioro tions dr Slats -_ Shot ~ Dens 7op IND) Btm (ND) ~ Top (RKB) Btm (RKB) i (RKB) (RKB) ii Zone Date (sh... Type Comment 7,279 7,297 ' 6,723.4 6,738.7 i, A-3, 3K-09A 927/1987 8.0 RPERF 2 1/8" Silver Jei, 60 ph ' 7,284 7,284 6,727.7 6,727.7 A-3, 3K-09A 121411986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 1 ~ 7,289 7,289 ! 6,731.9 6,731.9 A-3, 3K-09A iZ14/1986 1.01 IPERF 2 1/8" EnerJet, 0 deg ph , 7,3101 7 7,315 7,315 6,754.0 6,754.0 A-2, 3K-09A 1214/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,325 7,325 6,762.5 6,762.5 A-2, 3K-09A 1214/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,333 7,333 6,769.3 6,769.3 A-2, 3K-09A 1214/1986 1.0 IPERF 2 1l8" EnerJet, 0 deg ph ~,. 7,339 7,339 6,774.4 6,774.4 A-2, 3K-09A 1214/1986 1.0 IPERF 2 1l8" EnerJet, 0 deg ph I~ 7,344 7,344 6,778.7! 6,778.7 A-2, 3K-09A 1214/1986 1.0 IPERF 2 118" EnerJet, 0 deg ph 7,348 7,352 6,782.1' A-2, 3K-09A 121411986 1.0 IPERF 2 118" EnerJet, 0 deg ph 7,359 7,363 A-2, 3K-09A 1214/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph _ -._.. Notes: General dr Safety- - -- --_ - _- ----- _- - _- _ - Mandrel Details _ ---- Top Depth lop Pori (ND) Incl OD Valve Latch Size TRO Run i, Stn lop (/tl(B) IRKBI (°) Make Model % (in) Serv Type Type (inl (psi) Run Date ~ Co 1 2,396.3 2,396.2 2.10 CAMCO MMG '~ 1 tl2 GAS LIFT GLV RK 0.188 1,346.0 9282008 2 3,532.7 3,523.8 11.53 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,327.0 92812008 3 4,606.5 4,510.4 37.11 CAMCO MMG 1 12 GAS LIFT DMY I RK 0.000 0.0 9/22008 4 5,586.4 5,305.4 34.86 CAMCO MMG 1 12 GAS LIFT ; GLV 'A RK 0.1881 1,307.0 92812008 51 I 6,307.0 5,900.31 33.53 CAMCO MMG 1 12 GAS LIFT DMY RK 1 1 0.000 0.0 9122008 61 6,839.0 6,348.4 32.17 CAMCO. MMG 1 1/2 GAS LIFT ~ OV ' iRK j 0.188~ 0.0 91272008 Davies, Stephen F Subject: ~I FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELL5 {IPBRD) Type Work Code in RBDMS 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill, the initial reviewer {Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Farm 10-403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "iBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 forthe redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. 1 ~E~~li/E~ ~ STATE OF ALASKA • 0 C T 1 3 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~~~i) & Gas Gons. C~ommission n,,,.~,n~~~,~ 1. Operations Pertormed: Abandon ^ Repair Well 0~ Plug Perforations ~ Stimulate ^ Other Alter Casing ^ Pull Tubing ^~ , Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~• Exploratory ^ 186-174 /' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21656-01 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-09A • 8. Property Designation: 10. Field/Pool(s): ADL 25519 ~ Kuparuk River Field / Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 7580' ' feet true vertical 6984' " feet Plugs (measured) 6984' RHC body w/ball & rod Effective Depth measured 7472' feet Junk {measured) 7400', 7473' true vertical 6891' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 3103' 9-5/8" 3172' 3170' PRODUCTION 7490' 7" 7559' 6966' PerForation depth: Measured depth: 7279'-7297', 7310'-7326' , 7333', 7339', 7344', 7348'- 7352', 7359'-7363' true vertical depth: 6727'-6743', 6754'-6767', 6773', 6779', 6783', 6786'-6790', 6796'-6799' Tubing (size, grade, and measured depth) 3.5", L-80, 6940' MD. ~~_ ,•~ y~~,~`~ ~~ ~; ~'~~ `~ ~~~~, ;~' ~r~ n c: .: ~ .:, ~ w~. +.~ PBCkers & SSSV (type & measured depth) Baker SAB3 retainer producti on pkr ~ 6936' 3.5" TRMAXX-5E SSSV @ 2183' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicab/e Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 109 ° 466 12 -- 113 Subsequent to operation 329 985 81 -- 146 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ' Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Niq if C.o. Exempt: none contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Weils Group Engineer Signature -~ Phone: 263-4220 Date `~?!~ ~ ~ -Orake 263-4612 Pre ared b Sharon All ~ t (''~ ~ ~ ~ ~ _. ,~ ~. ~,., ~: ~ ~ 2~~~ Form 10-404 Revised 04/2006 ~~ 1.~ 4~ k~~`~ ~ L 1 ~f~. ~o.2:a o~j Submit Original Only DATE JOBTYP 8/13/08 Ann- Comm 8/15/08 Drilling Support Capital 8/16/08 Drilling Support Capital SUMMARY FUNCTION TEST LD RE-RWO) ~ TAGGED @ 7240' SLM. BRUSHED NIPPLE @ 7118' RKB. MEASURED - BHP @ 7247' RKB: 1727 PSI. SET CA-2 BLANKING PLUG @ 7118' RKB. PULLED GLV @ 2596' RKB. OPERATIONS REMOVING FLOWLINE AND WELL HOUSE. IN PROGRESS. ATTEMPTED PULL GLV @ 4970' RKB, STRIPPED F/N. SET DV @ 2596' - RKB. PULLED OV @ 7029' RKB. LOADED TBG & tA WITH SW / DSL. COMBO MIT TO 2500 PSI, PASSED. SET DV @ 7029' RKB, PULLED CA- 2@ 7118' RKB. SET 2.25" CCX SHEAR OUT PLUG Ca~ 7118' RKB (BENCH TESTED TO SHEAR @ 3000 PSI). PULLED DV @ 7029' RKB. READY FOR BPV. 9/26/08 Driliing UNSUCCESSFUL ATTEMPT TO PULL BALL AND ROD. MOVE TO Support - PRIORITY JOB. IN PROGRESS. Capital 9/27/08 Drilling SET CATCHER @ 6959' SLM. REPLACE SOV @ 6839' RKB W/ DMY. Support - PERFORM SUCCESSFUL MITIA TO 3000 PSI. PULL DMY @ 6839' RKB. Capital IN PROGRESS 9/28/08 Drilling SET GAS LIFT VALVES PER DESIGN @ 2396 & 3532' RKB; OV @ 6839' Support - RKB. TESTED TBG TO 2500 PSI, GOOD. PULL CATCHER, IN Capital PROGRESS. 9/29/08 Drilling UNSUCCESSFUL ATTEMPT TO PULL BALL & ROD. RECOVERED Support - SAMPLE OF FILL. JOB SUSPENDED. Capital ~~nQ~~p~~~~~~~ Time Log & Summary WefN7ew Web Re0or7ing Re po rt Well Name: 3K-09 Rig Name: DOYON 15 Job Type: RECOMPLETION Rig Accept: 8/24/2008 9:00:00 PM Rig Release: 9/3/2008 8:00:00 AM 8/07/2008 24 hr Summarv Begin move off 3C-15. Soft spot on pad. Lay mats to pad entrance. 18:00 00:00 6.00 MIRU MOVE MOB P Moved rig off of well # 3C-15 encounter a soft spot in the pad, forced to set mats to the pad entrance. 8/08/2008 Sub stuck on 3C-15 pad, cribbed up on mats while waiting for Peak cats. Pulled rig upon mats. Moved 1/4 mi down access road w/ one layer of mats. Encountered a soft spot in the road. R/U Peak cats pulled rig up on double mats. 00:00 06:00 6.00 MIRU MOVE MOB P Moved sub compiex down the pad 200', back wheels went down in a soft spot, crib up w/ dunnage to get mats under tires, rig un able to climb out. 06:00 12:00 6.00 MIRU MOVE MOB P Ordered cats from Peak, while attem tin to move sub base. 12:00 18:00 6.00 MIRU MOVE MOB P Pull sub out w/ cats, mat road to road entrance. 18:00 00:00 6.00 MIRU MOVE MOB P Move sub 1/4 mi. and rear wheels went down in a soft spot, hooked cats on and pulled rig forward 140' on double mats. 8/09/2008 Moved rig 1/4 mi up access road, fell through once w/ single mats and once w/double matting. Moved rig back to 3C ad and re aired and com acted road w/ roads and ads e ui ment. 00:00 01:00 1.00 MIRU MOVE MOB P Double stack mats behind rig. 01:00 01:15 0.25 MIRU MOVE MOB P Moved rig down road 100' 01:15 02:00 0.75 MIRU MOVE MOB P Triple stack mats behind rig. 02:00 04:30 2.50 MIRU MOVE MOB P Attempt to roll back from double stacked mats to triple stacked mats, road gave way, shim under wheels w/ dunna e. 04:30 05:00 0.50 MIRU MOVE MOB P Roll back on triple stacked mats 1/8 mi. 05:00 06:00 1.00 MIRU MOVE MOB P Moved triple stacked mats in front of ri . 06:00 07:30 1.50 MIRU MOVE MOB P Try to move forward on double stacked mats, road ave wa . 07:30 08:15 0.75 MIRU MOVE MOB P Wait on plywood from tool house. 08:15 08:30 0.25 MIRU MOVE SFTY P Safety meeting on moving rig back on 3 C ad. 08:30 15:45 7.25 MIRU MOVE OTHR P Move back on double mats to 3 C ad. 15:45 16:00 0.25 MIRU MOVE SFTY P PJSM on moving mud pits from entrance. 16:00 17:00 1.00 MIRU MOVE OTHR P Moved mud pits off to the side of ad. 17:00 20:00 3.00 MIRU MOVE OTHR P Shuffle mats to put sub in center of the ad. 20:00 20:30 0.50 MIRU MOVE OTHR P Move sub in center of pad. 2030 21:00 0.50 MIRU MOVE OTHR P Lower stompers in back of sub. 21:00 21:30 0.50 MIRU MOVE OTHR P PJSM on skidding floor on sub. 21:30 22:00 0.50 MIRU MOVE OTHR P Skid floor in position to lower derrick. 22:00 23:00 1.00 MIRU MOVE OTHR P R/U beaver slide for organizing tools on floor. 23:00 00:00 1.00 MIRU MOVE OTHR P Clean and organize around floor. 8/10/2008 Prepare to lower derrick and clearing floor while working on the road. Rigged back up to leave derrick up, prep mud its to move. La I wood and mats on access road. 00:00 06:00 6.00 MIRU MOVE OTHR P Continue cleaning and organizing around the rig, remove Xt -39 saver sub, upper and lower IBOP valves from to drive. 06:00 08:00 2.00 MIRU MOVE OTHR P Remove bell guide and break lower and lower IBOP valves off to drive. 08;00 12:00 4.00 MIRU MOVE OTHR P Clear floor, disconnect tongs, mud bucket and tie u lines in the derrick. 12:00 13:30 1.50 MIRU MOVE OTHR P Berm up cellar box under the floor, install new drains and hook up cellar alarm. 1330 14:00 0.50 MIRU MOVE SFTY P PJSM on removing iron rough neck from ri floor. 14:00 15:00 1.00 MIRU MOVE OTHR P Pull iron rough neck off rig floor. 15:00 15:30 0.50 MIRU MOVE SFTY P PJSM on removin mud manifold. 15:30 16:15 0.75 MIRU MOVE OTHR P Puli iron rough neck back on floor. 16:15 16:45 0.50 MIRU MOVE OTHR P Bring tongs , mud , bucket and sub stand back on floor. 16:45 17:15 0.50 MIRU MOVE OTHR P R/U lines in derrick and reassemble mud manifold. 17:15 18:00 0.75 MIRU MOVE OTHR P Hang tongs back in derrick. 18:00 00:00 6.00 MIRU MOVE OTHR P Install upper and lower IBOP valves, bell guide and prepare pit complex for moving. Lay plywood on access road w/ sin le la er of mats. 8/11 /2008 Moved mud pit complex from 3C pad to Oliktok road, 1.2 mi..w/ plywood and matting boards on top. 00:00 02:00 2.00 MIRU MOVE MOB P Cont. to lay plywood w/ single layer of mats w/ CPAI loaders. 02:00 02:45 0.75 MIRU MOVE MOB P Prepare mud pit for moving, staged 3C entrance. 02:45 04:30 1.75 MIRU MOVE MOB P Cont. to lay plywood and mats. 04:30 06:00 1.50 MIRU MOVE MOB P Move pit complex 1/2 mi.on access road. 06:00 07:45 1.75 MIRU MOVE MOB P Shuffle double mats in back of pits. 07:45 08:15 0.50 MIRU MOVE MOB P Move pits backwards 950' 08:15 11:00 2.75 MIRU MOVE MOB P Shuffle mats in front of pits, (work on seal in to drive w/ mechanic ri 11:00 12:00 1.00 MIRU MOVE MOB P Move pits 1850' forward. 12:00 13:45 1.75 MIRU MOVE MOB P Shuffle mats ( double stack) in back. 13:45 14:15 0.50 MIRU MOVE MOB P Move pits back 920' 14:15 15:45 1.50 MIRU MOVE MOB P Shuffle mats. 15:45 16:30 0.75 MIRU MOVE MOB P Roll forward 1850' on single stacked mats. 16:30 18:00 1.50 MIRU MOVE MOB P Shuffle mats double stacked. While moving mud pits part of the crew installed wash pipe packing in top drive. unhooked top drive from block UD for ins ection. 18:00 18:30 0.50 MIRU MOVE MOB P Move pits back on double stack mats. 18:30 20:00 1.50 MIRU MOVE MOB P Shuffle mats ahead. 20:00 20:45 0.75 MIRU MOVE MOB P Roll forward 1850' on single stacked mats. 20:45 22:15 1.50 MIRU MOVE MOB P Double stack 22:15 23:00 0.75 MIRU MOVE MOB P Move pits back on double stacked mats 920' 23:00 00:00 1.00 MIRU MOVE MOB P Shuffle mats ahead. Continue moving pit module. Weld up cracks in mud pits. 00:00 00:15 0.25 MIRU MOVE MOB P Continue to doublestack mats behind its. 00:15 01:00 0.75 MIRU MOVE MOB P Move pits back 850' 01:00 02:45 1.75 MIRU MOVE MOB P Lay single mats forward 02:45 03:30 0.75 MIRU MOVE MOB P Move Pits forward 1700' 03:30 04:30 1.00 MIRU MOVE MOB P Double stack mats behind pits. 04:30 05:15 0.75 MIRU MOVE MOB P Move pits back 850'. 05:15 06:00 0.75 MIRU MOVE MOB P Lay single layer of mats forward. 06:00 07:30 1.50 MIRU MOVE MOB P Continue to lay mats. 07:30 08:00 0.50 MIRU MOVE MOB P Move pit complex forward 900' on accessroad. 08:00 09:00 1.00 MIRU MOVE MOB P Double stack mats behind pits. 09:00 09:30 0.50 MIRU MOVE MOB P Roll back with pit complex on double stacked mats. 09:30 10:45 1.25 MIRU MOVE MOB P Move mats in front of pit complex. 10:45 11:15 0.50 MIRU MOVE MOB P Move pit complex forward 600' to Oliktok road & 3C intersection. 11:15 15:00 3.75 MIRU MOVE MOB P Double stack mats, PJSM, Pin hook and blocks on sub com lex 15:00 15:30 0.50 MIRU MOVE MOB P Roll back 300' on double mats. 15:30 16:45 1.25 MIRU MOVE MOB P Move mats in front of pit complex. 16:45 17:15 0.50 MIRU MOVE MOB P Move Pits forward 300' to Oliktok road & 3-C intersectibn. 17:15 18:00 0.75 MIRU MOVE MOB P Move mats behind & in front of pits @ intersection. Got go ahead to move to 3-K ad 1800 hrs 18:00 00:00 6.00 MIRU MOVE RGRP P Found cracked H-beam and pad eyes @ rear of mud pits above wheels, air arc out old wefds & welded u . 8/13/2008 Continue to weld up mud pit complex, move to Oliktok and 3K access road intersection. stage mats ahead of com lex, mi. .4 com lex fell into soft s ot, ulled out w/ Peak cats, roceed w/ mats. 00:00 00:30 0.50 MIRU MOVE MOB P Continue to weld on broken welds on it com lex. 00:30 01:00 0.50 MIRU MOVE MOB P R/D scaffolding and put tools away while building a ramp to get off double stacked mats. 01:00 01:30 0.50 MIRU MOVE MOB P Move mud pits forward to intersection on s ine. 01:30 03:00 1.50 MIRU MOVE MOB P Wait on AES to spot matts on spine road. 03:00 05:00 2.00 MIRU MOVE MOB P Move mud pits up spine road to 4 wa intersection. 05:00 06:00 1.00 MIRU MOVE MOB P Wait on loaders to lay matts and chan e crews. 06:00 09:00 3.00 MIRU MOVE MOB P Lay mats w/ pit complex @ Oliktok road. Continue work on sub complex w/ hook dynaflex & install com ensatin rams. 09:00 13:00 4.00 MIRU MOVE MOB P Lay mats ahead and pepare 3K acess road for move. 13:00 14:00 1.00 MIRU MOVE MOB P Move pits ahead without mats .4 mi. 14:00 18:00 4.00 MIRU MOVE MOB P Complex went down in a soft spot, hooked Peak cats on pulled unit up on mats w/ I wood under. 18:00 21:00 3.00 MIRU MOVE MOB P Rebuild the road 21:00 21:30 0.50 MIRU MOVE MOB P Move complex forward 1200' 21:30 23:00 1.50 MIRU MOVE MOB P Double mat back to pits. 23:00 00:00 1.00 MIRU MOVE MOB P Move mats forward 8/14/2008 Proceed to down access to 3-K pad road single mats, spot on NE corner of pad, mob all mats back to 3-C ad re ri com lex. 00:00 00:30 0.50 MIRU MOVE MOB P Continue laying single mats in front of its. 00:30 01:00 0.50 MIRU MOVE MOB P Move pits forward 1600' 01:00 02:45 1.75 MIRU MOVE MOB P Double mat behind 02:45 03:00 0.25 MIRU MOVE MOB P Move pits back 800' 03:00 04:00 1.00 MIRU MOVE MOB P Lay single mats out in front. 04:00 04:30 0.50 MIRU MOVE MOB P Move pits forward 1600' 04:30 05:45 1.25 MIRU MOVE MOB P Double stack mats 05:45 06:00 0.25 MIRU MOVE MOB P Move pits back 800' 06:00 06:45 0.75 MIRU MOVE MOB P Move complex ahead on single mats. 1600' 06:45 08:00 1.25 MIRU MOVE MOB P Shuffle mats behind pits. 08:00 08:30 0.50 MIRU MOVE MOB P Move pit complex back 800' on double mats. 0830 09:45 1.25 MIRU MOVE MOB P Shuffle mats in front of pits. 09:45 10:15 0.50 MIRU MOVE MOB P Shuffle mats in front of pits. 10:15 11:30 1.25 MIRU MOVE MOB P Shuffle Mats 11:30 11:45 0.25 MIRU MOVE MOB P Roll back 150' 11:45 14:00 2.25 MIRU MOVE MOB P ShufFle mats ahead down 3-K access road 14:00 15:00 1.00 MIRU MOVE MOB P Move pit complex back down 3-k access road 1600' on sin le mats. 15:00 16:15 1.25 MIRU MOVE MOB P Shuffle mats 16:15 16:45 0.50 MIRU MOVE MOB P Move complex back on double mats 16:45 18:00 1.25 MIRU MOVE MOB P Shufffe mats, lay plywood on 3-K pad over fresh di b well houses. 18:00 19:15 1.25 MIRU MOVE MOB P Continue to lay mats to enterance to ad 19:15 20:15 1.00 MIRU MOVE MOB P Move pit complex on 3-K pad. 20:15 22:15 2.00 MIRU MOVE MOB P Fuel up complex and spot off in NW corner of ad. 22:15 00:00 1.75 MIRU MOVE MOB P Mob all the mats from 3-K to 3-C pad, crew prepare to skid floor back to road position while mats are being moved. 8/15/2008 Move rig on 3C access road shuffling mats in front staying in front of soft spot. 00:00 01:15 125 MIRU MOVE MOB P Skid rig floor. 01:15 12:00 10.75 MIRU MOVE MOB P Lay plywood and mats for rig complex move down 3-C access road 12:00 13:00 1.00 MIRU MOVE MOB P PJSM w/ Peak & DDI, continue w/ coverin road. 13:00 14:00 1.00 MIRU MOVE MOB P Move sub from 3-C pad 2300' on access road w/ Peak weighted bed sow. 14:00 16:00 2.00 MIRU MOVE MOB P Double stack mats behind rig. 16:00 16:15 025 MIRU MOVE MOB P Roll back on double stack mats. 360' 16:15 17:15 1.00 MIRU MOVE OTHR P Shuffle mats in front of rig. 17:15 17:30 0.25 MIRU MOVE MOB P Pull ahead w/ weighted sow , 270' 17:30 18:00 0.50 MIRU MOVE MOB P Double stack mats behind the rig: 18:00 20:00 2.00 MIRU MOVE MOB P Continue to double stack mats. 20:00 22:00 2.00 MIRU MOVE MOB P Moved rig back and front end of rig settled, R/U a sling and pulled rig back on double mats w/ Peak cat ( sta ed 3-C ad 22:00 00:00 2.00 MIRU MOVE MOB P Back rig up on double mats 300' shufFle mats to single in front , fill in hole w/ ~Ivwood. 8/16/2008 za hr Summarv Continue to move rig, mats, and plywood down 3 C access road, removing same from behind. Reached the i e line access road, able to set 100 mats out front to Oliktok intersection. 00:00 01:30 1.50 MIRU MOVE MOB P Continue to lay single mats in front of sub. 01:30 02:00 0.50 MIRU MOVE MOB P Move sub forward 500' 02:00 03:30 1.50 MIRU MOVE MOB P Double stack mats behind sub. 03:30 03:45 0.25 MIRU MOVE MOB P Move sub back 250' 03:45 04:30 0.75 MIRU MOVE MOB P Lay single mats in front of sub. 04:30 05:00 0.50 MIRU MOVE MOB P Move sub forvvard 250'. 05:00 05:30 0.50 MIRU MOVE MOB P Double mats behind sub. 05:30 06:00 0.50 MIRU MOVE MOB P Move sub back 250'. 06:00 07:30 1.50 MIRU MOVE MOB P Continue to shuffle mats in front of sub/ sin le mats. 07:30 08:00 0.50 MIRU MOVE MOB P Roll forward w/ weighted Sow on sin le mats 300' 08:00 09:00 1.00 MIRU MOVE MOB P Shuffle mats behind sub U double stack mats. 09:00 09:30 0.50 MIRU MOVE MOB P Move sub on double stacked mats. 09:30 10:30 1.00 MIRU MOVE MOB P Shuffle mats in front of sub U single stacked mats. 10:30 11:00 0.50 MIRU MOVE MOB P Move sub forward w/ weighted Sow 405' on sin le stacked mats. 11:00 12:00 1.00 MIRU MOVE MOB P Shuffle mats behind sub & stage mats in utl off behind sub. 12:00 16:30 4.50 MIRU MOVE MOB P Continue to stage mats in pull off road. 16:30 17:00 0.50 MIRU MOVE MOB P Move sub back on single mats for access U mats on ulloff. 17:00 00:00 7.00 MIRU MOVE MOB P Shuffle mats from pulloff to front of sub & lay ahead to Oliktok intersection. 8/17/2008 Moved matting boards past the rig @ spine road, lay over culverts on spine road and stage mats @ Oliktok / 3 K intersection. lay plywood on 3K access road. Move rig 100' down spine road, road give way in front and back. Shored u w/ dunna e, hooked Peak cats on front and back. Pulled back on mats. 00:00 01:30 1.50 MIRU MOVE MOB P Lay mats in front of sub complex to Oliktok s ine road. 01:30 03:30 2.00 MIRU MOVE MOB P Postion rig on intersection to allow sin le lane traffic, 03:30 06:00 2.50 MIRU MOVE MOB P Load mats and plywood around the ri , haul to Oliktok intersection. 06:00 18:00 12.00 MIRU MOVE MOB P Gather plywood and mats from 3C pad access to Oliktok/ 3K intersection. Lay plywood down 3K accessroad. 18:00 20:30 2.50 MIRU MOVE MOB P Moved sub complex off mats onto spine road, front and back fell throu h the road. 20:30 00:00 3.50 MIRU MOVE MOB P Shore up under wheels w/ dunnage and hooked cats on front and back ~ulled out back on mats. 8/18/2008 24 hr Summarv Continue to spot rig back on mats @ spine road / and 3C access road, repaired spine road w/ 3 loads of gravel. Wheel packed fill w! loaders, set plywood and mats over bad spot. Set mats beyond pipe line access road 3/4 mile. Moved rig complex past turn out, staged mats. Moved rig back and lay mats ahead of rig w/ 3 tool house loaders. Drillin crew ahead on 3 K access road la in I ood. 00:00 00:15 0.25 MIRU MOVE MOB P Continue to pull sub complex back up on matting boards. Spot unit to allow single lane traffic. Cleaned up plywood from road, hauled 2 loads of gravel to repair road edge and in front of the rig. Reset plywood and mats over bad spot, and continue to lay 00:15 01:30 1.25 MIRU MOVE MOB P Clean up dunnage & plywood in road, move access mat to allow roads an ads to dress road. 01:30 03:45 2.25 MIRU MOVE MOB P Continue to clear plywood on 3C access road w/ roads and pads, ( fix 03:45 06:00 2.25 MIRU MOVE MOB P Lay plywood on & mats on Oliktok road. 06:00 13:30 7.50 MIRU MOVE MOB P Ri sta ed (c~ Oliktok / 3C intersection, continue to lay mats ahead, while cleaning debris from 3C access. 13:30 1430 1.00 MIRU MOVE MOB P Move rig on down road 1/4 mi. from 14:30 16:00 1.50 MIRU MOVE MOB P Double stack mats behind rig. 16:00 1630 0.50 MIRU MOVE MOB P Move sub back 800' 16:30 17:30 1.00 MIRU MOVE MOB P Lay single mats in front of rig. 17:30 18:00 0.50 MIRU MOVE MOB P Move the sub forward 1800' past the i e line access road. 18:00 00:00 6.00 MIRU MOVE MOB P Move mats from behind on to pipeline access turn out. 8/19/2008 Continue to lay 300 mats forward in front of rig, Move rig complex ahead 2400', double stack mats, back up 1200'. Move ahead w/ sin le stack mats, Move ri ahead 2400' within 600' of 3 K access road. 00:00 09:00 9.00 MIRU MOVE MOB P Continue to set 300 singie stacked mats in front of ri . 09:00 10:00 1.00 MIRU MOVE MOB P Move rig ahead 2400'. 10:00 18:30 8.50 MIRU MOVE MOB P Double stack mats behind the rig. 18:30 19:00 0.50 MIRU MOVE MOB P Move rig back 1200' 19:00 23:30 4.50 MIRU MOVE MOB P Lay out single layer of mats in front of ri 23:30 00:00 0.50 MIRU MOVE MOB P Move forward 2400' Continue to shuttle mats to Oliktok / 3 K intersection, Moved the rig to Oliktok intersection, spot the rig out of the wa of traffic. Set 4 rows of I wood and mats down access the road .5 mile. 00:00 08:00 8.00 MIRU MOVE MOB P Shuttle mats in front of rig cmplex to Oliktok / 3K intersection. 08:00 10:00 2.00 MIRU MOVE MOB P Move rig to intersection, position it along the edge of the road allowing tra~c to po bv. 10:00 18:00 8.00 MIRU MOVE MOB P Lay plywood 4 rows wide down access road, while loaders staged mats the intersection. 18:00 00:00 6.00 MIRU MOVE MOB P Set mats down ahead of the rig .5 miles. @ 20:30 hrs. a tool house loader got to far on shoulder of the road, shoulder give way and the operator stopped. The other 4 loaders moved to spine road and shuttled the remaining mats off the spine road. Pulled the loader back to the center of the road without any event. 8/21 /2008 Move rig from .5 mi. to 1.1 mi on 3 K access road, making short sets to keep from backing back over soft s ots and culverts. Ri is 1/4 mile from 3 K ad turn off. 00:00 02:00 2.00 MIRU MOVE MOB P Continue to lay matts in front of the 02:00 02:45 0.75 MIRU MOVE MOB P Move rig ahead 800' 02:45 05:00 2.25 MIRU MOVE MOB P Double stack matts behind rig. 05:00 05:30 0.50 MIRU MOVE MOB P Move rig back 400' 05:30 06:00 0.50 MIRU MOVE MOB P Lay single layer matts in front of the 06:00 08:30 2.50 MIRU MOVE MOB P Lay single layer matts in front of rig on 3 K access road. 08:30 08:45 0.25 MIRU MOVE MOB P Move sub fonrvard 600'. 08:45 10:00 1.25 MIRU MOVE MOB P Double stack matts behind rig. 10:00 10:15 0.25 MIRU MOVE MOB P Move rig back 500'. 10:15 13:30 3.25 MIRU MOVE MOB P Lay a single layer of matts in front of ri . 13:30 14:00 0.50 MIRU MOVE MOB P Move rig forward 3000' 14:00 22:00 8.00 MIRU MOVE MOB P Lay double stack matts behind 22:00 22:30 0.50 MIRU MOVE MOB P Move back 1200' 22:30 00:00 1.50 MIRU MOVE MOB P Lay a single layer of matts in front of ri . 8/22/2008 Move rig from mile .7 to mile 12 intersection of 3 K pad access road. Pulled rig off to the side, move all the mattin board toward 3 K ad. 00:00 04:00 4.00 MIRU MOVE MOB P Continue to lay matts in front of the ri . 04:00 04:30 0.50 MIRU MOVE MOB P Move eback 2400' 04:30 06:00 1.50 MIRU MOVE MOB P Double stack mats behind rig, drilling crew laying plywood down to 3 k ad. 06:00 06:45 0.75 MIRU MOVE MOB P Double stack mats. 06:45 07:00 0.25 MIRU MOVE MOB P Move rig back 500' 07:00 08:00 1.00 MIRU MOVE MOB Lay single layer mats in front of rig. 08:00 08:15 0.25 MIRU MOVE MOB Move rig ahesd 700'. 08:15 11:00 2.75 MIRU MOVE MOB Stage mats and plywood in turn out, enou h to clear 3 K access road. 11:00 11:30 0.50 MIRU MOVE MOB Move rig back 500' to clear turn out. 1130 12:00 0.50 MIRU MOVE MOB Lay mats and plywood in front of rig to 3 K turn off. 12:00 14:00 2.00 MIRU MOVE MOB Move rig ahead 1400' and clear access road to 3 K ad. 14:00 00:00 10.00 MIRU MOVE MOB Lay piy wood and mats on 3 K access road w/ rig staged @ intersection. 8/23/2008 Moved all 300 mats around the rig @ the intersection to 3K access road, double stacked mats iwice. Moved rig onto pad matted up to and around the weli head. Lined up sub w/ cellar set stomper in the back to stack BOPE, while setting mats for pit complex. Tool house loaders loading out matting boards and removing , I wood from the road. 00:00 07:00 7.00 MIRU MOVE MOB P Laying single mats in front of the rig on access road to 3K ad. 07:00 07:15 0.25 MIRU MOVE MOB P Move rig back 300' 07:15 08:00 0.75 MIRU MOVE MOB P Lay an extra 16 mats in front of rig on 3K access road. 08:00 09:00 1.00 MIFtU MOVE MOB P Turn rig down onto 3K access road, • move ri forward 3000' 09:00 12:00 3.00 MIRU MOVE MOB P Double stack mats behind rig. 12:00 12:30 0.50 MIRU MOVE MOB P Move rig back 1000'. 12:30 15:15 2.75 MIRU MOVE MOB P Lay single mats in front of rig. 15:15 15:45 0.50 MIRU MOVE MOB P Move rig forvvard 1000' onto 3K pad. 15:45 00:00 8.25 MIRU MOVE PSIT P Pre well site, spread herculite, lay mats for cellar and lay out mats for sub base. Position sub base in front of tree and lay out mats for pit Stacked BOPE in sub, and set back on stub, pull over the wellhead, skid floor over the well. R/U utilities waik ways, berm rig, R/U lines for displacement. Did a walk around observe rig up. Accept rig @_ 2100 HRS. Held a re s ud meetin w! crew. Walk line to flow back tank and start dis lacin well with sea water 2 BPM. 00:00 06:00 6.00 MIRU MOVE RURD P Stack BOPE's and orient mud cross for dual completion coming up. Move mud pit complex up on mats next to the sub. 06:00 09:00 3.00 MIRU MOVE RURD P Continue to Stack up BOP's & M/U all flan es, sort koome lines. 09:00 11:30 2.50 MIRU MOVE RURD P Change lower pipe rams U 2 7/8 x 5" variables, change upper pie rams U 3 1/2 x 6 variables, hook up koomey lines, set BOPE on the stump & secure, install BOP landing, and lift stom ers. 11:30 12:00 0.50 MIRU MOVE RURD P Spot sub over well # 3K-09A 12:00 12:30 0.50 MIRU MOVE RURD P Spot pits against sub. 12:30 14:00 1.50 MIRU MOVE RURD P Start bleedin off 3k-09A outer annulus ( 50~si.~), install cellar cover, ready to skid floor, set stompers & secure cellar doors, start re . for rock washer area. 14:00 14:30 0.50 MIRU MOVE RURD P Skid floor, turn one pin & instali knee brace, install all hand rails/ grates & covers on the to deck. 14:30 15:30 1.00 MIRU MOVE RURD P Start on rig acceptance check list, hook up mud lines between modutes & under rig floor, steam/ air/ and H20 lines under rig & between complexes, lay liner f/ rock washer/ s ot matts. 15:30 16:30 1.00 MIRU MOVE RURD P Spot rock washer, start berming around the rig, continue bleeding off outer annulus, build loading dock from its, continue on mud lines. 16:30 17:30 1.00 MIRU MOVE RURD P M/U panic line, poor boy degasser & flare lines, hang pipe shed braces, start berm around ri . 17:30 18:00 0.50 MIRU MOVE RURD P Hang beaver slide 18:00 21:00 3.00 MIRU MOVE RURD P Continue installing beaver slide, berm up rock washer, finish berms rig. Install safety cables on mud lines. Build ramps for loading rock washer and truck ramps for cutting tanks. Install stairs and landings for rock waher. Set tanks and rock walkways for rock washer. Set chan e house and hook u same. 21:00 21:30 0.50 MIRU MOVE RURD P Pre- spud meeting w/ CPAI rep/ MI re .and DDI em lo ees. 21:30 00:00 2.50 MIRU MOVE RURD P PJSM on BPV remove CIW- BPV Displace well w/ sea water taking returns (diesei ) to a tiger tank. With weli dead set BPV, nippled up BOPE and tested. AOGCC waved witness b Jeff Jones. 00:00 00:45 0.75 MIRU RPCOM NUND P P,1SM / R/U lines to displace well w/sea water, diesel returns to 500 bbl. ti er tank. 00:45 05:15 4.50 MIRU RPCOM CIRC P Displace well w! 55 bbls. Safe Surf o pill that was 80-90 degrees. Followed w/ sea water @ 2 BPM, 230 psi. Pumped a total of 407 bbls. Verify well was dead. No known losses durin dis lacement. 05:15 05:45 0.50 MIRU RPCOM NUND P Blow down lines and rig down e ui ment. 05:45 06:30 0.75 MIRU WELCTL NUND P Set HP- BPV. 06:30 07:45 1.25 MIRU WELCTL NUND P Bleed off void, drain tree, N/D & UD same ( wing valve pointing toward flow lines 07:45 09:00 1.25 MIRU WELCTL NUND P P/U adapter flange M/U same on well head, MU plug off tool in HP-BPV, P/U riser & install work platform, M/U riser. 09:00 12:00 3.00 MIRU WELCTL NUND P P/U adapter flange & set and re rig pipe rams 90 degrees, set & M/U same, M/U kill line and chokeline, hook up tie downs, load pipe shed w/ 4" drill i e. 12:00 14:00 2.00 MIRU WELCTL NUND P Continue to N/U BOP, tighten upper 13 5/8" flanges on riser, finish M/U choke line, flow line and center stack. Load pipe shed w/ 4" drill i e. 14:00 15:00 1.00 MIRU CASING RURD P Bring up xo subs and handling e ui ment. 15:00 16:00 1.00 MIRU CASING NUND P R/U new hydraulic lines for GBR. R!U GBR equipment and M/U 2 7!8 test ~oint. 16:00 17:00 1.00 MIRU WELCTt BOPE P R/U to test BOPE. 17:00 18:00 1 00 MIRU WELCTI BOPE P . PJSM. test BOPE U 250 psi low - 3000 si. pressure test lines and double check connections. AOGCC waived BOP witness. 18:00 19:00 1.00 MIRU WELCTI BOPE P Tighten up bottom flange between tubin s ool and riser. 19:00 00:00 5.00 MIRU WELCTL BOPE P Test BOPE 250 psi. low , 3000 psi. high/ test bag w/ 2 7/8", 4" top rams (3 1/2" x 6" variable ) w/ 2 7/8" 3 1/2", 4" test joints/ bottom rams ( 2 7/8" x 5" variable ) w/2 7/8, 4" test joints/ w/ choke manifold / HCR kill /and manual kill. 8/26/2008 Completed BOPE test 250 psi. low 3000 high. All components passed. Attempt to pull tubing. Would not come free. Cut tubin , ulled 9'oints lus u s, set storm acker and ulled tubin head. 00:00 03:30 3.50 0 0 MIRU WELCTL BOPE P Continue to test BOPE, 250 psi low, 3000 psi high. Test bag w/ 2-7/8" & 4", test top rams w/2-7/8", 3-1/2" & 4" and test bottom rams w/2-7/8" & 4" test joints. Accumulator drawdown test starting pressure 3000 psi. After functioning 1050 psi, 200 psi gain in 1 min 4 sec, full charge 3 min 19 sec. Total of 34 components tested, no failures. 03:30 04:15 0.75 0 0 MIRU WELCTL BOPE P Rig down test equipment and blow down lines 04:15 05:00 0.75 0 0 MIRU RPCOM RURD P Rig up crossovers wlTIW valve. 05:00 07:15 2.25 0 0 MIRU RPCOM RURD P Drain stack and pull HP-BPV and lu off tool. 07:15 08:00 0.75 0 0 MIRU RPCOM RURD P Rig up to take returns thru degasser. 08:00 09:00 1.00 0 0 MIRU RPCOM OTHR P Run out lock down screws, unseat hanger and attempt to pull tubing. Pull to 195k (blocks 74k). Did not ull free. 09:00 10:00 1.00 0 0 MIRU RPCOM CIRC P Circulate 140 bbls at 3 bpm, 350 psi while Schlumberger rigs up to cut tubina. 10:00 11:00 1.00 0 0 MIRU RPCOM RURD P Pick up and rig up toois to cut tubin . 11:00 12:00 1.00 0 0 MIRU RPCOM OTHR P Pick up to 132k on weight indicator and set sli s. RIH with cuttin tool. 12:00 14:15 2.25 0 0 MIRU RPCOM OTHR P RIH, cut tubin at 7077.5' MD and OOH with cutter. 14:15 15:00 0.75 0 0 MIRU RPCOM RURD P Rig down wireline tools. 15:00 16:00 1.00 0 0 MIRU RPCOM RURD P Rig up GBR. Pull tubing hanger, 9 joints and 3 pup joints. PU wt 111 k SO wt 110k. 16:00 17:00 1.00 0 0 MIRU RPCOM OTHR P Make up storm packer and RIH to 160'. Set acker and test with 500 psi. Pressure held. Lay down packer runnin tools. 17:00 18:45 1.75 0 0 MIRU RPCOM NUND P Drain stack, remove turnbuckles, bell nipple and lines. Hook up bridge cranes and start breaking bolts on tubin head. 18:45 23:45 5.00 0 0 MIRU RPCOM NUND P 7' casin rowin while loosenin bolts. Corrosion on lower nuts slowing removal. Called for pnumatic saw-zall from Kuparuk Tool House. Installed 4, 15" bolts to control rowth. Casin rew total of 7-1/2". 23:45 00:00 0.25 0 0 MIRU RPCOM NUND P Set stack with tubing head on sills in front of well. 8/27/2008 Speared 7" casing, pulled tension and reset slips. Cut 7" casing and installed new packoff and tubing head. Installed test plug, nippled up stack and tested. Could not pull test plug. Nipple down stack, installed new DSA and retested. Test pressure 250 psi low, 3000 psi high. Pressures held, charted tests. Moved sho and arts house from 3C ad to 3K ad 00:00 01:45 1.75 0 0 MIRU WELCTL EQRP P Cut remaining tubing head studs with saw. 01:45 02:00 0.25 0 0 MIRU WELCTL EQRP P Pull packoff 02:00 04:00 2.00 0 0 MIRU CASING OTHR P Pick up casing spear and stab into 7" casing. Pull 100k over block weiqht and reset casina slios. Release from casing and lay down s ear. 04:00 05:00 1.00 0 0 MIRU CASING OTHR P Cut off 1.95' off of 7" casina and install new ack . 05:00 07:00 2.00 0 0 MIRU WELCTL EQRP P Nipple up new tubing head and test packoff to 3000 psi for 10 minutes. Good test. 07:00 09:00 2.00 0 0 MIRU WELCTL EQRP P Set test plug in tubing head and ni le u BOPE. 09:00 10:45 1.75 0 0 MIRU WELCTL BOPE P Ri u and test BOPE to tubing head connection, 250 psi low / 3000 psi hi h. Good test. 10:45 12:30 1.75 0 0 MIRU WELCTL BOPE T Pick u test 'oint and attempt to, retrieve test plug. Test plug will not ull thru 13-5/8" x 7-1l16' DSA. 12:30 18:00 5.50 0 0 MIRU WELCTI NUND T Nipple down stack. Remove DSA and wait for replacement. Clean and inspect test plug, tubing head and wear rina. Measure IDs and ODs. II'~_ 18:00 21:00 3.00 0 0 MIRU WELCTI NUND T Install new spool (7-3/16" ID) and ni le u BOP stack. 21:00 21:30 0.50 0 0 MIRU WELCTL BOPE T Fill stack with water, install test plug and ri u to test connections. 21:30 21:45 0.25 0 0 MIRU WELCTL BOPE T Test breaks 250 psi low, 3000 psi hi h. Tested ood, charted test. 21:45 22:30 0.75 0 0 MIRU RPCOM OTHR P Pull test plug. Install wear ring 22:30 22:45 0.25 0 0 MIRU WELCTL SFTY P PJSM - pulling storm packer and la in down com letion strin . 22:45 23:45 1.00 0 0 MIRU WELCTL TRIP P TIH with retrieving tool, install TIW in drill string. Screw onto storm packer (8 turns) and open valve (12 turns). O en TIW to check for ressure. 23:45 00:00 025 0 0 MIRU WELCTL TRIP P Pick up 5' to confim fish on. PU wt 100k. 8/28/2008 RIH and retrieved storm packer. Continue to pull out of hole and lay down 2-7/8" completion. RIH with 1st fishing overshot and retrieved Overshot Expansion Joint. Dress fishing tool for second run to retrieve slick stick and acker and RIH. 00:00 01:15 1.25 MIRU RPCOM CIRC P Close top pipe rams, open HCR choke and circulate bottoms up thru de asser at 4 b m, 520 si. 01:15 02:15 1.00 MIRU RPCOM PULD P POOH and la down storm acker. ~ PU wt 110k. 02:15 02:30 0.25 MIRU RPCOM OTHR P Blow down topdrive and lines 02:30 02:45 0.25 MIRU RPCOM RURD P Rig up 2-7/8" handling tools. 02:45 06:00 3.25 MIRU RPCOM PULD P POOH and lav down 2-7/8" com I tion 105 joints. PU wt 105k, SO wt 105k. 06:00 08:15 2.25 MIRU RPCOM PULD P Continue POOH with 2-7/8" completion. Hole took proper fill durin tri . 08:15 09:00 0.75 MIRU RPCOM RURD P Rig down and lay down 2-7/8" handlin e ui ment. 09:00 11:45 2.75 MIRU FISH RURD P Bring Baker fishing tools to rig floor and make u fishin BHA. 11:45 16:45 5.00 0 7,050 MIRU FISH TRIP P Sin le in hole with OEJ fishin BHA. 16:45 17:15 0.50 7,050 7,050• MIRU FISH CIRC P CBU pumping 8 bpm, 980 psi, rotating 40 rpm. PU wt 173k, SO wt 163k. 17:15 18:15 1.00 7,050 7,077 MIRU FISH FISH P Tag up on fish and olish off top of fish with milis. Rotate and circulate while slacking off to engage fish. Pick up to pull fish free. Cock jars at 275k and pulled 290k after jars fired. Continue 'arrin until fish free 18:15 18:30 0.25 7,077 6,931 MIRU FISH TRIP P POOH with fish. PU wt 173k 18:30 19:00 0.50 6,931 6,931 MIRU FISH CIRC P CBU at 7 bpm, 730 psi. 19:00 19:15 0.25 6,931 6,931 MIRU FISH OTHR P Monitor well - static. 19:15 21:15 2.00 6,931 230 MIRU FISH TRIP P POOH with fish. Calculated hole fill 48.5 bbls, actual 49 bbls. 21:15 21:45 0.50 230 0 MIRU FISH PULD P Lay down jars and rack back drill collars. 21:45 22:45 1.00 0 0 MIRU FISH PULD P Break out fish from overshot. Pup 5.91', OEJ 16.49' 22:45 23:15 0.50 0 0 MIRU FISH PULD P Redress overshot with 3.220" ra le. La down hollow mill. 23:15 23:45 0.50 0 230 MIRU FISH TRIP P TIH with fishing BHA and drill collars. 23:45 00:00 0.25 230 420 MIRU FISH TRIP P Single in hole with 4" drill pipe. Trip in hole with slick stick fishing BHA. Engage fish and jar loose. Slick stick parted from packer. Service rig and order overshot mill. Tri in hole with overshot mill and mill acker stu b. Be in tri out of hole. 00:00 00:30 0.50 420 797 MIRU FISH TRIP P Single in hole with 4" drill pipe. 00:30 03:00 2.50 797 7,054 MIRU FISH TRIP P TIH to top of fish. PU wt 173k SO wt 165k. Calculated displacement 48.5 bbls, actual dis lacement 49 bbls. 03:00 0430 1.50 7,054 7,054 MIRU FISH OTHR P Close rams, open HCR kill and pressure up to 1500 psi to shear out plu . No shear, Pressure up to 2500 psi, still no shear. Call town and discuss o tions. 04:30 05:15 0.75 7,054 7,091 MIRU FISH FISH P TIH to engage fish pumping 4 bpm, 300 psi. Siack off 10k. Pick up to 225 and fire jars. Pick up to see if fish free, not free. Pick up to 280k and fire jars. Lost all weight, PU wt 173k. Set down to try and re-engage fish severai times. 05:15 05:30 0.25 7,091 6,965 MIRU FISH TRIP P POOH seawater flowin over to of stum . PU wt 173k, SO wt 165k. 05:30 06:00 0.50 6,965 6,965 MIRU FISH CIRC P CBU pumping 7 bpm, 760 psi. Observed a littie as at bottoms u. 06:00 06:15 0.25 6,965 6,965 MIRU FISH OTHR P Monitor well - static. 06:15 08:30 2.25 6,965 230 MIRU FISH TRIP P POOH with fishing BHA. Hole took 7 bbls over calculated fill. 08:30 10:00 1.50 230 0 MIRU FISH PULD P Stand back drill collars, retrieve "slick stick" from grapple. Slick stick parted from packer at connection 2' above acker. Fish 11.16' long x 3.25" OD 10:00 10:30 0.50 0 0 MIRU FISH RURD P Clear and clean rig floor. 10:30 11:30 1.00 0 0 MIRU RIGMN7 SVRG P Service top drive, blocks, crown and drawworks. 11:30 12:00 0.50 0 0 MIRU RIGMNT SFTY P PJSM - slip and cut drilling line 12:00 13:30 1.50 0 0 MIRU RIGMNT SVRG P Slip and cut drilling line. 13:30 18:00 4.50 0 0 MIRU FISH WOEQ T Waiting on overshot miil to be built and delivered, 18:00 18:30 0.50 0 0 MIRU FISH SFTY P PJSM - picking up fishing / overshot millin assembl . 18:30 19:30 1.00 0 215 MIRU FISH PULD P Pick u and make un fishina / milling BHA + jars, bumper sub and drill collars. 19:30 21:00 1.50 215 7,005 MIRU FISH TRIP P TIH to top of fish. PU wt 175k, SO wt 165k. Calculated displacement 44.5 bbls. actual 44.5 bbls. 21:00 21:15 0.25 7,005 7,086 MIRU FISH WASH P Wash in hole pumping 420 gpm, 1420 psi, rotating 60 rpm, torque 5-6k ft Ibs. 21:15 21:45 0.50 7,086 7,089 MIRU FISH MILL P Mill on packer stub pumping 420 gpm, 1420 psi, rotating 60 rpm, tor ue 5-6k ft Ibs. 21:45 22:45 1.00 7,089 7,089 MIRU FISH CIRC P CBU pumping 420 gpm, 1420 psi. 22:45 00:00 1.25 7,089 5,306 MIRU FISH TRIP P POOH with overshot mill. PU wt 130k, SO wt 130k. 8/30/2008 Run in hole with fishing grapple and latch on to fish. Work fish out of hole. Recovered packer and tail pipe. Lay down fish and pick up clean out BHA. Run in hole, wash and ream to 7367' MD. Sim o s- ni le u diverter on 3K-108. 00:00 02:00 2.00 5,306 212 MIRU FISH TRIP P POOH with overshot mill. Calculated hole fill 48 bbis, actual 48 bbls. 02:00 02:30 0.50 212 0 MIRU FISH PULD P Lay down overshot mill. 02:30 02:45 0.25 0 0 MIRU FISH SFTY P PJSM - picking up and making up overshot BHA. 02:45 03:00 0.25 0 0 MIRU FISH PULD P Pick u overshot mill and insert ra le into tool. RIH with BHA and drill coliars. 03:00 05:00 2.00 0 7,021 MIRU FISH TRIP P TIH with overshot BHA. PU wt 175k, SO wt 165k. Calculated displacement 48 bbls, actuai 48 bbls. 05:00 05:30 0.50 7,021 7,091 MIRU FISH FISH P Wash down and set 10k down on fish. Pick up to 225k and fire jars. Pick up to 235k and fire jars second time. ish on PU wt 235k, SO wt 180k 05:30 05:45 0.25 7,091 7,051 MIRU FISH TRIP P POOH with fish, swabbing. Attempt to shear lu . Stage pressure up to 3000 si, ressure holdin , no shear. 05:45 06:15 0.50 7,051 7,021 MIRU FISH TRIP P Work pipe up and down to wear down acker element. 06:15 06:45 0.50 7,021 7,021 MIRU FISH CIRC P Observed as at surface. CBU 295 gpm, 720 psi. Max gas 5000 units. 06:45 07:45 1.00 7,021 7,232 MIRU FISH TRIP P Continue working pipe. Pulled tight, PU wt 300k. Fired jars and lost up weight. PU wt 175k SO wt 165k. Chased fish to bottom. Set 40k on fish PU wt 180k. 07:45 08:45 1.00 7,232 7,232 MIRU FISH CIRC P CBU x2 pumping 295 gpm, 750 psi. Max as 5000 units. 08:45 09:00 0.25 7,232 7,232 MIRU FISH OTHR P Monitor well - static 09:00 11:00 2.00 7,232 1,792 MIRU FISN TRIP P POOH with fish. PuAed thru ti ht s ots at 6986' & 4282' M D. 11:00 11:30 0.50 1,792 1,792 MIRU FISH CIRC P CBU x2 pumping 295 gpm, 580 psi, max as 390 units. 11:30 14:00 2.50 1,792 227 MIRU FISH TRIP P POOH with fish. 14:00 15:30 1.50 227 0 MIRU FISH PULD P Stand back drill collars and lay down BHA and fish. Recovered packer 15:30 16:00 0.50 0 0 MIRU DRILL PULD P Clear and clean rig floor. Bring clean out BHA to ri fllor. 16:00 17:15 1.25 0 387 MIRU DRILL PULD P Make up BHA for clean out run~ mill tooth bit, magnets, collars, pump out sub and 'ars 17:15 19:45 2.50 387 7,116 MIRU DRILL TRIP P TIH with clean out BNA. PU wt 180k, SO wt 165k, rotatin wt 170k. 19:45 20:45 1.00 7,116 7,116 MIRU DRILL CIRC P CBU pumping 7 bpm, 780 psi. Max as 233 units. 20:45 00:00 3.25 7,116 7,367 MIRU DRILL REAM P Wash and ream in hole circulating bottoms up every 20'. Circulated 20 bbl high vis sweeps at 7185', 7305' and 7345'. Circulate out gas as needed. max qas observecTi~S~ units. 8/31l2008 Wash and ream untii stacking out at 7425' MD. Circulate hole clean and pull out of hole. Pick up and run in hole with packer on drill pipe. Attempt to set packer with ball & rod. Unable to build pressure. Work pipe t in to et ball & rod seated. Ri u slickline to locate ball & rod and ush on seat. 00:00 01:30 1.50 7,367 7,425 MIRU DRILL REAM P Wash and ream in hole circulating bottoms up every 20'. Circulated 20 bbl high vis sweeps at 7185', 7305' and 7345'. Circulate out gas as needed, max gas observed 3800 units. 01:30 02:15 0.75 7,423 7,423 MIRU DRILL CIRC P Pump 20 bbi high-vis sweep around at 330 gpm, 910 psi. PU wt 183k, SO wt 165k. Max gas 3300 units. Lost 5 bbis. 02:15 02:30 0.25 7,423 7,423 MIRU DRILL OWFF P Monitor well - falling 02:30 03:30 1.00 7,423 7,423 MIRU DRILL CIRC P Pump 20 bbl high-vis sweep around at 330 gpm, 890 psi. PU wt 183k, SO wt 165k. Max gas 172 units. Lost 4 bbls. 03:30 03:45 0.25 7,423 7,423 COMPZ DRILL OWFF P Monitor well - falling. 03:45 06:15 2.50 7,423 387 MIRU DRILL TRIP P POOH on elevators. Dropped 1.90" drift. 06:15 08:15 2.00 387 0 MIRU DRILL PULD P Lay down clean out BHA. 08:15 09:15 1.00 0 0 COMPZ RPCOM RURD P Clear and clean rig floor, Rig up GBRs 3.5" tools. 09:15 09:45 0.50 0 96 COMPZ RPCOM RCST P Plck up 3 joints of tubing tail. 09:45 10:00 0.25 96 96 COMPZ RPCOM SFTY P PJSM - picking up and making up acker assembl . 10:00 10:45 0.75 96 138 COMPZ RPCOM RCST P Pick u and make up packer. Make up cross overs. Ail connections below packer are thread locked or tack welded. 10:45 15:00 4.25 138 7,050 COMPZ RPCOM TRIP P TIH with packer on drill pipe, 73 stands + sin le. 15:00 15:45 0.75 7,050 7,050 COMPZ RPCOM CIRC P Circulate drill pipe volume before dro in ball & rod. 15:45 16:15 0.50 7,050 7,050 COMPZ RPCOM PACK P Drop 1-5/16" ball & rod, wait 10 minutes and begin pumping at 1.5 bpm, 70 psi. Ball not seating, increase ~umos to 3 bom. 120 ~si. 16:15 ~ 17:45 ~ 1.50 I 7,050 I 7,050 ICOMPZ~ RPCOM~PACK I T IAttempt to seat ball, work pipe and town. 17:45 18:00 0.25 7,050 7,050 COMPZ RPCOM OWFF T Monitor well -static 18:00 19:30 1.50 7,050 4,193 COMPZ RPCOM TRIP T POOH 30 stands attempting to shake bali and rod onto seat. 19:30 21:00 1.50 4,193 7,050 COMPZ RPCOM TRIP T TIH to packer setting depth. 21:00 23:15 2.25 7,050 7,050 COMPZ RPCOM PACK T Attempt to seat bail & rod, pumping 3 bpm, 130 psi. Pump hig-vis sweep trying to dislodge ball & rod. Sim ops, PJSM - rigging up slickline. Bring slickline tools to rig floor. make u floor safe valve. 23:15 00:00 0.75 7,050 7,050 COMPZ RPCOM RURD T Rig up slickline over well. 9/01 /2008 Rig up and run in hole with slickline to locate ball & rod. Tagged up at 7373' WLM, - 390' deeper than expected. Pulled drill pipe and packer running tool out of hole. Screws had sheared and packer was left in hole. Ran in with acker retrievin tool and fished acker. Redressed acker, ran in and set acker on de th. 00:00 00:30 0.50 7,050 7,050 COMPZ RPCOM RURD T Rigging up slickline over well. 0030 02:15 1.75 7,050 7,050 COMPZ RPCOM SLKL T RIH with slickline inside drill pipe. Worked tools down to 7373' WLM. f Tagged up and ulled tools out of hole. Hole took 7 bbls while running lickline tools. 02:15 02:30 0.25 7,050 7,050 COMPZ RPCOM RURD T Rig down slickline tools. Call out for packer retrieving tooi from Baker Oil Tools. 02:30 02:45 0.25 7,050 7,050 COMPZ RPCOM OWFF T Monitor well - fluid level fallin . 02:45 05:45 3.00 7,050 0 COMPZ RPCOM TRIP T POOH. Recorded weights-every 10 stands on trip out. Packer left in hole. Lay down crossovers and seal assembly. Hole took 15 bbls over calculated fill on tri . 05:45 06:45 1.00 0 0 COMPZ FISH TRIP T Clear and clean rig floor. Pick up and make u acker retrievin tool. 06:45 09:15 2.50 0 6,992 COMPZ FISH TRIP T TIH with packer retrieving tool. 09:15 10:00 0.75 6,992 6,992 COMPZ FISH CIRC T CBU at 7 bpm, 480 psi. Max gas 0 units. 10:00 10:15 0.25 6,992 7,265 COMPZ FISH TRIP T TIH 10:15 11:15 1.00 7,265 6,914 COMPZ FISH FISH T Establish pump rates and presssures before tagging packer. 1 bpm, 70 psi; 2 bpm, 80 psi; 3 bpm, 120 psi. PU wt 171 k, SO wt 163k. Set 5k on top of packer and pick up, PU wt 175k. Siack off and tag up second time. Tagged 1' higher. Set down 5k second time. POOH and obtain new pump rates, 2 bpm, 110 si; 3 b m, 230 s i 11:15 14:45 3.50 6,914 100 COMPZ FISH TRIP T POOH with acker. 14:45 15:15 0.50 100 0 COMPZ FISH TRIP T Inspect packer assembly, ok. 15:15 16:30 1.25 0 0 COMPZ RPCOM PULD T Stab seal assembly into packer and ressure test to 200 si. 16:30 17:15 0.75 0 0 COMPZ RPCOM PULD T Pull up to inspect wireline entry guide, ok. Lost 11 bbls while circulatin over to of hole. 17:15 17:45 0.50 0 232 COMPZ RPCOM TRIP T TIH slowly thru BOP stack. 17:45 21:00 3.25 232 7,050 COMPZ RPCOM TRIP T TIH with packer 73 stands + single. Set packer on depth and rig up to set acker. 21:00 23:30 2.50 7,050 7,050 COMPZ RPCOM PACK P re s e up on drillpipe to 4000 psi .~ . ..v v.a.. N..~~ u~ ~.. ~ ~v p......a.~...~.. loss. Bleed off pressure and repeat procedure. No overpuli. Slack off, not ~ stacking out. Walk lines and check valves. Pressure up to 4000 psi. Observed acker set at 1500 psi and screws shear at 2500 psi. Hold 4000 psi for 10 minutes and bleed off. Slack off and set down 8k on packer. Pick up 2', pressure up 7" x drillpipe annulus to 2500 psi and hold for 10 minutes. Pressure held. Bleed off ressure and ri down lines. 23:30 00:00 0.50 7,050 7,023 COMPZ RPCOM CIRC P Lay down single and CBU at 5 bpm, 280 si 9/02/2008 RIH with 3 1/2" tubing completion and seal assembly, spotted 1% corrosion inhibited sea water in the annulus rior to landin tubin , landed tubin and RILDS at re ort time. 00:00 04:45 4.75 0 0 COMPZ RPCOM TRIP POOH with running tool on elevators from 7,023' to 20', while laying down 4" DP. 04:45 06:00 1.25 0 0 COMPZ RPCOM RCST Cleared floor, LD running tool, dressed seals for tubing run, RIH with 4 stands of drill pipe and layed down same, drained stack and pulled wear bushin 06:00 07:45 1.75 0 0 COMPZ RPCOM OTHR LD Test Joint and wear ring cleared and cleaned floor, RU GBR for running completion tubing, serviced rig topdrive and drawworks, replaced 3 gland nuts with lock downs on wellhead 07:45 08:30 0.75 0 0 COMPZ RPCOM SFTY PJSM for running 3 1/2", 9.3#, L-80, 8rd Mod. Tubin 08:30 12:00 3.50 0 3,638 COMPZ RPCOM RCST RIH with seal assemblv on 3 1/2", 9.3#, L-80, 8rd Mod. tubing to 3,638' recording up and down weights every 10 'oints, U Wt:98K, Dn Wt:102K 12:00 17:45 5.75 3,638 6,940 COMPZ RPCOM RCST Continued RIH with completion tubing to 6,940'MD, recording up and down weights every ten joints, Up Wt: 125K, Dn Wt: 120K 17:45 18:00 0.25 6,940 6,940 COMPZ RPCOM RCST POOH with 3 1/2" tubing from 6,940' to 6,868' recording up and dn weights every ten joints, ran back to 6920', U Wt: 125K, Dn Wt: 120K 18:00 20:00 2.00 6,940 6,940 COMPZ RPCOM HOSO Spaced out tubing, PU hanger and ~anding joint, tied in SSSV control line to hanger, lower tubing string, RD GBR 20:00 20:15 0.25 6,940 6,940 COMPZ RPCOM HOSO Lowered tubing in hole while circulating at 1 BPM (50 psi), located seals with 150 psi and 26 feet in on landin 'oint. 20:15 00:00 3.75 6,940 6,940 COMPZ RPCOM SFTY PJSM for pumpinq corrosion inhibited of 1% corrosion inhibited seawater followed by 10 bbis of seawater, with 168 gpm and 830 psi, Cleared floor and landed tubing with tail at 6940.38', RILDS 9/03/2008 Tested tubing to 2500 psi for 15 minutes followed by testing the casing to 3000 for 30 minutes, sheared out the lowest GLM @ 6839' with 1800 psi differential pressure while bleeding of the tubing to zero. Set two way check vavle and ND BOPE, NU X-mas tree, freeze protected well with 85 bbls of diesel, released rig at 20:00 hours 9/3/08. 00:00 01:00 1.00 6,940 COMPZ RPCOM DHEQ With the annulus open, test 3 1/2" tubing to 2500 pis for 15 minutes, shut in annulus and pressured up casinq to 3000 for 30 minutes, both tested ood, bted off the tubin pressure and sheared ou the lowest GLM at 6839' with 1800 psi differential pressure, both sides were bled to zero 01:00 05:00 4.00 COMPZ RPCOM NUND RD circulating equipment, and LD landing joint, set two way check, ND BOPE 05:00 10:30 5.50 COMPZ RPCOM NUND PU X-mas tree and installed new API rings and tightened bolts, installed lubricator on 7" X 3 1/2" annulus and installed BPV to rotate wing valve, pressured up to 6000 psi to open SSSV, tested lower neck seals, API rin , main bod seals, retrieved BPV 10:30 16:00 5.50 COMPZ RPCOM FRZP RU Little Reds to freeze protect, pumped 85 bbls of diesel down annulus, hooked up jumper hose from annufus to tubing and U-tubed fluids in well, RD and blew down hose. 16:00 20:00 4.00 COMPZ RPCOM OTHR RU lubricator and installed BPV, ~ cleaned cellar box, installed tree cap with new gauges, RD down rock washer, rig released at 20:0~ hours . 9/3/08. . ConocoPhillips A.1:4v;,,~, iqr:. HANGER, ~ CONDUCTOR, 0-t o s~e~yv~~e, 2.183 GAS LIFT, 2.396 SURFACE, _ 0-3.1I2 GAS LIFT, _ _ 3.533 GASLIFT. __ __ 4.fi07 GAS LIiT, 5.586 GASLIFT, __ 6307 GNSLIFT._ __ 6,839 NIPPLE.6.886- -- --- S~AL ASSY, 6 ~~35 ?ACK_3. 6.Y36- xo REDUCING, 6,966 NIPPLE, 6,981- WLEG. 7.0l9- 110.0 '...I_..6250...,_..H-0O p[h (TVD~... iSiring Wt_.IiSinng G ,169.6 36.00 J-55 pth (TVDI...J'ISiring Wt...ISiring G ,9662 I 26-00 ' J-55 .. . ._. ___. .. .. I IPERF, 7,T92 IPERf, T,25C 7,310-J,326 IPERF,7,325--- IPERf,7.333 IPERF,],339 IPERF, 7,3M IPERF, _ __~ ].3a8-].352 y IPERF, 7.359-'/,363 ; FISM,],600 ~~ f ISH, 7.473 PRODUCTION, 0 7.559 TD (3K-09A), ],580 ~ WellboreAPWWI ~. ! 500292165600 Description IPARUK RIVER UNIT IPROD 3K-09A ;I (°) MD (ftKB) '~~TD (max) (ft... 37.30 4,527.99 ', 7.580 0 H3S (pqn) Dale 135 ~ 7/V2008_ ~pth (ftKBi End Data Annofation 7,240.0 I 8/162008 I Rev Reason: 7 I 6.151 I~ 0.0 pth (TVD~ ... ~,String Wt... String Gi Top Depth (ND) Top Top(i1K8) (ftKe) ~~el(°J nemDescription Comment ID(in) 0.0 0.0 0.00 HANGER 3.5" Gen V Tubing Hanqer EUE Srd Mo0 (Pup jt 3.66') 3500 2,183.3 2,783.3 1.30 Safery Valve 3.5' TRMAXX-SE SCSSV w/ 2.812" X Profle EUE 8rd Motl 2.812 6,888.0 6,3932 3t52 NIPPLE 3.5" X Nipple w/ 2 813" profile : 2.813 I 6,927.6 6,427.0 31.39 LOCATOR Baker 3.5" Locator O.D. 454" L D. 3.99" ' 3.030 6,927 9 ~I 2.990 6,427.3 37 39 SEAL ASSY Baker80-00 PBR wlSeal Assembl O.D.4.01" I D. 2 99 r...' So-~ opTME n (C..isat D~... stri Q...;Stri 9 V 9 9 P( ) sh .. sa ... ro 'Sa I ~ i 9 ~ L-SO EUE 8r0 TUBINGOriginai 312 I 2.992 i 6.9216 70 O 653 6 Comple tion Details Top Deplh . . . . ___ _._ . _ _. . . . . ._ _ __._. _. - . _. _._ . (ND) Top Top (kKB~'~ (ftKB~ ', Incl (°) kem Deseription Comment ID (in) 6,921.G'~ 6,421.9~~ 31.41 P8R Baker PBR Polish Bore Receptacie (6 Pins 40,000 ib Shear) 4.000 6,935.0~ 6,433.3~ 31.36 SEAL ASSY Baker KBH-22 Anchor Seal Assembly (3.5' EUE 8rd Box Up) 3.000 6,935.9~ 6,434.7 ~ 31.36 PACKER Baker 7" x 4.5" SAB3 Retainer Production Packer (LTC Box Down) 3250 6,946.4 ~ 6,443: i 31.33 XO - Crossover 4.5" LTC Box x 3.5" EUE Srd Pin 3.500 I REDUCING I 6,983.81 6,475.01 3120 NIPPLE 2 813"'XN' Nipple w/ RHC BoOy Instailed (2J5' No-Go) 2J50 i 7,049.1I . __... . ___ 6,530.9 31.12 WLEG Wireline Entry Guide 4.18" 0.0. 2.992 Other In ... - Hole (Wi_reline retrievable plug_s,_yalves, pumps, fish, etc,~__ -- ~ - - -~ ~ - - - Top Depih' (TVD) '~, Top Top (HKB) (nKg) ~ Incl (°) Description Comment Run Date ID (in) 7 400.0 6,830.5! 31.30 FISH 1 1!2" OV 1.5" OV LOST 2/24/2006 224/2006 74730 6,8929'i 31.47~FISH 11/2"DV&TGLatchDroppedtoRathole 1?J76/1986 iZ1611986 Perfora --_ tions _ _ _ ~, -- --- '~ snof' i Top (TVD) I B~m (TVD) Dens ~~, ~ Top (RKB) 84n (itl(B) (kKB) (ftK6) Zone Date '(sh... ', Typa Comment 7,279.0 ~,29~.Oi 6,727.3 6.742.6 A3,3K-09A 9/27/1987 . S.O~RPERF I 21/8"SilverJet,60ph 7,284.0 7,284.0 ~ 6,731.6 1 6,731.6 A3, 3KL9A 12/14/7986 ~, 1.O 'IPERF _ 2 7/8" EnerJet, 0 aeg ph 7,289.0 7,289.01 6,735.8 6,735.8 A3, 3K-09A 12/14/1986 1.O~IpERF 2 1/8" EnerJet, 0 deg ph J,292.0 7,292.0 6,738.4 6,738.4 A3, 3K-09A 1211411986 1.0 IPERF 2 7/8" EnerJet, 0 aeg ph 7,294.0 7,294.0 6,740.1 6,740.1 A3, 3K-09A 12114l1986 1.0 IPERF 21/8" EnerJet, 0 deg ph 7,370.0 7,326 0 6,753J 6,767.4 A-2, 3K-09A ~9127/7987 8.0 RPERF 2 1/8" Silver Jet, 60 ph 7,315.0 7,315.0 I 6,758.0 6,758.0 A-2, 3K-09A '~ 72/74/1986 1.0 IPERF 2 7/8" EnerJet, 0 deg ph 7,325.0 7,325.0~ 6,766.5 6,766.5 A-2, 3K-09A ~ 12/14/1986 1.0 IPERF 2 1/8" EnerJet 0 deg ph 7,333.OI 7,333 0'4 6,773_3 6,773.3 A-2, 3K~19A 112/7411986 1.0 IPERF 21/8" EnerJet, 0 deg ph 7,339 0 ~ ~ 7,339.OI 6,778.S 6,778.5 A-2, 3K-09A 12/7411986 ~ 7 0 ' IPERF 2 1/8" EnerJet, 0 aeg ph 7,344.0 I 7.344.Oi 6,782J 6,782J A-2, 3K-09A 12/14/1986 1.0 IPERF 2 1/8" EnerJet, 0 deg ph 7,348.0 7 352.0 6,786 7 6,789.6 A-2, 3K-09A 12/14I7986 7.0 IPERF 2 7l8" EnerJet, 0 deg ph 7,359.0 7,3630~1 6,795.5'~~ 6,798.9 i A-2,3K-09A 12/74/1986 10 IPERF 21/8"EnerJet,Oaegph ~ , Notes: , General 8 Safety . _ _ _ . . _.. . . . . _ _ _. . . . . . . .. __ ': End Date __ _ __ -- Mnota tion ____ _ - _... - 9/2012008 NO7E: VIEW SCHEMATIC w/Alaska Schematic9.0 __- ..._.- . __ _ . _ ... .._ _ . .. _. . ._ ... Mandrel Details .._.. ._ . _ . _ . _- ' -- -- - __. _ _. Top Dep~h Top I ~ Por~ ~ I (TVD) Incl OD Valva Lahh Siza TRO Run 'Stn Top ((1 K8) (kKe) (°) I Naka Motlel (~N Serv Type Type (~N (psi) ~~,.. Run Dab 1 2,396_3 2,396_1 241~, CAMCO MMG I112 GasLih I GLV RK 3/16 1,346.0 9/282008 2 3,532J~I 3,523.81 11.41~I CAMCO MMG I 112I GasLih ~ GLV I RK 3/16 1,327.0~ 9/282008 3 4,606.5 4,512.0 37.35 CAMCO MMG 1 1/2 j Gas Lift DMY I RK 0 0.0 9/2/2008 4 5,586 4 5.307.1 34.97 CAMCO __ _ MMG I 1 12 Gas Lift GLV RK 3/16 1,307.0 __ 9/28/2008 5 6,307 0 5,903.0 33.63 CAMCO MMG 4 1 1/2 Gas Lift DMY .. RK - 0 0.0 9/2/2008 6_~_6,839.0 6,351.6 31.68 CAMCO MMG. _ I_7 12 1 Gas Lift OV RK 3l161 I 0.0 9/27/2005 3K-09A (PTD 1861740) Report ailed TIFL Page 1 of 1 Regg, James B (DOA} • From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, February 08, 2008 3:04 PM ~ ~~ {~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~ Cc: NSK Welf Integrity Proj; NSK Problem Wel! Supv Subject: 3K-09A (PTD 1861740) Report Of Failed TIFL Follow Up Flag: Follow up Flag Status: Green Attachments: 3K-09A Wellbore Schematic.pdf; 3K-09A TIO Plot.jpg Tom & Jim, Kuparuk gas lifted producer 3K-09A (PTD 1861740) failed a diagnostic TIFL on 2/6/07 as a part of regularly scheduled waiver compliance testing and has been added to the weekly SCP report. The TIO prior to shut in for the TIFL was ~ 150/1150/660. A leaking GLV is suspected. Slickline will trouble shoot the tubing leak and repair if possible. Attached is a 90 day TIO plot and a schematic. Please let me know if you have any questions. «3K-09A Wellbore Schematic.pdf» «3K-09A TIO Plot.jpg» Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1720 Pager (907) 659-7000 pgr. 909 ~~ ~~t~NNIE~ FEB ~ 0 2008 '6'(k~zk~o~- (~~~r~~sv~.~e_ b1e~ ~ti `~~~5j ~.~ ~p~' ~ ~I-z~~- ~~- ~ssw~e_~~"t~-~iP 2 ~t~O(z ~- vt.~~i~cr~-~~ti ~~ '~ ~, t~ ~ ~- ~ ~ ~~ ~ r~ s~s ~~.~es t ~ v~ ~ a u,~ Zr~p ~~,~, 3 ~ ~ Zc~~ -- ~~~"~ z~;les ~ D l 2/13/2008 KRU 3K-09A PTD 186-174 TIUO Plea - 3K-OJ 1200 1000 800 ~. 800 400 200 0 01-yep-07 01-Oct-07 01-Nov-07 Gate 01-Dec-07 01-Jan-OS 200 150 r~. 100 c 50 01-Feb-O$ • '~ ~~ ' ,,~1 Cflnac~oPhill~s Alas~Ca, inc. ', ~3K-Elr----,gam---- - NIP (501502, _ .I T • - ~, 7 f' ~~1J Casing String -ALL STRINGS Gas Lift ?~ 1 Descri lion S I~ MandrelNalve CONDUCTOR 16 1 F' *~ SURF. CASING 9. (2696-2597, G ~ ~~ ,' ,t ~ PR~n CASING 7. • KRU 3K-09A AI=D: SOtita~ IoSoe I vvell T e: t'R~G Hn lea 15 si oe m / 107 SSSV T e: NIPPLE Ori Com letion: 10/21!1986 An le TD: 31 de 7580 Annular Fluid: Last W/O: 4/3/1999 Rev Reason: GLV C/O, TAG FILL Reference Lo Ref Lo Date: Last U ate: 1/20/2007 Last Ta : 7286' TD: 7580 ftKB Last Taq Date: 1/15/2007 Max Hole Anale 37 dea ~ 4600 Tubing String -TUBING Gas Lift _~ a¢e l ~ BOttOm I TVD I W[ I Gra ~~ MandrelNal 2 t ~ --- I:'I' I f, de I Threatl ~,- ~ ~, I~-: - ~ I-~ ~ CUE -I f - is l.~l) (3661-3862, = Perforations Summary ~~~ Gas Lift drelNalv M ~~ '._~ an e l3. ~ 3 ~ (4970-4971, - ' Gas Lift ~ ~ ~, andrel/Dummy ;~ I Valve 4 z (58315832, , OD:4.750) ~ Gas Lift ', • t I :; ~ andrel/Dummy ; . ~~ . I Vale 5 . . F...._ (65075508, ~'. OD:4.750) t:j SBR (7083-7084, OD:2.875) PKR (7102-7103, OD:6.151) NIP (7118-7119, OD:2.875) TUBING (0-7128, OD:2.875, ID:2.441) Perf (7284-7284) Perf (7279-7297) Perf (7315-7315) Pert (7310-7326) Perf (7333-7333) Perf (7339-7339) Perf (7348-7352) Interval TVD Zone Status Ft SPF Date T e Comment 7279 - 7284 6727 - 6732 A-3 5 8 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7284 - 7284 6732 - 6732 A-3 0 9 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7284 - 7289 6732 - 6736 A-3 5 8 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7289 - 7289 6736 - 6736 A-3 0 9 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7289 - 7292 6736 - 6738 A-3 3 8 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7292 - 7292 6738 - 6738 A-3 0 9 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7292 - 7294 6738 - 6740 A-3 2 8 9/27/1987 RPERF 2 1/8"Silver Jet 60 h 7294 - 7294 6740 - 6740 A-3 0 9 9/27/1987 RPERF 2 1!8" Silver Jet 60 h 7294 - 7297 6740 - 6743 A-3 3 8 9/27/1987 RPERF 2 1/8" Silver Jet 60 h 7310 - 7315 6754 - 6758 A-2 5 8 9/27/1987 RPERF 2 1/8"Silver Jet 60 h 7315 - 7315 6758 - 6758 A-2 0 9 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7315 - 7325 6758 - 6767 A-2 10 8 9/27/1987 RPERF 2 1/8" Silver Jet, 60 h 7325 - 7325 6767 - 6767 A-2 0 9 9/27/1987 RPERF 2 1/8"Silver Jet, 60 h 7325 - 7326 6767 - 6767 A-2 1 8 9/27!1987 RPERF 2 1/8" Silver Jet, 60 h 7333 - 7333 6773 - 6773 A-2 0 1 12/14/1986 IPERF 2 1/8" EnerJet, 0 de h 7339 - 7339 6778 - 6778 A-2 0 1 12114/1986 IPERF 2 118" EnerJet, 0 de h 7344 - 7344 6783 - 6783 A-2 0 1 12/14/1986 IPERF 2 1/8" EnerJet, 0 de h 7348 - 7352 6786 - 6790 A-2 4 1 12/14!1986 IPERF 2 1/8" EnerJet, 0 de h 725Q _ 7483 67QF - 679_9 4-? 4 1 12/14/10RR IPERF '.Gas Lift Mandrels/Valves St MG TJD Man MfrY Man Type V Mfr V Type V OD Latch Port ? 1/R" Fnaa lat n ¢~~ Ph TRO Date Run Vlv Cmnt 1 2596 2596 Merla TMPD GLV 1.0 BK 0.156 1320 1/15/2007 2 3861 3844 Merla TMPD GLV 1.0 BK 0.188 1358 1/15/2007 3 4970 4803 Merla TMPD OV 1.0 BK 0.250 0 1/15!2007 4 5831 5508 Merla TMPD DMY 1.0 BK 0.000 0 4/3/1999 5 6507 6070 Merla TMPD DMY 1.0 BK 0.000 0 4/3/1999 6 7029 6514 Merla TGPD DMY 1.5 RK 0.000 0 1/14/2007 Other (plugs, equip., etc.) - JEWELRY i ~lanih I iV~r I Tvno I flocrrintinn Bread I In I 501 501 NIP Camco DS Ni le. 2.310 7083 6560 SBR Camco'OEJ' 2.310 7102 6576 PKR Camco'HRP-I-SP' 2.347 7118 6590 NIP Camco'D' Ni le NO GO 2.250 7128 6598 SOS Camco'PE-500' 2.441 I nzn I ntivx I i l~ I Fish -FISH Depth Description -.1r I I -C I I ~ C T!.S L, L. l i General Notes I l 441 I Comment Date Note { 10/2/1996 NOTE: Ta ed Sand and Scale 6123'; sam le recovered - 3/16/2006 NOTE: WA IVERED WELL: IA x OA ANNULAR COMMUNICATION ~ __ _ f"':~ L -~ k ~~,r~ Cam) 4a~~~/. ;9 [._3 - f ',~ N+ fe -r No ice of Kuparuk Waivere~ell WELL: 3K-09A WELL TYPE: Producer Gaslift DATE: 03-10-06 Production Data: OIL= 170 bopd GOR = 440 WATER CUT = 3 ..................... ......................... .................................. Pressures: Tubing IA OA Producing: 140 psi 777 psi 850 psi Shut-In: 750 psi 1200 psi 1200 psi REASON FOR NOTICE: Production casing by surface casing communication (IA x OA) TUBING x IA COMMUNICATION? YES NO XX •TIFL passed 02/28/06 showing no T x IA communication. IA x OA COMMUNICATION? YES XX NO • IA x OA communication recently became evident with increase bleed frequency; • The records indicate the inner casing packoffs and P seal have been reenergized with McEvoy sealant; • IG packoff testing failed prior to renergizing the P seal, indicating a possib{e leak source; • Annulus trends and recorded bleeds indicate a constant leak from the IA to OA; • IA x OA communication exists and may be downhole or through the casing packoffs. IMPORTANT CONSIDERATIONS/COMMENTS: • Well requires gas lift to produce; • Production casing packoffs may be leaking; • Surface casing has integrity based on passing MITOA @ 1800 psi on 02/15/06; • The surface casing has a cement shoe and Arctic Pack; • IA x OA communication may be downhole or through production casing packoffs. PLAN OF ACTION: XX...... ..... Grant waiver to continue operations • Allow operation with gaslift as needed; • Allow OA to equalize with IA pressure up to 1400 psi; `~ • Monitor well head pressures daily and log as per surveillance requirements into Setcim; • PerForm the following waiver compliance testing: • 2-year TIFL / MITOA @ 1800 psi alternating with a 2-year OA fluid level; • A failing MITOA will void the waiver and require SI the well and securing; • T x IA communication (failed TIFL) will void the waiver and require SI the well and securing. Problem Well Supervisor CPF Production Engineer Problem Well Su ervisor Date: Date: ENDORSEMENT: CPF Su ervisor Date: Wells Team Leader Date: Distribution: Send Original to: Problem Well Supervisor, NSK-69 DS Operator CPF PE Wells File and schematic Central Files ATO Central Files Kuparuk • KRU_3K-09,4_TxI,4_2006-0216.txt Subject: 3K-09 (PTD 186-174) Failed TIFL From: NSK Problem well supv <n1617@conocophillips.com> Date: Thu, 16 Feb 2006 16:06:36 -0900 TO: Thomas Maunder <tom_maunder@admin.state.ak.us>, dames Regg <jim_regg@admin.state.ak.us> Tom, 3K-09 (PTD 186-174) Failed a TIFL yesterday. Initial pressure readings were 150/1020/740. Near term plans include replacing the gas lift design and ReTIFL'ing the well. Let me know if you have any questions. MJ Loveland ConocoPhillips Problem well supervisor 659-7224 Page 1 . . ConocJ'Phillips Alaska :",:, ~ JUL 7..: P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 28, 2007 Mr. Tom Maunder ~i;S~e~i~~ :va:n~~,r:i~~i~;o S~NED AUG () 1. 2007 Anchorage, AK 99501 \~~... \ 1 Lt Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ) --~_. 7!'¿'illo7- Perry KI . ConocoPhillips Well Integrity Supervisor . . JUL ~ i 'l) ..a.. 2007 g, "" ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na gal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 71712007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K:.11 186-164 43' 6.5 . 21" .. 7/10/2007 ... ." 7.8 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 (j .j£~--~--~ 01/02/07 SchlumbBPger .--,,.,-'".....,~.. NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: SCANNED JAN 0 8 Z007 1~0-1?~( Field: Kuparuk Well CD Job # Log Description BL Color Date 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N·304 11296737 FBHP SURVEY 11/04/06 1 10-109 N/A INJECTION PROFILE 11/27/06 1 1J·136 (REDO) 11534188 USIT 12/10/06 1 1R·18 N/A SBHP/DD 12/18/06 1 1G·16 11551836 INJECTION PROFILE 12/19/06 1 1D·103 11548555 INJECTION PROFILE 12/20/06 1 3K·09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N·326 11551840 SBHP SURVEY 12/24/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M·16 11551842 INJECTION PROFILE 12/26/06 1 2A·20 11548565 INJECTION PROFILE 12/26/06 1 2M·15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Re: CPAI Kuparuk Wells 3K-08 and 3K-09 ) '3lL-oC¡A- Subject: Re: CPAIKuparuk Wells 3K-08 and ~Jß,e..- From: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us> Date: Wed, 04 May 2005 17:05:53 -0800 To·: NSK Problem Well Supv <n1617@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us> ) ~ii.. '¿<'.. ::·I~.I"~.:~,¡(l t.t " {~GfJJ .... I NSK Problem Well Supv wrote: Lou, Below is a follow-up on the 2 wells you discussed with Wrongway during state SVS testing. The injection rate on 3K-08 was reduced from 400 bpd to 200 bpd, subsequently reducing the IA pressure from 3050 psi to 2910 psi. The OA pressure on 3K-09 was bled from 925 psi to 500 psi. The OA pressure will be monitored for a pressure build up rate. please call with any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 Thanx Brad, I appreciate your attention to this matter. SCliNNED MAY 2 f) 2005 1 of 1 5/6/2005 4:25 PM MEMORANDUM. State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3KPad May 18,2001' I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad w/no problems witnessed. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested. 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc.; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc 1 Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Ph!llips Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Well Permit Separ Set L/P Test Test Test Date oa, WAG, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3K-01 1861010 65 70 50 P P OIL 3K-03 1861030 65 70 55 P P OIL 3K-06 1861240 65 70 50 P P OIL , ~3K-09A 1861740 65 60 54 P P OIL , , 3K-10 1861630 65 70 52 P P OIL ,3K-11 1861640 65 70 50 P P OIL 3K-14 1861370 65! 60 58 P P OIL t3K-16 1861390 65 70 70 P "P OIL 3K-17 1861520 65 60 35 P P OIL , , 3K-23 1970970; 65 70 58 P P OIL 3K-24 1982490 65 70 50 P P OIL 3K-27 1970460 65 70 52 P 4 OIL 3K-32 1970760 65 70 55 P P 0IL 3K-35 1971090 65 70 50 P P OIL Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% [3 9o oar Remarks: RJF 1/16/01 Page 1 of 1 SVS KRU 3K 5-18-01jc MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~X Plugging _ Perforate _ Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development X. 69' RKE 3. Address: Exploratory . 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1234' FSL, 317' FWL, Sec 35, T13N, R9E, UM 3K-09A At top of productive interval: 9. Permit number/approval number: 1325' FSL, 2199' FWL, Sec 35, T13N, R9E, UM 86-174 At effective depth: 10. APl number: 1332' FSL, 2388' FWL, Sec 35, T13N, RgE, UM 50-029-21656-01 At total depth: 11. Field/Pool: 1334' FSL, 2445' FWL, Sec 35, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7580 feet Plugs (measured) None true vertical 6983 feet Effective Deptt measured 7472 feet Junk (measured) None true vertical 6891 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 1540# POLESET 121' 121' Surface 3135' 9-5/8" 1400 Sx AS iV & 3172' 3169' 125 Sx Class G Production 752~4' 7" 910 Sx Class G 7559' 6965' Liner Perforation Depth measured 7279'-7297', 7310'-7326', 7333', 7339', 7344', 7348'-7352', 7359'-7363' true Metrical 6727'-6743', 6754'-6767', 6773', 6778', 6783', 6786'-6790', 6796'-6799' Tubing (size, grade, and measured depth) 2.875", 6.5 Ib/ft, J-55 @ 7128' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 7102'; SSSV: None, nipple @ 501' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 4/20/98. Intervals treated (measured) 7279'-7297',7310'-7326',7333',7339',7344',7348'-7352',7359'-7363' Treatment description including volumes used and final pressure Pumped 260,137 lbs of 16/20, 12/18, & 10/14 ceramic proppant into formation, fp was 8800 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 110 123 0 998 142 Subsequent to operation 559 415 0 964 159 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil _X Gas _ Suspended _ Service _ i17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ o Form 10 404 Ret~ ~-''-~- Title: Production Engineering Supervisor Date - '~]6/~ 5/88 SUBMIT IN DUPLICATE .¢O Alaska, Inc. KUPARUK RIVER UNIT ,cELL SERVICE REPORT · KI(K-09A(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-O9A FRAC, FRAC SUPPORT 0414980725.3 DATE DAILY WORK UNIT NUMBER 04/20/98 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~ Yes (') NoI {~ Yes O No DS-YOKUM JOHNS FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE KD2072 230DS36KL $151,756 $158,247 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 345 PSI 500 PSII 700 PSII 500 PSI DALLY SUMMARY PUMPED "A" SANDS RE-FRAC, TOTAL 260, 137 # TO 10/14,14 PPA AT PERES. LEFT 2500# IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC SUPPORT. 08:11 HELD SAFETY MEETING AND PRESSURE TEST SURFACE LINES. 08:20 PUMP BREAKDOWN WITH 100 BBLS 50# GEL, 25 BPM TO 8567 PSI. SAW GOOD BREAKDOWN. PUMPED 1PPA 16/20 PROPPANT 2011# SCOUR. PUMP CONDITION 50 BBLS, 15 BPM. PUMP 2PPA 16/20 3860#. PUMP 89 BBLS FLUSH 15 BPM AND3479 PSI. SHUTDOWN. ISIP 1684 PSI. 09:13 PUMP DISPLACMENT AND DATA FRAC WITH159 BBLS FLUIDS. 5 TO15 BPM AND5232 PSI. SHUT DOWN FOR ISIP 1789 PSI AND CLOSURE CALCULATION. 10:06 INCREASE TO MAX PAD, PUMPED 700 BBLS, 5 TO 15 BPM, 50 # GEL AND 5566 PSI. 10:59 PUMPED 7719 # 16/20 PROPPANT/GEL SLURRY. 2PPA, 5191 PSI. 11:05 PUMPED 232,000# OF 12/18,6PPA TO 12 PPA, 4902 PSi TO 6591 PSI. 12:17 PUMPED 13,676# OF 10/14,14 PPA, 5978 PSI. 12:20 WENT TO FLUSH WITH DIESEL GOT 28 BBLS DIESEL DOWN HOLE , WELL SCREENED OUT 10 BBLS SHORT OF PERES. MAX. PRESSURE 8800 PSI. 12:23 SHUTDOWN WITH 10/14 ON PERES AT 14 PPA. PUMPED 17000 16/20,232000 12/18 AND 13676 10/14. LEFT 2539 # PROPPANT IN PIPE. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $420.00 APC $7,800.00 $7,800.00 DOWELL $142,356.00 $142,356.00 HALLIBURTON $0.00 $3,271.00 LITTLE RED $1,600.00 $4,400.00 TOTAL FIELD ESTIMATE $151,756.00 $158,247.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _X Alter casing _ Repair well _X Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 29' Rig RKI~ 3. Address: Exploratory_~ 7. Unit or Property: P.O, Box 100360 Stratagrapic Anchora,qe, AK 99510-0360 Service ~ Kuparuk River Field 4. Location of well at surface: 8. Well number: 1234' FSU 317' FWU Sec. 35, T13N, R9E, Uk 3K-09A At top of productive interval: 9. Permit number/approval number: 1325' FSU 2199' FWU Sec. 35, T13N, R9E, Uk 86-174/399-036 At effective depth: 10. APl number: 50-029-21656-01 At total depth: 11. Field/Pool: 1334' FSU 2455' FWL, Sec. 35, T13N, R9E, UN Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 7580' Plugs (measured) true vertical 6983' Effective Deptt measured 7472' Junk (measured) true vertical 6891' Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 16" 1540# Poleset 110' 110' Surface 3143' 9.625" ~400 sx AS IV & 12,5 sx Class G 3172' 31 69' Production 7530' 7" 910 sx Class G & 175 sx AS I 7559' 6965' Liner Perforation Depth measured 7279'-7297' E 7310'-7363' true vertical 6727'-6742' E 6753 '-6798' Tubing (size, grade, and measured depth) 2.875", 6.5#, L-80 @ 7083 Packers and SSSV (type and measured depth) Camco 'HRP-1-SP' Pkr @ 7102', -' ...... Camco 'DS' nipple @ 501' 13. Stimulation or cement squeeze summary Intervals treated (measured; N/A Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations __X Oil __X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Date: 4/20/99 ARCO ALASKA INC. WELL SUMPLARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3K-09 WELL_ID: 999295 TYPE: AFC: 999295 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/29/99 START COMP:03/28/99 RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21656-01 03/28/99 (C1) TD: 7580' PB: 0' 03/29/99 (C2) TD: 7580' PB: 0' 03/30/99 (C3) TD: 7580' PB: 0' 03/31/99 (C4) TD: 7580' PB: 7492' 04/01/99 (C5) TD: 7580' PB: 7492' 04/02/99 (C6) TD: 7580' PB: 7492' CIRCU & CONDITION MUD TO MW: 0.0 SUPV:DEARL W. GLADDEN Move rig from 3K-31. Accept rig @ 1000 hrs. 3/28/99. Rig up. Test tree. UPCOMING OPERATIONS:KILL WELL -INSTALL BPV - N/D TREE - N/U BOPS & TEST SAME WELL SHUT IN-MONITOR BUIL MW: 0.0 SUPV:DEARL W. GLADDEN Shut in well. Weight up mud. UPCOMING 0PERATIONS:KILL WELL - INSTALL BPV - N/D TREE - N/U BOP PULL TBG TO RIG FLOOR 70K MW: 0.0 SUPV:DONALD L. WESTER Continue to kill well pump 10.8 ppg mud down tubing and through choke. Continue to weight up to 11.5 ppg. Well dead. N/D tree, N/U BOPE and test BOPE to 250/3000 psi. UPCOMING 0PERATIONS:P/U 3-1/2" DP & WASH PIPE C/O SAND ON TOP OF PACKER ~ 7102' L/D DP TAG SAND @ 7002' CIRCULAT MW:ll.5 LSND SUPV:DONALD L. WESTER PJSM. Pull tubing hanger. Circulate out gas cut mud at bottoms up. Pull 2-7/8" tbg. Clean out frac sand. UPCOMING OPERATIONS:C/O TO PACKER TOP @ 7102' LOAD PIPE SHED W/ NEW 2-7/8" TBG & REPAIRE TOP DRIVE. CONTINUE TO L/D 3.5" DP. MW:ll.5 LSND SUPV:DONALD L. WESTER Continue to RIH w/BHA #1. Circulate out gas cut mud. Clean out frac sand from 7002' to 7095'. UPCOMING OPERATIONS:RUN COMPLETION PUMPED 290 BBLS SEA WATER MW: 8.6 DOILW SUPV:DONALD L. WESTER PJSM. Run 2-7/8" completion. N/D BOPE. NU tree and test tree to 250/5000 psi. UPCOMING OPERATIONS:MOVE RIG FROM 3K PAD TO iD PAD. Date: 4/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/03/99 (C7) TD: 7580' PB: 7492' SUPV:DONALD L. WESTER Release rig @ 1000 4/3/99. UPCOMING OPERATIONS: M~: 0.0 DOILW STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Aband~"n _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Other __ Change approved program _ Pull tubing _X Variance _ Perforate _ Annular Injection. 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 29 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 1234' FSL, 317' FWL, Sec. 35, T13N, R9E, UM 3K-09A At top of productive interval 9. Permit number/approval number 1325' FSL, 2199' FWL, Sec. 35, T13N, R9E, UM 86-174 At effective depth 10. APl number 50-029-21656-01 At total depth 11. Field / Pool 1334' FSL, 2455' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Field/Kuparuk Oil Po? 12. Present well condition summer Total depth: measured 7580 feet Plugs (measured) true vertical 6983 feet Effective depth: measured 7472 feet Junk (measured) true vertical 6891 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 81' 16" 1540# Poleset 110' 110' Surface 3143' 9.625" 1400 sx AS IV & 125 sx Class e 3172' 3169' Production 7530' 7" 910 sx Class G & 175 sx AS I 7559' 6965' ORIGINAl_ Perforation depth: measured 7279'-7297', 7310'-7363 ....~? F f¢;'~ ~-""~" true vertical 6727'-6742', 6753'-6798' iTubing (size, grade, and measured depth 2.875", 6.5#. J-55 @ 7093' ' t'~ e' ,- Packers & SSSV (type & measured depth) Camco 'TRDP-1A-SSA' @ 1795', Camco 'HRP-1-SP' pkr @ 7102' ,~;~li~'~fl 13. Attachments Description summary of proposal ___X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: March 10, 1999 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed ~/~ (~4.~ Title: Drilling EngJneering Supervisor Date · / ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no.k..~3, Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- ~ O~ - ORIGINAL SIGNED BY Apprqyed by order of the Commission Robert N. Ohdstenson ~.. r,o'.J Commissioner Date~""/ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PRE-RIG WORK: KRU 3K-09 GENERAL WORKOVER PROCEDURE 1. RU Slick Line Unit. RIH and pull Dummy Valve from GLM @ 5685' leaving an open pocket. Dummy off all other GLM's. 2. Set BPV in tubing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with seawater. Displace tubing and annulus with seawater. SI well and monitor pressure to determine kill weight. 3. Load pits with kill weight mud. Displace tubing and annulus with kill weight mud. SI well and monitor pressure to ensure well is dead. Set BPV. 4. ND / NU and test B OPE. 5. Screw in landing joint. POOH laying down 2-7/8" tubing and spooling up SSSV control line. Lay down SSSV and continue POOH laying down 2-7/8" tubing and jewelry. Note: Tubing is filled w/frac sand and corkscrewed from the packer to approximately 6123'. If unable to pull off SBR it will be necessary to cut the tubing as deep as possible and fish the remaining tubing from the well bore using drill pipe. Load, strap and drift 3-1/2" drill pipe. RIH with cleanout assembly picking up 3-1/2" drill pipe off the rack. Cleanout to top of packer and POOH laying down 3-1/2" drill pipe. Load, strap and drift 2-7/8" tubing. 10. RIH with 2-7/8" completion assembly as per schematic. Circulate over slick stick, spaceout with tubing pups and land tubing hanger. Pressure test tubing and annulus. ND / NU and test tree. Displace well to seawater and freeze protect with diesel to +\- 2000' TVD. , . . 11. 12. 13. 14. Lower Limit: 4.5 days Expected Case: 5.5 days Upper Limit: 7.0 days No problems pulling or re-running completion Difficulties encountered pulling completion, or re-running completion MAC 2/15/99 3K-09 Proposed Complet,on 7" 26# J-55 @ 7,559' M. 2-7/8" 5M Cameron Gen IV tubing hanger with 2-7/8" L-80 EUE 8rd pin down. L. 2-7/8" 6.5# L-80 EUE 8rd Mod tubing to the tubing hanger. K. 2-7/8" Camco 'DS' Nipple with 2.312" profile set @ +/- 500' MD. J. 2-7/8" 6.5# L-80 EUE 8rd Mod tubing to the 'DS' Nipple with 2-7/8" x 1" Camco 'KBMM' mandrels w/DV's spaced out as follows. GLM # MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD 6 TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. I. 2-7/8" x 1-1/2" Merla q'GPD' mandrel w/DCR Dump Kill Valve & RK Latch (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. (4102910) H. 1 Joint 2-7/8" 6.5# L-80 EUE 8rd Mod tubing G. 8' Pup Joint 2-7/8" 6.5# L-80 EUE 8rd Mod tubing F. Camco 'OEJ' SBR w/2.313" ID E. 7" x 2-7/8" Camco 'HRP-1-SP' Hydraulic Set Retrievable Packer @ 7102' D. 8' Pup Joint 2-7/8" J-55 EUE 8rd AB Mod Tubing. C. 3-1/2" Camco 'D' Nipple w/2.25" Profile. B. 8' Pup Joint 2-7/8" J-55 EUE 8rd AB Mod Tubing. A. Camco 2-7/8" PE-500 shear out @ 7128'. Tubing tail @ 7129'. A3-Sand Perfs 7,279' - 7,294' A2-Sand Perfs 7,310' - 7,362 PBTD @ 5,980' - Corkscrewed tubing and sand from this point to FC. PBTD @ 7,472' - Actual 7" casing PBTD to FC. TD @ 7,580' 2/9/99 MAC 3K-09A.pdf at www.aai.arco.ce Page 1 of 2 ARCO Alaska, Inc. Kuparuk 3K-O9A 3K-O9A ~V Type: Carn~'~-IA-SS/~ Amula~ Ruid:I Last Tag:11910' Pev Reasor[ I T/~/DF~ FT byvg Elevations Well Type:l PROO Odg Ccr~]~ion:I Last W/O:I Last Tag Date: 4/22./98 Last Update: 4/23/98 PBTD,17,5~0 ~ TD,17~580 flKB Ancjle @ TS: 31 deg @ 7107 ; Ar~e @ TD:131de9 @ 7580 Grd I~ft CaSing Strin§ - CONDUCTOR Item 16 in COt~T~ Casing String - SURFACE Item 9.5~8 in SUR. CASING Casing String - PRODUCTION Item 7 in PPEI3. CASAIG I Odcn~ Fig F~<B I Btm dnts Wt Grd Thd 110 62.50 H-40 Btm Jnts Wt Grd Thd 3,172 36.03 J-55 Btm Jnts Wt Grd Thd 7,559 28.03 J-55 Tubing String - TUBING Item Top Len Jnts Wt Grd 2 7/8 inTUBING ;36 7,093 6.501 J-S5 Perforations Interval 7,284-7~84 7,289 - 7¢~89 7,2g~ - 7¢q92 7,294 - 7,294 7,315 - 7,315 7,325 - 7,325 7,333 - 7,388 7,339 - 7,339 7~348 - 7~352 7~389 - 7,383 7,279 - 7,297 7,310-7,326 Zone A-3 A-3 A-3 A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-3 A-2 Gas Lift Mandrels/Valves Status Feet SPF Date IType 1 12/14/86 12 1/8" Ena.Jet I 12/14/86 12 1/8" Ena.Jet I 12/14/86 12 1/8" EnerJet I 12/14/86 12 1/8" Ena.Jet I 12/14/86 12 1/8" Ena.Jet I 12/14/86 12 1/8" Ena.Jet I 12/14/86 12 1/8" Ena.Jet I I I 1112/14/86 J2 1/8" Ena.Jet I I I 1112/14/88 /21/8" B-ia'Jet I I 4j 1112/14/86 121/8" Ena.Jet I I 41 1112/14/86 12 1/8" Ena.Uet I I 18j 8I 9'27/87 J2 1/8" Silver Jet I I 16J 8J 9'27/87 J2 1/8" Silver Jet Thd EUE 8rd ~ MOD Comment Zero deg. phasing Zero deG, phasing, Zero deG, phasing, Zero deg. phasing Zero deg phasing Zero de9 phasir .q. Zero deg phasing, Zero de9 phasing Zero de9. phasing Zero de~., phasing Zero deg. phasing 60 de9 phasing ~o c~ t:tasing StnJ MDI TVDIMan Mfr IMan Type Mfr Type Latch PortI TRO Run 1 I 2,555J 2,..'5~ Meda 27/SXITM:O MVH DV 13~ 0 J 0.0J 4/16/~13 2 4,157 4,127 IVbrla 2 7/8 X 1TIVPD DV BK 0 0.0 12/2/86 3 5,181 4,975 Merta 2 7/8 X 1TIVPD IVM-I DV B~ 0 J 0.0 4/16/~13 4J 5,686J 5,389J IVerla J2 7/8 X 1TIVPD DV E~ 0 0.01 12,~11 5 J 6,130J 5,756 IV'erla 27/SX1TMC'D DV ~ 0 I 0'01 12r~611 6 6,579 6,131 Meda 2 7/8 X 1TMC~D DV 13~ 0 0.0J 12f2/86 JJ 7 7,035 6,519 IVeda 27/8X1 1/2TGPD k,/vl-I DV TG 0 0.0J 4/16/9eii Depthl Type I Description ID2 7,0761 SEa Camco'O~J' Z312 7,1c~J ~ Carnco'l-P,P-1-SP' 2_347 7,118J kO GO Camco'E~ ~pp~e ~_250 II 7,12~1SHE~ ou'r Carnco'~-~ I~441 Il 7,128J TUBI',IG TAIL J2.441 II Fish - FISH Depth Description 7,473 1 1/2 DV & TG Latch Dropped to Ra~de Comment General Notes Date 10/2/96 Note Tagged Sand and Scale @6123'; sarrpe recovered Ma~r~/CuTrny VaJve 1 Ma'drd/Cu'rm/Va~e 2 Mardrel/Cu'rrry Valve 3 Ma-drd/D. xm~ Va~e 4 Ma'dreVDJ'm~ Va~e 5 Mmd~V~e 6 Iv'erd~D. rrm/Va~e 7 Peri Perf Peri 1 1/Z DV 2/23/99 4:11 '01 PM ADDENDUM WELL: 3/10/87 3K-9A RU CTU, tst ins to 4000 psi. TIH to 7300'; did not tag up. POOH to tbg tail, wsh & CO to PBTD @ 7472'. Pmp total of 138 bbls gel diesel; rec'd 130 bbls. Back flushed w/80 bbls diesel. Rec'd 78 bbls. Turn well over to Production. DriVing ~-~p e rv~or /Date STATE OF ALASKA ALAbr,,-~ OIL AND GAS CONSERVATION CON ..... -SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~, Alter casing ..r-] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate Fi Other Name of Operator ARCO Alaska, Inc Address PO Box 100360, Anchorage: AK 99510-0360 Location of well at surface 1234' FSL, 317' FW'L, Sec 35 T13N RgE UM At top of productive interval ' ' ' ' 1325' FSL, 2199' FWL, .Sec.35, T13N, RgE, UM At effective depth 1332' FSL, 2388' FWL, Sec. 35, T13N, RgE, UM At total depth 1334' FSL, 2445' FWL. Sec. 35: T13N: RgE. tim 11. Present well condition summary Total depth: measured 7580' MD feet true vertical 6983' MD feet Effective depth: measured 7472' MD feet true vertical feet 6891' MD 5. Datum elevation (DF or KB) RKB 69 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-9A 8. Permit number Permit #86-174 9. APl number 50-- 029-21656-01 10. Pool K~;narlJk Rivpr flil Pnnl feet Casing Length Size Structural 80' 16" Conductor Surface 3135' 10-3/4" Plugs (measured) None SEP 2 ]. dunk (measured) None , Naska 0il & Gas Cons. Commission Cemented Measured aepth ~0~cal depth 1540# Poleset 110' MD 1400 SX ASIV & 3172' MD 110' TVD 3169' TVD x x X l~¢,0exec~:~t e Production 7524' xxx k <xxxx Perforation depth: measured 125 SX Class G 7" 910 SX Class G 7559' MD 6965' TVD & 175 SX ASI 7284' 7289' 7294' 7315' 7325' 7333' 7339' 7344' MD 7348'-7352' 7359' 7363' MD true vertical6731, 6735' 6739' 6757' 6765' 6773' 6778' TVD 6782' 6785'-6789' 6794'-6798' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7128' Packers and SSSV (type and measured depth) HRP-I-SP pkr ¢ 7102' & TRllP-1A-_qg/I SSSV _Fa !795' 12.Attachments Description summary of proposal ~ Detailed operations program [] Convert wel 1 from oil ,producer to water injector 13. Estimated date for commencing operation October I, 1987 BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the ~oregoing is true and correct to the best of my knowledge y ~ ~ ,~ '-~ .. .... -~ *~;¢' ~ ,~' Sr. Operations Engineer Signed Date9/16/87 Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 iA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET' 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 - CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC / -'M Ay 987 (_.7 :01_! & Gas ConS. Commisslo. A~chorage ~ State. of:.Alas~' ~.(+sepia)'~.:~?~ BPAE Chevron Union Vault (film) ARCO Alaska, Inc. is a Subsidiary of AflanlicRIchlieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CC.,MISSION ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well /,~// / OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 86-17/+ 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21656-01 4. Location of well at surface 9. Unit or Lease Name 1234' FSL, 317' FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1325' FSL, 2199' FWL, Sec.35, T13N, RgE, UM 3K-9A At Total Depth 11. Field and Pool 1334' FSL, 2445' FWL, Sec.35, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.} 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 69' ADL 25519, ALK 2555 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions 10/17/86 10/20/86 01/18/87'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7580'MD 6983'TVD 7472'MD 6891 'TVD YESES] NO [] 1795' feet MDI 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SP/SFL/Cal, FDC/CNL, GR, CBL/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 16" 62.5# H-40 Surf 110' 24" 1540# Pol eset /~ 9-5/8" 36.0~ J-55 Surf 3172' 12-1/4" 1400 sx AS IV & 125 sx ;lass G · ~'~-~/~ 26.0# J-55 Surf 7559' 8-1/2" 910 sx Class G & 175 sx AS I 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) 7284'HD 6730'TVD 7339'MD 6778'TVD 2-7/8" 7128' 7102.' 7289'MD 6735'TVD 7344'MD 6782'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7292'MD 6737'TVD 7348'-7352'MD 6785'-6789'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7294'MD 6739'TVD 7359'-7363'MD 6795'-6798'TVD 7315'MD 6757'TVD See attached AddenJum_~ dated 7325'MD 6766'TVD 02/17/87, for Fracture data' 7333'MD 6772'TVD Perforated w/1 spf, 0° phasing 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test HOurs Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RA'rE ~ 28. CORE DATA Brief ~escription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Mone · · · · Note: Drilled RR 10/21/86. Tubing run 12/03/86 ...... ~·. -. ... . WC2: 038: DAN I Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARk~- I~l::: S FORMATION-TESTS .': . .. .., .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7108' 6581' N/A Base Kuparuk C 7146' 6613' Top Kuparuk A 7260' 6710' Base Kuparuk A 7401' 6831' 31. LIST OF ATTACHMENTS Addendum; (dated 02/17/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ (,~/)~/~tk ,1 ,~--.~/~.~/_ "~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 10/22/86 11/14/86 1/18/87 3K-9A Arctic Pak w/175 sx AS I, followed by 90 bbls Arctic Pak. Tst OK. Rn CBL/GR/CCL f/7460' - 5408'. Rn GCT gyro f/surf - 7420'. Make GR/JB rn to PBTD, RD Schl. Frac Kuparuk "A" sand perfs 7284', 7289', 7292', 7294', 7315' 7325' 73333' 7339' 7344' 7348'-7352' & , , , , 9 7359'-7363' per procedure dated 12/16/86 as follows: Stage 1: 40 bbls 145° diesel w/10% Musol @ 4.5 BPM, 5450 - 4210 psi Stage 2: 160 bbls gelled diesel @ 12 - 20 BPM, 7600 - 6720 psi Stage 3: 20 bbls gelled diesel @ 20 BPM, 6800 psi Stage 4: 45 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM, 6800 - 7270 psi Stage 5: 360 bbls gelled diesel @ 20 BPM, 7270 - 5830 psi Stage 6: 30 bbls gelled diesel w/2# 20/40 sand @ 20 BPM, 5830 - 5890 psi Stage 7: 30 bbls gelled diesel w/3# 20/40 sand @ 20 BPM, 5890 - 5360 psi Stage 8: 80 bbls gelled diesel w/3# - .5# 20/40 sand @ 10 - 20 BPM, 5360 - 5420 psi. Stage 9: 80 bbls gelled diesel 2# - 7# 20/40 carbolite @ 20 BPM, 5260 - 5160 psi Stage 10:60 bbls gelled diesel 8# 20/40 carbolite @ 20 BPM, 5160 - 5450 psi Stage 11:40 bbls gelled diesel flush @ 20 - 16 BPM, 5450 - 8400 psi. Screened out to 8400 psi 7 bbls short of intended. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 945 bbls 1900# 100 mesh, 15,000# 20/40 sand & 29,118# 20/40 Carbolite 1881# 20/40 Carbolite 5700 psi 'Dr-illing Supervisor S UB.S URFA CE DIRECTIONAL SURVEY ~'~ UIDANCE J~JONTINUOUS J~OOL Company A~CO ALAS~ [~. Welt Name 3K-gA (1234'FSL~317'F~/L, SEC.35~T13N.RgE,u~) Field/Location ~-~A~U~ ~O~TH SLOPE, AI_ASK~ Job Reference No. 72104 Lc;~ed By: Date , , ~_:~/ls/8~) Computed By': · GCT OIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3K-gA KUPARUK NORTH SLOPEtALASKA SURVEY DATE: 15 NOV 86 ENGINEER: PEPPEL METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATZON AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 86 DEG 4T MIN EAST ARCO ALASKA, INC. 3K-gA KUPARUK NORTH SLOPE~ALASKA INTERPOLATED VALUE'S TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E lO0.O0 100.00 31.00 0 32 N 4 1.6 E 200.00 199.99 130.99 0 24 N 22 26 W 300.00 299.99 230.99 0 29 N 2 37 E 400.00 399.99 330.99 0 34 N 3 22 E 500.00 499.98 430.98 0 39 N 1 30 W 600.00 599.98 530.98 0 32 N 8 22 W TO0.O0 699.97 630.97 0 21 N 29 5 W 800.00 799.97 730.97 0 16 N 39 11 W 900.00 899.97 830.97 0 15 N 66 16 W 1000.00 999.97 930.97 0 23 S 79 42 W 1100.00 1099.96 1030.96 0 23 S 59 40 W 1200.00 1199.96 1130.96 0 17 S 42 48 W 1300.00 1299.96 1230.96 0 9 S 77 37 W 1400.00 1399.96 1330.96 0 12 S 30 31 W 1500.00 1499.96 1430.96 0 14 S 0 22 E 1600.00 1599.96 1530.96 0 18 S 10 59 E 1700.00 1599.96 1610.96 0 16 S 29 0 E 1800.00 1799.96 1730o96 0 9 S 62 49 E 1900.00 1899.96 1830.96 0 31 N 46 23 E 2000.00 1999.95 1930.95 0 54 N 37 22 E 2100.00 2099.93 2030.93 I 1 N 36 57 E 2200.00 2199.92 2130.92 1 21 N 26 30 E 2300.00 2299.88 2230.88 I 43 N 20 47 E 2400.00 2399.81 2330.81 2 25 N 16 26 E 2500.00 2499.71 2430.71 2 36 N 13 5 E 2600.00 2599.60 2530.60 2 50 N 11 41 E 2700.00 2699.48 2630.48 2 48 N 10 57 E' 2800.00 2799.36 2730.36 2 44 N 7 2 E 2900.00 2899.24 2830.24 3 8 N 27 19 E 3000.00 2998.98 2929.98 4 45 N 54 46 E 3100.00 3098.41 3029.41 7 33 N 66 27 E 3200.00 3197.15 3128.15 10 13 N 72 11 E 3300.00 3295.40 3226.40 10 59 N 73 3 E 3400.00 3393.48 3324.48 11 21 N 73 14 E 3500.00 3491.54 3422.54 11 16 N 73 3 E 3600.00 3589.57 3520-57 11 42 N 73 4 E 3700.G0 3687.37 3618.37 12 19 N 73 5 E 3800.00 3784.95 3715.95 12 56 N 73 20 E 3900.00 3882.28 3813.28 13 46 N 73 27 E FOR EVEN 100 VERTICAL SECTION FEET 0.00 0.07 -0.08 -0.06 0.04 0.11 0.11 -0.08 -0.35 -0.68 -1.22 -1.90 -2.40 -2.66 -2.88 -2.96 -2.94 -2.77 -2.53 '-2.06 -1.19 -0.14 I .06 2.23 3.57 4.92 6.17 7.47 8.44 9.76 14.81 24.28 39.41 57.48 76.41 95.47 114.70 134.89 156.19 178.53 FEET OF DOGLEG SEVERITY DEG/IO0 0.00 0.17 0.45 0.29 0.13 0.26 0.16 0.51 0.16 0.19 0.21 0.35 0.48 0.31 0.15 0.26 0.22 0.22 0.28 0.47 0.21 0.20 0.47 0.46 0.43 0.33 0.41 0.58 0.18 2.51 1.83 3.19 1.62 0.45 0.32 0.37 0.59 0.76 0.52 1.48 DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL MEASURED DEPTH RECTANGULAR NORTH/SOUTH FEET COORDINATES EAST/WEST FEET HORIZ. DIST. FEET 0.00 N 0.45 N 1.32 N 2.07 N 3.07 N 4.15 N 5.14 N 5.94 N 6.32 N 6.59 N 0.00 E 0.05 E 0.15 W 0.18 W 0.14 W 0.12 W 0.18 W 0.42 W 0.70 W 1.05 W 69.00 . 6. 6. 5. 5. 5. 4. 4. 4. 4. 66 41 03 81 68 33 84 38 O7 29 1.60 2.27 2.75 2.99 3.20 3.26 3.21 3.02 2.77 2.30 DEPARTURE AZIMUTH DEG MIN 5.28 N 6.60 N 8.31 N 10.84 N 14.28 N 18.56 N 23.24 N 28.11 N 32.88 N 37.68 N .49 .51 .59 .63 .77 .89 .87 .90 .60 .66 0.00 N 0 0 E 0.45 N 6 14 E 1.33 N 6 30 W 2.07 N 4 57 W 3.07 N 2 32 W 4.15 N I 40 W 5.14 N 2 0 W 5.95' N 4 I W 6.36 N 6 21 W 6.67 N 9 2 ~ 42. 47. 53. 58. 64. 69. 75. 81. 88. 94. 61 N 85 N 13 N 64 N 30 N 97 N 76 N 84 N 14 N 67 N 12.44 21.63 36.49 54.27 72.92 91.69 110.62 130.51 151.48 173.49 6.85 6.80 6.62 6.54 6.52 6.25 5.81 5.32 4.92 4.87 N 13 29 W N 19 27 W N 24 29 W N 27 11 W N 29 22 W N 31 26 W N 33 35 W N 34 39 W N 34 13 W N 28 12 W 5.49 N 15 43 W 6.62 N 4 23 W 8.33 N 4 4 E 10.96 N 8 31 E 14.55 N 10 58 E 18.97 N 11 49 E 23.74 N 11 50 E 28.72 N 11 51 E 33.54 N 11 21 E 38.45 N II 29 E 44.39 52.51 64.45 79.91 97.22 115.34 134.08 154.05 175.26 197.64 N 16 16 E N 24 19 E N 34 29 E N 42 47 E N ~8 35 E N 52 39 E N 55 35 E N 57 54 E N 59 48 E N 61 22 E FT ARCO ALASKA~ INC. 3K-9A KUPARUK NORTH SLOPE,ALASKA DATE DF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATIDN AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 4000.00 3978.93 3909.93 16 23 4100.00 4073.87 4004.87 20 7 4200.00 4166.61 4097.61 23 49 4300.00 4256.65 4187.65 27 44 4400.00 4343.37 4274.37 32 3 4500.00 4426.04 4357.04 35 57 4600.00 4506.08 4437.08 37 8 4700.00 4585.76 4516.76 37 4 4800.00 4665.69 4596.69 36 46 4900.00 4745.94 4676.94 36 31 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION ,SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 5000.00 4826.65 4757.65 35 35 5100.00 4908.49 4839.49 34 59 5200.00 4990.33 4921.33 35 10 5300.00 5072.14 5003.14 34 50 5400.00 5154.13 5085.13 35 8 5500.00 5235.74 5166.74 35 15 5600.00 5317.55 5248.55 34 56 5700.00 5399.66 5330.66 34 41 5800.00 5482.03 5413.03 34 27 5900.00 5564.54 5495.54 34 18 N 74 58 E 203.47 N 80 13 E 234.35 N 86 21 E 271.63 N 88 59 E 315.06 S 89 13 E 364.71 S 88 39 E 420.76 S 88 50 E 480.52 S 89 16 E 540.78 S 89 43 E 600.74 N 89 52 E 660.32 6000.00 5647.24 5578.24 34 9 6100.00 5730.11 5661.11 33 57 6200.00 5813.09 5744.09 33 49 6300.00 5896.24 5827.24, 33 40 6400.00 5979.65 5910.65 33 11 6500.00 6063.56 5994.56 32 42 6600.00 6147.86 6078.86 32 20 6700.00 6232.59 6163.59 31 59 6800.00 6317.52 6248.52 31 43 6900.00 6402.70 6333.70 31 29 N 88 54 E 719.28 N 87 38 E 776.73 N 87 25 E 834.19 N 88 48 E 891.68 S 86 36 E 948.73 S 86 34 E 1006.09 S 86 56 E 1063.24 S 87 12 E 1119.98 S 87 25 6 1176.40 S 87 33 E 1232.61 7000.00 6488.16 6419.16 31 9 7100.00 6573.67 6504.67 31 12 7200.00 6659.15 6590.15 31 21 7300.00 6744.43 6675.43 31 34 7400.00 6829.68 6760.68 31 18 7500.00 6914.98 6845.98 31 28 7580.00 6983.21 6914.21 31 28 S 87 47 E 1288.56 S 88 6 E 1344.30 S 88 23 E 1399.90 S 88 21 E 1455.25 S 88 31 E 1510.22 S 88 54 E 1564.45 S 89 8 E 1618.09 S 89 38 E 1671.09 N 89 53 E 1723.79 N 89 24 E 1776.11 N 89 2 E 1827.99 N 88 42 E 1879.81 N 88 17 E 1931.66 N 87 52 E 1983.88 N 87 40 E 2036.16 N 87 39 E 2088.34 N 87 39 E 2130.10 3.31 4.54 4.01 4.30 4.59 2.72 0.20 0.53 0.55 0.54 101.83 N 198.06 E 222.71 N 62 47 E 108.70 N 228.61 E 253.14 N 64 34 E 112.83 N 265.72 E 288.68 N 66 59 E 114.43 N 309.12 E 329.62 N 69 41 E 114.42 N 358.85 E 376.65 N 72 18 E i13.22 N 415.06 E 430.22 N 74 44 E 111.89 N 474.99 E 487.99 N 76 44 E 110.86 N 535.40 E 546.76 N 78 18 E 110.34 N 595.49 E 605.63 N 79 30 E 110.28 N 655.16 E 664.38 N 80 26 i ? 1.96 0.29 0.54 2.06 1.84 0.63 0.43 0.33 0.06 0.37 110.72 N 714.19 E 722.72 N 81 11 E 112.71 N 771.62 E 779.81 N 81 41 E 115.10 N 829.04 E 836.99 N 82 5 E 117.43 N 886.49 E 894.23 N 82 27 E 116.26 N 943.70 E 950.83 N 82 58 E 112.41 N 1001.36 E 1007.65 N 83 35 E 109.21 N 1058.78 E 1064.39 N 84 6 E 106.29 N 1115.77 E 1120.83 N 84 33 E 103.64 N 1172.43 E 1177.00 N 84 56 E 101.14 N 1228.87 E 1233.03 N 85 17 E 0.24 0.24 0.20 0.35 0.73 0.55 0.54 0.40 0.32 0.48 98.86 N 1285.04 E 1288.84 N 85 36 E 96.86 N 1340.97 E 1344.47 N 85 52 E 95.20 N 1396.75 E 1399.99 N 86 6 E 93.65 N 1452.28 E 1455.30 N 86 18 E 92.12 N 1507.43 E 1510.24 N 86 30 E 90.95 N I561.81 E 1564.46 N 86 40 E 90.05 N 1615.58 E 1618.09 N 86 48 E 89.42 N 1668.71 E 1671.10 N 86 55 E 89.32 N 1721.49 E 1723.81 N 87 I E 89.62 N 1773.88 E 1776.14 N 87 6 [ 0.35 0.37 0.33 0.25 0.95 0.00 0.00 90.38 N 1825.80 6 1828.04 N 87 9 E 91.37 N 1877.64 E 1879.86 N 87 12 E 92.69 N 1929.50 E 1931.73 N 87 14 E 94.46 N 1981.70 E 1983.95 N 87 16 E 96.55 N 2033.95 E 2036.24 N 87 16 E 98.69 N 2086.09 E 2088.42 N BT 17 E 100.40 N 2127.82 E 2130.19 N 87 17 E COMPUTATION DATE: 9-DEC-86 P4GE 3 ARCO ALASKA, INC. DATE OF SURVEY: 15 NOV 86 3K-gA KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.00 FT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -69.00 0 0 1000.00 999.97 930.97 0 23 2000.00 1999.95 1930.95 0 54 3000.00 2998.98 2929.98 4 45 4000.00 3978.93 3909.93 16 23 5000.00 4826.65 4757.65 35 35 6000.00 5647.24 5578.24 34 9 7000.00 6488.16 6419.16 31 9 7580.00 6983.21 6914.21 31 28 N 0 0 E 0.00 S 79 42 w -1.22 N 37 22 E -1.19 N 54 46 E 14.81 N 74 58 E 203.47 N 88 54 E 719.28 S 87 47 E 1288.56 N 89 2 E 1827.99 N 87 39 E 2130.10 0.00 0.21 0.21 1.83 3.31 1.96 0.24 0.35 0.00 0.00 N 0.00 E 0.00 N 0 0 E 6.66 N 1.60 W 6.85 N 13 29 W 5.28 N 1.49 W 5.49 N 15 43 W 42.61 N 12.44 E 44.39 N 16 16 E 101.83 N 198.06 E 222.71 N 62 47 E 110.72 N 714.19 E 722.72 N 81 11 98.86 N 1285.04 E 1288.84 N 85 36 L 90.38 N 1825.80 E 1828.04 N 87 9 E 100.40 N 2127.82 E 2130.19 N 87 17 E ARCO ALASKA, INC. 3K-gA KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -69.00 69.00 69.00 0.00 169-01 169.00 100.00 269.01 269.00 200.00 369.01 369.00 300,00 469o0Z 469.00 400.00 569.02 569.00 500°00 669.03 669.00 600.00 769.03 769.00 700°00 869.03 869.00 800°00 969.03 969.00 900.00 1069.03 1069.00 1000.00 1169.04 1169.00 1100.00 1269.04 1269.00 1200.00 1369.04 1369.00 1300.00 1469.04 1469.00 1400.00 1569.04 1569.00 1500.00 1669.04 1669.00 1600.00 1769.04 1769.00 1700.00 1869.04 1869.00 1800.00 1969.05 1969.00 1900.00 2069.06 2069.00 2000.00 2169.08 2169.00 2100.00 2269.11 2269.00 2200.00 2369.17 2369.00 2300.00 2469.26 2469.00 2400.00 2569.37 2569.00 2500.00 2669.49 2669.00 2600.00 2769.61 2769.00 2700.00 2869.72 2869.00 2800.00 2969.92 2969.00 2900.00 3070.36 3069.00 3000.00 3171.41 3169.00 3100.00 3273.11 3269.00 3200.00 3375.02 3369.00 3300.00 3477.02 3469.00 3400.00 3579.01 3569.00 3500.00 3681.19 3669.00 3600.00 3783.64 3769.00 3700.00 3886.33 3869.00 3800.00 COURSE DEVIATION. AZIMUTH DEG MIN DEG MIN 0 0 N 0 0 E 0 32 N 6 50 E 0 30 N 20 45 W 0'28 N 3 47 E 0 34 N 2 35 E 039 N 0 25 W 033 N 7 13 W 0 27 N 21 9 W 0 15 N 39 31 W 0 13 N 64 22 W 0 20 N 89 39 W 0 24 S 66 13 W 0 21 S 47 58 W, 0 8 S 55 0 W 0 9 S 45 13 W 0 11 S 0 43 E 0 16 S 8 53 E 0 17 S 27 53 E 0 10 S 46 55 E 0 22 N 57 0 E 0 50 N 39 54 E 0 56 N 36 49 E 1 16 N 31 28 E 1 37 N 21 30 E 2 14 N 17 51 E 2 34 N 13 52 E 2 46 N 11 44 E 2 52 N 12 0 E 2 46 N 7 35 E 2 51 N 15 17 E 4 18 N 49 19 E 6 42 N 62 13 E 9 39 N 71 39 E 10 52 N 72 57 E 11 19 N 73 9 E 11 17 N 73 6 E 11 34 N 73 0 E 12 11 N 72 59 E 12 51 N 73 20 E 13 34 N 73 31E DATE DF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COOR SECTION SEVERITY NORTH/SOUTH EAST FEET DEG/IO0 FEET FEE 69.00 FT 0.00 0.00 0.00 N O. 0.03 0.34 0.16 N O. 0.01 0.21 1.09 N O. -0.09 0.13 1.81 N O. 0.00 0.09 2.75 N O. 0.10 0,19 3.79 N O. 0.14 0.10 4.84 N O. 0.00 0.21 5.73 N O. -0.26 0.06 6.21 N O. -0.57 0.28 6.54 N O. DINATES HORIZ. DEPARTURE /WEST DIST. AZIMUTH T FEET DEG MIN -1.02 0.31 6.68 N 1. -1.70 0.22 6.51 N 2. -2.26 0.38 6.15 N 2. -2.58 0.18 5.85 N 2. -2.81 0,32 5.76 N 3. -2.95 0.16 5.45 N 3. -2.96 0.28 5.00 N 3. -2.84 0.27 4,51 N 3. -2.60 0,16 4.12 N 2. -2.26 0.61 4.14 N 2. O0 E 0.00 02 E O. 17 05 W 1.09 19 W 1.82 15 W 2.75 11 W 3.79 14 W 4.84 32 W 5.74 61 W 6.24 93 W 6.61 -1.51 0.37 4.91 N -0.48 0,38 6.18 N 0.68 0,78 7,68 N 1.86 0.10 10.00 N 3.13 0,65 13.08 N 4.52 0.26 17.21 N 5.79 0.60 21.76 N 7.07 0.11 26.62 N 8.17 0.16 31.44 N 9.10 2.26 36.23 N 40 W 6.82 06 W 6.83 61 W 6.68 91 W 6.53 14 W 6.56 27 W 6.35 24 W 5.96 10 W 5,47 84 W 5.01 49 W 4.83 12.85 2.49 41.18 N 20.89 3.42 46.28 N 34.56 2.60 51.59 N 52.53 0.45 57.16 N 71.61 0.45 62.87 N 91.12 0.35 68.67 N 110.60 0.60 74.53 N 130.99 0.82 80.67 N 152.65 0.54 87.10 N 175.39 1,13 93.75 N 1.79 W 5.23 0.83 W 6.23 0.25 E 7.69 1,30 E 10.09 2,40 E 13.30 3.56 E 17.58 4.58 E 22.23 5.59 E 27.20 6.42 E 32.08 7.07 E 36.91 55 E 42.51 32 E 49.77 71 E 60.56 40 E 75.54 19 E 92.75 40 E 111.16 59 E 130.06 66 E 150,17 O0 E 171.73 39 E 194.48 10. 18. 31. 49. 68. 87. 106. 126. 148. 170. N 0 0 E N 6 47 E N 2 40 W N 6 7 W N 3 9 W N 1 40 W N I 36 W N 3 14 W N 5 37 W N 8 7 N N 11 49 W N 17 35 W N 22 56 W N 26 27 W N 28 34 W N 30 56 W N 32 57 W N 34 28 W N 34 31 W N 31 4 W N 20 1 W N 7 38 W N 1 50 E N 7 24 E N 10 23 E N 11 41 E N 11 53 E N 11 51 E N 11 32 E N 11 3 E N 14 22 E N 21 35 E N 31 34 E N 40 50 E N 47 19 E N 51 50 E N 55 2 E N 57 30 E N 59 31 E N 61 10 E ARCO ALASKA, INC. 3K-gA KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 9-DEC-86 P~GE DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 69.~0 FT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 3989.68 3969.00 3900.00 16 3 4094.81 4069.00 4000.00 19 55 4202.63 4169.00 4100.00 23 55 4313.93 4269.00 4200.00 28 19 4430.44 4369.00 4300.00 33 25 4553.50 4469.00 4400.00 36 56 4678.97 4569.00 4500.00 37 8 4804.13 4669.00 4600.00 36 45 4928.67 4769.00 4700.00 36 22 5051.83 4869.00 4800.00 35 0 N 74 39 E N 79 51E N 86 26 E N 89 18 E S 88 52 E S 88 44 E S 89 9 E S 89 44 E N 89 44 E N 87 54 E 200.72 3.29 232.58 4.58 272.71 3.99 321.50 4.18 381.08 4.34 452.54 0.89 528.11 0.41 603.21 0.55 677.33 0.70 749.14 0.96 101.07 N 195.36 E 219.95 N 62 38 E 108.~,0 N 226.85 E 251.42 N 64 27 E 112.89 N 266.80 E 289.70 N 67 3 E 114.55 N 315.57 E 335.71 N 70 2 E 114.15 N 375.27 E 392.24 N 73 4 E 112.49 N 446.93 E 460.87 N 75 52 E 111.03 N 522.70 E 534.37 N 78 0 E 110.33 N 597.96 E 608.05 N 79 32 E 110.33 N 672.20 E 681.19 N 80 40 E 111.58 N 744.05 E 752.37 N 81 28 E 5173.92 4969.00 4900.00 35 5 5296.17 5069.00 5000.00 34 50 5418.19 5169.00 5100.00 35 13 5540.69 5269.00 5200.00 35 7 5662.68 5369.00 5300.00 34 46 5784.20 5469.00 5400.00 34 28 5905.40 5569.00 5500.00 34 17 6026.31 5669.00 5600.00 34 6 6146.89 5769.00 5700.00 33 56 6267.27 5869.00 5800.00 33 43 N 87 32 E 819.19 N 88 38 E 889.50 S 86 8 E 959.13 S 86 47 E 1029.38 S 87 5 E 1098.83 $ 87 23 E 1167.50 S 87 34 E 1235.64 S 87 53 E 1303.28 S 88 17 E 1370.40 S 88 23 E 1437.18 0.37 1.95 1.17 0.28 0.24 0.15 0.41 0.50 0.32 0.43 114.43 N 814.06 E 822.06 N 81 59 E 117.41 N 884.30 E 892.06 N 82 26 E 115.57 N 954.15 E 961.13 N 83 5 E 111.07 N 1024.76 E 1030.76 N 83 48 E 107.35 N 1094.53 E 1099.78 N 84 23 E 104.04 N 1163.50 E 1168.14 N 84 53 E 101.01 N 1231.91 E 1236.05 N 35 18 E 98.30 N 1299.81 E. 1303.52 N 85 40 E 96.04 N 1367.17 E 1370.54 N 85 58 E 94.16 N 1434.15 E 1437.24 N 86 14 E 6387.26 5969.00 5900.00 33 15 6506.46 6069.00 6000.00 32 40 6625.00 6169.00 6100.00 32 11 6742.93 6269.00 6200.00 31 53 6860.48 6369.00 6300.00 31 33 6977.63 6469.00 6400.00 31 9 7094.55 6569.00 6500.00 31 13 7211.53 6669.00 6600.00 31 23 7328.84 6769.00 6700.00 31 33 7445.09 6869.00 6800.00 31 28 7563.34 6969.00 6900.00 31 28 7580.00 6983.21 6914.21 31 28 S 88 29 E 1503.26 S 88 55 E 1567.93 S 89 11 E 1631.40 S 89 52 E 1693.79 N 89 37 E 1755.50 N 89 5 E 18.16.45 N 88 43 E 1876.99 N 88 14 E 1937.67 N 87 45 E 1998.98 N 87 39 E 2060.20 N 87 39 E 2121.40 N 87 39 E 2130.10 0.65 0.47 0.68 0.49 0.51 0.36 0.41 0.38 0.29 0.00 0.00 0.00 92.32 N 1500.45 E 1503.28 N B6 28 E 90.89 N 1565.29 E 1567.93 N 86 40 E 89.85 N 1628.92 E 1631.40 N 86 50 E 89.33 N 1691.44 E 1693.80 N 86 58 E 89.46 N 1753.25 E 1755.53 N 87 4 E 90.19 N 1814.24 E 1816.48 N 87 9 E 91.30 N 1874.82 E 1877.04 N 87 12 E 92.88 N 1935.50 E 1937.73 N 87 15 E 95.04 N 1996.79 E 1999.05 N 87 16 E 97.54 N 2057.97 E 2060.28 N 87 17 E 100.04 N 2119.13 E 2121.49 N 87 17 E 100.40 N 2127.82 E 2130.19 N 87 17 E ARCU ALASKA, INC. 3K-gA KUPARUK NORTH SLOPE,ALASKA TOP BASE TOP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A INTERPOLATE[) VALUES FOR MEASURED DEPTH BELOW KB 7108.00 7146.00 7260.00 7401.00 7472.00 7580.00 CftOSEN HORZZONS ORZGIN= TVD FROM KB 6580-51 6613.01 6710.35 6830.53 6891.10 6983.21 DATE OF SURVEY: 15 NOV B6 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.00 FT 1234' FSL, SUB-SEA 6511.51 6544.01 6641.35 6761.53 6822.10 6914.21 317" SURFACE L.OC AT FWL, SEC 35, T1 RECTANGULAR CO NORTH/SOUTH ATION 3N, RgE, ORDINATES EAST/WEST UM 91.47 N 91.93 N 93.71 N 96.57 N 98.09 N 100.40 N 1881.78 E 1901.46 E 1960.78 E 2034.47 E 2071.48 E 2127.82 E ARCO ALASKA, INC. 3K-9A KUPARUK NORTH SLOPE,ALASKA MARKER TOP BASE TOP BASE PBTD TO KUPARUK C KUPARUK C KUPARUK A KUPARUK A FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH STRATIGRAPHIC MEASURED DEPTH BELOW KB 7108.00 7146.00 7260.00 7401.00 7472,00 '1580.00 SUMMARY ORIGIN= TVD FROM KB 6580.51 6613o01 6710.35 6830.53 6891,10 6983.21 DATE OF SURVEY: I5 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.00 .FT 1234' FSL, SUB-SEA 6511.51 6544.01, 6641.35 6761.53 6822.10 6914.21 317" SURFACE LOCATION AT FWL, SEC 35t T13N, RgE9 UM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 91.47 N 1881.78 E 91.93 N 1901.~6 E 93o71 N 1960.78 E 96°57 N 203~.4T E 98.09 N 2071.~8 E 00.40 N 2127.82 E HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7580.00 6983.21 6914.21 2130.19 N 87 17 E SCHLUMBERGER D l RECT TONAL SURVEY COMPANY ARCO ALASKA INC. WELL 3K-gA F ~ ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED IS - NOV - 88 R£F£R£NC5 72!04 WL,LL,: (123/4'FSL,317'FWL, 'C. 35,T13N,RgE,UM) HO. Z)NT~ FROJF_L~ION NORTH 2000 1000 soo -2000 -!OOO REF 72104 SCALE = 1/SO0 IN/FT ' ' . I - . ~ : : - : ~ . ' . ] ' : . j . ·. - ' ~ - . ~ I , , ' '!-f-?'r--!-'-r~-~-'rq-.t'-f'ff-~-FT-~"T~-l-'-T ..... ~ .... T'* I'''~ ............. (- ............... , 't ............... ~ .......... !' .............. ; ................... ! ..........t ........ ,t ........... , ............ · "!"m'm"t"'"'".*-"~'"?"'!' ..... T'-T"."="'! .................. ? t ....... ?'-t'"T"r-:'"r'"~-r'': .......*'' ~ .... ;'' '? ......... *, .........* ............... 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I - - - : · ~ ~ ; ~ ........ -4 ~ : : ........ 7TM ........ ~-~- ................ ~ ...... ~ ....... ~ ....................... t ........................ t ............. ] -!i,.!!i!!-il;~_+~;.'i~-:.i~!.;~ ...... . ..... ' .......... ? ........ ~-", .... r ............ : ...... ~ ~:-i-~ t'~"i' '!''~i'~' [ ....... i ..... :--! ........ - ................ ..L_ ...... i ....... ':::':~:~:'i':i~':":':"'!::'': -SO0 0 ~00 1022 1530 2000 2500 3000 EAST ' (1234 FSL,317'I , SEC.35,T13N,R9E,UM) VERTICAL PROJEDI'ION -SO0 0 0 500 !000 1500 2000 2500 3000 86. : ~'~-"~-";--+-i-~--.~---;--~ ..... ~-.-;--,--:--i .... ~ ; J'. , , ~ ............ . , ;;:: ~ ~:;; ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::..i. :: ,:..~::: :.....:. ~ :..:..::.,.:. i ARCO Alaska, Inc. Post Office IB~.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 19, 1987 Transmittal #5889 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. · ppen Hole Finals: 3K-10 Cyberlook 10-28-86 '6650-7150 5" FDC Raw & 2" FDC Raw 10-28-86 .6600-7146 5" FDC Porosity & 2" FDC Porosity 10-28-86 " DIL & 2" DIL 10-28-86 3830-7172 3K-9A2" & 5" FDC Porosity 10-19-86 6800-7495 2" & 5" FDC Raw 10-19-86 6800-7495 ~...,,~'~' 2" & 5" DIL 10-19-86 1000-7521 ~~,~Cyberlook 10-19-86 6800-7450 3K-9 Formation Micro Scanner 10-16-86 3175-7407 2" & 5" FDC Porosity 10-15-86 3175-7399 2" & 5" FDC Raw 10-15-86 3175-7399 2" & 5" DIL 10-15-86 3175-7425 5" High Resolution Passes 10-15-86 3300-7368 yberlook 10-15-86 3175-7399 2" & 5" BHCS 10-15-86 3175-7394 6600-7146 R~ceipt Acknowledged: ~~~~Date: /~--~ ~~~ DISTRIBUTION'~~.~.~ ~--- NSK ~ng' Rathmell D & M ~,~i.~~~t~ ---~ ..... ~ ' ~' 'p) L. Johnston (vendor package) Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AllanticRIchlieldCompany STATE OF ALASKA ALASKA .L AND GAS CONSERVATION COMMIS,,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown :--i Stimulate ~ Plugging Alter Casing ~ Other ~ C(:NPLETE 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 99510 1234' FSL, 317' FWL, Sec.35, T13N, RgE, LIq At top of productive interval 1325' FSL, 2199' FWL, Sec.35, T13N, R9E, LN At effective depth 1332' FSL, 2388' FWL, Sec.35, T13N, RgE, ~ At total depth ].3..34' FSL, 2445' FWL, Sec.35, T13N, RgE, LlVl 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Cas~n2nductor Length 80' Surface 3135' Production 7524' Perforation depth: measured None Perforate - Pull tubing - true vertical None Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7128' 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit 7. Well number ~-qA 8. Approval number 585 9. APl number 50-- 029-21656-01 10. Pool Kuparuk River Oi 1 Pool 7580'MD 6983'TVD 7472'MD 6891'TVD feet feet feet feet Plugs (measured) None Junk (measured) None Size 10-3/4" 7" Cemented Measured depth 1540~ Pol eset 1lO'MD 1400 sx AS IV & 3172'MD 125 sx Class G 910 sx Class G & 7559'MD 175 sx AS I Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7102' & TRDP-1A-SSA SSSV @ 1795' 12. Stimulation or cement squeeze summary i. N/A nmrva~s treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 14. Attachments (Ccmpletion Well History w/AddendLml, dated 11/19/86) Daily Report of Well Operations ~,. Copies of Logs and Surveys Run ~X 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~~~ Title Associate Enqineer Form 10-404 Rev. 12-1-85 ~/ (DAM) SW0/137 Feet True Vertical depth llO'TVD 3169'TVD 6965 'TVD Tubing Pressure Submit in Duplicate Date Gyro ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the ¢irst Wedr~esday after a~owabie has been assigned or well is Plugged, Acandoned, or Sold. "Final Report" should be submitted also when operatior~s are suscer~ed for an indefinite or appreciable !eng-'.h of time. On '.vorkovers when an official test is nol required upon completion, report completion and representative ~est data m b!ocks provided The "Final Report" form may be used for reporting the entire operation if space is availaoie. Accounting cost center code Alaska District North Slope Borough State Alaska County or Parish Field Lease or Unit Well no. Kuparuk River ADL 25519 3K-9A Auth. or W.O. no. T t e AFE AKi410 Completion Nordic 1 AP1 50-029-21656 Operator ARCO Alaska, Inc. Spudded or W.O. be9un Complete A.R.Co. W.I. 56.24% Date 12/2/86 I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1000 hrs. Date and depth as of 8:00 a.m. 12/03/86 Complete record for each day reported 7" @ 7559' PBTD TT @ 7128', FC @ 7472', RR 6.8 ppg diesel Accept ri~ @ 1000 hrs, 12/2/86. ND tree, NU & tst BOPE. RU & rn 219 jts, 2-7/8", 6.5# J-55 EUE, 8RD AB-Mod tbg w/SSSV @ 1795', HRP-1-SP pkr @ 7102', TT @ 7128'. Tst tbg & ann to 2500 psi' OK. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 0545 hfs, 12/3/86. Old TD New TD Released rig Date 0545 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing J PB Depth 12/3/86 IKind of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7472' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time .Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 10/22/86 11/14/86 3K-9A Arctic Pak w/175 sx AS I, followed by 90 bbls Arctic Pak. Tst OK. Rn CBL/GR/CCL f/7460' - 5408'. Rn GCT gyro f/surf - 7420'. Make GR/JB rn to PBTD, RD Schl. · Drilling ~Super~i~or ' Da~:e STATE OF ALASKA ALASK, . ,.)IL AND GAS CONSERVATION COMMi,.,61ON APPLICA'I"ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~- Time extension ~ Change approved program ~ Plugging ~ Stimulate .~ Pull tubing ~- Amend order ~ Perforate- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0 · Box 100360 Anchorage, AK 9951 0-0360 4. Location 1234 At top of 1320' FSL, 2348' FWL, Sec.35, At effective depth 1296' FSL, 2383' FWL, Sec.35, At total depth 1298' FSL, 2440' FWL, Sec.35, of well at surface ' FSL, 317' FWL, Sec.35, T13N, R9E, UM productive interval T13N, R9E, UM T13N, R9E, UM T13N, R9E, UM 5. Datum elevation (DF or KB) 69'RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 3K -9A 8. Permit number 86-174 9. APl number 50-- 029-21656-01 10. Pool K~paruk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 3135' 7524' Production 7580'MD 6985'TVD feet feet 7472'MD 6893'TVD feet feet Plugs (measured) None Junk (measured) None Size Cemented Measured depth 16" 1540# Poleset 1lO'MD 10-3/4" 1400 sx AS IV & 3172'MD 125 sx Class G 7" 910 sx Class G & 7559'MD 1 75 sx AS I ~ue Verticaldepth 110'TVD 3170'TVD 6967'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal ~ Detailed operations program ~- BOP sketch -- Well History 13. Estimated date for commencing oPeration November, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ (/~/7~ ,. _,~~t-,,, Title Associate Engineer Commission Use Only ( DAM ) Conditions of approval Notify commission so representative may witness Date SA/142 J Approval No. Plug integrity ~ BOP Test ~ Location clearance '-.-~ .... -~.~. :.~ ~ ... ..~ ;~.~'~: by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 ......... ' .... ~' Submit in triplicate · ARCO Oil and Gas Company Well History - Initial Report- Daily Prepar~ and submit the "lnlUal Rel~rt" on the first Wednesday after a well is spudc~ed or workover operations are started. Daily woril prior to Sl:~Jdding should be summarized on the form giving inclusive dates only. _,- I~o~, parisi~ or borough ,~i:-'~:. North Slope Borough t~''''' °r u"" ADL 25519 / Drill L0/02/86 10/03/86 10/04/86 thru 10/06/86 10/07/86 lo/o8/86 Theabove is correct For f~ ~m~tlon ~d ~l~bution, Pmcedu~ M~u~l, ~ctlon 10, Dfllll~, Pa0e~ ~ and 87. AP1 50-029-21656 ]D~te IHOur 10/1/86 0001 hfs ColT~le~e re~ord for e~ch dey reposed State Alaska Well no. 16" @ 110' 960', (850'), Drlg Vt'.. 9.2+, PV 17, YP 31, PH 8.5, WL 12.4, Sol 6 Accept rit @ 2030 hfs, 9/30/86. NU dtverter sys. 0001 hfs, 10/1/86. Dr1 to 960'. 56.24% ARCO W.I. Prior statue if I W.O. Spud ~11 @ 16" @ 110' 3108', (2148'), DrL~ Wt. 9.4, PV 12, YP 8, PH 8.5, WL 12.8, Sol 8 Drl & surv to 3108'. 472', 0.4°, N45.3E, 472 TVD, 1.23 VS, 1.16N, 1.17g 1483', 0.4°, $27.6W, 1482.96 TVD, -3.41 rS, 2.93N, 3.58W 2493', 2.5°, NIO.6E, 2492.73 TVD, 7.36 VS, 10.78N, 6.76E 10-3/4" @ 3172' 3185', (77'), DO cmt 8.4 ppg (wtr in pits) Drl 13-1/2" hole to 3185', short trip, C&C, POOH. RU & rn 77 its, 10-3/4", 45.5#, K-55 BTC csg w/FC @ 3085', FS @ 3172'. Cmt w/1400 sx AS IV & 125 sx C1 "G" w/2% CaCi~ & .2% D-46. Displ cmt w/wit using rig pmps, bump plug. CIP @ 1850 hfs, 10/2/86. ND diverter, NU & tst BOPE. RIH w/BHA, DO flt equip. 3130', 8.4°, N73.Sg, 3128.22 TVD, 28.94 VS, 39.65N, 26.75E 10-3/4" @ 3172' 3444', (259'), Corin~ Wt. 9.0+, PV 24, YP 6, Sol 8 DO fit equip & cmt + 10' new hole. Conduct formation tst to ~'" '~':':: ~' ' 11.5 ppg EMW. Displ well to EZ Core. Contrl drl 9-7/8" hole to 3365'. RU & cut core #1, 3365'-3388', rec'd 19.3'. Core #2 ." f/3388'-3419', rec'd 24.5'. Core #3,-3419'-3425" rec'd 19'. Core #4, 3425'-3444' service core bbl. MU core #5 , , ,' ....... ~,~-~ 10-3/4" @ 3172' i~' ....... " 3930', (486'), Logging Wt. 9.0+, PV 20, YP 7, Sol 15 Rec'd 18.5' f/core #4. Core #5, 3444'-347~5', rec'd 31'. Core #6, 3475'-3506', rec'd 31'. T~H, drl to 3930', circ hole cln, TOH. RU & log DIL/GR/LSS, LDT/CNL/NGT/CAL 10-3/4" @ 3172' 3930', (0'), Cln pits Wt. 9.0, PV 5, YP 5, PH 10, WL --, Sol 3 Rn LDT/CNL/NGT/CAL w/high resolution rn. Rn VSP. Cln pits, build wtr base mud. TIH, displ hole to wtr base mud. Cln pits. ~,..~/ I Date / ] T~tle , Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim In,tructlona: 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. Repot1 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. Dletrlct Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25519 Complete record for each day while drilling or workover in progres~ 10/09/86 lO/lO/86 10/11/86 thru 10/13/86 10/14/86 10/15/86 10/16/86 Is,ara Alaska lWell no. 3K-9/3K-9A 10-3/4" @ 3172' 5507', (1577'), Drlg Wt. 9.0, PV 8, YP 4, PH 9.8, WL 9.6, Sol 3 POH. RIH w/turbine, drl 8½" hole to 5507'. 3863', 10.90°, N71.9E, 3848.00 TVD, 163.38 VS, 80.87N, 159.09E 4181', 20.40°, N87.5E, 4150.25 TVD, 259.80 VS, 101.99N, 254.48E 4528', 33.40°, S88.6E, 4449.62 TVD, 433.68 VS, 102.70N, 428.62E 10-3/4" @ 3172' 6370', (863'), Drlg Wt. 9.2, PV 5, YP 2, PH 9.1, WL 10.2, Sol 3 Drl & surv 8½" hole to 6370'. 5526', 31.1°, N83.SE, 5270.72 TVD, 999.30 VS, 106.15N, 994.90E 6032', 22.1°, NS1.7E, 5721.10 TV]], 1228.02 VS, 138.43N, 1222.17E 6212', 18.5e, N77.4E, 5889.92 TVD, 1289.97 VS, 149.76N, 1283.58E 10-3/4" @ 3172' 7102', (732'), Coring Wt. 10.0, PV 15, YP 9, PH 9.4, WL 4.4, Sol 10 Drl & surv to 6967'. Core #1, 6967'-7027', rec'd 43'. Core #2, 7027'-7062', rec'd 33'. Core #3, 7062'-7102', rec'd 37'. 6401', 15.5e, N84.4E, 6070.66 TVD, 1344.94 VS, 158.60N, 1338.14E 6935', 12.5°, S82.7E, 6588.47 TVD, 1474.78 VS, 159.62N, 1468.12E 10-3/4" @ 3172' 7199', (9'), RIH Wt. 10.0, PV 13, YP 8, PH 9.0, WL 5.0, Sol 10 Core #4 f/7102'-7139', rec'd 37'. Core #5 f/7139'-7199' , POH. 10-3/4" @ 3172' 7443', (244'), Short trip Wt. 10.1, PV 17, YP 11, PH --, WL 4.2, Sol 11 Rec'd core #5. RIH to 7199', well flowing, SI &circ out gas cut mud. Core #6, 7199'-7243', rec'd 44'. RIH, drl ,, ..~ f/72~3~-__, 15 std short trip. 10-3/4" @ 3172' 7443', (0'), TIH Wt. 10.1, PV 17, YP 9, PH 9.5, WL 4.0, Sol 11 Short trip, spot diesel on btm, TOH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL w/hi resolution pass. Rn B~Cs & FMS~~ RD Schl. TIH. 7443', 11°, 881.75E, 7085.83 TVD, 1576.33 VS, 145.63N, 1570.62E The above is correct see Procedures Manuel Section 10, Drilling, Pages 86 anti 87 Date / / IT~tle Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructiona: 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 linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth aa of 8:00 a.m. I County or Parish A!~aska North Slope Borough I Lease or Unit Kuparuk River ADL 25519 Complete record for each day while drilling or workover in progress 10/17/86 lO/18/86 thru 10/20/86 10/21/86 IState 10-3/4" @ 3172' 7443', (0'), TIH Wt. 10.1+, PV 17, YP 6, PH 9.5, WL 4.4, Sol 12 . RIH, circ & spot diesel pill, POOH, LD DP. Change of orders. TIH to 7227', spot 500' plug across Kuparuk, f/6730'-7227' (approx) w/175 sx Class G circ, POOH to 5000' & spot 300' plug f/KOP f/5060'-5300' (approx) w/150 sx Class G. Circ out cmt, POOH 92 its, PU BHA. Alaska 10-3/4" @ 3172' 7527', (189'), Prep to rn OHL Wt. 10.4, PV 14, YP 7, PH 9.0, WL 4.4, Sol 14 WOC. 3K-9 Abandoned 10/17/86. 3K-9A commenced 1600 hfs, 10/17/86. TIH, wsh & drl to 5338'. Sidetrack hole to 7527' TD, short trip, C&C, well flowing, SI well. Circ gas cut mud, inc mud wt to 10.2 ppg, short trip, CBU. Inc mud wt to 10.4 ppg, TOH. RU Schl to rn OHL. 5062', 34.8°, S88.7E, 4881.36 TVD, 746.94 VS, 94.70N, 742.79E 6449', 33.1°, N89.4E, 6026.15 TVD, 1525.70 VS, 49.76N, 1524.13E 7527', 31.7°, N87.5E, 6940.25 TVD, 2096.91VS, 63.08N, 2095.30E 10-3/4" @ 3172' 7580', (53'), Rn'g 7" csg Wt. 10.4, PV 17, YP 6, PH 8.5, WL 4.2, Sol 14 Rn DIL/SFL/SP/CAL f/7527'-3172'. Ran GR from 7527 to 1000'. Rn FDC/CNL f/7527'-6800', RD Schl. Drl rathole to 7580', CBU, spot diesel pill, POOH, LD DP. no, 3K-9/3K-9A The above is correct For form preparation and distribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 Date Title Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and sut)mit the "Final Report" on the first Wednesday after allowable has been assigned or weJl is Plugged, Abandoned, or Sold. "Filial Rel)erl" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data. in blocks provided. The "Filial Report" form may be used for reporting the entire operation if space is available. District ICounty or Perish I Alaska Field ~Lea.ae or Uni{ I Kuparuk River Autll. or W.O. no. ]Title AFE AK1410 Doyon 9 A.R.Co. W.I. Operator ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded Date and'depth Complete record for each day reported as of 8:00 a.m. North Slope Borough ADL 25519 Drill Old TO Released rig 2030 hrs. tAccounting cost center code stat, Alaska Well no. 3K-9/3K-9A 10/22/86 Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data API 50-029-21656 ~otal number of wells (ective or inective) on this, Icost center prior to plugging and 56 · 24~ laban(:lonment of this well , IHour I PHor status If . W.O. o/1/86 / oool hr,. I 7" @ 7559' 7580' (0') TD, RR 10.4 ppg NaCl/NaBr brine Rn 179 JCs + mkr jr, 7", 26#, J-55 BTC cs$ w/FC @ 7472', FS @ 7559' Cmt w/650 sx 50/50 Pozz & 260 sx C1 "G". Displ w/lO.4 ppg N~C1/NaBr, bump plug. ND BOPE, Instl & tst pack-off. RR @ 2030 hfs, 10/21/86. 7580' TD Depth I Kind of rig 10/21/86 Rotary Type completion (single. dual, etc.) Single Official reservoir name(s) Kuparuk Sands New TO Date Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ! For form ~reparation and distribution, ~ Pmceduree Men-al, 8~otion Ddll~n~, Peges $~ end 8'/'. Date [Title Drilling Supervisor ARCO Alaska, Inc. Post Office Bc 90360 Anchorage, Ah_ ~a 99510-0360 Telephone 907 276 1215 October 3i, 1986 RETURN TO' ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5804 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tape with Listing ~-~ 3K-gA 10-19-86 996' - 7542.5g~-~3 ~3K-9 10-15-86 995' - 7438 Receipt Acknowledged- Distribution. ~ A~as~ Oil & Commission Gas Cons. , Anchotra9e D. Wethere'~ ARCO October 17, 1986 Mr. J. B. Kewin Regional Drilling Engineer ~RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy-. (907) 276-7542 Re: Kuparuk River Unit 3K-9A ARCO Alaska, Inc. Pemit ~o. 86-174 Sur. Loc. 1234'FSL, 317'FWL, Sec.35, T13N, R9E, UM. Btmhole Loc. !3!9'FSL, 2494'F~'~, Sec. 35, T13N, RgE, U~.4.. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to 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 ~urface casing shoe is drilled. ~nere 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. V~r~y~ tru~:~urs,~-- "'~ ~ ~ ~' V: Cha:ter~n Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF NE CO~.~,~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviro.n3.~enta! Conservation w/o encl. Mr Doug L. T .~e~v STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C~..,¢IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~. Redrill ~,1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry ~ DeepenL%I Service ~ Developement Gas ~ Single Zone ,~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25519 ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025} 1234'FSL, 317'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1320'FSL, 2348'FWL, Sec.35, T13N, R9E, UH 3K-9A #8088-26-27 At total depth 9. Approximate spud date Amount 1319'FSL, 2494'FWL, Sec.35, T13N, R9E, UM 10/16/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth IMO and TVD) property line 7568 ' MD 317' @ surface feet 3K-8 25'¢ surface feet 2560 f6935'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth2932 feet Maximum hole angle 30 o Maximum surface 2300 psigAt fetal depth 0'VD) 3470 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) !3-~" 10-3/~''' a. 5.0# ~-~ BTC 3!37' 35' 35' 3!72' 3!70' !a. O0 sx AS HF-FEW 125 SX ¢'1~$ ¢, hl,~nd 8-1/2" 7" 26.0# J-55 BTC 7534' 34' 34' 7568' 6935' ~'0 sx Class GfMin.~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. '~,~~p Ku-p) Present well condition summary Total depth' measured feet Plugs (measured) v~/~O ~ true vertical feet f2ir~ A/° ~.~.//.~4¢. ~.//'../f'- Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ..... ~; -' .,'~ Intermediate Production [ii_., i -- Liner .... ' Perforation depth' measured Al~tsk& 0il & OF,~ Or;ns. true vertical 20. Attachments Filing fee ,~ Property plat I~ BOP Sketch~ DiverterSketch~ Drillingprogram/~:, Drilling fluid program ~Timevs depth plot ..~ Refraction analysis ~ Seabed report C 20AAC25.050 requirements 21. I hereby cer/ti,f~ that the forego,~ng is true and correct to the best of my knowledge // ~ ~ '' ' ; · Signed/' ~.~,~-~/~'///~.~,~¢.6Z/~A'~ Title Reg,onal Drilling Engineer Date~¢,¢~'~ ~//' "' ~/" ~' ,,//-~ " Commission Use Only ( HRE ) PD/01 3 / Permit Number ~C~/?,.f APInumber IApprovaldate [ See cover letter 50- o ~, - ~/~-~% -o/ 10/17/86 for other requirements Conditions of approval Samples required D Yes ~No Mud Icg required [] Yes ~No Hydrogen sulfide measures ii' Yes [] No Directior~al survey required ~ Yes ~ No rkin ure r ,'~ M; ; [] 5M; [] 10M; ',-q, 1'5M Requiredwo ~~~~ ~ Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Subr :riplicate 0 leo ~CAL£ 2O33 21 T9 TARGET ~ , C~ 'A re, r,~ 3. 3s-'~' i': ' ~i~ i:: i_~ ~..~ :~ rio ~ 7568. 35'1' I I 000 0 V.SECTTON PLANE~ N87'35'E SURVEY tS0~365.2AR PROPOS,M. ~ P00231 · 3AR SCALE 1 ' ~ I O00FT. , I I I I I I I ..... ? ..... ....... '-:-~' .... i- .......... \ : . : 'i · ? ..... 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' I---~'-"~ ' ':'- :--~-:: .... ._~-.,.~,~,_~._~_:_, _,:.,._.,-~~:--_-_-. *~l'~_/l.: .... ~_- :. .. ___? ......... ~ ...... ,_~ ........ ! :~.~-~-~--:~/:$~.~- .................. ~-,_._ ,, .... __.:ti :-- m -~'- ~. .... ~ .......... ~ ........ . -' ~ , '-~ ~~-~ . ~--': '' ........ ~?..-:~--> ........ ........ ---~' ._ . 1~:-~ ~~ .- ~ :__.. ' ......... ~'o~ ..... ~ ........ ~ ........ : - :__ ~. '~_1000__--_~ ?--- ': ---:-~' :--'-- -'~ ' ' ...... "'~ - ....... L,: ~__ ._~:~~~_ . ....... ~ ..... ... _ ~:. ......, ..... ~ ~ ; ..... I~~ ~ ...... ,. ..... I :::::- ;~ ........... I ..... -::_ _:::-~: ..... :- .~ ........... , ...... I i ..... : ": - - . _ ....: ......... ,.- ..... E~. ................. ~ ~]~* ....... ~:.:_ I ....... - ~__ :. , I ' '- ' ~ " " .... OOC ~ . . ~ [ ..... - · --. :_ ?~2~ I . · __ - .... '__-22.~L:~_: .... -Z :'_ .................... L' ....... .. . .....~...,~:.. ¢ .... ~ ~ ~ ................ ~ __. ~00_ .... .......~j --~ .~ c.~ ~,'~.; t '- / ~-~,,~: r ,,-,'- i~ .- · :- / I .-.:. - : Od b. ~"'~: "' ' ...... ' ..... _800_ ---r ................... - ............................. ~- r ..... / I / I ..... r-_ ..... ~s~ - ~- ........... ~ ....... ~'- zo~ ...... l / ~ sos. ~ .[ ........ 7o0 0 1 O0 200 300 400- 500 600 w- KUPARUK R I VER UN I T 20" D I VERTER $CHEMRT I C DESCRIPTION · 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/IO" OUTLETS. 7. 10" HCR 8ALL VALVES DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNiA. AR PREVENTER. 6 7 ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 035 (b) 4 3' 2 MAI NTENANCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNN I ND D I VERS I ON, ' '~ ~m ~.-,pJt,"~ DO NOT SHUT IN NELL .~., { ~,...>?i. :"' '" ' :-; ',_. .~ ~....-:,. ~,?-~. UNOER ANY C I RCUMSTANCE S. · ~ ~c.t ',' ~ %'.? 6 DIAGRAM #1 t~-5/8" 5000 PSI RSRRA BOP STACK I. 16' - 2000 PSI TA, N~ STARTING HEAD 2. !1' - 3000 PSI CASING HEAD 3. I!' - 3000 PSI X 13--5/8' - 5000 PSI SPACER SPCCL 4. 13-5/8" - 5000 PSI PIPE EAMS 5. 13-5/8' - 5000 PSI DRILLING SPOOL W/CHOKE A, hD KILL LIhE. S 6. 13-5/8' - 5000 PSI DOUBLE RAM W/PIPE ~ ON TOP, BLINO ~ ~ BOl'l'(]~4. 7. 13-5/8' - 50(30 PSI A~ ACCLMJLATOR C~pAC)TY TEST I. CHECK AbD FILL A~TDR RESERVOIR TO PRCFER LEVEL WITH HYDRALLIC FLUID. 2. ~ THAT ACCUVI,~ATDR PRES,.~ IS 3000 PSI WITH 1500 PSI ~TRE~4 OF THE REGULATC~. 3. OBSERVE TINE, THEN CLOSE ALL UNITS SIMULTAt~OUSLY A~D RECCRD THE TINE ~ PR~ RIDa~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUV~ OFF. 4. RE~ ON NADC REPORT, THE ACCEPT~ LO~ER LIMIT IS 45 SE~ CLOSING TINE A~D 12DO PSI RBV~INING PRESS1JI~. 5 4 2 13-5/8" BOP STACK TEST. I. FILL BCP STACK AI~ Q-i(](E MANIFClD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LO(]( D(3~ ~ IN Wlg_LFEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN Y~ELLI~ WITH RUNqlNG JT ~ RUN IN LCX]<I:X]f~ SC~-WS. 3. CLOSE ANqLJLAR PR~ AhD MANUAL KILL A~D LIhE VALVES ADJACENT TO BOP STACK, ALL OTHER VALVES AN) CHCKES SHOULD BE OPEN. 4. PRE~ UP TO 250 PSI ~ HOLD FDR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI ~ HCLD FDR i0 MIN. BLEED PRE~ TO 0 PSI. 5. OPEN ~ PREVENTER AAD MAhlJAL KILL AAD CHCKE LIhE VALVES. CLOSE TOP PIPE ~ AAD HCR VALVES ON KILL AhD CHCKE LIAES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. T. CONTINUE TESTING ALL VALVES, LIAES,, AAD CHOKES WITH A 250 PSI LOW AhD 3000 PSI HIGH. TEST AS IN STEP 4. BO NOT PRE~ TEST ANY ~ THAT IS NOT A FULL CLOSING POSITIVE SEAL o OALY FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS A, hD CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK CUT RUht~ING JT PULL OUT OF HOLE. I0. CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD 3000 PSI. I!. OPEN BLIN) RAMS mN) RETRIEVE TEST PLUG. MAKE SURE L , MANIFOLD A~D LI~ES ARE FULL OF' NON-FREEZI~NG I FLUID. SET ALL VALVES IN DRILLING POSITI._~N. _.__ [ 12. TEST STAhDPIPE VALVES, KELLY, KELLY ! PIPE SAFETY VALVE, A~D INSICE BOP TO 250 , 3000 PSI. T ~ ~.,". '.~ 13. RECCRD TEST INfOrMATION ON BLCWOUT PR_E~.._Et~r___ER TES I I ~ :,."~, ~" FORM, SION, ~ SEN) TO DRILLING SUPERV_I~_o~...- AN) I~ ] -. ~, ~'~.'~"~ ' 14. PERF(]~M (X]v~LETE BOPE TEST AFTER NIP_P~_I_~__u_P ...... '~ '~...--~'-'< ~'.',~.'::-~ ' ~,c~i~ WEEKLY THEREAFTER FUI~IONALLY OPERATE BUl-'t. U~iL¥. )84001 REV. 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 / Weight 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 pH 9-10 / % Solids 10± / Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser 9.5-10.5 4-7 - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators 9.5-10.5 9-12 Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. 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. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install TankCo diverter system. 3. Drill 13½" hole to 10-3/4" surface casing point according to directional plan. Run and cement 10-3/4" casing· [ Install and test blow out preventer.~' Test3'~°° ~ casing to 2000 psig. 6. Drill out cement and 10' new holeco~e Perform leakoff teSt.Sak poi . Cor erval with oil base core fluid. · After coring, convert oil base mud to water base, drill 8½" hole according to directional plan to Kuparuk core point. Core Kuparuk interval with water base core fluid. Drill sufficient rathole to provide 100' between plug back total depth and bottom of Kuparuk sands. Run open hole logs. 9. Run and cement 7" casing. Pressure test to 3500 psig. 10. Downsqueeze Arctic Pack and cement in 7" x 10-3/4" annulus. 11. Nipple down blow out preventer and install temporary Xmas tree. 12, Secure well and release rig. 13. Run cased hole logs· 14. Move in workover rig. Nipple up blow out preventer. 15. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 16. Perforate and run completion assembly. 17. Nipple down blow out preventer and install Xmas tree. 18. Change over to diesel and set packer. 19. Flow well' to tanks, Shut in. 20. Secure well and release rig. ~,~,. ~_ 21. Fracture stimulate. --~ DE~A,~ER I ,.-.' SHALE SHAKERS ii,iUD CLEANER .~. STIR .~. .~ STIR _~ STIR CLEANER HRE/11 ih TYPICAL MUD SYSTEM SCHEMATIC C~H~CK LIST FOR NKW W~.I. PERMITS ITEM APPROVE DATE (1) Fee ,z/.~,~.~ ,3 ~,-,. ~ 1. Is (2 thru 8) 3. Is 4. Is 5. Is 6. 7. 8. (8) ' (3) ~ , ~. ,..- /,~ W -~/ 9. .thru 13) . 10. ...., ,, ., ., ~:.,.~ 11. (10 ~d 13) 12. 13. ' (1-4 t~ 22) (5) BOPE ru 28) (6) (7II-~ 2J2~~, ( thru 31) (6) Add: ~: Engineering: rev: 07/1'8/86 6. 011 ., {{t~" '~ ,,,, ~. ' ., ,~ ~ ~ ',, ,.. . the permit fee attached ........................................... well to be located in a defined pool ............................ well located proper distm~ce from property line well located proper distance from other wells ...~i[. sufficient undedicated acreage available in this Iswell to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fffteen-day wait ...................... Lease & Well No. /< /~ ~ ~Y/< - ~/g NO P~~ Does operator have a bond in force .................................. ~ Is a conservation order needed .................. ' Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does thewell have a unique name and number ......................... .~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ............. f., ....... Is enough cement used to circulate on conductor and surface ......... Will ceme~t tie in surface and intermediate or production strings ... Will cement cover all known productivehorizons ..................... 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 adequatewellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate wy<Z Are necessary diagrmns and descriptions of diverter and BOPE attached. Does BOPEhave sufficient pressure rating - Test to ,~Ooo psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphicwells: 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 ............................................. POOL INITIAL CL~'S STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarl~: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE VERIFIC6TION LISTING .VP 010.~02 VERIFICATION LISTING PAGE ~::.- R:=L HEAD=R,_ ....,. ;ERVI"E~ NAME, :=DIT DATE : 56/10/23 ]RIG=N~ .. ~;EL NAME :149576 :ONTZNUATISN ~ :01 ~REVIGUS REEL : ~OMMENTS :LIBRARY TAPE ::'4~ TAPE HEADER :~ ~ERVICE NAME :EDIT )ATE :86/10/23 ]RIGIN :FSlA [APE NAME : :ONTINUATIDN ~ :Oi ~REVZOUS TAPE : :OMMENTS :LIBRARY TAPE "'"' FILE HEADER ..... ',- -,~ :ILE NAME :EDIT ~ERVICE NAME : CERSION # : ]ATE : ~I,~XIMUM LENGTH : FILE TYPE : PREVIOUS FILE : .001 1024 ;.:~,. INFORMATION RECORDS " MNEM CONTENT'S UNIT TYPE CATE SIZE CGDE CN : ARCO ALASKA, INC. 000 000 018 065 WN : 3K-ga 000 000 006 065 FN : KUP~RU'K 000 000 008 0,65 RANG: gE 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: 35 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE PRES: E OOO 000 001 065 ~,--,- COMMENTS ":...,- .VP OlO.H02 VERIFICATION LISTING PAGE 2 : S CHLUMSE RGb.: R " ALASKA COMPUTING CENTER '~: : .......... ~, ;:: ~: ~: ;',: ~',= ;~ -~ .,. ....................................... -,- -,. -,--,- -,- -,- ,~- -,- .~- .~- -,- .,- o,- -,- -,- -,- .,- q- -,- -,- -,- -,- -,- -,. .,..,. .,..,..,..,. -,..,..,..,. S',C ;O~PaNY : ARCO ALASKA INC ~ELL = 3K-OA =IELD = KUP~RUK ;OUNTY = NCRTH SLOPE 5CROUGH iTATE = ~LASKA 7OB NUMEER AT ~CC: 72001 ~UN ~ONE, DATE LOGGED: 19 OCT 86 .DP: T H~LSTE&D ;ASING : 10.'750" @ 3172' - BIT SIZE : $.5" T~ 7527' tYPE FLUID : LSND POLYMER )ENSlTY : 10.4 LB/G RM : 2.850 ~ 55 DF IISCOSITY : 38.0 S RMF = 2.160 @ 66 'DF ~H : 9.0 RMC : 2.390 @ 65 DF :LUID LOSS = 4.4 C3 RM AT BHT = 1.435 ~ 138 DF qATRZX SANDSTONE ~:~:~:~:~ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIEL~ PRINTS ~I:~:: .VP OlO.H02 VERIFICATION LISTING P.&GE 3 ;,: SCHLUMBERGER LeGS INCLUDED WITH THIS MAGNETIC TAPE: -",: ;:= DUAL INDUCTION SPHERICALLY FOCUSED LOG (OIL) '~ ',DATA AVAILABLE: 7521' TD 3172' -" ~-ORM~TIgN DENSITY COMPENSAT:D LOG (~DN) ".,- CCMP~NSATED NEUTRSN LOG (FDN) .-'" "' DATA AV~ILABL:: 7495' 'tO 6800' '-:: -'- GAMMA RAY IN CASING (GR.CNL) "' -,.-'- DATA AVAILABLE: 3172' TB 1000 .... .,. .,. ., .... .,. .,. :',:.,.~.,.-,- ;,,...,. ........... .,. ....,. ;.-. :g :',: :1.- :1: :',: -.~ :,,: ~,-. .-,,: ~,-. :,: .,. q.. .,. DATA FORMAT RE~CRD-,--,- :NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 i 66 0 4 t 66 ~ 8 4 73 60 9 4 65 .liN 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NO. CODE (DCT~L) OEPT FT O0 000 O0 0 0 4 1 68 O0000000000OO0 SFLU DIL OHMM O0 220 O1 0 0 4 1 68 00000000000000 ILD DIL OHMM O0 120 46 0 0 4 ! 68 00000'000000000 ILM OIL 3HMM O0 120 44 0 0 4. I 68 00000000000000 SP DZL MV O0 010 01 0 0 ~ 1 68 00000000000000 GR DIL GAPI O0 310 O1 0 0 4 1 68 00000000000000 .VP OlO.H02 VSRIFICATIDN LISTING PAGE 4 ;R FDN GAPI O0 'ALI FDN IN O0 ~HOB F3N G/C3 O0 )RHO ~DN G/C3 O0 1RAT FDN O0 {NRA FON O0 ~Pml FDN PO O0 )PHI FON PU O0 JCNL FDN CPS O0 =CNL FDN CPS O0 ;R CNL GAPI O0 310 28O 350 355 420 000 89O 890 330 330 310 O1 Ol 02 O1 O1 O0 O0 O0 31 30 O1 -,- DATA-,..,. )EPT 7542,5900 SFLU ~P -138.2500 GR ~HOB 2,5313 DRHO qPHI 33.9355 DPHI 3R -99'9.2500 3EPT 7500.0000 SFLU 5P -151,6250 GR RHOB 2.5215 DRHO ~PHI 33.6914 DPHI ~R -999.2500 DEPT 7400,0000 SFLU SP -150,8750 GR RHOB 2,4316 DRHO NPHI 31,6895 DPHI GR -999,2500 DEPT 7300.0000 SFLU SP -159,8750 GR RHOB 2.4707 DRHO NPHI 31.83,59 OPHI GR -999.2500 DEPT 7200,00:00 SFLU SP -164,5000 GR RHOB 2.4355 DRHO NPHI 30,7129 DPHi GR .-999,2500 DEPT 7100.0000 .SFLU SP -165.2500 GR RHOB 2.5039 DRHO NPHt 37,15:82 O'PHI GR -999,2500 DEPT 7000,0000 SFLU SP -143,2500 GR RHOB 2,4473 DRHO 4.5138 117.6875 0.0356 7.Z062 3.0669 117.6875 0.0269 7.7980 5.5337 85.0625 0,03'71 13.2426 8.0703 85.6250 0.0342 10. 8754, 5.3067 84.6875 0.0264 13.0059 2. 8925 107.3750 0.O454 8.8633 3.7702 111.5625 0.0439 ILO GR NRAT NCNL iLD GR NRAT N C NL ILD GR NRAT NCNL ILD GR NRAT NCNL ILO GR NRAT NCNL ILO GR NRA'T NCNL ILO GR NRAT 3.7571 117.5875 3.0898 1919.0000 2.7003 117.6875 3.0898 1919.0000 3.9179 85.0625 2.8730 1593.0000 6,0494 85,6250 2,8750 2160,0000 5.6371 84.6875 2.8281 2188.0000 2.8038 107.3750 3.2537 2132.0000 1.7247 ti1.5625 3.~082 68 68 58 68 68 68 68 68 68 68 ILM CALZ RNRA FCNL ILM CALl RNRA FCNL. ILM CALl RNRA FCNL ILM CALI RNR~ FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL !LM 'C A L I RNRA O00000OO 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 3.9727 9.6719 3.2129 597.0000 2.8264 9.8516 3.2129 597.0000 3.9560 8.7344 2.7363 5~2.0000 6.3787 8.6563 3.1016 696.0000 5.7299 8,9766 2.9531 740.5000 2.8888 9.6484 3.3281 640.5000 1.9407 9.3281 3,6.426 .VP 010.H02 YER!FICATISN LISTING mASE 5 iPHI 40.2832 DPHI ;R -999.2500 )EPT 6900.0000 SFLU ;P -129.0000 SR :HOB 2.3145 DRHO lPHl 43.068~ DPHI ;R -999.2500 )EPT 6800.0000 SFLU ;P -133.2500 GR ~H~B 2.3495 ORHO JPHI 47.3145 DPMI ;R -999.2500 ]EPT 6700,0000 SFLU ~P -117,1250 GR ~HOB -999,2500 DRMO ~PHi -999.2500 g?HI iR -999.2500 }EPT 6600.0000 SFLU ~P -120,2500 GR ~HOB -999,2500 DRH~ ~PHI -999.2500 DPHi JR -999.2500 ]EPT 6500.0000 SFLU SP -108.3750 GR RHOB -999.2500 DRHO ~PHI -999.2500 DPHI ~R -999,2500 DEOT 6400,0000 SF~LU SP -110,3750 GR RHOB -999.2500 DRHO NPHi -999,2500 DPHI GR -999.,2500 OEPT 6300,0000 SFLU SP -111.1875 GR RHOB -999.2500 DRHO NPHI -999.2500 DOMI GR -999.2500 DEPT 6200.0000 SFLU SP -107.8125 GR RHOB -999.2500 DRHO NPHI -999,2500 'DPHI GR -9'99,2500 OEPT 6100,0000 SFLU SP -129,7500 GR RH3B -999,2500 DRHO 12.2937 NCNL 1.7322 ILD 112,9375 GR 0,0078 NRAT Z0.3441 .NCNL 2,3934 ILD 121,0625 GR 0.0210 NRAT 18.2137 NCNL 3.3824 ILO 200.3000 GR -999.2500 NRAT -999.2500 NCNL 2,4916 ILD 259.2500 GR -999.2500 NRAT -999,2500 NCNL 2,4730 ILD 107,0625 GR -999,2500 NRAT -999,2500 NCNL 1.9599 ILD 143.8750 GR -999.2500 NRAT -999.2500 NCNL 2.1956 iLO 109,4375 GR -999,2500 NRAT -999.2500 NCNL 1,5257 ILO 97,8125 GR -999,250'0 NRAT -999,2300 NCNL 2, 6645 !LD 89,8125 GR -9'99,2500 NRAT 1829.0000 1.3310 112.9375 3.6406 1591.0000 1.9028 121.0625 3.7793 1618.0000 2.7509 -999.2300 -999.2500 -999.2500 1.6477 -999.2300 -999.2500 -999.2500 1,7818 -999.2300 -999,2500 -999,2500 1,8668 -999.2500 -999,2500 -999,2500 1.9989 -999.2500 -999.2500 -999.2500 1.$106 -999.2500 -9'99.2300 -999.2500 2.3293 -999,2500 -999,2500 FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL iLM CALI RNRA SCNL ILM CALi RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA 502.0000 1.4229 8.9766 3.7871 4ZO.O000 2.0125 9.1719 3.8047 425.2500 2.7775 -999.2500 -999.2500 -999.2300 1.7433 -999.2500 -999.2500 -999.2500 1.9009 -999.2500 -999.2500 -999.2500 1.9539 -999.2500 -999.2500 -999.2500 2,0951 .-999,2500 -999,2500 -999.2500 1,6665 -999.2500 -999.2500 -999,2300 2.4052 -999,2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE )EPT ;R )EPT ;P ~hOB 4PHI ;R DEPT ~P ;~HOB qPHI 3EPT RHO~ NPHI DEPT SP RHOB NPHI GR DEPT SP RHD:B NPHI GR DEPT SP RhOB NPHI DEPT RH08 NPHI GR ,.SEPT SP RHOB -999.2500 OPHZ -999.2500 6000.0000 SFLU -147.2500 GR -'999.2500 DRH2 -999.2500 DPHI -999.2500 5900.0000 SFLU -137.5000 GR -999.2500 DRHO -999.2500 DPHi -999.2500 5800.0000 SFLU -137.8750 GR · -999.2300 DRHO -999.2500 DPHI -999.2500 5700.0000 SFLU -142.1250 GR -999.2500 DRHO -999.2500 DPHI .-999.2500 5600.0000 SFLU -145.5000 GR -999.2500 DRHO -9'99.2500 DPHI -999.2500 5500.0000 SFLU -156.2500 GR -999.21500 DRHD -999.2500 DPHI -999.2300 5400.0000 SF.LU -13'9.6250 GR -999.2500 DRHO -999,2500 OPHt -999.2500 5300.0000 SFLU :-147.5.250 GR -999.2500 DRHO -999.2500 OPHI -999.2500 5200.0000 SFLU '152.5000 GR -999.2,500 D,RHD -999.2500 NCNL 3.1281 IL9 115.8750 GR -999.2300 NRAT -999.2300 NCNL '1.~902 iLD 95.1250 GR -999.2300 NRAT -999.2500 NCNL 3.4311 ILD 116.7500 GR -999.2500 NRAT -999.2500 NCNL 2,5021 ILD 93.6250 GR -999.2500 NRAT -999.2500 NCNL 4.2134 ILD 100.7500 GR -999.2500 NRAT -999. 2500 NCN:L 3.2265 ILD 99.4375 GR -999.2300 NRAT -999.2500 NCNL 1.5573 ILD 123.7500 GR -999.2500 NRAT -999.2500 NCNL 3.4915 ILD 90.0525 GR -999.2500 NRAT -999.2300 NCNL 3.4813 ILD 8.6.3125 GR -999.2500 NRAT -999.2500 2.7509 -999.2500 -999.2500 -999.2500 2.0274 -999.2500 -999.2500 -999.2500 2.9590 -999.2500 -999.2500 -999.2500 2.0440 -999.2500 -999.2500 -999.2500 3.2787 -999,2500 -999.2500 -999,2500 2'9703 -999.2500 -999.2500 -999.2500 2,3755 -999.2500 -999,2500 -999,2500 3.1113 -999.2500 -999.2500 -999.2500 3.3031 -999.2500 -999.2500 FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNR~ FCNL ILM CALi RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNR~ FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI -999.2500 2.8761 -999.2500 -999.2500 -999.2500 2.0752 -999.2500 -999,2500 -999.2500 3.0876 -999.2500 -999.2500 -999.2500 2.1007 -999.2500 -999,2500 -999.2500 3.a575 -999.2500 -999.2500 -999.2500 3,0740 -999.2500 -999.2500 -999,2500 2.3397 -999.2500 -999.2500 -999.2500 3.1955 -999.2500 -999.2500 -999.2500 3.3710 -999.2500 -999.2500 .VP OlO.H02 VErIFiCATION LISTING PAGE 7 )EPT ;P ,~PHi ;R }EPT ~HCB ~PHI )EPT ~HOB ~PHI )EPT 2HOB qPHI SR DE PT RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI GR DEPT SP RHDB NPHi GR DEPT SP RHOB -999.2500 DPHZ -999.2500 5100.0000 SFLU -148.6250 GR -999.2500 DRHD -999.2500 DPHI -999.2500 5000.0000 SFLU -154.6250 GR -999.2500 DRHO -999.2500 DPHI -999,2500 4900.0000 SFLU -155.3750 GR '-999.2500 DRHO -999.2500 DPHI -999.2500 4800.0000 SFLU -159.7500 GR -999.2500 DRHO -999.2500 DPHI -999,.2500 4700.0000 SFLU -136.8750 GR -999.2500 DRHD -999.2500 DPHI -999.2500 4600.0000 SFLU -156.5000 GR -999.2500 DRHO -999.2500 DPHI -999.2500 4500.0000 SFLU -157.7500 GR -999.2500 DRHD -999.2500 DPHI -999.2500 4400.0000 SFLU -156.8T50 GR -999.2500 DRHO -999.2500 DP~I -999.2500 4300.0000 SFLU '-159.3750 GR ,-999.2500 DRHO -9'99.2500 NCNL 3.3275 iLO 84.3125 GR -999.2500 NRAT -999.2500 NCNL 3.5733 iLD 88.2500 GR -999.2500 NRAT -999.2500 NCNL 2.9123 iLD 94.4375 GR' -999.2500 NRAT -999.2500 NCNL 3.0812 ILO 90.3750 GR -999.2500 NRAT -999.2500 NCNL 2.8225 ILO 95.4375 GR '-999.2500 NRAT -999.2500 NCNL 2.8967 ILD 94.5000 GR -999.2500 NRAT -999.2500 NCNL 2,.6467 I:LD 100.0000 GR -999.2500 NRAT -999.2500 NCNL 3. 0764 ILD 52.3125 GR -999.2.500 NRAT -999.2500 NCNL 3.3535 !LD 83.5625 GR -999.2500 NRAT -999.2500 3.3120 -999.2500 -999.2500 -999.2500 3.5938 -999.2500 -999.2500 -999.2500 2.6797 -999.2500 -999.2500 -999.2500 3.0671 -999.2500 -999.2500 -999.2500 2.7968 -999.2500 -999.2500 -999.2500 2.8818 -999.2500 -999.2500 -'999.2500 2.6962 -999.2500 -999.2500 -999.2500 3.0670 -999.2500 -999.2500 -999.2500 3.3801 -999.2500 -999.2500 FCNL ILM CALl RNRa FCNL ILM CALI RNRA FCNL ILM CALi RNRA FCNL ILM CA:Li RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCN'L ILM C ALI RNRA F CN L ILM CALl RNRA FCNL ILM CALl RNRA -999.2500 3.4205 -999.2500 -999.2500 -999.2500 3.7816 -999.2500 -999.2500 -999.2500 2.7283 -999.2500 -999.2500 -999.2500 3.1100 -999.2500 -999.2500 -999.2500 2.8394 -999.2500 -999.2500 -999.2500 2.9062 -999.2500 -999.2500 -999.2500 2. 6267 -999.2500 -999.2500 -999.2500 3.0571 -999.2500 -999.2500 -999.2500 3.3670 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE iPHI -999.2500 DPHI ;R -999.2500 )EPT 4200.0000 SFLU ;P -148.5000 GR ~HOB -999.2500 DRHO ~PHI -999.2500 DPHi ;R -999.2500 )EPT 4100.0000 SFLU ~P -156.6250 GR ~HOB -999.2500 DRHD ~PHI -999.2500 DPHI ~R -999.2500 DEPT 4000.0000 SFLU SP -151..1250 GR ~HOB -999.2500 DRHO qPHI -999.2500 DPHI ~R -999.2500 DEPT 3900.0000 S~LU SP -153.8750 GR RMOB -999.2500 DRHO NPHI -999.2500 DPHI ~R -999.2,500 DEPT 3800.0000 SFLU SP -151.8750 GR RHDB -999.2500 DRHG NPHI -999.2500 DPHI GR -999.2500 DEPT 3700.0000 SFLU SP -148.6,250 GR RHOB -999.2500 DRH'O NPHI -999.2500 DPHI GR -999,2500 DEPT 3600.0000 SFLU SP -1.49.6250 GR RH05 -999.2500 DRHO NPHI .-999.2500 DPHI GR -999.2500 DEPT 3500.0000 SFLU SP -154.1250 GR RHOB -999.2500 DRHO NPHI -999.2500 DPHI GR -999.2500 DEPT 3400.0000 SFLU SP -152.7500 GR RHO$ -999.2500 DRHO -999.2500 NCNL 3.4793 ILD 79.8750 GR -999.2500 NRAT -999.2500 NCNL 3.3671 ILO 54.9375 GR -999.2500 NRAT -999.2500 NCNL 2.6898 ILD 80.4375 GR -999.2500 NRAT -9'99.2500 NCNL 5.1910 ltd 77.5625 GR -999.2500 NRAT .-999.2500 NCNL 3.7231 ILD 76.3125 GR -999.2500 NRAT -999.2500 NCNL 4.6153 ILD 76.7500 GR -999.2500 NR'AT -999.2500 NCNL 4. 3680 iLD 8 T. 68 '75 G R -999. 2500 NRAT -999. 2500 NCNL 3.7324 ILO 68.7500 GR -999.2500 NRAT -999.2500 NCNL 14.5009 ILO 65'.3750 GR '-999.2500 NRAT -999.2500 3.4583 -999.2500 -999.2500 -999.2500 3.1736 -999.2500 -999.2500 -999.2500 2.8078 -999.2500 -999.2500 -999.2500 4.41'97 -999.2500 -999.2500 -999.2500 3.3925 ,-999.2500 -999.2500 -999.2500 4.3878 -999.2500 -999.2500 -999.2500 4.8628 -999.2500 -999.2500 -999.2500 5.1225 -999.2500 -999.2500 -999.2500 10.5059 -999.2500 -999.2500 FCNL ILM CALI RNR4 FCNL ILM CALI RNRA FCNL ILM CALI RNR~ FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ! LM CALI RNRA FCNL !LM CALI RNRA FCNL ILM CALI RNR4 -999.2500 3.4746 -999.2500 -999.2500 -999.2500 3.2733 -999.2500 -999.2500 -999.2500 2.7630 -999.2500 -999.2500 -999.2500 4.6837 -999.2500 -999.2500 -999.2500 3.8202 -999.2500 -999.2500 -999.2500 4.2230 -999.2500 -999.2500 -999.2500 4.6243 -999.2500 -999.2500 -999.2500 4.90,29 -999.2500 -999.2500 -999.2500 10,.1111 -999.2500 -999.2500 .VP OlO.H02 VERIFICATIDN LISTING ~PHI )EPT ;P ~PHI ;R )EPT tHDB ,]PHi ;R )EPT ~P qPHi ;R )EPT SP RHDB ~PHI ~R 3EPT RHOB qPHI ;R 3EPT SP RHOB NtPHI SR 3EPT SP RHOB NPHI 3R 3EPT SP RHOB NPHZ GR DEPT SP RHOB -999.2500 DPHi -999.2500 3300.0000 SFLU -151.6250 GR -999.2500 DRH3 -999.2500 DPHI -999.2500 3200.0000 SFLU -156.6250 GR -999.2500 DRHG -999.2500 DPHi 68.8750 3100.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPH'i 42.0313 3000.0000 SFLU -999.2500 GR '-999.2500 DRHO -999.2500 DPHI 26,7031 2900.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 34.0000 2800.0000 SFLU -99'9.2500 GR .-999.2500 DRHO -999.2500 DPHI 51.9375 2700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPHI .38.53:13 2600.0000 SFLU -999.2500 GR -999.2,500 DRHO -99'9.2500 DPHi 24.9687 2500.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 NCNL 8.4725 ILD 59.0313 GR -999.2500 NRAT -999.2500 NCNL 5.4676 ILD 66.1875 GR -9'99.2500 NRAT -999.2500 NCNL -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRA'T -999.2500 NCNL -999.2500 ILD .-999.2500 GR -999.2500 NRAT -999.2500 NCN'L -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999. 2500 ILO -999.2500 GR -999.2500 NRAT -999.2.500 NCNL -999.2500 IiLD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -99'9.2.500 ILD -999.,2500 GR -999.2500 NRAT -999.2500 7.2729 -999.2500 -999.2500 -999.2500 5.6555 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 '-9:~9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 FCNL iLM C~LI RNRA FCNL !LM C4LI RNRA FCNL ILM CALI RNRA FCNL ILM C4LI RNRA FCNL ILM .CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL, ILM CALi RNRA -999.2500 7.3058 -999.2500 -999.2500 -999.2500 5.4261 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 .V? OlO.H02 VERIFICATION LISTING PAGE 10 iPHi ;R ;r-pT ~HOB ~PHI ]~.PT ~HOB qPHI 3R 3EFT 5P 2HO6 qPHI DEPT SP RHO 5 NPHI DEFT SP RHO& NPHI GR DEPT SP RHDB NPHI DSPT SP RH08 NPHI GR DE P'T RHOB NPHI GR DEPT .SP RHO5 -999,2500 ~PHI 41.0000 2400,0000 SFLU -999,2500 GR -999,2500 DRHD -999.2500 DPHI 34,7500 2300,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 DPHi 31.5781. 2200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPHI 29,0000 ZlO0,O000 SFLU -999,2500 GR -999,2300 DRHO -999,2500 DPHI 32,2500 2000.0000 SFLU -999.2500 GR -999.2500 DR~O -999.2500 OPHI 22.9687 1900,0000 SFLU -999,2500 GR -'999,2500 DRHO -999.2500 DPHI 37.0625 1800,0000 SFLU -999,2300 GR -999.2500 ORHO -999.2300 DPHi 28.0156 l?O0,O000 SFLU -999,2500 GR -999,,2300 DRHO -999.2500 DPHI 42.0938 1600.0000 SFLU -9'99,2500 GR -999,2500 DRH'O -999.2300 NCNL -999.2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999,2500 ILO -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILD -999,2500 GR -999.2500 NRAT -999,2300 NCNL -999.2500 ILD -999,2500 GR -999,2500 NRAT -999.2500 NCNL -999. 2500 ILD -999.,2500 GR -999.2500 NRAT -9'99.2500 NCNL -999,2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILO -999,2500 G.R -999.2500 NRAT -999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2300 NRAT -999.2500 N:CNL -999,.2500 ILO -999.2300 GR -999.2500 NRAT -999.2500 -999.2500 -999.2300 -999.2500 -999.2300 -999.2500 -999.2500 -999.2300 -999.2500 -999.2300 -999.2500 -999.2500 -999.2300 -999,2500 -999,2300 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2300 -9'99.2500 -999.2300 -999,2500 -999,2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 FCNL ILM CALI RNRA ~CNL ILM C~L! RNRA FCNL ILM CALI RNRA FCNL ILM CALZ RNR4 FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCNL ILM C.4LI RNR4 FCNL ILM CALI RNRA FCNL ILM CALI RNRA -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2300 -999.2500 -99'9,2500 -999,2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 ,VP 810.H02 VERIFICATION LISTING PAGE 11 iPHI -999.2500 DPHI ;R 18.0625 )EPT 1500.0000 SFLU ;P -999.2500 GR ~H05 -999.2500 DRHD ~PHI -999.2500 DPHi ;R 39.4063 }EPT 1400.0000 SFLU ~P -999.2500 GR ~HO5 -999.2500 DRHO ~PHI -999.2500 DPHi ;R 23.6719 )EPT 1300.0000 SFLU ~P -999.2500 GR ~HSB -9'99.2500 DRHD ~PHI -999.2500 DPHi DR 45.0000 ]EPT 1200.0000 SFLU 5P -999.2500 GR ~HOB -999.Z500 DRHO ~PHI -999.2500 DPHI 3'R 30.7344 3EPT 1100.0000 SFLU SP -999.2500 GR RHOB -999.2,500 DRHO ~PHI -999.2500 OPHI ~R 47.7813 DEPT 1000.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 DPHI GR 50.4375 DEPT 996.0000 SFLU SP '-999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 DPHI GR 57.7813 *:~ FILE TRAILER ** FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : -999.2500 NCNL -999.2500 ILC -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -9'99.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999,2500 GR -999,2500 NRAT ,-999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 FCNL iLM CALI RNRA FCNL !LM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCN'L I L M CALI RNRA FCNL ILM CALI RNRA FCNL ,ILM C A~LI RNRA F C N L -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999,2500 -999.2500 -99~.2500 -999.2500 YP OlO.H02 VERIFICATION LISTING PA65 12 · ~ TAPE T~AILmR ,'ERVICE NAM=~ 'EDIT. )ATE :86/10/23 )RIGIN :FS1A 'APE NAME : ;QNTINUATION ~ :01 ~EXT TAPE NAME : 'DMMENTS :LIBRARY TAPE ..... R:EL TRAIL=R ~ERVICE N~ME :EDIT )ATE :86/10/23 ]RIGIN : KEEL NaME :149576 'ONTINUATION # :O1 qEXT REEL NAME : '~MMENTS :LIBRARY TAP
