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Home My WebLink About198-017 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG o 1 a. Well Status: DOil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 9/21/2006 198-017 306-005 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 02/15/1998 50-029-22861-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 03/01/1998 Kuparuk 1C-14 1566' FNL, 1139' FWL, SEC. 12, T11N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 1461' FSL, 3322' FWL, SEC. 06, T11N, R11E, UM 101.3' Kuparuk River Unit 1 Kuparuk Total Depth: 9. Plug Back Depth (MD+ TVD) River Pool 1642' FSL, 3511' FWL, SEC. 06, T11N, R11E, UM 10743 + 6591 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 562146 y- 5968672 Zone- ASP4 10980 + 6772 Ft ADL 028242 TPI: x- 569581 y- 5971865 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 569769 y- 5971947 Zone- ASP4 N/A MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1465' (Approx.) 21. Logs Run: GR 1 RES 22. CASING, LINER AND CEMENTING RECORD .'. SETTING DEPTH MD SETTING DEPTHTVD HOLE ... "<:." r~t.lNt. . SIZE WI. PER Ft. GRADE Top BOTTOM Top BOTToM SIZE < < ~R~"":i\Þ"': I <.P,,,.,:,, 16" 62.5# H-40 Surface 121' Surface 121' 24" 9 cu vds Hiah Earlv 9-5/8" 40# L-80 Surface 7292' Surface 4527' 12-1/4" 612 sx AS III LW, 348 sx 'G', 60 sx AS I 7" 26# L-80 Surface 1 0503' Surface 6409' 8-1/2" 130 sx Class 'G' 4-1/2" 12.6# L-80 1 0300' 1 0980' 6259' 6772' 6-1/8" 130 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. >.... /.. V:·<·< <......««} ....:...:...<......... ..... """1'1'" Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.3#, L-80 1 0336' 1 0300' MD TVD MD TVD 25. AClb. ..CEIlAENT....·:·· '·E¥d·,.<ii«/····t<t;<i··.·...·..<? . .< ¡SCA~N1Er ¡'In\¡ 2 '¡ ?lìr1f~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED \!·V t.. "J...L i-:""'U'..) 10873' Set Whipstock 1 0742' Set 2nd Whipstock 10743' P&A wI 14 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED OIL -BBl GAs-McF WATER-BBL Oil GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). ,~m:i!r;:œq:hips; if none, state "none". ~~.... ¡.,,¡ ¿ -/ ,.~ II~ 11--. ØO'\ N ne 7;' //~ RBOMS 8Ft .2 :¡ ZDD6 ~ VE::l!~:¡ED ¡ .. .;.t Form i04ö7 ~evised 12/2003 CONTINUED ON REVERSE SIDE 6 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Kuparuk C 10664' 6531' None Base Kuparuk C 10823' 6652' Top Kuparuk A 10890' 6703' Base Kuparuk A 10890' 6703' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ . Title Technical Assistant Date t l~ Co VCo Kuparuk 1 C-14 198-017 306-005 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Permit No. I A roval No. Drilling Engineer: Sean McLaughlin, 564-4387 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 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 elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only . . Well: Field: API: Perm it: 1 C-14 Kuparuk River Unit 50-029-22861-00 198-017 PRE-RIG WORK 12/05/05 PRE CTD MITIA PASSED, POT & PPPOT- T PASSED, POT-IC PASSED, PPPOT-IC FAILED, PT & DRAWDOWN TESTS MV & SV PASSED, DRAWDOWN TEST SSSV FAILED. 12/26/05 TAGGED FILL AT 10,725' RKB, 9' OF RAT HOLE. OBTAINED SBHP OF 4491 PSI WI BHT OF 1170 F AT 10,693' RKB. MADE A GRADIENT STOP AT 10,493' RKB. EXERSIZED & FLUSHED SSSV WI HOT DIESEL. SSSV CLOSURE TESTED GOOD. 01/21/06 FCO TO HARD TAG AT 10860' CTMD. NO CLEAR INDICATION OF FILL. SWEPT HOLE WITH BIOZAN, 1.5:1 RETURNS THROUGHOUT JOB. FP TUBING WITH 22 BBLS. DIESEL. WELL LEFT SHUT IN. 01/24/06 TAGGED OBSTRUCTION AT 2976' SLM WI 2.72" G. RING. WORKED 1.75" SAMPLE BAILER BY OBSTRUCTION AND TAGGED AT 10841' SLM. EST 125' OF RATHOLE. IN PROGRESS. 01/25/06 PUMPED 40 BBLS OF HOT DIESEL DOWN TBG AND DRIFTED A 2.77" BROACH PAST OBSTUCTION AT 2976' SLM AND TAGGED D NIPPLE AT 10272' RKB. DRIFTED TBG WI 2.74" X 10' BUT SET DOWN IN D NIPPLE AT 10272' RKB. ON FURTHER INSPECTION FOUND SOME SPOTS ON DRIFT MEASURED 2.745". 01/26/06 SET BAKER GEN II WHIPSTOCK TOP AT 10742' WITH THE FACE ORIENTED 3.5 DEG CCW FROM THE HIGH SIDE OF THE HOLE - RA PIP TAGS AT 10749.3'. 08/09/06 DRIFT TUBING WI 1.75" SAMPLE BAILER. WORK THROUGH BRIDGE OF ASPHAL TENES AT 7038' SLM. OBTAIN SBHP'S OF 3649 PSI (1220 F) AT 10693' RKB AND GRADIENT OF 3564 PSI (1410 F) AT 10451' RKB. JOB COMPLETE. 09/01/06 TAGGED TOP OF WHIPSTOCK AT 10871' RKB (129' BELOW TARGET DEPTH OF 10742' RKB). DRIFTED DOWN TO 10851' WI 10' BARBELL DRIFT (2.71 CENT., 4' STEM, 2.65 CENT., 3' STEM, AND 2.74 SWAGE) WI NO PROBLEMS. 09/15/06 RIH WITH BOT 1-1/2" MHA, X-TREME MOTOR AND 3.799 TRI BLADE UNDEREAMER TO 10857' CTMD. PIU 10' FLAGGED PIPE AND RESET COUNTERS TO 10847 RKB. PIU TO 10820' RKB AND STARTED PUMPING AT.4 BBUMIN. INCREASED RATES TO 1.4 BBUMIN. AND STARTED UNDEREAMING FROM 108. 09/17/06 TAGGED TOP OF WHIPSTOCK AT 10873' RKB. RAN PDS CALIPER LOGGING FROM 10870' RKB TO SURFACE. TOOL DOWNLOADED. GOOD DATA. JOB COMPLETE. xx-xx Page 2 . . 09/18/06 SET BAKER GEN II WHIPSTOCK IN 4 1/2" LINER WITH TOP AT 10742'. RA PIP TAGS AT 10749.3'. WHIPSTOCK FACE ORIENTED TO 1.1 DEG CCW FROM HIGH SIDE LOOKING DOWNHOLE. TAGGED WHIPSTOCK TO CONFIRM SET. 09/20/06 TAG TOP OF WHIPSTOCK AT 10750' RKB. 09/21/06 PERFORMED A CEMENT SQUEEZE WITH 15.8 PPG CLASS G CEMENT. 14 BBLS SQUEEZED BEHIND PIPE. DURING SECOND RINSE CYCLE BY PERFORATIONS LOST FLUID. CLEANED OUT NEAT CEMENT TO 10,748' RKB. RINSED ALL JEWELERY ON WAY TO SURFACE. WELL FREEZE PROTECTED TO 3,500. 09/27/06 PRESSURE TESTED CEMENT SQUEEZE UP TO 1500 PSI. WHTP FELL BACK TO 1150 PSI AFTER 30 MINUTES. TOOK APP: 1 BBL OF DIESEL TO BRING PRESSURE UP FROM THE INITIAL WHTP OF 900 PSI TO 1500 PSI. 10/07/06 TAG AT 10750' RKB, JOB COMPLETE. BEGIN RIG WORK 11/05/06 NORDIC #2 RIG ACCEPTED ON THE WELL. 11/06/06 BOP TEST. RU CT AND INJECTOR HEAD. CT SLACK MANAGEMENT. 11/07/06 MANAGE SLACK. TEST DEPLOYMENT PROCEDURES. RIH. MILL WINDOW AT 10743'. 11/08/06 DRESS WINDOW. BHA TRIP. CIRCULATE HOLE. BEGIN DRILLING BUILD SECTION. - END OF THIS SUMMARY FOR THE ORIGINAL WELLBORE. - NIP (10272-10273, 00: 3 500) PKR- (10300·10301, 00:6.151) SEAL (10311·10312, 00:4.000) SSE (10321·10322, 00:4.500) TTL (10337·10338, 00:3500) Perf (10670·10696) Perf (10696-10716) KRU BAKER GEN.II WHIPSTOCK RESET 9/18/2006 WHIPSTOCK FACE ORIENTED TO 1.1 DEG CCW LOOKING SIDE SET. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and lor 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 attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 BL / EDE Disk 1C - 14 Caliper Report 1 7 -Sep-06 1) 2) 3} 4) 5} 6) 7} " ~t:"k\ C'1t' h ~~ ~~,J:L) <~~t~, .. r 'j, " (, Signed: CQ~ RECEIVED Date: SEP 2 9 2006 Print Name: ~11^ P, {V\'iJA IA ~~ Þ, '^ AIIIka Oil & Gas Cons. CommIssion Anchorage ~ Cft"-Ol'r · 1 J../ Jl../3 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE(1ì!MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:lOO _ PDSANC-20061Z _ WordIDislribulÌOnlTranSlllinal_ Sheersl TransmiU)riginatdoc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Desc.: Use: Pipe2Desc: Pipe2 Use: ConocoPhilJips Alaska, Inc. September 17, 2006 6608 2 3.5' 9.3 lb. L-80 Tubing 4.5" 12.6Ib. L-80 Liner Well: Field: State: API No.: Top Log Intvit Bot intvI1.. Top Log Intv!1.: Bot. Log ! ntv! 1. : 1C-14 Kuparuk Alaska 50-029-22861-00 Surface 10,337 Ft (MD) 10,337 Ft. (MD) 10,865 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the end of the tubing tail @ 10,337' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage and to determine potential whipstock setting depth. 3-D log plots of the caliper recordings across the bottom of the 3.5" tubing and the 4.5" liner are included in this report for the purpose of aiding in the selection of the interval for whipstock placement. The caliper recordings indicate the 3.5" tubing is in good to poor condition, with a maximum recorded wall penetration of 74% in joint 268 (8,558'). The damage recorded appears in the form of scattered pitting and corrosion above the SSSV and as a line of pits and line of corrosion on the low side (-2,000' -10,337'). No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate the 4.5" liner logged is in good to poor condition with respect to corrosive damage. Wall penetrations from 20% to 49% are recorded throughout a line of pits and line of corrosion on the low side running the length of the interval logged. No significant areas of cross-sectional wall loss or I. D. restrictions are recorded. This is the second time a PDS caliper has been run in this well. Comparison graphs illustrating the difference in maximum recorded penetrations between logs for the 3.5" tubing and 4.5" liner are included in this report. MAXIMUM RECORDED WALL PENETRATIONS· Corrosion ( 74%) Jt. 268 @ 8,558 Ft. (MD) Line of pits ( 66%) Jt. 254 @ 8,099 Ft. (MD) Line of pits ( 54%) Jt. 224 @ 7,168 Ft. (MD) Corrosion ( 53%) Jt. 230 @ 7,349 Ft. (MD) Line of pits ( 52%) Jt. 262 @ 8,369 Ft. (MD) " MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 9%) are recorded throughout the 3.5" tubing logged. .. MAXIMUM RECORDED ID RESTRICTIONS: RECEIVED No significant I.D. restrictions are recorded. SEP 2 9 2006 Prz,\L\,ctive DJagnost¡c Servicest Tnc- f 7l r"-, nn'"'''' ~rf"i '''1'''!AO~ . . . ..,., ')' 'y'- , "-?' ,. Co ISSloo ':~:.' '.~:;-'::{ ". -M ..' J~OII&GasCons. mm .>r/-._1 ~J;{::, e-mail' })1 i:,u''j1fnp'·fin¡~\.> _~._ _ "£:5'9~:::Ú)?' ....~.¿,." . N" Anchorage 1C)~-(j(1- ;t /4/43 I I I I I I I I I I I I I I I I I I I . . 4.5" LINER - MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion Line Corrosion Line Corrosion Line Corrosion Corrosion ( 49%) ( 40%) ( 36%) ( 36%) ( 34%) Jt. Jt. Jt Jt. Jt. 10 3 5 6 16 @ @ @ @ @ 10,617 Ft. (MD) 10,425 Ft. (MD) 10,463 Ft. (MD) 10,511 Ft. (MD) 10,820 Ft. (MD) 4.5" LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 14%) are recorded throughout the 4.5" liner logged. 4.5" LINER - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 4.5" liner logged. I Field Engineer: N. Kesseru Analyst M. Lawrence Witness: Woods 565-9085 crudhoe Sav Fjeld C)ff¡ce I I I I I I I I I I I I I I I I I I I 3 u 1C-14 Detail of Across 3.5" I/w b~~~_Ma.L£~ 0500 MIN ID (mOI1lVn ) 35!l1J¡ ~_,~.I..D..,,_J.5!lIJ! I· ..... .... Joint 313 10025 f- - - -"I·- e··· I Joint 314 10050 'm n 10015 Joint 315 + 1 01 00 Joint 318 I· ¡..... I·· 10125 1-.. I~ . Joint 317 10150 7,2006 Window I ~-"~.- ~"._-- ~ ' I I I I I Joint 318 10175 [\f I I !ø@ t~~' r"~ ".... ...JH-1- I 10200 Joint 319 I I ~~~' Pup Jt. 10225 ...J-!- - 319.1 GLM6 I I Pup Jt. , I 319.3 (Tool Hang Up) . I I 10250 ....... '''1"" I Joint 320 I D NJpple 10275 .~ 'W+ r- I I Joint 321 I 10300 I Packer & r-- ~.. Seals I Pup Jt. 321.2 10325 Pup Jt. I I 321.3 1 End of T.'hi......T"'¡¡ I I I I I I I I I I I I I I I I 3.5" Tubing Joint 1 Joint 2 Joint 3 I I I I I I Joint 4 Joint 5 Detail of Inc. 4 ! n M.." J:lo" to!..\ 240 W+lL~~ 10350 10375 10400 1_ 10425 ~-, 10450 10415 3 Date' Across 4.5" Liner Potential I.... U 1M."" ;" \ 13500 MI~ iD (1/1000 in ) 4500, ~lUl._~'M~5D.Q¡ .. !......... .... .......... I 1 2006 Window I I I I I I I I I I I I I I I I I I I ~I 10500 Joint ô 10525 ~ ,~ Joint 7 10550 Joint 8 10575 $~ ~ Joint 9 10600 10625 Joint 10 10650 Joint 11 10675 ~ I I I I I I I I I I I I I I I I I I I I I I 1J ....... Joint 12 ·H Perforations ···'I··T 10700 ~- Joint 13 10m~ i Perforations Joint 14 10750 ~ - 10775 .......... Joint 15 nt - 10800 L 11 , I Joint is 10825 Joint 17 10850 Joint 18 ~ I I Pipe 1 Pipe 2 I I I I I I I I I I I I I I 3194 GLM 1 4781 0 I- ¿ <) ..Q +' E L.I... :¡ C z 6356 ..!:: GLM 2 .;:;: õ.. <) .s; 0 7965 GLM 3 Correlation of Recorded Damage to Borehole Profile 3.5 in (26.3'· 10340.8') 4.5 in (10340.8' -10860.0') Well: Field: Company: Country: Survey Date: 1C-14 Kuparuk ConocoPhilfips Alaska, Inc. USA September 17, 2006 Approx. Tool Deviation Approx. Borehole Profile GLM 4 GLM 5 50 Damage Profile (% wall) I Tool Deviation (degrees) I Bottom 0 f Su rvey = 18 I I 30 1593 9566 10341 10860 100 I I I Maximum Recorded Penetration Comparison To Previous Max. Rec.l'en. (mils) 0 100 200 0.1 9 19 29 39 49 56.3 66 76 86 96 106 116 123 133 .. 143 "- OJ 153 OJ .Q .Q E 163 § :::I Z z 1!! 173 1!! :! 183 :! 193 203 210 220 230 240 250 260 267 277 287 297 304 314 320 I Well: Field: Company: Country: I I I I I I I I I I I I I I I 1C·14 K uparuk ConocoPhillips Alaska, Inc. USA Overlay Survey Date: Prevo Date: Tool: Tubing: September 1 7, 2006 January 25, 2006 MFC 24 No. 040665 3.5" 9.3 Ib L-80 Difference Oiff. in Max. Pen. (mils) -100 ·50 o 50 100 I I I I I I I I I I Well: Field: Company: Country: lC-14 Kuparuk ConocoPhillips Alaska. Inc. USA Maximum Recorded Penetration Comparison To Previous Survey Date: Prevo Date: rool: rubing: 300 ·100 Overlay o Max. Rec.Pen. (mils) 100 200 I ... .. <11 <11 .Q .Q E E " " Z Z ¡; ... c ]. ]. 11 I I I I I I I I September 1 7, 2006 January 25, 2006 MFC 24 No. 040665 4.5" 12.6 Ib L-80 Difference Diff. in Max. Pen. (mils) ·50 o 50 100 I I I Well: Field: Company: Country: lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread L-80 I I Penetration and Metal loss (% wail) penetration body metal loss body I 400 I 300 200 I 100 o o to 1% I I Damage Configuration ( body ) 200 I 150 100 I 50 o I isolated general line ring hole / poss pitting corrosion corrosion corrosion ¡ble hole I I I I I over 85% o o o PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: Nom.ID 2.992 ins September 17, 2006 MFC 24 No. 040665 1.69 24 M. I awrence Nom. Upset 3.5 ins Upper len. '1.2 ins Lower len. 1.2 ins Damage Profile (% wail) penetration body o o GLM 1 GLM 2 GLM3 GLM4 GLM 5 metal loss body 50 100 Bottom of Survey = 321,4 Analysis Overview page 2 I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-14 Kuparuk ConocoPhiffips Alaska, Inc. USA September 17, 2006 I Joint Jt. Depth Pcn, Pen. Pen, ¡j Min. Damag e Profile No. (Ft.) 'I Body I.D. Comments (% wall) (ins.) (Ins,) 0 50 100 .1 26 II 0.03 10 (, 2.89 PUP ~ 1 30 (} 0.03 11 ) 2.94 1.1 62 {I 0.01 3 H= 2.89 PUP 2 65 0.02 ') 2.91 3 96 0.02 <) 2.93 4 128 0.02 :2 2.93 5 161 I 0.01 :2 2.94 6 192 0 0.01 :2 2.93 7 224 0 0.04 I 2.93 Shallow oittim~. 8 256 0 0.03 I) 2.94 9 288 II 0.01 4 2.94 10 319 II 0.02 <) 2.93 11 351 {I 0.03 10 :2 2.94 12 383 0 0.03 1 :2 2.94 Shallow oittin2. 13 415 0 0.02 :2 2.93 14 447 0 0.02 " :2 2.93 15 479 II 0.03 1 J ;> 2.92 16 511 0 0.02 ( 1 2.93 17 542 0 0.02 <) 2 2.92 18 574 (} 0.01 5 I 2.94 19 606 0 0.02 7 :2 2.92 20 638 0 0.03 II 2.94 21 670 0 0.02 9 2.93 22 702 0 0.03 1 2.94 23 733 0 0.03 I 2.93 24 765 0 0.03 10 2.92 25 797 I) 0.03 1 2.91 Lt. Deposits. 26 829 0 0.02 ( 2 2.93 27 861 0 0.03 10 2.94 28 893 0 0.02 ( 2,92 29 925 I) 0.03 10 2.93 3D 956 0 0.02 ( 2.92 31 988 I) 0.03 10 2.94 32 1020 0.02 7 2.93 33 1052 ~~ L1 2.93 Shallow pitting. 34 1084 0.013 :2 2.92 Shallow oitting. Lt. Deoosits. 35 1116 0.011 2.93 36 1148 0 0.03 L 2.92 37 1180 I) 0.03 11 2.93 38 1212 I) 0.02 E' 2.94 39 1244 I) 0.05 2 ) 2.95 Shallow corrosion. Lt. DefJOsits. 40 1275 I 0.03 13 2 2.94 Shallow corrosion. Lt. De fJOsi ts. 41 1307 I om I ) 2.93 42 1338 I 0.04 I :2 2.95 Shallow oittíng. 43 1370 I 0.04 1 I 2.93 Shallow corrosion. 44 1401 0 0.04 1 2.94 Shallow oittím:. 45 1433 0 0.05 20 2.93 Isolated pitting. 46 1465 0 0.03 ¡ '. 2.92 . ¡ 47 1498 II 0.07 26 2.94 Isolated pitting. 48 1529 0 0.06 24 2.94 Corrosion. I I I I I I I I I I I I I Penetration Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Compa ny: Country: Survey Date: 1C-14 Kuparuk ConocoPhillips Alaska, Ine. USA September 17, 2006 I I Joint Jt. Depth Pel Pen. Perr Meta! Min. Damage Pr ofile No. (Ft.) .¡ Body 1.0. Comments (%wall) I is) (Ins.) (Ins.) 0 50 100 49 1561 () 0.07 ) 2.92 Corrosion. I 50 1593 () 0.05 )( 2.93 Shallow oit1ím.!:. 51 1625 í 0.06 )¡ 2.93 Line of nits. 52 1657 ( 0.ü3 I 2.93 Shallow nitling. 53 1689 ( 0.03 15 2.94 Shallow oit1ím;¡. 54 1721 ( 0.ü3 13 2.94 Shallow oitling. 55 1752 0 0.10 313 2 2.94 Line of oits. 56 1784 0 0.06 25 2 2.94 Line of oits. 56.1 1815 () 0.05 ) í 2.89 PUP Corrosion. U. Deoosits. 56.2 1822 () 0 í 2.81 SSSV 56.3 1828 () 0.05 1B 2.90 PUP Shallow corrosion. Lt. Deoosits. 57 1835 () 0.04 14 2.94 Shallow corrosion, 58 1867 0 0.ü3 12 I 2.94 59 1898 0 0.04 16 2 2.93 Shallow corrosion. 60 1930 Ii 0.04 I 2 2.93 Shallow corrosion. 61 1962 () 0.04 2.94 Shallow oit1ím;¡. 62 1994 Ii 0.05 2.93 Shallow nitling. 63 2025 () 0.05 2.94 Shallow nitling. 64 2057 () 0.05 2.94 Line of nits. L1. Deoosits. 65 2088 Ii 0.04 17 2 2.93 Shallow nit1ínQ". 66 2120 0 0.05 20 : 2.93 Line of oits. 67 2152 0 0.06 22 3 -HH Corrosion. 68 2183 0 0.06 Line of oits. 69 7215 0 0,06 2.93 Line corrosion. 70 2247 () 0.06 2.94 Corrosion. 71 2279 () 0.07 2.94 Line of pits. 72 2311 () 0.06 2.94 Line of nits. Lt. Denosits. 73 2343 0 0.05 2.93 Corrosion. Lt. Deoosits. 74 2374 0 0.06 2.94 Line of nits. Lt. De oosits. 75 2406 0 0,07 2.94 Corrosion. Lt. Deoosits. 76 ~~) 0.07 2.93 Corrosion. 77 0.07 2.95 Corrosion. 78 2501 í 0.07 2.95 Corrosion. 79 2533 1 0.05 j 4 2.94 Line corrosion. 80 2564 0.08 ) 2.94 Line of nits. Lt. Deoosits. 81 2596 (1 0.06 25 2 2.94 Line of oits. Lt. Deoosits. 82 2628 0 0.10 4¡ 2.92 Line of oits. 83 2659 0 0.03 2.92 Shallow line of oils. 84 2690 () 0.07 2.93 Corrosion. 85 2722 0 0.05 2.93 Shallow line of pits. 86 2753 Ii 0.07 2.92 Corrosion. 87 2784 0 0.09 2.93 Line of nits. 88 2816 () 0.08 2.94 Line of nits. 89 2848 0 0.06 24 2 2.93 Corrosion. I=iÏ=± 2879 0 0.07 2 2.92 Line of oits. 2910 0 0.07 2.92 Corrosion. 92 2941 n 0.07 2.94 Li ne of Di ts. 93 2973 n 0.08 2.93 Line of nits. 94 3005 n 0.05 2.94 Shallow line of nils. 95 3036 n 0.04 2.94 Shallow corrosion. I I I I I I I I I I I I Penetration Body Metal Loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lC-14 Kuparuk ConomPhillips Alaska, Inc. USA Sep1ember 17, 2006 I Joint Jt Depth F'el Pen. Pc ¡1/1e:al Min. Damage Pr ofile No. (Ft.) 'I Body I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 96 3068 0.06 24 ;> 2.94 Li ne of nits. Lt Denosits. 97 3100 0.06 25 4 2.93 Corrosion. 98 3131 0.06 24 2 2.92 Line of nits. 99 3163 0.07 3 2.93 Line of nits. 100 3194 U 0.08 3 2.92 Corrosion. 101 3225 0 0,08 2.92 Corrosion. 102 3257 0 0.06 2.92 Line of nits. 103 3289 0 0.09 2.92 Line of nits. 104 3320 0 0.08 ¡¡ 2.92 Corrosion. Lt. Deoosits. 105 3352 0 0.08 )0 2.92 Line corrosion. 106 3383 0 0.08 :1 3 2.92 Corrosion. 107 3414 0 0.06 4 2.93 Line of nits. 108 3446 () 0.07 ;> 2.93 Line of nits. 109 3477 0 0.08 2.92 Corrosion. 110 3507 0 0.06 2.92 Corrosion. 111 3540 0 0.05 2.92 Line of nits. 112 3571 0 0.09 33 2.92 Line corrosion. 113 3602 0 0.07 29 2.92 Corrosion. 114 3633 0 0,09 37 2 2.92 Corrosion. 115 3664 0 0.10 ;> 2.91 Line of nits. Lt. Deoosits. 116 3696 I 0.10 4 2.92 Corrosion. 117 3728 0 0.10 2.93 Corrosion. 118 3759 0 0.08 2.92 Corrosion. Lt. Deoosits. 119 3790 0 0.09 35 1 2,92 Corrosion. 119.1 3821 (: 0.02 2.94 PUP 119.2 3828 0 0 0 N/A GLM 1 (I atch @ 3:30\ 119.3 3835 0 0.02 ß 2.84 PUP 120 3841 0 0.09 4 2.91 Corrosion. 121 3872 0 0.09 4 2.92 Corrosion. L t. De oosi ts. 122 3903 0 0.09 { 2.91 Corrosion. Lt. Deoosits. 123 3934 OO!) 0.08 ;> 2.92 Corrosion. 124 3964 0.08 32 4 2.92 Corrosion. Lt. Deoosits. 125 3996 006 0.09 36 3 2.93 Corrosion. Lt. Deoosits. 126 4027 0.10 3 2.94 Line corrosion. 127 4060 ( 0.07 2.93 Line of nits. 128 4091 0 0.06 2.92 Line of nits. 129 4123 0 0.07 2.93 Line of nits. 130 4154 0 0.07 2.93 Line of nits. 131 4186 003 0.11 2.90 Corrosion. Lt. Deoosits. 132 4217 0 0.08 30 2.92 Corrosion. 133 4249 0 0.07 2.92 Corrosion. Lt. Deoosits. 134 4279 0 0.07 2 2.93 Corrosion. 135 4311 0 0.13 3 2.93 Corrosion. 136 4343 0 0.08 2 2.91 Corrosion. 137 4372 0 0.10 : 4 2.93 Line corrosion. 138 4404 0 0.08 1 4 2.92 Line corrosion. 139 4436 0 0.D7 7 3 2.92 Corrosion. 140 4467 0 0.09 36 3 2.93 I ine corrosion. 141 4499 0 0.11 /1.1 4 2.92 Line corrosion. 142 4530 0 O.D7 n 4 2.92 Corrosion. U. DepOsits. I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-14 Kuparuk ConocoPhillips Alaska, Inc. USA September 17, 2006 Joint Jt. Depth Pen. Pen. /\¡Jel;¡1 Min. Damage Profile No. (Ft.) Ilns;! Body 1.0. Comments (%wall) (Ins.) (Ins.) 0 50 100 143 4562 0 0.08 3 ,+ 2.93 Corrosion. 144 4593 0 0.10 4 4 2.93 Corrosion. 145 4625 .,0 0.06 2, 2.93 Line corrosion. 146 4656 .0 0.07 .4 2.93 Line corrosion. Lt. D~posits. 147 4688 0 0.07 4 2.89 Line of oits. Lt. Deoosits. 148 4718 0 0.07 2 2.93 Corrosion. Lt. Deoosits. 149 4749 (I 0.08 2.92 Line of oits. 150 4781 0 0.07 2.92 Line corrosion. 151 4812 (I 0.07 2.91 Corrosion. Lt. DerJOsits. 152 4844 0.09 2.91 Corrosion. 153 4876 0 0.10 39 3 2.93 Line corrosion. 154 4906 .i 0.08 3 2.91 Line of pits. 155 4938 0.07 2 2.91 Corrosion. 156 4970 J 0.08 2.93 Line corrosion. 157 5001 ( 0.09 2.91 Corrosion. 158 5032 0 0.08 ¡ 2.92 Line corrosion. 159 5063 (I 0.12 'b 2.90 Corrosion ring. Lt. Deposits. 160 5094 0 0.11 [4 2.90 Corrosion ring. Lt. Deposits. 161 5124 .0 0.08 10 2 2.90 Corrosion. Lt. D€¿J:)Osits. 162 5156 j} 0.10 I( 2.92 Line corrosion. 163 5188 0 0.07 2.91 Corrosion. 164 5219 U 0.09 2.90 Line corrosion. Lt. Deoosits. 165 5250 0 0.07 2.92 Corrosion. 166 5282 (I 0.11 2.92 Corrosion. 167 5312 0.08 2.92 Line of pits. Lt. D~sits. 168 5344 I 0.06 24 2 2.92 Corrosion. 169 5376 J) 0.07 ) 2.92 Corrosion. 170 5407 J 0.06 2.92 Corrosion. 171 5439 0 0.09 2.92 Line of pits. 172 5471 U 0.06 2 2.91 Li ne of pi ts. 173 5503 0.09 2.92 Line of pits. Lt. De,Püsits. 174 5535 I. 0.09 I) 3 2.92 Line of pits. 175 5566 J 0.06 ..1+ 2.92 Line of oits. 176 5594 0.07 2 2.92 Line of oits. 177 5626 ! 0.09 + 2.91 Corrosion. Lt. Deoosits. 178 5658 0 0.11 , 2.92 Corrosion. 179 5689 0 0.10 2.92 Corrosion. 180 5722 0 0.08 3 2.92 Line of pits. 181 5752 U 0.10 J 2.91 Line of pits. 182 5785 0 0.09 _';7 4 2.91 Line of pits. 183 5817 J) 0.06 /4 2 2.91 Corrosion. 184 5848 0 0.12 J 2.92 Line of oits. 185 5880 0 0.08 3 2.91 Line of oits. 186 5911 0 0.07 2 2.92 Corrosion. 187 5943 0 0.09 37 2 2.93 Line corrosion. 188 5976 U 0.09 15 2 2.93 Line of pits. 189 6007 J1 0.13 'i 2.92 Line of pits. 190 6038 0 0.08 3 2.92 Line of oils. 191 6070 ( 0.09 3 2.93 Line corrosion. 192 6103 0 0.07 2 4 2.93 Line of pits. Page 4 Body Met:!1 Loss Body - I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: BodyWaJl: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 C- 1 4 Kuparuk ConocoPhiDips Alaska, Inc. USA September 17, 2006 Joint Jt Depth Pel Pen. Per \;$'1;11 Min. Damage Profile No. (Ft.) 'I Body !.D. Comments (%wall) liS) (Ins.) (Ins.) 0 50 100 193 6134 I) 0.09 ) 2.92 Une of nits. Lt. Demsits. 194 6166 $ 0.09 2.91 Une of nits. 195 6197 0 0.1 2.92= = Corrosion. 196 6229 () 0.1 2.93 Line of nits. 197 6261 () 0.07 29 2.93 Line of nits. 198 6293 0 0.08 3 2.92 Line of nits. 199 6325 1 0.13 50 "1 2.93 Line of nits. 200 6356 0.12 4 ;; 2.91 Line of nits. 201 6388 () 0.10 4 'I 2.92 Line of nits. 202 6420 n 0.12 4 4 2.92 Line of nits. 203 6452 () 0.11 4 ) 2.92 Line of nits. 204 6484 n 0.12 4 ) 2.91 Corrosion. Lt. Denosits. 204.1 6511 i 0.02 I 2.97 PUP 204.2 6520 .\ 0 n n N/A GLM 2 (Latch @ 2:30\ 204.3 6528 1 0.02 9 )" 2.92 PUP Lt. Deoosits. 205 6534 ! 0.11 L4 4 2.92 Corrosion. 206 6566 !) 0.11 ;\ 4 2.92 Corrosion. 207 6598 IY 0.10 l) 2.91 Line of nits. 208 6630 () 0.11 c2 2.93 Line of nits. 209 6662 () 0.09 35 2.92 Line of nits. 210 6694 n 0.09 34 2.91 Corrosion. 211 6726 n 0.08 3 1 2.92 Corrosion. 212 6758 n 0.11 ) 2.93 Corrosion. 213 6789 ( 0.12 I 2.92 Line of nits. 214 6821 \) 0.10 2.91 Corrosion. 215 6853 () 0.12 2.91 Line of nits. 216 6885 0.11 2.92 Line of nits. 217 6916 0.09 1 2.93 Line of oits. 218 6948 0.12 2.92 Line of nits. 219 6980 0.07 2.93 Line of nits. 220 7012 () 0.10 ;; 2.92 Line of nits. 221 7044 n 0.12 ) 2.93 Line of nits. 222 7076 () 0.12 2.92 Line of nits. 223 7107 () 0.12 7 2.91 Line of oits. 224 7139 () 0.14 ) 2.92 Line of nits. 225 7171 () 0.10 37 2.92 Line of nits, 226 7203 n 0.11 2.92 Corrosion. 227 7234 Ii 0.09 j 2,92 Line of nits. 228 7266 n 0.10 i" 2.93 Corrosion. 229 7298 C 0.11 ) 2.92 Line of nits. 230 7330 1 0.14 2.92 Corrosion. 231 7362 n 0.10 2.92 Corrosion. 232 7393 n 0.12 iJ 2.93 Corrosion. 233 7425 () 0.10 41 2.91 Line of nits. 234 7458 n 0.11 4, ;) 2.93 Line corrosion. 235 7489 () 0.09 ) ) 2.92 Corrosion. 236 7521 ! 0.12 4: . 2.91 Line of nits. 237 7552 ! 0.12 4. 2.92 Line of oits. 238 7584 n 0.08 ,3 2.92 Line of nits. 239 7617 () 0.ü7 2 2.92 Line of nits. Penetration Body Metal Loss Body Page 5 I PDS REPORT INT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf l-80 0,254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lC-14 Kuparuk ConocoPhillips Alaska, Ine. USA September 17, 2006 I I Joint jt. Depth PC'! Pen, Pen, ¡\Antal Min. Damage Pr ofìle No, (Ft.) I;::;(;t Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 240 7648 (I 0.08 I 2 2.93 Line of nits. 241 7679 (I 0.10 n 3 2.91 Corrosion. 242 7712 U 0.08 ) 2.91 line corrosion. 243 7743 (I 0.07 h 2.92 Line of nits. 244 7774 U 0.08 I 2.92 Line of nils. 245 7807 U 0.10 7 2.93 Line of nits. 246 7838 n 0.10 ß 2.93 Line corrosion. 247 7869 (I 0.11 2 2.94 Line of nils. 248 7901 n 0.10 3fJ 2.92 Corrosion. 249 7934 U 0.08 : 2.91 Line of oils. 250 7965 U 0.12 n 2.92 Corrosion. 251 7997 (I 0.12 2.93 Line of nits. 252 8028 U 0.08 ) 2.92 Corrosion. 253 8060 I) 0.09 I) 2.92 Line of nits. 254 8092 I 0.17 66 { 2.92 Line of nits. 255 8124 I 0.10 3 2.92 Line of nils. 256 8155 ( 0.08 ti 2 2.92 Line of nits. 257 8187 ( 0.11 2 2.91 Corrosion. 258 8218 0 0.10 2.92 Line of nits. 259 8249 0 0.12 2.92 Line corrosion. 260 8282 n 0.09 2.90 Corrosion. 261 8313 I 0.12 47 2.91 Line of nits. 262 8345 I 0.13 '52 2.92 Li ne of nits. 263 8377 0.08 ! ) 2.91 Corrosion. It De oosits. 264 8408 ) 0.08 2.92 Corrosion. U. Deoosits. 265 8440 0 0.09 2.92 Corrosion. 265.1 8471 0 0,05 ) 2.90 PUP Corrosion. It. Denosits. 265.2 8476 0 0 I N/A GlM 3 (lalch @ 9:001 265.3 8484 n 0.05 ;; 2.81 PUP Line corrosion. It. Denosils. 266 8491 0 0.12 40 2.91 Corrosion. It. Deoosits. 267 8523 0 0.08 22 2.92 Line of nits. 268 8554 (I 0.19 7· ,) 2.92 Corrosion. 269 8585 0 0.10 2 2.92 Line of oils. 270 8617 0 0.07 2 2.92 Line of oits. 271 8649 0 0.12 2.93 Line of nits. 272 8681 ( 0.13 2.94 Line of nits. 273 8713 0 0.09 2.92 line of nils. 274 8744 0 0.08 ) 2.91 Line of oits. 275 8775 0 0.09 2.92 Une of oils. 276 8808 0 0.12 i 2 2.92 Line of oits. 277 8839 0 0.11 2.91 Li ne of nits. 278 8872 0 0.08 2.91 Line of nits. 279 8902 n 0.12 2.91 Corrosion. 280 8934 0 0.08 21 2.91 Line of nils. 281 8966 n 0.06 2.91 Line of nits. 282 8997 0 0.07 2 2.90 Corrosion. 283 9030 0 0.09 2.92 Corrosion. 284 9060 0 0.11 2.91 Corrosion. 285 9092 0 0.07 2.91 Line of nils. 286 9124 0 0.09 2.91 Corrosion. I I I I I I I I I I I I I Body Metal loss Body Page 6 I I I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Waif: Nominal I.D.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1C-14 Kuparuk ConocoPhiflips Alaska, Inc. USA September 17, 2006 Joint J t. Depth Pen, Pen. Pen, ,.Lhl Min. Damage Profile No. (Fl.) 'I Body 1.0. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 287 9156 0 0.06 2 2.92 Corrosion. 288 9188 0 0.10 ¿ 2.91 Line of oits. 289 9219 0.10 2 2.91 Corrosion. 290 9251 0.07 2.92 Line of oils. 291 9283 0.05 20 2.92 Line of oils. 292 9314 0.05 20 2.92 Shallow line of oils. It Deoosits. 293 9344 ( 0.08 31 2.91 Corrosion. 294 9376 1 0.06 22 2.92 Line of oils, It Deoosits. 295 9408 ( 0.05 20 2.90 Shallow line of oils. 296 9440 ( 0.05 19 2.92 Shallow line of oils. 297 9471 I) 0.07 29 2 2.91 Corrosion. 298 9502 0 0.07 2ß 2.92 line of oits. 299 9536 0 0.05 19 2.92 Shallow line of oils. 300 9566 0 0.08 30 ) 2.92 Line of oils. 301 9598 0 0.05 20 2.92 Line of oits. 301.1 9630 0 0.ü3 12 4 2.93 PUP 301.2 9635 0 0 0 N/A GlM 4 (latch @ 4:30) 301.3 9641 ( 0.04 17 5 2.81 PUP Shallow corrosion. It. D~sits. 302 9650 ( 0.11 42 2.91 Line of oits. 303 9681 1 0.08 31 2.92 Line cnrrosion. 304 9713 ( 0.05 21 2.91 Line of oits. 305 9744 ( 0.05 2.91 Line of oits. 306 9777 I 0.07 2.92 Line of oits. 307 9809 0 0.09 2.92 Line of oits. 308 9839 0 0.ü7 2.91 Line of oils. 309 9872 ( 0.06 2 2.94 Line of pits. 310 9903 I 0.09 31 3 2.92 Corrosion. 311 9936 ( 0,08 31 2.93 Line of oilS. 312 9967 I 0.06 2.93 Li ne of oi ls. 313 9999 0 0.05 ) 2.92 Shallow line of oils. 314 10030 Ii 0.08 2.90 Line of oits. It. De oosits. 315 10063 I 0.07 2 2.92 Line of oils. 316 10094 0 0.07 2.91 Line of oils. 317 10125 J) 0.09 c14 2.92 Li ne of oi ls. 318 10158 0 0.07 213 2.91 I ine of oits. 319 10190 I 0.10 4() 2.91 Corrosion. 319.1 10221 0 0.03 ( 2.92 PUP Shallow line of oils. 319.2 10229 0 0 N/A GlM 5 (latch @ 6:00) * 319.3 10239 0 0.05 2.94 PUP Line of oils. 320 10240 0 0.09 () 2 2.92 Line of oils. 320.1 10272 11 0 J 0 2.75 D NIPPl E 321 10274 () 0.10 m 2.91 Corrosion. U. Deoosits. I\IIII!I! F£íIF£íI 321.1 10306 0 0 0 N/A Packer Seals rM 321.2 10311 0 0.07 2 2.94 PUP Line of oits. 321.3 10324 0 0.05 I 2.95 PUP Shallow line of oits. 321.4 10337 0 0 N/A End ofTubingTail Body Meidl loss Body Page 7 .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. PDS Report Cross S ons 1C-14 Kuparuk ConocoPhiflips Alaska, Inc, USA 3,5 ins 9,3 f L·80 September 17, 2006 MFC 24 :\lo. 040665 1.69 24 M. Lawrence Survey Date: Tool Type: Tool Size: :\lo, of Fingers: Anal st: Cross Section for Joint 268 at depth 8558.36 ft Tool speed ~ 50 :\lominallD ~ 2,992 Nominal OD ~ 3.500 Remaining wall area ~ 95 % Tool deviation ~ 81 0 Finger 5 Penetration ~ 0,187 ins Corrosion 0.19 ins ~ 74% Wall Penetration HIGH SIDE ~ UP Cross Sections page 1 .. .. - .. .. --....-- --.... ....- - .. PDS Report ross Sections Well: Field: Company: Country: Tubin : 1C14 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 1 7, 2006 MFC 24 No. 040665 1.69 24 M. Lawrence Cross Section for Joint 254 at depth 8099.33 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 64 0 Finger 3 Penetration = 0,167 ins Line of pits 0,17 ins 66% Wall Penetration HIGH SIDE UP Cross Sections page 2 - - - .. I I I Well: Field: Company: Country: lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 4.5 ins Weight 12.6 f Grade & Thread L-80 I I Penetration ami Metal Loss (% wall) penetration body metal loss body 20 I 10 I o o to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85%, I o o I pene. loss I Damage Configuration ( body) 10 I I o I isolated pitting general line ring hole / poss corrosion corrosion corrosion ¡ble hole I o I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 3.958 ins Nom. Upset 4.5 ins penetration body o 1 Bottom of Survey = 18 Analysis Overview page 2 I I September 17, 2006 MFC 24 No. 040665 1.69 24 M. Lawrence Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) metal loss body 50 100 11 I I PDS REPORT JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 1 C-14 Kuparuk ConocoPhiBips Alaska, Inc. USA September 17, 2006 I Joint Jt. Depth 1\,: Pen. Pen, i '\'1.f'!al Min. Damage Profile No. (Ft.) Body ¡ !.D. Comments (%walf) (Ins.) (Ins.) 0 50 100 1 10341 0 0.08 X¡y ;; 3.93 Line corrosion. Lt. Denosits. 2 10370 0 0.08 ìí ; 3.94 Line of Pits. 3 10401 0 0.11 1{ .: 3.93 I ine corrosion. 4 10430 0 0.09 4 3.93 Line of Pits. Lt. Dennsits. 5 10462 (I 0.10 3~ Line corrosion. Lt. Denosits. 6 10493 0 0.10 3. Line corrosion. 7 10522 o +*08 3.90 Line of Pits. U. Demsits. 8 10554 o 07 3.93 Line corrosion. 9 10585 o .08 ;::if 3.94 Line of Pits. 10 1061 6 0 0.13 'Iii) 4 3.85 Line corrosion. 11 1 0644 0 0.07 ::7 ;; '~ Line corrosion. Lt. Denosits. 12 10672 0 0.12 (. 3 Perforations. Lt. Dennsits. 13 10704 0 0.19 14 3.78 Perforations. U. Dennsits. 14 10734 (. 0.09 H 3.90 Line of Pits. 15 10764 0 0.06 7 3.86 line of Pits. U. Demsits. 16 10796 0 0.09 10 3.89 Corrosion. It. Demsits. 17 1 082 8 0 0.01 4- ì 3.87 18 10860 0 0.01 T I 3.92 I I I I I Body Metal Loss Body I I I I I I I I Page 1 I I ------ ------- - - ----- Well: Field: Company: Country: Tubin : lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA 4,5 ins 12.6 f L·BO Cross Section for Joint 10 at depth 10616.46 ft Tool speed = 50 ,',JominaIID = 3.958 Nominal 00 = 4.500 Remaining wall area = 96 % Tool deviation = 50 0 Finger 4 Penetration = 0,132 ins Line Corrosion PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 17, 2006 MFC 24 No. 040665 1,69 24 M. Lawrence 0.13 ins 49% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ------ ------- - - -- - .. PDS Report Cross Sections Well: Field: Company: Country: Tubin : 1C-14 Kuparuk Conocophillips Alaska, Inc. USA 4.5 ins 12.6 f L.80 SUlVey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 17, 2006 MFC 24 No, 040665 1.69 24 M, Lawrence Cross Section for Joint 3 at depth 10424.64 ft Tool speed = 48 l'\Iominal ID = 3.958 Nominal OD = 4,500 Remaining wall area = 98 % Tool deviation = 44 0 Finger 3 Penetration = 0,108 ins Line Corrosion 0.11 ins = 40% Wall Penetration HIGH SIDE = UP Cross Sections page 2 I I ~' I SSSV (1830-1831, 00:3,500) TUBING (0-10336, 00:3.500, 10:2.992) I Gas Lift I ndrelJOummy Valve 1 (3835-3836, 00:5.500) I Gas Lift I ndrel/Dummy Valve 2 (6523·6524, 00:5.500) I I Gas Lift ,. ndrel/Dummy Valve 3 (8478-8479, 00:5,500) I Gas Lift I ndrel/Dummy Valve 4 (9634-9635, 00:5,500) I Gas Lift I ndrel/Dummy Valve 5 102:26-10227, 00:6,018) I NIP 10272-10273, 00:3,500) I I PKR 10300-10301, 00:6.151) LINER 10300-10980, 00:4,500, Wt:12,60) I SEAL 10311·10312, 00:4,000) I SBE 10321·10322, 00:4.500) I I m 10337·10338, 00:3,500) I Perf 10070-1(696) -_. -- Perf -, ~.~~- 10696-10716) _._~ -- ~ ~ --- '- '-_. '-'- -- I I KRU 1C-14 I "IC-14 API: 500292286100 SSSV Type: TROP Well Type: INJ Orig 3/411998 Completion: LastW/O: Ref Log Date: TO: 10980 ftKB Max Hole Angle: 59 deg @ 7450 Anole av TS: 40 deo av 10664 Angle @ TO: 40 deg @ 10980 Annular Fluid: Reference Log: Last Tag: 10725 L ate: 12/27/2005 I../ALL Rev Reason: TAG FILL Last UDdate: 12/31/2005 Description Size Top Bottom NO Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SURF. CASING 9,625 0 7292 4525 40.00 L-80 PROD. CASING 7.000 0 10503 6409 26,00 L-80 LINER 4.500 10300 10980 10980 12.60 L-80 1/ ..~ Size I Bottom i NO I Wt I Grade Thread 3,500 I 10336 I 6285 I 9,30 I L-80 I ABM EUR Interval 10670 - 10696 10696·10716 NO 6536 - 6555 6555 - 6571 Zone C-4 C-4,C-3 Status Ft SPF Date Tvoo Comment 26 4 11/21/1999 APERF 2.5" HSD, 180 deg ph 20 4 3/17/1998 IPERF 2.5" HSD, 180 deg ph; oriented +/- 90 deg from low side IGa~/~ St MD I ND Man Mlln Type Mfr 1 383512588 Cameo KBMM 2 6523 Cameo KBMM 3 8478 Cameo KBMM 4 9634 II Cameo KBMM 510226 62061 Cameo MMM IOt1'l~¡' (cluClS" /ScIÜic,èt, .r ~JI:\I\II: DeDth NO T'Ioe 1830 1474 SSSV 10272 6239 NIP 10300 6259 PKR 10311 6267 SEAL 10314 6269 HNGR 10321 6274 SBE 10337 6286 TTl NOtIS Date Nota 8112/1998Asphaltines in tubing@ 10190' VMfr V Type VOD latch Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0,000 0 OMY 1.0 BK 0.000 0 OMY 1.5 RK 0.000 0 !:IV Description Date Run 318/1998 318/1998 318/1998 318/1998 3/8/1998 Vlv Cmnt ID 2.812 2.750 4.438 3.000 4.438 4.000 2.992 Cameo 'TRDP-4E' Cameo '0' Nipple NO GO Baker 'ZXP' Pkr Baker Locator SEAL ASSY Baker 'HMC' Liner Haf1ger Baker . . ~¡eû IG- J4 9 B- or=¡ MECHANICAL INTEGRITY REPORT' ""- SPUD DATE: .: '2-I,\5"I~ ~ RIG RELEASE: ~II':J\"~ OPER & FIELD Ì\'ELL NUMBER A.A \ ~p...u 9f>-J1 . WELL DATA .TD:. )o~ f)eMD.. bi,2. TVD: P B TD : loß~~ MD bbC) f> TVD C . 1-" "l,bAk Shoe: lo50~ TVD¡ DV: MD -TVD as~ng: 1-' ~ '¿) MD rz...c.... till Liner: -"'I. ':)1\ &..' ßC Shoe: Jo ~oo rm- \o9~ð TVD i TOP: TVD Tubing: 5'1z," Packer )a~ot)' HD TVD¡ Set at lo3~b _. " . .'. Hole Size ~.\z.s,. and 8'1z, ¡ Perfs )Obqb to lo1Jb MECHANICAL INTEGRITY - PART 11 Annulus Press Test: IP J 15 min 30 min Comments: ",- .. ~rt:.~~~~u~cX~~ ~~~~\\~, MECHANICAL INTEGRITY - PART #2 \ 1ct-<ì.~ -Q~ ('(' \ (' \ (\ r.. \\ _ ... ~ r<)ù~~c.~(.....~~\~~(J O~~\ Cement Volumes:' Amt. Liner I~ ~"J. Csg J~o~')C. ; DV ",,/ZIZ·"'~-::.o13JCwt vol to cover perfs _ S s~fJ.F --=1 . I -9 2.2., t:J 1.'/6 -'::.\=1~ð ~JF "O~~Ð"'o!J8~))..O:¡311- L\0980-1~&,:)')x.I~1'8"'llo~8D-loI.~b,)x.o~~ðO~X Wz C -l,'/ð " . ::::::=.. .o~42C?~Theoretical TOC - I ZA 2- :: . o~~ sf./LF \ o.(,~ b - [t 130 - .~o J -;-- . 0'- ~oS" J:: 9"'S~ Cement Bond Log (Yes or No) No In AOGCC File CEL Evaluation, zone above perfs Lo7rJ ¡/'2.~ljq - E~ C.D ((Qý-f VoM..((~j ~7T(/"Q .;~ Produ~tion Log: Type J Evaluation .:c CJ::¡¡;:.~ ~ r A1-~'W1 ,.- \ /,-\-0'> . - ø e/:~I ¡J. \t()~ <! ~J . \(j'~ 'f.i? r (b1~VQ)~ c.; -CONCLUSIONS: P ar t # 1 : Part 12: J-11 is ¡f\i{)/CA7fJ) cOt- l~ þlC ~ 3("iJ(t¡., ~ _~, ',,, ß l' Uv\Í ~ () I-UN\ -G,<-, IANV! I L ~ I ð 1'-') ~ .---:=, tft<1YV\ t{ \..\-0 G nl:"''"tnfn-, ,.. "'''''''''' e . FRANK H. MURKOWSKI, GOVERNOR AI,J\SIiA OIL AND GAS CONSERVATION COMltDSSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer Conoco Phillips Alaska, Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ¡q<ù-Ol7 Re: Kuparuk 1 C-14 ,·¡¡t,,~\~\\B3-; '~"'-r;?I{\.~ '\'" " Sundry Number: 306-005 t·<¡· Dear Mr. McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this.i day of January, 2006 Encl. ().1f 1/ 1-/1;. , # I.;{;.,of, e STATE OF ALASKA _ Æ.1t¡ = " =1' ALASKA OIL AND GAS CONSERVATION COMMISSION ~ R _C_ VED APPLICATION FOR SUNDRY APPROVAL JAN 032006 20 AAC 25.280 1, Type of Request: 181 Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension Alaska Oil & Gas Cons. Commission Anthorage 2. Operator Name: Conoeo Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 1m Service 5. Permit To Drill Number 198-017 V"'" 6. API Number: 50-029-22861-00-00 V 99519-6612 11. Total Depth MD (ft): 10980 Casing Structural Conductor Surface Intermediate Production Liner 9. Well Name and Number: Kuparuk 1C-14 10. Field / Pool(s): Kuparuk River Unit / Kuparuk River Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): 6772 10714 6569 Length Size MD TVD 41' 8. Property Designation: ADL 028242 Plugs (measured): None Burst Junk (measured): None Collapse 121' 16" 121' 121' 7292' 9-5/8" 7292' 4525' 5750 3090 10503' 7" 10503' 6409' 7240 5410 680' 4-1/2" 10300' - 10980' 6259' - 6772' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 10670' - 10716' 6536' - 6571' Packers and SSSV Type: 7" x 3-1/2" Baker 'ZXP' packer; 3-1/2" Camco 'TRDP-4E' SSSV Tubing Size: 3-1/2",9.3# Tubing Grade: L-80 Packers and SSSV MD (ft): 10300' 1830' Tubing MD (ft): 1 0336' 12. Attachments: 1m Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development 1m Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sean McLaughlin Title CT Drilling Engineer .~~j\ltl/~ January 20, 2006 Date: 15. Well Status after proposed work: o Oil o Gas o WAG 0 GINJ o Plugged DWINJ 1m Abandoned o WDSPL Contact Sean McLaughlin, 564-4387 Signature Phone 564-4387 Commission Use Only Date l/3/0£ I Sundry Number:3jl I) ...tX)5 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other: S500 ~\ M ('.'\II'-\.~<H...·\SO\?\e.",>\- RBDMS BFL JAN 0 5 2DD6 COMMISSIONER APPROVED BY THE COMMISSION Date /_J_/)b SUb¡it In Duplicate e e Thomas Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission To: ~ ~~~:. Date December 27. 2005 ~ ?J µ. ~Árt' r"ti'/ Re: IC-14 Sundry Approval r ;r- ~~ ~úr ~ WelllC-14 was drilled and completed in March 1998 as part ofthe Gas Storage Area (GSA) redevelopment. The well was (/1('0 completed and fracture stimulated in the C4/C3 sands with -27M Ibs 12/18 propp ant. An initial SBHP was measured at \ 3731 psi (high pressure confirms gas storage in the area). The well was brought on-line April 1998. Oil production declined by January 1999, at which time the well was converted to injection. From: Sean McLaughlin CTD Engineer The lC-14 provides water and MI injection support for lC-16 to the north and lC-23 to the east. Current bottom hole pressures for the lC-14 and lC-22 injectors have been requested as part of the evaluation for this CTD prospect. The lC-14 injection pattern is bounded on the north, south, and east sides by likely sealing large fault networks. lC-14 has been selected for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around January 27, 2006. A single lateral is proposed as a pre-produced injector. lC-14A, will exit the 4-1/2" liner from a /'" mechanical whipstock in the target C sand. The existing perforations will be isolated by a cement squeeze and the liner V cement job. The following describes work plannèd and IS submitted as an attachment to Form 10-403. A schematic diagram ..... of the proposed sidetrack is attached for reference. CTD Drill and Complete lC-14A: Planned for Januarv 20. 2006 Pre-Rig Work 1. DHD 2. DHD 3. DHD 4. DHD 5. DHD 6. S 7. C 8, S 9. S 10. E 11. C 12, 0 13, 0 14. 0 15. 0 MIT-IA, and OA. PPPOT-T & Ie. PT Master & Swab to 4500 psi. Drawdown test on Master & Swab to 0 psi. Drawdown test SSSV. Obtain SBHP (3-5 day shut-in); Drift & tag PBTD. FCO to 10800' Drift and Tag; Caliper log to PBTD Run dummy whipstock drift (2.7" x 10') T~ '\ > c. 'O(')~(:)~o...\ Set 3-112" x 4-1/2" Baker TTWS at 10742' t'" P&A liner - 15.8 ppg cmt squeeze PT cement plug to 1500 psi. Torque wellhead bolts to spec. ~ Bleed gas lift and production flowlines down to zero and blind flange Remove wellhouse, drill mouse hole, level pad ~W~ I 1. MIRU Nordic 2, NU 7-1/16" BOPE, test .. 2. Mill 2.74" window off a whipstock. The planned KOP is at 10742' in the C sand. 4'0 \ CA~Ç~\ 3. Drill 3" bicenter hole horizontal lateral from window to 14,200' TD targeting Kuparuk C sands. t'\E..t:..'ðCêc) 4. Complete with a 3 segmented 2 3/8" solid/slotted liner from TD to 10285' md. Use SSSV for liner run. 5. Cement liner from the 10670' to -12500'. Slotted liner will be below this point. 6. Cleanout liner and mill baffle plate. 7. ND BOPE. RDMO Nordic 2. Post Rig work 8. Post CTD rig -Run GLVs. Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble Pert :10671).10696) Pert :10696·10716) ~ ~ m SSE SEAL Gas Lilt "" NIP 2588 4094 5195 10212 10300 10311 10314 10321 Note in tubing @ NIP PKR SEAL liNGR S8E TIl 10190' Cameo 'TRDP-4E' Cameo 'D' Nipple NO GO Baker 'lXP' Pkr Baker locator SEAL ASSY Båker 'liMC' Liner lianger Baker ID 2.812 2,150 4.438 3.000 4.438 4.000 2.992 KBMM KBMM KBMM KBMM MMM JEWELRV DMV OMY DMY DMY OMY Description 1.0 1.0 1.0 1.0 1.5 BK BK BK 81< RK 0.000 0.000 0,000 0.000 0.000 o o o o o Date Run 3/8/1998 31811998 31811998 31811998 31811998 Vlv Cmnt Man Type V IIMr V Type VOD 3/11/1998 ¡PERI" 2.5" liSD, 180 deg ph; oriented +1- 90 deg from low side Latch Port TRO 10696 3.500 Imerval 1(1610 - 10696 10116 6555 6571 6536 - 6555 C-4,C-3 Bottom 10336 C-4 Status 20 ft 26 4 Wt 9.30 Date 11/21/1999 2.5" Thread ABM EUR liSD, 1S0 de!;! ph SURf. CASING PROD. CASING LINER Size 16.000 9.625 MOO 4.500 TQP o (I o 10300 TVD 6285 1292 Grade L-80 TVD '121 4525 6409 10980 40.00 26.00 12.60 Grade 1i-40 All STRINGS Annular fluid: Reference last last Tag Date: 10114 10/15/2004 TUBING sssv API: 500292286100 SSSV Type:· TRDP Ref Thread ftKB 59 @ 1450 Well INJ 3/4/1998 Rev Reason: FILL last Update: KRU Angle @ TS: 40 @ Angle @ TO: @ 1 10664 109110 4 KRU 1 C-14A C-sand Injector Proposed Completion ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9-5/8" 40# ....J L-80 @ 7292' ~ ~ ~ ~ ~ 7" 26# L-80 @ ~ 10503' MD KOP 10742' MD, in C-sand 4-1/2" 12.6# L-80 - '" --........... .-- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 'H ~ ~ ~ ~ ~ ~ 3-%" muleshoe @ 10336' MO ~ ~ ¡;¿ ~ ¡;¿ ~ ~ ~ ~ ~ ~ ¡;¿ ~ ¡;¿ ~ 3-1/2" Cameo TROP-4E SSSV at 18301 MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing ConocóPhillips Alaska, Inc. '1..- 3-¥2" Cameo KBMM GLM's @ 3835': 6523': 8478': and 96341 MD 3-¥2" Cameo MMM GLM @ 102261 MD -' _iiJ;'.1if)<;fK%f.,. 3-¥2" Cameo OS nipple, 2.75" min 10 @ 102721 MD c--J 2-3/8" STL liner top wI "G" fishneek and seal bore @ 10290' MD Baker ZXP Packer w/SBE @ 103001 MD Bonsai cire subl baffle plate Squeezed C sand peñs 10670' - 10716' md . . . . ~ . . . . . . " . . ....................... .. .. . .. " .. .. . . .................... . . . . . . . . . .. .. .. . . .. .. .. . .. . . .. .. . .. . . .. . . . .. . . . . . . . . .. . .. . .. . . . . . . .. . .. . .. . . . . . .. . . .. . . . .. . . .. .. . . .. . . . . . - . . . . . .. .. .. . . . . . .. .. .. . . .. . . .. . . . . . .. . .. .. .. . . .. . . .. . . . . . . . 3-%" X 4-%" Baker whipstock 3" openhole . . . . . . . . . . . . . . . . . - ~ 1 C-14A TD @ 14,200' md \ ) ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska, Inc. KRU 1C 12/09/05 Rodgers/Sauvageau AES /' \ {1/11 \'4J Packer Depth Pretest Initial 15 Min. 30 Min. Well1C-14 Type Inj. W TVD 6,259' Tubing 2350 2350 2350 2350 Interval 0 P. T.D. 1980170 Type test P Test psi 1565 Casing 1300 3000 2990 2990 P/F P Notes: Diagnostic MITIA pre-CTD OA 350 500 500 500 Well P.T.D. Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) ~CANNED IJEC 1 6 2005 MIT KRU 1C-14 12-09-05.xls ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 '--¡v")!'f' l F tLd¡Jlj Subject: Report of Sundry Well Operations for 1 C-14 (APD # 198-017) Dear Commissioner: ConoeoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 C-14. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Hl / MtrrÞJ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNEC NO\f 2, Li 2004 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 41', Pad 61' 8. Property Designation: ADL 28242, ALK 2292 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF. CASING PROD. CASING LINER Perforation depth: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing 0 Operat. ShutdownO Stimulate 0 Waiver 0 Other o o o Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 198-0171 6. API Number: 50-029-22861-00 Exploratory Service o o 9. Well Name and Number: 1 C-14 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 1 0980' feet true vertical 6772' feet measured 10714' feet true vertical 6569' feet Length Size MD 121' 16" 121' 7191' 9-5/8" 7292' 10402' 7" 10503' 680' 4-1/2" 10980' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4527' 6409' 6772' Measured depth: 10670'-10716' true vertical depth: 6536'-6571' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10336' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'ZXP' PKR pkr= 10300' SSSV= 1830' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10670'-10716' 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 1503 2107 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO GasO WAG0 GINJO WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 705 bbls of slick seawater Oil-Bbl n/a Casinq Pressure Tubinq Pressure 2092 2086 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature WDSPLD Mike Mooney @ 263-4574 Mike Mooney Title Phone Kuparuk Wells Team Leader Date 111 z.. ,-)ö i Preoared bv Sharon Allsuo-Drake 263-4612 IV/,M~ HBUMS at-L NOV?, 9. 7004 Form 10-404 Revised 04/2004 Submit Original Only ') 1C-14 Well Events Summary ) Date Summary 10/31/04 POOR BOY HPBD COMPLETED. PUMPED 705 BBLS OF 55 DEGREE SLICK SEAWATER. MAX WHTP 3800 PSI & MAX RATE OF 9.6 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN. [HPBD] ) Con,ocoPhiIUps· _.Alask.a,lnc. 1 C-14 SSSV 11830-1831, 00:35001 TUBING \0-1ü3:<6. 00:3.5CII), 10'2 ~921 G.:;", Lift ,nQrtl/OlJmmy Valv.; 1 13835·3836. 005.500, Ga5 Lilt ·,ndrtl/Oummy Val-Ji? :< 16523-652-1. 005.5001 G"s Lift ,n'JrellOlJmmy '/al'.", 3 13-178·8-179. ûD ~I. 5Ü(¡ I Gas Loil in'Jr",I/OlJm m y Valv", .. 1963-1·9635. 0055(10, Ga;_ Llit In'Jr'¡-IIOummy Val,~ 5 .1 (1;'.26-1Ij227'. 00'(1)18, rllP 11).27i·10.273 OD j 500i PKR 1('JOO-1')301. 0061511 LNER 11) )(11). 1 (/';'80, 00 -I 5(11), WI 126(" SEAL 10311-10312 'JD .. (II)'} 1 SBE 1 '):'21·1ID22. OO.. 500, TTL 10:<]7-1\):<38. GO 15001 Ptrf 1')670·1('6';'6) P",rf 1('6~6·1,)71;:;) .11 " L I : · . f ì I ò ~ ! ~ r I_·~ ~ Im__~ f ì ¡ I I -iW .-. - - - ~ f¡ ~ f r. ¡ I ¡') ro .- ~. ~Itt ~ I ,~. ---~.- i ~ ;1. ---tJ~ 11---.. · .!J -, - . . - , ::.~ .1. pll:'~-~1 ,1: I ~ J' ~~' I.' I II I . I, ~'LI_. ! ~ ~ . -[ , ¡ 1 . J - API: 500292286100 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 10714 Last Tag Date: 10/15/2004 Casing String - ALL STRINGS Description CONDUCTOR SURF. CASING PROD. CASING LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 10670 - 10696 6536 - 6555 10696 - 10716 6555 - 6571 ) KRU 1 C-14 Well Type: INJ Orig 3/4/1998 Completion: Last W/O: Ref Log Date: TO: 10980 ftKB Max Hole 59 deg @ 7450 Angle: Angle (ã> TS: 40 deg (ã> 10664 Angle @ TO: 40 deg @ 10980 Rev Reason: TAG FILL Last Update: 10/18/2004 Size Top Bottom 16.000 0 121 9.625 0 7292 7.000 0 10503 4.500 10300 10980 Bottom TVD Wt 10336 6285 9.30 TVD 121 4525 6409 10980 Wt 62.58 40.00 26.00 12.60 Grade H-40 L-80 L-80 L-80 Thread I Grade I L-80 Thread ABM EUR Zone Status Ft SPF Date Type Comment C-4 26 4 11/21/1995 APERF 2.5" HSD, 180 deg ph C-4,C-3 20 4 3/17/1998 IPERF 2.5" HSD, 180 deg ph; oriented +/- 90 deg from low side Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3835 2588 Cameo KBMM DMY 1.0 BK 0.000 0 3/8/1998 2 6523 4094 Cameo KBMM DMY 1.0 BK 0.000 0 3/8/1998 3 8478 5195 Cameo KBMM DMY 1.0 BK 0.000 0 3/8/1998 4 9634 5851 Cameo KBMM DMY 1.0 BK 0.000 0 3/8/1998 5 10226 6206 Cameo MMM DMY 1.5 RK 0.000 0 3/8/1998 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 10 1830 1474 SSSV Cameo 'TRDP-4E' 2.812 10272 6239 NIP Cameo 'D' Nipple NO GO 2.750 10300 6259 PKR Baker 'ZXP' Pkr 4.438 10311 6267 SEAL Baker Locator SEAL ASSY 3.000 10314 6269 HNGR Baker 'HMC' Liner Hanger 4.438 10321 6274 SBE Baker 4.000 10337 6286 TTL 2.992 General Notes Date I Note 8/12/1998 Asphaltines in tubing (ã> 10190' - ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission '1//) J TO: Randy Ruedrich It ~4( i:» Chair " DATE: June 18, 2003 SUBJECT: Mechanical Integrity Tests THRU: Jim Regg <r?IlA . 1V(\07 ConocoPhillips Alaska Inc. P.I. Supervisor \ '*/t 1 C 190,09, 14, 17,26 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 1 C-190 Type Inj. S T.V.D. 3833 Tubing 1000 1000 1000 1000 Interval ./ P.T.D. 2030030 Type test P Test psi 958 Casing 3000 3000 3000 3000 P/F Notes: Well 1 C-09 Type Inj. S T.V.D. 6205 Tubing 2370 2368 2370 2367 Interval 4 P.T.D. 1821850 Type test P Test psi 1551 Casing 400 3100 3125 3100 P/F f Notes: Well 1C-14 Type Inj. G T.V.D. 6259 Tubing 3806 3811 3826 3823 Interval 4 P.T.D. 1980170 Type test P Test psi 1565 Casing 50 3000 3000 3000 P/F f Notes: Well 1C-17 Type Inj. S T.V.D. 6145 Tubing 2370 2370 2372 2367 Interval 4 P.T.D. 1982240 Type test P Test psi 1536 Casing 1000 3100 3100 3050 P/F f Notes: Well 1 C-26 Type Inj. S T.V.D. 6433 Tubing 2258 2258 2257 2258 Interval 4 P.T.D. 1990510 Type test P Test psi 1608 Casing 900 3000 3000 3000 P/F f Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: cc: MIT report form 5/12/00 L.G. 2003-0618_MIT _KRU_1 C-26-Ïs.xls 7/9/2003 SC,~NNE'[:, ;l\UG Ü 112003 /. ) ·ConocóP'hillips January 10, 2003 Cammy Oeehsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: ) Randy Thomas I Cj~ -oj 7 Greater Kuparuk Team leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas@ppco.com Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, \\~~~ R. Thomas Greater Kuparuk Team Leader RT/skad ce: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison I R. Overstreet Sharon Allsup-Drake Well Files RECEIVED A ¡:' (2' 0 (r~ , \ ^-N \ -J v"-! Alaska Oil&.ß~.S cons, . Commission , ~líANNIiUr~AN: 2 4 2003 Annular Disposal during the fourth quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dee 2002 3S-09,3S-14,3S~10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 3S-18 ) Total Volumes into Annulifor which Disposal Authorization Expired during thefourth quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze· Protected October Sept 2002 CD2-15, CD2-47, CD2~ 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January lC-109, lR-36, lC-24 2001 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-I7 2002 2002 Cook Inlet Annular Disposal during the fourth quarter 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October 2002 2002 Source Wells Hansen # 1 SCANNED JAN 2 4 2003 Annular Disposal during the first quarter of 2002.- h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly # 1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 lC-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 /9g"01 Î 2001 2002 CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 ( 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 Freeze protect only for CD2-26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only Total Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2002.- Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus ( ID-32 23162 100 0 337 23599 Open, Freeze Protected January February ID-39 2001 2001 IJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 Annular Disposal during the fourth quarter of 2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, ) 2001 CD2-14 lC-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 I q <6 ..0 J"1 lC-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 IC-109 2P-438 30331 100 0 30431 212 0 30643 Oct 200 1 Dec 2001 2P-420,2P-415,2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47 10315 100 0 10415 375 0 10790 Dec 200 1 Dec 2001 CD2-34 Total Volumes into Annuli for which Disposal Authorization Expired during the fourth c;uarter 2001: Freeze Protect Total Volume Start End Source Wells ) Total h(l) Total h(2) Total h(3) Fluids Injected Date Date :J> Well Name Volume Volume Volume Volume Status of Annulus m en :::c ::II::" 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2000 2L-317,2L-307 m º c:..... m ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 ID-42, ID-34 S20 Þ »G) Z () CDl-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CD 1-14 ~Q) (")en 2001 gC') ~ m æg C.C) - 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect teen < CD· c') '"'-' volumes only 0 c::> 3 C) m ID-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2000 ID-32, ID-40A 3 r--... ~ ãr 0 Open, Freeze Protected en 2N-349A 0 0 0 0 0 ër ~ ID-42 32040 100 0 265 32405 Open, Freeze Protected Dec2000 Jan 2001 ID-37, ID-39 r 01." ~) ~ PHilliPS Alaska, Inc. m. A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,yaska 9951~60 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: ) '-.1 Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 200 1, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 200 1. Please call me at 265-6830 should you have any questions. Sincerely, ~~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental: Engel I Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files ~€.c€.\\I€.O ~ ~ l~~l j ~ ~ ~~\O'(\ \}:fI\s, Gomm a·~ &. Gas n.e þ..\~~'ð ~ p..'(\c"o1'ð~ Annular Disposal during the fourth quarter of 2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes lQf ~. ~~7 CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 o t - fr9 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 lO( , qs CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 Ct~~Jllb lC-16 12338 100 0 12438 0 19679 32117 Sept 200 1 October lC-131, lC-125, lC-102 2001 1 ~O,-' fW CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15,CD2-47 2001 2001 lOI ~ 117 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 ~~-<J11' lC-14 22389 100 0 22489 0 0 22489 Oct 200 1 Nov 2001 1 C-l 09 ~ t--g;t 2P-438 30331 100 0 30431 212 0 30643 Oct 200 1 Dec 2001 2P-420, 2P-415, 2P-429 ;P1 ,t5~ . CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only 'Dl ;';05 CD2-47 10315 100 0 10415 375 0 10790 Dec2oo1 Dec2oo1 CD2-34 Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2001: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date :1> Well Name Volume Volume Volume Volume Status of Annulus m I '18-~\~ en ;0' 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2000 2L-317,2L-307 Kf ~' º c.... m'>- , <D." l3=f ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, ID-34 Si!O ):::t »G') Z 0 CDl-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CD1-14 :;:'Q) ~Q:)-118 0(1) 2001 5C) t-.,:) m QJO 2N-305 380 Open, Freeze Protected NA** NA** ** freeze protect cc::J CoD - ~-l35 0 0 0 380 CD~ < 9 1"-0 volumes only <:::I ~())- [1,13 3 C) m ID-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2000 ID-32,ID-40A 3 r.....J ü¡- 0 ;p:>~' (3 q 2N-349A 0 Open, Freeze Protected en 0 0 0 0 õ' :::¡ tD:)-··' ~ ID-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 ID-37, ID-39 Annular Disposal during the fourth quarter of 2001.- h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume V olulne Volume Quarter Protect Total Total Date Date Volumes 1';:- ~/-¿'''? CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 ;.0/ -0(.,7' 2P-417 5331 100 0 5431 0 627 6058 Sept 200 1 December 2P-420, 2P-448 2001 o/-¿)9::¡ . CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 I f'i )7'C~ lC-16 12338 100 0 12438 0 19679 32117 Sept 200 1 October IC-131, lC-125, lC-102 2001 ")-¿:J/-/ ~o CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 ,0/-/7'7 CD2-14 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 'f¿( 0/7 IC-14 22389 100 0 22489 0 0 22489 Oct 200 1 Nov 2001 lC-109 -.0 / - t,? ga-' 2P-438 30331 100 0 30431 212 0 30643 Oct 200 1 Dec 200 1 2P-420, 2P-415, 2P-429 lo/ - /S?, CD2-IS 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only ~o / -,;) ¿J ~ CD2-47 10315 100 0 10415 375 0 10790 Dec 200 1 Dec 2001 CD2-34 Total Volume.\· into Annuli for which Disposal Authorization Expired during the fourth quarter 2001.- Freeze Protect Total Volume Start End Source WeUs Total h(l) Total h(2) Total h(3) Fluids Injected Date Date ::Þ Well Name Volume Volume Volume Volume Status of Annulus i» %~ J/ en ;C ~ 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec2000 2L-317,2L-307 Q) .Q c.... m 2 c?(."' /:...:';'( I 11)-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 ID-42, ID-34 S20 þ ::t>G) Z 0 CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200 1 March CD 1-14 ~Q) ;J ¿J(' /i/';- °en 2001 50 ~ m Open, Freeze Protected NA** NA** ** freeze protect Æg Co.;,) - ).or:.) /,.;,) 2N-30S 0 0 0 380 380 CD~ < 0 f'o0 volumes only 0 <=:) r ,._____ 3 c:::> m ) c (' . / 'I <_.___..1 1>:34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec2000 ID-32, ID-40A 3 1'.) ëñ- 0 en it'i' ,,/ II) ,__.~N-]49A 0 0 0 0 0 Open, Freeze Protected 0- ~ ...1 (..~'.''c-., " ,'". II I D-42 32040 100 0 265 32405 Open, Freeze Protected Dec2000 Ian 2001 ID-37, ID-39 ~ '-'-' ,--", ..--- ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS :. '1:;Ppe.~åti~riS· perfotmed:: . - , . . .. . . ... Operation shutdown_ PuJl tubing _ . . .. ... . ... ........ . .. . 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1564' FNL, 4138' FEL, Sec. 12, T11 N, R10E, UM At top of productive interval 1502' FSL, 1550' FEL, Sec. 6, T11 N, R11 E, UM At effective depth At total depth 3698' FNL, 1360' FEL, Sec. 6, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical 1 0980 feet 6772 feet Effective depth: Stimulate Aller casing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service_X (asp's 562146,5968672) (asp's 569796,5971884) Plugs (measured) Plugging _ Perforate Repalrwell_ Olher _X WlNJ to WAG 6. Datum elevation (OF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-14 9. Permit number I approval number 198-017/ 10. API number 50-029-22861 11. Field I Pool Kuparuk Oil Pool measured feet Junk (measured) true vertical feet Length Size Cemented Measured Depth True vertical Depth 121' 16" 9 cu Yrds High Early 121' 121 ' 7191' 9-5/8" 612 sx AS III LW & 348 sx Class (; 7292' 4527' 1 0402' 7" 130 sx Class G 1 0503' 6409' 680' 4-1/2" 130 sx Class G 1 0980' 6772' Casing CONDUCTOR SURF. CASING PROD. CASING LINER LINER Perforation depth: measured 10670-10696; 10696-10716 true vertical 6536-6555; 6555-6571 Tubing (size, grade, and measured depth) 3-1/2.', 9.3#,l-80 Tbg r@ 10336' MD. Packers & SSSV (type & measured depth) BAKER 'ZXP' PKR @ 10300' MD. SET ON 3123/98 @ 1830' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. n.~ f"~I'j___"r\ /If '~'.ij:'~~~ ~t~~"~ ~ '~,¡I . ~ ......., t¡.",..,' 1'-0 \W D JAN' () 8 lðoz. I~lae-!(a (" :1 ,) G . '" , ..' h lX ;;:.I....O~1~. Commission Anchoraqe Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 3952 Tubing Pressure 2658 3800 Subsequent to operation 2727 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 0,1 Gas ' 'Sûspend8d~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 1]-. S ~ Title Production Engineering Supervisor Jeff A. Spencer Prior to well operation Form 10-404 Rev 06/15/88· Casing Pressure 1250 1250 Service _X WAG Injector Questions? Call Jeff Spencer 659-7226 ..-:-- Date'lâ¡/¡. 03 ~O2- Prepared by Robert Christensen 659-7535 JAi\! ':J- o F< \ G \ l\~ j~\ L R B 0 M 5 B F l 9ÎOO? SUBMIT IN DUPLICATE -) 1 C-14 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary ) ~¡s" PHilLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY ) Post Office Box 100360 Anchorage, Alaska 99510-0360 c. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 October 9, 2001 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 1 C-14 Application for Sundry Approval T~\'~*Gr-ot', \ C·_"\~ <.. , ~~ - ddS\ wet<::. (). \~O ~\C\,"t~~ 'TIxJ'\~~,,-\'S tV\, ~~ \1...% \l-C; \ ~ '$7Jv¡ Vs-o F> Dear Commissioner Taylor: Phillips Alaska, Inc. hereby files this Application for Sundry Approval for annular disposal down the Kuparuk 1C-14 well. Please find attached for your review: Application for Sundry Approvals Form 10-403 (1 page) · Annular Disposal Permit Transmittal Form (1 page) · 1 C-14 Well Schematic ( 1 page) · 1C-14 Horizontal Clearance Plot by Baker Hughes Inteq (1 page) · 1C-14 Horizontal Clearance Report by Baker Hughes Inteq (1 page) · 1C-14 Hourly Operations Report (5 pages) · 1 C-14 Surface Casing Running Report (1 page) · 1C-14 Surface Casing Cementing Report (1 page) · 1 C-14 Surface Casing Drill Out FIT Report (1 page) · 1 C-14 Surface Casing Drill Out LOT Report ( 1 page) · 1 C-14 Production Casing Running Report ( 1 page) · 1C-14 Production Casing Cementing Report (1 page) RECEIVED · 1 C-15 Well Schematic ( 1 page) · 1C-15 Hourly Operations Report (3 pages) OCT 0 9 2001 · 1 C-15 Surface Casing Running Report ( 1 page) · 1 C-15 Surface Casing Cementing Report (1 page) Alaska Oil & Gas Cons. Commission · 1C-15 Surface Casing Drill Out FIT #1 Report (1 page) Anchorage ORIGlr~AL · IC-I5 Surface Casing Do" 1ut FIT #2 Report (1 page) ) · 1 C-15 Open Hole Leak: Out Test Report (1 page) · 1 C-15 Production Casing Running Report ( 1 page) 1 C-15 Production Casing Cementing Report ( 1 page) · Calculation of the Maximum Allowable Fluid Density and Maximum Pressure at the 1 C-14 Surface Casing Shoe, Burst Limited (1 page) · Calculation of the Maximum Allowable Fluid Density and Maximum Pressure at the 1 C-14 Surface Casing Shoe, Collapse Limited ( 1 page) As this application is reviewed please note in the report of lC-14 hourly operations: · the deep open hole leak: off test conducted on 2/24/98 · the annulus freeze protection operation conducted on 3/3/98. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, c.e~( 9f)d~ C.R. Mallary GKA Drilling Engineering Supervisor P AI Drilling RECEIVED OCT 0 9 2001 Alaska Oil & Gas Cons. Commission Anchorage OR\G\N!~L · 1. Type of request: ) ) ~bV,)W~o( \"1LJ /b / :P'S ¡I' .././ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend_ Alter casing _ Repair well_ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1564' FNL, 4138' FEL, Sec. 12, T11N, R10E, UM At top of productive interval 1502' FSL, 1550' FEL, Sec. 6, T11 N, R11 E, UM At effective depth At total depth 3698' FNL, 1360' FEL, Sec. 6, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing CONDUCTOR SURF. CASING PROD. CASING LINER LINER Perforation depth: measured true vertical Length Size 121 ' 16" 7191' 9-5/8" 1 0402' 7" 680' 4-1/2" measured 10670'-10716' true vertical 6536' -6571' Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 562146,5968672) (asp's 569606, 5971806) (asp's 569796, 5971884) 1 0980 feet 6772 feet 10877 feet 6693 feet Plugs (measured) Junk (measured) Cemented 9 cu yds High Early 612 sx AS III LW, 348 sx G, 60 sx ASI 130 sx Class G 30 sx Class G ¡Tubing (size, grade, and measured depth 3-1/2",9.3#, L-80 Tbg @ 10336' MD. I ¡ Packers & SSSV (type & measured depth) BAKER 'ZXP' PKR @ 10300' MD. Camco TRDP-4E SSSV @ 1830' MD. 13. Attachments Description summary of proposal J Detailed operations program_ 14. Estimated date for commencing operation 15. Status of well classification as: October 12, 2001 16. If proposal was verbally approved Oil Gas Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) RKB 101 feet 7. Unit or Property name Other _X Annular Disposal Kuparuk Unit 8. Well number 1 C-14 9. Permit number / approval number 198-017 10. API number 50-029-22861 11. Field / Pool Kuparuk Oil Pool Measured Depth 121 ' 7292' 1 0503' 1 0980' True vertical Depth 121' 4525' 6409' 6772' RECEIVED OCT 0 9 2001 Alaska Oi/ & Gas Cons. Commission Anchorage BOP sketch Suspended _ Date approved Service_X Water Iniector to the best 01 my kn"'$:,ì t.. g,,., . Questions? Call SIeve McKeever 265-6826 TrtJa: itnlf [n~~r ~l Data 9 Dd .2ÞtI / c;¡u ~tK ~J , Prepared by Sharon AlIsu,rDrake 263-4612 FOR COMMISSION USE fSNL Y . Conditions of approval: Notify Commission so re sentative may witness Approval no. Plug Integrity _ BOP Test _ Location clearance _ 220\ - ~ ~ Mechanical Integrity Test _ . . SubjEft1.~ent fonn required 1 0- ~ ~~ Q.\, ~""~ \(A.'t Ò~~~c:.. \ Orlganal Signeo DY ,. . Canny ~~~hsli .. .. .nnn... c:olTll11issi,,~~r .. n.. ..()at.a i arJ/o 1... . Name of approver 17. I hereby certify that the /1g0ing is true and cor Signed e !(, c. R. Mallary ~ _ ~pp'royedJ;>Y or_d~r__<?tthe _º2!!.1mi~~i~~_ Form 10-403 Rev 06/15/88· 00. f. G~ f\Jlj'\ ¡ J ~..., I -.¡ t!. \.~\.. I -:. ~ \ t "I l . \ i- SUBMIT IN TRIPLICATE ) ) Transmittal Form Application for Annular Disposal Permit - Kuparuk WelllC-14 A. Designation of the well or wells to receive drilling wastes: B. The depth to the base of freshwater aquifers and permafrost, if present. lC-14 No Aquifers / Base Permafrost = 1,801 TVD RKB C. A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is open open annulus and other information sufficient to support is shale or minor non-hydrocarbon bearing sands. a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. D. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry . F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. G. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: 1. Any additional data required by the Commission to confirm containment of drillinq wastes: See attached horizontal plane clearance report and plot, indicating one well, lC-15, penetrating the 1/4 mile radius circle centered at the lC-14 surface casing shoe of lC-14. There are no water wells within one mile of lC-14. Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1,853 psi. See attached calculation page. See attached: operations reports, cementing reports, LOT / FIT reports and casing reports. See attached casing summary sheet and calculation pages. See attached reports for penetrating well lC-15 1C-14 Annular Disposal Transmittal Form.xls prepared by Steve McKeever 10/09/01 PHilliPS Alaska, Inc.. A Subsidiary of PHILLIPS PETROLEUM COMPANY SSSV (1830-1831, 1C-14 00:3.500) TUSING (0-10336, 00:3.500, 10:2.992) NO GO (10272-10273, 00:3.500) PKR (10300-10301, 00:6.151) SEAL ASSY (10311-10312, 00:4.000) SSE (10321-10322, 00:4.500) TTL (10337-10338, 00:3.500) Perf ~"""H". (10670-10696) Perf -----._. (10096-10716) 1c-14 API: 500292286100 SSSV Type: Camco 'TROP-4E' Annular Fluid: Angle ~ TS: 40 deg @ 10664 Angle @ TO: 40 deg @ 10980 Well Type: INJ Orig Compltn: 3/4/98 Last W/O: Ref Log Oate: TO: 10980 ftKB Max Hole 59 deg @ 7450 Angle: Rev Reason: Fix Perf Oata; by JWP Last Update: 11/9/00 Reference Lo¡¡: Last Tag: 10877 Last Tag 11/18/99 Oate: Casing Strings - All Description Size CONOUCTOR 16.000 SURF. CASING 9.625 PROO. CASING 7.000 LINER 4.500 Tubing Strings· Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 0 7292 4525 40.00 L-80 0 10503 6409 26.00 L-80 10300 10980 10980 12.60 L-80 Bottom I TVD I Wt I Grade I .1'i1read 10336 62851 9.30 L-80 ABM EUR Interval 10670 _ 10696 10696 - 10716 TVD Zone Status Ft SPF Date Type Comment 6536 - 6555 C-4 26 4 11/21/99 APERF 2.5" HSO, 180 deg ph 6555 _ 6571 C-4,C-3 20 4 3/17/98 IPERF 2.5" HSO, 180 deg ph; oriented +/- 90 deg from low side Gas I.ift MandrelsNalves 8t MD TVD Man Man Mfr Type 1 3835 2588 Cameo KBMM 2 6523 4094 Cameo KBMM 3 8478 5195 Cameo KBMM 4 9634 5851 Cameo KBMM 5 10226 6200 Cameo MMM Other (plugs. equip., etc.) - JEWELRY HQe2!!'i TVD Type 1830 1474 SSSV 10272 6239 NO GO -10300 6259 PKR 103f1 6267 SEAL ASSY 10314 6269 HNGR Baker 'HMC' Liner '10321'6274 SBE Baker 10337 6286 '-rrL General Notes Date I Note 8/12/98 Asphaltines in tubing @ 10190' V Type VOD Latch Port TRO Date Vlv Run Cmnt OMY 1.0 BK 0.000 0 3/8/98 OMY 1.0 BK 0.000 0 3/8/98 OMY 1.0 BK 0.000 0 3/8/98 OMY 1.0 BK 0.000 0 3/8/98 OMY 1.5 I RK 0.000 0 3/8/98 Description If) 2.812 2.750 4.438 3.000 4.438 I 4.000 VMfr Cameo'TROP-4E' Cameo '0' Nipple Baker 'ZXP' Pkr Baker Locator StructuF$ : Pad t c WeH: 14 Fh'!1d : Kupon,,¡k River Unit .!..oe-Qtlon: NQrth SIQpe. 3400 3600 3800 4000 4200 4400 ,A í§J rID * 4527 East (feet) -> 4800 5000 5200 4527 5400 5600 6000 6200 6400 , , , Cfeo.~Ø by fim;h Doto!t piQUed; l1~J",¡~2001 IJ:[J -4200 4000 - 3800 - 3400 - 3000 2800 ^ I 1800 1600 1400 -1200 - 1000 600 - 400 - 200 - 0 ) Phillips Alaska, Inc. Pad lC 14 slot #14 Kuparuk River Unit North Slope, Alaska ') H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License PMSS <0-10980'> svy5733 Date printed Date created Last revised ll-Jul-2001 17-Feb-1998 18-Mar-1998 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.771,w149 29 45.878 Slot Grid coordinates are N 5968671.588, E 562145.222 Slot local coordinates are 1566.00 S 1139.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet Phillips Alaska, Inc. Pad lC,14 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref PMSS <0-10980'> Last revised : 18-Mar-1998 Reference wellpath Object wellpath PMSS <0-9390'>, ,15,Pad lC M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 7292.1 4527.0 2016.6N S005.0E 6307.5 4527.0 1268.0N 3927.1E 235.2 1312.3 896.7 Phillips Alaska, Inc. Pad lC,14 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref PMSS <0-10980'> Last revised : 18-Mar-1998 Reference wellpath Object wellpath PMSS <0 - 11918'>,,16,Pad lC M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 7292.1 4527.0 2016.6N 5005.0E 7416.1 4527.0 3514.4N 4018.0E 326.6 1793.8 1786.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #14 and TVD from RKB (Parker #245) (102.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 67.66 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Well Name:1 C-14 Rpt Date Beain End Time Time 02/14/98 14:00 18:00 02/14/98 18:00 22:30 02/14/98 22:30 24:00 02/15/98 00:00 00:30 02/15/98 00:30 12:00 02/15/98 12:00 13:00 02/15/98 13:00 13:30 02/15/98 13:30 14:00 02/15/98 14:00 14:30 02/15/98 14:30 15:30 02/15/98 15:30 17:30 02/15/98 17:30 19:00 02/15/98 19:00 20:00 02/15/98 20:00 21:30 02/15/98 21 :30 22:30 02/15/98 22:30 23:00 02/15/98 23:00 24:00 02/16/98 00:00 12:00 02/16/98 12:00 12:30 02/16/98 12:30 23:30 02/16/98 23:30 24:00 02/17/98 00:00 01:30 02/17/98 01 :30 07:00 02/17/98 07:00 07:30 02/17/98 07:30 11 :00 02/17/98 11 :00 12:00 02/17/98 12:00 12:30 02/17/98 12:30 23:00 02/17/98 23:00 24:00 02/18/98 00:00 01:30 02/18/98 01 :30 02:00 02/18/98 02:00 04:30 02/18/98 04:30 06:00 02/18/98 06:00 08:30 02/18/98 08:30 10:30 02/18/98 10:30 12:30 02/18/98 12:30 13:00 02/18/98 13:00 17:00 02/18/98 17:00 18:00 02/18/98 18:00 24:00 02/19/98 00:00 05:00 02/19/98 05:00 06:30 02/19/98 06:30 13:30 Type Op MIRU NU_ND BHA BHA DRIL DRIL RIGS DRIL CIRC DRIL CIRC CIRC TRIP_OUT TRIP_OUT TRIP _IN CIRC DRIL DRIL RIGS DRIL CIRC CIRC TRIP_OUT BHA TRIP _IN CIRC RIGS DRIL CIRC WIPERTR WIPERTR DRIL CIRC TRIP _OUT TRIP_OUT RIGS RIGS TRIP _IN CIRC DRIL DRIL CIRC TRIP_OUT 02/19/98 13:30 14:30 BHA 02/19/98 14:30 15:00 RIGS 02/19/98 15:00 16:00 BHA 02/19/98 16:00 20:30 TRIP_IN 02/19/98 20:30 23:30 CIRC 02/19/98 23:30 24:00 SURV 02/20/98 00:00 05:00 TRIP_OUT 02/20/98 05:00 06:30 CASG ) ) Page 1 Comments Move rig 302' to weIl1C-14. Rig accepted @ 1800 hrs. on 1C-14. Nipple up diverter system, perform diverter function test, fill conductor & check for leaks. P/U BHA #1. Program MWD tool. Drill 12.25" hole from 121' to 1178'. ADT=6.8 Drilling 12.25" hole from 1178' to 1268'. ADT=0.86 Service rig & top drive. Drilling 12.25" hole from 1268' to 1298'. ADT = .23 Circ out gas, mud weight cut to 8.5 ppg. Drilling 12.25" hole from 1298' to 1359'. ADT = .69 Circ & cond mud for trip (circ out gas) Monitor well, circ bottoms up. POOH to 1172' (above gas) circ bottoms up. Monitor well. Static. POOH. Tight @ 684' (35k overpull) Change out bits. Change out MWD tool (washed out) program & orient tools. RIH bridge @ 591'. wash to 631'. Continue RIH. 0' fill on bottom Fill pipe & circ bottoms up (gas cut to 8.6 ppg). Drilling 12.25" hole from 1359' to 1452'. ADT = .42 Drilling 12.25" hole from 1452' to 3693'. (TVD 2509') Service rig & top drive. Drilling 12.25" hole from 3693' to 5277' (TVD 3380') Circ low high vis sweep. Circ low/high vis sweep around. POOH. Pumped out of hole 1641' to 1272'. Download MWD. Change bits. RIH w/new bit. CBU to cleanup gas in mud. Service rig and top drive. Drill from 5277' to 6301'. having high torque and backreaming from 6101' to 6301'. Circulate bottoms up. Short trip from 6301' to 5277'. RIH. Drill from 6301' to 6500'. Hole ratty and experiencing torque. CBU. POOH to 1923'. Hole tight. Pump out to 1364'. POOH. Tight from 687' to 455' - 25k to 35k over. Not swabbing. Cut drilling line. Service rig and top drive. RIH. Tight spots @ 868' & 874' & 3850' & 3945'. CBU to condition gas cut mud. Drill from 6500' to 6870'. ADT=3.6 hrs. Drill from 6870' to 7307'. ADT=4.69 Circ hole clean. POOH. Hole not taking right fill 32 stands out. Check flow. Pump out 10 stands. Check flow. POOH to 1750. Hole tight. Pump out of hole. Download MWD. UD BHA. Service rig and top drive. P/U hole opener and BHA. Trip in hole. Wash/ream bridge at 1470'. RIH. Circ hole clean. Drop survey and pump down. POOH w/hole opener. R/U casers and hold pre-job safety meeting. 1 Well Name:1 C-14 Rpt Date Beain End Type Op Time Time 02/20/98 06:30 20:00 CASG 02/20/98 20:00 24:00 CIRC 02/21/98 00:00 00:30 CIRC 02/21/98 00:30 03:00 CASG 02/21/98 03:00 04:30 CIRC 02/21/98 04:30 06:30 CASG 02/21/98 06:30 10:30 NU_ND 02/21/98 10:30 12:00 PRB_MISC 02/21/98 12:00 12:30 NU_ND 02/21/98 12:30 15:00 NU_ND 02/21/98 15:00 18:00 BOPE 02/21/98 18:00 18:30 BHA 02/21/98 18:30 20:00 TRIP_IN 02/21/98 20:00 21:00 CIRC 02/21/98 21:00 21:30 BOPE 02/21/98 21:30 23:00 CLN_OUT 02/21/98 23:00 23:30 CIRC 02/21/98 23:30 24:00 BOPE 02/22/98 00:00 01 :00 TRIP_OUT 02/22/98 01:00 02:30 BHA 02/22/98 02:30 05:30 TRIP IN 02/22/98 05:30 06:00 CLN_OUT 02/22/98 06:00 07:00 CIRC 02/22/98 07:00 08:00 BOPE 02/22/98 08:00 14:00 CLN_OUT 02/22/98 14:00 14:30 CIRC 02/22/98 14:30 15:00 BOPE 02/22/98 15:00 15:30 DRIL 02/22/98 15:30 16:00 CIRC 02/22/98 16:00 17:00 BOPE 02/22/98 17:00 18:00 CIRC 02/22/98 18:00 24:00 DRIL 02/23/98 00:00 00:30 DRIL 02/23/98 00:30 01:00 CIRC 02/23/98 01:00 03:30 PRB_BIT 02/23/98 03:30 04:30 PRB_BIT 02/23/98 04:30 07:00 PRB_BIT 02/23/98 07:00 08:00 PRB_BIT 02/23/98 08:00 08:30 PRB_BIT 02/23/98 08:30 09:00 PRB_BIT 02/23/98 09:00 24:00 DRIL 02/24/98 00:00 08:30 DRIL 02/24/98 08:30 09:30 CIRC 02/24/98 09:30 10:30 OTHER ) ') Page 2 Comments Run 190 total jts of 9-5/8" 40#, L-80, BTC mod casing. CBU at 2546' & 3800' & 4749' & 5801' & 6742' & 7249'. LID fillup tool, P/U hanger and landing jt. R/U cement head and circ and condition mud. Reduce FV from 560 to 160. Pump total of 1485 bbls. Circ and condition mud. Reduce FV to 100. Cement first stage: flush lines w/5 bbls H20. Test lines to 4000 psi. Pump 50 bbls H20, 236 bbls lead cement @ 10.5 ppg, drop plug. Pump 130 bbls tail cement. Drop plug, pump 9 bbls tail cement and 25 bbls H20. Displace w/508 bbls mud. Bump plug. Check floats - OK. CIP @ 0300. Open stage collar w/2500 psi. Circ and condition mud - reduce FV to 120. Circ out 50 bbl cement contaminated mud and 5 bbls cement. Cement second stage: pump 30 bbls H20, 442 bbls lead cement, (had good 10.8 slurry in returns) 10 bbls tail cement. Drop closing plug. Pump 25 bbls H20 and 164 bbls mud. Bump plug and clost tool wI 1150 psi. CIP @ 0625. RID cement head. LID landing joint, casing elevators and R/U for drilling. C/O diverter stack, washout flowline. N/D diverter stack. Had small amount of cement flow out of annulus «2 bbl). Monitor well. N/U speed head. Torque to 20K ft-Ibs. N/U BOPE. Test BOPE to 300/3000 psi all components. Set wear ring. M/U BHA. RIH. P/U 48 jts D.P. CBU. test casing to 2000 psi for 10 min. Drill out stage tool @ 2493'. CBU. Test casing to 2000 psi for 10 min. POOH. M/U BHA. Load MWD. _ RIH w/directional BHA. Tag cement @ 7006'. Drill cement from 7006' to 7130'. CBU. Test casing to 3000 psi for 30 min. wIno bleed off. Drill cement, baffle plate, float collar, float shoe and 20' of new hole to 7327'. CBU. Run FIT to 16 ppg EMW - 1700 psi w/8.8 ppg mud @ 4528' TVD - wIno indication of leakoff. SI for 15 min. and pressure stabilized at 815 psi. Drill from 7327' to 7349'. ADT=.33 CBU. Run LOT to 15.4 ppg EMW - 1550 psi w/8.8 ppg mud @ 4528' TVD. SI for 12 min. and pressure stabilized at 791 psi. Circ and displace spud mud w/LSND mud. Drill from 7349' to 7782'. ADT=4.15. Drill from 7782'-7822'. ADT=.59. ROP decreased. CBU. POOH. Change bit. Download MWD. RIH to shoe. Cut and slip 90' drilling line. Finish RIH. Wash and ream 30' to bottom. Drill from 7822' to 9675'. ADT=1 0.7 Drill from 9675' to 10580' ADT=6.32 Circ and condition mud. Run FIT to 11.4 ppg EMW at TD of 10580' MD (6467' TVD) w/9.0 ppg mud. 2 Well Name:1 C-14 Rpt Date Beain End Type Op Time Time 02/24/98 10:30 12:30 WIPERTR 02/24/98 12:30 13:00 RIGS 02/24/98 13:00 14:00 WIPERTR - 02/24/98 14:00 15:30 CIRC 02/24/98 15:30 16:00 SURV 02/24/98 16:00 17:30 TRIP _OUT 02/24/98 17:30 21:00 TRIP_OUT 02/24/98 21:00 22:00 TRIP _IN 02/24/98 22:00 22:30 CIRC 02/24/98 22:30 24:00 TRIP_OUT 02/25/98 00:00 03:30 TRIP_OUT 02/25/98 03:30 04:00 BHA 02/25/98 04:00 04:30 BHA 02/25/98 04:30 05:30 CASG 02/25/98 05:30 06:00 CASG 02/25/98 06:00 19:00 CASG 02/25/98 19:00 20:00 PRB_LR 02/25/98 20:00 21:00 PRB_LR 02/25/98 21 :00 24:00 PRB_LR 02/26/98 00:00 02:30 PRB_LR 02/26/98 02:30 03:00 CASG 02/26/98 03:00 04:30 CIRC 02/26/98 04:30 06:00 CASG 02/26/98 06:00 06:30 CASG 02/26/98 06:30 07:00 NU_ND 02/26/98 07:00 08:00 NU_ND 02/26/98 08:00 09:30 NU_ND 02/26/98 09:30 10:30 OTHER 02/26/98 10:30 14:30 NU_ND 02/26/98 14:30 18:30 NU_ND 02/26/98 18:30 19:30 PREP 02/26/98 19:30 23:30 BOPE 02/26/98 23:30 24:00 RIGS 02/27/98 00:00 04:30 BHA 02/27/98 04:30 13:00 TRIP_IN 02/27/98 13:00 14:30 CIRC 02/27/98 14:30 15:30 BOPE 02/27/98 15:30 22:00 CLN_OUT 02/27/98 22:00 23:00 CIRC 02/27/98 23:00 24:00 OTHER 02/28/98 00:00 02:00 CIRC 02/28/98 02:00 04:00 CLN_OUT 02/28/98 04:00 05:30 CIRC 02/28/98 05:30 06:30 WL_ TST 02/28/98 06:30 09:00 DRIL 02/28/98 09:00 10:00 CIRC 02/28/98 10:00 11 :00 WL_ TST 02/28/98 11 :00 16:00 DRIL 02/28/98 16:00 17:30 CIRC ) Page 3 ) Comments Make short trip to shoe. No problems. Service rig and top drive. RIH. Circ and condition mud. Drop survey, pump pill and blow down TDS. POOH to shoe. POOH. LID 5" drill pipe. RIH w/drill pipe in derrick. Circ and pump pill POOH. LID 5" drill pipe. POOH. LID drillpipe. Download MWD. LID BHA. R/U casers. Hold safety meeting. Run 7" casing to 10365'. Circ @ 100 jts and shoe. Hit bridge at 10365'. Work to 10455' without returns. POOH to 10310' and regained circulation. CBU. Wash casing in hole to 10450' w/fillup tool. Raise mw to 9.7 ppg. Attempt to wash casing to bottom. Packed off 7' in on jt #254. LID jt# 254 and regain circulation @ 10496' . LID fillup tool and M/U cement head. Circ and condition mud. Cement: flush lines w/1 bbl H20. Test lines to 3500 psi. Pump 10 bbl preflush, 50 bbl ARCO spacer, 27 bbl cement. Drop plug and pump 20 bbl H20. Displace w/rig 378 bbl mud. Bump plug and check floats. CIP @ 0600. R/D cement equipment. N/D BOPE. Set casing slips w/240K indicator wt. Make rough cut. LID cutoff jt. R/U floor for drilling. Finish N/D BOPE. Held safety stand down. Make final cut and dress. N/U tubing spool and test to 3000 psi. N/U BOPE and change rams to 3.5 x 6 VBR's on top and 3.5" on bottom. Dress top drive and iron roughneck for 3.5" DP. R/U and test BOPE to 300/5000 psi all components except annular to 300/3000 psi. Service rig and top drive. P/U BHA, hold safety meeting on radioactive sources. Program MWD, P/U collars and HWDP. RIH P/U 3.5" DP tag cement at 10240'. Circ and condition mud. Test casing to 3000 psi for 30 min. No bleed off. Drill cement and float equipment and cleanout rathole to 10516'. Hole packing off w/high torque. Circ and displace hole w/12.0 ppg mud. Circ and raise mud weight to 12 ppg. Clean out cement from 10518' to 10580' and drill 20' of new hole to 10600'. CBU. Perform FIT to 16.2 ppg EMW. Drill from 10600' to 10630'. Raise mud weight to 12.4 ppg. CBU. Run FIT to 17.2 ppg emw wIno breakover. Drill from 10634' to 10766'. ADT=3.96 CBU check for gas on bottoms up. 3 ') Page 4 Well Name:1 C-14 ) Rpt Date Beain End Time Time 02/28/98 17:30 24:00 03/01/98 00:00 01 :00 03/01/98 01:00 02:30 03/01/98 02:30 03:00 03/01/98 03:00 04:00 03/01/98 04:00 12:30 03/01/98 12:30 14:30 03/01/98 14:30 15:00 03/01/98 15:00 21:00 03/01/98 21:00 24:00 03/02/98 00:00 00:30 03/02/98 00:30 07:30 03/02/98 07:30 08:30 03/02/98 08:30 16:00 03/02/98 16:00 18:00 03/02/98 18:00 18:30 03/02/98 18:30 21 :30 03/02/98 21:30 22:30 Type Op DRIL DRIL CIRC TRIP _IN OTHER EVAL CIRC SURV TRIP _OUT BHA OTHER CASG CIRC TRIP _IN CIRC TRIP _IN CIRC CASG 03/02/98 22:30 23:00 CIRC 03/02/98 23:00 24:00 CIRC 03/03/98 00:00 01 :00 CIRC 03/03/98 01:00 02:00 OTHER 03/03/98 02:00 03:00 TRIP_OUT 03/03/98 03:00 05:00 OTHER 03/03/98 05:00 07:30 TRIP_OUT 03/03/98 07:30 08:30 CIRC 03/03/98 08:30 13:30 TRIP _OUT 03/03/98 13:30 14:00 RIGS 03/03/98 14:00 14:30 PREP 03/03/98 14:30 21:30 RUN_COM P 03/03/98 21:30 22:30 BOPE 03/03/98 22:30 24:00 RUN_COM P 03/04/98 00:00 03:30 RUN_COM P 03/04/98 03:30 05:00 RUN_COM P 03/04/98 05:00 09:00 CIRC 03/04/98 09:00 09:30 RUN_COM 03/04/98 09:30 11 :00 BOPE 03/04/98 11:00 14:30 NU_ND 03/04/98 14:30 16:00 NU_ND 03/04/98 16:00 17:00 RIGS 03/04/98 17:00 18:00 RIGS Comments Drill from 10766' to 10955'. ADT=5.49 Drill from 10955' to 10980' ADT=1.0 Circ and condition mud. Pump out of hole 6 stands. Monitor well - change grabs in top drive. Make MAD pass at 90'/hr. Circ high vis sweep around. Drop survey. Pump out of hole 6 stands. POOH-SLM. LID HWDp. Hold safety meeting. Remove radioactive source from MWD. LID BHA. Pull wear bushing. R/U casers and hold safety meeting. Run 20 jts 4.5" liner + marker jt+liner hanger w/packer. Circ and condition mud. Trip in with liner to 10500'. Circulate and condition mud. Finish RIH w/liner. Circulate and condition mud. Cement liner: pump 5 bbl ARCO preflush, test lines to 4600 psi, pump 5 bbl ARCO preflush, pump 30 bbl ARCO spacer, pump 26 bbl cement @ 15.8 ppg. Drop plug and displace w/5 bbl H20 and 71.6 bbls mud. Set packer w/4500 psi. CIP @ 22:13. Release from liner hanger and reverse out 5 bbls cement 30 bbl spacer and 10 preflush. Circ and condition mud to cleanup drillpipe. Circulate and condition mud, 5 bpm, 2400 psi. Test casing & liner to 3500 psi for 5 minutes, OK. Break out & LD top drive cement head. Pump slug. POH - LD 30 jts 3.5" DP. Flush 9-5/8" x 7" annulus with 300 bbls water, 8 bpm, 1800 psi. Follow with 82 bbls diesel for freeze protection, 2.5 bpm, 1150 psi. POH LDDP. Build and pump 2nd slug. POH LDDP. Service rig & top drive. RU GBR. Hold pre-job safety meeting on running tubing. MU Baker locator seal assembly. Run 3.5" completion assembly with D-nipple & 5 GLMs up to SSSV (265 joints of 3.5"). Close pipe rams & test casing & liner to 3500 psi for 30 minutes; lost 50 psi, OK. MU Camco SSSV. MU control line & test to 5000 psi. Continue running 3.5" completion. (289 joints run at midnight - ran 321 joints total). Run 3.5" completion assembly. Stab seals into SBE below liner hanger. Verify position with weight indicator & circulating slowly while stabbing first set of seals into SBE. Space out. Install 2' pup below joint #321 & install hanger on top of joint #321. MU LJ. MU control line to hanger & test line to 5000 psi, OK. Displace mud from tubing & annulus. Pump 50 bbls water, followed by 25 bbls viscous water spacer, followed by 150 bbls water. Follow water with clean sea water, continued circulating until clean SW returns, pumped 490 bbls total SW. Freeze protect tubing & annulus with 100 bbls diesel. Pumped 100 bbls diesel down tubing & let U-tube back to annulus until equalized for -2800' MD diesel cap. Stab seals back into SBE & land tubing hanger. RILDS. Test tubing to 3500 psi for 10 minutes, OK. Bleed off tubing and test annulus to 3500 psi for 10 minutes, OK. Bleed off pressure. Set BPV. ND BOPE. Install 4.5" x 7" variables in top rams, 5" in bottom pipe rams. NU FMC Gen IV tubing head adapter & 3.125" 5000 psi master valve. Test packoff to 5000 psi, OK. Test control line to 5000 psi, OK. Close SSSV & secure well. Slip & cut 138' of drilling line. Reset Duo-Matic. Dress top drive to 5". Install new link tilt cylinders. Service rig & top drive. 4 ) Page 5 Well Name:1C-14 ') Rpt Date 03/04/98 18:00 21 :00 Beain End Time Time Tvpe Op MIRU Finish injecting fluids into 1 C-13 annulus; finish with 450 bbl water flush & 80 bbls diesel for freeze protection. Vacuum out & disconnect injection line to 1 C-13. Prepare rig for move. Release rig @ 2100 hrs. 3/4/98. CBU to cleanup gas in mud., CBU to condition gas cut mud., CBU., Cement first stage: flush 5 ("~ . J ~') CASING ¡ TUBING ¡LINER DETAIL 9-5/8" Surface/Production Casing Kuparuk WELL: 1C-14 DATE: 2/17/98 1 OF 2 PAGES LENGTH DEPTH TOPS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 63 Jts Joint'S Joint 'A 122 Jts 1 Jt 1 Jt 1 Jt RKB to Landing Ring FMC Fluted Mandrel Casing Hanger 9-5/8", 40.0#, L-80, ABM-BTC Casing--#126-#188 9-5/8", 40.0#, L -80, ABM-BTC Casing - Baker Locked Gemoco 754 Cementing Stage Collar 9-5/8", 40.0#, L-80, ABM-BTC Casing - Baker Locked 9-5/8", 40.0#, L-80, ABM-BTC Casing--#4-#125 Gemoco Insert Shut-Off Baffle 9-5/8",40.0#, L-80, ABM-BTC Casing--#3 Gemoco Float Collar 9-5/8",40.0#, L-80, ABM-BTC Casing - Baker Locked--#2 9-5/8", 40.0#, L-80, ABM-BTC Casing--#l Gemoco Float Shoe 41.06 1.80 2405.71 44.60 2.87 46.49 4609.65 41.06 42.86 2448.57 2493.17 2496.04 2542.53 7152.18 7152.18 7196.90 7198.45 7244.26 7290.33 7292.06 Remarks: String Weights with Blocks:_K# Up, _K# Dn, 76K# Blocks. Ran 190 joints of casing. Drifted casing with 8.50" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections (National = BOL 2000). Made up connections to base of triangle s1 44.72 1.55 45.81 46.07 1.73 TD = 7307' MD (- 15' Rathole) I BakerLock to Top of Baffle Collar Joint (LC), pius Stage Collar to Jts 'A' & 'B 76 Bow Sprin9 Centrali7ers Install a Centralizer on the first 17 joints (3 Stop Rings, 17 Centralizers), Install a Centralizer on every 3rd joint to Surface, Install a Centralizer on a Stop Ring on SakerLock Jts 'A' & 'B Run Stage Collar & BakerLock Jts 'A' & 'B' between Jts # 125 & # 126 Run Fluted Casing Hanger on Top of Jt # 188. Leave? Jts in the Shed (Jts # 189 thru # 190) Parker Rig #245 Drilling Supervisor: G.R. Whitlock ') / r·:. I ) I <> ARCa Alaska, Inc. Well#: 1 C-14 Casing Size Hole Diameter 9-5/8" 12-1/4" Centralizers Cementing Details Field: Kuparuk Date: 2/21/98 KOP & Angle Shoe Depth LC Depth % washout 300' - 55* 7292' 7152' State type used, intervals covered and spacing 76 Gemoco Bow Spring Centralizers: One on each of 1 st 17 joints, 1 st 3 on stop rings middle of float joints; One on coupling for every 3rd joint to surface, with one on sto in middle of joint on each side of Gemoco stage collar. Weight PV(prior cond) PV(after cond) YP(prior cond) YP(after cond) 10.6 36 27 28 16 Gels before Gels after Total Volume Circulated 13/29 7119 Stage 1: 1675 Bbls / Stage 2: 540 Bbls Type Volume Weight - Water 50 Bbls / 30 Bbls 8.34 ppg Type Mix water temp No. of sacks Weight Yield AS III LW -75* F 269 sx / 343 sx 10.5 ppg - 4.42 cfs Additives: Class G + 3.5% D44 + 0.6% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% Sl Type Mix water temp No. of sacks Weight Yield ClassG&ASI -75*F 348sx/60sx 15.8115.7 1.16/0.93 Additives: Stage 1: Class G + 0.2% D46 + 0.3% D65 + 0.55% D 156 + 1 % S 1 Stage 2: Arctic Set I Displacement Rate(before tail at shoe) Rate(tail around shoe) 6.5 BPM 6.0 BPM Reciprocation length Reciprocation speed -15' -20 FPM Theoretical Displacement Actual- Displacement 542 Bbls I 189 Bbls 543 Bbls / 190 Bbls Calculated top of cement CIP Bumped plug Floats held Cemented to Surface 0617, 2/21 Yes Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage #1: Had full returns throughout both stages. Reciprocated pipe until tail around shoe. Bumped plug and opened stage collar w / 3500 psi. H Mud Spacer Lead Cement Tail· Cement Str. Wt. Up 320K Str. Wt. Down 145K Str. Wt. in mud 242K Stage #2: Circulated 50 bbls clabbered mud and 5 bbls cement between stages. Bumped plug and closed stage collar wI 1150 psi. Pressured up to 2000 psi. CIP @ 0617 hrs 2/21/98. Cement Company Dowell Rig Contractor Parker Rig #245 Signature G.R. Whitlock ) ) CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 1C-14 FIT #1 Date: 2/22/98 Supervisor: G.R. Whitlock Casing Size and Descrip 9-5/8",40#, L-80, BTC Casing Setting Depth: 7292' TMD 4528' TVD Mud Weight: 8.8 ppg EMW = Leak-off Pressure (PL + MW 0.052 x TVD LOT = 1700 psi/(0.052 x 4528 ft)+8.8 ppg = 16.0 pp Hole Depth (md)= 7327 Fluid Pumped = 4.6 bbls. Pump output = .101 bps 3300 ---- .___......._._..n_._ -.-....--.----. --.---- -.....-...- -.- .-.-------.--.-- --... -- -- -....-..-.--...---...--- __._ ___ _____... 3200 -- ..- --.-- _n.. ---... _h' ___ _____ ______._. _ ______. ._...._.. __o. _. _ __. __ _._.... ___.._ __h' ___.__ _.____ 3100 ------- ------.---- ---- 3000 -- ..-- --. --.------..----.- .- -----..-- ---- .----.. -..-- -.---. --- --- ..-..- ..-- --.-----.- -----.-- _h' --------. ,. _h' ---..---.-. ..-.- 2900 -..-..-. ..-..-- -...--.-. -.- -------.-----.---.---.----..- ---. .----. .--.- .-- -..-.----- .--.-- ---... .----....-. -..-- - - --.---.-.--- ---.- * 2800 --.----------..--..- -..--.------.-- ----- -. --.-- --.-- ------- ---.--- ---'-'- .-..--- .---- -- -...- --.. 2700 --. ....-- --- --- --- -- ---... --.-. _d'____ ------.--- -- --- -..- -.--.. -. -....- .-.-. --..--- -..- --..-. --------- -.. -...-...- --. ---..-.--. -..--.-. 2600 --. .---------.------- --- 2500 -.-.-..--.----...--- --- -'--- --.--- n__' ---. -.--- --- --.------.- --- --.- ------- ---- -.-. .-... -... --.. ------.--. ---- ----- ..-- --- 2400 -- ...--- ---..--.. --- --..----.- _h' -.--. --.-- ------.. --..--- -.-. .-.-.- ---- _h' - --.__._ -,--- ,,--- "'_" __._.... - 2300 ------ ---.------ -.-- -.--. _no' -...-----. --- ---- ---- ____ -__ ____.__._ ._ ____ ....._...__ - m_. -- ..., ...,. ....-- . .__.._ _. ..._.... ._.... __ _____ __ ___._ 2200 --- _n .----. _h' 2100 -'-.-. --- ---.. ------ -.-. -- - --- ...-.. -." -.-....------. -... --.---- --- --- --.----.--- --._- ---.--- -.... --- ---- -.- -------- -.--.--- .---. 2000 --------------- -- --- 1900 ----.- -.------.-- -. --- - ----- __h' _____.______. ____ __ _..._ _._..___ .___.h - -_.-.- -- __._ .--.__._._. _______ ___ __ _. __ __ _._.. w 1800 - ------ .---- --.- ----.....-- ..----.-. --..- .--. - ----.---- ----..--------.- .--- - ..----.- -.- .-- -- --- ----- -- --- -----.---- --.. --- -.-..- Q:: => en en w Q:: Q. :: ==~=====~=====-~==:==-=== ===~~._-========== ::: ========n----=~:==17_~==:~======== :~ =~~;;~==~,-~~~~~~~.~~~~~~=-~;~~~~., " )( :; == ====~----~ - r- -==~-==------------=====-===:::-- - -=----- 500 ------ -- - ------------------------.---.-- ----,,----- ----- ------------..----- 400 300 200 100- -+- LEAK-OFF TEST --Ð- CASING TEST _ - -...---.-.----- ---------~----,-_.- -.-. _.._-~_._...- -- -..-...-..--..-,------.- o ' o 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 STRO KES '> } ) CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 1 C-14 LOT#1 Date: 2/22/98 Supervisor: G.R. Whitlock Casing Size and Descrip 9-5/8",40#, L-80, BTC Casing Setting Depth: 7292' TMD 4528' TVD Mud Weight: 8.8 ppg EMW = Leak-off Pressure (PL + MW 0.052 x TVD LOT = 1550 psi/(0.052 x 4528 ft)+8.8 ppg = 15.4 pp Hole Depth (md)= 7349 W Fluid Pumped = 4.6 bbls. Pump output = .101 bps 3300 ___._______________d___. -- --- -- .-.---.-----. .------- --------------.---..---- -- ------.--- -..--.-- -..- ---.- --.---.--... --.- 3200 -- ----- ____d_ ___d· ___._. ._.___._ _.. ._d. - --- ____d. ___..___ ___ ___ _________.___ 3100 ------ ------ ----- ------ ----- -..--- --- ._._._m ------ -..-. --.- - ------ -------.- --- --- ---- 3000 - -- -- - -- --- -- ---- .-------.---. --..-- .----. --..--- ------------ --- -.- - .-- ---.--- 2900 __d' --- ___d. ----.--.---....-.---------. ___ _______. -- .___ - --.- -_____ ____._._____.. ____.___.. _.__ ____._ - ____._._..___ 2800 ----- 2700 -- --.---- --- -.---- ---- _dO' ____d__.__d_. --- ---. -..--.-..- -....- .-- -- ----- ...-. 2600 -... .-- ---. --.---.- ------.. -----.--. ---.- ..--- -'- --- -.--- --- ---.----- --_.-.-..- -- ----- -.-..... '__d__ 2500 --- --.-.-- ---...-------..--. -----.-.--------- ..--- ----------.-.--.- -.--. -.- - ---.-----. .. --..- - ___u__ ----.- -.- 2400 --- -.-- -----.- --.. ---..- ------ ---- -..---- -.------- ---- - - ----. ---- -.-.- --.. .--. ..-.- - -- ...-.. ---. -..----- ----- -.... - ..-.. 2300 -.. -- -- ---- -...-- --..- ------.---------.- --.-. .-- -.--.-- -..- .-..------.---. --- -.----- _d' ---- - -'-- ----- -- .--. - -- ----- ---- 2200 -- -- ---..----- ---.------.- ------ --- -- ..----. .___d --. -...- '__nd__' ______._ __no ____. _______.._ .__ ___ ____..._ _'n _n_ ____ ___ -' 2100 --- --- ------ ---.----- ------..--- ._-- .--.-.-.------ .--.-..----- --- .---.- __d. ._d._ .__. .________..._.._..__ __'___d._'__'_ .-.- 2000 _.d___ .-.- ___d' __'d d_._.__ .__._ __ __ ___ _ ___ _____ __ __ _____ _ _ _'__d _._._ _________m_._.__.. __..__.___..... _d. ___ _.._____ 1900 --------.-------------- w 1800 -- --- ------.- ..-- ---.. ---- -.---.- ..-.- -.------ -.....--. -- - -----.- -- - .--. _______h__ -.-. ...-- --- --- -'--- - -' --- ---- ~ ~ 1700 --------------- ~ 1600 -- ---- ---------- -- ----...........----- - -- .--..-.-- -------.----..-- -.--- --- --.-.--.--"..--.-- ___d. __. __._ '_"'h.._ --. --- ~ " ~:I , I 500 ------- ----- --- ---------- ------ --- --..- -----. 400 300 200 --- LEAK-OFF TEST -œ-CASING TEST _ -"""----_._- -------------- -----,---.--- --_._--_._--.--,.._--,~--, ----,,-----~~,.,,-~,- o o 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 STROKES .1~ () ~) CASING I TUBING I LINER DETAIL 7" Intermediate Casing WELL: 1 C- 14 KRU DATE: 2/23/98 1 OF 1 PAGES LENGTH DEPTH TOPS ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 7" Long StrinÇJ (Landing Joint = 45.48', ?' above RKB) 249Jts RKB to top flange of tubing spool FMC, Gen IV 7-1 /16"-5M x 11"-3M tubing spool 7",26#, L-80, ABM-BTC Casing, Cutoff 7",26#, L-80, ABM-BTC Casing Gemoco Float Collar 7",26#, L-80, ABM-BTC Casing Gemoco Float Shoe 36.81 1.79 37.73 10338.97 1.36 85.22 1.48 Bottom of Shoe ==» I TD = 10580' MD (2' Rathole) 36.81 38.60 76.33 10415.30 10416.66 10501.88 10503.36 2 Jts Baker Lock thru Float Colla, 13 Bow Spring Central;7ers: Run one on each of first 13 joints. Use stop rings in the middle of the first two joints. ?? Centering Guides: Slip on Joints # 188, 191, 194, 197,200,203,206,209,212: #215,218,221,224,227,230,233,236,239,242,245,248,25 ; Should tag with 8' up on Jt #25~ (Leave 5 Joints in the Shed => Jts #256-260.) Remarks: String Weights with Blocks: 305K# Up, 140K# Dn, 78K# Blocks. Ran 253 joints of casing. Drifted casing & hanger with 6.151" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections (National = BOL 2000). Torqued connections to the base of triangle stamp (7000 ft-Ib Average). Parker Rig #245 Drilling Supervisor: G.R. Whitlock () () <> ARCa Alaska, Inc. Well#: 1 C- 14 Casing Size Hole Diameter 7" 8- 1/2" Mud Cementing Details Field: Kuparuk Date: 2/26/98 KOP & Angle Shoe Depth LC Depth % washout 300' - 55* 10503' 10,415 State type used, intervals covered and spacing 13 Gemoco Bow Spring Centralizers: One on each of 1 st 13 joints, 1 st 3 on stop rings middle of float joints; One on coupling for next 10 joints. 22 rigid centering guides 01 "188,191, 194, 197,200,203,206,209,212,215,218,221,224,227,230,233,236,239,242,245,248,251 Weight PV(prior cond) PV(after cond) YP(prior con d) YP(after cond) 9.8 21 20 26 . 22 Gels before Gels after Total Volume Circulated 7 18 7 18 Stage 1: 1350 Bbls Type Volume Preflushl Arco spacer 10 Bbls I 50 Bbls Type Mix water temp No. of sacks Class G ~75* F 130 sx Additives: Class G + .2% D800 + 0.2% D46 + .3% D65 Weight 15.8 ppg Weight 8.34 ppg/1 0.5pp~ Yield 1 . 15 cfs Centralizers Spacer Lead Cement Tail Cement Type Mix water temp No. of sacks Weight Yield Displacement Rate(before tail at shoe) 5.0 BPM Reciprocation length Rate(tail around shoe) 5.0 BPM Reciprocation speed Str. Wt. Up 305K . Str. Wt. Down 140K Str. Wt. in mud 235K Theoretical Displacement Actual Displacement 398.6 bbls 396.2 bbls Calculated top of cement CIP Bumped plug Floats held 10000' 0600,2/26 Yes Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Unable to reciprocate pipe. Had full returns throughout job. Cement Company Dowell Rig Contractor Parker Rig #245 Signature G.R. Whitlock ) ) Calculation of Maximum Allowable Fluid Densitv and Pressure at the Surface CasinQ Shoe" Burst Limited We1l1C-14 Surface Casing: Size Weight Grade Shoe Depth 9-5/8 40# L-80 7292 M D 4525 TVD Burst (1000/0) Bu rst (85%) 5750 psi 4888 psi Assumptions: Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1 C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density (MW) to Reach 85% of Burst Ratinq of 9-5/8" Casing: 4,888 psi + 8.3 ppg (.052) (4,520' TVD) = 1,500 psi + MW (.052) ( 4520') Maximum Fluid Density = 22.7 ppg Maximum Pressure on 9-5/8" Shoe: Max Pressure = 1,500 psi + 9.8 ppg (.052) (4,525') - 8.3 ppg (.052) (4,525') Max Pressure = 1,500 psi + 2,303 psi - 1950 psi Max Pressure = 1,853 psi 1 C-14 Maximum Pressure at Shoe. xIs prepared by Steve McKeever 10/8/01 ) ) Calculation of Maximum Fluid Densitv at the Surface CasinQ Shoe, Collapse Limited Well 1 C-14 Casing: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) 7" 26# L-80 10,503' MD / 6,409' TVD 5,410 psi 4,598 psi Assumptions: 9-5/8" Casing Shoe @ 4,525' TVD Inside T' Casing - Diesel from 2,800' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,525' TVD to 2,800' TVD (8.4 ppg) Maximum Fluid Density in 7" x 9-5/8" Annulus to Collapse 7" Casing: 4,598 psi + 6.7 ppg (.052) (2,800') + 8.4 ppg (.052) (4,525' - 2,800') = 1500 + MW (.052) (4,520) MW = (4,598 psi + 975 psi +753 psi - 1500 psi) / (0.052*4,525) MW = 20.5 ppg 1C-14 Maximum Mud Weight to Collapse Casing. xIs prepared by Steve McKeever 10/8/01 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS measured 1 0860 feet Junk (measured) true vertical 6680 feet Length Size Cemented Measured Depth 121 ' 16" 9 cu yds High Early 121 ' 7191' 9-5/8" 612 Sx AS III LW, 7292' 348 Sx G, & 60 Sx AS I 1 0402' 7" 130 Sx Class G 1 0503' 680' 4-1/2" 130 Sx Class G 1 0980' 1. Operations performed: Operation shutdown_ Pull tubing _ Stimulate Alter casing _ 5. Type of Well: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1566' FNL, 1139' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1502' FSL, 1550' FEL, Sec. 6, T11 N, R11 E, UM At effective depth Development _ Exploratory __ Stratigraph ic_ Service__X (asp's 562146, 5968672) (asp's 569606,5971806) At total depth 1581' FSL, 1360' FEL, Sec. 6, T11N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 569795, 5971887) 1 0980 feet 6772 feet Plugs (measured) Effective depth: Casing CONDUCTOR SURFACE CSG PROD CSG LINER Perforation depth: measured 10670 - 10696'; 10696 - 10716' true vertical 6536 - 6555'; 6555 - 6571' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 10336' MD. Packers & SSSV (type & measured depth) BAKER 'ZXP' PKR @ 10300' MD. CAMCO 'TRDP-4E' @ 1830' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Plugging _ Perforate _X Repair well _ Other 6. Datum elevation (OF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-14i 9. Permit number / approval number 198-017 10. API number 50-029-22861 11. Field / Pool Kuparuk Oil Pool Tagged PBTD (11/18/99) @ 10860' MD. True vertical Depth 121 ' 4527' 6409' 6772' RECE1VED FEB 1 3 2.001 AI k 0"1\ & ", , ,'~" (',,"',"\S', ! ommissior as a c ':\"; v " u AndiOrage Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 2750 Tubing Pressure 2300 2300 14. Subsequent to operation 3050 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations J Oil Gas Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,u~ Title: Form 10-404 Rev 06/15/88 · Service _(Water Inj)_ Date ë/7/Ó/ Prepared by John Peirce 265-6471 SUBMIT IN DUPLICATE ~ ) ) 1 C-14i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 11/18/99: RIH w/dummy gun & tagged PBTD @ 10860' MD. 11/21/99: MIRU & PT equipment. RIH w/perforating guns & shot 26' of perforations as follows: Added perforations: 10670 - 10696' MD Used 2-1/2" HSD carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. Returned the well to Water injection. - ) "_n_ __ __.. '.n_ __..".,~... ..____._, ,.",...__.,_,__~._____ _..._ __nO' ,,_ .__,___ _ ___." h .~__~._,._. ____._ _, n _ __ .,~"~,,_________,.__,,,_._____ ___..___.__.__,..__._"~,,.__,__._._____._____,,_____ ,__.._"'__...~, ."h~'_.~"__.___,_.,_,_.,__.__.___,,__,_ ...', . ....._ _...,_._____.._..._.....u_____..,__.___..._" .._ __...._0._..'_____....___ _.."....._______.__.._...__...___...._.__ _____. ."._._,___...___.__ ._..._".__._,.. ....._ n_ --. .,.-,.-~--- ........,....... ,,~.- """ '. ."..- l:;:~:::ide. o~::e:6n2K=:~:~JÍ1 :/~14C~:Plete::t~:;2~::Ö :~:t: T Name Interval Sent Received _________________________ _ _ _ _~~~::~::::::_:::~"- ___ _ _ __ __ _ _ __ _ _ _ _ n __ _ __ _ _ _ _ ___ _ ______ _ ___"___ _________"_______ ______________"_____._____________________ D 8411 ~ c SPERRY MPT/GR/EWR4/CNP/SLD OR 4/8/98 4/8/98 L DGR/CNP/SLD-MD ~L 7307-10980 OH L DGR/CNP/SLD-TVD ~L 4536-6771 L DGR/EWR4-MD íRÍÑAL 7307-10980 L DGR/EWR4-TVD ~NAL 4536-6771 ~J'"···,s.GM:f"··~·"· t;f~:A(-';~ 0300 100'l'ö L SCMT ~AL BL(C) 10300-10870 1/22/99 R DIR SRVY ~RY 0-10980. R SRVY RPT -g-p{RRY 0.-10980. Daily Well ops'2fi'1!tf2 ---- ))2.)j7 f Was the well cored? yes ß).--.. .--.......---..----- ---.,...,.,,"-. _._.......,,___'.___ .____m ___0 Well Compliance Report 4/9/98 OJ-I 4/9/98 OR 4/9/98 OR 4/9/98 rT-T .:: ;.> /11~ CH 5 6/8/99 OR 4/15/98 OH 5/13/98 4/9/98 4/9/98 4/9/98 4/9/98 ? /;1 /91) 6/16/99 4/16/98 5/14/98 Are Dry Ditch Samples Required? yes ~~"And Receive~ no Analysis Description Received? -YPs 1!.~ .J' Sample S'ét # ______.___ ~__.n___~ Comments: ·~~l~--- ,Jj Tuesday, April 04, 2000 ........-... ._~---".-.".,,_....,-.._._,_..- ---.-----,----.... - T/C/D Page 1 of 1 6/8/99 NO. 12633 GeoQuest 3940 Arctic Blvd Company Alaska Oil & Gas Cons Comm Anchorage, AK 99503 Aftn: Lori Taylor A TIN: Sherrie 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job# Log Description Date Color -- Print ---''1(::, ,).~ s 2T - 21 0 99240 CBL W /PSP ISCMT 990523 1 /' (\'1 00 \ 2N-320 99241 SCMT 990303 1 ti ,¿, ,).s , 2L-323 \).\ c 99239 CBT W /PSP /SCMT 990221 1 /- C¡-:::¡· cc~ 1 C- 18 99243 CBT W /PSP /SCMT 990402 1 -- q-¿ ,;).\ 1 D- 132 LA l <-- 99248 SCMT 990216 1 _ <12· ILtÍ 1 D- 125 99249 CBT W /PSP ISCMT 990220 1 - / q·Z· IS(, 1 D- 114 L\ \ C 99246 CBT W /PSP /SCMT 990421 1 é, l--' I ~.~ 1 D- 128 99247 SCMT 990215 1 /- ci2·¡r-rl 1 D- 122 lAlL-- 99244 CBT W /PSP /SCMT 990226 1 __ Ci 8· {(,,(.- 1 D-111 L,i..I ( 99245 CBT W /PSP /SCMT 990415 1 c¡;3 c ,I '{ 1 C- 14 (.,uC 99242 SCMT 990122 1 /' L_ ri-------·· " )() fi~\ SIGNE~ . ...... þ(Q.j.. 6 ~ 3) DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. i) ~~~ { .,; ~ .., ~ "\' I ~;~ '¡' :-. I '\ l~- '-~;., b;. I Lt:.£.o, ~. ,:\..JHï 6 1999 .tJJSiŒ C¡¡ & GJ5 Con;:; (\)I\E¡IÎ;J,;¡iUH f\nct ¡Of3!}\¡ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie Qß·O\'1 1C-14 8<D'()(Ø) 31-12 S'GNEDð Well Job # Log Description Date Blueline Sepia SCMT INJECTION PROFILE 990122 990107 2/1/99 NO. 12293 Company Alaska Oil & Gas Cons Comm Aftn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool ....~- : -Ì-"" ~ -:--:1.:", tr~:·-.~ t·~ .! ;', \\, J ;~~~: 1-t.o,;\:-· ß ¡i" .. ¡;~H 1 1- if t· -!11 ~ i·-' U:: \:-_.-f ïx¿~ ¡ \J ~~':~j ï,,~~7 DATE: fEB \) 4 r~999 Please sign and return one copy of this transmitlal to Sherrie at the above address. Thank you. Alas\<a on & Gas Cons. Commission Anchorage ) ') ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ April 15, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: lC-14 (Permit No. 98-17) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU lC-14. If there are any questions, please call 265-6120. Sincerely, Âl"L {. Ot.( G. C. Alvord Drilling Engineer Kuparuk Drill Site Development GCA/skad 6 \C:l,.t:IIf, .. A.PD t:..~." , '1 7 6' tVaSkJJOi/& 1998 ~Con. ~~ ~ Coml1J,' -....II.I~t?$ ~+Jf1 OIL D GAS D 2 Name of Operator ARCO Alaska, Inc 3 Address SUSPENDED D STATE OF ALASKA J RIG I N A L' (:l.."" ALASKA OIL AND GAS CONSERVATION COMMISSION ,., ~.w WELL COMPLETION OR RECOMPLETION REPORT AND LOG ''(:-If V/;..":J:'é Classification of Service vtlåftl_. 1 6 , ",' ,";" ~\) '~Q¡..ø ,.~1fj", ,'.," "', ~ G:tsc \~~~. 'I!n.- OIJ., ,~1 , "''''~fÞ . . . ~'q¡lf\ ABANDONED DSERVICE [[] Injector 7 Permit Number ) 1 Status of Well 98-17 8 API Number P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 1566' FNL, 1139' FWL, Sec. 12, T11N, R10E, UMr·Ô',::;:..······ At Top Producing Interval 1. ß..li?!..~ ~ At':~' ~~~~ 550' FEL, Sec. 6, TII N, RI1 E, UM L1¿~] 1581' FSL, 1360' FEL, Sec. 6, T11N, R11E, UM 5 Elevation in feet (indicate KB, DF, etc.) , " '" " ';,;f 50-029-22861 9 Unit or Lease Name ~:.. Kuparuk River Unit 10 Well Number .' '.. 1 C-14 11 Field and Pool 6 Lease Designation and Serial No. KUPARUK RIVER Kuparuk River Oil Pool Rig RKB 41', Pad 61' 12 Date Spudded 15-Feb-98 17 Total Depth (MD+TVD) 10980' MD & 6772' TVD 13 Date ToO. Reached 01·Mar-98 18 Plug Back Depth (MD+ TVD) 10883' MD & 6698' TVD ADL 28242 ALK 2292 14 Date Compo , Susp. or Aband. 17-Mar-98 19 Directional Survey YES ~ NO D 115 Water Depth, if offshore 116 No. of Completions NA feet MSL 1 20 Depth where SSSV set 21 Thickness of permafrost 1830 feet MD 1465' APPROX 22 Type Electric or Other Logs Run GR/Res CASING SIZE WT 16" 62.5# 9.625" 40.0# 7" 26.0# 4.5" 12.6# CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I GRADE TOP BTM HOLE SIZE CEMENT RECORD H-40 SURF. 121 ' 24" 9 cu. Yards High Early L-80 SURF. 7292' 12.25" 612 sx AS III LW, 348 sx Class G, 60 sx AS I L-80 SURF. 1 0503' 8.5" 130 sx Class G L-80 1 0300' 10980' 6.125" 130 sx Class G 23 24 Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25 SIZE 3.5" TUBING RECORD DEPTH SET (MD) 10336' PACKER SET (MD) 1 0300' 10696'-10716' MD 6555'-6571' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10696'-10716' MD 26708# proppant in formation wl7# ppa of 12/18# at the perfs Flow Tubing Casing Pressure Press. 160 -15 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Pre-Produced Injector PRODUCTION FO OIL-BBL GAS-MCF TEST PERIOI : 905 558 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE: 1653 1211 WATER-BBL CHOKE SIZE GAS-OIL RATIO 27 Date First Production 3/19/96 Date of Test Hours Tested 4/9/98 12.00 o 176 733 WATER-BBL OIL GRAVITY-API (corr) 34 23.5° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NIA Form 1 0-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 9. ~) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS DEPTH Include interval tested, pressure data, all fluids recovered and gravity, TRUE VERT. DEPTH GOR, and time of each phase. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 10664 ' 10823' 10890' 10890' 6531' 6652' 6703' 6703' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Þ t. De Title þ~ Drl 'yTe¿JI- Le,J,er DATE +- I ,ç r 98 Prepared by NaffJe/Number Sharon Allsup-Drake/263-4612 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 (OF, 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 Date: 4/2/98 ) ') ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:1C-14 WELL_ID: AK9117 TYPE: AFC: AK9117 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:02/15/98 START COMP: RIG:PARKER 245 WI: 0% SECURITY: 0 API NUMBER: 50-029-22861-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 02/14/98 (D1) TD : 12 l' ( 121 ) SUPV:FH 02/15/98 (D2) TD : 14 52' (13 3 1 ) SUPV:FH 02/16/98 (D3) TD : 52 7 7' (3 8 2 5 ) SUPV:FH 02 /17 / 9 8 ( D4 ) TD : 63 0 l' (1 0 2 4 ) SUPV:GRW 02/18/98 (D5) TD : 6 8 7 0' ( 5 6 9 ) SUPV:GRW 02/19/98 (D6) TD: 7307' ( 437) SUPV:GRW 02/20/98 (D7) TD : 7 3 0 7' ( 0 ) SUPV:GRW 02/21/98 (D8) TD : 7 3 07' ( 0 ) SUPV:GRW MW: 10.3 VISC: 185 PV/YP: 49/54 APIWL: 5.2 DRILLING AHEAD Move rig to well 1C-14. Rig accepted @ 1800 hrs. on 2/14/98. NU diverter system. Perform diverter function test. MW: 10.2 VISC: 151 PV/YP: 40/51 APIWL: 5.5 DRILLING AHEAD Drilling 12.25" hole from 121' to 1359'. Circ and condition mud (circ out gas). POOH. Tight @ 684'. Wash to 631'. Drill from 1359' to 1452'. MW: 10.2 VISC: 108 PV/YP: 31/42 TRIP FOR BIT Drilling 12.25" hole from 1452' to 5277'. APIWL: 5.8 MW: 10.2 VISC: 132 PV/YP: 35/45 APIWL: 5.5 POOH CBU to cleanup gas in mud. Drill from 5277' to 6301'. having high torque and backreaming from 6101' to 6301'. CBU. MW: 10.3 VISC: 195 PV/YP: 37/47 APIWL: 5.5 CIRC FOR WIPER TRIP Drill from 6301' to 6500'. Hole ratty and experiencing torque. POOH to 1923'. Hole tight. Pump out to 1364'. POOH. Tight from 687' to 455'. Not swabbing. CBU to condition gas cut mud. Drill from 6500' to 6870'. MW: 10.3 VISC: 190 PV/YP: 43/55 APIWL: 5.4 R/U CASERS Drill from 6870' to 7307'. Circ hole clean. Hole not taking right fill. Check flow. Hole tight. Pump out of hole. RIH with hole opener , wash/ream bridge at 1470'. MW: 10.3 VISC: 103 PV/YP: 36/40 APIWL: 5.8 CEMENTING Hold pre-job safety meeting. Run 9-5/8" casing. Circ and condition mud. MW: 8.8 VISC: 46 PV/YP: 6/23 APIWL: 20.0 DRILLING CEMENT Cement first stage and second stage. N/D diverter stack. Had small amount of cement flow out of annulus. Monitor Date: 4/2/98 02/22/98 (D9) TD : 7 7 82 ' ( 4 7 5 ) SUPV:GRW 02/23/98 (D10) TD : 9 67 5' (18 9 3 ) SUPV:GRW 02/24/98 (D11) TD : 1 0 5 8 0' ( 9 0 5 ) SUPV:GRW 02/25/98 (D12) TD : 1 0 5 8 0' ( 0 ) SUPV:GRW 02/26/98 (D13) TD : 1 0 5 8 0' ( 0 ) SUPV:GRW 02/27/98 (D14) TD : 1 0 5 8 0' ( 0 ) SUPV:GRW 02/28/98 (D15) TD : 1 0 9 5 5' ( 3 7 5 ) SUPV:GRW 03/01/98 (D16) TD : 1 0 9 8 0' ( 2 5 ) SUPV:GRW ') ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 well. N/U speed head. N/U BOPE and test to 300/3000 psi. Test casing to 2000 psi. Drill out stage tool @ 2493'. MW: 8.6 VISC: 45 PV/YP: 9/16 APIWL: 14.5 RH W/NEW BIT Drill cement from 7006' to 7130'. Drill cement, baffle plate, float collar, float shoe and 20' of new hole to 7327'. Run FIT to 16 ppg EMW. Drill from 7327' to 7349'. Run LOT to 15.4 ppg EMW. Drill from 7349' to 7782'. MW: 8.9 VISC: 51 PV/YP: 13/21 APIWL: 5.6 DRILLING @ 10350' Drill from 7782' to 7822'. CBU. Change bit. Wash and ream 30' to bottom. Drill from 7822' to 9675'. MW: 9.3 VISC: 54 PV/YP: 17/21 APIWL: 5.0 RUNNING 7" CASING Drill from 9675' to 10580'. Run FIT to 11.4 ppg EMW. Circ and condition mud. MW: 9.8 VISC: 56 PV/YP: 21/22 APIWL: 4.6 CEMENTING Hold safety meeting. Run 7" casing to 10365'. circ. Hit bridge at 10365'. Work to 10455' without returns. Wash casing in hole to 10450'. Raise mw to 9.7 ppg. MW: 9.7 VISC: 62 PV/YP: 24/21 APIWL: 4.3 P/U 3.5" DRILLPIPE Attempt to wash casing to bottom. Packed off 7' in oon jt #254. Circ and condition mud. Pump cement. N/D BOPE. Held safety stand down. N/U BOPE and test BOPE to 300/5000 psi. MW: 12.0 VISC: 90 PV/YP: 47/40 APIWL: 4.7 DOING FIT Safety meeting. Test casing to 3000 psi for 30 min. No bleed off. Drill cement and float equipment and cleanout rathole to 10516'. Hole packing off w/high torque. Circ and displace hole w/12.0 ppg mud. MW: 12.7 VISC: 57 PV/YP: 32/19 APIWL: 4.5 MAKING MAD PASS Circ and raise mud weight to 12 ppg. Clean out cement from 10518' to 10580' and drill 20' of new hole to 10600'. Perform FIT to 16.2 ppg EMW. Drill from 10600' to 10630. Raise mud weight to 12.4 ppg. Run FIT to 17.2 ppg EMW wi no breakover. Drill from 10634' to 10955'. MW: 12.7 VISC: 63 PV/YP: 31/31 APIWL: 3.2 RIH W/LINER Drill from 10955' to 10980'. Hold safety meeting. Date: 4/2/98 03/02/98 (D17) TD : 1 0 9 8 0' ( 0 ) SUPV:GRW 03/03/98 (D18) TD : 1 0 9 8 0' ( 0 ) SUPV:DEB 03/04/98 (D19) TD : 10 9 8 0' ( 0 ) SUPV:DEB ') ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 12.6 VISC: 60 PV/YP: 33/29 APIWL: 4.0 L/D 3 1/2" DRILLPIPE R/U casers and hold safety meeting. Run 4-1/2" liner + marker jt + liner hanger w/ packer. Pump cement liner. MW: 12.7 VISC: 60 PV/YP: 33/29 APIWL: 4.0 DISPLACING WELL-CLEAN SEAWATER Circulate and condition mud. POH - LD 30 jts 3-1/2"DP. POH LDDP. Pre-job safety mtg on running tubing. MW: 12.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED @ 2100 HRS 3/4/98 Close SSSV and secure well. Prepare for rig move. Release rig. End of WellSumrnary for Well:AK9117 ) ARca Alaska, Inc. .....~ ~". JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERFORATE 20' ZONE 10696' TO 10716' OPERATION COMPLETE SUCCESSFUL YES YES Initial Tbg Press Final Tbg Press Initial Inner Ann o PSI 690 PSI 0 PSI WELL 1 C-14 DATE 03/17/98 DAY 2 ') KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (1 C-14(W4-6» JOB NUMBER 0309981559.2 UNIT NUMBER KEY PERSON SUPERVISOR SWS-ELMORE SCHUROSKY Final Inner Ann Initial Outer Ann Final Outer Ann o PSI 200 PSI 200 PSI DAILY SUMMARY I PERFORATE 20' ZONE 10696' TO 10716' WITH 2.5" HSD GUN 4SPF 180 DEG. PHASE. + - 90 DEG. FROM BOTTOM TIME LOG ENTRY 08:30 MIRU SWS #8293 ELMORE, HOLD TGSM, RESTRING AND TIE HEAD. 11 :30 MAKE UP TOOLS, PT LUB & BOP TO 3000#, RIH WITH 20' X 2.5" HSD GUN, 4SPF, 180 DEG. PHASE! + - 90 DEG. FROM BOTTOM. GUN GRI ROLLER ON BOTTOM OF GUN. 13:00 TIE INTO SPERRY MWD LOG DATED 3-1-98 CORRECTED 6'. 13:30 PUMP TBG. UP TO 700 PSI TO GET TO AN UNDER-BALANCE OF + - 300 PSI. LOG INTO POSITION AND SHOOT GUN AT 10696' TOP SHOT 10716' BOTTOM SHOT WITH GOOD INDICATION AT SURFACE. POOH, CHECK FOR MISFIRES, START RD. 14:30 COMPLETE RIG DOWNI MOVE OFF. ) ) WELL 1 C-14 DATE 03/27/98 DAY ARca Alaska, Inc. ~~ ~,.. JOB SCOPE FRAC, FRAC SUPPORT DAILY WORK "C" SAND SKIN FRAC OPERATION COMPLETE YES Initial Tbg Press Final Tbg Press 1000 PSI 600 PSI KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (1 C-14(W4-6» JOB NUMBER 0323980810.4 UNIT NUMBER 1 SUCCESSFUL YES Initial Inner Ann 900 PSI KEY PERSON DS-GALLEGOS Final Inner Ann Initial Outer Ann 500 PSI 600 PSI SUPERVISOR CHANEY Final Outer Ann 700 PSI DAILY SUMMARY "C" SAND SKIN FRAC COMPLETED THRU FLUSH. INJECTED 26708 LBS OF PROP IN THE FORMATION WI 7# PPA OF #12/18 @ THE PERF'S.FREEZE PROTECTED TBG WI 20 BBLS OF DIESEL DOWN TO 2300' RKB. MAXIMUM PRESSURE 7400 PSI AND F.G. (.71) TIME LOG ENTRY 08:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCK. 10:30 ONE OF THE TURBINE PUMPS BAD. STOOD-BY TO GET ANOTHER FROM DEADHORSE SHOP. 13:00 TURBINE FROM DEADHORSE ARRIVED. HELD SAFETY MEETING (18 PEOPLE ON LOCATION). 13:15 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9300 PSI. 13:45 PUMP BREAKDOWN WI 30# GW & 50# DELAYED XL GW @ 22 TO 10 BPM. SLURRY VOLUME PUMPED 275 BBLS. USED 2165 LBS OF #16/20 PROP FOR SCOURING. MAXIMUM PRESSURE 7300 PSI AND ENDING PRESSURE 2200 PSI. SID AND OBTAINED ISIP OF 1762 PSI WI F.G. @ (.71). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 13 MINS @ 1600 PSI. 15:00 PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 8 BPM. SLURRY VOLUME 157 BBLS. MAXIMUM PRESSURE 3650 PSI AND ENDING PRESSURE 2500 PSI. SID AND OBTAINED ISIP OF 1767 PSI WI F.G. @ (.71). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 18.4 MINS @ 1070 PSI. PAD VOLUME = 7 BBLS. 16:40 PUMP FRAC WI 30# GW & 50# DELAYED XL GW @ 8 BPM. COMPLETED THRU FLUSH. PUMPED 27282 LBS OF PROP (7832 LBS OF #16/20 & 19450 LBS OF #12/18). INJECTED 26708 LBS OF PROP IN THE FORMATION WI 7# PPA OF #12/18 @ THE PERF'S. LEFT 574 LBS OF PROP IN THE WELLBORE, EST FILL LEVEL @ 10800' RKB. EST BHP @ 3200 PSI. FREEZE PROTECTED TBG WI 20 BBLS OF DIESEL DOWN TO 2300'. SLURRY VOLUME PUMPED 310 BBLS. MAXIMUM PRESSURE 4900 PSI AND ENDING PRESSURE 2900 PSI. TIME LOG ENTRY 17:15 STARTED RID. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND RID LRS HOT OIL UNIT. 18:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED RID. 19:30 RID COMPLETE AND ALL WELL SERVICE PERSONNEL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. ) ') Page 1 SPERRY-SUN DRILLING SERVICES '1~. 0 f r-¡ KUPARUK RIVER UNIT 1C-14(A) MAR 1, 1998 50-029-22861-00 NORTH SLOPE MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH DEG DEG DEPTH FEET FEET SECTION LEG 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 121.00 0.00 0.00 121.00 0.00 0.00 0.00 0.00 160.24 1.04 147.85 160.24 0.30 S 0.19 E 0.06 2.65 282.50 2.26 76.77 282.45 0.69 S 3.13 E 2.63 1.77 372.86 6.07 69.54 372.56 1.39 N 9.34 E 9.17 4.25 451.22 9.89 63.82 450.15 5.81 N 19.26 E 20.03 4.97 549.66 13.61 60.35 546.51 15.27 N 36.92 E 39.96 3.84 641.47 17.70 64.39 634.90 26.65 N 58.91 E 64.62 4.61 732.10 23.06 67.28 719.83 39.47 N 87.72 E 96.14 6.02 821.72 29.20 65.94 800.25 55.18 N 123.91 E 135.58 6.88 911.58 31.96 65.24 877.60 74.08 N 165.53 E 181.26 3.10 1002.75 35.44 66.23 953.44 94.85 N 211.65 E 231.81 3.86 1093.18 41.40 66.69 1024.26 117.27 N 263.15 E 287.97 6.60 1185.53 47.14 68.20 1090.36 141.94 N 322.67 E 352.40 6.32 1277.94 51.71 67.54 1150.45 168.39 N 387.67 E 422.57 4.97 1372.66 51.54 67.20 1209.26 196.96 N 456.20 E 496.83 0.33 1467.64 53.28 68.61 1267.19 225.26 N 525.94 E 572.08 2.18 1562.87 53.87 68.54 1323.74 253.25 N 597.27 E 648.70 0.62 1749.69 56.38 70.06 1430.56 307.39 N 740.63 E 801.88 1.50 1936.33 57.60 69.48 1532.23 361.51 N 887.48 E 958.29 0.70 2120.31 57.18 67.67 1631.39 418.11 N 1031.74 E 1113.23 0.86 2307.85 56.29 68.04 1734.26 477.22 N 1176.98 E 1270.04 0.50 2590.39 55.08 66.18 1893.54 567.96 N 1391.96 E 1503.37 0.69 2867.31 55.74 66.79 2050.75 658.91 N 1601.00 E 1731.29 0.30 3238.88 56.40 67.27 2258.15 779.22 N 1884.85 E 2039.57 0.21 3604.58 56,. 29 68.61 2460.83 893.55 N 2166.96 E 2343.96 0.31 3981.35 56.92 67.02 2668.21 1012.33 N 2458.22 E 2658.50 0.39 4359.27 57.01 68.21 2874.24 1132.98 N 2751.16 E 2975.32 0.27 4729.97 56.42 67.81 3077.68 1249.01 N 3038.50 E 3285.20 0.18 5103.08 56.86 69.02 3282.86 1363.65 N 3328.27 E 3596.79 0.30 5195.78 56.84 68.48 3333.55 1391.78 N 3400.61 E 3674.39 0.49 5572.50 53.27 67.04 3549.31 1508.55 N 3686.41 E 3983.13 1.00 5756.81 54.19 68.76 3658.35 1564.44 N 3824.08 E 4131.71 0.90 5942.07 55.70 71.36 3764.76 1616.12 N 3966.63 E 4283.20 1.41 6128.43 54.83 71.81 3870.94 1664.50 N 4111.94 E 4435.99 0.51 6219.53 54.60 71.78 3923.57 1687.74 N 4182.58 E ,4510.16 0.25 6407.68 56.31 71.26 4030.26 1736.86 N 4329.55 E 4664.78 0.94 6690.37 56.63 69.48 4186.41 1816.03 N 4551.49 E 4900.15 0.54 6971.47 55.84 65.19 4342.70 1906.01 N 4767.06 E 5133.74 1.30 7223.93 54.05 64.98 4487.69 1993.06 N 4954.49 E 5340.19 0.71 ORËG~NAl ') ) Page 2 SPERRY-SUN DRILLING SERVICES KUPARUK RIVER UNIT 1C-14(A) MAR 1, 1998 50-029-22861-00 NORTH SLOPE MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH DEG DEG DEPTH FEET FEET SECTION LEG 7449.92 58.84 65.31 4612.57 2072.18 N 5125.33 E 5528.29 2.12 7636.96 56.35 67.88 4712.81 2134.94 N 5270.20 E 5686.14 1.77 7913.59 55.59 67.33 4867.62 2222.28 N 5482.16 E 5915.39 0.32 8194.52 53.46 66.61 5030.65 2311.76 N 5692.70 E 6144.14 0.79 8475.37 55.48 66.56 5193.85 2402.58 N 5902.43 E 6372.65 0.72 8846.54 57.35 66.42 5399.16 2525.93 N 6185.96 E 6681.78 0.50 9219.61 53.98 66.87 5609.56 2648.06 N 6468.73 E 6989.75 0.91 9497.31 53.76 65.43 5773.30 2738.74 N 6673.86 E 7213.95 0.43 9684.58 57.43 67.49 5879.10 2800.38 N 6815.50 E 7368.39 2.16 9870.41 55.45 68.92 5981.83 2857.89 N 6959.26 E 7523.22 1.24 9964.18 53.40 70.36 6036.38 2884.43 N 7030.75 E 7599.44 2.52 10057.64 50.94 71.10 6093.70 2908.80 N 7100.43 E 7673.14 2.71 10151.56 47.89 70.46 6154.79 2932.27 N 7167.77 E 7744.35 3.29 10243.80 44.99 68.55 6218..35 2955.64 N 7230.38 E 7811.15 3.48 10336.00 42.72 65.31 6284.84 2980.63 N 7289.15 E 7875.00 3.46 10430.84 41.89 65.26 6354.98 3007.32 N 7347.13 E 7938.78 0.88 10524.10 41.00 65.25 6424.89 3033.16 N 7403.19 E 8000.45 0.95 10603.67 40.53 66.59 6485.16 3054.36 N 7450.63 E 8052.38 1.25 10701.03 40.25 68.39 6559.31 3078.51 N 7508.90 E 8115.46 1..23 10794.29 40.66 66.70 6630.28 3101.63 N 7564.82 E 8175.97 1.26 10882.91 40.36 67.20 6697.66 3124.17 N 7617.79 E 8233.53 0.50 10980.00 40.36 67.20 6771.64 3148.53 N 7675.75 E 8296.40 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 67.66° (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 8296.41 FEET, IN THE DIRECTION OF 67.70° (TRUE) ) sper'r'v-sun CAlL-LING SEAVICES AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 <q\ß .--0\1 Re: Distribution of Survey Data for Well 1 C-14 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 0.00' MD Window I Kickoff Survey: n/a' MD (if applicable) Projected Survey: 10,980.00' MD Please call me at 563-3256 if you have any questions or concerns. Regards, it- William T. Allen Survey Manager Attachment(s) '. .' -. ~ ~ ,; 13-May-98 ~~ ~~LI !~-ð 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 . Fax (907) 563-7252 A Division of Dresser Industries, Inc, CfS,ol'l J Kuparuk Unit Kuparuk 1 C 1C-14 ~JI1/~g SURVEY REPORT 13 May, 1998 Your Ref: API-500292286100 Last Survey 01-March-98 Job # AKMM80128 KBE -101.30' OR1G~NAl spe...,...,v-sun DRILLING seRVIc:es A DI\1SIO:"t or DRI'.:S3£R ISDlISfRID. I:'IiC. Survey Ref: svy2 Sperry-Sun Drilling Services . Survey Report for 1C-14 Your Ref: API-500292286100 Kuparuk Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 0.00 0.000 0.000 -101.30 0.00 0.00 N 0.00 E 5968672.21 N 562146.39 E 0.00 50.00 0.000 0.000 -51.30 50.00 0.00 N 0.00 E 5968672.21 N 562146.39 E 0.000 0.00 121.00 0.000 0.000 19.70 121.00 0.00 N 0.00 E 5968672.21 N 562146.39 E 0.000 0.00 160.24 1.040 147.375 58.94 160.24 0.305 0.19 E 5968671.91 N 562146.58 E 2.650 0.06 282.50 2.260 76.295 181.15 282.45 0.665 3.13 E 5968671.55 N 562149.52 E 1.767 2.63 372.86 6.070 69.065 271.26 372.56 1.47 N 9.33 E 5968673.68 N 562155.72 E 4.248 9.17 451.22 9.890 63.345 348.85 450.15 5.97 N 19.22 E 5968678.18 N 562165.61 E 4.973 20.03 549.66 13.610 59.875 445.21 546.51 15.58 N 36.80 E 5968687.79 N 562183.19 E 3.845 39.96 641.47 17.700 63.915 533.60 634.90 27.14 N 58.68 E 5968699.35 N 562205.07 E 4.608 64.62 732.10 23.060 66.805 618.53 719.83 40.20 N 87.39 E 5968712.41 N 562233.78 E 6.016 96.14 821.72 29.200 65.465 698.95 800.25 56.20 N 123.45 E 5968728.41 N 562269.84 E 6.882 135.58 911.58 31.960 64.765 776.30 877.60 75.45 N 164.91 E 5968747.66 N 562311.30 E 3.097 181.26 1002.75 35.440 65.755 852.14 953.44 96.60 N 210.85 E 5968768.81 N 562357.24 E 3.864 231.81 1093.18 41.400 66.215 922.96 1024.26 119.44N 262.17 E 5968791.65 N 562408.56 E 6.598 287.97 1185.53 47.140 67.725 989.06 1090.36 144.61 N 321.48 E 5968816.82 N 562467.87 E 6.319 352.40 1277.94 51.710 67.065 1049.15 1150.45 171.59 N 386.26 E 5968843.80 N 562532.65 E 4.975 422.57 1372.66 51.540 66.725 1107.96 1209.26 200.73 N 454.56 E 5968872.94 N 562600.95 E 0.334 496.83 1467.64 53.280 68.135 1165.89 1267.19 229.60 N 524.05 E 5968901.81 N 562670.44 E 2.177 572.08 1562.87 53.870 68.065 1222.44 1323.74 258.18 N 595.15 E 5968930.39 N 562741.54 E 0.622 648.70 1749.69 56.380 69.585 1329.26 1430.56 313.51 N 738.06 E 5968985.72 N 562884.45 E 1.500 801.88 1936.33 57.600 69.005 1430.93 1532.23 368.85 N 884.46 E 5969041.06 N 563030.85 E 0.704 958.29 2120.31 57.180 67.195 1530.09 1631.39 426.64 N 1028.25 E 5969098.85 N 563174.64 E 0.860 1113.23 2307.85 56.290 67.565 1632.96 1734.26 486.95 N 1172.99 E 5969159.16 N 563319.38 E 0.502 1270.04 2590.39 55.080 65.705 1792.24 1893.54 579.47 N 1387.21 E 5969251.68 N 563533.60 E 0.692 1503.37 2867.31 55.740 66.315 1949.45 2050.75 672.15 N 1595.49 E 5969344.36 N 563741.88 E 0.299 1731.29 3238.88 56.400 66.795 2156.85 2258.15 794.80 N 1878.34 E 5969467.01 N 564024.73 E 0.207 2039.57 3604.58 56.290 68.135 2359.53 2460.83 911.46 N 2159.49 E 5969583.67 N 564305.88 E 0.306 2343.96 3981.35 56.920 66.545 2566.91 2668.21 1032.66 N 2449.75 E 5969704.87 N 564596.14 E 0.390 2658.50 4359.27 57.010 67.735 2772.94 2874.24 1155.73 N 2741.68 E 5969827.94 N 564888.07 E 0.265 2975.32 4729.97 56.420 67.335 2976.38 3077.68 1274.14 N 3028.05 E 5969946.35 N 565174.44 E 0.183 3285.20 Continued... 13 May, 1998 - 0:22 - 2- DrillQuest Sperry-Sun Drilling Services . Survey Report for 1C-14' Your Ref: API-500292286100 Kuparuk Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) ',} 5103.08 56.860 68.545 3181.56 3282.86 1391.16N 3316.87 E 5970063.37 N 565463.26 E 0.295 3596.79 5195.78 56.840 68.005 3232.25 3333.55 1419.89 N 3388.97 E 5970092.10 N 565535.36 E 0.488 3674.39 5572.50 53.270 66.565 3448.01 3549.31 1539.03 N 3673.79 E 5970211.24 N 565820.18 E 0.998 3983.13 5756.81 54.190 68.285 3557.05 3658.35 1596.06 N 3811.00 E 5970268.27 N 565957.39 E 0.903 4131.71 5942.07 55.700 70.885 3663.46 3764.76 1648.92 N 3953.11 E 5970321.13 N 566099.50 E 1 .409 4283.20 6128.43 54.830 71.335 3769.64 3870.94 1698.50 N 4098.01 E 5970370.71 N 566244.40 E 0.507 4435.99 6219.53 54.600 71.305 3822.27 3923.57 1722.32 N 4168.46 E 5970394.53 N 566314.85 E 0.254 4510.16 6407.68 56.310 70.785 3928.96 4030.26 1772.66 N 4315.02 E 5970444.87 N 566461.41 E 0.937 4664.78 6690.37 56.630 69.005 4085.11 4186.41 1853.66 N 4536.29 E 5970525.87 N 566682.68 E 0.537 4900.15 6971.47 55.840 64.715 4241.40 4342.70 1945.42 N 4751.11 E 5970617.63 N 566897.50 E 1.299 5133.74 7223.93 54.050 64.505 4386.39 4487.69 2034.02 N 4937.81 E 5970706.23 N 567084.20 E 0.712 5340.19 7449.92 58.840 64.835 4511.27 4612.57 2114.56 N 5107.99 E 5970786.77 N 567254.38 E 2.123 5528.28 7636.96 56.350 67.405 4611.51 4712.81 2178.52 N 5252.34 E 5970850.73 N 567398.73 E 1.766 5686.14 7913.59 55.590 66.855 4766.32 4867.62 2267.61 N 5463.57 E 5970939.82 N 567609.96 E 0.320 5915.39 8194.52 53.460 66.135 4929.35 5030.65 2358.83 N 5673.36 E 5971031.04 N 567819.75 E 0.786 6144.14 8475.37 55.480 66.085 5092.55 5193.85 2451.38 N 5882.33 E 5971123.59 N 568028.72 E 0.719 6372.65 8846.54 57.350 65.945 5297.86 5399.16 2577.07 N 6164.82 E 5971249.28 N 568311.21 E 0.505 6681.78 9219.61 53.980 66.395 5508.26 5609.56 2701.54 N 6446.58 E 5971373.75 N 568592.97 E 0.909 6989.75 9497.31 53.760 64.955 5672.00 5773.30 2793.92 N 6650.95 E 5971466.13 N 568797.34 E 0.426 7213.95 9684.58 57.430 67.015 5777.80 5879.10 2856.73 N 6792.07 E 5971528.94 N 568938.46 E 2.160 7368.39 9870.41 55.450 68.445 5880.53 5981.83 2915.43 N 6935.36 E 5971587.64 N 569081.75 E 1.244 7523.22 9964.18 53.400 69.885 5935.08 6036.38 2942.56 N 7006.63 E 5971614.77 N 569153.02 E 2.518 7599.44 10057.64 50.940 70.625 5992.40 6093.70 2967.50 N 7076.09 E 5971639.71 N 569222.48 E 2.705 7673.14 10151.56 47.890 69.985 6053.49 6154.79 2991.53 N 7143.24 E 5971663.74 N 569289.63 E 3.288 7744.35 10243.80 44.990 68.075 6117.05 6218.35 3015.42 N 7205.66 E 5971687.63 N 569352.05 E 3.483 7811.15 10336.00 42.720 64.835 6183.54 6284.84 3040.89 N 7264.21 E 5971713.10 N 569410.60 E 3.462 7875.00 10430.84 41.890 64.785 6253.68 6354.98 3068.06 N 7321.98 E 5971740.27 N 569468.37 E 0.876 7938.78 10524.10 41.000 64.775 6323.59 6424.89 3094.36 N 7377.82 E 5971766.57 N 569524.21 E 0.954 8000.45 10603.67 40.530 66.115 6383.86 6485.16 3115.96 N 7425.07 E 5971788.17 N 569571.46 E 1.248 8052.38 10701.03 40.250 67.915 6458.01 6559.31 3140.59 N 7483.15 E 5971812.80 N 569629.54 E 1.232 8115.46 Continued.. . 13 May, 1998 - 0:22 -3- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-14 Your Ref: API-500292286100 . Kuparuk Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) (ft) ) 10794.29 40.660 66.225 6528.98 6630.28 3164.17 N 7538.87 E 5971836.38 N 569685.26 E 1.255 8175.97 10882.91 40.360 66.725 6596.36 6697.66 3187.15 N 7591.65 E 5971859.36 N 569738.04 E 0.499 8233.53 10980.00 40.360 66.725 6670.34 6771.64 3211.99 N 7649.41 E 5971884.20 N 569795.80 E 0.000 8296.40 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to Grid North. Vertical depths are relative to Well Referance. Northings and Eastings are relative to Well Referance. The Dogleg Severity is' in Degrees per 100ft. Vertical Section is from Stucture and calculated along an Azimuth of 67.185° (Grid). Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot. Grid Convergence at Surface is 0.475°. Based upon Minimum Curvature type calculations, at a Measured Depth of 10980.00ft., The Bottom Hole Displacement is 8296.41ft., in the Direction of 67.222° (Grid). 13 May, 1998 - 0:22 -4- DrillQuest ARca Alaska, Inc. LII SSSV (1830-1831, OD:3.500) TUBING (0-10336, OD:3.500, ID:2.992) Gas Lift landrel/Dummy Valve 1 (3835-3836, OD:5.500) Gas Lift landrel/Dummy Valve 2 (6523-6524, OD:5.500) Gas lift landrel/Dummy Valve 3 (8478-8479, OD:5.500) Gas lift landrel/Dummy Valve 4 (9634-9635, OD:5.500) Gas Lift landrel/Dummy Valve 5 (10226-10227, OD:6.018) NO GO (10272-10273, OD:3.500) PKR (10300-10301, OD:6.151) LINER (10300-10980, OD:4.500, Wt:12.60) SEAL ASSY (10311-10312, OD:4.000) SBE (10321-10322, OD:4.500) TUBING TAIL (10337-10338, OD:3.500) Perf (10696-10716) 'J_; .. I······~ '11': . 'J -J , IF_ I 1 I \ , ¡ ~ .~ ~". KRU '" 98 - Of? 1 C-14 Well Type: INJ Orig Compltn: 3/4/98 Last W/O: Ref Log Date: TD: 10980 ftKB Max Hole Angle: 59 deg @ 7450 Angle @ TS: 40 deg @ 10664 Angle@ TD: 40 deg @ 10980 Rev Reason: Tag fill by ImO Last Update: 1/14/99 Bottom TVD 121 121 Bottom TVD 7292 4525 Bottom TVD 10503 6409 Bottom TVD 10980 10980 Bottom TVD 10336 6285 Wt 62.58 Grade H-40 Thread API: 500292286100 SSSV Type: Cameo 'TRDP-4E' Annular Fluid: Reference Log: Last Tag: 10896 LastTag Date: 1/13/99 Càsi ngStl'i rig-CONQUCrOR Size I Top I 16.000 0 Casing String· SURFACE Size I Top I 9.625 0 CasinQ$tring···PRODLJCTION Size I Top I 7.000 0 C8sIng·'.SfrinCi'.·..L.INER Size I Top I 4.500 10300 TUbll1gSìrlng.·;,TUB.ING Size I Top I 3.500 0 Pertol"stlons$Uml'l'låry Interval TVD Zone Status Feet SPF Date Type 10696 - 10716 6555 - 6571 C-4,C-3 20 4 3/17/98 21/2" HSD Gas Lift MandrelsNalves Stn MD TVD Man Man V Mfr V Type Mfr Type 1 3835 2588 Cameo KBMM 2 6523 4094 Cameo KBMM 3 8478 5195 Cameo KBMM 4 9634 5851 Cameo KBMM 5 10226 6206 Cameo MMM Other (plugs, equip., etc.) . JEWELRY Depth TVD Type 1830 1474 SSSV Cameo'TRDP-4E' 10272 6239 NO GO Cameo 'D' Nipple 10300 6259 PKR Baker 'ZXP' Pkr 10311 6267 SEAL ASSY Baker Locator 10314 6269 HNGR Baker 'HMC' Liner Hanger 10321 6274 SBE Baker 10337 6286 TUBING TAIL Wt Grade Thread 26.00 L-80 Wt Grade Thread 12.60 L-80 Wt Grade Thread 9.30 L-80 ABM EUR Comment 180 deg. phasing; Oriented (+1-) 90 deg. V aD Latch Port TRO Date Run 3/8/98 3/8/98 3/8/98 3/8/98 3/8/98 Vlv Comment DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 1.5 RK 0.000 0 Description ID 2.812 2.750 4.438 3.000 4.438 4.000 2.992 GeneràFNotes Date I Note 8/12/98 Asphaltines in tubing @ 10190' SENT BY:ARCO ALASKA 1-28-99 ; 3:29PM ; KPS/WELLS/CNST/PROJ~ ') 907 276 7542;# 1/11 98-0,.1 ,[ lC -" I'^: t W~-14KRU) ~ - WELL INFORMATION SITP 0 psi. ~" "YELL HIST9RY HANDOVER FOR'" To Production To Drilling 7" Casing Press. o psi, 9~5J8·t Casing Pres$~ -750 ~s¡ 6HP psi/depth Date Instrument Packer fluid: piesellª~W Weight: 6.8/8.6 ppg Tubin~ fluíd: Diesel'SV\(!~.ud Post-it' Fax Note 11). ø t,,- \. v:- Co./Dept. Phone # Faxfl' SSSV Status: xx AFE NumbeL--ð~K 9117 1671 l~~res ~ From .:z f) t V" ( "-- f~ J s,. r CV) Co. IIfÇ(.t:¡'. PhOne , Dafe Fax # { ~ ~ QJRECTIONAL INFORMATION RKB: 36.60' TbQ Hgr L~§ KOP ªOO' A~ Hole Angle ., ..",_",. .?~" Max angle of 58.8" @ 7450' Hole Angle @ TD 40.4" Weight 6.8/6.6/12,7 ppg Size WI. Condo ,. 16~' .52.Set'. Surf. 9·5/8" 40# Prod. '''' _ 7~1 26# Liner. , 4~1l~'1j2,1$# Tubing: 3-1/2" 9.3# Weil Head; VVKM 3~1/a" p K,~i Tree. J=MC Gen IV Wellheads (Type/Pressure Rating) CASIN G1T.UBING Dl~J: A Grade Conn. Depth t1~.O YVelded 121' L-80 _~IC _. 7292' , '-..(jO ~TC Mod 1 O,,~03' L.-Sø NSCT 10300- 1098 L-a9 .""., ABM~~UE 10,336'. Trè8 Cap Conn ,ºti,~. Union Tbg Hgr Conn ,..ª:.1/2" EUE . ~.EW. ADD OR RE-PËRFED IN,ERVI\LS Type Guns SPF From I2. ~]uJCIIW:t....; ...,... ·irVV~~"'''rI'r,-jAI'J. i. .~II ~~ /tfP . q. /0 VII, Rig r$Ieased subsequant to full ~II ocmpletion as required on statu Drilling p~rmf ..,.3"'-- Yes _ '. No ìC711t1, If no, specify remaining operations: ~..". ..~. ... COMPLETION INFO~MAJ.19~ Tapa MfgrlType/Size/durntny Or Orifice/Latch J.Mm. f(!r-.<.:· . ~ ~.J.L :$ Ve.:A 3 -ti9 - sssv CAMCQ.~::l[~,'~ 1'ROP-4e' sssv. ~!!'I HGS-~63, 2.812" tD ~ GLM CAMeo 3-112" x 1" KBMM. DV. BK-5latch GlM ~CAMCO ~_112" x 1ï.- KBMM. ~y.~ B,K-5 I~tc~ -.~.~ GlM CAMCO 3-1/2" x 1" KBMM. DV. ~K-5 iatch' GLM CAMC9 ~:!/2" x 1" KBMM. DV, BK-5latch GLM CAMCO 3-1J2")( 1-112" MMM, DV, RK latch NIP CAMCO 3-1J2" D-NiØple, 2.750" tD LSA BA~ER.~.oc~lto~ Seal Ass~mbly~.~: 00. s8~.I~.. locator Rõ)' Bottom of locator ~=>:> .E\ottom of Seal AS6emby'~~:» . ~.. ~.... ".-- - 3835' 6523' .!ill:. ~ .. 1 º,--226' '?)-.ß ''"19 10,272' 10.311' 10,312' 10,337' 4-112" Uner - TUbina Seals stabbed into.. SSE be/ow Liner Hanasr PKF B.AKER.ZXP..Liner Pack~rJ 4·71~91·ID '[QP Q.f LI~l!r_=>.. HGR BAKER HM.C.Llner Hanger, 4·7/16" 10 see BA~ER Seal Bo~o .E~.f~msion. 4" ID . MJ 4:,,112" Marker Pup J~ints LC .BA~~R 4·112" landíng .ColI~r . . PBTD ;=» FS BAKER 4·1/2" Float Shoe Bottom of Shoe ==» . . . .' --, .-.. -. Drilling Department Rep~~n ~. Bre~Ø.eJ:l. 10....300' 10,314' 10,321' 10.638' 10,883' 10.980' Perforate, FR~'<::.? - - .. ",- .". .. N'ore ~ - r--(Á(',&60' Ht{ ~ft~ft'I'Oq~8: ÍlKØ 3 ','1 f}' " "~""1. . JENVIRONMENTAL SIIF INSPECTION Loca~Qn ~Iean. · !&NfBA-~ tNFORMATION Put -~800' Diesel caø Qn .TubinR _~ A.nn~lu$,.__ Clean Sea Water below there t~ ~9P- af liner in both tu~!~g.~ a~nLl.I!Js: 12.7 PP9 Mud in 4-112'~~~ner_~ ,.. PBTD. _r _ .... ..... ... T~þinQ & Annulys tested,.Cl0od to 350~ psi. - 9-5/8" x 7" Annutus was fJushed with water. . .. . fOllowed by a 60 Bbls of Diesel for Freez~ Protection - it has NOT been Arctic Packed, - .. ..... - . ~. - . Do NOT Bleed Off 9-5J8" x r Annulus III .. -. - Tubing Detail Attached Title QfÏ.lljrtQ Superviso! . Date 3I8/9B Production/OperDept.Rep. ~Lhz~~ Title ./JSr Date ¥ø/,.~ SENT BY:ARCO ALASKA , ARCa Alaska, Inc. ~-... ~". "'WELL 1C-14 DATE 03/18/98 DAV' , 3 FIELb ESTIMATE 1-28-99 KPS/WELLS/CNST/PROJ~ 907 276 7542;# 2/11 Y· ~fARUK RIVER UNIT Wf:.-..L SERVICE REPORT K1 (1 C-14(W4-6» JOB NUMBt:J~ 0309981559.2 'UNIT NUMBER 70356 '"KEY PERSON SUPERVISOFf' ..-,.. HES..SCHNEIDER FITZP:ÄTRICK ACCUM COST Signed'- $24,'30 _ Finai ïnneT Ann llnitiai Outer Ann I Final Outer Ann 1 000 PSI _._ 250 PSI _ __250P~.I 3:30PM JOB SCOPE P~RFORATE.PERFSUPPORT DAILY WORK ..... BHP, GASLIFT & þ/r CSG '" ""'OPERATION COMPLETE I SUecEssrÜ'l. (i) Yes 0 NQ _.....(i) Yes ,0 No AFC# ec# DAllVê'ðST ._, ...~9~148 ~ 230DS10CG $1,914 Initial Tbg Press 'Final Tbg Press Initial Inner Ann 950 PSI 950 PSI 1000P~.t , DAilY SUMM~RY ..., ...., I MEASURED BHP @ ÙjSOOï ~,~,~: 366~, P~H. SET DV @ 10226~ RKB. TESTED'¡ií'CSG ~~~_.PS'r G<?ºº TeST. TIME 07:15 .. . 08:30 11 :30 13:20 14:15 -----....,.... .. . lOG E~T.~V . ._...........,,' u,," MTTGSM: SCAFFOLDING LADDER, WELL HOUSE DOORS ARE NOT WORKING PAOPERl Y (HINGES ARE'SEIZEI UP)- RU TS: 1.815" RS. OC, ,~\..~~' 5', KJ~.~~S, QC- PfT LUB TO 750# MAKE UP DUAL 6000# AMEFlADAS UPPER & LOWER LUB 926# & 894# 10300' RKB- 10284' WLM 3666# & 3600# 10706' AK8-10670' WlM 3766# & 3731# lUB 945# & 920ft .... ."-,,, " .... ""~.__.- RIH W/3" OM-1 & 1~~'I...DV O~J:~~ TO 10200' WlM (10226' RKB) SET- POOH .., u..._. LRS ON lOC- RIG UP TO 7" CSQ- pIT CSG TO 3000# W/3 BBlS OF DIESEL- HELD SOLID FOR 20 MIN. BLED BACKTO 1000#- RDMO TO 1C-12 ,,'. ..."......'."...",. ._,.__.."..,.~".. ..,,,,-, "-"-"" -. . .... . .. . .,....-'... ....,..--.,........T'I'"'ftO"!~''IN...._,.......oOII '..,·\·'..,....,1.___ -··..··-·"'1'.'",\"'., SERVICE' COMPANY. SERVICE DAIL ý' CÕST $12.60 , $0.00 '"u $0.00 $J.692.24 .,. $210.00 . $0.00 $' ,914.84 ACCUM TOTAL . ..__'''. .... ~~_?~O $6,000.00 . , u '$6~5ÖO.OO $3,108.24 ~21 0.00 $8,300.00 $24,130.84 APC DOWELL HALLIBURiON LÍTILE RED SCHlUMBERGER TOTAL FIELD ESTIMATE ) ) sper-r-\l-sun C RILL IN C; 5 e R V I c:: e 5 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 9"8· or 1 RE: MWD FonnationEvaluation Logs lC-14, AK-rvIM:-80128 April 9, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 lC-14: 2" x 5" 1\1D Resistivity & Gamma Ray Logs: 50-029-22861-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22861-00 1 Blueline 1 Folded Sepia 2" x 5" 1\1D Neutron & Density Logs: 50-029-22861-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Neutron & Density Logs: 50-029-22861-00 1 Blueline 1 Folded Sepia C?~~ 'I/9/9g 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. ) ) sper'r'v-sun ----'.- -".---' ,..,.--,-..._'--" ,......_."._..~.._._..."----_...-._..,,' .,,---.. CRILLING SERVICES "._--_...,--,_.__...~ . - ~ - - .-. .-......-----.-.--..-."...... ...,.. . ".,. ..-,.. WELL LOG TRANSMITTAL To: State of Alaska April 8, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. q<J 0/7 ,1 ( \ Anchorage, Alaska 99501 0 / .cr:- <3 -\ \ RE: MWD Formation Evaluation Logs 1 C-14, AK-Ml\1-80128 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22861-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A TT ACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: '-/ 1'6 /c,'6 Si~~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. ) ) TONY KNOWLES, GOVERNOR ALASIiA. OIL Al¥D GAS CONSERVATION COMMISSION Febnmry 5, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Fred 10hnson, Drilling Engineer ARCa Alaska, Inc. P a Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit lC-14 ARCa Alaska, Inc. Permit No. 98-0017 Sur. Loc. 1566'FNL, 1139'FWL, Sec. 12, TllN, RI0E, UM Btmhole Loc. 1574'FSL, 1781 'FEL, Sec. 06, TIIN, RIlE, UM Dear Mr. 10hnson: Enclosed is the approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations. The blowout prevention equipment (SOPE) must be tested in accordance \vith 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the SOPE test performed bcforc drilling bclow the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David \V. Johnston Chairman , "'- BY ORDER OF THE COMMISSION ~ dlf/Enc losu re cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation \\'10 encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b Type of Well Exploratory D Stratigraphic Test D Development Oil D Service X Development Gas D Single Zone X Multiple Zone D 5. Datum Elevation (OF or KB) 10. Field and Pool RKB 41', Pad 61' feet Kuparuk River Field 6. ~. prO%;~eSignation V" Þ\\ '^"\, .Kuparuk Oil Pool I'" ~ ).&f.l t:1,1.q.:t A- 1.'~UW'Io\..~( ADL , ALK 467 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ORiG:NAL ') 1a. Type of Work Redrill Drill X 2. Re-Entry Name of Operator ARCO Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface Deepen 3. 4. 1566' FNL, 1139' FWL, Sec. 12, T11N, R10E, UM At top of productive interval (@ TARGET) 1517' FSL, 1920'FEL,Sec.6,T11N, R11E, UM At total depth 1574' FSL, 1781'FEL, Sec. 6, T11N, R11E,UM 12. Distance to nearest 13. Distance to nearest well property line 1 C-03 1920' @ TO feet 25.6' @ 501' 16. To be completed for deviated wells Kickoff depth 300' feet Maximum hole angle 55.9° 18. Casing program size Hole 24" 12.5" Casing 16" 9.625" Specifications Grade Coupling Length H-40 Weld 80' L-80 BTC ERV\i 7222' Weight 62.5# 40.0# 8.5" 7" L-80 BTC MOC 10557' 26# 6.125" 4.5" L-80 NSCT 12.6# 526' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured true vertical Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical $200,000 15. Proposed depth (MD and TVD) 10924' MD 2560 6715' TVD 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Maximum surface 3815 psig At total depth Setting Depth Bottom MD TVD 121' 121' 7263' 4528' \) Kuparuk River Unit 8. Well number 1 C-14 9. Approximate spud date 2/9/98 14. Number of acres in property feet Top MD 41' 41' TVD 41' 41' 41' 41' 10598' 6466' 10398' 6313' 10924' 6715' Plugs (measured) feet feet Junk (measured) Cemented Statewide Number #U-630610 Amount feet 4526 psig Quantity of cement (include stage data) ±200 CF 975 Sx Arcticset III & 640 Sx Class G & 60 sx AS I 80 sx Class G Top @ 500' above shoe 60 sx Class G Measured depth True Vertical depth RECEIVED JAN 2ß 1998 Alaska Oil & Gas Cons. Commission Anchorage Diverter Sketch X Drilling program X Seabed report 0 20 AAC 25.050 requirements X by order of the commission Date 1/;;' 7/98 20. Attachments Filing fee X Property plat 0 BOP Sketch 0 Drilling fluid program X Time vs depth plot 0 Refraction analysis 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signer{ j {. j ¡J ~ ~.I( Æ ;:! ~r;H / Title Drilling Superintendent ~ Commission Use Only Perm~Number I API number () l \ I Approval date.- 9 0 q ö - DOL '7 50- 0 ^ q - ^;l 0 \Q d- - - ~ - D Conditions of approval Samples required C Yes ex No Mud log required Hydrogen sulfide measures ~Yes ONO Directional survey required ~Yes D No Required working pressure for BOPE D2M D 3M ~ 5M 0 10M 0 15M Other: /t?'9T ~pe 5ctU' - ~~·I':¡,vr~f2.-,.41eP S-~ I""'; Approved by \ ;-r~J~ Signed By Commissioner ¡ h3Vld W. Johnsto!1 I See cover letter for other requirements [J Yes W No Date a --;.~-- ffJ ) ) GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 1C-14 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (+/7263') according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (+/- 10598') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. NU and test BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6.125" hole to well total depth (10,924') according to directional plan, running LWD logging equipment as needed. 12. Run and cement 4-1/2" NSCT liner with Baker liner-top packer and hanger. Hydraulically set packer ±200' inside intermediate casing shoe to provide appropriate liner lap. 13. Pressure test liner to 3500 psi. 14. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 15. ND BOPE and install production tree. 16. Shut in and secure well. 17. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SL T -J or CST) will be run to establish isolation after the cleanout is completed, but prior to perforating. 1 C-14 T AB,01 127/98, v.1 ) " DRilliNG FLUID PROGRAM, PRESSURE CALCULATIONS, & DRilLING AREA RISKS Well KRU 1c-14 Drilling Fluid Properties: Density PV yp Viscosity Initial Gel 10 Minute Gel API Filtrate pH % Solids Spud to 9-5/8" surface casing 9.5-10.2 15-35 25-50 130-150* 1 0-25 15-40 5-7 9.5-10 ±10% Drill out to 7" interm. casing 8.8-9.0 4-8 5-8 35-40 2-4 4-8 8-15 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 130-150 sec/qt to drill gravel beds Notes: Drill out toTD 11.5-12.0 15-25 5-8 50-65 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Maximum Anticipated Surface Pressure: 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 (O.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressu re of 2,672 psi. MASP = (4528 ft)(0.70 - 0.11) = 2672 psi Maximum anticipated surface pressure is calculated using a intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 3,815 psi. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. MASP = (6466 ft)(0.70 - 0.11) = 3815 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1 C pad are expected to be 3900 psi (0.60 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6502'. ) ') Well Proximity Risks: The nearest existing well to 1C-14 is 1C-03. As designed, the minimum distance between the two wells would be 26' at 501' MD. Drilling Area Risks: Risks in the 1c-14 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular PumpinQ Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of we1l1c-12 or another permitted existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1c-14 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1c-14 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Su rface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set ±200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4325 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt conx Collapse 850/0 of Burst 850/0 of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Bu rst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). 1 C-1 4 TAB, 1/27/1998, v.1 ~-... ~". ) ) Ince ARC a Alaska, Crccted by finch For: T BROCKWAY Dote plotted: 23-Jon-98 structure : Pad 1 C Well : 14 Field: Kuparuk River Unit Location: North Slope. Alaska Tru. Vortical Dopths oro r.l.ronco RKB (Porkor #H~). Plot RaforcncQ iu 1 + Version #3. Coordinates ore in feet reference: slot *14. 550 - o - 550 - 1100 - r-.. +- Q.) Q.) - '-"" 1650 - 2200 - ....c +- 0... Q.) 2750 - o o u 3300 - +- I- Q.) > 3850 - Q.) ::J l- I-- I V 4400 - 4950 - 5500 - 6050 - 6600 - 7150 550 C40 DLS: 2.00 deg per 100 ft BEGIN ANGLE DROP TVD=6006 TMD=9897 DEP=7522 C35 B/ HRZ TVD=6308 TMD= 10378 DEP=7896 5400 K-l MARKER TVD=6397 TMD= 1 0504 DEP=7985 50.00C30 7" CSG PT TVD=6466 TMD= 1 0598 DEP=8049 4600C20 T/ 0 TVD=6502 TMD= 10646 DEP=8081 ~. TARGET(EOD) TVD=6536 TMD= 1 0691 DEP=811 0 ~2.00 TI Ç3 TVD=6572 TMD=10738 DEP=8140 '\."'" TI.:. C2 TVD=6594 TMD=1 0766 DEP=8158 l> 14 T 1 C1 TVD=6639 TMO= 1 0825 OEP=8196 T/ B SHALE TVD=6659 TMO=10851 DEP=8213 Tn -; csp PT TVp=67 t 5 I™Il= t ~9241 nF.~=8~60 I 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 Vertical Section (feet) -> Azimuth 67.66 with reference 0.00 N, 0.00 E from slot #14 ~ INTEQ 600 East (feet) -> 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 o 600 TO - Casing pt TARGET (EOO) - T/ C4 . 7 Casing Begin Angle Dra C40 C50 C9mpanian SS h 9 5;8 Casing ___ WS10 ~ Top West Sak Sands SURFACE LOCATION: 1566' FNL, 1139' FWL SEC. 12, T11N, R10E TO LOCATION: 1574' FSL, 1781' FEL SEC. 6, T11N, R11E RKB ELEVATION: 102' TARGET LOCATION: 1517' FSL, 1920' FEL SEC. 6, T11N, R11E TARGET TVD=6536 TMO= 1 0691 DEP=8110 NORTH 3083 EAST 7501 KOP TVD=300 TMD=300 DEP=O 5.00 15.00 25.00 DLS: 5.00 deg per 100 ft 35.00 45.00 55.00 EOC TVO= 1249 TMD= 1417 DEP=503 B/ PERMAFROST TVD= 1802 TMO=2404 DEP= 1320 67.66 AZIMUTH 8110' (TO TARGET) MAXIMUM ANGLE 55.87 DEG T / W SAK SNDS TVD=3905 TMD=6152 DEP=4422 WS10 TVD=4328 TMD=6906 DEP=5047 9 5/8" CSG PT TVD=4528 TMD=7263 DEP=5342 ~ C1 00 CAMP SS TVD=4692 TMD=7555 DEP=5584 C80 - TARGET ANGLE 40 DEG o 1 1 00 1 650 550 3600 - 3000 - 2400 ^ I - 1800 Z 0 ï -+ ::r- - 1200 ,,--.... -+, CD CD - 600 -+ '--'" - 0 - 600 80 480 ARca Alaska, Date platted: 2J-Jan-g8 For: T BROCKWAY Structure: Pad 1 C Well: 14 Field : Kuporuk River Unit Locotion: North Slope. Alaska Cre(]ted by finch Plot Reference is 14 Version HJ. Coordinotes ore in feet reference sial #14. True Vert;cal Depths are reference RKB (Parker 8245). ,=] 1NJ'l3Q 40 o 40 Inc. 480 560 680 ~.... ~,.. 800 480 440 - - 440 .- 400 - 400 -360 280 - ^ I 240 - ,.--., -+- Q) Q) 200 - - ""--/ ...c -+- L 160 - 0 Z 120 - 80 40 0 - 40 - 80 80 80 120 160 240 East (feet) -> 280 320 360 400 440 200 ~ Ø) ~ ÇI) g t,¡c; :Þ0 ::1~ CO) en ::To ~o ~~ ~{:-~ ~(.-;, o :3 3. (ii- rft %~ 700 ,./",-- 600 ..../-" 500 ...,/ e-' 40 o 40 c- ¡o rn ~ rn ..-. J> Z rv C:J ~ W <.0 00 < rn o 800 1200.r-//'/' 1100 ///"'/'// /-//-/'//.... 1 0~9///' ----- 900/.,//// ---.............- _...JI"...... 80 120 160 200 360 400 240 280 320 East (feet) -> 600 640 720 760 520 /,/,,/,//í§1- 320 1400,_r/'/ - 280 /////'/ -~-~~~///'/'/ 23_~g/--/ 2400 440 520 760 560 600 640 680 720 480 -240 ^ I z o -. -+ ::r - 200 - 160 ,.--., --+. () () -+ ""--/ "-/ - 120 - 80 - 40 - 0 - 40 80 800 1000 - 900 - 800 700 - 600 ^ I ,-.... 500 - -+- (l) Q) - -....- 400 - ...r:: -+- ~ 0 300 Z 200 - 100 0 ARca Alaska, Il~Ca Created by finch For: T BROCKWAY Dote plaited, 2J-Jan-gB Structure: Pod 1 C Well 14 Field: Kuparuk River Unit Location: North Slope, Alaska Plot Reference is 14 Version HJ. Coordinotes are in feet reference slot H 14 True Vertical Depths ore reference RK8 (Porker 1245). ~ ,NTSQ. East (feet) -> 300 400 500 600 800 1000 1300 2100 2300 1400 1500 1600 1700 1800 1900 2000 2200 1100 1200 700 900 1100 /@- 1000 2 6_~9--/-/ 2500.-///- --,.. /~;?-º~//// 23qQ....-// 2200 _r-//-/// --.......--.... 21°9/.// 2000 -/-// --....--.........- 1 900 ;-// 1 800 //--//-/- --..---.......... /~~9-9/.//- 1 ~~?._~--/ 1 5~.9/-//- 1 4_~-~-//-// 200 - 300 400 500 600 700 900 1000 1600 2300 1700 1800 1900 2000 2100 2200 1100 1200 1300 1400 1500 800 East (feet) -> ~~ ~~ 2400 2400 1100 - - 900 800 - 700 600 - 500 ^ I z o ï -+- :::r 400 300 ,-.... -+. CD CD -+- -....- - 200 - 100 o - 100 - 200 J ARCO Alaska, Inc. Pad lC 14 slot #14 Kuparuk River Unit North Slope, Alaska ) 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License 14 Version #3 prop2723 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Date printed Date created Last revised 23-Jan-98 8-Jan-98 22-Jan-98 Slot location is n70 19 29.771,w149 29 45.878 Slot Grid coordinates are N 5968671.588, E 562145.222 Slot local coordinates are 1566.00 S 1139.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Object wellpath DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* MSS <0-7000'>,,9GI,Pad 1C PMSS <0-11300'>,,11,Pad 1C GMS <0-9600'>,,8,Pad 1C GMS <0-7780'>,,1,Pad 1C GMS <0-7615'>,,2,Pad 1C PGMS <0-9002'>,,10GI,Pad 1C GMS <0-9700'>,,3,Pad 1C GMS <0-7575'>,,4,Pad 1C GMS <0-7753'>,,5,Pad 1C PMSS <0-17089'>,,12,Pad 1C MMS <6948-7570'>"WS#24,Pad 1C GMS <0-10243'>,,6,Pad 1C GMS <0-9784'>,,7,Pad lC 13 Version #5,,13,Pad 1C Closest approach with 3-D Last revised Distance 2-Jan-98 625.0 19-Mar-97 605.7 5-Aug-92 569.4 5-Aug-92 226.1 5-Aug-92 125.3 5-Aug-92 474.6 5-Aug-92 25.6 5-Aug-92 88.6 5-Aug-92 208.3 7-Jan-98 590.6 17-Dec-97 1624.9 5-Aug-92 329.0 5-Aug-92 448.5 20-Jan-98 306.8 M.D. 300.0 300.0 20.0 900.0 750.0 20.0 501. 0 300.0 325.0 350.0 10924.3 300.0 300.0 300.0 Minimum Distance method Diverging from M.D. 300.0 300.0 300.0 900.0 750.0 300.0 501. 0 300.0 325.0 350.0 10924.3 10690.7 300.0 300.0 ---.J ) "1- 7 2 < r ~ < 6 ~ 5 r c( 4 L, 3 \ 2 \ 1 ) B1 1. 16- - 2000 PSI STARTING HEAD 2. 11- - 3000 PSI CASING HEAD 3. 11- - 3000 PSI X 13-518" - 5000 PSI SPACER SPOOL 4. 13-518- - 5000 PSI VARIABLE PIPE RAMS 5. 13-518" - 5000 PSI DRLG SPOOL WI CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM WI PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-518" - 5000 PSI ANNULAR > > > , . 13 5/8" 500J PSI BOP STACK ACCUMULATOR CAPACITY TE$T 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS . ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL,AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES. LINES, AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERA TE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH ) KUPARUK RIVE~ )UNIT' 20" DIVERTER SCHEMA'TIC ...-J L--. 6 DO NOT SHUT IN DIVERTER ~ ~ ,:AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 5 4 ¡-l MAINTFNANCF & nPFRATION .. 1. UPON INITIAL INSTALLATION: · CLOSE VALVE AND ALL PREVENTER WITH WATER TO ENSURE NO LEAKS. 3 · CLOSE PREVENTER TO VERIFY OPERATION AND 11-IA T 11-IE VALVE OPENS IMMEOIA TEL Y. I ) 2. CLOSE ANNUU\R PREVENTER IN 11-IE EVENTlHAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. I J,.,......J OPEN VALVE TO ACHIEVE DIVERSION. ~ 2 ) b-J 1 ARCO AU\SKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.03S(b) , , 1. 16" CONDUCTOR. 2. SLlP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DlVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTEA. DKP 11/9/34 WELL PERMIT CHECKLIST COMPANY )i V~ L~ WELL NAME \\ ~Q (c.. -) L{ PROG,RAM: exp 0 dev 0 redrll 0 serv P( wellbore seg C ann. disposal para req¿ç FIELD & POOL L1. q n [ l~ (') INIT CLASS S E V\. I - \N f N ,) GEOL AREA C/JfO UNIT# 1/1 " Ù ON/OFF SHORE {Î V\. ADMINISTRATION ·..__."'·..._,..--;RJ~,""·_..,_,_..,.~~·__"'I:~ \\: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. D~T\E r1 \l 12. ~~ dlN'\.~ 13. Permit fee attached. . . Lease number appropriate. . Unique well name and number. Well located in a defined pool. . Well located proper distance from drilling unit boundary. Well located proper distance from other wells. Sufficient acreage available in drilling unit. If deviated. is well bore plat included. Operator only affected party. . Operator has appropriate bond in force. Permit can be issued without conservation order. Permit can be issued without administrative approval. . Can permit be approved before 15-day wait. . ENGINEERING _~?".. .....".......":-r.-,_~.,.""..,,~......,,.~-rtII:"'."""'::~~.....,___'''''>.:___~_-.......,_...-.::I:.,.. _ -~ ......-..~~.__~~ APPR ~~ TE Æ- '!),t> 14. Conductor string provided 15. Surface casing protects all known USDWs. 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg. . 18. CMT will cover all known productive horizons. . . . . . 19. Casing designs adequate for C, T, B & permafrost. 20. Adequate tankage or reserve pit.. . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed.. . 23. If diverter required, does it meet regulations 24. Drilling fluid program schematic & equip list adequate, 25. BOPEs, do they meet regulation . . . . :3. '~' L"::" . .. 26. BOPE press rating appropriate; test to oc:::e. ?oeJC:>psig. 27. Choke manifold complies w/API RP-53 (May 8 ). , . . . . . . 28. Work will occur without operation shutdown. . . . 29. Is presence of H2S gas probable.. . . GEOLOGY ...,"_I"_I.."......'(_':I.,.I:...'..,___'.,.c'__..._.II......-','..~t.I....-·~...--· ._......._.......___..-.ø. A::)PR ~ DA1E ¡? ?JJ~,A~ HOWlln - A \FO'~MS\rll(>I.II';1 I"v (I"'' .-."_"""",_~-=__,,,,-,---~,,_. ~_..._~.,..-"".~~~~.,_.-..._~..._....,..........-..''''"" REMARKS ~~ &~ ØN ~N CY>N ~~ .ð2...N ~~ i -----.- - - -. ....., 2. -. -- -3 ~ :::0 - -3 H :z -3 - ..... - \J'; \J'; I ~ >- l) H æN æ>N C?@ GN ð?N ð>N Y N tJ'A- $~pÞv ~~ ~NP:¡;¡,/ ~~ ______.._ø...___. -.,.,-.--.- ,-,,_.~--_...._~ -.-.------ ----- -_.._---_.__..,~._._.~~- -- )lJ / f:- 30. 31. 32. 33. 34. Permit can be issued wlo hydrogen sulfide measu~.".~-Y--N-- -----..., Data presented on potential overpressure z.or:¡.e.s-:-, . . . Y N SeismIc analysis of shall~~.. . ., Y N Seabed conditin~ (if off-shore). . . . . . . Y N Con~ame/phone for weekly progress reports . Y N [exploratory only] Qf~~: RPC_~_ ENGINEERING: COMMISSION: BEW~ '2/?L DWJ æ: JDH ~ fiB RNC' f? co ít- 'lIt¡ rCù ------.------.---...-------.,---------.-----.---.- ___.__.,.. _,_u .. Comments/Instructions: ) ') 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. MICROFIL^fE[ Date ì !30j{)d, I I I I I I I I I I I I I I I I I I I Jds Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Inspection Type: COMMENTS: e e Memory Multi-Finger Caliper Log Results Summary jqB-- 0/7 ConocoPhillips Alaska, Inc. January 25, 2006 6554 1 3.5" 9.3 lb. L-80 Tubing 4.5" 12.6 lb. L-80 Liner Well: 1C-14 Field: Kuparuk State: Alaska API No.: 50-029-22861-00 Top Log IntvI1.: Surface Bot. Log Intvl1.: 10,336 Ft. (MD) Top Log Intvl1.: 10,336 Ft. (MD) Bot. Log IntvI1.: 10,870 Ft. (MD) COffosive & Mechanical Damage Inspection This caliper data is tied into bottom of the 3.5" Tubing @ 10,336' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and 4.5" liner with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing is in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 72% in joint 237 (7,582'). The damage appears in the forms of lines of corrosion, general corrosion, and isolated pitting. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the 3.5" tubing logged. The caliper recordings indicate the 4.5" liner is in good to poor condition with respect to corrosive damage, with a recorded maximum wall penetration of 47% in joint 15 (10,739'). The damage appears mainly in the form of a line of corrosion. Perforations are recorded in the interval between (10,674' - 10,716'). No significant areas of cross-sectional wall loss are recorded throughout the 4.5" liner interval logged. Heavy buildup is recorded in joint 14 (10,716' -10,740') below the perforation interval, with a recorded minimum I.D. of 3.03" (10,717'). Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Corrosion Corrosion Line Corrosion Line Corrosion Corrosion ( 72%) ( 70%) ( 61 %) ( 56%) ( 56%) Jt. Jt. Jt. Jt. Jt. 237 @ 268 @ 254 @ 230 @ 271 @ 7,582 Ft. (MD) 8,557 Ft. (MD) 8,099 Ft. (MD) 7,348 Ft. (MD) 8,675 Ft. (MD) 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the 3.5" tubing logged. 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the 3.5" tubing logged. FE;) FJ ,3 Prot~ct¡ve PI,one: OJ' Prudíloe RECEIVED P,{J, 565-1.369 E-mail: 659-2307 Fax: Inc. 56.5--9085 [=a\: Field Office Pl10ne: 'b 'VD~ d F E B 0 2 2006 '"iaska Oil & Gas Cons. CommIeIakIn Anchorage I I I I I I I I I I I I I I I I I I I e e 4.5" LINER - MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion ( 47%) Jt. 15 @ 10,739 Ft. (MD) Line Corrosion ( 46%) Jt. 5 @ 10,463 Ft. (MD) Line Corrosion ( 41%) Jt. 6 @ 10,505 Ft. (MD) Line Corrosion ( 41%) Jt. 4 @ 10,452 Ft. (MD) Line Corrosion ( 40%) Jt. 3 @ 10,402 Ft. (MD) 4.5" LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the 4.5" liner interval logged. 4.5" LINER - MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 3.03" Jt. 14 @ 10,717 Ft. (MD) No other significant I.D. restrictions are recorded throughout the 4.5" liner interval logged. I Field Engineer: N. Kesseru Analyst: M T ahtouh Witness: T. Senden I PmAdive Phone: or Prudhoe ! P.O. Box 565-1369 659-2307 659-2314 I I I Well: Field: Company: Country: IC-14 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 9.3 ppf Grade & Thread l-30 Norn.OD 3.5 ins I Penetration ami Metal loss (',/" wiln) I penetration body metal loss body 400 I I 300 200 I 100 o I to 10% o to 1% 10 to 20% 20 to 40% 40 to 85% over 85% I Number of joints analysed (total = 337) pene. 0 10 63 135 79 loss I 3 324 0 0 0 o o I I DiUnage (body) 150 I I 50 o I Isolated pitting gPller;.1] ¡me ring hole / po",> corrosion corros.\On corroSion ¡ble- hole I Number of joints 90 74 147 = 312) o 0 I I P S Repo Overview Body Region nalysis Survey Date: 1001 Iype: 1001 Size: No. of Fingers: Nom.ID 2.992 ins hnuary 25. 2006 Iv\FC 24 No, 40665 169 24 M, rahtouh Nom, Upset 3.5 ins Dam,lge Profile (% wan) penetration body o o GlMI GlM 2 ClM 3 G l:'v\ 4 GlM 5 metal loss body 50 100 Bottom of Survey = 321.4 Analysis Overview page 2 I· I I S EET Alaska, Inc. USA January 25, 2006 4 o C-1 Well: Field: Company: Country: Survey Date: OINT TAB j PDS REPO L-80 3.5 in 9.3 0.254 in 0.254 in 2.992 in Wall: Upset Wall: Nominal I.D I I ( ments D~Q.osits C Shallow pitting. Shallow pitting. Lt Isobtesipitting, Shallow pitting. Isolated pitting. Cj¿ nosio eup ~h,!I!()\'y_pi tti I'g. pitting. SI", IIQ~Y..l2itti I ,g. . Slh,IIow pitting. Shallmv pitting'--.___ ~hallow corrosiol .~hallow corrosiol pitting.__. pitting. pitting. COrl:~t5.IOI1. corrQ.siol.L corIQ5.1911. corrosion corrosion pitting. pitting. Shallow Shallmv Shallow Shallow Shallow Shallow Mi D. IS. 2,91 2.94 2 .9Q__ 2.93 2.95 2.94 2.95 2.94 2.93 2.94 2.95 2.94 2.93 2,93 2.92 2.93 2.93 2.95 2.94 2.95 2.93 2.94 2.9.4 2.96 2.94 2.94 2.93 2.93 2.93 2.92 2.94 2.94 2.94_ 2.94 2.94 2.94 2.93 2.92 2.94 L2.4 ~-,CJ.4 ':L24 2.93 2.93 2.92 2.94 2.93 2.92 2.93 2,94 ft 64 95 128 159 191 224 2.57 289 320 352 384 416 448 480 51 671 702 734 765 797 1?£9 861 893 925 957 989 021 053 108:; 111Z L149 1 H31 1212 1244 1276 1307 1339 1370 1402 1433 1465 1497 1529 5]5 607 It Joint No. 1 I 1.1 ") ., .J 4 5 8 24 25 26 27 28 30 31 y'} )~ ') <J -,--} 34 35 36 37 38 39 40 41 ----±2~ ____4:1:___ 45 46 4~ I 48 6 7 8 20 21 22 I I I I I I I I I I I I I I I I I I Pipe: Body Wall: Upset Wall: NominaIID.: I I Joint No. I I I _~QJ 5(,,2 .56.3 .57 58 59 60 61 62 63 --..i>L! 65 66 67 68 69 ~_. __21___ ----.1.2 _..lL 74 7.5 ~_.,~ I I I I I 76 ----.11... ---2.8.. I I 84 _1l5 _.lliL _.IlZ__ 'H88 89 90 91 92 93 94 95 I I I I I PDS EPORT JOINT TABULATION SH 3.5 in 9.3 ppf L-8D D.254 in D.254 in 2.992 in Je DC'pth (Ft.) 42 50 51 ~') )~ 5'Y . --) 54 1561 1593 1625 1657 168') 1720 1752 1783 1815 1821 1828 1834 1866 lB98 1930 1961 1993 2025 2057 20BB 2120 2151 21B4 2216 224B 2279 2311 2343 2375 55 2406 243B 2470 2502 2533 2565 2596 262B 2659 2691 2722 2754 27B5 21?J7 284ß 2ß79 2911 2942 2974 3005 3037 d (Ins,) 0.07 0.05 0.05 OJ)6 0.04 0.03 0.09 0.07 0,03 ° 0.04 Cl04 (UB 0.04 0.05 (L05 0,05 0,07 0,06 0.05 (J.() 6 0,06 0.07 , _.JlJlZ........ OJ)7 0.07 0.01l 0.05 0.09 0.07 0.06 0,07 0,08 0.05 0.06 0.05 OQ9 0.04 0.07 ÇJ.06 0,07 0.07 0.08 0.07 0.07 0.06 0.08 0.08 0.05 0.03 {j II ¡j Pen. ¡vlin. I.D. (Ins,) 2.92 2.92 2.93 2.94 2.94m 2.93 2.94 2.93 2.89 281 2.90 2.93 2.93 2.92 2.93 2.93 2.92 2.93 2.92 2,93 2,92 2.94 2.93 291 2.94 2.92 2,92 2.91 2.92 293 2,93 2.93 2.93 2.92 2.94 2.94 2.91 2.91 2.90 2.9L 2.91 2.92 2,91 2.91 2.90 2.9] 2.92 2.91 2.92 2.92 Well: Field: Company: Country: Survey Date: 1 C-14 Kuparuk ConocoPhillips Alaska, Ine. USA January 25,2006 Comments pitting. Shallow pitting. Isolated pitting. Shallow pitting. Shallow corrosion. Line corrosion. Line corrosion. PUP Shallow corrosion. SSSV PUP Shallow pitting.Lt Deposits. Shallow pitting. Shallow pitting, Shallow pitting. Isolated pitting. Shallow corrosion. Corrosion. Isolated pitting. Co rrosi(jn, Shallow pitting. Lt. Deposits. Line corrosion. Lint' corrosion. Lt. Deposits, Line corrosion, Line çorrosion. Line corrosion. Line corrosion, Line corrosion. Line corrosion, Line corrosion, Line corrosion, ~ine corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Isolated pitting. Shallow pitting. Isolated pitting. Isolated pitting. Lt. Dep()sjts. Line corrosion. Line corrosion. Line cQJrosion, Line corrosion. Lt. Deposits. Lil)e corrosion. Lt. Deposits. Line corrosion, LJ. Deposits. Line_ corrosion. Line corrosion. Lt. Deposits. Line corrosion, Shallow pitting"'mH Page 2 Damage ('10 wall) o 50 100 I Body Metal Loss Body I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: I I ~--~"- Joint It Depth No. (Ft.) I 96 3068 97 3100 98 3131 99 3163 100 31 91 101 3226 102 3257 103 3289 104 3320 105 3352 106 3383 107 3415 108 3446 109 3478 110 35J)8 ----11l~~ 3540 112 3571 11 3 3602 114 3634 115 3665 .-----1lfL 3696 ..1~---Îl.2g 118 3759 119 3791 119.1 3822 119.2 3821,) 119.3 3835 120 3841 121 3871 P) 3903 123 3934 124":91',5 125 3996 126 4028 12ì 4060 128 4091 129 4122 4154 4186 4217 4248 4279 4310 4342 43ì2 4404 I 4435 4467 4498 4530 I I I I I I I I I 31 I l"'C¡ ,_I..... 133 134 135 136 137 138 139 I 140 141 ~- 142 I I I PDS EPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in IJ Pen, Body (Ins,) 0.()6 0.07 0.07 0.07 0,10 0,06 0.08 0.06 0.08 0.08 0.09 0.06 ~Q,QZ- 0,08 0,07 0.()6 0.08 0.03 010 CL08 0.07 0))9 O.H) 011 0.03 ..0 0.05 0.08 CU)7 0.()9 0.08 0.07 0.09 0.()7 0.07 0.06 0.07 () () 0,10 0,09 0.08 0.09 0.09 0,08 0.09 0.02 0.10 0.11 0.11 0.07 2.91 2.91 2.92 2,93 2.91 2.93 2.92 N/A 2.81 2.91 2.91 2.90 2.92 2.92 2.94 2.94 2.94 2.93 2.94 2.93 2.90 2.92 2,94 2.93 2.92 2.92 2,93 2.92 292 2.93 2,91 2.92 Well: Field: Company: Country: Survey Date: lC14 Kuparu k ConocoPhillips Alaska, Ine. USA January 25, 2006 Min. ID (Ins.) Comments Damage Profile (%wall) o 50 100 2.93 2.93 2.90 2.93 2.89 2.89 2,91 2.89 2.90 2.89 2.91 2.91 2,92 2.92 2.92 2.91 2.92 Isç¡Jated pitting. Lt Dep(Jsits. .Corrosion. Lt Deposits, Corrosion, Isoh ted pitting, . Line corrosion. Un.S' corrosion. Line corrosion, Line corrosion, Lt Deposits. Line corrosion. Lt Deposits, Line corrosion. Lil1e corrosion. Line corrosion. Line çorrosion. Line corrosion. Lil(~ corrosion. Line corrosion. Lir¡e corrosion, Lt [Jeposits. Lim' CQHosion, Line corrosion, Line corrosion. LLDeposits. Line corrosion, LLDeposits. Litle corrosion, LtDeposits. Line corrosiQIL Lt. Deposits. Corrosion. Lt Del29sits. PUP ÇLMI (Latch.(Í1)3:30) PUP SI1allowpitting. Lt. Depç¡:;it;s. Corrosion. Lt Deposits. Line corrosiOlL Lt Deposits, Line corrosion. Lt. Deposits, Line corrosion. Lt. Deposits. Line corrosion, Line corrosion. Lt. Deposits. Line corrosion, Line corrosion. Line corrosion, Line corrosion. Line corrosion. Corrosion, Lt. Deposits. Line corrosion. Line corrosion, Line corrosion, Line corrosion. Line corrosion. Line corrosion, LiIj£corrosi0l1, Line CQHosion, Lt Deposits. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Body Metal Loss Body Page 3 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I I I 146 ._14L 148 ....J.42... 150 151 152 153 154 155 156 I I 158 159 160 .......l2L. ~_. I I I I 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 ......1/lEL 189 190 191 192 I I I I I I I PDS REPO 3.5 in 9.3 ppf 1.-80 0.2 54 in 0.254 in 2.992 in loint Jt. Depth No, (Ft.) 143 144 4561 4593 4624 4656 4688 47W _~4749 4780 4812 4844 4876 4906 4938 4969 5(H)! 5032 5062 5094 5124 5156 5187 521 5250 5281 5312 5344 53Z6 :]408 5439 5471 5502 5534 5566 5594 562(, 5658.,.. 56139 57~1 57.53 57/l4 5816 5847 51379 5911 5943 5974 6006 60313 6070 6101 164 1 167 168 169 170 II Pen. Body (Ins.) 0.09 0.09 0.06 0.08 0.07 0.07 0.07 0.07 0.09 0.10 0.10 0.07 0.08 0.09 0.08 (J.I 0 0.07 0.09 0.10 (J06 0.07 0.09 0.07 0.07 0,09 0.08 0.07 0.013 0.09 0.12 0.12 (l08 0,10 0.11 0.05 0.13 0.10 0,09 0.10 0.09 0.12 0.07 0.11 0.09 JOINT TABULATION SHEET Min, LD (Ins.) 2.94 __~..94 .294 2.94 2.9) 2.94 2.94 2.93 2.92 2.92 2.91 2.91 2.92 2.93 2.93 2.93 2.91 2.91 2.91 2.93 2.91 2.90 2.92 2.92 2.92 2.93 2.92 2.91 2.91 2.91 2.93 2.91 2.92 2.92 2.91 2.92 2.94 2.94 2.94 293 2.92 2.93 2.94 2.94 2.92 2.94 2.93 2.94 2.92 2.92 Well: Field: Company: Country: Survey Date: 1 C-14 Kuparuk ConocoPhillips Alaska, Inc. USA January 25,2006 Comments Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. l,ine corrosion, Line cor[Q2ion. LinS' corrosion. Line corrosion. Line corrosion. Line corrosion. Lt, Deposits. Line corrosion. Line corrosion. U,-.Deposits, Line corrosion. Line CorroSil}i1._Lt. Deposits, Corrosion. Corro?ig!ì. CornJ?igll. Lt. Deposits. Corrosion. Lt.J2s:posits. Corros,Î()n. Lt. Deposits, Corrosl~!D, CqJJosiol1. Line C{H[osion. Lt. Deposits, Corn2sion. Lt. Deposits, Corrosjg!l. CorrosigD. Lt. Deposits, Isol.1IecLpitting. Lt. Deposi.t?,-., I?olated pitting, Isolated pitting. Corrosion. Isolated pitting, Cgrrosion. ._.Corrosion. bolated pitting, Lt DelJgsits. Isolated pitting. Corrosion. Cqrrosion, Lt. Deposits. Corrosion, bglated pitting. Corrosion. (orrosion. (orrosiolì. Corrosion. Isolated pitting. Isolated pitting. Corro?ÌS)l1. IsolatE'(1 pitting, Isolated pitting. Isolated pitting. Isolated pitting, Corrosion. Page 4 Damage Profile (%wall) o 50 100 I, I I Body Metal Loss Body I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in I I loint Jt Depth Pen, No, (Ft.) (Ins,) 6133 0.08 194 6165 0.10 195 6197 II 0.09 6228 II 0,11 197 6260 0.10 198 6292 0.09 6324 0.12 200 6356 201 202 __1>419 203 6451 204 6483 0,10 _2Q:!J 6515 0.04 204.2 6520 0 204.3 6527 0.01 205 6533 _.º,-1 0 206 6565 0,14 0.10 208 6629 0.12 6661 0.0;;'_ 210 6693 Q.lO 211 6724 0.11 212 ..j)756 0.11 213 6788 0.12 214 6820 008 215 6852 0.12 216 6884 0.1)9 217 691 0.09 218 6947 0.14 219 6979 {) 0.07 220 7011 CU3 221 7043 CUI 222 7075 0.1] 7106 0,1 0,13 /0 0,10 226 7202 0.10 227 7234 0.12 228 7265 Q.ll 229 7297 . J),IO 230 7J29 0.14 231 _. 7360 0.11 'ì ,.~ ') 7394 0.10 .<-,),i.,.. .....LD 7425 0.13 234 ì45~,~, II 0.11 ,)r}L' 7489 0.10 .....~) -) 236 7521 0.14 237 7552 0.18 238 7584 0.09 I 239 76H, 0,11 I I I I I I I I I I I I I I I Isolated pitting, Corrosion. pitting. 2.94_ . Is()I,üê"d pitting. 2,93 . _.<;:orrosion. 2.95 IsolateJil2iitÜ¡g I 2.94 15QJi\tê:d!2ittÜ}.ß.__ 2.92 Isolated pittin!L..__ 2.92 Isolated !2ittiu.ß. 2.93 Isolated pitting. 2.94 2.93 2.91 N/A 2.93 2.92 2.94 2.92 2.93 2.93 2.92 2.93 2.94 292 2.92 2.92 2.94 2.94 2.93 2.94 2.93 2.93 2.92 2.93 2,93 2.94 2.92 2.92 2,93 294 2.93 2.93 2,92 2.89 2.91 2.91 2,89 2.89 2.92 2.92 Well: Field: Company: Country: Survey Date: lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA january 25,2006 Min. ID (Ins,) Damage Profile (01<) o 50 100 Comments 2.93 2.93 Corrosion. PUP Shallow pitting. ell',,] 2 (Latch ((I) 2 :30) PUP Isolated !2itting. Isolated pitting. Isolated pitting,. Isolated pitting. Isolated pitting. Isolated pitting, Isolated pitting. Corrosion. Corrosion. CorrosiOlL. Isolated pitting. Isolated pitting. Isolated pitting. Iso1<lted pitting, Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting, Isolated pitting, Isolated pitting. pitting, Corrosion. Isolated pitting. Corrosion. Isolated pitting. Line corrosion. Line corrosion Corrosion. Isola ted pi tting. Line corrosion. Corrosion. Corrosion. Corrosion. Lt. Deposits. Isolated pitting. Isolated pitting. Body Metal Loss Body Page 5 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I I 242 243 244 245 246 24ì ì8ìO 248 ì902 249 ì934 250 ì965 251 ì99ì 252 8029 253 8060 254 8092 _25.5 . _ .. .13123 _1.'2.(1. ._ ..8155 25ì 8!8ì 25 ß __E\~Jª 259 ß249 ß281 8313 ß344 83ì6 ß409 ß440 84ì2 84713 84ß5 8491 852l 85.53 85ß4 8616 I I I I I 261 262 263 264 I 265 265.1 265.2 265.3 266 26ì 268 269 2ìO I I I 87ì6 8ßOì 8839 88ì1 2ì9 8903 ... 280 ß934 2ßl ß966 2ß2 899ì 2ß3 9029 284 9060 285 9092 286 9124 I I I I I PDS REPORT JOINT TABU 3.5 in 9.3 ppf 1.-80 0.254 in 0.254 in 2.992 in 2.91 2')3 2.91 2.91 2.92 2.92 291 2.91 L9! 2.90 N/A 27ì 2.91 2.92 2.91 291 2.90 2.91 2.92 2.90 2.91 2.91 2.92 2.91 2.90 2.90 2.91 2.91 _2·91 2.91 2.91 2.92 2.91 ONSH Well: Field: Company: Country: Survey Date: 1C-14 Kuparuk ConocaPhillips Alaska, Ine. USA January 25, 2006 Min, ID. (Ins.) 2.94 2.92 2.91 2.92 2.91 2.92 2.93 2.94 2.92 2.91 2,93........ 2.93 2.91 2.92 2.91 2.91 Comments Isolated pitting. line corrosion. Line corrosion, line corrosion. line corrosion. Lt. Deposits, line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Line corrosion, line corrosion, line çorrÇJsiol1. Lt. Deposits, Line corrosion. Lim' corrosion. .. .Line corrosion. Line corrosion. Lil1ecgrrosiol1. Line corrosion. Line corrosion, Corrosion. . Corrosion. Isolated pitting. Corrosion, Lt. Deposits, _.Corrosion. Lt. Deposits, Line corrosion, Lt. Deposits. PUP Shallow corrosion.______ CLM 3 (Latch @ 9:QJ)L. PUP Shallow corrosion. Corrosion. Isolated pitting, Corrosion, Line corrosiç¡n. Lt. Deposits, Line corn?sicJI), Corrosioll. Lt,J}~posits, Isolated pitting. Corrosion. Lt. [)J::[Jgsìts. Corrosion. Corrosion, Lt. Deposits, Corrosion. Corrosion. Corrosion. Lt. Deposits. Corrosion. Lt Deposits. Corrosion, Corrosion. Corrosion. Isolated pitting. Line corrosion. Line corrosion. Line corrosion, Page 6 I Damage Profile (o¡;,) o 50 100 Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: BodyWall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA January 25,2006 Well: Field: Company: Country: Survey Date: ^~------ I~ Dam,1ge Profile ('Yo w,¡II) [0 50 100 ¡oint No. It. Depth (Ft.) Comments Min, LD (Ins,) 2.92 2.90 ::1~..2.91. 2.91 ) ..c'.~.__!L_ 2.90 2.92 2.92 2.91 2.92 2.91 2.92 Line COIJ~)síon. .~~_ Line corrosion. . LineLQrrosiol}, Line corrosion, . Line .(:orrosiQ.l1. Line corrosion, LiI1e.<;orrosi(j11. Line corrosion. Li/l", corro?io~. Line corrosion. Line corrosion, ....~ cj 2,90 Line corrosion, let DeDosil?-'----_ 2.90 Line corrosion. Lt. Deposits. ).89 _C(jrrosion, It.~Deposi\?.~~..__ . ..---1)90 ..---Cmrosion, u. Deposits.~_ 2.91 Line corrosion. 2.91 ~. Lineç.cJrr()sion,. . .~__ 2.91 Line' corrosion. 2,90 Line corrosion, 2.90 Line corrosion. 2.90 linE' corrosion, 2.92 Line .corrosion. ...._..~~_ 2.91 Line corrosion. 2,92 Line corrosion. ..._ 2.92 ... Line corrosion, 2.90 Line corrosion, 2.88 PUP Lt. Deposits, N/A eL:\!1 4 (Latch -_...,~ 295 296 _297_ 298 299 300 301 301.1 1 .¡ ------- ..319,. 10189 319.1 10220 319.2 10226 319.3 10234 320 .....JCJ 24<2....... 320.1 10272 321 102~~ 321.1 10305 _2.21.2 ~~J03Il Line corrosio~ Line corrosiolJ.~____ . ._. PUP Shallow pitting. Lt. Deposits, eLM 5 (Latch (iJ! 6:(0) PUP Shallow pitting. Lt. D(:l2osits, .J .~2)C)L___JiDe corrQsioll........... D Nipple. _... Line corr(j?Ì9ll........... PACKER and Seal . PUP Li/l~e corrosi()1l............. PUP Line corrosion, END OE 3.5 LOe __iL.... ...-º--_ 0,04 iI OJ)9 o .I..L.......JJ.09 o 0.08 0.06 o -_._-~ Body Metal Loss Body Page 7 - - - - - - - - Well: Field: Company: Country: Tubing: 1C-14 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 ! Cross for 237 Tool speed 53 NominallD 2.992 Nominal OD = 3.500 Remaining wall area 94 % Tool deviation = 80 0 depth - - - - - - - - s s rt ns Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: January 25, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh 1 6 ft Finger 19 Penetration = 0.183 ins Corrosion 0.18 ins = 72% Wall Penetration HIGH SIDE UP Cross Sections page 1 - - - .. .. .. .. .. .. Well: Field: Company: Coun try: Tubing: .. .. lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9,3 ppf L-80 Cross Section Tool speed = 47 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 95 % Tool deviation = 70 0 268 .. .. .. .. .. .. .. .. s s ns Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: January 25, 2006 MFC 24 No, 40665 1.69 24 M Tahtouh 5 7 Finger 6 Penetration = 0.178 ins Corrosion 0.18 ins = 70% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. .. .. I I I Well: Field: Company: Country: lC-14 Kuparuk ConocoPhi!lìps Alaska, Inc. USA I Ins Weight 12.6 ppf Grade & Thread I Penetration and Metal loss (% wall) I penetration body metal loss 20 I 10 I 0 0 1 10 20 40 to to to to to over to"';) 10% 20%, 40%, 85°í~ 85°/~ analysed (total =19) pene, I 1 10 6 0 I loss 18 0 0 0 0 i I I I Damage 20-- I I 10 ---.- o I Isobted pining genera! Iltk' nng hole / poss corrosIon COITO"'lon COITOSlon ¡hie hole I o of joints damaged 3 13 6) o I I DS Repo Ove ew dy Region Analysis Survey I)ate: 1001 Iype: 1001 Size: No. of Fingers: Nom.lO 3.958 ins january 25, 2006 MFC 24 No, 40665 1.69 24 t\lt lahtouh Nom. Upset Upper Damage Profile (% wall) pen etm tion metal loss body 50 100 o 1 11 Bottom of Survey = 19 Analysis Overview page 2 I I I SH Alaska, Inc. USA January 25, 2006 C-14 Well: Field: Company: Country: Survey Date: OINT J EPORT L-30 PDS 2.6 4.5 in 0.271 in 0.271 in 3.958 in Wall: Upset Wall: Nominall.D I I Damage Profile (%wal 50 ) o ts Line corrosion. Line corrosion. Line corrº~i()I}. Line corr-º~i()I.L Line corro?i()l1., Line corrosion. Line corrosiQll, Line corrosion. Line corrosion. Li ne corfQ~i()!!, Line corrosion. Line corrosion. Short Jt U. Deposits. Perforation Interval. l1. Deposit", Perforation Interval. Heavy Deposits, Line corrosion. Deposits. Isolated pittill~~I;)eposits. Lt Deposits, L1. Deposits. End of Lo~ mer 01 Min .D. ns. 94 97 94 ., " " .) ., .) Pen 0.11 0.10 0.11 0.10 0.10 0.09 0.09 0.13 0.18 0.13 (W9 O.t)) 0.00 0.01 1S. F1. 10340 10370 10400 10430 10460 10491 10522 10553 10584 10614 1 106ì2 10702 10732 1 <W,"L 1 0 L()2_ 10827 1 t. lomt No. '7 / 8 I 2 " :, 4 5 6 7 8 9 4 5 1 2 1 1 1 1 1 I I I I I I I I I I I I I I Page I I .. .. .. .. .. .. Well: Field: Company: Country: Tubing: .. .. .. lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA 4.5 ins 12,6 ppf L-80 Cross Tool speed 48 NominallO 3.958 Nominal 00 = 4.500 Remaining wall area = 94 % Tool deviation = 61 0 15 depth 1073 .. .. .. .. .. .. .. os ross S o ns Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: january 25, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh it Finger 4 Penetration = 0.128 ins Line of Corrosion 0.13 ins = 47% Wall Penetration HIGH SIDE UP Cross Sections page 1 .. .. .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubing: lC-14 Kuparuk ConocoPhillips Alaska, Inc. USA 4,5 ins 12.6 ppf L-80 Section 5 Tool speed = 48 NominallD = 3.958 Nominal OD = 4.500 Remaining wall area = 98 % Tool deviation = 49 0 .. .. .. .. .. .. .. .. s s ep ns Survey Date: Tool Type: Tool Size: No, of Fingers: Analyst January 25, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh 10462.8 ft Finger 5 Penetration = 0.125 ins Line of Corrosion 0,1 3 in s = 46% Wall Pene tration HIGH SIDE = UP Cross Sections page 2 .. .. .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubing: 1C-14 Kuparuk ConocoPhillips Alaska, Inc. USA 4.5 ins 12,6 ppf L-80 Cross Joint 14 Tool speed = 50 Nominal 10 = 3.958 Nominal 00 = 4500 Remaining wall area = 96 % Tool deviation 62 0 .. .. .. .. .. .. .. .. s ross S ns Survey Date: Tool Type: Tool Size: I\JO. of Fingers: Analyst: January 25, 2006 MFC 24 No. 40665 1.69 24 M. Tahtouh 1071 7.1 7 ft Finger 8 Projection -0.994 ins Heavy Buildup Minimum 1.0. = 3.03 ins HIGH SIDE =UP Cross Sections page 3 .. .. .. I I SSSV (1830-1831. OD:3500) TUBING (0·10336, OD:3500, ID:2,992) I I Gas Lift ;HldrellDummy Valve 1 I Gas lift I Valve (6523·6524, OD:5,500) I Gas Lift ~ndre!/Dummy Valve 3 (8478-8479, OD:5,500) I Gas Lift Õlndrel/Dummy Valve 4 I Gas Lìft ô\ndreilDummy Valve 5 :10226-10227, OD:6,0'18) I NIP :10272·10273. OD:3,500) I I PKR :10300-'10301. OD:6,151) LINER : 10300·10980, OD:4500, Wt1260) I SEAL :10311.10312, OD:4,000) I SBE :10321-10322. OD:4,500) I I TTL --" '10337·10338 , OD:3.500) I Perf :10670·10696) Perf :10696-10716) I I KRU 1C-14 API: 500292286100 SSSV Type: TRDP Well Type: INJ Orig 3/4/1998 Completion: LastW/O: Ref Log Date: TO: 10980 ftKB Max Hole 59 7450 Angle @ TS: 40 deg @ 10664 Angle @ TO: 40 deg @ 10980 Size 16,000 9,625 7,000 4,500 L-80 L-80 L-80 SURF, CASING PROD, CASING LINER Thread ABM EUR Bottom 10336 Wt 9,30 Grade L-80 Interval 10670 - 10696 10696 - 10716 Ft SPF Date Type 26 4 11/21/1999 APERF 20 4 3/1m998 IPERF Comment 2,5" HSD, 180 deg ph 2,5" HSD, 180 deg ph; oriented +/- 90 deg from low side 6536 - 6555 6555 - 6571 C-4.C-3 St MD ND Man Type VMfr V Type VOD Latch Port TRO Run Cmnt 2588 DMY 1,0 BK 0,000 0 3/8/1998 4094 DMY 1,0 BK 0,000 0 3/8/1998 5195 DMY 1,0 BK 0,000 0 3/8/1998 5851 DMY 1,0 BK 0,000 0 3/8/1998 1 RK 0,000 0 3/8/1998 Description Camco'TRDP-4E' 2,812 NIP Cameo 'D' Nipple NO GO 2.750 PKR 'ZXP' Pkr 4.438 SEAL Locator SEAL ASSY 3,000 HNGR Hanger 4.438 SBE Baker 4,000 TTL ) ) Thu Apr 02 08:11:08 1998 C¡8· 0', 11:- 8c-( t ( Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name... .... ......LISTPE Date... ...... ...... ......98/04/02 1;~ ~9g Or i gin. . . . . . . . . . . . . . . . . . . S T S II Reel Name..... ...........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments..... ... .... .....STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... ...... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .98/04/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... .............UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments....... ..........STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA lC-14 500292286100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-APR-98 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MM-80128 P. SMITH G. WHITLOCK MWD RUN 6 AK-MM-80128 P. SMITH G. WHITLOCK MWD RUN 7 AK-MM-80128 B. HENNINGSE G. WHITLOCK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MM-80128 B. HENNINGSE G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: 12 11N 10E 1566 ) ) FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1139 .00 101.40 60.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12.250 8.500 6.125 9.625 7.000 7292.0 10503.0 10980.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 5 & 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUN 7 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO- DENSITY (SLD). 5. DATA FROM 10493'MD, 6401'TVD TO 10980'MD, 6771'TVD WAS ACQIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE AFTER MWD RUN 7. THIS DATA IS PRESENTED AS A TAIL ON THIS LOG. 6. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M KREMER OF ARCO ALASKA, INC. AND A TURKER OF SPERRY-SUN DRILLING SERVICES ON 3/23/98. THIS DATA IS CONSIDERED PDC. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10980'MD, 6771'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY-SS MATRIX FIXED HOLE SIZE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE (THERMAL NEUTRON) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE (THERMAL NEUTRON) . SBDC SMOOTHED BULK DENSITY COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ) ) SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. AN "M" SUFFIX DENOTES MAD PASS DATA ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6.125" MUD FILTRATE SALINITY: 400-500 PPM CHLORIDES MUD WEIGHT: 11.9-12.7 PPG FORMATION WATER SALINITY: 9500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .98/04/02 Maximum Physical Record. .65535 File Type. ... ........... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX FCNT NCNT NPHI DRHO RHOB PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7266.5 7307.0 10493.0 10493.0 10493.0 10493.0 10493.0 10498.0 10498.0 10498.5 10505.0 10505.0 10524.5 STOP DEPTH 10899.5 10980.5 10906.5 10906.5 10906.5 10906.5 10906.5 10937.5 10937.5 10937.5 10953.5 10953.5 10954.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 5 6 7 # MERGED MAIN PASS. $ MERGE TOP 7307.0 7822.0 10580.0 MERGE BASE 7822.0 10580.0 10980.0 ) ) Data Format Specification Record Data Record Type.......... ........0 Data Specification Block Type.....O Logging Direction........ ..... ....Down Optical log depth units...... ... ..Feet Data Reference Point......... ... ..Undefined Frame Spacing.. ..... ......... ... ..60 .1IN Max frames per record... ..... .....Undefined Absent value...................... -999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT RO P MWD RP S MWD RPD MWD RPX MWD RPM MWD FET MWD GR MWD TNPS MWD CTNA MWD CTFA MWD RHOB MWD DRHO MWD PEF MWD Units FT FT/H OHMM OHMM OHMM OHMM HOUR API P.U. CNTS CNTS G/CC G/CC BARN Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Nsam Rep 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 First Last Name Min Max Mean Nsam Reading Reading DEPT 7266.5 10980.5 9123.5 7429 7266.5 10980.5 ROP 3.8672 610.547 190.35 7348 7307 10980.5 RPS 0.2823 2000 37.5088 828 10493 10906.5 RPD 0.1593 2000 40.0146 828 10493 10906.5 RPX 0.4904 2000 18.297 828 10493 10906.5 RPM 0.24 2000 51.7246 828 10493 10906.5 FET 1.5263 100.724 22.9188 828 10493 10906.5 GR 15.4655 520.084 138.393 7267 7266.5 10899.5 TNPS 16.97 123.38 42.0879 879 10498.5 10937.5 CTNA 546.556 1607.06 1017.02 880 10498 10937.5 CTFA 1.767 28.876 10.9804 880 10498 10937.5 RHOB 1.874 3.177 2.37797 898 10505 10953.5 DRHO -0.098 0.239 0.025804 898 10505 10953.5 PEF 4.572 16.493 7.56206 860 10524.5 10954 First Reading For Entire File........ ..7266.5 Last Reading For Entire File.. .... ... ..10980.5 File Trailer Service name. ........... .STSLIB.OOl Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..98/04/02 Maximum Physical Record..65535 File Type........... .... .LO Next File Name. ........ ..STSLIB.002 Physical EOF ) File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .98/04/02 Maximum Physical Record..65535 File Type...... ....... ...LO Previous File Name... ....STSLIB.001 Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX GR RAT DRHO RHOB PEF $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: START DEPTH 10498.0 10498.0 10498.0 10500.0 10500.0 10500.0 10500.0 10500.0 10500.0 10500.0 10505.0 10505.0 10525.0 STOP DEPTH 10941.0 10941.0 10941.0 10909.5 10909.5 10909.5 10909.5 10909.5 10902.5 10980.0 10957.5 10957.5 10958.0 MAD RUN NO. MAD PASS NO. MERGE TOP 7 10580.0 MERGED MAD PASS. $ MERGE BASE 10980.0 # Data Format Specification Record Data Record Type......... .... ... ..0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units...... ... ..Feet Data Reference Point............. .Undefined Frame Spacing......... .......... ..60 .1IN Max frames per record..... ...... ..Undefined Absent value...................... -999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 TNPS MAD P.U. 4 1 68 32 9 CTNA MAD CNTS 4 1 68 36 10 CTFA MAD CNTS 4 1 68 40 11 RHOB MAD G/CC 4 1 68 44 12 DRHO MAD G/CC 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 10498 10980 10739 965 10498 10980 RAT 31.105 210.156 80.3179 961 10500 10980 GR 30.395 135.397 82.1117 806 10500 10902.5 RPX 0.097 13.771 3.76831 820 10500 10909.5 RPS 0.086 14.086 3.7159 820 10500 10909.5 RPM 0.091 2000 20.6415 820 10500 10909.5 RPD 0.05 2000 18.3232 820 10500 10909.5 FET 14.622 119.648 39.3662 820 10500 10909.5 TNPS 18.41 136 43.6923 887 10498 10941 CTNA 539.136 1575.61 980.811 887 10498 10941 CTFA 1.707 26.583 10.2647 887 10498 10941 RHOB 1.76 2.962 2.35402 906 10505 10957.5 DRHO -0.118 0.201 0.026266 906 10505 10957.5 PEF -464.306 19.643 8.17238 867 10525 10958 First Reading For Entire File... ..... ..10498 Last Reading For Entire File.. ........ .10980 File Trailer Service name. ... ...... ...STSLIB.002 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation.......98/04/02 Maximum Physical Record. .65535 File Type... .... ....... ..LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name... ..... .....STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .98/04/02 Maximum Physical Record..65535 File Type........ ....... .LO Previous File Name...... .STSLIB.002 ) Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ) header data for each bit run in separate files. 5 .5000 START DEPTH 7266.5 7307.0 STOP DEPTH 7780.0 7822.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 23-FEB-98 Ise 5.06 eIM 5.46,SP4 5.03,SLD 10.53 MEMORY 7822.0 7307.0 7822.0 56.3 58.8 TOOL NUMBER P0954CG6 8.500 8.5 SPUD MUD 8.60 55.0 11.0 500 20.0 .000 .000 .000 .000 30.6 # Data Format Specification Record Data Record Type............. ... ..0 Data Specification Block Type... ..0 Logging Direction........... .... ..Down Optical log depth units...... ... ..Feet Data Reference Point......... ... ..Undefined Frame Spacing......... ...... ..... .60 .1IN Max frames per record........... ..Undefined Absent value...................... -999.25 Depth Units..................... . . Datum Specification Block sub-type. ..0 Name Service Order DEPT GR MWD 5 ROP MWD 5 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 7266.5 7822.5 7544.5 1113 7266.5 7822.5 GR 51.9669 156.743 103.452 1020 7266.5 7780 ROP 11.6695 466.699 183.279 1021 7307 7822.5 First Reading For Entire File..........7266.5 Last Reading For Entire File... ........7822.5 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .98/04/02 Maximum Physical Record. .65535 File Type. ...... ........ .LO Next File Name.. ..... ... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .98/04/02 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 6 .5000 # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 7781.0 7824.0 STOP DEPTH 10537.5 10580.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. ....... ..........0 Data Specification Block Type.....O Logging Direction...... ..... ..... . Down Optical log depth units..... ..... .Feet Data Reference Point......... .... .Undefined ) 24-FEB-98 ISC 5.06 CIM 5.46,SP4 5.03,SLD 10.53 MEMORY 10580.0 7822.0 10580.0 41.0 57.4 TOOL NUMBER P0954CG6 8.500 8.5 LSND 8.90 51.0 8.5 450 5.6 .000 .000 .000 .000 52.1 ) ) Frame Spacing......... ....... ... ..60 .1IN Max frames per record............ .Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT GR MWD 6 ROP MWD 6 Name DEPT GR ROP Min 7781 15.4655 3.8672 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 FT/H 4 1 68 8 3 Max 10580 520.084 610.547 First Reading 7781 7781 7824 Last Reading 10580 10537.5 10580 Mean 9180.5 151.434 212.46 Nsam 5599 5436 5501 First Reading For Entire File... .......7781 Last Reading For Entire File.. ..... ....10580 File Trailer Service name........ .....STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......98/04/02 Maximum Physical Record..65535 File Type............... .LO Next File Name... ........STSLIB.005 Physical EOF File Header Service name.... ........ .STSLIB.005 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation.... ...98/04/02 Maximum Physical Record. .65535 F i 1 e T yp e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS 5 header data for each bit run in separate files. 7 .5000 START DEPTH 10493.0 10493.0 10493.0 10493.0 STOP DEPTH 10906.5 10906.5 10906.5 10906.5 RPX FCNT NCNT NPHI DRHO RHOB PEF GR ROP $ 10493.0 10498.5 10498.5 10498.5 10505.0 10505.0 10524.5 10538.0 10580.5 10906.5 10937.5 10937.5 10937.5 10953.5 10953.5 10954.0 10899.5 10980.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRI LLER' S CAS ING DEPTH ( FT) : # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ ) 01-MAR-98 ISC 5.06 CIM 5.46,SP4 5.03,SLD 10.53 MEMORY 10980.0 10580.0 10980.0 40.3 41.0 TOOL NUMBER P0960SP4 P0960SP4 P0960SP4 P0960SP4 6.130 6.1 LSND 12.70 57.0 9.4 500 4.5 2.000 1.440 2.000 2.100 56.1 . 6 ) # Data Format Specification Record Data Record Type........ .... ... ...0 Data Specification Block Type.....O Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing. ... ....... ...... ....60 .1IN Max frames per record........ .....Undefined Absent value. ....... .......... ....-999.25 Depth Units....................... Datµm Specification Block sub-type. ..0 Name Service Order DEPT GR MWD 7 RPX MWD 7 RPS MWD 7 RPM MWD 7 RPD MWD 7 ROP MWD 7 FET MWD 7 RHOB MWD 7 DRHO MWD 7 PEF MWD 7 TNPS MWD 7 CTNA MWD 7 CTFA MWD 7 Units FT API OHMM OHMM OHMM OHMM FT/H HOUR G/CC G/CC BARN P.U. CNTS CNTS Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam Rep 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 10493 10980.5 10736..8 976 10493 10980.5 GR 32.6044 173.855 91.0184 723 10538 10899.5 RPX 0.4904 2000 18.297 828 10493 10906.5 RPS 0.2823 2000 37.5088 828 10493 10906.5 RPM 0.24 2000 51.7246 828 10493 10906.5 RPD 0.1593 2000 40.0146 828 10493 10906.5 ROP 4.1626 369.141 48.1144 797 10580.5 10980.5 FET 1.5263 100.724 22.9188 828 10493 10906.5 RHOB 1.874 3.177 2.37797 898 10505 10953.5 DRHO -0.098 0.239 0.025804 898 10505 10953.5 PEF 4.572 16.493 7.56206 860 10524.5 10954 TNPS 16.97 123.38 42.0879 879 10498.5 10937.5 CTNA 546.556 1607.06 1017.44 879 10498.5 10937.5 CTFA 1.767 28.876 10.9895 879 10498.5 10937.5 First Reading For Entire File......... .10493 Last Reading For Entire File.......... .10980.5 File Trailer Service name........ .... .STSLIB.005 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .98/04/02 Maximum Physical Record..65535 File Type..... ... ... .... .LO ) Next File Name......... ..STSLIB.006 Physical EOF File Header Service name. ........ ....STSLIB.006 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.... ...98/04/02 Maximum Physical Record..65535 File Type................ LO Previous File Name. ..... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX GR RAT DRHO RHOB PEF $ 6 header data for each pass of each run in separate files. .5000 7 START DEPTH 10498.0 10498.0 10498.0 10500.0 10500.0 10500.0 10500.0 10500.0 10500.0 10500.0 10505.0 10505.0 10525.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP STOP DEPTH 10941.0 10941.0 10941.0 10909.5 10909.5 10909.5 10909.5 10909.5 10902.5 10980.0 10957.5 10957.5 10958.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMPENSATED NEUTRON 01-MAR-98 ISC 5.06 CIM 5.46,SP4 5.03,SLD 10.53 MEMORY 10980.0 10580.0 10980.0 40.3 41.0 TOOL NUMBER P0960SP4 P0960SP4 P0960SP4 ) SLD $ STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ........ ..... ..0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units. ... ..... ..Feet Data Reference Point.. .......... ..Undefined Frame Spacing...... ........ .......60 .1IN Max frames per record........... ..Undefined Absent value........ ....... ..... ..-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) P0960SP4 6.130 6.1 LSND 12.70 57.0 9.4 500 4.5 2.000 1.440 2.000 2.100 56.1 . 6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 7 FT/H 4 1 68 4 2 GR MAD 7 API 4 1 68 8 3 RPX MAD 7 OHMM 4 1 68 12 4 RPS MAD 7 OHMM 4 1 68 16 5 RPM MAD 7 OHMM 4 1 68 20 6 RPD MAD 7 OHMM 4 1 68 24 7 FET MAD 7 HOUR 4 1 68 28 8 TNPS MAD 7 P.U. 4 1 68 32 9 CTNA MAD 7 CNTS 4 1 68 36 10 CTFA MAD 7 CNTS 4 1 68 40 11 RHOB MAD 7 Glee 4 1 68 44 12 DRHO MAD 7 Glce 4 1 68 48 13 PEF MAD 7 BARN 4 1 68 52 14 ) Physical EOF End Of LIS File