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Home My WebLink About204-101 STATE OF ALASKA ALA ,OIL AND GAS CONSERVATION COME JION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell ("- Rug Perforations r Perforate rOther Cement Squeeze Alter Casing Pull Tubing r Stimulate Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-101 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r50-029-20849-01 7.Property Designation(Lease Number). 8.Well Name and Number: ADL 25640 KRU 1 G-08A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7960 feet Plugs(measured) none true vertical 6947 feet Junk(measured) none Effective Depth measured 7825 feet Packer(measured) 4603 true vertical 6829 feet (true vertical) 4421 Casing Length Size MD ND Burst Collapse CONDUCTOR 54 16 80 80 SURFACE 2206 10 75 2232 2232 PRODUCTION 4744 7 4770 4538 RECEIVED LINER A 3366 3.5 7957 6945 JAN 1 3 2015 Perforation depth: Measured depth 7290-7292, 7306-7310, 7326-7328',7728-7736 AOG V V True Vertical Depth: 6388-6390,6401-6404,6416-6418,6745-6752 l� iCA��E h f L r Tubing(size,grade,MD,and TVD) 3.5, L-80,4642 MD,4448 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER HRD ZXP PACKER @ 4603 MD and 4421 TVD NIPPLE-CAMCO DS LANDING NIPPLE @ 489 MD and 489 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 6200-7345 Treatment descriptions including volumes used and final pressure: 10 bbls of 15.8ppg Class G 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ E SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt: 314-509 Contact Jason Burke( 265-6097 Email Jason.Burke • conoco•hilli•s. : ' � Printed Name Jason Burke Title CTD Engineer r i Signature Phone:265-6097 ��. /—G q$7 VT'- 1/ f//, RBDMS JAN 1 3 2015 Form 10-404 Revised 10/2012 A //294 lfi Submit Original Only 1G-08A WELL WORK SUMMARY • DATE SUMMARY 8/7/2014 DRIFTED FOR SPINNER; TAGGED @ 7746'SLM. LOGGED MEMORY SPINNER SURVEY, MAKING 30 MIN STOPS @ 7309', 7538', &7779' RKB. RECOVERED DATA. COMPLETE. 8/16/2014 TAGGED @ 7754' SLM, EST. 33' RATHOLE. MEASURED BHP @ 7500' RKB: 2292 PSI. COMPLETE. 9/20/2014 SET 2.81" CA-2 PLUG W/DUAL SPARTEK GAUGES @ 4565' RKB; SET BAITED GUTTED JD ON PLUG; PULLED GLV'S &SET DV'S @ 3838'AND 2651' RKB; PULLED OV @ 4516' RKB ( READY FOR CIRC OUT). IN PROGRESS. 9/21/2014 CIRC OUT W/87 BBLS INHIBITED SEA WATER& 80 BBLS DIESEL (U-TUBE FREEZE PROTECT). SET 1.5" DV @ 4516' RKB. IN PROGRESS (LRS ON LOCATION DOING MIT'S) 9/22/2014 PULLED 2,81" CA-2 PLUG @ 4565' RKB. IN PROGRESS/READY FOR E-LINE. 9/24/2014 SET 2.81" CAT SV @ 4566' RKB. MITT TO 2500 PSI ( PASS) MITIA TO 2500 PSI ( PASS) PULLED CAT SV. IN PROGRESS. READY FOR E-LINE. 10/2/2014 E-Line Unit#3030 set a Composite Brdige Plug @ 7,349.1' MD and get a SBHP of the C-Sands(2,302 10/3/2014 INJECTIVITY TEST. JOB COMPLETE. 10/9/2014 Performed injectivity test per procedure, pumpingl0 bbls @ .25 bpm, 1550 psi. Attempted 2nd rate of 0.5 bpm but reached max pressure of 1850 psi in 1.4 bbls. Dropped rate to 0.39 for 4.4 bbls, 1850 psi, then 0.32 bpm, pressure/rate stabilizing there for remaining 4.2 bbls of the test. 10/16/2014 MIRU CTU #5, PERFORM WEEKLY BOP TEST, JOB IN PROGRESS. 10/17/2014 CREW TRIES TO RIG UP ON THE WELL, WELLHEAD PLATFORM IS VERY UNSTABLE, NO MANLIFT ON LOCATION, CALL DOYON 141 TO BORROW THEIR MANLIFT, SHUT DOWN THE JOB, CALL SAFETY TO INSPECT THE WELLHEAD PLATFORM, HAVE AES CREW EITHER STABILIZE PLATFORM OR TAKE IT DOWN AND PUT UP SCAFFOLDING, HAVE CEMENT CREW STAGE EQUIPMENT UNTIL TOMORROW, JOB IN PROGRESS. 10/18/2014 LAY IN 10 BBLS OF 15.8 PPG CLASS G CEMENT FROM 7345' RKB TO 6200' RKB WHILE MAINTAINING 1:1 RETURNS, HOLD SQUEEZE PRESSURE OF 1100 PSI FOR 30 MINUTES, CONTAMINATE CEMENT TO 7250' RKB, CHASE OOH AT 80%, WELL LEFT F/P WITH DIESEL TO 7250' RKB, ALLOW 48 HRS CURE TIME BEFORE RETURNING TO MILL, JOB IN PROGRESS 10/23/2014 RIH START MILLING CMT @ 7234' CTMD, MILLED AT .3-.5 FPM DOWN TO 7310' CTMD 7330' RKB, SHUT IN DO A PT ON CMT. 1411 PSI STARTING, ENDING PSI 1378, PROCEEDED TO MILL OUT REST OF CMT AND CBP, PUSH CBP TO 7650' RKB POOH FREEZE PROTECT TO 2500' DIESEL. *****WELL READY FOR SLICK LINE DRIFT**** 10/24/2014 DRIFT W/BAKER DMY WHIPSTOCK&TAG @ 7756' SLM. READY FOR E-LINE. 10/26/2014 SET BAKER 3.5" MONOBORE XL WHIPSTOCK. TOP OF WHIPSTOCK AT 7540' RKB. SET 40.3 DEG ROHS. CCL TO TOP OF WHIPSTOCK= 18.7'. CCL STOP DEPTH 7521.3'. TWO PIP TAGS INSTALLED IN WHIPSTOCK AT 7546' RKB. MEASURED SBHP OF 2651 PSI AT 7700' RKB, 2612 PSI AT 7600' RKB. *JOB COMPLETE* 10/27/2014 (PRE-CTD): TREE VALVE TEST SV,SSV,MV ALL PASSED POSITIVE TESTS 10/28/2014 (PRE CTD): TREE VALVE DDT. MV(PASSED), SSV(PASSED), SV(PASSED). f . KUP PROD • 1G-08A ConocoPhillips o Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UNA Field Name Wellbore Status ncl(°) MD(ftKB) Act atm(ftKB) ,-,......_4,' airs 500292084901 KUPARUK RIVER UNIT PROD 46.90 4754.00 7,960.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-08A,10/27/20141049.17 AM SSSV:NIPPLE 35 12/16/2013 Last WO: 7/7/2004 33.49 12/24/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...................................................... Last Tag:SLM 7,756.0 10/24/2014 Rev Reason:TAG,SET WHIPSTOCK hipshkf 10/28/2014 HANGER;25.3 IL'4j Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread Nib CONDUCTOR 16 15.063 26.0 80.0 80.0 62.50 H-40 WELDED Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I SURFACE 103/4 9.797 26.0 2,232.0 2,231.9 45.50 K-55 BTC CONDUCTOR;26.0430.0 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread PRODUCTION Post SIT 7, 6.276 26.0 4,770.0 4,537.2 26.00 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth((tKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW 7 6.156 4,755.0 4,767.0 4,535.2 26.00 L-80 SLHT Casing Description OD(in) 'ID(in) Top((KB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;a39.2 i LINER A 31/2 2.992 4,590.9 7,957.0 6,944.4 9.30 L-80 SLHT Liner Details SURFACE;26.0-2,232.0 • • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I") Item Des Com (in) 4,590.9 4,411.8 43.98 TIEBACK BAKER SEAL BORE TIE BACK EXTENSION 5.250 4,602.6 4,420.2 44.22 PACKER BAKER HRD ZXP PACKER 4.340 GAS LIFT:2.651.8 4,610.7 4,426.0 44.36 NIPPLE BAKER PACKOFF SEAL NIPPLE 4.260 4,613.5 4,428.0 44.41 HANGER BAKER FLEX-LOCK HANGER 4.360 4,622.6 4,434.5' 44.56 SBE BAKER CASING SEAL BORE EXTENSION 4.030 7,505.8 6,559.0 35.87 NIPPLE SEAL BORE NIPPLE***NO LOCKING PROFILE IN 2.750 I R•••8)7/2006 GAS LIFT 3.83809 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..t Set Depth(TVD)(...Wt ilb/ft) Grade Top Connection ___ TUBING 31/2 2.992 25.3 4,642.2 4448.4 9.30 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(^) Item Des Com (in) GAS UFT 4.516.9 25.3 25.3 0.00 HANGER MCENVOY GEN 3 TUBING HANGER 3.500 489.2 489.2 0.09 NIPPLE CAMCO DS LANDING NIPPLE 2.875 _ 4,565.8 4,393.7 43.42'NIPPLE CAMCO DS LANDING NIPPLE 2.812 4,604.3 4,421.4 44.25 LOCATOR LOCATOR SPACER 3.000 NIPPLE;4,565.6 I 4,605.5 4,422.3 44.27 SEAL ASSY SEAL ASSEMBLY 80-40 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) • 7,540.0 6,586.8 35.04 WHIPSTOCK 3.5"MONOBORE XL SET AT 40.3 DEG RIGHT OF 10/26/2014 HIGH SIDE.(LENGTH=10.5') U • 7.650.0 6,678.4 32.16 FISH MILLED CBP PUSHED TO 7650' 10/23/2014 I! LOCATOR;4,604 3 Perforations&Slots Shot ]'mat 16 Dens •tTop(TVD) Btm(ND) (shots/f •l■'. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,290.0 7,292.0 6,387.9 6,389.4 C-4,1G-08A 8/21/2004 6.0 (PERF 2.5"HSD HJ 2506 1Ink .;I 7,306.0 7,310.0 6,400.4 6,403.6 C-4,1G-08A 8/21/2004 6.0 IPERF 2.5"HSD HJ 2506 - SEAL ASSY;4,605.5 III 7,326.0 7,328.0 6,416.2 6,417.7 C-4,1G-08A 8/21/2004 6.0 IPERF 2.5"HSD HJ 2506 7,728.0 7,736.0 6,744.9 6,751.8 A-3,1G-08A 7/232004 6.0 IPERF 2.5"HSD HJ 2506 I Stimulations&Treatments Min Top Max Btm I Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (MB) Type Date Com 7,728.0 7,736.0 6,744.9 6,751.8 FRAC 8/19/2004 A-SAND FRAC-172,650#on 10 ppa 7,290.0 7,328.0 6,387.9 6,417.7 FRAC 8/22/2004 C-SAND FRAC-51,000#16/20 CERAMIC PROPPANT WINDOW;4,755.0<.7670 Cement Squeezes PRODUCTION Post S/r; Top(ND) Btm(ND) 26.0-4,770.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com _ 7,250.0 7,349.1 6,356.6 6,434.3 -10/18/201 Lay in 10 BBLS of 15.8 PPG Class G Cement. (PERF;7,290.0-7,292.0 4 Mandrel Inserts St IPERF;7.306.0-7.310.0 ati FRAC;7,290.0 on N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 2,651.8 2,651.6 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/20/2014 7:00 (PERF;7,326.0-7,326.0 4 2 3,838.0 3,809.9 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 920/2014 7:30 3 4,516.9 4,357.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/21/2014 10:00 Ir Notes:General&Safety 1L End Date Annotation 7/4/2008 NOTE:SIDETRACKED WELL I 9/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 WHIPSTOCK;7,540,0 PI FISH;7,650.0 FRAC;7,728.0 I I (PERF;7,728.0-7,736.0 • LINER A;4,590.9-7,957.0 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (;)04- 1 0 L Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 R,CAN ~ Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: D Other:: MP ,~IIIIIIIIIIIIIIIII M ~ NOTES: BY: ~ Isl Project Proofing BY: c- Maria -;:> J S = TOTAL PAGES 7S ~ (Count does not include cove~ Isl Scanning Preparation BY: Date: Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: 7 (P (Count does include cover sheet) Page Count Matches Number in Scanning preyaration: V YES NO BY: ~ Date: 'õ / d-CI / ó 0 Isl VV\ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Isl 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned III "lilt 11I111111/ BY: Maria Date: Isl Comments about this file: Quality Checked 11111111I1111111111 10/6/2005 Well History File Cover Page.doc • • ~~ ~ _~: ~ '• ~ 03/01 /2008 DO NOT PLACE ANY NEW 11~ATERIAL UNDER THIS PAGE F:\LaserFiche\CbrPgs_Inserts\Microfilm Marker.doc 06/14/07 Schlumberger n N 2 1 2007 .;.'J'''...·k!..'...NNEv JU NO. 4300 :iiV~ (I't~ "-J~"Ä f! \~ff ,''IY'. i ,j \'! Ih= ..... ;)04--1 DI Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth .~~ 0 20m Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description BL Color CD Date 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1 A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . .l '1 ~~~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2041010 Well Name/No. KUPARUK RIV UNIT 1G-08A Operator CONOCOPHILLlPS ALASKA INC JPtt-J.. ~ ..,J-. ~'-/ API No. 50-029-20849-01-00 MD 7960 ,...., TVD 6948 /" Completion Date 7/23/2004__ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Name Interval Start Stop Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval . Log Log Run OH/ Scale Media No Start Stop CH Received Comments 4755 7960 7/20/2004 MWD ----, 5 Blu 2098 7766 Case 1 0/17/2005 Production Profile PresslT emp/Spin/GRlCCL 1 Oct 2005 0 0 Open 8/26/2004 LDWG, GR, GRAPHIC IMAGES 2 Blu 4797 7906 Open 8/26/2004 LDWG, GR, GRAPHIC IMAGES DSN 12621, MWD 25 Blu 4794 7906 Open 8/26/2004 MWD, GR, DSN 12621 25 Blu 4794 7906 Open 8/26/2004 MWD, GR, DSN 12621 25 Blu 4794 7906 Open 8/26/2004 MWD, GR, DSN 12621 25 Blu 4794 7960 Open 8/26/2004 MWD, GR,RPD,RPM,ROP,FET,R . EF, DRHO, RHOB,RPX,RPS DSN 12621 5 Blu 4450 7822 Case 8/9/2004 PERFORATION RECORD,W/SBHP & JEWELRY LOG Sample Set Sent Received Number Comments DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens/Neutron, eeL, USIT Well Log Information: Log/ Data Type IRPt Electr Digital Dataset Med/Frmt Number Name Directional Survey Production C Tf 12621 Density Density c6g Ind uction/Resistivity Density Induction/Resistivity LIS Verification Perforation Well Cores/Samples Information: Permit to Drill 2041010 MD 7960 TVD 6948 ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Well Name/No. KUPARUK RIV UNIT 1G-08A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20849-01-00 UIC N Comments: Compliance Reviewed By: Completion Date 7/23/2004 Completion Status 1-01L Current Status 1-01L Daily History Received? y:J2- ~/N Formation Tops ~ Date: ~>~ ~fa . . 10107/05 Schlumbepgep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD . 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1 G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V-08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10102/05 1 1E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: 1L_ fDl{ DATE: /7 (1).1- Jvtt r " . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. J.OV/- {fJ ( F,j¿ Re: FW: Kuparuk Well testing requiremement-IG-07 & IG-08 e e Mark, Further to Jack's reply. According to our records, IG-08 was plugged back for sidetrack in late June 2004. The correct well name reference should be 1 G-08A which was completed July 24, 2004. Tom Maunder, PE AOGCC John Hartz wrote, On 8/23/2005 11 :03 AM: Mark, Thanks for the reminder. Your request appears to be an operational necessity for a short period until the parts are available and repair work can be done on the divert valve. Your proposal to produce 1G- 07 and 1G- 08 until divert valve repairs are completed is acceptable. Notify me if the repairs will be significantly delayed beyond October 1. Thank you for the notification. Jack Hartz, P.E. Sf. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 Kovar, Mark wrote: I don't know if you received my email below so just following up on it. Thanks. Mark Kovar Kuparuk Drillsite Engineer ConocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 Iof2 8/23/2005 11 :24 AM Re: FW: Kuparuk Well testing reQuirememen¡-07 & lG-08 e -----Original Message----- From: Kovar, Mark Sent: Wednesday, August 17,20057:19 AM To: 'jack hartz@admin.state.ak.us' Cc: CPFl Prod Engr Subject: Kuparuk Well testing requiremement-1G-D7 & 1G-D8 CPAI requests a waiver from the 3D-day well testing requirement for wells IG-07 and IG-08. These wells share a production flowline and are twin tested. The divert valve to the test separator is not operational and requires replacement. We are waiting on parts and expect to have the work complete by or before October I, 2005 at which time we will commence with twin well testing. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Mark Kovar Kuparuk Drillsite Engineer GonocoPhillips Alaska, Inc. 700 G Street, A TO 1280 Anchorage, AK 99501 Office: (907) 265-6097 2of2 8/23/2005 11 :24 AM e ConocriP'hillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 September 2, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1G-08A (APD #204-1(1) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 G-08A. If you have any questions regarding this matter, please contact me at 265-6830 or Kelly McLure at 265-6059. Sincerely, ....~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad RECEIVED SEP -S1 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended U WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPl D No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., ,,3 p¡.,ø·' 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: JuIY.7,2004 204--1011 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 June 24, 2004 50-029-20849-01 4a. location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1323' FSL, 590' FWL, Sec. 29, T12N, R10E, UM July 2,2004 1 G-08A At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 2493' FNL, 1324' FEL, Sec. 30, T12N, R1OE, UM 29' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Kuparuk River Oil Pool 2306' FNL, 1644' FEL, Sec. 30, T12N, R10E, UM 7825' MD 16829' TVD 4b. location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 540361 y- 5981970 Zone- 4 . 7960' MD / 6948' TVD - ADL 25640 TPI: x- 538434 y- 5983425 Zone-4 11. Depth where SSSV set: 17. land Use Permit: Total Depth: x- 538113 - y- 5983610 Zone-4 Landing Nipple @ 489' ALK 2571 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1500' MD 21. logs Run: """F /4..1 .AJ.a1A) "75>"" nJZ> ~j) GR/Res/Dens/Neutron, CCL, US IT 'fS2.7''7"t'þ If. lð·c>Y 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE CEMENTING RECORD PUllED WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE 16" 62.5# H-40 29' 80' 29' 80' 24" 265 sx AS II 10.75" 45.5# K-55 29' 2232' 29' 2232' 13.5" 1300 sx AS III, 250 sx AS I 7" 26# K-55 29' 4755' 29' 4527' 8.75" 1140 sx Class G, 250 sx AS I 3.5" 9.3# L-80 4591' 7957' 4412' 6945' 7" 398 sx LiteCrete cement retainer @ 4772' cement plug from 6163'-6413' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 4642' 4603' 7728' - 7736' MD 6745' - 6752' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE. ETC. 7290' - 7292' MD 6388' - 6390' rvD 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7306' - 7310' MD 6401' - 6404' TVD 6 spf 4772 198 sx Class G 7326' - 7328' MD 6417' - 6418' TVD 6 spf 6163' - 6413' 48 sx Class G 7728'-7736' 173,600# proppant 7290'-7328' 51000# Proppant 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) August 28, 2004 Flowing Date of Test Hours Tested Production for Oll-BBl GAS-MCF W A TER-BBl CHOKE SIZE GAS-OIL RATIO 8/30/2004 17.5 hours Test Period --> 1155 1216 103 176 bean 435 Flow Tubing Casing Pressure Calculated Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (corr) press. 162 psi 933 24-Hour Rate -> 1476 1759 140 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). RECEIVED Submit core chips; if none, state "none". ~.....'*""-...-... ¡ COMPLETiON I SEP - ~ Z004 IJ~ NONE t.,,_:~D . AI.aka Oil & Gas Cons. Commission RfJ)MS RF SEP 2 1 Anchorage ,..... ..... ......l 2004 G /; Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL G 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 G-08A Top Kuparuk D C4 sand Base Kuparuk 7201' 7284' 7816' 6319' 6383' 6821' N/A RECEIVED SEP - ~ 2004 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelly McLure @ 265-6059 Signature Title: Phone KUDaruk Drillina Team Leader ,'r-6"83ò Date ~ (~(o.., Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n 1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 6/16/2004 06:00 - 09:00 3.00 MOVE DMOB DEMOB Held PJSM on RD and moving rig, prepared rig and moved rig off 2N-311 and cleaned around well, rig off well at 08:30 09:00 - 00:00 15.00 MOVE MOVE DEMOB Began moving rig from 2N pad to 1 G pad, have moved rig approx 18 of 25 miles 6/17/2004 00:00 - 05:00 5.00 MOVE MOB MOVE Fin moving rig from 2N pad to 1 G pad, rig moved a total of 25 miles 05:00 - 07:30 2.50 MOVE RURD MOVE Level ground around cellar, layout herculite and berm around cellar ACCEPTED RIG @ 06:30 hrs 6/17/04 07:30 - 08:30 1.00 MOVE POSN MOVE Spotted rig over well and leveled same 08:30 - 11 :30 3.00 DRILL OTHR ABANDN Loaded 8.8 ppg brine into pits and began loading pipe shed with 4" DP 11 :30 - 12:30 1.00 WELCT OTHR ABANDN RU wells group lubricator and pulled BPV, checked well presures, Tbg -0-, IA -0-, OA 50 psi and bled down to -0- 12:30 - 14:30 2.00 DRILL PULD ABANDN Cont to load pipe shed with 4" DP and flushed out surface lines with water 14:30 - 20:30 6.00 DRILL PULD ABANDN PU and stood back 40 stands of 4" DP, RU open top kill tank for well retu rns NOTE: While racking back DP, hydraulic fitting on spinners failed causing hyd oil to spray into floorhands eye's, flushed eye's at rig then sent to Prudhoe Bay Industrial Clinic to be checked out, was looked at and his eye checked ok and returned to work. 20:30 - 22:45 2.25 DRILL CIRC ABANDN Pressure tested lines to open top tank, checked well pressures, tbg & IA -0- psi, circ new 8.8 ppg brine around well at 4 bpm at 410 psi, blew down lines 22:45 - 00:00 1.25 WELCT OTHR ABANDN Installed BPV and began ND Tree NOTE: Held pre-planning mtg with service company personnel followed with pre-spud mtg with rig crews 6/18/2004 00:00 - 00:30 0.50 WELCT NUND ABANDN Fin ND 11" 3M tree 00:30 - 03:30 3.00 WELCT EQRP ABANDN Cameron service man inspected LDS on tbg head, of the 12 LDS, 7 were in contact with pack-off, worked all LDS and found 3 that would not move, then ground down the 3 LDS, cleaned flange and hanger and installed H-P blanking plug 03:30 - 08:00 4.50 WELCT NUND ABANDN NU 11" 3M x 11 "5M DSA, spacer spool and 11" 5M BOP stack 08:00 - 12:00 4.00 WELCT BOPE ABANDN RU & tested BOPE, manifold, valves, rams and annular to 250 psi low and 3,000 psi high, tested to 3M due to top flange only being rated to 3M Note: Chuck Scheve W/AOGCC waived witnessing of BOP test 12:00 - 15:00 3.00 WELCT EQRP ABANDN Backed out LDS, LDS were tight, installed blanking plug 15:00 - 18:00 3.00 CMPL TN PULL ABANDN Held PJSM, PU on hanger and 31/2" completion string to 100K and worked same with only 27" of movement and pipe did not come free, ordered out Schlumberger Wireline (SWS) to re-cut tbg LD 3 1/2" landing jt 18:00 - 22:00 4.00 DRILL PULD ABANDN PU and stood back an additional 23 stds of 4" DP while waiting on SWS 22:00 - 23:30 1.50 LOG RURD ABANDN Held PJSM, RU SWS scheaves and pack-off 23:30 - 00:00 0.50 LOG ELOG ABANDN RIH W/CCL and string shot to 3,000', RIH with 1 11/16" eeL and 12' single string, 80 grain string shot, max od of string shot 2 1/8" 6/19/2004 00:00 - 01 :30 1.50 LOG ELOG ABANDN Cont RIH with string shot from 3,000' to 6,520', correlated to completion assembly, PU and ran string shot from 6,465' to 6,477', POOH LD fired string shot 01 :30 - 05:00 3.50 LOG ELOG ABANDN MU 1 11/16" CCL and 2 518" chemical cutter with 4 centralizers and RIH, tool sat down at 5,130', PU on tool and began staging pump rate up to 2 bpm at 110 psi while attempting to work tool down, was able to work down to 5,279' and stopped in btm GLM, POOH 05:00 - 08:00 3.00 LOG ELOG ABANDN Changed out top centralizer from ridgid to bow spring centralizer and re-adjusted btm bow spring and ran back in hole with chemical cutter Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: pumping at 2 bpm and 110 psi, RIH to 6,520' with no problems, PU and cut 31/2" tbg at 6,475' WL, POOH PU on hanger and completion assembly, PU to 75K st wt and tbg was free, PU and LD hanger and pups, RU to LD 3 1/2" tbg and RD SWS POOH with 31/2" completion assembly. recovered 35 clamps, control line, SSSV, 4-GLM's and 208 jts with 1-cut piece of 31/2",9.3#, J-55 BTC tbg, Total recovered 6,486', Found tbg pin ends sand cut with corrosion on many of the collars, NORM tbg and checked ok. Valve pocket of # 2 GLM washed out. RD 3 1/2" handing tools and finished wrapping conn's on tubing and unloaded pipe shed RU rig floor to run 4" DP MU 6 1/8" bit, 7" csg scraper, bit sub, 6.16" Baker string mill and oil jars, began RIH W/BHA #1 PU singles from pipe shed, RIH at 1,300' RIH to 6,400' with BHA #1 to 6,400', Fin PU 48 jts of 4" DP from pipe shed then TIH with bit, scraper and mill from stds in derrick to 6,400', no problems Est circ and washed down to 6,478', began seeing drag at 6,417' and set down with 30K st wt at 6,471', PU and washed down to 6,478' and set down 30K wt, appeared to be pushing fill or tagged top of stub from WL cut at 6,475', st wt up 118K, down wt 90K PU to 6,463' and pumped 2-20 bbls hi vis sweeps and circ hole clean, circ hole at 7.5 bpm at 1,100 psi and reciprocated pipe, had very little increase in cuttings from sweep, circ 4X btms up POOH LD, bit, scraper and mill, found 2- 3 1/2" tbg cmt retainer slips after POOH, 1-on mill and other from scraper MU Baker 7" 26# model K-1 cement retainer and started RIH to 280', stopped to discuss with town about recovering slip segements Decision was made to run gauge ring junk basket before running retainer, POOH & LD retainer Loaded pipe shed with 4" HWDP and 4 3/4" De's and strapped while waiting on HES slickline Held PJSM and RU HES slickline, RIH with 6.06" gauge ring/junk basket, set down at 6,372', PU and cont RIH to 6,450' with no other problems, POOH and recovered 2 additional pieces of slip segements, decision made to run retainer ABANDN MU Baker K-1 cement retainer and RIH, set same at 6,413' with no problems, st wt up 118K, down wt 90K ABANDN While stung out of retainer attempted to pressure test same to 2,000 psi, after pumping 6.5 bbls of 8.8 ppg brine, only had a pressure increase of 1,300 psi, (1.5 bbls calc to press up to 2,000 psi) stung into retainer and attempted to test annulus, at 1 bpm was pumping either past retainer or had a hole in csg at 760 psi, PU out of retainer and pumped 1 bpm with same results, stung back into retainer pumping down DP and est an inj rate of 1/2 bpm at 1,710 psi below retainer with no communication into annulus, determined retainer was holding and had hole in csg 1.00 ABAND OTHR ABANDN Discussed with town about hole in casing, decision was made to spot 250' /10 bbl cement plug on top of retainer to P & A lower zone, then POOH and PU packer to isolate hole in casing. Note: Notified Chuck Scheve with AOGCC of plan forward and he approved setting of 250' plug on retainer without attempting to squeeze 6/19/2004 05:00 - 08:00 3.00 LOG ELOG ABANDN 08:00 - 08:45 0.75 CMPLTN PULD ABANDN 08:45 - 09:15 0.50 CMPL TN RURD ABANDN 09:15 - 21 :00 11.75 CMPLTN PULL ABANDN 21 :00 - 22:00 1.00 CMPL TN RURD ABANDN 22:00 - 22:30 0.50 CMPL TN RURD ABANDN 22:30 - 00:00 1.50 ABAND PULD ABANDN 6/20/2004 00:00 - 02:45 ABANDN 02:45 - 03:15 ABANDN 03:15 - 04:45 ABANDN 04:45 - 08:15 ABANDN 08:15 - 09:30 ABANDN 09:30 - 11 :00 ABANDN 11 :00 - 13:00 ABANDN 13:00 - 16:15 ABANDN 16:15 - 20:45 20:45 - 22:30 22:30 - 23:30 Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: cement below retainer due to low inj rate and pressure Held PJSM with Dowell then began batching up cement 6/21/2004 Dowell pumped 5 bbls FW and tested lines to 3,500 psi, then mixed and pumped 10 bbls (48 sxs) of class "G" cement at 15.8 ppg and 1.16 yield WI add., ave 4 bpm at 500 psi, followed with 1 bbl FW and rig displaced cement to balance plug with 63 bbls of 8.8 ppg brine, ave displacement rate 3.5 bpm at 400 psi, CIP at 00:45 hrs, EST T.O.C. @ 6,136' 00:45 - 01:15 0.50 CEMEN TRIP ABANDN POOH slow 3 stds to 6,130' 01 :15 - 01 :30 0.25 CEMEN CIRC ABANDN Reversed out 1 DP cap and circ out cement contaminated brine, circ till clean 8.8 brine out, circ at 4 bpm at 400 psi 01 :30 - 01 :45 0.25 CEMEN TRIP ABANDN POOH 3 stds to 5,844' 01 :45 - 02:45 1.00 CEMEN CIRC ABANDN Dropped DP wiper dart and circ down to wipe DP, did not see wiper plug shear, cont to circ hole at 7 3/4 bpm at 1,000 psi while reciprocating, no cement on btms up and circ a total of 4X btms up, st wt up 108K, dn 85K 02:45 - 05:30 2.75 CEMEN TRIP ABANDN POOH LD Baker retainer setting tool and recovered DP wiper plug in plug catcher 05:30 - 08:00 2.50 ABAND TRIP ABANDN MU Baker EA 7" retrievamatic test pkr and RIH and set same at 3,500' 08:00 - 16:00 8.00 ABAND DPST ABANDN Pressure tested csg at 3,500' to 3,000 psi for 30 min, good test, RIH to 4,543' and tested csg for 30 min, good test, RIH to 5,490' and attempted to test csg and would not test, cont to POOH testing csg and found hole in csg at 4,845' with good csg at 4,827', tested csg at 4,827' for 30 min and had good test Good csg to 4,827' and hole in csg below 4,845' 16:00 - 19:00 3.00 ABAND TRIP ABANDN POOH with Baker packer from 4,827' and LD same 19:00 - 22:00 3.00 DRILL PULD ABANDN Began loading pipe shed with 31/2" completion tubing and installed valve onto storm packer while waiting on Baker oil tools to return with re-dressed cement retainer and plug catcher 22:00 - 00:00 2.00 CEMEN TRIP ABANDN MU Baker 7" K-1 cast iron cement retainer, RIH at 1,900' 6/22/2004 00:00 - 01 :45 1.75 CEMEN TRIP ABANDN RIH w/ Baker cement retainer to 4,772'. 01 :45 - 02:45 1.00 CEMEN OTHR ABANDN Rig cmt lines, Set retainer @ 4,772', Break circ, Test 7" casing to 2000 psi for 30 min. 02:45 - 05:00 2.25 CEMEN SQEZ ABANDN Held PJSM, Dowell pumped 2 bbls fresh water, Test lines to 3500 psi, Sting into retainer, Est. injection rate of 2 bpm @ 1600 psi, Pull out of retainer, Mixed and pumped 40 bbls (198 sxs) of class "G" cement at 15.8 ppg and 1.16 yield with add., ave 3 bpm at 350 psi, holding 350 psi back pressure on choke, Sting into retainer, Dowell continue to displace cmt below retainer with fresh water, ave 3 bpm displacing cmt, Max pressure 1700 psi, Shut down with cement displaced to retainer, CIP @ 04:00 hrs., Saw increase in pressure after pumping 5.9 bbls cement below retainer, while pumping 3 bpm at ave 70 psi, pressure increase to 1,100 psi, Monitored outer annulas with no change while pumping cement, Pick up out of retainer and reverse out drill pipe at 4 bpm at 630 psi, had approx 2 bbls cmt back at btm's up, circ until clean, Shut down and drop wiper dart, Wipe drill pipe and shear dart wI 1600 psi, had no cmt at btm's up, circ total of 2X btm's up at 7.75 bpm at 1000 psi, Placed total of 38 bbls below retainer @ 4,772'. 05:00 - 06:15 1.25 CEMEN TRIP ABANDN POOH 3-1/3 stands, Pick up Baker storm packer & set same @ 36'. 06:15 - 12:00 5.75 WELCT EQRP ABANDN Change lower pipe rams to 4", Nipple down BOPE, PJSM on changing out tubing spools. 12:00 - 15:00 3.00 WELCT NUND ABANDN Remove old 3000 psi tubing spool and Install new 5000 psi tubing spool, Test same to 3000 psi f/15 min. Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: Nipple up BOPE. Test BOPE to 250 psi low and 5000 psi high against blinds. Witness of test waived by AOGCC inspector Chuck Scheve. 19:00 - 19:15 0.25 WELCT ABANDN Tighten gray-Ioc clamps on choke line. 19:15 - 19:45 0.50 WELCT ABANDN Test BOPE to 250 psi low and 5000 psi high against blinds. 19:45 - 20:30 0.75 WELCT ABANDN Replace gray-Ioc gasket on choke line. 20:30 - 21 :00 0.50 WELCT ABANDN Test BOPE to 250 psi low and 5000 psi high against blinds. 21 :00 - 21 :15 0.25 WELCT ABANDN Tighten studs on DSA (7 1/16" 5M x 11" 5m) 21:15-00:00 2.75 WELCT ABANDN Test BOPE to 250 psi low and 5000 psi high. Testing blinds, choke manifold, floor safety valves, top drive. 6/23/2004 00:00 - 01 :45 ABANDN Continue testing BOPE. Test upper pipe rams, lower pipe rams to 250 psi and 5000 psi. Test annular to 250 psi low and 3000 psi high. Test accumulator. Witness of test waived by AOGCC inspector Chuck Scheve. 01 :45 - 03:00 ABANDN Pull Baker 7", model EA retrieveamatic storm packer @ 36', POOH, UD storm packer. 03:00 - 05:15 2.25 CEMEN TRIP ABANDN POOH LD Baker 7" retainer setting tool and recovered DP wiper plug in plug catcher 05:15 - 06:30 1 .25 LOG RURD ABANDN RU SWS. PJSM, MU USIT tool string (42.5'), consisting of Q head, CAL-Y(CCL), TCC,GR, 2 knuckles, Centralizer, cartridge, SON, transducer. 06:30 - 07:45 1.25 LOG ELOG ABANDN RIH w/ US IT logging tools. Ran in hole to 4738' WLM. Correlated w/ DIUSFL log dated 12/15/1982. Casing 7", 26 #/ft, K-55, BTC. 07:45 -11:15 3.50 LOG ABANDN POOH f/4738' w/ USIT logging tools @ 1500 ftImin. 11 :15 - 12:45 1.50 LOG ABANDN RID Schlumberger WL. 12:45 - 13:00 0.25 WELCT ABANDN Set 61/4" ID wear bushing. Run in two LDS's. 13:00 -14:00 1.00 ABAND ABANDN PU Baker MWD f/ running whipstock, break and install cover over electrical connection on bottom. 14:00 - 15:15 ULD ABANDN PU/MUlRIH w/ (9) 4 3/4" DC's and (21) 4" HWDP. Drift collars to 1.91', Drift HWDP to 2.24". 15:15 - 15:30 ABANDN Circ to clean rust f/ 4 3/4" De's. Circ @ 7.88 bpm w/440 psi. Circ 75 bbls. 15:30 - 16:15 0.75 WINDO ABANDN POOH stand back4 3/4' Drill collars and 4' HWDP in derrick. 16:15 - 16:30 0.25 WINDO ABANDN PJSM on PU/MU Whipstock assembly 16:30 - 19:00 2.50 WINDO ABANDN PU/MU Baker 7" WindowMaster Bottom Trip Whipstock System. 19:00 - 20:45 1.75 WINDO ABANDN RIH w/ 3 stands 4 3/4" De's, 7stands of 4" HWDP. 20:45 - 21 :00 0.25 DRILL ABANDN Surface test MWD tools. 21 :00 - 23:30 2.50 WINDO RIP ABANDN RIH w/ whipstock slow to 4,560'. 23:30 - 00:00 0.50 RIGMNT RSRV ABANDN Service top drive. 6/24/2004 00:00 - 00:15 0.25 WINDO RIP ABANDN RIH w/ whipstock slow from 4560' to 4,655'. 00:15 - 01 :00 0.75 WINDO SETW ABANDN Orient toolface. Set whipstock on retainer @ 4772', top of whipstock @ 4755',21 deg left of high side. 01 :00 - 02:30 ABANDN Displace 8.8 ppg brine f/ hole w/1 0.0 ppg LSND new mud to mill window. 02:30 - 03:15 0.75 CASE ABANDN Test casing to 2000 psi f/30 min. Chart test. Good test, lost 20 psi. 03:15 - 07:30 4.25 WINDO ABANDN Mill Window in 7" 26#/ft, K-55 BTC. Top of window @ 4755' (4527' TVD). Bottom of window @ 4767' (4535' TVD). Drill formation to 4797' (4555' TVD). Dress window. 07:30 - 08:15 IRC ABANDN Pump 20 bbls super sweep pill.. Hole appears clean. Formation cuttings in returns. Blow down top drive. Stand back 1 stand 4' DP. 08:15 - 10:00 1.75 DRILL FIT ABANDN RU to perform FIT/LOT. Check 103/4" x 7" annulus prior to test. 130 psi on annulus. Bleed off 5 gal, pressure decreased to 85 psi. Bring bleed tank over to bleed into. Left annulus open while testing formation. Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 10:00 - 10:30 PROD 10:30 - 12:45 PROD 12:45 - 14:00 1.25 WINDO ULD PROD 14:00 - 15:00 1.00 RIGMNT RSRV PROD 15:00 - 19:00 4.00 DRILL PULD PROD 19:00 - 19:30 0.50 DRILL DEOT PROD 19:30 - 21 :15 1.75 DRILL TRIP PROD 21 :15 - 22:00 0.75 DRILL REAM PROD 22:00 - 00:00 2.00 DRILL DRLG PROD 6/25/2004 2.25 DRILL DRLG PROD 00:00 - 02:15 02:15 - 02:45 0.50 DRILL WIPR PROD 02:45 - 12:00 9.25 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 6/26/2004 00:00 - 09:45 9.75 DRILL DRLG PROD 09:45 - 10:30 0.75 DRILL CIRC PROD 10:30 - 19:15 8.75 DRILL DRLG PROD 19:15 - 20:00 0.75 DRILL WIPR PROD 20:00 - 20:30 0.50 DRILL CIRC PROD 20:30 - 22:15 1.75 DRILL DRLG PROD 22:15 - 22:30 0.25 DRILL OBSV PROD 22:30 - 00:00 1.50 DRILL DRLG PROD 6/27/2004 00:00 - 02:15 2.25 DRILL DRLG PROD Tank level increased f/2" to 5" while testing. Tested formation to 1050 psi w/10 ppg mud. Window top @ 4755' MD (4527' TVD). EMW 14.5 ppg. Rig down test equipment. Pump Dry job, Rig down circ equipment. POOH w/ Baker window mill assembly. Stand back 39 stands 4" DP, stand back 7 stands HWDP, UD single HWDP, UD single 4" DP, UD (9) 4 3/4" DC's. UD Baker Windowmaster mills. The Full guage 6.151" is still 6.151". Slip and cut 1 1/8" Drilling line, cut 48.75'. Check crown-o - matic Make up 4-3/4" x 7" bit & BHA, Orient tools, Program MWD/LWD tools, RIH w/ DC's & HWDP. Surface test MWD tools, Held tripping drill. RIH to 4,633'. Obtain slow pump rates, Orient tool face, Wash & ream f/4,781' to 4,797'. Drill f/4,797' to 4,823', AST= 0.5 hrs ART= 0.1 hrs, WOB 2/8K, RPM 40/60,300 GPM @ 2200 psi, UP 115K, DN 85K, ROT 94K, TO 2400 ftllb Note; Had extreme trouble working stab thru bottom of window @ 4,767', Mild packing off and unable to work pipe up or down at times. Drill f/ 4,823' to 4,856', AST = 0.0 hrs ART = 1.0 hrs, WOB 2/8K, RPM 40/60,300 GPM @ 2200 psi, UP 115K, DN 85K, ROT 94K, TO 2400 ftllb, Pump Hi-vis sweep, Continued to have extreme difficulty trying to slide or rotate down to 4,833' then smothed out. Wipe through window f/4,856' to 4,732' with no problems- window F/ 4,755' to 4,767' very smooth. Drill f/ 4,856' to 5,103', AST = 3.0 hrs ART = 4.4 hrs, WOB 5/15K, RPM 80, 300 GPM @ 2450 psi, UP 96K, DN 87K, ROT 94K, TO 3000/4000 ftllb, Perform clean hole base line of 10.74 ppg w/9.8 ppg mud. Drill f/ 5,103' to 5,435', AST = 3.5 hrs ART = 5.1 hrs, WOB 4/8K, RPM 85,300 GPM @ 2200 psi, UP 103K, DN 90K, ROT 97K, TO 3800/4100 ftllb. Drill f/5,435' to 5,720', AST = 0.0 hrs ART = 7.5 hrs, WOB 6/1 OK, RPM 85,300 GPM @ 2400 psi, UP 105K, DN 95K, ROT 98K, TO 3900/4300 ftlb, Ave ECD's 10.9 ppg w/9.8 ppg mud. Circ & repair swab in pump. Drill f/5,720' to 5,887', AST= 1.0 hrs ART= 6.0 hrs, WOB 6/18K, RPM 85,300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TO 4100/4500 ftllb, Ave ECD's 10.9 ppg w/9.8 ppg mud. Wipe hole 5 stands in attempt to possibly unball bit, Hole very free and in good shape. Circ just off btm and pump 5 ppb medium nut plug to clean bit. Drill f/5,887' to 5,912', AST= 0.0 hrs ART= 1.0 hrs, WOB 6/18K, RPM 85, 300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TO 4100/4500 ftllb, Ave ECD's 10.9 ppg w/9.8 ppg mud. Note; Flow check @ 5907' due to possible gain, Lost 20 bbls mud @ 5910'. Observe well for losses- Well static. Drill f/5,912' to 5,937', AST= 0.0 hrs ART= 1.2 hrs, WOB 6I18K, RPM 85,300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TO 4100/4500 ftllb, Ave ECD's 10.9 ppg w/ 9.8 ppg mud. Drill f/5,937' to 5,972', AST= 0.0 hrs ART= 1.1 hrs, WOB 6/18K, RPM Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 6/27/2004 00:00 - 02:15 2.25 DRILL DRLG PROD 85,300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TO 4100/4500 ftllb, Ave ECD's 10.9 ppg w/9.8 ppg mud, Pump Hi-vis sweep @ 5,955'. Note; ROP below 15 ftlhr. 02:15 - 02:45 0.50 DRILL OBSV PROD Observe well, Pump dry job. 02:45 - 09:00 6.25 DRILL TRIP PROD POOH (Hole in very good shape), Set back BHA, PJSM, Remove RA sources, UD Short NM DC, Break bit & RWD-(Found 11 of 24 RWD cutters broken and missing and in very bad shape), Down load MWD/LWD tools while servicing tools. 09:00 - 15:15 6.25 DRILL TRIP PROD Make up RR bit #2 & rebuilt RWD, Load MWD/LWD, Load RA sources, Pick up Short NM DC, RIH to 5,972', Fill pipe @ 2000'/4000', Had no problems going in hole, Wash last stand to btm. 15:15 - 00:00 8.75 DRILL DRLG PROD Drill f/5,972' to 6,241', AST= 0.0 hrs ART= 7.6 hrs, WOB 6/8K, RPM -a5, 300 GPM @ 2350 psi, UP 115K, DN 95K, ROT 106K, TO 4900/5300 ftllb, Ave ECD's 10.9 ppg w/9.8 ppg mud. 6/28/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill f/ 6,241' to 6,553', AST = 0.0 hrs ART = 9.9 hrs, WOB 618K, RPM 85, 300 GPM @ 2350 psi, UP 135K, DN 90K, ROT 108K, TO 5600/6000 ftllb, Ave ECD's 10.9 ppg w/9.8 ppg mud. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill f/ 6,553' to 6,855', AST = 1.3 hrs ART = 9.2 hrs, WOB 4/8K, RPM 85,300 GPM @ 2400 psi, UP 136K, DN 99K, ROT 109K, TO 5700/6400 ftllb, Raise mud weight to 10.0 ppg @ 6,810', Ave ECD's 11.2 ppg w/1 0.0 ppg mud. 6/29/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill f/6,855' to 7,230', AST = 0.0 hrs ART= 10.3 hrs, WOB 4/6K, RPM 85, 300 GPM @ 2450 psi, UP 125K, DN 100K, ROT 113K, TO 7000/7500 ftIIb, Ave ECD's 11.2 ppg w/1 0.0 ppg mud. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill f/7,230' to 7,573', AST = 0.0 hrs ART = 10.3 hrs, WOB 4/6K, RPM 85,300 GPM @ 2500 psi, UP 175K, DN 90K, ROT 118K, TO 8700/8800 ftllb, Ave ECD's 11.3 ppg w/1 0.0 ppg mud, Maintain 2 ppb Mix II & Nut plug in mud system. 6/30/2004 00:00 - 00: 15 0.25 DRILL DRLG PROD Drill f/7,573' to 7,592', AST = 0.0 hrs ART = 0.2 hrs, WOB 4/6K, RPM 85,300 GPM @ 2550 psi, UP 175K, DN 90K, ROT 118K, TO 8700/8800 ftllb, Ave ECD's 11.3 ppg w/1 0.0 ppg mud, Maintain 2 ppb Mix II & Nut plug in mud system. 00: 15 - 02:00 1.75 DRILL CIRC PROD Pump Hi-vis weighted sweep, Circ hole clean w/3 times btm's up, Monitor well - Static, Blow down top drive. 02:00 - 04:15 2.25 DRILL TRIP PROD POOH to 4,728' (Window @ 4,755'), Hole in very good shape, No tight hole, Took proper fill. 04:15 - 06:00 1.75 DRILL LOT PROD PJSM, Rig & perform LOT of 12.4 ppg EMW w/540 psi, 10.1 ppg mud, 4,527' TVD. 06:00 - 06:30 0.50 RIGMNT RSRV PROD Service rig. 06:30 - 11 :00 4.50 DRILL TRIP PROD RIH w/ no problems to 7,474', Percautionary wash f/7,474' to 7,592. 11 :00 - 17:45 6.75 DRILL CIRC PROD Raise mud weight f/1 0.1 to 11.0 ppg, Pumping at rate of 270 gpm @ 2125 psi, Final ECD's 11.9 ppg, Stand back & Run 1 stand every hour f/ 7,592' to 7,365'. 17:45 - 18:15 0.50 DRILL TRIP PROD RIH to 7,592', Obtain slow pump rates w/11.0 ppg mud. 18:15 - 20:30 2.25 DRILL DRLG PROD Drill f/7,592' to 7,649' (6,677' TVD), ART = 1.7 hrs AST = 0.0 hrs, WOB 4/6K, RPM 85, 270 gpm @ 2400 psi, UP 175K, DN 90K, ROT 120K, ECD's 11.9 ppg, Had 6.9 bbl gain. 20:30 - 21 :30 1.00 DRILL OBSV PROD Check flow- well flowing, Shut well in and monitor 15 min.- No change - in drill pipe pressure (20 psi), 20 psi build on casing pressure, Open well, Circ btm's up- OK. 21 :30 - 00:00 2.50 DRILL DRLG PROD Drill f/7,649' to 7,704' (6,724' TVD- Top of A6 sand @ 6,712' TVD), ART = 2.0 hrs AST = 0.0 hrs, WOB 4/6K, RPM 85, 270 gpm @ 2400 psi, Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 6/30/2004 21 :30 - 00:00 2.50 DRILL DRLG PROD UP 175K, DN 90K, ROT 120K, ECD's 11.9 ppg, Mud wt. 11.0 ppg. NOTE; Well is flowing mildly during connections. 7/1/2004 00:00 - 00:45 0.75 DRILL CIRC PROD Circ btm's up (No gas cut mud), Monitor well - Well flowing mildly. 00:45 - 01:15 0.50 DRILL DRLG PROD Drill f/7,704' to 7,720' (6,738' TVD), ART"" 0.4 hrs, AST"" 0, Had drilling break for 1 0' from 30 ftIhr to 85 ftIhr. 01:15-05:30 4.25 DRILL CIRC PROD Circ btm's up (Mud cut 0.7 ppg on btm's up), Raise mud weight f/11.0 ppg to 11.2 ppg. 05:30 - 06:00 0.50 DRILL DRLG PROD Drill f/7,720' to 7,735' (6751' TVD) at 80/90 ftIhr, ART"" 0.4 hrs, AST "" O. 06:00 - 07:00 1.00 DRILL CIRC PROD Circ btm's up (Mud cut 0.3 on btm's up and drill gas). 07:00 - 11 :00 4.00 DRILL DRLG PROD Drill f/7,735' to 7,805' (6,812' TVD) ART"" 3.1 hrs, AST"" 0, WOB 3/4K, RPM 83, 230 gpm @ 1550 psi, UP 170K, DN 93K, ROT 117K, TO 8600/9470 ft/]b, Ave. ECD's 12.0-12.1 ppg w/11.2 ppg. 11 :00 - 12:00 1.00 DRILL CIRC PROD Circ & begin raising mud weight to 11.3 ppg, 210 gpm @ 1480 psi. 12:00 - 17:30 5.50 DRILL DRLG PROD Drill f/7,805' to 7,871' (6,868' TVD) ART"" 4.6 hrs, AST"" 0, WOB 4/8K, RPM 83, 230 gpm @ 1500 psi, UP 175K, DN 93K, ROT 120K, TO 8600/9470 ft/]b, Ave. ECD's 12.0-12.1 ppg w/11.3 ppg. 17:30 - 18:30 1.00 DRILL CIRC PROD Circ btm's up for possible T.D. 18:30 - 00:00 5.50 DRILL DRLG PROD Drill f/7,871' to 7,946' (6,935' TVD) ART"" 4.6 hrs, AST"" 0, WOB 8K, RPM 80, 237 gpm @ 1800 psi, UP 180K, DN 95K, ROT 122K, TO 8950/9100 ft/]b, Ave. ECD's 12.0-12.1 ppg w/11.3 ppg. 7/2/2004 00:00 - 01 :45 1.75 DRILL DRLG PROD Drill f/7,946' to 7,960' (6,948' TVD) T.D., ART"" 0.9 hrs, AST"" 0, WOB 8K, RPM 80, 237 gpm @ 2150 psi, UP 180K, DN 95K, ROT 122K, TO 8950/9100 ftIlb, Ave. ECD's 12.0-12.1 ppg w/11.3 ppg, Flow check on connection @ 7,946'- Mild flow, Begin raising mud weight to 11.4 ppg @ 7,946'. 01 :45 - 03:00 1.25 DRILL CIRC PROD Continue to raise mud weight to 11.4 ppg & circ hole clean, No noticeable mud loss. 03:00 - 04:00 1.00 DRILL OBSV PROD Flow check well- Showed to be flowing very little, Put well on trip tank for 40 min.- had 0 gain first 10 min., 0.2 bbl gain next 10 min., 0.2 next 10 min., 0 gain last 10 min., Observe well visually- very slight flow. 04:00 - 04:30 0.50 DRILL WIPR PROD Wipe hole 4 stands to 7,621', RIH to 7,960' - No tight hole. 04:30 - 06:45 2.25 DRILL CIRC PROD Circ btm's up & hole clean at rate of 230 gpm @ 1800 psi. 06:45 - 13:00 6.25 DRILL WIPR PROD Monitor well, Wipe hole 20 stands to 6,053', Tight hole @ 7538' and 7348', wipe through 7348', OK. Monitor well, RIH to 7,960'. Actual fill 2.2 bbls over calc. 13:00 - 15:30 2.50 DRILL CIRC PROD Circ btm's up & hole clean, Start circ @ 100 gpm w/900 psi, at 3000 strokes increase to 143 gpm w/950 psi & ECD of 12.09 ppg, at 4500 strokes increase to 179 gpm w/1200 psi & ECD of 12.08 ppg, at final rate of 200 gpm @ 1400 psi w/ ECD 12.1 ppg. Circ total of 3 BU's, w/ 11.4 to11.4+ ppg mud. 15:30 - 00:00 8.50 DRILL TRIP PROD Monitor well, Drop 2.40" rabbit, POOH slow, Tight hole @ 7280' to 7317', work through hole, continue POOH to BHA, Monitor well. Actual fill 7.6bbls over calc f/ dp. 7/3/2004 00:00 - 04:30 4.50 DRILL PULD PROD PJSM, Lay down Non-mag DC's, Remove RA sources, Down load LWD/MWD (Lost 0.4 bbls mud while down loading LWD in 1.75 hrs), Lay down LWD/MWD, Motor & bit. 04:30 - 06:00 1.50 CASE RURD PROD PJSM, Rig to run 3-1/2" liner. 06:00 - 16:00 10.00 CASE PULR PROD Pick up & run 3-1/2 Shoe, 3 jts 3-1/2",9.3#, L-80, SLHT liner, Float collar, 1 jt, Landing collar, 100 jts 3-1/2",9.3#, L-80, SLHT liner, Pick up Baker liner hanger, UP 55K, DN 40K. 16:00 - 17:45 1.75 CASE CIRC PROD Circ complete circulation at rate of 2.4 bpm @ 200 psi. 17:45 - 00:00 6.25 CASE OTHR PROD Stand back Baker liner hanger in derrick, Rig & POOH and stand back Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 7/3/2004 17:45 - 00:00 6.25 CASE OTHR PROD 7/4/2004 00:00 - 02:00 2.00 CASE PULR PROD 02:00 - 03:30 1.50 CASE RUNL PROD 03:30 - 04:45 1.25 CASE CIRC PROD 04:45 - 05:30 0.75 CASE RUNL PROD 05:30 - 07:00 1.50 CASE CIRC PROD 07:00 - 09:00 2.00 CASE RUNL PROD 09:00-11:15 2.25 CASE CIRC PROD 11: 15 - 13: 15 2.00 CASE RUNL PROD 13:15 - 14:00 0.75 CEMEN PULD PROD 14:00 - 19:00 5.00 CEMEN CIRC PROD 19:00 - 20:45 1.75 CEMEN PUMP PROD 20:45 - 21:15 0.50 CASE DEOT PROD 21 :15 - 23:30 2.25 CEMEN CIRC PROD 23:30 - 00:00 0.50 CEMEN OTHR PROD 00:00 - 00:30 0.50 CEMEN PULD PROD 00:30 - 06:00 5.50 CEMEN TRIP PROD 06:00 - 06:30 0.50 CEMEN PULD PROD 06:30 - 13:45 7.25 DRILL TRIP PROD 13:45 - 14:45 1.00 DRILL OTHR PROD 14:45 - 16:45 2.00 RIGMNT RSRV PROD 16:45 - 00:00 7.25 CMPL TN RUNT CMPL TN 00:00 - 02:00 2.00 CMPL TN RUNT CMPL TN 02:00 - 02:45 0.75 CMPL TN DEOT CMPL TN 02:45 - 10:30 7.75 CMPLTN CIRC CMPL TN 10:30 - 13:00 2.50 CMPL TN SOHO CMPLTN 7/5/2004 7/6/2004 liner in derrick, Install 2.75" Nipple, Rig & RIH w/liner. RIH w/liner to 3,310'. Make up Baker liner hanger, RIH on drill pipe to 4,714', Good displacement. Circ hole volume stage rate up to 3 bpm @ 380 psi, Mud gas cut 0.8 ppg on btm's up, UP 75K, DN 60K, Check rotary torque of 3700 ftllb at 10 RPM, ROT 65K, No mud lost. RIH w/linerto 5,661', Good displacement. Circ btm's up, Stage rate to 3 bpm @ 450 psi, Mud gas cut 0.8 ppg on btm's up, No mud lost. RIH w/liner to 6,797', Good displacement. Circ btm's up, Stage rate to 3 bpm @ 450 psi, Mud gas cut 0.3 ppg on btm's up, No mud lost. RIH w/liner to 7,930', Good displacement. Pick up Baker cement head, Break circ, Wash to btm & tag @ 7,960'. Circ btm's up, Stage rate to 3 bpm @ 450 psi, Mud gas cut 0.3 ppg on btm's up, No mud lost, Held PJSM for cmt job. Turn over to Dowell, Dowell pumped 2 bbls 8.3 ppg CW100 at rate of 3.2 bpm @ 650 psi, Shut down and test lines to 4500 psi, Continue pumping 18 more bbls CW100, 30 bbls 12.0 ppg MudPUSH at rate of 3.0 bpm @ 850 psi Followed by 158.8.0 bbls (398 sxs) 12.5 ppg LiteCRETE cement wI 31.0%D124, 0.7%D65, 0.025%C359, 0.100%D800, 1.5%D600G, 0.200%D47, Pumped at rate of 3.0 bpm @ 450 psi, Shut down, Wash lines to rig floor, Drop Baker wiper dart, Dowell kicked out dart w/ 33.5 bbls fresh water, Switch to rig pumps and finish displacing cmt w/ total of 44.0 bbls 11.4 ppg mud at rate of 3 bpm @ 1275 to 1420 psi, Bumped plug w 2900 psi, Had full circ thru out job, No mud lost, Reciprocate liner until cement at top of liner then stopped pipe, CIP @ 20:45 hrs 7/4/2004. Set liner hanger wI shoe @ 7,957.00', Float collar @ 7,858.20', Landing collar @ 7,825.08', Seal bore nipple @ 7,505.80', Flex-Lock liner hanger @ 4,613.50', ZXP liner top packer @ 4,602.64', Top of liner @ 4,590.87', Release from liner, Set liner top packer & test same to 1000 psi-OK. Circ out CW100, MudPUSH, And est. 9.4 bbls good cmt. to surface, Flush out cement from shakers and possum belly, Continue to circ and reciprocate pipe total of 5 btm's up. Function and circ out all BOP equipment. Lay down Baker cement head. Pump dry job, POOH & lay down 4" drill pipe. Lay down Baker liner running tool. RIH w/4" drill pipe from derrick, POOH & lay down same. Wash BOPE & Drain pan, Pull wear bushing. Cut drill line, Service rig. Rig & run 3-1/2" completion string to 4,637'. MU pump in sub, est circ and located top of seal bore extension, st wt up 60K, dn wt 53K RU & tested 3 1/2" x 7" annulus to 3,000 psi for 30 min with 11.4 ppg mud in hole, good test Circ out 11.4 ppg mud with clean seawater, circ hole at 9.5 bpm at 500 psi, circ a total of 4X hole volume to clean out mud and circ clean Spaced out tbg string, MU hanger, spotted 108 bbls of corrosion inhibitor in well, landed tbg hanger and RILDS, landed completion with Printed: 7/13/2004 4:08:36 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 G-08 1 G-08 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 6/16/2004 Rig Release: 7/7/2004 Rig Number: Spud Date: 11/30/1982 End: 7/7/2004 Group: 7/6/2004 10:30 - 13:00 2.50 CMPL TN SOHO CMPL TN btm of seal assembly at 4,642', Camco "DS" Nipple with 2.812" No Go at 4,565', GLM with DCR shear valve at 4,517' and Camco "DS" nipple with 2.875" ID at 489', st wt in 8.5 SW, up wt 60K, dn wt 57K with 22K block wt 2.25 CMPL TN DEOT CMPL TN RU and tested 31/2" tbg to 3,500 psi for 30 min, bled pressure down to 1,500 psi, pressure tested 3 1/2" x 7" annulus to 3,000 psi for 30 min, good test, bled down pressures and pressured up on annulus to 3,000 psi to shear DCR valve with no success, pressure up on tbg and annulus then droppped tbg to -0- and valve still didn't shear, cont to attempt to shear valve, had slight decrease in pressure but DCR valve would not shear RD test lines and LD 3 1/2" landing jt, installed TWC ND DSA, spool and BOPE and set back stack NU 7 1/16" 5M x 3 1/8" 5M adapter and 3 1/16" 5M re-conditioned tree and tested void to 5,000 psi for 30 min, good test Tested 3 1/8" 5M tree to 250 psi low and 5,000 psi high, good test, RU wells group lubricator and pulled TWC Held PJSM, RU HES Slickline, RIH and set junk basket in "DS" nipple at 4,566', POOH, RIH and retrieved DCR shear valve from GLM #3 at 4,517', POOH and Valve had not sheared, RIH and retrieved junk basket 3.00 CMPL TN FRZP CMPL TN Held PJSM, RU Little Red and pressure tested lines to 2,500 psi, then pumped 75 bbls diesel to freeze protect well, allowed well to U-tube, RD Little Red 3.50 CMPL TN SUN CMPL TN RU slickline and RIH setting junk basket in "DS" nipple at 4,566', POOH, RIH and set 1 1/2" Dummy valve in GLM #3 at 4,517', POOH, RIH and retrieved junk basket and RD HES 1.00 WELCT OTHR CMPL TN RU wells group lubricator and installed Cameron "H" type BPV, RD lubricator and secured well RELEASED RIG @ 12:00 Hrs 7-7-04, rig to move to 10 pad and stack out on 7-8-04 13:00 - 15:15 15:15 - 16:00 0.75 CMPL TN RURD CMPL TN 16:00 - 21 :00 5.00 WELCT NUND CMPL TN 21 :00 - 00:00 3.00 WELCT NUND CMPL TN 7/7/2004 00:00 - 02:00 2.00 WELCT CMPL TN 02:00 - 04:30 2.50 CMPL TN SUN CMPL TN 04:30 - 07:30 07:30 - 11 :00 11 :00 - 12:00 Printed: 7/13/2004 4:08:36 PM e 1G-08A Well Events Summary e Date Summary 06/05/04 INJECTIVITY TEST PRE P&A PERFS: 2.5 BPM @ 1200 PSI. MITIA FAILED (KNOWN TUBING LEAKS). [Workover prep] 06/09/04 RIH TO 7143' AND TAGGED ON COLAPSED TUBING, CIRCUALTED 190 BBLS WATER IN WELL BORE - GAS WOULD,NOT DIE. RECIPED COIL AT -7120' AND KILLED WELL WITH ADDTIONAL 150 BBLS WATER, FOLLOWED BY 40 BBLS CEMENT- SQUEEZED IN 35 BBLS WITH 500 PSI PRESSURE INCREASE AND LAY IN THE LAST 5 BBLS TAKING 1:1 RETURNS. JET DOWN TO 7100' CTM WITH 30 BBLS OF BIO, POOH WASHING GLM #6 AT 6681' RKB EXTRA WELL WITH BIO. LEFT FRESH WATER IN WELLBORE FROM 7100' TO 2500' WITH A DIESEL CAP - TOP OF CEMENT IS AT 7100'. 06/11/04 CMIT-T x IA failed, LLR of 4.5 gpm @ 950 psi. Function tested all OC- LSD's.D [ANN COM ISSUES, WH Maintenance] 06/12/04 TAGGED CEMENT PLUG @ 7077' RKB, ESTABLISHED INJ RATE 1 BPM @ 1500 PSI. [ANN COM ISSUES, Tag] 06/12/04 SET BAKER CEMENT RETAINER IN 3.5" TUBING AT 6975' (CENTER OF ELEMENT). RETAINER WAS SET IN CENTER OF THIRD FULL JOINT ABOUT CEMENT TOP (TAGGED AT 7062').[Cement-Poly Squeeze] 06/13/04 ATTEMPTED TO SET CEMENT PLUG THROUGH A RETAINER. PUSHED RETAINER TO BOTTOM @ 7056' CTM. ESTABLISHED INJECTIVITY @ 1 BPM AND 1500 PSI. POOH AND MU CEMENTING ASSEMBLY. RIH AND KILLED WELL BY BULLHEADING 80 BBLS SLICK SEAWATER. PUMPED 14.5 BBLS CEMENT FOLLOWED BY FRESH WATER (BULLHEAD 11.5 BBLS / LAY IN 3 BBLS ABOVE RETAINER). 06/14/04 DRIFT TO 6805 SLM, TAG TOP OF CEMENT, START INJECTIVITY TEST WITH PDS SPINNER. LEAK IN TUBING BETWEEN 6500' AND 6600' [Leak Detect-Patch] 06/15/04 LEAK DETECT USING, W/PDS SPINNER @ 1 BPM (LEAK VERIFIED) @ 6518' SLM TO 6561' SLM. PUMPED 133 BBLS SEA WATER WITH A 30 BBL DIESEL FP. [Leak Detect- Patch] 06/15/04 PULL DV FROM STA.# 5 @ 6604' WLM (6613'RKB) DRIFTED WELL WITH KOT WITH OD OF 2.710" WENT TO 6710' WLM. [Workover prep] 06/15/04 FIRED STRING SHOT TO CLEAN PIPE OVER CUT INTERVAL. CHEMICAL CUT TUBING AT 6665' RKB (CENTER OF FIRST FULL JOINT ABOVE GLM#6) USING 2 5/8" CHEMICAL CUTTER. WELL FLUID WAS 8.8 PPG BRINE, DEVIATION AT CUT DEPTH WAS 57 DEG. TUBING/IA EQUALIZED BY OPEN GLM#5. TAGGED TD AT 6712'. 06/15/04 PUMP KILL JOB PRE RWO WITH 400 BBLS 8.8 PPG BRINE.D [Workover prep] 06/20/04 DRIFTED CASING TO 6450' WLM, CEMENT & SLIP'S IN JUNK BASKETD [Tag, Fish] 07/06/04 WORK OVER ASSISTANCE PULLED DCR @ 4566' RKB. SET DV @ SAME.D [Workover prep] 07/14/04 PT TUBING AND IA PRE FRAC POST WORK OVERD [PT Tbg-Csg] 07/15/04 DRIFTED TBG 2.74" & TAGGED IN LINER @ 7368' RKB, WORKED TO 7374' RKB, EST. 352' ABOVE TARGET PERF @ 7736' RKB. 2.5" SAMPLE BLR RAN TO 7377' RKB, MINIMAL SAMPLE OBTAINED OF GREY PASTE? IN PROGRESS. [Tag] 07/16/04 INITIAL TAG @ 7357' SLM. WORKED FROM 7377' TO 7391' RKB; LOOSING SPANGS AND TOOLS WERE STICKING. OBTAINED SAMPLE OF THICK GRAY PASTE, SENT TO LAB FOR ANALYSIS. [Tag] e 1G-08A Well Events Summary e 07/21/04 RIH. TAGGED FILL @ 7372' CTM. CLEANED OUT MUD TO TOP OF LANDING COLLAR @ 7810' CTM. POOH DISPLACING WELL TO DIESEL. CLEANED UP GLM'S @ 4517',3838' AND 2652' WHILE POOH. RDMO. [FCO] 07/22/04 DRIFTED TBG W/ 2.60" X 11.5' DUMMY GUN TO 7807' WLM. [Tag] 07/22/04 JOB NOT COMPLETED -- OPEN HOLE TIE IN LOG FOR PERFORATING NOT AVAILABLE UNTIL NEXT DAY -- LOGGED GR/CCL FROM 7800 TO 7350 (NOT TIED IN). [Perf] 07/23/04 PERFORATED 7728' -7736', 6 SPF -- AFTER PERFORATING MEASURED SBHP AT _ 7732'= 3993.6 PSIA, TEMP= 165.1 DEGF AND AT 7632'= 3962.9 PSIA, TEMP= 163.9 DEGF -- RAN GR/CCL LOG FROM 7822' TO 4450' [Perf] 08/19/04 PUMP FRACTURE TREATMENT USING 50# DELAYED X-LINK GEL AND 16/20 CERAMIC PROPPANT. PUMPED A TOTAL OF 173,600# PROPPANT, PLACING 172,600# BEHIND PIPE WITH 10 PPA ON PERFS. 8/20/2004 TAGGED TOP OF FILL AT 7580' CTM (7600' RKB); LAYED IN DIESEL FREEZE PROTECT FROM 2500'. 8/21/2004 PERFORATED 7290'-7292', 7306'-7310', 7326'-7328' 6 SPF HYPERJET. 8/22/2004 PUMP C4 SAND FRACTURE TREATMENT USING 50# DELAYED X-LINK GEL AT 15 BPM, WITH 16/20 CERAMIC PROPPANT. FLUSH JOB TO COMPLETION. PLACE TOTAL OF 51,000# OF PROP BEHIND PIPE WITH 10 PPA ON PERFS. 8/24/2004 CLEANED OUT TO TAG @ 7810' CTM. WELL FREEZE PROTECTED W/DIESEL. 8/25/2004 TAGGED FILL @ 7804' RKB. ¥ ConocoPhillips e e,;<ðy-/O I SURVEY LISTING Page 1 Wellbore: 8A Wellpath: MWD w/Sag <4917 -7960'> Date Printed: 14-Jul-2004 rei. BAKER HUGHES INTEQ ConocoPhillips Alaska, Inc.,slot #8 Pad 1G, Kuparuk River Unit,North Slope, Alaska We II bore Name 8A ___~l Last Revis~ . . _lJ-Jul-2004 --~--------~._..,~~- Created .._.---..1b.!!JJJ~2ÇI~ ... Well Name 8 I Government ID ! I Last Revised . 13-Mav-2004 ! I Slot Latitude N70 21 42.0428 ! Lon itude W149 40 19.6737 North 1323.35N East ¡ 585.67E Name slot #8 Installation Name Pad 1 CL. E-ªstina NorthinQ __~..l-ª2.8874L~Q.644.6237 North Alianment J Tnt~ --~--- ._~_.~ ~! Field Name Ku aruk River Unit Eastin 487754.6208 CreatØd;B ¡ ! L--__"_.~~___.__ ---- -~-----_.~._"- 'Comments . ¡ . ! I --~-~----- ."--_.._-_._~-,----------_. ._.',__ _"_.·_______~_._.m____ reJ~d 7/~j)!O « All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III RKB 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2783.02 Feet on azimuth 306.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ ConocoPhillips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 2 Wellbore: 8A Wellpath: MWD w/Sag <4917 -7960'> Date Printed: 14-Jul-2004 mi. BAKER HUGHES INTEQ i TVD[ft] Vertical North[ft] J East[ft] Station Station ! Dogleg I Vertical Station Comment I Depth SS Position(Grid Position(Grid I [deg/101 Section[f i ! North) East) I Oft] in 4755.00 46.88 315.20! 4526.95 4437.95 553.00N, 473.12W 5982521.33 539885.41' 0.00 ! 713.03 Tie-on to Previous survev 4917.0L.~Q,1~.! 308.97 14637.94 4548.94. ~3N I 560,l2Y'1. ,5982599JF 539797,;39 2.80 .L~. ..5012.15 46.02¡ 310~85 . 47~_4614.54 ...676.27N '613,~Q982643.8,~ 539744.37 I 1.61 ! J!.99.54 5106.72 44.05! 309.55 T 4770.37 4681.37 719.47N I 664.61W 5982686.74 539693.05 2.30 ¡ 966.39 ~Q2.34 _A.MLl.;307.4514839'?Q...A7-º-Q~Z!Lt-Z6Q.47N,L 716.14.W ~Z2L4.6.c--Q~!J641.31 ..1.86 1032.23 5295.96 42.31 298.88: 4908.61 4819.61 795.13N 769.12W 5982761.84 539588.14! 6.24 . 1095.34 5391.61 41.97! 299.28 14979.53 4890.53 826.33N 1 825.21W 5982792.72 539531.89! 0.45 ! 1158.75 5485.87 42.05! 299.48 ! 5049.57 4960.57 857.27N 1 880.18W 5982823.37 539476.76 0.17 1221.14 5579.10 43.35 300.63 ¡ 5118.09 5029.09 888.94N I 934.90W 5982854.74 539421.88! 1.63 ! 1283.77 5674.36 44.14 , 300.69 ! 5186.9.Q ~,~º.+..922.53N ! .!J.91.55W 5982888.02 539365.05 I 0.83 ! 1349.11 5768.72 44.66 1 299.85 1 5254.32 5165.32 955.81N! 1048.57V'i 5982920.99 539307.85 0.83 I 1414.55 .5864.54 42.53 ;..301.4.;3 · 532.~-----º-Z34......n..989.46~j 1105.42.\lL~819M,R_539250.83 ,..2.50 ! 1480.08 5958.45 4~300.79 ¡ 5392.73 53Q3.73 1022.37Ni 1159.96'{\ 5982986.94 !?~9196.13! 0,.59 11543.3~ 6053.16 4~~9.9.14 \ 5461.88 5372.8-ª-~.69N!! 12J~. 598301.8.95 539.139.90, 1.26'fW-ºZA2.~_ ~9.56 43.47. 299.905531.93~9~_~Z.32N 12.Z~ . 5983051.27 5390.82.10 i 0.56 ,1672.94 6243.88 43.6º~.54 15600.27 5511.27 1119.55N! 1330.10V'i 5983083.19 539025.48 I 0.33 L1];37.28 ~6Ji.~W 1 29a2LL!i669.12 5580.12 1151.25NI13.8~ 5983114c.58 538968,42~L1.801.64 ~4.ª 43.10~7'...86! 5739.06_.5650.06. 1182.29NI1444.68V'i 5983145.~1 538910.57! 0.61 ¡ 1869.24 6528.41 43.32 297.37' 5807.52 5718.52 1212.10N! 1501.67,^ 5983174.80 538853.43! 0.43 11929.51 6622.64 42.41 1 296.77 15876.59 5787.59 1241.27N11558.74\¡'\ 59832º~c---5.J--ª196.20! 1.06 11992.47 6718.09 41.73 1 297.44 ! 5947.44 5858.44 1270.41NI1615.68V'i 5983232.49 538739.12! 0.85 ,2055.30 6812.98 40.27 i 304.83 ! 6019.10 5930.10 1302.50NI1668.91,^ 5983264.29 538685.72 I 5.33 12117.02 6907.03 40.09 1 304.81 16090.95 6001.95 1337.15N! 1718.73,^ 5983298.67 538635.72 1 0.19 12177.61 7001.68 39.22! 303.04 16163.82 6074.82 1370.86NI1768.84V'i 5983332.11 538585.44 i 1.51 i 2237.86 70.96.73 38.75: 301.01 ¡ 6237.71 6148.71 1402.57Ni 1819..~~Q983363.54 538534.58 I 1.43 12297.34 7192.32 39.64 i 301.94 16311.79 6222.79 1434.12Ni 1871.04,^ 5983394.81 538482.90, 1.12 12357.37 7286.34 38.24 1 301.59 .j.6384.92~~c-H6§.23NiJ921.28V'i 598342~c--!2.~8432.50 ¡ 1.Q1 j 2416.1.2 ~?5 38.11 ¡ 301.88 16459.14 6370.14 1495.92Ni 1970.91V'i 5983456.06 5~8382.72 i 0,23 r 2474.13 ....H.Th.Q~L__~6J~~. 300~.534.1º 6445.º.!L~c61Ni 2019.8Z'l'! 598348~.49 5363.33.60 I 1.76 I ;S~1Ó1.. 2531.01 ._. 7571.11 34.3Q~..06 6~ 6523.29 1553.34N 12068.21V'i 5983512.95 53828Q.12 2.6112586.18 7664.13 31.81 j 301.24 ! 6690.26 6601.26 1578.79NI2112.09V'i 5983538.16 538241.11 I 2.97 12636.44 7758.51 30.54 f 298.81 16771.01 6682.01 1603.25N! 2154:37,^ 5983562.39 538198.70 L 1.89 12684.63 7854.85 28.80 T 299.43 1.6854.71 ~.lLr-1º2.6.45N¡ 2196.03V'i 5983585.36 5~8156.92 1 1.8~ 2731.96 __. 7957.00 28.80 i 299.43 .6944.23 6855.23 1650.63NI2238.89V'i 5983609.31 538113.93 I 0.00 12780.6331/2" Liner 7960.00 28.80 1299.43 I 6946.86 6857.86 1651.34NI2240.15,^ 5983610.01 538112.67 1 0.00 12782.06 Projected Data - NO SURVEY, 95/8" I 1 ' ! Casino. 7" Casino 1 Wellpath Report MD[ft] Inc[deg] I Azi[degJ , ..~ --'---', ----~ _.-_._~._- .--1 ! ._---~-~- . -.---..j ----~ " ~-~--------1 ! . -----------¡ _._.~---------; ---, I ··--·-~-·-l _._~'-~--. ! .._~.--._--~ . , I ..-------.J I ---..---' _.,---_.._-~- 'j ! --_._~ ._"_.._~ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III RKB 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2783.02 Feet on azimuth 306.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ..... ConocoPhillips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 3 Well bore: 8A Well path: MWD w/Sag <4917 - 7960'> Date Printed: 14-Jul-2004 rei. BAKER HUGHES INTEQ NoJtl!ff!L__ Comme~__ __~__ __ 553"OON_1 Tie-Qr"lJo PHtvious S!J~_.. ~______ _ 165L~~_proiecJed Data - NO $URVEY_~________ -'""--'.-'_..- __.____..._~___._____J Hole Sections i , Diameter I Start Start Start ~ Start End End lEnd End\nEast[ft] Wellbore I linL_ ' MDlftl TVDfftl Northr~_, I:astlftl M Dlftl TVDlftl --r-NorthfID ! - 12 114 i 0.00 0.00 O.OON I O.OOE 2232.00 2231.92 0.07S 9.10E 8 81/2 " 2232.00 2231.92 0.07S 9.10E 8715.00 6956.55 I 1830.06N 2556.94W 8 , 43/4 4755.00 4526.95 553.00N i 473.12W 7960.00 6946.86 1651.34N 2240.15W 8A Casin Name i Top Top i MDf~_---+1Y~ 9 5/8" Cas~_ i 0.00 _ +- 0.00 _ 7" Ca§~__---L_--º,º_º---L 0.00 3 1/2" Liner 4590.87 ' 4411.79 Top Shoe NQrthfft] I;astlftl _ M~_ _O.OON _~_O.00E_--L2232.0Q . ---º--~_L----..M~---ªZ15.00 470.09N 390.69W! 7957.00 Shoe ! Shoe I Shoe Wellbore TVDJ~~J\QrtbfftL...._ i Eastfftl 22]1.92 ! .0.o7S¡ 9.10E 8 6956.55 , 2864.06N i 2546.53W 8 -. 6944.23-T165Û.63N i 2238.89W 8A __.~_---.--J ----~ ! ----~._~ Surve Reference 96862 666585 Surve Name PGMS <0-8715'> MWD wI Sag <4917 - 7960'> MDft 4755.00 7960.00 Error Model Standard MWD+SAG - ISCWSA - 28 Ja 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III RKB 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2783.02 Feet on azimuth 306.40 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e c;....€jJa'., R~CEII:D Transmittal Form AUG 2 6 2004 r'~ _ A/asK~VI' & GasCons.Comm"~KrR- Anchorage HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: --Rob;.. Dus9IL. Reference: 1 G-08A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - GRlMPR Measured Depth Log 1 blueline - GR/MPR TVD Log 1 blueline - CCN/ORD Measured Depth Log 1 blueline - CCN/ORD TVD Log LAC Job#: 701823 Date: Aug 2 cI Date: PLEASE ACKNOW EDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 , 2..Co 2.. ( Re; lG-08 P&A Original Wellbore & Current Status . Subject: Re: 1G-08 P&A Original Wellbore & Current Status From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 30 Jun 2004 11:18:53 -0800 To: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> . \ G -0 ~ ~ dOL\-\O \ Either way, changing rams to run pipe would be in your future. at balance. ECD will be the telling factor. Again, good luck with the operations. Tom Maunder, PE AOGCC Based on the pressure, your 11 ppg should be r " McLure, Kelly wrote: We have already drilled through the C sands. This was the lower reservoir pressured sand and currently in the B sand. Below that is the A sand believed to be pressured up with max pressure of 4000 psi, but they don't expect that high. Most likely 3800 psi. We plan to change the rams for the 3-1/2" liner if we get to drill all the way to bottom and run that. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, June 30,200411:08 AM To: McLure, Kelly Cc: AOGCC North Slope Office Subject: Re: 1G-08 P&A Original Wellbore & Current Status Kelly, Are you already through the C sands or are they to still be drilled?? An extension of the BOP test is approved. How your work plan develops will likely be the determinant of when you next need to test. Depending on the rams in use, your next test or partial test would be to change the rams for running the liner. Good luck with the operations. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, As per our conversation we are currently at the window depth of 4579' MD/4529' TVD. We have completed our open hole LOT/FIT test and found a 12.4 ppg EMW at the window depth. Our desire is to trip in the hole back to 6628'TVD/7601' MD and do 2 full circualations to increase the mud weight from the current 10.0 ppg to 11.0 ppg. We would like to do this to test the strength of the C sand interval. If it holds this mud weight we plan to drill ahead the remaining 447' to total depth of the well. We are currently at the 7 day BOP test date requirement. We have not been to surface with the bit since Sunday. I would like to ask for an extension on our BOP test to the 14 day mark from the original done on 6-22-04. Please let me know if this exception is granted. Thanks, Kelly McLure -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, June 23, 2004 4:28 PM 10f5 7/2/200410:36 AM Re: lG-08 P&A Original Wellbore & Current Status To: McLure, Ke' · Subject: Re: lG-08 P&A Original Wellbore & Current Status Kelly, Good news on the USIT log. Good luck with the remainder of the well. I will place a copy of this message in the well file. As usual, please call with any questions or information. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, We have the USIT log for the 1G-08 wellbore. It shows no corrosion beyond a 4 pits in the casing which look to be the thickness of a couple pencil leads. Therefore, we plan to run the one trip whipstock in and place it on the top of the cement retainer that was set at 4777' MD. The window will be milled and the FIT/LOT performed to 15.0 ppg then pulled out of the hole. We will proceed with the BRA pickup and drill our sidetrack (if the LOT/FIT test is okay) . Any further questions, call me. Thanks, Kelly Kelly McLure Operations Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) -----Original Message----- From: McLure, Kelly Sent: Tuesday, June 22, 2004 8:23 AM To: Tom Maunder (E-mail) Cc: Thomas, Randy L¡ Pysz, Nick P Subject: 1G-08 P&A Original Wellbore & Current Status Tom, The top of the Our plan is to set holes at 4777' MD. below the retainer. A CCL log was already run on the original drilling of the well in 1982. It correlates with the 7" casing tally from the original well. The original rig was Parker 141 which is now Doyon 141 with an RKB of 28 feet. The current Nordic RKB is 30.3'. The data we have, plus the shallow depth makes us feel confident we will be close to the accurate depth for not placing the retainer and whipstock in a collar not having to run another CCL log. The cement retainer has been set at 4777' MD¡ 38 bbls were pumped below the retainer. The whipstock will be placed on top of the retainer and is approximately 12' long. This puts the top of the whipstock at 4765' MD. (Directional planning attached shows 4759' MD with the whipstock being placed at 4771' for planning purposes. ) holes in the 7" casing were located at 4827' MD. a cement retainer +/- 50 above the top of the We will leave the 8.8 ppg Brine and cement Plan forward is to run a storm packer and set at 35'. The lower rams will be changed to 4" and then ND BOP and change out the 20f5 7/2/200410:36 AM Re: 10-08 P&A Original Wellbore & Current Status tubing he4IÞ. Test the BOP's, 250 and 50004!!i' and pullout of the hole with the storm packer, DP, and cement retainer stinger. The window will be milled and then kick off for the sidetrack. Please contact me if you have any further questions. Kelly Kelly McLure Operations Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 21, 2004 9:43 AM To: McLure, Kelly Subject: Re: IG-08 P&A Original Wellbore & Current Status Ke 11 y , I confirm receiving your message. What you propose, determining if there is a 7" casing leak is appropriate. Please keep us informed of the results and appropriate plans forward. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, The plan as shown below for the P&A of the original wellbore as shown below. A current status is at the bottom in red. Pre-Rig Well Work: 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. Have DHD crew PT tubing and casing packoffs. Cycle lock down screws and pressure test OA. 3. Slickline: Drift and tag tubing restriction at 7127' MDRKB. 4. Rig up CTU and cement unit. RIH to7120' and squeeze away cement into to the open A and C sand intervals. Bring cement to 7050' and jet out excess. 5. Slickline: Wait 24 hours and tag TOC. Pull DV at 6681' and circulate well to seawater. Pressure (CMIT) test to 2000 psi for 30 minutes (Call AOGCC to witness tag & CMIT) SEE BELOW SKIP TO HISTORY >FROM STEP 5 ABOVE History: 5. Attempted the first CTU squeeze (without a Cement retainer) was not successful in isolating the perfs. Pumped 45 bbls cement. 6. The second CTU squeeze did not hold either as Jerry Dethlefs passed on to you yesterday. Pumped 15 bbls cement. TOC in the tubing is about 6850'. 7. Ran a memory PDS spinner which showed multiple holes in the 30f5 7/2/2004 10:36 AM Re: IG-08 P&A Original Wellbore & Current Status tubing tlt6500-6600 ft. above the curren~op of cement. We are sill able to bullhead over 1 bpm down tubing. Fluid is exiting from the tubing holes. It appears the cement in the tubing is holding OK. 40f5 Plan forward as of June 15, 2004: Basically the plan is to have the rig finish the P & A. Will prep the well for the rig by circulating KWF and chemical cutting the tubing. Wells Group: 1) Have SL drift tubing with 2.70" drift for the 2 5/8" chern cutter to TOC. (tagged TOC last night at 6805') 2) Pull DV in GLM @ 6681' 3) Circulate well with KWF brine (8.8 ppg brine.. assumes 150 psi overbalance with seawater below 6681' to the perfs) 4) RU e-line and chern cut tubing at approx. +1- 6640' (mid jt.) 5) Set BPV and VR, prep wellsite. Nordic 3 Rig showed up on location and accepted the rig 06:30 on 6-17-04. Plan was as follows: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. Prior to moving rig over well check handover form that BPV has been installed. 2. MI/RU Nordic 3. Check IA & OA for pressure. Record on IADC report 3. Load 4.0" DP in shed while taking Brine in pits. 4. Take on 8.8 ppg Brine in pits. Pull BPV. R/U on tree and circulate 8.8 ppg Brine. Circ through choke until clean 8.8 ppg Brine returns are observed at surface. Run and set BPV again. 5. Take KB measurement and note on morning report. 6. Bleed the IA, inner annulus and remove the tree and adapter. Check landing threads and LDS. 7. Install blanking plug on top of the BPV. 8. NU BOP and test. NOTE: the Top flange of Gen 1 Spool is 11" 3000 PSI BOPE to 250# I 3000# * NEED 11 3000 x 115M DSA - ANNULUS VALVES ARE 3000 PSI 9. Cameron or Valve shop to pull BPV. Engage the 3-1/2" tubing hanger with a joint and LID the tubing hanger. (If unable to use a joint to screw in we need to use a spear from Baker Fishing), notify Wells Group to have Schlumberger on notice if original tbg cut failed.) 10. LD all the tubing. Accurately record jts laid down and length 11. PU 4.0" DP and rack back. 12. PU mill and casing scraper RIH to +1- 6650' MD. C&C. POOH 13. PU 7" cmt retainer & RIH to 6600' MD (50' above tbg cut at 6650' MD). Set retainer. Pressure test the casing IA and retainer. Establish injection rate. 14. Mix 100 BBL, 15.8 ppg Class G. Pump 100 bbls of cement through the cement retainer. IF the 100 bbls gets pumped away and no pressure increase seen then plan to mix and pump another 50 BBLS. If the cement is just pumping away then we will stop there. 7/2/200410;36 AM Re: IG-08 P&A Original Wellbore & Current Status 50f5 . . * We will then increase the volume from 50 FEET (2.0 bbls) to 100 FEET (3.8 BBLS) of cement on top of the retainer. This will be the P&A of the original wellbore. Current Status: When we went into pull the tubing the tubing was not cut so a second cut had to be made in the tubing. This was completed and the tubing was cut at 6475' MD. The completion was pulled and then a casing scraper and mill where picked up and ran in the hole. When we pulled out of the hole, 2- 31/2" slips were found. One found in the mill and the other in the scraper. A gauge ring and junk basket run was made and the well clear to 6450' MD. The 7" retainer was picked and ran in the hole. While stung out of the retainer attempted a pressure test to 2000 psi. Held okay. We stung into the retainer and attempted to test the annulus at 1 bpm. It was either pumping past the retainer or there was a hole in the casing. Picked up out of the retainer and pumped at 1 bpm again with the same results. Stung into the retainer and established an injection rate 1/2 bpm at 1710 psi below the retainer with no communication into the annulus. Either the retainer was holdign or we had a hole in the casing. Spotted 250 feet of cement on top of the retainer and pulled out of the hole. Picked up a packer and ran in hole to 3500 feet to pressure test trying to find the hole in the casing. Any questions please give me a call at 907-265-6059. Regards, Kelly McLure 7/2/200410:36 AM ConocÓPhillips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1G, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 8A Wellpath: 8A Ver#3 Date Printed: 21-Jun-2004 dOL\-\O\ l_ _ All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2855.36 Feet on azimuth 306.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated eonoa})h¡llips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 2 Wellbore: 8A Wellpath: 8A Ver#3 Date Printed: 21..Jun-2004 4759.00 46.96 315.20 4529.69 4440.69 555.08N 475.18W 5982523.39 539883.34 0.00 715.93 Toe Whicstock Face Tie on 4771.50 48.59 313.95 4538.09 4449.09 561.57N 481.77W 5982529.85 539876.71 15.00 725.12 Base WhiDstock Face End of Buildffur 4789.50 48.59 313.95 4549.99 4460.99 570.94N 491.49W 5982539.16 539866.94 0.00 738.55 End Milled Openhole. Begin Drpffrn, 3DJ Kick off Point 4800.00 48.38 313.63 4556.95 4467.95 576.38N 497.17W 5982544.57 539861.24 3.00 746.37 4900.00 46.49 310.47 4624.60 4535.60 625.72N 551.83W 5982593.61 539806.32 3.00 819.80 5000.00 44.69 307.10 4694.58 4605.58 670.48N 607.48W 5982638.06 539750.44 3.00 891.21 5100.00 43.00 303.53 4766.71 4677.71 710.53N 663.97W 5982677.81 539693.74 3.00 960.39 5143.40 42.30 301.90 4798.63 4709.63 726.43N 688.70W 5982693.57 539668.92 3.00 989.68 End of 3/100 Curve End of Drocffurn 5200.00 42.30 301.90 4840.49 4751.49 746.56N 721.04W 5982713.53 539636.47 0.00 1027.56 5300.00 42.30 301.90 4914.45 4825.45 782.13N 778.18W 5982748.79 539579.15 0.00 1094.50 5400.00 42.30 301.90 4988.40 4899.40 817.70N 835.32W 5982784.05 539521.83 0.00 1161.44 5500.00 42.30 301.90 5062.36 4973.36 853.28N 892.46W 5982819.30 539464.50 0.00 1228.38 5600.00 42.30 301.90 5136.32 5047.32 888.85N 949.60W 59828!j4.56 539407.18 0.00 1295.32 ~.p0 42.30 301.90 5210.28 5121.28 924.42N 1006.74W 5982889.82 539349.85 0.00 1362.25 5800.00 42.30 301.90 5284.24 5195.24 959.99N 1063.88W 5982925.08 539292.53 0.00 1429.19 5900.00 42.30 301.90 5358.20 5269.20 995.56N 1121.02W 5982960.34 539235.21 0.00 1496.13 6000.00 42.30 301.90 5432.16 5343.16 1031.13N 1178.16W 5982995.60 539177.88 0.00 1563.07 6100.00 42.30 301.90 5506.11 5417.11 1066.70N 1235.29W 5983030.86 539120.56 0.00 1630.01 6200.00 42.30 301.90 5580.07 5491.07 1102.27N 1292.43W 5983066.12 539063.23 0.00 1696.95 6300.00 42.30 301.90 5654.03 5565.03 1137.84N 1349.57W 5983101.38 539005.91 0.00 1763.88 6400.00 42.30 301.90 5727.99 5638.99 1173.42N 1406.71W 5983136.64 538948.59 0.00 1830.82 6500.00 42.30 301.90 5801.95 5712.95 1208.99N 1463.85W 5983171.90 538891.26 0.00 1897.76 6600.00 42.30 301.90 5875.91 5786.91 1244.56N 1520.99W 5983207.15 538833.94 0.00 1964.70 6700.00 42.30 301.90 5949.86 5860.87 1280.13N 1578.13W 5983242.41 538776.61 0.00 2031.64 6800.00 42.30 301.90 6023.82 5934.82 1315.70N 1635.27W 5983277.67 538719.29 0.00 2098.58 - 6900.00 42.30 301.90 6097.78 6008.78 1351.27N 1692.40W 5983~12.93 538661.97 0.00 2165.51 7000.00 42.30 301.90 6171.74 6082.74 1386.84N 1749.54W 5983348.19 538604.64 0.00 2232.45 7100.00 42.30 301.90 6245.70 6156.70 1422.41 N 1806.68W 5983383.45 538547.32 0.00 2299.39 7188.29 42.30 301.90 6311.00 6222.00 1453.82N 1857.13W !)983414.58 538496.71 0.00 2358.49 Too Kucaruk D 7200.00 42.30 301.90 6319.66 6230.66 1457.98N 1863.82W 5983418.71 538490.00 0.00 2366.33 7280.24 42.30 301.90 6379.00 6290.00 1486.53N 1909.67W 5983447.00 538444.00 0.00 2420.04 Top C4 Target, Drop 2/100, 1G-08A To KUD C4 Tat Rvsd 24 Mav 04 End of Hol 7343.16 41.05 301.90 6426.00 6337.00 1508.64N 1945.18W 5983468.92 538408.37 2.00 2461.65 C3 ,----- 7376.15 40.39 301.90 6451.00 6362.00 1520.01N 1963.45W 5983480.19 538390.04 2.00 2483.05 C2 7380.24 40.30 301.90 6454.12 6365.12 1521.41N 1965.70W 5983481.58 538387.79 2.00 2485.68 7411.41 39.68 301.90 6478.00 6389.00 1531.99N 1982.71W 5983492.07 538370.72 2.00 2505.60 C1 7478.33 38.34 301.90 6530.00 6441.00 1554.26N 2018.47W 5983514.14 538334.85 2.00 2547.50 B 7480.24 38.30 301.90 6531.49 6442.49 1554.88N 2019.47W 5983514.76 538333.84 2.00 2548.67 7580.24 36.30 301.90 6611.03 6522.03 1586.91N 2070.92W 5983546.50 538282.23 2.00 2608.94 7601.23 35.88 301.90 6628.00 6539.00 1593.45N 2081.42W 5983552.98 538271.69 2.00 2621.24 5 1/2in lQQ Set Contina PI. 7680.24 34.30 301.90 6692.64 6603.64 1617.45N 2119.97W 5983576.78 538~33.01 2.00 2666.42 7703.61 33.84 301.90 6712.00 6623.00 1624.37N 2131.09W 5983583.64 538221.86 2.00 2679.44 A6 7708.42 33.74 301.90 6716.00 6627.00 1625.78N 2133.36W 5983585.04 538219.58 2.00 2682.10 A5 7720.43 33.50 301.90 6726.00 6637.00 1629.30N 2139.01W 5983588.52 538213.92 2.00 2688.71 A4 7750.31 32.90 301.90 6751.00 6662.00 1637.94N 2152.90W 5983597.09 538199.98 2.00 2704.98 A3 .- 7780.24 32.30 301.90 6776.21 6687.21 1646.47N 2166.59W 5983605.54 538186.25 2.00 2721.02 7807.12 31.77 301.90 6799.00 6710.00 1654.00N 2178.69W 5983613.01 538174.10 2.00 2735.20 A2. All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2855.36 Feet on azimuth 306.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated eonocJ'Ph¡llips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1G, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 3 Well bore: 8A Wellpath: 8A Ver#3 Date Printed: 21-Jun-2004 7839.94 31.11 301.90 6827.00 6738.00 1663.05N 2193.22W 5983621.98 538159.53 2.00 2752.22 Top Miluveach, End 2/100 Drop, End of Dro 7900.00 31.11 301.90 6878.43 6789.42 1679.45N 2219.57W 5983638.23 538133.09 0.00 2783.09 8000.00 31.11 301.90 6964.04 6875.04 1706.76N 2263.43W 5983665.30 538089.09 0.00 2834.47 8039.94 31.11 301.90 6998.24 6909.24 1717.66N 2280.95W 5983676.11 538071.51 0.00 2855.00 TO 3 1/2in Liner End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2855.36 Feet on azimuth 306.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated eonocJ'Á,illips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 4 Wellbore: 8A Wellpath: 8A Ver#3 Date Printed: 21-Jun-2004 OO.Q 0.00 0.00 O.OON O.OOE 4759.00 4529.69 555.08N 475.18W 4771.50 4538.09 561.57N 481.77W 4789.50 4549.99 570.94N 491.49W 5143.40 4798.63 726.43N 688.70W 7188.29 6311.00 1453.82N 1857.13W 7280.24 6379.00 1486.53N 1909.67W 2/100 7343.16 6426.00 1508.64N 1945.18W 7376.15 6451.00 1520.01 N 1963.45W 7411.41 6478.00 1531.99N 1982.71W 7478.33 6530.00 1554.26N 2018.47W 7601.23 6628.00 1593.45N 2081.42W PI. 7703.61 6712.00 1624.37N 2131.09W 7708.42 6716.00 1625.78N 2133.36W 7720.43 6726.00 1629.30N 2139.01W 7750.31 6751.00 1637.94N 2152.90W 7807.12 6799.00 1654.00N 2178.69W 7839.94 6827.00 1663.05N 2193.22W 8039.94 6998.24 1717.66N 2280.95W 1G-08A Top Kup C4 Tgt Rvsd 24 May 04 1 G-08A Hardline Pt#2 26 Mav 04 1911.30N 1245.90W 6310.70 1G-08A Hardline Pt#1 26 Ma 04 978.18N 2172.04W 6310.70 N70 22 0.8391 W149 N70 21 51.6599 W149 539105.40 538184.40 5983875.30 5982937.30 Standard MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2855.36 Feet on azimuth 306.98 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . @fE llU u . ~!Æ~[ß!Æ FRANK H. MURKOWSKI, GOVERNOR A I,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1 G-08A ConocoPhillips Alaska, Inc. Permit No: 204-101 Surface Location: 1323' FNL, 590' FWL, SEC. 29,TI2N, RI0E, UM Bottomhole Location: 2338' FNL, 1647' FEL, SEe. 30, TI2N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom 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 t ness any required test. Contact the Commission's petroleum field inspector at (907) 659- 60 ager). BY ORDER OF THE COMMISSION DATED this~day of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . ... ConocòPhillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com May 21,2004 RECEiVED JUN 042004 Alaska Oil and Gas Conservation Commission 333 West y'h Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 & Commission Re: Application for Permit to Drill, Rotary Sidetrack, Producer 1 G-08A Dear Commissioner: / ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 1 G-08A, a development well. It is planned to abandon the original wellbore then set a CIPB at 5418' MD and place a permanent whipstock on top of the CIBP with the top of the whipstock at 5400' MD. We will then cut and mill a window in the existing 7" production casing with a planned KOP point from the 7" casing is +/- 5430' MD. / The existing 7.0" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform a FIT test! Leak off, which ever comes first, with a required minimum of 14.0 ppg EMW. ** If the FIT/LOT is too low, a squeeze cement job will be performed placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test the production section will be drilled down through the Kuparuk C sand and stop above v the Kuparuk A sand at approximately 7623' MD/ 6629" TVD. An open hole LOT/FIT test wil be performed to 14.0 ppg EMW. This second test will help determine if the Kuparuk C sand will hold the required mud weight to drill through the Kuparuk A sand to total depth of 8048' MD/ 7006' TVD. The logging program will consist of a Triple Combo: Gamma Ray/ Resistivity/ Density/ Neutron for the production ¡/ hole of this well and the well will be completed with a 3-1/2" monobore completion. Contingency drilling plan if the Kuparuk C sand is depleted is to set 5.5" flush joint below the C sand tying it backup inside and cementing inside the 7.0 casing window. Then the 4-3/4" tools and 2-7/8" drill pipe would be picked up and drilled to 8048' MD. A 3-1/2" liner would be run to total depth and tied back up inside the 7" being placed above the 5.5"x 7" liner top. This will isolate the 5.5" x 7" liner top to help ensure quality liner cement job. A waiver to 20 ACC 25. 412.~iS required and hereby requested regarding packer placement more than 200' above the perforations. N ~ 0 If\. CÀ ? \<J0 ð "- ÇL \" , Note: this well is to be temporarily completed as a 3-1/2" mono-bore producer. The spud date is expected to be approximately 6-15-04. If you have any questions or require any further information, please contact Kelly McLure at 265-6059. Sincerely. 9'M~ +'/ /4J, fA CJAP5 Randy Thomas l 1 . GKA Drilling Team Leader 0 RIG 1 N A L . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R E C E i\/E [) . h/~ PERMIT TO DRILL 20 AAC 25.005 JUN 04: /004 1 a. Type of Work: Drill D Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Redrill~ 1 b. Current Well Class: Stratigraphic Test 0 . EXP:~:~C:~ &v~~!ieW~~ 1î , C!Jn::" CO~~~o~: 8 5. Bond: ~ Blanket U Single Well ffW'én Nal'Í1e and Number: Bond No. 59-52-180 1 G-08A 6. Proposed Depth: 12. Field/Pool(s): MD: 8048' / TVD: 7006' .; Kuparuk River Field 7. Property Designation: P.O. Box 100360 Anchorage, AK 99510-0360 4a. location of !el~wmmental Section): Surface: 1323'~, 590' FWL, Sec. 29, T12N, R1OE, UM / Top of Productive Horizon: 2470' FNL, 1314' FEL, Sec. 30, T12N, R1OE, UM ,/ Total Depth: 2338' FNL, 1647' FEL, Sec. 30, T12N, R10E, UM j 4b. location of Well (State Base Plane Coordinates): Surface: x- 540361 / y- 5981970 ALK 25640 8. land Use Permit: Kuparuk River Oil Pool 13. Approximate Spud Date: 6/15/2004 ALK 2571 9. Acres in Property: 2459 14. Distance to Nearest Property: 2338' 10. KB Elevation 15. Distance to Nearest 01 Zone- 4 (Height above GL): 30' Rig RKB feet Well within Pool: 16- 5) ß31 ' "5-( fI? ,< 17. Anticipated Pressure (see 20 MC 25.035) v ø' ¿ .~. Max. Downhole Pressure: 4027 psig / Max. Surface Pressure: 3288 psig Setting Depth Quantity of Cement Top Bottom c. f. or sacks length MD TVD MD TVD (including stage data) 16. Deviated wells: Kickoff depth: 5400 18. Casing Program Size Hole Casing , ./ ft. Maximum Hole Angle: SDecifications Weight Grade Coupling 7" 3.5" 9.3# L-80 SLHT 2798' 5250' 4832' 8048' 7006' 287 sx LiteCrete 19 Total Depth MD (It): 8715' Casing Structural Conductor Surface Intermediate Production Liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) 6957' (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 8128' 6522' MD rvD 80' 80' 2232' 2232' 8698' 6944' Length Size 80' 16" 2143' 10-3/4" 8609' 7" Cement Volume 265 sx AS II 1300 sx ASIII, 250 AS I 1140 sx Class G, 250 sx ASI Perforation Depth MD (ft): 8091'-8163',8187'-8192',8195'-8199', 8440'-8454', 8470'-8493' 20. Attachments: Filing Fee 0 BOP SketchD Drilling Program0 Property Plat 0 Diverter Sketch 0 Seabed Report D Perforation Depth TVD (ft): 6495'-6547', 6564'-6567', 6570'-6572', 6750'-6760', 6772'-6789' Time v. Depth Plot U Shallow Hazard Analysis Q Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kelly McLure @ 265-6059 Printed Name ,_.._~andY Tho}flas h. etc· . Title Kuparuk Drilling Team Lead~er Signature ':::: ?'"\ // ÁÝ... ./ _ Phone Date £. /. I.( J...JU /( (./L/~..../ 7c:Y'l4C;.;r 'I ~ PreDarp" h. "h"rnn AI'-~/Jn-Drflk" Commission Use Only Permit Approval Permit to Drill Number: ,2óL/- /ûj 50- 02-51-2D'ð t.f9-0j, Date: Conditions of approval: Samples required 0 Yes ~ No Mud log required ~s ~ No ~rogen sulfide measures ~Yes 0 No Directional survey required )¥1 Yes 0 ~o Othe, V:;1Yi¡'-'1 ß() ~ ~-'I · $'qX\~, o.Ç\~s-á~..~"":,'w \:;\~ "'~ A_'" l1 ~ ~ COMMISS"N'R :::::'~;KJN "." ~ 1;/ ðf Fo~ ~ "",<::'2/2003- 0 R , GIN A L / tubm. L ""pi".,. API Number. See cover letter for other requirements v . . Application for Permit to Drill, Well 1 G-08A Revision No.1 . Saved: 3-Jun-04 Permit It - Kuparuk Well 1 G-08A Sidetrack Application for Permit to Drill Document Table of Contents 1. Well Name......................................................................... ........................................ 2 Requirements of 20 AAC 25.005 (f) .......................................................................................................2 2. Location Summary................................................................................................... 2 Requirements of 20 AAC 25. 005( c)(2) ...................................... ..................................................... ........ 2 Requirements of 20 AAC 25. 050(b) .............................................................. ............... .......................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ........................................................................... ........................ 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program............................................................................. 3 Requirements of 20 AAC 25.005(c)(6) .......................... ......................................................................... 3 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25. 005( c)(7) ..................................... .......... .................................................... 4 8. Drilling Fluid Program .............................................................................................4 Requirements of 20 AAC 25.005(c)(B) .... ............................................... ....................................... ......... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 1 O. Seism ic Analysis................ ....................................................... ....................... ........ 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................ ..... ..... .......... 5 12. Evidence of Bondi ng ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ............................................................................ .................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 ORIGINAL 1G-DBA PERMIT IT. DOC Page 1 0(6 Printed: 3-Jun-D4 · . Application for Permit to Drill, Well 1 G-08A Revision No.1 Saved: 3-Jun-04 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Discussion of Loggi ng Program ............................................................................. 5 16. Attachments.. ........... ....... ................................ ...... ...... ......... ..................... ....... ........ 6 Attachment 1 Drilling Program................................ .............................................................................. 6 Attachment 2 Directional Plan.... ....... ......... ............... ..... ......... ........... ....... ............. ..... ........6 Attachment 3 Well Schemaics.... ..... ......... ............. .......... ......... ........ ... ...... ...... ..... .......... .....6 1. Well Name Requirements of 20 AAC 25.005 (f) Eik7J well must be identified by a unique name designated by tile operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branche:,~ eai.7J branch must sirl7llady be identífìed by a unique name and API number by adding a suffix to the name designated far the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as lG-08A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commis'Sion and Identified in the application: (2) a plat identifying the property and the property~<; owners and showing (A)the coordinates of the propose:d location of the well at the surface, at the top of each objective formatiof/,. and at total depth referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective fomlation and at total depth; Mr L 590' FWL Location at Surface NGS Coordinates Northings: 5,981,970 Sec 29 T12N R10E UM RKB Elevation 89.0' AMSL Pad Elevation 57.6' AMSL ./ Eastings: 540,361 Location at Top of Productive 2470' FNL, 1314' FEL, Sec 30, T12N, R10E, UM Interval Ku aruk C-4 Sand NGS Coordinates Northings: 5,983,447 Eastings: 538,444 ./ 7323' 6379' 6290' Location at Total De th 2338' FNL NGS Coordinates Northings: 5,983,577 Eastings: 538,110 1647' FEL Sec 30, T12N R10E UM Measured De th RKB: Total Vertical De th, RKB: Total Vertical De th, 55: 8048' 7006' 6917' and (D) other informatkJn required by 20 AAC 25.0S0(bX Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the applÍLation for a PemJit to Drill (FOI7n 10-401) must (l) include a p!a~ drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores witliín 200 feet of any portion of the proposed well,: Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those: well~ to the extent tbat those names are known or dL-;coverabfe in public records, and show that each named operator has been furnished a copy of the application by certified mail,· or (8) state that the applicant is the only affected ov,¡ner: ORIGINAL 1G-OBA PERMIT IT. DOC Page 2 of 6 Printed: 3-Jun-04 · . Application for Permit to Drill, Well 1 G-08A Revision No.1 Saved: 3-Jun-04 The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the followli¡g Item~ except for an ¡tem already on file with the commission and Identíf!ed in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035; 20 MC 25.03fi or 20 MC 25.030 as applicable; Please reference l1"x SM BOP schematics on file for Nordic 3. 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 fbllowlng item~ except for an Item already on file with the commission and Identífìed In the application: (4) Information on drilling hazards; including (A) the maximum downhole pres...çure that may be encounterect criteria used to determine It, and maximum potential surface pressure based on a methane gradient; ./ U., tp ~\--\"'-.J Max reservoir pressure for 1G-08A is ~ 4000 psi at 6637' 1VD, 0.60 psi/ft gas gradient of 0.11 psi/ft or 10.46 ppg EMW. The maximum potential surface pressure (MPSP) while drilling 1G-08A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6712' 1VD: MPSP =( 6712 ft)*(0.60 - 0.11 psi/ft) = 3288 psi v (B) data on potential gas zones; KOP is between the C-85 and C-80 markers, in the Hue shale. The well bore is not expected to penetrate any gas zones between KOP and TD. ;/ And (C) data mnæming potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential sticking; 1. The first potential hazard is the LOT at the window. It is planned to prform a LOT/FIT of at least 14.0 ppg after milling the window in the 7.0" casing. This should be attained for kick tolerance. 2. A second LOT/FIT test will be performed to 14.0 ppg EMW at 7623' MD/ 6629' 1VD prior to drilling the Kuparuk A sand to test the strength of the Kuparuk C sand and kick tolerànce prior to drilling into it. 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 item~ except for an ¡tem already on file with the commission and Identified in the application: (5) a description of the procedure for conductli¡g formation Integrity tes~ as required under 20 AAC 25.030(f); A procedure is on file with the commission for performing LOT's. For 1G-08A the procedure will be followed after milling the window, with one exception. The formation at the window depth will be pressured until leak-off occurs or to 13.0 ppg EMW, which ever comes first (see step 6 in the procedure). 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pe¡m¡t to Dn!1 must be accompanied by each of the following items; except for an item already on file w¡th the commission and identified Ii) the application: (6) a complete proposed msing and cementing program as required by 20 MC 25.030, and a description of any slotted Ilne~ pre- perforated Ilne~ or SGTeen to be installect· ORIGINAL 1G-OBA PERMIT IT. DOC Page 3 of 6 Printed: 3-Jun-04 . . Application for Permit to Drill, We1l1G-08A . Revision No.1 Saved: 3-Jun-04 Casina and Cementing Program lG-08A I Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program Oriainal Well bore lG-08 7" 8-1/2 26 L-80 BTC-Mod 28'/28' 8698/6944 Estimated Original TOC = 7476' MD no cmt at window 3-1/2" 8-1/2" 9.3 L-80 EUE 8 11104' MD 13650/6066 liner RD 3-1/2 8-1/2" 9.3# L-80 8RD EUE 30'/30' 11154/5102 Packer/PBR w/ wireline entry Tubing MOD guide stung below the ZXP lG-08A Long String Case 3-1/2" 7" 9.3# L-80 SLHT 5250' MD 8048'/ 7006' 287 sx 12.5 Lite Crete Class liner G, 2.02 fe/sk (TOC 150' abovetop of window) 3-1/2 7" 9.3# L-80 8RD EUE 30'/30' 10530'/6776 Packer/PBR w/ wireline entry Tubinq MOD gUide stung below the ZXP lG-08A Sidetrack Top Set CONTINGENCY Window 8-1/2" 26# L-80 BTC-Mod 18' 30'/30' 5400'/ 4917' Squeeze window if In the 7" insufficient FIT/LOT Casinq 5.5" 7" 15.5# L-80 Hydril 2473' ~MD 7623'/ 6629' 135 sx 12.5 Lite Crete, 2.02 flush jt 511 r; -'" fe/sk (TOC 150' abovetop of ;-:¡<'U __ v'_J liner) 3-1/2" 7" 9.3# L-80 Hydril 2798' ·<;\5U 8048'/7006' 117 sx 12.5 Lite Crete, 2.02 liner 511 ~O'MD fe/sk (TOC 150' abovetop of liner) 3-1/2 7" 9.3# L-80 8RD EUE 5250 30'/30' 5250' MD Packer/PBR w/ wireline entry Tubinq MOD guide stunq below the ZXP * This is a mono-bore completion requiring a waiver of ACC 20.25.412 p,J: 6 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Penmt to Drill must be accompanied by each of the fo/lowing item~ except for an item a/ready on file with the commission and identified in the applicalìon: (7) a diagram and desaiption of the divelfer ::'jstem as required by 20 MC 25.03~ unless ttJis requirement is waived by the commission under 20 MC 25.035(11)(2)/ This rotary sidetrack will exit pre-existing casing and drill new hole at ± 5430' MD. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An applk:â!íon for a PermIt to Drill must be accompanied by eaLTI of the following item~ except for an item a/ready on file with ó'le commission and identified in tile application: (8) a drilling fluid progralT& inäuding a diagram and desCliptton of the drilling flUId system, as required by 20 MC 25.033/ ORIGINAL 1G-OBA PERMIT IT. DOC Page 4 of 6 Printed: 3-Jun-04 · . Application for Permit to Drill, Well 1 G-08A Revision No.1 Saved: 3-Jun-04 SOd t k H I LSND d rt" I e rac oe mu Drope les /nitial Drillout Top Kuparuk C Top Set Top Kuparuk A TD Pretreat LCM Depth Density (ppg) 9.8 10.0 10.3 11.4 11.7 Funnel Viscosity 44 - 52 44 - 52 42-50 42 - 50 42 - 50 (seconds) Yield Point 25 - 30 25 - 30 25 - 30 25 - 30 25 - 30 (cP) Plastic Viscostiy (lb/100 11 - 20 11 - 20 15 - 24 15 - 24 18 - 26 sf) 10 second Gel Strength 8 - 10 8 - 10 10 - 14 10 - 14 11-16 (1M 00 sf) 10 minute Gel Strength 10 - 13 10 - 13 12 - 15 12 - 15 12 - 18 (1M 00 sf) pH 9.0 - 9.5 9.0 - 9.5 9.0 - 9.5 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <6 <6 <5 <5 <5 Solids (%) 5 - 10 5 - 10 9 - 14 9 - 14 12 - 16 v Diagram of Nordic 3 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 lor a Permit to Drì!1 must be aŒompanied by each of the following item!i¿ except for an item already on file wIth the commi!>'Sion and identified in the application: (9) for an exploratory or stratigrapf1ic test wel¿ a tabulation setting out the depths of¡xedicted abnormally geo-pressured strata as required by 20 MC 25:0:13(1)/ N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Pelmlt to Dn!1 must be accompanied by each of the following Item~ except for an Item already on file with the commission and identitied in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 MC 25.061{a)/ N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Dn!1 must be accompanied by each of the following item~ except for an item already on tile with the commission and identitied in the application: (11) for a well drilled from an offshore platform, mobJle bottom-founded structure, jack-up rig, or floating drilling vesse¿ an analysis of seabed conditions as required by 20 MC 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 tlie lollowing item~ except for an item already on tile with the commission and ident/t7ed in the application: (12) evidence sllowíng tllat tile requirements of 20 AAC 25: 025 {Bondíng}fJave been met/ Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 1G-OBA PERMIT IT. DOC Page 5 of 6 Printed: 3-Jun-04 · . Application for Permit to Drill, We1l1G-08A Revision No.1 Saved: 3-Jun-04 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items; except for an Item already on file with the commis:.7on and identified in the application: 1. See attachment 1, and refer to Attachment 3, Well Schematics. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dlill must(; be accompanied by each of the fol/owing items; exœpt for an item already on file with the commission and identified in the app/kation: (14) a general description of how the operator plans to dispœ;Y3 of drilling mud and cuttings and a statement of wl7ether the operator intends to request authorization under 20 AAC 25.080 for an annular di::;posal operation in the well.; Waste fluids generated during the drilling process will be disposed of by transporting to KRU's, 1R-18 Class II disposal well. t/ 15. Discussion of Logging Program ~. C:<~, vC/j /~-I4-r. 16. Attachments: Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 2 Well Schematics ,~z 6, 8- öf ORIGINAL 1G-OBA PERMIT IT. DOC Page 6 of 6 Printed: 3-Jun-04 . . We1l1G-08A Revision No.1 Saved: June 1, 2004 lG-08 Drilling Proaram Pre-Rig Well Work: 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. Have DHD crew PT tubing and casing packoffs. Cycle lock down screws and pressure test OA. 3. Slickline: Drift and tag tubing restriction at 7127' MDRKB. 4. Rig up CTU and cement unit. RIH t07120' and squeeze away cement into to the open A and C sand intervals. Bring cement to 7050' and jet out excess. 5. Slickline: Wait 24 hours and tag TOe. Pull DV at 6681' and circulate well to seawater. Pressure (CMIT) test to 2000 psi for 30 minutes (Call AOGCC to witness tag & CMIT) 6. Freeze protect well with diesel. 7. Eline: Chemical cut tubing 50' above TOC (approx. 7000'). 8. Set BPV and VR plug. Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. Prior to moving rig over well check handover form that BPV has been installed. 2. MIIRU Nordic 3. Check IA & OA for pressure. Record on IADC report 3. PU 4.0" DP and rack back 4. Take on seawater in pits. Pull BPV & VR plug. RlU on tree and circulate out freeze protect fluid from tbg thru choke until clean seawater returns are observed at surface. Run and set BPV again. 5. Take KB measurement and note on morning report. Install blanking plug. 6. Bleed the IA, inner annulus and remove the tree and adapter. Check landing threads and LDS. 7. Install blanking plug on top of the BPV. 8. NU BOP and test the Top flange of Gen 1 Spool is 11" 3000 PSI BOPE to 250# / 3000# . NEED 11 3000 x 11 SM DSA - ANNULUS VALVES ARE 3000 PSI 9. Cameron or Valve shop to pull BPV. Engage the 3-1/2" tubing with joint and LID the tubing hanger. (If unable to use a joint to screw in we need to use a spear from Baker Fishing) 10. LD two joints tbg and run a storm packer approximately 60' from surface in the 7.0" casing. Bleed annulus pressures to Zero and leave open to tank while pulling tubing spool and changing primary seal 11. ND BOP, Pull the tubing head and packoff (btm packoff is the primary seal) 12. Remove the slip packoff (primary seal) and replace with the modified packoff. 13. Replace the spool & packoff with the McEvoy Gen 3 (11" 3000 x 7-1/16" x SM) 14. NU Bop's to the 7", 5000 psi flange & test 250 psi & 5000 psi. 1 1G-OBA DRILLING PROGRAM.doc ORIGINAL Printed: 2-Jun-04 . . We1l1G-08A Revision No.1 Saved: June 1, 2004 15. POOH wI storm packer. PU mill and bit scraper RIH to PBTD. C&C. POOH. RU wire line set a CIBP inside the 7" casing at +1- 5418' MD based on casing collar depth. (Note: CIBP must be;::: 2.0' above a casing collar and;::: 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. Test okay, go to next step 16. Displace the hole with new 9.8 ppg LSND mud. 17. PU and RIH with Baker's "WindowMaster" whipstock system, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Orient and set the whipstock using the MWD with the top of the whipstock set at +1- 5400' MD. End Of Decomplete Start Sidetrack 18. Shear off the whipstock. Displace the 7" casing and the pits with LSND mud. Mill the window in the 7", 26#, L-80 casingat 5400' MD/4917' TVD, and continue milling until the upper watermelon mill is outside the casing: ~ 29'. After reaming through the window to eliminate burrs and other irregularities. Perform a FIT/LOT to 14.0 ppg EMW with a Minimum acceptable EMW = 13.0 ppg POOH. The 13.0 ppg Minimum includes kick tolerance down to the C sand. ¡/ 19. Drill the Intermediate hole section with a 6-118" pilot bit and a Hughes RWD (ream while drilling) Hole Opener to 7.0" to the contingency top set depth of 7622' MDI 6628' TVD between the C sand and A sand intervals. Take an open hole FIT test to 14.0 ppg EMW. This FIT/FIT is to see if C sand will hold. When the hole takes the FIT 14.0 ppg EMW then we drill ahead. (IF NEED TO TOP SET SKIP DOWN TO CONTINGENCY SECTION) 20. Assuming the Kuparuk C sand held a 14.0 ppg FIT at approximately 7623' MD/6629' TVD, continue drilling to TD through the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 8048' MD17006' TVD. At TD, circulate bottoms and make a wiper trip up inside the window. RIH to TD. Circulate and condition the hole to run the liner. POOH. 21. R/U and run the 3-112" liner to TD. The required overlap is ~ 150': TOL = approximately 5250' MD. Reciprocate the 3-112" SLHT liner while circulating and cementing. RlU Dowell and prepare to cement the liner. 22. Cement liner as per cement program bringing the cement up inside the window. Release from liner. Set the packer. 23. Displace the well above the TOL with seawater and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 24. RlU and RIH with the 3-112" tubing tag the TOL. Set packer & shear out of PBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. 25. Install a TWC. ND BOPE. NU and test the 3-118" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve. Install a BPV. RID and MlO Nordic 3. Post-Rig Well Work: 1. Pull the BPV. RlU SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. RID SLU. 3. R/U E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. RID E-Line. 5. Install new "s" riser and replace the well house(s). 2 1G-OBA DRILLING PROGRAM.doc Printed: 2-Jun-04 ORIGINAL . . We1l1G-08A Revision No.1 Saved: June 1, 2004 CONTINGENCY ONLY Top Set 26. If insufficient FIT test is achieved between the C sand and A sand interval then a top set will be needed. 27. PU and run 5.5" flush joint casing to the top set depth of 7622' MD/6539' TVD. Cement as per the contingency cement program. 28. P/U a 2-7/8" DP and the 4-3/4" PDC bit, MWD, L WD, non-mag flex collars, jars, and DP as required. 29. Test casing to 3500 psi, drill cmt, float equip, drill 20' new hole and perform an FIT/LOT to 14.0 ppg EMW to ensure shoe will hold TD MW with ECD's. 30. Drill ahead, (Baker Inteq Directional Program attached). Maintain the LSND mud properties as per the MI program. The MW should be 11.4 ppg at the Top/A6: 7718' MD/6712' TVD. 31. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 8048' MD, 7006' TVD. At TD, circulate bottoms and make a wiper trip. RIH to TD. Circulate and condition the hole to run the liner. POOH. 32. RlU and run the 3-1/2" liner from TD up to above the existing 5.5" flush joint liner top. The top of the 3-1/2" hydril 511 liner will be approx 5150' MD. The required overlap is;::: 150': TOL = 5150' MD. (Th second liner will be approximately 100' above the top of the 5.5"x 7"liner top. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 33. Cement liner as per cement program. Release from liner. Set ZXP. 34. Displace the well above the TOL with seawater and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 35. RlU and RIH with the 3-1/2" tubing tag the TOL. Set packer & shear out of PBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. 36. Install a TWC. ND BOPE. NU and test the 3-1/8" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve. Install a BPV. RID and MlO Nordic 3. Post- Rig Well Work: 6. Pull the BPV. R/U SLU. Drift and tag to PBTD. 7. Dummy-off the GLM. RID SLU. 8. RlU E-Line. Run cement bond log inside the liner. 9. Perforate the Kuparuk as directed. RID E-Line. 10. Install new "s" riser and replace the well house(s). 3 1G-OBA DRILLING PROGRAM.doc Printed: 2-Jun-04 ORIGINAL )w.~ ConocóPhillips . ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit, North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 8A Wellpath: 8A Ver#2 Date Printed: 24-May-2004 ,&.. BAKlR HUGHES INTEQ Wellbore Name 8A .. I Created 13-Mav-4Q1t4 . _..__._-_.."~~_..---_.. : Last Revised I 24-Mav-2004 --_.~--~--_._._- Government 10 Revised 13-Ma -2004 Name slot#8 5981970.9368 v Latitude N70 21 42.0428 Lon itude W149 40 19.6737 East 585.67E Installation Name Pad 1G -3 .... Eastino ..... .. ... -. 539782.8874 No[\IJino 598.9644.6237 ~-~- Gº.9rd Svstem Name __ North Alionment ...J AK-4 QoJiQ8.I!::LAMERICAN DATUM 1927 datu.__ Truel -~- --------...-..- Field Name Ku aruk River Unit Eastin 487754.6208 I Northin 5948985.8206 Coord S stem Name AK-4 on NORTH AMERICAN DATUM 1927 datu ---------..,.-.----.- .~"-. --.-...-,.-.-- ---. '.'- _._._~--_.~_.~_.._- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2766.19 Feet on azimuth 305.82 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ConocoPhillips Alaska, Inc.,slot #8 Pad 1G, Kuparuk River Unit,North Slope, Alaska .,../ ConocòPhillips Well ~th Re(:)ort_ MD[ft] Inc[de fi[deg] TVD[ft] g] I , I 5400.00 55.43 316.30 541:1.50 57.06~ 315.18 5430.50 57.06, 315.18 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6094.49 6100.QQ 6200.0J> . 6300.00 6400.00. . 6500.00. 11600.00 6700.00 68JtO.00 6900.00 7000.00 7100.00 7200.00 .J238.9!:! 7300.00 7323.50 7"381 .49 7400.00 7:411.99 J423.50 7444.69 7500.00 7506.96 7523.50 7600.00 7623.50 7700.00 U18.55 7723.10 7723.5Q 7734.46 1762.75 7800.00 ]816.67". ~7823.50 .. 7847.8!t 7900.00 8000.00 54.72 313.38 51.39 310.59 48.14 307.54 44.98! 304.16 41.93 L 300.40 39.02 296.17 36.43 291.67 36.43;191.67 36.43 i .291.67. 36.43 ;1fJ.1.67 36.43 291.67 36.43 291.67 36.43! 291.67 36.43' 291.67 36.43 291.6J 36.43 291.67 36.43, 291.67 36.43 í 291.67 36.43 291.67 36.43 ;1~1.67 36.43 291.67 36.43, 291.67 .. ~---+----~ 35.27 I 291.67 3.1.90 I 291.67 34.66 i 291.67 ~4.431 291.67 ~3.4.00 1 291.67 32.90 I 291.67 32]6 í 291 &7 32.43 291.67 30.90 291.67 30.43 291.67 28.90 291.67 ;18.53 2Q1.67 28.44 291.67 28.43 I 291.67 28.:1.1 291.f3] ;1].64 291.67 Station Station ! Dogie l.vertical II' StaÚ;;-;;- Comment Position(Grid Position(Grid' g i Section[ North) East) [deg/1 ft] I OOft ¡ 5~82889.85 . 539529.56 I 0.90 1219.86 Tor> Whipstock Face 5982897.211 ~ 539522.27 ' 15.00 ! 1230.15ß-ª-se Whipstock Face. End of,ß,IJildlTurn I 5982907.91 539511.56 .~.OO 11245.1~iEnd Milled Openhole, DireCti~~~~TOOI KO~j 5982947.87 539470.17 4.00 1302.32 5983001.02 539410.53 4.00 1382.01 5983048.83 539351.05 4.00 1458.31 5983091.06 539292.03 4.00 1530.85, 5~983127.51 ~~39233.74 4.00. 1599.27' 5983158.00 539176.49! 4.00 1663.24 59&,3181.19 539123.58 4.00 1719.32 End of 4/100 curve. End ofDroplTurn í ~~~~;~~:~~ ~j~6~~:~~ ~:~~ ~I~~::~! ~~__~~~~ ~~. ~ 59832;15.64 539009.94: 0.00 ! 183~- .. I ¡E~:~:~ ~~J!~: ~.~~ : i:§~I=· ~ .. .···1 5983312.15 538788.76'1 0.00 2064.55 'j .5983333.78.538733.47 I 0..0.0 2121.57 5983355.41 538678.17 0.00 2178.58' 5983377.03 538622.88 I 0.00 2235.60 5983398.66 538567.59 0.00 2292.61 5983420.29 538512.29 0.00 2349.621 5Q¡¡:3428.72 53.8490.73 0.00 .2371.851 To ~lS:uparuk D 5983441.92 538457.00, 0.00 I 2406.64 5983447.00 538.4....44.00 1 0.00 124..20.04. Top C4 Target, Drop 2/.100, 1G-08A Top K ~ . I 1---..-) C4 Tat Rvsd 2.4 Mav04. End of HOld..--------j 538412.3JLJ 2.00 12~5;1,~ C3..__. ~.------.J ~;¡~::IJ: l~r~:1c2= .- .~ ~~:~¿~:;~ I ;:~~ : ~~~:~~ C1 -.~~~-.----= 538347.03 I 2.00 2520.03' B 538338.73'1 2.00 ,2528~58 538301.34 '2.00 2567.14, 538290.18 2.00 2578.64' 538254.92 2.00 2614.99 538246.63 : 2.00 í 2623.55 A6 538244.61 2.00 "2625.63! A5 538244.43 2.00 2625.6.2~_ _'--j 538239.59 i 2.00 ! 2630.!UJA4.~ .... ._~ ~j~{~~:~~~~:~~i~~:~:~~1 A3.. ~ I '53.8204.37 2.0Ò!.2667.12IA2~., ..1 !138201.54 , 2.0º11 2670.04!.~j .5.38191.51 1 2.ºº. 2680.37' Tor> Miluveach. En<:! 2/100 DroPL~.¡ 538170.29 lõ.oo .2702.26 53812!:!.56.: 0.00 i 2[44..261 Vertical I North[~ft] Depth SS ' I I 4917.55 4924.50 4934.28 4828.55 923.48N 827.02W 4835.50 ! .930.92N ~8j4.27W 4845.29 ¡ 941.64N I 844.92W 59834!19.37 5983463.24 5983495.73 598~4.ºª.11 5983472.45 5983483.56 5983484.~3 5983488.17 5983502.80 5983507.16 5983520.95 5983524.20 5983524.99 5983525.06~ 5983526.95 5983531.78 5983537.99 59JI~~540.73 5!t8.3541.83 5983545.75 5983554.06 5983569.99 . PROPOSAL LISTING Page 2 Wellbore: 8A Wellpath: 8A Ver#2 Date Printed: 24-May-2004 4973.26 5033.36 5097.95 5166.71 5239.30 5315.37 5390.12 5394.1)5 5475.0.2 5555.48 .5635.94~ . 5716.40~ 5796.86. 5877.32 5957.78 6038.24 6118.71 6199.17 6279.63 6311.00 6360.09 6379.00 ---, ~-I -~._.~..~_. All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2766.19 Feet on azimuth 305.82 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL ")w/ ConocòPhíllips -- ConocoPhillips Alaska, Inc.,slot #8 Pad 1G, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 3 Wellbore: 8A Wellpath: 8A Ver#2 Date Printed: 24-May-2004 Well ath Rep()rt MD[ft] Inc[de iAzi[deg] TVD[ft] g) , V~rtical forth[ft] East[ft] Depth SS i Station St;t~~ Vertical I StationCom~-~nt Position(Grid position(Gridg -~.- Section[¡ North) East) i [deg/1 ft] I 100ft 5983577.62 538110.05 0.00 I 2764.37 TD, 3 1/2in Liner 8047.89 25.94 291.67 7006.85 6917.85 1618.95N¡2242.94 All data is in Feet unless otherwise slated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2766.19 Feet on azimuth 305.82 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL re.. BAkER MUGHES INTEQ I I conocriPhillips - ConocoPhillips Alaska, Inc.,slot #8 Pad 1 G, Kuparuk River Unit,North Slope, Alaska . PROPOSAL LISTING Page 4 Wellbore: 8A Well path: 8A Ver#2 Date Printed: 24-May-2004 r&l. BAklER HUGHIS INTEQ Comments -- -- MDrftJ TVDfftJ E~strftJ Northlftl i Comment --~ l --- --- I 5400.00 , 4917.55 827_02W 923.48N TOD WhiDstock Face ; .--.--- 5412_50 4924.50 834.27W 930.92N Base Whinstock Face r----M3O.5O 4934.28 844_92W 941.64N Ene! Milled ODenhole~ Directional Tool KOP -- 6094.49 5390_12 1231.46W 1217.03N i End of 4/190 Curve ----- 7238.99 6311.00 1863.03W 1467_99N TOD KUDaruk D 7323.50 6379J)--º-- _ 1909.67W 1486_53N TOD C4 Target. DroD 211-00 I 7381.49 ! 6426.00 1941.22W 1499.06N C3 7411_99 i 6451.00 1957.47W 1505.52N C2 7444_69 6478.00 1974_60W 1512_33N C1 7506_96 6530.00 2006.44W 1524.98N IB 7718.55 6712.00 2106_64W 1564.79N A6 __"_nO_.' I 7723.10 6716.00 2108.66W 1565.60N A5 , 7734.46 6726.00 2113.67W 1567'.59N A4 H f-_llJi2.75 I 6751_00 2125.913W 15]2.48N A3___ r_1M!U57 i 6799.00 2148_81W 1581,55N A2 -- 7847.89 i 6827.00 2161.64W 1586.65N TOD Miluveach. End 2j100 DroD - --- -- 8047_89 7006_85 2242_94W 1618_95N i TD. 3 1/2 Liner PI- ..- ... --.. ----~-- Diameter in End\nEast[ft] Wellbore 12 1/4 81/2 61/8 9.10E 2514.12W 2242.94W 8 8 8A 9 5/1:1" Casing 7_000in Casin 3 1/2in Liner Casings Name - iTop ~L L__.Q._º-P... ¡ 0_00 5400.00 ¡TOP , TVDrftl I 0.00 0.00 4917.55 Top ~ NorthrftJ --J Eastlftl O_OON L MOE O.OON O.OOE 923.48N 827.02W iShoe . 'MDft 2232.00 8715.00 _ 8047.89 Shoe _TVDrftl _;!..-?31-92 6956.55 7.Q__º-§.85 I Shoe I Northlftl 0.07S I 2864_06N 1618.95N I Shoe Wellbore East ft _J!.10E _. 8 2546.53W 8 2242.94W 8A --~ j --I Latitude N70 21 56.6601 41 15.5249 Surve Tool Pro ram Reference I Survev Name 99862 ~.. PGMS <0-87::¡S;;:-- 664236 Planned _.~~.- . MDlftl 5400_00 8047_89 TVDlftl 4.917.55 7006.85 Survey Tool : Level RoJo! Gvro i ISCWSA MWD i Error Model_~ ~ard --..--J I MWD+SAG - ISCWSA - 28 Jarl i03 OJH _ I All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 307.90 degrees Bottom hole distance is 2766.19 Feet on azimuth 305_82 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL 10 i :::0 ,- (j) :~ ');> -..------...-.........".."..... INTEQ Scale 1 cm = 200 ft -5600 -5200 -4800 ~.. .L~_...L ~] -4400 -4000 -3600 ...1 -3200 -2800 .L _ I 6700 TVD 6400 TVD 6100 TVD 5800 TVD 5500 TVD , 5200 TVD 4900 TVD IT] 6700 TVD 6400 TVD 6100 TVD ',5800 ;VD 5200 TVD ConocoPhillips Alaska, Inc. Conocri'PhilIi ps Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1G Slot: slot #8 Well: 8 Wellbore: 8A reated by' Planner Date plotted: 3-Jun-2004 Plot reference is 8A Ref well path is 8A Ver#2. Coordinates are in feet reference slot #8. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 89.00 ft. ~Iot ~~rthiS aligned to TRUE Norttt.__----" ·"'1 ..- , -2400 East (feet\ -> -2000 -1600 -1200 -800 2800 -400 o 400 800 1200 1600 2000 2400 L. . L_..J c.... I L.._.L ....1 L__L--.J~ ~ Q¡ i I I rn rn 6700 TVD 6400 TVD 6100 TVD 5800 TVD 6700 TVD 6400 TVD 6100 TVD '+ 58000TVD 5500 TVD 5200 TVD 5200 TVD 5500 TVD 4900 TVD 5200 TVD 4900 TVD .'. ~~ 11~J ''\,(\ 4900 TVD " Y,.., 550g1b~q.VD 7000 TVD rn /~ . . 6700 ::r:vD 6400 TVD '. 6100 TVD, '., . 580gJõ~Dfvd! / >/5200:tVD \ .' ../ %lffj~ . 3200 2800 2400 2000 1600 ^ I 1200 , 800 ::T ;; CD - 400 - o -400 en £ -800 ëD o 3 -1200 II N o o -1600 ;::> w/ ConocOPhillips . e ConocoPhillips Alaska, Inc. 8A Ver#2, 8A slot #8, Pad 1 G CLEARANCE LISTING Page 1 Date Printed: 3-Jun-2004 Kuparuk River Unit, North Slope, Alaska Ellipse separations are reported ONLY if BOTH wells have uncertainty data Only Depth and MaQnetic Reference Field error terms are correlated across tie points Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Horizontal Plane clearance calculation for all minima Hole size/CasinQs are NOT included Hole size/CasinQs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.58standard deviations. ClosinQ Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation Name 8~. -~-_.~ Created 13-Mav-2004 _ INTEQ Name Pad 1 G Coord S stem Name 5980644.623 AK-4 on NORTH AMERICAN DATUM 1927 datu Eastin 539782.887 Field NamE:!_._. KuparlJk River LJ~_, Eastin__ i NorthinQ__. Çoord System t-Jame North AIiQnmenL.....J _ 487754.620~_. 59489135.820 AK-4 on NORTH. AMERICAN DATUM 1927 datu True 1 --_.~~~-~-~_._. Clea.rêlì:1ce·.·.St.lml11·~·rY......·..... OffsetT Offset i Offset WellName i We II bore I Slot 8 -----18 . slot #8 15 115 slot #15 9 19 slot #9 4 4 i slot #4 3 3 slot #3 1º--.-----1J'ª____ slot #16 17A 17A Islot#17 Pad 1G 3371.20 7323.5 1 1 ==tSlot#1 Pad 1G 4359.99 _ 7323.5 6A.~+M........slot#6. pad 1G . i 488~Æ-_-7323.5 . 7 . 1*= ".' slot #7 . Pad 1 G==r~ 527~.6 . 7323.5 14 .. .~ 14 .. flot#14 '..pad 1G..'-----+-- 5497.3 .., 7323~.5 10 10 slot #1 0 Pad 1 G i 5511.9 . 7323.5 10 .~. 08 . ·,S.lot#10..·· P.ad.1G ==f--_5591.~ - 7~Ú.5 U___ ~ i slot #13 pad 1 G 6653,2 _ 7323.5 .. 11 . 11 slot #11 Pad 1 G I 6891.5 7323.5 2 i 2A slot #2 Pad 1 G I 7064.55 7323.5 5 5 i slot #S' Pad 1 G 8418.95~i3.5 _.~.~ Offset Structure , .+-.. Pad 1 G Pad 1 G Pad 1 G Pad 1 G Pad 1 G _._._~..- All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig ( Planned Datum 89.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) PoaR l ~el Nhj([orated True Clearance Factor "-1 I i I I -=+=~~ --+'-~1 ! " (:) :::0 - iÚ'} - z: ):> II INTEQ Scale 1 cm = 80 ft -3520 -3360 -3200 ~ 1 _I ~L 4500 TVD -3040 ConocoPhillips Alaska, Inc. , Location: I Field: ~~llation: North Slope, Alaska Kuparuk River Unit Pad 1G Slot: slot #8 Well: S Wellbore: SA -2880 -2240 East (feen -> -2080 -1920 -1760 -1600 -1440 -2720 -2560 -2400 _L 1 1 ~_ L_ I _~L.. _. I 1.___1 ~ I TO LOCATION: , ¡ 2338' FNL, 1647' FEL : I SEC. 30. T12N. R10E I TARGET LOCA nON: 2471' FNL, 1314· FEL SEC. 30, T12N, R10E '- " 4000 TVD ..~ 1_ ___.1 6000 TVD -.., -320 -160 . L "r 2400 2240 L i ~ 2080 1920 1- 1760 1600 ^ I 1440 , ~ - - 1280 m - - 1120 960 Conoc~hnlips Created by : -Píaririe, Date plotted 24:r,¡!iy:2004 f'IOí reference is 8A . Ref well path is 8A Ver#2. Coordinates are in feet reference slot #8. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum Rig Datum: Planned Datum J Rig Datum to mean sea level: 89.00 ft. Plot North is aligned to TRUE North. . _ -1280 -960 -480 -640 -1120 -800 J___L _L._._L.--.J 5500 TVD v~~e \"c:::,c:::, òo\þ. ~~ ~ ---. KOP LOCATION: 2265' FSL, 251' FEL S~~30, T12N, R10E 'f-O?'è>"e e -<.,00\ ~ « «'è>G ~. s\O" ,,'+- ,,~O~~\Ç·RS\O Q\~e se ~~~ O\e, «)'õ--<.,oç e~~ Oç ~~\eÒ ~~Ò 800 en £ iD 640 ~ 0 3 II 480 CO 0 ;::> · ----, ConocoPhillips Alaska, Inc. . Conoc6Phillips e£ iÑ'TiQ" Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1G Slot: slot #8 Well: 8 Wellbore: 8A G TRUE NORTH Created by : Planner Date plotted: 24--r..1aJ~~()()4 Plot reference is SA . Ref well path is 8A Ver#2. Coordinates are in feet reference slot #8. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 89.00 ft. Plot North is aligned to TRUE North. 340 3'50 \6200 o 10 20 200 290 330 30 320 40 310 50 300 60 70 280 80 270 20 90 260 100 250 110 240 120 230 130 220 140 1 0 210 2 0 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ORIGINAL ~ g 4800 II E u 4920 Q) (ij u CI) 5040 5160 5280 5400 5520 5640 - - () () ::. 5760 .c - c. () 5880 C ca (,) 6000 :e () > 6120 () ::s ... l- I 6240 V 6360 6480 6600 6720 6840 6960 7080 7200 ------~e . ConocoPhillips Alaska, Inc. i -tlI: ¡Kiftf- Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1G "--- <b. Top Whipstock Face Base Whipstock Face End Milled Openhole, Directional Tool KOP DLS: 4.00 deg/100ft TANGENT ANGLE 36.43 DEG 1G-08A Top Kup C4 Tgt Rvsd 24 May 04 FINAL ANGLE 25.94 DEG 1080 1200 1320 1440 1560 1680 Scale 1 cm = 60 ft . Slot: slot #8 Well: 8 Well bore: 8A Conoc6Phillips reated by: Planner Date plotted. 24-May-2004 Plot reference is 8A . Ref wellpath is 8A Ver#2. Coordinates are in feet reference slot #8. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 89.00 ft. Plot North is aligned to TRUE North. .<ò Top Kuparuk D Top Miluveach, End 2/100 Drop Top C4 Target, Drop 2/100 C3 C2 C1 B 30.43 2400 2520 2640 2760 2880 3000 · e Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 ORIGiNAL . . 1G-08A Vers2 Grid Report.txt 5097.95 1083.43N 1458.31 EMPTY 5166.71 1125.98N 1530.85 EMPTY 5239.30 1162.75N 1599.27 EMPTY 5315.37 1193.55N 1663.24 EMPTY 5390.12 1217.03N 1231.46w 5983181.19 1719.32 End of 4/100 curve, End of Drop/Turn 5394.55 1218.24N 1234.50w 5983182.39 1722.47 EMPTY 5475.02 1240.17N 1779.48 EMPTY 5555.48 1262.10N 1836.49 EMPTY 5635.94 1284.02N 1893.51 EMPTY 5716.40 1305.95N 1950.52 EMPTY 5796.86 1327.88N 2007.54 EMPTY 5877.32 1349.81N 2064.55 EMPTY 5957.78 1371.73N 2121. 57 EMPTY 6038.24 1393.66N 2178.58 EMPTY 6118.71 1415.59N page 1 539529.56 539522.27 539511. 56 point 539470.17 0.00 0.00 4.00 5400.00 55.43 316.30 4917.55 923.48N 827.02w 5982889.85 1219.86 TOp whipstock Face, Tie on 5412.50 57.06 315.18 4924.50 930.92N 834.27w 5982897.26 15.00 1230.15 Base whipstock Face, End of Build/Turn 5430.50 57.06 315.18 4934.28 941.64N 844.92w 5982907.91 1245.14 End Milled Openhole, Directional Tool KOP, 3D] Kick off 5500.00 54.72 313.38 4973.26 981.82N 886.10w 5982947.87 1302.32 EMPTY 5600.00 51.39 310.59 5033.36 1035.29N 4.00 1382.01 EMPTY 5700.00 48.14 307.54 539351.05 4.00 5800.00 44.98 304.16 539292.03 4.00 5900.00 41.93 300.40 539233.74 4.00 6000.00 39.02 296.17 539176.49 4.00 6094.49 36.43 291.67 539123.58 4.00 6100.00 36.43 291.67 539120.53 0.00 6200.00 36.43 291.67 539065.24 0.00 6300.00 36.43 291.67 539009.94 0.00 6400.00 36.43 291.67 538954.65 0.00 6500.00 36.43 291.67 538899.35 0.00 6600.00 36.43 291.67 538844.06 0.00 6700.00 36.43 291.67 538788.76 0.00 6800.00 36.43 291.67 538733.47 0.00 6900.00 36.43 291.67 538678.17 0.00 7000.00 36.43 291.67 945.46w 5983001.02 539410.53 1004.69w 5983048.83 1063.49w 5983091. 06 1121. 58w 5983127.51 1178.67w 5983158.00 1289.68w 5983204.01 1344.87W 5983225.64 1400.05W 5983247.27 1455.23W 5983268.90 1510.42w 5983290.52 1565.60w 5983312.15 1620.78w 5983333.78 1675.97W 5983355.41 1731.15w 5983377 . 03 ORIG1NAL · e 1G-08A vers2 Grid Report.txt 538622 .88 0.00 2235.60 EMPTY 7100.00 36.43 291.67 6199.17 1437.52N 1786.33w 5983398.66 538567.59 0.00 2292.61 EMPTY 7200.00 36.43 291. 67 6279.63 1459.44N 1841. 52w 5983420.29 538512.29 0.00 2349.62 EMPTY 7238.99 36.43 291.67 6311. 00 1467. 99N 1863.03w 5983428.72 538490.73 0.00 2371.85 TOp Kuparuk D 7300.00 36.43 291.67 6360.091481.37N 1896.70W 5983441.92 538457.00 0.00 2406.64 EMPTY 7323.50 36.43 291. 67 6379.00 1486.53N 1909.67W 5983447.00 538444.00 0.00 2420.04 TOp C4 Target, Drop 2/100, 1G-08A TOp KUp c4 Tgt Rvsd 24 May 04, End of Hold 7381.49 35.27 291. 67 6426.00 1499.06N 1941. 22w 5983459.37 538412.38 2.00 2452.64 C3 7411. 99 34.66 291.67 6451.00 1505.52N 1957.47w 5983465.73 538396.10 2.00 2469.43 c2 7423.50 34.43 291.67 6460.48 1507.93N 1963.53w 5983468.11 538390.02 2.00 2475.69 EMPTY 7444.69 34.00 291. 67 6478.00 1512.33N 1974.60w 5983472.45 538378.93 2.00 2487.13 C1 7506.96 32.76 291.67 6530.00 1524.98N 2006.44w 5983484.93 538347.03 2.00 2520.03 B 7523.50 32.43 291.67 6543.94 1528.27N 2014.72w 5983488.17 538338.73 2.00 2528.58 EMPTY 7623.50 30.43 291.67 6629.26 1547.52N 2063.18w 5983507.16 538290.18 2.00 2578.64 EMPTY 7718.55 28.53 291.67 6712.00 1564.79N 2106.64W 5983524.20 538246.63 2.00 2623.55 A6 7723.10 28.44 291.67 6716.00 1565.60N 2108.66w 5983524.99 538244.61 2.00 2625.63 A5 7723.50 28.43 291. 67 6716.36 1565.67N 2108.84W 5983525.06 538244.43 2.00 2625.82 EMPTY 7734.46 28.21 291.67 6726.00 1567.59N 2113.67W 5983526.95 538239.59 2.00 2630.81 A4 7762.75 27.64 291. 67 6751. 00 1572 .48N 2125.98w 5983531. 78 538227.25 2.00 2643.53 A3 7816.67 26.56 291.67 6799.00 1581. 55N 2148.81W 5983540.73 538204.37 2.00 2667.12 A2 7823.50 26.43 291.67 6805.11 1582.68N 2151. 64w 5983541. 83 538201. 54 2.00 2670.04 EMPTY 7847.89 25.94 291.67 6827.00 1586.65N 2161.64W 5983545.75 538191. 51 2.00 2680.37 TOp Miluveach, End 2/100 Drop, End of Drop 7900.00 25.94 291.67 6873.86 1595.07N 2182.82w 5983554.06 538170.29 0.00 2702.26 EMPTY 8000.00 25.94 291. 67 6963.78 1611.22N 2223.47w 5983569.99 538129.56 0.00 2744.26 EMPTY 8047.89 25.94 291.67 7006.85 1618.95N 2242.94w 5983577.62 538110.05 0.00 2764.37 Assumed vertical to 3101, TD, 3 1/2 Liner Pt., 3 1/2in Liner, End of Hold page 2 ORIGINAL · e o r-0¡ j ì V\-oSL Welt Ipo-'\.L ConocòPhillipsAlaska, Inc. KRU 1 G-08 1G4I8 > API: 500292084900 Well Tvoe: PROD AnQle @¡ TS: 45 dea (cj) 7958 SSSV Type: LOCKED OUT Orig 12/24/1982 Angle @ TD: 41 deg @ 8715 Comoletion: Annular Fluid: Last W/O: 7/8/1984 Rev Reason: GLV DESIGN Reference LOQ: Ref Loa Date: Last Update: 5/12/2003 Last TaQ: 8128 TD: 8715ftKB Last TaQ Date: 11/30/1999 Max Hole AnQle: 57 deQ @¡ 6900 Câšihg...sttihg;';···ALLSTRINGS < ...... .... DescriDtion Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.50 H-40 SUR. CASING 10.750 0 2232 2232 45.50 K-55 PROD. CASING 7.000 0 8698 6944 26.00 K-55 TûbinaStdna..··. rUBING i ........ ..... ·3< Size Too I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 7929 I 6381 I 9.20 I J-55 I BTC 3.500 7929 I 8276 I 6628 I 9.30 I J-55 I EUE 8RD pê¡fo"âtionsSÚmmarv > Interval TVD Zone Status Ft SPF Date TYDe Comment 8091 - 8163 6495 - 6547 C-1 72 12 12/23/198 IPERF 5" Dresser, 120 den DA 8187-8192 6564 - 6567 UNITB 5 12 12/23/198 IPERF 5" Dresser, 120 den DA 8195 - 8199 6570 - 6572 UNITB 4 12 12/23/198 IPERF 5" Dresser, 120 den DA 8440 - 8454 6750 - 6760 A-4 14 12 12/23/198 IPERF 5" Dresser, 120 den DA 8470 - 8493 6772 - 6789 A-4.A-3 23 12 12/23/198 IPERF 5" nr..""", 120 den DA GášiLiftiMándtelšJVálves ii > I St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr TVDe Run Cmnt 1 1944 1944 Cameo KBUG DMY 1.0 BK 0.000 0 5/4/2003 2 3606 3597 Cameo KBUG DMY 1.0 BK 0.000 0 5/4/2003 3 5212 4810 Cameo KBUG DMY 1.0 BK 0.000 0 5/4/2003 4 5279 4849 Cameo KBUG DMY 1.0 BK 0.000 0 5/4/2003 5 6613 5601 Cameo KBUG DMY 1.0 BK 0.000 0 5/5/2003 6 6681 5638 Cameo KBUG DMY 1.0 BK 0.000 0 3/9/1990 7 7572 6142 Cameo KBUG DMY 1.0 BK 0.000 0 7/8/1984 8 7640 6185 Cameo KBUG DMY 1.0 BK 0.000 0 3/18/1996 (1\ 1. Extended Pka PrôduCtiôn·.·MâhdrelslValves St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr TVDe Run Cmnt 9 7960 6403 Cameo KBUG DMY 1.0 BK 0.000 0 12/2/1999 Closed 10 8029 6451 Cameo KBUG DMY 1.0 BK 0.000 0 1/30/199 Closed 11 8211 6581 Cameo KBUG CV 1.0 BEK 0.000 0 9/26/1999 Ooen Othêt IUåšêôqiD. ete:; .~. JEwELRY Depth TVD TVDe Description ID 1901 1901 SSSV Cameo TRDP-1A -locked out 3/85 2.813 7127 5885 SLlPSTOP UNABLE TO PULL SLlPSTOP 5/3/2003 2.992 7900 6360 SEAL Bot G Seal Assvw/Otis X Profile 2.813. 2.813 - 7923 6377 PKR BOT 'HB' 3.000 - f-- 8239 6601 PKR BOT '2-B' 3.000 - f-- 8262 6618 NIP Cameo 'D' Nioole NO GO 2.750 - f-- 8275 6628 SOS Brown 2.992 - f-- - f-- 8276 6628 TTL 2.992 - f-- Fish.. ¡SH .......... >.....i< - f-- > - f-- DeDth I DescriDtion I Comment 8430 11"CV I Dropped in Hole II 8518 ITAILPIPE w/ BOT 2B PKR IJUNK Left in Hole GenerâlNoteš < i< Date Note 3/18/1996 OV pulled arom GLM (cj) 7640' was flow-cut in half 9/21/1998 Leaks found at GLM (cj) 7640', 7690' and 8211' 9/27/1999 TbQ +/- 6570 - 7600 is tinht. 2/19/199 FCO to 8520' (fish \ - - - - ;;;;;; - , = - - - - - - - ORIG INAL 1G~08A PROPOSED SI.TRACK Producer COMPLETION - Planned Longstring Case 10-3/4" K-55 csg @ 2232' MD I 2232 TVD 3-1/2" X 7" Liner Top 5250' MD/4832 TVD Sidetrack KOP @ +1- 5400' MD, +1- 4917' TVD Baker "K-1" CIBP @ +1- 5418' MD Original Wellbore 7" 26# L-80 shoe at 8698' MDI 6944' TVD CO"oc6PhmiPs ~ 3-1/2" 3K Cameron G3 tubing hanger with 3-1/2" L-80 EUE 8rd pin down SPECIAL DRIFT TO 2.91" 3-1/2", 9.3#, L-80 EUE 8rd tubing to surface SPECIAL DRIFT TO 2.91" 3-1/2" Cameo 'DS'landing nipple with 2.875" ID No-Go profile set at +1-500' MD 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM GLM Placement: Valves #1-4: 3-W' x 1" KBUG mandrels & 6 Ft. handling pups installed on top and bottom Place gas-lift mandrels at the fallowing depths: TVD 2650 4050 4745 Approx MD 2650 4133 5100 ValveGL 1.00 wI Dummy 1.00 wI Dummy 1.00 wI Shear Valve 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary 3-1/2" Cameo 'D'landing nipple with 2.81"ID No-Go profile and 6 ft. Handling pups One Joint 3-1/2" 9.3# L-80 EUE 8rd Mod tubing Baker 80-40 GBH-22 Seal Assembly (4.00" OD) wI 3-%" EUE-Mod Box up and 6 Ft. Handling Sub ORIGINAL 3-1/2" LINER ASSEMBLY 5" X 7" ZXP Liner Hanger Packer wI HR Profile 5" X 7" Flexlock Hydraulic Liner Hanger 80-40 Casing Sealbore Receptacle 3-%" SLHT Liner as needed 3- %" Landing Collar wI SLHT box x pin One Joint 3-%" SLHT Tubing 3-%" Float Collar wI SLHT Box x Pin Two Joints 3-%" SLHT Tubing 3·%" Float Shoe wI SLHT Box up 3-%" tbg required = +/- 5250' 3- %" SLHT Liner w/150' overlap = +/- 2798' Estimated BH P "C" Sand = 2700 pSI stimated BHP "A" Sand max = 4000 psi Sidetrack TO @ 8048' MO /7006' TVO Drawn by JI 5-26-04 1G~08A PROPOSED SeTRACK Producer COMPLETION - Contingency Top Set Case C~ocóPhillips - 10-3/4" K-55 csg @ 2232' MD I 2232 TVD 3.5" X 7" Liner Top 5150' MD 5.5" X 7" Liner Top 5250' MD/4832 TVD Sidetrack KOP @ +1- 5400' MD, +1- 4917" TVD Baker "K-1" CIBP @ +1- 5418' MD Original Wellbore 7" 26# L-80 shoe at 8698' MDI 6944' TVD 3-1/2" 3K Cameron G3 tubing hanger with 3-1/2" L-80 EUE 8rd pin down SPECIAL DRIFT TO 2.91" 3-1/2",9.3#, L-80 EUE 8rd tubing to surface SPECIAL DRIFT TO 2.91" 3-1/2" Cameo 'DS' landing nipple with 2.875" ID No-Go profile set at +1-500' MD 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM GLM Placement: Valves #1-4: 3-Y:," x 1" KBUG mandrels & 6 Ft. handling pups installed on top and bottom Place gas-lift mandrels at the fallowing depths: TVD 2650 4050 4745 Approx MD 2650 4133 5100 ValveGL 1.00 wI Dummy 1.00 wI Dummy 1.00 wI Shear Valve 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary 3-1/2" Cameo 'D' landing nipple with 2.81" ID No-Go profile and 6 ft. Handling pups One Joint 3-1/2" 9.3# L-80 EUE 8rd Mod tubing Baker 80-40 GBH-22 Seal Assembly (4.00" OD) wI 3-%" EUE-Mod Box up and 6 Ft. Handling Sub 5-%" x 7" " LINER ASSEMBLY 5" X 7" CPH Liner Hanger Packer 5" X 7" HMC Hydraulic Liner Hanger 5-%" Hydril 511 Liner as needed 5-%" Landing Collar One Joint 5-%" Hydril 511 Casing 5-%" Float Collar Two Joints 5-%" Hydril 511 Casing 5- %" Float Shoe 3-1/2" LINER ASSEMBLY 5" X 7" ZXP Liner Hanger Packer wI HR Profile 5" X 7" Flexlock Hydraulic Liner Hanger 80-40 Casing Sealbore Receptacle 3-%" SLHT Liner as needed 3-%" Landing Collar wI SLHT box x pin One Joint 3-%" SLHTTubing 3-%" Float Collar wI SLHT Box x Pin Two Joints 3-%" SLHT Tubing 3-%" Float Shoe wI SLHT Box up Estimated BHP "C" Sand = 2700 psi Top Set Depth = 7623'MD/6629' TVD/ 6540' TVD SS Estimated BHP "A" Sand = 400 psi Sidetrack TO @ 8048' MD / 7006' TVD Drawn by J 5-26-04 ORIGJN.AL 10-06 10-05 ~ 1<;-09 . . SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1065 DATE tf:J;.;¡..¿. 2W-/- 62-14/311 PAY TO THE ORDER OF $ 100. 00 ---- ...... CHASE Chas. Manhattan Bank USA, N.A. Valid Up To 5000 Dollars U "_"0__',.,,,,. d ~~ ///7- lhL M,.o-____Æ~f.: ___ . .. I: 0 :3 ¡. ¡. 0 0 ¡. a. 1.1: 2 ¡. B a. 7 ¡. gO 7 g 2 7 bill ¡. 0 b 5 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k::£¿J /4 '-ò[~A PTD# 2-C)~-/O/ / Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new weUboresegment of LATERAL existing weD , Permit No, API No. . (If API number Production. shouJd continue to be reported as Jast two (2) digits a function· of the original API number. stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1),al1 (PH) records, data and Jogs acquired for the piJot boJe must be clearly differentiated In both name (name on permit plus PH) and API Dumber (SO - 70/80) from records, data and Jogs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:xception. (Company Name) assumes the liability of any protest to tbe spacing exception that may occur. DRY DITCH An dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater ·thaD 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. KRU I G-08A Potential Spacing Exception R.nse . Lisa: Based on the well plat that you sent, proposed sidetrack well KRU 1 G-08A will not require a spacing exception. This Kuparuk River Oil Pool development well is governed by Conservation Order 432B. Rule 3 of that CO states: "Not more than one well may be drilled on any governmental quarter section or governmental lot corresponding to it nor may any well be drilled on a governmental quarter section or governmental lot corresponding to it which contains less than 125 acres, nor may the pool be opened in a well bore that is closer than 500 feet to any property line nor closer than 1,000 feet to the pool opened to the well bore in another well except that: (Source CO 173) In Sections 5, 6, 7, 8, 15, 16, 21, and 22, TllN, RI0E, UM, an unrestricted number of wells may be drilled. (Source CO 182)" Since the originall G-08 well bore will be plugged and abandoned, the proposed 1 G-08A will be the only well bore open the pool in the NE 1/4 of Section 30, T12N, RlOE. The perforated interval in 1 G-08A will lie entirely within state lease ADL 0025640 and the Kuparuk P A, more than 1500 feet from any property line, and more than 1000 feet away from the nearest well bore open to the pool. All conditions of Rule 3 appear to be satisfied. If you have any questions, please call me at 793-1224. Steve Davies Petroleum Geologist AOGCC Wright, Lisa H wrote: «statefig.ppt» thanks, Lisa Wright lisa.h.wright@conocophillips.com 907-263-4823 I of I 5121/2004 10:06 AM PTD#: 2041 01 0 Administration 11160 Program DEV On/Off Shore On Appr Date SFD 6/9/2004 Engineering Appr Date TEM 6/9/2004 ~ Geology Appr SFD Geologic Commissioner: Dfß Date 6/9/2004 Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType 1 P~rmitfee attache~:L . . . . . . . . . . . . . . . . . . . . Y~s . 2 .Leas~.n!Jmber .ap;!ro;!ri<lte. . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . 3 .U.n[q!Je weILn.a[11~.arl(j oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WellJocat~d In.a.ct.efioe.dppol. . . ......... . . . . . . . . . . . . Y~s . . . . . . . Kup.aruk River. Oil f>o.ol goyerned. byCQ 43.26. . 5 WelUocat~d prpperd[stance. from driJIing uoitb.ouod.ary. .............. . Y~s. . . . . . . CO ~32ß specifje.s.drilliog. u.nlt Pf. Gov~t Qtr .sectipo aod.tOOQ' pffs.et from adjaceotwells. As prpposed . 6 WelUoc<lt~d prpperd[stance. from other wells. . . Yes. . . . . . 1G-08A is the.only w~1J intheNE 1/4 of.Sec..:10, anditlies moœthan1000 feetJrpm.offset wells. . . . . . . 7Sufficieotacrea~eaYailablein.dri[lio~unjt... ......... Y~s. . .1G-:I6and.tG.-03.withln.the.popl,.. ........................ 8 Jf.deviated, js. weJlbore platioc]u.ded . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . .. .............. 90per.ator ool~ affected party. . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Oper.ator has.apprppriate.bond [nJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P~rmit can be issued wjthout conservatioo order. . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . 12 P~(mitc.anbe[ssuedwjthoutad.mioistr.ative.apprpvaJ....... ............ yes.................. ....... 13 Can permit be approved before 15-day wait Yes 14 WeJUocated w[thio area and.strat<l.author[zed by.lnjectipo Ord.er # (puUOtl [n.cpmm~nts).(For. y~s . . . . . . . . . . . . . . . . 15 A]lweIJs.within1¿4.miLe.area.ofreyiewjd~otified(Fprservjc.e.wellool~L............. Y~s........................................................................... 16 Pre-produced injector; .duration.of pre-pro.d!Jctipo Less. than:3 mooths. (For.se(lllce well on]y) . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 ACMPFïodingof CQnsi$tencyhas been issued forthis prolect . . . . . . . . . . . . . . . . . . . NA . . . . . . Sidetrack ofe~isting welJ . Well Name: KUPARUK RIV UNIT 1G-08A DEV I PEND GeoArea 890 Unit Well bore seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - .. - - - - - - - - - - - - - -- - - - - - - 18 Conductor str.iogprov[ded . . . . . . . . . . . . . Yes. . . . . . . Conductorsetio origjn.al well. 19 .Swíace .casiogpJQtects alLknown USDWs . . . . .NA . .1\11 aquifers exempted,.4.o .CFR H7.:I 02.(b).. 20 .CMTv.oladequatetocirc.ulate.o.n.cpod.uctor.&su.rf.C$g . ........ Y~s...... .Suffjcje.ntce.mentp-umpedtp.clrcuJate.losurface......... ...... 21 .CMT vol adequateto tie-in Jong string to surf csg. . . . . . . . . . . . . . . . . . . . No. . . . . . . . T'.was notnpt requjred to.be .cementedto surface.. Kuparuk i$olated.. . . 22 .CMT will coyeraH koownproductiye horizon.s. . . . . . . . . . . . . . Y~s . 23 .C.asing designs adeQua.te fpr C,T" 6& permafrpst . . . Y~s. 24 .A.dequate.lan.kage.oJ re.serye pit. . . . . . Y~s. . . . . . . Rig jsequippe.d.with $teelpits.No œseJllepjtplanoed, Wasteto ao approyed disppsaJ well.. . . . . . . . 25 Jf.a. re-.drill, has.a. 10:4.03 for abandonment be~o <lPPJQved . . . . . . . . . . . . . . . . . . Yes 30.4:2.1:1 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .A.dequate.welibore sep¡¡¡ratjo.n.proposed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . f'.IeaJest wellþore jstbe ori.g[naLweH <lithe kick.off.p-olnt. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Jf.djverter Jeq.uired, does jt meet reguJatioos. . ... . . . . . . . . . . . . . . . . . NA . .. ........................ . . . . .. ........................... . . . . . . 28 .DJi[liog fJujd.pJQgram schematic.&eq.uipJistadequ<lte. . . . . . . . . . . . . . . . . . . . . . . Y~s. .. ... Maximum expected fpr.matioo pressuœ1L6EMW.. MWplanned.11A.-.tL7.ppg... .............. 29 .BOPES, do they meet reguJatioo . . . Yes. . . . . . . . . . . . . . . . . . . .. ............ . . . . . . 30 .BOPE.press ratiog appropriate; .test to.(pu.t psig In .commeots). . . . . . Y~s. . . . MASf> calcuJate.d.at 3288 psi, 30QOp$jjoitiaJ testdue to wellbead Jimitatipos.. .5.000 psi ¡¡¡fter ch.ange.out . 31Choke.manjfold compJies w/APLRF'-5:1 (May 84) . . . . . . . . . Y~s . 32 Work wi]1 pccur withputoperationsbutdown. . . . Y~s . . . . . . . 33 Js presence of H2S gas probable . No. . 34 Mecha.nicaLC:~JI)djtion pf wells w[thio I\OR yerified (for.s.ervjce welJ only). NA - - - - - - - - - - - - - - . Mud sh.ould pœclude. H2.S. onthe rjg, Hj~ is equjpped with. s.ensors and .alarms.. . 35 P~rmit can be [ssued wlo hydr.ogen sulfide meaSJJres . 36 .D.ata.preseoted on. pote.ntial PveJpres.sure .zooes. . 37 .S~lsmicanalysjs of sbaJlow gaszooes. 38 .S~abed .coodjtipo survey.(if off-sh.ore) . 39 . Conta.ct oa.melphooe. for.weekly prpgress.re;!orts [exploratpry .0nlYl .......... No. . . . . . .. . . . . . Y~s l.a.test l:i2S SUJvey resl,Jltsiodjc.ate.tG.-;!ad welJs. rao~eJr.o[11.2.2.to 1t3.ppmH2S, . . . . . Drj iii ng Haz..Section: M<lx reservojrpressure [s<= 4000. at 66:17' T\lD = :11.6 p;!g.EMW.. WilLbe.drilJed . . . . . . with.t1 ]ppg m.ud.. Kup.aru.k .C.reserv.oir .may also be depleted.. Contio~eocy.p]andiscussed io cov~r . . . . . . . . letter to appljc¡;¡tion.a.nd In''Cootinge.ncy Ooly Top.Set"sectloo PO page 3, . . .NA ...... ...... NA ....... ....NA - - - - - - Date: Engineering Commissioner: Date c;)/o{l D D . . e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 04/08/26 AWS 01 **** TAPE HEADER **** LDWG 04/08/26 01 *** LIS COMMENT RECORD *** . . !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 2 C. WONG G. RIZEK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE # REMARKS: IG-08A 500292084901 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 26-AUG-04 MWD RUN 3 3 F. WENDLER M.THORTON MWD RUN 29 12N 10E 90.00 59.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 7.000 4767.0 7960.0 ~Ðcf-ID I 12.~2.. ( RECEIVED A,UG 2 6 2004 Alaska Oii & Gas Cons. Commission Anchorage . . GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 21' 42.043" LONG: W149 DEG 40' 19.674" LOG MEASURED FROM D.F. AT 89.00 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 2 & 3 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD) , Caliper Corrected Neutron (CCN) , with Multiple Propagation Resistivity (MPR) , Gamma Ray, and Drill Collar Pressure (DCP) services from 4797 - 7960 feet MD (4556-6948' TVD). REMARKS: (1) Bottom of 7" Casing window - Driller: 4767 feet MD (4535' TVD) (2) The interval from 5948 to 5972 feet MIl (5385 - 5402' TVD) was logged 13 hours, 5 minutes, after drilling due to a bit trip. (3) The interval from 7531 to 7592 feet MIl (6580 - 6630' TVD) was logged up to 21.5 hours after drilling due to a short trip for an open hole formation integrity test (FIT). (4) The interval from 7906 to 7960 feet MD (6899 - 6948' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 74 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4767.0 STOP DEPTH 7960.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) _uu_u_ EQUIVALENT UNSHIFTED DEPTH _uuuu . . BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 2 3 MERGE TOP 4767.0 5918.0 MERGE BASE 5918.0 7960.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT Ig-08a_5.xtf 150 ConocoPhillips Alaska, Inc. IG-08A Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAFM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 RHOB RHOB BDCFM 0.0 DRHO DRHO DRHFM 0.0 PEF PEF DPEFM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 48 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units Size Length . 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 ------- 44 Total Data Records: 305 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4767.000000 7960.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 351 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!! !! !!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 . log header data for each bit run in separate files. 2 .2500 START DEPTH 4765.0 STOP DEPTH 5918.0 # 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) 27-JUN-04 MSB 18704 4.75 SDN MEMORY 5972.0 4765.0 5918.0 o . # MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ # BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # . 42.5 46.7 TOOL NUMBER DAS 91639 SDN 44706 SDN 44706 MPR 54964 SRIG 58019 7.000 4767.0 LSND 10.00 .0 .0 800 .0 .000 .000 .000 .000 128.0 .0 .0 .0 SANDSTONE .00 .000 .0 o BIT RUN 2 (MWD Run 2) . GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU . . -------------------------------- WDFN LCC CN WN FN COUN STAT Ig-08a.xtf 150 ConocoPhillips Alaska, I IG-08A Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAFM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCFM 0.0 DRHM DRHM DRHFM 0.0 DPEM DPEM DPEFM 0.0 NPCK NPCK NPCKSM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPA MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 . . ------- 60 Total Data Records: 308 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4765.000000 5918.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 416 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! LDWG File Version 1.000 !!!!!!!!!!! !!!!!!!! Extract File: FILEOI2.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 3 .2500 START DEPTH 5918.0 STOP DEPTH 7960.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 02-JUL-04 MSB 18704 4.75 SDN MEMORY 7960.0 5918.0 7906.0 o 28.8 43.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER DAS 91639 SDN 44706 SDN 44706 MPR 54964 SRIG 58019 . . # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.000 4767.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.70 .0 .0 700 .0 .000 .000 .000 .000 148.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 3). GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 19-08a.xtf 150 ConocoPhillips Alaska, I 1G-08A Kuparuk River North Slope Alaska . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAFM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCFM 0.0 DRHM DRHM DRHFM 0.0 DPEM DPEM DPEFM 0.0 NPCK NPCK NPCKSM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPA MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 ------- 60 Total Data Records: 545 Tape File Start Depth 5918.000000 Tape File End Depth 7960.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet .A ,; \ w **** FILE TRAILER **** . . Tape Subfile: 4 653 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 04/08/26 01 **** REEL TRAILER **** LDWG 04/08/26 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes