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Home My WebLink About205-032CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification CRU CD3-112 (PTD# 206-032) Date:Monday, June 23, 2025 2:15:10 PM Attachments:image001.png AnnComm Surveillance TIO for CD3-112.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Monday, June 23, 2025 12:53 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: AOGCC Notification CRU CD3-112 (PTD# 206-032) Well Name: CD3-112 Facility: WNS PTD: 206-032 Well Type: Injector AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Chris, CRU CD3-112 (PTD# 206-032) was placed on a 30-day monitoring period to watch to watch OA pressures while on sea water injection. During the 30 days, the OA and IA has not exhibited problematic behavior and has been stable on injection. Attached is the 90-day TIO plot and wellbore schematic. The plan is to stop the 30-day monitor and continue sea water injection. Please let me know if you have any questions or disagree with the plan forward. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD3-112 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD3-112 2025-03-31 460 960 500 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:CD3-112 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled and re-set injection valve for drift CD3-112 3/22/2024 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic10.0 4/19/2019 jennalt NOTE: Waiver for water-only injection cancelled 4/17/19 post RWO. 4/17/2019 sheskin NOTE: TREE - FMC UNIHEAD GEN II 4 1/16" 5K PSI - TREE CAP - 7" OTIS 4/16/2006 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR Insulated 24" 16 15.01 36.0 114.0 114.0 84.00 J-55 WELDED SURFACE 9 5/8 8.83 36.5 2,726.0 2,485.4 40.00 L-80 BTC INTERMEDIATE 7 6.28 34.2 8,572.6 6,920.7 26.00 L-80 BTCM OPEN HOLE 6 1/8 8,572.6 16,021.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.1 Set Depth … 7,998.0 Set Depth … 6,758.0 String Max No… 3 1/2 Tubing Description Tubing – Production Wt (lb/ft) 9.30 Grade L-80 Top Connection 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.1 31.1 0.00 HANGER 10.860 FMC 11" x 4-1/2" 5k PSI Alpine horizontal producer with elastomer seals FMC Alpine Hroz 3.900 116.1 116.1 0.60 XO ENLARGING 5.190 4-1/2" 12.6# L-80 563 Hydril x 3-1/2" 9.3# L-80 563 Hydril X-O 00 2.992 2,181.3 2,030.7 32.91 NIPPLE 4.490 3-1/2" (2.813" HES "X" nipple) S/N 21605-03 SLB 0 2.813 7,817.2 6,657.2 52.01 INJ 5.700 3-1/2" x1-1/2" MMG W/SOV 563 BxP set to shear IA to Tbg 2000psi SN;20819-05 SLB MMG 2.867 7,908.4 6,710.7 56.13 PACKER 6.276 Baker Premier Packer Assy PN H784-63-0255 BOT 0 2.870 7,966.7 6,742.1 58.80 NIPPLE 4.490 2.813" XN with 2.75" No-Go Hyd 563 BxP SLB 0 2.750 7,987.5 6,752.7 59.75 XO ENLARGING 6.050 3-1/2" 9.3# L-80 563 Hydril B x EUE 8rd Pin BOT 0 2.992 7,989.3 6,753.6 59.83 POORBOY OVERSHOT 6.060 Baker Poorboy 4.5" Tubing Stub Overshot W/O Packing 7" x 3-1/2" Nominal 6.5' of swallow BOT 0 4.800 Top (ftKB) 7,993.8 Set Depth … 8,096.5 Set Depth … 6,803.7 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,023.1 6,770.2 61.36 PACKER 5.970 BAKER PREMIER PACKER Baker T&C Upset 3.875 8,084.0 6,798.3 63.80 NIPPLE 5.000 HES 'XN' NIPPLE **Nipple Reducer Installed w/ 2.313" X Profile** T&C Upset 3.725 8,095.1 6,803.1 64.24 WLEG 5.000 WIRELINE ENTRY GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,181.3 2,030.7 32.91 INJ VALVE 3.5" A-1 Injection valve (SN: 5212.2, OAL=45") on 2.81" X- Lock 3/22/2024 1.250 7,993.0 6,755.5 60.00 TUBING CUT TUBING CUT @ 7993' RKB Casing bridge plug 3/18/2019 3.958 8,084.0 6,798.3 63.79 NIPPLE REDUCER 3.813" XN NIPPLE x 2.313" X NIPPLE REDUCER (OAL=54") 12/18/2018 2.313 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,817.2 6,657.2 52.01 1 INJ DMY RKP 1 1/2 4/20/2019 RK Latch Schlumb erger Camco MMG Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,572.6 6,920.7 86.10 OPEN HOLE 6.125 Horizontal, CD3-112, 3/23/2024 7:35:27 AM Vertical schematic (actual) OPEN HOLE; 8,572.6-16,021.0 INTERMEDIATE; 34.2-8,572.6 NIPPLE REDUCER; 8,084.0 PACKER; 8,023.1 TUBING CUT; 7,993.0 NIPPLE; 7,966.7 PACKER; 7,908.4 INJ; 7,817.2 SURFACE; 36.5-2,726.0 NIPPLE; 2,181.3 CONDUCTOR Insulated 24"; 36.0-114.0 HANGER; 31.1 WNS INJ KB-Grd (ft) 42.76 RR Date 4/13/2006 Other Elev… CD3-112 ... TD Act Btm (ftKB) 16,021.0 Well Attributes Field Name FIORD NECHELIK Wellbore API/UWI 501032052700 Wellbore Status INJ Max Angle & MD Incl (°) 92.84 MD (ftKB) 10,277.56 WELLNAME WELLBORECD3-112 Annotation Last WO: End Date 4/10/2019 H2S (ppm) DateComment SSSV: A-1 INJ VLV · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c2 Q ~ - 0"3 ~ Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) page. .count Matches NUl nber in scanni~~ P7paration: L YES BY: ~ Date:1/1~ 07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided 11111111111111 II III R:7CAN \Z1" Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date 7 iw-I 0 7 I I Date7J/~/07 I I ~ x 30 = ltï ó Date: i 0 Project Proofing BY: ~ Scanning Preparation BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed "111111I11 II "1111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: me ,;"11111I11111I111 VV1 p 151 + /5 = TOTAL PAGES 17t:; (Count does not include cove~ 151 p III 1111111111111111 NO 151 ~p NO 151 II/ "111111I111111I ReScanned BY: Maria Date: 151 Comments about this file: 11/1111111111111111 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc C,G,~~- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.4550 _ ~ '~~~~ Company: Alaska Oil & Gas Cons Comm i ' `: ~ '~a~~~'~i ~q~G'H ~~~ ~ ~' Attn: Christine Mahnken ~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 01 /11 /08 1J-164 11964565 INJECTION PROFILE 01/04108 1 30-22 11970623 PRODUCTION PROFILE , J 01/04/08 1 3R-21 11964567 LDL - 01106/08 1 3J-12 11970620 INJECTION PROFILE 'Z j - ~ 01/01/08 1 3H-10B 11964562 PATCH EVALUATIONILDL U'=,~ ~ - ~ 01/01/08 1 1F-01AL1 11994591 FLOWING BHP SURVEY = 3 a 12/20/07 1 2N-342 11964561 OILPHASESAMPLER '~-- 12/31107 1 2L-330 11970618 SCMT - a 12/30107 1 2A-20 10194199 RST ~ - ~ 10/30/07 1 1 2X-19 11850441 RST - '-~-s , 07/09/07 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or faz to (907) 561-8317. Thank you. · J I JI/ll. DATA SUBMITTAL COMP-ÛANCE REPORT 7/2/2007 Permit to Drill 2050320 Well Name/No. KUPARUK RIV UNIT 1F-01AL 1 Operator CONOCOPHILLlPS ALASKA INC Spa/. j-j-. ÂA'\ll API No. 50-029-20889-60-00 MD 10216 /' TVD 6026 --- Completion Date 6/11/2005..-- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No Directional Survey c.....~ Current Status 1-01L UIC N - -_.._-~ DATA INFORMATION Types Electric or Other Logs Run: GRlRes, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name r Directional Survey b99 14245 Induction/Resistivity '-rOQ 14245 Induction/Resistivity Rpt 14245 LIS Verification ED C Lis 14245 Induction/Resistivity "',Id.., ~"}I[~"'L-L .f.-I::og 14300 Gamma Ray , ~ 14300 Gamma Ray 14300 LIS Verification o C Lis 14300 Induction/Resistivity t\t,,~ ) ~ L Well Cores/Samples Information: Log Log Run Scale Media No 25 Blu 25 Blu 5 Blu 5 Blu Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~,' 14 Daily History Received? Formation Tops Analysis Received? ~ (data taken from Logs Portion of Master Well Data Maint Interval OH/ Start Stop CH Received Comments 4 10216 Open 7/14/2005 MD 'O'"ctIO: R.., GR, ::-. 8255 10533 Open 11/17/2006 May-05 8255 10533 Open 11/17/2006 TVD Induction Res, GR, I 31-May-05 8259 10533 Open 11/17/2006 LIS Report, GR, ROP 10- Nov-2006 8259 10533 Open 11/17/2006 LIS Report, GR, ROP 10- Nov-2006 8143 10216 Open 12/28/2006 TVD MPR, GR 9-Jun-2005 8143 10216 Open 12/28/2006 MD MPR, GR 9-Jun-2005 8151 10216 Open 12/28/2006 LIS Veri, GR, ROP w/Graphics 8151 10216 Open 12/28/2006 LIS Veri, GR, ROP Sample Set Number Comments &/N œN e - Permit to Drill 2050320 MD 10216 TVD 6026 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Well NamelNo. KUPARUK RIV UNIT 1F-01AL1 Operator CONOCOPHILLlPS ALASKA INC Completion Date 6/11/2005 Completion Status 1-01L Current Status 1-01L -/J¿ API No. 50-029-20889-60-00 UIC N Date: }ÓJ~ ~') e e . .~ \ /,j'z~J Transmittal Form n.:~"itl . .., 'IIAI\ER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1F-01A, 1F-01AL1 Contains the following: ¡¡ 11 II 1i 11 2 LDWG Compact Disc (Includes Graphic Image files) 2 LDWG lister summary !J 11 :¡ !I II II II II II II II II ¡¡ n II n Ii I, , 2 bluelines - MPR-DIR_md Log 2 bluelines - MPR-DIR_tvd Log LAC Job#: 906970 Sent By: Cosetta TOd¿ca Received By: t, ,t ( .----- Date: Dec. 15, 2006 Date: I /5/ 0 --::; I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ;;o-S- -O¿;¡'ì ,í1. Il.{ ;1'1'4 905 -03d -.¡t: IL/30D Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ! r-·"~~~'P..q- 1(~·!ltimnl'ÜlJ \ ~'.~ .. ......'. c .. . c'·· ~ " .'U'¡(... _ ." .'" ...., ... "," ,-, l=~.-_~_Z~.~._~·;.._;_:.,._;=_~.,~! !7~::, -"' · STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COM~IO~ t(l:lit::IVt:'D JUl13 2005 rt!Bf~ :øo ('''ftA~' , WELL COMPLETION OR RECOMPLETION REP LIJ -LU' . ./$$/O'¡ 1 a. Well Status: Oil[] Gas U Plugged D Abandoned D Suspended D WAG 0 1 b. Well Class: -0· 20AAC 25.105 20AAC 25.110 Development [] Exploratory 0 GINJ 0 WlNJ 0 WDSPL 0 No. of Completions Other Service 0 Stratigraphic TestD 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: / ConocoPhillips Alaska, Inc. or Aband.: June 11, 2005 205-032 3. Address: 6. Date Spudded: :; ß-Þ . ',. ¡..ç 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 June K2005 '7· 2f- 50-029-20889-60 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: / 1 F-01AL 1 Surface: 1161' FNL, 388' FEL, Sec. 19, T11N, R10E, UM June 9, 2005 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 2322' FNL, 1030' FEL, Sec. 18, T11N, R10E, UM 44' AMSL Kuparuk River Field Total Depth: t~NL,~L,~e;~ T11N, R10E, UM 9. Plug Back Depth (MD + TVD): Kuparuk Oil Pool S~ 8301' MD / 5989' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 539592 y- 5958365 Zone- 4 10216' MD /6026' TVD ADL 25652 TPI: x- 538913 y- 5962480 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 536995 y- 5962808 Zone- 4 2400' ALK 2578 18. Directional Survey: Yes [] NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1450' MD 21. Logs Run: GRlRes, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 80' Surf. 80' 24" 250 sx AS 11 10.75" 45.5# K-55 Surf. 2630' Surf. 2216' 13.5" 1000 sx Fondu & 250 sx Permafrost C 7" 26# K-55 Surf. 6253' Surf. 4331' 8.5" 850 sx Class G & 250 sx PF C 4.5" 12.6# L-80 6086' 8335' 4217' 6070' 6-1/8" 65.4 bbls LiteCrete 2-7/8" 6.2# L-80 8164' 10100' 5969' 6006' 4-1/8" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6100' none Slotted liner from 8164'-10100' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 25, 2005 Oil Producer - shares production with 1 F-01A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WA TER-BBL CHOKE SIZE GAS-OIL RATIO 6/28/2005 6 hours Test Period --> 152 621 306 176 bean 4506 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 178 ps 749 24-Hour Rate -> 559 2518 1205 23° 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS 8Ft .iUI 9 1) 2005 COMPLETION ~ry þ( ~ NONE 1_· .0 L~~D _ ~ ".....;;.- Form 1 0-407 Revised 12/2003 C!Ô'~NOJEfP~:~E\'t~\ 1_ 28. 29. GEOLOGIC MARKERS FORMATION 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". 1 F-01AL 1 KOP (Kuparuk C4) Top Kuparuk B Base Kuparuk C4 Top Kuparuk B 8147' 8195' 8335' 10135' 5959' 5983' 5985' 6011' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randv Thomas Signature ~. ~- Title: Greater Kuoaruk Area Drillino Team Leader Phone ~, ç 6-fi >1> Contact: Jake Flora @ 265-6040 or Dan Venhaus @ 263-4372 7/, 2.(005 Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 abour 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, 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 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/19/2005 17:00 - 00:00 7.00 MOVE DMOB MOVE Prep rig for move, Remove beaver slide from outside sub base. Prep to slide floor. 4/20/2005 00:00 - 02:00 2.00 MOVE DMOB MOVE Disconnect service loops between drilling module and support module. 02:00 - 04:00 2.00 MOVE DMOB MOVE Skid rig floor and derrick to middle of drilling module. 04:00 - 06:00 2.00 MOVE MOB MOVE Move support module off well 3H-14B. 06:00 - 08:00 2.00 MOVE MOB MOVE Contact CPAI CPF-3 DSO to observed moving rig off well. Move drilling module offweIl3H-14B. 08:00 - 09:00 1.00 MOVE OTHR MOVE P/U matting boards around wellhead. Clean location. Take on fuel in drilling module. 09:00 - 18:00 9.00 MOVE MOB MOVE Held PJSM w/ crew on rig move. Notified NSK Security of rig move. Move rig down access road from 3H-pad to CPF-3 pad. 18:00 - 20:00 2.00 MOVE RGRP MOVE Repair moving system. 20:00 - 00:00 4.00 MOVE MOB MOVE Move rig and support module from CPF-3 Pad onto spine road. Move down spine road. Located in from of KCS pad at midnite. 4/21/2005 00:00 - 05:00 I 5.00 MOVE MOVE MOVE ,Move Rig down Spine Road to 1 F-Pad access road. 05:00 - 10:30 I 5.50 MOVE MOVE MOVE I Turn corner off spine road, Move rig down access road onto 1 F-Pad. 10:30 - 12:30 2.00 MOVE MOVE MOVE Move rig across pad and stage in front of well 1 F-01 A. 12:30 - 16:30 4.00 MOVE POSN MOVE Lay down liner and matting boards around well 1 F-01 A. 16:30 - 18:00 1.50 MOVE POSN I MOVE Position drilling module to move over well. 18:00 - 19:00 1.00 MOVE OTHR MOVE Lower wellhead casing valve leaking. Will not hold pressure. Call out FMC and CPAI valve crew. Casing valve repaired and secured. OA= 50 psi, IA= 550 psi. 19:00 - 22:30 3.50 MOVE POSN MOVE Call out CPAI DSO from CPF-1 to witness rig moving over well. Move drilling module over well. Move support module next to drilling module. i Skid rig floor and derrick over well center. RKB measurements = GL , 140.59', Csg Spool 36.89', Tbg Spool 34.85' i i 22:30 - 00:00 1.50 MOVE RURD RIGUP RIU beaver slide, Berm up around rig and cellar area. Hook up all I , service lines between modules. 4/22/2005 00:00 - 06:00 6.00 MOVE RURD RIGUP Accept rig at 00:00 hrs, 4/22/2005. Hook up all service lines, berm I around rig, spot bleed tank and choke skid. Prep to RU on tree to circulate. 06:00 - 07:30 1.50 MOVE RURD DECOMP Continue RU of hardline from tree to choke skid. Take on 8.8 ppg brine in pits. Spot rock washer. RU bleeder tank, manifold and flowline. 07:30 - 09:00 i 1.50 WELCT CIRC DECOMP Pull BPV (550 psi on tbg and 550 psi on 3-1/2" x 7" annulus). 09:00 - 10:30 I 1.50 WELCT CIRC DECOMP PJSM. Blow air through line and bleeder tank. Test lines to 1,500 psi 110:30 - 12:00 ì w/ brine. 1.50 WELCTU CIRC DECOMP I Circulate 8.8 ppg brine thru outer choke and bleed tank. Displace I I freeze protect diesel from well. I 12:00 - 14:00 2.00 WELCT CIRC DECOMP Continue circulating at 4 BPM and 500 psi. Shut down and monitor well for 10 minutes, 70 psi of press. Circulate and monitor well for 10 I minutes. Well was static. Blow down lines. 14:00 - 15:30 DECOMP Drain diesel from tree. Set BPV. 15:30 -18:00 . DECOMP PJSM. NO tree. Inspect and confirm threads on hngr - 4-1/2" LH , Acme. Remove tree from cellar. I 18:00 - 00:00 I 6.00 WELCT DECOMP Continue NU DSA and riser. Studs too short for 11", 3,000 lb. Replace studs. NU BOPs. Measure and cutoff pitcher nipple. Install I turnbuckles and mousehole. i 4/23/2005 i 00:00 - 03:00 3.00 WELCT NUND DECOMP Continue NU. Install turnbuckles and mousehole. '03:00 - 05:30 2.50 WELCTL BOPE DECOMP RU test joint and crossovers. Fill BOPs with water. Body test stack to I I 250 psi / 3,000 psi for 5 min each. RD. 05:30 - 06:00 0.50 WELLS PLGM DECOMP Pull Blanking plug. RU and pull BPV. 06:00 - 07:00 1.00 WELLS RURD DECOMP PU/RU Control line spooling unit and tubing handling equipment. 07:00 - 08:00 1.00 WELLS PULD DECOMP MU landing joint and crossovers. Attempt to screw into 4-1/2" LH acme Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07:00 - 08:00 08:00 - 10:30 10:30-11:30 11 :30 - 12:00 12:00 - 14:00 14:00 - 15:30 15:30 -16:30 16:30 - 18:30 18:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 4/24/2005 00:00 - 00:30 00:30 - 01 :30 01 :30 - 08:00 08:00 - 10:30 10:30 - 11 :00 11 :00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 20:45 20:45 - 21 :45 21:45 - 00:00 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: running tool into tubing hanger. Made numerous attempts. No-Go. Lay down landing joint. Call out Baker Fishing with spearing equipment. MU Spear. Spear into tubing, back out lock down screws. Pull tubing, working up to 250K, (11 OK over). Continue working tubing, pulling to 250K, plus. Note: when hanger was pulled near the rig floor, the control line was missing from the hanger port. CIRC DECOMP Reverse circulate tubing at 15 SPM and 520 psi. Discuss options with Drilling Management. OTHR DECOMP Continue pulling and work torque into string., working tubing, spear released. PULD DECOMP Lay down spear, break down landing joint, pup joint, TIW valve, crossovers, 15 pup joint to floor. Wait on subs for surface jars from Baker. PU/MU spear with bumper sub Spear into tubing hanger and adjust trip on jar to 120K, jar down. Adjust trip on jars to 180K, continue jarring. Total movement string I moved down +/- 4". JAR DECOMP. Continue jarring down on tbg string. No movement observed. OTHR I DECOMP I M/U top drive to jarring assembly. Attempt to work torque down into tbg I i string. Work string up and down. String rotates freely. No movement I I observed. 6.50 WAlTON EQIP DECOMP Discuss options with Drilling Management. Call out Schlumberger E-line I unit to run freepoint and cut tbg. CPBO DECOMP I Attempt to release 3-1/2" spear from tbg. Unable to release spear. Attempt to work RH torque down into string, no movement. Work LH I torque into string. String free, pull tbg hgr to rig floor. String weight ! indicates that +/- 1,000' of 3-1/2" tbg back-off. 0.50 CMPL TN PULD DECOMP! Lay down jarring assembly. Lay down FMC/OCT tbg hgr and pup jts. 3.50 CMPL TN PULD DECOMP I POH, lay down 27 jts. of 3-1/2" tbg. Recovered C/L entangled around I tbg collars starting at jt # 10 to jt # 27. Estimate TOF at 920'. Observed I C/L in stack at top of wellhead. DECOMP Clear rig floor of C/L, spooling unit, and tbg tongs. DECOMP Service Fishing tools, M/U jars and driil pipe. DECOMP PU Baker Rope spear BHA, Jars and 1 DC. Tag birdnested control line at the wellhead. Rotate and PU to rig floor (recovered 100-200') Continue RIH picking up DCs to 300'. TRIP DECOMP Continue PU/MU 4-3/4" Des and 20 joints of 4" DP, rabbiting on pipe skate. RIH and tag TOF at 913' DP measure. TRIP DECOMP POOH standing back DP and Des. Recover +/- 30' of additional control line. LD Rope Spear and Jars. TRIP DECOMP PU/MU overshot. RIH with DP from derrick, PU 8 additional joints. Tag up on TOF at 913'. Wash down with 4-5 BPM and swallow 2' offish, PU to 150K, set back down to 130K. PU to 250K slowly and monitor- no movement. Circulate and prep to chemical cut tbg. OTHR DECOMP Attempt to work tbg string free, work drill pipe from 130K dn to 250K up. No movement, string not free. CIRC DECOMP Circulate btms up from TOF. Sand and scale observed in returns at surface. Slight volume of gas at BU (max = 4,980 units). Shut down pumps. Monitor well, static. Call out Schlumberger to cut tbg. ELlN DECOMP Release overshot. Change out bales on top drive for longer set. M/U Schlumberger pump-in sub. 1.00 WELLS PULD 2.50 WAlTON EQIP 1.00 FISH PULD 0.50 FISH OTHR 2.00 FISH OTHR 1.50 I FISH 1.00 FISH 2.00 FISH 2.00 WAlTON EQlP 0.50 FISH PULD 3.00 FISH I JAR I I DECOMP DECOMP DECOMP 0.50 FISH 1.00 FISH 2.50 FISH 0.50 CMPL TN PULD 1.00 FISH PULD 1.00 FISH TRIP , 3.75 FISH 1.00 FISH 2.25 FISH 4/25/2005 00:00 - 01:15 1.25 FISH 01:15 - 02:00 0.75 FISH 02:00 - 03:45 1.75 FISH Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/25/2005 03:45 - 05:00 1.25 FISH ELlN DECOMP M/U Schlumberger equipment on drill string. 05:00 - 05:15 0.25 FISH ELlN DECOMP M/U jt of drill pipe. Slack off down over fish. Engage fish with 20K overpull. 05: 15 - 06:30 1.25 FISH ELlN DECOMP I M/U E-line sheave, M/U 80 gr string shot and tool string, stab into drill pipe. 06:30 - 08:15 1.75 FISH ELlN DECOMP RIH with string shot on E-line. Log into position. Fire string shot at 6,320' ELM. 08:15 -10:00 1.75 FISH ELlN DECOMP POH with E-line to surface. 10:00 - 10:15 0.25 FISH ELlN DECOMP PJSM on handling chemical cutter. 10:15 -11:30 1.25 FISH ELlN DECOMP M/U 2-1/4" chemical cutter on E-line tool string. 11 :30 - 13:00 1.50 I FISH ELlN DECOMP RIH with 2-1/4" chemical cutter on E-line. Log into position. Fire chemical cutter at 6,320' ELM. 13:00 - 14:30 1.50 FISH ELlN DECOMP POH with E-line to surface. 14:30 - 15:00 0.50 FISH ELlN DECOMP RID Schlumberger. 15:00 -15:15 0.25 FISH PULL DECOMP Latch elevators onto drill string. P/U string free at 130K. 15:15 -16:30 1.25 FISH CIRC DECOMP Circulate btms up, slight gas show at surface (max = 2,020 units). Circulate until well bore static. Shut down pumps. Monitor well, Static. Pump slug. 16:30 - 18:00 1.50 FISH DECOMP POH with tbg & drill pipe. Stand drill pipe in derrick. LD overshot. 18:00 - 19:45 1.75 WELLS DECOMP RU to circulate. Increase brine weight to 9.0 ppg. 19:45 - 21:00 1.25 WELLS DECOMP Circulate 9.0 ppg brine at 3 BPM (Max gas 3,070 units). Monitor well, Static. (7" x 9-5/8" Annulus pressure before circ = 300 psi, after = 600 psi). 21 :00 - 21 :30 0.50 WELLS DECOMP Pump slug and blow down all surface lines. 21 :30 - 23:30 2.00 WELLS DECOMP POOH, LD tbg. (control line was on jt below drillpipe). Cut C/L in 30-60' lengths and put in waste bags. Recovered 21 additional clamps. LD41 joints and SSSV. NORM tested same + tree - okay. 23:30 - 00:00 0.50 WELLS DECOMP PU storm pkr and set 90' below RKB with 20K below pkr. 4/26/2005 00:00 - 00:30 0.50 WELLS DECOMP Monitor well. No flow 00:30 - 04:30 4.00 WELLS DECOMP Drain BOPs. NO Bell Nipple and remove turnbuckles while bleeding off ! pressure from 9-5/8" x 7" annulus. 04:30 - 05:30 1.00 WELLS DECOMP I NO BOPs and riser from DSA. 05:30 - 06:00 0.50 WELLS DECOMP i Remove DSA and FMC Gen I casinghead. Pull packoff. 06:00 - 09:00 3.00 WELLS DECOMP I Clean Packoff area. Install new packoff. NU Gen V casinghead and : test packoff seals to 3,000 psi, for 10 min - okay. New RKB to LOS = 134.5'). 09:00 - 12:00 3.00 WELLS NUND DECOMP ! PJSM. NU DSA and BOPs. 12:00 - 12:30 0.50 WELLS NUND DECOMP I Continue NU BOPs. 12:30 - 14:00 1.50 WELLS SEQT DECOMP I RU and run test joint. Fill BOP stack and choke manifold. 14:00 - 18:00 4.00 WELLS SEaT DECOMP I Test BOPE - Annular to 250 /3,500 psi, Pipe rams, Blind rams, Choke i and Kill line valves, TIW, dart valve, manual and auto IBOP. Perform I accumulator closure test. 18:00 - 19:30 1.50 WELLS DECOMP I Continue testing BOPE to 250 psi low and 3,500 psi high. AOGCC rep, John Spaulding waived witnessing of test. 19:30 - 20:30 1.00 WELLS PLGM DECOMP Pull test plug and install Wear bushing. Run in 2 lock down screws on I DECOMP WB. 20:30 - 21 :00 0.50 WELLS PLGM PU Storm packer pulling equipment. 21 :00 - 22:00 1.00 WELLS PLGM DECOMP RIH, screw into Storm packer, close annular preventer, open choke, i release packer, monitor well, open annular and pull Storm packer + i i Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 4/27/2005 00:00 - 02:00 02:00 - 03:00 03:00 - 04:15 04: 15 - 06:00 06:00 - 12:00 12:00 - 12:30 12:30 - 14:30 114:30 - 15:00 115:00 -18:00 18:00 - 18:30 18:30 -19:00 19:00 - 20:15 20:15 - 21:00 21 :00 - 22:00 22:00 - 22:30 22:30 - 00:00 4/28/2005 00:00 - 00:30 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 03:45 I 03:45 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 11 :30 .11:30 -12:00 12:00 - 12:30 12:30 - 14:30 14:30-17:30 I i i 17:30 - 18:00 18:00 - 18:45 18:45 -19:15 119:15-19:45 19:45 - 20:30 20:30 - 22:30 22:30 - 23:00 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 4/19/2005 5/11/2005 Spud Date: 4/22/2005 End: 5/11/2005 Group: Sta rt: Rig Release: Rig Number: 1.00 WELLS PLGM 0.50 WELLS OTHR 1.50 WELLS~ PULD 2.00 WELLS 1.00 WELLS 1.25 WINDO 1.75 WINDO 6.00 WINDO 0.50 WINDO 2.00 WINDO tubing to rig floor. LD Storm packer. POOH and LD 3-1/2" tubing. (Note: tubing free of pitting, chemical scale, and threads are in good condition). Continue POOH and LD 3-1/2" tubing. Total of 129 jts +26.27' cutoff. RD tubing handling equipment. PU/MU Mill BHA. RIH picking up 4" DP from the pipe shed, drifting every joint. Continue RIH picking up DP. Continue RIH and tag up on Tbg stump at 6,329' DPM. Circulate one full hole volume at 5 BPM and 530-570 psi. Note: peak gas measurement = 4,980 units. Pump 30 bbl sweep. Monitor well - static. Pump slug, LD two singles and blow down TO. POOH with mills. LDmills. Clear rig floor of mill assembly. RU wireline equipment, and MU wireline head. RIH with 6.0" Guage Ring and Junk Basket to 6,315' (no tight spots). POOH with GRlJB (no tight spots - no overpull). No junk recovered in Junk Basket. DECOMP PU/MU Baker WL Bridge Plug. DECOMP RIH, log on depth, set Bridge Plug at 6,265' WLM (7' above csg collar and 30' below collar. POOH w/ WL tools. RD, LD WL tools. RU recording equipment. Pressure test casing to 3,000 psi for 15 minutes. ULD DECOMP 'I PU whipstock assembly and MWD. THR DECOMP PU Upload MWD data. Surface test. ULD IDECOMP Continue PU BHA. RIP DECOMP RIH w/ 4" DP from derrick. THR DECOMP Lubricate rig. RIP DECOMP RIH with Whipstock assembly to 6,271' DPM and tag up on retainer. IRC DECOMP Cir and condition mud. THR DECOMP Orient whipstock 85L degrees. Set whipstock IRe DECOMP Displace 8.8 ppg brine from hole with 10.2 ppg LSND. TWP DECOMP 1 Mill window. TOW = 6,253' md, BOW = 6,265' md. Drill new hole to 16,283'. Work mills through window. CIRC DECOMP Pump "Super Sweep at 4 BPM. Had 50-75% increase in cuttings I returns. CIRC DECOMP Continue circulating out sweep. Hole losing mud. Lost a total of 45 bbl. OTHR DECOMP Shut down pumps. Monitor well. Well flowing with 90 psi drillpipe pressure. Flow decreased to 2 bbl/hr and 70 psi DPP. Mud out: 10.2+ ppg, FV=48 sec. CIRC INTRM1 Circulate bottoms up at 7 BPM with hole losing mud. Slowed pumps to ! 5 BPM and 1,100 psi circ pressure, and losses were minimal. Max gas I was seen at btms up 576 units). Lost 12 bbl while circ. OTHR INTRM1 Monitor well with returns taken at an isolated pit. Flowback = 8 bbl. CIRC INTRM1 Circ @ 5 BPM and 1,100 psi with Max Gas = 449 units. Not losing returns. Stage up to 5.5 BPM, not losing. Stage up to 6 BPM and hole began losing returns at a small rate. Back off pump rate to 5.5 BPM. LOT INTRM1 Attempt to perform FIT to 12.5 ppg with 10.2 ppg LSND mud in the hole. Leak-off occured at 440 psi surface presure for 12.2 PPG EMW. DECOMP DECOMP DECOMP DECOMP DECOMP IDECOMP DECOMP 0.50 WINDO 3.00 WINDO 0.50 WINDO 0.50 WINDO 1.25 WINDO 0.75 WINDO 1.00 WINDO DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 0.50 WINDO 0.50 WINDO 0.50 WELLS I 2.25 WINDO 0.75 WINDO 1.00 WINDO 0.50 WINDO 1.00 WINDO 4.50 WINDO 0.50 WINDO . 0.50 WINDO 2.00 I WINDO 3.00 WINDO INTRM1 INTRM1 DECOMP 0.50 DRILL 0.75 DRILL 0.50 DRILL 0.50 DRILL 0.75 DRILL 2.00 DRILL 0.50 DRILL Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: Rig Release: Rig Number: 4/19/2005 5/11/2005 Spud Date: 4/22/2005 End: 5/11/2005 Group: 23:00 - 23:30 Break circulation at 5 BPM. 23:30 - 00:00 Pump 20 bbl pill of fine, 20 Ib/bbl LCM material. Note: Open hole 100:00 - 00:30 I volume := 1 bbl. 4/29/2005 0.50 DRILL CIRC INTRM1 Pump 20 bbl pill of fine, 20 Ib/bbl LCM material. Note: Open hole 00:30 - 03:00 I volume := 1 bbl. 2.50 DRILL CIRC INTRM1 I PU 5 stands to pull out of LCM pill. RU to hesitation squeeze LCM pill. I Close upper pipe rams. Pump until pressure just below leak-off pressure, allow to dissapate and pump again. Maintain pressure on LCM pill between 270 - 470 psi. Squeezed away 6 bbls. opened well and 1 bbl flowed back. 03:00 - 04:00 1.00 DRILL OBSV DECOMP Monitor well and RD squeeze equipment. 04:00 - 04:30 0.50 DRILL TRIP DECOMP Wash to bottom, 6,283' at 5 BPM. Lost 8.5 bbl, loss rate decreasing to zero. 04:30 - 05:00 0.50 DRILL CIRC DECOMP POOH t() inside window. Circulate bottoms up at 2-5 BPM. Lost 3 bbl. 05:00 - 05:30 0.50 DRILL OBSV DECOMP Monitor well, flowed back with initial DP pressure at 150 psi. Pressure and flowback rate decreased to zero. Flow back of losses from washing and circulating. Net loss zero. 05:30 - 06:00 0.50 DRILL LOT DECOMP Repeat LOT with same results. 06:00 - 07:30 1.50 DRILL CIRC DECOMP Circ and Cond mud. Spot 17 bbl LCM pill. 07:30 - 09:00 1.50 DRILL TRIP DECOMP POOH 10 stds slowly, with 40K of drag from 6,251' - 6,064'. 09:00 - 09:30 0.50 DRILL OBSV DECOMP Monitor well for 15 minutes - static. Pump slug and blow down TO. 09:30 - 12:00 2.50 DRILL TRIP DECOMP POOH and stand back 58 stds of DP and 5 stds of HWDP. 12:00 - 14:00 2.00 DRILL PULD DECOMP LD MWD and mills, clear rig floor. Note: mills in guage. 14:00 - 15:30 1.50 DRILL OTHR DECOMP RU and wash out stack. Function test all ram BOPs. Blow down TO. 15:30 - 17:00 1.50 DRILL PULD INTRM1 PU motor and set AKO to 1.5 deg/ MU bit. PU/MU MWD including PWD. 17:00 - 18:00 1.00 DRILL PULD INTRM1 Upload MWD. 18:00 - 20:30 2.50 I DRILL PULD INTRM1 Handle BHA. LD 9 joints of steel 4-3/4" Des. 20:30 - 21:15 0.751 DRILL PULD INTRM1 RIH w/ HWDP, PU jars, RIH w/ MWD and shallow test same. 21:15 - 22:45 1.501 DRILL ITRIP INTRM1 PU 39 joints of 4" DP from pipe shed, TIH. 22:45 - 00:00 1.25 DRILL ITRIP INTRM1 TIH w/4" DP from the derrick. 4/30/2005 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 ContinuE~ TIH with DP from derrick. 01 :00 - 02:30 1.50 DRILL OTHR INTRM1 Cut and slip 101' of drill line. Check crown-o-matic. 02:30 - 03:30 1.00 DRILL TRIP INTRM1 Orient toolface, pass through window - no problems. Wash to TO at 6,283'. 03:30 - 06:00 2.50 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,283' to 6,365' MD, 4,409' TVD. ADT - 2.4 hrs, ART - 0.0 hrs, AST - 2.4 hrs. WOB - 9K, RPM - 0, GPM-256, PRESS - 2,020 psi UWT = 155K, DWT = 120K 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,365" to 6,445' MD, 4,470' TVD. ADT - 4.83 hrs, ART - 0.68 hrs, AST - 4.15 hrs. WOB - 5K, RPM - 80, GPM-264, PRESS - 2,300 psi TORQUE on/off =-7K15K UWT = 155K, DWT = 115K, ROT= 140K 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,445" to 6,725' MD, 4,710' TVD. ADT - 11.78 hrs, ART - 7.59 hrs, AST - 4.19 hrs. WOB - 2-5K, RPM - 80, GPM-264, PRESS - 2,330 psi TORQUE on/off =-7K15K UWT = 155K, DWT = 115K ECD = 11.96 ppg, ECD @ Window = 11.92 (calc) Losses for day = 180 bbl (5-30 bbl/hr losses, 5/20 bbl flowback when pumps shut off). Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Sta rt: Rig Release: Rig Number: 4/19/2005 5/11/2005 Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/1/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,725' to 6,833' MD, 4,790' TVD. ADT - 4.18 hrs, ART - 1.52 hrs, AST - 2.66 hrs. WOB - 5K, RPM - 80, GPM-264, PRESS - 2,100 psi TORQUE on/off =-7K / 5K UWT = 155K, DWT = 115K ECD = 11.74 ppg, ECD Losses = 180 bbl Note: Increased Mud Wt to 10.6 ppg to test formation integrity with anticipated MW for well TO. 06:00 - 11 :00 5.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,833' to 7,064' MD, 5,000' TVD. ADT - 3.56 hrs, ART - 1.64 hrs, AST - 1.92 hrs. WOB - 2-5K, RPM - 80, GPM-254, PRESS - 2,400 psi TORQUE on/off =-7K /4K UWT = 160K, DWT = 128K, ROT =140K ECD = 12.04 ppg, ECD 11 :00 - 12:00 1.00 I DRILL CIRC INTRM1 Circ and condition mud. Loss rate increased from 30 bbl/hr to 60 bbl/hr. Mix and pump 39 bbl of DynaRed Fine + Safe Carb LCM pill at 20 Ib/bb/. 12:00 - 14:30 2.50 DRILL CIRC INTRM1 Continue to circulate decreasing flowrate to 3 BPM, 2 BPM, 1-1/2 BPM. Losses = 520 bbl (0700 hrs - 1400 hrs) 14:30-15:30 I 1.00 DRILL iOBSV INTRM1 Monitor wel/. Flowback decreasing. , 15:30 - 18:00 2.50 DRILL TRIP INTRM1 POOH slowly, 9 stands, and pass through window. 18:00 - 19:00 1.00 DRILL OBSV INTRM1 Try to break circulation - losing returns. Monitor well for flowback in trip tank. 19:00 - 23:00 4.00 DRILL ¡CIRC INTRM1 Circulate at 1-2.5 BPM to circulate btms up (Max Gas = 65 units). I Confer with Anchorage. Losses = 110 bbls (1800 hrs - 2300 hrs) 23:00 - 00:00 1.00 DRILL OBSV INTRM1 Monitor well. Flowback = 72 bbl total in one hour. Flowrate negligble at the end of the hour. 5/2/2005 00:00 - 00:30 0.50 DRILL ,TRIP i INTRM1 POOH 5 stands, from 6,230' - 5,805'. Gain - 17.5 bbl 00:30 - 02:30 2.00 DRILL IOBSV INTRM1 I Monitor well, gained 10 bbl in first 50 min, gained 3 bbl in the next 30 I ¡min. 02:30 - 03:00 , 0.50. DRILL TRIP INTRM1 POOH 5 stands, from 5,805' - 5,341'. Gain - 11.5 bb/. 103:00 - 04:00 1.00 DRILL OBSV INTRM1 Monitorwel/. Well gained 17.8 bbl, with decreasing flowback rate. 104:00 - 04:30 0.50 DRILL TRIP INTRM1 POOH 5 stands, from 5,341' - 4,873'. Gain - 10 bb/. i 04:30 - 05:30 1.00 DRILL OBSV INTRM1 Monitor well, gained 2.8 bb/. 05:30 - 06:00 0.50 DRILL TRIP i INTRM1 POOH 5 stands, from 4,873' - 4,402'. Gain - 7 bb/. 06:00 - 06:15 0.25 DRILL OBSV INTRM1 Monitor well, gained 1.7 bb/. 06:15 - 06:30 0.25 DRILL ICIRC INTRM1 Break circ., pump slug. 06:30 - 07:45 1.25 DRILL 'TRIP INTRM1 POOH 25 stands, from 4,402' - 2,083'. Gain - 23.5 bb/. 07:45 - 08:00 0.25 DRILL OBSV INTRM1 Monitor well, gained 2.2 bb/. 08:00 - 11 :00 3.00 DRILL TRIP INTRM1 POOH to MWD. 11 :00 - 12:00 1.00 DRILL PULD INTRM1 Download MWD. Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/2/2005 12:00 - 13:00 1.00 DRILL PULD INTRM1 I Clean rig floor and RU 2-7/8" tubing cement stinger. 13:00 - 14:15 1.25 CEMEN PULD INTRM1 PU 10 jts of 2-7/8" tubing from pipe shed. RD tubing handling equip. 14:15 - 16:00 1.75 CEMEN TRIP INTRM1 TIH w/ drillpipe from derrick to 3,000'. 16:00 -16:45 0.75 CEMEN CIRC INTRM1 Circ btms up at 2.5 BPM and 340 psi. 16:45-17:15 0.50 CEMEN TRIP INTRM1 Blow down top drive and TIH to 4,535'. 17:15-18:15 1.00 CEMEN CIRC INTRM1 I Circ btms up at 2.5 BPM and 400 psi. 18:15-19:15 1.00 CEMEN TRIP INTRM1 TIH to 6,200'. 19:15 - 20:45 1.50 CEMEN CIRC INTRM1 Circ btms up at 1.5 to 2.5 BPM - Lost 22 bbl. 20:45 - 21 :45 1.00 CEMEN OTHR INTRM1 Monitor well, gained 17 bbl. 21 :45 - 22:00 0.25 CEMEN~ SFTY INTRM1 PJSM for cement squeeze job. 122:00 - 22:30 0.50 CEMEN PUMP INTRM1 TIH to 6,300', RU cmt head, pump bbl of water, pressure test lines to 3,000 psi, jet mix and pump 8 bbl of 13.3 PPG, 8% bentonite cmt, Yld = 1.9 ft3/sk, followed by 5 bbl of water. 22:30 - 23:00 I Note: Thickening time = 5 hr 40 min at 90 deg BHT. 0.50 CEMEN DISP INTRM1 Displace cement with 5 bbl of 12.8 ppg mud and 60 bbl of 10.6 ppg , LSND mud at 3.5 BPM and 500 psi. 23:00 - 00:00 1.00 CEMEN TRIP ! INTRM1 POOH 5 stands to 5,832'. I Note: BOP test interval was verified to be 14 days by Tom Maunder- AOGCC. 5/3/2005 00:00 - 04:30 4.50 CEMEN CIRC INTRM1 Circulate and condition mud. Reduce mud weight to 10.4 ppg 04:30 - 06:45 2.25 WELCT OBSV INTRM1 Observe well. Gained 33 bbl. 06:45 - 08:00 1.25 DRILL CIRC INTRM1 CBU @ 2.5 bpm,410 psi 08:00 - 08: 15 0.25 DRILL REAM INTRM1 Wash and ream from 5832' to 6018' 08:15 - 09:15 1.00 DRILL CIRC INTRM1 CBU @ 2.5 bpm, 420 psi 09:15 - 10:00 0.75 DRILL REAM INTRM1 Wash and ream from 6018' to 6300' 10:00 - 11 :00 1.00 DRILL CIRC INTRM1 CBU @ 3.0 bpm, 470 psi 11 :00 - 12:45 1.75 DRILL REAM INTRM1 Wash and ream from 6300' to 7064' 12:45 - 13:45 1.00 DRILL CIRC INTRM1 Circulate and condition mud. P/U= 152k, S/O=115k, 43 spm @ 660 psi 13:45 -14:30 0.75 WELCTL OBSV INTRM1 Monitor well-slight flow back. Flow back decreasing 14:30 - 15:15 0.75 DRILL TRIP INTRM1 POOH to 6025' 15:15 -15:45 0.50 DRILL TRIP INTRM1 Pump slug and blow down top drive 15:45 - 18:00 2.25 DRILL TRIP INTRM1 POOH to 320' and prepare to UD 2-7/8" tubing stinger 18:00 -19:00 1.00 DRILL PULD INTRM1 UD 2-7/8" stinger 19:00 - 19:30 0.50 DRILL RIRD INTRM1 RID tubing tools 19:30 - 22:00 2.50 DRILL PULD INTRM1 M/U BHA and uplow MWD 22:00 - 22:45 0.75 DRILL TRIP INTRM1 Trip in hole to 3000' 22:45 - 23:00 0.25 DRILL CIRC INTRM1 CBU @ 185 gpm, 1000 psi 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Trip in hole to 6178' 5/4/2005 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 CBU @ 185 gpm and 1200 psi. Orient to go through window 01:00-02:15 1.25 RIGMNT RSRV INTRM1 Change TDS saver sub 02:15 - 04:00 1.75 DRILL REAM INTRM1 Trip through window and wash to 6636' 04:00 - 05:00 1.00 DRILL CIRC INTRM1 CBU 05:00 - 06:00 1.00 DRILL REAM INTRM1 Wash from 6636' to 7064' 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill from 7064' to 7149',5078' TVD 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drill from 7149' to 7300',5219' TVD. AST=5.9, ART=3.3, Pump pressure = 1700 psi on bottom/1500 psi off bottom, Torque= 6K on/ 5k off, P/U= 170k, S/O= 130K. WOB=8K, 43 spm/180 gpm, 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill from 7300' to 7363', TVD=5215' 5/5/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7363' to 7438' 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill and slide ffrom 7438' to 7522'. TVD=5432' 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drill and slide form 7522' to 7581'. TVD=5489'. 42 spm, 180 gpm @ 11900 psi on bottom/1700 psi off bottom. 80 rpm, Torque= 6 k off Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/5/2005 12:00 - 18:00 6.00 DRILL DRLG INTRM1 bottom, 6.5 k on bottom. WOB = 8k. P/U = 175k, S/O = 130k. Rot=150k 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7581' to 7666', TVD=5569' AST=4.89, ART=.49 5/6/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7666' to 7742'. TVD=5639'. AST=3.32 hrs. ART=.24 hrs 06:00 - 12:00 6.00 DRILL DRLG INTRM1 I Drill and slide from 7742' to 7832'. TVD=5720'. AST=4.73 hrs. ART=.44 hrs 12:00 - 18:00 6.00 DRILL DRLG INTRM1 I Drill and slide from 7832' to 7923'. TVD=5797'. AST=2.80 hrs. I ART=2.08 hrs Pump = 43 spm (180 gpm) @ 1900 psi on bottom /1610 I psi off bottom. Torque= 7k on/6k off. P/U=180kl S/O=135k1Rot=150k 118:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7923' to 8035'. TVD=5898'. AST=3.71 hrs. I ART=.68 hrs. max gas @ 7995' = 1464 units. Flow-chekc no flow 5/7/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 8035' to 8118'. K-1 @ 8025' MD. Max gas =5014 units.. Flow check-well static. AST=3.28, ART=.29 P/U=195k, S/O=135k Rot=160k 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill from 8118' to 8232'. TVD=6010'. AST=2.8 hrs, ART=1.11 hrs 12:00 - 14:15 2.25 DRILL DRLG INTRM1 Drill from 8232' to 8336'. TVD=6070'. ART=1.64hrs. Connection gas = 2500 units. 14:15 - 15:15 1.00 DRILL CIRC INTRM1 Circulate and condition mud to 10.4 ppg 15:15 - 16:45 1.50 DRILL CIRC INTRM1 Circulate high vis sweep. Lost 30 bbl mud. ECD=12.0 ppg EMW 16:45 - 17:00 0.25 DRILL OBSV INTRM1 Monitor well on trip tank. Flow back decreasing. 17:00 - 18:00 1.00 DRILL CIRC INTRM1 Circ and condition mud w/ full returns 18:00 - 21 :30 3.50 DRILL TRIP INTRM1 Pump out of the hole from 8336' to 6224' 21 :30 - 22:00 0.50 DRILL OBSV INTRM1 Monitor well. Well static 22:00 - 23:00 1.00 DRILL TRIP INTRM1 RIH from 6224' to 8234' 23:00 - 23:45 0.75 DRILL REAM INTRM1 Wash and ream from 8234' to 8336' 23:45 - 00:00 0.25 DRILL CIRC INTRM1 Circulate and condition mud while circulating 128 gpm, 80 rpm, 1100 psi. 5/8/2005 00:00 - 01 :45 1.75 DRILL CIRC INTRM1 Circulate and condition mud 01 :45 - 02:00 0.25 DRILL OBSV INTRM1 Monitor well- static 02:00 - 02:30 0.50 DRILL OTHR INTRM1 Spot 100 bblliner running pill 02:30 - 05:00 2.50 DRILL TRIP INTRM1 Pump out of hole from 8336' to 6070' 05:00 - 07:45 2.75 DRILL CIRC INTRM1 Pump super sweep pill around 07:45 - 08:00 0.25 DRILL OBSV INTRM1 Monitor well-static 08:00 - 11 :00 3.00 DRILL TRIP INTRM1 Pump slug. Drop rabitt and POOH from 6070' to 700' 11:00-12:00 1.00 DRILL PULD INTRM1 UD HWDP, jars, flex collars 12:00 - 14:00 2.00 DRILL PULD INTRM1 PJSM, drain motor, break bit and motor. Download MWD 14:00 - 14:30 0.50 DRILL PULD INTRM1 UD BHA 14:30 - 15:30 1.00 CASE RURD INTRM1 Clear floor and R/U to run 4-1/2" liner 15:30 -16:15 0.75 CASE SFTY INTRM1 PJSM prior to running liner 16:15 - 19:30 3.25 CASE PULR INTRM1 M/U shoe track and check floats. fill pipe and run liner per running order 19:30 - 20:30 1.00 CASE PULR INTRM1 P/U liner hanger and fill top w/ gel 20:30 - 21 :30 1.00 CASE ICIRC INTRM1 Circulate liner volume and blow down 21 :30 - 00:00 2.50 CASE ,RUNL INTRM1 Run liner on d.p. from derrick to 6199' 5/9/2005 00:00 - 00:30 0.50 CEMENj PULD INTRM1 M/U cement head w/ single and UD 00:30 - 01 :15 0.75 CASE CIRC INTRM1 CBU 01:15-03:15 2.00 CASE I RUNL INTRM1 Trip in hole w/ d.p. from derrick 03: 15 - 03:45 0.50 CASE IRUNL INTRM1 P/U cement head and tag bottom @ 8336' 03:45 - 06:00 2.25 CEMENfRC INTRM1 Circ and condition mud for cement job @ 3 bpm -750 psi 06:00 - 06:30 0.50 CEMEN CIRC INTRM1 Circ and condition mud while holding PJSM 06:30 - 07:30 1.00 CEMEN PUMP INTRM1 Pump 5 bbl water and test lines to 3960 psi. Pump 20 bbl CW100, 30 Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 06:30 - 07:30 1.00 CEMEN PUMP INTRM1 07:30 - 08:30 1.00 CEMEN DISP INTRM1 08:30 - 08:45 0.25 CEMEN OTHR INTRM1 08:45 - 09:45 1.00 CASE CIRC INTRM1 09:45 - 10:30 0.75 CASE RURD INTRM1 10:30 - 11 :00 0.50 CASE OTHR INTRM1 11 :00 - 14:00 3.00 CASE OTHR INTRM1 14:00 - 15:00 1.00 DRILL TRIP INTRM1 15:00 - 17:30 1 2.50 DRILL PULD INTRM1 17:30 - 18:00 0.50 CEMEN PULD INTRM1 18:00 - 19:00 1.00 CMPL TN NUND CMPL TN 19:00 - 20:00 1.00 CMPL TN RURD CMPL TN 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN 00:00 - 02:00 2.00 CMPL TN RUNT CMPL TN 02:00 - 02:45 0.75 CMPL TN DEOT CMPL TN 02:45 - 05:30 2.75 CMPL TN RUNT CMPL TN 05:30 - 07:15 1.751 CMPL TN SOHO CMPL TN 07: 15 - 11 :00 3.75 CMPL TN CIRC CMPL TN 11:00-12:00 1.00 CMPL TN SOHO CMPL TN 12:00 - 13:00 1.00 CMPL TN RURD CMPL TN 13:00 - 13:30 0.50 CMPL TN RURD CMPL TN 13:30 - 15:30 2.00 CMPL TN NUND CMPL TN 15:30 - 19:30 4.00 CMPL TN NUND CMPL TN 19:30 - 21 :00 1.50 CMPL TN NUND CMPL TN 21 :00 - 22:00 1.00 CMPL TN SEQT CMPL TN 22:00 - 23:00 1.00 CMPL TN RURD CMPL TN 23:00 - 23:30 0.50 CMPL TN SEQT CMPL TN 23:30 - 00:00 0.50 CMPL TN SEOT CMPL TN 00:00 - 00:30 0.50 CMPL TN FRZP CMPL TN 00:30 - 01 :00 0.50 CMPL TN FRZP CMPL TN 01 :00 - 01 :45 0.75 CMPL TN FRZP CMPL TN 01 :45 - 02:45 1.00 CMPL TN FRZP CMPL TN ì 02:45 - 03:00 0.25 WELLS~ PLGM CMPL TN 03:00 - 04:00 1.00 MOVE ! DMOB CMPL TN 5/9/2005 5/10/2005 5/11/2005 bbl Mudpush XL @ 12.5 ppg. Mixed and pumped 65.4 bbl Litecrete slurry @ 12.5 ppg. Dropped plug. Displace cement w/ 40 bbl water w/ OS and 62 bbl mud w/ rig pump. Bumped plug. Set liner hanger w/ 2900 psi. Set liner top packer w/ 3900 psi. P/U and establish circulation. Set down on top of hanger to insure released. Circulate and condition mud. Had 5 bbl contaminated mud cement in returns. Set down weigh to insure packer set. RID cement head and broke down manifold. Blew down Pumped slug, cleared floor and blew down top drive POOH UD 4" d.p. RIH w/21 stands 4" d.p. from derrick UD 4" d.p. UD liner setting tool and r/u to pull wear ring Pull wear ring. Drain stack and make dummy run w/ tubing hanger and landing jt. RIU to run 4-1/2" tubing. Hold PJSM Run 4-1/2" tubing and completion jewelry. i RIH with 4-1/2" Completion string. ! M/U TRSSSV with C/L, Test to 5,000 psi, OK. IRIH with 4-1/2" completion string and C/L. Totaljts. ran 191. Total C/L I bands 80. I Space out seal assembly, Pressure up to ensure seals engaged. OK. 1 M/U space out pup jts with tbg hgr and C/L. Land tbg. P/U hgr off seat, Break circulation and displace well to seawater with corrosion inhibitor. ii' Land tbg hgr. RILDS, Back out and lay down landing jt. Clear rig floor, lay down all handling tools. I Set BPV in tbg hgr. I C/O top pipe rams to 4-1/2" x 7" VBR, Btm pipe rams to 3-1/2" x 6" IVBR. ,Pull and lay down mouse hole. N/D BOPE. I N/U adapter flange and production tree. Test adapter flange to 5,000 i psi for 15 min. OK I RIU Pump Truck to tree, Pressure test tree to 5,000 psi for 15 min. OK Pull 2-way check. RIU lines to test tbg and annulus. PT surface lines to 4,000 psi. OK Pressure test tbg to 3,500 psi for 30 min. OK Bled off tbg pressure to 1,500 psi. Pressure up on tbg x csg.annulus to 13,500 psi for 30 min test. OK Bled down tbg pressure, observed valve shear at 2,650 psi. il LRS pump truck displaced 67 bbls diesel to well for freeze protection. U-tube Diesel I Clear all surface lines of diesel to LRS pump truck. RID test lines from ¡tree. Set BPV. ! Secure wellhead and tree. Finish cleaning Rock Washer and Pits. I Prepare for Rig Move. Released rig from operations on Well 1 F-01A at 104:00 hrs on 5/11/2005. I Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/23/2005 00:00 - 12:30 12.50 MOB P PRE Rig released on 3M-13 at 22:00 hrs 5-22-2005. Moved off well and made ready to mobilize to 1 F Pad. Started rig move at midnight Stopped at 1 Q Pad for Kuparuk Crew change Stopped at 1 A Pad for low fling planes Travel up 1 F Pad excess road 12:30 - 14:00 1.50 MOB P PRE Rig on 1 F Pad Load 2-3/8" reel on rig. Conducted Pad Inspection with DSO Working with Kup Safety on placement of camps. 14:00 - 17:00 3.00 MOB PRE Moved rig to edge of well, PJSM and put flange and new kill hose in well cellar. 17:00 - 18:00 1.00 MOB P PRE Moved rig onto well. Remove tree cap. Prep to NU BOP's. 18:00 - 23:30 5.50 BOPSU P PRE NU 7-1/16" 5K BOP's. Install 3" combi's. Take on 290 bbls 8.6ppg used Flo-Pro mud. 23:30 - 00:00 0.50 BOPSU PRE Pressure test BOP's 250 psi low 4500psi high. Witnessing waived by AOGCC 5/24/2005 00:00 - 04:30 4.50 BOPSU PRE Continue to test BOPE. 250 psi low and 4500 psi high. Tested accumulator. 04:30 - 06:00 1.50 WHIP P WEXIT PU injector. Make up pack-off assembly. String coil across and stab to injector. 06:00 - 10:00 4.00 WHIP P WEXIT Finished securing BOP stack. Install control panel on TRSSSV and pressured up to 5,000 psi. Meged Eline at 60mH, Pumping fluid (rev cir) for CT slack management. 10:00 - 13:00 3.00 WHIP P WEXIT RU to cut off CT to find wire. Cut off 17 ft CT. Dimpled CTC Pull test CTC to 50k Rehead CT Eline. Repacked wireline packoff and rehead BHI tested tool. Circ CT and open well. Pc = 50 psi. Open up and bled down to zero. 13:00 - 13:45 0.75 WHIP P WEXIT Circulated 1 coil volume and Cut off MH for BHA's, check reel bushing OK 13:45 - 14:45 1.00 WHIP P WEXIT PU 3.8" Parabolic Mill BHA and stab CT 14:45 - 16:45 2.00 WHIP P WEXIT RIH wo/ pumping w/ new 3.8" Parabolic mill BHA No problem running throught TRSSSV at 2,400 ft. Tagged 8217 ft, PU, open EDC and started cir down CT at 2.75 bpm to swap well bore to 8.6ppg flo-pro and tie-in 16:45 - 17:00 0.25 WHIP P WEXIT PUH to 8,000 ft to tie-in 17:00 - 17:30 0.50 WHIP P WEXIT Logging down to tie-in Corrected +5' Circulated 30 bbls 10.5ppg drilling mud with lots of sand of of well bore. Closed EDC and cir through bit. RIH and confirm PBTD before cleanout. 17:30 - 18:15 0.75 WHIP P WEXIT Cleanout well bore at 2.8 bpm 3552 psi Nothing hard from 8,222 ft to 8265 ft Tagged landing colllar at 8265 ft. PUH and wash from 8222 ft to 8263 ft twice 18:15 - 20:30 2.25 WHIP P WEXIT PUH to 8050 ft and painted flag. EOP at 8000 ft, Opened EDC and circulated 3.00 bpm POOH. Stop at 2000'. Pressure well to 1000 psi. Close SSSV. Open well to help verify SSSV is holding. Appears to be holding based on small volume of fluid rtns. Hold PJSM to discuss BHA un-deploy and WS make up. 20:30 - 21 :45 1.25 WHIP P WEXIT At surface. Get off well. LD motor & mill. No wear on mill. Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/24/2005 20:30 - 21 :45 21 :45 - 22:45 5/25/2005 22:45 - 23:45 23:45 - 00:00 00:00 - 00:30 00:30 - 01:15 01:15 - 01:30 01 :30 - 02:00 02:00 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 06:55 06:55 - 08:30 08:30 - 10:50 1 0:50 - 11 :30 11 :30 - 18:00 18:00 - 00:00 5/26/2005 00:00 - 00:30 00:30 - 01 :15 01:15 - 02:45 02:45 - 03:45 1.25 WHIP P WEXIT 1.00 WHIP P WEXIT 1.00 WHIP P 0.25 WHIP P 0.50 WHIP N WEXIT WEXIT DFAL WEXIT 0.75 WHIP N DFAL WEXIT 0.25 WHIP N 0.50 WHIP N DFAL WEXIT DFAL WEXIT 2.00 WHIP P 0.50 WHIP P 0.25 WHIP P WEXIT WEXIT WEXIT 2.17 WHIP P 1.58 WHIP P WEXIT WEXIT 2.33 WHIP P WEXIT 0.67 STWHIP P WEXIT 6.50 STWHIP P WEXIT 6.00 STWHIP P WEXIT 0.50 STWHIP WEXIT 0.75 STWHIP 1.50 STWHIP WEXIT WEXIT 1.00 STWHIP WEXIT Re-configure MWD tools to run orienter. Test same. MU Weatherford 4-1/2" LSX-N whipstock on Fury setting tool. Inspect all components. Scribe orienter to ws tray. TOW to tray btm: 8.25' TOW to PIP tag: 8.90' Stab coil. Get on well. RIH at 75 fpm. Tag sssv at 2400'. Check control panel pressure. Increase from 4000 to 4500 psi. Tag up again. Suspect sssv is closed. POOH. Get off well. Un stab coil. LD whipstock. MU nozzle on MWD tools. Stab coil. Get on well. RIH. Tag SSSV at 2400'. Pressure up well to 1500 psi. RIH. SSSV open. Bleed WHP and try again. Valve open. POOH Get off well. Remove nozzle. MU and scribe whipstock to MWD tools. Test tools. Get on well. RIH. Log GR tie in from 8050'. Add 4' correction. Continue in hole. Set top of whipstock at 8249' with a 30r orientation. Close EDC and presure coil to 2950 psi. Whipstock appears to have set. POOH. Closed SSSV at 2200 ft LD WFT running tool and PU WFT window exit BHA. Added 5 ft lubricator for pressure deployment and checked measurements. 1.5 ft down after tagging up on pack off for pressure undeployment and deployment RIH to 470 ft, found lubricator leaking (oring). POOH and changed, RIH Tied in at 8,020 ft logging down Corrected - 2ft Closed EDC RIH and tagged 8253 ft. Set WOB Milled window at 0.1 ft / hrs WOB changing due to geometry of wellbore Be careful so not to jump out to soon. Started at 9249.1 ft and raising mud denity to 9.9 ppg Continue milling ahead. 3780 psi @ 2.72 in/out. DHWOB: 2-3k#. WHP/BHP/ECD: 73/3550/11.58 ppg IAlOAlPVT: 365/242/375 bbls. Increase whp to 650 psi, ECD to 13.45, BHP: 4100 psi. 4100 psi @ 2.55 in/out. Appear to milling formation. Exit casing. Mill formation to 8265'. Confirm formation in btms up sample. Uncorrected to mother bore Top window: 8249.1' Btm window: 8255.2' RA tag: 8258' Ream and backream window three times. Dry drift. Open EDC. Circulate out of hole following pressure schedule. Paint EOP flag at 8000'. Continue to POH. Close sssv. Rearrange sssv panel control line to correct fitting on wellhead. Bleed WHP to zero. Tag up. Get off well. Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/26/2005 02:45 - 03:45 1.00 STWHIP WEXIT Unstab coil. LD BHA assembly. 03:45 - 04:30 0.75 DRILL PROD1 MU build assemby #1 (2.2 deg mtr w/ HTC bicenter). Stab coil. Test MWD. Get on well. 04:30 - 06:25 1.92 DRILL PROD1 Open EDC. RIH. Circulate and maintain WHP to follow pressure schedule once sssv is opened Tied-in at 8020 ft. Correction -2 ft, closed EDC and oriented TF to HS 06:25 - 06:35 0.17 DRILL PROD1 RIH string wt lower than normal, 6500 down wt above the window wo circulating, Tagged at 8265 ft Open choke and adusted Qp to achieve BHP of 4200 psi and 600 psi at surface. Vp = 367 bbl 06:35 - 11 :00 4.42 DRILL PROD1 DOCTDD TF @ 75R- 90R ROP 30-40 fph Qp = 2.61/2.65 bpm; Pp = 3,800 / 4222 psi BHP / WHP = 4,100/600 psi; Increased to 4200 /700 psi ECD = 13.4pppg Density = 9.9/ 9.96 ppg Vp = 367 @ 0635 hrs 0.171 DRILL Drilled through A5 at 5,975 ft TVD (as per prognosis) 11:00-11:10 PROD1 Computer locked up. SO pump, SWI at 1,100 psi. Reset at 8,354 ft 11:10-14:30 3.33 DRILL PROD1 DOCTDD in A5 TF @ 90R- 120R ROP 15-25 fph Qp = 2.61 /2.65 bpm; Pp = 3,800 / 4222 psi BHP / WHP = 4,248 /700 psi; ECD = 13.8pppg Density = 9.91 19.97 ppg Vp = 364 @ 11 :00 hrs 14:30 - 14:50 0.33 DRILL PROD1 Wiper trip and change to MP2 Clean wiper trip 14:50 - 17:00 2.17 DRILL PROD1 DOCTDD A51 A4 w/TF @ 90R- 120R ROP 15-25 fph Qp = 2.60 I 2.61 bpm; Pp = 4,000 / 4,400 psi BHP / WHP = 4,318 I 690 psi; ECD = 13.9pppg Density = 9.91 I 10.00 ppg Vp = 363 @ 14:45 hrs Fault 1 at approximately 8,538 ft MD 6,015ft TVD Reduced WHP to 630 psi at 8,481 ft to keep BHP at closer t04200 psi 17:00 - 21 :00 4.00 DRILL PROD1 DOCTDD A5 I A4 wI TF @ 75R ROP 15-70 fph Qp = 2.60/2.61 bpm; Pp = 4,0611 4,200 psi BHP I WHP = 4,218 I 630 psi; ECD = 13.6pppg Density = 9.91/10.00 ppg Vp = 360 @ 17:00 hrs Land build at 8600'. Projected Inc I Az: 92 deg /285 deg. 21 :00 - 22:30 1.50 DRILL PROD1 Wiper trip to window. Hole smooth. Orient TF for window. Shut dn pump and inc WHP to 1050 psi. Resume circulation. Continue to POOH following WHP/BHP pressure schedule. Transfer fluid in pits to prep for mud swap. Close TRSSSV with 1100 psi on well. Continue to POOH. 22:30 - 00:00 1.50 DRILL PROD1 At surface. Get off well. LD BHA assy. MU resistivity tool in MWD string. Test same. 5/27/2005 00:00 - 01:15 1.25 DRILL P PROD1 Continue to mu and catwalk test mwd with resistivity tool added to string. MU BHA with Hycalog bi-center bit on 0.8 deg mtr. Change packoffs and inspect power pack. Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/27/2005 00:00 - 01 :15 1.25 DRILL P PROD1 Stab coil. Test MWD. Get on well. 01 :15 - 02:45 1.50 DRILL P PROD1 RIH. Inc WHP to 1100 psi. Open TRSS8V. RIH. Follow BHP schedule. 02:45 - 03:15 0.50 DRILL P PROD1 Log gr tie in from 8040'. Minus 2 ft correction. 03:15 - 04:00 0.75 DRILL P PROD1 RIH to window. MADD pass resistivity down through build section. Circ at min rate. Tag btm at 8601'. New mud to bit. Take last of used mud to pit #1. Mud swap complete. New mud system ordered to top off uprights on 04:00 - 06:00 I location. 2.00 DRILL P PROD1 Drill ahead from 8600'. 3900 psi fs @ 2.65 in/out. 200-300 , dpsi. DHWOB: 1 k-2k#. ROP: 40-60 fph. WHP/BHP/ECD: 600/4100/13.1 ppg. IAlOAlPVT: 5/10/353 bbls. I NC/AZ/TF: 92.8/294/80r. 06:00 - 06:45 0.75 DRILL P PROD1 DOCTDD in A4 TF @ 60L ROP 15-30 fph Op = 2.69/ 2.66 bpm; Pp = 4,000 / 4200 psi BHP / WHP = 4,200 /650 psi; ECD = 13.2pppg Density = 9.91/9.97 ppg Vp = 351 @ 06:15 hrs 06:45 - 10:20 3.58 DRILL P PROD1 DOCTDD in A4 TF @ 90R-135R. ROP 5-30 fph Op = 2.69 / 2.66 bpm; Pp = 4,000 / 4175 psi BHP / WHP = 4,145/650 psi; ECD = 13.2pppg Density = 9.92 / 9.96 ppg Vp = 352 @ 06:45 hrs Next Fault at 8,825 ft MD / 6002 ft TVD 10:20 - 11 :15 0.92 DRILL P PROD1 Wiper trip to tie-in 4-1/2" liner to RA in WS Reduced Op to 0.25 bpm and trapped 900 psi on WH and pulled through wind. Open EDC and cir at 2.00 bpm pulling tight, some packing off above WS. Worked bit down and increased Op to 2.6 bpm. RIH to TOW and cleaned up solids buildup above WS. PUH to 8,050ft and RIH at 80 fpm to assist in hole cleaning 11:15-11:35 0.33 DRILL P PROD1 Logging tie-in Corrected + 1 ft RIH, closed EDC and RIH through window to 8,290 ft 11 :35 - 11 :50 0.25 DRILL P PROD1 Tie-in RA Marker Corrected RA Marker: TOW @ 8251.1 ft BOW @ 8258.0 ft RA Marker 8260.0 ft 11:50-12:10 0.33 DRILL P PROD1 RIH 12:10 -12:15 0.08 DRILL P PROD1 DOCTDD in A4 TF @ 90R. ROP 1-5 fph Op = 2.53/2.52 bpm; Pp = 3,900/ 4175 psi BHP / WHP = 4,133/640 psi; ECD = 13.2pppg Density = 9.92 / 9.96 ppg Vp = 340 @ 12:00 hrs Maintain 92-93 deg hole angle until 8,900 ft Adding dry product Flo-Vis Plus to mud to increase LSRV to 55-60k 12:15 - 12:35 0.33 DRILL P PROD1 Lost all rig power while drilling. Re-started 2 generators and made 100 ft wiper trip. Down for 5 minutes. 12:35 - 15:20 2.75 DRILL P PROD1 DOCTDD in A4 TF @ 140 - 90R. ROP 5-20 fph Op = 2.53/2.53 bpm; Pp = 3,900 / 4175 psi BHP / WHP = 4,150/645 psi; ECD = 13.2pppg Density = 9.92 / 9.96 ppg Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/27/2005 12:35 - 15:20 2.75 DRILL P PROD1 Vp = 336 @ 12:00 hrs 8,750 ft sample showed hard shale and claystone, ROP was 1-5 fph 15:20 - 17:00 1.67 DRILL P PROD1 DOCTDD in A4 TF @ 140 - 180R. ROP 5-30 fph Qp = 2.53/2.57 bpm; Pp = 3,900 I 4275 psi BHP / WHP = 4,197/652 psi; ECD = 13.4pppg Density = 9.92/9.96 ppg Vp = 340 @ 1530 hrs. LSRV at 58k 17:00 - 17:15 0.25 DRILL P PROD1 DOCTDD in A4 TF @ 90 R. ROP 30-50 fph Qp = 2.53/2.59 bpm; Pp = 3,900 I 4215 psi BHP / WHP = 4,199/635 psi; ECD = 13.48pppg Density = 9.92 / 9.96 ppg Vp = 340bbl @ 1700 hrs. The 0.8 deg motor bend is giving us and 14.8 deg DLS averages DLS 17:15 -18:15 1.00 DRILL P PROD1 Wiper trip to check soilds build up above WS Clean above WS 18:15 - 21:00 2.75 DRILL P PROD1 Drill ahead from 8850'. 4050 psi fs @ 2.7.in/2.7 out. 300-400 dpsi. DHWOB: 2k-3k#. ROP: 30-50 fph. WHPIBHP/ECD: 645/4200/13.4 ppg. IAlOAlPVT: 229/2561331 bbls. INC/AZ/TF: 92.1/287/110r. Drilling ROP continues to be variable. 20 to 60 fpm. Numerous stalls noted. 21 :00 - 22:30 1.50 DRILL P PROD1 Drill ahead from 8955'. 3950 psi fs @ 2.6 in/2.6 out. INC/AZ/TF: 89,7/300.1/85L 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to 7900'. Open and cased hole very smooth. Maintain TF as drilled in and out of hole. 5/28/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 9002'. 4000 psi fs @ 2.4.in/2.4 out. 250-400 dpsi. DHWOB: 2.5k-3k#. ROP: 20-60 fph. WHP/BHP/ECD: 600/4220/13.46 ppg. IAlOAlPVT: 420/410/325 bbls. I NC/AZ/TF: 90.9/299/40L. Continue to experience numerous stalls. Not much margin between pump pressure and max pump pressure available due to WHP needed to maintain required BHP. 03:00 - 04:00 1.00 DRILL P PROD1 Drill ahead from 9072'. Plow into shale. 04:00 - 05:15 1.25 DRILL P PROD1 Wiper trip to 7900'. Plot logs and discuss geology with town. Decide to drill ahead and try to drill down out of shaley interval. Log GR tie in to well bore. Minus 4.5' correction. Hole very smooth. 05:15 - 08:45 3.50 DRILL P PROD1 Drilling in A4 TF @ 180. Turned TF to 90L 9,130 ft ROP 5-20 fph Qp = 2.40/ 2.43 bpm; Pp = 4,100 / 4450 psi BHP 1 WHP = 4,210 1 571 psi; ECD = 13.5pppg Density = 9.95/9.99 ppg Vp = 326 @ 06:30 hrs; 334 bbl @ 0830 hrs Called for Mud Swap at 1200 hrs, Solids at 0.5% CTP at 4350 psi.at 2.37 bpm 08:45 -11:15 2.50 DRILL P PROD1 POOH, Need mud swap, CTP at 4400 psi at 2.3 bpm on bottom, A V dropping and ROP to slow for Be bit. Pulled through window while trapping 1000 psi WHP and tried to open EDC while move CT Unable to open, Cir through bit and POOH. Closed SSV with 1100 psi below. Printed: 6/22/2005 2:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/28/2005 11 :15 - 13:30 2.25 DRILL P PROD1 OOH, checked flow, stood injector back. LD MWD and tested EDC. Changed out bit and checked HS on motor, (OK) Change out EDC (bad pump) and DBV inserts. PU BHA 13:30 - 15:15 1.75 DRILL P PROD1 RIH with EDC open at 3.00 bpm Stopped at 1,950 ft closed choke and pressured up on wellbore to 1,100 psi, Open SSSV and let equalize. Pressure under SSSV 1,190 psi, no loss or gain while changing out BHA (3 hrs). RIH following pressure schedule 15:15 - 16:00 0.75 DRILL P PROD1 SO pumps, closed EDC and orient TF to HS RIH past WS, RIH tagged bottom at 9,159 ft. 16:00 - 18:15 2.25 DRILL P PROD1 Drilling in A4 TF @ 90L ROP 2-45 Iph in Ankerite stringers Op = 2.40 /2.43 bpm; Pp = 4,000 / 4250 psi BHP / WHP = 4,250 1 600 psi; ECD = 13.7pppg Density = 9.95 1 9.99 ppg Vp = 322 bbl @ 16:00 hrs. Begin mud swap. 18:15 - 20:30 2.25 DRILL P PROD1 Wiper trip to window. Hole smooth. Log gr tie from 8060. Add l' correction. Log RA tag. Found at 8260' (no change). Continue in hole. 20:30 - 0.00 DRILL P PROD1 Drill ahead form 9275'. 3800 psi Is @ 2.4 in/2.4 out. 200-350 dpsi. DHWOB: 1k-2k#. ROP: 40-80 Iph. WHP/BHP/ECD: 650/2400/13.45 ppg. INONPVT: 0/61/341 bbls. I NC/AZfTF: 88.1/270/80R. 5/29/2005 00:00 - 00:45 0.75 DRILL P PROD1 Complete wiper trip to/from window. Hole smooth. 00:45 - 06:00 5.25 DRILL P PROD1 Drill ahead rorm 9500'. 3800 psi fs @ 2.4 in/2.4 out. 200-350 dpsi. DHWOB: 1k-2k#. ROP: 60-110 Iph. WHP/BHP/ECD: 630/4198/13.45 ppg. INONPVT: 24/100/320 bbls. INC/AZfTF: 87.1/282/92R. Hit a hard spot f/9555' to 9560'. 1-5 fph. ROP increased again at 9560'. 06:00 - 09:05 3.08 DRILL P PROD1 Drilling in A4 TF @ 75R. ROP 5 fph Ankerite Op = 2.54/2.56 bpm; Pp = 3975 / 4000 psi BHP / WHP = 4,206/600 psi; ECD = 13.5 ppg Density = 9.95/10.0 ppg Vp = 327/314bbl @ 06:15 hrs Drilling in Ankerite Invert at 91 deg to 10,000 ft 1 6,010 ft TVD at 10,000 ft, drop angle and land at 6045 ft TVD at 10,400 ft Tested all emergency alarms on rig. 09:05 - 10:45 1.67 DRILL P PROD1 Wiper trip to below WS 10:45 - 17:05 6.33 DRILL P PROD1 Drilling in ankerited A4 TF @ 60L-90R-30L. ROP 0-5 fph. WOB 14k (-6.7k string wt) Op = 2.54 1 2.56 bpm; Pp = 3975/ 4190 psi BHP / WHP = 4,224 1 600 psi; ECD = 13.5 ppg Density = 9.95 /9.99 ppg Vp = 313/312bbl @ 12:00 hrs Drilling in Ankerite. Broke through at 9,682 ft 17:05 - 17:45 0.67 DRILL P PROD1 Drilling in A4 TF @ 30L. ROP 45-70 fph Op = 2.54/2.56 bpm; Pp = 3975 1 4000 psi BHP 1 WHP = 4,251/600 psi; ECD = 13.6 ppg Density = 9.96/9.9 ppg Vp = 303/310bbl @ 06:15 hrs Printed: 6/22/2005 2: 10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/29/2005 17:45 - 20:45 3.00 DRILL P PROD1 Drill ahead form 9718'. 3930 psi fs @ 2.4 in/2.4 out. 100-250 dpsi. DHWOB: 2k - 4k#. ROP: 30-50 fph. WHP/BHP/ECD: 620/4252/13.6 ppg. IAlOAlPVT: 590/566/301 bbls. INC/AZ/TF: 92.7/292.2/80L. Alternating fast drilling with hard (ankerite) streaks. 20:45 - 22:30 1.75 DRILL P PROD1 Wiper trip to window. Hole very smooth in and out. 22:30 - 00:00 1.50 DRILL P PROD1 Drill ahead from 9803'. 3950 psi fs @ 2.5 in/2.5 out. 100-250 dpsi. DHWOB: 2k - 4k#. ROP: 30-60 fph. WHP/BHP/ECD: 580/4200/13.5 ppg. IAlOAlPVT: 610/597/297 bbls. INC/AZ/TF: 94.1/286/95L. Note GR change at 9840'. Appear to nearing base of A5. Turn TF down to begin slow drop towards TO. 5/30/2005 00:00 - 02:45 2.75 DRILL P PROD1 Drill ahead from 9868'. 3950 psi fs @ 2.5 in/2.5 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 30-50 fph. WHP/BHP/ECD: 550/4260/13.6 ppg. IAlOAlPVT: 620/5981296 bbls. INC/AZ/TF: 90.5/281.6/130L. Appear to be in lower A5. Continue to drill ahead at 85-86 deg incl. GR begining to drop. 02:45 - 05:30 2.75 DRILL P PROD1 Wiper trip to 7900'. Log gr tie in at 8060'. Add 6 ft correction. Continue to RIH. Hole very smooth in and out. 05:30 - 08:30 3.00 DRILL P PROD1 Drill ahead from 9990 ft to 10119 ft Drilling in A4 TF @ 165R. ROP 20-50 fph. Qp = 2.54/2.56 bpm; Pp = 3975 1 4000 psi IA 1 OA I SSSV= 620/615/4248 psi BHP / WHP = 4,226/502 psi; ECD = 13.5 ppg Density = 10.0/10.05 ppg. Vp = 290/295 bbl @ 06:15 hrs 08:30 - 11 :20 2.83 DRILL P PROD1 Drill ahead from 10,119 ft. WOB = 5.5K Drilling in A4 TF @ 165-180 R. ROP 5-10 fph Ankerite Qp = 2.54 1 2.56 bpm; Pp = 3975/ 4,000 psi IA I OA / SSSV= 624/610/4,288 psi BHP 1 WHP = 4,226/502 psi; ECD = 13.5 ppg Density = 10.0/10.05 ppg. Vp = 284 1 289 bbl @ 09:15 hrs Drilled into Ankerite at 6,023 TVD as yesterday 11 :20 - 13:40 2.33 DRILL P PROD1 Wiper trip to repair MP #1 and wipe hole after drilling 146 ft. Fixed MP1 and switched from MP#2 and test drive 13:40 - 18:00 4.33 DRILL P PROD1 Drill ahead from 10,136 ft. in Ankerite Drilled 10,141 ft to 10159 ft at 50 ftp then back to 2 fph. Drilling in A4 TF @ 150-165 R. ROP 5-10 fph Ankerite Qp = 2.44 / 2.48 bpm; Pp = 3990 / 4,250 psi BHP / WHP = 4,235 1 520 psi; ECD = 13.6 ppg Density = 9.93/9.94 ppg. Vp = 272/280 bbl @ 14:00 hrs Started mud swap at 15:00 hrs at 10,137 ft Finished at 17:30 hrs 10,160 ft 18:00 - 22:30 4.50 DRILL P PROD1 Drill ahead from 10,167'. 3950 psi fs @ 2.4 in/2.4 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 2-10 fph. WHP/BHP/ECD: 650/4212/13.5 ppg. IAlOAlPVT: 0/56/349 bbls. INC/AZ/TF: 85,5/279/120L. Continue to drill hard A4 (ankerite!) ROP approaching zero. Decide to POH to check BHA and bit. 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to window. Circ out of hole to check BHA and bit. Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/31/2005 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to POOH. Shut in well at 2000'. Hold 1100 psi on well. Close TRSSV. POOH to surface. WHP 7 psi and steady. RIH to 500' to circ cuttings out. Hold PJSM with crew to discuss BHA handling procedure. 01 :30 - 02:00 0.50 DRILL P PROD1 At surface. Get off well. Note minor flat spot on coil above connector. Check with ultrsonic tester. +/- 12% wall loss. Break off motor and bit. Bit 5-6-1. 02:00 - 02:30 0.50 BOPSU P PROD1 Weekly function test of BOPs. Inspect injector sling and shackles. 02:30 - 03:00 0.50 DRILL P PROD1 MU replacement 08. mtr and HCC bi-center bit. Stab coil. Test MWD. 03:00 - 04:45 1.75 DRILL P PROD1 Run in hole with BHA # 9. Stop at 2000'. Pressure up well to 1100 psi. Open TRSSSV. Continue to run in hole following pressure schedule. 04:45 - 05:00 0.25 DRILL P PROD1 Log gr tie in at 8060'. No correction. 05:00 - 06:10 1.17 DRILL P PROD1 Circulate while running in hole. 06:10 - 09:30 3.33 DRILL P PROD1 Tagged bottom at 10,178 ft, Sticky on bottom cleaned up Drill ahead from 10,178 ft Broke through Ankerite at 10,184 ft TF @ 100L - 165R. ROP 50-70 fph. Qp = 2.45 1 2.46 bpm; Pp = 3,975 1 4,090 psi BHP 1 WHP = 4,217/615 psi; ECD = 13.5 ppg Density = 9.91 /9.92 ppg. Vp = 342 / 347 bbl @ 07:30 hrs 09:30 - 11 :50 2.33 DRILL P PROD1 Wiper trip at 10,330 ft, Clean trip. 1 small bopple at 10151 ft. 11 :50 - 15:00 3.17 DRILL P PROD1 Tagged bottom at 10,330 ft Drill ahead from 10,330 fit TF @ 100L - 165R. ROP 50-70 fph. Qp = 2.45 1 2.46 bpm; Pp = 3,975 1 4,090 psi BHP 1 WHP = 4,243 1 630 psi; ECD = 13.5 ppg Density = 9.91/ 9.92 ppg. Vp = 337 / 344 bbl @ 11 :30 hrs 15:00 - 16:30 1.50 DRILL P PROD1 Drill ahead from 10,460'. 3950 psi fs @ 2.4 in/2.4 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 40-60 fph. WHP/BHP/ECD: 630/4280/13.65 ppg. INONPVT: 408/403/344 bbls. I NC/AZfTF: 89.5/279.8/120L. TO "A" lateral at 10530'. 16:30 - 18:30 2.00 DRILL P PROD1 Wiper trip to 7900'. 18:30 - 18:45 0.25 DRILL P PROD1 Log gr tie in at 8060'. Carr +5' 18:45 - 20:00 1.25 DRILL P PROD1 Wiper back to TO was clean. Tagged at 10533' (official TO) 20:00 - 21:15 1.25 DRILL P PROD1 Wiper back to window 2.5/3760/550 maintaining 4200 psi bhp leaving fresh mud in hole 21:15 - 23:00 1.75 DRILL P PROD1 Pull thru window, clean. Circ thru bit while POOH following pressure schedule 2.6/4000. Close TRSSSV after trapping 1100 psi below 23:00 - 00:00 1.00 DRILL P PROD1 Set injector on legs. LD drilling BHA 6/1/2005 00:00 - 01:1 0 1.17 CASE P LNR1 RU to run liner 01:10 - 01:25 0,25 CASE P LNR1 Safety mtg re: liner 01 :25 - 04:25 3.00 CASE P LNR1 MU Unique indexing shoe, one jt 2-7/8" STL solid liner, O-ring sub, 66 jts 2-7/8" 6.16# L-80 STL slotted liner and 6 jts 2-7/8" STL solid liner. MU BTT 4" GS CTLRT 04:25 - 05:25 1.00 CASE P LNR1 MU BHI MWD assy 05:25 - 07:45 2.33 CASE P LNR1 RIH w/liner on CT. Correct to EOP flag at 5500'. Subtract 6' Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/1/2005 05:25 - 07:45 2.33 CASE P LNR1 correction. Up wt at window: 32k#. On wt: 9k#. Through window ok. RIH open hole. Set down a few times near TO. Able to PU and work ahead. Definitely running out of push. Stop at 10473'. Inc pump rate to 1.3 bpm. Release from liner. 07:45 - 08:15 0.50 CASE P LNR1 POOH. Log gr tie in from 8060'. Add l' correction. Liner TOP at 8242' Liner btm at 10474'. 08:15 - 10:00 1.75 CASE P LNR1 Open EDC. Circulate out of hole maintaining whp pressure as per schedule. Close TRSSV w/11 00 psi on well. Pull to surface. 10:00 - 10:30 0.50 CASE P LNR1 LD MWD tools. 10:30 - 14:00 3.50 STWHIP P WEXIT RU to reveres circulate reel to manage e-line slack. Circ at 3700 psi @ 3.18 bpm. Cut 72' coil and 10' e-line. MU Kendal connector and Inteq connector. Circulate forward 90 bbls. 14:00 - 14:45 0.75 STWHIP P WEXIT PU packer and setting tool assembly. Place in mouse hole to inspect same. Weatherford hand attempted to adjust setting sleeve above packer. Packer fell off setting tool into mouse hole. 14:45 - 16:00 1.25 STWHIP N SFAL WEXIT Order replacement packer and fishing tools from Deadhorse. 16:00 - 17:15 1.25 STWHIP P WEXIT MU replacement KS-WS packer assembly. Scribe to Inteq orienter. Mule shoe lug set to orienter highside. Stab coil. Get on well. Test Inteq mwd tools. 17:15-19:20 2.08 STWHIP P WEXIT Run in hole to TRSSSV. Pressure well to 1100 psi. Open valve. RIH at 70'/min circ thru EDC 1.0/2300 following pressure schedule 19:20 - 19:40 0.33 STWHIP P WEXIT Log GR tie-in down from 8075' 1.0/2170/780 Add + l' 19:40 - 20:05 0.42 STWHIP P WEXIT Log CCL tie-in down from 8150 to 8235' 1.0/2180/750 wlo tag (TOL is @ 8242'). Check tie-in with collars on PDS GR/CCL of 5/15/05 and are within 2' when tied back to geo PDC 20:05 - 20:20 0.25 STWHIP P WEXIT PUH to 8200' (end of BHA) 25.4k. SO pump, close EDC holding 1100 psi WHP. Orientation is 8R. Pressure up dn CT at 18.5k to 3950 psi and lost 7.5k string wt. Pump thru at 0.5 bpm. Orientation is now 10R. SO pump w/1 050 psi bp. Stack 7k to 8203.5'. PUH 26.3k and left packer with top at +/- 8159' ELMO and end of guide shoe at +/- 8202'. Open EDC PVT 113 (10.0 ppg mud) 20:20 - 21 :50 1.50 STWHIP P WEXIT POOH w/ packer setting assy 1.1/2200 following pressure schedule. Close TRSSSV 21 :50 - 23:00 1.17 STWHIP P WEXIT LD WIS setting tool, standback MWD assy. MU WIS WS/seal assy and jars. Add MWD assy 23:00 - 00:00 1.00 STWHIP P WEXIT RIH wI BHA #12 @ 70'/min 6/2/2005 00:00 - 01 :15 1.25 STWHIP P WEXIT Continue RIH w/ WS assy circ thru EDC 0.2/1700 following pressure schedule 01 :15 - 01 :35 0.33 STWHIP P WEXIT 8100' 28.4k 0.2/1680/800 RIH w/9.7k to wt loss at 8162' CTD. Stack 9k in 3 stages to 8164.3'. PUH 40.5k and sheared off. PUH 10' and park. Bleed off WHP and no flow for 5 min. PVT 110 Preliminary WS depths are TOWS 8150', RA 8152', BOWS 8159' Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/2/2005 01 :35 - 02:50 1.25 STWHIP P WEXIT 02:50 - 03:30 0.67 STWHIP N DFAL WEXIT 03:30 - 05:20 1.83 STWHIP N DFAL WEXIT 05:20 - 06:15 06:15 - 08:45 0.92 STWHIP N 2.50 STWHIP N DFAL WEXIT DFAL WEXIT 08:45 - 09:00 0.25 STWHIP N DFAL WEXIT 09:00 - 10:00 10:00 - 12:00 1.00 STWHIP N 2.00 STWHIP N DFAL WEXIT DFAL WEXIT 12:00 - 12:30 0.50 STWHIP N DFAL WEXIT 12:30 - 14:30 2.00 STWHIP N DFAL WEXIT 14:30 - 14:45 0.25 STWHIP N DFAL WEXIT 14:45 - 16:30 1.75 STWHIP N DFAL WEXIT 16:30 - 16:45 0.25 STWHIP N DFAL WEXIT 16:45 - 18:00 1.25 STWHIP N DFAL WEXIT 18:00 - 19:00 1.00 STWHIP N DFAL WEXIT 19:00 - 21: 15 2.25 STWHIP N DFAL WEXIT 21:15-22:30 1.25 STWHIP N DFAL WEXIT 22:30 - 23:30 1.00 STWHIP N DFAL WEXIT POOH w/ WS setting tool circ'ing thru open choke 1.0/1400. Close TRSSSV Oust because. ..) PVT 68 Found WS was still attached to setting tool! Wear marks on top of latch collet indicated it had entered packer bore and had at least partially latched. Also, a few minor scars in seal area verified the same-seals were okay. The bottom of the lug was slightly bent outward. But, why the well didn't flow is a real mystery . . . Wait on replacement of complete latch assy from WIS Deadhorse shop Remove orientor and GR from MWD assy Remove existing latch assy and replace with new one Stab coil. Test MWD. Get on well. Run in hole. Open TRSSSV Continue to RIH holding 200 psi whp. 29.4k# up, 11 k# dn wt at 8100'. Tag packer at 8162.2' RIH additional 2'-3' and set dn 5k#. On jars fired. PU to neutral. Set dn 5k#. No jar indication. PU to neutral again. Set dn 5k# over. Jars fired again. PU. SHeared in up direction at 45k# (+/- 15k# over free up wt.) RIH. Set down at 8159' or +/- 3' above initial tag depth of 8162'. This looks good. POOH holding 200 psi whp. At surface. Get off well. WS still attached to running tool. Alignment lug showed signs of deformation on btm of "V", as though it is too far down whipstock mandrel body. Send seal assembly to Deadhorse to shorten lug. Injection test into well at 0.22 bpm @ 1600 psi MU 2" x 4' stinger and 2.5" 00 nozzle as per town. Stab coil and get on well. RIH to clean out seal bore on packer while waiting on ws latch. Tag packer at 8166'. Make three passes. Coil pressured up each time nozzle sat down inside packer. Circulate out of hole. Hold 200 psi WHP. Close TRSSSV with 200 psi on well. Continue out of hole. At surface. Get off well. Unstab coil. LD nozzle assembly. Change packoffs on injector while waiit on whipstock from Deahorse. Also, add GR to MWD assy MU WIS WS assy with shorter lug and corresponding shorter mandrel 00. Add jars and MWD assy PVT 82 RIH w/ BHA #15 at 70'/min 0.4/1150 thru open EDC holding 200 psi bp. Open TRSSSV and saw no pressure change PVT 121 8050' close EDC, pump thru tool 0.5/1300/200. Wt chk 29.2k wI 200 psi bp. Begin GR log down from 8030' to packer 11.1 k dn. Corr was less than -0.5' and did not correct Start losing wt at 8159.5' Stack 6k to 8161.2' and no jar action. PUH slowly w/ same 0.5/1300/200 to 31.3k. RIH and set 7k down to 8162.2' wI no jar action. PUH slow to 33k at 8158.3'. Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/23/2005 6/10/2005 2 Spud Date: 5/23/2005 End: 6/11/2005 6/2/2005 22:30 - 23:30 1.00 STWHIP N DFAL WEXIT RIH slow and stack 7k and got a jar lick. Repeat last sequence 4 more times, but only got to 30k. PUH to 8148' wI no overpull. RIH and start losing wt at 8160.3' and stack 8k to 8162.6'. Repeat to 8148' and stack 12k to 8163.6'. PUH w/ no overpull. Doesn't act like it latched-may have left it in hole tho after the first jar lick. .. PVT 120 23:30 - 00:00 0.50 STWHIP N DFAL WEXIT POOH 1.0/1750/200 to check assy 6/3/2005 00:00 - 01:1 0 1.17 STWHIP N DPRB WEXIT Finish POOH w/ WS setting tools 1.0/1600/200. Close TRSSSV PVT 80 01:10- 02:00 0.83 STWHIP N DPRB WEXIT Standback BHA and WS was still attached to setting tool. Bottom of tool had flat spot/scar indicating tool probably never IWEXIT entered packer. LD BHA while discuss 02:00 - 04:00 2.00 STWHIP N DPRB Wait for new packer/anchor assy from WIS Deadhorse. Will need to machine off bottom STL pin to give extra room when setting (so that next WS exit will be just below 4-1/2" collar at 8143' ELMO). Power outage in Deadhorse Reconfigure BHI tool string for running packer Replace reel swivel and PT @ 5k 04:00 - 06:15 2.25 STWHIP N DPRB WEXIT Wait on packer 06:15 - 07:00 0.75 STWHIP N DPRB WEXIT MU replacement/modified 4-1/2 KS-WS packer assembly on Inteq mwd. Stab coil. Get on well. Test mwd. 07:00 - 09:15 2.25 STWHIP N DPRB WEXIT RIH. Hold 200 whp. Open TRSSSV. Continue to RIH. 09:15 - 10:00 0.75 STWHIP N DPRB WEXIT Log gr tie in from 8060' to top of packer at 8159'. No initial correction. Packer top tagged at 8159'. 10:00 - 10:45 0.75 STWHIP N DFAL WEXIT PU l' above packer at 8159'. Orient packer alignment slot to 1 OR. Attempt to close EDC. No repsonse from EDC. Trouble shoot, but no progress. 10:45 - 13:00 2.25 STWHIP N DFAL WEXIT Pull out of hole. 13:00 - 14:00 1.00 STWHIP N DFAL WEXIT At surface. Get off well. LDpacker assy. Change out EDC module. MU packer assy. Stab coil. Get on well. Test MWD. 14:00 - 16:45 2.75 STWHIP N DFAL WEXIT Run in hole at 70 fpm with packer. 16:45 - 17:00 0.25 STWHIP N DFAL WEXIT Tag lower packer at 8159'. PU to neutral weight plus 1 foot. Orient alignment slot to 190 deg. Close EDC. Pressure coil slowly to 4350 psi. Setting tool activated and sheared off packer. Circ 1700 psi @ 0.5 bpm to ensure setting tool has fully stroked. 17:00 - 19:00 2.00 STWHIP N DFAL WEXIT POOH with setting tool. Close TRSSSV. PVT 77 19:00 - 20:10 1.17 STWHIP N DFAL WEXIT Standback MWD assy. LD packer setting assy. MU WS assy w/ normal latch assy and orient lug to 190 deg to WS. Add MWD assy 20:10 - 22:25 2.25 STWHIP N DFAL WEXIT RI H w/ BHA #18 0.36/1180/200 Open TRSSSV PVT 116 22:25 - 22:40 0.25 STWHIP N DFAL WEXIT Log tie-in down from 8050' 0.36/1180/200 Corr -1'. Up wt chk @ 8076' 29.0k 22:40 - 23:05 0.42 STWHIP N DFAL WEXIT RIH from 8140' @ 5'/min 11 k 0.36/1180/200 and had first wt loss at 8153.0' and stack 2k to 8153.5'. PUH slow to 8152.3' @ 29k. RIH and stack 4k to 8153.6', no jar lick. Stack 5.6k to 8154.0'. PUH to 29k. Stack 6.2k to 8154.5', 8.9k to 8154.9'. PUH to 29k and hold at 25k 8151.4. PUH to 31 k and never got above 30k. PUH to 8149' 23:05 - 23:25 0.33 STWHIP N DFAL WEXIT Start over. RIH and stack 9.6k to 8154.3' and jars went off and Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 5/23/2005 6/10/2005 2 Spud Date: 5/23/2005 End: 6/11/2005 6/312005 23:05 - 23:25 0.33 STWHIP N DFAL WEXIT gained 5k string wt. Stack back the 5k, then 1 k more to 10k wob at 8155.8' and lug went in with quick string wt gain then loss back to prior wt. PUH to 29k, solid. PUH to 31 k, solid. PUH to 33k, solid. 35k 8150.6' and -3k wob. 37k -4k wob. 39k -5k wob. 41k -6.2k, 43k -7.7k and lost wt back to neutral at 15k and 0 wob. PUH 29k Looks like a good set PVT 115 Preliminary depths of WS are TOWS 8142, RA 8144, BOWS 8151' 23:25 - 00:00 0.58 STWHIP N DFAL WEXIT POH 1.0/1500/200 6/4/2005 00:00 - 01 :00 1.00 STWHIP N DFAL WEXIT Fin POOH wI WS setting tool 1.0/1500/200. Close TRSSSV PVT 76 01 :00 - 01 :30 0.50 STWHIP N DFAL WEXIT LD MWD assy. LD setting tool wlo WS attached 01 :30 - 02:20 0.83 STWHIP N DFAL WEXIT Reconfigue MWD tools for milling ops and test. MU HCC 3.80" window mill and 3.80" SR on WIS straight motor. Add MWD assy 02:20 - 04:15 1.92 STWHIP N DFAL WEXIT RIH wI BHA #19 circ thru mill 0.3/1250/200 PVT 114 04:15 - 04:25 0.17 STWHIP N DFAL WEXIT Park at 8100' and SI @ choke. Perform pressure test to 2000 psi. Injected at 0.48 bpm @ 1850 psi for 5 min. Red rate to 0.24 bpm and stabilized @ 1650 psi (which is similar to prior test when ensuring tailpipe was clear) No change to IA and OA, both =0 04:25 - 05:15 0.83 STWHIP N DFAL WEXIT Will try to push into place. Open EDC. Chk up wt 32k wI no pump. RIH 11.2k wI 0.25/940/0 looking for WS and tag at 8142' CTD and set 6k wob. Stack additional wt in stages to a total of 8.3k wob at 8144.8'. Repressure wellbore to 2000 psi and injected 0.46 bpm @ 1550 psi. Red rate to 0.3/2100/1300 PUH 24.7k 20'. Take a run at 25'/min and stack 8.3k wob and no pressure increase. PUH 25k 20'. Take a run in 15'/min increments up to 1 OO'lmin and stack max surface CT wt, but still only showing 8.3k wob wI no WHP incr 05:15 - 05:40 0.42 STWHIP N DFAL WEXIT Will try to turn and push into place. Bleed off WHP. Close EDC. Start pump at milling rate wI open choke 2.5/3600/60 Ease in hole to tag WS at 8.4k at 1 'Imin and first MW at 8142.6' and drilled off. Stack 5k quickly. SO pump, PUH 20' and park. Close choke and pressure test to 2040 psi. Looks like we gained a little. SO pump and bled to 1100 psi in 10 min PVT 102 05:40 - 06:00 0.33 STWHIP N DFAL WEXIT Bleed off WHP and circ 0.6/1250 wI open choke while do crew change 06:00 - 07:00 1.00 STWHIP N DFAL WEXIT Spud on whipstock with milling assy a few more times. Run into same at 120 fpm. Pressure well to 1800 psi. Well bleeding off to 1000 psi in 15 minutes. No improvement over previous spudlpressure cycle. Discuss situation with town. Decide to pull whipstock tray due to concerns about orientation and how securely ws tray is latched. 07:00 - 09:00 2.00 STWHIP N DFAL WEXIT POOH with milling assy. Call for fishing tools from Deadhorse. 09:00 - 10:30 1.50 STWHIP N DFAL WEXIT Wait on fishing tools. 10:30 - 11 :45 1.25 STWHIP N DFAL WEXIT MU whips stock retrieval BHA #20 (box tap, mtr, jars, Inteq mwd) 11:45-13:15 1.50 STWHIP N DFAL WEXIT Stab coil. Get on well. Run in hole. 13:15 - 13:30 0.25 STWHIP N DFAL WEXIT 31k# up, 11k# dn wt. Circ 1500 psi @ 0.7 bpm. Tag fish at 8144'. Inc rat to 2. 0 bpm, set dn 10k#. Jars went Printed: 6/22/2005 2:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/412005 13:15 - 13:30 0.25 STWHIP N DFAL WEXIT off down. Set dn 12k# and pump press up to 3000 psi. Pump at 0.7 bpm, 1900 psi. Mtr is stalled. PU 40k#. Jars fired. Set dn to 6k# to re set jars. PU to 44k#. Jars fired. PU to 48k# Set dn to 5k# to re-set jars. PU to 48k#. Jars fire. PU to 52k#. Set down to 5k#. PU to 50k#. Jars fired. PU to 55k#. Set down to 5k#. Re-set jars. PU to 52k#. Jars fired. PU to 55k#. Fish (or something else) came free. Open EDC. 13:30 - 15:15 1.75 STWHIP N DFAL WEXIT Pull out of hole. Hold 200 psi whp. Close TRSSSV. Continue to POH. Parted CT drill 16:00 - 17:00 1.00 STWHIP N DFAL WEXIT MU replacement WS and latch assembly on BHA. Include orienter with lug scribed to HS TF. Stab coil. Test mwd. Get on well. 17:00-19:10 2.17 STWHIP N DFAL WEXIT Run in hole @ 70'/min 1.0/1600/200 thru EDC. Open TRSSSV 19:10 - 19:35 0.42 STWHIP N DFAL WEXIT 8100' Close EDC. Circ 0.3/1170/200 Wt chk 29k. Orient TF to 190R. RIH at 1 O'lmin from 8140' 11.5k and first wt loss at 8154.1'. Continue RIH 10'/min and stop wI -8k surface, -9.4k wob at 8159.5'. Jars went off. Pressure wellbore to 2140 psi and hold for 4 min wlo loss. IA and OA gained 1 psi each. Bleed WHP to zero PVT 99 19:35 - 20:00 0.42 STWHIP N DFAL WEXIT Circ thru tool 0.5/1100/10 PUH to 2k over and hold to open jars. Work string wt up in stages to 39k. RBIH and stack 10k to close jars. PUH to 40k until jars hit and released from WS. PUH 50'. SI choke and pressure wellbore to 2150 psi and hold for 2 min wI no loss-good to go, 2.7 days later. . . Preliminary WS depths are TOWS 8142' BOWS 8151' wI no RA tag. Will use prior tie-in points above window at 8020' 20:00 - 21 :50 1.83 STWHIP N DFAL WEXIT POOH circ thru tool 1.0/1400/20. Close TRSSSV PVT 58 21 :50 - 22:30 0.67 STWHIP N DFAL WEXIT LD WS setting tool and MWD tools 22:30 - 00:00 1.50 STWHIP P WEXIT SI swab. Stab onto lub. Reverse slack back (two attempts and no slack pumped) 3.9/4500 Need more rate Fire drill 6/5/2005 00:00 - 04:45 4.75 STWHIP P WEXIT Fill pit #4 and CT wI water, then reverse slack back wI water 5.0/4500. Cut off 63' of CT before finding wire. Install CTC, PT 40k. Meg test 59 ohms. PT 3500 psi. Displace water in CT wI 10# used mud 2.0/1700. Meanwhile, MU milling BHA 04:45 - 06:45 2.00 STWHIP P WEXIT RIH wI BHA #22 (3.80" window miIl/SR). Open TRSSSV 06:45 - 08:30 1.75 STWHIP P WEXIT Tag ws at 8144' with pumps off. PU. 3800 psi fs @ 2.7 bpm inlout. Tag WS at 8143'. Begin time milling at 0.1 ft per 5 or 6 min, or as limited by DHWOB (> 5k#). IAlOAlPVT: 20/24/94 bbls. WHP/BHP/ECD: 8114115/11.5 ppg. 08:30 - 10:00 1.50 STWHIP P WEXIT Time mill from 8146'. 200-300 dpsi. DHWOB: 4k-5k#. Increase DPSI to 500-600 psi. DHWOB:6k-7k# and make a foot. Reduce DPSI to 200-300 psi. DHWOB: 5k# or less. 10:00 - 13:00 3.00 STWHIP P WEXIT Time I WOB mill from 8146'. 150-300 dpsi. DHWOB: 2k-3k#. Lots of metal on magnets, 13:00 - 15:00 2.00 STWHIP P WEXIT Begin swap to 9.2 ppg. Continue to mill. 150-250 dpsi. DHWOB: 2k-3k#. Printed: 6/22/2005 2:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/512005 15:00 - 15:45 0.75 STWHIP P WEXIT Appear to be in formation. Drill to 8160'. Catch btms up sample. A lot of sand noted. Uncorrected window depth: Top: 8145' Btm: 8151' 15:45 - 18:00 2.25 STWHIP P WEXIT Back ream window. Make three up and down passes. Dry drift down. Swap from used 10.0# mud to fresh 9.2# Flopro. PUH to 8000' EOP and flag 18:00 - 18:30 0.50 STWHIP P WEXIT SO pump, SI well for crew change. After 25 min WHP=O, DHP 2882 psi (ECD 9.65). Open choke and no flow PVT 149 18:30 - 20:15 1.75 STWHIP P WEXIT POOH circ thru mill wI open choke 1.0/1425/25. Close TRSSSV. PVT 105 20:15 - 20:45 0.50 STWHIP P WEXIT LD milling assy. Mill and SR gauged 3.80" go, 3.79" no go. Mill had center wear 20:45 - 21 :50 1.08 DRILL P PROD2 Reconfigure MWD assy for drilling and test. MU build assy for 45 DLS 21 :50 - 00:00 2.17 DRILL P PROD2 RIH wI BHA #23 (3.2 deg motor, HCC bibit) 6/6/2005 00:00 - 00:15 0.25 DRILL P PROD2 Log tie-in down from 8020' 0.3/1000/0. Corr -1.5' 00:15 - 00:25 0.17 DRILL P PROD2 RIH wI 0.3/1100/0 and clean thru window at 10R. Tag TO at 8159'. PUH 30k Start motor 2.6/3300/60 RIH 16k PVT 337 00:25 - 01 :00 0.58 DRILL P PROD2 Drill from 8158' 2.6/2.6/3320/15R wI open choke and 60 psi induced. DHP 3270 psi wI 10.8 ECD. Work for a bit to get believable TF. Losing some mud over shaker due to high LSRV PVT 333 01 :00 - 02:00 1.00 DRILL P PROD2 Drill from 8175' 2.613280/1 OR at avg 50'/hr contol drilling PVT 325 02:00 - 02:20 0.33 DRILL P PROD2 Drill from 8220' 2.64/3300/15R w/ 1 k wob, 200 psi diff at DHP 3315/ECD 10.9 Penetration rate incr 100-120'/hr in 'B' shale. Drill to 8262' and differentially sticky PVT 322 02:20 - 02:30 0.17 DRILL P PROD2 Wiper to window, clean both ways 02:30 - 03:45 1.25 DRILL P PROD2 Drill from 8262' 2.6/3300/90R w/1.7k wob, 300 psi diff at DHP 3335/ECD 10.9 at 80'/hr and guessing 90 deg at bit. Drill from 8320' 15R to 90R in prep for lateral assy. Drill to 8350' EOB PVT 318 03:45 - 04:00 0.25 DRILL P PROD2 Wiper to window 2.6/3150, clean 04:00 - 06:15 2.25 DRILL P PROD2 Park at 8100' and open EDC after trapping 500 psi WHP. POOH 2.66/2940 following pressure schedule. Close TRSSSV. Finish POOH to surface. 06:15 - 07:00 0.75 DRILL P PROD2 At surface. Get off well. Unstab coil. LD BHA. Bit has one broken cutter on gauge blade and one broken cutter near center of nose. One jet was plugged between gauge cutter blades. 07:00 - 11 :00 4.00 BOPSU P PROD2 Perform weekly BOP equipment test. Witness waived by AOGCC rep J. Jones. 11 :00 - 12:00 1.00 DRILL P PROD2 MU BHA #23 (HYC bi w. 0.8 mtr & resistivity tool). Stab coil. Tets mwd tools. Get well. 12:00 - 13:15 1.25 DRILL P PROD2 Run in hole. Put 500 psi on well. Open TRSSSV. Continue to run in hole. Maintain BHP as per schedule. 13:15 - 14:15 1.00 DRILL P PROD2 Log gr tie in from 8040'. Add 7' correction. MADD pass for resistivity from window to 8350'. 14:15 - 17:30 3.25 DRILL P PROD2 Drill ahead from 8350'. 3300 psi @ 2.7 in/out DPSI: 250-350. DHWOB: 2k-3k#. ROP: 40-80 fph. WHP/BHP/ECD: 73/3301/10.85 ppg. IAlOAlPVT: 45/16/326 bbls. I NC/AZMITF: Printed: 612212005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/612005 14:15 - 17:30 3.25 DRILL P PROD2 99.2/237/100R. 17:30 - 18:00 0.50 DRILL P PROD2 Wiper to window, clean both ways PVT 308 18:00 - 20:15 2.25 DRILL P PROD2 Drill ahead from 8500' 2.7/3280175R w/2-3k wob, 150-300 psi diff w/ DHP 3360/ECD 11.0 at 90 deg in 75 api rock at 70'/hr. Lots of stalls (harder rock) and slower penetration rate after 8550'. Also, attempting to push due to directional concerns, but not getting required turn. Drill to 8637' PVT 297 20:15 - 20:35 0.33 DRILL P PROD2 Wiper to window, clean. Open EDC at 8100' trapping 3400 psi DHP wI 500 psi surface press 20:35 - 22:00 1.42 DRILL P PROD2 POOH for motor bend 2.66/3160 following pressure schedule. Close TRSSSV PVT 251 22:00 - 22:45 0.75 DRILL P PROD2 Change motor bend from 0.8 to 1.8 deg. Chk bit 0-1-1 (one small chip) 22:45 - 00:00 1.25 DRILL P PROD2 RIH wI BHA #24 following pressure schedule circ thru bit 0.6/1400. Open TRSSSV 6/7/2005 00:00 - 00:15 0.25 DRILL P PROD2 Log tie-in down from 8050'. Corr -1' 00:15 - 00:30 0.25 DRILL P PROD2 Wiper to TO wI one set down at 8250' 2.0/2500. Tagged TO at 8640' PVT 290 00:30 - 01:1 0 0.67 DRILL P PROD2 Drill from 8640' 2.74/3400/75R w/2"3k wOb, 300 psi diff wI DHP 3335, ECD 10.96. Got bottoms up gas back (from UB condition pulling thru window on trip earlier) which set off alarms. Drill to 8685' and stall PVT 287 01:1 0 - 02:30 1.33 DRILL P PROD2 Drill from 8685' 2.65/3300/45R w/2k wob, 0-300 psi diff, DHP 3340, ECD 11.02. Drill wI several stalls and may be mapped fault #1. Broke thru at 8695' and back into steady digging sand which cut DLS back to less than 10. Drill to 8800' PVT 278 02:30 - 03:10 0.67 DRILL P PROD2 Wiper to window, clean both ways PVT 270 (changed both shaker screens to 175) 03:10 - 05:15 2.08 DRILL P PROD2 Drill from 8800' 2.68/3325/35R wI 2-3k wob, 300 psi diff, DHP 3347, ECD 11.07 at 90'/hr. Drill to 8950' PVT 266 05:15 - 06:00 0.75 DRILL P PROD2 Wiper to window, clean both ways 06:00 - 10:00 4.00 DRILL P PROD2 Drill ahead from 8950'. 3100 psi fs @ 2.7 in/out. 300-400 dpsi. DHWOB: 0.5k-1.0k#. ROP: 40-80 fph. WHP/BHP/ECD: 7313350/11.0 ppg. IAlOAlPVT: 256/227/264 bbls. INC/AZMITF: 93.9/282175r. Apear to have build established at 93 deg inc. 10:00 -11:00 1.00 DRILL P PROD2 Wiper trip to below window. Hole smooth in and out. 11:00-13:15 2.25 DRILL P PROD2 Drill ahead from 9100'. 3200 psi fs @ 2.4 inlout. 300-400 dpsi. DHWOB: 2.0-3.0k#. ROP: 40-80 fph. WHP/BHP/ECD: 6513375/11.2 ppg. IAlOAlPVT: 350/326/254 bbls. INC/AZMITF: 88.7/307/100L. 13:15 - 14:45 1.50 DRILL P PROD2 Wiper trip. Hole smooth in and out. Micro motion out plugged off several times. Found several large chunks of rubber material in micro out. PVT 252 14:45 - 18:50 4.08 DRILL P PROD2 Drill ahead from 9250' 2.5/3300/115L w/1-4k wob, 150-400 psi diff, DHP 3385, ECD 11.18 at 40'/hr at 91 deg and starting slow drop 18:50 - 20:00 1.17 DRILL P PROD2 Wiper trip to window. No problems. 20:00 - 23:05 3.08 DRILL P PROD2 Directionally drill ahead f/9400' Q=2.57/3400psi TF=160-180L MW=300-400psi WOB= 2-3k Ann= 3371 psi ECD 11.2ppg. Drilled to 9550'. No significant drop in angle for the last 150'. 23:05 - 00:00 0.92 DRILL P PROD2 Wiper trip to window. Discuss apparent inability to drop hole angle with town geo's. Agreed to drill ahead another 30-40'. If Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/7/2005 23:05 - 00:00 0.92 DRILL P PROD2 unable to drop angle will trip for higher bend motor. 6/8/2005 00:00 - 00:30 0.50 DRILL P PROD2 Finish wiper trip. No problems. 00:30 - 01 :30 1.00 DRILL P PROD2 Directionally drill ahead f/ 9550' Q=2.6/3450psi MW=200-400psi Ann=3390psi ECD=11.23 WOB=2-3k TF=180 ROP=50-60fph Swapping out to new flo-Pro mud system. Drilled to 9592'. Unable to drop angle. 01 :30 - 02:30 1.00 DRILL P PROD2 Wiper trip while preparing to swap hole to new mud system. 02:30 - 05:30 3.00 DRILL P PROD2 TOH following Pressure Schedule. At 700' closed SSSV continue OH. Unalbe to bleed off well. RIH to 200'. Repressure well to 500psi. Cycle SSSV. TOH bleed down well. 05:30 - 07:00 1.50 DRILL P PROD2 Set back injector. PU BHA and inspect motor settings and everything is tight and in spec. Change bit to M09X. Pulled bit was 2-2-1. Also, inspected annular element 07:00 - 08:30 1.50 DRILL P PROD2 RIH wi BHA #26 (1.8 deg motor, 3.75" M09X bit) circ thru EDC 0.47/1480 following pressure schedule. Open TRSSSV PVT 393 08:30 - 08:50 0.33 DRILL· P PROD2 Log tie-in down from 8050', corr +2' 08:50 - 09:30 0.67 DRILL P PROD2 Wiper thru window, clean. RIH to TO 2.5/3140, clean. Tag at 9595' PVT 403 09:30 - 10:45 1.25 DRILL P PROD2 Drill from 9595' 2.57/3150/170L w/2.5k, 100 psi diff, 3309 psi DHP, 10.94 ECD purposely holding back and letting bit cut probable hard formation interface. Within 30' the NB incl is showing a 3 deg drop 10:45 - 12:30 1.75 DRILL P PROD2 Resume drilling at normal penetration rate while bringing TF up to level out and break extreme downward trend. Drill to 9700' and are back on track at 87 deg incl. See GR change at 9635' and corresponding res change 12:30 - 13:15 0.75 DRILL P PROD2 Drill from 9700' 2.55/3150/90-100L w/3-4k wob, 100-300 psi diff, DHP 3333, ECD 11.0 and now in a shale(?). Have trouble making hole and sticky. Drill to 9717' 13:15 - 15:00 1.75 DRILL P PROD2 Wiper to window, clean both ways. Adding Flo Vis to new mud 15:00 - 16:00 1.00 DRILL P PROD2 Drill from 9717' 2.62/3150/100L w/1-3k wob, 100-300 psi diff, DHP 3314, ECD 10.93 and work to get thru shale. Drill to 9727' and faster penetration PVT 408 16:00 - 16:30 0.50 DRILL P PROD2 Ream and backream to 50' above 9727' and bring TF to right side 16:30 - 19:25 2.92 DRILL P PROD2 Drill from 9727' to 9850'. Q= 2.6/3100psi MW 300-400psi 19:25 - 21 :15 1.83 DRILL P PROD2 Wiper out of window. No problems, clean. Set reel brake. Tighten up backing plates on reel drive plates. Pull up to log depth. 21 :15 - 21 :30 0.25 DRILL P PROD2 Log tie-in. +5 correction 21 :30 - 22:30 1.00 DRILL P PROD2 TIH seen slight motor work at 8245' and 8280' 22:30 - 00:00 1.50 DRILL P PROD2 Directionally drill ahead f/9855' to 9936' Q=2.6/3160psi MW= 100-300 psi Ann= 3750psi ECD 11.18ppg WOB= 2-4k ROP= 30'/hr 6/9/2005 00:00 - 01 :25 1.42 DRILL P PROD2 Directionally drilled from 9936' to 10016'. 01 :25 - 03:30 2.08 DRILL P PROD2 Wiper trip to window. Hole in good shape. 03:30 - 06:10 2.67 DRILL P PROD2 Directionally drill f/1 0016' Q=2.631 3200psi MW 200psi Ann=3385 ECD 11.13 WOB 2-3k 20-30'/hr. Hard to make hole and sticky. Drill to 10095' PVT 404 06: 10 - 07:40 1.50 DRILL P PROD2 200' wiper and 10k overpulls at 10016'. Continue wiper and go to window, clean. Pull thru window, clean Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/9/2005 07:40 - 08:00 0.33 DRILL P PROD2 Log tie-in down from 8050'. Corr +3' PVT 388 08:00 - 09:00 1.00 DRILL P PROD2 RIH thru window, clean. Wiper to TO. Wt loss beginning at 10023' until set down at 10088'. Ream w/ neg wt to 10095' 09:00 - 10:25 1.42 DRILL P PROD2 Drill from 10095' 2.6/3180/90L w/ 3k wob, DHP 3334, ECD 10.95 wI -8k surface wt at less than 1 O'/hr to 10103' PVT 400 Geo sees sand in samples, so bit or motor must be shot 10:25 - 11 :30 1.08 DRILL P PROD2 Wiper to window 2.6/2900 w/10k overpull at 10015' 11 :30 - 13:30 2.00 DRILL P PROD2 POOH to check BHA 2.6/2840 following pressure schedule. Close TRSSSV. Check for flow at 300' and had to recycle TRSSSV shut 13:30 - 14:20 0.83 DRILL P PROD2 Change bit and motor. Bit was 3-2-1, motor was okay PVT 143 14:20 - 16:00 1.67 DRILL P PROD2 RIH wI BHA #27 (HCC bi bit, 1.2 deg motor) following pressure schedule. Open TRSSSV 16:00 - 16:15 0.25 DRILL P PROD2 Tie-in down from 8050', corr +2' 16:15 - 17:50 1.58 DRILL P PROD2 RIH thru window, clean. Wiper to 9600' was clean. Precautionary ream at 20'/min to 9935' and had set down and were temporarily immobile. Precautionary ream 5-10'/min to set down and sticky pickup at 10018'. Assume siderite streaks. Ream thru this one after 3 tries. Ream to 10089' and set down and became temporarily bit stuck. Ream down slower. MW at 10098' and sticky pickup. Find TO at 10100' and it is hard 17:50 - 18:05 0.25 DRILL P PROD2 Wiper to 9900' and was clean. Wiper back to TO 18:05 - 21 :45 3.67 DRILL P PROD2 Directionally drill ahead f/ 10100' Q=2.53/3090psi. Ann=3390 ECD=11.15ppg avg 30'/hr wI 2-3k wob making short 50' wiper trips after stacking out. hard/stacking 10132-10137' then took off drilling good intil10170'. Resistivity dropping GR increasing. Back to slow drilling. wob=2.6k Pumped 20bbl 100k sweep. Didn't see excess cuttings across shaker. Drilled to 10210' TO 21 :45 - 22:30 0.75 DRILL P PROD2 Wiper trip to 7900'.. Condition hole for liner. Pump another 20 bbl hi-vis pill. Hole good shape. 22:30 - 22:50 0.33 DRILL P PROD2 Log final tie-in +7' 22:50 - 00:00 1.17 DRILL P PROD2 Wiper trip. Small bobble at 9980' good to revised TO of 10216'. 6/10/2005 00:00 - 00:45 0.75 DRILL P PROD2 Wiper back to 9800' then to TO. Hole good shape. 00:45 - 03:30 2.75 DRILL P PROD2 TOH laying in new Flo-Pro. Flag EOP at 8100'. Once above 2400' closed SSSV trapping 500psi below. Pull to 485' open Baker choke check for flow - dead. TOH 03:30 - 04:15 0.75 DRILL P PROD2 LD BHA #27 04: 15 - 04:30 0.25 CASE P PROD2 PJSM review liner running hazards and procedures. 04:30 - 06:00 1.50 CASE P PROD2 PU 2-7/8" 6.16# STL slotted liner. 06:00 - 06:15 0.25 CASE P PROD2 Crew change safety mtg re: run rest of liner 06:15 - 08:50 2.58 CASE P PROD2 Fin MU slotted liner assy, BHA #28. MU BTT 4" GS LRT PVT 250 08:50 - 10:30 1.67 CASE P PROD2 RIH wI slotted liner on CT following pressure schedule circ thru GS 0.3/1450. Open TRSSSV. PVT 282 10:30 - 11 :00 0.50 CASE P PROD2 8100' 34k114.8k 0.3/1460 RIH thru window, clean. RIH to 10100' wI nary a bobble at 70'/min w/ final RIH wt 4.3k PVT 293 11 :00 - 11 :40 0.67 CASE P PROD2 Park at 10100' CTD. Incr rate to 1.5/4600 psi and release from liner (two tries) leaving top at 8163' CTD. PUH to 8000'. Log tie-in down and had no corr. RIH to tag and inadvertently latched up at 8163'. Release (in two tries) as before after PUH Printed: 6/22/2005 2: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/10/2005 11 :00 - 11 :40 0.67 CASE P PROD2 47k to 10090' and getting a run at it. TOL @ 8163.7', BOL @ 10100' 11 :40 - 13:20 1.67 CASE P PROD2 POOH following pressure schedule. Close TRSSSV PVT 251 13:20 - 13:40 0.33 CASE P PROD2 Standback MWD assy. LD BTT GS assy 13:40 - 14:30 0.83 FISH P PROD2 WO WIS tools-stuck behind Nabors 3S rig move 14:30 - 15:00 0.50 FISH P PROD2 MU WS retrieval BHA 15:00 - 16:30 1.50 FISH P PROD2 RIH wi BHA #29 circ thru tool 0.5/1400 following pressure schedule PVT 291 16:30 . 16:45 0.25 FISH P PROD2 Log tie-in down from 8050', corr + 1 ' 16:45 - 17:05 0.33 FISH P PROD2 RIH wlo pump and first wt loss at 8142'. Start motor and engage. Use down jars, then PU to 49k and up jars fired. RBIH and lost wt at 8140' 17:05 - 19:00 1.92 FISH P PROD2 Open EDC. POOH 0.7/1500 following pressure schedule. Trap 600psi on well and close SSSV pull to 450' open Baker choke bleed off. SSSV not holding. Repressure and cycle SSSV. Bleed off and holding. Tag up at surface. 19:00 - 20:10 1.17 FISH P PROD2 Setback injector. Confirm whipstock on. LD BHi tools and Weatherford's retrievable whipstock. 20:10 - 20:30 0.33 CASE P PROD2 PU nozzle stab injector. 20:30 - 22:00 1.50 CASE P PROD2 TIH. Pressure up well to 600psi and open SSSV seeing 350psi on well after opened. TIH to 8100' 22:00 - 00:00 2.00 WHSUR P PROD2 TOH displacing Flo-Pro with seawater to 2400'. Close SSSV. Freeze protect with diesel fl 2350' to surface. 6/11/2005 00:00 - 00: 15 0.25 WHSUR P PROD2 Finish FP well with diesel fl 2350' to surface. Pumped total of 34 bbls. Close Master and Swab valves. (Spot N2 equipment) 00:15 - 00:30 0.25 DE MOB P POST PJSM: Review procedures for pickling coil. 00:30 - 01 :40 1.17 DEMOB P POST Pump 10bbls of bleach water followed by 60bbls SW then 15 bbls diesel. Taking returns to Tiger Tank. 01 :40 - 01 :55 0.25 DEMOB P POST PJSM: review blow down procedures using N2. 01 :55 - 03:00 1.08 DEMOB P POST Line-up valves. PT to 3000psi. Blow down to TT. Bleed down. 03:00 - 04:30 1.50 DEMOB P POST Break off well with injector. UD BHA. Remove lubricator sections. Cut off CTC. RU pull back cable to secure end of coil to reel. Cleaning centrifuges and mud pits. 04:30 - 08:00 3.50 DEMOB P POST Pull back coil and secure to reel. 08:00 - 11 :00 3.00 DEMOB P POST Load out reel onto lowboy. NO BOPE. Install tree cap and test '" to 5000psi. Release rig at 1100 hrs 6-11-2005 Printed: 6/22/2005 2:10:34 PM ConocóP'hillips .øaker Hughes INTEQ . :BIP:r Hughes INTEQ Survey Repo Kuparuk River Unit North Slope UNITED STATES I Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) , Sys Datum: Mean Sea Level Site: KRU 1 F Pad Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 North Slope Site Position: Northing: 5958733.30 ft Latitude: 70 17 53.527 N From: Map Easting: 539521.50 ft Longitude: 149 40 47.811 W Position Uncertainty: 0.00 ft North Reference: True Ground Levet: 0.00 ft Grid Convergence: 0.30 deg Well: 1 F-01 Slot Name: Well Position: +N/-S -368.55 ft Northing: 5958365.15 ft Latitude: 70 17 49.903 N +E/-W 68.43 ft Easting : 539591.86 ft Longitude: 149 40 45.817 W Position Uncertainty: 0.00 ft Wellpath: 1 F-01AL 1 deepen lateral with new geological data Current Datum: 1 F-01A Height Magnetic Data: 2/11/2005 Field Strength: 57583 nT Vertical Section: Depth From (TVD) ft 4.80 119.80 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1F-01A- Rotary ST 8077.49 ft Mean Sea Level 24.38 deg 80.73 deg Direction deg 275.00 +N/-S ft 0.00 Survey Program for Definitive Wellpath Date: 5/12/2005 Validated: No Actual From To Survey ft ft 104.80 6253.00 6298.75 8077.49 8100.00 10216.00 Version: 3 Toolcode Tool Name GMS (104.80-8719.80) (0) MWD (6298.75-8336.00) (1) MWD (8100.00-10216.00) CB-GYRO-MS MWD MWD Camera based gyro multishot MWD - Standard MWD - Standard J Annotation 8077.49 8143.00 10216.00 5914.27 5957.14 6026.31 TIP KOP TO Survey: MWD Start Date: 6/8/2005 Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Engineer: Tied-to: Mel Rixse From: Definitive Path ConocJ'Phillips .øaker Hughes INTEQ . ~r Hughes INTEQ Survey Repo 8077.49 46.69 211.62 5914.27 5794.47 4163.36 -629.32 5962524.73 538940.68 989.79 0.00 MWD 8100.00 48.35 212.10 5929.47 5809.67 4149.26 -638.09 5962510.59 538931.99 997.29 7.54 MWD 8143.00 51.54 212.94 5957.14 5837.34 4121.52 -655.78 5962482.75 538914.44 1012.50 7.57 MWD 8161.12 56.29 219.74 5967.82 5848.02 4109.75 -664.47 5962470.94 538905.82 1020.13 40.07 MWD 8185.65 65.75 227.60 5979.70 5859.90 4094.31 -679.30 5962455.43 538891.07 1033.56 47.64 MWD 8211.38 75.78 234.77 5988.18 5868.38 4079.15 -698.22 5962440.17 538872.23 1051.08 47.00 MWD 8239.08 86.64 233.31 5992.40 5872.60 4063.10 -720.34 5962424.00 538850.20 1071.72 39.55 MWD 8271.36 94.22 236.67 5992.16 5872.36 4044.59 -746.76 5962405.36 538823.88 1096.42 25.68 MWD 8300.08 94.81 247.12 5989.90 5870.10 4031.13 -771.97 5962391.76 538798.74 1120.37 36.33 MWD 8330.98 101.72 259.37 5985.44 5865.64 4022.31 -801.17 5962382.78 538769.59 1148.69 45.13 MWD 8360.07 98.35 264.88 5980.37 5860.57 4018.39 -829.53 5962378.72 538741.25 1176.60 21.95 MWD 8393.11 94.44 263.44 5976.69 5856.89 4015.05 -862.19 5962375.21 538708.62 1208.84 12.60 MWD 8420.42 92.69 259.66 5974.99 5855.19 4011.04 -889.14 5962371.06 538681.69 1235.35 15.23 MWD 8450.37 93.16 257.26 5973.46 5853.66 4005.06 -918.45 5962364.92 538652.42 1264.02 8.16 MWD 8481.29 92.04 256.64 5972.06 5852.26 3998.08 -948.54 5962357.79 538622.37 1293.38 4.14 MWD 8519.42 90.81 261.87 5971.11 5851.31 3990.98 -985.97 5962350.49 538584.97 1330.06 14.09 MWD 8557.98 89.09 262.34 5971.14 5851.34 3985.69 -1024.17 5962344.99 538546.81 1367.64 4.62 MWD 8586.64 88.17 262.24 5971.83 5852.03 3981.84 -1052.56 5962341.00 538518.44 1395.59 3.23 MWD 8617.71 88.60 268.10 5972.70 5852.90 3979.23 -1083.49 5962338.22 538487.53 1426.18 18.90 MWD 8647.54 88.88 271.32 5973.36 5853.56 3979.08 -1113.31 5962337.92 538457.71 1455.87 10.83 MWD 8677.77 89.80 275.90 5973.71 5853.91 3980.98 -1143.47 5962339.66 538427.55 1486.08 15.45 MWD 8706.71 89.31 278.69 5973.93 5854.13 3984.65 -1172.17 5962343.18 538398.83 1515.00 9.79 MWD 8744.65 90.23 281.62 5974.09 5854.29 3991.34 -1209.51 5962349.67 538361.46 1552.78 8.09 MWD 8774.15 89.74 281.38 5974.09 5854.29 3997.22 -1238.42 5962355.40 538332.52 1582.09 1.85 MWD 8807.23 89.83 281.41 5974.22 5854.42 4003.76 -1270.85 5962361.77 538300.06 1614.96 0.29 MWD 8841.22 89.28 281.07 5974.48 5854.68 4010.38 -1304.19 5962368.21 538266.70 1648.75 1.90 MWD 8872.47 90.51 281.58 5974.54 5854.74 4016.52 -1334.83 5962374.19 538236.03 1679.81 4.26 MWD 8904.90 90.57 282.42 5974.23 5854.43 4023.26 -1366.55 5962380.76 538204.27 1712.00 2.60 MWD 8933.73 94.48 286.91 5972.96 5853.16 4030.55 -1394.40 5962387.90 538176.39 1740.38 20.64 MWD 8962.84 92.97 290.75 5971.07 5851.27 4039.92 -1421.89 5962397.13 538148.85 1768.58 14.15 MWD 8991.13 90.69 296.46 5970.17 5850.37 4051.24 -1447.78 5962408.31 538122.90 1795.36 21.72 MWD 9024.92 91.03 303.46 5969.66 5849.86 4068.10 -1477.04 5962425.02 538093.56 1825.97 20.74 MWD 9060.88 91.00 308.37 5969.02 5849.22 4089.19 -1506.15 5962445.95 538064.34 1856.81 13.65 MWD 9090.66 91.52 313.97 5968.37 5848.57 4108.78 -1528.55 5962465.42 538041.84 1880.84 18.88 MWD 9121.18 91.64 311.94 5967.53 5847.73 4129.57 -1550.88 5962486.08 538019.40 1904.89 6.66 MWD 9153.39 91.67 306.70 5966.59 5846.79 4149.96 -1575.78 5962506.35 537994.40 1931.47 16.26 MWD 9206.48 90.48 299.00 5965.60 5845.80 4178.73 -1620.33 5962534.88 537949.70 1978.37 14.67 MWD 9234.50 90.57 293.60 5965.34 5845.54 4191.14 -1645.44 5962547.15 537924.52 2004.46 19.27 MWD 9267.14 90.38 287.45 5965.07 5845.27 4202.58 -1676.00 5962558.43 537893.91 2035.90 18.85 MWD 9300.38 90.29 282.81 5964.87 5845.07 4211.25 -1708.07 5962566.93 537861.79 2068.61 13.96 MWD 9331.37 89.83 280.66 5964.84 5845.04 4217.56 -1738.41 5962573.08 537831.42 2099.38 7.09 MWD 9366.14 90.11 277.63 5964.86 5845.06 4223.08 -1772.74 5962578.42 537797.07 2134.06 8.75 MWD 9393.94 89.28 274.31 5965.01 5845.21 4225.97 -1800.38 5962581.16 537769.42 2161.85 12.31 MWD 9422.65 89.46 273.69 5965.32 5845.52 4227.97 -1829.02 5962583.02 537740.77 2190.55 2.25 MWD 9454.09 89.52 279.14 5965.60 5845.80 4231.49 -1860.25 5962586.36 537709.53 2221.97 17.33 MWD 9484.42 90.08 283.60 5965.71 5845.91 4237.46 -1889.98 5962592.18 537679.77 2252.11 14.82 MWD 9514.00 89.49 288.33 5965.82 5846.02 4245.60 -1918.41 5962600.17 537651.30 2281.14 16.11 MWD 9542.07 90.02 291.82 5965.94 5846.14 4255.23 -1944.77 5962609.66 537624.89 2308.24 12.58 MWD 9574.43 90.26 293.99 5965.86 5846.06 4267.82 -1974.58 5962622.10 537595.02 2339.03 6.75 MWD 9605.29 89.37 294.59 5965.96 5846.16 4280.52 -2002.70 5962634.64 537566.83 2368.15 3.48 MWD 9635.77 82.97 287.70 5968.00 5848.20 4291.48 -2031.03 5962645.45 537538.45 2397.33 30.81 MWD 9665.07 85.57 281.06 5970.93 5851.13 4298.72 -2059.26 5962652.54 537510.19 2426.08 24.23 MWD 9694.80 86.42 274.76 5973.01 5853.21 4302.79 -2088.62 5962656.46 537480.81 2455.68 21.33 MWD Conoc~hillips .øaker Hughes INTEQ . BWlr Hughes INTEQ Survey Repo 9800.60 85.87 286.05 5982.75 5862.95 4318.39 -2192.54 5962671.51 537376.81 2560.57 15.61 MWD 9829.42 89.22 290.64 5983.99 5864.19 4327.45 -2219.86 5962680.42 537349.45 2588.58 19.70 MWD 9861.58 89.80 299.53 5984.26 5864.46 4341.07 -2248.96 5962693.89 537320.29 2618.75 27.70 MWD 9892.15 86.73 306.16 5985.19 5865.39 4357.63 -2274.61 5962710.31 537294.55 2645.75 23.89 MWD 9932.30 83.43 308.23 5988.63 5868.83 4381.81 -2306.47 5962734.32 537262.56 2679.60 9.69 MWD 9970.11 85.78 297.46 5992.20 5872.40 4402.18 -2338.05 5962754.53 537230.88 2712.83 29.03 MWD 10005.34 89.18 288.50 5993.75 5873.95 4415.91 -2370.42 5962768.07 537198.44 2746.27 27.18 MWD 10035.09 84.11 281.15 5995.49 5875.69 4423.50 -2399.10 5962775.52 537169.73 2775.50 29.97 MWD 10070.74 79.27 281.31 6000.64 5880.84 4430.37 -2433.69 5962782.20 537135.11 2810.56 13.58 MWD 10097.04 81.47 273.01 6005.05 5885.25 4433.59 -2459.39 5962785.29 537109.39 2836.45 32.22 MWD 10123.68 80.12 277 .45 6009.31 5889.51 4435.99 -2485.57 5962787.55 537083.20 2862.74 17.21 MWD 10152.25 79.24 283.66 6014.44 5894.64 4441.13 -2513.19 5962792.54 537055.56 2890.70 21.60 MWD 10165.04 79.27 284.40 6016.82 5897.02 4444.18 -2525.38 5962795.53 537043.35 2903.11 5.69 MWD 10216.00 79.27 284.40 6026.31 5906.51 4456.63 -2573.88 5962807.72 536994.80 2952.50 0.00 MWD I ---1 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: .¡¡Ln..H~gg@_ªgfIÜLt§.t9.tfLª-KJ¿.;<¿ 9.Qgç.~~...p.ßEiJlºfL..QfAY.@Æi!.T.HLU~tªAfi.:9.1s:.~2 .Þ.J!.tLJjgç.~f;mf?.tgjH@.ªgfXJJLt§.t9.tfUàK,h!.;<¿ Contractor: Nordic Rig No.: 2 DATE: 6/6/05 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich / Sevcik E-Mail ~_~m~i~{f.grJ11r!.m:~:H~:?tQQI1~Y..f?_hm:@.~·m:g~1 Well Name: 1F-01AL1 PTD # 205-032 Operation: Drlg: XXX Test: Initial: Test Pressure: Rams: 400/4500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #4 Rams #5 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quantity 1 1 1 1 1 1 1 2 1 o Workover: Weekly: Annular: 400/4500 TEST DATA Test Result p P P Explor. : Bi-Weekly XXX Valves: 400/4500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 2 P Inside BOP NT Well Sign Drf. Rig Hazard Sec. Size/Type 23/8" 7 1/16" Blind / Shear 3" Slip 2 3/8"x 3.5" 2 3/8" Combi N/A 31/8" 3 1/8" 3 1/8" N/A CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P Test Result P P P P P P NA P P P NA MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P P P Alarm P P P P P Quantity Test Result Inside Reel valves ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 2250 P 200 psi Attained 15 sec P Full Pressure Attained 70 sec P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4 2000 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: .HLn...mgg@ªgmt.u?J9.iJLª.KJ"-~ Remarks: Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector Coil Tubing BFL 11/09/04 YES Date Test start 24 HOUR NOTICE GIVEN NO 6/6/05 Time 0630 Finish xxx Waived By Jeff Jones 0400 Witness Tyler Mcconnell 1100 Nordic 2 BOP 6-06-05p.xls 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: J¡fXL.mgg@.ªgm.ln:§.t~tçt:ª-~:!d§ ~Q9.ç.ç...QnL~1j.1Qg...¡¿fÜ:@.fg1ff.l¡f.l,.~~tªAf:!.:~~:.!¿1?: bob neckenstein:Waamìn.state.aK.us .._____n.._.._n_nn_____..__n_nn___n^.~_____.._n..nn....__.n__..____..._..__n. Contractor: Nordic Rig No.: 2 DATE: 5/24/25 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Hildreth - Feketi E-Mail gH'JgY'f.grJ.(JX!g!:Q¡£~.tQQ!n!J.§.b!~f@!llH¿~!¡ Well Name: 1F-01AL1 PTD #....32 Operation: Drlg: XXX Workover: Explor. : Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 400/4500 Annular: 400/4500 Valves: 400/4500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Dr!. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 71/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 3" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8"x 3.5" P H2S Gas Detector P P #4 Rams 1 2 3/8" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" P Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve 0 N/A NA Time/Pressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 2300 P Quantity Test Result 200 psi Attained 22 sec P No. Valves 14 P Full Pressure Attained 75 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4@ 2100 Test Results Number of Failures: º Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: J1rn...mgg@.ªgf.EiLt§.t~tÇ1.:ª~J}_§ Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper.lRig Waived By Chuck Sheve c - Database Date 5/23/05 Time 18:00 c - Trip Rpt File Witness Brain Pederson c - Inspector Test start 00:00 Finish 04:30 Coil Tubing BFL 11/09/04 Nordic 2 BOP 5-24-05p.xls AI.ASIiA.. OIL AlQ) GAS CONSERVATION COltlMISSION . / FRANK N, MURKOWSKI, GOVERNOR f I / , 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 . ~~~~Œ (ID~ ~~iÆ~æ~ Mike Mooney GKA Wells Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IF-OIALI ConocoPhillips Alaska, Inc. Pennit No: 205-032 Surface Location: 1161' FNL, 388' FEL, SEC. 19, T11N, RIOE, UM Bottomhole Location: 2080' FNL, 1900' FWL, SEC. 18, TIIN, RlOE, UM Dear Mr. Mooney: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ess any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). DATED this 1 day of March, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Cohoc~lIliþS . Post Office Box 100360 Anchorage, Alaska 99510-0360 Mike Mooney Phone (907) 265-4574 Fax: (907) 265-1535 Email: m.mooney@conocophlllips.com February 24, 2005 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Sidetrack w/ CTD lateral, Producer 1 F-01 AL 1 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 1 F- 01 AL 1, a development well. The CTD spud date is expected to be 4-01-05 and one of BP's Nordic CTD units will perform the work. The CTD scope actually includes adding 2 horizontals laterals, one in the A-sand and the other in the C-sand. The A-sand lateral is included in a previous permit application, 1 F-01 A, and will be drilled first. After completing the A- sand lateral, a whipstock will be set at the top of the C-sand and the 1 F-01 AL 1 leg targeting C only will be drilled. Both laterals will be completed with 2-7/8" slotted liners with the upper liner dropped just outside the casing exit to facilitate retrieval of the upper whipstock, thereby allowing access to the lower lateral. Logging program will consist of MWD gamma ray and resistivity. If you have any questions or require any further information, please contact Dan Venhaus at 263-4372. Sincerely, /Il-J- J1v~ Mike Mooney D&W Wells Team Leader . . k&ó STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: DrillD Redrill L:.J 1 b. Current Well Class: Exploratory U Development Oil L:.J Multiple Zone D Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: L:.J Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 F-01AL 1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10325' TVD: 5985' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1161' FNL, 388' FEL, Sec. 19, T11 N, R10E, UM ADL 25652 Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2490' FNL, 1159' FEL, Sec. 18, T11N, R10E, UM ALK 2578 4/1/2005 Total Depth: 9. Acres in Property: 14. Distance to 2080' FNL, 1900' FWL, Sec. 18, T11N, R10E, UM 2560 Nearest Property: 2080' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 539592 y- 5958365 Zone- 4 (Height above GL): 39' AMSL feet Well within Pool: 1 F-11 @ 725' , 16. Deviated wells: Kickoff depth: 8165' ft. 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 93· deg Downhole: 3473 psig Surface: 2814 psig 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ìVD MD ìVD (including stage data) ~ - ....... ....... Y'" "-- ( 4.125" 2-7/8" 6.16# L-80 STL 2150' 8175' 5976' 10325' 5985' slotted liner ~ ---- 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ìVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ìVD (ft): Junk (measured) 8715' 6399' 8059' 8273' 8297' Casing Length Size Cement Volume MD TVD Structural Conductor 80' 16" 250 sx AS II 80' 80' Surface 2630' 1 0-3/4" 1000 sx Fondu & 250 sx Perma- 2630' 2216' Intermediate frost C Production 8698' 7" 850 sx Class G & 250 sx PFC 8698' 6383' Liner - refer to 1 F-01A 2315' 4.5" 15.8 ppg Class G 8275' 10550' Perforation Depth MD (ft): Perforation Depth TVD (ft): refer to 1 F~OJ1A refer to 1 F-01A 20. Attachments: Filing Fee ' ~ BOP Sketch~ Drilling Program 0 Time v. Depth Plot U Shallow Hazard Analysis ~ Property Plat LJ Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 MC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Venhaus @ 263-4372 Printed Name Mike Mooney Title GKA Wells Team Leader Signature /IIL¡ d~ Phone Date -Z/-z ~ > haron AI/sun-Drake Commission Use Only Permit to Drill API Number: Permit Approval .0 If) S- See cover letter Number: 2. 0 5"... c> ,j> .2.- 50- 02.. 9 _:2.,.0 8 ~9-6 0 Date: for other requirements Conditions of approval: É}"'CO' Ye, 0 No~ Mud log required Yes D No ~ droge sulfide measures .::! No D Directional survey required Yes ~ No D o..e'(/-,~þ~ -f0~0-<'-,,~ . . APPROVED BY ð);ðr Approved bt: - ~M.. ____ THE COMMISSION Date: \....../ L./" f I ORIGINAL Form 10-401 Revised 06/2004 Submit in Duplicate . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 Permit It - Kuparuk Well 1 F-01AL 1 Application for Permit to Drill Document Men: i r'I'1 i it Ii WIfi!'II VQI!,!!; Table of Contents 1. Well Name .............. ............ ........... .................. ............ .......... ...... .............................. 2 Requirements of 20 AAC 25.005 (f) ..... .......... ........... ......................... ............ ............... ...... ......... .......... 2 2. Location Summary ......... ............................... ............. ........... ...... ............................. 2 Requirements of 20 AAC 25. 005(c)(2). ........ ............. .............................. ................. ........... ....... ....... ..... 2 Requirements of 20 AAC 25.050(b) . ....... ..... ............. ......................... .......................... ......... .... ..... .... .... 2 3. Blowout Prevention Equipment Information ......................................................... 2 Requirements of 20 AAC 25. 005(c)(3) ........................................ ........... ..... ........... ..... ............... .... ... ..... 2 4. Drilling Hazards Information ..................... ................ .......... ..... ................... ............ 3 Requirements of 20 AAC 25.005 (c)( 4)................................. ......................... ........ ....... ......................... 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5)..... .... ........................................,............ .................................... 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25. 005(c)(6)...... ........................................ ........................................ ...... ....... 3 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7)....... ........ .... ................ .............................................. ......... ......... 4 8. Drilling Fluid Program..... ............ ................... .............. .................... ....................... 4 Requirements of 20 AAC 25. 005(c)(8) ............... ........... ............ .............. ............ ...................... ............. 4 9. Abnormally Pressured Formation Information...........Error! Bookmark not defined. Requirements of 20 AAC 25.005 (c)(9).................................................. Error! Bookmark not defined. 10. Seismic Analysis........................................... ............. .................... ................... ....... 5 Requirements of 20 AAC 25.005 (c)(10)...... .................. ....... ..................... .................... .................... .... 5 11. Seabed Condition Analysis..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ...... ....... .......... ..................... ............ .......................... ............. 5 Requirements of 20 AAC 25.005 (c)(12) .....................................................................,.......................... 5 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13).... ................... ....... ........ ...... ............. ...... ...... .......... ................. 5 14. Discussion of Mud and Cuttings Disposal and Annular DisposaL..................... 6 ORIGINAL 1F-01AL1 PERMIT IT. DOC Page 10'6 . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 Requirements of 20 AAC 25.005 (c)(14)................. .,. ............ ........... ................. ....... ..................... ........ 6 15. Attachments............................................................................................................. 6 Attachment 1 Directional Plan................................... .................. ,. .................................. ....6 Attachment 2 Well Schematic.. ............ .... ....... .............. ,................................. .................... 6 Attachment 3 CTD BOPE Schematic....................... ......... ...... ...................... .......... .... ............ ............... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 1 F-01AL 1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,958,365. 15 I 1160'FNL, 388'FEL, Sec19, T11N,R10E,UM I RKB Elevation I Eastings: 539,591.86 I Pad Elevation I 115.0' AMSL 76.0' AMSL Location at Total Depth I NGS Coordinates Measured Depth, RKB: 10325' Northings: 5,962,711.99 Eastings: 536,904.75 Total Vertical Depth, RKB: 5985' Total Vertical Depth, SS: 5870' and (D) other information required by 20 AAC 25. 050(b): Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells. to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20AAC 25.035,20 AAC 25.036, or 20 AAC 25.037, as applicable: ORIGINAL 1F-01AL1 PERMIT ITDOC Page 2 of 6 . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 Please see attached BOP schematic. Pipe rams, blind rams and the CT packoff will be pressure tested to 400 psiClncl4.QQ.Q..e..si. The annular preventer will be tested to 400 psi and 2500 psi. --' ) 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dril/ must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it and maximum potential surface pressure based on a methane gradient; BHP data on offset injectors indicates that the current C-sand reservoir pressure for 1 F-01AL 1 is ~ 3500 psi at 5988' TVD, 0.58 psi/ft or 11.2 ppg EMW. The maximum potential surface pressure (MPSP) while drilling 1F-01AL 1 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psilft, and the Kuparuk C sand target at 5988' TVD: MPSP = (5988 ft)*(O.58 - 0.11 psi/ft) = 2814 psi (B) data on potential gas zones; KOP is within the Kuparuk C-sand, which is also the drilling target. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; 1. Mud losses in the C sand due to low reservoir pressure, could also have problems while tripping and running the liner with differential sticking. 2. H2S is approximately 59 ppm in 1 F-01. The 1 F pad is a designated H2S area with a high H2S reading of 128 ppm on well 1 F-14. Hydrogen sulfide contingency measures will be effect. Production Hole Interval DrillinQ Hazards Shale instability at B/C sand interface Moderate Differential Stickin Lost Circulation Moderate High 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AA C 25.030(f); 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-petforated liner, or screen to be instal/ed ORIGINAL 1F-01AL1 PERMIT IT. DOC Page 3 of 6 . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 Cement Pro ram 8378'/ 6091' CTD Plan: 2-7/8" 8175'/5976' 10325'/5985 No cement, slotted liner 2-7/8" liner top will be placed 5'-10' outside the window in the open hole. This will allow pulling the whipstock and allowing access to lower portion of well. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverler system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Sidetrack will exit pre-existing casing. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; CTD will utilize solids-free polymer DIF having the following properties: Sidetrack Hole mud ro erties CTD Horizontal AL 1 Chloride Flo-Pro CTD Horizontal AL 1 Formate KWF Depth MD/ TVD Density (ppg) Funnel Viscosity (seconds) Yield Point cP Plastic Viscostiy (lb/100 sf) 10325'/5985' 8.7 60,000 c LSR 22-28 7-9 7-9 Solids (%) Solids free Solids free Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. During CTD drilling operations, two well bore volumes of KWF will be on location for well control purposes. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: ORIGINAL 1F-01AL1 PERMIT IT DOC Page 4 of 6 . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform. mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Pre-RiQ Well Work: N/A - CTD rig will have just completed the 1 F-01A lateral in the A-sands. CTD Ria Work: Items in italics are øermitted under seøarate AFD for 1 F-01 A 1. MIRV Nordic 2 CTO rig. NV 7-1/16" BOPE and test. 2. Set 4-1/2" LSX whipstock @ 8285' md. 3. Mil/3.80" window at 8285' and 10' of openhole. 4. Oril/4-1/8" bicenter hole horizontal A-sand lateral from window to -10550' md. 5. Complete with 2-7/8" slotted liner from TO -10590', up into the 4-1/2" liner to 8275' md. ~ Followina work is for this permit. 1 F-01 AL 1 6. Set Weatherford KSWS packer at -8180' md. 7. Stab into KSWS Weatherford packer with retrievable 4-1/2" whipstock, targeting top of whipstock @ 8165' md. ~ ~ 8. Mill 3.80" window at 8165' and 10' of open hole. "\ ~,~Y 9. Drill 4-1/8" bicenter hole horizontal C-sand lateral from window to -10325' md. ~' ~ Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and lor fracturing at the end of the long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. ORIGINAL 1F-01AL1 PERMIT IT. DOC Page 5 of 6 . . Application for Permit to Drill, Well 1 F-01AL 1 Revision No.O Saved: 22-Feb-05 Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipelslips (VB pipe rams and 3" slip rams, see attached BOP configuration) andlor the tested tubing retrievable sub-surface safety valve that will be installed during the rotary portion of this sidetrack. The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 3500 psi @ 5988' SSTVD, 11.2 ppg EMW Expected annular friction pressure loss while circulating: 490 psi Planned mud density: 10.0 ppg equates to 3114 psi hydrostatic BHP While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 3604 psi or 11.6 ppg ECD, thereby providing 108 psi overbalance. When circulation is stopped, a minimum of 500 psi surface pressure will be applied to to maintain constant BHP. 10. Complete with 2-7/8" slotted liner from TD -10325, up to 5-10' outside the 4-1/2" casing exit - 8165' md 11. Pull 4-1/2" retrievable whipstock @ 8165' md 12. ND BOPE. RDMO Nordic 2. Post-Rig Well Work: 1. Drift and tag to PBTD. 2. Run new GL V design. 3. Install new "S" riser and replace the well house(s). 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; The liquid waste fluids generated during the drilling process will be taken to one of the KRU's Class II disposal wells, and the Class II solids will go to DS-4 in Prudhoe (G&I facility). Class I wastes will go to Pad 3 for disposal. 15.Attachments : Attachment 1 Directional Plan Attachment 2 Well Schematic Attachment 3 Nordic 2 BOP config ORIGINAL 1F-01AL1 PERMIT IT. DOC Page 6 of 6 o ;0 - (j') - z » r- KRU 1 F-01A & L 1 Producer Proposed Completion 10 3/4" 45.5# @ 2630' 7" 26# K-55 Window @ -6232 MD' C - Sand 4 %" Cameo TRM-4E SSSV 3.812" Min. 1.0. 4-1/2" 12.6# L-80 IBT Mod Tubing 4-%" Cameo KBMG GLMs at 2600',3700', & 4175' MD 4-%" Cameo DB nipple, 3.75" min 10 Baker ZXP liner top packer/hanger/seal assembly at 6082' MD T,,\~ \X<~\~ ~·---=ð:P-·"'·~ 4-1/8" open hole S 1 F-01AL 1 Lateral, TD @ 10,325' m .,.....,--,,--_.-..,-'~~=:::;:~~ -z:1íã;' liner top @ +1-8175'MD o o ConocJPhillips Alaska, Inc. . ''''''-' -..., --,-- o o 0 0 000 o o o o o o o 0 o o o o o 0 o 0 o o o o o 0 o 0 o o o o Weatherford rievable whipstock @ 8165'Æ~.",(willl~ 2-7/8" slotted liner ~ Weatherford KS perm p~~íí~~~:~~;180' MD-------'"-··,,··-··········,-· 2-7/8" Cameo 0 nipple, 2.25" min ID (or HES XN, 2.25" min 10) @ 8200' md KOP 8285' MD A - Sand 4-1/2" 12.6# L-80 @ 8378' MD o o 2-7/8" Baker deployment sub @ 8275' md 4-1/8" openhole o o o o 0 0 o 0 0 o 0 o 0 o o o 0 o 0 o o o o o 4-Y:z" LSX WS o o o o o o o o o 2-7/8" slotted liner 1 F-01A, TO @ 10,550' md o o o 0 o o o o o o o o o o o 02/11/05 Kuparuk DOBCTD BOP configuration 2-3/8" Coil Well Rig Floor iIo ssv Pagé 1 .. I .. aker Hughes I TEQ ellplanning Report INTEQ: James Ohlinger GJNAL . Operator: ConocoPhillips Well: Field: Kuparuk Version # Date Include relevant comments including incoming document source & output recipients when appropriate Well plan Revision Log 1F-Q1A & AL 1 RKB: Rig: Nordic 2 Engineer: Rvsd/Drawn Description 5 Copy of Lamar's Plan#S for 1 F-01A (CTD) 4 Copy of Lamar's Plan#4 for 1 F-01AL 1 WPRevLog ver 1.117-May-99 ORIGINAL . 115.0 L. Gantt ... BAKER HUGHES INTEQ . . BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map Systeni:lS State Plane Coordinate System 1927 Geo Datum:NAD27 (Clarke 1866) Sys Datum:Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5958733.30 ft Easting: 539521.50 ft Latitude: 70 Longitude: 149 North Reference: Grid Convergence: 17 53.527 N 40 47.811 W True 0.30 deg 0.00 ft 0.00 ft Well: 1 F-01 Slot Name: Well Position: +N/-S -368.55 ft Northing: 5958365.15 ft +E/-W 68.43 ft Easting: 539591.86 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 17 49.903 N 149 40 45.817 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1 F-01A - Rotary ST 8165.00 ft Mean Sea Level 24.38 deg 80.73 deg Direction deg 349.00 Wellpath: Plan #4 1 F-01AL 1 Current Datum: 1F-01 RKB Magnetic Data: 2/11/2005 Field Strength: 57583 nT Vertical Section: Depth From (TVD) ft 0.00 Height 115.00 ft 8100.00 5929.77 llP 8165,00 5969.19 KOP 8185.00 5980.40 3 - end of 9 DLS 8365,00 5996.97 4 - end of 38 DLS 10325.00 0.00 TO Plan: Plan #4 Date Composed: 2/11/2005 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 8100.00 50.31 208.33 5929.77 4146.46 -673.49 0.00 0.00 0.00 0.00 8165.00 55.00 210.00 5969.19 4101.36 -698.68 7.50 7.22 2.57 16.32 8185.00 56.77 210.37 5980.40 4087.05 -707.01 9.00 8.87 1,87 10.00 8289.46 96.00 216.78 6004.54 4004.42 -762.43 38.00 37,55 6.13 10.00 8365.00 95.26 245.61 5996.97 3957.83 -820.39 38.00 -0.98 38,18 90.00 8515.00 95.24 268.21 5983.06 3924.23 -964.93 15.00 -0.01 15.06 89.00 8615.00 95.32 283.27 5973.80 3934.16 -1063.71 15.00 0.08 15.06 89.00 8765.00 92.82 305.69 5963.02 3995.81 -1198.97 15.00 -1.67 14.95 95.50 9030.00 92.17 265.91 5951.01 4066.43 -1448.62 15.00 -0.25 -15.01 270.00 9180.00 92.61 288.43 5944.68 4085.01 -1596.36 15.00 0,30 15.01 88.40 9340.00 92.79 312.45 5937.02 4165.38 -1733.14 15.00 0.11 15.02 89.00 9705.00 85.91 258.10 5941.47 4258.04 -2071.94 15.00 -1.89 -14.89 263.00 ORIGINAL . . BP-GDB Baker Hughes INTEQ Planning Report 8100.00 50,31 208.33 5814.77 4146.46 -673.49 5962507.60 538896.61 4198.79 0.00 0.00 MWD 8150.00 53,92 209.63 5845.47 4111.95 -692.61 5962472.99 538877.67 4168.56 7.50 16,32 MWD 8165.00 55.00 210.00 5854.19 4101.36 -698.68 5962462.37 538871.65 4159.33 7.50 15.52 MWD 8185.00 56.77 210.37 5865.40 4087.05 -707.01 5962448.02 538863.40 4146.86 9.00 10.00 MWD 8190.00 58.64 210.76 5868.07 4083.41 -709.16 5962444.37 538861.27 4143.70 38.00 10,00 MWD 8200.00 62.39 211.49 5872.99 4075.96 -713.66 5962436.90 538856.81 4137.25 38.00 9.79 MWD 8210.00 66,14 212.17 5877.34 4068.31 -718.41 5962429.22 538852.10 4130.64 38.00 9.43 MWD 8220.00 69.89 212.81 5881,08 4060.49 -723.39 5962421.38 538847.16 4123.92 38.00 9,14 MWD 8230.00 73.65 213.42 5884.21 4052.54 -728.58 5962413.40 538842.02 4117.10 38.00 8.90 MWD 8240.00 77.41 214.01 5886.70 4044.49 -733.95 5962405.32 538836.69 4110.22 38.00 8,71 MWD 8250.00 81.17 214.58 5888.56 4036.37 -739.49 5962397.17 538831.19 4103.31 38.00 8.56 MWD 8260.00 84.92 215.15 5889,77 4028.23 -745,16 5962389.00 538825.56 4096.40 38.00 8.45 MWD 8270.00 88.68 215.70 5890.33 4020.09 -750.95 5962380.84 538819.82 4089.52 38.00 8,39 MWD 8280.00 92.44 216.25 5890.23 4012.00 -756.82 5962372,72 538813.99 4082.70 38.00 8.35 MWD 8289.46 96.00 216.78 5889.54 4004.42 -762.43 5962365.11 538808.42 4076.33 38.00 8.36 MWD 8300.00 95.99 220.80 5888.43 3996.25 -769,00 5962356.90 538801.90 4069.56 38.00 90.00 MWD 8310.00 95.94 224.62 5887.40 3988.95 -775.74 5962349.56 538795.19 4063.68 38.00 90.42 MWD 8320.00 95.88 228.44 5886.37 3982.10 -782.96 5962342.68 538788.01 4058.34 38.00 90.82 MWD 8330.00 95,78 232.26 5885.35 3975.76 -790,62 5962336.30 538780.39 4053.57 38.00 91.21 MWD 8340.00 95.66 236.08 5884.35 3969.93 -798.69 5962330.43 538772.35 4049.39 38.00 91.60 MWD 8350.00 95.52 239.90 5883.38 3964.66 -807.12 5962325.11 538763.94 4045.82 38,00 91.98 MWD 8360.00 95.35 243.71 5882.43 3959.96 -815.89 5962320.36 538755.20 4042.88 38.00 92.35 MWD 8365.00 95.26 245.61 5881.97 3957.83 -820.39 5962318.21 538750.71 4041.65 38,00 92,71 MWD 8375.00 95.28 247.12 5881.05 3953.83 -829,52 5962314.17 538741.61 4039.47 15,00 89.00 MWD 8400.00 95,33 250.89 5878.73 3944.92 -852.75 5962305.13 538718.42 4035.15 15.00 89,14 MWD 8425.00 95,35 254.65 5876.41 3937.54 -876.52 5962297.64 538694.69 4032.45 15.00 89.49 MWD 8450.00 95.35 258.42 5874.07 3931.75 -900.72 5962291.72 538670.53 4031.38 15.00 89,84 MWD 8475.00 95.33 262.19 5871.75 3927.56 -925.26 5962287.39 538646.02 4031.95 15.00 90.19 MWD 8500.00 95.28 265.95 5869.43 3924.99 -950.01 5962284.69 538621.28 4034.14 15.00 90,54 MWD 8515.00 95.24 268.21 5868.06 3924.23 -964.93 5962283.85 538606.37 4036.24 15.00 90,89 MWD 8525.00 95.27 269.72 5867,14 3924.05 -974.88 5962283.62 538596.42 4037.97 15.00 89,00 MWD 8550.00 95.31 273.48 5864.84 3924.74 -999.76 5962284.18 538571.53 4043.40 15.00 89.14 MWD 8575.00 95.33 277.25 5862.52 3927.07 -1024.54 5962286.38 538546.75 4050.41 15.00 89.49 MWD 8600.00 95.33 281.01 5860.19 3931.02 -1049.11 5962290.20 538522.16 4058.97 15.00 89.83 MWD 8615.00 95.32 283.27 5858.80 3934.16 -1063.71 5962293.27 538507.54 4064.84 15.00 90.18 MWD 8625.00 95.18 284,77 5857.89 3936.57 -1073.37 5962295.63 538497.87 4069.06 15.00 95.50 MWD 8650.00 94.80 288.52 5855.71 3943,71 -1097.23 5962302.63 538473.98 4080.61 15.00 95.64 MWD 8675.00 94.40 292.26 5853.71 3952.39 -1120.59 5962311.19 538450.58 4093.59 15,00 95.96 MWD 8700.00 93.98 296.00 5851.88 3962.58 -1143.34 5962321.26 538427.78 4107.93 15,00 96.26 MWD 8725.00 93.54 299,73 5850.24 3974.23 -1165.39 5962332.80 538405.67 4123.58 15.00 96.54 MWD 8750.00 93.09 303.46 5848.79 3987.31 -1186.64 5962345.76 538384.35 4140.47 15,00 96.78 MWD 8765.00 92.82 305,69 5848.02 3995.81 -1198.97 5962354.19 538371.97 4151.17 15,00 97.00 MWD 8775.00 92.82 304,19 5847.53 4001.53 -1207.16 5962359.87 538363.75 4158.35 15,00 270.00 MWD 8800.00 92.81 300.44 5846.30 4014.87 -1228.26 5962373.10 538342.59 4175.47 15.00 269.93 MWD 8825.00 92.78 296.68 5845.08 4026.81 -1250.19 5962384.92 538320.60 4191.37 15.00 269.74 MWD 8850.00 92.75 292.93 5843.88 4037.28 -1272.85 5962395.28 538297.88 4205.98 15.00 269,56 MWD ORIGINAL . . BP-GDB Baker Hughes INTEQ Planning Report 8875.00 92,70 289.18 5842.69 4046.25 -1296.15 5962404.12 538274.54 4219.23 15.00 269.38 MWD 8900.00 92.64 285.42 5841.52 4053.68 -1319.99 5962411.42 538250.66 4231.07 15.00 269.20 MWD 8925.00 92.57 281.67 5840.38 4059.52 -1344.27 5962417.14 538226.36 4241.44 15.00 269.02 MWD 8950.00 92.49 277 .92 5839.28 4063.77 -1368.87 5962421.26 538201.73 4250.30 15.00 268,85 MWD 8975.00 92.40 274.16 5838.21 4066.40 -1393.71 5962423.75 538176.89 4257.62 15.00 268.69 MWD 9000.00 92.30 270.41 5837,18 4067.40 -1418.66 5962424.62 538151.93 4263.36 15.00 268.53 MWD 9025.00 92.19 266.66 5836.20 4066.76 -1443.63 5962423.85 538126,97 4267.50 15.00 268.37 MWD 9030.00 92.17 265.91 5836.01 4066.43 -1448.62 5962423.50 538121.99 4268.13 15.00 268.23 MWD 9050.00 92.25 268.91 5835,24 4065.53 -1468.58 5962422.49 538102.03 4271.05 15.00 88.40 MWD 9075.00 92.34 272.66 5834.24 4065.87 -1493.55 5962422.70 538077.06 4276.16 15,00 88.52 MWD 9100.00 92.42 276.42 5833.20 4067.85 -1518.45 5962424.55 538052.15 4282.85 15.00 88.67 MWD 9125.00 92.49 280.17 5832.13 4071.45 -1543.16 5962428.02 538027.43 4291.10 15.00 88.82 MWD 9150.00 92.55 283.92 5831,03 4076.66 -1567.58 5962433.10 538002.98 4300.87 15.00 88.98 MWD 9175.00 92.60 287.67 5829.90 4083.46 -1591.61 5962439.77 537978.92 4312.13 15.00 89.15 MWD 9180.00 92.61 288.43 5829.68 4085.01 -1596.36 5962441.29 537974.16 4314.55 15.00 89.32 MWD 9200.00 92.66 291.43 5828.76 4091.82 -1615.14 5962448.00 537955.35 4324.82 15.00 89.00 MWD 9225.00 92.71 295.18 5827,58 4101.69 -1638.07 5962457.76 537932.37 4338.89 15.00 89.14 MWD 9250.00 92.75 298.94 5826.39 4113.05 -1660.30 5962469,00 537910.08 4354.28 15.00 89.31 MWD 9275.00 92.78 302.69 5825.18 4125.84 -1681,74 5962481.67 537888,57 4370.93 15,00 89.49 MWD 9300.00 92.79 306.44 5823.97 4140,01 -1702.30 5962495.73 537867.94 4388.76 15.00 89.67 MWD 9325.00 92.80 310.20 5822.75 4155.49 -1721.89 5962511.10 537848.27 4407.69 15,00 89.86 MWD 9340.00 92.79 312.45 5822.02 4165.38 -1733,14 5962520.93 537836.97 4419.55 15,00 90.04 MWD 9350.00 92.61 310.96 5821.55 4172.03 -1740.60 5962527.54 537829.48 4427.49 15.00 263.00 MWD 9375.00 92.14 307.24 5820.51 4187,78 -1759,98 5962543.19 537810.02 4446.65 15.00 262.93 MWD 9400.00 91.67 303.52 5819.68 4202.24 -1780.35 5962557.54 537789.58 4464.74 15,00 262.78 MWD 9425.00 91.18 299.80 5819.05 4215.35 -1801.62 5962570.54 537768.24 4481,67 15.00 262.65 MWD 9450.00 90.70 296.08 5818.64 4227.06 -1823.70 5962582.13 537746.10 4497.38 15.00 262.56 MWD 9475.00 90.21 292.36 5818.45 4237.31 -1846.49 5962592.26 537723.25 4511.79 15.00 262.50 MWD 9500.00 89,71 288,64 5818.46 4246.07 -1869.90 5962600.89 537699.80 4524.85 15.00 262.4 7 MWD 9525.00 89.22 284,92 5818.70 4253.28 -1893.83 5962607.98 537675.83 4536.50 15,00 262.47 MWD 9550.00 88.74 281.20 5819.14 4258.93 -1918.18 5962613.50 537651.46 4546.69 15.00 262.51 MWD 9575.00 88.26 277.48 5819.80 4262.99 -1942.83 5962617.43 537626.79 4555.38 15,00 262.57 MWD 9600.00 87.78 273,76 5820.66 4265.44 -1967.70 5962619.75 537601.92 4562.52 15,00 262.67 MWD 9625.00 87.32 270.04 5821.73 4266.27 -1992.65 5962620.44 537576.96 4568.10 15.00 262,80 MWD 9650.00 86.86 266.31 5823.00 4265.47 -2017.60 5962619.52 537552.01 4572.08 15,00 262.96 MWD 9675.00 86.42 262.58 5824.47 4263.06 -2042.44 5962616.97 537527.19 4574.45 15.00 263.15 MWD 9700.00 86,00 258.85 5826.12 4259.03 -2067.05 5962612.82 537502.60 4575.19 15.00 263.37 MWD 9705,00 85.91 258.10 5826.47 4258.04 -2071.94 5962611.79 537497.72 4575.15 15.00 263,61 MWD 9725.00 85,81 261.11 5827.92 4254.44 -2091.56 5962608.09 537478.12 4575.36 15.00 92.00 MWD 9750.00 85.71 264.86 5829.76 4251.39 -2116.30 5962604.92 537453.40 4577.09 15.00 91,78 MWD 9775.00 85,62 268.62 5831,66 4249.98 -2141.18 5962603.37 537428.53 4580.45 15.00 91.51 MWD 9800.00 85.55 272.38 5833.58 4250.19 -2166.10 5962603.46 537403.61 4585.42 15.00 91.22 MWD 9825.00 85,50 276.15 5835.54 4252.05 -2190.95 5962605.18 537378.75 4591.98 15.00 90,93 MWD 9850.00 85.46 279.91 5837.51 4255.53 -2215.63 5962608.53 537354.07 4600.10 15.00 90,64 MWD 9875.00 85.45 283.67 5839.49 4260.62 -2240.02 5962613.49 537329.65 4609.75 15.00 90.34 MWD 9900.00 85.46 287.43 5841.47 4267.30 -2264.02 5962620.04 537305.61 4620.89 15.00 90.04 MWD 9925.00 85.48 291.19 5843.45 4275.54 -2287.54 5962628.16 537282.06 4633.47 15.00 89.74 MWD 9950.00 85.53 294.95 5845.40 4285.30 -2310.46 5962637.80 537259.08 4647.43 15.00 89.45 MWD 9975.00 85.60 298.71 5847.34 4296.55 -2332.70 5962648.93 537236.79 4662.71 15.00 89.15 MWD 10000.00 85.68 302.47 5849.24 4309.24 -2354.15 5962661.50 537215.27 4679.26 15.00 88.86 MWD 10005.00 85.70 303.23 5849,62 4311.94 -2358.34 5962664.18 537211.07 4682.71 15.00 88.57 MWD 10025.00 85.70 300.22 5851.12 4322.43 -2375.31 5962674.58 537194.05 4696.24 15.00 270.00 MWD 10050.00 85.73 296.46 5852.99 4334.26 -2397.24 5962686.29 537172.05 4712.04 15.00 270.23 MWD ORIGINAL . . BP-GDB Baker Hughes INTEQ Planning Report 10075.00 85.77 292.70 5854.84 4344.62 -2419.91 5962696.54 537149.33 4726.54 15,00 270.51 MWD 10080.00 85.78 291.95 5855.21 4346.52 -2424.52 5962698.41 537144.71 4729.28 15.00 270.79 MWD 10100.00 85.87 288.94 5856.66 4353.48 -2443.21 5962705.28 537125.99 4739.69 15.00 271.50 MWD 10125.00 85.99 285.18 5858.44 4360.80 -2467.05 5962712.46 537102.12 4751.41 15.00 271.72 MWD 10150.00 86.12 281.42 5860.16 4366.54 -2491.32 5962718.07 537077.82 4761.68 15.00 271.99 MWD 10175.00 86.28 277.67 5861,82 4370.67 -2515.91 5962722.08 537053.21 4770.43 15.00 272.24 MWD 10200.00 86.45 273.92 5863.40 4373.19 -2540.73 5962724.47 537028.38 4777.64 15.00 272.49 MWD 10225.00 86.64 270.16 5864.91 4374.08 -2565.66 5962725.22 537003.44 4783.27 15.00 272.73 MWD 10250.00 86.84 266.41 5866.33 4373.33 -2590.61 5962724.35 536978.51 4787.29 15.00 272.96 MWD 10275.00 87.05 262.66 5867.67 4370.96 -2615.45 5962721.84 536953.67 4789.70 15.00 273.17 MWD 10300.00 87.28 258.92 5868.90 4366.96 -2640.10 5962717.71 536929.06 4790.48 15.00 273.37 MWD 10325.00 87.52 255.17 5870.04 4361.36 -2664.43 5962711.99 536904.75 4789.63 15.00 273.56 MWD ORIGINAL CTD) 2/11/2005 PIal Plan #5 (1F-01/Plan #5 1F-01A Potní: Date Create Azimuths to True North Magnetic North: 24.380 Magnetic Field Strength: 57583nT Dip Angle: 80.730 Date: 2/11/2005 Model: bggm2004 ConocoPhmips Alaska, Inc. WEL.I..PATHD-ETAILS Pia" #5 1 F.aU.· CTD Pal"etltWeUpath: tP>01A-Rotary ST ileol'< MO: 82.00.00 Dat~~; Nørdlc2 115,0&t 1F"(}1 RKG Sedlo" Origin OriSI" Starting Angle '--"'J.S "'EI.W I'rom'f'VD 349.00' AM 48 .... C ~47 ::: o 046 ,.. .... .-.45' ... .... ,c44' 1:: o ~43' - . J:4200~~ ... 541 en 40 Ta·o \fS~<:o ~*~* <1M!!".$(¡ 40t1\33 ~~Hi ~g~:~~ :~¡~~Õ :~t~ 4719,30 j¡I~~ TFø«> '.00 O.OG 30.00 '.00 90.00 53.00 89.00 266,00 90.00 276,00 Z58.00 "'.00 269.00 (1M{) 8'1.00 270.00 OI.I>S 0,(10 0.00 9.00 28.00 ~~ii 15.00 15,M ~UI +EI·W ·'113,12 :~~¡:~ -716,1)(1 1~~U: 1080A5 1211.45 ~:~t~~ 1'758.(10 ii~:g~ ~~~N~ +N,c8 4076.41 ~~lH 392ß.95 i~~;g ~~H! 4151,92- ~~~H1 j~k~¥ m 5874.11 S91!:2.$7 i:~i~ 59910.53 &1M.69 ¡E:ii ~~:~~~ M86.81>" ~~~:~~ G014.61 G022.Si "" Z10,00 210,(10 ~~~;g~ 252..9!! 2ß/i.S¡;- 299,48 269;!\3 3bM,ß iiiig ~~f:~i 214,01 SIl¢ MO !II¢ 1 8200.00 5!\.OO 2 8285.01) 55/00 :1 630!1,OO 56.56 ~ fi~~:~ ~:~~ 6 88(11,2095,00 i ;~:gg ¡Ui ¡! e~:gg ~:gi 139$32.(11) 87,58 1~ ~g¡¿~:gg ~:~~ 1610550,0088.57 $h, TlP.1f'»Ú1AL1 KOP·1F·(1AL1 KOp-1F.01A 3.e-ndof90LS 4.t!l1d<)f28 DSL ;. TIP. 81{\O.OO 8165,00 8285.00 8305.00 8601.20 0550.M 8200.00 !Xi14.11 5854.04 5922.87 5934.11 6024.69 .115.00 5874,11 No. ,c ... s::I.5 CI Q _5 m ,!:!5 1:: GI :> 5900' ~5 .. 1-6 SHARON K ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1093 PAY TO THE ORDER OF $ fa? Oô --- . .111III-" C H A SE Chas. Manhattan Bank USA, N.A. Valid Up To 5000 Dollars ~, ... 200 White Clay Center Dr.. Newark, DE19711 . .,.. ~~~/hø~L_~ I: 0 ~ ¡. ¡. 0 0 ¡. I. I.': 2 ¡. B I. 7 ¡. t1 0 7 t1 2 7 b III ¡. 0 t1 ~ / t/NlVE;RSAt . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ;ff{~ Y~-o/A¿/ PTD# Zo5-032 >< Development Service Exploration Stratigraphic CßECK WHAT ADD-ONS "'CLUE"· AP~LlES (OPTIONS) MULTI The permit is for a Dew weJlbore ·segmeDt of X LATERAL e:xistiDg wen ßI.4-.. /,Þ -~/A Permit No~O$_ o:J.:·9 API No. SO-02.~ -:2oi" (If API Dum ber ProductiOD. sbould continue to be reponed as last two. (2) digits a functioD' of tbe original API number. stated are between 60-69) above. PD..,OT HOLE )n accordaDce with· 20 AAC 25.005(1), aU (PH) records, data and Jogs acquired .for tbe pilot bole must be clearJy differentiated lD botb Dame (name OD permit plus PH) .' and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION .' compliance witb 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:lceptioD. (Company Name) assumes the liabiUty of any protest to tbe spacing .~:Jception that may occur. : DRY DITCH AU dry ditch sample sets submitted to the SAMPLE Commission must be in no greater 1ban 30' .. sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample iDter:vaJs through target ZODes. .. 87 -0 ( Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: NIT 1 F-01AL 1 Program DEV Well bore seg ~ COPHILLlPS ALASKA INC Initial ClasslType DEV 11-01L GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 0 Administration PelJ1JiUee <lttaçhe~L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - -- - - - - - - - I~ :~~~:~en~:~~:;~:~~ri:~:"-er _ : : _ : : : _ : _ _ _ _ _ _ _ _ _ _ _ _ : : : : _ _ _ _ _ : _ _ :~:: _ _ _ _ : : : : _ _ _ _ _ : : : : : : : : : _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ : : : _ _ . _ _ _ _ _ _ _ _ _ _ 4 WellJocated inad_efioepppol _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - - - - - - - - - - - - - - - - - - - - - 5 WelUocaled proper distance_ from driJling unitb_ounda(y_ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 6 WellJocated proper distance_ from otber welJs_ _ _ _ _ _ _ Yes - - - - - - - - - - - 7Sutfiçient acre<lge_ayailable indrilJilJg unjt _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - . - - - - - 8 Jtdeviç¡ted, js_ weJlbore plaUlJcJuped _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - 9 _Operator only. <lffected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - - - - - - - - - - - - - - - - - 10 _Operator bas_appropriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permilc.anÞeissuedwjtboutco_nservaJionorder_ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - . - -- Appr Date 12 PelJ1Jil c_an Þe issu.ed witbout ç¡dmini$trati",e_approvaJ _ _ _ _ _ _ _ _ _ _ _ - - Yes - - - - - - - - - - - - - - - - - - - - - - RPC 2/28/2005 13 Can permit be approved before 15-day wait Yes . 14 WeJUocated within area and_strata _authorized byJnjectiolJ Order # (puUO# incomm_ents) (For. NA - - - - - - - - - - - - - - 15 AJI welJs_withinJl4J'uite_are.a_of reyiew jdelJtified (For $ervjce_~ell ol'!ly.L _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; puralionof pre-propuc;tiOIJ less than 3 montbs (FQr_service well onJy) _ _ NA - - - - - - - - - - - - - - - - 17 _ACMP_Findingof Consisleocy_has Þee_nJssuedJorJbis project _ _ NA - - - - - - - - - - - - - - Engineering 118 Coodu_ctor string_provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ Conductor _string seUn originç¡l~ell1 1=-01 (162-219)._ !19SUrf<lcecasing_PJotecJs alLknown USDW$ _ _ _ _ _NA _ _ _ All aq_uifer$ exempled,40_CFR1~7.1Q2(b)(3). - - - - 20 _CMT vol adequ.ateto çirc_ulate_o_n _conductor_ & surfq¡g _ NA _ _ Su.rtace casing seUn_ originç¡l~ell. - - - - - - 121CMT vol adequate to tie-in Jong _string to surf ~g _ _ _ _ _ _ _ _ _ NA _ Produ.ction c:.asing set in_origiOal welJ. - - - - - - - - 22CMTwill coyera!1 klJo.wnpro_ductiye borí;!:ons_ _ No _ _ _ SlottedJiner_completloo p1aoned. 23C_asiog designs adeQuate for C,T, B_&permafrosl Yes - - - - - - - - - - - - - - - - - - - - - !24 _Mequatet<lnkage_one_serve pit _ _ _ _ _ Yes _ _ _ Rig jSßquippedwith steeLpits. No resel'lle_pjtplaOlJed. All wa$te to Class JI wells. 25 Jtare-drilt has a 10~4_03 for abandonment beeo aPPJoved Yes _ _ _ 3Q5:O~2 - - - - - - - 26 Apequate_~ellbore.separatjo_nproPO$e~L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _Pro~imity'¡:¡nalysispe.rforme_d, Jf-j)1Ais_oOlypro~imalewellbore_appro?<imale[y_50'Jvd_be!0w_aH<içk.off._ - - -- 27 Jtdivecter reqJJired, does it meel reguJaJiOlJs _ _ _ _ _ NA _ _ _ aop stack. wilJ already_bein plç¡ce, - - - . - - - - - - - - - - - - Appr Date 28 _DJilliog flujd Rrogram schematic_& eQ-uip Jisladequate _ _ _ _ _ Yes _ _ _ Maximum expected BI-I~ 1 t,2 EMW PJa_nned_ MW _8, 7_ Rpgba$eJtuip with Þackpressure_ to overbalance. fO!JTlation. TÄ-~~;r5 ~~:~;~s~r:::~:~:e:;;~:;li:::;nt~st lo_{put p$ig incomment~)- : - - ~:: _ _ _ MAS~ cal~u¡ated_at 28HPsi: 35QO psi appropriate. Plani~ lotest loA50Q psi. - - - - - - - - - - - . . 31 _C_hokemanjfoldçompJiesw/APtR~-53(May64) ______ Yes ----- ------ ---------------- ----- 32 Work will occur withouloperation _shu.tdo_~n_ _ Yes - - - - - - - - - - - - - - 33 Js presence of H2S g<ls_ Rro"-aþle _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 1:i2S hasÞeen reported on 1 F: pad. Mud sho_uld_preclude 1:i2S on rjg. Rig is equ.iRped with_ sensors and_a!arm$. 34 MecbanicaLcoodJtlon of wells within AOR yerified (For service welJ only) NA Geology 35 Pe(mit c_a(l be issued wlo hydrogen s_ulfide meas).Jres. _ No. 36D_ata_PJeseoted Qn_ pote_ntial overRres_surezone$ _ . . . . _ _ _ NA Appr Date 37 _Seismic_analysis Qf sbaJlow gas_zooes_ _. _ _ _ _ _ _ _ _ . _ _ _NA RPC 2/28/2005 38 _Seabedconditioo su.rvey{if Qff-$h9re) . _ . . _ _ _ .NA 39 _ CQntact namelphoneJor_~eekly progress_reports [expIQrato(y _only]NA GeOlOgic) Engineering = c;,p ;,Io( Comml~ooe, D.te ?~J _ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infomlation, infonnation 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. . . **** REEL HEADER **** LDWG 06/12/15 AWS 01 **** TAPE HEADER **** LDWG 15/12/06 01 :""0, 0\.4..." l... t Jf RECEIVED DEC 2 8 2006 -'01 & Gas Cons. Commission Anchorage *** LIs COMMENT RECORD *** !! !! ! " ! !! ! ' ! " ! ", LV"G File Version 1. 000 " " " !' "!! " " ,,! Extract File, LISTAPE,nED TAPE HEADER KUPARUK RIVER UNIT .MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: F'WL : ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING . . '~.,.- r-""::>~\ (NO -.. ~ÇÝ ;PI./. /':;?þ. 7(.;c'<..J IF-OIALl 500292088960 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 15-DEC-06 .MWD RUN 23 23 E. AGUIRRE G. GOODRICH .MWD RUN 26 26 S. TUFTON M. FEKETI .MWD RUN 24 24 S. TUFTON c. SEVCIK MWD RUN 27 27 E. AGUIRRE C. SEVCIK .MWD RUN 25 25 E. AGUIRRE G. GoODRICH 19 11N 10E 119.80 00.00 00.00 OPEN HOLE BIT SIZE (IN) CASING SIZE (IN) 10.750 7.000 DRILLERS DEPTH (FT) 2630.0 6232.0 . . 3RD STRING PRODUCTION STRING 4.500 8336.0 10216.0 4.25 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 49.903" LONG: W149 DEG 40' 45.817" LOG MEASURED FROM K.B. AT 119.8 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are real time data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, and vibration stick-slip), a Gamma and Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC (7) through a milled window for well 1F-01AL1. The 1F-01AL1 wellbore was drilled from 1F-01APB1 in 4.5" liner. Top of window 8145 ft. MD (5838 ft. SSTVD) Bottom of window 8151 ft. MD (5842 ft. SSTVD) The interval from 10178 ft. to 10216 ft. MD (5899 ft. to 5906 ft. SSTVD) was not logged due to (8) bit to sensor offset. (9) The 1F-01AL1 wellbore was tied to 1F-01 at 8022 ft. MD (5754.9 ft. SSTVD). (10) The interval from 8183 ft. to 8350 ft. MD (5858 ft. to 5862 ft. SSTVD) was recorded in a MAD PASS. $ Tape Subfile: 1 83 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 . . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!! !!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8151. 0 STOP DEPTH 10216.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 23 24 25 26 27 MERGE TOP 8151. 0 8320.0 8605.0 9559.0 10074.0 MERGE BASE 8320.0 8605.0 9559.0 10074.0 10216.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1F-01AL1 5.xtf 150 ConocoPhillips Alaska, Inc. IF-01AL1 Kuparuk River North Slope Borough Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) . . Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 115 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8151.000000 10215.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 159 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!! !!!!!!!!!!!!!!!! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY 2 log header data for each bit run in separate files. 23 .2500 . VENDOR TOOL CODE START DEPTH MWD 8151.0 $ STOP DEPTH 8320.0 # 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 MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. RESIST. GAMMA RAY DIRECTIONAL # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 06-JUN-05 ADVANTAGE 3 CTK MEMORY 8349.0 8151. 0 8320.0 o 48.4 94.8 TOOL NUMBER 10023579 1068825 10079128 4.25 8151. 0 FIo-Pro 9.20 .0 .0 100000 .0 .000 .000 .000 .000 104.0 .0 .0 .0 .00 .000 .0 o BIT RUN 23 (MWD Run 23) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU . . WDFN LCC CN WN FN COUN STAT IF-OIALl.xtf 150 ConocoPhillips Alaska, I IF-OIALI Kuparuk River North Slope Bora Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 19 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8151.000000 8320.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 101 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes . **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 24 .2500 START DEPTH 8320.0 STOP DEPTH 8605.0 # 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 MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 06-JUN-05 ADVANTAGE 3 CTK MEMORY 8637.0 8320.0 8605.0 o 88.2 101.7 TOOL NUMBER 10023579 1068825 10079128 4.25 8151. 0 Flo-Pro 9.3 .0 .0 100000 .0 .000 .000 .000 .000 106.0 .0 .0 .0 .00 . . HOLE CORRECTION (IN): .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 24 (MWD Run 24) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT IF-OIAL1.xtf 150 ConocoPhillips Alaska, I IF-OIALI Kuparuk River North Slope Boro Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 . 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 32 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8320.000000 8605.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 114 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!! !!!!!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 25 .2500 START DEPTH 8605.0 STOP DEPTH 9559.0 # 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 MPR GRAM DIR BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. 08-JUN-05 ADVANTAGE 3 CTK MEMORY 9591. 0 8605.0 9559.0 o 88.2 94.5 TOOL NUMBER 10023579 1068825 10079128 . $ # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 4.25 8151. 0 Flo-Pro 9.3 .0 .0 100000 .0 .000 .000 .000 .000 121. 0 .0 .0 .0 .00 .000 .0 o BIT RUN 25 (MWD Run 25) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1F-01AL1.xtf 150 ConocoPhillips Alaska, I 1F-01AL1 Kuparuk River North Slope Boro Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 . . Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 107 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8605.000000 9559.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 189 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 5 log header data for each bit run in separate files. 26 .2500 START DEPTH STOP DEPTH . MWD $ 9559.0 10074.0 # 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 MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 09-JUN-05 ADVANTAGE 3 CTK MEMORY 10106.0 9559.0 10074.0 o 83.0 89.8 TOOL NUMBER 10023579 1068825 10079128 4.25 8151. 0 FIo-Pro 9.2 .0 .0 100000 .0 .000 .000 .000 .000 123.0 .0 .0 .0 .00 .000 .0 o BIT RUN 26 (MWD Run 26) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1F-01AL1.xtf . . LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska, I IF-OIALI Kuparuk River North Slope Boro Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 58 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9559.000000 10074.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 140 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** . LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 . log header data for each bit run in separate files. 27 .2500 START DEPTH 10074.0 STOP DEPTH 10216.0 # 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 MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-JUN-05 ADVANTAGE 3 CTK MEMORY 10216.0 10074.0 10216.0 o 79.3 80.1 TOOL NUMBER 10023579 1068825 10079128 4.25 8151. 0 Flo-pro 9.2 .0 .0 100000 .0 .000 .000 .000 .000 117.0 .0 .0 .0 .00 .000 . . # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 27 (MWD Run 27). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT IF-OIALI.xtf 150 ConocoPhillips Alaska, I IF-OIALI Kuparuk River North Slope Bora Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 . 5 6 RACH MWD ROPA MWD 68 68 1 1 OHMM FPHR Total Data Records: 16 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** 10074.000000 10215.250000 0.250000 teet Tape Subtile: 7 98 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 15/12/06 01 **** REEL TRAILER **** LDWG 06/12/15 AWS 01 Tape Subtile: 8 Minimum record length: Maximum record length: 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes . 4 4 4 4 ------- 24