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Home My WebLink About202-187Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 2021870 E-Set: 34564 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 2021870 E-Set: 34563 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6633'feet N/A feet true vertical 6091'feet N/A feet Effective Depth measured 6413'feet 6272'feet true vertical 5874'feet 5735'feet Perforation depth Measured depth 6388'-6413' feet True Vertical depth 5849'-5874' feet Tubing (size, grade, measured and true vertical depth)3.5 L-80 6304' 5766' Packers and SSSV (type, measured and true vertical depth)Packer Baker SAB-3 6272' 5735' SSSV N/A 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 11/19/2020 Contact Phone: N/A Authorized Name: Authorized Signature with date: ----- ----- N/A Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Production 6653'7"6623'6081' Surface 2799'9.625"2769'2580' Conductor 138'16"108'108' true vertical Casing Length Size MD TVD Junk measured Burst Collapse 202-187 50103204300000 ADL0380107 KRU 3S-07 P.O. Box 100630, Anchorage, Alaska 99508 N/A Kuparuk River/Kuparuk River Oil Plugs measured Packer measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: t Fra O 6. A G L PG R h Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:51 pm, Nov 19, 2020 Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.11.19 14:06:34 -09'00' RBDMS HEW 11/20/2020 DSR-11/19/2020 SFD 11/24/2020VTL 2/17/21 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 19, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 3S-07 (PTD 202-187). Please contact Jan Byrne or me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.11.19 14:05:51 -09'00' Event Summary Executive Summary Installed a retrievable tubing patch over tubing leak at 6235'. Date 10/28/20 (AC EVAL) MIT-T (FAILED TO 3000 PSI) CMIT-T X IA (PASSED TO 3000 PSI) T X IA LLR (8.4 gal/min) CDDT T X IA (PASS) 11/04/20 LOG SPINNER TEMP. LDL FROM 2.75" CA-2 PLUG @ 6296' RKB TIE INTO TBG TALLY, LOG TO SURFACE PUMPING @ .25 BPM @ 2550 PSI FIND LEAK @ ~6235' RKB NO OTHER LEAKS OBSERVED. COMPLETE 11/07/20 PULLED 2.75" CA-2 PLUG BODY @ 6296' RKB, TAG W/ GAUGES @ 6413' RKB MEASURED BHP @ 6400' RKB, BRUSH n' FLUSH TBG FROM 6278' RKB TO 6228' RKB, ATTEMPT TO SET LOWER PACKER @ 6240' RKB POSSIBLE WEAK IGNITER FAILED TO FIRE POWER CHARGE (3 HRS NPT), SET LOWER 2.72" P2P @ 6240' RKB (ME) (OAL 4.01' / SN:CPP35105). IN PROGRESS 11/08/20 CMIT TBG x IA WITH 3 1/2 TTS TEST TOOL IN LOWER PACKER @ 6240' RKB (PASS), SET UPPER 2.72" P2PPATCH ASSEMBLY @ 6230' RKB (OAL 10.86' / SN:CPP35275 / CPAL35103), MIT-IA 2500 (PASS). JOB COMPLETE. PRE CMIT T/I/O= 859/340/350, PRESSURE UP SEVERAL TIMES TO EQUALIZE TBG & IA (1.7 BBLS) T/I/O= 2650/2250/390, 15 MIN T/I/O= 2550/2200/390, 30 MIN T/I/O= 2550/2200/390 ***PASS*** BLEED BACK PRESSURE LRS RIG UP TO IA PRE MITIA T/I/O= 775/325/340, PRESSURE UP (1.4 BBLS) T/I/O= 775/2550/390, 15 MIN T/I/O= 775/2500/390, 30 MIN T/I/O= 775/2490/390 ***PASS*** Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,413.0 11/7/2020 3S-07 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set TBG patch 11/8/2020 3S-07 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 28.8 Set Depth (ftKB) 2,769.4 Set Depth (TVD) … 2,580.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.2 Set Depth (ftKB) 6,623.2 Set Depth (TVD) … 6,081.1 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.1 Set Depth (ft… 6,304.0 Set Depth (TVD) (… 5,766.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.1 26.1 0.12 HANGER FMC TUBING HANGER 2.992 497.2 496.7 5.47 NIPPLE CAMCO DS NIPPLE w/ 2.875" NO GO 2.875 6,210.5 5,674.9 13.21 SLEEVE BAKER CMU SLIDING SLEEVE w/NO GO PROFILE 2.813 6,257.4 5,720.6 12.20 PBR BAKER 80-40 PBR 3.000 6,271.1 5,734.0 11.91 ANCHOR KBG-22 ANCHOR TUBING SEAL NIPPLE 2.993 6,272.0 5,734.9 11.89 PACKER BAKER SAB-3 PACKER 3.250 6,276.9 5,739.7 11.78 MILLOUT EXT BAKER 80-40 MILLOUT EXTENSION 3.730 6,296.1 5,758.5 11.37 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO 2.750 6,303.1 5,765.4 11.22 WLEG WIRELINE ENTRY GUIDE w/ SHEAR OUT SUB, 5" OD 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,230.0 5,693.9 12.79 PACKER - PATCH - UPR Upper patch assembly consisting of P2P packer, xo.spacer pipe, & anchor latch (OAL 10.86') 11/8/2020 1.625 CPP35275 6,234.0 5,697.8 12.70 Spacer Pipe Spacer pipe. Length included in upper patch assembly 11/8/2020 1.600 CPAI 6,235.0 5,698.8 12.68 LEAK - TUBING Tuging leak found with Relay 11/04/20 11/4/2020 0.000 6,240.0 5,703.6 12.58 PACKER - PATCH - LWR Set P2P packer (OAL 4') 11/7/2020 1.625 CPP35105 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,388.0 6,413.0 5,848.9 5,873.6 C-4, 3S-07 11/26/2002 6.0 IPERF 1.5" HSD PJ 2506, 60 deg phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,791.9 2,600.4 Camco KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 8/15/2007 2 4,065.3 3,727.5 Camco KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 8/10/2019 3 4,992.7 4,549.1 Camco KBUG- M 1 GAS LIFT DMY BK 0.000 0.0 8/10/2019 4 5,639.1 5,132.8 Camco KBUG- M 1 GAS LIFT DMY BK-5 0.000 0.0 11/21/2002 5 6,158.6 5,624.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/17/2019 Notes: General & Safety End Date Annotation 4/27/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 3S-07, 11/9/2020 8:40:09 AM Vertical schematic (actual) PRODUCTION; 26.2-6,623.2 IPERF; 6,388.0-6,413.0 WLEG; 6,303.1 NIPPLE; 6,296.1 TUBING COLLAR; 6,282.5 MILLOUT EXT; 6,276.9 PACKER; 6,272.0 ANCHOR; 6,271.1 PBR; 6,257.4 PACKER - PATCH - LWR; 6,240.0 Spacer Pipe; 6,234.0 LEAK - TUBING; 6,235.0 PACKER - PATCH - UPR; 6,230.0 SLEEVE; 6,210.5 GAS LIFT; 6,158.6 GAS LIFT; 5,639.1 GAS LIFT; 4,992.7 GAS LIFT; 4,065.3 GAS LIFT; 2,791.9 SURFACE; 28.8-2,769.4 NIPPLE; 497.2 CONDUCTOR; 28.0-108.0 HANGER; 26.1 KUP PROD KB-Grd (ft) 33.37 Rig Release Date 11/21/2002 3S-07 ... TD Act Btm (ftKB) 6,633.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032043000 Wellbore Status PROD Max Angle & MD Incl (°) 29.98 MD (ftKB) 1,998.79 WELLNAME WELLBORE3S-07 Annotation Last WO: End DateH2S (ppm) 45 Date 12/21/2014 Comment SSSV: NIPPLE 11/28106 Sc~lIIIIbepgep NO. 4054 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NOV ~, ~) zmJ{) comml$8ion Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 DOd -1157- Field: Kuparuk Well Job# Log Description Date BL Color CD 3B-13 11415652 PROD PROFILE W/DEFT 11/16/06 1 3&-07 11502019 SBHP SURVEY 11/19/06 1 3S~1 0 11502020 SBHP SURVEY 11/19/06 1 1 E-24A 11502021 SBHP SURVEY 11/20/06 1 1 Y -23 11502022 PROD PROFILE W/DEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-09 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê,Jk-- ~ . . . ~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 7, 2006 :~ ~.~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 aOd-.- \ C67 3 g, - 07 !) Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on November 18, 2003 and was previously reported to the Commission as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 4 -5,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7043, if you have any questions. Sincerely, J ~f~ ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field August 7,2006 Well Name Initial top Vol. of cement Final top of Cement top PTD # of cement urn ed cement off date ft bbls ft Corrosion inhibitor/ sealant date 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 8/5/2006 --~--~~-<~ - Permit to Drill 2021870 REQUIRED INFORMATION MD 6633'/ < .u____~__~._ _~.____~_______ _._----~---~ - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number D D /' 41520 ;;;z to tL~ ~ '-1 DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. KUPARUK RIV UNIT 3S-07 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20430-00-00 -- -- -~--'---- - ---. ----- TVD 6091- Completion Date 11/26/2002-/ Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Directional Survey Yes 1~. (data taken from Logs Portion of Master Well Data Maint) ~/ Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 0 6633 Open 12/13/2002 1 0 6633 Open 12/13/2002 1 181 6594 Case 2/18/2003 1 181 6594 Case 2/18/2003 5 Blu 80 6459 Case 2/14/2003 5 Blu 80 6459 Case 2/14/2003 5 Blu 80 6459 Case 2/14/2003 5 Blu 80 6459 Case 2/14/2003 Sample Set Sent Received Number Comments ~ GR/Res, Dens/Newtron Name Directional Survey Directional Survey LIS Verification LIS Verification Production Pressure Temperature Gradiometer Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y €J Chips Received? Y I N Analysis Received? Comments: ~- ------~------_._-~--~- ~ - .~_._-------- -----------~----~--- ----. -~-- ----~- ---------- <--~------_._-_.~-- DailyiHistbryReceived? cfJN &/N Formation Tops Permit to Drill 2021870 MD 6633 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. KUPARUK RIV UNIT 3S-07 Oper~tor..CONOCOPHILLlPS ALASKA INC 6091 1-01L Current Status 1-0IL, UIC N Date: Co çJ ~ ~~ ~ 11/26/2002 Completion Status API No. 50-103-20430-00-00 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic 0 Service 0 6. Permit to Drill Number: 202-187 ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 7. Well Name: 38-07 2. Address: 4b. Well Status: Oil 0 Gas 0 WAGD 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ 0 WINJ 0 WDSPL 0 50-103-20430-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal 0 or Continuation of Disposal 0 302-361 12/6/2002 Kuparuk River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred .~j fluids, formation fluids and any necessary water added Previous 216* 216 totals (bbls): 2002 / 4th 18155 100 0 18255 20 12/9/2002 12/31/2002 38-09, 38-14, 38-10 2003/1 st 13415 100 0 13515 14 1/1/2003 1/15/2003 38-10,38-15 YYYY /0# YYYY /0# ..... --. Total Ending Report is due on the 20th ~;)' Volume 31570 200 216 31986 34 (bbls): of the month foJ/owing the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Step Rate Test 0 October 20 for the third quarter, and January 20 for the Other (Explain) 0 fourth quarter. 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ Date: \/~(oy Printed Name: ~~-J. T\L...~ """'-J" Title: '\Jcr-lù -C- ~ _ L.c.-J Phone Number: GGS--6'83~ Form 10-423 Rev. 9/2003 INSTRUCTIONS ON RFVFR~F ~In¡:: -. -.' - .. Conoc~hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ) Ii~C~/J i I.·", VF:;" 4I~tI1O¡l.~.'n_· 0 ,12{}O;l..I ~ VfJ8 ~ ~, Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on November 18,2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high-pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. ;%/?¿ MJ ~an: . ConocoPhillips Problem Well Supervisor Attachment :Co\. '\ ",:) f'<:)~ ~ ~,~C""\. ~'" ~,'-<Z. ~~\-- +0 Cr k\\ 'ov.-c... \.:.." <::A-~~ b~~~ '>~<!:. ""s'£,.ù \\..../ ,~f\>.,.«. r-.~d -\0 s.",~. À \ \ oç -\-4. "T<J (.:' ~-\-'"' s ~~ 'VCè..t-'1 f""\Q..G\ +'-'<ë Sù~~. ~O.ÇÙ'-\-"'CL' a..c...\\o~ t'\Ct.ct.~{)..'' ß)!¥?\~ f..-å~ · -;." ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field Well Well Toe Volume Sacks Name PTO# Type ft BBLS Cement 3S-03 2030910 Prod 8 0.6 3.6 3S-07 2021870 Prod 8 1.5 9.1 3S-09 2022050 Inj 14 2.5 15.1 3S-10 2022320 Prod 12 1.5 9.1 3S-14 2022210 Inj 3 1.5 9.1 3S-15 2022540 Prod 8 0.8 4.8 3S-17 A 2030800 Prod 12 1.1 6.6 38-18 2022060 Prod 10 1.1 6.6 3S-19 2030960 Prod 5 1.1 6.6 38-21 2030310 Inj 5 0.5 3.0 38-22 2030110 Inj 7 0.9 5.4 38-23 2030450 Prod 2 0.3 1.8 Annular Disposal during thefirstquarter of2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-18 31501 100 0 31601 306 0 31907 January March 3S-15,3S-16,3S-22,3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 ) 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21, 3S-08 2003 2003 1C-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 TotaÍ Volumes into Annuli for which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 150 372 52 Start End Date Date April 2002 May 2002 October Dec 2002 2002 March 2002 April 2002 Total h(l) Total h(2) Total h(3) Well Name Volume Volume Volume 2P-420 9479 100 0 CD2-34 22895 100 0 Status of Annulus Open, Freeze Protected Open, Freeze Protected 9729 23367 31333 Open, Freeze Protected 2P-415A 31181 0 100 CD2-26 CD2-49 29146 27474 0 0 380 386 29626 27960 Open, Freeze Protected September October 2002 2002 April 2002 May 2002 100 100 Open, Freeze Protected Source Wells 2P-427, Heavenly CD2-13, CD2-37, CD2- 35 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-13 CD2-50, CD2-46, CD2- 22 ) ~ECEIVED APR 1 6 Z003 Qj ~ ( - Alaska Oil & Gas Cons. Commission Anchorage 0« ~ " t:xJ Annular Disposal during the first quarter of 2003: '"""-- h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells ((j Well Name Volume Volume Volume Quarter. Protect Total Total Date Date Ü Volumes ra 38-18 31501 100 0 31601 306 0 31907 January March 38-15,38-16,38-22,38-08 2003 2003 38-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 38-10,38-15,38-09,38-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 ,( CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2~08, CD2-36, CD2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 38-21,38-08 2003 2003 1 C-22 26944 100 0 27044 0 0 27044 March March lC-190, lC-174 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during thefirst quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 CD2-13, CD2-37, CD2- 2002 35 ( 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October CD2-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 CD2-50, CD2-46, CD2- 22 , Ancoor Nipp~ (6271-6272, OD:4.74O) PACKER (õ2.72.fr2.77, OD:5.956) Perf (6383-6413) ) ) ~ 03 -1<67 . c.. :.... ...... .,.. .'P..h.II..li'.'...'. .À;I..'.~.. I. ..... .. .. ':.. 'pnqç'. .::..:...:\..:p.:'~ :~~"..:; .I!.~.~ '.::.:. .., ::',;!. Q :: ~~5 ,".,: .:')' q. ~ KRU 38-07 3S-07 API: 501032043000 SSSV Type: Nipple Well Type: PROD Orig 11/21/2002 Completion: LastW/O: Rev Reason: Tag fill, pull CR Lock/GauQes Last Update: 1/29/2003 AnQle (á} TS: 1 0 deQ @ 6388 Angle @ TO: 9 deg @ 6633 Annular Fluid: Ref Log Date: TO: 6633 ftKB Max Hole Angle: 30 deg (á} 1999 Reference Log: RKB 24.10' LastTaQ: 6307 Last Tag Date: 1/22/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size I Top . 3.500 0 Perforations Summary Interval TVD 6388 - 6413 5849 - 5874 Top Bottom TVD Wt Grade Thread 0 108 108 62.50 H-40 WELDED 0 2769 2580 40.00 L-80 STCM 0 6623 6081 26.00 L-80 STCM TVD I Wt I Grade I Thread 5767 9.30 L-80 EUE8RD Status Ft SPF Date Type Comment 25 6 11/26/2002 IPERF 1.5" HSD PJ 2506, 60 deg phasing I Bottom 6304 Zone C-4 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2790 2598 CAMCO KBUG-M 2 4063 3725 CAMCO KBUG-M 3 4991 4548 CAMCO KBUG-M 4 5637 5131 CAMCO KBUG-M 5 6157 5623 CAMCO MMG Other ('lugs, equip., etc.: - JEWELRY Depth TVD Type 24 24 HANGER 495 495 NIP 6209 5673 SLEEVE-C 6257 5720 PBR 6271 5734 Anchor Nipple PACKER BAKER SAB-3 PACKER EXTENSION 4.5" 80-40 MILLOUT EXTENSION NIP CAMCO '0' NIPPLE WITH NO GO PROFILE WLEG BAKER PUMP OUT SUB TIL V Mfr V Type V 00 Latch Port TRO Date Vlv Run Cmnt 0 11/21/2002 0 11/21/2002 0 11/21/2002 0 11/21/2002 0 11/24/2002 OMY OMY DMY OMY DMY 1.0 BK-5 0.000 1.0 SK-5 0.000 1.0 BK-5 0.000 1.0 SK-5 0.000 1.5 RK 0.000 Description FMC 3.5" GEN 5 TUBING HANGER w/EUE 8RD CONNECTION CAMCO 'OS' NIPPLE WITH NO GO PROFILE BAKER CMU SLIDING SLEEVE - closed BAKER 80-40 PBR BAKER KSH-22 ANCHOR TUBING SEAL ID 3.500 2.875 2.813 3.000 2.993 6272 5735 6277 5740 6296 5759 6303 5766 6304 5767 General Notes Date Note 11/21/200~ TREE: FMC/GEN5/S TREE CONNECTION: TOP 5.75" ACME Wf3.5" EUE8RD THREAD 2.992 3.730 2.750 3.000 2.992 RECE'VED N1AR 1 4 2.003 Alaska or¡ & Gas Cons. eommi8eioo Anchorage ) ) Casing Detail 9 618" Surface Casina 8~~~~~~~!L,!s-J~~~~'~EY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 46 to 70 Nabors"7ES RKB to Landing Ring FMC Gen V Hanger 9-5/811 40# L-80 BTC Csg TAM Port Collar 40# L-80 BTC 9-5/811 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/811 40# L -80 BTC Gsg Davis Lynch Float Shoe 25 Jts Jts 3 to 45 43 Jts Jts 1 to 2 2Jts TD 12 1/4" Surface Hole RUN TOTAL 14 BOWSPRING CENTRALlZERS- 2 on it. #1 (10' up across stop ring and over collar) 1 on Jt. ##2 (across stop ring 10 . below FC) 1 per jt on Jt #3 . #13 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 160k Dn Wt - 130k Block Wt - 70k Well: 38-07 Date: 11/13/2002 LENGTH 28.80 2.20 969.34 3.00 1681.08 1.48 81.74 1.71 Supervisor: David Buffey DEPTH TOPS 28.80 31.00 1000.34 1003.34 2684.42 2685.90 2767.64 2769.35 2776.00 Itlft~1::r'-;:"'~': ,. ') ) .;..';";;~~~~~lij~t~~U~:~f':":.,:,.,'.:',...~,:':,..,.. ,.: ' ' ~", . '. I' , . l.' , . ;", . . Legal Well Name: 38-07 Common Well Name: 38-07 Event Name: ROT - DRILLING ! :", . .-::' '::.... ::. .'- ~ ..., . ,- :-prlmary': 12.250 (in) 2,767 (ft) 11/13/2002 Surface Casing 9.625 (in.) . . Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Cmtd. CS9: Surface Casing Cement Co: Dowell Schlumberger ,:"',:~~¡~'I, " "',} ;7:~;:~':~';;;i!\1, .) :~,.::~'" ; ~ , :. " . ., Report #: Start: 8pud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 . " - ~.~.~.,nt:J.Ob type:. Rr.ì~ar.v:.'. , -' ,. -:,.. -:', S.queeze,ôpen ~ole.. . :.. ß~~Ei~ieëa5hg Hole Size: Hole Size: sa TMD: (ft) TMD Set: sa Date: Date Set: sa Type: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos ;, Cmtd. Csg: , . ro,' I, '-,',..:.,',," r, ..: ., . Plug .' Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Rot Time Start: : Time End:: RPM: Rec Time Start:20:00 Time End: 00:30 SPM: 1 In it Torque: (ft-lbf) Stroke Length: 20.0 (ft) Avg Torque: (ft.lbf) Drag Up: 150 (Ibs) Type: Cement Casing Volume Excess %: 250.00 Meas. From: 45 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 336 (gpm) Mud Circ Press: 430 (psi) ~. ~~ .- - . .. :': . ,stage No: 1 of 1 Start Mix Cmt: 22:43 Start Slurry Displ: 22:44 Start Displ: 00:14 End Pumping: 00:44 End Pump Date: 11/15/2002 Top Plug: Y Bottom Plug: Y . '.,: '-'. I,. Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) N 315 (psi) (psi) (min) Y Max Torque: (ft-Ibf) Drag Down: 11 0 (Ibs) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 45.00 (bbl) Ann Flow After: N Mixing Method: Dir blow Density Meas By: densometer . -- Type: Spud Mud Density: 9.8 (ppg) Vise: 75 (s/qt) Bottom Hole Circulating Temperature: eF) Displacement Fluid Type:Mud PVIYP: 34 (cp)/31 (lb/100ft2) Gels 10 see: 10 (lb/100ft2) Gels 10 min: 17 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 204.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) . . .:M lid J;>~ta: --. . ...'",\~;\i¡,):r~J)~~þ~~9;'i,~~i{~!~,~:,~B~ff¡'~'." . ~ ". L ",--, To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: 50.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11:27:30 AM ") ) ...,.' .,'"' .. .,.","i!¡;~ti:~;if~í¡f";:"'..., ; ').' '. ~ . I ' . I . , ~ft"~~~: r¡'>'.i ;..; ,'; "":'.. ,,:,'f~~;;'''~~J\t.' ..., ,... . : '., . I':' .': ,,,: . ~ ':. . \ - .' . ~ ...:, ':. .,'. :/~.< '.. ,:':" ' .~.. .:.. :',1' : Legal Well Name: 3S-07 Common Well Name:, 3S-07 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: , . "~it,,' "~'('~~~~;~~,¡ '.. Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 1 0/29/2002 End: 11/22/2002 :, Stage No: 1SlurryNo:2of 4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) (OF) Stage No: 1 Slurry No: 3 of 4 Slurry Data Fluid Type: LEAD Description: ASLite Class: Slurry Interval: 1,605.00 (ft}To: 29.00 (ft) Cmt Vol: 432.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Source: Lake water Slurry VoIS90 (sk) Water Vol: 280.0 (bbl). Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: , .: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) (OF) - $ta.ge No: 1 Slurry No: 4 of 4 . Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,769.00 (ft}fo: 1,605.00 (ft) Cmt Vol: 74.0 (bbl) Water Source: lake Slurry Vol220 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 38.0 (bbl) Other Vol: () Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) (OF) . .', .J,,! Purpose: Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: 7.45 (gal) Foam Job: N Pressure (psi) (psi) Printed: 11/23/2002 11 :27:30 AM ) ) Legal Well Name: 3S~07 Common Well Name: 3S~07 Event Name: ROT ~ DRILLING Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 .:'i":ç,:~~,ri~fT~st' ., Test Press: (psi) For: (min) Cement Found between Shoe and Collar: '. ", ': ;,). - ,".:Shòe..Ì"est . ...:>",.Linèr' TbPT~st... ,. ; ", . . Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: ,Log/Survey .i:valuation Interpretation" Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: ;~':-:' . ftemarks . Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chem Wash, Dropped 8tm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt. Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 8pm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs. Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm /350 psi. Dropped top plug - cementers displaced with 20 bbls FW - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untlll last 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. Printed: 11/23/2002 11:27:30 AM ') WELL NAME 38-07. II JOB NUMBER 'I EVENTODCRODE 1124 HRS PROG TMD I'TVD " DFS 2,776.0 2,586.0 5.00 SUPERVISOR I RIG NAME &. NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG David Burley/Peter Wi/so N1268@ppco.co Nabors 7E8 Kuparuk River 6,611.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD ND Divertor 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL NU Wellhead & BOPS, Test BOPE, PU 81/2" Drlg Assembly 11/11/2002 312,453 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE . WCD.K3S.0045.01 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXTCASING 11/12/2002 2,701.33 25.450 54.050 16.000 (in) @ 108.0 (ft) 9.625 (in) @ 2,770.0 (ft) _'~E~$!fi(p~~) ~:I 9.80 I pp I IE~DI MUU'Ð.AiA! 'DAIÙ~COST 'I 0.00 I CUM'CO~T I 0.00 :-' ~V:', .PVr(P -GELS WUHTHP' .FcmSOL - 'OiuWAT - %saridIMaT . . Ph/pM. Pf/Mf CI. Ca - H2S . LIME ES 75 34/31 10/17 5.0/ 2/ / 121.0 / 1 . ~H~;~o.:.1 . 2 L. :.BHA:WT. BI:LOW JARS' REPTNO. I DATE 13 11/13/200Z I CUM. TANG 0.00 CUM INT ANG WI MUD 0.00 CUM COST WI MUD 1,533,678 AUTH. 2,484,894 LAST BOP PRES TEST STRING WT. UP . SHA I HOl;E 'CONDITIONS. I ~ITNO: I 2 STRING WT. DN SIRING .Wt. flCT TORQUE/UNITS BHA LENGTH 930.45 NOJ1S LENGTH a.D. I.D. CONN SIZE CONN TYPE 1.20 12.250 4.000 1 29.28 8.000 5.250 1 2.24 8.000 2.500 1 6.03 8.000 2.810 1 5.26 8.000 2.875 1 22.84 8.000 2.900 1 9.20 8.000 3.450 1 25.13 8.110 2.900 1 9.94 8.000 2.815 1 2.77 7.750 2.750 3 90.42 6.500 2.813 9 272.23 5.000 3.000 1 31.71 6.250 2.750 14 422.20 5.000 3.000 fTEM DESCRIPTION Bit Mud Motor Float Sub Pony Collar - NonMag Stabilizer LWO GRlRES MWD OIR LWO DEN/NEU MWD HOC Crossover Flex Collar - NonMag Drill Pipe - Heavy Wgt Hyd Jars Drill Pipe - Heavy Wgt ~~~V~~~~f;:;~1t~JtË'''; .,,;;~~~~~:JXTi~;,~:X~;~~~f;;~.~Brt~;;~Òijé#~;': .... DE~\~:~~~j~" ',.... .:L~.;;¡;Q'«\'ó..l\ . 1/ 1 12.250 HTC MX-C1 5012523 24/24/24/10/1 228.0 11/9/20020-0---- 2/ 1rr1 12.250 HTC MX-C1 5012523 24/24/24/101/ 228.0 11/9/20022-3-WT-A-E-1-NO-TD ~~~~~~~~T~;\~J~";)~fz.~~~~i':1!;~~:i:j:~~¡¡~~j~rl~t~~~~~1~~¡¡.~~4Ht~~Þ~i'~#~~~~¡~~iili'í'~'J~;~~: ;~I;'°i;~~;YwJ&ij~'~~Jd¿~j~:~6~~(r'n~ri~1{~~~~!1~~~~~~~gr~;;.'\' .,p~¡è~;p~(iij" ..,.' ."'.. 00:00 02:00 2.00 DRILL P TRIP SURFAC Fin POOH to Flex Collar & LD Collar 02:00 05:30 3.50 DRILL P TRIP SURFAC Pulled Sperry Suns Nuclear Source, Downoad MWD, LD MWD & 1.5 deg MM & 12 1/4" Bit RURD SURFAC RU Nabors Csg Tools and GBR Fill-up Tool. RURD SURFAC Made dummy run with Hanger & Landing JT, had to center twenty inch riser to rotary table to allow centralizer on landing joint to pass. SFTY SURFAC Held Safety Mtg on Running of 9 5/8" Csg RUNC SURFAC MU 95/8" Flaot Shoe, 2 Jts of 95/8" 40# L-80 BTC Csg, Float Collar, Tested 05:30 08:00 2.50 CASE P 08:00 09:00 1.00 CASE Np EQIP 09:00 09:30 0.50 CASE P 09:30 16:00 6.50 CASE P Printed: 11/23/2002 11:28:57 AM ') ) t .¡, .' ':.~".i";. '.',. .., . ... ,.. ... "/i;::,.:'.:::.. ,.,::,;:d",;'''..:'.:'¡';'.l:.;;;:~i:\%~;~~1J.~j(),: ~;;¡\f;:.:,c"". ",. '..'" ... ,);: /;. \; ':,;;t/'.,::,. .'.,.,.:':.:... .,..:.:,'.(~.:...:..:".':.'.'.:.,::..'::.'.:.~,t:~,...b::.'.~..:.;:.'.:,:.:::,'..'...';;:':'::O:::'.'.'m::.~'.."'...¡:~.'J.'.H::...~:,,::..\,-:..::::~:O::.""I:,::"..'.I.....:.,ðtf.y:.:'.':.~:..:.."'..~:r,'~..,::...,..:iD:~.';...:...~.:.'::.::.~.',..~:::ì..,::.~.ß::':.'..:i"::.~;.'::.:..1~,:,:'l¡':."'~:."¡;lr..:;...J';"'n.'..',..:~.t,.....,:.:.:':.'..'.'P'..'...~g.'.:..~......;:~.:::.,I"...:...:.:":-'..::R'.:.:::.,...:,..:,:..'.:......A~~::"...'..Þ'.:I,. a:.'.' O':.,....:.s......,:.'rt~.'..'.':k.::.'.;....a......:~..:...'...'...',.. :: " :,,>,,' - : .: ." .. '.;;'~;,',."':' ,:\'~~~~~1t?1. i.::;.~,I...;.:.,;;...:},.,.;,:,: ':.~. ~; ';~i~', ' .,. ,0"1, ."; " WELL NAME " 'JOBNUMBER".ŠVEmCODE .1~4H~SP~OG I~MD IrvD DFS REPTNO. I.~A~E . 38-07 ODR 2,776.0 . 2,586.0 5.00 13 11/13/2002 .OPERÁ'TlONS SUM~ARY . , '. . . PHÀ.SE .. ... .qE~CÂIP:nC;>N. . . .'.', SURFAC Float Equip, Thread Locked 8tm 3 Conn,. Ran 43 Jts 9 5/8- Csg, Tam Port Collar, 25 Jts of 95/8" Csg, (Total of 70 Jts Ran 2,769.35' ) While TIH Started taking Wt at 2,626' SURFAO Est Circ at 6.5 bpm at 350 Psi, Washed Csg Down from 2,626' to 2,769', Up Wt W/Pumps on 134K, Dn Wt 94K SURFAC RD Fill Up Tool & MU Cmt Head on Landing Jt & Landed Csg in Hanger SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield Pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. SURFAC RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chern Wash, Dropped 8tm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt 2,415 Cu ft of Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs, Reciprocated Csg During Cmt Job FRO.~ TO HOORS : .tODE TROUBLE SUB 09:30 16:00 6.50 CASE P RUNC 16:00 18:30 2.50 CASE P RUNC 18:30 19:00 0.50 CASE P RUNC 19:00 22:00 3.00 CASE P GIRC 22:00 00:00 2.00 CEMENT P PUMP 24 HR SUMMARY: Fin POOH & LD LWD/MWD with MM & 12 1/4" Bit, RU Csg Tools, Ran 70 Jts of 9 5/8" 40# L-80 BTC Csg, Set Csg at 2,769', Girc & Cond Mud for Cmtg, Began Cmtg Csg ... . ~...._. ÇpMP~NY ConocoPhillips Nabors Halliburton / Sperry-Sun . SERVICE ITEM UNITS. gals bbls USAGE Fuel Water, Drilling PER.S;ONNEL DATA NO. .t-iOURS'COMPANY. 3 Doyon Universal 33 APC 4 Baroid SERVICE NO. HOURS 6 2 2 MATERIALS ¡CONSUMPTION .ONH.t\,ND ITEM' -14,184 Water, Potable -1,420 USAGE UNITS bbls ON.HAND. -638 Printed: 11/23/2002 11 :28:57 AM " ') ) ~~:;~ WELI~'ÑAME. . .. . 3S-07.. . I'JOB~~M~ER.I'EVENTO.D. CR'ODE 124HRS.P~~G TMD TVD DFS REPTNO. .DATE . " - 2,776.0 2,586.0 6.00 14 11/14/2002 SUPERVISOR RIG NAME i NO. FIELDNAME/OCSNO. AUTHMD DAILYTANG CUM.TANG David Burley/Pete Wilson N1268@ppco.co Nabors 7ES Kuparuk River 6.611.0 0.00 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INT ANG WI MUD PU Additional 5" DP & TIH 0.00 0.00 24HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD STAND BACK DP,MU 81/2" BHA & PU DP & TIH, Circ & Test C 11/11/2002 104,147 1,637,825 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INspl. LEAKOFF AFE AUTH. WCD.K3S.0045.01 2,484,894 INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 28.090 53.120 16.000 (in) @ 108.0 (ft) 9.625 (in) @ 2,770.0 (ft) 11/15/2002 LAST SURVEY: DATE TMD 11/14/2002 4,444.88 , . -!: ~ ,,~:: . . .c..'..'.'; ~,<'SUÅVEY,bATA ., . '-'1- ..'J '"." :;.M.Ø., Ws CUM E(w C(JNI~;éi1ÒN, . M.p~ AZIMUTH I.". . - " , , . ',' . INçL.; AZIMUTH T~V..Q.... ..INCL. T.V~D. . NIS CUPJi EIW~CU~ .SECTlON , 2,826.59 27.730 54.470 2,631.19 493.36 736.73 886.33 3,686.65 28.660 56.520 3,393.26 717.67 1,065.85 1,284.54 2,920.33 27.780 53.320 2,714.14 519.09 772.00 929.98 3,781.56 28.500 56.440 3,476.60 742.74 1,103.70 1,329.92 3,015.82 27.020 53.090 2,798.92 545.41 807.19 973.91 3,871.29 28.200 56.440 3,555.57 766.30 1,139.21 1,372.51 3,112.75 26.070 53.400 2,885.63 571.33 841.90 1,017.22 3,968.83 27.580 56.360 3,641.78 791.55 1,177.21 1,418.11 3,208.01 27.560 56.790 2,970.65 595.88 877.14 1,060.17 4,067.28 27.000 56.170 3,729.27 816.61 1,214.75 1,463.23 3,303.99 27.130 57.690 3,055.91 619.74 914.22 1,104.21 4,159.66 26.460 56.950 3,811.78 839.51 1,249.42 1,504.76 3,400.18 26.670 57.600 3,141.69 643.03 950.98 1,147.67 4,255.70 28.890 53.190 3,896.83 865.09 1,285.94 1,549.34 3,496.75 28.930 57.270 3,227.11 667.28 988.93 1,192.65 4,350.39 28.880 52.940 3,979.74 892.57 1,322.50 1,595.06 3,591.75 29.130 56.640 3,310.17 692.41 1,027.58 1,238.71 4,444.88 28.090 53.120 4,062.79 919.68 1,358.50 1,640.11 ,-;t.;,.. : ~ .'. . a;':..'..:r,"'{.."..';c.,. 'C' .::'.'... : {{RQ~( ::.:T<L'" :H~URS . 00:00 00:15 0.25 00:15 01:00 0.75 01:00 04:30 3.50 04:30 05:00 0.50 05:00 09:30 4.50 09:30 12:00 2.50 12:00 17:00 5.00 17:00 18:00 1.00 18:00 19:30 1.50 19:30 00:00 4.50 ".. COðE :..:- TROUBLE.. . ~U~B,._c:~~~.!:~~I]QN~ S.UMMARY' . . .' .DESC.tiìpiloN. .'. '. . CEMENT P PUMP SURFAC Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm /350 psi. CEMENT P DISP SURFAC Dropped top plug - cementers displaced with 20 bbls FR - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe unti/l last 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. PULD SURFAC RD Cmt Head & Nabors Csg Tools, LD Landing Jt and Changed Out Long Elevator Bails to Short Drlg Bails OTHR SURFAC Flushed out Divertor with Jetting Tool NUND SUAFAC ND 16- Divertor Lines & 211/4" divertor, Removed Starting Head NUND SUAFAC Installed FMC Gen 511" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead NUND SÜAFAC NU BOP's, Change Out Flanges under Drip PAn, Instatl Riser & Turnbuckles, Changed out Blind Rams to Blind Shear Rams BOPE SURFAC RU Test Equipment & Filled Stack With Water BOPE SURFAC On Rrst Attempt to Test BOP's had Gland Pkg Nut Leak, Sensor Hose Leaked, Replaced Hose and fitting on Manifold Started Leaking, Tightened Same BOPE SURFAC Tested BOPE, Tested 5" Pipe Rams, Manifold & Valves to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 Psi Then 3,500 Psi, Note: John Crisp with AOGCC Witnessed Test CEMENT P CEMENT P WELCTL P WELCTL P WELCTL P WELCTL P WELCTL T EQIP WELCTL P 24 HR SUMMARY: Fin Cmtg 9 5/8" Surface Csg, Had 45 bbls of 10.7 ppg cmt at Surface, Plug Didn't Bump, Ck Floats & Held, CIP at 00:46 hrs. RD Csg Tools, ND Divertor & Lines, Installed Gen5 Wellhead with Tbg Spool & DSA, NU Bops & Tested Same i~~~~~~~ '.' h .'.,;:;~ ~~~fciË"." .'N~.'f~:'j~~t4_~L;U.~¡~~~{,,'5~;\r ';ã~~Ý.I;~~ .." .. ""~t;:"';;~-~~; ConocoPhillips 3 Nabors 33 Printed: 11/23/2002 11 :28:37 AM ) ') ;;,..;:.:;...~~ . 3S.07 . . 'J08 ~~~' I';;~~D~~~I'~ ~¡'~~¡'OG' I~~ 776.0 I ~~586. ~ IOFS6.00 :"'P,ê.RSONNËl DATA' ,'No'...:.' .HÔQf(S . . '. 'COMPANY 4 6 . f.i. COM~ÅNY. Halliburton / Sperry-Sun Doyon Universal . SERvlta: SERVICE APC Baroid ,""'1 ',;" . " ... . '.'. MAtERIAlSICONSUMÞtION. '. USACU('. . ')6'~,'.HA~D'. . .ItEM. -14,184 Water, Potable -1 ,420 UNITS bbls .,. ,- . .~M.~ .uNiTS' gals bbls Fuel Water, Drilling ':'~~~~!\1f{~.i,'.J'_"~.ì.t '~ . I" ~ i ~ REPT NO. DATE 14 11/14/2002 . . , , ~ I' .: NO; 2 2 ¡'¡Ö~R'~ USAGE qN HAND. -638 Printed: 11/23/2002 11 :28:37 AM 9.8 ppg 40.0 Lb/100 Ft2 2,500 psi 94,000 Lbs 26,000 Lbs 1.7 bbls I. PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES Date: 11/16/2002 Volume Input Volume/Stroke Pump used: , #1 Mud Pump r... Strokes 'Y 0.0710 Bbls/Strk 'Y ... Pumping down annulus and DP. ... Hole Depth 2,796 Ft-MD 2,605 Ft-TVD I. Pressure IntearitvTest Mud Weight: 9.5 ppg Mud 1 ° min Gel: 4.0 Lb/100 Ft2 Rotating Weight: 100,000 Lbs Blocks/Top Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1140 psi 0.8 bbls I. EMW = Leak-off Pressure + Mud Weight = 1150. + 95 0.052 x TVD 0.052 x 2580 . EMW at 2769 Ft-MD (2580 Ft- TVD) = 18.1 ppg Well Name; 38-07' Rig: Drilling Supervisor: David Burley Type of Test: I Casing Shoe Test LOT/FIT Hole Size: 18-1/2" I. Casing Shoe Depth RKB-CHF: 26.3 Ft 2,769 Ft-MD 2,580 Ft- TVD Casinq Size and Description: 19-5/8" 40#/Ft L-80 BTC Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocks/Top Drive Weight: Estimates for Test: 3000 - 2500 . 2000 C) ~ _..-: ..,,, ~ ...., -,.". ~ ~ :.~. UJ ~ :::> ~ 1500- uJ ~ a.. 1 000 - 500 - 0 0 Barrels ---CASING TEST PIT 15 Second Shut-in Pressure, psi 1140 ... - Lost 90 psi during test, held = 96.4% of test pressure. uu¡...\, r t - / ~, 2 3 0 5 10 15 20 25 30 Shut-In time, Minutes 0 PIT Point ~LEAK-OFF TEST Comments: Changed hole over to 9.5 ppg new LSND mud prior to FIT. Casin9 Test Pumping Shut-in Strks psi Min psi 0 0 0 2500 2 80 1 2490 4 170 2 2490 6 290 3 2490 8 400 4 2490 10 500 5 2490 12 650 6 2480 14 810 7 2480 16 930 8 2470 18 1090 9 2470 20 1240 10 2470 22 1425 15 2450 24 1600 20 2440 26 1760 25 2420 28 1950 30 2410 30 2125 32 2310 34 2500 Volume Volume Pumped Bled Back 2.4 Bbls _Bbls Pump Rate: 8.0 Strk/min .... Pressure Integrity Test Pumping Shut-in Strks psi Min psi 0 0 0 1150 1 60 0.25 1140 2 125 0.5 1130 3 195 1 1110 4 265 1.5 1110 5 330 2 1100 ~ 6 400 2.5 1090 7 480 3 1080 8 555 3.5 1070 9 630 4 1060 10 700 4.5 1050 11 775 5 1040 12 840 5.5 1040 13 900 . 6 1030 14 965 6.5 1020 15 1030 7 1020 16 1095 7.5 1010 17 1150 8 1000 8.5 990 9 990 9.5 980 10 980 ~' Volume Volume Pumped Bled Back 1.2 Bbls _tsblS ConocoPhillips Alaska Jt Number Num of Jts Jts 3 to 155 Jts 1 to 2 Remarks: 153 Jts 2 Jts Up Wt = 190k ) ) Casing Detail _7" Intermediate Casino COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Davis Lynch Flo~t Collar 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe TO of 8-1/2" hole @ 6633' MD - 6091' TVD 7" Shoe @ 6623' MD 6081' TVD Total Centralizers 1- 7" Bowspring centralizer over stop rings center of joints # 1 & #2 Bowspring centralizer over collar on joints #3 thru #25 7" x 8-3/8" Centering guide on every jt. From #92 thru #96 (Total of 5) 7" x 8-318" Centering guide on every third jt. From #143 to #155 (Total of 5) Total of 173 jts.on location Total of 155 jts. Ran in hole Total of 18 jts. Out (13 Its. Inside shed & 5 jts. Outside shed) Use Best-o-Life 2000 pipe dope On Wt = 110k Block Wt= 26k Well: 3S-07 Date: 11/21/2002 LENGTH 26.20 2.51 6507.96 1.31 83.72 1.48 DEPTH TOPS 26.20 28.71 6536.67 6537.98 6621.70 6623.18 Supervisor: Mike Thornton I Peter Wilson ) ') Legal Well Name: 35-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING .. .,". i ,'j , i,.1:;~~~~' Hole Size: 8.500 (in) TMD Set: 6,623 (ft) Date Set: 11/20/2002 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Osg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: : Time End: : Time End: : ,\'\ iL'. . ~}':~I J: ,~þ' : Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 470 (psi) <,," ',', ,I. ~:~ . ." . '. ..-. Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 ,,'>iJ¿jeez:!¡f!;::~ÔbTY~~::!P~[~:ca~,ng Hole Size: Hole Size: SQ TMD: (ft) TMD Set: SQ Date: Date Set: SQ Type: Csg Type: SO TMD: SO Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: . , . . ~ f, . , - '~ " :.:;~ " '," ¡ , ',I' . ..Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Stuck prior cmt Pipe Movement. RPM: SPM: Inlt Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) . $tatle.No:..:1of1 . . . - . . . Start Mix Cmt: 17:00 Start Slurry Displ: 18:00 Start Displ: 18:53 End Pumping: 19:50 End Pump Date: 11/20/2002 Top Plug: Y Bottom Plug: Y . . - ~,' . -.. , ~ '.. . '." I.'.., . . ',w"" ...- ". , " ~ J ";. Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: .5.00 (bbl/min) 5.00 (bbl/min) Y 1 ,400 (psi) 2,200 (psi) 5 (min) Y (ft) (ft) Max Torque: (ft-Ibf) Drag Down: (Ibs) - Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch mix Density Meas By: Densometer . . . - ; I. - ~':'.:~ ". ".. " ..: . .', ,',. ¡.,r '. . Mì.Îd ,[)áfa .. Type: Non-Disp. lS Density: 12.3 (ppg) Vise: 45 (s/qt) PV/yP; 20 (cp)/19 (lb/100ft2) Gels 10 see: 6 (lb/100ft2) Gels 10 min: 8 (lb/10Oft2) Bottom Hole Circulating Temperature:75 eF) Bottom Hole Static Temperature: (OF) Displacement Fluid Type:Seawater Density: 8.5 (ppg) Volume: 255.70 (bbl) ~J:;;;~j~j~~l¡tÜ',,, .. 'i;~i¡:.~~~;i;,;~;:';>~~w~~~?;Iì-~i9'¡;Y;~,9:,1~~~;~i:;;'\'<.. . Slurry Data Fluid Type: FLUSH Slurry Interval: 2,931.00 (ft}To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Description: CW100 3,373.00 (ft) Cmt Vol: 10.0 (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) eF) . .~ .:...:.' . . .':': ' '. ;'-"1 " '. . Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11 :26:36 AM " ) ) Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING . .! ., - .' ~<;" >,; :" . '.' Slurry Data Fluid Type: FLUSH Slurry Interval: 3,373.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 5,585.00 (ft¡ro: Water Source: Test Data Thickening Time: 3.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) '.i - .. . . . ---,'Trâd~:.Narñè-.:- .;"-.,- D65 0600G 047 Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 ..;. \ I . ~ ; ;,", , ;>/,,~t~~~O:'1SI~;~;N~;~'oÜ~;: ," . I .' ' " 1 .", . I Description: MUDPUSH XL Class: 5,585.00 (ft) Cmt Vol: 50.0 (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 Description: 6,623.00 (ft) Cmt Vol: 45.0 (bbl) Slurry Vol218 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (fWsk) Water Vol: (bbl) Other Vol: () Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp eF) (OF) . . . . - - . :$tägê:N(): 1,$I,ürr;Y,:~Q: 3. of 3..,:Additiv~;S. . ' . '".:. ': : -- -,' . . - ,-' .' -' ¡';. ~.-' - ". - ... -..: : . " I .'. - ". " . : -. - . of. :.. . -. _.~:- -. Type. ,.- . " - 1.. . - . Goncehtration; . .' 1:".;,. . :Units .: .:Liqu\d Conc~, ;Units'- . 0.3C %BWOC 2.0C G P S O.2C G P S Printed: 11/23/2002 11 :26:36 AM ) ') Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 ',!:~:(;Aj~~lnø;f~$t .' Test Press: (psi) For: (mln) Cement Found between Shoe and Collar: . c. . ' -' ~ ,1 "..". : ,. ""'.:/ .<'~$'~~:'ié.S~; . , .. .,'.: '1 . ,. .' "." '. . I ,." '",' , ,",t- -\' , r',. t - ,I ..:: 1', \ '~'-. . ,I¡ ,. . . , '. \: . . ~ ~ ;'.' ::':~;.'i:>':.:-:.¡:Liner.t~þ:Te~~.... . ; -',' ." '.. Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: J" . . . . . ..~. . ..Log/SurVey Èvaluation. , ".", . . interpret~tion Summary . CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) ~:'. ,'~~.'.. ~ . Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wI Class G + .300% 065, 2.000 gal/sk 0600G, .200 gal/sk D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls cmt at rate of 5.5 bpm at 500 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmt around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wI total of 257.5 bbls, Bumped plug wI 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20/02, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. . , - . Remarks " Printed: 11/23/2002 11:26:36 AM ) '~EL~NAME" ..".,.. .. .. . 1"~~BNUMBER''E;~rir~O~E 24.HRSPROG TMD ITVO IOFS /.REPTNO. /DATE . 35-07 ODR 6,633.0 6,091.0 12.00 20 11/20/2002 SUPERVISOR I RIG NAME' NO. I FIELD NAME I OCS NO. AVTH MD I DAILY TANG I CUM. TANG Mike Thornton/PeterWils N1268@ppco.co Nabors 7ES Kuparuk River 6,611.0 0.00 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD TIH with 3 1/2" Completion Assembly 0.00 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING OAIL Y TOTAL CUM COST WI MUD Set Pkr & Complete Well Per Plan, Freeze Protect Well 11/17/2002 202,518 2,466,354 lITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 18.00 WCD.K3S.0045.01 2.484,894 INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 8.780 51.110 9.625 (in) @ 2,769.0 (ft) 7.000 (in) @ 6,611.0 (ft) 11/15/2002 r~cpI1.3.10I'JJlÙiJOATÁló~i~Y.ëOSJ I 0.00 . I.CUMCpST I 0.00 FCrr.Sç)L : OILA¥A'f..' ~andiMØT~Ph1pM: 'ÞffMf clbå H2S UME ES 2/ / /18.8 7.71 / LAST SURVEY: DATE TMO 11/18/2002 6,633.00 ."DE~;~~p.ti~).1 12.25 Ip~I FV. PVNP' ':.GELS . WLiHTH~' 48 18/23 8/10 2.5/10.4 .. .;OPERATIONS$UMMARY . mquBLE . soa. . PHAS-i; . :.. . , . DESCRIPTION RURD INTRM1 Fin RU Nabors Csg Equipment & GBR Fill-Up Tool RUNC INTRM1 Held Safety Mtg on Running of 7" Csg MU 7" Float Shoe, 2 Jts of 7" 26# L-80 BTC Mod Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 153 Jts 7" Csg, (Total of 155 Jts Ran 6,623.18') Note: Nabors Floorhand Robert Miller Twisted Ankle While Running 7" Csg, Stepped on Railing Stop for Iron Roughneck While Tailing in Csg INTRM1 Est Circ & Reciprocating Pipe Up Wt190K, Dn Wt 11 OK -While Reciprocating Pipe after approx 25 Min Dn Wt down to 80K,Attempted to PU on Csg, PU WnOK Over, Pipe Stuck, Landed Csg in Hanger, RD Fill Up Tool & MU Cmt Head on Landing Jt & Cont to Circ Csg for Cmt Job, Lowered YP from 30 to 23 with 45 vis, Circ at 209 Gpm's at 470 Psi, Landed Csg With FS @ 6,623', FC @ 6,S36' PUMP INTRM1 RU Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, SO bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wi Class G + .300% D6S, 2.000 gal/sk D600G, .200 gallsk.D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls of at 15.8 at rate of 5.5 bpm at 500 psi, Shut down,. INTRM1 Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmtaround shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug w/ total of 257.5 bbls, Bumped plug w/ 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20/02, Ck floats & Held, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. CIRC INTRM1 Rushed Out Mud Pump, Stack & Flowline RURD INTRM1 LD Landing Jt, RD Csg Tools & Changed Out Elevator Bails OTHR INTRM1 RU & RIH and Set 7" Pack-off, Tested Same to 5,000 Psi for 10 Min, LD Setting Tool RURD CMPL TN RU Nabors 3 1/2" Tbg Handling Tools CIRC f:~qNl: to... HOURS conE. 00:00 02:00 2.00 CASE P 02:00 12:00 10.00 CASE P 12:00 18:00 6.00 CASE P 18:00 19:00 1.00 CEMENT P 19:00 20:00 1.00 CEMENT P DISP 20:00 21 :00 1.00 CEMENT P 21 :00 22:30 1.50 CEMENT P 22:30 23:00 0.50 CMPL TN P 23:00 00:00 1.00 CMPL TN P 24 HR SUMMARY: RU & Ran 155 Jts of 7" 26# L-80 BTC Mod Csg, Landed Csg at 6,623', Circ & Cond Mud, Cemented 7" Csg, Bumped Plug, Floats Held, CIP at 19:50 Hrs, RD Cmt Head, RU to Run 3 1/2" Completion Printed: 11/23/2002 11 :29:52 AM " ) ~EL~~AM~ <.... ,-',.: ,,'. .".. _.I'.JOB'~U~BËR.I'EV~~~O~E'I'2~HRSP~OG . '.l'~MD TVO' OFS REPTNO. IOAT~. 3$-07 ODR 6,633.0 6,091.0 12.00 20 11/20/2002 '(,: , . ~ I 't :", : : -ífè,Ji. .>: " ,I :~.:. :.'p;~Rsó.N'NEL:,bÂtA . .~,~:.' :'-".:H:O~RS'..:, L-:,.,:'.CÓ~PANY 3 Baroid 39 Canrig 4 Baker 6 FMC 2 . . :. :);ßAtìiRIÂL.SIC:ONSUMÞ,TION . 'US~Ge~. . .:.~Þ~'HÁ~D.'-: ~.'-;~:':.-/. ITEM. 2,730 -14,262 Water, Potable 372 -1,946 " I' , ,. .'"0 ., '... '"f' 'COMPANY , ConocoPhillips Nabors Halliburton / Sperry-Sun Doyon Universal APC ,. \ SERVI~~ .. SERVICE HQUFU; ..~O"', 2 1 1 1 Fuel Water, Drilling UNits gals bbls .UNITS bbls USAG~. -. oN HAND -638 , . Printed: 11/23/2002 11 :29:52 AM Type of Test: Annulus Leak Off Test for Disposal Adequacy -Iole Size: 18-1/2" I"'. Casing Shoe Depth RKB-CHF: 26.3 Ft 2,769 Ft-MD 2,580 Ft-TVD Casina Size and Description: 19-5/8" 40#/Ft L-80 BTC Chanaes for Annular Adequacy Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Well Name: Jrilling Supervisor: 38-07 I Rig: Mike Thorton PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Nabors 7ES Date: 11/21/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump [... Strokes'" 0.0710 Bbls/Strk ... ... Pumping down annulus. ... Pump Rate: 7.0 Strkjmin .. Casing Test Hole Depth Pum ing Shut-in 5,585 Ft-MD 5,083 Ft-TVD Strks si Min si I.., Pressure IntearitvTest Mud Weight: 12.3 ppg Inner casing 00: 7.0 In. Desired PIT EMW: Estimates for Test: 18.1 ppg 778 psi 0.4 bbls [... l... :MW = Leak-off Pressure + Mud Weight = 620 + 123 0.052 x TVD 0.052 x 2580 . EMWat 2769 Ft..MD (2580 Ft-TVD) = 16.9 1 000- UJ e::: ::> U) U) UJ e::: a.. 500 - 0 0 3 4 Barrels "'-CASING TEST -8-LEAK-OFF TEST :;omments: PIT 15 Second Shut-in Pressure, psi 400 ~ 6 7 8 0 10 15 20 25 30 Shut-In time, Minutes 0 PIT Point Pressure Integrity Test Pumping Shut-in Strks psi Min psi 0 0 0 450 7 70 0.25 400 14 80 0.5 380 21 100 1 320 28 180 1.5 310 35 300 2 300 ,.~ 42 480 2.5 300 49 620 3 300 56 500 3.5 300 63 490 4 300 70 490 4.5 295 77 480 5 290 84 480 5.5 290 91 450 6 290 98 450 6.5 285 7 280 7.5 270 8 260 8.5 255 9 250 9.5 250 10 250 I.". _if ,,~ Volume Bled Back _Bbls Volume Volume Pumped Bled Back 7.0 Bbls _tsbls ) ) ó1Da-/tl / /59.0 WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 17, 2003 RE: MWD Formation Evaluation Logs 3S-07, AK-MW-22174 1 LDWG formatted Disc with verification listing. API#: 50-103-20430-00 . \ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Si~ cJ)QJ(?~ J RECEIVED FEB 1 8 2003 Ata8Iœ on & Gas Cons. Commi8Iion AndøIge Scblumbepger Schlumberger Technology Corporation, by and through is Geoquest Division . 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well 18-11 28-10 2G-17 3N-18 3S-07 3S-14 3S-26 3S-14 ~ ~ oo-alD Job# Log Description 1 ?ll, /3f.o LDL J~...O~G} STATIC BHP SURVEY ~Od -a4 ~ PERF RECORD & SBHP ¡)lln- r;At~ STATIC BHP SURVEY ~- I >(í PRODUCTION PROFILE drH"'d) 0 CROSSFLOW DETERMINATION LOG aOI-oL/ 0 PRODUCTION PROFILE ,!)?,(,~~ SCMT Sl~~ 000Qr) DATE: NO. 2655 02/12/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Field: Date BL Sepia 01/26/03 1 01/30/03 1 02/04/03 1 01/28/03 1 02/02/03 1 02/01/03 1 01/24/03 1 01/31/03 Kuparuk CD ~ Color 1 ~~ RECEIVED FEB 1 4 2003 A1u1œ on & Gas Cons. Commiaeion Anchorage .> Randy Thomas Greater Kuparuk Team Leader Drilling & Wells ¿;)od-l?7 ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas @ppco.com January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, -\~~ ....' . \, ~'~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison / R. Overstreet Sharon Allsup-Drake Well Files RECE1VED I 1\ "I 1 hI ?on-~ ':/-'.',\ ¡ '.~. L-.- V'v t\Jaska Oil & Gas Co~s.. Commission ÞJ\ChorëQt Annular Disposal during the fourth quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2-28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 35-09,35-14,35-10 3S-l8 206 100 0 306 0 0 306 Dec 2002 Dec 2002 35-18 ( Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-l4 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January IC-I09, IR-36, IC-24 2001 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-l5 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 Cook Inlet Annular Disposal during the fourth quarter 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October 2002 2002 Source Wells Hansen # 1 ) ConocJPhillips ) Randy Thomas Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 20, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-07 (202-187) Dear Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 3S-07. If you have any questions regarding this matter, please contact Scott Lowry at 265- 6869. Sincerely, ,..."\....""""~ '~\. ~~--- \'~ R. Thomas Greater Kuparuk Team Leader CPAI Drilling RL T/skad RECEIVED JAN 0 Ó 2003 Alaska OU & Gas Cons. Commission Anchorage ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Suspended D Abandoned D Service Oil 0 Gas D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2487' FNL, 935' FEL, Sec. 18, T12N, R8E, UM At Top Producing Interval 1122' FNL, 1023' FWL, Sec. 17, T12N, R8E, UM AtTotal Depth 1097' FNL, 1048' FWL, Sec. 17, T12N, R8E, UM (ASP: 478313, 5995312) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 24' feet ADL 380107 ALK 4624 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.,~. Or Aba_~. November 9,2002 November 19,2002 Novembe£2?,'200VS...b 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 6633' MD / 6091' TVD 6536' MD I 5995' TVD YES 0 No D (ASP: 476325, 5993928) (ASP:478282, 5995288) Classification of Service Well 7. Permit Number 202-187/ 8. API Number 50-103-20430 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3S-07 11. Field and Pool Kuparuk River Oil Pool Kuparuk River Field 15. Water Depth, if offshore N/A œetMSL 20. Depth where SSSV set Land Nipple @ 495' 22. Type Electric or Other Logs Run GR/Res, Dens/Neutron 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 108' Surface 2769' Surface 6623' 16. No. of Completions 21. Thickness of Permafrost 1605' MD CASING SIZE WT. PER FT. HOLE SIZE CEMENTING RECORD 59 sx ArcticCrete AMOUNT PULLED GRADE B L-80 L-80 42" 12.25" 8.5' 590 sx AS Lite, 220 sx LiteCrete 218 sx Class G 16" 9.625" 62.5# 40# 26# 7" 3.5" TUBING RECORD DEPTH SET (MD) 6304' PACKER SET (MD) 6272' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 6388' - 6413' MD 5849' - 5874' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 27. Date First Production December 3, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing Production for OIL-BBL GAS-MCF 4252 1814 OIL-BBL GAS-MCF 5637 3015 CORE DATA 0 WATER-BBL 0 WATER-BBL 12/6/2002 16 3/4 hours Flow Tubing Casing Pressure pressure 225 ps. not available 28. Test Period> Calculated 24-Hour Rate> Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE RBOMS 8Fl CHOKE SIZE 99% OIL GRAVITY - API (corr) 25 API GAS-OIL RATIO 535 RECEIVED JAN 0 6 2003 Alaska Oil & Gas Cons. Cúrnmissìor: Anchorage (.~,v .....,' Submit in duplicate Jt~N 9 2003 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME 3S-07 Kuparuk C Kuparuk A 6387.5' 6412.5' 5848' 5873' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869 Signed~c...~~~. .._'-~ R. Thomas r HJJ;! Kuparuk Drilling Team Leader Date (1.... (2- 6 (c) ¿ 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ) ConocoPhillips Alaska Operations Summary Report Page 1 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-07 3S-07 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 1 0/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: 11/1/2002 23:30 - 00:00 0.50 MOVE MOVE MOVE Begin moving drilling module from Deadhorse to DS-3S 11/2/2002 00:00 - 00:00 24.00 MOVE MOVE MOVE Continue moving Nabors 7ES from Deadhorse to DS-3S. 11/3/2002 00:00 - 00:00 24.00 MOVE MOVE MOVE Continue moving Nabors 7ES from Deadhorse to DS-3S. 11/4/2002 00:00 - 12:30 12.50 MOVE MOVE MOVE Continue moving Nabors 7ES from Deadhorse to DS-3S. Drilling module on location at 12:30. 12:30 - 00:00 11.50 MOVE RURD MOVE Continue to move pit module while rigging up drilling module. 11/5/2002 00:00 - 03:00 3.00 MOVE RURD RIGUP RU Cattle shute - remove bridal lines from blocks. 03:00 - 06:00 3.00 MOVE RURD RIGUP Spot pit module and rig shop. 06:00 - 12:00 6.00 MOVE RURD RIGUP Prep location and spot ball mill - injection skid and generator. 12:00 - 17:00 5.00 MOVE RURD RIGUP Berm pits, ballmill and cellar - ready pits for spud mud. 17:00 - 18:00 1.00 MOVE RGRP RIGUP Hook up support lines to ball mill. 18:00 - 21 :00 3.00 MOVE RURD RIGUP NU Hyrill and knife valve - continue rigging up pits. 21 :00 - 00:00 3.00 MOVE RURD RIGUP Change out drip flanges below royary table to 20" - cut floor mats for Iron roughneck tracks - RU on floor. 11/6/2002 00:00 - 03:00 3.00 MOVE RURD RIGUP Unload pipe shed loaded with materials from drilling yard - connect standpipe hose to Top Drive. 03:00 - 06:00 3.00 MOVE RURD RIGUP Mix spud mud - pull communication lines from rig to ball mill. 06:00 - 12:00 6.00 MOVE RURD RIGUP Inspect and service equipment in ball mill - NU Divertor line. 12:00 - 15:30 3.50 MOVE RURD RIGUP Assist welder modifiying riser - work with electrician installing camera on monkey board - Completed hook up of generator power to ball mill - ball mill powered up @ 1530 hrs. 15:30 - 17:30 2.00 MOVE RURD RIGUP Remove side plate and balls from mill. Install crownl traveling block audible warning safety system - load and strap 75 jts of 5" drill pipe in shed. 17:30 - 22:00 4.50 MOVE RURD RIGUP Install riser - repair light fixtures and check out pumps and motors in Ball Mill. 22:00 - 00:00 2.00 MOVE RURD RIGUP Installed standpipe clamps in derrick - continue working on ball mill. 1117/2002 00:00 - 03:00 3.00 MOVE RURD RIGUP Install clamps on standpipe - work on cement line ru - continue ru ball mill. 03:00 - 08:00 5.00 MOVE RURD RIGUP Remove bladder in #1 pump pulsation dampner - ru cellar pump - continue to inspect and service equipment in ball mill. 08:00 - 12:00 4.00 MOVE RURD RIGUP Install flowline jets - service ball mill equipment - ru shipping lines. 12:00 - 15:30 3.50 MOVE RURD RIGUP Complete installation of camera on monkey board - install shaker screens - assist rig mechanic inspecting equipment in ball mill. 15:30 - 18:30 3.00 MOVE RURD RIGUP Assist Canrig rep testing safety systems on Top Drive - RU bulk barite shipping system - install new bladder in pulsation dampner- complete flowline jets installation. 18:30 - 00:00 5.50 MOVE RURD RIGUP Wt up spud mud to 9.4 ppg with bulk system, no problems. Continue to service equipment in ball mill. Ru hole fill line. 00:00 - MOVE RIGUP Electricians: Work on gas detectors/Gaitronics audible alarm system - PLC boards in SCR house - Gaitronics system tied in to Sperry Sun shack and Rig Camp. KUP base radios installed in Doghouse and rig camp. Network comms from rig to camp remain in progress. 11/8/2002 00:00 - 04:00 4.00 MOVE RURD RIGUP Remove misc materials off the top of the injection pump skid - installed check valves on brake cooling system pumps. 04:00 - 08:30 4.50 MOVE RURD RIGUP Replace packing on bucket elevator drive shaft - function test pumps in ball mill - RU shipping lines to inj. skid. 08:30 - 12:00 3.50 MOVE SFTY RIGUP Perform Zonal inspection of derrick. Held site specific orientation with crew on skate and iron roughneck operations. 12:00 - 14:30 2.50 MOVE RURD RIGUP Function tested Hydril - continue to service equipment and rig up ballmill. 14:30 - 15:00 0.50 MOVE SFTY RIGUP Held Pad Evacuation Drill - all personell working on pad responded to Printed: 12/2/2002 4:54:58 PM ) Page 2 of 7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Contractor Name: N 1268 @ ppco.com Rig Name: Nabors 7ES Date From - To Hours Code Sub Phase Code 11/8/2002 14:30 - 15:00 0.50 MOVE SFTY RIGUP 15:00 - 16:00 1.00 MOVE RURD RIGUP 16:00 - 18:30 2.50 MOVE RURD RIGUP 11/9/2002 18:30 - 22:30 4.00 MOVE RURD RIGUP 22:30 - 00:00 1.50 MOVE RURD RIGUP 00:00 - 03:00 3.00 DRILL PULD RIGUP 03:00 - 04:00 1.00 MOVE RURD RIGUP 04:00 - 06:30 2.50 DRILL PULD RIGUP 06:30 - 07:00 0.50 DRILL SFTY RIGUP 07:00 - 07:30 0.50 RIGMNT RGRP RIG UP 07:30 - 08:00 0.50 DRILL DRLG RIG UP 08:00 - 13:30 5.50 RIGMNT RGRP RIG UP 13:30 - 14:00 0.50 DRILL OTHR RIG UP 14:00 - 15:15 1.25 CEMENT COUT RIG UP 15:15 - 15:30 0.25 DRILL OTHR RIG UP 15:30 - 18:30 3.00 DRILL DRLG SURFAC 18:30 - 18:45 0.25 DRILL CIRC SURFAC 18:45 - 19:00 0.25 DRILL TRIP SURFAC 19:00 - 19:30 0.50 RIGMNT RSRV SURFAC 19:30 - 23:30 4.00 DRILL PULD SURFAC 23:30 - 00:00 0.50 DRILL DRLG SURFAC 00:00 - 01 :30 1.50 DRILL DRLG SURFAC 01 :30 - 06:30 5.00 RIGMNT RGRP SURFAC 11/10/2002 06:30 - 09:30 3.00 DRILL DRLG SURFAC 09:30 - 13:00 3.50 RIGMNT RGRP SURFAC 13:00 - 14:30 1.50 DRILL DRLG SURFAC 14:30 - 15:30 1.00 RIGMNT RGRP SURFAC 15:30 - 00:00 8.50 DRILL DRLG SURFAC 11/11/2002 00:00 - 03:00 3.00 DRILL DRLH SURFAC 03:00 - 04:00 1.00 DRILL OTHR SURFAC 04:00 - 04:30 0.50 DRILL DRLG SURFAC 04:30 - 05:00 0.50 DRILL OTHR SURFAC 05:00 - 00:00 19.00 DRILL DRLG SURFAC 11/12/2002 00:00 - 02:00 2.00 DRILL DRLG SURFAC Start: 10/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: Description of Operations Primary Muster area (Rig Shop). Calibrate pressure sensors on drilling console - safety walk rig addressing start up housekeeping issues. Perform Divertor and Accumulator tests - initial test of gas detection equipment unsatisfactory - trouble shoot - and retest, ok. Testing witnessed and approved by Chuck Scheve (AOGCC). Accepted rig to 3S-07 well operations @ 1830 hrs. PJSM. PU and stand back 75 joints of new 5" drill pipe - (MU/SO redopel MU). Move in and measure 24 jts of 5" hwdp, unable to drift drill pipe, steam drill pipe to remove ice plugs. PU and stand back 24 jts of hwdp and jars. MU blower and kelly hoses to Top Drive. MU bha #1 set motor to 1.5 ako. Held Pre-spud meeting with drilling and support crews. Pump through bleeder - repair stroke counter #1 pump. Fill Conductor and check for leaks. Knife valve gatel seat leaking. Remove, repair and reinstall valve. Pressure test mud lines to 3000 psi, ok. Clean out cement in conductor from 50' to 105' with water, displace conductor with spud mud. Clean out cement to 108', eirc. Spud well @ 1530 hrs - drill 12-1/4" hole to 228'. Circ hole clean Stand back 2 stand of hwdp. Service top drive - tighten fitting on hyd. line. MU SHA #2, Initialize tools (held safety meeting) load source. Wash down from 204' to 228', drill to 238' ART =.25 Drill from 238' to 294', attempted to obtain survey, unable. ART =1.0 AST =0 Cleaned cement cuttings and fisheyes out of suction screens - attempted to survey, no good - go through fluid ends on pumps, found a suction valve retainer loose - lowered precharge on pulsation dampner to 350 psi. Drill from 294' to 432' ART =0.4 AST =1.92 Seal on Top Drive hyd. oil filter failed, changed oil in top drive to PCU EP-68, installed new filter. Drill from 432' to 517' ART =0.25 AST =0.5 Change out leaking oil filter on Top Drive, adjusted system oil pressure. Drill from 517' to 1214' (1198 tvd) ART=2.56 AST =3.04 PUW 80k SOW 75k RWT 78k 522 gpm I 630 psi 20/25k wob Torque 3200 on 11500 off Drill from 1214' to 1377' ART = 0.36 AST = 1.77 Shaker screens in ball mill blinded, change out screens. Drill from 1377' to 1387' ART =0.28 Cuttings handling bottlenecked in ball mill, transfered 60 bbls from cuttings tank outside to open top tank storage. Drill from 1387' to 2642' (2465 tvd) ART = 11.56 AST = 1.79 POW 105k SOW 90k RWT 95k 537 gpm 11000 psi WOS 25-30K Torque on I 6000 off I 4000 Drill from 2,642' to 2,776' MD/2,568' TVD, ART 1.31 Hrs, AST .5 Hr Printed: 12/2/2002 4:54:58 PM .) ") Page 3 of 7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-07 3S-07 ROT - DRILLING N 1268@ ppco.com Nabors 7ES Start: 1 0/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: SOb FtÖm+To htol.JJ's..COdê. COde 11/12/2002 00:00 - 02:00 2.00 DRILL DRLG SURFAC 02:00 - 05:00 3.00 DRILL CIRC SURFAC 02:00 - 05:00 3.00 DRILL CIRC SURFAC 05:00 - 06:30 1.50 DRILL TRIP SURFAC 05:00 - 06:30 1.50 DRILL TRIP SURFAC 06:30 - 07:30 06:30 - 07:30 07:30 - 08:30 07:30 - 11 :30 1.00 DRILL CIRC SURFAC 1.00 DRILL CIRC SURFAC 1.00 DRILL TRIP SURFAC 4.00 DRILL TRIP SURFAC 08:30 - 11 :30 3.00 DRILL CIRC SURFAC 11 :30 - 13:30 2.00 DRILL TRIP SURFAC 11 :30 - 13:30 2.00 DRILL TRIP SURFAC 13:30 - 15:30 2.00 DRILL TRIP SURFAC 13:30 - 15:30 2.00 DRILL TRIP SURFAC 15:30 - 21 :00 5.50 DRILL CIRC SURFAC 15:30 - 21 :00 5.50 DRILL CIRC SURFAC 21 :00 - 00:00 3.00 DRILL TRIP SURFAC 21 :00 - 00:00 3.00 DRILL TRIP SURFAC 11/13/2002 00:00 - 02:00 2.00 DRILL TRIP SURFAC 02:00 - 05:30 3.50 DRILL TRIP SURFAC 05:30 - 08:00 2.50 CASE RURD SURFAC 08:00 - 09:00 1.00 CASE RURD SURFAC 09:00 - 09:30 0.50 CASE SFTY SURFAC 09:30 - 16:00 6.50 CASE RUNC SURFAC 16:00 - 18:30 2.50 CASE RUNC SURFAC 18:30 - 19:00 0.50 CASE RUNC SURFAC Drill from 2,642' to 2,776'MD/2,568' TVD ART 1.3 Hrs, AST .5 Hr Circ & Cond mud, Pumped 49 bbl Hi Vis sweep, Circ Hole Clean, Circ at 588 GPM 11,000 Psi I 80 RPM's Circ & Cond Mud, Pumped 49 bbl Hi Vis sweep, Circ Hole Clean, Circ at 588 gpm's, 1,000 psi and 80 Rpm's Monitored Well, Started POOH Pulled 40K over at 2,324', Unable to work down, LD Single & Est Circ & Rotation, Packed Off & Lost Approx 10 bbls of Mud before Re-Est Circ at 2,315' Monitored Well, Started POOH, Pulled 40K over at 2,324', Unable to work down, LD 1 Single & est circ & rotation, Packed off & lost approx 10 bbls mud, before re-est circ at 2,315' Circ Btms Up & Had Large Amount of Sand at Btms Up Circ Btms Up, had large amount of sand on btms up POOH Stds Pumping Out to 1,563', Pulled Tight, RIH to 1,660' Back ream F/2,328' to 2,040' 550 gpm, 830 psi & 80 rpm's, Pulled F/2,040', Tight at 1,900', 50K over, Backream F/1.947' to 1,566', Pulled tight after conn, 50k over, rih to 1,660', Backream F/1 ,660' to 1,560', 575 gpm at 866 psi & 80 rpm's, circ btms, heavy sand @ shaker Circ & Cond Mud, Lowered Vis?????? POOH F/1 ,560' to 980', 5-10K over St wt, Monitored Well, & blow down Top drive POOH from ????' to 900', Monitored Well & Blew Down Top Drive RIH, Reamed tight spot at 1,560', precautionary Ream to 1,750', RIH to 2,776', washed last 90' to Btm with No Problems Began RIH, Started taking WT at 1,560', Wash & Reamed Down from 1,560' to 1,750', Cont TIH to Btm WINo Other Problems, Washed 90' to Btm with No Problems Circ & Cond Mud at 560 Gpm, Raised MW F/9.6 ppg to 9.8 ppg, Increased Vis F/80 to 120, Pumped 45 bbls, 11.6 ppg Barafiber Hi Vis Sweep, Observed large increase in cuttings with sweep back, Monitored Well & Static Circ & Cond Mud, Raised MW from 9.6 ppg to 9.8 ppg, Raised Vis to 120, pumped 42 bbls of 11.6 ppb Barafiber Hi Vis Sweep & Circ Clean POOH, Pulled 55K over at 2,700', Backreamed F/2,740' to 1,404' with 429 Gpm's, 730 Psi & 70 Rpm's, Began increaing Vis to 180 Vis in & out by 1,404' Backreamed & Pumped Out of Hole from 2,776' to 1,404', Pumped at 495 GPM/730 PsiOO RPM's, Cont to POOH without Pumping Or Backreaming Fin POOH to Flex Collar & LD Collar Pulled Sperry Suns Nuclear Source, Downoad MWD, LD MWD & 1.5 deg MM & 12 1/4" Bit RU Nabors Csg Tools and GBR Fill-up Tool. Made dummy run with Hanger & Landing JT, had to center twenty inch riser to rotary table to allow centralizer on landing joint to pass. Held Safety Mtg on Running of 9 5/8" Csg MU 95/8" Flaot Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 43 Jts 9 5/8" Csg, Tam Port Collar, 25 Jts of 9 5/8" Csg, (Total of 70 Jts Ran 2,769.35' ) While TIH Started taking Wt at 2,626' Est Circ at 6.5 bpm at 350 Psi, Washed Csg Down from 2,626' to 2,769', Up Wt WIPumps on 134K, Dn Wt 94K RD Fill Up Tool & MU Cmt Head on Landing Jt & Landed Csg in Hanger Printed: 12/2/2002 4:54:58 PM ) ) Page 4 of 7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-07 38-07 ROT - DRILLING N 1268@ ppco.com Nabors 7E8 SUb Froh1+ To . HoursCodè COde Phase 11/13/2002 19:00 - 22:00 3.00 CASE CIRC SURFAC 22:00 - 00:00 2.00 CEMENT PUMP SURFAC 11/14/2002 00:00 - 00:15 0.25 CEMENT PUMP SURFAC 00:15 - 01:00 0.75 CEMENT DISP SURFAC 01 :00 - 04:30 3.50 CEMENT PULD SURFAC 04:30 - 05:00 0.50 CEMENT OTHR SURFAC 05:00 - 09:30 4.50 WELCTL NUND SURFAC 09:30 - 12:00 2.50 WELCTL NUND SURFAC 12:00 - 17:00 5.00 WELCTL NUND SURFAC 17:00 - 18:00 1.00 WELCTL BOPE SURFAC 18:00 - 19:30 1.50 WELCTL BOPE SURFAC 19:30 - 00:00 4.50 WELCTL BOPE SURFAC 11/15/2002 00:00 - 03:30 3.50 WELCTL BOPE SURFAC 03:30 - 04:00 0.50 WELCTL OTHR SURFAC 04:00 - 06:30 2.50 DRILL PULD SURFAC 06:30 - 07:30 1.00 RIGMNT RSRV SURFAC 07:30 - 08:30 1.00 DRILL CIRC SURFAC 08:30 - 09:30 1.00 DRILL PULD SURFAC 09:30 - 13:00 3.50 DRILL PULD SURFAC 13:00 - 15:00 2.00 DRILL PULD SURFAC 15:00 - 16:00 1.00 RIGMNT RSRV SURFAC 16:00 - 18:00 2.00 DRILL PULD SURFAC 18:00 - 19:00 1.00 DRILL CIRC SURFAC 19:00 - 19:30 0.50 RIGMNT RGRP SURFAC 19:30 - 20:00 0.50 DRILL PULD SURFAC 20:00 - 21 :30 1.50 DRILL OTHR SURFAC Start: 1 0/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield Pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chern Wash, Dropped Btm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt 2,415 Cu ft of Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs, Reciprocated Csg During Cmt Job Pumped 220 sxs of 12.0 ppg, 2.4 cflsx Lite Crete tail cmt at 6 bpm 1350 psi. Dropped top plug - cementers displaced with 20 bbls FR - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untill last 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. RD Cmt Head & Nabors Csg Tools, LD Landing Jt and Changed Out Long Elevator Bails to Short Drlg Bails Flushed out Divertor with Jetting Tool ND 16" Divertor Lines & 21 1/4" divertor, Removed Starting Head Installed FMC Gen 5 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead NU BOP's, Change Out Flanges under Drip PAn, Install Riser & Turnbuckles, Changed out Blind Rams to Blind Shear Rams RU Test Equipment & Filled Stack With Water On First Attempt to Test BOP's had Gland Pkg Nut Leak, Sensor Hose Leaked, Replaced Hose and fitting on Manifold Started Leaking, Tightened Same Tested BOPE, Tested 5" Pipe Rams, Manifold & Valves to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 Psi Then 3,500 Psi, Note: John Crisp with AOGCC Witnessed Test Fin Testing BOPE Tested, IBOP, Blind Shear Rams & 7" VBR's with 7" Test Jt to 250 Psi Low & 5,000 Psi High, John Crisp with AOGCC Witnessed Test. Pulled 7" Test Jt with Test Plug & LD Same, RD Test Tools & Installed Wear Bushing PU 14 Stds of 5" 19.5# S-135 DP from Shed & TIH to 1,320', New DP Had to MU & Break Out Then Make BU Serviced Top Drive, Greased Top Seals & Changed Out Saver Sub Circ 1 Complete Circ from 1,320' to Clear New DP, Blew Down Top Drive POOH & Stood back 14 Stds of New DP, PU & MU Directional BHA #3, Load MWD, TIH with 1 STD DC & HWDP & Test MWD, TIH with Remaining HWDP PU 5" DP & TIH to 1,400' with BHA #3 Slip & Cut 82' of Drlg Line Cont to TIH with BHA#3 PU 5" Dp, Tagged up with 15k Wt at 2,526' Circ 1 Complete Dp Volume to Clean Out New DP Repaired Iron Roughneck Blow Down Top Drive & POOH 2 Stds RU & Pressure Tested 9 5/8" Csg to 2,500 Psi for 30 Min with 9.8 ppg Mud, Press Bled Down to 2,410 Psi after 30 Min Printed: 12/2/2002 4:54:58 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: -) ) Page 5 of 7 ConocoPhillips Alaska Operations Summary Report 38-07 38-07 ROT - DRILLING N1268@ppco.com Nabors 7E8 Date Sub From - To Hours Code Code Phase 11/15/2002 21 :30 - 23:00 23:00 - 00:00 11/16/2002 00:00 - 00:30 00:30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 00:00 11/17/2002 00:00 - 00:30 00:30 - 00:00 11/18/2002 00:00 - 03:00 03:00 - 08:30 1.50 WELCTL STRP SURFAC 1.00 WELCTL SFTY SURFAC 0.50 DRILL PULD SURFAC 2.00 CEMENT DSHO SURFAC 0.50 RIGMNT RGRP SURFAC 1.00 CEMENT DSHO SURFAC 1.00 DRILL CIRC SURFAC 1.00 DRILL FIT SURFAC 0.50 RIGMNT RSRV SURFAC 17.50 DRILL DRLG INTRM1 0.50 RIGMNT RSRV INTRM1 23.50 DRILL DRLG INTRM1 3.00 DRILL CIRC INTRM1 5.50 DRILL WIPR INTRM1 08:30 - 09:30 1.00 DRILL CIRC INTRM1 09:30 - 11 :00 1.50 DRILL FIT INTRM1 11 :00 - 13:30 2.50 DRILL TRIP INTRM1 13:30 - 16:30 3.00 DRILL TRIP INTRM1 16:30 - 17:00 0.50 RIGMNT RSRV INTRM1 17:00 - 17:30 0.50 DRILL TRIP INTRM1 17:30 - 22:00 4.50 DRILL TRIP INTRM1 22:00 - 22:30 0.50 DRILL REAM INTRM1 22:30 - 23:00 0.50 DRILL CIRC INTRM1 23:00 - 00:00 1.00 DRILL CIRC INTRM1 11/19/2002 00:00 - 03:00 3.00 DRILL CIRC INTRM1 Start: 10/29/2002 Rig Release: 11/21/2002 Rig Number: 8pud Date: 11/1/2002 End: 11/22/2002 Group: Description of Operations Held PJSM, RU & Performed Stripping Drill Held Well Kill Drill & Blew Down Top Drive & Choke Manifold Stood Back 2 Stds 5" DP & PU & RIH with 9 Jts of Dp Cleaned Out Soft-Med Hard Cmt from 2,526' to FIt Collar at 2,684', Drill Out Plugs & FC to 2,705' at 0-2 K WOB, 50 RPM's, 390 GPM's, Rot Wt 100K, 105K PU/95K S/O Replaced Broken Dies on Top Drive Cont to Drill Out Soft-Med Cmt in Shoe Jts from 2,705' to Fit Shoe, Drilled Fit Shoe at 2,769', Cleaned out to Td at 2,776', Drilled'20' of New Formation to 2,796' for FIT Test, 2-5K WOB, 60 RPM's, 390 GPM at 850 PSi, Rot Wt 100K, PU 105K, S/O 95K Circ Out Spud Mud and Displace Hole with 9.5 PPG LSND Mud RU & Perform FIT to 18.0 ppg EMW w/9.5 ppg Mud, test to 1,150 psi, RD Blow Down Lines & Adjust Breaks on Drawworks Drilled 81/2" Hole from 2,796' to 4,315' MD/4,122' TVD, ART 9 Hrs, AST 1 Hr, Rot Wt 118K, Up Wt 120K, Dn Wt 110K, WOB 10-15K, 100 RPM's, 155 SPM, 460 GPM's at 1,750 psi, Ave 150'/Hr, Raised Mw to 10.2 ppg per Wt Up Schedule. Serviced Top Drive and Took Slow Pump Rates Drill 81/2" Hole from 4,513' to 6,278' MD/5,471, TVD, Deep FIT Test PT, ART 14 Hrs, AST .75 Hrs, Ave ROP 133'/hr, Drill at 100 RPM's, 160 SPM, 480 GPM's with 2,100 psi on Btm, 1,850 psi Off Btm, 15-20K WOB, Raised MW from 10.3 ppg to 10.8 ppg per Wt Up Schedule Ave BGG 20-30 Units, Max BGG 129 Units, Rot Wt, 157K, Up Wt 190K, Dwn Wt 130K, Off Btm Torque 8,500 Ft #'s, On Btm 9,500 Ft #'s Pumped 30 bbl Hi Vis sweep & Circ Out, had Silver dollar Sized Pieces of Clay over Shakers, Pumped 2nd 40 bbl Hi Vis Sweep with Very Little Over Shakers, Circ Clean at 480 Gpm's, 1,850 Psi with 100 Rpm's, Rot Wt 157K, Up Wt 190K, Dwn 130k, 8k Torque Off Btm Monitored well-Static, POOH to 5,846' Pulled Tight, Backreamed Out from 5,846' to 5,561' at 60 Rpm's at 477 Gpm's at 1,800 Psi, Cont POOH from 5,561' to 2,739',60' Inside 9 5/8" Csg With No Problems, Monitored Well-Static, RIH to 2,869' Circ Btms Up and Blew Down Top Drive RU & Performed DEEP FIT Test to 16.6 ppg EMW with 10.8 ppg at 780 psi, RD & Blew Down Lines Pump Dry Job & POOH from 2,869', Monitored Well at BHA-Static, POOH to Bit Download MWD, PU Density/Neutron Tool & Uploaded Serviced Rig & Top Drive Pulse Test MWD & Load Nuclear Source TIH Filling Pipe at 2,915' & 4,910' Precautionary Wash & Reamed from 6,159' to 6,278' (120') No Problems or Fill on Btm Circ Btms up with 10.8 ppg Mud in Hole, Max Gas at Btms Up 137 Units, Circ at 140 Spm, 417 Gpm's at 1,735 Psi Began Displacing 10.8 ppg in Hole with 12.3 ppg. Fin Displacing 10.8 ppg Mud in Hole Over 12.3 ppg, Cleaned out at Shakers & Possum Belly, Fin Raising MW in Pits to 12.3 ppg, Took SPR's & Took PWD Base Lines at 6,250', @ 475 GPM & 50 RPM's had 13.13 ECD, 400 GPM & 70 RPM's 13.0 ECD, 475 GPM & 70 RPM's had 13.15 ECD Printed: 12/2/2002 4:54:58 PM ) ) Page 6 of 7 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3S-07 3S-07 ROT - DRILLING N1268@ppco.com Nabors 7ES Start: 1 0/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: F'rom>Tb HoUrs ......Cbde ¿6äbè De$criptiþn...of...Qþerati90$ 11/19/2002 03:00 - 10:00 7.00 DRILL DRLG INTRM1 10:00 - 11 :30 1.50 DRILL CIRC INTRM1 11 :30 - 13:30 2.00 DRILL WIPR INTRM1 13:30 - 15:30 2.00 DRILL CIRC INTRM1 15:30 - 20:30 5.00 DRILL TRIP INTRM1 20:30 - 23:00 2.50 DRILL TRIP INTRM1 23:00 - 23:30 0.50 DRILL TRIP INTRM1 23:30 - 00:00 0.50 CASE RURD INTRM1 11/20/2002 00:00 - 02:00 2.00 CASE RURD INTRM1 02:00 - 12:00 10.00 CASE RUNC INTRM1 12:00 - 18:00 6.00 CASE CIRC INTRM1 18:00 - 19:00 1.00 CEMENT PUMP INTRM1 19:00 - 20:00 1.00 CEMENT DISP INTRM1 20:00 - 21 :00 1.00 CEMENTCIRC INTRM1 21 :00 - 22:30 1.50 CEMENT RURD INTRM1 22:30 - 23:00 0.50 CMPL TN OTHR INTRM1 23:00 - 00:00 1.00 CMPL TN RURD CMPL TN 11/21/2002 00:00 - 08:00 8.00 CMPL TN RUNT CMPL TN Drilled from 6,278' to 6,633' MD/ 6,091' TVD, 8 1/2" TD, ART 4 3/4 Hrs, AST 1/2 Hr. 15-20K WOB, 100 RPM's, 160 SPM, 475 GPM at 2,350 Psi, Torque Off Btm 8,500 Ft#'s, On Btm 9,500 Ft#'s, ROT Wt 159K, Up Wt 195K, Dn Wt 130K, Est Top of KUP "c" 6,385' MD/5,846' TVD Pump 45 bbl Hi Vis Sweep, Had Silver Dollar Size Clay Pieces Back at Btms Up, Circ Hole Clean, Ave 10 Units BGG, Monitored Well-Static Wiped Hole 12 Stds to 5,490' No Problems, TIH & Washed 96' to Btm, No Problems or Fill, Pumped 45 bbl Hi Vis Sweep & Circ Hole Clean, Max Gas 37 Units BGG, Monitored Well-Static Pumped Dry Job & POOH to Dir BHA, No Problems, SLM, No Corr, Monitored Well at Shoe & at BHA Held PJSM, Removed Radioactive Source, Download MWD, LD 3-6 1/2" Dc's, MWD, Density Neutron & MM Pulled Wear Bushing Began RU to Run 7" Csg, Changed Out Elevator Bails Fin RU Nabors Csg Equipment & GBR Fill-Up Tool Held Safety Mtg on Running of 7" Csg MU 7" Float Shoe, 2 Jts of 7" 26# L-80 BTC Mod Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 153 Jts 7" Csg, (Total of 155 Jts Ran 6,623.18' ) Note: Nabors Floorhand Robert Miller Twisted Ankle While Running 7" Csg, Stepped on Railing Stop for Iron Roughneck While Tailing in Csg Est Circ & Reciprocating Pipe Up Wt190K, Dn Wt 11 OK -While Reciprocating Pipe after approx 25 Min Dn Wt down to 80K,Attempted to PU on Csg, PU W/70K Over, Pipe Stuck, Landed Csg in Hanger, RD Fill Up Tool & MU Cmt Head on Landing Jt & Cont to Circ Csg for Cmt Job, Lowered YP from 30 to 23 with 45 vis, Circ at 209 Gpm's at 470 Psi, Landed Csg With FS @ 6,623', FC @ 6,536' RU Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wI Class G + .300% D65, 2.000 gal/sk D600G, .20Q gallsk D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls of at 15.8 at rate of 5.5 bpm at 500 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmt around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wI total of 257.5 bbls, Bumped plug wI 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20102, Ck floats & Held, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. Flushed Out Mud Pump, Stack & Flowline LD Landing Jt, RD Csg Tools & Changed Out Elevator Bails RU & RIH and Set 7" Pack-off, Tested Same to 5,000 Psi for 10 Min, LD Setting Tool RU Nabors 3 1/2" Tbg Handling Tools RIH with 31/2" Completion Assembly per Well Plan, RIH with 195 Jts 3 1/2" 9.3#, L-80 EUE Mod Tbg, Baker Pkr/Pbr & GLM assembly to 6,230' Printed: 12/2/2002 4:54:58 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') Page 7 of 7 ConocoPhillips Alaska Operations Summary Report 3S-07 3S-07 ROT - DRILLING N 1268 @ ppco.com Nabors 7ES Date Sub From - To Hours Code Code Phase 11/21/2002 08:00 - 09:00 09:00 - 09:30 09:30 - 10:30 10:30 - 13:00 1.00 CMPL TN OTHR CMPL TN 0.50 CMPL TN PCKR CMPL TN 1.00 CMPL TN RUNT CMPL TN 2.50 CMPL TN DEaT CMPL TN 13:00 - 13:30 0.50 CMPL TN RURD CMPL TN 13:30 - 16:30 3.00 CMPL TN NUND CMPL TN 16:30 - 18:30 2.00 CMPL TN NUND CMPL TN 18:30 - 20:00 1.50 CMPL TN SEaT CMPL TN 20:00 - 21 :00 1.00 DRILL LOT INTRM1 21 :00 - 22:00 1.00 CMPL TN FRZP CMPL TN 22:00 - 23:00 1.00 CMPL TN FRZP CMPL TN 23:00 - 00:00 1.00 CMPLTN TRIP CMPLTN Start: 1 0/29/2002 Rig Release: 11/21/2002 Rig Number: Spud Date: 11/1/2002 End: 11/22/2002 Group: Description of Operations RU & tested 7" Csg to 3,500 Psi for 30 Min, Final Press after 30 Min 3,460 Psi, Good Test, RD Droped Ball & Press Up to 3,500 Psi & Set Baker 31/2" x 7" "SAB-3" Perm Pkr with 80-40 PBR at 6,271', PU & PBR Sheared When Ball Sheared, PU 15' RIH & Tagged Pkr. MU Gen V 7" x 9 5/8" Hanger & Landed Tbg, LD Landing Jt and RD Tbg Tongs, Verified Hanger Landed & Ran in Lock Downs, Landed Tbg String with WLEG @ 6,303', "D" Nipple @ 6,296', Pkr @ 6,271', PBRlSBR @ 6,257', CMU SLDG Sleeve @ 6,208', GLM's @ 6,156', 5,637',4,990',4,063',2,789' & "DS" Nipple @ 495'. RU & Tested 31/2" Tbg to 3,500 Psi for 15 Min, Tested Tbg With Ann Open, Tested 31/2" x 7" Annulus to 3,500 Psi for 15 Min While Holding 1,500 Psi on Tbg, Good Tests, Bled Off Tbg Press & Sheared out DSR Valve RD 31/2" Tbg Handling Tools Installed BPV, ND 135/8" 5M BOP Stack, Changed Out Riser adapter to 20" NU 11" 5M x 3 1/8" 5m Tree, Pulled BPV & Installed 2 Way Ck. Tested Tbg Hanger Pack-off to 5,000 Psi, Tested Tree to 5,000 Psi, Good Test, Pulled 2 Way Ck. RU & Performed LOT on 7" x 9 5/8" csg Annulus for Annular Inj, Had Leak off at 620 Psi with 12.3 ppg Mud in Hole for a 16.9 ppg EMW, RD RU on Tbg & Freeze Protected Tbg to 6,156' & 31/2" x 7" Annulus to 2,000' with 105 bbls of Diesel, Final Press 300 psi, Installed BPV Pumped 160 bbls Water Down 7" x 9 5/8" Ann At 3 BPM @ 800 Psi, Followed with 56 bbls of Diesel to Freeze Protect Ann to 2,000', Final Press 625 Psi, Shut In Ann. & Secured Well LD 45 Jts of 5" DP from Derrick & Fin Cleaning Mud Pits, RELEASED RIG @ 24:00 Hrs 11/21/02, To Move Rig to 3S-18 Printed: 12/2/2002 4:54:58 PM Date 11/24/02 11/26/02 ) 3S-07 Event History ) Comment TAGGED @ 65211 RKB, DRIFTED WI 231-6" OF 2.59" DUMMY GUN1S, REPLACED SHEARED 1.5" DCR @ 61571 RKB WI DV, PT IIA & TBG TO 2500# [TAG, GLV, PTTBG-CSG] PERFORATED 25 FT 2506 POWERJETS @ 6 SPF-- PERF INTERVAL (6388 TO 6413)- AFTER PERF BOTTOM HOLE PRESSURE -TEMP.-- TAGGED @ 6528. DROPPED WHP TO MINIMUM (-100 PSI) AT TIME OF PERF-- SHUT IN PRESS. POST JOB 1150 PSI. WELL TURNED BACK TO PAD OP. WELL LEFT SHUT IN. -- Page 1 of 1 12/3/2002 ) AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3S-07 Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey Projected Survey: ) 08-Dec-02 0.00 I MD 0.00' MD (if applicable) 6,633.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 1'~' IE I.< .~ IVED DEC 1 3 2002 " . l :'~. 'r" if, ~.",' ,.~ J"tíã,;,.\a Ii Gas GO(j(,i; t'M'f) ..' . -I"". v"'li~ndSSlon Anchorage c:3,D¿;. - / 't 7 Sperry-Sun Drilling Services Western North Slope ConocoPhillips Kuparuk 38 Pad 38-07 ~/ Job No. AKMW22174, Surveyed: 19 November, 2002 Survey Report 6 December, 2002 Your Ref: API 501032043000 Surface Coordinates: 5993928.18 N, 476324.84 E (70023'40.3534" N, 150011' 33.4660" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 993928.18 N, 23675.16 W (Grid) Surface Coordinates relative to Structure: 84.77 N, 130.43 W (True) Kelly Bushing: 56.37ft above Mean Sea Level Elevation relative to Project V Reference: 56.37ft Elevation relative to Structure: 0.27ft sper-''-'y-sul! i:U=tlLLING SERVices A Halliburton Company Survey Ref: svy9996 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-07 Your Ref: API 501032043000 Job No. AKMW22174, Surveyed: 19 November, 2002 ConocoPhif/ips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -56.37 0.00 0.00 N 0.00 E 5993928.18 N 476324.84 E 0.00 MWD Magnetic 162.49 0.720 161.300 106.12 162.49 0.97 S 0.33 E 5993927.21 N 476325.16 E 0.443 -0.29 216.93 0.890 170.520 160.55 216.92 1.71 S 0.51 E 5993926.47 N 476325.34 E 0.392 -0.58 310.06 1.830 90.350 253.66 310.03 2.43 S 2.11 E 5993925.74 N 476326.95 E 2.033 0.31 406.21 4.250 71.870 349.67 406.04 1.33 S 7.03 E 5993926.83 N 476331.87 E 2.684 4.96 493.51 5.400 75.510 436.66 493.03 0.70N 14.09 E 5993928.84 N 476338.93 E 1.363 11.89 -' 584.66 6.990 69.560 527.27 583.64 3.71 N 23.44 E 5993931.82 N 476348.29 E 1.879 21.26 675.32 7.540 65.990 617.21 673.58 8.06N 34.04 E 5993936.13 N 476358.90 E 0.785 32.42 765.42 7.670 61.830 706.51 762.88 13.30 N 44.74 E 5993941.34 N 476369.62 E 0.628 44.18 855.74 9.680 60.870 795.80 852.17 19.85 N 56.69 E 5993947.85 N 476381.59 E 2.231 57.71 950.78 12.670 60.200 889.02 945.39 28.92 N 72.72 E 5993956.87 N 476397.65 E 3.149 76.03 1046.75 15.560 59.920 982.09 1038.46 40.60 N 92.99 E 5993968.49 N 476417.96 E 3.012 99.32 1139.15 18.390 56.870 1070.45 1126.82 54.78 N 115.93 E 5993982.60 N 476440.94 E 3.210 126.23 1238.10 20.780 56.590 1163.67 1220.04 72.98 N 143.65 E 5994000.71 N 476468.72 E 2.417 159.38 1333.16 24.950 55.060 1251.24 1307.61 93.76 N 174.18 E 5994021.39 N 476499.32 E 4.431 196.30 1428.71 26.150 55.170 1337.45 1393.82 117.33 N 207.98 E 5994044.85 N 476533.19 E 1.257 237.50 1523.52 26.930 54.140 1422.27 1478.64 141.84 N 242.53 E 5994069.25 N 476567.82 E 0.955 279.87 1614.77 29.110 53.730 1502.82 1559.19 167.08 N 277.18 E 5994094.38 N 476602.55 E 2.398 322.73 1712.95 29.070 54.680 1588.61 1644.98 194.99 N 315.90 E 5994122.17 N 476641.35 E 0.472 370.46 1808.28 29.650 54.900 1671.70 1728.07 221.94 N 354.09 E 5994149.00 N 476679.63 E 0.619 417.20 1903.73 29.660 54.760 1754.65 1811.02 249.15 N 392.69 E 5994176.08 N 476718.32 E 0.073 464.42 1998.79 29.980 55.060 1837.12 1893.49 276.32 N 431.37 E 5994203.13 N 476757.08 E 0.371 511.69 2091.95 29.780 55.180 1917.90 1974.27 302.86 N 469.44 E 5994229.55 N 476795.24 E 0.224 558.10 2188.73 28.220 54.410 2002.54 2058.91 329.90 N 507.78 E 5994256.47 N 476833.67 E 1.657 605.02 .'~ 2283.82 27.620 53.490 2086.56 2142.93 356.10 N 543.78 E 5994282.56 N 476869.75 E 0.777 649.54 2379.58 25.980 54.840 2172.03 2228.40 381.39 N 578.78 E 5994307.73 N 476904.82 E 1.827 692.71 2475.30 25.190 54.950 2258.37 2314.74 405.16 N 612.59 E 5994331.40 N 476938.71 E 0.827 734.05 2567.86 25.060 55.330 2342.17 2398.54 427.62 N 644.84 E 5994353.76 N 476971.03 E 0.224 773.34 2664.59 25.480 54.510 2429.64 2486.01 451.36 N 678.63 E 5994377.38 N 477004.90 E 0.565 814.64 2701.33 25.450 54.050 2462.81 2519.18 460.58 N 691.45 E 5994386.57 N 477017.75 E 0.544 830.43 2826.59 27.730 54.470 2574.82 2631.19 493.32 N 736.96 E 5994419.16 N 477063.36 E 1.826 886.49 2920.33 27.780 53.320 2657.77 2714.14 519.04 N 772.23 E 5994444.77 N 477098.71 E 0.574 930.14 3015.82 27.020 53.090 2742.55 2798.92 545.36 N 807.42 E 5994470.98 N 477133.99 E 0.804 974.07 3112.75 26.070 53.400 2829.26 2885.63 571.28 N 842.13 E 5994496.79 N 477168.77 E 0.990 1017.38 3208.01 27.560 56.790 2914.28 2970.65 595.84 N 877.37 E 5994521.23 N 477204.10 E 2.241 1060.33 6 December, 2002 - 15:02 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad. 3S-01 Your Ref: AP/501032043000 Job No. AKMW22114, Surveyed: 19 November, 2002 ConocoPhillips Western North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3303.99 27.130 57.690 2999.53 3055.90 619.69 N 914.45 E 5994544.98 N 477241.24 E 0.621 1104.37 3400.18 26.670 57.600 3085.32 3141.69 642.98 N 951.21 E 5994568.15 N 477278.08 E 0.480 1147.83 3496,75 28.930 57.270 3170.73 3227.10 667.23 N 989.16 E 5994592.27 N 477316.11 E 2.346 1192.81 3591.75 29.130 56.640 3253.80 3310.17 692.37 N 1027.81 E 5994617.29 N 477354.83 E 0.385 1238.87 3686.65 28.660 56.520 3336.89 3393.26 717.62 N 1066.08 E 5994642.42 N 477393.19 E 0.499 1284.70 3781.56 28.500 56.440 3420.23 3476.60 742.70 N 1103.93 E 5994667.38 N 477431.12 E 0.173 1330.08 ~ 3871.29 28.200 56.440 3499.20 3555.57 766.25 N 1139.44 E 5994690.82 N 477466.70 E 0.334 1372.67 3968.83 27.580 56.360 3585.41 3641.78 791.50 N 1177.44 E 5994715.95 N 477504.78 E 0.637 1418.27 4067.28 27.000 56.170 3672.90 3729.27 816.57 N 1214.98 E 5994740.90 N 477542.40 E 0.596 1463.39 4159.66 26.460 56.950 3755.41 3811.78 839.47 N 1249.65 E 5994763.69 N 477577.14 E 0.697 1504.92 4255.70 28.890 53.190 3840.46 3896.83 865.04 N 1286.17 E 5994789.14 N 477613.74 E 3.115 1549.50 4350.39 28.880 52.940 3923.37 3979.74 892.53 N 1322.73 E 5994816.51 N 477650.39 E 0.128 1595.22 4444.88 28.090 53.120 4006.42 4062.79 919.63 N 1358.73 E 5994843.50 N 477686.48 E 0.841 1640.27 4539.73 27.680 52.860 4090.26 4146.63 946.33 N 1394.16 E 5994870.09 N 477721.99 E 0.451 1684.62 4634.59 27.390 52.290 4174.37 4230.74 972.98 N 1428.98 E 5994896.63 N 477756.90 E 0.413 1728.44 4730.13 27.030 52.110 4259.34 4315.71 999.76 N 1463.50 E 5994923.30 N 477791.50 E 0.387 1772.09 4827.49 26.610 52.600 4346.23 4402.60 1026.59 N 1498.28 E 5994950.02 N 477826.37 E 0.488 1815.98 4923.77 27.890 53.470 4431.82 4488.19 1053.09 N 1533.51 E 5994976.41 N 477861.68 E 1.392 1860.05 5018.93 27.880 53.800 4515.93 4572.30 1079.48 N 1569.35 E 5995002.68 N 477897.60 E 0.163 1904.55 5112.59 27.11 0 53.110 4599.01 4655.38 1105.22 N 1604.09 E 5995028.32 N 477932.42 E 0.890 1947.78 5207.33 26.400 52.980 4683.61 4739.98 1130.86 N 1638.17 E 5995053.85 N 477966.58 E 0.752 1990.41 5302.83 25.750 52.770 4769.39 4825.76 1156.20 N 1671.64 E 5995079.08 N 478000.13 E 0.687 2032.37 5397.89 24.980 52.980 4855.28 4911.65 1180.78 N 1704.11 E 5995103.55 N 478032.68 E 0.816 2073.07 "",~,.j'/ 5492.97 23.970 54.110 4941.82 4998.19 1204.19N 1735.78 E 5995126.86 N 478064.43 E 1.171 2112.45 5588.40 22.620 53.880 5029.47 5085.84 1226.37 N 1766.31 E 5995148.95 N 478095.03 E 1.418 2150.19 5678.17 21.330 53.930 5112.71 5169.08 1246.16 N 1793.46 E 5995168.65 N 478122.23 E 1.437 2183.78 5775.46 20.170 53.280 5203.69 5260.06 1266.61 N 1821.20 E 5995189.01 N 478150.05 E 1.216 2218.24 5872.29 19.490 52.660 5294.78 5351.15 1286.39 N 1847.43 E 5995208.71 N 478176.33 E 0.735 2251.07 5967.84 18.290 52.630 5385.18 5441.55 1305.16 N 1872.02 E 5995227.40 N 478200.98 E 1.256 2281.99 6063.41 16.880 52.600 5476.28 5532.65 1322.69 N 1894.96 E 5995244.86 N 478223.98 E 1.475 2310.84 6158.14 13.890 53.300 5567.61 5623.98 1337.84 N 1915.01 E 5995259.95 N 478244.07 E 3.162 2335.96 6208.57 13.250 52.500 5616.63 5673.00 1344.97 N 1924.44 E 5995267.05 N . 478253.53 E 1.323 2347.79 6373.15 9.720 52.630 5777.89 5834.26 1364.89 N 1950.46 E 5995286.89 N 478279.61 E 2.145 2380.53 6468.52 9.180 51.360 5871.96 5928.33 1374.53 N 1962.80 E 5995296.49 N 478291.98 E 0.607 2396.17 6562.98 8.780 51,110 5965.27 6021.64 1383.76 N 1974.30 E 5995305.68 N 478303.51 E 0.425 2410.89 6 December, 2002 - 15:02 Page 3 of4 DrillQuest 3.03.02.004 '" Sperry-Sun Drilling Services Survey Report for Kuparuk 3S Pad - 3S-07 Your Ref: API 501032043000 Job No. AKMW22174, Surveyed: 19 November, 2002 Western North Slope Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 6633.00 8.780 51.110 6034.47 6090.84 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1982.61 E 5995312.37 N 478311.85 E 1390.47 N All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.31' MSL. Northings and Eastings are relative to 2481' FNL, 935' FEL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2481' FNL, 935' FEL and calculated along an Azimuth of 54.610° (True). Magnetic Declination at Surface is 25.287°(06-Nov-02} Based upon Minimum Curvature type calculations, at a Measured Depth of 6633.00ft., The Bottom Hole Displacement is 2421.61ft., in the Direction of 54.957° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 6633.00 6090.84 1390.47 N 1982.61 E Projected Survey Survey tool program for 35-07 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 6633.00 6090.84 MWD Magnetic 6 December, 2002 - 15:02 Page 4 of4 Dogleg Rate (0/100ft) Vertical Section ConocoPhillips Comment 0.000 2421.56 Projected Survey ~ ~ DrillQuest 3.03.02.004 ) ~ ConocoPhilUps ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Scott Lowry Phone (907) 265-6869 Fax: (907) 265-1535 Email: scott.l.lowry@Conocophillips.com November 26,2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well 3S-07 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that 3S-07 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regula?- 20 ACC 25.080. It is intended to begin annular disposal operations on 3S-07 as soon as possible. Please find attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). / 6. Production Casing Description 7. Production Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus /' 9. Plan View of Existing Adjac~ e s 10. Plan View of Existing an Flann Adjacent Wells 11. Details on we1l3S-26 (c the only other well at DS-3S) / If you have any questions or require further information, please contact Scott Lowry at 265-6869, or Randy Thomas at 265-6830. Sincerely, ~~ Scott Lowry Drilling Engineer RECEIVED NOV 2 6 2002 Alaska Oil & Gas Cons. GommlSSIOf Anchoraae STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS J 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2487' FNL, 935' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 1109' FNL, 1041' FWL, Sec. 17, T12N, R8E, UM At effective depth At total depth 1090' FNL, 1068' FWL, Sec. 17, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical 6633 6091 Effective depth: measured true vertical Casing Length Size Conductor 80' 16" x 30" Surface 2741' 9.625" Production 6595' 7" Perforation depth: measured No Perforations true vertical No Perforations Tubing (size, grade, and measured depth 3.5",9.3#, L-80 @ 6304' Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _XX Exploratory Stratigraphic - Service - (asp's: 476325, 5993928) (proposed) (proposed) feet feet feet feet Plugs (measured) Junk (measured) Cemented 59 sx Arctic Crete 590 sx AS Lite, 220 sx LiteCrete 218 sx Class G Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 6272', No SSSV 13. Attachments Description summary of proposal _XX 14. Estimated date for commencing operation November 27,2002 16. If proposal was verbally approved ) vJ6,A- I L! OS/ OL ~ rz/S'!~ íJ75 1(/-5 /'fl. vß '''1.-/ r /0 ~ Re-enter suspended well - Time extension - Stimulate - Variance - Perforate- 6. Datum elevation (DF or KB feet) RKB 28 7. Unit or Property name Other _X Annular Disposal Kuparuk River Unit 8. Well number 3S-07 9. Permit number I approval number 202-187 10. API number 50-103-20430 11. Field I Pool Kuparuk River Field / Kuparuk Oil Pool Measured Depth 108' 2769' 6623' True vertical Depth 108' 2580' 6081' RECE1VED NOV 2 6 2002 A\aska Oit & Gas Cons, comffi\ssion Anchorage Detailed operations program 15. Status of well classification as: BOP sketch - Oil_XX Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed \ Z~ \. ~ R. Thomas , Gas- Suspended - Questions? Call Scott Lowry 265-6869 ~ Title: Kuparuk Drilling Team Leader Date \ \ (<..b (0'( Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- Approved by order of the Commission QR'G'NAL SIGNED BY Nt BiB Form 1 0-403 Rev 06/15/88 . \. ¡', Approval no. ,,-3'¿').;2. -_3 (;. t Ikpoyt ~ ctrtlt trtltit,r d.t'!.f" $:A..(, Commissioner Date h?{ ./0. ()¿) 9 2002 DEC f?B OMS BF l SUBMIT IN TRIPLICATE ) ) Note to File Well 3S-07 PTD 202-187 Sundry 302-361 ConocoPhillips Alaska, Inc. requests approval for annular disposal in the subject well. This note analyzes information submitted by the applicant, affirms me- chanical integrity of all wells within 3S-07's area of review (AOR), and recom- mends approving this request for annular disposal. 3S-07 9-5/8" surface casing was cemented with 432 bbls lead cement followed by 74 bbls tail cement, totaling about 2500/0 excess cement relative to gauge wellbore. 45 bbls of lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that 3S-07's surface casing is adequately cemented. The formation below the 9-5/8" casing shoe supported an 18.1 ppg EMW forma- tion integrity test. Applied pressure dropped 170 psi (from 1150 psi) during a 10 minute observation. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 16.9 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure reached a maximum of 620 psi. The pressure then stabilized and shut in pressure varied between 450 psi and 250 psi over 10 minutes. Cementing records indicate mechanical integrity of the well (35-26) within 35-07's AOR. Based upon information submitted, AOGCC recommends approval of Conoco- Phillips's request for annular disposal in Well 3S-07 (PTD 202-187). Wc.k- p-II!J"SjO"L- Winton Au bert Petroleum Engineer AOGCC Geologic Considerations Annular Disposal 3S Pad KRU The 3S Pad is located within the Kuparuk River Unit aquifer exemption area. This aquifer exemption was issued by the EPA and includes all aquifers through a very large area including Kuparuk River, Milne Point and portions of Prudhoe Bay and Hemi Springs Units. The 3S pad is near the western extreme of the area. ) Surface casing is set below the West Sak sands in the Colville Shale in this por- tion of the KRU. The disposal interval will consist of low mechanical strength shales and silts with minor low permeability, low volume sands. The sands are frequently hydrocar- bon bearing. This sequence of mudstones referred to as the Colville Shale is several thousand feet thick in the Palm area. The Colville shale has a long es- tablished track record of functioning well as a receiving zone for annular disposal operations. Alpine, Meltwater, Tarn and numerous pads within the KRU all have established histories of successful annular disposal operations in the Colliville Shale. Geologic conditions are favorable for annular disposal operations on the KRU 3S Pad. I concur with Dr. Aubert. Robert Crandall Senior Petroleum Geologist AOGCC ) ) Annulus Disposal Transmittal Form - Well 35-07 A. Designation of the well or wells to receive drilling wastes: B. The depth to the base of freshwater aquifers and permafrost, if present. 38-07 No Aquifers / Base Permafrost = +/- 1546' TVD RKB C. A stratigraphic description of the interval exposed to the From the 9-5/811 shoe to the Cement top all that is open open annulus and other information sufficient to support is interbedded claystone, siltstone and shale with a commission finding that the waste will be confined and occasional minor non-hydrocarbon bearing sands. will not come to the surface or contaminate freshwater. D. A list of all publicly recorded wells within one-quarter 8ee attached horizontal plane clearance report and plot mile and all publicly recorded water wells within one mile indicating one well (38-26) within 1/4 mile of the surface of the well to receive drilling waste. casing shoe of 38-07. There are no potable water wells within one mile of 38-07. As of 11/25/02, no other wells have been permitted for annular disposal on D8-38. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. G. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: H. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: I. Any additional data required by the Commission to confirm containment of drilling wastes: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 2,131 psi. 8ee attached calculation page. 8ee attached: cementing reports, LOT / FIT reports and casing reports. 8ee attached casing summary sheet and calculation pages. w w :; :; (J) (J) (J) (J) ~ ~ Co Q ã5 ã5 "'C "'C a:I a:I CJ) CJ) ..c: ..c: ëñ ëñ Co Q 0 0 It') It') Ct) Ct) r- r- + + ~ ~ ëñ ëñ Co Q r- r- Ó Ó (J) (J) a:I a:I ø ø L Well 3S-07 Date 11/23/2002 ~ 9 518" Surface Csg .---------- .--- --. ---tõë-ËšC@-Š-ŠŠ'8' MDI 5067' TVD Z8 3 1/2"Tb£ L ~ 7" Production Csg ) TVD 2580 ft. Assumptions Maximum injection pressure of 1500 psi Maximum density of the injection fluid is 13.0 ppg Pore pressure at the 9 5/8" casing shoe is .4316 psi/ft Gas lift gas pressure is 0.11 psi/ft + 1350 psi header pressure Maximum Pressure at Surface Shoe Max Disposal MW 13.0 ppg Max Pressure at Surface Shoe = 2131 psi Max Pressure at Surface Shoe Max Press=Max Disposal Press+(Max Disposal MW)(.052)(TVD)-(Fluid WI. On Backside)(.052)(TVD) (FIT performed on surface casing shoe to 18.1 ppg EMW or 2428 psi) Production CasinQ Size Wt. Grade Pcollapse @ 100% Pcollapse @ 85% Gas Depth (TVD) Gas Gradient Max Disposal Pressure Gas Lift Header Pressure 7.000 In. 26.00 Ibs. L 80 5410 psi 4599 psi 5067 ft. 0.11 ppg 1500 psi 1350 psi Maximum Mud Weight = (to collapse casing) 19.0 ppg Intermediate Casing Collapse MMW = Pc@85%+(Gas Gradient)(Gas TVD)+Gas Lift Header Pressure-Max Disposal Press (TVD)(.052) Surface CasinQ Size Wt. Grade Pburst @ 100% Pburst @ 85% Fluid Weight on Backside Max Disposal Pressure 9.625 In. 40.00 Ibs. L 80 5750 psi 4888 psi 8.3 ppg 1500 psi Maximum Mud Weight = (to burst casing) 33.5 ppg Surface Casing Burst MMW = Pb@85%+(FluidWeighton Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) ) ) Casing Detail 9 5/8" Surface CasinQ ~,m.~.i.~(.PHILLIPS Alaska, Inc. t~) A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num 01 Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 46 to 70 Jts 3 to 45 Jts 1 to 2 25 Jts Nabors 7ES RKB to Landing Ring FMC Gen V Hanger 9-5/8" 40# L -80 BTC Csg TAM Port Collar 40# L-80 BTC 9-5/8" 40# L-80 BTC Csg Davis Lynch Float Collar 9-5/8" 40# L -80 BTC Csg Davis Lynch Float Shoe 43 Jts 2 Jts TD 12 1/4" Surface Hole RUN TOTAL 14 BOWSPRING CENTRALIZERS - 2 on jt. #1 (10. up across stop ring and over collar) 1 on Jt. #2 (across stop ring 10 . below FC) 1 per jt on Jt #3 - #13 Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 160k Dn Wt - 130k Block Wt - 70k Well: 3S-07 Date: 11/13/2002 LENGTH 28.80 2.20 969.34 3.00 1681.08 1.48 81.74 1.71 Supervisor: David Burley DEPTH TOPS 28.80 31.00 1000.34 1003.34 2684.42 2685.90 2767.64 2769.35 2776.00 ) ') ConocoPhillips Alaska Cementing Report Legal Well Name: 38-07 Common Well Name: 38-07 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,767 (ft) 11/13/2002 Surface Casing 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Page 1 of 3 Report #: Start: 8pud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Rick Gallegos Cmtd. Csg: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) pipf!""ôv~mer'lt Pipe Movement: Reciprocating Rot Time Start:: Time End:: RPM: Ree Time Start:20:00 Time End: 00:30 SPM: 1 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 150 (Ibs) Type: Cement Casing Volume Excess %: 250.00 Meas. From: 45 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 336 (gpm) Mud Circ Press: 430 (psi) Max Torque: (ft-Ibf) Drag Down: 110 (Ibs) §t~geNØ:1ôf1 Start Mix Cmt: 22:43 Start Slurry Displ: 22:44 Start Displ: 00:14 End Pumping: 00:44 End Pump Date: 11/15/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 8.00 (bbl/min) 8.00 (bbl/min) N 315 (psi) (psi) (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 45.00 (bbl) Ann Flow After: N Mixing Method: Dir blow Density Meas By: densometer Type: Spud Mud Density: 9.8 (ppg) Visc: 75 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PV/yP: 34 (cp)/31 (lb/100ft2) Gels 10 sec: 10 (lb/100ft2) Gels 10 min: 17 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 204.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1$lurry No: 1 ôf4 To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: 50.0 (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11 :27:30 AM ConocoPhillips Alaska Cementing Report ) Page 2 of 3 Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: $tag~Nt1: t SlurrvNg: 2qf4 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Slurry Data Fluid Type: LEAD Description: AS Lite Class: Slurry Interval: 1,605.00 (ftJfo: 29.00 (ft) Cmt Vol: 432.0 (bbl) Density: 10.70 (ppg) Yield: 4.28 (ft3/sk) Water Source: Lake water Slurry VoIS90 (sk) Water Vol: 280.0 (bbl) Other Vol: () Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: 19.93 (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) (OF) Slurry Data Fluid Type: TAIL Description: LiteCRETE Slurry Interval: 2,769.00 (ftJfo: 1,605.00 (ft) Cmt Vol: 74.0 (bbl) Water Source: lake Slurry Vol:220 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Class: Density: 12.00 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 38.0 (bbl) Other Vol: () Purpose: PRIMARY Mix Water: 7.45 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11:27:30 AM ') ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 1 Report Date: 11/15/2002 10/29/2002 End: 11/22/2002 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: LqQl~~rvèy.E\Î~ltJ~~~9P Iptë..þt~t~ti()1i $tJli1li1~ry CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield Pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chem Wash, Dropped Btm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt. Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs. Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm I 350 psi. Dropped top plug - cementers displaced with 20 bbls FW - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untilllast 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. Printed: 11/23/2002 11 :27:30 AM ') ) Page 1 of 2 ConocoPhillips, Alaska Daily Drilling Report TMD I TVD I DFS 2,776.0 2,586.0 5.00 AUTH MD I DAILY TANG 6,611.0 0.00 DAILY INT W/O MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 11/11/2002 312,453 ILEAKOFF AFE WCD.K3S.0045.01 I NEXT CASING 9.625 (in) @ 2,770.0 (ft) 0.00 CùMP(j$tl Pf/Mf CI Ca H2S I I REPT NO. I DATE 13 11/13/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,533,678 WELL NAME 3S-07 I JOB NUMBER I EVE~OC~DE 124 HRS PROG SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. David Burley/Peter Wilso N1268@ppco.co Nabors 7ES Kuparuk River CURRENT STATUS ACCIDENTS LAST 24 HRS.? ND Divertor 24 HR FORECAST NU Wellhead & BOPS, Test BOPE, PU 8 1/2" Drlg Assembly LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 11/12/2002 2,701.33 25.450 54.050 16.000 (in) @ 108.0 (ft) DENSITY(ppg) I 9.80 Ippl IE.êó IMU[)[)À'ÀIDÂI~xç(j$tl FV. PVIYP GELS WLlHTHP Fcrr~SOL OIUWAT %SandlMBT phlPIl.4 75 34/31 10/17 5.01 2/ / /21.0 I AUTH. 2,484,894 LAST BOP PRES TEST 0.00 LIME ES I ~ltNë>.1 2 BHA LENGTH 930.45 CONN SIZE CONN TYPE 6tilÄ ~9.1 2 I . aHAWT~BElOWJAR$ BHAIHOLECONDITIONS StRING WT.ON STRINGWr~ROt l.ENGTH 1.20 29.28 2.24 6.03 5.26 22.84 9.20 25.13 9.94 2.77 90.42 272.23 31.71 422.20 ITEM DESCRIPTION O~D. 12.250 8.000 8.000 8.000 8.000 8.000 8.000 8.110 8.000 7.750 6.500 5.000 6.250 5.000 I.D~ 4.000 5.250 2.500 2.810 2.875 2.900 3.450 2.900 2.815 2.750 2.813 3.000 2.750 3.000 NOJTS Bit Mud Motor Float Sub Pony Collar - Non Mag Stabilizer LWD GRlRES MWD OIR LWD DEN/NEU MWD HOC Crossover Flex Collar - Non Mag Orill Pipe - Heavy Wgt Hyd Jars Drill Pipe - Heavy Wgt 1 1 1 1 1 1 1 1 1 3 9 1 14 BITS SERIAL NO. JETSORTFA 5012523 24/24/24/1011 5012523 24/24/24/1011 DEPTH IN DATE IN I-O-D-L-B-G-O-R 228.0 11/9/20020-0------ 228.0 11/9/20022-3-WT-A-E-1-NO-TD BIT OPERATIONS RPM I GPM I PRESS I P BIT I HRS I 24Hr DIST I 24HrROP ICUMHRS I CUM DEPTH I CUM ROP OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Fin POOH to Flex Collar & LD Collar SURFAC Pulled Sperry Suns Nuclear Source, Downoad MWD, LD MWO & 1.5 deg MM & 12 1/4" Bit SURFAC RU Nabors Csg Tools and GBR Fill-up Tool. SURFAC Made dummy run with Hanger & Landing JT, had to center twenty inch riser to rotary table to allow centralizer on landing joint to pass. SURFAC Held Safety Mtg on Running of 9 5/8" Csg SURFAC MU 95/8" Flaot Shoe, 2 Jts of 9 5/8" 40# L-80 BTC Csg, Float Collar, Tested WOB BIT I RUN FROM TO HOURS CODE TROUBLE SUB 00:00 02:00 2.00 DRILL P TRIP 02:00 05:30 3.50 DRILL P TRIP 05:30 08:00 2.50 CASE P RURD 08:00 09:00 1.00 CASE Np EOIP RURD 09:00 09:30 0.50 CASE P SFTY 09:30 16:00 6.50 CASE P RUNC Printed: 11/23/2002 11 :28:57 AM ConocoPhillips, Alaska Daily Drilling Report I JOB NUMBER I EVE~DC~DE 124 HRS PROG I T~~776.0 ) WELL NAME 3S-07 f;ROM TO HOURS OODE TROUBLE SUB 09:30 16:00 6.50 CASE P RUNC 16:00 18:30 2.50 CASE P RUNC 18:30 19:00 0.50 CASE P RUNC 19:00 22:00 3.00 CASE P CIRC 22:00 00:00 2.00 CEMENT P PUMP ) Page 2 of 2 ITVD I DFS I REPT NO. I DATE . 2,586.0 5.00 13 11/13/2002 OPERATIDNS..SlJMMARY t ... ÞHASE DESCRIPttON SURFAC Float Equip, Thread Locked Btm 3 Conn, Ran 43 Jts 9 5/8" Csg, Tam Port Collar, 25 Jts of 9 5/8" Csg, (Total of 70 Jts Ran 2,769.35' ) While TIH Started taking Wt at 2,626' SURFAC Est Circ at 6.5 bpm at 350 Psi, Washed Csg Down from 2,626' to 2,769', Up Wt W IPumps on 134K, Dn Wt 94K SURFAC RD Fill Up Tool & MU Cmt Head on Landing Jt & Landed Csg in Hanger SURFAC Circ & Cond Mud for Cmtg Csg, Lowered Vis to 75 & Yield Pt to 28, final rate 8 bpm @ 430 psi, last 100 bbls of mud pumped with nutplug for marker. Reciprocated Csg with full returns throughout. PJSM. SURFAC RU Dowell, Tested Lines to 3,000 Psi, Pumped 50 bbls CW 100 Chem Wash, Dropped Btm Plug, Pumped 50 bbs of 10.5# MudPush Spacer, Mixed & Pumped 430 bbls of lead Cmt 2,415 Cu ft of Arctic Set Cmt at 10.7 ppg & 4.28 Yield, Ave Rate of 6 Bpm @ 625 Psi, Observed Nut Plug marker at Shakers, Began Pumping Tail Cmt At 00:00 Hrs, Reciprocated Csg During Cmt Job 24 HR SUMMARY: Fin POOH & LD LWDIMWD with MM & 12 1/4" Bit, RU Csg Tools, Ran 70 Jts of 9 5/8" 40# L-80 BTC Csg, Set Csg at 2,769', Circ & Cond Mud for Cmtg, Began Cmtg Csg Fuel Water, Drilling PERSONNEL .DATA NO. HOURS COMPANY 3 Doyon Universal 33 APC 4 Baroid MATERIALS/CONSUMPTION ON HAND ITEM -14,184 Water, Potable -1 ,420 Printed: 11/23/2002 11 :28:57 AM ConocoPhillips, Alaska Daily Drilling Report WELL NAME 3S-07 I JOB NUMBER \ EVEN aT OCR ODE \24 HRS PROG TMD \ TVD I DFS 2,776.0 2,586.0 6.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG David Burley/Pete Wilson N1268@ppco.co Nabors 7ES Kuparuk River 6,611.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD PU Additional 5" DP & TIH 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL STANO BACK DP,MU 81/2" BHA & PU OP & TIH, Circ & Test C 11/11/2002 104,147 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE WCD.K3S.0045.01 INC AZIM I LAST CASING I NEXT CASING 28.090 53.120 16.000 (in) @ 108.0 (ft) 9.625 (in)@ 2,770.0 (ft) ) LAST SURVEY: DATE TMD 11/14/2002 4,444.88 ') Page 1 of 2 JREPT NO. I DATE 14 11/14/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,637,825 AUTH. 2,484,894 LAST BOP PRES TEST 11/15/2002 SURVEY DATA M.D. INCL. AZIMUTH T.V.D. NJS CUM E/W CUM SECTION M.D. INCL. AZIMUTH T.V.D. N/S CUM E/W CUM SECTION 2,826.59 27.730 54.470 2,631.19 493.36 736.73 886.33 3,686.65 28.660 56.520 3,393.26 717.671,065.85 1,284.54 2,920.33 27.780 53.320 2,714.14 519.09 772.00 929.98 3,781.56 28.500 56.440 3,476.60 742.741,103.70 1,329.92 3,015.82 27.020 53.090 2,798.92 545.41 807.19 973.91 3,871.29 28.200 56.440 3,555.57 766.30 1,139.21 1 ,372.51 3,112.75 26.070 53.400 2,885.63 571.33 841.90 1,017.22 3,968.83 27.580 56.360 3,641.78 791.551,177.21 1,418.11 3,208.01 27.560 56.790 2,970.65 595.88 877.14 1,060.17 4,067.28 27.000 56.170 3,729.27 816.61 1,214.75 1,463.23 3,303.99 27.130 57.690 3,055.91 619.74 914.22 1,104.21 4,159.66 26.460 56.950 3,811.78 839.51 1,249.42 1,504.76 3,400.18 26.670 57.600 3,141.69 643.03 950.98 1,147.67 4,255.70 28.890 53.190 3,896.83 865.09 1,285.94 1,549.34 3,496.75 28.930 57.270 3,227.11 667.28 988.93 1,192.65 4,350.39 28.880 52.940 3,979.74 892.57 1,322.50 1,595.06 3,591.75 29.130 56.640 3,310.17 692.41 1,027.58 1,238.71 4,444.88 28.090 53.120 4,062.79 919.68 1,358.50 1,640.11 COilE TROOBLE SUB CEMENT P PUMP CEMENT P OISP 01 :00 04:30 3.50 CEMENT P PULD 04:30 05:00 0.50 CEMENT P OTHR 05:00 09:30 4.50 WELCTL P NUND 09:30 12:00 2.50 WELCTL P NUND 12:00 17:00 5.00 WELCTL P NUND 17:00 18:00 1.00 WELCTL P BOPE 18:00 19:30 1.50 WELCTL T EQIP BOPE 19:30 00:00 4.50 WELCTL P BOPE OPERATIONS SUMMARY PHASE 'DESCRIPTION SURFAC Pumped 220 sxs of 12.0 ppg, 2.4 cf/sx Lite Crete tail cmt at 6 bpm 1350 psi. SURFAC Dropped top plug - cementers displaced with 20 bbls FR - switch to rig pumps and continued displacement with 184 bbls of 9.8 ppg mud - average disp rate 8.0 bpm - did not bump plugs. Reciprocated pipe untilllast 80 bbls of displacement - had 45 bbls of 10.7 ppg cement returns to surface. Full returns throughout - CIP @ 0046 hrs - floats held. SURFAC RD Cmt Head & Nabors Csg Tools, LD Landing Jt and Changed Out Long Elevator Bails to Short Drlg Bails SURFAC Flushed out Divertor with Jetting Tool SURFAC ND 16" Divertor Lines & 21 1/4" divertor, Removed Starting Head SURFAC Installed FMC Gen 5 11" 5m Wellhead & Tbg Spool, Tested Seals to 1,000 Psi, Set Bop Stack on Wellhead SURFAC NU BOP's, Change Out Flanges under Drip PAn, Install Riser & Turnbuckles, Changed out Blind Rams to Blind Shear Rams SURFAC RU Test Equipment & Filled Stack With Water SURFAC On First Attempt to Test BOP's had Gland Pkg Nut Leak, Sensor Hose Leaked, Replaced Hose and fitting on Manifold Started Leaking, Tightened Same SURFAC Tested BOPE, Tested 5" Pipe Rams, Manifold & Valves to 250 Psi Low & 5,000 Psi High, Tested Annular to 250 Psi Then 3,500 Psi, Note: John Crisp with AOGCC Witnessed Test 24 HR SUMMARY: Fin Cmtg 95/8" Surface Csg, Had 45 bbls of 10.7 ppg cmt at Surface, Plug Didn't Bump, Ck Floats & Held, CIP at 00:46 hrs. RD Csg Tools, NO Oivertor & Lines, Installed Gen5 Wellhead with Tbg Spool & DSA, NU Bops & Tested Same COMPANY ConocoPhillips SERVICE PERSONNELDATA NO. HOURS COMPANY 3 Nabors SERVICE NO. 33 HOURS Printed: 11/23/2002 11 :28:37 AM WELL. NAME COMPANY Halliburton I Sperry-Sun Doyon Universal ITEM Fuel Water, Drilling 3S-07 UNITS gals bbls SERVICE ) ConocoPhillips, Alaska Daily Drilling Report IJOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~776.0 PERSONNEL DATA N~ HOURS COMPANY 4 APC 6 Baroid USAGE MATERIALS I CONSUMPTION ON HAND ITEM -14,184 Water, Potable -1 ,420 ) Page 2 of 2 I TVD I DFS I REPT NO. I DATE 2,586.0 6.00 14 11/14/2002 SERVICE NO. 2 2 HOURS UNITS bbls USAGE ON HAND -638 Printed: 11/23/2002 11 :28:37 AM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 11/16/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump I. Strokes ... 0.0710 Bbls/Strk ... ~ Pumping down annulus and DP. ~ Well Name: Drilling Supervisor: 3S-07 I Rig: David Burley Type of Test: Casing Shoe Test LOT IFIT Hole Size: 18-1/2" RKB-CHF: 26.3 Ft Casina Size and Description: Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: Blocksffop Drive Weight: Estimates for Test: I. Casing Shoe Depth 2,769 Ft-MD 2,580 Ft-TVD 19-5/8" 40#/Ft L-80 BTC Hole Depth 2,796 Ft-MD 2,605 Ft-TVD I. Pressure IntearitvTest Mud Weight: 9.5 ppg Mud 10 min Gel: 4.0 Lb/100 Ft2 Rotating Weight: 100,000 Lbs Blocksffop Drive Weight: 26,000 Lbs Desired PIT EMW: 18.0 ppg Estimates for Test: 1140 psi 9.8 ppg 40.0 Lb/100 Ft2 2,500 psi 94,000 Lbs 26,000 Lbs 1.7 bbls 0.8 bbls I. I. PIT 15 Second Shut-in Pressure, psi 1140 EMW = Leak-off Pressure + Mud Weight = 1150 9 5 0.052 x TVD 0.052 x 2580 + . EMW at 2769 Ft-M D (2580 Ft- TVD) = 18.1 PPQ 3000 . - Lost 90 psi during test, held = 96.4% of test pressure. .~~~~~:*:11;t.*~1.m..._..1..mu.J~.....w.,L-.......:¡¡. 2500 - 2000 - UJ a: :) ~ 1500- W a: 0. . "":'~':':'::;::::::::::.:.:.~... 1 000 - 500 - Barrels 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point "':'-CASING TEST ~LEAK-OFF TEST Comments: Changed hole over to 9.5 ppg new LSND mud prior to HI. Casing .. est Pumping Shut-in Strks psi Min psi 0 0 0 2500 2 80 1 2490 4 170 2 2490 6 290 3 2490 8 400 4 2490 10 500 5 2490 12 650 6 2480 14 810 7 2480 16 930 8 2470 18 1090 9 2470 20 1240 10 2470 22 1425 15 2450 24 1600 20 2440 26 1760 25 2420 28 1950 30 2410 30 2125 32 2310 34 2500 30 Volume Volume Pumped Bled Back 2.4 tsbls ] tsbls Pump Rate: 8.0 Strk/min ... Pressure Integrity. est Pumping Shut-in Strks psi Min psi 0 0 0 1150 1 60 0.25 1140 2 125 0.5 1130 3 195 1 111 () 4 265 1.5 11 I "---' 5 330 2 1100 6 400 2.5 1090 7 480 3 1080 8 555 3.5 1070 9 630 4 1060 10 700 4.5 1050 11 775 5 1040 12 840 5.5 1040 13 900 6 1030 14 965 6.5 1020 15 1030 7 1020 16 1095 7.5 1010 17 1150 8 1000 ,¡ 8.5 990 9 990 9.5 9' 10 9~ Vo ume Pumped 1.2 tsbls Volume Bled Back tSbls ConocoPhillips Alaska Jt Number Num of Jts Jts 3 to 155 Jts 1 to 2 Remarks: 153 Jts 2 Jts Up Wt = 190k ) ') Casing Detail 7" Intermediate Casina COMPLETE DESCRIPTION OF EQUIPMENT RUN NABORS 7ES RKB to LDS FMC 11" X 7" Hanger 7" 26# L-80 BTCM Csg 7" Davis Lynch Floa,t Collar r 26# L-80 BTCM Csg r Davis Lynch Float Shoe TD of 8-1/2" hole @ 6633' MD' 6091' TVD 7" Shoe @ 66231 MD 6081' TVD Total Centralizers 1- r Bowspring centralizer over stop rings center of joints # 1 & #2 Bowspring centralizer over collar on joints #3 thru #25 7" x 8-3/8" Centering guide on every jt. From #92 thru #96 (Total of 5) 7" x 8-3/8" Centering guide on every third jt. From #143 to #155 (Total of 5) Total of 173 jts.on location Total of 155 jts. Ran in hole Total of 18 jts. Out (13 jts. Inside shed & 5 jts. Outside shed) Use Best-a-Life 2000 pipe dope On Wt = 11 Ok Block Wt= 26k Well: 38-07 Date: 11/21/2002 LENGTH 26.20 2.51 6507.96 1.31 83.72 1.48 DEPTH TOPS 26.20 28.71 6536.67 6537.98 6621.70 6623.18 Supervisor: Mike Thornton / Peter Wilson ') ) ConocoPhillips Alaska Cementing Report Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 6,623 (ft) 11/20/2002 Production Casing 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Page 1 of 3 Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Cmtd. Csg: Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Stuck prior cmt (ft) (ft) Rot Time Start: : Rec Time Start: : Time End: : Time End: : RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 4.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 470 (psi) Max Torque: (ft-Ibf) Drag Down: (Ibs) ~~ageN():l of1 Start Mix Cmt: 17:00 Start Slurry Displ: 18:00 Start Displ: 18:53 End Pumping: 19:50 End Pump Date: 11/20/2002 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 5.00 (bbl/min) Y 1 ,400 (psi) 2,200 (psi) 5 (min) Y Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Batch mix Density Meas By: Densometer Type: Non-Disp. LS Density: 12.3 (ppg) Visc: 45 (s/qt) PVIYP: 20 (cp)/19 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 8 (lb/100ft2) Bottom Hole Circulating Temperature:75 (OF) Bottom Hole Static Temperature: (OF) Displacement Fluid Type:Seawater Density: 8.5 (ppg) Volume: 255.70 (bbl) Slurry Data Fluid Type: FLUSH Description: CW100 Slurry Interval: 2,931.00 (ftJfo: 3,373.00 (ft) Cmt Vol: 10.0 (bbl) Water Source: Slurry Vol: (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 8.30 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/23/2002 11 :26:36 AM ) ) ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: FLUSH Description: MUDPUSH XL Class: Slurry Interval: 3,373.00 (ft}ro: 5,585.00 (ft) Cmt Vol: 50.0 (bbl) Density: 13.30 (ppg) Yield: (ft3/sk) Water Source: Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 5,585.00 (ft}ro: 6,623.00 (ft) Cmt Vol: 45.0 (bbl) Water Source: Slurry Vol:218 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: 3.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Type Concentration 0.30 %BWOC Stage NC):1.. SlutryNo: 3 of3 ;'Ad(jitivøs D65 D600G D47 2.00G P S 0.20G P S Printed: 11/23/2002 11 :26:36 AM ') ) ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: 3S-07 Common Well Name: 3S-07 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/1/2002 2 Report Date: 11/20/2002 10/29/2002 End: 11/22/2002 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: ~dgzStJryey E:"ØI~Øti()... Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: (ft) Rig Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wI Class G + .300% D65, 2.000 gal/sk D600G, .200 gal/sk D47, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls cmt at rate of 5.5 bpm at 500 psi, Shut down, Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1035 psi until cmt around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wI total of 257.5 bbls, Bumped plug wI 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20102, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. Printed: 11/23/2002 11 :26:36 AM ) ) Page 1 of 2 WELL NAME ConocoPhillips, Alaska Daily Drilling Report ¡JOB NUMBER EVENOTDCRODE 124 HRS PROG TMD TVD DFS 3S-07 6,633.0 6,091.0 12.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Mike Thornton/Peter Wils N1268@ppco.co Nabors 7ES Kuparuk River 6,611.0 0.00 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD TIH with 3 1/2" Completion Assembly 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Set Pkr & Complete Well Per Plan, Freeze Protect Well 11/17/2002 202,518 LITHOLOGY JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 18.00 WCD.K3S.0045.01 2,484,894 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 11/18/2002 6,633.00 8.780 51.110 9.625 (in) @ 2,769.0 (ft) 7.000 (in) @ 6,611.0 (ft) 11/15/2002 QEN$I1'Y(ppg) I 12.25 ¡Þ~.I I E:ÞØI13.101 MUD DATAl DAILY COST I 0.00 I CUM COST I 0.00 FV PVIYP GELS. WLJHTHP FClT;SOL OIUWAT %SandlMBT Ph/pM Pf/Mf CI Ca H2S LIME ES 48 18/23 8110 2.5/10.4 21 I 118.8 7.71 I REPT NO. I DATE 20 11120/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 2,466,354 OÞERATIONSSUMMARV TRO.UBLE SUB PHASE DESCRtPTloN RURD INTRM1 Fin RU Nabors Csg Equipment & GBR Fill-Up Tool RUNC INTRM1 Held Safety Mtg on Running of 7" Csg MU 7" Float Shoe, 2 Jts of 7" 26# L-80 BTC Mod Csg, Float Collar, Tested Float Equip, Thread Locked Btm 3 Conn, Ran 153 Jts 7" Csg, (Total of 155 Jts Ran 6,623.18') Note: Nabors Floorhand Robert Miller Twisted Ankle While Running 7" Csg, Stepped on Railing Stop for Iron Roughneck While Tailing in Csg 12:00 18:00 6.00 CASE P CIRC INTRM1 Est Circ & Reciprocating Pipe Up Wt190K, Dn Wt 11 OK -While Reciprocating Pipe after approx 25 Min Dn Wt down to 80K,Attempted to PU on Csg, PU W/70K Over, Pipe Stuck, Landed Csg in Hanger, RD Fill Up Tool & MU Cmt Head on Landing Jt & Cont to Circ Csg for Cmt Job, Lowered YP from 30 to 23 with 45 vis, Circ at 209 Gpm's at 470 Psi, Landed Csg With FS @ 6,623', FC @ 6,536' 18:00 19:00 1.00 CEMENT P PUMP INTRM1 RU Dowell, Batch mix 10 bbls CW100 @ 8.3 ppg, 50 bbls MudPUSH @ 13.3 ppg, 218 sxs (45 bbls) @ 15.8 ppg GasBLOK wI Class G + .300% D65, 2.000 gallsk D600G, .200 gal/sk 047, Pump 5 bbls CW100, Test lines to 4000 psi, Pump 5 bbls CW100, Drop #1 btm plug, Reload head, Pump 50 bbls MudPUSH at rate of 5 bpm at 500 psi, Drop #2 btm plug, Pump 45 bbls of at 15.8 at rate of 5.5 bpm at 500 psi, Shut down, 19:00 20:00 1.00 CEMENT P DISP INTRM1 Flush lines to rig floor with seawater, Drop top plug, Displace first 208 bbls seawater at rate of 5 bpm at 1 035 psi until cmt around shoe, Slowed rate to 3.5 bpm @ 1400 psi & bumped plug wI total of 257.5 bbls, Bumped plug wI 2200 psi, Bled back 1.8 bbls for a total of 255.7 total bbls displaced, CIP @ 1950 hrs 11/20102, Ck floats & Held, Had good circ. thru out job, (Note; Calculated displacement to float collar =250.3 bbls, Displacement to Shoe= 253.2 bbls, Displacement around shoe to base of Kuparuk C =257.9 bbls), Displaced entire job with Dowell. 20:00 21 :00 1.00 CEMENT P CIRC INTRM1 Flushed Out Mud Pump, Stack & Flowline 21 :00 22:30 1.50 CEMENT P RURD INTRM1 LD Landing Jt, RD Csg Tools & Changed Out Elevator Bails 22:30 23:00 0.50 CMPL TN P OTHR INTRM1 RU & RIH and Set 7" Pack-off, Tested Same to 5,000 Psi for 10 Min, LD Setting Tool 23:00 00:00 1.00 CMPL TN P RURD CMPL TN RU Nabors 3 1/2" Tbg Handling Tools 24 HR SUMMARY: RU & Ran 155 Jts of 7" 26# L-80 BTC Mod Csg, Landed Csg at 6,623', Circ & Cond Mud, Cemented 7" Csg, Bumped Plug, Floats Held, CIP at 19:50 Hrs, RD Cmt Head, RU to Run 31/2" Completion Printed: 11/23/2002 11 :29:52 AM WELL NAME 3S-07 COMPANY ConocoPhillips Nabors Halliburton / Sperry-Sun Doyon Universal APC Fuel Water, Drilling SERVICE ) ConocoPhillips, Alaska Daily Drilling Report IJOB NUMBER IEVE~DC~DE 124 HRS PROG IT~~633.0 PERSONNEL DATA NO. HOURS COMPANY 3 Baroid 39 Canrig 4 Baker 6 FMC 2 USAGE 2,730 372 MATERIAl...s.,..caNSUMPTlaN ON HAND ITEM -14,262 Water, Potable -1,946 ) Page 2 of 2 I TVD I DFS I REPT NO. I DATE 6,091.0 12.00 20 11/20/2002 SERVICE NO. 2 1 1 1 HOURS Printed: 11/23/2002 11 :29:52 AM Well Name: Drilling Supervisor: 3S-07 I Rig: Mike Thornton PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Nabors 7ES I Date: 11/21/2002 I Volume Input Volume/Stroke Pump used: I #1 Mud Pump I.. Strokes "Y 0.0710 Bbls/Strk "Y Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" I. Casing Shoe Depth RKB-CHF: 26.3 Ft 2,769 Ft-MD 2,580 Ft-TVD Casina Size and Description: 19-5/8" 40#/R L-80 BTC ChanQes for Annular Adeauacv Test Enter outer casing shoe test results in comments Casing Description references outer casing string. Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. ... Pumping down annulus. ... Casing .. est Hole Depth Pumping Shut-in 5,585 Ft-MD 5,083 Ft-TVD Strks psi Min psi I... Pressure -lntearitvTest Mud Weight: 12.3 ppg Inner casing OD: 7.0 In. 0 26,000 18.1 ppg 778 psi Desired PIT EMW: Estimates for Test: I. EMW = Leak-off Pressure + Mud Weight = 620 123 0.052 x TVD 0.052 x 2580 + . EMW at 2769 Ft-M D (2580 Ft- TVD) = 16.9 1 000 . W 0: :) ~ 500- W 0: C. ^- / 0/1- 3 4 Barrels 5 ~CASING TEST ---LEAK-OFF TEST Comments: r l :~ \"1~,qt, ..~:\:::::::; 7 8 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point 0.4 bbls I. PIT 15 Second Shut-in Pressure, psi 400 95/8" Csg Shoe tested to 18.1 ppg ~MW with 9.5 ppg Mud in Hole, (1,150 psi) Bled back 1/2 bbl after holding pressure 10 minutes. 30 Pump Rate: 7.0 Strk/min ... Pressure Integrity Test Pumping Shut-in Strks psi Min psi 0 0 0 450 7 70 0.25 400 14 80 0.5 380 21 100 1 3r 28 180 1.5 3~ 35 300 2 300 42 480 2.5 300 49 620 3 300 56 500 3.5 300 63 490 4 300 70 490 4.5 295 77 480 5 290 84 480 5.5 290 91 450 6 290 98 450 6.5 285 7 280 7.5 270 8 260 8.5 255 9 250 9.5 2 , 10 25'0"'" 0 1 2 3 4 5 6 7 8 9 10 15 20 25 30 ~ - . ..... :s- 'J'olume Volume Pumped Bled Back 0.0 ~bls [I'El:Sbls Volume. Pumped 1.0 ~bls Volume Bled Back ~bls Name iN/-S l'13n: JS~)7 85.188 -1J0.17J -1333 -\250 "'-.1000 -750 ----jOO -250 -0 -250 -500 -750 -1000 -1250 -1333 ilV-W 5991928.18 WELL OETAII$ COMPANY DETAILS WELLP A TIJ DETAILS ANTI-COLLISION SETTINGS Nllrthing Eusliny Latitude LungitudIJ Slut Phi1lips Alaska Inc. Engineering Kuparuk 3S-07 (Rig Surveys) Plan: 3S-07 0.000 Interpolation Method:TVD Interval: 5.000 Depth Range From: 2585.000 To: 2586.000 ).{onituuRI fiol\~1 IOOOo...cOO fiefm:I\HI ~fil\il¡'f'I! IW...-¡:y 476324.84 70"23'40353N 150"11'33.466W NiA Parent Wellpath: Tie on MD: Calculation Methud: Minimum Curvature ElTOr System: ISCWSA Scan Method: Horizontal Plane Error Surface: Elliptical + Casing Warning Method: Rules Based Rig: Ref. Datum: 56.1 56.IOOft V.Section Origin Origin Starting Angle +N/-S +EI-W From TVD 55.05" 0.000 0.000 0.000 0 IJJJ 270 90 / (P ~l "^ From 0 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 10000 12000 14000 16000 Colour ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 10000 12000 14000 16000 18000 -~ .~ 1/4 Jt;lile Radil~S oj' f 3S-0 7 ... 9-5/8" C.\'g .Pt (@; 2776' j~ID /2586' TJ/D) 180 Bjj Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] Name 'N/-S "..,,: 3S-07 85.188 .130.173 -1333 -1250 -.- 1000 -750 ----'500 -250 -0 -250 -500 -750 -1000 -1250 -1333 'EI.W 5993928. 18 WELL DETAII$ NI)rthinB ANTI-COLLISION SETTINGS COMPANY DETAILS Easling Latih.klc Longilude Slot Phillips Alaska Inc. Engineering Kuparuk 476324.84 70"23'40.J53N 150"11'J3.4('¡;W N/A Intetpolation Method:TVD Interval: 5.000 Depth Range From: 2585.000 To: 2586.000 UWilllUIII I\al\~t 10000,000 I\du.nul DofillitÍf1... 1Wf\-.y Ca1culation Method: Mininnun Curvature Error System: ISCWSA Scan Method: Horizonlal Plane Em" Surface: Elliptical + Casing Warning Method: Rllies Based 0 lJ33 Plan: 180 b-,j Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] WELLPATH DETAILS 3S-07 (Rig Surveys) Parent WellpaOJ: Tie on MD: Plan: 3S-07 0.000 Rig: 56.\ 56.\0011 Ref. Datum: V.Section Origin Origin Starting Angle +N/-S +EI-W From TVD 55.05" 0.000 0.000 0.000 90 From 0 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 10000 12000 14000 16000 Colour ToMD 200 400 600 800 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 10000 12000 14000 16000 18000 ~ .~ 1/4 l~lile RadillS of' 3~5-07 uo 9-5/8" Csg '/)t (Cf!:; 2776' ltJD /2586' TJ/D) ) PHilliPS Alaska, Inc. / A Subsidiary of PHILLIPS PETROLEUM COMPANY T(~:~ ) r¡r W ~ PALM 1A API: 501032036101 OD:3.5oo, ~. II .11...... i SSSV Type: NIPPLE ID:2.992) II . t r r) I ¡ , t ~- ~ I ,¡ II tI .. ' 18 ",,1iIIIIII IZí ~ODUCTION (G-9389, 00:7.000, \Þ(¡'~m' ) KRU 35-26 Well Type: TH Orig Completion: Last W/O: Ref Log Date: TD: 9400 ftKB Max Hole Angle: 68 deg @ 8935 Angle @ TS: 68 deg @ 9044 Angle @ TD: 68 deg @ 9400 Annular Fluid: Reference Log: Last Tag: Last Tag Date: Casing String. ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String. TUBING Size I Top 3.500 0 Peñorations Summary Interval I TVD I Zone 9047 - 9137 5811 - 5845 C-4 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 2514 2513 CAMCO KBMM~2 2 3995 3784 CAMCO KBMM-2 3 6194 4675 CAMCO KBMM-2 4 7764 5307 CAMCO KBMM-2 5 8777 5710 CAMCO KBMM-2 Production MandrelsNalves St MD TVD Man Man Mfr Type 6 8934 5769 CAMCO KBUG 7 8961 5779 CAMCO KBUG Other ~Jlugs, equip., etc.: . JEWELRY Depth TVD Type 506 506 NIP 8819 5726 SLEEVE-C 8859 5741 SEAL 8860 5741 PBR 8881 5749 PKR 8987 5789 NIP 8987 5789 PLUG 8999 5793 XO 9000 5794 TBG 9002 5794 GUN Rev Reason: New Well by ImO Last Update: 4/11/2002 Bottom 9005 Top Bottom TVD Wt Grade Thread 0 115 115 /65.50 WELD 0 2616 2615 ý36.00 J-55 BTCM 0 9389 5941 26.00 J-55 BTCM TVD Wt I Grade I Thread 5796 9.30 L-80 8rdMOD I Status I Ft SPF Date I Type I Comment 90 5 3/13/2001 PERF 45/8" Scallop guns V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BEK 0.000 0 3/21/2001 DMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK5 0.000 0 3/13/2001 DMY 1.0 BK5 0.000 0 3/13/2001 Description CAMCO 'DS' NIPPLE 2.875 NO GO BAKER COMMINGLING SLEEVE W/2.813 'DS' PROFILE, closed 4/20/01 BAKER SEAL ASSEMBLY BAKER POLISHED BORE RECEPTACLE W/12' SEAL TRAVEL BAKER SAB-~ PACKER PINNER FOR 1500 PSI SHEAR HOWCO 'XN' NIPPLE W/2.75" NO GO, 2.813" BORE SET XXN PLUG 4/20/2001 XO 3.5" TO 2 7/8" ID 2.875 2.812 2.992 3.000 3.250 2.750 0.000 2.440 2.441 0.000 HOWCO 4 5/8" Scallop Guns, 5 spf w/27' of stim sleeves; tubing auto release & spaces 3'x15' General Notes Date I Note 4/11/2002 This well is a Kuparuk well, pad 3S; pdf included with CPF3 schematics ') Casing Detail 9-5/8" surface casing ) PHilLIPS Alaska, Inc. COMPLETE DESCRIPTION OF EQUIPMENT RUN Nabors 19E RKB to GLE = 34.85 9 5/811 Landing Joint ( Above RKB) 95/811 Landing Joint (34.85' Below RKB) 95/811 FMC GEN V FLUTED MANDREL HANGER W / 40# Pup jt. jts.40-63 9 5/811, 36#, J-55 BTC (24 jts) 9 5/811, 40# TAM Port Collar jts 3-39 9 5/811, 36#, J-55 BTC (38 jts) Gemeco Float Collar jts 1-2 9 5/811, 36#, J-55 BTC (2 jts) Gemeco Float Shoe # ITEMS BTM OF SHOE @ TD of 12.2511 hole = 2633' MD/2622' TVD, rat hole = 16.95' 38 Gemeco Bow Spring Centralizers Run on stop collars in center of jts. 1, 2, 39,40 Run over collars on Jts.3-12, 14, 16, 18, 20, 22, 24, 26, 28, 30, 32 34,36,38,42,44,46,48,50,52,54,56,58,60,62 WELL: Palm # 1 DATE: 2/3/01 1 OF 1 PAGES LENGTH DEPTH TOPS 6.02 -6.02 34.85 2.80 34.85 981 .62 37.65 2.95 1019.27 1506.65 1022.22 1.45 2528.87 84.01 2530.32 1.72 2614.33 2616.05 Remarks: String Weights with Blocks: 700k Up, 85k On, ??k Blocks. Ran 63 joints of casing. Drifted casing with 8.765" plastic rabbit. Used National Lead Free Modified thread compound on all connections. Nabors 79E Drilling Supervisor: R. Morrison/ O. Simonton ) Phillips Alaska Drilling I Well Name: Palm #1 Rig Name: Nabors 19E Casing Size .1') 9.325 ¿,2 Centralizers Comments: See Casing Detail for Placement Mud Comments: Wash 0 Comments: Spacer 0 Comments: Lead Cement 0 Comments: Tall Cement 0 Comments: Displacement 0 Comments: Calculated top of cement: Surface I Cement Company: Dowell ) Shoe Depth: 2616.05 Cementing Details Report Number: 1 I Field: Exploration I Hole Diameter: 12.25 Angle thru KRU: nla Report Date: 02/0512001 AFC No.: AX2141 % washout: ? Weight: 10.2 PV(prior cond): 41 Gels before: 23124 Gels after: 4/8 Type: ARCO Wash Type: MUDPUSHXL Type: AS III Ute Mix wtr temp: 80 LC Depth: 2528.87 State type used, intervals covered and spacing PV(after cond): 24 YP(prior cond): 42 YP(after cond): 11 Total Volume Circulated: 1200 bbls Volume: Weight: 8.3 20 Volume: 40 Weight: 10.2 No. of Sacks: 580 Weight: 10.7 Yield: 4.44 Type: G Mix wtr temp: 80 Additives: G+50% D124, 0.9% D44, 0.4% D46, 30"10 D53, 1.5"10 S1, 1.5% D79 Yield: 1.17 Additives: G+1% s1, 0.2% D46, 0.3% D65 Rate(before tail at shoe): 6 Reciprocation length: 10 Theoretical Displacement: 195.5 BBLS I Rig Contractor: NABORS. No. of Sacks: 340 Weight: 15.8 CP: Date: 02/05101 Time:10:36 am Remarks:Had full returns throughout job. Reciprocated casing until top plug was dropped. Had 80 barrels good cement returns to surface @10.7 ppg. Mixed and pumped lead and tail at 6.2 to 6.4 BPM. Displaced using 25 barrels wash up water from Dowell and 170.5 barrels mud with the rig pumps at 6 BPM. Rate(tail around shoe): 6 Str.WI.Up: 100 Reciprocation speed: 10 FPM Str. WI. Down: 85 Actual Displacement: 195.5 BBLS Bumped plug: Yes Str. WI. in mud: 85 Floats held: Yes I Approved By: Robert L. Morrison Jr. Phillips Alaska Drilling AFC No. I Date Rpt No AX2141 02105/2001 11 Well: PALM #1 Depth (MD/TVD) I Rig Accept. hrs 01/31/2001 2633/2622 Prey Depth MD: 2633 Days Since AccepVEst: 4 /5 Contractor: NABORS Rig Name: Nabors 19E Operation At 0600: Make up BHA #2 Upcoming Operations: Trip in to cement, test casing, drill out, change over to fresh mud, lOT. MUD DATA MUD TYPE lSND WEIGHT 10.1ppg VISCOSITY 50sqc PV/yP 24 / 11 GELS 4/8/ APIWL 6 HTHP WL mli30 min SOLIDS 12% HOLE VOLUME 181bbl MBT 20 ph 8.8 lGS 10.7% PIT VOL 550 DAILY MUD $921 TOTAL MUD . $38059 COMPANY BAROID BHA DESCRIPTION BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: TIME I END 12:00 AM 12:30 AM 12:30 AM 01:00 AM 01:00 AM 02:30 AM 02:30 AM 07:00 AM 07:00 AM 07:30 AM 07:30 AM 08:00 AM DRilLING DATA DEPTH ROTWT PUWT SOWT AVG DRAG MAX DRAG TRO BTM TRO OFF PUMP PRES 1500 I I I PUMP NO 1121 I LINER SZ 6161 I SPM 1 571581 I GPM2 239124311 SPS 1 II I SPP 1 III MUDWT 10.1 I I 1 Daily Cost $ 594715 Last Csg: 9.625 @2616' Cum Cost $ 1245241 Next Csg: 7 @7440' BIT NO. 2 BIT DATA BIT NO. EH&S ACCIDENT (non-spill) N Daily Drilling Report Rig Relase - hrs: Progress: 0 Est Cost To Date $ Shoe Test: NI A DRillS/BOP DATA LAST BOP/DIVERT LAST BOP/DRILL TST 02/06/2001 02/06/2001 LAST H2S DRILL LAST CONFINED SPACE LAST FIRE DRILL 01/08/2001 LAST SPILL DRILL 01/19/2001 SIZE 8.5 MAKE HYC SIZE EMPLOYER MAKE SPILL N FUEL & WATER FUEL USED 2705 TYPE DS70FNPV SERIAL NO 24312 DEPTH OUT TYPE TYPE SERIAL NO VOLUME (gallons) DRILL WATER USED - BBLS POTABLE WATER USED - BBLS 620 100 DEPTH OUT LAST SAFETY MTG 0210512001 DEPTH IN 2633 FOOTAGE 0 ADT/AST / WOB2 DEPTH IN FOOTAGE INJECTION INJECTION WELL WEATHER & PERSONNEL DATA TEMP of -5 ADT/AST / WOB2 SOURCE WELL RATE (bpm) RPM 1 RPM 1 PRESSURE (psi) WIND SPEED 23 TFA TFA INJECTION FLUIDS 0 JETS JETS 1211211211211212 11111 I BIT COST BIT COST 35825 DULL DULL III I II GRADE GRADE I II III 0 0 0 0 TOTAL VOL (bbl) 0 TOT FOR WELL (bbl) WIND DIRECTION 1000 2 1110.86 OD 4 WEIGHT 15.7 CHILL FACTOR of -49.20 ID 3.24 Daily Drilling Report: PALM #1 02/05/2001 PHILLIPS PERSONNEL 3 CONTRACTOR PERSONNEL 35 MISC PERSONNEL 6 SERVICE PERSONNEL 16 TOTAL 60 18.5" bit, 8" Sperry motor @1.22 degrees, mwdllwd wlfloat sub, 3- nm flex drill collars, XO, 4- 4" hwdp, jar, 25 - 4" hwdp, xo..... Bit to RES = 35.14', bit to PWD 43.69', bit to GR = 44.95', bit to Survey = 60.19', bit to DEN. = 86.35', bit to NUT. = 91.61 DRILLPIPE DATA GRADE CONNECTION 5-135 4" HT 40 CLASS 2 PREM LENGTH 0-14710019 HOURS OPS CODE HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 0.50 OTHER SURF Casing and Finish repairs to flow riser. Cementing 0.50 CASG SURF Casing and Circulate through tight spot at 2040'. Cementing 1.50 CASG SURF Casing and Finish run 9.625" casing to bottom at 2616'. Land casing on Cementing hanger and make up Dowell cement head. 4.50 CIRC SURF Casing and Circulate and cndition mud prior to cement job. Cementing 0.50 OTHER SURF Casing and Held PJSM with all contact personnel. Cementing 0.50 PRB_EFC SURF Casing and The 2" cement line on the rig floor got a pin hole in it when Cementing we psi tested the line prior to cementing. Replaced line with hi-psi hose. Page 1 ) ) 08:00 AM 11:00 AM 3.00 CEMENT SURF Casing and Test cement line to 3500 psi. Cement casing per Cementing procedure-see cementing detail for additional info. CI~ 1036 hrs. 0210512001. Bumped plugs and floats held. 11:00 AM 01:00 PM 2.00 CEMENT SURF Casing and PJSM. Clean out dlverter . nipple down and set out Cementing same. Set in and nipple up 135/8. 5m BOPE. 01 :00 PM 10:00 PM 9.00 BOPE PROD Other Set in and nipple up 13 5/8. 5m BOPE. 10:00 PM 11:00 PM 1.00 OTHER PROD Other Rig down casing elevators. balls. Rig up floor to drill ahead. 11:00 PM 12:00AM 1.00 BOPE PROD Other Rig up to test BOPE. 24.00 Supervisor: R. MORRISON! D. SIMONTON Daily Drilling Report: PALM #1 02/05/2001 Page 2 CASING TEST and FORMATION INTEGRITY TEST Well Name: Palm #1 Date: 2/6/01 Supervisor: R. Morrison Jr. [iJ Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625'" 36#, J-55, BTC Casing Setting Depth: 2,616' TMD 2,816' TVD Hole Depth: 2,653' TMD 2,652' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 37' EMW = Leak-off Press, + Mud Weight 0.052 x TVD 925 psi 0.052 x 2,652' + 9.3 ppg = Pump output = 0.1000 bps EMW for open hole sectio~ Fluid Pumped = 0.7 bbl 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,600 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi W 1,900 psI 0::: 1,800 psi ~ 1,700 psi en 1,600 psi W 1,500 psi 0::: 1,400 psi D.. 1,300 psi 1 ,200 psi 1,100 psi ~' . 1,000 psi I 900 psI 800 psi - 700 psi '" 600 psi 500 psi J 400 psi 300 psi 200 psi {' 100 psi 0 psi ~~~~~~~~~~~~t~~~mm~~~m~~~g~~a~~~~~~;~¡~~~mi~~~m STROKES II 111111 111111 11111111111111111111111111111111111111111111111 / ITtME UNE ONE MINUTE TICKS , ~g\I,a"..."."..., ....... ..... LEAI(..OFF TEST ""'CASING TEST ~ LOT SHUT IN TIME -+-CASING TEST SHUT IN TIME -+- TIME LINE NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE '--------------"--------------T----------------' t--------------t--~-~~~~---t---2-~f~Þf--1 r--------------T--4-šiiiš---r--šõõ-pšf--l ~-----------------------------..----------------. ¡ ! 6 stks ! 725 psi! í--------------T--~ršiiiš--T--92š-pšr-l r--------------.,..--------------~----------------, I I I J I 1 I I ~--------------+--------------+----------------.¡ I I I I I I I I t---------------+--------------t----------------i I I I I L______--------..1.----------____l__--------------J I I I I I I I I I . I I "--------------""--------------"----------------1 I I . I . I , I I I I I ,--------------.,..--------------,.----------------" I I I I I . I I ~--------------..¡..--------------~----------------~ I I I I ~--------------"¡"--------------f-- --------------f I I I I I I I t--------------+--------------f----------------1 I I J - I t_------------_.L_--------_____l_____----------_J I I I :---------------.l--------------:-------------...--J I I : I , I p--------------..,..-------"'------"'----------------' I I I I I I I I ~--------------..¡..--------------~----------------~ I I . I ~--------------"¡"--------------f---------------f I I I I t--------------+----_:._-------i----------------i . I I . I , I I t--------------'t'--------------t----------------1 I , I I I I I I t--------------¡------..-------t-------------"'--1 I I I I I I I I r--------------T--------------¡----------------' ~--------------4.............................~................................J I I I I ¡ ¡ ~ ~ I SHUT IN TIME I SHUT IN PRESSURE ~--------------""'--------------T----------------- LQ~9__~!~__L______-----_.l_--~?_~-p.~J_J L-.L9__~!~--L-------------L--~_~~_p.~L.J ! 2.0 min ! ! 875 psi! r--3:Õ-miñ-¡--------------¡--1fšõ-pšT-l ~--------------..¡..--------------~----------------~ I 4.0 min I I 840 psi I .----------,;,---+--------------i-------------:--i ~__~~9__~!~_-+--------------J---~-~~-p.!~--~ L_-§'~9__~!~_~L______-______l___~-~~-p.!~_J i-}_~9__~!~_j------------..l---~_~~_p.~L.J ! 8.0 min ! ! 810 psi! r-g:Õ--miñ-¡--------------¡---äõõ-psr--ì ~--------------..¡..--------------~----------------~ t_1Q.._Q_!n~~_1______--______L_~_~~_p.!~_J CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r--------------,---------------r--------------- L_-------------~---~_!!~.!_--~--__.Q_P'!i_____ L_-----------_J._-~-~-~.!__-L__~~r1~!LJ l-------------_J.-_:t~-~~.!--l--~~~-~!~---I ! ! 6 stks ! 818 psi ¡ r--------------'---ã-štks--T-;¡;rãõ-pšil r--------------~---------------~----------------I I I 10 stks I 1,390 psi I ~--------------'¡---------------~----------------I : I 12 stks I 1,660 psi I I---------------i---------------t--------------:- I 14 stks I 1,950 pSI [~~~~~~~~~~~~~~]~~~!~~~~~!~]~!;~~~~~P'!~~j ! ¡ 18 stks ! 2,500 psi! ,.--------------.,---------------,.-----..----------, I I I I f I 1 ~--------------~---------------~----------------I I I I . . I I I I---------------~---------------~----------------I I I I I . I f I I---------------i---------------t---------------- Iff I I I I I 1----..----------.1----------"----"-----..----------1 I . I I f I I I t I I I "---"----------"---------------"----------------41 I . I . I I I I ..--------------~ ---------------1-----------------1 I J I I I I ¡'--------------"---------------~----------------I I I I I 1---------------' ---------------~---------------I I I ~--------------i---------------~----------------I I I I I ¡ SHUT IN TIME I S~UT IN PRESSU~E "--------------1---------------"----------------- l-_9.:g_!!!~~--~---------------l-?l~Q.9_p.~L! ~--~.:g_!!!~~--~---------------~-~~~~õo -P-!~-i I 2.0mm I I 2,45 pSI I I-----------:"---of---------------~----------------I I 3.0 mm I I 2,450 psi ~----------:"---i---------------t--------------:-I I 4.0 mm I I 2,450 pSI r--š.-õ-ñifñ--r-------------r2;i5Õ-pšri r--[-õ-ñifñ--1--------------1-2;i5õ-psr¡ r--:rõ-ñifñ--,---------------r2;i5Õ-pšri r--------------~---------------~----------------I 8.0 min I r 2,450 psi I ~----------:"---of------------------------------:-I ~--~.:g_!!!~--~-----------------~~~~~_P.!~-I I 10.0 mm I I 2,450 pSI I r-1-Š~Õ-mTñ-r-------------r2;45õï)šri r2õ~õ-mfñT--------------r2;isõ-pšn r-2Š:õ-mfñ-,---------------r2;isõ-pšri ,.--------------~---------------~----------------I L?.9.:Q_!:!l~I]_J.--------______L~!~~~_P.!U ~' NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ') Casing Detail 7" 26# Production Casing ARC a Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN Nabors 19E RKB to LOS = 29.60 Nabors 19E Rotary Table to LOS = 31.00 7" Landing Joint (above table 5.80) 7" Landing Joint (below table 31.00) '. 7" FMC GEN V, fluted mandrel hanger with 7", 26#, L-80 pup jts 16-230 7", 26#, J-55, BTC-MOD (215 jts) Marker A 7", 26#, L-80, BTC-MOD Marker, top jt. = 19.63 Bottom jt. = 19.52 jts.3-15 7", 26#, J-55, BTC-MOD (13 jts) Davis Lynch Double Valve Float Collar 7", 26#, J-55, BTC-MOD (1 jt.) Davis Lynch Double Valve Float Shoe jts 1 BTM OF SHOE @ TD at 9400' 204' of cased rat hole RA Marker @ 8736, Marker Joint Collars @8777.31 and 8796.94 Joint #2 and joints 231-242 will not be run on this well Total Solid Centralizers=16---- Total Bow Spring Cents.=63 7xB 3IBxB Gemeco Solid Spiral Centralizers Floating on Joints .Joints #4 through #14 (11 total) Gemeco Bow Spring Centralizers Run over Stop Rings Joint #1 10' above shoe and 10' below collar (2 total) Joint #3 in center of joint (1 total) ) WELL: Palm #1A DATE: 03/07/01 1 OF 1 PAGES LENGTH DEPTH TOPS 5.80 31.00 2.54 8743.77 39.15 526.37 2.02 41.85 2.38 -5.80 31.00 33.54 8777.31 8816.46 9342.83 9344.85 9386.70 9389.08 Gemeco Bow Spring Centralizers Run over Casing Collars On Every 3rd joint---- Joints #15,18,21,24,27,30,33,36 (8 total) On Every Joint---- Joints #37,38,39,40,41,42,43,44,45,46,47,48,49, 50 and 51 (15 total) On Every 3rd Joint---- Joints #54,57,60,63,66,69,72,75,78,81,84 87,90,93,96,99,102 (17 total) On Every 3rd Joint--- Joints #105,108,111,114,117,120,123,126,129,13: 135,138,141,144 and 147 (15 total) On Every 3rd joint--jointS#150, 153, 156, 159 and 162 (5total) 7x8 3/8x12 Gemeco Solid Straigt Blade Centering Guides Floating on Joints On every 2nd Joint--- Joints #165,167,169,171 and 173 (5 total) Remarks: String Weights with Blocks: 170k Up, 85k On, 25k Blocks. Ran 230 joints of casing. Drifted casing with 6. 151 n plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Nabors 19E Drilling Supervisor: R. Morrison >.. J.JING I TUBING I LINER DETAIL 7" ~S# Production Casing ') # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN WELL: Palm # 1 A DATE: 03/07/01 2 OF 2 PAGES LENGTH DEPTH TOPS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Remarks: String Weights with Blocks: 300k Up, 150k Dn, 70k Blocks. Ran 262 joints of casing. Drifted casing with 6.15111 plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Phillips Alaska Drilling WeIlName:'~.~~ 'Ç)~\M \ \\ . Rig Name: Nabors 19E ) Cementing Details Report Number: W1 ildeat I Field: Casing Size 7" Hole Diameter: 8.5" Angle thru KRU: 68 Report Date: 03/09/2001 AFC No.: AX2143 "10 washout: Centralizers Comments: . Shoe Depth: 9389 LC Depth: 9342 State type used, intervals covered and spacing See easing detail for details on centralizers. Ran 63 bow springs, 11 solid spiral 7 x 8 3/8 x 8, 5 solid straight 7 x 8 3/8 x12 Mud Comments: PV(prior cond): Weight: 12.7/12.2 Gels before: Gels after: 619 Wash 0 Comments: Spacer 0 Comments: Type: CW 100 Type: MUDPUSHXL Lead Cement 0 Comments: Ught weight blend Type: G Mix Wlr temp: 80 PV(after con d): 22 YP(prior cond): YP(after cond): 13 Total Volume Circulated: 942 Volume: Weight: 8.3 ppg 40 bbls Volume: 40 bbls Weight: 12.5 No. of Sack)' 282 Weight: 13.0 ppg Yield: 1.99 Tall Cement 0 Comments: Mix Wlr temp: 80 Additives: 8.0"loD020, 0.60"A.D800, 0.60"/oD167,0.20"loD046, 0.30"loD065 Yield: 1.2 Type: G No. of sac7ks. 398 Weight: 15.8 Displacement 0 Comments: Rate(before tail at shoe): 4.9 BPM Additives: 3.0"loD053, 0.60"loD065, 0.120"loD8oo, 2.0 gaVsk D600, 0.150 gaVsk D135, 0.20 gaVsk D047 Str. WI. Up: 170 CP: Date: 03/09/01 Time: 11 :31 am Remarks:Ran casing to bottom at 9389' and landed on hanger. Made up Dowell cementing head. Attempted to pull off hanger, pipe was stuck. Broke circulation and circulated 942 barrels of mud. Mud weights 12.5 to 12.7 and viscosities 80 to 102 were measured coming out of the hole. The mud was conditioned to 12.2 wt and 52 vis, In and out of the hole. Dowell batch mixed the tail cement. Dowell pressure tested lines to 3500 psi. Dowell mixed and pumped 100 barrels of lead at 13.0 ppg followed by 85 barrels of tail at 15.8 ppg. Flushed lines prior to dlplaclng with 357.4 barrels of 12.2 ppg mud. The cement was preceeded with 40 barrels of CW100 flush at 8.3 ppg and 40 barrels of mud push XL spacer at 12.5 ppg. The bottom plug was dropped between the flush and spacer. The top plug was dropped after pumping the tail cement. We had full returns to suñace throughout the Job. The plugs did not bump and the floats did not hold (slight flow back). The casing was shut In with 0 psi for 4 hours. Reciprocation length: pipe stuck Theoretical Displacement: 357.16 Calculated top of cement: 4100' Cement Company: Dowell Rig Contractor: NABORS Rate(tail around shoe): 4.9 BPM Reciprocation speed: 0 Str. WI. Down: 85 Actual Displacement: 357.4 Str. WI. in mud: Bumped plug: no Floats held: no Approved By: R. L. Morrison/ R. Bowie ) ) Phillips Alaska Drilling Daily CompletionlWorkover Report AFC No. Date Rpt No I Rig Accept - hrs Days Since AcceptlEst: 19/ Rig Relase - hrs: AX2143 03109/2001 3 03107/2001 Well: Palm #fA Depth (MD/TVD) 9400/5946 PBTD (MD) 9339.93' Top of Fill Contractor: NABORS Daily Cost $163588 CompletionJWorkover Cost Total Well Cost $ 2165020 $494914 Rig Name: Nabors 19E Intermediate Csg: 9.625"02616' Production Liner: 7.0" 89386' Total Estimated Cost $ Operation At 0600 Drlg cmt , 9105', taged . 9063. Upcoming Operations: Drill to float collar at 9342'. chanQe over to sea water, test castn$. , pooh laying down. FLUID DATA FLUID LOSS BIT DATA EH&S ,DRILLSlBOP DATA MUD lYPE DAILY LOSS (bbls) BIT NO. BIT NO. ACCIDENT (non-spilO LAST BOPIDIVERT LAST BOP/DRILL LSND 3 N TST 03103/2001 03101/2001 WEIGHT TOTAL LOSS (bbls) SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 12.2ppg 6.125 02107/2001 VISCOSITY MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 55sqc HTC N SPACE 0310212001 PVNP PERFORATED TYPE TYPE TYPE FUEL & WATER 23117 INTERVALS ATJ4 GELS SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3140 5/91 F83JF APIWL DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 150 3.4 03lO9l2OO1 BBlS HTHP WL DEPTH IN DEPTH IN POTABLE WATER 100 10.4mlf30min 9095 INJECTION USED - BBlS SOLIDS FOOTAGE FOOTAGE INJECTION WEll WEATHER & 19% 305 1R18 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMPERATURE OF -22° 321 bbl III 1 1 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 17 27.5 ppb I I I ph LINER SZ RPM1 RPM 1 PRESSURE (PSi) WIND DIRECTION 60° 10.5 I I I LGS SPM1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -64.77° 8.4% 111 .9204 Water Base Muds 990 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 2 446 bbJ III 1811811811 I 11111 0 0 DAILY MUD SPS1 BIT COST BIT COST CONTRACTOR 29 $850 III 2861 PERSONNEL 0 0 DULL DULL TOTAL VOL (bbO MISC PERSONNEL III III 990 GRADE GRADE TOT FOR WELL (bbl) SERVICE III III 8600 PERSONNEL TOTAL MUD SPP1 $8770 III COMPANY MUDWT BAROID III TIME I END I HOURS 12:00 04:30 AM 4.60 AM 04:30 06:00 AM 0.60 AM 06:00 09:00 AM 4.00 AM 09:00 11 :30 AM 2.60 AM 11:30 12:00 PM 0.60 AM 12:00 03:30 PM 3.60 PM 03:30 04:30 PM 1.00 PM 04:30 06:00 PM 1.60 PM 06:00 07:30 PM 1.60 PM 07:30 08:00 PM 0.60 PM 08:00 12:00 AM 4.00 PM 24.00 I OPS CODE} HOLE SECT I PHASE OPS CASG PROD Casing and Cementing CASG PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing CEMENT PROD Casing and Cementing Daily CompletionlWorkover Report: Palm #1A 03/09/2001 8 TOTAL I OPERATIONS FROM 0000 - 0000 Completed running 7" csg to 9389'. 47 Make up hanger to csg & rih on Idg jt. Install cmt head. Clr / cond mud from 12.7 ppg 187 vis outto 12.2 In / out I 64 vis, yp reduced to 13. PJSM. Cement 7" as per program, see csg 1 cmt rpt for details. Plug did not Idg on calculated disp of 367 bbl - no press Increase as plug approached Idg collar. Cip 1131hrs 03092001. Floats I plug did not hold. SI for cmt to gel. Wash up trucks & surface lines. WOC Open up 7", no now, observe for 30 min. Recover Idg jt. Run pack off assby & test to 6kpsi I 30 min. PJSM. X-out pipe rams to 4" & test to 6k psi. Set wear bushing. Make up bha & tih filling dp each 3000'. Depth @ midnight 3000" Supervisor: . MORRISON / R. BOWIE Page 1 CASING TEST and FORMATION INTEGRITY TEST Well Name: Palm #1A Date: 3/10/01 Supervisor: R. Morrison Jr. 0 Initial Casing Shoe Test Reason(s) for test: ~ Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 36#, J-55, BTC Casing Setting Depth: 2,616' TMD Hole Depth: 2,616' TMD 2,616' TVD 2,616' TVD Mud Weight: 12.2 ppg Length of Open Hole Section: 0' EMW= Leak-off Press. + Mud Weight = 680 psi + 12.2 ppg 0.052 x TVD 0.052 x 2,616' EMW for open hole section = 17.2 ppg Pump output = 0.0840 bps Fluid Pumped = 5.5 bbl 3.200 psi 3.100 psi 3.000 psi 2.900 psi 2.800 psi 2.700 psi 2,800 psi 2.500 psi 2.400 psi 2.300 psi 2.200 psi 2,100 psi 2.000 psi W 1,900 psi 0:: 1.800 psi ~ 1.700psl f/J 1 ,600 psi W 1.500 psi 0:: 1.400 psi Q. 1.300 psi 1.200 psi 1.100 psi 1,000 psi 900 psi 800 psi 700psl . . ~ m~r ~. 100 psi 0 psi . -~~~~~~~~~~~t~~~mm~~~~ii~g~i~~~~~~~~~¡m~~~i~~~~ STROKES ITlME liNE ONE MINUTE TICKS / --- LEAK-OFF TEST ""'CASING TEST -@- LOT SHUT IN TIME -ir-CASING TEST SHUT IN TIME -+- TIME LINE 111111111111 1111111111111111111111111111111111111111111111111 .. It' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE r--------------.,..--------------,----------------, r--------------,--------------r----------------, L____________l__.Q_!!~~--~---__QJ~!L___~ L_------------~-_-!>_!i!~---~____.Q_e!~---i L---_--______L_~_!!~!___L_~_C!~_e~J__J L_----------_J_--------______L______-------_J ! ! 4 stks ! 400 psi! i ! ¡ ! r-------------T--.fšikš---r--¡Õõ-p--šf-¡ r--------------l---------------r----------------¡ I I I I I . I I [~~~~~~~~~~~~I~~~!!~!~]~~~i!~~p.!(][~~~~=~~~~~~~I~~~~~~~~~~=~~[~~~~~~~~~~~~] ~--------------¡--~~_!!~!_-¡__~?~_e~_~__~ ~--------------~---------------~---------------- I I 12 stks I 500 pSI I I I I I ~--------------+-------------t---------------_J L._-------------i---------------t---------------- i I 14 stks I 525 psi! ! I I : 10--------------"'--------------"----------------01 ~--------------..---------------..._---------------. L------------l--~!_!~~!-J--_~_~~_e!~J L------------~---------------L-------------J L--------___-l._i~_!!~f!_-l..-~?~_e!~--l l--------------~---------------i----------------I II 20 stks I 600 psi I I . I I ~--------------+--------------~--------------~ "----------------------------~----------------I ~--------------¡--~~_!~~f!_-¡---~_!~_P.!~--~ ~-------------_.:_-------------~----------------¡ I I 24 stks I 625 psi I I i I I t--------------t--------------t-------------.:"--i~---------------'--------------t---------------I : . 26 stks : 660 pSI I I : I . I .-------------_..a._------------.--------------.. ..--------------..---------------.----------------. I ! 28 stks I 680 psi! ! ! ! ! r--------------...------------J---------------. ..--------------..---------------..----------------. I ! 30 stks ! 650 psi! ! ¡¡I [~~~~~~~~~~~~I~~~!~1~!~~[=!~~~p.!C][~~~~~~~~~~~~]~~~~~~~~~~~~~~]~~~~~~~~~~~~~~] : : 42 stks I 520 psi: : I I : ~--------------+------------i-------------.---i ----------------I---------------.----------------I t--------------t--;~-¡~~j--1---~-gg-~if--1 r--------------;---------------r----------------! ~--------------...------------..--------------. I - i i 60 stks i 475 psi! I SHUT IN TIME. SHUT IN PRESSURE "--------------"'------"-"-----1---------------~"-"-----------.....----......--------.-------------..--. l--------------l.-~!_!!~!_-!---~-~~-p.~J.-.l l-_9.:_q_!!!l~__~__------------J---__Q_P.~L_--I I I ¡I: 1.0 min. I I ~--------------................................,.................................~ ,,----------,.---4---------------.---------------1 I I : I I 2.0mm I I : 1 I . . -----------:-----I---------------.----------------I ISHUTINTIMEI SHUT IN PRESSURE I 3.0 mm I I I t--------------+--------------T---------------'L._-------------1---------------t---------------1 LQ:.9__':!1!~__1______--______L_?.9.Q_p.~J__J L_~.:g_!!!l~__J__-----------_-L_------------_J ! 1.0 min i ! ! i 5.0 min ! ! ! ..--------~-----~--------------..----------------.. ÞO--------------"---------------"----------------I ! 2.0 min Iii! 6.0 min i ! ! .-------------~--------------"---------------1"'-"-----------.,--------------,,----------------. i 3.0 min I I I I 7.0 min I I I r----------,;,---+-------------~----------------~ "--------------4---------------1-----------------1 I 4.0 mm I I I I 8.0 min I I : t----------,;,---+--------------i----------------i}----------:----I-------------~----------------I ~-_?.:.9__':!1~~-+--------------i----------------~ ~--~.:_Q_!!!~~--~---------------~---------------i I 6.0 mm I I I I 10.0 mm I I : t----------':"---T-----"'--------f----------------1 t"-----------.---1--------------~----------------1 I 7.0 mm I I I I 15.0 mm : : I Jo--------------"'--------------+----------------of "'--------------"---------------..----------------a i 8.0 min ¡¡I i 20.0 min ¡ i ! .-------------...--------------~----------------" ,.--------------...---------------..----------------, I 9.0 min i'l' 25.0 min I :. I ~-----------:'--T------------~---------------_J ~--------------~---------------~----------------I I 10.0 mm I . I , I 30.0 min I : I ~-------------_.1._------------_J._--------------_J '--------------_J_-----------__L____-_------__-_I .~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY r , l' ~~~~~Jf ~11Æ~[{1Æ / AJ."'SIiA OIL AND GAS /1 CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 3S-07 ConocoPhillips Permit No: 202-187 Surface Location: 2487' FNL, 935' FEL, Sec. 18, T12N, R8N, UM Bottomhole Location: 1090' FNL, 1068' FWL, Sec. 17, T12N, R8E,UM Dear Mr. Thomas: ~. r: ::\ ~' 7 l&r; Enclosed is the approv. ed application for permit to re rill the above development well. . ~) The permit to rßdri11 does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits 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 terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, r bAA- .--. .rÛul~'k¿¡ C~;;-dechsli Taylo~- Chair BY ORDER OF THE COMMISSION DATED thisLZ day of September, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~ ') PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY \, ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com September 3, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 3S-07 Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 3S-07, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Scott Lowry at 265-6869. Sincerely, ~~. Randy Thomas GKA Drilling T earn Leader ) 0) VJ GA- 'i I Y/ () 'L- ~- cr(r,>(~ 1 a. Type of work: Drill ~ Redrill U Re-entry DDeepen D 2. Name of Operator ConocoPhillips 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. location of well at surface 2487' FNL, 935' FEL, Sec. 18, T12N, R8E, UM At top of productive interval 1109' FNL, 1041' FWL, Sec. 17, T12N, R8E, UM At total depth 1090' FNL, 1068' FWL, Sec. 17, T12N, R8E, UM 12. Distance to nearest property line 13. Distance to nearest well 1041 @ Target 3S-26A @ 357' / 16. To be completed for deviated wells Kickoff depth: 300 MD 18. Casing program size STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service D Development Gas D Single Zone D 5. Datum elevation (DF or KB) RKB = 28' feet 6. Property Designation ADL 380107 ALK 4624 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit /' Statewide 8. Well numbeý Number 3S-07 / #59-52-180 9. Approximate spud date / Amount October 15, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2448 6611 ' MD / 6058 ' TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2}) Maximum surface 2971 psig At total depth (TVD) 3612 psig Setting Depth Development Oil ~ Multiple Zone D 10. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Maximum hole angle 55° Hole Casing Weight 42" 16" x 30" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTCM length 80' 2742' 6583' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 9 cy High Early ./ 28' 28' 2770' 2579' 520 sx AS Lite & 220 sx LiteCrete 28' 28' 6611' 6058' 210 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth Perforation depth: measured true vertical .. 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is. true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869 S;gned ~:,-\ ' ~ Title: Kuparuk Drilling Team Leader Date ~ 1'$ It) z.. PrfmArArl hv ,c;hAmn AIIRlm-DmkA Permit Number I API number ~ ð-Z. - / f 7 50- / ð l-- Z ÞNo$l.] ð Conditions of approval Samples required D Yes ~ r Hydrogen sulfide measures DYes .81 No Required working pressure for BOPE D2M; D 3M; Other: T€c:.t- 1517 PE to 5000 1J c¿" OrigInal SIgneD °1 Cammy Qechsli T aylof Commission Use Only I Approval date C\ \ '1 O~ Mud log required ' Directional survey required ~ D 5M; D 10M; D D Isee cover letter for other requirements U Yes ~ No Yes D No Approved by Commissioner by order of the commission Date q/11 }lì~ Form 10-401 Rev. 12/1/85. L, ~ .J .~/ ". ~ .:;.A Submit in triplicate ) AP"'j.. tion for Permit to Drill, We1l3S-07 Revision No.O Saved: 3-Sep-02 Permit It - Kuparuk Well 35-07 Application for Permit to Drill Document Table of Contents 1. Well Name .... ............. ........ ...... ........ ... ..... ...... ...... ............... ....... .......... ...... ........... ..... 2 Requirements of 20 AAC 25.005 (f)............ ........... ......... '"'''' ............................ ..................... '''''''''''''''' 2 2. Location Sum mary .......... .... ... ...... ........... ...... .............. ...... ... .... ........ ...... ....... ...... ..... 2 Requirements of 20 AAC 25. 005( c)(2) ........ ........... ......... ............. ............ ..... ............. ........ ........ ............ 2 Requirements of 20 AAC 25. 050(b).... .................. .......... .... ........... ....... ........................... ....... ................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...... ........... ......... ...... ............ ...................... ......... ........ ................ 3 4. Dri II i ng 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 Cementi ng Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) ..............,.... .......................................... ............. ................... ...... 4 7. Diverter System Information.. ....... ....... ..... .... .... .................. ...... ......... ....... .... ....... ... 4 Requirements of 20 AAC 25.005(c)(7) ............... ................ .......... ....... ............. ...... ......... ...... ....... .......... 4 8. Dri II i ng FI uid Program .... .... ...... ......... ................ .......... ........ ...... ......... ..... ... ........ ..... 4 Requirements of 20 AAC 25.005(c)(B) ..,.. """""''''''''''''' ..... .................. .............. ............... ................... 4 9. Abnormally Pressured Formation Information...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ...... ............................................... ..... .....,... ................. "'''' ........ 5 10. Seismic Analysis ........ ....... ..... ...... ....... ...... ........ ..... ....... ...... ... ....... .......... ............. .... 5 Requirements of 20 AAC 25.005 (c)(10) ............... .......... ........ ......... ......... ...., ....... ........ ........ ................. 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bondi ng .... .......... ....... ..... ....... .... ... .... .............. ... ... ........ ....................... 6 Requirements of 20 AAC 25.005. (c)(12) ......................................................................... ......,................ 6 13. Proposed Drilling Program .....................................................................................6 Q ¡ ¡ . ""', , i~' L 3S-07 PERMIT IT. DOC Page 1 of 6 Printed: 3-Sep-02 ') Apr"-,. tion for Permit to Drill, We1l3S-07 } Revision No.O Saved: 3-Sep-02 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ....... .... ... ....... ..... .............. ... ... ........ .......... ................. ...... ...... ..... ...... ..... 7 Attachment 1 Directional Plan ........................................... '"'''''''''''' .........,........ ............. ........ ....... ""'" 7 Attachment 2 Drilling Hazards.... .................. ....... ..... .... .... .......... ............ ................... ...... ....6 Attachment 3 Well 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 we!! with mu!tlple well br'i3nche0 eaä7 branch must similarly be Identified by a unique narne and API number by adding a suffix to the name designated for the we!! by the operator and to the number as!::igned to the we!! by the commission. The well for which this application is submitted will be designated as 35-07. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fòr a Permit to Drill mU5t be accompanied by each of the following items? except for an item already on tìle with the commission and Identified in the application: (2) a plat identifying the property and the propert)/'s owners and showing (A)the coordinates of the pf'.f)jJosed loœtion of the well at the surfac~ at the top of each objective formation and at total depth referenced to governmental section lines. (8) the coordinates of the proposed location of the ¡Alel/ at the surface, referenced to the state plane coordinate system f..0r thl." state as maintained by the Nationa! Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we!1 at the top of each objective formation and at total depth; Location at Suñace NGS Coordinates Northings: 5,993,928 Eastings: 476,325 I 2487' FNL, 935' FEL, Sec 18, T12N, R8E, UM RKB Elevation Pad Elevation 56.1' AMSL 28.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,995,300 1109' FNL, 1041' FWL, Sec 17, T12N, R8E, UM Eastings: 478,300 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6375' 5825' 5769' Location at Total Depth 11090' FNL, 1068' FWL, NGS Coordinates Northings.' 5,995,319 Eastings.' 478,327 Sec 17, T12N, R8E, UM Measured Depth, RKB.' Total Vertical Depth, RKB.' Total Vertical Depth, 55: 6611' 6058' 6002' and (D) other information required by 20 MC 25. 050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a PermIt to Dnll (Form 10-401) must (I) include a plat; dl'i3wn to a sUItable scale, showing the path of the proposed wellboref including all adjacent well bores within 200 feet of any portion of the proposed well,' Please see Attachment 1: Directional Plan 0 I ¡ lord; I!) L 3$-07 PERMIT IT. DOC Page 2 of 6 Printed: 3-$ep-02 ') Apr "j... tion for Permit to Drill, Well 3S-07 Revision No.O , Saved: 3-Sep-02 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well".- to the extent that those names are known or discoverable in public record~ and show tllat eacll named operator has been furnished a copy of the application by certilìed mad; 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 appkcation for a Pe¡mit to Drill must be accvmpanied by each of the fa/lowing ItemSr except for an Item already on file with the commission and identífied in the applìcatìon: (3) a diagram and description of the blov,Iout prevention equipment (BOPE) as required by 20 AAC 25.035" 20 AAC 25.036, or 20 AAC 25.037; as applicable; Please reference BOP schematics on file for Nabors 7E5. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must' be accompanied by each of the fo/lowlng itemSr except lor an item already on file with the commls..tj'Íon and identitìed in the application' (4) information on drilling hazards, including (A) the maxfi7Jum downhole pressure that may be encountered; cnteria used to detelmine it and maximum potent/~ll swface pressure based on a methane gradient. A pressure build-up test performed on Palm lA (35-26) in 4/01 indicated a reservoir pressure in the Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MP5P) while drilling 35-07 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5825' tvd: MP5P =(5825 ft)*(0.62 - 0.11 psi/ft) = 2971 psi (' (8) data on potentia! gas zones/ The well bore is not expected to penetrate any gas zones. / and (C) data concerning potential causes of hole problems such as abnormally geo-pre.%ured strata; lost circulation zone~ and zones that have a propensity for differential sticking/ Please see Attachment 2 - Drilling Hazards Summary 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 following items, except for an item already 017 fìle wIth the commission and Identified In the application: (5) a description of the procedure for conducting formation integrity testSr as required under 20 MC 25.030(f); A procedure is on file with the commission for performing LOT's. For 35-07 the procedure will be followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0 ppg EMW maximum will not be observed. (see step 6 in the procedure) J I'm\ ~ IJ ;;.........../1 ........., t.:! Î ; d $ ~" i 1,,1 l .(¡jI 35-07 PERMIT /T.DOC Page 3 of 6 Printed: 3-5ep-02 ) Ap"'''.,tion for Permit to Drill, Well 3S-07 J Revision No.O " Saved: 3-Sep-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by ea(;f¡ of the following ¡tem~ except tor an item already on file with the commission and Identified in the applicðtion: (6) a complete proposed casing and cementing program as required by 20 MC 25. 03~ ðnd ð descríption of any slotted liner; pre- perforated líner; or screen to be installed,. Casing and Cementinq Program Hole / Top Btm CsglTbg Size Weight Length MDITVD MDITVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 2742' 28'/28' 2770'/2579' Lead: 520 sx 10.7 ppg AS Lite Tail: 220 sx 12.0 ppg 'LiteCRETE'. (Yield=2.40 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 6583' 28'/28' 6611'/6058' 210 sx 15.8 ppg 'G' w/ add. Planned TOC= 5575' 3-1/2 9.3 L-80 EUE 8rd 6247' 28' / 28' 6275'/5725' SAB-3 packer set at Mod 6275' MD. / / An open-hole leak-off test will be performed on the 8 112" open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7" casing will be top-set above the Kuparuk C sand. In this case, 6 1/8" hole would be drilled to total depth and a 3 112" 9.3 ppf L -80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be aŒompanied by each of the following items., except for an item already on file with the commission and identitied in the application: (7) a diagram and description of the diverter system as required by 20AAC 25.(J3~ unless thìs requirement is waived by the commis-sion under 20 MC 25. 035{h){2}; Please reference diverter schematic on file for Nabors 7ES. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for c7 Pe¡m¡t to Dríll must be accompc7nied by ec7ch of the follow/i7g ¡tem~ except for an item c7/ready on file with the commission and identified in the application: (8) a drilJing fluid programf including a diagram and description of the drilling fluid systemf as required by 20 AAC 25. 033; Drilling will be done using mud systems having the following properties: OR}; , ~ I! M " I" 3S-07 PERM/T /T.DOC Page 4 of 6 f Printed: 3-Sep-02 ¡¡::ø 6 ~ ) Apr" "\l... tion for Permit to Drill, We1l3S-07 , Revision No.O , Saved: 3-Sep-02 Suface Hole mud properties Spud to Base of Permafrost Initial Value / Final Value 9.4 / 9.4* 120-130 120-100 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH 8-9 API Filtrate(cc) 12-15 Solids (%) 6-9 * 9.8 if hydrates are encountered Base of Permafrost to Total Depth Initial Value Final Value 9.4* 9.4* 100-120 100-75 35-45 8-15 27 -40 11-22 8-9 7-8 6-12 25-35 20-30 15-30 15-30 1 0-25 10-25 20-40 15-35 8-9 8-9 7-8 7-8 6-12 6-12 10-30 25-55 10-25 25-55 Production Hole mud properties initial 4,485' 5,600' 6,000 Kuparuk " Density (ppg) 9.5 10.2 10.6 10.8 12.3 / Funnel Viscosity 40-55 42-55 42-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 20-25 (cP) Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25 (lbl1 00 sf) 10 second Gel 2-5 3-6 3-6 4-7 4-8 Strength (lb1100 sf) 10 minute Gel 4-10 7-10 7-112 7-12 8-16 Strength (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <4 <4 Solids (%) 6-11 9-14 1 0-15 1 0-15 15-19 Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Pelmlt to Drill mU::.7 be accompanied by each of the following ftem~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f}-- Nj 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 eaäJ of the following item~ except for an item already an file witl] the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seismic refracuon or rellection analysis as required by 20 MC 25.061(a)/' Nj A - Application is not for an exploratory or stratigraphic test well. 0 1", .~ 3S-07 PERMIT IT. DOC Page 5 of 6 , Printed: 3-Sep-02 ~ M I,; ) AP"'''.''''jtion for Permit to Drill, We1l3S-07 Revision No.O Saved: 3-Sep-02 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applicatIon for a Permit to Drill must be accompanied by ead} of the fbllowing }tem5~ except for an ìtem 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 tig/ or floating drilling vesse¿ an analysìs of seabed mnditlons 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 item;;,~ except for an Item already on file with the commission and identified in the application: {12} evidence showìng that the requirements of 20 MC 25.025 (Bonding}have been met/ Evidence of bonding for Phillips 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 ítem~ except for an item already on file v'lith the mmmisslon and Identified in the applkè1tion: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 7ES. / / 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run LWD logging equipment with GR, resistivity, and neutron density tools. / 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi/Test casing to 2500 psi. ./ 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. POOH and P/U neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L-80 BTCM casing to surface and cement. / Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped f~solation in accordance with 20 MC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer, shear out of PBR, P/U tubing hanger, ~d land tubing. Pressure test tubing to 3500 psi. Pressure test 3 '12" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. 8. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L-80 BTCM / casing will be run and cemented above the Kuparuk C sand. 6 1/8" hole will be drilled to total depth according to the directional plan and a 3 V2" 9.3# L-80 SLHT liner will be ran and cemented across the productive interval. 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 followìng item~ 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 MC 25:080 for an annular disposal operation in the well.,: 0 3fo7 PERMIT IT. DOC :~ !\ j,:~ Page 6 of 6 .'" .,.,ì ¡ ; .i í..I..L,.!. If'rinted: 3-Sep-02 ¡¡ Î! ~U 5., ¡¡¡. Ar""~rtion for Permit to Drill, We1l3S-07 , Revision No.O I Saved: 3-Sep-02 Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 35 pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 35 pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. / At the end of drilling operations, an application may be submitted to permit 35-07 for annular pumping of fluids occurring as a result of future drilling operations on 35 pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 0 j /:" " $ . i 38-07 PERMIT IT. DOC Page 7 of 6 L Printed: 3-Sep-02 ~..t <:::> :1'r'J KuparuklColville North Slope, Alaska Kuparuk 35, Slot 35-07 35-07 (wp03) Revised: 26 August, 2002 PROPOSAL REPORT 26 August, 2002 ~ .]'a Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Surface Coordinates: 5993927.99 N, 476324.92 E (70023' 40.3515" N, 150011'33.4636" W) Surface Coordinates relative to Project H Reference: 993927.99 N, 23675.08 W (Grid) Surface Coordinates relative to Structure: 84.58 N, 130.35 W (True) Kelly Bushing: 56. 10ft above Mean Sea Level r-- u ""'y-SU" aIÊI]Jb:I;::EHD::::::::.,.:B:2:)C:I]~; A h.idti;Nntm ~MþiW!%t' Proposal Ref: pr09969 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth IncJ. Azim. Depth Depth Northings Eastings Northings Ea . Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ~OOft) 0,00 0,000 0,000 -56,10 0.00 O.OON 0,00 E 5993927,99 N 0.00 SHL (2487' FNL & 935' FEL, SEC, . .,.,.,,<:- ~'N- 18- T12N - R8E) 50,00 0,000 0,000 -6,10 50.00 5993927.99 N 0,000 0.00 100.00 0,000 0.000 43,90 100,00 5993927.99, N 0.000 0.00 150.00 0,000 0.000 93.90 150,00 5993927.99'N 0.000 0,00 ~ 200,00 0.000 0.000 143,90 200,00 5993927.99 N 0.000 0.00 250,00 0,000 0,000 193,90 250.00 ;"'"'5993927,99 N 476324.92 E 0.000 0.00 300.00 0,000 0,000 243,90 300.00 5993927,99 N 476324.92 E 0,000 0.00 Begin Dir @ 2.00/100ft : 300,001t M 300.00ft TVD 350.00 1,000 70.000 293,90 350.00 0.41 E 5993928,14 N 476325.33 E 2,000 0.42 400.00 2.000 70.000 343,88 399.98 1,64 E 5993928,58 N 476326,56 E 2.000 1.68 450,00 3.000 70.000 393,83 449,93 3,69 E 5993929.32 N 476328,61 E 2.000 3.79 500,00 4,000 70.000 443,74 499.84 2,39N 6.56 E 5993930.36 N 476331.49 E 2.000 6.73 550,00 5,000 70.000 493.58 8 3,73 N 10.24 E 5993931,69 N 476335,18 E 2.000 10.51 600.00 6,000 70,000 543.35 5 5 5,37 N 14.75 E 5993933,31 N 476339.68 E 2.000 15.13 650,00 7,000 70,000 593.03 649.13 7,30N 20.07 E 5993935,23 N 476345,01 E 2,000 20,59 700.00 8,000 70.000 642,60, 698,70 9,54N 26.20 E 5993937.44 N 476351,15E 2.000 26,88 750,00 9,000 70.000 '692,05 748,15 12,06 N 33.14 E 5993939.95 N 476358.10 E 2.000 34,01 70,000 741 ,37 797.47 14,89 N 40,90 E 5993942.75 N 476365.86 E 2.000 41.96 Increase in Dir Rate @ 3.00/100ft : / 800.00ft MD, 797.47ft TVD 66.957 790.50 846.60 18,30 N 49.52 E 5993946,14 N 476374.50 E 3,000 50.97 64,573 839,38 895.48 22,61 N 59.07 E 5993950.42 N 476384.06 E 3.000 61.25 62,659 888.00 944.10 27,82 N 69,53 E 5993955,59 N 476394,54 E 3,000 72.80 - a 1000,00 15,681 61,089 936,30 992.40 33,91 N 80.91 E 5993961 .64 N 476405,94 E 3.000 85.60 1050,00 17,135 59,779 984,27 1040.37 40,88 N 93.19 E 5993968.58 N 476418.24 E 3.000 99.65 -~. 1100.00 18,596 58,669 1031 ,85 1087.95 48,74 N 106.37 E 5993976,39 N 476431.44 E 3.000 114.94 --~"J 1150.00 20,062 57,715 1079,03 1135.13 57.46 N 120.43 E 5993985,07 N 476445.53 E 3,000 131.45 ~:~;¡""'¡,-7 "'.;;:a !.~~":þ 1200.00 21 .533 56,887 1125.77 1181.87 67,06 N 135.36 E 5993994,62 N 476460.50 E 3,000 149.19 ~\':'-'~-"'~ 1250.00 23,008 56,160 1172,04 1228,14 77.51 N 151,17E 5994005,02 N 476476,33 E 3.000 168,13 ~~l""'_",.~ 1300.00 24.485 55,516 1217.81 1273,91 88.82 N 167.82 E 5994016.28 N 476493.03 E 3.000 188.25 "'- L~ 1350.00 25.965 54.941 1263.04 1319.14 100,97 N 185.33 E 5994028.38 N 476510,56 E 3.000 209.56 1400,00 27.447 54.424 1307.71 1363.81 113,97 N 203.66 E 5994041.31 N 476528,94 E 3.000 232,03 r-- 1401,21 27.483 54.412 1308.78 1364.88 114.29 N 204.11 E 5994041.63 N 476529.39 E 3.000 232.59 End Dir, Start Sail @ 27.483° : 1401.21ftMD,1364.88ftTVD 26 August, 2002 - 14:17 Page 2 of9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 Kuparuk/Colvi lie Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) OOft) 1450.00 27.483 54.412 1352.06 1408.16 127.39 N 222.42 E 5994054.68 N .0.000 255.10 1500.00 27.483 54.412 1396.42 1452.52 140.82 N 241.19 E 59949,§~.05 N 0.000 278.18 1550.00 27.483 54.412 1440.78 1496.88 154.25 N 259.95 E 5994081.42 N 0.000 301 .25 1600.00 27.483 54.412 1485.14 1541 .24 167.68 N 278.72 E 5994094.78 N 0.000 324.33 1605.48 27.483 54.412 1490.00 1546.10 169.15 N 4t~; 77 6.2S"N 0.000 326.86 Base Permafrost ~ 1650.00 27.483 54.412 1529.49 1585.59 297.48 4108.15 N 476622.97 E 0.000 347.40 1700.00 27.483 54.412 1573.85 1629.95 316.2 5994121.52 N 476641.78 E 0.000 370.47 1750.00 27.483 54.412 1618.21 1674.31 335.01 5994134.89 N 476660.59 E 0.000 393.55 1800.00 27.483 54.412 1662.57 1718.67 353.77 E 5994148.26 N 476679.39 E 0.000 416.62 1850.00 27.483 54.412 1706.92 1763.02 372.54 E 5994161.63 N 476698.20 E 0.000 439.70 1900.00 27.483 54.412 1751.28 391 .30 E 5994174.99 N 476717.01 E 0.000 462.77 1950.00 27.483 54.412 1795.64 410.07 E 5994188.36 N 476735.81 E 0.000 485.84 2000.00 27.483 54.412 1840.00 428.83 E 5994201.73 N 476754.62 E 0.000 508.92 2050.00 27.483 54.412 1884.35 447.60 E 5994215.10 N 476773.43 E 0.000 531.99 2100.00 27.483 54.412 1928.71 466.36 E 5994228.47 N 476792.23 E 0.000 555.07 2129.63 27.483 54.412 955.00 2011.10 309.92 N 477.48 E 5994236.39 N 476803.38 E 0.000 568.74 Top West Sak 2150.00 27.483 54.412 3.07 2029.17 315.39 N 485.12 E 5994241.84 N 476811.04 E 0.000 578.14 2200.00 27.483 54.412 17.43 2073.53 328.81 N 503.89 E 5994255.21 N 476829.85 E 0.000 601 .21 2250.00 27.483 54.412 2061.78 2117.88 342.24 N 522.65 E 5994268.57 N 476848.65 E 0.000 624.29 2300.00 27.483 54.412 2106.14 2162.24 355.67 N 541.42 E 5994281.94 N 476867.46 E 0.000 647.36 2350.00 , 27.483 54.412 2150.50 2206.60 369.10 N 560.18 E 5994295.31 N 476886.27 E 0.000 670.44 2400.0Ò' 27.483 54.412 2194.86 2250.96 382.52 N 578.95 E 5994308.68 N 476905.08 E 0.000 693.51 ---' 2450.00. 27.483 54.412 2239.21 2295.31 395.95 N 597.71 E 5994322.05 N 476923.88 E 0.000 716.58 2500.00 27.483 54.412 2283.57 2339.67 409.38 N 616.48 E 5994335.42 N 476942.69 E 0.000 739.66 C) 2550.00 27.483 54.412 2327.93 2384.03 422.81 N 635.24 E 5994348.78 N 476961.50 E 0.000 762.73 2600.00 27.483 54.412 2372.29 2428.39 436.24 N 654.00 E 5994362.15 N 476980.30 E 0.000 785.80 2631.24 27.483 54.412 2400.00 2456.10 444.63 N 665.73 E 5994370.51 N 476992.05 E 0.000 800.22 Base West Sak ~) 2650.00 27.483 54.412 2416.64 2472.74 449.66 N 672.77 E 5994375.52 N 476999.11 E 0.000 808.88 2700.00 27.483 54.412 2461.00 2517.10 463.09 N 691 .53 E 5994388.89 N 477017.92 E 0.000 831.95 Z«J¡-;¿;';.:-'4-~:~ 2750.00 27.483 54.412 2505.36 2561.46 476.52 N 710.30 E 5994402.26 N 477036.72 E 0.000 855.03 ~-~~~;~ i~ 26 August, 2002 - 14:17 Page 3 of9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) 100ft) 2770.00 27.483 54.412 2523.10 2579.20 481.89 N 717.80 E 0.000 864.26 9-5/8" Csg Pt... Drill out 8-1/2" Hole 2770.00ft MD, 2579.20ft TVD 9-5/8" Casing 2800.00 27.483 54.412 2549.72 2605.82 489.95 N 729.06 E 5994415.63 N 0.000 878.10 2850.00 27.483 54.412 2594.07 2650.17 503.38 N 747.83 E 5994429.00 N 0.000 901.17 2870.21 27.483 54.412 2612.00 2668.10 508.80 N 755.41 E 5994434.40 N 0.000 910.50 C-80 (K-10) .~ 2900.00 27.483 54.412 2638.43 2694.53 516.80 N 766.59 E 5994442.36 N 0.000 924.25 .;::-:~ ::(,~..; 2950.00 27.483 54.412 2682.79 2738.89 785.36¡¡~ 5994455.73 N 477111.95 E 0.000 947.32 3000.00 27.483 54.412 2727.15 2783.25 804.12 E 5994469.10 N 477130.76 E 0.000 970.40 3050.00 27.483 54.412 2771 .50 2827.60 822.88 E 5994482.47 N 477149.56 E 0.000 993.47 3100.00 27.483 54.412 2815.86 2871 .96 841.65 E 5994495.84 N 477168.37 E 0.000 1016.54 3150.00 27.483 54.412 2860.22 2916.32 860.41 E 5994509.21 N 477187.18 E 0.000 1039.62 3200.00 27.483 54.412 2904.58 2960.68 597.37 N 879.18 E 5994522.57 N 477205.98 E 0.000 1062.69 3250.00 27.483 54.412 2948.93 3QQli.g3 610.80 N 897.94 E 5994535.94 N 477224.79 E 0.000 1085.77 3300.00 27.483 54.412 2993.29 30419:89 624.23 N 916.71 E 5994549.31 N 477243.60 E 0.000 1108.84 3350.00 27.483 54.412 3037.65 3093.75 637.66 N 935.47 E 5994562.68 N 477262.41 E 0.000 1131.91 3400.00 27.483 54.412 082.01 3138.11 651.08 N 954.24 E 5994576.05 N 477281.21 E 0.000 1154.99 3450.00 27.483 54.412 26.36 3182.46 664.51 N 973.00 E 5994589.42 N 477300.02 E 0.000 1178.06 3500.00 27.483 54.412 3170.72 3226.82 677.94 N 991.76 E 5994602.79 N 477318.83 E 0.000 1201.14 3550.00 27.483 54.412 3215.08 3271.18 691.37 N 1010.53 E 5994616.15 N 477337.63 E 0.000 1224.21 3600.00 27.483 54.412 3259.43 3315.53 704.80 N 1029.29 E 5994629.52 N 477356.44 E 0.000 1247.28 3650.0Q 27.483 54.412 3303.79 3359.89 718.22 N 1048.06 E 5994642.89 N 477375.25 E 0.000 1270.36 ','"-'" 3700.0Q 27.483 54.412 3348.15 3404.25 731.65 N 1066.82 E 5994656.26 N 477394.05 E 0.000 1293.43 3750.00 27.483 54.412 3392.51 3448.61 745.08 N 1085.59 E 5994669.63 N 477412.86 E 0.000 1316.51 C) 3800.00 27.483 54.412 3436.86 3492.96 758.51 N 1104.35 E 5994683.00 N 477431.67 E 0.000 1339.58 3850.00 27.483 54.412 3481 .22 3537.32 771 .94 N 1123.11 E 5994696.36 N 477450.47 E 0.000 1362.65 =:J 3900.00 27.483 54.412 3525.58 3581.68 785.36 N 1141.88 E 5994709.73 N 477469.28 E 0.000 1385.73 ~J'-:,;.~~ ~~_: 3950.00 27.483 54.412 3569.94 3626.04 798.79 N 1160.64 E 5994723.10 N 477488.09 E 0.000 1408.80 4000.00 27.483 54.412 3614.29 3670.39 812.22 N 1179.41 E 5994736.47 N 477506.89 E 0.000 1431.88 ~~~;:Z&lC':..b 4050.00 27.483 54.412 3658.65 3714.75 825.65 N 1198.17 E 5994749.84 N 477525.70 E 0.000 1454.95 4100.00 27.483 54.412 3703.01 3759.11 839.07 N 1216.94 E 5994763.21 N 477544.51 E 0.000 1478.02 :t.> 4150.00 27.483 54.412 3747.37 3803.47 852.50 N 1235.70 E 5994776.58 N 477563.32 E 0.000 1501.10 r-- 26 August, 2002 - 14:17 Page 4 of9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: 5HL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 KuparuklColvi lie Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea . Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) ;OOft) 4200.00 27.483 54.412 3791.72 3847.82 865.93 N 1254.47 E 5994789.94 N 0.000 1524.17 4250.00 27.483 54.412 3836.08 3892.18 879.36 N 1273.23 E 59948Q3.31 N 0.000 1547.24 4300.00 27.483 54.412 3880.44 3936.54 892.79 N 1291.99 E 5994816.68 N 0.000 1570.32 4350.00 27.483 54.412 3924.80 3980.90 906.21 N 1310.76 E 5994830.05, N 0.000 1593.39 4400.00 27.483 54.412 3969.15 4025.25 919.64 N 13~~.52 3.42:N 0.000 1616.47 -~ 4450.00 27.483 54.412 4013.51 4069.61 933.07 N 1348.29 4856.79 N 477676.16 E 0.000 1639.54 4485.49 27.483 54.412 4045.00 4101.10 942.60 N 1361.61t,f 5994866.28 N 477689.51 E 0.000 1655.92 C-40 (K-3) 4500.00 27.483 54.412 4057.87 4113.97 ~tç.50 N 1367.05'e 5994870.15 N 477694.96 E 0.000 1662.61 4550.00 27.483 54.412 4102.23 4158.33 959.93 N 1385.82 E 5994883.52 N 477713.77 E 0.000 1685.69 4600.00 27.483 54.412 4146.58 4202.68 973.35 N 1404.58 E 5994896.89 N 477732.58 E 0.000 1708.76 4650.00 27.483 54.412 4247.04 986.78 N 1423.35 E 5994910.26 N 477751.38 E 0.000 1731.84 4700.00 27.483 54.412 4291.40 1000.21 N 1442.11 E 5994923.63 N 477770.19 E 0.000 1754.91 4750.00 27.483 54.412 6 1013.64 N 1460.87 E 5994937.00 N 477789.00 E 0.000 1777.98 4800.00 27.483 54.412 1 1027.07 N 1479.64 E 5994950.36 N 477807.80 E 0.000 1801 .06 4850.00 27.483 54.412 .7 1040.49 N 1498.40 E 5994963.73 N 477826.61 E 0.000 1824.13 4900.00 27.483 54.412 4468.83 1053.92 N 1517.17E 5994977.10 N 477845.42 E 0.000 1847.21 4950.00 27.483 54.412 4513.19 1067.35 N 1535.93 E 5994990.47 N 477864.22 E 0.000 1870.28 5000.00 27.483 54.412 4557.54 1080.78 N 1554.70 E 5995003.84 N 477883.03 E 0.000 1893.35 5050.00 27.483 54.412 4601 .90 1094.21 N 1573.46 E 5995017.21 N 477901.84 E 0.000 1916.43 5100.00 27.483 54.412 4646.26 1107.63 N 1592.23 E 5995030.58 N 477920.65 E 0.000 1939.50 5150.00 27,483 54.412 4634.52 4690.62 1121.06 N 1610.99 E 5995043.94 N 477939.45 E 0.000 1962.58 5200.00 27.483 54.412 4678.87 4734.97 1134.49 N 1629.75 E 5995057.31 N 477958.26 E 0.000 1985.65 ~.; 5250.00 27.483 54.412 4723.23 4779.33 1147.92 N 1648.52 E 5995070.68 N 477977.07 E 0.000 2008.72 5300.00 27.483 54.412 4767.59 4823.69 1161.35 N 1667.28 E 5995084.05 N 477995.87 E 0.000 2031.80 5350.00 27.483 54.412 4811.95 4868.05 1174.77 N 1686.05 E 5995097.42 N 478014.68 E 0.000 2054.87 10 5400.00 27.483 54.412 4856.30 4912.40 1188.20 N 1704.81 E 5995110.79 N 478033.49 E 0.000 2077.95 :J::J 5450.00 27.483 54.412 4900.66 4956.76 1201 .63 N 1723.58 E 5995124.15 N 478052.29 E 0.000 2101 .02 ~,,- 5500.00 27.483 54.412 4945.02 5001.12 1215.06 N 1742.34 E 5995137.52 N 478071.10 E 0.000 2124.09 ~'~":Þ 5550.00 27.483 54.412 4989.38 5045.48 1228.49 N 1761.10 E 5995150.89 N 478089.91 E 0.000 2147.17 ~.J; ---- 5596.1 5 27.483 54.412 5030.32 5086.42 1240.88 N 1778.43 E 5995163.23 N 478107.27 E 0.000 2168.47 Begin Dir @ 2.500o/100ft: 5596.1e :;:::: MD, 5086.42ft TVD ~ r--- 26 August, 2002 - 14:17 Page 50f9 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Ea Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) :OOft) 5600.00 27.387 54.413 5033.74 5089.84 1241.91 N 1779.87 E 5995164.26 N 2.500 2170.24 5650.00 26.137 54.417 5078.38 5134.48 1255.01 N 1798.18E 5995J,¡Z.30 N 2.500 2192.75 5700.00 24.887 54.421 5123.50 5179.60 1267.54 N 1815.69E 5995189.78 N 2.500 2214.29 5731 .32 24.104 54.424 5152.00 5208.10 1275.10 N 1826.25 E 5995197.30 N 2.500 2227 .27 Top Morraine 5750.00 23.637 54.426 5169.09 5225.19 1279.50 N 1 a;l~.4°tii; :;o;,9:99?€;p1.68+N 2.500 2234.83 --..-/ 5800.00 22.387 54.431 5215.11 5271 .21 1290.87 N 1848.30 E 5995212.99 N 478177.30 E 2.500 2254.38 5850.00 21.137 54.438 5261 .54 5317.64 1301.65 N 1863.38 E'1<:"'\"5995223.73 N 478192.41 E 2.500 2272.91 5900.00 19.887 54.444 5308.37 5364.47 1 .84 N 1877.63"E 5995233.87 N 478206.69 E 2.500 2290.43 5950.00 18.637 54.452 5355.57 5411.67 13 .43 N 1891.05 E 5995243.42 N 478220.14 E 2.500 2306.93 6000.00 17.387 54.461 5403.12 5459.22 1330.41 N 1903.63 E 5995252.37 N 478232.75 E 2.500 2322.39 6022.89 16.814 54.465 5425.00 1334.32 N 1909.10 E 5995256.26 N 478238.24 E 2.500 2329.12 Top H RZ 6050.00 16.137 54.471 5451.00 1338.79 N 1915.36E 5995260.71 N 478244.51 E 2.500 2336.80 6100.00 14.887 54.482 5499.17 1346.56 N 1926.24 E 5995268.44 N 478255.42 E 2.500 2350.18 6150.00 13.637 54.496 5547.63 1353.72 N 1936.27 E 5995275.57 N 478265.47 E 2.500 2362.49 6200.00 12.387 54.512 5596.35 1360.25 N 1945.44 E 5995282.08 N 478274.65 E 2.500 2373.75 6203.74 12.293 5656.10 1360.72 N 1946.09 E 5995282.54 N 478275.31 E 2.500 2374.55 Base H RZ 6250.00 11.137 5701.40 1366.17 N 1953.73 E 5995287.96 N 478282.97 E 2.500 2383.94 6300.00 9.887 5750.56 1371.46 N 1961.16 E 5995293.23 N 478290.42 E 2.500 2393.06 6309.68 9.644 5760.10 1372.41 N 1962.50 E 5995294.18 N 478291.76 E 2.500 2394.71 K-1 6350.00 8.637 5799.90 1376.12 N 1967.72 E 5995297.88 N 478296.99 E 2.500 2401.11 8.000 54.610 5769.00 5825.10 1378.26 N 1970.72 E 5995300.00 N 478300.00 E 2.500 2404.79 TARGET: Start Sail @ 8.00 : 6375.46ft MD, 5825.1 Oft TVD, ",! FNL & 1041' FWL, SEC. 17 -T12Ñ- R8E) Kuparuk a Target - 3S (7), 150.00 Radius., ::::0 Current Target 6400.00 8.000 54.610 5793.30 5849.40 1380.24 N 1973.51 E 5995301.97 N 478302.79 E 0.000 2408.21 ~~--::> r, ~z::a 6410.81 8.000 54.610 5804.00 5860.10 1 381 .11 N 1974.73 E 5995302.84 N 478304.02 E 0.000 2409.71 Miluveach L;-~) 6450.00 8.000 54.610 5842.81 5898.91 1384.27 N 1979.18E 5995305.98 N 478308.48 E 0.000 2415.17 ClIn«'~"4.."C~ 6500.00 8.000 54.610 5892.32 5948.42 1388.30 N 1984.85 E 5995309.99 N 478314.16 E 0.000 2422.13 ~~J:~~~._;~~.~;:a ,~ :~ r-- 26 August, 2002 - 14:17 Page 6 of9 DrillQuest 2.00.09.006 'CJ ~!':-~'~--':'~ ~'-.....,-:{ :s~ ~H..~ Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 Kuparuk/Colville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eas' (ft) (ft) (ft) (ft) (ft) (ft) 6550.00 8.000 54.610 5941 .84 5997.94 1392.33 N 1990.53 E 6600.00 8.000 54.610 5991 .35 6047.45 1396.36 N 1996.20 E 6611.00 8.000 54.610 6002.24 6058.34 1397.24 N 1997.45 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 56.1' MSL. Northings and Eastings ar lative to 2481' FNL, 935' FEL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 3S-07 and calculated along an Azimuth of 54.610° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 6611.00ft., The Bottom Hole Displacement is 2437.64ft., in the Direction of 55.027° (True). Comments Measured Depth 5596.15 6375.46 6611.00 26 August, 2002 - 14:17 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 0.00 Sfj)O.OO 797.47 1364.88 2579.20 0.00 N 0.00 N 14.89 N 114.29 N 481.89 N SHL (2487' FNL & 935' FEL, SEC. 18- T12N - R8E) Begin Dir @ 2.00/100ft : 300.00ft MD, 300.00ft TVD Increase in Dir Rate @ 3.00/100ft : 800.00ft MD, 797.47ft TVD End Dir, Start Sail @ 27.483° : 1401.21 ftMD. 1364.88ftTVD 9-5/8" Csg Pt ... Drill out 8-1/2" Hole: 2770.00ft MD, 2579.20ft TVD 0.00 E 0.00 E 40.90 E 204.11 E 717.80 E 5086.42 5825.10 6058.34 1240.88 N 1378.26 N 1397.24 N 1778.42 E 1970.72 E 1997.45 E Begin Dir @ 2.5000/100ft: 5596.15ft MD, 5086.42ftTVD TARGET: Start Sail @ 8.0°: 6375.46ft MD, 5825.10ftTVD (1109' FNL & 1041' FWL, SEC. 17-T12N-R8E) Total Depth: 6611.00ft MD, 6058.34ft TVD (1090' FNL & 1068' FWL, SEC. 17-T12N-R8E) Page 70f9 orth Slope, Alaska Kuparuk 3S Vertical Section Comment 2429.09 2436.04 2437.58 Total Depth: 6611.00ft MD, 6058.34ft TVD (1090' FNL & 1 r'"'Q' FWL, SEC. 17-T12N-R8E) -' 7" Casing DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 Kuparuk/Colvi lie Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Easting~M¡k', (ft) . , Northings (ft) 1490.00 0.000 359.819 1605.48 1546.10 1490.00 1955.00 0.000 359.819 2129.63 2011.10 1955.00 2400.00 0.000 359.819 2631.24 2456.10 2400.00 2612.00 0.000 359.819 2870.21 2668.10 2612.00 4045.00 0.000 359.819 4485.49 4101.10 4045. 5152.00 0.000 359.819 5731 .32 5208.10 5152.00 12 .10 N 5425.00 0.000 359.819 6022.89 5481 .1 0 5425.00 1334.32 N 5600.00 0.000 359.819 6203.74 5656.10 5600.00 1360.72 N 5704.00 0.000 359.819 6309.68 5760.10 5704.00 1372.41 N 5769.00 0.000 359.819 6375.46 5825.10 5769.00 1378.26 N 5804.00 0.000 359.819 6410.81 5860.10 5804.00 1 381 .11 N Casing details To easured Vertical Depth Depth Casing Detail (ft) (ft) <Surface> 2770.00 2579.20 9-5/8" Casing <Surface> <Surface> 6611.00 6058.34 7" Casing ~::,. ""-- ~::,.... r-==~ 26 August, 2002 - 14:17 Page 8 of9 280.77 E 477.48 E 665.73 E 0>"'''755.41 E 1361.61 E 1826.25 E 1909.10 E 1946.09 E 1962.50 E 1970.72 E Base Permafrost Top West Sak Base West Sak C-80 (K-10) C-40 (K-3) Top Morraine Top H RZ Base H RZ K-1 Kuparuk 1974.73 E Miluveach orth Slope, Alaska Kuparuk 3S ,--",' ~ DrillQuest 2.00.09.006 Q =0 -':'P.~- {~) ~J:':,-,,-;:.¡:..i:ã :~~ r-- Sperry-Sun Drilling Services Proposal Report for 35-07 (wp03) Your Ref: SHL per 'As-Planned' Lounsbury Coordinates Revised: 26 August, 2002 KuparuklColville Targets associated with this well path Target Name 3S (7) Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 26 August, 2002 - 14:17 Page 9 of9 Target TVD (fJ),'j; " 5825.10 5769.00 150.00ft .26 N 1970.72 E 5995300.00 N 478300.00 E 70° 23' 53.9052" N 1500 10' 35.7288" W orth Slope, Alaska Kuparuk 3S Target Target Shape Type Circle Current Target -' '-~,) DrillQuest 2.00.09.006 SpertÎ-Sun Drilling Se, ~ices Proposal Data - 35-07 - 35-07 (wp03) MD Delta Inclin.. Azimuth TVD Northings (ft) MD (ft) (°) (°) (ft) (ft) r'. ::~I ::::~:~:,. 7~~Ë .d:~~!.:.-1~I~! 4 1401.21 601.21 27.483 54.412 1364.88 114.29 N 5 5596.15 4194.94 27.483 54.412 5086.42 1240.88 N 6T 6375.46 779.31 8.000 54.610 5825.10 1378.26 N 7 6611.00: 235.54i 8.000 54.6101 6058.341 1397.24 Nt 26 August" 2002 -14:17 Eastings Dogleg (ft) (°/1 OOft) . . 0.06'. ....... 0.00 0.000 40.90 E 2.000 204.11 E 3.000 1778.43 E 0.000 1970.72 E 2.500 1997.45 EI 0.000: - 1 - A.Build (0/100ft) 0.000 2.000 2.908 0.000 -2.500 0.000' A. Turn TooIface I (0/100ft) (°) .... .....:..~::.....T:...:. .1 0.0001 0.000 0.000 70.000 -2.593 336.390 0.000 0.0001 0.025 179.9171 0.000 0.000 ¡ IþrillQuest ~ i; .",.. ,~ Ò,~.ID 1 I. 2 3 4 5 6T 7 MD Delta (ft) MD (ft) ... 6:00ì ......... .. 300.00 300.00 800.00 500.00 1401.21 601.21 5596.15 4194.94 6375.46 779.31 6611.00: 235.54: 26 August, 2002 - 14:18 SpertÎ-Sun Drilling Set ~ices Proposal Data - 35-07 - 35-07 (wp03) Inclin. Azimuth (°) (") O.öÒo. . ö.ö6ö!'" 0.000: . 0.0001 10.000; 70.181! . I 27.483 54.594 27.483 54.594 8.000 54.791 8.000 54.791 i TVD (ft) -.Sà..1 0 I 243~961 ¡ 741.371 1308.78 5030.32 5769.00 6002.24; Northings I Eastings Dogleg (ft) (ft) (°/1 OOft) 5993927.99 .~/. 47632.i:92.E[ ... ............ .... ....- . ~... ... 5993927.99 N 476324.92 E 5993942.75 N 476365.86 E 5994041.63 N 476529.39 E 5995163.23 N 478107.27 E 5995300.00 N 478300.00 E 5995318.90 N 478326.78 E - 1 - A. Build A. Turn (0/100ft) (°/1 OOft) 0.000 2.000¡ 3.000 0.000 2.500 0.000. 0.000 2.000 2.908 0.000 -2.500 O.OOOi .. . .~ .. . ï 0.0001 .O.OOO¡ -2.593 .0.000 0.025 0.000 ORi T oolface I (°) I .. I 0.006 70.181, i 336.390' 0.000 179.917 0.000, /"', .r /'<"; J i I DrillQuest t.::- ') ') Phillips Alaska, Inc. Kuparuk River Unit 35 Pad 35-07 ( ~"y-.u., aJDJ¡;;]id:S:I[:J.,J:!:~j[;II ~ tf.U!%ul'Ít$fl ifa~~'l p03) 0 _..... (2487' FNL & 835' FEL, SEC. 18- Tí2N. RaE) Begin Oir @ 2.0"/100ft : 300.00ft MO, 300.00ft TVD /' _/ 800 - ~~ .4'. increase in Dir Rate @ 3.0o/100ft: , 800.00ft MD, 797.47ft TVD , // 1 ---/ <§f'9~ , End Oir, Start San @ 27.483" : 1401.21 ftMD, 1364.88ftTVD 1600 Well: Reference is True North Current Well Properties 3S-07 Horizontal Coordinates: Ref. Global Coordinates: 5993927.99 N, 476324.92 E Ref. Structure: 84.58 N, 130.35 W Ref. Geographical Coordinates: 70023' 40.3515" N, 1500 11' 33.4636" W (2487' FNL & 935' FEL, SEC. 18- T12N - R8E) RKB Elevation: North Reference: Units: 56.10ft above Mean Sea Level True North Feet (US) Approved Plan (~ ~ 9-5/8" Csg Pt .,. Drill out 8-1/2" Hole: 2770.00ft MD, 2579.20ft TVD 2400 - :::J U) ~ cD l!) II CD ~ ES 3200 - ~ ã. Q) 0 (¡j u '1:: Q) > 4000 - ......., .................."....... 9,5/8" Csg Pt 2770.00' MD 2579.20' TVD 4800 - lAK(;1::T; ¡St}' Udhi.' (in);: it TVU. í378.26,v. § 0 CO II ~ U .S 5600 - Begin Dir @ 2.500o/100ft: 5596.15ft MD, 5086.42ft TVD / /'/ oÇ)o./ ~/ ~~~----- --'---------.."....... :~~;.;.0¡,...._.. -.--- "--':-:::7'~;. 'F7f717Tm ....._m',--','..-m_. ._u'" Qj (¡j u U) I 0 800 Scale: 1 inch = 800ft DrillQuest 2.00.09.006 ......... u- ._.._....~..... 7' Csg Pt. 6611.00' MD 6058.34' TVD Total Depth: 6611.00ft MD, 6058.34ft TVD (1090' FNL & 1068' FWL, SEC. 17-T12N-R8E) 1600 2400 3200 4000 0 .q # " a ::t:J ~-~::-'''-o.:.-..;,¡¡ ---- ~ r--- 11 /i-Hn~Lìps,\ ..e:u. 1500 - 1200 - (J' 0) c: E t:: 0 Z ~ 0 II .s= 0 .1; Q; ~ en DrillQuest 2.00.09.008 900 - 600 - 300 - Scale: 1 inch = 300ft Phillips Alaska, Inc. Kuparuk River Unit 3S Pad 38-07 (wp03) 0 300 I 600 I 900 I Reference is True North Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: 3S-07 5993927.99 N, 476324.92 E 84.58 N, 130.35 W 70023' 40.3515" N, 150011' 33.4636" W (2487' FNL & 935' FEL, SEC. 18- T12N - R8E) 56. 10ft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: Approved Plan (wp03) 9-5/8' Gsg PI 2770.00' MD 2579.20' TVD sp.nnY-1lU11 a:iJJ;:j;J1l1l::::'::][,BCfiSt:JEe;:I::I it tfu;Mbmm t:cÓft¥*tl'f 1200 I 1500 I 1800 I 2100 I 2400 I L1RDET: FYi' N.adim; ('irdr SR2S.1O TVD, 1378.26 ¡\i, iV70J2.E Total Depth: 6611.00ft MD, 6058.34ft TVD (1090' FNL & 1068' FWL, SEC. 17-T12N-R8E) - 1500 7" Gsg PI. 6611.006' MD 6058.34' TVD - 1200 ~' Beøin Dir @ 2.500.'/100fl : 5596.15ft MD. 5086.4211 TVD - 900 (J' 0) c: E t:: 0 Z - 600 9-5/8" Csg pt ... Drill oul 8-1/2" Hole: 2770.00ft MD, 2579.20ft TVD End Dir, Start Saii @ 27.483": 1401.21I1MD.1364.88ftTVD Increase in Dir Rate @ 3.0"/100ft : BOO.OOit MD, 797.47ft TVD Begin Dir @ 2.0"!100ft: 300.0011 MD, 300.00ft TVD SHL {24(~T rNL ('; FEL. SEC. 1 B.. T12N. H8E) I 300 I 600 I 900 0 .~ - 300 0 I 1200 I 1500 I 1800 I 2100 I 2400 Eastings <:::> ::x:J -..- ~ --- :?~ ~:r.;:a. r-- Phillips Alaska, Inc. MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) e 11 OOft) (ft) .~ ; (H)() 0,00 0,00 -56, 1 ° 0,00 0,00 N OJ)O E 599a927,£-)9 N 476324,92 E 0,00 0,00 SHL 300.00 0.00 0.00 243.90 300.00 0.00 N 0.00 E 5993927.99 N 476324.92 E 0.00 0.00 Begin Dir in 12-114" Hole 800.00 10.00 70.00 741.37 797.47 14.89 N 40.90 E 5993942.75 N 476365.87 E 2.00 41.96 Increase in DLS 1401.21 27.48 54.41 1308.78 1364.88 114.29 N 204.11 E 5994041.64 N 476529.40 E 3.00 232.59 End Dir; Start Sail 1605.48 27.48 54.41 1490.00 1546.10 169.15 N 280.77 E 5994096.25 N 476606.23 E 0.00 326.86 Base Permafrost 2129.63 27.48 54.41 1955.00 2011.10 309.92 N 477.48 E 5994236.39 N 476803.38 E 0.00 568. 74 Top West Sak 2631.24 27.48 54.41 2400.00 2456.10 444.63 N 665.73 E 5994370.51 N 476992.05 E 0.00 800.22 Base West Sak 2770.00 27.48 54.41 2523.10 2579.20 481 .89 N 717.80 E 5994407.61 N 477044.25 E 0.00 864.26 9-5/8" Csg pt ... Drill 8-1/2" Hole 2870.21 27.48 54.41 2612.00 2668.10 508.80 N 755.41 E 5994434.40 N 477081.94 E 0.00 910.50 C-80 (K-1 0) 4485.49 27.48 54.41 4045.00 4101 .10 942.60 N 1361.61 E 5994866.28 N 477689.51 E 0.00 1655.92 C-40 (K-3) 5596.15 27.48 54.41 5030.32 5086.42 1240.88 N 1778.43 E 5995163.23 N 478107.27 E 0.00 2168.4 7 Begin Dir @ 2.5°/1 OOft 5731.32 24.10 54.42 5152.00 5208.10 1275.10 N 1826.25 E 5995197.30 N 478155.20 E 2.50 2227.27 Top Morraine 6022.89 16.81 54.47 5425.00 5481 .1 0 1334.33 N 1909.11 E 5995256.26 N 478238.24 E 2.50 2329.12 Top H RZ 6203.74 12.29 54.51 5600.00 5656.10 1360.72 N 1946.09 E 5995282.54 N 478275.31 E 2.50 2374.55 Base HRZ 6309.68 9.64 54.56 5704.00 5760.10 1372.41 N 1962.50 E 5995294.18 N 478291.76 E 2.50 2394.71 K-1 ß375-47 8.00 54.G1 57G9.00 5825, '10 '137ß.2G ì"J 1 970]3 E 5995300,00 N 478300..00 E ') "'f) 2404,80 TARGET: Start Sail @ 8.00 L,0"" 6410.81 8.00 54.61 5804.00 5860.10 1381 .11 N 1974.74 E 5995302.84 N 478304.02 E 0.00 2409.71 Miluveach ~ 6611.00 8.00 54.61 6002.24 6058.34 1397.24 N 1997.45 E 5995318.90 N 478326.78 E 0.00 2437.58 Total Depth çompany; Field: Referënce Sitë; ReferénceWell; Reference Well path; Phillips Alaska Inc. Kupàri.Jk~iver Unit Kuparuk 38 Pad Plan: 38-07 Plan: 38-07 '') Sperry-Sun Anticollision Report Date; 8/26/2002 Time; 14:44:56 Page; 1 Co-ordinate(NE)jleference; Vertical(TVD) jlefërence; Well: Plan: 38-07, Grid North 56.1 5R1 GLOBAL SCAN APPLIED; All well paths within 200'+ 100/1000 of reference Interpolation Method; MD Interval; 50.000 ft Depth Range; 28.100 to 6611.000 ft Maximum Radius; 858.290 ft Reference; Error Model; Scan Method; Error Surface; 'Db: Oracle Principal Plan & PLANNED PROGRAM 18CW8A Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date; 5/14/2002 Validated; No Planned From To Survey ft ft 28.100 6611.000 Planned: 38-07 (wp03) V5 Casing Points MD TVD Diameter Hole Size ft ft in in 2770.000 2579.158 9.625 12.250 6611.000 6058.271 7.000 8.500 Name 95/8" 7" Summary <--~--------~---------- Offset Wellpath -------~~------------~> Site Well Wdlpath Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad Kuparuk 38 Pad 3S-26 Plan: 38-01 Plan: 3S-02 Plan: 38-02 Plan: 38-03 Plan: 38-06 Plan: 38-06 Plan: 38-08 Plan: 38-08 Plan: 38-09 Plan: 38-10 Plan: 38-10 Plan: 38-14 Plan: 38-15 Plan: 38-16 Plan: 38-17 Plan: 38-17 Plan: 38-18 Plan: 38-19 Plan: 38-19 38-26a VO Plan 38-01 V2 Plan: 31 Plan: 38-02 V2 Plan: 3 Plan: 3S-02F V2 Plan: Plan: 38-03 V2 Plan: 3 Plan: 38-06 V2 Plan: 3 Plan: 3S-06F V2 Plan: Plan: 3S-08 V2 Plan: 3 Plan: 3S-08F V2 Plan: Plan: 3S-09 V1 Plan: 3 Plan: 3S-10 V1 Plan: 3 Plan: 38-10F V3 Plan: Plan: 38-14 V1 Plan: 3 Plan: 3S-15 V1 Plan: 3 Plan: 38-16 V1 Plan: 3 Plan: 3S-17 VO Plan: 3 Plan: 3S-17F V1 Plan: Plan: 38-18 V3 Plan: 3 Plan 3S-19FV2 Plan: 3 Plan: 3S-19 V1 Plan: 3 Version; Toolcode 3 Tool Name MWD MW D - Standard Reference Offset Cti"-Ctr No-Go Allowable MD MD DiStance Area Deviation Warning ft ft ft ft ft 4842.793 5650.000 356.621 No Offset Errors 249.997 250.000 120.424 4.584 115.840 Pass: Major Risk 249.997 250.000 100.355 4.531 95.825 Pass: Major Risk 249.997 250.000 100.355 4.531 95.825 Pass: Major Risk 607.530 600.000 84.122 9.540 74.760 Pass: Major Risk 249.997 250.000 20.430 4.624 15.807 Pass: Major Risk 249.997 250.000 A°.430 4.624 15.807 Pass: Major Risk 498.625 500.000 15.669 9.096 6.586 Pass: Major Risk 498.625 500.000 15.669 9.096 6.586 Pass: Major Risk 596.054 600.000 35.854 10.664 25.302 Pass: Major Risk 446.864 450.000 58.373 8.266 50.112 Pass: Major Risk 446.864 450.000 58.373 8.266 50.112 Pass: Major Risk 347.628 350.000 140.253 6.515 133.739 Pass: Major Risk 299.980 300.000 160.630 5.610 155.021 Pass: Major Risk 299.980 300.000 180.798 5.594 175.204 Pass: Major Risk 249.997 250.000 200.314 4.654 195.660 Pass: Major Risk 249.997 250.000 200.314 4.592 195.722 Pass: Major Risk 299.998 300.000 220.306 5.574 214.732 Pass: Major Risk 249.997 250.000 240.395 4.616 235.779 Pass: Major Risk 249.997 250.000 240.395 4.616 235.779 Pass: Major Risk n ~","'/ I j¡z.¡¡¡ i ¡ N¡unc I'lall: 3S-07 -368 -300 -..200 -100 -0 270" -100 --.200 -300 -368 C:> ::!r:) '''~;=!i''-:v:,:.,t.''¡)i ~~."C"':'::'4:~ ~"";¿""->'>.:2J r- WI~,L DETAII.S ANTI-COLLISION SEmNGS Interpolation Method:MD Interval: 50.000 Depth Range From: 28.100 To: 6611.000 Maximum Range: 858.290 Reference: Plan: 3S-07 (wp03) Starting From TVD +N/-S +liI-W Ntlrthing I~isting I.atitude Lnngitude SÞI H4.<J<JH .DIUm 5'11.1<)27.'1'1 476324.<)2 70'23'4IU5IN ¡51n 1'3:1.464W N/A SURVEY PROGRAM Dcpth bn Dèpth Tn SurveyW~1n From Colour 0 200 400 600 800 1000 2000 5000 Tool 2KIIX) M1I.IXX) I'lall"'-.I: :IS.07 (wpm) V5 MWD 0 35J-07 (wp()3) Appr()ved Plan Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] COMPANY DETAILS waLPATH DETAILS Phillips Alaska Inc. Engineering Kuparuk Calcu1alion Method: Minimum Curvature Error System: tSCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warning Method: Rules Based Plan: 3S.07 Rig: Ref. Duwm: N7ES 56.1 56. 100ft V.Section Angle Origin +N/-S Origin +FJ-W 55.18" 0.000 0.000 0.000 ToMD 200 400 600 800 1000 2000 5000 10000 From Colour 0 200 400 600 800 1000 2000 5000 ToMD 200 400 600 800 1000 2000 5000 10000 -36 PRinn3 38)98:~Rlnn3 3 8191<) () ;(-, -~' -30 2£1 - -~tI I";~-. , I 1,0 , - '-20 -10 -IH -0 -10 - - --HJ ----20 ~ ~,/<':._-'~~Z -~----<// . .';<j/// -30 - - --- -\11 - -36 Ihlj'n SECTION DETAILS See MD Ine Azi TVD +N/-S +E/- W DLeg TFace VSee Target 1 28.100 0.00 0.00 28.100 0.000 0.000 0.00 0.00 0.000 2 300.000 0.00 0.00 300.000 0.000 0.000 0.00 0.00 0.000 3 800.000 10.00 70.00 797.465 14.886 40.898 2.00 70.00 42.074 4 1400.798 27.48 54.61 1364.481 113.840 204.277 3.00 -23.32 232.703 5 5596.190 27.48 54.61 5086.390 1235.258 1782.607 0.00 0.00 2168.763 6 6375.537 8.00 54.61 5825.100 1372.146 1975.276 2.50 180.00 2405.099 3S (7) 7 6611.000 8.00 54.61 6058.271 1391.125 2001.99 I 0.00 0.00 2437.867 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] ~) ) 35-07 Drillina Hazards Summary .12-1/4" Hole / 9-5/8" Casina Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole SwabbingjTight Hole on Trips Possible thaw bulb / water flow around 1200' Lost Circulation I Risk Level I Low Low Moderate J Moderate Low Low 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ, K-1, and Miluveach High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Low Moderate Low Moderate Moderate Moderate M itiqation Strateqy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM I M itiqation Strateqy Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. / Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3S-07 Drilling Hazards Summary. doc prepared by Scott Lowry 7/30/02 ~gl! t, d/ 1l\ ! '} i: i 'tifJ KRU - 38-07 pro,-hcer Proposed Completion Schematic Single Completion wI Jet Pump Contingency 16"x30" insulated I ( I conductor @ I I ~ +1- 109' MD I § ~ I I ~ TAM 9-5/8" PortJÎ. d I Collar Stnd ~ ~ Grade BTC I ~ Threads (+/- !EJ ~ 1000'MDITVD) I ~ ¡:¡ ~ I " æ ~ Surface csg. I ~ 9-5/8"40# L-80 ~ ~ BTC (2770' MD / ~ 2579' TVD) ~ Casing point i 100' above the I C80 sand ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " ~ ~ ~ ~ ~ ~ " ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " ~ ~ " ~ ~ ~ ~ I ~ " .J ..:_-~ j C Sand Perfs (to be done after rig moves off) Production csg. 7" 26# L -80 BTCM (+/- 6611' MD) ~ 2:;V II ~ I I ~ I ! 2 I ! ~ I ! ~ ~ ! ~ I ...... ~þ ~R ~I ~r i i ~ I! ~ I ~ I ~ I ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ § ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r .--:-¡' i:" '--y~ r- ~ ~ ~ ~ " ~ " ~ ~ ~ ~ ~ ~ J J:i,R*8H..'.L ~ ') PHllL.IPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. / GLM Placement: Placement TBO. Valves #1-4: 3-%" x 1" KBUG Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM w/ OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Baker 'CMU' sliding sleeve w/2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. / Baker 7" x 3-1/2"'SAB-3' Permanent Packer set +1-100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple w/2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-112" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. I TD @ 6,611' MD /6058' TVD (200' MD below Miluveach) Scott L Lowry 8/2/02 i S. K. ALLSUP-DRAKE 1001 { ~:::~~~~::::::sc~!~~~1~t~=fF~~ !~ --:;q~l('~'t€~~l~;>~k~¡;". .,. ..D~L~~S{i)~~Içl !~ Oi~"'A.æ . ~.7::;£,t~,;~,,;vaua2Ý5000urnws ...._i . ... .i,<).~;J l~~.;.~;:.~~!~,~,~~~L~ ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME j(jUJ .3 ~ -~ 7 PTD# .2./)...,- - /'17 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. .., WELL PERMIT CHECKLIST COMPAN~.-~...t~~f~WELL NAME /)/(1, 35-ð 7 PROGRAM: Exp - DevX- Redrll- Re-Enter - Serv - Wellbore seg- FIELD & POOL 7'9~/1'"}r\ INIT CLASS /J~~1 / -016/ GEOL AREA <111"'1 UNIT# /// ~ d ON/OFF SHORE It,;) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 'Y N 2. Lease number appropriate. . . " . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 4jy N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ÞA--" ,~-'/ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ~Z- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . ; Y N 12. Permit can be issued without administrative approval.. . . . . }(~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#~ Y. /'-1./1. (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. N I ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N I (0 If )( ,011 @ J 0 .ft, 16. Surface casing protects all known USDWs. . . . . . . . . . . ,N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y <6V 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N ~~: ~~:~~a~:~~~~~;~~~~:~~~~ ~¡t:.' ~ ~ :~r~~fr~~t.. : :: : : : ~ ~ rJ~ bo~~ 't£<';. 22. If a re-drill, has a 10-403 for abandonment been approved. . . /'.lIlT- 23. Adequate well bore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N 25. Drilling fluid program schematic & equip list adequate. . . . . N ì1A.lU'i- AI{ \ø..J ,{., ~ P"fIC¡ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ; 27. BOPE press rating appropriate; test to S"' () 0 0 psig. N Ÿl1. ~ P 7P¡ 7/ p~ .. I I 28. Choke manifold complies w/API RP--53 (May 84). . . . . . . . N JIÞ / P / Ji t . / ' 11 /' WC.7It-CZ ..¡. O~ 29. Work will occur without operation shutdown. ... . ...... &tN ~ (--",A:j"'AJI1(/II~ç" ¡tI~~. r-..tþ"l9". /'@~'~I~~ ;Ÿ.l' 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . Y ~ / A ¿ I . ./" ~; c:. ~ N .11 I ) 31. Mechanical condition of wells within AOR verified. . . . . . . . ¡J11t.:J.-.N. ~~ - ~ - -~ ~ ..L-/~./~ "Q. (( ~~..-v/J'tI~.I 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Q N ? /~~... - ~r- 33. Data presented on potential overpressure zones. . . . . . .. Æ 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . NN 1'~1 4. 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . Y N .1£ / ¿. ~-~,,-j. A..J...,f ~~ ¡f,¡".,. jJA er -.t'/'¿ /,.),j.l :! ~ t~L - #t- 4 .,(/ ~~fftv r'-/-//.,AJ-I /1 / C/~""1. / APPR DATE (Service Well Only) GEOLOGY APPR DATE IÞ'~ "~2- (Explorato~ ó~1y) GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH JfY UIC ENGINEER JBR COMMISSIONER: COT DTS Oq/ly/o<- Comments/lnstructions: Rev: 07/12/02 SFD- WGA ~k- MJW G :\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. . To inlprove the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special. effort has been made to chronologically organize this category of information. ) Sperry-Sun DrillLng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 12 10:57:14 2003 Reel Header Service name............ .LISTPE Date.....................03/02/12 Or i gi n. . . . . . . . . . . . . . . . . . . ST S Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Tape Header Service name.............LISTPE Date.....................03/02/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: }\PI NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ) Library. Scientific Technical Services Writing Library. Scientific Technical Services MWD RUN 1 MW2217400000 P. SMITH D. BURLEY MSL 0) OPEN HOLE BIT SIZE (IN) 12.250 8.500 8.500 3S-07 501032043000 ConocoPhillips Sperry Sun ll-FEB-03 MWD RUN 2 MW2217400000 P. SMITH D. BURLEY 18 12N 08E 2487 935 .00 28.67 27.70 CASING SIZE (IN) 16.000 9.625 9.625 MWD RUN 3 MW2217400000 P. SMITH D. BURLEY DRILLERS DEPTH (FT) 108.0 2769.0 2769.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. ~wD RUNS 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) ao~~/~7 //50D ) ) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) , AND STABILIZED LITHO-DENSITY (SLD). 4. MWD RUN 2 IS DIRECTIONAL WITH DGR, AND EWR4. 5. MWD RUNS 3 IS DIRECTIONAL WITH DGR, EWR4, CNP, AND SLD. 6. MWD DATA ARE CONSIDERED PDC PER GKPA GEOSCIENCE GROUP. RESISTIVITY, NEUTRON, AND DENSITY DATA HAVE BEEN DEPTH-CORRECTED FOR DRILLPIPE COMPRESSION TO THE MWD GR CURVE FOR RUNS 2 AND 3. CNP DATA ARE CALCULATED USING THE SLD 'CALIPER' FOR HOLE SIZE INDICATION. 7. MWD RUNS 1-3 REPRESENT WELL 3S-07 API#:50-103-20430-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6633'MD I 6090'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPliCING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNl\ = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: SLD CALIPER DATA (BIT SIZES 12.25", 8.5") MUD WEIGHT: 9.4, 10.8 PPG MUD SALINITY: 1200, 300 PPM CHLORIDES FORMATION WATER SALINITY: 15000, 25000 PPM CHLORIDES FLUID DENSITY: 1.0 GIce MATRIX DENSITY: 2.65 Glec LITHOLOGY: SANDSTONE $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/02/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record ) FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FCNT NCNT NPHI PEF DRHO RHOB RPD RPM FET RPX RPS GR $ 1 ) clipped curves; all bit runs merged. .5000 START DEPTH 108.5 132.5 132.5 132.5 142.5 142.5 142.5 171. 5 171. 5 171.5 171.5 171.5 181. 0 STOP DEPTH 6633.0 6543.5 6543.5 6543.5 6550.5 6550.5 6550.5 6587.5 6587.5 6587.5 6587.5 6587.5 6594.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 108.5 2 2775.5 3 6278.0 # REMARKS: MERGED MAIN PASS. $ MERGE BASE 2775.5 6278.0 6633.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Ty~e.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-ty~e...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX 1'1WD OHJv1M 4 1 68 12 4 RPS MWD OHJv1M 4 1 68 16 5 RPM MWD om-1M 4 1 68 20 6 RPD MWD OHJv1M 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 6633 3370.75 13050 108.5 6633 ROP MWD FT/H 0 419.24 146.687 13050 108.5 6633 GR MWD API 24.41 420.98 97.884 12827 181 6594 RPX MWD OHMM 0.39 1332.76 11.3911 12758 171. 5 6587.5 RPS MWD OHMM 0.45 1817.8 20.0624 12758 RPM MWD OHMM 0.45 2000 34.8387 12758 RPD MWD OHMM 0.5 2000 44.1335 12758 FET MWD HOUR 0.1602 100.646 1.34157 12758 NPHI MWD PU-S 5.69 79.41 46.2856 5803 FCNT MWD CNTS 453 850 621. 242 5803 NCNT MWD CNTS 2047 3580 2389.84 5803 RHOB MVvD G/CM 1.116 3.021 2.00754 5801 DRHO MWD G/CM -0.217 0.616 0.032362 5801 PEF MWD B/E 1.23 17.29 3.63794 5801 First Reading For Entire File..........l08.5 Last Reading For Entire File...........6633 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP NCNT FCNT NPHI PEF DRHO RHOB RPD RPM RPX FET RPS GR $ 2 ) 171.5 171.5 171.5 171.5 132.5 132.5 132.5 142.5 142.5 142.5 6587.5 6587.5 6587.5 6587.5 6543.5 6543.5 6543.5 6550.5 6550.5 6550.5 header data for each bit run in separate files. 1 .5000 START DEPTH 108.5 132.5 132.5 132.5 142.0 142.0 142.0 173.0 173.0 173.0 173.0 173.0 181.0 # 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 HINIMUM ANGLE: STOP DEPTH 2775.5 2679.0 2679.0 2679.0 2689.5 2689.5 2689.5 2721. 0 2721.0 2721.0 2721.0 2721.0 2728.5 12-NOV-02 Insite 0.43 Memory 2776.0 .7 ) MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (NT): MUD AT NAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: NUD CAKE AT NT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value.... ................. .-999.25 Depth Units....................... Datum Specification Block sub-type...O ) 30.0 TOOL NUMBER 132477 63122 68676 121169 12.250 108.0 Water 9.40 120.0 9.6 500 6.0 Based 5.200 5.010 6.500 4.500 67.0 69.8 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWDOI0 API 4 1 68 8 3 RPX MWDOI0 OHMM 4 1 68 12 4 RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 Om'1M 4 1 68 20 6 RPD MWDOI0 OHMM 4 1 68 24 7 FET M'V'iJDOI0 HOUR 4 1 68 28 8 NPHI MWDOI0 PU-S 4 1 68 32 9 FCNT MWDOI0 CNTS 4 1 68 36 10 NCNT MWDOI0 CNTS 4 1 68 40 11 RHOB MWDOI0 G/CM 4 1 68 44 12 DRHO MWDOIO G/CM 4 1 68 48 13 PEF MWDOI0 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 2775.5 1442 5335 108.5 2775.5 ROP MWDOI0 FT/H 0 273.04 112.973 5335 108.5 277 5.5 GR MWD010 API 24.41 125.33 70.0548 5096 181 2728.5 RPX MWD010 Om.1M 1. 54 173.27 21. 364 5097 173 2721 RPS MWD010 OHMM 1. 57 1817.8 43.3446 5097 173 2721 ) ') RPM MWDOIO OHMM 1.67 2000 72.4732 5097 173 2721 RPD MWDOIO OHMM 1. 71 2000 94.1922 5097 173 2721 FET MWD010 HOUR 0.2645 7.2025 1.22335 5097 173 2721 NPHI MWD010 PU-S 5.69 75.62 45..5317 5094 132.5 2679 FCNT MWD010 CNTS 496 850 628.484 5094 132.5 2679 NCNT MWD010 CNTS 2047 3274 2379.62 5094 132.5 2679 RHOB MWD010 G/CM 1.116 3.021 1. 94926 5096 142 2689.5 DRHO MWD010 G/CM -0.217 0.616 0.0285257 5096 142 2689.5 PEF MWD010 B/E 1.23 7.23 3.03408 5096 142 2689.5 First Reading For Entire File..........108.5 Last Reading For Entire File...........2775.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO3 Physical EOF File Header Service name............... STSLIB.003 Service SubLevel Name... Version Number...........1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 Fi 1 e Tjrpe................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2729.0 2757.5 2757.5 2757.5 2757.5 2757.5 2776.5 STOP DEPTH 6239.0 6231.5 6231.5 6231.5 6231.5 6231. 5 6278.0 # 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 AN"GLE: MAXIMUM ANGLE: 18-NOV-02 Insite 6.02 Memory 6278.0 13.3 29.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR DiJR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 164580 103792 ) # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH CFT): 8.500 2769.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMMì AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.40 47.0 9.2 300 3.0 3.600 2.308 5.000 3.000 70.0 113.0 70.0 70.0 # NEUTRON TOOL MATRIX: 1vlATRIX DENSITY: HOLE CORRECTION (IN ì : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value...................... -999.25 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FTIH 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MírifD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2729 6278 4503.5 7099 2729 6278 ROP MWD020 FT/H 0 419.24 179.543 7004 2776.5 6278 GR MWD020 API 46.52 420.98 11 7 . 079 7021 2729 6239 RPX MWD020 OHMM 0.39 1332.76 3.84307 6949 2757.5 6231. 5 RPS MWD020 OHMM 0.45 1477.26 4.02948 6949 2757.5 6231.5 RPM MWD020 OHMM 0.45 2000 9.86484 6949 2757.5 6231.5 RPD MWD020 OHMM 0.5 2000 10.0856 6949 2757.5 6231.5 FET MWD020 HOUR 0.1602 100.646 1.11216 6949 2757.5 6231.5 First Reading For Entire Fi1e..........2729 Last Reading For Entire Fi1e...........6278 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 ) Fil e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number.... . . . . . . .1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO RPM RPX RPS RPD FET GR ROP $ 4 ') header data for each bit run in separate files. 3 .5000 START DEPTH 6189.5 6189.5 6189.5 6198.5 6198.5 6198.5 6232.0 6232.0 6232.0 6232.0 6232.0 6239.5 6278.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ # STOP DEPTH 6543.5 6543.5 6543.5 6550.5 6550.5 6550.5 6587.5 6587.5 6587.5 6587.5 6587.5 6594.0 6633.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS HUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 19-NOV-02 Insite 6.02 Memory 6633.0 8.8 11.9 TOOL NUMBER 164580 103792 119007 67985 8.500 2769.0 Water 12.00 53.0 8.7 200 2.9 Based ) ) MUD AT .MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 2.800 1.689 2.300 3.100 72.0 123.8 72.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999.25 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1. 68 0 1 ROP MWD030 FT/H 4 1. 68 4 2 GR M'iiifD 0 3 0 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1. 68 16 5 RPM MWD030 OHMM 4 1. 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1. 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6189.5 6633 6411. 25 888 6189.5 6633 ROP MWD030 FT/H 8.98 173.47 76.0336 710 6278.5 6633 GR MWD030 API 41.02 233.56 107.809 710 6239.5 6594 RPX MWD030 OHMM 1.02 990.47 13.6651 712 6232 6587.5 RPS MWD030 OHMM 1 387.83 9.87018 712 6232 6587.5 RPM MWD030 OHMM 1.01 217.01 9.16539 712 6232 6587.5 RPD MWD030 OHMM 1. 01 861. 82 18.0795 712 6232 6587.5 FET MWD030 HOUR 0.517 2 27.8485 4.42692 712 6232 6587.5 NPHI MWD030 PU-S 19.82 79.41 51. 7026 709 6189.5 6543.5 FCNT MWD030 CNTS 453 811 569.203 709 6189.5 6543.5 NCNT MWD030 CNTS 2080 3580 2463.28 709 6189.5 6543.5 RHOB MWD030 G/CM 1. 963 2.916 2.4288 705 6198.5 6550.5 DRHO MWD030 G/CH -0.088 0.264 0.0600922 705 6198.5 6550.5 PEF MWD030 B/E 3.7 17.29 8.00282 705 6198.5 6550.5 First Reading For Entire File..........6189.5 Last Reading For Entire File...... .....6633 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/02/12 Maximum Physical Record..65535 File Type................ LO .. Next File Name...........STSLIB.OO5 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/02/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Reel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/ 02/12 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File ) Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services