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Home My WebLink About206-040 2.QC0- `-I 0 • WELL LOG TRANSMITTAL# DATA LOGGED t /2.T/2014 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. December 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 _ RECEIVED JAN 0 5 Z61h RE: Static Bottom Hole Pressure Record: 2T-40 AOGGC Run Date: 11/19/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-40 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20528-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-103-20528-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 042A6.-eotegt 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. ~~j - Q ~~ Well History File Identifier Organizing (done> ^ Two-sided III II'lll ll 111 II I~I ^ Rescan Needed RESCAN DI ITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No.' ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: b /s/ ~' Project Proofing II I II ~I II I I III ()III BY: Maria Date: U /s/ Scanning Preparation _~ x 30 = ~ + ~,, U =TOTAL PAGES {~ ~ O / / (Count does not i ~ude cover sheet) , A /~ BY: Maria _____ Date: /7 '~ ~ Q ~ ~S ~uY Production Scanning Stage 7 Page Count from Scanned File: ___~_,~_~_ (Count does include cove heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: - ~ ~ ~ /s/ ~ ~ I/~ f Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II I) I (III (I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 201 '' 4 ,'�- 1 i Asr.� . - Commissioner Dan Seamount Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 1 - r � t r , � , ;y mwi3S10/i Anchorage, AK 99501 Commissioner Dan Seamount: D _ q Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 6130111 2F,2M,2N,2T,2X,2Z,3B,3O PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement _ date _ inhibitor sealant date ft bbls ft _ gal 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A ' 50103201770100 1960900 SF N/A 18" N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" N/A 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" N/A _ 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" N/A 7 6/27/2011 2T-40 . 50103205280000 2060400 2' N/A 2' N/A - 6 6/26/2011 2T -202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" N/A 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A 21" N/A 2.5 6/25/2011 2Z -02 50029209600000 1830800 18" N/A 18" N/A 2.6 6/24/2011 3B -01 50029213180000 1850560 SF 1.50 17" 5/23/2011 6 6/22/2011 30 -12 50029218040000 1880410 SF N/A 22" N/A 1.7 6/22/2011 ~~ ~ ~ * ; t ',,~ ., .,, ..>.. w - ..f-. t _ ._ . ., _ .~._ 1 `~= x q ~ ~ •,FC q -.~ rt z -. MICROFILMED 6/30/20'10 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ti W1EIl.~, I,®G TI~A1®1SMITT~, To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2T-40 July 8, 2008 AK-MW-4263654 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2T-40 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-103-20528-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-103-20528-00 Digital Log Images ~C~NE~ JUL 2 ~ 200 50-103-20528-00 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. An~Io~age, :Alaska 995 I8 Date: i ,Q Signed: 1 ~ J„-~-- DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060400 Well Name/No. KUPARUK RIV UNIT 2T-40 Operator CONOCOPHILLIPS ALASKA INC MD 11661 TVD 6044 Completion Date 5/10/2006 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20528-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye ~' DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neutron, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 41 11661 Open 6/27/2006 fit 14036 LIS Verification Open 8/22/2006 ~L'og Cement Evaluation 5 Col 1 0 11537 Case 6/23/2006 PSP: SCMT- ' CB/Pres/Temp 14-Jun- 2006 ~D C Lis 14036 nduction/Resistivity 8009 11575 Open 8/22/2006 NPHI, RHOB, FET, GR, ROP, Res Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y I~ Daily History Received? v N Chips Received? `fs`iQ"' Formation Tops ~N Analysis ~fTiQ' Received? Comments: Compliance Reviewed By: Date: s • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD rormation Evaluation Logs 2T-40, August 3, 2006 AK-MW-4263654 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20528-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: !~ Signed: " ~~,~~~~ AUG 2 2 2006 ~~~~hOrag ommisslon ~dCo-DyC~ `~/~'036 s ConocoPhillips July 12, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2T-40 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~E~~ ~uL ~ g 2006 Ctxgson plaska'Git & Gas Oons. Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2T-40. If you have any questions regarding this matter, please contact me at 265-6830 or Tim Billingsley at 265-6531. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~~~~VED ~` STATE OF ALASKA ~ Ji,l~ ~ S 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION f ~~; WELL COMPLETION OR RECOMPLETION REPORT ANA s. ~~nissian 1a. Well Status: Oil ^/ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: May 10, 2006 ~ 12. Permit to Drill Number: 206-040 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 7, 2006 13. API Number: 50-103-20528-00 ' 4a. location of Well (Governmental Section): Surface: 290' FSL, 556' FWL, Sec. 1, T11N, RO8E, UM 7. Date TD Reached: May 3, 2006 14. Well Name and Number: 2T-40 ' At Top Productive Horizon: 923' FSL, 1111' FEL, Sec. 34, T12N, R08E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1079' FSL, 1102' FEL, Sec. 34, T12N, R08E, UM 9. Plug Back Depth (MD +TVD): ~ 11535' MD / Kuparuk Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498945 y- 5970270 Zone- 4 10. Total Depth (MD +TVD): 11661' MD / 6044' TVD - 16. Property Designation: _ ADL 25569 & 25549 TPI: x- 491996 y- 5976186 Zone- 4 Total Depth: x- 492004 , - 5976343 Zone- 4 11. Depth where SSSV set: Landing nipple @ 509' 17. Land Use Permit: 2667 8~ 2662 18. Directional Survey: Yes ^~ No ~ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1518' MD 21. Logs Run: GR/Res/DenslNeutron, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 164.8# A-106 40' 116' 40' 116' 24" driven 9.625" 40# L-80 40' 8075' 40' 4121' 12.25" 578 sx ASLite, 781 sx LiteCRETE 7" 26# L-80 40' 11223' 40' 5686' 8.5" 168 sx Class G 3.5" 9.3# L-80 11041' 11661' 5540' 6044' 6.125" 130 sx Class G" 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" 11092' 10924'/11045' 11402'-11412' MD 5830'-5838' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11420'-11430' MD 5845'-5853' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11402'-11430' 181414# of 16/20 proppant 26. PRODUCTION TEST Date First Production June 25, 2006 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil Date of Test 6/21/2006 Hours Tested 17 hours Production for Test Period --> OIL-BBL 365 GAS-MCF 451 WATER-BBL 25 CHOKE SIZE 23 Bean GAS-OIL RATIO 1446 Flow Tubing press. 403 psi Casing Pressure 1227 Calculated 24-Hour Rate -> OIL-BBL 472 GAS-MCF 682 WATER-BBL 35 OIL GRAVITY -API (corr) 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). Submit core chips; if none, state "none". S BFI JUL 2 4 2006 ccr;~r~~ta~ NONE ~ ~~~~ E v' '~ ~ -~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~ ,~ 7~~.pL lam, ~.!/~ t 2a. 2s: GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD InGude and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2T-40 C4 Target 11384' 5815' Base C Sand 11396' 5825' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley @ 265-6531 Printed Nam R. Thomas Title: GKA Drillino Team Leader e % ~ t ~710 Si t h D t G . gna ure one L (G S (~ ~ ~ ~ a e INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~onoctPhiliips Time Log Summary Welhier~ tYeb Repvrl)sg Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM _ 04/02/2006 02:00 00:00 22.00 0 116 MIRU MOVE MOB P Move Rig From 1D-41 to 2T-40 04/03/2006 00:00 00:00 24.00 116 116 MIRU MOVE MOB P Move Rig from 1 D-41 to 2T-40. Shut down @CPF-1, Oliktok "Y", and CPF-2 for crew chan es, 04/04/2006 00:00 07:00 7.00 116 MIRU MOVE MOB P Check Tires and Hydraulic system. Wait on Ku aruk CPF-2 Chan a out. 07:00 12:00 5.00 MIRU MOVE MOB P Continue to move Rig from 26 pad to 2W Pad. 12:00 13:00 1.00 MIRU MOVE MOB P Lay Matting Boards & Pit Liner. Drive Ri u on Mats. 13:00 18:00 5.00 MIRU MOVE MOB P Continue to Move Rig from 2W PAd to 2T Pad. 18:00 21:30 3.50 MIRU MOVE PSIT P Spot Sub Base. Sub Base spotted @ 21:30 HRS. 21:30 22:30 1.00 MIRU MOVE PSIT P Lower Stompers in cellar. Shut all windwalls in, and close doors. 22:30 00:00 1.50 MIRU MOVE PSIT P Spot Pit Module. Pit Module in place and spotted @ 22:30 HRS. Close all Hatches and prepare to Skid Derrick and Ri Floor. 04/05/2006 00:00 01:00 1.00 MIRU MOVE PSIT P PJSM with crew. Discuss safety issues and procedure for skidding rig floor and deriick. Skid Rig Floor & Derrick into lace. 01:00 02:30 1.50 MIRU MOVE PSIT P Lay Pit liner, and berms. Spot Rockwasher Module in place. Attach mud, steam, air & water lines. 02:30 06:00 3.50 MIRU MOVE RURD P Continue Hook up all Mud, water, air & steam lines.lnstall hand rails where a livable. 06:00 12:00 6.00 MIRU MOVE RURD P Continue Hook up all lines, and ready rig for acceptance. Berm around cuttings tanks, trim pit liners, and rig up lines to Pit Modules, and Rockwasher. Rig accepted @ 0700 HRS 4/5/06. 12:00 18:00 6.00 MIRU MOVE RURD P Cut hole in cellar windwall for Diverter system line to be oriented out of drillers side of rig. Install Diverter system including Annular & KNife valve. Make up section 1 of the diverter line. Load pits with 620 BBLS of water & re are to mix s ud mud. 18:00 00:00 6.00 MIRU MOVE RURD P Continue nipple up diverter riser and flowlines. Attach diverter line sections .Berm & install cuttings tanks, and install grip strut walkways around tanks. ___m.,_T ~~ ~ F'~€Je 1 of 52 Time Logs Date From To Dur 'h, e th E. De th Phase Code Subcode 'OM 04/06/2006 00:00 03:30 3.50 MIRU MOVE RURD P Continue Make up Flow line assembly. MU choke line and dresser sleeve on flowline. Load 5" DP in i e shed. 03:30 06:00 2.50 MIRU DRILL RURD P Change out Saver Sub on Top Drive to 4 1/2" IF. Continue pulling all tools to ri floor. XO's, etc.. 06:00 08:00 2.00 SURFA DRILL RURD P Continue pull all tools to rig floor and i e shed fors ud. 08:00 10:00 2.00 SURFA RIGMN SVRG P Service crown section, and Top Drive. Perform Derrick Inspection. Continue load pipe shed with a total of 240 joints of 5" DP. Load 21 Joints of 5" HWDP 10:00 10:15 0.25 SURFA DRILL SFTY P PJSM with crew. Discuss safety issues and procedure for picking up 5" drill i e and rackin in derrick. 10:15 11:15 1.00 SURFA DRILL RURD P Install mouse hole,and lay down pipe rack mat. Obtain RKB Meaurements. RF-GL = 41.05", RF -Landing Ring = 41.50', RF - To of Annular = 30.24'. 11:15 12:00 0.75 SURFA DRILL RURD P Pick up 5" drill pipe into stands and rack back in derrick. Use a 2 7/8" drift on DP as it was icked u . 12:00 18:00 6.00 SURFA DRILL RURD P Continue Pick up 5" drill pipe into stands and rack back in derrick. Use a 2 7/8" drift on DP as it was picked up. NOTE: Use steam to thaw out joints as they were picked up and the Drift would not fall through joint because they were snowpacked. 45 stands total icked u . 18:00 00:00 6.00 SURFA DRILL RURD P Continue pick up 5" DP from shed . Rack back in derrick, using 2 7/8" drift, and thawing pipe to allow drift to fall. Pick up stands 45 - 80. Mix 100 BBL of spud mud and add to system for a total of 842 BBLs to s ud with. 04/07/2006 00:00 03:30 3.50 SURFA DRILL RURD P Continue pick up 5" Drill pipe from shedand rack back in derrick. PU 21 joints of 5" HWDP, and drilling jars, rack back in derrick. 03:30 04:30 1.00 SURFA DRILL OTHR P PU 1 stand of 5" DP. RIH to tag @ 46' in on stand. Put Koomeys on line & Function test Annular & Knife Valve. Perform Diverter Test. Knife fully opened in 14 seconds, and Annular fully closed in 37 seconds. Perform Accumulator test. Starting pressures = ACC = 2900 PSI, MAN = 1300 PSI, and Ann = 850 PSI. Shut in Annular - Pressure = 1600 PSI. 2Min = 22 seconds, and full pressure to 2900 PSI in 2 minutes, 10 seconds. Open Annular & Shut Knife Valve. Diverter Function test, witness waived by AOGCC re -John Cris on 4/6/06 ~~_ ~e_._ ~ ~ ~ ~,. P~~ 2 t~fi 52 Time Logs Date From To Dur :ale th E. De th Phase Code Subcode .,OM 04/07!2006 04:30 04:45 0.25 SURFA DRILL OTHR P PJSM with entire crew & Sperry Sun reps. Discuss Safety issues (New hands & New Driller)and procedure for picking SPUD BHA. Pull stand, and rack back in derrick. 04:45 06:00 1.25 SURFA DRILL PULD P Make up BHA # 1 for Spud. MU 12 1/4" Hughes MXL-1 bit (1.15')with TFA of .752 sq. in. Jets = 2 x 16's, 1 x 12, and 1 x 18. Make up 8" Sperry Drill Lobe 4/5 - 5.3 stage Motoer with a 2.12 Deg bend (28.93'), 10 5/8" Sleve type Stabilizer (5.56'), and a Bottleneck crossover sub to DP. 06:00 07:00 1.00 SURFA DRILL OTHR P Rig Up flood conductor & pressure test all surface lines to 3500 PSI. Observed a small Riser leak. 07:00 08:00 1.00 SURFA DRILL OTHR P Stand back 1 stand of 5" drill pipe. Stand back Motor and Bit assembly, blow down To Drive and all lines. 08:00 08:15 0.25 SURFA DRILL SFTY P Held PJSM with crew and Sperry Sun Gyro reps. Discuss safety issues and procedure for hanging sheaves and ri in u G ro crew. 08:15 08:45 0.50 SURFA DRILL OTHR P Hang sheave & wireline in Derrick. 08:45 12:00 3.25 SURFA WELCT NUND P Pull Master bushings & Iron roughneck tracks. Nipple down Riser & Install new gasket. Bolt up Riser, and rehang turnbuckles. Install correct plates under rig floor on drip pan, and herculite liner around Riser & Mouse hole. Install Master Bushings & Iron rou hneck tracks. 12:00 12:45 0.75 45 100 SURFA DRILL REAM P RIH with Bit & Motor assembly to wash & ream from 45' to 100', at 40 RPM's, 240 GPM's -340 PSI. 12:45 13:00 0.25 100 35 SURFA DRILL TRIP P POOH with Assembly standing back 1 stand of 5" HWDP & XO. 13:00 13:30 0.50 35 SURFA DRILL PULD P Make up MWD assembly. 8" Non MAg PSI Drop sub (2.02', 8" MWD - DIR/HCIM (25.31'), 8" NonMAg Float sub (2.41'), 8" NonMAg UBHO sub (2.59'). and Orient MWD to motor as er MWD -DD's. 13:30 15:45 2.25 100 198 SURFA DRILL DDRL P Directional drill as per DD's from 100' - 198' MD. TVD = 198'. AST = .48 HRS, ART = .48 HRS, ADT = .71 HRS. Total Bit HRS = .71, Totaf JAr HRS = .71, Pumps @ 425 GPM - 1100 PSI. RPM's = 40, with 4-5K Torqu. UP WT = 95K, SO WT' = 92K, ROT WT = 92K. 15:45 16:00 0.25 SURFA DRILL TRIP P POOH, racking back 1 stand of DP. 16:00 16:15 0.25 SURFA DRILL OTHR P Rig up and blow down Top Drive. Time Logs ~ Date From To Dur e th E. De th Phase Code Subcode -i'~ ~OM 04/07/2006 16:15 17:00 0.75 SURFA DRILL TRIP P Continue POOH to MWD assembly. 17:00 17:45 0.75 SURFA RIGMN RURD NP Adjust Top Drive Link Tilt. Clamps had rotated and would not allow correct ositionin of Bales. 17:45 18:00 0.25 SURFA DRILL PULD P Make up remaining BHA #1. Pick up 3 - 8" Non Mag Flex Drill Collars (90.51'), 8" Drilling Jars (39.78'), and XO.NoteZ: Rig on High line power starting at 12:30 HRS. 18:00 00:00 6.00 198 628 SURFA DRILL DDRL P RIH to 198' and continue directional drill from 198' - 628' {430'). TVD = 619'. INC = 2.22 Deg, AZ = 308.64 Deg. AST = 1.46 HRS, ART = .92 HRS, ADT = 2.38 HRS. Total Bit HRS = 3.09, Total Jar HRS = 3.09, Pumps @ 455 GPM - 1400 PSI. RPM's = 40, with 8-10K Torque. UP WT = 105K, SO WT = 102K, ROT WT = 102K. GYRO Depths = 198', 259', 351', 444', 536', 628'. 04/08/2006 00:00 06:00 6.00 628 1,001 SURFA DRILL DDRL P Continue Directional Drill from 628' - 1001' (373'). TVD = 970'. INC = 22.87 Deg, AZ = 314.88. Deg. AST = 1.66 HRS, ART = 1.72 HRS, ADT = 3.38 HRS. Total Bit HRS = 6.47, Total Jar HRS = 6.47, Pumps @ 455 GPM - 1500 PSI. RPM's = 40, with 10-15K Torque. UP WT = 110K, SO WT = 108K, ROT WT = 110K. GYRO Depths = 720',813',907'. WOB = 10-15K 06:00 12:00 6.00 1,001 1,477 SURFA DRILL DDRL P Continue Directional Drill from 1001' - 1477' (478'). TVD = 1374'. INC = 34.38 Deg, AZ = 308.59. Deg. AST = 2.14 HRS, ART = 1.38 HRS, ADT = 3.52 HRS. Total Bit HRS = 9.99, Total Jar HRS = 9.99, Pumps @ 470 GPM - 1720 PSI. RPM's = 40, with 6-7K Torque. UP WT = 130K, SO WT = 108K, ROT WT = 125K. Max Gas = 27 Units. WOB = 10 - 15K 12:00 12:45 0.75 1,477 1,477 SURFA DRILL CIRC P Circulate & condition mud @ 9.2 PPG, 470 GPM's, 1720 PSI. Observe hole cleaned up, no gas. Make connection & to le mode on MWD assembl . 12:45 18:00 5.25 1,477 1,857 SURFA DRILL DDRL P Continue Directional Drill from 1477' - 1857 (380'). TVD = 1623'. INC = 55.93 Deg, AZ = 312.22. Deg. AST = 2..35 HRS, ART = .77 HRS, ADT = 3.12 HRS. Total Bit HRS = 13.13, Total Jar HRS = 13.13, Pumps @ 470 GPM - 1720 PSI. RPM's = 40, with 6-7K Torque. UP WT = 140K, SO WT = 115K, ROT WT = 128K. Max gas = 31 Units. WOB = 10 -15K Time Logs Date From To Dur e th E De th Phase Code Subcode `OM 04/08/2006 18:00 22:45 4.75 1,857 2,238 SURFA DRILL DDRL P Continue Directional Drill from 1857' - 2238' (381'). TVD = 1788'. INC = 67.92 Deg, AZ = 307.58. Deg. AST = 1.0 HRS, ART = .72 HRS, ADT = 1.72 HRS. Total Bit HRS = 15.79, Total Jar HRS = 15.79, Pumps @ 460 GPM - 1575 PSI. RPM's = 40, with 6-7K Torque. UP WT = 135K, SO WT = 110K, ROT WT = 120K. Max gas = 31 Units WOB = 10-15K. Acheived tangent section parameters as per well Ian. 22:45 23:15 0.50 2,238 2,238 SURFA DRILL CIRC P Circulate bottoms up @ 425 GPM's, 1500 PSI. Reciprocate drill string. UP WT = 140K, SO WT = 115K. No gas. Monitor well -static. 23:15 00:00 0.75 2,238 1,770 SURFA DRILL CIRC P POOH from 2238' - 1770'. Hole taking ro er hole fill. 04/09/2006 00:00 01:15 1.25 1,770 813 SURFA DRILL TRIP P Continue POOH with BHA #1 from 1770' -BHA 813'. 01:15 02:15 1.00 813 0 SURFA DRILL PULD P Breakout & Rack back 5" HWDP, and 1 stand of 8" Flex Drill collars. Pull to Motor assembly and drain motor. Breakout & lay down 12 1/4" Bit. Inspect & gauge bit to 1 / 1 / E / A / E /I/PN/BHA 02:15 03:30 1.25 0 0 SURFA DRILL OTHR P Plug in and download MWD assembly. U load MWD as it will be Rerun. 03:30 04:45 1.25 0 810 SURFA DRILL PULD P Make up BHA # 2. Make up 12 1/4" HTC HCR605 PDC Bit (.99') w/jets of 4 x 14's, and 3 x13's for a TFA of .990 sq. in., 8" Sperry Drill Lobe 4/5 - 5.3 stg Motor (28.93'), 10 5/8" Sleeve type stabilizer (5.56'), 8" Non Mag Crossover (1.86'), 8" MWD - DIR / HCIM (25.31'), 8" Non Mag Float sub (2.41'), 3 - 8" Non Mag Flex Drill Collars (90.51'), 8" Dailey Drilling Jars (39.78'jand 20 - 5" HWDP. Total BHA = 810.20' NOTE: Ran same Motor as BHA #1, Change bend to 1.15 DEG, and orient to MWD assembl . 04:45 05:15 0.50 810 810 SURFA RIGMN SVRG P Service Top Drive & Crown section sheaves. 05:15 06:00 0.75 810 1,570 SURFA DRILL TRIP P Trip in hole from BHA to 1570'. Crew Chan e. 06:00 08:45 2.75 1,570 2,238 SURFA DRILL TRIP P Continue Trip in hole from 1570' - 1770'. (200') Fill Drill String @ 1770'. Continue TIH to bottom @ 2238'. Observe ood hole fill and tri seed. s ~ ~ ... P~ ~f ~~ Time Logs Date From To Dur e th E. De th Phase Code. Subcode 'OM 04/09/2006 08:45 12:00 3.25 2,238 2,712 SURFA DRILL DDRL P Continue Directional Drill from 2238' - 2712 (474'). TVD = 1986'. INC = 68.92 Deg, AZ = 310.53. Deg. AST = .63 HRS, ART = 1.6 HRS, ADT = 2.23 HRS. Total Bit HRS = 2.23, Total Jar HRS = 18.02, Pumps @ 680 GPM - 1700 PSI. RPM's = 90, with 5-6K Torque on bottom. Torque - 2-3K off Btm. UP WT = 155K, SO WT = 112K, ROT WT = 130K. Max gas = 46.2 Units WOB = 5-10K. BAckground gas = 15.1 Units. 12:00 18:00 6.00 2,712 3,377 SURFA DRILL DDRL P Continue Directional Drill from 2712' - 3377 (665'). TVD = 2243'. INC = 66.22 Deg, AZ = 310.20 Deg. AST = 1.68 HRS, ART = 2.06 HRS, ADT = 3.74 HRS. Total Bit HRS = 5.97, Total Jar HRS = 21.76, Pumps @ 680 GPM - 1700 PSI. RPM's = 90, with 8-9K Torque on bottom. Torque - 4-5K off Btm. UP WT = 150K, SO WT = 112K, ROT WT = 130K. Max gas = 37.5 Units WOB = 5-10K. Background gas = 14 Units. 18:00 23:00 5.00 3,377 3,855 SURFA DRILL DDRL P Continue Directional Drill from 3377' - 3855' (478'). TVD = 2431'. INC = 67.40 Deg, AZ = 310.35 Deg. AST = 1.38 HRS, ART = 1.54 HRS, ADT = 2.92 HRS. Total Bit HRS = 8.89, Total Jar HRS = 24.68, Pumps @ 680 GPM - 1735 PSI. RPM's = 90, with 5-6K Torque on bottom. Torque - 4-5K off Btm. UP WT = 150K, SO WT = 125K, ROT WT = 135K. Max gas = 35 Units WOB = 5-10K. Background gas = 16 Units. 23:00 00:00 1.00 3,855 3,855 SURFA DRILL OTHR T Make connection & could not obtain MWD survey. Troubleshoot & Toggle tool to et ood surve s. 04/10/2006 00:00 01:00 1.00 3,855 3,950 SURFA DRILL DDRL P Continue Directional Drill from 3855' - 3950 (95'). TVD = 2465'. INC = 67.40 Deg, AZ = 310.35 Deg. AST = .24 HRS, ART = .34 HRS, ADT = .58 HRS. Total Bit HRS = 9.47, Total Jar HRS = 25.26, Pumps @ 680 GPM - 1850 PSI. RPM's = 90, with 7-9K Torque on bottom. Torque - 6-7K off Btm. UP WT = 150K, SO WT = 130K, ROT WT = 135K. WOB = 5-10K. 01:00 01:30 0.50 3,950. 3,950 SURFA DRILL OTHR T MWD failed. Could not get surveys, observed flatline. Trouble shoot tool with no success. LAst good survey at MD of 3855'. ® ~ _ r~~ & csfi ~~ Time Logs .Date From To Dur e th E. De th Phase Code Subcode 7 OM 04/10/2006 01:30 06:00 4.50 3,950 1,950 SURFA DRILL TRIP T Pump out of hole from 3950' - 1950'. Pumping at 680 GPM - 1750 PSI. Pumped out 20 stands, observe hole unloading, cleaning up. Pull stand # 21 on elevators. Blow down To drive. 06:00 08:00 2.00 1,950 200 SURFA DRILL TRIP T Continue POOH on elevators from 1950' to BHA. Rack back Flex drill collars, and 5" HWDP & Jars. 08:00 08:30 0.50 200 0 SURFA DRILL PULD T Breakout & lay down MWD and float sub assembly. Make up backup MWD assembly and float sub. MAke up 8" MWD DIR/HCIM (25.37'), 8" Float sub 2.46' . 08:30 09:15 0.75 0 200 SURFA DRILL PULD T Plug in and download MWD assembly. 09:15 09:30 0.25 200 0 SURFA DRILL PULD T Inspect Motor & bit. Bit OK. BHA#3 total len th = 810.31'. 09:30 10:00 0.50 200 810 SURFA DRILL TRIP T Trip in hole with BHA #3. from 200' - 810'. 10:00 11:00 1.00 810 2,330 SURFA DRILL TRIP T Continue TIH w/ 5" Drill pipe from 810' - 2330'. Fill Drill strin with mud. 11:00 11:30 0.50 2,330 2,330 SURFA DRILL TRIP T Continue fill drill pipe & blow down Top Drive. 11:30 12:00 0.50 2,330 2,710 SURFA DRILL TRIP T Continue trip in hole from 2330' - 2710' 380' . 12:00 12:30 0.50 2,710 3,855 SURFA DRILL TRIP T Continue trip in hole from 2710' - 3855'. 1145' . 1 stand off bottom. 12:30 13:30 1.00 3,855 3,665 SURFA DRILL OTHR T Observed Auger froze up on Rockwasher. Rack back 3 stands, reciprocate drillstring while monitor well and thaw out au er assembl . 13:30 16:00 2.50 3,665 3,665 SURFA DRILL OTHR T Continue reciprocate drill string, monitor well while Rig electrician re aired Au er in Rockwasher. 16:00 16:15 0.25 3,665 3,950 SURFA DRILL TRIP T Trip in hole from 3665' - 3950' (285'). 16:15 17:00 0.75 3,950 3,950 SURFA DRILL CIRC T Circulate & reciprocate drill string while filling pipe & obtain pumping parameters. Pumps @ 433 GPM - 840 PSI. At 524 GPM- 1090 PSI. 17:00 18:00 1.00 3,950 4,045 SURFA DRILL DDRL P Continue driectional drilling from 3950' -4045' (95'). TVD = 2504'. INC = 67.25 Deg, AZ = 310.20 Deg. AST = .21 HRS, ART = .32 HRS, ADT = .53 HRS. Total Bit HRS = .53, Total Jar HRS = 25.79, Pumps @ 670 GPM - 1720 PSI. RPM's = 90, with 6-10K Torque on bottom. Torque - 5-6K off Btm. UP WT = 158K, SO WT = 120K, ROT WT = 138K. WOB = 6-10K. ___,_ ~ P~~ 7 ~~f Time Logs Date From To Dur eoth F nenth Phases Cnde SuhrnriP ,nM 04/10/2006 18:00 00:00 6.00 4,045 4,587 SURFA DRILL DDRL P Continue driectional drilling from 4045' - 4587' (542'). TVD = 2715'. INC = 67.25 Deg, AZ = 310.20 Deg. AST = 1.02 HRS, ART = 3.07 HRS, ADT = 4.09 HRS. Total Bit HRS = 4.67, Total Jar HRS = 29.88, Pumps @ 670 GPM - 1650 PSI. RPM's = 90, with 7-9K Torque on bottom. Torque - 5-6K off Btm. UP WT = 165K, SO WT = 125K, ROT WT = 135K. WOB = 3-4K. 04/11/2006 00:00 06:00 6.00 4,587 5,007 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 4587' - 5007' (420') (TVD = 2880'). ART = 2.94 HRS, AST = 1.10 HRS. Total hrs on bit = 8.66 hrs., Total hrs on jars = 33.92 hrs, 5-10k WOB, 90 rpm's, 175- 179 mtr rpm, 674-690 gpm w/ 9.5 ppg MW, on bottom press 1630-1750 psi, off bottom press 1523-1575 psi, on bottom torque 6-12k fUlb, off bottom torque 6-12k ft/ Ib, PU wt 165-170k, SO wt 125k, Rot wt 145k. Max gas= 98 units, background gas = 30 units. Note: ROP slowed f/ 220 ft/hr to 10 ft/hr f/ 4587' to 4590', then picked back u. 06:00 12:00 6.00 5,007 5,530 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 5007' - 5530' (523') (TVD = 3086'). ART = 3.73 HRS, AST = .67 HRS. Total hrs on bit = 13.06 hrs., Total hrs on jars = 38.32 hrs, 4-10k WOB, 90 rpm's, 175- 188 mtr rpm, 674-723 gpm w/ 9.5 ppg MW, on bottom press 1640-1940 psi, off bottom press 1510-1880 psi, on bottom torque 6-13k fUlb, off bottom torque 6-10k ft/ Ib, PU wt 175-185k, SO wt 125-128k, Rot wt 145-150k. Max as= 30 units. 12:00 13:45 1.75 5,530 5,619 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 5530' - 5619' (89') (TVD = 3120'). ART = 1.17 hrs, AST = 0.0 hrs. Total hrs on bit = 14.23 hrs., Total hrs on jars = 39.49 hrs, 6-10k WOB, 90 rpm's, 192 mtr rpm, 738 gpm w/ 9.5 ppg MW, on bottom press 1900 psi, off bottom press 1850 psi, on bottom torque 8-16k ft/Ib, off bottom torque 6-15k ft/ Ib, PU wt 190k, SO wt 120k, Rot wt 150k. Max as= 30 units. 13:45 14:30 0.75 5,619 5,619 SURFA DRILL CIRC P Circulate and condition mud @ 5619'. Shaker screens blinding off. Pumping 316 gpm w/ 730 psi, 569 gpm w/ 1500 si. ~~ ae~~ ~ ~ f ~~2 ...® ~ ,~ Time Logs ~ , Date From To Dur epth E. De th Phase Code Subcode OM 04/11/2006 14:30 18:00 3.50 5,619 5,940 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w! 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 5619' - 5940' (321') (TVD = 3247'). ART = 2.68 hrs, AST = 0.0 hrs. Total hrs on bit = 16.91 hrs., Total hrs on jars = 42.17 hrs, 6-12k WOB, 90 rpm's, 189-192 mtr rpm, 728-738 gpm w/ 9.5 ppg MW, on bottom press 1900-2000 psi, off bottom press 1850-1870 psi, on bottom torque 8-16k ftnb, off bottom torque 6-15k ft/ Ib, PU wt 195k, SO wt 120-125k, Rot wt 150k. Max gas= 30 units. 18:00 00:00 6.00 5,940 6,239 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 5940' - 6329' (389') (TVD = 3406'). ART = 3.11 hrs, AST = 1.15 hrs. Total hrs on bit = 21.17 hrs., Total hrs on jars = 46.43hrs, 9-12k WOB, 90 rpm's, 187-191 mtr rpm, 720-735 gpm w/ 9.5 ppg MW, on bottom press 1900-2000 psi, off bottom press 1850-1870 psi, on bottom torque 8-16k ft/Ib, off bottom torque 6-15k fU Ib, PU wt 195-200k, SO wt 130k, Rot wt 158-155k. Max as= 32 units. 04/12/2006 00:00 06:00 6.00 6,329 6,732 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 6329' - 6732' (403') (TVD = 3569'). ART = 3.6 hrs, AST = .41 hrs. Total hrs on bit = 25.18 hrs., Total hrs on jars = 50.44hrs, 8-12k WOB, 90 rpm's, 190-192 mtr rpm, 732-739 gpm w/ 9.5 ppg MW, on bottom press 2250-2380 psi, off bottom press 2144-2250 psi, on bottom torque 11-17k fUlb, off bottom torque 8-14k ft/ Ib, PU wt 200-205k, SO wt 130k, Rot wt 158-160k. Max as= 32 units. 06:00 12:00 6.00 6,732 7,186 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 6732' - 7186' (454') (TVD = 3762'). ART = 3.91 hrs, AST = .24 hrs. Total hrs on bit = 29.33 hrs., Total hrs on jars = 54.59hrs, 8-12k WOB, 90 rpm's, 187-192 mtr rpm, 721-740 gpm w/ 9.5 ppg MW, on bottom press 2200- 2690 psi, off bottom press 2130-2560 psi, on bottom torque 10-18k ft/Ib, off bottom torque 9-18k fU Ib, PU wt 220-230k, SO wt 130k, Rot wt 158-160k. Max as= 40 units. ~'~~ ~f ~~ .~ ®~ ~ r.~ . ,. a ~ ~ ..~... . Time Logs G Date From To Dur th E. De th Phase Code Subcode OM 04/12/2006 12:00 18:00 6.00 7,186 7,644 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 7186' - 7644' (458') (TVD = 3946'). ART = 3.41 hrs, AST = .42 hrs. Total hrs on bit = 33.16 hrs., Total hrs on jars = 58.42 hrs, 12-14k WOB, 100 rpm's, 187-192 mtr rpm, 721-737 gpm w/ 9.5 ppg MW, on bottom press 2600-2720 psi, off bottom press 2510-2580 psi, on bottom torque 12-18k ft/Ib, off bottom torque 10-18k it/ Ib, PU wt 225-235k, SO wt 130k, Rot wt 162k. Max gas= 40 units. 18:00 00:00 6.00 7,644 8,020 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 7644' - 8020' (376') (TVD = 4099'). ART = 2.12 hrs, AST = .47 hrs. Total hrs on bit = 37.22 hrs., Total hrs on jars = 62.48hrs, 10-14k WOB, 100-90 rpm's, 189-187 mtr rpm, 727-721 gpm w/ 9.5 ppg MW, on bottom press 2720- 3000 psi, off bottom press 2510-2800 psi, on bottom torque 12-19k ft/Ib, off bottom torque 11-20k ft/ Ib, PU wt 235-240k, SO wt 130-135k, Rot wt 162-175k. Max gas= 40 units. Note: hard s of 7944' 4072' TVD 04/13/2006 00:00 01:30 1.50 8,020 8,090 SURFA DRILL DDRL P Directional Drill 12-1/4" hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.15 deg bend from 8020' - 8090' (70') (TVD = 4126.52'). ART = .91 hrs, AST = 0.0 hrs. Total hrs on bit = 38.13 hrs., Total hrs on jars = 63.39hrs, 10-12k WOB, 90 rpm's, 189-187 mtr rpm, 727 gpm w/ 9.5 ppg MW, on bottom press 3000 psi, off bottom press 2800 psi, on bottom torque 13-19k ft/Ib, off bottom torque 13-20k ft/ Ib, PU wt 240k, SO wt 135k, Rot wt 162k. Max gas= 40 units. 01:30 02:00 0.50 8,090 8,090 SURFA DRILL CIRC P Circulate and condition mud 02:00 06:00 4.00 8,090 5,378 SURFA DRILL TRIP P Monitor well-static, Pump out of hole from 8090' to 5378' MD. Pump 720 m. Record PU & SO wt's. 06:00 07:00 1.00 5,378 4,800 SURFA DRILL TRIP P Pump out of hole from 5378' to 4800' @ 720 gpm and 1800 psi. Record PU & SO wt's. 07:00 08:00 1.00 4,800 4,800 SURFA DRILL CIRC P Circulate and condition mud. Stage rate from 200 gpm @ 500 psi to 732 gpm @ 2050 psi. Rotate string @ 90 r m w/ 10-12kft-Ibs for ue 08:00 09:15 1.25 4,800 3,951 SURFA DRILL TRIP P Pump out of the hole from 4800' to 3951' Pump @ 720 gpm w/ 1750 psi. Record PU & SO wt's. ~- ~ ~_ ~ _ P~~ ~~ ~t S~~ - Time Logs ~ Date From To Dur th E. Depth Phase Code Subcode OM _ 04/13/2006 09:15 10:00 0.75 3,951 3,951 SURFA DRILL CIRC P Circulate bottoms up. Work pipe from 3951' to 3856'. Pump 726 gpm @ 1700 psi. RPM= 90 rpm w/ 8-9kft-Ibs torque. P/U= 165k, S/0=118k, Rot=138k 10:00 10:15 0.25 3,951 3,951 SURFA DRILL OTHR P Blow down top drive 10:15 12:00 1.75 3,951 6,330 SURFA DRILL WPRT P Trip in from 3951' to 6330' and fill drill i e. 12:00 12:30 0.50 6,330 7,947 SURFA DRILL WPRT P Trip in from 6330' to 7947'. 12:30 13:00 0.50 7,947 8,090 SURFA DRILL REAM P Fill pipe and wash and ream from 7947' to 8090'. Pumping 710 gpm w/ 2240 psi. Rotate 90 rpm w/ 16-17k ft Ib for ue. No fill. 13:00 14:30 1.50 8,090 8,090 SURFA DRILL CIRC P Circulate and condition mud and hole prior to POOH f/ 9-5/8" casing. Pumping 710 gpm w/ 2240 psi. Rotate 90 rpm w/ 16-17k ff/Ib torque. Pumped total of 1586 bbls. 14:30 15:30 1.00 8,090 7,663 SURFA DRILL TRIP P Monitor well- static. POOH on elevators f/ 8090' to 7663'. OK. 15:30 16:00 0.50 7,663 7,663 SURFA DRILL CIRC P Pump dry job. Blow down top drive. 16:00 18:00 2.00 7,663 3,760 SURFA DRILL TRIP P POOH f/ 7663' to 3760'. SLM. Record PU and SO wt's. PU wt @ 3760' _ 175k, SO wt = 115k. 18:00 20:00 2.00 3,760 810 SURFA DRILL TRIP P Continue POOH f/ 3760' to 810'. SLM- no correction. Record PU and SO wt's. PU wt 160k & SO wt 115k 810'. 20:00 20:45 0.75 810 195 SURFA DRILL TRIP P Continue POOH f/ 810' to 195'. Stood back 6 stands of 5" Weatherford HWDP. 20:45 23:00 2.25 195 0 SURFA DRILL PULD P UD (2) joints of Weatherford 5" HWDP, UD Daily drilling jars. PU and drain bit, break off bit. Run in hole and flush Sperry Sun motor w/ water. Pulled back out and UD MWD w/ x-o and float sub. UD Sperry motor w/ stabilizer. 23:00 00:00 1.00 0 0 SURFA DRILL OTHR P Clear and clean rig floor. 04/14/2006 00:00 01:00 1.00 0 0 SURFA CASIN( RURD P Bring Tam port collar, centralizers, hanger and elevators to floor while downloading MWD. Clear pipe shed of BHA. Put landing joint in pipe shed for dumm run. 01:00 01:45 0.75 0 0 SURFA CASIN( RURD P Make up 9-5/8" casing hanger on landing joint. Make dummy run and mark landing joint. POOH w/ landing joint and hanger. Left fluted landing ring from hanger in well. Lay down landin 'oint and han er in i eshed. 01:45 03:30 1.75 0 0 SURFA CASIN( RURD T Drained stack and fished fluted landing rin from well bore. ~~® ~ ~ 1'I ~fi r~ I e. _ ®~~~ Tim LoeTim Loe gs Date From To Dur epth E. De th Phase Code Subcode OM 04/14/2006 03:30 04:15 0.75 0 0 SURFA CASIN( RURD T P/U landing joint and hanger from shed. Broke off damaged casing han er and fill diverter 04:15 05:00 0.75 0 0 SURFA CASIN( RURD P M/U new casing hanger and make dummy run. Mark landing joint and UD in pipeshed. Drifted landing joint w/ 8.525" drift 05:00 06:00 1.00 0 0 SURFA CASIN( RURD P R/U to run casing. UD side door elevators, short bales and bad hanger. P/U long bales, filllup tool, and torqued fillu tool to to drive 06:00 08:00 2.00 0 0 SURFA CASIN( RURD P Continue rigging up to run casing. P/U 350 ton air slips, elevators and power ton s. 08:00 08:15 0.25 0 0 SURFA CASIN( SFTY P Hold pre-job safety meeting with crew, toolpusher, mud engineers, and co. man 08:15 11:30 3.25 0 1,553 SURFA CASIN( RNCS P Make up shoe track with 3 joints casing between float shoe and float collar. Install centralizers on stop rings in the middle of each shoe joint and baker lock each shoe joint. Run 25 more joints of casing installing centralizers over the collars of each joint. Run 12 more joints without centralizers. Run a total of 37 joints of 9-5/8" 40#, L-80 BTC casing to 1553'. Tor ue to 8500 ft-Ibs. 11:30 12:00 0.50 1,553 1,553 SURFA CASIN( CIRC P Circulate on casing volume-120 bbls mud. Stage rate up from 4 bpm @ 100 psi to 5.5 bpm @ 280psi., final 200. 12:00 20:30 8.50 1,553 7,996 SURFA CASIN( RNCS P Continue running 9-5/8" 40 ppf L-80 BTC casing f/ 1553' to 6513'. Record PU and SO wt's every 10 jts. Broke circ @ 3654' w/ 6 bpm and 170 psi, circ @ 5758' pumping 4 bpm w/ 280 psi, continue running casing,run jt # 168 and install a centralizer on stop in middle of jt, install TAM port collar, run jt # 169 and install centralizer on stop in middle of jt, ran casing to 7996'. PU wt 380k, SO wt 150k. 20:30 21:15 0.75 7,996 7,996 SURFA CASIN( CIRC P Circ and condition mud using Frank's fillup tool. Stage up to 4 bpm w/ 260- 270 psi. PU wt 380k - 340k. SO wt 150k. 21:15 21:45 0.50 7,996 8,075 SURFA CASIN( RNCS P Continue running 9- 5/8" 40 ppf L-80 BTC casing f/ 7996' to 8075' (landed).Circ joint # 190 down w/ 4 bpm. R/D Frank's fillup tool. Remove casing spiders. MU/RIH landing joint to 8075'. SO wt 160-155k. PU wt 360k. 21:45 22:30 0.75 8,075 8,075 SURFA CEMEI~ RURD P RU Dowell cement head and circ hoses. _ _ ~~ m ~ _ ~ _ ~ ~'a~~ 1~ o$ a~ Time Logs -~ Date From To Dur th E. De th Phase Code Subcode ~OM 04/14/2006 22:30 00:00 1.50 8,075 8,075 SURFA CEMEf~ _ CIRC P Circ prior to cement job. Start w/ 3 bpm w/ 150-160 psi, Circ 63 bbls, stage up to 4 bpm (180-200 psi) w/ total of 170 bbls pumped, stage up to 5 bpm (280-310 psi) for total of 295 bbls um ed midni ht. 04/15/2006 00:00 03:15 3.25 8,075 8,075 SURFA CEME~ CIRC P Continue circulating prior to cementing. Circulating @ 5 bpm (280-310 psi) until total of 450 bbls pumped (Bottoms up). Stage pumps to 5.5 bpm (310-330 psi) until total of 625 bbls pumped. Stage up to 6 bpm (340-360 psi) until total of 1525 bbls pumped. Reoi p+i~ for 30' stroke. PU wt 340k-350k. SO wt 140-145k. 03:15 03:30 0.25 8,075 8,075 SURFA CEMEf~ SFTY P Hold PJSM with drilling crew and dowell and truck drivers while continue circulating prior to cementing. Circulating @ 6 bpm (340-360 psi) until total of 1600 bbls pumped. Reciprocating pipe for 30' stroke. PU wt 340k-350k. SO wt 140-145k. 03:30 03:45 0.25 8,075 8,075 SURFA CEMEI~ CIRC P Continue circulating prior to cementing. Circulating @ 6 bpm (340-360 psi) until total of 1672 bbls pumped. Reciprocating pipe for 30' stroke. PU wt 340k-350k. SO wt 140-145k. Final mud properties: Wt 9.5 ppg, vie 56, PV 16, YP 19, 10 sec gal = 8, 10 min gel = 9, 30 min gel = 10. 03:45 07:15 3.50 8,075 8,075 SURFA CEMEI~ PLUG P Dowell pump 10 bbls CW 100, test lines to 3500 psi, pump 40 bbls f/ total of 50 bbls CW 100 @ 5.5 bpm w/ 300 psi, shut down and drop bottom plug, mix and pump 70 bbls MudPush (10.5 ppg) w/ red dye @ 4.5-5.3 bpm w/ 230- 380 psi, follow by mixing and pumping @ 6.5-5 bpm w/ 366 psi- 170 psi :462 bbls ASlite lead (10.7 ppg) (yield 4.49 cuft/sx = 577.7 sx) ,follow @ 05:47 hrs mixing 342 bbls LiteCrete tail 12.0 ppg) (yield 2.46 cuft/sx = 780.5 sx), pumping 4-4.5 bpm w/ 400-900 psi. Shut down, drop top plug. Dowell pump 20 bbls water @ 5 bpm w/300 psi and turn over to rig for displacement. ReeiFxoced pipe 30' stroke unit) 16fl bbts lead cement around shoe w/ final PU wt 420k and SO wt 135k. Landed on hanger @ 0708 hrs. ~ _ e e 1~~~r ~;~ czz ~ i.~.._.~.. . ~ ~...~ _ ~ . ._. .._ Time Logs _ Date From To Dur ~ th E. De th Phase Code Subcode .,OM 04/15/2006 07:15 08:15 1.00 8,075 8,075 SURFA CEME~ DISP P Rig displace cement w/ 9.5 ppg mud w/ rig pumps. Initial rate 5 bpm w/ 360 psi, after 50 bbls pumped (0732 hrs) press 490 psi, after 110 bbls pumped 720 psi, after 150 bbls pumped 800 psi, after 200 bbls pumped 940 psi then slowed pumps to 4.5 bpm. After 220 bbls total pumped :1000 psi, after 231 bbls pumped : 1040 psi, after 251 bbls total pumped, rate was slowed down to 4 bpm w/ 1260 psi (appears to be fosl a smelt arr+ount oaf returns . 08:15 09:30 1.25 8,075 8,075 SURFA CEMEI~ DISP T Rig displace cement w/ 9.5 ppg mud w/ rig pumps. After total of 272 bbls pumped,still 4 bpm w/ 1310 psi, showing to be bring aN returns. Slowed pumps to 2 bpm w/ 1190 psi after pumping a total of 278 bbls. Shut down pumps @ 0825 hrs and pressure decreased and stayed @ 840 psi. Attempt to circ. Pumped @ 2 bpm w/ 1190 psi, with 278 bbls pumped, slowed to .7 bpm w/ 1700 psi @ 0834 hrs w/ 286 bbls pumped. Pressure broke back f/ 1700 psi to 1320 psi and pump rate increased to 1 bpm. Pumped @ 1-1.5 bpm with press increasing f/ 1320 psi to 1710 psi @ 0847 hrs & 302 bbls total pumped. Gon~ued to purrrp ~ returns f! 1 to .5 bpm w! pressure creasing f/ 1794 pai to' 3~€)fT psi rK/ rro returns. Had tried to work pipe to regain circ and ended up w/ hanger above starting head approx 6 -8 1/2". Max pull 600k including block/top drive wt of 70k. Shut down pumps @ 0925 hrs w/ total of 332 bbls mud displacement. 2A~93 strokes of ~ displacement (251 bbls before calculated . 09:30 12:00 2.50 8,075 8,075 SURFA CEMEt` RURD P Bleed off 3800 psi pressure. Drain stack. Rig down Dowell cement head, remove slips, elevators, change bails and elevators. Blow down mud lines. Remove landing joint. Break connection to split below floor, RIH, make up landing joint, remove top section of 9-5/8" landing joint, leaving the rest below floor level. 12:00 12:15 0.25 8,075 8,075 SURFA CEMEI~ SFTY T PJSM on running TAM port collar Combo tool. 12:15 14:30 2.25 0 1,010 SURFA CEMEI~ TRIP T RIH w/ TAM port combo tool on 5" drill pipe to open TAM port collar @ 1010'. RU circulatin / cementin hose. ~~ r ~~e ~1~ oaf S m® ~ Time Logs _ _ Date From To Dur th E. De th Phase Code Subcode OM _ 04/15/2006 14:30 15:30 1.00 1,010 1,010 SURFA CEMEI~ CIRC T Circulate bottom's up on 12-1/4" x 9-5/8" annulus. Circ @ 5 bpm w/ 90 psi. TotaP sf 33t3 . No ~cerneni bserved in annulus. 15:30 15:45 0.25 1,010 1,010 SURFA CEMEf~ SFTY T PJSM w/ Dowell and rig crew on cement 'ob throu h TAM ort collar. 15:45 17:00 1.25 1,010 1,010 SURFA CEMEf~ PLUG T Dowell pump 20 bbls water ahead, follow w/ASLite (10.7 ppg) (yield 4.49 cuft/sx) 183 bbls cement pumped, 20 bbls cement returns to surface.. Dowell dis lace w/ 18 bbls water. 17:00 17:15 0.25 1,010 1,010 SURFA CEMEf~ CIRC T Shut Tam port collar. Test to 1000 psi. OK. R/D circulating lines. Blow down lines. 17:15 18:00 0.75 1,010 0 SURFA CEMEI~ TRIP T POOH w/ TAM shifting tool and 5" drill i e. 18:00 18:15 0.25 0 0 SURFA CASIN( SFTY T PJSM on laying down casing tools f/ ri floor. 18:15 18:45 0.50 0 0 SURFA CASIN( RURD T Clear rig floor of casing tools. 18:45 19:00 0.25 0 0 SURFA CEMEf~ CIRC T Flush out TAM shifting tool w/water @ 3b m. Pum 10 bbls. 19:00 20:15 1.25 0 0 SURFA CEMEf~ OTHR T Drain stack. Use trip tank pump and flush stack w/ SAPP pill. UD TAM port collar shifting tool/ Blow down cement line back to mud um s. 20:15 20:45 0.50 0 0 SURFA CEMEI~ OTHR T PU single of drill pipe in shed. Make up to the double used to MU TAM tool. Stand back stand. Hang up cement hose. 20:45 21:15 0.50 0 0 SURFA CASIN( OTHR T PU/MU 9-5/8" pup joint on top of landing joint. Back out of FMC hanger LH thread . UD landin 'oint. 21:15 21:45 0.50 0 0 SURFA WELCT OTHR P Flush out stack again w/ SAPP pill. Flush flow line back to its. 21:45 00:00 2.25 0 0 SURFA WELCT NUND P N/D 21 1/4" diverter system. Flush flow line some more. Cement in flow line. 04/16/2006 00:00 02:00 2.00 0 0 SURFA WELCT NUND P Finish nippling down diverter system. 02:00 04:45 2.75 0 0 SURFA WELCT WOOR T Waiting on decision of how to handle mandrel fluted hanger being 6" above landed position. Confirm w/ FMC and en ineer ono tions. 04:45 05:00 0.25 0 0 SURFA WELCT OTHR P Back out 4 set screws on fluted hanger and let mandrel drop down into starting head to load shoulder. Measures 6" that ring is away from han er bod . 05:00 07:00 2.00 0 0 SURFA WELCT NUND P NU FMC Gen 5 casing head and tubin s ool. Time Logs a Date From To Dur ~ th E. De th Phase Code Subcode OM 04/16/2006 07:00 11:30 4.50 0 0 SURFA WELCT NUND P _ Continue nippling up DSA, Spacer spool, 13-5/8" BOP stack. Torque all connections. Install turnbuckles. Attatch choke and kill lines. Change out spacer spool f/ choke line. Cut and weld flow nipple. Set mouse hole in lace. 11:30 12:00 0.50 0 0 SURFA WELCT OTHR P Rig up to test BOPE. MU test joint. RU test um . 12:00 13:00 1.00 0 0 SURFA WELCT OTHR P Fill BOP stack with water. Check for leaks. Bod test BOP stack. 13:00 13:15 0.25 0 0 SURFA WELCT SFTY P PJSM on testing BOP equipment. 13:15 22:00 8.75 0 0 SURFA WELCT BOPE P Test BOPE. Witness of test by AOGCC inspector John Spaulding. Test all components to 250 psi low and 3500 psi high. Hold each test 5 min low and 5 min high. Test accumulator, full chage 3100 psi, after closure 1350 psi, 200 psi build up in 43 seconds, full charge 3 min 17 seconds. Nitrogen precharge avg 1900 psi. Tested methane and H2S gas alarms. Tested w/ 5" test joint both top and bottom rams and annular, and top i e rams onl w/ 7" test 'oint. 22:00 23:45 1.75 0 0 SURFA WELCT NUND P Nipple up riser on top of hydril. Connect flow line. 23:45 00:00 0.25 0 SURFA WELCT OTHR P Blow down kill and choke lines and choke manifold after testing BOPE. Ri in down test a ui ment. 04/17/2006 00:00 00:15 0.25 0 0 SURFA WELCT OTHR P Continue to blow down kill and choke lines and choke manifold after testing BOPE. Ri in down test a ui ment. 00:15 01:15 1.00 0 0 SURFA WELCT OTHR P RIH with test joint, screw into test plug, pull test plug. RIH w/ FMC wear bushing. Wear bushing is 38' long, 9-7/8" ID, 10.8" OD. 01:15 02:30 1.25 0 1,054 SURFA DRILL TRIP T MU mule shoe, RIH 11 stands of 5" dp f/ derrick (pipe used to cement 9-5/8" trough TAM port collar). RIH slow due to fluid runnin over the to ofd . 02:30 02:45 0.25 1,054 1,054 SURFA RIGMN SFTY P PJSM with crew and tourpusher on slipping and cutting drilling line. First time to cut line with this crew. 02:45 04:45 2.00 1,054 1,054 SURFA RIGMN SVRG P Slip and cut 145' of 1-3/8" drilling line. Inspected brakes, drum, drilling line, deadman, linka es, and do knot. 04:45 05:45 1.00 1,054 1,054 SURFA RIGMN SVRG P Service top drive, crown, blocks and drawworks. Clean and inspect saver sub. 05:45 08:00 2.25 1,054 1,054 SURFA RIGMN SVRG P Change out 4-1/2" IF saver sub on top drive. 08:00 10:45 2.75 1,054 1,054 SURFA DRILL CIRC T Circ 400 bbls through 5" dp @ 1054' to flush out drill i e. -.-~_s~~. ~ ~ P~~~e `ta of ~~ ~ ~.___._ ~ _ Time Logs i Date From To Dur e th E. D~th Phase Code Subcode OM - 04/17/2006 10:45 11:30 0.75 1,054 0 SURFA DRILL TRIP T POOH, UD 11 stands of Weatherford 5" d . 11:30 11:45 0.25 0 0 SURFA DRILL SFTY T PJSM on PU BHA # 4. 11:45 14:00 2.25 0 770 SURFA DRILL PULD T PU/MU BHA #4 : Hughes 8-1/2" MXL-1 milltooth bit w/ 3-20's and 1-12 jet nozzle (TFA 1.031), 7" SperryDrill 6/7-6 stage motor w/ 0 deg bend (.33 rev per gal) , nm float sub, (3) 6-1/2" NM flex drill collars, (3 jts) Weatherford 5" HWDP, Drilling jars w/ 150.19 hrs, (5 jts) Weatherford 5" drill pipe, accelerators, (11jts) Weatherford 5" HWDP to 770.7' to cleanout cement inside of 9-5/8" casin . 14:00 14:45 0.75 770 1,054 SURFA DRILL PULD T Continue RIH f! 770.70' to 1054', picking up 5" newly inspected Weatherford drill pipe f/ pipe shed. Rabbit pipe to 2.875". Pick up total of 9 jts (3) stands. MU top drive. Pressure test port collar to 500 psi f/ 5 min. Good test. Blow down to drive. 14:45 18:00 3.25 1,054 3,148 SURFA DRILL PULD T Continue RIH f/ 1054' to 3148' picking up 5" newly inspected Weatherford drill pipe f/ pipe shed. Rabbit pipe to 2.875". Pick up total of 66 jts more for total of 75 jts. (22 more f/ total of 25 stands . 18:00 19:30 1.50 3,148 4,100 SURFA DRILL PULD T Continue RIH f/ 3148' to 4100' picking up 5" newly inspected Weatherford drill pipe f/ pipe shed. Rabbit pipe to 2.875". Pick up total of 30 jts more for total of 105 jts. (10 more f/ total of 35 stands . 19:30 20:30 1.00 4,100 2,863 SURFA DRILL TRIP T POOH, stand back 13 stands of Weatherford 5" d fresh) ins ected . 20:30 22:00 1.50 2,863 4,098 SURFA DRILL PULD T Continue RIH f/ 2863' picking up 5" newly inspected Weatherford drill pipe f/ pipe shed. Rabbit pipe to 2.875". Pick up remaining 39 jts more for total of 144 jts. (13 more f/ total of 48 stands-- only 35 stands in hole-- 13 stands in derrick. . 22:00 22:45 0.75 4,098 4,383 SURFA DRILL TRIP T MU top drive, break circ, RIH f/ 4097' to 4383' Stand 38 in hole . 22:45 23:15 0.50 4,383 4,519 SURFA DRILL CIRC T MU top drive, fill pipe, establish circulation @ 26 spm w/ 330-390 psi. RIH f/ 4383 and tag up w/ 15k wt @ 4519' 40.5' in on stand 40 . 23:15 00:00 0.75 4,519 4,380 SURFA DRILL CIRC T Pull back and stand back stand # 40 (4519' to 4378'). Circ and recip stand # 39 f/ 4475' to 4380'. Circ @ 126 spm (530 gpm) w/ 1320 psi. Rotate pipe 30 rpm w/ 8-10k ft Ib torque. PU wt 200k, So wt 100k. Circ total of 3728 strokes 375 bbls midni ht. ®T._ ® Time Logs ~ Date From To Dur e th E. De th Phase Code Subcode ~ ~"OM 04/18/2006 00:00 00:15 0.25 4,380 4,478 SURFA DRILL CIRC T Circ and recip stand # 39 f/ 4475' to 4380'. Circ @ 126 spm (530 gpm) w/ 1320 psi. Rotate pipe 30 rpm w/ 8-10k ft Ib torque. PU wt 200k, So wt 100k. Circ total of 5528 strokes 556.7 bbls . 00:15 00:30 0.25 4,478 4,478 SURFA DRILL OTHR T Blow down top drive. 00:30 01:15 0.75 4,478 4,478 SURFA DRILL DHEQ T RU to test 9-5/8" casing. Bleed air from kill line and cement sirs hose. RU to chart test. 01:15 02:00 0.75 4,478 4,478 SURFA DRILL DHEQ T Test 9-5/8" 40 ppf L-80 BTC, test to 3000 psi. Pump @ 5 spm (0.5 bpm), 4.4 bbls to pressure up (total of 44 strokes). Shut in csg f/ 30 min. charted test. Lost 30 psi. Good test. Bleed off fluid. 02:00 03:00 1.00 4,478 4,478 SURFA DRILL DHEQ T R/D test equipment. Blow down kill line. 03:00 06:00 3.00 4,478 4,700 SURFA CEMEC\ COCF T MU top drive on stand # 40, rotate @ 60 rpm, pump @ 500 gpm (mtr rpm = 165 rpm), pressure 1270 psi. PU wt 200k, SO wt 100k, Rotating wt 130k. T top plug @ 4525' MD, Drill semen# inside of 9-5/8" casing f/ 4519' to 4700'. 06:00 12:00 6.00 4,700 5,240 SURFA CEMEf~ COCF T Drill cement inside of 9-5/8" casing f/ 4700' to 5240'. WOB= 8-15k. Pumping 357 to 551 gpm w/ 790 to 1390 psi. Bit rpm = 118 to 182, Rotate 120 rpm w/ 6-15k ft Ib torque. PU wt @ 5240' _ 230k, SO wt = 95 k, Rotatin wt 142k. 12:00 18:00 6.00 5,240 6,030 SURFA CEMEf~ COCF T Drill cement inside of 9-5/8" casing f/ 5240' to 6030'. WO6= 10-16k. Pumping 551 to 702 gpm w/ 1440 to 2050 psi. Bit rpm = 182 to 232, Rotate 120 rpm w/ 6-16k ft Ib torque. PU wt @ 6030' = 250k, SO wt = 100k, Rotating wt 148k. 18:00 00:00 6.00 6,030 6,513 SURFA CEME~ COCF T Drill cement inside of 9-5/8" casing f/ 6030 - 6513'. WO6= 10-16k. Pumping 702- 420 gpm w/ 2270 to 930 psi. Bit rpm = 232 to 139 Rotate 120 rpm w/ 6-16k ft Ib torque. PU wt @ 6513' _ 260k, SO wt = 110k, Rotating wt 152k. Note: Displaced mud in hole to 8.4 ppg water--PH was ettin hi h. 04/19/2006 00:00 02:00 2.00 6,513 6,666 SURFA CEME~ COCF T Drill cement inside of 9-5/8" casing f/ 6513 - 6666'. WO6= 10-15k. Pumping 704-712 gpm w/ 1600 to 1800 psi. Bit rpm = 232 to 235 Rotate 120 rpm w/ 16k ft Ib torque. PU wt @ 6666' _ 261 k, SO wt = 110k, Rotating wt 154k. Note: Displaced mud in hole to 8.4 ppg water--PH was ettin hi h. ~_ --~ ~ e -- - P~~ 1 ~a i......~,.....~..~v. 0 m~~ e ~ 3 Time Logs _ Date From To Dur .. e th E. De th Phase Code Subcode OM 04/19/2006 02:00 03:30 1.50 6,666 6,666 SURFA RIGMN RGRP T Remove actuating hydraulic cylinder on top drive f/ upper IBOP vavle. Leaking hyd fluid. Circ while working on removal w/ circ hose 250 m. 03:30 06:00 2.50 6,666 6,900 SURFA CEME~ COCF T Drill cement inside of 9-5/8" casing f/ 6666' - 6900'. WO6= 10-14k. Pumping 704-710 gpm w/ 1800- 1820 psi. Bit rpm = 232 to 235 Rotate 120 rpm w/ 16k ft Ib torque. PU wt @6900' = 270k, SO wt = 105k, Rotating wt 160k. 06:00 12:00 6.00 6,900 7,510 SURFA CEMEf~ COCF T Drill cement inside of 9-5/8" casing f/ 6900' - 7510. WO6= 10-14k. Pumping 705 gpm w/ 1820- 1850 psi. Bit rpm = 232. Rotate 120 rpm w/ 16-20k ft Ib torque. PU wt @ 7510' = 315k, SO wt = 95k, Rotating wt 162k. Pumped sweep @ 0900 hrs (7047') and 1200 hrs 7510' , 48 bbls each. 12:00 15:00 3.00 7,510 7,878 SURFA CEMEf~ COCF T Drill cement inside of 9-5/8" casing f/ 7510' to 7878'. WOB= 10-18k. Pumping 705 gpm w/ 1820- 180-18700 psi. Bit rpm = 232. Rotate 120 rpm w/ 11-21 k ft Ib torque. PU wt @ 7878' _ 315k, SO wt = 90k, Rotatin wt 165k. 15:00 16:15 1.25 7,878 7,878 SURFA DRILL CIRC P Circulate and recip pipe prior to erformin casin test. 16:15 16:30 0.25 7,878 7,878 SURFA DRILL RURD P RU to test equipment 9-5/8" 40 ppf L-80 BTC casing. RU hoses and chart recorder. 16:30 17:00 0.50 7,878 7,878 SURFA DRILL DHEQ P Perform casing test. Weight of water in the hole 8.5 ppg.Pump 5-6 spm (1/2 bpm). Pressure to 3000 psi. Hold test for 30 min. Lost 125 si. Good test. 17:00 17:30 0.50 7,878 7,878 SURFA DRILL RURD P Bleed off pressure. Rig down test e ui ment. Blow down lines. 17:30 18:00 0.50 7,878 7,878 SURFA RIGMN RGRP T Install hydraulic cylinder for accuation of u er IBOP valve on to drive. 18:00 19:15 1.25 7,878 7,956 SURFA CEME~ COCF T Drill cement inside of 9-5/8" casing f/ 7878' to 7956' (bottom wiper plug ) +(Float collar). WOB= 10-18k. Pumping 705 gpm w/ 1820 -1870 psi. Bit rpm = 232. Rotate 120 rpm w/ 11-21 k ft Ib torque. PU wt @ 7956' _ 315k, SO wt = 115k, Rotatin wt 175k. 19:15 21:15 2.00 7,956 8,055 SURFA CEMEI~ DRLG P Drill cement f/ 7956' to 8055'. WO6= 10-14k. Pumping 705 gpm w! 1820- 180-18700 psi. Bit rpm = 232. Rotate 120 rpm w/ 11-21k ft Ib torque. PU wt @ 8055' = 315k, SO wt = 115k, Rotatin wt 175k. 21:15 23:30 2.25 8,055 8.,055 SURFA CEME~ CIRC T Change out 8.5 ppg water in hole to 9.4 ppg LSND mud by circulating bottom's up ,follow w/ biozan sweep, then 9.4 LSND mud. _.,......._____ ---- _ ___. ~~. _e. ....._.....,ma~r~~ 13 rsf 52 Time Los Date From To Lour e th E. De th Phase Code Subcode OM 04/19!2006 23:30 00:00 0.50 8,055 8,075 SURFA CEME~ DRLG P Drill cement inside of 9-5/8" shoe track f/ 8055' to FS @ 8073' to 8075'. W06= 10-12k. Pumping 440 gpm (#2 mud pump) w/ 1200 psi. Bit rpm = 145. Rotate 120 rpm w/ 17k ft Ib torque. PU wt @ 8075' = 320k, SO wt = 115k, Rotating wt 170k. Hrs on bit @ midni ht = 27.72 hrs. 04/20/2006 00:00 01:00 1.00 8,075 8,110 SURFA CEMEI~ DRLG P Drill rat hole f/ 8075' to 8090', then 20' new hole f/ 8090' to 8110'. W06= 10-12k. Pumping 440 gpm (#1 mud pump) w/ 1050 psi. Bit rpm = 145. Rotate 110 rpm w/ 17k ft Ib torque. PU wt @ 8075' = 250k, SO wt = 115k, Rotating wt 170k. Hrs on bit = 28.13hrs. 01:00 03:00 2.00 8,000 8,000 SURFA DRILL CIRC P Circulate and condition mud to 9.6 . Circ 700 m w/ 2200 si. 03:00 03:30 0.50 8,110 8,000 SURFA DRILL TRIP P POOH 2 stands to get up inside of surface casin 8000'. 03:30 04:30 1.00 8,000 8,000 SURFA DRILL FIT P RU and perform Formation integrity test to 14.6 ppg. 9.6 ppg MW 1080 psi TVD 4120'. 04:30 04:45 0.25 8,000 8,000 SURFA DRILL OTHR P Biow down kill line and circ line. 04:45 05:00 0.25 8,000 8,000 SURFA DRILL TRIP P RU and pump dry job. 2 ppg over mud wt= 11.6 05:00 05:30 0.50 8,000 8,000 SURFA RIGMN RGRP T Work on hole fill pump (trip pump). Re lace 2" hose frozen . 05:30 10:30 5.00 8,000 28 SURFA CEMEf~ TRIP T POOH w/ BHA #5 (cleanout cement inside of 9-5/8" casing). POOH f/ 8000' to 28'. Record PU & SO wt's every 10 stands. 10:30 11:45 1.25 28 0 SURFA CEME~ PULD T UD BHA #4 : nm float sub, 7" SperryDrill 6/7- 6 stage mtr (ser # 700091) and Hughes 8-1/2" MXL-1 bit ser # 5084362 . Clear ri floor. 11:45 12:00 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up BHA #5 (mtr assembl to drill 8-1/2" intermediate . 12:00 13:30 1.50 0 111 SURFA DRILL PULD P PU/MU BHA #5. 8-1/2" Hughes HCM605 PDC bit (ser # 7110657), 7" SperryDrill 6/7- 6 stage mtr (ser # 700162), welded blade stabilizer, nm float sub, Gamma/Res/PWD, directional, Neutron density, TM-HOC to 111'. 13:30 14:15 0.75 111 111 SURFA DRILL OTHR P Upload Sperry MWD/LWD tools. 14:15 15:00 0.75 111 134 SURFA DRILL PULD P Continue PU/MU BHA # 5 : Bat sonic to 134'. 15:00 15:15 0.25 134 134 SURFA DRILL SFTY P PJSM on loading nuke sources w/ S er Sun and drillin crew. 15:15 15:45 0.50 134 134 SURFA DRILL OTHR P Sperry Sun load nuke sources. ~~ ~ s~~~ ~. .~~ ~ ~~ ~f Time Logs Date From To Dur e th E_ De th Phase Code Subcode _ (~M 04/20/2006 15:45 16:45 1.00 134 876 SURFA DRILL TRIP P MU stand of 6-1/2" flex collars, stand of Weatherford 5" HWDP, stand w/ drilling jars (ser # 15061148) on top and (2) Weatherford 5" HWDP, another stand of Weatherford 5" HWDP, stand w/ accelerators on top w/ (2) Weatherford 5" HWDP, follow w/ 3 more stands Weatherford 5" HWDP to 876.77' 16:45 18:00 1.25 876 3,254 SURFA DRILL TRIP P Continue trip in hole w/ BHA # 5 f/ 876.66'. PU 1st stand of Weatherford 5, MU top drive on 2nd stand, Rotate through TAM port collar @ 1010'. Saw a 10k bobble while going through TAM port collar. Trip in hole to stand #25 bit de th 3254' . 18:00 18:30 0.50 3,254 3,254 SURFA DRILL DHEQ P Pressure test 9-5/8" casing to 510 psi to verify TAM port collar did not get shifted open. Pump @ 5 spm through kill line and down drill string. Pump a total of 16 strokes (1.6 bbls). Hold f/ 5 min. OK. Blow down top drive and kill line. 18:30 21:30 3.00 3,254 7,535 SURFA DRILL TRIP P Continue trip in hole f/ 3254' to 7535'. Fill pipe @ 5630'. Pump 50 spm (210 gpm) w/365 psi. Record PU and SO wts eve 10 stands. 21:30 22:30 1.00 7,535 7,535 SURFA RIGMN SVRG P Service rig and top drive. 22:30 23:00 0.50 7,535 7,535 SURFA DRILL OTHR P Test MWD tools @ 7535' 23:00 23:30 0.50 7,535 8,110 SURFA DRILL TRIP P Continue RIH f/ 7535' to 8003'. Tagged fill. Ream f/ 8103' to 8110'. Pumping 553 gpm w/ 1950 psi. WOB 5-8k. 55 r m. 23:30 00:00 0.50 8,110 8,105 SURFA DRILL OTHR P Perform PWD baseline test @ 8105'. 80 rpm w/ 505 gpm = 10.59 ppg, 80 rpm w/ 550 gpm = 10.67 ppg, 100 rpm w/ 505 gpm = 10.62 ppg, 100 rpm w/ 550 m = 10.69 04/21/2006 00:00 00:30 0.50 8,105 8,105 INTRM1 DRILL CIRC P Pump 48 bbls steel tube pill, follow w! 9.5 ppg mud, pump 100 bbls up into casin rior to drillin . 00:30 06:00 5.50 8,110 8,386 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 8110' - 8386' (276') (TVD = 4246'). ART = 4.59 hrs, AST = 0.0 hrs. Total hrs on bit = 4.59 hrs., Total hrs on jars = 176.5 hrs, 3-8k WOB, 80 rpm's, 179 mtr rpm, 544 gpm w/ 9.5 ppg MW, on bottom press 1950- 2025 psi, off bottom press 1880-1900 psi, on bottom torque 16-20k ft/tb, off bottom torque 15-16k ft/ Ib, PU wt 270-290k, SO wt 120k, Rot wt 175k. Max gas= 26 units. ECD's = 10.5- 10.68 ~~ ® ~ ® e® ~~ .~ ~~~ ~ ; ~t ~ Time Los r~ Date From To Dur ._ e th E. De th Phase Code Subcode ~ - OM 04/21/2006 06:00 12:00 6.00 8,386 8,768 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 8386' - 8768' (382') (TVD = 4396'). ART = 3.14 hrs, AST = 0.4 hrs. Total hrs on bit = 8.13 hrs., Total hrs on jars = 180.04 hrs, 10-12k WOB, 80-90 rpm's, 189-194 mtr rpm, 574-588 gpm w/ 9.5 ppg MW, on bottom press 2410-2510 psi, off bottom press 2360-2420 psi, on bottom torque 16-20k ft/Ib, off bottom torque 19-21 k ft/ Ib, PU wt 270-280k, SO wt 125-128k, Rot wt 175k. Max gas= 25 units. ECD's = 10.94-11.39 ppg. Pumped 52 bbl Hi vis weighted sweep @ 8486' w/ 5 ppb nut plug, 10.7 12:00 13:15 1.25 8,958 8,867 INTRM1 DRILL CIRC P Pump 63 bbl Hi vis weighted sweep @ 8946' w/ 5 ppb nut plug, 10.7 ppg. CBU. Pump total of 1247 bbls @ 583 gpm w/ 2650 psi. Rotate pipe @ 90 rpm w/ 16-17k ft Ib torque. Reciprocate i e f/ 8958' to 8867' 13:15 17:30 4.25 8,768 8,958 INTRMI DRILL DDRL P Directional Drill 8-1/2" hole w/7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 8768' - 8958' (190') (TVD = 4473'). ART = 2.35 hrs, AST = 0.27 hrs. Total hrs on bit = 10.75 hrs., Total hrs on jars = 182.66 hrs, 10-12k WOB, 90 rpm's, 190- 192 mtr rpm, 577-583 gpm w/ 9.5 ppg MW, on bottom press 2510-2630 psi, off bottom press 2400-2450 psi, on bottom torque 16-20k ft/Ib, off bottom torque 17-21 k ft/ Ib, PU wt 285k, SO wt 130k, Rot wt 175k. Max gas= 29 units. ECD's = 11.32-11.36 17:30 18:00 0.50 8,958 8,958 INTRM1 DRILi_ CIRC T Record SPR's @ 8958' (4473' TVD). Attemp to mode switch MWD tools. # 1 mp @ 20 spm = 320 psi, 30 spm = 390 psi. #2 mp @ 20 spm = 320 psi, 30 s m = 390 si. 18:00 18:45 0.75 8,958 7,915 INTRM1 DRILL TRIP T POOH f/ 8958' to 7915' on elevators, wet. Monitor well f/flow- OK. 18:45 19:15 0.50 7,915 7,915 INTRM1 DRILL CIRC T Pump dry job, blow down top drive. 19:15 22:30 3.25 7,915 876 INTRM1 DRILL TRIP T POOH f/ 7915' to 876'. Record PU and SO wt's. 22:30 23:30 1.00 876 134 INTRM1 DRILL TRIP T Continue POOH, standing back Weatherford 5" HWD and jars and Sperry Sun 6-1 /2" flex collars from 876' to 134'. 23:30 00:00 0.50 134 134 INTRM1 DRILL OTHR T PJSM w/drilling crew and Sperry Sun on removing nuke sources. Also discussed BHA. Remove sources. 04/22/2006 00:00 01:30 1.50 134 134 INTRM1 DRILL OTHR T Sperry Sun download and troubleshoot tools strin BHA #5 . °~.~` - F?ar~~ ~~ oaf ~2._.. . s ~ ~ ~_ ~ ..~... Time Logs J` Date From To Dur e~th E. De th Phase Code Subcode OM 04/22/2006 01:30 03:15 1.75 134 27 INTRM1 DRILL PULD T L/D Sperry Sun MWD/LWD tools BHA #5 . 03:15 03:30 0.25 31 31 INTRM1 DRILL TRIP T POOH w/non mag float sub, welded straight blade stabilizer, 7" Speny drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend and Hughes 8-1/2" HCM605 (ser # 7110657) bit # 4. Bit looks good. Graded 1-1- Wt-A-E-O-No-DTF. RIH BHA # 6: 8-1/2" Hughes Bit # 4rr1 and Sperry drill 6/7 lobe- 6 stage mtr w/ 1.50 deg bend, welded straight blade stabilizer, and nm float sub. 03:30 05:00 1.50 31 109 INTRM1 DRILL PULD T Continue PU/MU BHA #6. PU new Sperry Sun Gamma/Res/PWD, same directional, changed neutron density, chan ed ulsar in TM-HOC to 109' 05:00 06:00 1.00 109 109 INTRM1 DRILL OTHR T Upload MWD tools. 06:00 07:00 1.00 109 109 INTRM1 DRILL OTHR T Shallow test MWD tools. Blow down to drive. 07:00 12:45 5.75 109 109 INTRM1 DRILL WOEQ T Waiting on Sperry Sun computer to talk to Bat sonic tool. While waiting: Table top drill w/ Waye Pitka crew on stripping in hole. H2S drill also. Service rig. Troubleshoot for ground fault- found small wall heater in SCR house. Computer still would not talk to Bat Sonic tool or backu tool. 12:45 13:30 0.75 109 109 INTRM1 DRILL OTHR T PJSM on loading nuke sources. Load sources. 13:30 14:00 0.50 109 852 INTRM1 DRILL TRIP T Finish RIH w/ BHA F/ 109' to 852'. Rotated through TAM port collar @ 110', no roblems. 14:00 16:30 2.50 852 3,230 INTRM1 DRILL TRIP T Continue trip in hole w/ BHA #6 f/ 852'. RIH to 3230', fill pipe, check MWD tools w/ 500-550 gpm w/ 1450-1670 psi. Pumped total of 281 bbls. Record PU & SO wt's eve 10 stands. OK. 16:30 18:45 2.25 3,230 7,896 INTRM1 DRILL TRIP T Continue trip in hole f/ 3230' to 7896'. Fill i e. 18:45 20:45 2.00 7,896 7,896 INTRM1 DRILL OTHR T Checking out Sperry Sun equipment. Intermittant pulses, no detection. Serviced stroke counters on mud pumps. Toggle tool to slower rate. Detection restored. Purring 63 spm both pumps =total of 126 spm (532 m w/ 2100 si. 20:45 21:45 1.00 7,896 8,935 INTRM1 DRILL TRIP T RIH f/ 7896 to 8935'. 21:45 22:00 0.25 8,935 8,961 INTRM1 DRILL REAM T MU top drive. fill pipe, ream f/ 8935' to bottom 8961'. 22:00 22:30 0.50 8,961 8,961 INTRM1 DRILL SRVY T PU to 8958', MWD survey. ._ ~~ ~ e .~~® age oaf s2 Time Lo s Date From To Dur th E. De th Phase Code Subcode COM 04/22/2006 22:30 00:00 1.50 8,961 9,030 INTRMI DRILL DRLG P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 8961' - 9030' (69') (TVD = 4506'). ART = 1.00 hrs, AST = 0.3 hrs. Total hrs on bit = 1.3 hrs., Total hrs on jars = 183.96 hrs, 3-5k WOB, 80 rpm's, 178 mtr rpm, 540 gpm w! 9.5 ppg MW, on bottom press 2250 psi, off bottom press 2030 psi, on bottom torque 18-20k ft/Ib, off bottom torque 15-20k ft/ Ib, PU wt 275k, SO wt 105k, Rot wt 175k. Max gas= 0 units. ECD's = 10.98- 11.2 04/23/2006 00:00 06:00 6.00 9,030 9,345 INTRM1 DRILL DRLG P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 9030' -9345' (315') (TVD = 4625'). ART = 3.12 hrs, AST = 0.4 hrs. Total hrs on bit = 4.82 hrs., Total hrs on jars = 187.48 hrs, 3-6k WOB, 80- 90 rpm's, 178- 200 mtr rpm, 540- 606 gpm w/ 9.5-9.9 ppg MW, on bottom press 2250- 2600 psi, off bottom press 2030- 2375 psi, on bottom torque 16-20k ft/Ib, off bottom torque 15k ft/ Ib, PU wt 270-280k, SO wt 122-130k, Rot wt 165-170k. Max gas= 26units. ECD's = 10.98- 11.2 06:00 08:00 2.00 9,345 9,504 INTRM1 DRILL DRLG P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 9345' -9504' (159') (TVD = 4688'). ART = 1.42 hrs, AST = 0.0 hrs. Total hrs on bit = 6.24 hrs., Total hrs on jars = 188.9 hrs, 4-8k WOB, 90 rpm's, 199-196 mtr rpm, 604-596 gpm w/ 9.5-9.6 ppg MW, on bottom press 2480-2390 psi, off bottom press 2368-2370 psi, on bottom torque 16-20k ft/Ib, off bottom torque 18-19k ft/ Ib, PU wt 278-275k, SO wt 130-135k, Rot wt 180k. Max as= 26units. ECD's = 10.29-11.4 08:00 10:15 2.25 9,504 9,318 INTRM1 DRILL CIRC P Change out liner and swab in # 2 mud pump. While changing out, circ and recip f/ 9504' to 9413'. Set back a stand after a hr. Recip and work pipe f/ 9413' to 9318'. Continue circulating w/ # 1 pump while working on # 2 mud um . 10:15 10:30 0.25 9,318 9,504 INTRM1 DRILL TRIP P Put # 2 pump on hole, OK. RIH f/ 9318' to 9504'. ,- ®~a~_~ ~ ~~ ~ P~~ ~~~1..~_~f ~~ ~ Time Logs Date From To- Dur e th E. De th Phase Code Subcode l OM 04/23/2006 10:30 12:00 1.50 9,504 9,599 INTRM1 DRILL DRLG P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 9504' -9599' (95') (TVD = 4728'). ART = .98 hrs, AST = 0.0 hrs. Total hrs on bit = 7.22 hrs., Total hrs on jars = 189.88 hrs, 6-10k WOB, 90 rpm's, 197 mtr rpm, 597 gpm w/ 9.5-9.6 ppg MW, on bottom press 2500 psi, off bottom press 2340 psi, on bottom torque 18-20k ft/Ib, off bottom torque 17-18k fU Ib, PU wt 275k, SO wt 135k, Rot wt 180k. Max gas= 26 units. ECD's = 11.09 12:00 18:00 6.00 9,599 9,930 INTRM1 DRILL DRLG P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 9599' -9930' (331') (TVD = 4867'). ART = 3.78hrs, AST = .34 hrs. Total hrs on bit = 11.34 hrs., Total hrs on jars = 194 hrs, 5-10k WOB, 90 rpm's, 197 mtr rpm, 597 gpm w/ 9.5-9.6 ppg MW, on bottom press 2500-2550 psi, off bottom press 2340-2400 psi, on bottom torque 17-20k fUlb, off bottom torque 17-19k ft/ Ib, PU wt 275k, SO wt 135-138k, Rot wt 180-182k. Max gas= 35 units. ECD's = 11.09-11.3 ppg. Pumped 63 bbl weighted hi vis sweep while drilling @ 9887' (4848' TVD). 80% estimated increase in cuttin s. 18:00 00:00 6.00 9,930 10,235 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from 9930' -10235' (305') (TVD = 5005). ART = 2.82 hrs, AST = .88 hrs. Total hrs on bit = 15.04 hrs., Total hrs on jars = 197.7 hrs, 5-10k WOB, 90 rpm's, 197 mtr rpm, 597 gpm w/ 9.5-9.7 ppg MW, on bottom press 2450-2550 psi, off bottom press 2340-2400 psi, on bottom torque 17-20k fUlb, off bottom torque 17-19k ft/ Ib, PU wt 275k, SO wt 135-138k, Rot wt 180-182k. Max gas= 13 units. ECD's = 11.09-11.36 .~ ~. ~ F'~qe 2 t ~~ Time Logs -~ Da e From To Dur th E. De th Phase Code Subcode T OM 04/24/2006 00:00 06:00 6.00 10,235 10,540 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from10235' -10540' (305') (TVD = 5186'). ART = 3.59 hrs, AST = 0.0 hrs. Total hrs on bit = 18.63 hrs., Total hrs on jars = 201.29 hrs, 3-8k WOB, 90 rpm's, 197-198 mtr rpm, 596-600 gpm w/ 9.7-9.8 ppg MW, on bottom press 2845-2750 psi, off bottom press 2613-2520 psi, on bottom torque 18-24k ft/Ib, off bottom torque 16-28k ft/ Ib, PU wt 280k, SO wt 145-148k, Rot wt 180-185k. Max gas= 16 units. ECD's = 11.37-11.45 ppg. Pumped 35 bbl weighted hi vis sweep @ 10345' (0250 hrs), increase of cuttings when back to surface. Dump sweep along w/pit volume to allow f/ h2o additions to control wei ht. 06:00 12:00 6.00 10,540 10,839 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from10540' -10839' (299') (TVD = 5380'). ART = 1.57 hrs, AST = 2.14 hrs. Total hrs on bit = 22.34 hrs., Total hrs on jars = 205 hrs, 3-8k WOB, 90 rpm's, 197-198 mtr rpm, 596-600 gpm w/ 9.7-10.5 ppg MW, on bottom press 2880-2750 psi, off bottom press 2613-2510 psi, on bottom torque 20-22k ft/Ib, off bottom torque 18-24k ft/ Ib, PU wt 280-285k, SO wt 145-160k, Rot wt 185-190k. Max gas= 15 units. ECD's = 11.23-11.54 12:00 18:00 6.00 10,839 11,124 INTRM1 DRILL DDRL P Directional Drill 8-1/2" hole w/ 7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from10839' -11124' (285') (TVD = 5605'). ART = 1.66 hrs, AST = 1.35 hrs. Total hrs on bit = 25.35 hrs., Total hrs on jars = 208.01 hrs, 5-10k WOB, 90 rpm's, 184-187 mtr rpm, 560-567 gpm w/ 10.1 ppg MW, on bottom press 2870-2810 psi, off bottom press 2580-2700 psi, on bottom torque 20-23k ft/Ib, off bottom torque 18-20k ft/ Ib, PU wt 290-295k, SO wt 160-155k, Rot wt 190-200k. Max gas= 46 units. ECD's = 11.54-11.6 Tim LeTim ogs _ --~ - Date From To Dur ~ e th E De th Phase Code Subcode I~ - CCM 04/24/2006 18:00 20:15 2.25 11,124 11,232 INTRM1 DRILL DRLG P _ Directional Drill 8-1/2" holew/7" Sperry drill 6/7 lobe - 6.0 stage mtr w/ 1.50 deg bend from11124' -11232' (108') (TVD = 5693). ART = .81 hrs, AST = .32 hrs. Total hrs on bit = 26.48 hrs., Total hrs on jars = 209.14 hrs, 5-10k WOB, 90 rpm's, 187 mtr rpm, 567 gpm w/ 10.1 ppg MW, on bottom press 2770 psi, off bottom press 22620psi, on bottom torque 22-28k ft/Ib, off bottom torque 19-21 k ft/ Ib, PU wt 295-300k, SO wt 155-160k, Rot wt 200-203k. Max gas= 19 units. ECD's = 11.53 20:15 00:00 3.75 11,232 10,937 INTRM1 DRILL CIRC P Circ and condition mud and hole @ intermediate TD (11232' MD, TVD = 5693'). UD single dp (was drilled down 10'), set back a stand about every hr. Stand 107 in hole @ midnight (working f/ 11032' to 10937'). Pumping 570 gpm w/ 2700 psi w/ PU, 500 gpm w/ 2350 psi w/ slacking off. ECD's 11.38 ppg. Rotate @ 90 rpm w/ 22-28k ft Ib torque. Pumped a 35 bbl weighted (12.0 ppg) hi vis sweep initally, then about 5 BU till hole was clean and MW in 10.05 ppg, vis 42, PH 9.1 gels 10/13/19, fluid loss 3.8 and MBT 25 b. MW out 10.1 04/25/2006 00:00 01:30 1.50 10,937 10,746 INTRM1 DRILL CIRC P Continue circulating and condition mud and hole @ intermediate TD (11232' MD, TVD = 5693'). Stand 107 in hole @ midnight (working 11032'-10746'). Pumping 570 gpm w/ 2700 psi w/ PU, 500 gpm w/ 2350 psi w/slacking off. ECD's 11.38 ppg. Rotate @ 90 rpm w/ 22-28k ft Ib torque. MW in 10.05 ppg, vis 42, PH 9.1 gels 10/13/19, fluid loss 3.8 and MBT 25 ppb. MW out 10.1 01:30 03:45 2.25 10,842 7,985 INTRM1 DRILL TRIP P POOH f/ 10842' to 7985'. Record PU and SO wt's every 5stands. Hole fill f/ 30 stands = 27.2 bbls.Holein good sha e. 03:45 04:00 0.25 7,985 7,985 INTRM1 RIGMN' SFTY P PJSM on cutting 450' of drilling line. Circ @ 7985', 32 spm w/ 340 psi while cuttin line. 04:00 06:00 2.00 7,985 7,985 INTRM1 RIGMN- SVRG P Slip and cut 450' of 1-3/8" drilling line. Circ 32 s m w/ 340 si. 06:00 07:00 1.00 7,985 7,985 INTRM1 RIGMN SVRG P Complete slipping & cutting drilling line, Service draw works. 07:00 11:00 4.00 7,985 7,985 INTRM1 DRILL CIRC P Circulate ~ condition mud while mix Wellbore Strengthening Pill. Mix 1100 sacks of BAr, 76 sacks of Safecarb 500, 55 sacks of Safecarb 40, 76 sacks of Safecarb 250, and 160 sacks of G-Seat. e_ .® ~ ~ ~ ~~~ _ ~~~ 2? ~f Time Logs Date From To Dur e th E. De th Phase Code Subcode OM __ 04/25/2006 11:00 13:00 2.00 7,985 INTRM1 RIGMN RGRP NP Replace Brake pads on draw works. Adjusted same. Inspect & adjust tensions rin s & e ualizer bar. 13:00 13:15 0.25 7,985 7,985 INTRM1 DRILL OTHR P PJSM with crew. Discuss Safety issues and procedure for tripping back to bottom. 13:15 14:00 0.75 7,985 9,033 INTRM1 DRILL TRIP P Trip back in hole from 7985 - 9033 1048' .Monitor well -static. 14:00 16:00 2.00 9,033 11,127 INTRM1 DRILL TRIP P Continue trip in hole from 9033' - 11127' 2094' . 16:00 16:45 0.75 11,127 11,222 INTRM1 DRILL REAM P Make Top drive connection on stand # 109. Wash & ream from 11127' - 11222' (95'). Pumps @ 500 GPM - 2240 PSI. Rotate at 80 RPM's with UP WT - 225K, SO WT - 190K. 16:45 17:00 0.25 11,222 11,232 INTRMI DRILL REAM P Make connection with a single from shed on stand #109. Continue Wash & ream from 11222' - 11232' (10'). Pumps @ 500 GPM - 2240 PSI. Rotate at 80 RPM's with UP WT - 225K, SO WT - 190K. 17:00 17:15 0.25 11,232 11,232 INTRMI DRILL CIRC P Pump a 40 BBL Hi Visc sweep @ 500 GPM - 2240 PSI. 17:15 18:00 0.75 11,232 11,232 INTRM1 DRILL CIRC P Continue Circulate & condition mud @ 500 GPM - 2240 PSI, with 80 RPM's, 25 - 28K torque. UP WT= 225K, SO WT = 190K. 18:00 20:30 2.50 11,232 11,232 INTRM1 DRILL CIRC P Continue Circulate & condition mud for Well Bore Strengthening procedure @ 500 GPM - 2240 PSI, with 80 RPM's, 25 - 28K torque. UP WT= 225K, SO WT = 190K. Rig up vac trucks and prepare pits for displcing 13.0 PPG WBS mud. 20:30 21:30 1.00 11,232 11,232 INTRM1 DRILL CIRC P Pump 13.0 PPG Wellbore strengthening mud @ 400 GPM's - 1560 PSI. Pump a total of 347 BBLS in the annulus, and displace with 90 BBLS of 10.0 PPG mud. Reciprocate & Rotate drill strin . 21:30 23:30 2.00 11,232 7,796 INTRM1 DRILL TRIP P POOH from 11232' - 7796' (3436'). Pulled @ speed of 30 - 50 FT/Minute. Observed good hole conditions with proper fill, and dry pipe. Bit at 279' above shoe 8075'. 23:30 00:00 0.50 7,796 7,796 INTRM1 DRILL CIRC P Circulate & condition mud to observe returns of 40 BBLS of 13.0 PPG mud, and 10.0 PPG mud in & out, preparing for Well bore strengthening test. Reciprocate & rotate drill string at 50 RPM's - 15K torque, and pumps at 400 GPMs- 1230 PSI. Time Logs Date From To Dur th E. De th Phase Code Subcode OM 04/26/2006 00:00 00:30 0.50 7,796 7,796 INTRM1 DRILL CIRC P Continue Circulate & Condition mud while RU Dowell & Lines. Held PJSM with entire crew. Discuss Safety Issues and procedure for performinbg Wellbore Strengthening test. Desi Hate a S ill Cham ion. 00:30 02:00 1.50 7,796 7,796 INTRM1 DRILL LOT P Pressure test lines to 1500 PSI. Good test. Close Annular. With Dowell. pump down annulus with 8.3 PPG water @ .3 - .4 BPM observing prerssure to 1322 PSI. Shut down 2 minutes. Pressure bled to 1282 PSI. Pressure back to 1322 PSI. Held 2 minutes. Bleed ail pressure slowly. Total water pumped = 6 BBLS. Total water bled back to tanks = 5.5 BBLS. Drill pipe gauge indicated same pressure as annulus. Rig down Dowell & lines. NOTE: 1322 PSI indicated a EMW of 15.4 PPG @ TD of 5693 TVD, and 16.4 PPG at shoe. 02:00 03:00 1.00 7,796 9,033 INTRM1 DRILL TRIP P Blow down Top Drive & Lines. Trip in hole with 5" DP from 7796'- 9033'. Monitor well -static. Observed 23.76 BBL ain on Tri Tank. 03:00 04:30. 1.50 9,033 9,033 INTRM1 DRILL CIRC P Circulate & condition mud to displace out 13.0 PPG WBS fluid and maintain a 10.0 PPG mud all around. Pumps at 350 GPM's - 1325 PSI. Reciprocate & rotate drill Strin . 04:30 05:00 0.50 9,033 10,080 INTRM1 DRILL TRIP P Blow down Top Drive & Lines. Trip in hole with 5" DP from 9033' - 10080'. Monitor well -static. Observed 25.3 BBL ain on Tri Tank. 05:00 06:00 1.00 10,080 10,080 INTRM1 DRILL CIRC P Circulate & condition mud to displace out 13.0 PPG WBS fluid and maintain a 10.0 PPG mud all around. Pumps at 360 GPM's - 1380 PSI. Reciprocate & Rotate Drill String, 50 RPM's. Torque 12-14K. 06:00 07:00 1.00 10,080 10,080 INTRMI DRILL CIRC P Condition circulate & condition mud to displace out 13.0 PPG WBS fluid and maintain a 10.0 PPG mud all around. Pumps at 350 GPM's - 1380 PSI. Reciprocate & Rotate Drill String, 50 RPM's. Torque @ 12-14K. UP WT = 275K, SO WT = 150K. Crew Chan e 07:00 07:15 0.25 10,080 10,080 INTRM1 DRILL TRIP P Blow down Top Drive & lines. 07:15 08:15 1.00 10,080 11,232 INTRM1 DRILL TRIP P Trip in hole from 10080' - 11232' 1152' .Observe clean hole conditions. 08:15 08:30 0.25 11,232 11,232 INTRMI DRILL TRIP P Pick up single from pipe shed. Make to drive connection and fill drill strin . Pad 2~ of ~~ Time Logs _ Date From To Dur ._ e th E . De th Phase Code Subcode OM 04/26/2006 08:30 _ 12:00 3.50 11,232 _ 11,232 INTRM1 DRILL CIRC P _ Condition circulate & condition mud to displace out 13.0 PPG WBS fluid and maintain a 10.0 PPG mud all around. Pumps at 350 GPM's - 1400 PSI. Reciprocate & Rotate Drill String, 50 RPM's. Torque @ 12-14K. UP WT = 275K, SO WT = 150K. Observe ECD increase to 11.9 PPG, slowing pumps to 300 GPM's. 12:00 12:45 0.75 11,232 11,232 INTRM1 DRILL CIRC P Condition circulate & condition mud to displace out 13.0 PPG WBS fluid and maintain a 10.0 PPG mud all around. Pumps at 350 GPM's - 1400 PSI. Reciprocate & Rotate Drill String, 50 RPM's. Torque @ 12-14K. UP WT = 275K, SO WT = 150K. Observe ECD decrease as 13.0 PPG mud to surface. Increase pump strokes in 50 GPM increments to finally gain 500 GPM's - 2140 PSI. UP WT = 290K, SO WT = 152K. 12:45 13:00 0.25 11,232 11,232 INTRMI DRILL OWFF P Monitorwell-static. 13:00 13:15 0.25 11,232 11,232 INTRM1 DRILL CIRC P Mlx & Pump 20 BBL dry job @ 2 PPG over mud wt. Blow down Top Drive & Lines. 13:15 14:45 1.50 11,232 7,890 INTRM1 DRILL TRIP P POOH from 11232' - 7890' (3342'). Inside the 9 5/8" casing shoe. Monitor well -static. Observe ro er hole fill. 14:45 15:00 0.25 7,890 7,890 INTRM1 DRILL CIRC P Make up Top Drive & fill drill string and all lines. 15:00 16:00 1.00 7,890 7,890 INTRM1 DRILL CIRC P Continue circulate & condition mud with pumps at 500 GPM's - 1970 PSI. UP WT = 200K, SO WT = 135K. Verify godd 10.2 PPG mud all the way around, re arin for LOT. 16:00 16:30 0.50 7,890 7,890 INTRM1 DRILL LOT P Rig all lines and chart recorder for LOT. PJSM. Discuss safety issuyes and rocedure for um in LOT. 16:30 17:00 0.50 7,890 7,890 INTRM1 DRILL LOT P Close rams, Pump down annulus to pressure to 845 PSI observing breakover for an EMW of 14.1 PPG.Observe 10 minute bleed of from 700 PSI shut in pressure to 425 PSI. Record all ressures on chart. 17:00 17:15 0.25 7,890 7,890 INTRM1 DRILL LOT P Bleed & rig down all lines & recorder. 17:15 17:30 0.25 7,890 7,890 INTRM1 DRILL CIRC P Mlx & Pump 20 BBL dry job @ 2 PPG over mud wt. Blow down Top Drive & Lines. 17:30 18:00 0.50 7,890 7,224 INTRM1 DRILL TRIP P POOH from 7890' - 7224' (666'). Observe ro er hole fill. Crew Chan e 18:00 22:00 4.00 7,224 852 INTRM1 DRILL TRIP P Continue POOH from 7224' - 852' (6372'). Monitor well -static. Calculated hole fill = 3.7 BBLS / Stand. Actual hole fill = 5.1 BBLS / Stand. ~~ P~~~ ~~ ~t ~ Time Logs = ~ _ Date From To Dur e~th E. D~th Phase Code Subcode OM 04/26/2006 22:00 00:00 2.00 852 110 INTRM1 DRILL PULD P Lay down 5" HWDP (338.48'), 6 1/4" Accelerator Drilling Jar (35.60'), 5" HWDP (153.94'), 6 1/4" Drilling JArs (30.03'), 5" HWDP (91.66'), and 3 - 6 1/2" Non MAg Flex drill collars 92.96'). Flush BHA & Motor with 3 BBLS of fresh water. 04/27/2006 00:00 00:30 0.50 110 0 INTRM1 DRILL PULD P Hold PJSM. Discuss safety issues and procedure for removing radioactive sources form BHA with Sperry Sun MWD reps. Install warning signs, and remove sources form MWD assembly as per MWD reps. Secure sources in container, and remove from floor. Pull warnin si ns. 00:30 01:30 1.00 0 0 INTRM1 DRILL OTHR P Rig up and down load MWD assembly. 01:30 03:00 1.50 0 0 INTRM1 DRILL PULD P Continue lay down BHA #6. Lay down 6 3/4" TM -HOC (9.83), 6 3/4" Neutron Density (27.91'), 6 3/4" MWD Directional (9.17'), 6 3/4" Gamma / Res / PWD (28.16'), 6 3/4" Non MAg float sub (2.49'), 6 3/4" Welded Straight Blade Stabilizer (5.67'), 7" Sperry Lobe 6/7 - 6.0 Stage Motor (25.33') and 8 1/2" Hughes HCm605 bit (.96'). Inspect & gauge bit to 1 /1 /VVT/A/E/I/NO/TD. 03:00 03:30 0.50 0 0 INTRM1 DRILL PULD P Drain Stack, Pick up test joint. RIH, BOLDS & pull wear bushing. Clean & clear floor area. 03:30 03:45 0.25 0 0 INTRM1 CASIN< SFTY P Held PJSM with crew. Discuss Safety Issues and new hands. Discuss procedure for rigging up casing equipment, and 7" casing running rocedure. 03:45 06:00 2.25 0 0 INTRM1 CASIN( RURD P Rig up all casing equipment and tongs as per GBR reps. Ensure all equipment and tools ready as per DDI checklist. MU Franks fill up tool. Install long bales on top drive removing short bales. Crew Chan e 06:00 08:00 2.00 0 0 INTRM1 CASIN( RURD P Continue rig up all casing equipment and tongs as per GBR reps. Ensure all equipment and tools ready as per DDI checklist. 08:00 08:15 0.25 0 0 INTRM1 CASIN( SFTY P Held PJSM with entire crew and CAsing hands. Discus Safety Issues and procedure for running 7" 26# casing. Discuss New Hands in New ositions & otential hazards. ~~..~._ ~ _ ~~ 31 of ~? Time Logs _ Date From To Dur e~th E. De th Phase Code Subcode OM 04/27/2006 08:15 12:00 3.75 0 1,828 INTRM1 CASIN( RNCS P Make up first joint of 7" 26# casing with Weatherford Float shoe Model 303 Sure Seal 3, and 2 joints with Weatherford Model Float collar Model 402 Sure Seal 3, baker locking shoe track joints. MU torque to 8000 FT/ LBS. Fill with mud and check floats. Floats good. Continue run 7" casing filling each joint with Franks Fill up tool. Held Blow out drill while running casin . 12:00 15:00 3.00 1,828 4,000 INTRM1 CASIN( RNCS P Continue run 7" casing filling each joint with Franks Fill up tool. Make up for ue = 8000 FT /LBS 15:00 15:15 0.25 4,000 4,000 INTRMI CASIN( CIRC P Circulate bottoms up @ 4000' with 4 BPM - 280 PSI. 15:15 18:00 2.75 4,000 6,733 INTRM1 CASIN< RNCS P Continue run 7" casing filling each joint with Franks Fill up tool. Make up torque = 8000 FT /LBS Crew Chan e 18:00 20:00 2.00 6,733 8,508 INTRM1 CASIN( RNCS P Continue run 7" casing to shoe while filling each joint with Franks Fill up tool. Make u for ue = 8000 FT /LBS 20:00 22:00 2.00 8,508 8,508 INTRMI CASIN( CIRC P Establish circulation and circulate hole volume conditioning mud. Pumps @ 5 BPM - 500 PSI. Mud properties = 10.2 PPG, YP = 16 VISC = 47 Gels 6/9 22:00 23:30 1.50 8,508 9,670 INTRMI CASIN( RNCS P Continue run 7" casing from shoe to halfway into open hole @ 9670' while filling each joint with Franks Fill up tool. Make up torque = 8000 FT /LBS. Observe good hole good conditions and no issues. 23:30 00:00 0.50 9,670 9,670 INTRM1 CASIN( CIRC P Establish circulation and circulate open hole volume bringing old mud up into the shoe. Pumps @ 5 BPM -540 PSI. Mud properties = 10.2 PPG, YP = 16 VISC = 47 Gels 6 / 9 04/28/2006 00:00 01:30 1.50 9,670 11,222 INTRM1 CASIN( RNCS P Continue run 7" casing from 9670' - 11222' while filling each joint with Franks Fill up tool. Make up torque = 8000 FT /LBS. Observe good hole good conditions and no issues. Make up hanger & landing joint. RIH & land 7" casing 37.80' RKB, with shoe @ 11222' MD. UP WT = 285K, SO WT = 160 K. 01:30 02:30 1.00 11,222 11,222 INTRM1 CASIN( RURD P Rig down Franks fill up tool. Blow down Top Drive & lines. Install crossover & Dowell cement head with lu s installed. RU lines for circulate. ~ _ _~ Wage 32 ~3t r2 ..,.~ ®.~~ e Time Lo s Date From To Dur _. ~>> th E. De th Phase _ Code Subcode OM _ ___~ 04/28/2006 02:30 04:30 2.00 11,222 11,222 INTRM1 CASIN( CIRC P Circulate slow @ 2 BPM for 20 BBLS, 3 BPM for 10 BBLs, and 4 BPM for 10 BBIs, begin reciprocate casing string observing UP WT = 260K, SO WT =145K. Increse pump rate to 5 BPM - 720 PSI circulating & conditioning mud to properties of 10.2 PPG, YP =16, Visc = 47, zGels = 6 / 9 / 12 PV = 10. Hold PJSM while circulating. Discuss safety issues and procedure for Cment job. Designate Spill Champion. Load lines & begin batch mix cement @ 0400 HRS. 04:30 07:00 2.50 11,222 11,222 INTRM1 CEMEI~ CIRC P Turn over to Dowell Cement crew. Pump 2 BBIs H2O, Pressure test lines to 3500 PSI. Good test. Bleed pressure & Pump 20 BBLS of *.3 PPG CW 100 @ 5 BPM - 450 PSI, 30 BBLS of 12.5 PPG Mud Push @ 5 BPM - 450 PSI, Drop bottom plug @ 0500 HRS, Continue pump 36.6 BBLS of 15.8 PPG Tail Slurry @ 5 BPM - 300 PSI, and drop top plug @ 0507 HRS. Chase cement with 20 BBLS of 8.3 PPG H2O, and turn over to rig to displace cement @ 6 BPM 420 PSI, slowing pumps to 3 BPM to observe bumping plug with 3987 Stk - 402.68 BBLS. Pressure to 1050 PSI. Hold 5 minutes, bleed pressure & check floats. Floats held. CIP @ 0624 HRS. Blow down cement lines, & mud lines. Crew Chan e 07:00 07:15 0.25 11,222 11,222 INTRMI CEME~ SFTY P Held PJSM. Discuss Safety Issues and procedure for rigging down & plan of the da . 07:15 11:00 3.75 11,222 11,222 INTRM1 CEMEI~ RURD P Hang cement line in derrick. Lay down all casing running equipment including Franks Fill Up tool, Slips, elevators and tongs. LAy down Cement head & crossover. Drain stack & pull landing joint. Remove long bales form Top Drive & install short bales and adjust to link tilt. PU 5" Elevators & 5" - 4 1/21F x 30' with 10' pup joint to make up running tool. Make up 7" Packoff. Flush BOP stack. 11:00 12:30 1.50 11,222 11,222 INTRM1 CEMEI~ OTHR P RIH to land & set 7" x 11" packoff. Screw in lock down screws (450 IBS TQ), and gland nuts. RU & test packoff to 5000 PSI - 10 minutes. Good test. Release tool from packoff & POOH lay down runnin tool & 'oint. 12:30 12:45 0.25 11,222 11,222 INTRM1 CEMEI~ RURD P Install Iron roughneck tracks on rig floor. Install mousehole in rotary table re in for la in down 5" Drill i e. ~_~ _ ®.~ ~'ciq~ ~~ gat a2 ~ .~ ® s _~ Time Los date From To Dur ~ th E. De th Phase Code Subcode ., _ OM 04/28/2006 12:45 13:00 0.25 _ 11,222 11,222 INTRM1 CEME~ SFTY P PJSM. Discuss safety issues and procedure for laying down 5" DP from derrick usin mousehole. 13:00 13:15 0.25 11,222 11,222 INTRM1 CEMEf~ RURD P Pull all thread protectors to Rig Floor. Check a ui ment for la down. 13:15 18:00 4.75 11,222 11,222 INTRM1 DRILL RURD P Lay down 5" Drill pipe from derrick. Inspect & mark all bad joints to be sent out. Crew chan e. 18:00 00:00 6.00 11,222 11,222 INTRM1 DRILL RURD P Continue lay down all 5" Drill pipe from derrick. Inspect & mark bad joints for hard banding, cuts & washouts. No incidents or issues. 04/29/2006 00:00 01:00 1.00 11,222 11,222 INTRM1 DRILL RURD P Continue lay down all 5" Drill pipe from derrick. Inspect & mark bad joints for hard banding, cuts & washouts. No incidents or issues. 01:00 05:00 4.00 11,222 11,222 INTRM1 WELCT BOPE P Change out saver sub on Top Drive to 4" XT -39. Change out Rams in BOP stack installing 3 1/2" VAriable rams in top set & 4" Solid body rams in the Lower set. Pull all Floor valves, & misc crossovers to rig floor. Install 4" elevators. SIMOPS: Load pipe shed with 4" Drill i e. 05:00 06:00 1.00 11,222 11,222 INTRM1 WELCT ROPE P Rig up to test BOP's. Pull Testjooint to floor. Crew chan e. 06:00 08:00 2.00 11,222 11,222 INTRM1 WELCT BOPE P Continue rigging up to test BOP's. Install test plug. Rig up lines and chart. Fill stack & all lines with water. 08:00 13:00 5.00 11,222 11,222 INTRM1 WELCT BOPE P Test BOP's. Test Annular, Choke maifold valves # 16,17 & 18. Kill lines, #2 Choke Manifold valve & valves # 12,13,14 & 15. Test Kill line HCR, Upper IBOP on Top Drive. Test Top set of rams & valves # 5/6/10 & 11. Manual Kill & #4 Valve & 1/4/& 7. Test Choke manifold valves # 2/3/8 & 9. Test Choke HCR, Manual Choke, Bottom set of Rams. Perform Accumulator test. Observe 200 PSI increase after closed in 46 seconds and 3 minutes 34 seconds for full recovery in Koomey back to 2950 PSI. Nitrogen bottles = 5 @ average PSI of 2300 PSI Test Blind rams, 3 1/2" Floor valve, XT -39 Dart Valve& Xt -39 Floor valve. All test to 250 PSI low test, and 3500 PSI High test. All tests recorded on chart & sent to AOGCC. Witness of test waived b John Cris . 13:00 13:30 0.50 11,222 11,222 INTRM1 WELCT BOPE P Attempt to test lower IBOP valve. Failed. Service valve, retest -failed. 13:30 14:30 1.00 11,222 11,222 INTRM1 WELCT BOPE P Blow down Top Drive & all lines. Blow down Choke manifold & Kill Lines. Rig down test equipment, Make up test joint with Wear bushing, RIH to set WB & RILDS. La down Test Joint. ~.~.. ~ ~ ~--- ~~ ~'~cte 34 caf ~"~ Time Logs Date From To Dur pth E. Depth Phase Code Subcode OM 04/29/2006 14:30 14:45 0.25 11,222 11,222 INTRMI WELCT SFTY P PJSM with crew. Discuss Safety Issues and procedure for replacing Lower IBOP in To Drive. 14:45 17:30 2.75 11,222 11,222 INTRM1 RIGMN RGRP P Remove Lower IBOP & Install new IBOP valve. No incidents. 17:30 18:00 0.50 11,222 11,222 INTRM1 WELCT BOPE P Rig up lines, and test lower IBOP valve to 250 / 3500 PSI. Record on chart. Crew Chan e 18:00 18:30 0.50 11,222 11,222 INTRMI WELCT BOPE P Blow down Top Drive, Choke manifold, Kill Line and all lines. Prep Rig Floor for BHA Make u . 18:30 21:30 3.00 11,222 112 PROD1 DRILL PULD P PJSM with Crew & Sperry Sun Reps. Discuss safety issues and procedure for MU BHA #7 including loading Nuclear sources and order. MU BHA #7 picking up 6 1/8" Hughes HCM505 Bit with jets of 5 x 14's for a TFA of .752 Sq In.(.78'). MU 5" Sperry lobe 6/7 - 6.0 Stage Motor with a 1.50 Deg bend (23.13'), 4 3/4" NonMAg Float sub (2.18'), 5.940" Integral Blade Stabilizer (28.59'), 4 3/4" MWD Directional (8.58'), 4 3/4" Gamma/Res (24.50'), 4 3/4" Neutron Density (25.82'), 4 3/4" PWD (10.68'), TM-HOC 11.27' . MU Tor ue = 10K FT/LBS. 21:30 23:00 1.50 112 112 PROD1 DRILL PULD P Plug in and Down load MWD .Insert Sources as per SS reps. Perform Pulse test on MWD tools @ 280 GPM - 1150 PSI -Good test. 23:00 00:00 1.00 112 517 PROD1 DRILL PULD P Continue MU remaining BHA. MU 3 - 4 3/4" NonMAg Flex Drill Collars (93.35'), 4 3/4" Crossover Sub (2.99'), 3 - 4" HWDP (92.05'), 4 3/4" DNT Drilling jars (31.96'), and 6 - 4" HWDP (184.19'). Total BHA #7 = 517.01' NOTE: New 4" HWDP. Make up, Breakout 2 times as er reccomendations. 04/30/2006 00:00 01:30 1.50 517 517 PROD1 DRILL TRIP P Pick up 27 joints of 4" drill pipe from i e shed. 01:30 03:30 2.00 517 517 PROD1 DRILL TRIP P POOH racking back 7 stands in derrick. Change out rubbers in mud bucket. SPCC revention. 03:30 06:00 2.50 517 2,858 PROD1 DRILL TRIP P Continue TIH with 4" DP from pipe shed to 2858'. PU WT= 110K, SO WT = 92K. Crew chan e. 06:00 06:30 0.50 2,858 2,858 PROD1 DRILL CIRC P Fill drill string @ 280 GPMs- 1725 PSI. Pulse test MWD - ood test. 06:30 06:45 0.25 2,858 2,858 PROD1 DRILL CIRC P Blow down Top Drive & lines. 06:45 08:45 2.00 2,858 5,194 PROD1 DRILL TRIP P Continue to trip in hole from 2858' - 5194'. UP WT = 110K, SO WT = 92K. 08:45 09:15 0.50 5,194 5,194 PROD1 DRILL CIRC P Fill drill string @ 300 GPM - 2150 PSI. Pulse check MWD -OK. 09:15 09:30 0.25 5,194 5,194 PROD1 DRILL CIRC P Blow down Top Drive & lines. ~~ P~~ ~~ ~~ ~~ ~ ~ . e Time Logs _ Date From To Dur e th E. De th Phase Code Subcode OM 04/30/2006 09:30 12:00 2.50 5,194 6,800 PROD1 DRILL TRIP P Continue to trip in hole from 5194' - 6800'. UP WT = 175K, SO WT = 100 K. 12:00 12:45 0.75 6,800 8,400 PROD1 DRILL TRIP P Continue to trip in hole from 6800' 8400'. UP WT = 190K, SO WT = 105 K. 12:45 13:30 0.75 8,400 8,400 PROD1 DRILL CIRC P Fill drill string @ 296 GPM - 2380 PSI. Pulse check MWD -OK. 13:30 15:30 2.00 8,400 9,796 PROD1 DRILL TRIP P Continue trip in hole with 4" Drill pipe from i e shed to 9796'. 15:30 16:00 0.50 9,796 9,796 PROD1 DRILL CIRC P Fill drill string @ 286 GPM - 2660 PSI. UP WT = 230K, SO WT = 116K. 16:00 18:00 2.00 9,796 11,113 PROD1 DRILL TRIP P Continue trip in hole with 4" Drill pipe from 9796' - 11020'. Make up Top drive. Wash & ream from 11020' - 11113' MD. Pumps @ 280 GPM's - 2550 PSI. RPM = 40, Torque @ 11 K. UP WY = 175K, SO WT = 140K. ROT WT = 150K. NO pumps - UP WT = 235K, SO WT = 125K. Crew Chan e. 18:00 19:30 1.50 11,113 11,139 PROD1 DRILL REAM P Continue wash & ream from 11113' - 11139'. Tag float collar. Pumps @ 278 GPM's - 2600 PSI. Rotate @ 40 RPM's. Tagged with 8K WOB - 300 PSI Differential ressure. 19:30 20:30 1.00 11,139 11,139 PROD1 DRILL CIRC P Circulate bottoms up conditioning 10.2 PPG mud@ 278 GPMs - 2620 PS1.40 RPM's. Reciprocate drill string with UP WT - 152K, SO WT = 140K, ROT WT = 145K. Torque @ 11 K. Total strokes = 2500. 20:30 22:00 1.50 11,139 11,139 PROD1 DRILL DHEO P PJSM with crew. Discuss safety issues and procedure for testing casing @ 3000 PSI. Rig up and test 7" 26# casing to 3000 PSI.43 stks to pressure. Hold 30 minutes with 0 PSI bleed off. Record on chart. Bleed all ressure and ri down lines. 22:00 00:00 2.00 11,139 11,232 PROD1 CEMEI~ DRLG P Drill shoe track (firm cement & plugs) from 11139' - 11232' (93'). Last hole depth = 11232'. Pumps @ 278 GPM's - 2650 PSI. Rotating @ 40 RPM's, Torque @ 10K. UP WT = 240K, SO WT = 135K, ROT WT = 145K. Torque off bottom = 13K. Observe 100 - 300 differential ressure. 05/01/2006 00:00 03:00 3.00 11,232 11,232 PROD1 DRILL CIRC P Circulate & condition mud. Displace well from a 10.0 PPG to 12.1 PPG mud with pumps @ 260 GPMs - 2700 PSI. Reciprocate & rotate drill string @ UP WT + 240K, SO WT = 135K, ROT WT = 145K. Torque @ 13 K. Mud properities = 12.1 PPG, Visc = 43, PV/YP = 20/12. Gels 8/13/16. Time Logs ~ ~ - - Date From To Dur ~ th E. Depth Phase Code Subcode T~ t - - --- tC M O 05/01/2006 03:00 04:00 1.00 11,232 11,252 PROD1 DRILL DRLG P Drill new hole from 11232' - 11252'. Pumps @ 260 GPM's - 2750 PSI, pumps @ 270 GPM's - 2890 PSI. RPMs =40, Torque on bottom = 10K, Off bottom = 13-20K. AST = 0, ART Hrs = .61, ADT = .61 HRS, Total Bit HRs = .61, Total Jar HRS = .61. UP WT = 240K, SO WT = 135K, ROT WT = 145K. Mud wt = 12.1 PPG. YP = 12. Visc = 40, GELS @ 8 / 13. ECD @ 13.67 04:00 06:00 2.00 11,252 11,252 PROD1 DRILL CIRC T Observe 20.4 BBLS loss on last circulation. Monitor well 10 min - pumps off. Observed 15 BBLs gain in pits in 15 minutes. Observe well flow slowing but not stopping. Pumps on @ rate of 240 GPM - 2550 PSI. Observe losses of 30 -50 BBLS/HR. Stage pump strokes back to pump @ 200 GPM's - 1520 PSI pumping bottoms up. Observe gas breaking out in mud. After bottoms up, observe well. Well flowing strong, and gained 21.4 BBLS back from a 44 BBLS loss in the last bottoms u .Crew than e. 06:00 07:00 1.00 11,252 11,252 PROD1 DRILL OWFF T Continue monitor well, observing well still flowing minimal returns, but not sto in 07:00 07:15 0.25 11,252 11,252 PROD1 DRILL OWFF T Breakout & blow down Top Drive, while continue monitor well. Discuss options with town. 07:15 07:30 0.25 11,252 11,252 PROD1 DRILL OWFF P Continue monitor welt, observing well flow stopped. Total gain in pits - 23 BBLS. 07:30 08:30 1.00 11,252 11,252 PROD1 DRILL LOT P Rig up lines to perform LOT. PJSM with crew. Discuss safety issues and hi h ressure lines. 08:30 08:45 0.25 11,252 11,252 PROD1 DRILL LOT P Perform LOT to 14.0 PPG EMW. Pump 1/4 BBL & observe straight line in pressure of 592 PSI Shut in ressure, hold for 10 minutes. 08:45 11:00 2.25 11,252 11,252 PROD1 DRILL OTHR T Install rig floor valve in drill string, continuing to monitor well. Mix 40 BBLS of 12.0 PPG LCM pill. Pill made of 20 PPB G-Seal, 10 PPB Baracarb 600, 10 PPB Safecazrb 250 and 10 PPB Safecarb 40. 11:00 11:15 0.25 11,252 11,252 PROD1 DRILL CIRC T Make up Top Drive & RIH with stand # 115 to 11225' MD> 11:15 12:00 0.75 11,252 11,252 PROD1 DRILL CIRC T Reciprocate drill string while pump 20 BBLS of pill to spot in open hole. Pumps @ 116 GPMs - 1110 PSI. Pumped total of 1328 Strokes @ 28 SPM. 12:00 13:00 1.00 11,252 10,454 PROD1 DRILL TRIP T POOH from 11225' - 10454' (771'). UP WT + 250K, SO WT = 117K. ~® ® ~__ _... ~ m ~~ ® Time Logs Date From To Dur nth E Depth Phase Code Subcode OM 05/01/2006 13:00 14:30 1.50 10,454 10,454 PROD1 DRILL CIRC T Circulate & condition mud staging pumps from 240 GPMs-2750 PSI, to 270 GPM's - 3000 PSI. Monitor fluid losses. UP WT =220K, SO WT = 110K. Observe 14.6 PPG ECD's. RPM's @ 40, with torque @ 9K. Performed ECD baseline test @ 13.9 PPG. 14:30 15:00 0.50 10,454 11,207 PROD1 DRILL TRIP T Trip back in hole from 10454' - 11207'. 15:00 16:15 1.25 11,207 11,252 PROD1 DRILL REAM P Make up Top Drive on stand # 115, Fill Drill string @ 30 SPM, and wash & ream 6 1/8" hole from 11207' - 11252'. Observe hole packing off a little with no lost circulation. 16:15 18:00 1.75 11,252 11,263 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11252' - 11263' (9'). TVD - 5719'. UP WT = 245K, SO WT = 125K, ROT WT = 145K, ADT = .62 HRS, AST = .32 HRS, ART = .30 HRS. Total Bit Hours = 1.23, Total Jar HRS = 1.23, WOB = 5-10K, Pumps @ 245 GPM - 2750 PSI on btm, off btm = 2570 PSI. TQ on btm = 10-12K, TQ off btm = 10K. Max gas = 15 Units. Background gas = 15 Units, and ECD = 13.71 PPG. Crew Chan e. 18:00 00:00 6.00 11,263 11,312 PROD1 DRILL DDRL P Continue Directional drill 6 1/8" hole from 11263' - 11312' (9'). TVD - 5758'. UP WT = 200K, SO WT = 145K, ROT WT = 145K, ADT = 4.02 HRS, AST = 1.33 HRS, ART = 1.46 HRS. Total Bit Hours = 4.02, Total Jar HRS = 4.02, WOB = 5-10K, Pumps @ 251 GPM - 2950 PSI on btm, off btm = 2600 PSI. TQ on btm = 10-12K, TQ off btm = 8K. Max gas = 19 Units. ECD = 13.72 PPG. Fluid losses from 10 -30 bbls /hr. Pump 20 bbls LCM Pill observing fluid losses steadily dropping to less than 5 BBLS/HR. Allow mud weight to fall naturaly from 12.0 PPG to 11.8 PPG. ---m ~ ~ ~ ~~. ~ ~ _~ _____ ~ .~~ Time Los ~ - Dat From To Dur 9~5pth E. De th Phase Code Subcode OM 05/02/2006 00:00 05:45 5.75 11,312 11,355 PROD1 DRILL DDRL P __ Continue Directional drill 6 1/8" hole from 11312' - 11355' (43"). TVD - 5758'. UP WT = 200K, SO WT = 125K, ROT WT = 145K, ADT = 2.83 HRS, AST = 2.76 HRS, ART = .07 HRS. Total Bit Hours = 6.87, Total Jar HRS = 6.87, WOB = 10-15K, Pumps @ 245 GPM - 2900 PSI on btm, off btm = 2600 PSI. TQ on btm = 8K, TQ off btm = 8K. Max gas = 20 Units. ECD = 13.67 PPG. Fluid losses from 0 bbls in last 6 hrs. Pump 20 bbls LCM Pill observing fluid losses steadily dropping to less than 2 BBLS/HR. Allow mud weight to fall naturaly from 12.0 PPG to 11.6 PPG. Observed slow drilling as the inclination was seen as increasing to 38 Deg, while sliding @ 170 de left. Sto Drillin . 05:45 06:00 0.25 11,355 11,355 PROD1 DRILL CIRC T Circulate & condition Mud., reiprocate & rotate drill string. Discuss options with Co. Re s. Crew chan e. 06:00 06:45 0.75 11,355 11,355 PROD1 DRILL CIRC T Continue Circulate & condition Mud., reiprocate & rotate drill string. Discuss options with Co. Reps. Pumps @ 245 GPM's - 2900 PSt. UP WT = 200K, SO WT = 125K, ROT WT = 145K, RPM's, with 13K for ue. 06:45 07:00 0.25 11,355 11,355 PROD1 DRILL OTHR T Perform "Exhale "test observing flow back of onl .8 BBLS ain in its. 07:00 07:30 0.50 11,355 11,204 PROD1 DRILL TRIP T POOH to shoe. RU and blow down Top Drive. 07:30 08:00 0.50 11,204 11,204 PROD1 DRILL LOT T Rig up all lines & test chart to perform LOT. 08:00 08:30 0.50 11,204 11,204 PROD1 DRILL LOT T PJSM. Discuss procedure for LOT. Monitor well. No ains /losses. 08:30 09:15 0.75 11,204 11,204 PROD1 DRILL LOT T Perform LOT observing pressure to 800 PSI and break over. Final pressure to 850 PSI. Observe 10 minutes. Record on chart & calculate LOT pressure to a 14.3 PPG EMW. Bled back 1/2 BBL. 09:15 12:00 2.75 11,204 11,204 PROD1 DRILL OWFF T Monitor well. Decision to mix & pump 11.8 PPG - 25 BBLS of Forma Squeeze pill and spot same in open hole. Observe 2 BBL gain in pits in 2.75 HRS. 12:00 17:30 5.50 11,204 11,204 PROD1 DRILL OWFF T Clean pill pit for mixing pill, and mix 25 BBLS of Forma squeeze. Note:. Mud products not on location. Wait on products. NOTE: Wait on mud roducts for 2 1/2 HRS. 17:30 17:45 0.25 11,204 11,204 PROD1 DRILL SFTY T PJSM. Discuss safety issues and procedure pumping and spotting 20 BBLS of Forma Squeeze pill in open hole. ®_ ~ ®. e_ Time Logs Date From To Dur th E. De th Phase Code Subcode ? _ OM 05/02/2006 17:45 18:00 0.25 11,204 11,263 PROD1 DRILL TRIP T Trip in hole from 11204' to 11263'. UP WT = 190K, SO WT = 135K. SPR's = pump # 1- 20 SPM - 750 PSI. 30 SPM - 1110 PSI. #@ pump - 20 SPM - 730 PSI, 30 SPM - 1140 PSI. Crew Chan e. 18:00 18:15 0.25 11,263 11,355 PROD1 DRILL TRIP T Continue trip in hole from 11263' - 11355'. UP WT = 190K, SO WT = 130K. 18:15 19:00 0.75 11,355 11,355 PROD1 DRILL CIRC T Establish good circulation and pump 20 BBLS of 11.8 PPG Forma Sqeeze pill in to the open hole and up the annulus to 10562' to balance ill. 19:00 19:45 0.75 11,355 10,465 PROD1 DRILL TRIP T After spotting pill, POOH slow with wet drill string from 11355' - 10465'. UP WT = 190K, SO WT = 130K. 19:45 21:15 1.50 10,465 10,465 PROD1 DRILL CIRC T Circulate bottoms up @ 25 SPM - 900 PSI. 111 GPM's. Total of 2350 strokes on im #1. 21:15 22:00 0.75 10,465 10,465 PROD1 DRILL FIT T Blow down Top Drive & all lines. RU lines & chart to squeeze pill. Fill all lines ensuring no air in lines. Close top i e rams. 22:00 22:45 0.75 10,465 10,465 PROD1 DRILL FIT T Perform squeeze on Forma set pill. Pump 4 stks to 320 PSI, held 3 minutes, pressure held @ 310 PSI. Pump to 9 Total stks to 620 PSI. Pressure bled form 600 - 590 PSI in 4 minutes. Pump Total of 15 Strokes to 950 PSI. Pressure bled from 920 - 910 PSI, Pump total of 22 Strokes to 1220 PSI, Pressure bled from 1180 - 1170 in 5 Minutes. Observed bleed back of only 1/2 BBL. Discuss options with town en ineer. 22:45 00:00 1.25 10,465 10,465 PROD1 DRILL FIT T Pressure to 1220 PSI in 19 strokes. Shut in and observe pressure bleed from 1180 PSI to 1160 PSI in 10 minutes, and hold pressure 1 hour to observe final pressure of 1090 PSI. Observed 3/4 BBL bleed back. 05/03/2006 00:00 00:30 0.50 10,465 10,465 PROD1 DRILL FIT T Rig down & blow down all lines. 00:30 01:15 0.75 10,465 11,268 PROD1 DRILL TRIP T Trip in hole from 10465' - 11268'. Observe tagging Forma Set pill ?? @ 11268. Make up Top Drive on stand # 115. 01:15 02:00 0.75 11,268 11,355 PROD1 DRILL REAM T Wash down from 11268' - 11355' with pumps at initial rate of 3 BPM - 1100 PSI. Did not see an hin in well bore. 02:00 03:45 1.75 11,355 11,355 PROD1 DRILL CIRC T Tagged bottom @ 11355' MD. Circulate @ 3 BPM - 1100 PSI, slowly staging pumps up to 5 BPM - 1960 PSI, circulating out remainder of Forma Set Pill. Hole circulated clean with 11.6 PPG Mud wt. Reciprocate & rotate drill strin while circulatn . es.~e_ee e_ Q~ ®_~~W_ _.,_. ~ - __~. ~~~p~ ~~' rs~ ~~ ~ _ s _ .._. _.~ d. Time Lis Date From To Dur th E. De th Phase Code Subcode OM 05/03!2006 03:45 04:15 0.50 11,355 11,203 PROD1 DRILL TRIP T Trip out of hole from 11355' - 11203' to get inside shoe @ 11222'. Observe clean hole conditions. 04:15 04:30 0.25 11,230 11,203 PROD1 DRILL LOT T Rig all lines & chart for LOT. PJSM with crew. Discuss Safety issues & rocedure. 04:30 05:15 0.75 11,203 11,203 PROD1 DRILL LOT T Perform LOT pumping @ 1/2 BPM down DP & Annulus observing break over @ 25 STKs and 1150 PSI. Shut in 10 minutes, observe pressure bled from 1100 PSI to 1060 PSI. Bleed all pressures, record 1/2 BBL back. Pumped away 2 BBIs into formation and calculated a 15.48 PPG MWE on LOT. 05:15 05:30 0.25 11,203 11,203 PROD1 DRILL LOT T Rig down all test equipment & chart. Line u to circulate. 05:30 06:00 0.50 11,203 11,203 PROD1 DRILL CIRC T Circulate staging pumps to 4 BPM - 1430 PSI, increasing mud weight from 11.6 PPG to 12.0 PPG as planned. Crew Chan e. 06:00 09:30 3.50 11,203 11,203 PROD1 DRILL CIRC T Continue to circulate increasing system mud weight to 12.0 PPG. Reciprocate & rotate drill string. UP WT = 190K, SO WT = 132K. Obtain new SPR's at shoe before drill ahead. Pump#1 - 20 SPM - 690 PSI. 30 SPM - 1020 PSI. Pump #2 - 20 SPM - 660 PSI. 30 SPM - 920 PSI. 09:30 10:00 0.50 11,203 11,355 PROD1 DRILL TRIP T Trip in hole from 11203' - 11355'. Wash down last 50' to bottom. 10:00 12:00 2.00 11,355 11,389 PROD1 DRILL DDRL P Continue Directional drill 6 1/8" hole from 11355' - 11389' (34"). TVD - 5812'. UP WT = 190K, SO WT = 140K, ROT WT = 159K, ADT = 1.28 HRS, AST = 1.28 HRS, ART = .0 HRS. Total Bit Hours = 8.15, Total Jar HRS = 8.15, WOB = 5-10K, Pumps @ 268 GPM - 3100 PSI on btm, off btm = 2850 PSI. TQ on btm = 7K, TQ off btm = 5K. Max gas = 25 Units. ECD = 14.3 PPG. Mud wt = 12.0 PPG Yp = 21, Visc = 43, Gels 7/10. 12:00 18:00 6.00 11,389 11,559 PROD1 DRILL DDRL P Continue Directional drill 6 1/8" hole from 11389' - 11559' (170"). TVD - 5959'. UP WT = 195K, SO WT = 140K, ROT WT = 160K, ADT = 4.04 HRS, AST = .61 HRS, ART = 3.43 HRS. Total Bit Hours = 12.19, Total Jar HRS = 12.19, WOB = 10-15K, Pumps @ 264 GPM - 2950 PSI on btm, off btm = 2820 PSI. TQ on btm = 7K, TQ off btm = 6K. Max gas = 36 Units. Background gas = 18 Units. ECD = 14.10 PPG. Mud wt = 12.2 PPG Yp = 21, Visc = 43, Gels @ 7/10. No Fluid Losses. Crew Chan e ®~ ~ r~E:t~t~ ~~ ~F , Time Logs Date From To Dur th E. De th Phase Code Subcode OM 05/03/2006 18:00 21:45 3.75 1,559 11,661 PROD1 DRILL DDRL P Continue Directional drill 6 1/8" hole from 11559' - 11661' (102"). TVD - 6044'. UP WT = 190K, SO WT = 140K, ROT WT = 162K, ADT = 2.84 HRS, AST = 0 HRS, ART = 2.84 HRS. Total Bit Hours = 15.03, Total Jar HRS = 15.03, WOB = 10-15K, Pumps @ 263 GPM - 2940 PSI on btm, off btm = 2750 PSI. TQ on btm = 7K, TQ off btm = 5K. Max gas = 16 Units. Background gas = 16 Units. ECD = 14.10 PPG. Mud wt = 12.OPPG Yp = 21, Visc = 43, Gels @ 7/10. Observe well with minimal flow on connections. Increase Mud weight to 12.2 PPG while drilling. TD the well as per DD & Geologist @ 11661' MD. Observed fluid losses @ 58 BBLS /HR while drilling. Pumped LCM pill around seeing little effect. Slow pump rates to 225 GPM's 21:45 23:30 1.75 11,661 11,661 PROD1 DRILL CIRC P Continue circulate & condition hole @ 220 GPM's - 2350 PSI, monitoring fluid losses from 40-60 BBIs/HR. allowing pill to come back. Reciprocate & rotate drill strin while circulatin . . 23:30 00:00 0.50 11,661 11,661 PROD1 DRILL OWFF P Shut down pumps, observed well breathing and gain back 19 BBLS of 40 BBIS loss in the last circulation. Flow sto ed. 05/04/2006 00:00 00:30 0.50 11,661 11,661 PROD1 DRILL CIRC P Continue circulate & condition mud. Spot 40 BBLS of LCM 50# PPB pill on bottom. Pill = 13 PPB G SEaI, 7 PPB Nut Plug, 16 PPB SC 250, 7 PPB Baracarb, and 4 PPB Dyna red. Puymps @ 52 SPM - 219 GPM's - 2200 PSI. UP WT = 190K, SO WT = 140K, Rotatin 50 RPM's - 5K TQ. 00:30 01:00 0.50 11,661 11,203 PROD1 DRILL TRIP P POOH from 11661' - 11203', wet string to inside shoe. Observe ro er hole fill. 01:00 02:15 1.25 11,203 11,203 PROD1 DRILL CIRC P Circulated staging pumps up to 5 BPM, monitoring well for gains / losses. CBU @ 50 SPM - 2390 PSI. 30 RPM's with 5K toeque. Observed ECD's of 14.36 PPG at start, and 14.04 PPG when remaining sweep out of hole. Reciprocate drill string while circulatin . 02:15 03:00 0.75 11,203 11,203 PROD1 DRILL OWFF P Shut down pumps. Monitor well. Fluid loss while pumping = 38 BBLS, observed well breathing and gained 30 BBLS back into pits. Monitor until flow stopped and well -static. Service Top Drive while monitor well. m~~m ~, .®s ~® r~~~ cf 52 Time Logs ~ ` _ Date From To Dur th E. De th Phase Code Subcode OM 05/04/2006 03:00 03:15 0.25 11,203 11,203 PROD1 DRILL CIRC P Obtain SPR's before POOH. Pump# 1 - 20 SPM - 740 PSI, 30 SPM - 1000 PSI. Pump #@ - 20 SPM - 720 PSI, 30 SPM - 1000 PSI. Mud wt = 12.2 PPG 11203'. 03:15 06:00 2.75 11,203 6,805 PROD1 DRILL TRIP P Pump dry job, blow down Top Drive & lines. Drop a 2.35" Drift in drill string, POOH form 11203' - 6805' (4398'). Obtain SLM on TOH. Obtain torque & drag parameters as per rig engineer. Crew Chan e 06:00 06:30 0.50 6,805 6,530 PROD1 DRILL TRIP P Continue POOH from 6805' - 6530' (275'). Obtain SLM, torque & drag arameters as er ri en ineer. 06:30 06:45 0.25 6,530 6,530 PROD1 DRILL SFTY P Perform BOP drill while tripping. All hands at stations. 06:45 09:00 2.25 6,530 1,546 PROD1 DRILL TRIP P Continue POOH from 6530' - 1546' 4984'). Obtain SLM, and torque & drag parameters as per rig engineer. Observed ro er hole fill. 09:00 09:15 0.25 1,546 1,546 PROD1 DRILL TRIP P Pull air slips form rotary table. Clean slips and put away. Monitor well - static. 09:15 09:30 0.25 1,546 517 PROD1 DRILL TRIP P Continue POOH from 1546' - 517' 1029'. Obtain SLM & parameters as er ri en ineer. 09:30 10:00 0.50 517 517 PROD1 DRILL PULD P Rig up to lay down BHA #7 into pipe shed. PJSM -discuss safety issues and handlin of BHA. 10:00 12:00 2.00 517 102 PROD1 DRILL PULD P Lay down BHA #7. Lay down 4 3/4" Crossover Sub (2.99'), 3 - 4" HWDP (92.05'), 4 3/4" DNT Drilling jars 31.96' ,and 6 - 4" HWDP 184.19' . 12:00 12:15 0.25 102 102 PROD1 DRILL SFTY P PJSM with crew & Spery Sun reps. Discuss safety issues and procedure for removing Nuclear Sources from tools. 12:15 12:30 0.25 102 102 PROD1 DRILL PULD P Pull Nuclear Sources form MWD asembly, and remove sources form Rig Floor area in ro er containment. 12:30 12:45 0.25 102 66 PROD1 DRILL PULD P Continue lay down BHA . 3 - 4 3/4" NonMa Flex Drill Collars 93.35' , 12:45 13:30 0.75 66 66 PROD1 DRILL OTHR P Plug in and down load MWD assembl . 13:30 14:30 1.00 66 0 PROD1 DRILL PULD P Continue lay down BHA #7. Lay down 6 1/8" Hughes HCM505 Bit with jets of 5 x 14's for a TFA of .752 Sq In.(.78'). MU 5" Sperry lobe 6/7 - 6.0 Stage Motor with a 1.50 Deg bend (23.13'), 4 3/4" NonMAg Float sub (2.18'), 5.940" Integral Blade Stabilizer (28.59'), 4 3/4" MWD Directional (8.58'), 4 3/4" Gamma/Res (24.50'), 4 3/4" Neutron Density (25.82'), 4 3/4" PWD (10.68'), TM-HOC (11.27'). Inspect & gauge bit to 1/1/CT/G/X/I/ER/TD. s~ ~._..a ~ ~ ~~. m ~ _ &''i3 CIS F~~ +.f~ ~~ 3 . . .. Time Lo s Date From To Dur gth E. Depth Phase Code Subcode OM _ 05/04/2006 14:30 15:00 0.50 0 0 PROD1 DRILL OTHR P Clear & clean rig floor area. Send tools out. 15:00 16:00 1.00 0 0 PROD1 CASIN( RURD P Rig up casing running equipment. Tongs, elevators, slips etc.. Check 3 1/2 Liner equipment in shed double checkin runnin order. 16:00 16:30 0.50 0 0 PROD1 CASIN( SFTY P PJSM. Discuss Safety issues and procedure for making up 3 1/2 liner assembly as per Co. Rep and BOT re 16:30 18:00 1.50 0 600 PROD1 CASIN( PUTS P Pick up Float euipment and 18 joints of 3 1/2 liner. MU Baker V-set Float shoe (1.50'), 2 joints of 3 1 /2" liner (57.94'), Baker Float Collar (1.05'), 1 joint 3 1/2 liner (31.56'), Baker landing collar Insert type (1.38'), 1 joint 3 1/2" liner (31.27'), Crossover pup BTC-M x 8 round (5.78'). 14 joints of 3 1/2" Liner (437.30). Install total of 13 centralizers. 1 each joint on joints 1 -13. Crew Chan e. 18:00 18:45 0.75 600 633 PROD1 CASIN( PUTB P Continue MU 3 1/2" liner assembly. PU Baker Crossover Sub & 80 -40 Seal Bore Extensionwith Coupling and Flexlock Liner Hanger & ZXP Packer assembly. Total 3 1/2 Liner BHA = 633.20'. Crossover to 4" DP included in total len th of BHA. 18:45 19:30 0.75 633 633 PROD1 CASIN( PUTB P Inspect Liner tools for shear pins. Run hanger assembly with 5 pins to shear @ 1800 PSI as per BOT rep. Set string in slips. Change out handling e ui ment to run 4" DP. 19:30 20:30 1.00 633 726 PROD1 CASIN( RUNL P Make up first stand of 4" DP. MU floor valve & swing to break circulation filling liner and checking float equipment. Liner Volume = 7 BBLS, pumping @ 3 BPM - 260 PSI. BOT reccomended max pump rate 7 pressure - 3 BPM - 1000 PSI. 20:30 00:00 3.50 726 3,442 PROD1 CASIN( RUNL P Continue run in hole with 3 1/2" liner assembly with 4" drill pipe from 726' - 3442' (2716'). Average running speed - 90 ft/min as per BOT rep. Observe proper hole fill and obtain torque & drag paramters as per rig engineer. Fill DP eve 10 stands. 05/05/2006 00:00 06:00 6.00 3,442 10,006 PROD1 CASIN( RUNL P Continue run in hole with 3 1/2" liner assembly with 4" drill pipe from 3442' - 10006' (6564'). Average running speed - 90 ft/min as per BOT rep. Observe proper hole fill and obtain torque & drag paramters as per rig engineer. Fill DP eve 10 stands. ~~ ~_ ~ P~~ ~€ ~~ e _ ~ .~_mm .~~._ .. Time Logs Date From To Dur th E. De th Phase .Code Subcode OM 05/05/2006 06:00 06:30 0.50 10,006 10,948 PROD1 CASIN( RNCS P Continue run in hole with 3 1/2" liner assembly with 4" drill pipe from 10006' - 10948' (942'). Average running speed - 90 ft/min as per BOT rep. Observe proper hole fill and obtain torque & drag paramters as per rig engineer. Fill DP eve 10 stands. 06:30 07:00 0.50 10,948 10,948 PROD1 CASIN( RUNL P Fill Drill Pipe @ 10948'. Check float e ui ment. 07:00 07:15 0.25 10,948 11,168 PROD1 CASIN( RUNL P Continue run 3 1/2 Liner assembly from 10948' - 11168'. 220' . 07:15 07:30 0.25 11,168 11,137 PROD1 CASIN( RUNL P Run Drift in stand # 113. TIH with a double, lay down top single. Depth = 11137'. 07:30 09:30 2.00 11,137 PROD1 CASIN( CIRC P Circulate & condition mud @ 11137', reci rocatin strin . 09:30 11:00 1.50 PROD1 CASIN( RUNL P Make up rotating cementing head, 1 single of 4" XT39 DP and 10' Pup, with TIW valve & XO. MAke up Top drive connection on stump. All connections =22K ft/Ibs. 11:00 11:15 0.25 PROD1 CASIN( RUNL P POOH, break out & lay down cement head assembly with single joint of 4" DP for RIH. 11:15 12:00 0.75 PROD1 CASIN( RUNL P Continue RIH with 3 1/2" Liner from 11168', tagging bottom @ 11635' MD. Drop drift in stands # 114 - #118 on TIH. UP WT =180K, SO WT =130K. 12:00 13:00 1.00 PROD1 CASIN( RUNL P Pick up rotating cement head asssembly, and MU on stump. Rig up all cement lines and wash u lines. 13:00 14:00 1.00 PROD1 CASIN< CIRC P Esatablish circulation @ 2 BBLS /Min - 800 PSI. UP WT = 180K, SO WT = 130K. Slack off to observe tagging bottom @ 32.5 feet in on joint @ 11665' MD. Verify depths -good. Increase pump rates to 3 BPM - 1035 PSI. Observe no fluid loss while circulating. Pump a total of 198 BBLS while batch mix cement. 14:00 14:15 0.25 PROD1 CEMEI~ SFTY P Continue Circulate while hold PJSM with crew and Dowell. Discuss safety issues and procedure for pumping cemnet 'ob. 14:15 15:45 1.50 PROD1 CEMEf~ CIRC P Turn over to Dowell. Pump 5 BBLS fo water. Pressure test lines to 4500 PSI. Pump 10 BBLS 13.2 PPG Mud Push, pump 27 BBLS of 15.8 PPG Class G cement slurry. Wash up on top of plug and drop plug. Displace with Dowell , 20 BBLS of 8.3 PPG water, and displace with 99 BBLS of 12.1 PPG mud. Did not Bump plug. Bled back 3/4 BBLS. Floats held. Cement in lace 15:15 HRS. ~ s. ~ ~ r ~~ ~ of Time Logs Date From To Dur e th E. De th Phase :Code Subcode OM 05/05/2006 15:45 16:15 0.50 PROD1 CEME~ _ OTHR P Release form Liner hanger assembly as per BOT rep, rotating string 22 total right hand turns. Observed release, and pick up to observe pressure fall & do s kicked out. 16:15 17:45 1.50 PROD1 CEMEf~ CIRC P Establish circulation with rig pumps @ 7.5 BPM -1800 PSI, observing 6-8 BBLS of cement at surface on bottoms up. Total pumped 2 bottoms up = 5200 strokes. 17:45 18:00 0.25 PROD1 CEMEf~ OTHR P Break out & lay down rotating cement head assembl & lines. 18:00 18:30 0.50 PROD1 CEMEI~ TRIP P Continue breakout & lay down rotating cement head. & lines. POOH standing back 2 stands. 18:30 20:00 1.50 PROD1 CEMEI~ CIRC P Circulate hole clean .Monitor well. Static. Shut down all rig hydraulics and prepare rig for minimal oversight. Close pipe rams & install floor safety valve. Secure well. 20:00 00:00 4.00 PROD1 CEMEI~ OTHR P Rig shutdown for all personnel to attend Randy Smith Safety Leadership Training course planned for 2 days. Moduspec representative "Ken Eagles" here for ri ins ection. 05/06/2006 00:00 12:00 12.00 PROD1 CEMEC` SFTY P Rig Shutdown for Randy Smith Safety Leadership training at KIC. All rig personnel attending. Motorman & forklift driver d watchin ri . 12:00 00:00 12.00 PROD1 CASIN( SFTY P Rig Shutdown for Randy Smith Safety Leadership training at KIC. All rig personnel attending. Motorman & forklift driver d watchin ri . 05/07/2006 00:00 12:00 12.00 10,628 10,628 PROD1 CEMEI~ SFTY P Rig Shutdown for all personnel Ito attend Randy Smith Leadership Training. Motorman & forklift driver remamin at ri to d watch. 12:00 15:00 3.00 10,628 10,628 PROD1 CEMEI~ SFTY P Rig Shutdown for all personnel Ito attend Randy Smith Leadership Training. Motorman & forklift driver remamin at ri to d watch. 15:00 15:30 0.50 10,628 10,628 PROD1 CEME~ SFTY P Crews on rig at 1500 HRS. Held PJSM. Discuss safety issues, and rocedure for lan forward. 15:30 16:30 1.00 10,628 10,628 PROD1 CEMEI~ OTHR P DP & Annulus had built up pressure of 375 PSI. Bleed 375 PSI pressure off of Drill i e and annulus. 16:30 17:00 0.50 10,628 10,628 PROD1 CEMEI~ OTHR P Open top pipe rams & rig dowm monitoring equipment. Blow down choke lines and manifold. 17:00 17:15 0.25 10,628 10,771 PROD1 CEME~ TRIP P Trip in hole from 10628' - 10771' MD. To of acker = 11045'. Pa~st~ ~S ~t 52 Time Los Date From To Dur e th E. Depth Fhase Code Subcode OM 05/07/2006 17:15 18:00 0.75 10,771 10,771 PROD1 CEMEI~ CIRC P Circulate @ 80 SPM - 2900 PSI through Baker Setting tool assembly. UP WT = 252K, SO WT = 110K. Pump a total of 2450 Strokes, slowing rate to 1 BPM to handle excessive bar sag returns on shakers. Observed mud weight fluctuations from 11.5 PPG to 12.5 PPG, and aired up returns on bottoms u . 18:00 18:15 0.25 10,771 10,771 PROD1 CEMEN` CIRC P Continue circulate bringing rate up to 3 BPM - 340 PSI. 18:15 18:45 0.50 10,771 10,771 PROD1 CEMEt~ CIRC P Increase pump rate to 80 SPM - 2040 PSI observing returns cleaned up, and mud weight stabilizing @ 12.1 PPG . UP WT = 250 K, SO WT = 110K. 18:45 19:00 0.25 10,771 10,771 PROD1 CEMEf~ CIRC P Rig up and blow down Top Drive & lines. 19:00 19:15 0.25 10,771 10,771 PROD1 CEMEf~ RURD T Rig up lines & chart to test casing. 19:15 19:45 0.50 10,771 10,771 PROD1 CEMEI~ LOT T Fill lines with mud. Test down drill pipe & annulus to observe 1850 PSI and pressure broke over. Shut in and hold 10 minutes observing pressure decrease to 1350 PSI. Pumped 1 BBI into liner lap. Bleed ali pressures and ri down a ui ment. 19:45 20:30 0.75 10,771 10,882 PROD1 CEMEI~ TRIP T Trip in hole from 10721' - 10882'. Mu next stand and attempt to enter top of ZXP packer with stinger. Repeat attem ts. MU To Drive. 20:30 21:00 0.50 10,882 10,882 PROD1 CEMEI~ OTHR T Break Circulation @ 80 SPM - 2240 PSI. Repeat attempts to sting into ZXP acker assembl with no success. 21:00 21:15 0.25 10,882 10,786 PROD1 CEME~ TRIP P POOH stand back stand # 117. 21:15 21:30 0.25 10,786 10,786 PROD1 CEMEI~ CIRC P Mlx & pump 20 BBL. 2.0 PPG over, d 'ob. 21:30 22:00 0.50 10,786 10,786 PROD1 CEME~ OTHR P Blow down Top Drive & all lines. Clear & prepare rig floor for laying down drill strin . 22:00 23:00 1.00 10,786 10,628 PROD1 CEMEf~ TRIP P PJSM with crew. Discuss safety issues and procedure for layinig down drill string. POOH, breakout & lay down 4" drill i e. 23:00 00:00 1.00 10,628 10,628 PROD1 RIGMN SVRG P PJSM. Discuss safety issues and procedure for slipping & cutting drilling line. Rig up & slip & cut drilling line. Service To Drive. 05/08/2006 00:00 01:00 1.00 10,628 10,628 PROD1 RIGMN SVRG P Continue Slip & Cut Drilling Line & Ins ect Draw works. 01:00 06:00 5.00 10,628 4,820 PROD1 CEMEf~ TRIP P Continue POOH, breakout & lay down 4" Drill string. Pull from - 10628' - 4820'. Observe hole taking proper fill. Crew Chan e 06:00 06:15 0.25 4,820 5,200 PROD1 CEMEf~ TRIP P Trip in hole with 4 stands out of derrick from 4820' - 5200'. ~ _e. ~ e -~ s ~ ® ~ _ _~~ _..~~ Time Logs Date From To Dur e th E. De th Phase Code Subcode OM 05/08/2006 06:15 10:30 4.25 5,200 0 PROD1 CEMEf~ TRIP P Continue POOH, breakout & lay down 4" Drill string. Pull from 5200 - to surface. Observe hole takin ro er fill. 10:30 11:15 0.75 0 0 PROD1 CEME~ PULD P Change over to 3 1/2" handling equipment. Breakout & lay down Liner running /setting tools. Make all service breaks as er BOT re . 11:15 12:00 .0.75 0 0 PROD1 CEMEf~ OTHR P Pull test joint to rig floor. Make up tools to ull wear bushin . 12:00 12:15 0.25 0 0 PROD1 CEMEI~ OTHR P BOLDS and RIH with tool to engage wear bushing. Pull wear bushing and la down tools and test 'oint. 12:15 13:00 0.75 0 0 PROD1 CEMEI~ OTHR P Clean & clear rig floor. Send tools down beaver slide. 13:00 13:30 0.50 0 0 PROD1 RPCOh RURD P Pull tools to rig floor. Rig up to run 3 1/2" Completion as per detail. RU ower ton s etc... 13:30 14:30 1.00 0 0 PROD1 RIGMN SVRG P Service Top Drive & Blocks, while wait on DS ni le with RHC lu . 14:30 16:00 1.50 0 0 PROD1 RPCOti WOEO T Wait on equipment from toolhouse. DS ni le with RHC lu and ball & rod. 16:00 16:15 0.25 0 0 PROD1 RPCOh SFTY T PJSM with crew & BOT rep. Discuss safety issues and procedure for making up 3 1/2" completion assembl . 16:15 17:00 0.75 0 196 PROD1 RPCOh RCST T Make up Baker 80-40 Bonded Seal Assembly (11.49'), with Baker Spacer tubes (10.07', 10.07', & 5.07'. Baker Seal locator Sub 5" x 3" (7.35'), 2 joints of 3 1/2" EUE 8 RD tubing (60.12'), Pup joint (10.08'), Camco DS Landing Nipple 2.812" NO-GO profile (.94"0, pup joint (10.08'), 1 - jnt of tubing (31.35'), Pup Joint (4.18'), Baker FHL Retrievable Packer (7.37') Polished Seal Bore Receptacle (13.36'), Seal Locator assembly (.32'), and Pu 'oint 6.12' . 17:00 17:45 0.75 196 196 PROD1 RPCOh CIRC P Rig up and pump down tubing to verify clear ID through all equipment includin the DS ni le. 17:45 18:00 0.25 196 196 PROD1 RPCOti CIRC P Rig down lines and valve & blow down same. Crew Chan e. P~~~ ~ f 5~ Time Logs ~_ _ Date From To Dur e th E. De th Phase Code Subco de OM 05/08/2006 18:00 00:00 6.00 196 5,007 PROD1 RPCOh _ RCST P Continue run 3 1/2" Completion string as per detail to 157 jnoints = 5007'. Installing GLM's with Dummy valves to be postioned in well @ 10853', 10295', 8955', and 6812'. Install GLM with DCK Shear valve 2.875" ID to be positioned at 3758'. Observed hole taking proper dispalcement. Note: SIMOPS -Little red services rigiing up on well for Infectivity test & Freeze Protect. Held PJSM. Discuss Safety issues and procedure for rigging up and pumping. Pressure test lines to 3000 PSI. Open annulus valve and pump @ 1/4 BPM. Observe formation broke down at 1250 PSI (15.8 PPG MWE) at a shoe depth of 4121', pumping 3 BBLS away. 10 Minute shut in pressure bled from 1200 PSI to 800 PSI. Continue pumping a total of 256 BBLS of 8.3 PPG water and follow with 50 BBLS of Freeze protect diesel. 2 BPM FCP - 1500 PSI. Shut in pressure = 800 PSI. Record on chart. 05/09/2006 00:00 06:00 6.00 5,007 10,580 PROD1 RPCOh RCST P Continue run 3 1/2" Completion string as per detail from joint # 157 @ 5007' to 10580'. Installing GLM's with Dummy valves to be postioned in well @ 10853', 10295', 8955', and 6812'. Install GLM with DCK Shear valve 2.875" ID to be positioned at 3758'. Observed hole with proper dis lacement. 06:00 07:45 1.75 10,580 PROD1 RPCOh RCST P Continue running 3-1/2" completion string f/ 10580' to 11045'. PU wt 145k, SO wt 105k. Jt #346 in hole. 07:45 08:15 0.50 PROD1 RPCOCV RURD P Rig up pump in sub in top of jt # 347. RU cement line, remove top drive bell uide. 08:15 12:00 3.75 PROD1 RPCOh CIRC P Circulate down on jt #347 to confirm seals all the way in PBR. Circ @ 1 bpm w/ 380 psi. Half way down on jt # 347 saw a slight increase in pump pressure to 480 psi. Circulated all the way down on jt # 347 and did not engage seals in PBR. Pumped a total of 10 bbls. PU to circ tubing volume (96 bbls), circulated 100 bbls @ 27 spm (113 gpm) w/ 710 psi and mud still out of balance flowing out tubing. Circ all the wa around 363 bbls. 12:00 14:00 2.00 PROD1 RPCOR CIRC P MU jt #348 to circ down. Slack off total of 29' to engage seals in PBR while circulating. MU jt #349, RIH 19' to tag bottom tie back sleeve ZXP w/ locator on seal assembly. Slack off 15k on locator. e~ ~ ~m ~ ~__~_~ ~~ ~~ ~t ~~ Time Los date From To Dur e th E. Depth phase Code Subcode OM 05/09/2006 14:00 14:30 0.50 PROD1 RPCOti DHEQ T Rig up to pressure test annulus w/ rig pumps to 2000 psi. Chart test to compare test w/with drill pipe and liner running tools in hole test. Pressure built to 2000 si. 14:30 15:15 0.75 PROD1 RPCOh OTHR T PU out of PBR seal bore to drop ball and rod. PU wt 148k. Ball and rod overall length 8.58'. 1-5/16" ball OD. Mandrel OD 1.90" w/ .80' to fishing neck of first roller. OD of rod @ rollers = 2-9/16". Drop ball and rod. Pump down tubing to confirm ball and rod on seat (OK). Pressure up to 740 psi. Bleed off ressure. 15:15 15:45 0.50 PROD1 RPCOh PACK T Slack off and tag down on liner. PU wt 142k w/ 1-1/2 foot above locator. Line up on tubing pressure to set Baker FHL packer, with pressure @ 2500 psi, lost weight on weight indicator. Continue to bring pressure up to 3000 psi, hold f/ 5 min, OK. Bleed tubing down to 1500 si and shut in. 15:45 16:30 0.75 PROD1 RPCOh PACK P Pickup w/ 1500 psi on tubing. PBR sheared off while setting Baker FHL packer. 12.56 square inches x 3000 psi = 37680 lbs. PU wt 130k w/ seals in PBR, Pull up +/- 6' free from FHL PBR and did not see shear. Slack off, to downs ace out from that oint. 16:30 18:00 1.50 PROD1 RPCOh HOSO P Measure out RKB 35.5'+4.29' + 1' _ 40.79'. Mark and measure to next collr. Requires pup 6.13'. Pup available = 5.98'. Lay down jt # 249 + #348. Pull joint #347, break and install 5.98' pup below joint # 347, RIH #347, MU FMC hanger and landing joint. RIH, MU head in, PU out of PBR. 18:00 18:30 0.50 PROD1 RPCOh HOSO T With 15' picked up from landed, circulate while slacking off, engage seals @ 10' from being landed on tubin han er, ressure u to 300 si. 18:30 19:15 0.75 PROD1 RPCOh CIRC T Pickup to 25' from being landed. Circ 87 bbls of 8.5 ppg seawater. Stop pumps with 780 psi on tubing. Slackoff w/ 105k down weight to landed position w/ pressure increase to 1120 psi. Bleed off all pressure on tubing to test float equipment. No volume bleed back. Float a ui ment tested ood. 19:15 20:00 0.75 PROD1 RPCOh CIRC P Flush 12.2 ppg mud from all mud lines and um s with 8.5 seawater. 20:00 20:45 0.75 PROD1 RPCOCV OTHR P After flushing all surface equipment with seawater, pressure tubing up to 1120 psi. Pickup above PBR with seals (after picked up pressure again was 750 psi) to circulate 8.5 ppg seawater into well. Time Logs: i Date From To Dur e th E. Depth Phase Code Subcode OM _ 05/09/2006 20:45 21:00 0.25 PROD1 RPCOti SFTY P PJSM on displacing well f/ 12.2 ppg mud to 8.5 seawater. 21:00 22:15 1.25 PROD1 RPCOh CIRC P Displace well f/ 12.2 ppg to 8.5 ppg seawater. Displace @ 10 bpm w/3100 psi initial to 2100 psi final pressure. (Note pumped total of 7202 strokes, 725 bbls seawater including the first 87 bbls . 22:15 23:15 1.00 PROD1 RPCOh CIRC P Line up on inhibited seawater to mud pumps from vac truck. Pump 250 bbls 50 s m 5b m w/ 610 si. 23:15 23:30 0.25 PROD1 RPCOh CIRC P Chase inhibited 8.5 ppg seawater w/ 39 bbls 8.5 ppg seawater w/o inhibitor. Pum ed 6 b m w/ 840 si. 23:30 00:00 0.50 PROD1 RPCOh HOSO P Drain stack, land hanger. 135k PU wt, 109k SO wt. 05/10/2006 00:00 01:15 1.25 PROD1 RPCOCV DHEQ P RILDS on FMC 3-1/2" hanger, torque to 450 ftllb torque. Test 3-1/2" tubing to 3500 psi f/ 30 min. Chart test. Good test. 19 strokes to presssure up to .3500 psi. After test bleed off to 1675 si and shut in. 01:15 03:00 1.75 PROD1 RPCOh DHEQ P RU and test 3-1/2" x 7" annulus to 3500 psi. Chart test. Held f/ 30 min. Tubing pressure increased to 2200 psi while pumping ann to 3500psi. Both tubing and ann pressure stayed the same. 03:00 03:45 0.75 PROD1 RPCOh DHEQ P With 3500 psi on annulus and 2200 psi on tubing, bleed off tubing. With tubing at about 500 psi, DCK shear valve in GLM @ 2760' sheared, allowing communication f/annulus to tubing. Bleed ressure to zero. 03:45 04:00 0.25 PROD1 WELCT OTHR P RU and set BPV w/ "T" bar from surface. 04:00 10:30 6.50 PROD1 WELCT NUND P Blow down circulating lines to pumps and choke. Nipple down 13-5/8" BOPE. 10:30 12:00 1.50 PROD1 WELCT NUND P NU FMC adapter flange. Test void on SBMS seals. Pull BPV, install two wa check. 12:00 12:45 0.75 PROD1 WELCT NUND P PU WKM tree. Checked SBMS. Then hammered u tree. 12:45 13:30 0.75 PROD1 WELCT ROPE P RU little red to test tree to 250 psi low and 5000 si hi h f/ 5 min. Chart test. 13:30 13:45 0.25 PROD1 WELCT OTHR P Rig down test equipment. 13:45 14:00 0.25 PROD1 WELCT SFTY P PJSM on pulling Two way check w/ FMC re . 14:00 14:30 0.50 PROD1 WELCT OTHR P Pull two way check from hanger. 14:30 14:45 0.25 PROD1 RPCOh SFTY P PJSM w/ Little Red on freeze protection of 3-1/2" tubing and 3-1/2" x 7" annulus. ~ ~ ~ - _m_ ~ ~ a P~~ ~~! ~s~ x2 ~~ Time Los ~ _ Date From To Dur 9~ th E.'De t_h Phase Code Subcode OM 05/10/2006 14:45 16:30 1.75 PROD1 RPCOh FRZP P RU Little Red circulating lines. Pressure test lines to 2500 psi. Little Red pump 99 bbls diesel down annulus. Allow to "U" tube to tubing side. Blow down and rig down circulatin lines. 16:30 18:00 1.50 PROD1 WELCT OTHR P PU/MU lubricator. Install BPV. UD lubricator and secure well. 18:00 00:00 6.00 PROD1 MOVE OTHR P Cleaning pits and rockwasher. Wash down cellar. Remove FMC diverter "T". Remove FMC speed head and DSA f/ "T". Clean up boards incellar area. Blow down transfer lines from cellar and rig down lines and pump. Blow down steam lines and water lines. Remove seam caps from above pipe shed and remove handrails. Double check that well is secure. Rig released f/ move to 1J-127 @ 2359 hrs 5/10/2006 Midni ht ~ ~_ _ . .~~ l~~c~e ~'~ ~f a ~ ,. ~ ,.~ 2T-40 Well Events Summary • DATE Summary 05/22/06 PULLED BALL AND ROD AND RHC PLUG @ 10977' RKB. CHANGED OUT SHEAR VALVE W /DUMMY VALVE IN STA #1 @ 3761' RKB. IN PROGRESS. 05/23/06 PUSHED OBSTRUCTION DOWNHOLE TO 11164' RKB. RAN 2.68" CENT & BAILER, RECOVERED MUD. RAN 2.70" LIB, INCONCLUSIVE. ATTEMPTED SPEARING POSSIBLE WIPER, NO RECOVERY. MITIA, PASSED. IN PROGRESS. 05/24/06 ATTEMPTED SPEAR WIPER PLUG /OBSTRUCTION. DRAGGED SAME UPHOLE TO 10150' SLM & LOST IT. SUSPEND JOB TO ACCOMODATE CTU RIG UPON 2T-06. 05/29/06 MILLED ON RESTRICTION IN TUBING FROM 11,152' CTM TO 11,189' CTM, VERY SLOW GOING, GOOD CEMENT/MUD RETURNS THROUGH OUT MILL OPERATION. CIRCULATED TOTAL OF 485 BBLS SEAWATER THRU MI SWACO SKID, FOUND TWO SMALL CHUNKS OF WIPER RUBBER IN FLUTES OF MILL. 05/30/06 MILLED CEMENT WIPER PLUG/CEMENT IN 3.5" LINER WITH 2.75" THREE BLADE JUNK MILL FROM 11,196' TO 11,550' CTM. GOOD RETURNS THROUGH OUT JOB. CIRCULATED HOLE CLEAN WITH SEAWATER, FREEZE PROTECTED TUBING WITH DIESEL TO 2500'. PT TUBING/LINER TO 2500 PSI. 06/01/06 GAUGE TBG TO 2.775" & TAG FILL @ 11588' RKB. DRIFTED TBG W/ 23' X 2.78" DUMMY GUN TO 11286' RKB. TIGHT SPOTS @ 9084',10646' & 10786' RKB. DID NOT MAKE TARGET DEPTH OF 11430' RKB. METAL SCRAPES & RUBBER MARKS ON DRIFT. JOB COMPLETE. 06/02/06 RAN 2.75" OD, 12' DUMMY GUN TO 11202' SLM / WORKED TO 11205' SLM COULD NOT GO FURTHER, HAD TO WORK TOOL FREE. RDMO. 06/07/06 RIH W/ 2.80" string mill & 2.80" 5 blade Concave mill to 11551' CTMD. 1:1 returns throughout job, with no traces of solids in returns. Made 4 mill passes from 11200'- 11550' with mill BHA, performed dry drift to 11550' CTMD with no obstructions. 06/08/06 DRIFTED TBG W/ 11' 6" X 2.590" DUMMY GUN TO 11188' WLM. WORKED THRU TIGHT SPOT @ 11188' WLM W/ BL BRUSH & 2.50" BAILER & TAGGED FILL @ 11525' WLM. IN PROGRESS. 06/09/06 BROACHED TIGHT SPOT IN TBG @ 11188' WLM TO 2.75". UNABLE TO DRIFT W/ 11' 6" X 2.59" DUMMY GUN. 06/11/06 BROACHED TUBING TO 2.795" TO 11549' WLM. DRIFTED TO DEPTH W/ 15' X 2.125" STEM. UNABLE TO DRIFT PAST TIGHT SPOT @ 11210' WLM W/ 2.590" X 11' 6" DUMMY GUN. 06/14/06 LOGGED PMIT CALIPER FROM 11564' TO 10800', FOUND ANNOMOLIES AT COLLARS LOCATED AT 11320' AND 11100', POSSIBLE CEMENT BUILDUP AT 11234'- 11237' -- RAN SCMT CEMENT BOND LOG FROM 11557' TO 10800', GOOD CEMENT FROM 11557' TO BOTTOM OF 7" CASING AT 11220' -- 06/15/06 MITT PASSED. INITIAL T/I/O = 4500/190/450; 15 MIN = 4200/197/448; 30 MIN = 4125/190/448 06/16/06 PERFORATE INTERVALS: 11402' - 11412' AND 11420' - 11430' USING 2" HSD HYPERJET GUNS, 6 SPF (EHD= 0.33", PEN=9.6"). 06/18/06 PUMP INITIAL A SAND FRACTURE TREATMENT USING 50# X-LINK GEL AT 20 BPM. PLACE TOTAL OF 181,414# OF 16/20 PROPPANT BEHIND PIPE WITH 10 PPA ON PERFS. FLUSH JOB TO COMPLETION WITH 64 BBLS OF SEAWATER & 30 BBLS DIESEL. 06/20/06 PERFORM POST FRAC CLEAN OUT TO HARD BOTTOM @ 11554' CTM,USING SLICK DIESEL AND DIESEL GEL FOR FLUID.MAINTAIN GOOD 1 FOR 1 RETURNS THROUGH OUT THE JOB,WITH HEAVY THE LIGHT SAND DURING CLEANING OPERATIONS.POOH @ 80% WASHING COMPLETION/LINER JEWELRY AND GLM AT MAX PUMP RATE. • 2T-40 Well Events Summary 06/22/06 TAG @ 11471' RKB. PULLED DVs @ 3761', 6815' & 8985' RKB. SET GLV @ 3761' RKB. TOOLS FALLING SLOWLY; INITIALLY STOPPED AT 1672' SLM; PUMPED DOWNHOLE. 06/23/06 SET GLVs @ 6815' & 8958' RKB. SET D&D HOLEFINDER @ 9075' SLM & PT TBG TO 2000 PSI RESULTING IN GOOD TEST. 06/24/06 DRIFT TUBINGTO 11,440' RKB. RECORDED SBHP W/SURVEY STOP @ 11415' RKB 3375 PSI, 148 F) AND GRADIENT STOP @ 11315' RKB (3343 PSI, 151 F ). Halliburton Company Survey Report I ~nmp:w~: ConocoPhillipsAlaska Inc . ir,,t~~: G2i2006 I iinc: 11.59.13 I'sc: I Field: Kuperuk River Unit Cii-ordinate(\I:) Rc lcmncc: W ell_ 2T-40. True North 1i[c: Kuperuk 2T Pad ~criicnl (Ill>) Rcfc rcucc: 2T -d0- 113.9 11x11: 2T-~0 ~ccliun I~ ~1 Itcferc ncc: W ell i0 00N_D OOE310-44Azi) ~! cllpaih: 2T-;0 ~luncc ('alculaliou ~Icthud: Mi ni~rum Curvatu re Uh: Oracle Field: Kuperuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1 927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866} Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: ~ bggm2005 Well: 2T-40 Slot Name: Well Position: +N/-S -112.21 ft Northing: 5970270 .23 ft Latitude: 70 19 48.025 N +E/-W -0.26 ft Fasting : 498944 .65 ft Longitude: 150 0 30.815 W Position Un certainty: 0.00 ft Wellpath: 2T-40 Drilled From: Well Ref. Point 501032052800 Tie-on Depth: 41.05 ft Current Da tum: 2T-40: Height 118 .85 ft Above System D atum: Mean Sea Level Magnetic Data: 4/5/2006 Declination: 23.91 deg Field Strength: 57547 nT Mag Dip Angle: 80.76 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direc tion ft ft ft deg 41.05 0.00 0.00 310.44 Survey Program for Definitive Wellpath Date: 12/12/2002 Validated: No ~ Version: 3 Actual From To Survey Toolcode Tool Name ft ft 80.00 1013.00 2T-40 gyro (80.00-1013. 00) CB-GYRO-SS Camera based gyro single shot 1048.27 11624.78 2T-40 (1048.27-11624.78) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1U Incl Mini l ~ D 5}s 71 D V' S L~:'W ~lahA 11a1il; Tuul ft deg deg ft ft ft ft ft ft 41.05 0.00 0.00 41.05 -77.80 0.00 0.00 5970270.23 498944.65 • TIE LINE 80.00 0.67 339.34 80.00 -38.85 0.21 -0.08 5970270.44 498944.57 CB-GYRO-SS 144.00 1.19 311.31 143.99 25.14 1.00 -0.71 5970271.23 498943.94 CB-GYRO-SS 178.00 2.22 308.64 177.98 59.13 1.65 -1.49 5970271.88 498943.16 CB-GYRO-SS 269.00 6.04 304.55 268.72 149.87 5.46 -6.81 5970275.69 498937.84 CB-GYRO-SS 360.00 9.53 306.82 358.87 240.02 12.70 -16.79 5970282.93 498927.86 CB-GYRO-SS 452.00 12.70 308.31 449.13 330.28 23.53 -30.83 5970293.76 498913.83 CB-GYRO-SS 545.00 14.86 310.49 539.45 420.60 37.61 -47.92 5970307.85 498896.74. CB-GYRO-SS 638.00 14.69 309.49 629.38 510.53 52.86 -66.09 5970323.09 498878.58 CB-GYRO-SS 727.00 16.40 310.50 715.12 596.27 68.19 -84.35 5970338.43 498860.32 CB-GYRO-SS 825.00 19.68 312.59 808.29 689.44 88.35 -107.03 5970358.59 498837.65 CB-GYRO-SS 925.00 22.87 314.88 901.46 782.61 113.47 -133.20 5970383.70 498811.48 CB-GYRO-SS 1013.00 24.39 312.55 982.08 863.23 137.82 -158.71 5970408.06 498785.98 CB-GYRO-SS 1048.27 25.82 311.58 1014.02 895.17 147.84 -169.82 5970418.08 498774.87 MWD+IFR-AK-CAZ-SC 1142.18 30.16 312.15 1096.93 978.08 177.26 -202.62 5970447.50 498742.08 MWD+IFR-AK-CAZ-SC 1239.99 30.57 311.37 1181.32 1062.47 210.19 -239.50 5970480.43 498705.20 MWD+IFR-AK-CAZ-SC 1334.78 34.38 308.59 1261.28 1142.43 242.83 -278.53 5970513.07 498666.18 MWD+IFR-AK-CAZ-SC 1429.24 38.25 311.22 1337.38 1218.53 278.75 -321.39 5970548.99 498623.34 MWD+IFR-AK-CAZ-SC 1525.45 40.30 310.16 1411.85 1293.00 318.44 -367.57 5970588.69 498577.16. MWD+IFR-AK-CAZ-SC 1620.57 46.05 310.16 1481.19 1362.34 360.40 -417.29 5970630.65 498527.45 MWD+IFR-AK-CAZ-SC 1715.48 51.53 310.46 1543.70 1424.85 406.58 -471.71 5970676.83 498473.04 MWD+IFR-AK-CAZ-SC 1809.28 55.93 312.22 1599.18 1480.33 456.54 -528.45 5970726.80 498416.32 MWD+IFR-AK-CAZ-SC 1903.94 57.47 310.82 .1651.15 1532.30 508.97 -587.69 5970779.24 498357.09 MWD+IFR-AK-CAZ-SC 2000.39 63.30 310.64 1698.79 1579.94 563.66 -651.21 5970833.92 498293.59 MWD+IFR-AK-CAZ-SC 2095.22 63.60 308.41 1741.18 1622.33 617.64 -716.64 5970887.91 498228.17 MWD+IFR-AK-CAZ-SC 2191.17 67.92 307.58 1780.57 1661.72 671.48 -785.57 5970941.75 498159.25 MWD+IFR-AK-CAZ-SC 2283.14 66.33 309.22 1816.32 1697.47 724.10 -851.98 5970994.38 498092.86 MWD+IFR-AK-CAZ-SC 2373.59 67.24 308.18 1851.97 1733.12 776.07 -916.85 5971046.35 498028.00 MWD+IFR-AK-CAZ-SC ~ 2473.00 63.88 309.68 1893.10 1774.25 832.92 -987.25 5971103.20 497957.61 MWD+IFR-AK-CAZ-SC ~ • Halliburton Compan~ Survey Report Cuni~i,u~}: ConocoPhillfps Alaska Inc. Daic: 6i2;~006 1 imc: 11 59~ 13 Pac:_ Ficlil: Ku paruk Rive r Unit Cu-un linatcl~F.) R rfcrrncr. W ell: 2T-40 True Norfh ~itc: Ku paruk ~T P ad V'crtic al (11111 ILcf crcncc: 2T -40- 118.9 ~Fcll: 2T -40 >ectiu n <<~S~ Rrfcrc ucc W ell (O OON 0-OOE .310.44Azi) 11cII~c~Ui: 2T -40 tinr<<~y (aleulatiun ~lcthu~l: Mi nimum Curvatur e I)h: Oracle tiunc~ ~tl) Incl ~iim Il D Sys l ~1) \%ti I~:;'ti1' 11:~~iA ~lapl~: ~I nail ft deg deg ft ft ft ft ft ft 2568.20 66.29 309.26 1933.20 1814.35 887.80 -1053.90 5971158.09 497890.98 MWD+IFR-AK-CAZ-SC 2662.55 68.92 310.03 .1969.15 1850.30 943.45 -1121.06 5971213.75 497823.83 MWD+IFR-AK-CAZ-SC 2756.07 66.52 309.83 2004.60 1885.75 998.99 -1187.42 5971269.29 497757.49 MWD+IFR-AK-CAZ-SC 2852.23 67.82 311.45 2041.91 1923.06 1056.72 -1254.66 5971327.02 497690.26 MWD+IFR-AK-CAZ-SC 2946.65 67.61 311.46 2077.72 1958.87 1114.56 -1320.14 5971384.86 497624.80 MWD+iFR-AK-CAZ-SC 3045.37 66.38 312.26 2116.30 1997.45 1175.19 -1387.82 5971445.50 497557.14 MWD+IFR-AK-CAZ-SC 3137.69 69.08 313.02 2151.28 2032.43 1233.06 -1450.65 5971503.37 497494.31 MWD+IFR-AK-CAZ-SC 3232.81 67.66 312.30 2186.34 2067.49 1292.98 -1515.68 5971563.29 497429.31 MWD+IFR-AK-CAZ-SC 3327.74 66.22 310.20 2223.53 2104.68 1350.57 -1581.33 5971620.89 497363.67 MWD+IFR-AK-CAZ-SC 3424.53 67.89 310.56 2261.26 2142.41 1408.32 -1649.23 5971678.64 497295.79 MWD+IFR-AK-CAZ-SC 3520.25 66.36 310.83 2298.47 2179.62 1465.82 -1716.09 5971736.14 497228.94 MWD+IFR-AK-CAZ-SC 3613.99 66.64 310.24 2335.85 2217.00 1521.69 -1781.43 5971792.01 497163.62 MWD+IFR-AK-CAZ-SC 3709.83 65.76 310.70 2374.52 2255.67 1578.60 -1848.13 5971848.93 497096.92 MWD+IFR-AK-CAZ-SC 3807.51 67.40 310.35 2413.35 2294.50 1636.84 -1916.27 5971907.17 497028.81. MWD+IFR-AK-CAZ-SC 3901.90 67.19 310.18 2449.78 2330.93 1693.12 -1982.71 5971963.46 496962.38 MWD+IFR-AK-CAZ-SC 3995.99 67.63 310.10 2485.92 2367.07 1749.12 -2049.12 5972019.46 496895.98 MWD+IFR-AK-CAZ-SC 4091.60 68.32 308.76 2521.78 2402.93 1805.41 -2117.58 5972075.75 496827.54 MWD+IFR-AK-CAZ-SC 4187.16 68.30 308.93 2557.10 2438.25 1861.10 -2186.74 5972131.45 496758.40 MWD+IFR-AK-CAZ-SC 4282.45 67.36 310.89 2593.06 2474.21 1917.71 -2254.42 5972188.06 496690.72 MWD+IFR-AK-CAZ-SC 4373.06 66.96 310:28 2628.23 2509.38 1972.04 -2317.84 5972242.39 496627.32 MWD+IFR-AK-CAZ-SC 4469.35 66.06 309.63 2666.61 2547.76 2028.75 -2385.53 5972299.11 496559.64 MWD+IFR-AK-CAZ-SC 4565.99 65.63 310.82 2706.16 2587.31 2085.69 -2452.86 5972356.06 496492.33 MWD+IFR-AK-CAZ-SC 4657.97 66.90 309.93 2743.18 2624.33 2140.23 -2517.00 5972410.60 496428.20 MWD+IFR-AK-CAZ-SC 4754.76 66.57 310.19 2781.41 2662.56 2197.46 -2585.06 5972467.83 496360.16 MWD+IFR-AK-CAZ-SC 4851.29 66.93 311.71 2819.51 2700.66 2255.58 -2652.04 5972525.96 496293.19 MWD+IFR-AK-CAZ-SC 4947.95 66.59 310.92 2857.66 2738.81 2314.22 -2718.75 5972584.60 496226.50 MWD+IFR-AK-CAZ-SC 5039.11 66.04 310.44 2894.28 2775.43 2368.64 -2782.06 5972639.02 496163.20 MWD+IFR-AK-CAZ-SC 5135.87 66.06 310.55 2933.55 2814.70 2426.06 -2849.30 5972696.45 496095.97 MWD+IFR-AK-CAZ-SC 5229.71 66.56 311.14 2971.26 2852.41 2482.26 -2914.31 5972752.65 496030.98 MWD+IFR-AK-CAZ-SC 5328.37 67.65 309.54 3009.64 2890.79 2541.09 -2983.58 5972811.48 495961.72 MWD+IFR-AK-CAZ-SC 5420.44 67.55 307.86 3044.73 2925.88 2594.31 -3050.01 5972864.71 495895.31 MWD+IFR-AK-CAZ-SC 5519.98 67.73 307.71 3082.60. 2963.75 2650.71 -3122.77 5972921.12 495822.57 MWD+IFR-AK-CAZ-SC 5610.99 66.75 308.04 3117.81 2998.96 2702.23 -3189.01 5972972.64 495756.34 MWD+IFR-AK-CAZ-SC 5704.08 67.25 307.53 3154.18 3035.33 2754.73 -3256.73 5973025.15 495688.63 MWD+IFR-AK-CAZ-SC 5803.98 66.95 306.61 3193.05 3074.20 2810.21 -3330.16 5973080.62 495615.22 MWD+IFR-AK-CAZ-SC 5895.06 66.92 307.11 3228.74 3109.89 2860.47 -3397.21 5973130.90 495548.19 MWD+IFR-AK-CAZ-SC 5992.89 65.03 306.87 3268.56 3149.71 2914.24 -3468.57 5973184.66 495476.83 MWD+IFR-AK-CAZ-SC 6089.68 65.18 306.92 3309.31 3190.46 2966.94 -3538.79 5973237.38 495406.63 MWD+iFR-AK-CAZ-SC 6185.44 65.79 306.08 3349.04 3230.19 3018.77 -3608.83 5973289.20 495336.61 MWD+IFR-AK-CAZ-SC 6281.18 66.47 307.64 3387.79 3268.94 3071.29 -3678.87 5973341.73 495266.58 MWD+IFR-AK-CAZ-SC 6377.34 66.61 307.72 3426.07 3307.22 3125.21 -3748.68 5973395.65 495196.78 MWD+IFR-AK-CAZ-SC 6472.35 66.88 307.27 3463.58 3344.73 3178.34 -3817.94 5973448.79 495127.54 MWD+IFR-AK-CAZ-SC 6567.51 65.76 307.24 3501.80 3382.95 3231.09 -3887.31 5973501.55 495058.19 MWD+IFR-AK-CAZ-SC ~ 6662.79 65.98 306.75 3540.75 3421.90 3283.42 -3956.75 5973553.88 494988.75 MWD+IFR-AK-CAZ-SC 6756.33 65.01 307.65 3579.55 3460.70 3334.87 -4024.55 5973605.34 494920.97 MWD+IFR-AK-CAZ-SC 6845.79 64.77 307.69 3617.51 3498.66 3384.38 -4088.67 5973654.84 494856.86 MWD+IFR-AK-CAZ-SC ~ 6946.77 65.19 307.49 3660.22 3541.37 3440.20 -4161.18. 5973710.67 494784.37 MWD+IFR-AK-CAZ-SC 7040.69 64.93 307.23 3699.82 3580.97 3491.87 -4228.87 5973762.35 494716.70 MWD+IFR-AK-CAZ-SC 7138.89 65.99 306.82 3740.61 3621.76 3545.66 -4300.19 5973816.14 494645.39 MWD+IFR-AK-CAZ-SC ' 7234.26 66.26 306.51 3779.21 3660.36 3597.74 -4370.14 5973868.22 494575.45 MWD+IFR-AK-CAZ-SC 7329.21 66.55 306.36 3817.21 3698.36 3649.42 -4440.14 5973919.91 494505.46 MWD+IFR-AK-CAZ-SC 7424.57 65.66 307.53 3855.84 3736.99 3701.81 -4509.82 5973972.31 494435.80 MWD+IFR-AK-CAZ-SC Halliburton Company` Survey Report (~umpanp: ConocoPhillipsAlaskalnc. I)a[c: 6!212006 Iimc 1159'13 P:~c: 3 Picl~l: Kuparuk River Unit C„-~n~~lin,itcl~f) ~Zcti'r~~~~'~~ ~/`~°II: 2T-4Q True North 1itc: Kuparuk 2T Pad ~`crtical (C~l1) Reference: 2T-40 118.9 ~~cll: 2T-40 ~cciiun (BSI Reference: Well (0.00N,0-00E~10 ~4Azi) \1~ellpatl~: ZT-40 ~m~~cc ('.ilculatio^ ~lcthud: Minimum Curvature I)b: Oracle ~urcrc ~IU Inrl ~iim ~h11) >~~ l~~ I) \~~ F;~~ ~iat~A ~Iapl~; l~rnil ft deg deg ft ft ft ft ft ft 7519.75 65.87 306.67 3894.91 3776.06 3754.17 -4579.05 5974024.67 494366.59 MWD+IFR-AK-CAZ-SC 7614,87 65.35 308.33 3934.19 3815.34 3806.90 -4647.77 5974077.40 494297.88 MWD+IFR-AK-CAZ-SC 7709.03 65.37 308.72 3973.45 3854.60 3860.21 -4714.73 5974130.71 494230.93 MWD+IFR-AK-CAZ-SC 7803.40 65.20 308.48 4012.91 3894.06 3913.69 -4781.73 5974184.20 494163.95 MWD+IFR-AK-CAZ-SC 7899.73 66.89 307.18 4052.02 3933.17 3967.67 -4851.26 5974238.19 494094.44 MWD+IFR-AK-CAZ-SC 7992.19 66.86 306.78 4088.33 3969.48 4018.82 -4919.18 5974289.34 494026.52 MWD+IFR-AK-CAZ-SC 8042,22 67.02 306.74 4107.93 3989.08 4046.37 -4956.06 5974316.89 493989.65 MWD+IFR-AK-CAZ-SC 8129.48 67.38 305.66 4141.74 4022.89 4093.88 -5020.98 5974364.41 493924.75 MWD+IFR-AK-CAZ-SC 8224.65 66.40 305.14 4179.10 4060.25 4144.59 -5092.32 5974415.12 493853.42 MWD+IFR-AK-CAZ-SC 8317.90 64.89 305.60 4217.55 4098.70 4193.76 -5161.59 5974464.29 493784.16 MWD+IFR-AK-CAZ-SC 8412.65 67.13 306.46 4256.07 4137.22 4244.68 -5231.59 5974515.22 .493714.18 MWD+IFR-AK-CAZ-SC 8509.03 67.20 306.96 4293.48 4174.63 4297.77 -5302.80 5974568.32 493642.98 MWD+IFR-AK-CAZ-SC 8604.93 66.71 307.50 4331.02 4212.17 4351.16 -5373.06 5974621.71 493572.73 MWD+IFR-AK-CAZ-SC 8699,32 66.45 306.78 4368.53 4249.68 4403.46 -5442.11 5974674.01 493503.70 MWD+IFR-AK-CAZ-SC 8795.07 66.11 309.87 4407.06 4288.21 4457.81 -5510.87 5974728.37 493434.96 MWD+IFR-AK-CAZ-SC 8892.59 64.90 310.13 4447.49 4328.64 4514.85 -5578.85 5974785.41 493366.99 MWD+IFR-AK-CAZ-SC 8961,85 64.75 .309.78 4476.95 4358.10 4555.10 -5626.90 5974825.67 493318.95 .MWD+IFR-AK-CAZ-SC 9056.53 66.22 308.90 4516.24 4397.39 4609.70 -5693.52 5974880.27 493252.35 MWD+IFR-AK-CAZ-SC 9T51.87 69.20 310.73 4552.40 4433.55 4666.19 -5761.26 5974936.77 493184.62 MWD+IFR-AK-CAZ-SC 9246,32 67.90 309.43 4586.94 4468.09 4722.79 -5828.52 5974993.37 493117.38 MWD+IFR-AK-CAZ-SC 9341.56 67.12 309.08 4623.37 4504.52 4778.47 -5896.66 5975049.06 493049.26 MWD+IFR-AK-CAZ-SC 9436.16 66.25 308.28 4660.81 4541.96 4832.77 -5964.47 5975103.36 492981.45 MWD+IFR-AK-CAZ-SC 9531.13 64.96 308.14 4700.04 4581.19 4886.27 -6032:43 5975156.86 492913.51 MWD+IFR-AK-CAZ-SC 9628.00 65.32 307.32 4740.76 4621.91 4940.05 -6101.95 5975210.65 492844.01 MWD+IFR-AK-CAZ-SC 9722,71 66.19 307.13 4779.65 4660.80 4992.29 -6170.71 5975262.89 492775.26 MWD+IFR-AK-CAZ-SC 9818.17 65.18 307.00 4818.96 4700.11 5044.72 -6240.12 5975315.33 492705.86 MWD+IFR-AK-CAZ-SC 9912,93 63.95 306.75 4859.66 4740.81 5096.07 -6308.58 5975366.68 492637.42 MWD+IFR-AK-CAZ-SC 10007.97 64.57 307.15 4900.93 4782.08 5147.54 -6376.99 5975418.15 492569.02 MWD+IFR-AK-CAZ-SC 10103.61 63.03 310.40 4943.16 4824.31 5201.25 -6443.89 5975471.87 492502.14 MWD+IFR-AK-CAZ-SC 10198,79 58.28 309.13 4989.80 4870.95 5254.32 -6507.63 5975524.94 492438.41 MWD+IFR-AK-CAZ-SC 10293.86 54.94 308.64 5042.11 4923.26 5304.15 -6569.40 5975574.77 492376.65 MWD+IFR-AK-CAZ-SC 10389.82 54.46 309.40 5097.56 4978.71 5353.46 -6630.25 5975624.08 492315.82 MWD+IFR-AK-CAZ-SC 10483.28 53.26 308.58 5152.68 5033.83 5400.95 -6688.91 5975671.58 492257.17 MWD+IFR-AK-CAZ-SC 10579,76 52.12 310.93 5211.16 5092.31 5450.00 -6747.90 5975720.64 492198.19 MWD+IFR-AK-CAZ-SC 10673.67 49.52 319.49 5270.55 5151.70 5501.51 -6799.17 5975772.14 492146.93 MWD+IFR-AK-CAZ-SC .10765,44 47.29 324.74 5331.50 5212.65 5555.60 -6841.33 5975826.24 492104.79 MWD+IFR-AK-CAZ-SC 10864.18 41.59 330.12 5401.99 5283.14 5613.70 -6878.64 5975884.34 492067.49 MWD+IFR-AK-CAZ-SC 10958.83 38.20 336.19 5474.63 5355.78 5667.76 -6906.12 5975938.39 492040.01 MWD+IFR-AK-CAZ-SC 11054.58 37.12 342.58 5550.45 5431.60 5722.43 -6926.73 5975993.06 492019.41 MWD+IFR-AK-CAZ-SC 11148.69 36.18 348.46 5625.98 5507.13 5776.76 -6940.80 5976047.39 492005.36 MWD+IFR-AK-CAZ-SC 11218.31 35.15 353.62 5682.56 5563.71 5816.82 -6947.14 5976087.45 491999.03 MWD+IFR-AK-CAZ-SC 11260.57 35.68 356.79 5717.00 5598.15 5841.22 -6949.18 5976111.84 491996.99 MWD+IFR-AK-CAZ-SC 11290,90 37.44 357.07 5741.36 5622.51 5859.26 -6950.15 5976129.88 491996.02 MWD+IFR-AK-CAZ-SC 11309.17 38.01 357.35 5755.81 5636.96 5870.42 -6950.69 5976141.04 491995.48 MWD+IFR-AK-CAZ-SC 11354.53 37.16 0.59 5791.76 5672.91 5898.08 -6951.19 5976168.69 491994.98 MWD+IFR-AK-CAZ-SC 11383.12 35.99 3.22 5814.72 5695.87 5915.10 -6950.63 5976185.72 491995.54 MWD+IFR-AK-CAZ-SC 11413.98 35.77 2.96 5839.72 5720.87 5933.16 -6949.66 5976203.77 491996.52 MWD+IFR-AK-CAZ-SC ~ 11443.34 35.36 3.18 5863.61 5744.76 5950.21 -6948.74 5976220.82 491997.44 MWD+IFR-AK-CAZ-SC 11478.85 35.00 3.61 5892.63 5773.78 5970.64 -6947.53 5976241.25 491998.65 MWD+IFR-AK-CAZ-SC , i 11506.70 34.69 3.04 5915.49 5796.64 5986.52 -6946.61 5976257.13 491999.58 MWD+IFR-AK-CAZ-SC ~ 11542.16 33.99 3.63 5944.77 5825.92 6006.49 -6945.45 5976277.10 492000.74 MWD+IFR-AK-CAZ-SC f 11570,83 33.81 2.91 5968.56 5849.71 6022.45 -6944.53 5976293.06 492001.66 MWD+IFR-AK-CAZ-SC ~ 11600.76 33.43 3.36 5993.49 5874.64 6039.00 -6943.63 5976309.60 492002.57 MWD+IFR-AK-CAZ-SC Halliburton Compan~ Survey Report (~nn~p:~n~: C~~~nocoPhilliosAlaska Inc. 1)atc: ~%2i~OCr lin~~ ~: 11:59'13 Pac: -~ Ficl~l: Kuparuk River Unit Cu-urdinau~lAI.) Kcfcrence: Well_ 2T-40 l rue North tiitc: K!iparuk 2T Pad ~~crtical (l~U) llcfcrcnre: 2T 40 113.9 ~~cll: 2T-40 Sec~iun 1~~1 Rcftrcncc Well i0 00N.0 00E.~10A4Azi1 11cll~r:uh: 2T-40 dune} (alcnlaliun ~Icduxl: Minimum Cu[vatUre ~ I)h: Oracle tiunc~ III) incl ~iim Ill) 5~~~ Il'i) \1ti 1~:~1 ~Is~iA ~IapF. l~i~il ft deg deg ft ft ft ft ft ft SC B K 11661.00 33.14 3.00 6043.90 ~ 5925.05 JECT D to D 6071.94 -6941.86 5976342.54 - 492004.34 P O C • 09-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 2T-40 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 41.05' MD Window /Kickoff Survey: 11,624.78' MD (if applicable) Projected Survey: 11,661.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed ~ V Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) '~E~~,IVED JUN 2 7 2006 ~-& `~`~ ~. ~ b - o ~~ Scht~n6erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ '~~~~32~i?6 . * ~1 ~~- _l~,i NO. 3858 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 06/22/06 1F-O6 11249918 PRODUCTION PROFILE W/DEFT O6/13/O6 1 1F-20 11320984 PRODUCTION PROFILE W/DEFT 06/12/06 1 1A-15 11249917 INJECTION PROFILE O6/12/06 1 2T-40 11249919 SCMT 06/14/06 1 2M-20 11235372 PRODUCTION PROFILE 06/18/06 1 3G-12 11320978 INJECTION PROFILE 06/01/06 1 1Y-27 11235341 PRODUCTION PROFILE WIDEFT 02/26/06 1 3M-21 11213734 INJECTION PROFILE 04/04/06 1 2Z-12A 11216199 MEMORY PRODUCTION PROFILE 06/04106 1 1A-22 11213761 PRODUCTION PROFILE WIDEFT 06/15/06 1 Please sign and return one copy of this transmittal to Beth a the above address or fax to (907) 561-8317. Thank you. ,o G • ~ • ~~ ~~ ~ ~~ ~,d ") ~ '®' ~ ~ 9 ""~, ~,~ ~ ~'~ ~ FRANK H. MURKOWSKI GOVERNOR ~ tam ~r ~ ~+ ~~A ~~ ~ ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERVA'1'IOIY CUhil-IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 1 PHONE (907) 279-1433 Randy Thomas FAx (so7) 27s-7sa2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk Oil Pool, 2T-40 ConocoPhillips Alaska, Inc. Permit No: 206-040 Surface Location: 290' FSL, 556' FWL, SEC. 1, T11N, R08E, UM Bottomhole Location: 984' FSL, 4171' FWL, SEC. 34, T12N, R08E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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 Gode 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. When providing notice for a representative of the Commission to witness any equired test, contact the Commission's petroleum field inspector at~907) 6~~607 (pager). N DATED this ~ day of March, 2006 C cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~3 RECEDED ~~~ MAR 2 0 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oii & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil Q Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2T-40 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Propo ~ dDe tfi: ~ y/.r(~~r~~ MD 5;,28 TVD: X88`' 12. Field/Pool(s): Kuparuk River~r Field ~~' 4a. Location of Well (Governmental Section): Surface: 290' FSL, 556' FWL, Sec. 1, T11N, R08E, UM ' 7. Property Designation: x~~~ ADL 25569 &~,5~tt3'~S~.zl'` y~!~~..,~Y~ ~C~~'Garn `.' ~~ pia. it Pool `~,~-~' Top of Productive Horizon: 927' FSL, 4171' FWL, Sec. 34, T12N, RO8E, UM 8. Land Use Permit: ALK 2667 & 2662 13. Approximate Spud Date: 3/ 6 yl3.0 ~ Total Dept :,• ~ 3 Lr"'4 ~SL, 4171' FWL, Sec. 34, T12N, R08E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: <3 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498945 ~ y- 5970270 • Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest Well within Pool: 2T-07 , 13.38' @ 350' 16. Deviated wells: Kickoff depth: 300' ~ ft. Maximum Hole Angle: 66° ' deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4000 psig Surtace: 3364 psig 18. Casing Program Setting Depth Quantity of Cement Size SpeCiflcations Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.6# H-40 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 12-1/4" 9-5/8" 40# L-80 BTC 8032' 40' 40' 8072' • 4100' ~ 580 sx AS Lite, 770 sx DeepCRETE 8-1 /2" 7" 26# L-80 BTCM 11,381' 40' 40' 11,421' 5796' 170 sx Class G 6-1/8" 3-1/2" 9.3# L-80 8RD EUE 265 11,294 5692 11,559 - 5916' ~ 70 sx GasBlok 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike A. Winfree @ 265-6820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ Phone LAS ~,3Tc~ Date •3 /Lo~aS P ared b Mike A. Winfre Commission Use Only Permit to Drill 7 f Number: ~~[p ` ©~Zj API Number: ~ ~y 50- ~ba ' ~,,~l~i "G~ Permit Approval Date: •~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbe etha e, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ N ~ Mud log req'd: Yes ^ No [•~ Other: ~j~~S~ ~\r~~o~~~~Q~?~T' H2Smeasures: s [v]° o Directionalsvyreq'd: Yes []'" No ^ 3~ w , /' /~ APPROVED BY THE COMMISSION +v1,_/`II/ ~ IY//7 ,COMMISSIONER Form 10-401 Revised 12/2005 ~ s ~ `~ ~ ~,; E °~ ~`~ ~ V ~„/ ! ~,/~abmit in Duplicate Permit It - Kuparuk Well 2T-40 Application for Permit to Drill Document ~~~~~ M p x i m i x E 1A1~11 tilglyE Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ...................................................... ............................................ 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ....................................................... ............................................ 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ....................................................... ............................................ 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ....................................................... ............................................ 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ...................................................... ............................................ 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .................................................... ............................................ 5 11. Seabed Condition Analysis ................................................. .................................... 5 Requirements of 20 AAC 25.005 (c)(11) .................................................... ............................................ 5 12. Evidence of Bonding ........................................................... .................................... 5 Requirements of 20 AAC 25.005 (c)(12) .................................................... ............................................ 5 13. Proposed Drilling Program ................................................. .................................... 6 Requirements of 20 AAC 25.005 (c)(13) .................................................... ............................................ 6 ORtG1NAL ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 ~~ 2T-40 PERMIT IT Page 1 of 7 Printed: 18-Mar-06 • ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plan ...................................................................................................,........... 7 Attachment 2 Drilling Hazards Summary .............................................................................................. 7 Attachment 3 Well Schematic ......................................................:........................................................ 7 Attachment 4 Cement Summary ........................................................................................................... 7 Attachment 5 Diverter Placement Drawing ........................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2T-40. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 290' FSL, 556' FWL, Sec 1, T11N, R08E UM NGS Coordinates RKB Elevation 117.8' AMSL Northings: 5,970,270.23 Eastings: 498,944.65 Pad Elevation 77.8' AMSL Location at Top of 927' FSL, 4171' FWL, Sec 34, T12N, R8E, UM Productive Interval Ku aruk "C4" Sand NGS Coordinates Measured De th, RKB: 11,444' Northings: 5,976,190 Eastings: 491,998 Total Vertical De th, RKB: 5916' Total Vertical De th, SS: 5698' Location at Total De th 984' FSL, 4171' FWL, Sec 34 T12N, R8E, UM NGS Coordinates Measured De th, RKB: 11 559' Northings: 5,971,026 Eastings: 489,578 Total Vertical De th, RKB: 5916' - Total Vertical De th, SS: 5798' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-40i) must (i) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and ORIGINAL 2T-40 PERMIT IT Page 2 of 7 Printed: 18-Mar-O6 ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 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 following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Offset well data indicates a max BHP of 4000 psi at 5800' TVD for the 2T-40 location. Equivalent Mud Weight @TD = 4000 psi =13.3ppg 5800'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 2T-40 is calculated using the predicted 4000 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an A2 TVD of 5800'. MPSP = ~GradientMua - Gradient~as ~'I'VD GradientMua =13.3 ppg x 0.052 = 0.69 f l t Gradient~aS = 0.11 f l t TVD = 5800 ft MPSP = 0.69 psr - 0.11 psr 5800 ft = 3364psi ft ft (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 2T-40 PERMIT IT Page 3 of 7 /~ ~ Printed: 18-Mar-O6 • ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Drill out surtace and intermediate casing shoe and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft Cement Program 16 24 62.5 H-40 Welded 80' 40'/40" 120'/120' 260 sx 15.8 ppg AS1 Lead: 580 sx 10.7 ppg AS Lite 9-5/8 12-1/4 40.0 L-80 BTC 8032' 40'/40' 8072'/4100' Tail: 770 sx 12.0 ppg LiteCRETE Planned TOC=Surface 170 sx 15.8 ppg 'G' w/ 7 8-1/2 26.0 L-80 BTC 11,381' 40'/40' 11,421'/5796' additives. Planned TOC=10,421' EUE 8rd 294' / 11 ' ' 70 sx 15.8 ppg 3-1/2 6-1/8 9.3 L-80 Mod 265' , 5692, /5916 11,559 GASBLOK w/ add. Planned TOC=11,071' 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 15. 2T-40 PERMIT IT Page 4 of 7 Printed: 18-Mar-06 ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) . An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface Interval Intermediate Interval Production Interval Mud T e S ud Mud LSND LSND Densi 8.5-9.5 9.5-10 12.0 c-G. Funnel Viscosi sec 60-250* 35-41 45-55 Yield Point cP 30-50 24-30 23-28 Plastic Viscosi Ib/100 s 20-60 10-18 14-22 10 sec. Gel Ib/100 s 10-30 3-10 3-7 API Filtrate cc NC-8 <6 4-6 H 8.5-9 9-9.5 9-9.5 Solids % +10 < 11% < 4% *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. h~ 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i2) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. ORIGINAL 2T-40 PERMIT IT Page 5 of 7 Printed: 18-Mar-06 ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 15 on 2T-40 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (8072' MD/ 4100' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job or stage job with port collar (installed +/- 1000') if required to bring cement to surface.. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to 5000 psi. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. RIH clean out to float collar 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. ~ 10. Directionally drill 8-1/2"" hole to 11,421 MD/ 5796' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 11. Run 7" 26# L-80 BTCM casing and cement. 12. Install packoff test BOPE 13. RIH clean out to float collar 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 15. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. , 16. Directionally drill 6-1/8" hole to TD (11,559' MD/ 5916' TVD) according to directional plan. 17. Run 3-1/2"" 9.3# L-80 EUE 8RD MOD liner and Baker ZXP hanger/Packer assembly. Pump cement followed by DP wiper plug and brine displacement fluid. Set packer 150' above intermediate casing shoe to provide appropriate liner lap. Reverse out. 18. Shut in BOP's and pressure test casing and liner to 3000 psi per AOGCC regulations. Record results 19. Run and land 3-1/2" completion tubing string and pressure test to 3000 psi. Record results. 20. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 21. Freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 22. Clean location and RDMO. 23. MIRU Coil or E-Line, perforate well 24. RU Dowell, frac well. 25. RD Dowell, secure well, handover to production 2T-40 PERMIT /T Page 6 of 7 ~ R I G~ N A L. Printed: 18-Mar-06 . ,, ~ation for Permit to Drill, Well 2T-40 Saved: 18-Mar-06 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary Attachment 5 Diverter Placement Drawing 2T-40 PERMIT lT Page 7 of 7 f ^ ~ ~ n ( Printed: 18-Mar-O6 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk} Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-40 -Slot 2T-40 Plan: 2T- 40 (wp06) Proposal Report 09 March, 2006 • At~~.1~l Sperry Dr~l~in+g ~erviGes ORIGINAL Q HALLIBtJRTON ~.' CASING DETAILS 5 SHL @ 290ft FSL & 556ft FWL -Sec 1 - T11 N - R08E sp..r,, DrH11n0 s.rr+o.. ConocoPl'lillips Alaska No ND MD Name Size " 1 4099 80 8071.93 9 5/8" 9-5/8 ~---~ -'" 2 5795.8011420.83 7" 7 0 , - ' " " 3 5915.7911559.38 3.5 3-1/2 V J ~+~' Build @ 2.5°/100ft to 10° lint - 300ft MD, 300 ft ND 0°- - - FORMATION TOP DETAILS ~75 Continue Build @ 4°/100ft , 700ft MD, 698ft ND No. NDPath NDSS MDPath Formation e~~ q0°- - - - - - 939ft ND ti B ild 5°/100ft 950ft MD C 1 1517.80 1400 1707.00 Base of Permafrost 1 @ , on nue u , 2 2253.80 2136 3445.06 Top of W.Sak 950 2Q------------- ° 3 2667.80 2550 4482.89 Base W.Sak ~0 4 3037.80 2920 5410.41 C-80 Sail @ 56° Inc : 1675ft M ~p D, 1500ft ND 5 3057.80 2940 5460.52 Tabasco - ° o _ - - - - - - 6 4567.80 4450 9244.80 C-40 1425 h _ _ _ _ y`4 ~- - - - - Continue Build @ 5 °/100ft , 1875ft MD, 1611ft ND 7 5157.80 5040 10589.47 Top Moraine _ - - - - - - - - - - - - - - ro ° 8 5447.80 5330 11000.23 Top HRZ - - _ _ ' ---- 9 5635.80 5518 11232.98 Base HRZ , ----------------------- Base of Permafrost - - Sail @ 66.5° Inc : 2080ft MD, 1709ft ND 10 5745.80 5628 11362.83 K-1 1900 ~ 11 5815.80 5698 11443.92 C-4 (Top Kuparuk 12 5825.80 5708 11455.47 A-3 -- _ Top of W.Sak - - _ _ ro`O =--------------------- Begin Turn @ 3°/100ft, 5360ft MD, 3018ft ND 13 5830.80 14 5882.80 5713 11461.24 5765 11521.29 A-2 A-1 2375 Base W.Sak o ~ _ _ ___--- n 2850 Tobacco ~~ °' o - ' " -'" ~ ~ 2T-40 'i---------------------- Tabasco Hard line U ' ' - _ _ j 3325 c-ao Project: Kuparuk River Unit Site: Kuparuk 2T Pad _ _ - - - - - - - Sail @ 66.5°Inc 2T 40 & 307.32°Azi : 5457ft MD, 3056ft ND ~ Well: PIan:2T-40 ~avaos ~ ` 3800 Wellbore: Plan 2T-40 O Plan: 2T- 40 (wp06) ------------'e 4275 9 5/8" CSG @ 8072ft MD, 4100ft ND --------------------------------- Drop/Tum@4°/100ftto30°Inc80.0°Azi:10135ftMD,4923ft ND -------- - -- 4750 Top Moraine - - - _ _ _ 'rbpHRZ 7"CSG@11421ftMD,5796ftND --__ _ --------- __ - h~ 5225 ------~'-- ---------------------- --- Sail 30° Inc : 11421ft MD, 5796ft ND -' - - - _ o 5700 ~~ ~ ~ -~ -, _, - ` ~ ' - - _ - ~ Top Kuparuk - 11444ft MD, 5916ft ND - _ _ - - -' " ___ 6175 _, '~_ 2T-40 Geo-Paly __- 2T-40 DD Poly @ 95% 3.5 A-1 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 9025 Vertical Section at 310.44° (950 ft/in) 0 ~ ~ O$ y f r n nr.. 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I I I W I - O c a ~ V m C/ I 1 m l o ~. ~ n I I p Y e ~ \ N i+ b ~ 1 bo 0 b /K O O \ O O N~ T I A v O N A M ~p~~ \ ~ ~ I - N ~ ~ ~rfl ~~e V \ L °y/ G c I C N f A p 6 N \ e`Of ' `, ~ C b o N r2 O U \ ~ 7 A N O •~ v ~ e ~ \~ m' ~ g ~ m ~ ~ a ~ ~ d v m Y I N ~ E C C ° 7 m '~ I c n. c n ~ ~ Y I ~ I~ O U ~ o c o 0 1 W I~ f~1 m U N ~ I U 1- I d I ~ I y ~ c 1 I I I I I I p I I I ~ U N I I I I ~ I I 1 I i I I I I ~ I I I I a I I I i o I I I I (~ RS =M dc~ooo o d I I I I om LL mr oo O c I I I i ii~ zN ~v°m~~ ~ I I I_ a ~~ ~~~~~ Z'.~ N I I I ~ O m`n ~~ m I II e0 oZ ~~Q ~_ EJ III r .~ ~ ~ mao~ E ~ o III 4°0~„ ~ \ ~. 5 c °~~' o ~ ~ ~ n m _~ ~ V ~~ ~ ~ / ` ~ ~ ~ >+ Q / ~ N / // O 1; ~~ 0 Y U = h L~J r 0 an m r` 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N O N O N O N O ~ O ~ O N a0 'cf O) N O O r N a0 CI O 7 N N ~ ~ d' fh c7 N N ~ ~ ~u!/31006) ~+)43~oN/~-)43~oS Hf~iC.LIBl.3RTQlfV Project: K~ rukRiverUnit Well: Plan-40 '~'"r -----~Ii~~n-- ~~~-- Site: Kuparuk 2T Pad Wellbore: Plan 2T-40 COnE~CV!P[~~Ili~?S '~ Plan: 2T- 40 (wp06) Alaska ANNOTATIONS TVD TVDss MD 40.01 -77.79 40.01 300.01 182.21 300.01 697.97 580.17 700.00 939.15 821.35 950.00 1499.80 1382 1674.61 1610.97 1493.17 1874.61 1709.19 1591.39 2079.80 3017.80 2900 5360.29 3056.22 2938.42 5456.56 4099.80 3982 8071.93 4922.93 4805.13 10134.82 5795.80 5678 11420.83 5795.80 5678 11420.83 5815.80 5698 11443.92 5915.79 5797.99 11559.38 FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1517.80 1400 1707.00 Base of Permafrost 2 2253.80 2136 3445.06 Top of W.Sak 3 2667.80 2550 4482.89 Base W.Sak 4 3037.80 2920 5410.41 C-80 5 3057.80 2940 5460.52 Tobasco 6 4567.80 4450 9244.80 C-40 7 5157.80 504010589.47 Top Moraine 8 5447.80 5330 11000.23 Top HRZ 9 5635.80 5518 11232.98 Base HRZ 10 5745.80 562811362.83 K-1 11 5815.80 5698 11443.92 C-4 (Top Kuparuk) 12 5825.80 570811455.47 A-3 13 5830.80 571311461.24 A-2 14 5882.80 576511521.29 A-1 CASING DETAILS No MD TVD TVDss Name Size 1 8071.93 4099.80 3982 9 5/8" 9-5/8 2 11420.83 5795.80 5678 7" 7 3 11559.38 5915.79 5797.99 3.5 3-1 /2 Annotation SHL @ 290ft FSL 8~ 556ft FWL -Sec 1 - T11 N - R08E Build @ 2.5°/100ft to 10° lint - 300ft MD, 300 ft TVD Continue Build @ 4°/100ft , 700ft MD, 698ft TVD Continue Build @ 5°/100ft , 950ft MD, 939ft TVD Sail @ 56° Inc : 1675ft MD, 1500ft TVD Continue Build @ 5°/100ft , 1875ft MD, 1611ft TVD Sail @ 66.5° Inc : 2080ft MD, 1709ft TVD Begin Turn @ 3°/100ft, 5360ft MD, 3018ft TVD Sail @ 66.5°Inc Si 307.32°Azi : 5457ft MD, 3056ft TVD 9 5/8" CSG @ 8072ft MD, 4100ft TVD : 4322ft FSL 8~ 898ft FWL -Sec 2 - T11 N - R08E Drop/Turn @ 4°/100ft to 30°Inc & 0.0° Azi : 10135ft MD, 4923ft TVD 7" CSG @ 11421ft MD, 5796ft TVD Sail @ 30° Inc : 11421ft MD, 5796ft TVD Top Kuparuk -11444ft MD, 5916ft TVD 927ft FSL ~ 4171ft FWL -Sec 34 - T12N - R~ TD @ 11559ft MD, 5916ft TVD 984ft FSL 8< 4171ft FWL -Sec 34 - T12N - R08E Critical Issues 1. Build Rates in Surface Hole are Critical for Collision Avoidance as well as avoidance of depleted Tabasco main sand 2. May encounter thin depleted sand (10' thick) @ approximately 5458ft MD. 3. Offset Wells 2T-07 & 2T-06 will be shut-in during drilling operations. 4. Planned Topset above the Kuparuk @ approximately 11420ft MD. t MALLlBI.IMRT~N Project: K ruk River Unit Well: Plan. -40 - -~- Site: Kuparuk 2T Pad Wellbore: Plan 2T-40 ~OCtE?CtJ~'1~~~1~}S Spsrry Elrit~n9 5srvi~s Plan: 2T- 40 (wp06) Alaska WELLBORE TARGET DETAILS Name TVD TVDss +N/-S +EI-W Northing Easting Shape 2T-40 DD Poly @ 95% 5818.66 5700.86 5921.38 -6948.18 5976192.00 491998.00 Polygon -Point 0 51.50 5.43 5976243.49 492003.44 - Point 1 47.24 15.28 5976239.23 492013.29 - Point 2 42.70 24.03 5976234.69 492022.03 - Point 3 37.69 32.13 5976229.68 492030.13 - Point 4 31.94 39.88 5976223.93 492037.88 - Point 5 25.21 47.63 5976217.20 492045.63 - Point 6 17.05 55.70 5976209.04 492053.70 - Point 7 6.67 63.85 5976198.66 492061.84 - Point 8 -6.70 71.76 5976185.29 492069.75 - Point 9 -23.43 77.49 5976168.56 492075.48 - Point 10 -41.40 76.75 5976150.59 492074.74 - Point 11 -55.43 66.73 5976136.57 492064.72 - Point 12 -62.19 50.58 5976129.81 492048.57 - Point 13 -62.81 33.49 5976129.19 492031.48 - Point 14 -60.24 18.33 5976131.76 492016.32 - Point 15 -56.31 5.44 5976135.69 492003.43 - Point 16 -51.53 -5.66 5976140.48 491992.33 - Point 17 -46.17 -15.46 5976145.84 491982.54 - Point 18 -40.28 -24.40 5976151.73 491973.60 - Point 19 -33.66 -32.79 5976158.35 491965.21 - Point 20 -26.05 -40.89 5976165.96 491957.11 - Point 21 -17.06 -48.86 5976174.95 491949.14 - Point 22 -6.10 -56.51 5976185.91 491941.49 - Point 23 7.42 -63.36 5976199.43 491934.65 - Point 24 23.57 -67.23 5976215.58 491930.78 - Point 25 40.16 -64.44 5976232.17 491933.57 - Point 26 52.49 -52.97 5976244.49 491945.04 - Point 27 57.74 -36.42 5976249.74 491961.59 - Point 28 57.72 -20.08 5976249.72 491977.93 - Point 29 55.11 -6.14 5976247.11 491991.87 - Point 30 51.50 5.43 5976243.49 492003.44 2T-40 Geo-Poly 5818.66 5700.86 5921.38 -6948.18 5976192.00 491998.00 Circle (Radius: 150.0 ) 2T-40 Tabasco Hardline 3017.80 2900 3579.74 -2730.43 5973850.00 496215.00 Polygon - Point 0 0.00 0.00 5973850.00 496215.00 - Point 1 -1180.20 -374.90 5972669.97 495839.97 ORIGINAL ~'` Halliburton Energy Services ~~~i8~~~-~ COt'tOC©~"11~111~35 Planning Report -Geographic ~ - Alaska Database: EDM 2003.11 Singfe User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: PIan:2T-40 Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) 3perryt t1r{I{{ng Services Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 TVD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Ptan: 2T-40 -Slot 2T-40 Well Position +N/-S 0.00 ft Northing: 5,970,270.23ft Latitude: +E/-W 0.00 ft Easting: 498,944.65 ft Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70° 19' 48.025" N 150° 00' 30.815" W 77.80 ft _- - Welibore Plan 2T-40 -- _- Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 3/15/2006 23.9281 80.7603 57,546 Design - _ 2T- 40 (wp06) _ Audit Notes: Version: 4 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 40.00 0.00 0.00 310.44 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) ({{) (ft) (°1100ft) (°/100ft) (°/100ft) (°) 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.0000 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.0000 700.00 10.00 310.44 697.97 22.58 -26.50 2.50 2.50 0.00 310.4400 950.00 20.00 310.44 939.15 64.50 -75.68 4.00 4.00 0.00 0.0000 1,674.61 56.23 310.44 1,499.80 349.81 -410.45 5.00 5.00 0.00 0.0000 1,874.61 56.23 310.44 1,610.97 457.65 -536.98 0.00 0.00 0.00 0.0000 2,079.80 66.49 310.44 1,709.19 574.31 -673.86 5.00 5.00 0.00 0.0000 5,360.28 66.49 310.44 3,017.80 2,525.56 -2,963.33 0.00 0.00 0.00 0.0000 5,456.55 66.48 307.29 3,056.22 2,580.95 -3,032.06 3.00 -0.01 -3.27 -90.7647 10,134.81 66.48 307.29 4,922.93 5,179.88 -6,444.83 0.00 0.00 0.00 0.0000 11,420.83 30.00 0.00 5,795.80 5,908.18 -6,948.18 4.00 -2.84 4.10 149.4224 11,447.23 30.00 0.00 5,818.66 5,921.38 -6,948.18 0.00 0.00 0.00 0.0000 11,559.39 30.00 0.00 5,915.80 5,977.47 -6,948.18 0.00 0.00 0.00 0.0000 3/92006 5:04:OOPM Page 2 of 8 COMPASS 2003.11 Build 50 ~~~~.~ '' ~ Halliburton Energy Services ~ HAE.LrBI.,~R'TC3i1 -~~~~'~'~~~~~ Planning Report -Geographic S~Ry Drilling Services Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk} Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: PIan:2T-40 Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) Planned Survey 2T- 40 (wp06) Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 ND Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) North Reference: True Survey Calculation Method: Minimum Curvature MD Inclination Azimuth ND SSND (ft) (°) (°) (ft) Ift) 40.00 0.00 0.00 40.00 -77.80 SHL @ 290ft FSL & 556ft FWL -S ec 1 - T11 N - RO8E 100.00 0.00 0.00 100.00 -17.80 200.00 0.00 0.00 200.00 82.20 300.00 0.00 0.00 300.00 182.20 Build @ 2. 5°/100ft to 10° linc - 300ft MD, 300 ft ND 400.00 2.50 310.44 399.97 282.17 500.00 5.00 310.44 499.75 381.95 600.00 7.50 310.44 599.14 481.34 700.00 10.00 310.44 697.97 580.17 Continue Build @ 4°/1 00ft , 700ft MD, 698ft ND 800.00 14.00 310.44 795.77 677.97 900.00 18.00 310.44 891.87 774.07 950.00 20.00 310.44 939.15 821.35 Continue Build @ 5°/1 00ft , 950ft MD, 939ft ND 1,000.00 22.50 310.44 985.74 867.94 1,100.00 27.50 310.44 1,076.35 958.55 1,200.00 32.50 310.44 1,162.92 1,045.12 1,300.00 37.50 310.44 1,244.81 1,127.01 1,400.00 42.50 310.44 1,321.39 1,203.59 1,500.00 47.50 310.44 1,392.08 1,274.28 1,600.00 52.50 310.44 1,456.34 1,338.54 1,674.61 56.23 310.44 1,499.80 1,382.00 Sail @ 56° Inc : 1675ft MD, 1500ft ND 1,700.00 56.23 310.44 1,513.91 1,396.11 1,707.00 56.23 310.44 1,517.80 1,400.00 Base of Permafrost 1,800.00 56.23 310.44 1,569.50 1,451.70 1,874.61 56.23 310.44 1,610.97 1,493.17 Continue Build @ 5°/100ft , 1875ft MD, 1611ft ND 1,900.00 57.50 310.44 1,624.85 1,507.05 2,000.00 62.50 310.44 1,674.83 1,557.03 2,079.80 66.49 310.44 1,709.19 1,591.39 Sail @ 66.5° Inc : 2080ft MD, 1709ft ND 2,100.00 66.49 310.44 1,717.24 1,599.44 2,200.00 66.49 310.44 1,757.13 1,639.33 2,300.00 66.49 310.44 1,797.02 1,679.22 2,400.00 66.49 310.44 1,836.92 1,719.12 2,500.00 66.49 310.44 1,876.81 1,759.01 2,600.00 66.49 310.44 1,916.70 1,798.90 2,700.00 66.49 310.44 1,956.59 1,838.79 2,800.00 66.49 310.44 1,996.48 1,878.68 2,900.00 66.49 310.44 2,036.37 1,918.57 3,000.00 66.49 310.44 2,076.26 1,958.46 3,100.00 66.49 310.44 2,116.15 1,998.35 3,200.00 66.49 310.44 2,156.04 2,038.24 Map Map +N/-S +E/-W Northing Easting DLSEV Vert Section eft) (ft) (ft) (ftl (°/100ft) (ft) 0.00 0.00 5,970,270.23 ` 498,944.65 0.00 0.00 0.00 0.00 5,970,270.23 498,944.65 0.00 0.00 0.00 0.00 5,970,270.23 498,944.65 0.00 0.00 0.00 0.00 5,970,270.23 498,944.65 0.00 0.00 1.41 -1.66 5,970,271.65 498,942.99 2.50 2.18 5.66 -6.64 5,970,275.89 498,938.01 2.50 8.72 12.72 -14.92 5,970,282.95 498,929.73 2.50 19.61 22.58 -26.50 5,970,292.82 498,918.16 2.50 34.82 36.07 -42.32 5,970,306.30 498,902.34 4.00 55.61 53.94 -63.29 5,970,324.18 498,881.37 4.00 83.16 64.50 -75.68 5,970,334.74 498,868.98 4.00 99.44 76.26 -89.47 5,970,346.49 498,855.20 5.00. 117.56 103.66 -121.63 5,970,373.90 498,823.05 5.00 159.81 136.08 -159.67 5,970,406.32 498,785.01 5.00 209.79 173.28 -203.31 5,970,443.52 498,741.38 5.00 267.13 214.96 -252.22 5,970,485.20 498,692.49 5.00 331.39 260.81 -306.02 5,970,531.06 498,638.70 5.00 402.08 310.48 -364.30 5,970,580.73 498,580.43 5.00 478.66 349.81 -410.45 5,970,620.06 498,534.29 5.00 539.29 363.50 -426.51 5,970,633.75 498,518.24 0.00 560.39 367.27 -430.93 5,970,637.53 498,513.81 0.00 566.21 417.42 -489.78 5,970,687.68 498,454.98 0.00 643.52 457.65 -536.98 5,970,727.91 498,407.79 0.00 705.55 471.44 -553.16 5,970,741.70 498,391.61 5.00 726.81 527.60 -619.05 5,970,797.86 498,325.73 5.00 813.38 574.31 -673.86 5,970,844.58 498,270.94 5.00 885.39 586.32 -687.95 5,970,856.59 498,256.85 0.00 903.91 645.80 -757.75 5,970,916.08 498,187.07 0.00 995.61 705.29 -827.54 5,970,975.56 498,117.30 0.00 1,087.31 764.77 -897.33 5,971,035.05 498,047.52 0.00 1,179.01 824.25 -967.12 5,971,094.53 497,977.74 0.00 1,270.71 883.73 -1,036.91 5,971,154.02 497,907.97 0.00 1,362.41 943.21 -1,106.70 5,971,213.50 497,838.19 0.00 1,454.11 1,002.69 -1,176.49 5,971,272.98 497,768.42 0.00 1,545.81 1,062.17 -1,246.28 5,971,332.47 497,698.64 0.00 1,637.50 1,121.65 -1,316.07 5,971,391.95 497,628.87 0.00 1,729.20 1,181.13 -1,385.86 5,971,451.44 497,559.09 0.00 1,820.90 1,240.61 -1,455.65 5,971,510.92 497,489.32 0.00 .1,912.60 3/9/2006 5:04:OOPM Page 3 of 8 COMPASS 2003.11 Build 50 .~~~I ~_. 4..~,i:` ' ~ ~Ir - ' Halliburton Energy Servic es w,a-e~.~lreulr~'rta~r~l Ct~-1~-CO P1 t1II1 5 Planning Report -Geographic Alaska Sperry Dirllling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-40 -Slot ZT-40 Company: ConocoPhillips Alaska (Kuparu k) ND Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Project: Kuparuk River Unit MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Site: Kuparuk 2T Pad North Reference: True Well: Plan: 2T-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) Planned Survey 2T- 40 (wp06) Map Map MD Inclination Azimuth ND SSND +N/-S +E/_yi/ Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 3,300.00 66.49 310.44 2,195.93 2,078.13 1,300.09 -1,525.44 5,971,570.41 497,419.54 0.00 2,004.30 3,400.00 66.49 310.44 2,235.82 2,118.02 1,359.57 -1,595.24 5,971,629.89 497,349.77 0.00 2,096.00 3,445.06 66.49 310.44 2,253.80 2,136.00 1,386.38 -1,626.68 5,971,656.70 497,318.32 0.00 2,137.32 Top of W.Sak 3,500.00 66.49 310.44 2,275.72 2,157.92 1,419.05 -1,665.03 5,971,689.38 497,279.99 0.00 2,187.70 3,600.00 66.49 310.44 2,315.61 2,197.81 1,478.53 -1,734.82 5,971,748.86 497,210.21 0.00 2,279.40 3,700.00 66.49 310.44 2,355.50 2,237.70 1,538.02 -1,804.61 5,971,808.35 497,140.44 0.00 2,371.10 3,800.00 66.49 310.44 2,395.39 2,277.59 1,597.50 -1,874.40 5,971,867.83 497,070.66 0.00 2,462.80 3,900.00 66.49 310.44 2,435.28 2,317.48 1,656.98 -1,944.19 5,971,927.31 497,000.89 0.00 2,554.50 4,000.00 66.49 310.44 2,475.17 2,357.37 1,716.46 -2,013.98 5,971,986.80 496,931.11 0.00 2,646.19 4,100.00 66.49 310.44 2,515.06 2,397.26 1,775.94 -2,083.77 5,972,046.28 496,861.34 0.00 2,737.89 4,200.00 66.49 310.44 2,554.95 2,437.15 1,835.42 -2,153.56 5,972,105.77 496,791.56 0.00 2,829.59 4,300.00 66.49 310.44 2,594.84 2,477.04 1,894.90 -2,223.35 5,972,165.25 496,721.79 0.00 2,921.29 4,400.00 66.49 310.44 2,634.73 2,516.93 1,954.38 -2,293.14 5,972,224.74 496,652.01 0.00 3,012.99 4,482.89 66.49 310.44 2,667.80 2,550.00 2,003.68 -2,350.99 5,972,274.05 496,594.17 0.00 3,089.00 Base W.Sak 4,500.00 66.49 310.44 2,674.62 2,556.82 2,013.86 -2,362.93 5,972,284.22 496,582.23 0.00 3,104.69 4,600.00 66.49 310.44 2,714.52 2,596.72 2,073.34 -2,432.73 5,972,343.71 496,512.46 0.00 3,196.39 4,700.00 66.49 310.44 2,754.41 2,636.61 2,132.82 -2,502.52 5,972,403.19 496,442.68 0.00 3,288.09 4,800.00 66.49 310.44 2,794.30 2,676.50 2,192.30 -2,572.31 5,972,462.68 436,372.91 0.00 3,379.79 4,900.00 66.49 310.44 2,834.19 2,716.39 2,251.78 -2,642.10 5,972,522.16 496,303.13 0.00 3,471.49 5,000.00 66.49 310.44 2,874.08 2,756.28 2,311.26 -2,711.89 5,972,581.65 496,233.36 0.00 3,563.18 5,100.00 66.49 310.44 2,913.97 2,796.17 2,370.75 -2,781.68 5,972,641.13 496,163.58 0.00 3,654.88 5,200.00 66.49 310.44 2,953.86 2,836.06 2,430.23 -2,851.47 5,972,700.61 496,093.81 0.00 3,746.58 5,300.00 66.49 310.44 2,993.75 2,875.95 2,489.71 -2,921.26 5,972,760.10 496,024.03 0.00 3,838.28 5,360.28 66.49 310.44 3,017.80 2,900.00 2,525.56 -2,963.33 5,972,795.96 495,981.97 0.00 3,893.56 Begin Turn @ 3°/100ft, 5360ft MD, 3018ft ND - 2T-40 Tabasco Hardline 5,400.00 66.48 309.14 3,033.65 2,915.85 2,548.87 -2,991.32 5,972,819.27 495,953.99 3.00 3,929.98 5,410.41 66.48 308.80 3,037.80 2,920.00 2,554.87 -2,998.73 5,972,825.27 495,946.57 3.01 3,939.51 C-80 5,456.55 66.48 307.29 3,056.22 2,938.42 2,580.95 -3,032.06 5,972,851.35 495,913.26 3.00 3,981.79 Sail @ 66.5°Inc & 307.32°Azi : 5457ft MD, 3056ft ND 5,460.52 66.48 307.29 3,057.80 2,940.00 2,583.15 -3,034.95 5,972,853.55 495,910.37 0.00 3,985.42 Tobasco 5,500.00 66.48 307.29 3,073.55 2,955.75 2,605.08 -3,063.75 5,972,875.48 495,881.57 0.00 4,021.57 5,600.00 66.48 307.29 3,113.45 2,995.65 2,660.64 -3,136.70 5,972,931.04 495,808.64 0.00 4,113.12 5,700.00 66.48 307.29 3,153.36 3,035.56 2,716.19 -3,209.65 5,972,986.60 495,735.70 0.00 4,204.68 5,800.00 66.48 307.29 3,193.26 3,075.46 2,771.74 -3,282.60 5,973,042.16 495,662.77 0.00 4,296.23 5,900.00 66.48 307.29 3,233.16 3,115.36 2,827.30 -3,355.55 5,973,097.72 495,589.83 0.00 4,387.79 6,000.00 66.48 307.29 3,273.06 3,155.26 2,882.85 -3,428.50 5,973,153.27 495,516.90 0.00 4,479.35 6,100.00 66.48 307.29 3,312.96 3,195.16 2,938.40 -3,501.45 5,973,208.83 495,443.96 0.00 4,570.90 6,200.00 66.48 307.29 3,352.87 3,235.07 2,993.96 -3,574.40 5,973,264.39 495,371.03 0.00 4,662.46 6,300.00 66.48 307.29 3,392.77 3,274.97 3,049.51 -3,647.35 5,973,319.95 495,298.10 0.00 4,754.01 6,400.00 66.48 307.29 3,432.67 3,314.87 3,105.06 -3,720.30 5,973,375.51 495,225.16 0.00 4,845.57 6,500.00 66.48 307.29 3,472.57 3,354.77 3,160.62 -3,793.25 5,973,431.06 495,152.23 0.00 4,937.13 6,600.00 66.48 307.29 3,512.47 3,394.67 3,216.17 -3,866.20 5,973,486.62 495,079.29 0.00 5,028.68 6,700.00 66.48 307.29 3,552.38 3,434.58 3,271.72 -3,939.15 5,973,542.18 495,006.36 0.00 5,120.24 3/9/2006 5:04:OOPM Page 4 of 8 COMPASS 2003.11 Build 50 ®R~Gi~AL '" ~ ~ ~ Halliburton Energy Servic es HALt~.tBURTf~N Cancaco Pl~~[hps Planning Report -Geographic -- ~- -~ - ,4laska Sorry ©rilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Project: Kuparuk River Unit MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Site: Kuparuk 2T Pad North Reference: True Well: Plan: 2T-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) Planned Survey 2T- 40 (wp06) MD Inclination Azimuth TVD (ft) (°) (°) (ft) Map SSTVD +N/-S +Ei.W Northing (ft) (ft) (ft) (ft) Map Fasting DLSEV Vert Section (ft) (°i100ft) (ft) 6,800.00 66.48 307.29 3,592.28 3,474.48 3,327.28 -4,012.10 5,973,597.74 494,933.42 0.00 5,211.79 6,900.00 66.48 307.29 3,632.18 3,514.38 3,382.83 -4,085.05 5,973,653.30 494,860.49 0.00 5,303.35 7,000.00 66.48 307.29 3,672.08 3,554.28 3,438.38 -4,158.00 5,973,708.86 494,787.55 0.00 5,394.90 7,100.00 66.48 307.29 3,711.98 3,594.18 3,493.94 -4,230.95 5,973,764.41 494,714.62 0.00 5,486.46 7,200.00 66.48 307.29 3,751.88 3,634.08 3,549.49 -4,303.90 5,973,819.97 494,641.68 0.00 5,578.02 7,300.00 66.48 307.29 3,791.79 3,673.99 3,605.04 -4,376.85 5,973,875.53 494,568.75 0.00 5,669.57 7,400.00 66.48 307.29 3,831.69 3,713.89 3,660.60 -4,449.79 5,973,931.09 494,495.82 0.00 5,761.13 7,500.00 66.48 307.29 3,871.59 3,753.79 3,716.15 -4,522.74 5,973,986.65 494,422.88 0.00 5,852.68 7,600.00 66.48 307.29 3,911.49 3,793.69 3,771.70 -4,595.69 5,974,042.20 494,349.95 0.00 5,944.24 7,700.00 66.48 307.29 3,951.39 3,833.59 3,827.26 -4,668.64 5,974,097.76 494,277.01 0.00 6,035.79 7,800.00 66.48 307.29 3,991.30 3,873.50 3,882.81 -4,741.59 5,974,153.32 494,204.08 0.00 6,127.35 7,900.00 66.48 307.29 4,031.20 3,913.40 3,938.36 -4,814.54 5,974,208.88 494,131.14 0.00 6,218.91 8,000.00 66.48 307.29 4,071.10 3,953.30 3,993.92 -4,887.49 5,974,264.44 494,058.21 0.00 6,310.46 8,071.93 66.48 307.29 4,099.80 3,982.00 4,033.88 -4,939.96 5,974,304.40 494,005.75 0.00 6,376.31 9 5/8" CSG @ 8072ft MD, 4100ft TVD : 4322ft FSL 8~ 898ft FWL -Sec 2 - T11 N - RO8E - 9 5/8" 8,100.00 66.48 307.29 4,111.00 3,993.20 4,049.47 -4,960.44 5,974,319.99 493,985.27 0.00 6,402.02 8,200.00 66.48 307.29 4,150.90 4,033.10 4,105.02 -5,033.39 5,974,375.55 493,912.34 0.00 6,493.57 8,300.00 66.48 307.29 4,190.81 4,073.01 4,160.58 -5,106.34 5,974,431.11 493,839.40 0.00 6,585.13 8,400.00 66.48 307.29 4,230.71. 4,112.91 4,216.13 -5,179.29 5,974,486.67 493,766.47 0.00 6,676.68 8,500.00 66.48 307.29 4,270.61 4,152.81 4,271.68 -5,252.24 5,974,542.23 493,693.53 0.00 6,768.24 8,600.00 66.48 307.29 4,310.51 4,192.71 4,327.24 -5,325.19 5,974,597.78 493,620.60 0.00 6,859.80 8,700.00 66.48 307.29 4,350.41 4,232.61 4,382.79 -5,398.14 5,974,653.34 493,547.67 0.00 6,951.35 8,800.00 66.48 307.29 4,390.32 4,272.52 4,438.35 -5,471.09 5,974,708.90 493,474.73 0.00 7,042.91 8,900.00 66.48 307.29 4,430.22 4,312.42 4,493.90 -5,544.04 5,974,764.46 493,401.80 0.00 7,134.46 9,000.00 66.48 307.29 4,470.12 4,352.32 4,549.45 -5,616.99 5,974,820.02 493,328.86 0.00 7,226.02 9,100.00 66.48 307.29 4,510.02 4,392.22 4,605.01 -5,689.94 5,974,875.57 493,255.93 0.00 7,317.57 9,200.00 66.48 307.29 4,549.92 4,432.12 4,660.56 -5,762.89 5,974,931.13 493,182.99 0.00 7,409.13 9,244.80 66.48 307.29 4,567.80 4,450.00 4,685.45 -5,795.57 5,974,956.02 493,150.32 0.00 7,450.15 C-40 9,300.00 66.48 307.29 4,589.82 4,472.02 4,716.11 -5,835.84 5,974,986.69 493,110.06 0.00 7,500.69 9,400.00 66.48 307.29 4,629.73 4,511.93 4,771.67 -5,908.79 5,975,042.25 493,037.12 0.00 7,592.24 9,500.00 66.48 307.29 4,669.63 4,551.83 4,827.22 -5,981.74 5,975,097.81 492,964.19 0.00 7,683.80 9,600.00 66.48 307.29 4,709.53 4,591.73 4,882.77 -6,054.69 5,975,153.37 492,891.25 0.00 7,775.35 9,700.00 66.48 307.29 4,749.43 4,631.63 4,938.33 -6,127.64 5,975,208.92 492,818.32 0.00 7,866.91 9,800.00 66.48 307.29 4,789.33 4,671.53 4,993.88 -6,200.59 5,975,264.48 492,745.38 0.00 7,958.46 9,900.00 66.48 307.29 4,829.24 4,711.44 5,049.43 -6,273.54 5,975,320.04 492,672.45 0.00 8,050.02 10,000.00 66.48 307.29 4,869.14 4,751.34 5,104.99 -6,346.49 5,975,375.60 492,599.52 0.00 8,141.58 10,100.00 66.48 307.29 4,909.04 4,791.24 5,160.54 -6,419.44 5,975,431.16 492,526.58 0.00 8,233.13 10,134.81 66.48 307.29 4,922.93 4,805.13 5,179.88 -6,444.83 5,975,450.50 492,501.19 0.00 8,265.01 DropITurn @ 4°/100ft to 30°Inc & 0.0° Azi : 10135ft MD, 492 3ft TVD 10,200.00 64.25 308.76 4,950.10 4,832.30 5,216.37 -6,491.51 5,975,486.99 492,454.53 4.00 8,324.20 10,300.00 60.84 311.13 4,996.21 4,878.41 5,273.31 -6,559.54 5,975,543.94 492,386.51 4.00 8,412.91 10,400.00 57.49 313.67 5,047.47 4,929.67 5,331.17 -6,622.95 5,975,601.80 492,323.11 4.00 8,498.70 10,500.00 54.18 316.39 5,103.63 4,985.83 5,389.66 -6,681.44 5,975,660.29 492,264.64 4.00 8,581.16 10,589.47 51.28 319.03 5,157.80 5,040.00 5,442.30 -6,729.35 5,975,712.93 492,216.74 4.00 8,651.77 Top Moraine 10,600.00 50.95 319.35 5,164.41 5,046.61 5,448.51 -6,734.71 5,975,719.14 492,211.38 3.98 8,659.87 10,700.00 47.79 322.60 5,229.53 5,111.73 5,507.41 -6,782.52 5,975,778.05 492,163.59 4.00 8,734.47 3AJ/2006 5:04:OOPM Page 5 of 8 COMPASS 2003.11 Build 50 oRa~~~a~ '' ~ Halliburton Energy Services ~ H~L' tguRTCaN ~Clf"1000~11~~1~5 Planning Report -.Geographic - ~~ Alaska Sperry Drilling genricss Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: PIan:2T-40 Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) Planned Survey 2T- 40 (wp06) Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 TVD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) North Reference: True Survey Calculation Method: Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 10,800.00 44.74 326.18 5,298.67 5,180.87 5,566.09 -6,824.62 5,975,836.73 10,900.00 41.81 330.15 5,371.48 5,253.68 5,624.27 -6,860.81 5,975,894.90 11,000.00 39.03 334.60 5,447.62 5,329.82 5,681.65 -6,890.92 5,975,952.28 11,000.23 39.03 334.61 5,447.80 5,330.00 5,681.78 -6,890.98 5,975,952.41 Top HRZ 11,100.00 36.45 339.58 5,526.71 5,408.91 5,737.95 -6,914.80 5,976,008.58 11,200.00 34.10 345.19 5,608.37 5,490.57 5,792.91 -6,932.33 5,976,063.54 11,232.98 33.38 347.19 5,635.80 5,518.00 5,810.70 -6,936.70 5,976,081.32 Base HRZ 11,300.00 32.03 351.47 5,692.20 5,574.40 5,846.26 -6,943.43 5,976,116.88 11,362.83 30.90 355.78 5,745.80 5,628.00 5,878.83 -6,947.08 5,976,149.45 K-1 11,400.00 30.31 358.46 5,777.79 5,659.99 5,897.73 -6,948.04 5,976,168.34 11,420.83 30.00 0.00 5,795.80 5,678.00 5,908.18 -6,948.18 5,976,178.80 7" CSG @ 11421ft MD, 5796ft TVD -Sail @ 30° Inc : 11421ft MD, 5791ift TVD - 7" 11,443.92 30.00 0.00 5,815.80 5,698.00 5,919.73 -6,948.18 5,976,190.35 Top Kupar uk - 11444ft MD, 5916ft TVD 927ft FSL & 4171 ft FWL -Sec 34 - T12N - R08E 11,447.23 30.00 0.00 5,818.66 5,700.86 5,921.38 -6,948.18 5,976,192.00 2T-40 Geo-Poly - 2T-40 DD Poly @ 95% 11,455.47 30.00 0.00 5,825.80 5,708.00 5,925.51 -6,948.18 5,976,196.12 A-3 11,461.24 30.00 0.00 5,830.80 5,713.00 5,928.39 -6,948.18 5,976,199.01 A-2 11,500.00 30.00 0.00 5,864.36 5,746.56 5,947.77 -6,948.18 5,976,218.38 11,521.29 30.00 0.00 5,882.80 5,765.00 5,958.42 -6,948.18 5,976,229.03 A-1 11,559.39 30.00 0.00 5,915.80 5,798.00 5,977.47 -6,948.18 5,976,248.08 TD @ 11559ft MD, 591 6ft TVD 984ft FSL & 4171ft FWL -Sec 34 - T12 N - RO8E - 3.5 Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft) 492,121.50 4.00 8,804.57 492,085.32 4.00 8,869.85 492,055.22 4.00 8,929.99 492,055.16 4.77 8,930.12 492,031.35 4.00 8,984.68 492,013.83 4.00 9,033.68 492,009.46 4.01 9,048.54 492,002.74 4.00 9,076.72 491,999.09 4.00 9,100.64 491,998.14 4.00 9,113.62 491,998.00 4.01 9,120.51 491,998.00 0.00 9,128.00 491,998.00 0.00 9,129.07 491,998.00 0.00 9,131.75 491,998.00 0.00 9,133.62 491,998.00 0.00 9,146.19 491,998.01 0.00 9,153.09 491,998.01 0.00 9,165.45 3/9/2006 5:04:OOPM Page 6 of 8 COMPASS 2003.11 Build 50 ORDINAL ' ~ ~ ~ ' " Halliburton Energy Servic es HALL,.IBUATI©N~1. COt1t?G4 1t~~1~ PE i5 Planning Report -Geographic ---- -- _ _ ~w~ ~_. Alaska Sperry Drill[ng ServFc®s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Project: Kuparuk River Unit MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Site: Kuparuk 2T Pad North Reference: True Well: Plan: 2T-40 Survey Calculation Method: Minimum Curvature Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) Geologic Targets Plan 2T-40 TVD Target Name +N!-S +E!-W Northing Easting ~ (ft) -Shape ft ft (ft) (ft) 5,818.66 2T-40 DD Poly ~ 95% 5,921.38 -6,948.18 5,976,192.00 491,998.00 - Polygon Point 1 5.43 51.50 5,976,243.49 492,003.44 Point 2 15.28 47.24 5,976,239.23 492,013.29 Point 3 24.03 42.70 5,976,234.69 492,022.03 Point 4 32.13 37.69 5,976,229.68 492,030.13 Point 5 39.88 31.94 5,976,223.93 492,037.88 Point 6 47.63 25.21 5,976,217.20 492,045.63 Point 7 55.70 17.05 5,976,209.04 492,053.70 Point 8 63.85 6.67 5,976,198.66 492,061.84 Point 9 71.76 -6.70 5,976,185.29 492,069.75 Point 10 77.49 -23.43 5,976,168.56 492,075.48 Point 11 76.75 -41.40 5,976,150.59 492,074.74 Point 12 66.73 -55.43 5,976,136.57 492,064.72 Point 13 50.58 -62.19 5,976,129.81 492,048.57 Point 14 33.49 -62.81 5,976,129.19 492,031.48 Point 15 18.33 -60.24 5,976,131.76 492,016.32 Point 16 5.44 -56.31 5,976,135.69 492,003.43 Point 17 -5.66 -51.53 5,976,140.48 491,992.33 Point 18 -15.46 -46.17 5,976,145.84 491,982.54 Point 19 -24.40 -40.28 5,976,151.73 491,973.60 Point 20 -32.79 -33.66 5,976,158.35 491,965.21 Point 21 -40.89 -26.05 5,976,165.96 491,957.11 Point 22 -48.86 -17.06 5,976,174.95 491,949.14 Point 23 -56.51 -6.10 5,976,185.91 491,941.49 Point 24 -63.36 7.42 5,976,199.43 491,934.65 Point 25 -67.23 23.57 5,976,215.58 491,930.78 Point 26 -64.44 40.16 5,976,232.17 491,933.57 Point 27 -52.97 52.49 5,976,244.49 491,945.04 Point 28 -36.42 57.74 5,976,249.74 491,961.59 Point 29 -20.08 57.72 5,976,249.72 491,977.93 Point 30 -6.14 55.11 5,976,247.11 491,991.87 Point 31 5.43 51.50 5,976,243.49 492,003.44 3,017.80 2T-40 Tabasco Hardline 3,579.74 -2,730.43 5,973,850.00 496,215.00 - Polygon Point 1 0.00 0.00 5,973,850.00 496,215.00 Point 2 -374.90 -1,180.20 5,972,669.97 495,839.97 5,818.66 2T-40 Geo-Poly 5,921.38 -6,948.18 5,976,192.00 491,998.00 - Circle (radius 150.00) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 8,071.93 4,099.80 9-5/8 12-1 /4 11,420.83 5,795.80 7 8-1/2 11,559.38 5,915.79 3-1l2 6-1/8 3/3/2006 5:04:OOPM Page 7 of 8 COMPASS 2003.118ui1d 50 ~l~i~~L rr~'' ~ Halliburton Energy Services CiJf1000~11~~1~l5 Planning Report -Geographic Database: Alaska EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 2T Pad Well: PIan:2T-40 Wellbore: Plan 2T-40 Design: 2T- 40 (wp06) t-~AL.LIB IJ €~TCI~!'11 Sponry drilling Services __ Local Co-ordinate Reference: Well Plan: 2T-40 -Slot 2T-40 TVD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) MD Reference: Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +NI-E +E/-W (ft) (°) (°) (R) (ft) (ft) Name 1,707.00 56.23 310.44 1,517.80 367.27 -430.93 Base of Permafrost 3,445.06 66.49 310.44 2,253.80 1,386.38 -1,626.68 Top of W.Sak 4,482.89 66.49 310.44 2,667.80 2,003.68 -2,350.99 Base W.Sak 5,410.41 66.48 308.80 3,037.80 2,554.87 -2,998.73 C-80 5,460.52 66.48 307.29 3,057.80 2,583.15 -3,034.95 Tobasco 9,244.80 66.48 307.29 4,567.80 4,685.45 -5,795.57 C-40 10,589.47 51.28 319.03 5,157.80 5,442.30 -6,729.35 Top Moraine 11,000.23 39.03 334.61 5,447.80 5,681.78 -6,890.98 Top HRZ 11,232.98 33.38 347.19 5,635.80 5,810.70 -6,936.70 Base HRZ 11,362.83 30.90 355.78 5,745.80 5,878.83 -6,947.08 K-1 11,443.92 30.00 0.00 5,815.80 5,919.73 -6,948.18 C-4 (Top Kuparuk) 11,455.47 30.00 0.00 5,825.80 5,925.51 -6,948.18 A-3 11,461.24 30.00 0.00 5,830.80 5,928.39 -6,948.18 A-2 11,521.29 30.00 0.00 5,882.80 5,958.42 -6,948.18 A-1 3/92006 5:04:OOPM Page 8 of 8 COMPASS 2003.11 Build 50 o~~~lNa~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 2T Pad Plan: 2T-40 Plan 2T-40 2T- 40 (wp06) Anticollision Report 09 March, 2006 • HA~~ Sperry Qlrillir~g ~elrv~ces ORIGINAL 0 - - , m o ~;, o ~ ~ r ~ ,j C r -~ +~ __ ^o ~ i > > Z c u ~ ~ ~ ~ N ..~ _ O ` ~ '8 EvaioUm ~ e ~' 1C b ~;cmH .. ~ .. uy Ey afi~ ` r ~ ,sue fE~w,o o ~ °~ ~oe'~mmepM~~oe a ~" ~~d~ ~ ~ mn~°~~maaa c3 gaL ~~ o do g 0o e.°.e° a c`~y~ - U °o°o3°e°o°o °o ~n°ea°e °ee c ow`f ~'~ ° ~o eee cue C ~m AW; n ~ r ~ u h ~ O o g b e o 0 0 0 ~ e o e e U J C C tV V Yi G Yi G n C V C C ~ 1 v ~ o I ~ 30 ~~a M4~~ 'o ~ o u7° '° e~m°m yF _ Z + ~Rqh~ ~ N ~ ~ .-. F o w ~o .now m~ W ~o nm~o~vim eo~~na y N ~e eV<^OU^i~C^~C~Ih W rvwNNnn F Oeem ~romem-m NTa°Dbw ~~ '. I 7 z°One"am°n „o °naNNN c~ ~ ~ m J O yy pp yy y N ' III ~ ~ o o O V d~~<~~ O O L I 7 m I ~ oenrommmmeee a ° ° O1 ~' -eeoo.~uem~'ueoooo mt~n ~ N M V .-non .n ~eum~unesr Q ~ Cp Dep N C ~ 0 0 o e m b m N yu~~i m o N n ~ J a R ~~~ N ~ ~ N N N~ n~ N J _ F me.oo e~n~ Lu J ^ ui~e. '.aw~onwm.-.-.-~ a c rnw o « i° °o ? o ~`g ~ t") N d ~ ° O D0 ~ N C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O N O~ O if1 O~ 0 0 0 0 0 0 0 (O O ~ N O~ O~ N I~ O N N I~ O O O O O O O ~ N~ I~ r ~ ~ N N N N fh V~ N r OD O ~ 2 C N ! 2 N ' O N U I I it I I I ~ I I I I I O F N N ~ II ~ R H O u0'~ O N O~ O~ O~ 0 0 0 0 0 0 0 3 o O N N I~ O N u"i ~ N N N N fO') V u0'1 t00 OI` Om m I~' G N \ r .- r + I I N ~ p~j 1 I ~ _ \ 1 I 3 ~ ~ N 4 e ~ / \ I N O W _ I N N O O 1 I ~ O^ O N / / ~ t. % ~ N N _ ~oi~e ~ ~ ~ y ~/ L h \ ~_ ~ ~ R yU' _~°n °a i ~ i ~ d o e 3 / ~ N ~ z .' 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N CO O 1- U ., w ConocoPhillips Alaska Company.: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 2T Pad Site Error: O.OOft Reference Well: Plan: 2T-40 Well Error: O.OOft Reference Wellbore Pfan 2T-40 Reference Design: 2T- 40 (wp06) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • HALLtBURTON Spelrry Drilling Services Well Plan: 2T-40 -Slot 2T-40 Planned 2T-40 @ 117.80ft (Doyon 1 S (77.8+40)) Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 2T- 40 (wp08) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval SO.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,351.94ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma ~ Survey Tool Program Date 3/9!2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 1,000.00 2T- 40 (wp06) (Pfan 2T-40) CB-GYRO-SS Camera based gyro single shot 1,000.00 11,558.86 2T- 40 (wp06) (Plan 2T-40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/9/2006 4:34:56PM Page 2 of 4 COMPASS 2003.11 Build 50 / ~ Haiiiburton Energy Services ConocoPhillips Anticollision Report Alaska Company; ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 2T Pad MD Reference: Site Error: O.DOft North Reference: Reference WeII: Plan: 2T-40 Survey Calculation Method: Weli Error: O.OOft Output errors are at Reference Wellbore Plan 2T-40 Database: Reference Design: 2T- 40 (wp06) Offset ND Reference: • HALLt'BURTQN Sperry Qrilling Services Well Plan: 2T-40 -Slot 2T-40 Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) Planned 2T-40 @ 117.80ft (Doyon 15 (77.8+40)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 2T Pad 2T-02 - 2T-02 - 2T-02 1,379.04 1,350.00 95.50 30.70 64.87 Pass -Major Risk 2T-03 - 2T-03 - 2T-03 853.57 850.00 68.00 18.50 49.52 Pass -Major Risk 2T-04 - 2T-04 - 2T-04 900.68 900.00 43.00 24.18 19.06 Pass -Major Risk 2T-OS - 2T-OS - 2T-OS 851.78 650.00 30.94 11.72 19.22 Pass -Major Risk 2T-06 - 2T-06 - 2T-06 451.00 450.00 15.72 8.96 6.76 Pass -Major Risk 2T-07 - 2T-07 - 2T-07 350.57 350.00 13.38 7.87 5.51 Pass -Major Risk 2T-08 - 2T-08 - 2T-08 400.00 400.00 38.97 7.51 31.46 Pass -Major Risk 2T-09 - 2T-09 - 2T-09 349.89 350.00 63.17 6.36 56.82 Pass -Major Risk 2T-10 - 2T-10 - 2T-10 348.85 350.00 139.09 7.10 131.99 Pass -Major Risk 2T-11 - 2T-11 - 2T-11 348.55 350.00 162.63 6.39 156.23 Pass -Major Risk 2T-12 - 2T-12 - 2T-12 443.02 450.00 188.58 9.18 179.40 Pass -Major Risk 2T-12A - 2T-12A - 2T-12A 395.68 400.00 187.19 8.30 178.90 Pass -Major Risk 2T-13 - 2T-13 - 2T-13 347.90 350.00 213.23 6.77 206.46 Pass -Major Risk 2T-14 - 2T-14 - 2T-14 394.42 400.00 237.61 7.03 230.58 Pass -Major Risk 2T-201 - 2T-201 - 2T-201 295.77 300.00 51.21 5.09 46.12 Pass -Major Risk 2T-202 - 2T-202 - 2T-202 821.62 800.00 163.48 15.91 148.08 Pass -Major Risk 2T-203 - 2T-203 - 2T-203 Rig Surveys 1,424.43 1,300.00 309.09 29.60 279.83 Pass -Major Risk 2T-207 - 2T-207 - 2T-207 1,440.89 1,350.00 152.26 36.07 124.75 Pass -Major Risk 2T-208 - 2T-208 - 2T-208 1,286.40 1,150.00 358.03 26.61 331.89 Pass -Major Risk 2T-208 - 2T-208PB1 - 2T-208 P61 1,286.40 1,150.00 358.03 26.45 332.05 Pass -Major Risk 2T-208 - 2T-208PB2 - 2T-208 PB2 1,286.40 1,150.00 358.03 26.45 332.05 Pass -Major Risk 2T-208 - 2T-208PB3 - 2T-208PB3 1,286.40 1,150.00 358.03 26.61 331.89 Pass -Major Risk 2T-209 - 2T-209 - 2T-209 1,285.28 1,200.00 265.76 23.46 242.32 Pass -Major Risk 2T-210 - 2T-210 - 2T-210 1,434.33 1,300.00 321.25 31.41 290.71 Pass -Major Risk 2T-218 - 2T-218 - 2T-218 1,825.50 1,650.00 143.72 39.53 113.10 Pass -Major Risk 2T-22 - 2T-22 - 2T-22 1,156.99 1,150.00 46.57 23.11 24.58 Pass -Major Risk 2T-23 - 2T-23 - 2T-23 879.93 850.00 124.54 15.31 109.38 Pass -Major Risk 2T-26 - 2T-26 - 2T-26 863.94 850.00 166.20 15.77 150.47 Pass -Major Risk 2T-27 - 2T-27 - 2T-27 923.18 900.00 183.58 16.93 166.82 Pass -Major Risk 2T-28 - 2T-28 - 2T-28 769.60 750.00 210.94 14.01 197.03 Pass -Major Risk 2T-29 - 2T-29 - 2T-29 1,082.92 1,050.00 194.10 19.67 174.58 Pass -Major Risk 2T-30 - 2T-30 - 2T-30 777.77 750.00 253.12 14.38 239.11 Pass -Major Risk 2T-31 - 2T-31 - 2T-31 195.78 200.00 263.36 3.39 259.97 Pass -Major Risk 2T-32 - 2T-32 - 2T-32 1,421.07 1,350.00 244.08 30.92 213.31 Pass -Major Risk 2T-38 - 2T-38 - 2T-38 343.05 350.00 225.57 5.87 219.70 Pass -Major Risk 2T-38 - 2T-38A - 2T-38A 351.50 350.00 225.73 6.03 219.71 Pass -Major Risk 2T-39 - 2T-39 - 2T-39 254.08 250.00 24.53 4.57 19.96 Pass -Major Risk 3/9/2006 4:34:56PM CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation Page 3 of 4 COMPASS 2003.11 Build 50 ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 2T Pad Site Error: O.OOft Reference Well: Plan: 2T-40 Well Error: O.OOft Reference Wellbore Plan 2T-40 Reference Design: 2T- 40 (wp06) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: • HALLIBURTON Speny Drilling Services Well Plan: 2T-40 -Slot 2T-40 Planned 2T-40 @ 117.SOft (Doyon 15 (77.8+40)) Planned 2T-40 @ 117.SOft (Doyon 15 (77.8+40)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Reference Depths are relative to Planned 2T-40 @ 117.80ft (Doyon 15 Coordinates are relative to: Plan: 2T-40 -Slot 2T-40 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meridian is -150.00000000 ° Grid Convergence at Surface is: -0.0081 ° Ladder Plot ~ 1 0 u7 M_ C O .~ (4 Q N N C N U 0 a~ c U ~r 2T-07, 2T-07, 2T-07 V3 $ 2T-06, 2T-06, 2T-06 V2 •~~ 2T-32, 2T-32, 2T-32 VO $ 2T-207, 2T-207, 2T-207 V1 $ 2T-04, 2T-04, 2T-04 V2 -~ 2T-203, 2T-203, 2T-203 Rig Surveys VO $ 2T-39, 2T-39, 2T-39 V9 $ 2T-08, 2T-O8, 2T-08 V2 $ 2T-03, 2T-03, 2T-03 V2 ~~e~~ 2T-22, 2T-22, 2T-22 VO -34- 2T-202, 2T-202, 2T-202 V2 $ 2T-02, 2T-02, 2T-02 V2 $ 2T-31, 2T-31, 2T-31 VO $ 2T-201, 2T-201, 2T-201 VO °~ 2T-27, 2T-27, 2T-27 VO ~F 2T-11, 2T-11, 2T-11 V2 -~- 2T-14, 2T-14, 2T-14 V2 2T-208, 2T-208PB1, 2T-208 P61 VO -~ 2T-05, 2T-05, 2T-05 V2 -~~:~ 2T-209, 2T-209, 2T-209 V1 ~°- 2T-208, 2T-208PB3, 2T-208PB3 V0 2T-12, 2T-12, 2T-12 V2 $ 2T-29, 2T-29, 2T-29 VO $ 2T-208, 2T-208, 2T-208 VO $ 2T-09, 2T-09, 2T-09 V2 $ 2T-13, 2T-13, 2T-13 V2 °~- 2T-208, 2T-208P62, 2T-208 PB2 VO $ 2T-12A, 2T-12A, 2T-12A V2 2T-38, 2T-38A, 2T-38A VO -r~- 2T-218, 2T-218, 2T-218 V7 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/9/2006 4:34:56PM Page 4 of 4 COMPASS 2003.11 Build 50 ORIGINAL 0 1500 3000 4500 6000 7500 9000 Mea~t~e~~ggtb(1500 ft/in) 2T-40 [iri 1 I i na H (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 12-1/4" Surface Hole / 9-5/8"" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets um in out Anti-collision Low Follow directional plan as close as practical. Run SSG ros on surface interval 8-1/2" Intermediate/Pilot Hole / 7" Casing Interval Hazard Risk Level Miti ation Strate Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool decreased mud wei ht. Lost circulation Moderate Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-1/2" Production Hole / 3-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir High Stripping drills, shut-in drills, material on Pressure location for increased mud wei ht. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool, decreased mud wei ht Lost Circulation Moderate Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 2T-40 Drilling Hazards Summary.doc 2T-40 Filling Hazards Fmmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 12-1/4" Surface Hole / 9-5/8"" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low , Monitor cellar continuously du ng interval. Running Sands and Moderate Maintain planned mud par meters, Gravels - Increase mud weight, u weighted swee s. Hole swabbing on trips Moderate Trip speeds, prope ole filling (use of trip sheets , um in out Anti-collision Low Follow directi al plan as close as practical. Run SS G r s on surface interval Hazard isk evel Miti ation Strate Stuck Pipe h ood hole cleaning practices, maintain ~' optimum mud parameters, monitor PWD `~ a' tool decreased mud wei ht. Lost circulation Mod ate Reduced um rates, mud rheolo ,LCM Hole swabbing on trips derate Trip speeds, proper hole filling (use of trip sheets , um in out Hazard Risk Level Miti ation Strate Abnormal Res oir Low Stripping drills, shut-in drills, material on Pressure ~' location for increased mud wei ht. Stuck Pipe High Good hole cleaning practices, maintain optimum mud parameters, monitor PWD tool, decreased mud wei ht Lost rculation Moderate Reduced um rates, mud rheolo ,LCM Hol Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 2T-40 Drilling Hazards Summary 2T-40 Producer Proposed Completion Schematic Topset Base Case - 3-'/2' Completion String 16" 62.6# Conductor @ +/- 120' MD TAM 9-5/8" Port Collar Stnd Grade BTC Threads (+/- 1000' MDlTVD) Surface csg. 9-5/8"40# L-80 BTC +/- 8072' MD/ 4100' TVD ConocoPhilli s p 3-1/2" FMC Gen V Tubing Hanger, 3-1 /2" L-80 EUE8RD pin down Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. Use of port collar at the discretion of the drilling team. Place GLMs at the following planned depths- adjust accordingly at TD TVD MD GL Valve #1 1.0" Camco Bellows #2 1.0" Camco Bellows #3 1.0" Camco Bellows #4 1.0" Camco Bellows #5 1.5" Camco Orifice Valve #5: 3-1/2" x 1-1 /2" 'MMG' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 3-1/2" Camco'DS' nipple w/ 2.812" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below 3-1/2" Baker GBH-22 casing seal assembly w/ 15' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly Irun on drill~ipe). 150' of liner overlap 7" 26.0# L-80 BTCM 11,421' MD / 5,796' TVD Future Perforations 3-1/2" 9.3# L-80 SLHT 11,559' MD / 5,916' TVD oRt~~~a~. Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 20' Seal Bore Extension XO Sub, 5" BTC box x 3-1/2" SLHT pin 2/23/2006 ~i~~r~ CemCADE Preliminary Job Design 9 5/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Kuparuk Client: ConocoPhillips Alaska, Inc. Revision Date: 3/14/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 2634207 Mobile: (907) 748-6900 email: martin13@slb.com " < TOC at Surface Previous Csg. < 20", 91.5# casing at 118' MD < Base of Permafrost at 1,707' MD (1,518' TVD) Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 30% excess below the permafrost. The top of the tail slurry is designed to be at 3,329' MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.4895 ft3/ft x (118') x 1.00 (no excess) = 175.8 ft3 0.3132 ft3/ft x (1707' - 118') x 3.50 (250% excess) = 1741.9 ft3 0.3132 ft3/ft x (3329' - 1707') x 1.30 (30% excess) = 660.4 ft3 175.8 ft3 + 1741.9 ft3+ 660.4 ft3 = 2578.1 ft3 2578.1 ft3 / 4.45 ft3/sk = 579.3 sks Round up to 580 sks Have 260 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 250 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.56 ft3/sk 0.3132 ft3/ft x (8072' - 3329') x 1.30 (30% excess) = 1931.2 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1931.2 ft3 + 34.1 ft3 = 1965.3 ft3 1965.3 ft3/ 2.56 ft3/sk = 767.7 sks Round up to 770 sks BHST = 97°F, Estimated BHCT = 89°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 3,329' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 8,072' MD (4,100' TVD) Mark of Schlumberger QRI~I~AL CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 ASL 7.0 443.5 63.4 98.4 LiteCRETE 6.0 350.0 58.3 156.7 Drop top plug 0.0 0.0 5.0 161.7 Water 5.0 20.0 4.0 165.7 Switch to rig 0.0 0.0 5.0 170.7 Mud 7.0 577.0 82.4 253.1 Slow & bump plug 3.0 9.0 3.0 256.1 MUD REMOVAL Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 2 per joint on the shoe track and 1 per joint across zones of interest for proper cement placement. '' ~I~~r~ CemCADE Preliminary Job Design 7" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Kuparuk Client: ConocoPhillips Alaska, Inc. Revision Date: 3/14/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. < 9 5/8", 40.0# casing at 8,072' MD < Top of Tail at 10,421' MD < 7", 26.0# casing in 8 1/2" OH TD at 11,421' MD (5,796' TVD) Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 1000' MD annular length Tail Slurrv Minimum thickening time: 170 min. (Pump time plus 90 min.) 15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.06%6155, 0.35% D167 - 1.16 ft3/sk 0.1268 ft3/ft x 1000' x 1.40 (40% excess) = 177.5 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3 177.5 ft3 + 17.2 ft3 = 194.7 ft3 194.7 ft3/ 1.16 ft3/sk = 167.8 sks Round up to 170 sks BHST = 141°F, Estimated BHCT = 110°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 20.0 4.0 4.0 Pressure test lines & dro bottom lu 0.0 0.0 10.0 14.0 MUDPUSH II 5.0 30.0 6.0 20.0 Tail Slurry 5.0 34.7 6.9 26.9 Drop top plug 0.0 0.0 5.0 31.9 Wate 5.0 20.0 4.0 35.9 Switch to rig 0.0 0.0 5.0 40.9 Mud 6.0 385.0 64.2 105.1 Slow Rate -ECD 4.0 20.9 5.2 110.3 Slow -ECD & bum lu 2.0 8.0 4.0 114.3 MUD REMOVAL Recommended Mud Properties: 10.1 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv ? 19-22, TY ? 22-29 Centralizers: Recommend 2 per joint on shoe track and 1 'h per joint throughout cemented column ORIGINAL .~ CemCADE Preliminary Job Design ~ ~~~~~ 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Kuparuk Client: ConocoPhillips Alaska Revision Date: 3/14/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Top of Tail at < 11,071' MD < Liner Top at 11,271' MD Previous Csg. 7", 26.0# casing at 11,421' M D < 3 1/2", 9.3# casing in 6 1/8" OH TD at 11,559' MD ~ (5,916' ND) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Tail Slurry Minimum thickening time: 120 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gpS D600G + 0.04% B155 + 0.4% D65 + 0.2 gps D47 - 1.17 ft3/sk Liner Ca p: 3 0.1276 ft /ft x 200' x 1.00 (no excess) = 25.5 ft3 Liner Lap: 0.1480 ft3/ft x (11421' - 11271') x 1.00 (no excess) = 22.2 ft3 Annular Volume: 0.1378 ft3/ft x (11559' - 11421') x 1.50 (50% excess) = 28.5 ft3 Shoe Volume: 0.0488 ft3/ft x 60' x 1.00 (no excess) = 2.9 ft3 Totals: 25.5 ft3 + 22.2 ft3 + 28.5 ft3 + 2.9 ft3 = 79.1 ft3 79.1 ft3/ 1.17 ft3/sk = 67.6 sks Round up to 70 sks BHST = 144°F, Estimated BHCT = 112°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 MUDPUSH II 5.0 10.0 2.0 14.0 Line 5.0 14.8 3.0 17.0 Drop dart 0.0 0.0 5.0 22.0 Water 5.0 10.0 2.0 24.0 Switch to rig 0.0 0.0 5.0 29.0 Mud 5.0 109.0 21.8 50.8 Pick up plug & bum 2.0 3.0 1.5 52.3 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* 11, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 2 perjoint on shoe and 1 per joint from to inside casing ORIGINAL L'~SL'~~J 9ooza~,~ Ot~-1Z NO 5 ~ NOJIOa SCI I 1 O~OllO' psn';uawaoe~d ~a}~anip ped 1Z ' I • ~~ ~~o~~aays ~10~ 1N3W3~b~~d ?~312~3/~Ia • ~ J L~ x I ~~~ ~~r~ ~('' ~l I ~ I ~~ ~~-- ~ i i.~ '1 I ~ W C~ W ~ 05 = u~~! i ~a isNd ~ 05 = u~u~ zii .a isNd , ., . ..--~ -~-- . __~. ., :areas ~~ ~~ ooz osi ooi os o ~ ~' ' (spuooas ~, 6'saai6ap 08I = 4UON aml wml y]nwiry) ~ ~~.,1 y~0~ a~~s7J?~Ul ~~ j m __. Y ~ ~ a g ~~ ~~~~ -~ ~ anal, c~ ~~~ o ~ Q~ ~ dd ddd~d ~~ ~~ ~ _~ X ~ _~ • ~~ Z~Z • I~ • ~ - -~ ~,~© A , ~~} ~ '~~I, ~ F~15 i~ _~.' J N LL ~ ~-_-_. ~ ~ ~., ~ ~ z ¢ ~ ~ .' Q D ~ ..._.. ~C, CV O ~ -- ~ _ ~ ~ X + + ~ ~ ~ •~ , + + ~ ~ ~ 115' 6'i~--'~~ .~ + ~ / \ + + -----_ - a '~ - - __ +` ~ ~. + Q ~ o c ~~ ~Q ~w + c~ ~ ~ _ ++ ~ O ~•~ + + Q ~. ~: +'+ + + + ~ + + + • • ~~ ~~ • w o w ~W o ~ ~ ~ s~ ~~ cwn w LL ~ \ J W CO a ~ W ~ U ~ z O ~ ~ ~ ~a ~- ~,~ o a F- ~ ~ ~ ~ ~o L~ ZW N w ~ IO_ ~~ • N ~ ~ J v O Z z `l • (~ ~ ~ ~ O D ~ W W ~ • ~ V ~ ~ .. W ~ ~ z °~ w v ~ z ~ W~ c~ c~ '- W z ~ i c~ o ~'_ z z ~~ o z Q ~ ~' ~ ~ ~ > z i- v~ v~ z °o Q ~ ~ ~ 1 X X O~ m X Q ~~ W W U~ Q W ~ ~ I IJ -,- .....~ '~ .~ 0 RE: 2T-40 • • Subject: RE: 2T-40 From: "~~'infi~ec, Michael Alc~ (Jr.)" °~i~9ichaeLA.~Vinfrec(~c'conoco~~hillips.com= Date: Wed, ?? ~9ar ?OC)G l :~?:O7 -O~)0O To: Thomas ~~launder <~tom maunder(ct;admin.sfate.ak.us=~~ C'C: "Billingsley, Tim A" <'Tiny.A.Billin<~sley~la',conocophillips.com=-, Steve. Davies <steve_da~~ics~a~;admin.s~ate.ak.us==, "~l~}~o~nas, Randy L" <Randy. L.Thomas(ci?conoeophillips.com> Tom, Please find attached the support documents for the 2T-40 APD. Thank You, -Mike Mike A. Winfree Drilling Engineer ConocoPhillips Alaska 907.265.6820 Direct 907.242.0246 Cell -----Original Message----- From: Thomas Maunder [mailto:tom maunder:~admin.state.ak.us] Sent: Tuesday, March 21, 2006 2:06 PM To: Winfree, Michael Alex (Jr.) Cc: Billingsley, Tim A; Steve Davies Subject: 2T-40 Michael and Tim, We are reviewing the permit application and have a couple of questions. 1. You show potential BHP to be 4000 psi based on offset wells. At the tvd specified, this is 13.3 EMW but in the mud properties chart on page 5 only 12.0 ppg is specified for the production interval. The specified MW appears to be low. 2. On the hazard chart for the 3-1/2" interval, "low" is given for the risk of abnormal reservoir pressure. Is 13.3 EMW considered normal reservoir pressure? 3. when you delivered the permit application we discussed how the diverter line would be sited and your rationale. Would you please provide some further comments about the precautions and other mitigation measures that will be in place while drilling the surface hole? Thanks in advance for your replies. Call or message with any questions. Tom Maunder, PE AOGCC -. __ ___ _ __ Content-Description: 2T-40 APD Response to AOGCC.doc ''2T-40 APD Response to AOGCC.doc Content-Type: application/msword Content-Encoding: base64 2T-40 Drilling Hazards Summary.doc Content-Description: 2T-40 Drilling Hazards 1 of 2 3/23/2006 2:37 PM 1. You show potential ~ to be 4000 psi based on offse~lls. At the tvd specified, this is 13.3 EMW but in the mud properties chart on page 5 only 12.0 ppg is specified for the production interval. The specified MW appears to be low. The ret~uirements of 20 AAC 25A05{c)(4) state the APD must include "Maximum downhoie pressure that may be encountered, criteria used to determine it and maximum potential surface pressure based on a methane gradient". The maximum pressure we expect to encounter is 4000 psi {13.3 ppg), however, our best technical estimate for BHP is N3500 psi (12.0 ppg includes 150 psi trip margin). The maximum and expected BHP estimates were determined using offset injector pressure data. In November 2005 SI pressures were taken on offset injectors 2T-32, 2T-29 and 2T-02. The results are shown in table i. Well iurvey Date urvey TyF Sand PBar BHT SI Time FSIBHP ~ i ~ Depth (: ! PPG 2T-29 11/23/2005 SBHP A 4112 132 5232 3940 5708 13.3 2T-32 11/24/2005 SBHP A 3575 148 25000 3501 5678 11.9 2T-02 11/22/2005 SBHP A 4190 123 74 4003 5665 13.6 Table 1 The target block is defined by faults on the north, east and south, and is truncated by the erosional surface of the Lower Cretaceous Unconformity {LC) on the west, 2T-32 and 2T-29 are within our fault block polygon for the proposed 2T-40 bottom hole location whereas 2T-02 falls outside of our eastern fault delineated polygon. Figure 1 shows the target block and offset injector locations superimposed on a Kuparuk A2 net pay map. / y ~ ~ ~fF' ~ `~ i ~ i ~ ~~ °~°~~ ~~ Kid f ,~1~ ,'~ ~ ~~- i 1 ~ ~ l ~ ~ ~ ,, Y~ 11 ~ '-~ ?T-~Z ~~ ~~ N a ii ~ ` j \ c lll~" i i ~ - n\ z _ ,; y ~ ~~~''~ ~_~ '~•~~ J ~rt3A vt ~A rr' ~~ ~~-, ~ ~~ I 'eye zu-ie t_. ~ ~„ ~ dZ 2r-ez ~ ~_ ~i- e i zT-an i _ , ~ ~ ~ ~' ~ ~ _~ ~ ,~~ ~_ i ~~, ~ . r ~r ~~ zT-nz - ~ .. ~ ,% i ~/ ~ ~ ~ ~~ try \ . ~ ~ i i r-~ s 1 ~ '''. -e ~ ~'r. - ~ ~r~a~ %.. r u,~tti ~/n J(~i ~ ~ i ~~~ ~- ZA 2_5 /N 27 i _] ' R `!~ „P f 20.-02 2~-~7 ~ ~ ~ ~ l ~i / / DQ t m ~ .-~ / / ~ / t -__ 1 ~ ~ ~. ~ ~ ~ ~i The inconsistency between the value used in the MPSP calculation and ~3HP value used for the mud program is due to the uncertainty of the offset injector influence bath inside and outside the fault block. 2T-02 should not greatly influence our BHP estimate because it is outside our fault block and it is structurally higher than our proposed BHA. 2T-32 and 2T-29 are both within the target polygon however the expectation is that 2T- 32 is more representative of our expected reservoir pressure because of it`s proximity to the proposed BHi_ and 2T-3z also lies on the same contour interval as 2T-40. The tap set well design was chosen to mitigate our open hole exposure if the BHP required the heavier mud weights. The well plan procedure will include a FiT at the 7" top set to verify we have a competent shoe. 2. On the hazard chart for the 3-1/2" interval, "low" is given for the risk of abnormal reservoir pressure. Is 13.3 EMW considered normal reservoir pressure? I have updated and attached the revised Drilling Hazard Summary to include a high probability of abnormal reservoir pressure. 3. When you delivered the permit application we discussed how the diverter line would be sited and your rationale. Would you please provide some further comments about the precautions and other mitigation measures that will be in place while drilling the surface hole? While drilling the surface hole there will be signage on the pad (adjacent to the 75' perimeter measured from the end of the diverter line) indicating the rig has diverter equipment rigged up. There will be no admittance within the 75' perimeter without approval of the rig supervisor. This will apply to all personnel, including the drill site operators, while the rig has the diverter equipment in place. Although remote, should the diverter equipment be used, apre-assigned rig crew member will be stationed at the pad entrance to prevent non-essential personnel from accessing the pad. The rig crew member will mobilize to the pad access road at the company mans discretion. If you require additional ~i..nformat:i..on p.I.ease call M:i.ke A Winfree at 265-6820 or Ti.m Billingsley at 265-6531. Thank you, 6050000 6000000 5950000 5900000 5850000 ~ 400000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 500000 600000 700000 -- 8000001 • Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com March 19, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill 2T-40 Dear Commissioners, COP10C0~'lI~~I~S ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore producer well 2T- 40. The well will be drilled and completed using Doyon Rig 15. The planned spud date for 2T-40 is March 28th 2006. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike A. Winfree at 907- 265-6820. Sincerely, ~~`~ t Randy Thomas Kuparuk Drilling Team Leader ~ • ..SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS i 140 ATO 1530 700 G ST - ANCHORAGEAK 9950i! DArE 3 zo 2~~P ss-1551/441 PAY TO THE {~ C~ ~~ A C-Y l~Y~ ~~~'~~ € ; ORDER OF Q r,~, r'`, w VCs! {„sC0 DOLLARS LI o ~" JPMorganChase ~ j vaiia up r~.sooo ~ouars ~ } JPMorgan Chase Bank,. N.A. i Columbus; OH •, .MEMO --- - --- -~ `~' ,' , ~: 0 4 4 L L 5 5 1 L ~: 5 2 8 7 4 7 19 0 7 9 2 7 n' 1 L 4 0 -__-- __ -- --------_---_ ,~EA~.~ a • • TRANSMITTAL LETTER CHECKLIST IC ~~~--u~ ~~ W`'~'~ZG,~ ~-u-k. 2t ~r ~~ ~ WELL NAME ~~~ Z~ `~~ PTD# ,Z.bt<n -~~~--- "~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist WELL PER IT CH ECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 2T-40 ______ Program .DEV ___ Well bore seg ^ PTD#:2060400 Company CONOCOPHILLIPS ALASKA INC Initial Classffype DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore ~ Annular Disposal ^ Administration 1 Permitfee attached_ _ _ - - _ .. _ Yes - - - - - - -- - - - - - - - _ . 2 Lease number appropriate-__ -_-________________________ _________ No-______ _Corectionmadeto_1.0-401:_Prodlnt&TDinADL25549;Surf._LocinADL25569,_______-__._------ 3 Unique well-name and number --._--------- - -- -- --- ------- -Yes------ -- --- -------- --- ----------- -------------..-..---------- ---- -- 4 Well located in a_definedpool _ - _ Yes Kuparuk River Field, Kuparuk River Oil Pool 5 Well locatedp[operdistanGefromdrillingunitboundary________ ______ _________Yes_____ _____________--_-.__--__________-.__. - -- 6 Well located proper distance from other wells_ _ _ - ... - .Yes - - - - _ - . - 7 Sufficientaereageayail_ablein-drilling unit_______________________ _________Yes___-__ -_____--__-__-.__--_--__--__._---._--_________------__--__.---.__-__ 8 If deviated, is.wellborep1at-included - - Yes - - - - - - - - - - - - - - 9 Operator only affectedpar~y_----------------------------- -_ ----.Yes------ ---..--- 10 Operakorhasappropriake.bond(nfQrce------------- -- ------ ---- --- Yes------ -------- ------ --- -- -------- --- -- -------------------- -- - -- - 11 Permit_canbeissuedwithoutconservalionorder------------------- ---------Yes--_-_- --__--__--______-__-____----___--__-___-_--____---_-_--_--__ -_- - Appr Date 12 Permit_ean be issued without administrativ_e_appr_oyal _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes SFD 312112006 13 Can permit be approved before 15-day wait Yes 14 Wellloc~tedwithinareaandstrataauthorizedby_InjectionOrder#(put_IQ#in_comments)_(For_NA_______ _______________________________________-________________-__-------_ 15 Allwells-within 1l4_mile area.of review jdentified (For service well only}- - - - - - - - - - - - - - - NA_ _ _ _ _ _ - _ _ _ _ _ - - _ _ _ _ _ _ _ - . . 16 Pre-produced injectgr; duration of preproduction I_essthan 3 months_(For_se(vice well only) NA_ - - - ACMP_Finding of Consistency-h_asbeenissued-fo[thisproject-_-------- -----_-_ NA__-__-_ __-_----_________ ---------------------------------------------------- Engineering 18 Conduclorstring_provided_-__--------------------------- ---------Yes-----. __.._-..__-._-___ 19 Surface,casingprotect&allkngwn_USDW&___________________ __- ____-NA._-__-- _Allaquifersexempted, 40CFR_147.102(bk3}__________________________________________ 20 CMT_vol-adeguate_to circulate.on conductor 8 surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ - _ _ - - _ - 21 CMT_vok adequate_to tie•in long string to surf csg_ _ No_ All hydrocarbon zones will be-covered. Annular disposal may-be_proposed, - _ - . 22 CMT_willcoverallkno_wn_productivehorizons-------------- - ---- ---------Yes_---_. .---__--__------__----__--__- _-------__-_____--_- -- 23 Casing desgns adequste for C,_T, B &_Rermaf[ost - Yes 24 Adequate tankage_or reserve pit . . . . .. . . . . . . . . ... . . ... . .. . .. . . . ..... .Yes _ .. - - . -Rig is-egeipped with steelpits. No resen!e_pitplanned, All waste to approved disposal wells._ 25 Ifa_re-drill,has_a-10-403 for abandonmentlteenapproved--_---__--__ ___--_-_ NA------- ------------------- - - -- - - - 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ __ Yes _ _ _ _ _ _ _ Proximity analysis performed, Traveling cylinder plot_ineluded. _ Gyros possible. _ - - _ _ _ - _ _ _ _ _ _ _ - _ _ - - - - 27 If diverter required, does it meet regulations_ _ - _ _ _ - - _ - - - _ _ _ - Yes Diyerter line will-be directed-back on-pad.- Mitigation measures in place- - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid_program schematic & equip list adequate . . . . ...... . . . . . . . . .. . .. . Yes - ... - . - MASP Calculated x13364 psi, _Possible overpressure due to isolated fault block..lnteryal to be_tpp set. MW_ TEM 3123/2006 29 BOPEs,-do they meetregulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _most likely aboui 12.O ppg-with MW adjusted-per hole conditions.- _ _ _ _ _ _ - _ _ . _ - _ . _ - _ _ _ - . - .. - _ - (~ d~ 30 _B_OPE_press rating approprate; test to_(put prig mcomments) - .. _ . _ . _ Yes - .. - .. . MASP Calculated x13364 psi. 3500_psi_appr_opriate. CPA_I normally tesls_to 4000_psi, .yi~.~ 1 31 Choke_manifold complies wlAPl_RP-53 (May 84) - - Yes 32 Work willoccu[withoutoperaiionshutdown______________________ _________Yes______ __-___-___--_._ - - - - -- - 33 Is presence of H2S gas probable - - - Yes _ H2S is present at-2T, Mud should-preclude H2S on rig. -Rig hassensors-and alarms- - - - - - - - - - - - - - - 34 Mechanical condition of wells within AQR verified ~Forservice well onty) _ - _ - - _ - . - - _ NA_ _ - - Geology 35 Permit can be issued wlo hydrogen-sulfide measures .. . . . . . . . . . . . . . . . . .. . . .. No_ - - - - _ _ -?T-Pad_wells producing from Kuparuk_ measure_55.220 ppm H2S. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ - _ 36 Data_presented 4n potential overpressure zones . . . . . .... . .. . . ... . . . . . .. . .. .Yes - - - - - . . Maximum possible_ reservoir pressure is 13.3 ppg EMW, 4r_0,69psilft (TEM) - _ - - _ _ - Appr Date 37 Seismic-analysis_ of shallow gas_zones_ NA_ SFD 3121/2006 38 Seabed conditionsuryey_(ifoff-shore)________________________ __---__--_ NA 39 Contact namelpho_ne for weekly-progress reports-[exploratory only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ - Geologic Engineering lic Date: Date Ku Date p aruk A-sand develo ment well. SFD p Commissioner: Commissioner rs er p1~ ~3~z~~ `~ ~~`"~~ 3•Z~--o,6 s CJ 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. Sperry-Sun Dri~ng Services t LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 03 14:51:34 2006 Reel Header Service name .............LISTPE Date .....................06/08/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/08/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 2T-40 API NUMBER: 501032052800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: O1-AUG-06 JOB DATA MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: W-0004263654 W-0004263654 W-0004263654 LOGGING ENGINEER: P. SMITH P. SMITH P. SMITH OPERATOR WITNESS: F. HERBERT F. HERBERT F. HERBERT SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: 8E FNL: FSL: 290 FEL: FWL: 556 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 118.85 GROUND LEVEL: 77.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8075.0 2ND STRING 6.125 7.000 11223.0 3RD STRING PRODUCTION STRING ~d (~ ~D~b ~ 1~l03~ REMARKS: ~ • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1-3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 4-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 4,5 ALSO INCLUDED ACOUSTIC CALIPER (ACAL). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 7/25/06, FROM L. WRIGHT (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-6 REPRESENT WELL 2T-40 WITH API#:50-103-20528-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11661'MD/6044'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" & 6.125" BITS MUD WEIGHT: 9.5-12.0 PPG MUD SALINITY: 500-600 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name.. • Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NCNT 8009.0 11575.5 NPHI 8009.0 11575.5 FCNT 8009.0 11575.5 RHOB 8050.0 11585.5 DRHO 8050.0 11585.5 PEF 8050.0 11585.5 RPS 8059.5 11611.5 RPM 8059.5 11611.5 RPX 8059.5 11611.5 FET 8059.5 11611.5 RPD 8059.5 11611.5 GR 8067.5 11604.0 ROP 8090.5 11661.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 4 8009.0 8958.0 MWD 5 8958.0 11232.0 MWD 6 11232.0 11661.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 ~ RPX MWD OHMM 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8009 11661 9835 7305 8009 11661 FONT MWD CNTS 81.25 1629.67 815.54 7114 8009 11575.5 NCNT MWD CNTS 13003.9 166919 113017 7114 8009 11575.5 RHOB MWD G/CM 0.732 2.851 2.3584 7072 8050 11585.5 DRHO MWD G/CM -3.032 0.377 0.04864 7072 8050 11585.5 RPD MWD OHMM 1.16 2000 29.1383 7105 8059.5 11611.5 RPM MWD OHMM 1.08 2000 21.5715 7105 8059.5 11611.5 RPS MWD OHMM 1.03 1666.98 5.0702 7105 8059.5 11611.5 RPX MWD OHMM 1.02 1665.93 4.58968 7105 8059.5 11611.5 FET MWD HOUR 0.26 191.37 5.84408 7105 8059.5 11611.5 GR MWD API 43.91 436.88 136._189 7074 8067.5- 11604 PEF MWD BARN 1.81 19.49 4.27015 7072 8050 11585.5 ROP MWD FT/H 0.4 371.01 94.649 7142 8090.5 11661 NPHI MWD PU-S 23.41 75.52 39.2758 7114 8009 11575.5 First Reading For Entire File..........8009 Last Reading For Entire File...........i1661 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH NPHI 8009.0 FCNT 8009.0 NCNT 8009.0 PEF 8050.0 DRHO 8050.0 STOP DEPTH 8861.0 8861.0 8861.0 8874.5 8874.5 RHOB 8050.0• FET 8059.5 RPS 8059.5 RPM 8059.5 RPD 8059.5 RPX 8059.5 GR 8067.5 ROP 8090.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8874.5 8912.5 8912.5 8912.5 8912.5 8912.5 8920.0 8958.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined C, 21-APR-06 Insite 66.37 Memory 8958.0 8090.0 8958.0 64.9 67.4 TOOL NUMBER 132482 66259 1844674407370955 1064059 8.500 8075.0 Polymer 9.60 44.0 10.3 900 6.8 1.500 72.0 .930 120.0 1.200 72.0 1.800 72.0 Absent value............ ......-999 Depth Uni ts ..... ............ ...... Datum Spe cificat ion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8009 8958 8483.5 1899 8009 8958 FCNT MWD040 CNTS 577.18 1140.86 832.825 1705 8009 8861 NCNT MWD040 CNTS 101961 147246 123927 1705 8009 8861 RHOB MWD040 G/CM 0.732 2.784 2.28257 1650 8050 8874.5 DRHO MWD040 G/CM -2.476 0.26 0 .0164915 1650 8050 8874.5 RPD MWD040 OHMM 1.76 2000 24.112 1707 8059.5 8912.5 RPM MWD040 OHMM 1.66 2000 8.92947 1707 8059.5 8912.5 RPS MWD040 OHMM 1.57 1666.98 4.91469 1707 8059.5 8912.5 RPX MWD040 OHMM 1.49 1665.93 4.2452 1707 8059.5 8912.5 FET MWD040 HOUR 0.26 191.37 7.97834 1707 8059.5 8912.5 GR MWD040 API 51.74 203.53 130.375 1706 8067.5 8920 PEF MWD040 BARN 1.94 12.12 3.41338 1650 8050 8874.5 ROP MWD040 FT/H 1.31 316.26 100.651 1736 8090.5 8958 NPHI MWD040 PU-S 31.29 53.87 40.4535 1705 8009 8861 First Reading For Entire File..........8009 Last Reading For Entire File...........8958 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER • FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 8861.5 11138.0 FCNT 8861.5 11138.0 NPHI 8861.5 11138.0 DRHO 8875.0 11151.5 PEF 8875.0 11151.5 RHOB 8875.0 11151.5 FET 8913.0 11186.5 RPM 8913.0 11186.5 RPD 8913.0 11186.5 RPX 8913.0 11186.5 RPS 8913.0 11186.5 GR 8920.5 11194.0 ROP 8958.5 11232.0 LOG HEADER DATA DATE LOGGED: 24-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11232.0 TOP LOG INTERVAL (FT) 8958.0 BOTTOM LOG INTERVAL (FT) 11232.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 69.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 145654 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 102405 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 8075.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 47.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.200 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .680 134.6 MUD FILTRATE AT MT: 1.400 73.0 MUD CAKE AT MT: 1.800 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 FCNT MWD050 CNTS 4 1 68 4 2 NCNT MWD050 CNTS 4 1 68 8 3 RHOB MWD050 G/CM 4 1 68 12 4 DRHO MWD050 G/CM 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HOUR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 BARN 4 1 68 44 12 ROP MWD050 FT/H 4 1 68 48 13 NPHI MWD050 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8861.5 11232 10046.8 4742 8861.5 11232 FCNT MWD050 CNTS 572 1629.67 917.277 4554 8861.5 11138 NCNT MWD050 CNTS 103809 166919 126476 4554 8861.5 11138 RHOB MWD050 G/CM 1.729 2.71 2.40109 4554 8875 11151.5 DRHO MWD050 G/CM -0.01 0.377 0.0860782 4554 8875 11151.5 RPD MWD050 OHMM 1.16 22.03 4.42094 4548 8913 11186.5 RPM MWD050 OHMM 1.08 33.54 4.23029 4548 8913 11186.5 RPS MWD050 OHMM 1.03 19.45 3.9823 4548 8913 11186.5 RPX MWD050 OHMM 1.02 15.38 3.90726 4548 8913 11186.5 FET MWD050 HOUR 0.32 31 1.52975 4548 8913 11186.5 GR MWD050 API 58.09 436.88 143.682 4548 8920.5 11194 PEF MWD050 BARN 1.81 13.36 3.46999 4554 8875 11151.5 ROP MWD050 FT/H 3.26 371.01 101.616 4548 8958.5 11232 NPHI MWD050 PU-S 23.41 53.91 38.1442 4554 8861.5 11138 First Reading For Entire File..........8861.5 Last Reading For Entire File...........i1232 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type....... .......LO Next File Name...........STSLIB.004 Physical EOF ~ • File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 11148.5 NPHI 11148.5 FCNT 11148.5 PEF 11152.0 RHOB 11152.0 DRHO 11152.0 RPD 11187.0 FET 11187.0 RPS 11187.0 RPX 11187.0 RPM 11187.0 GR 11194.5 ROP 11232.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE; MAXIMUM ANGLE: STOP DEPTH 11575.5 11575.5 11575.5 11585.5 11585.5 11585.5 11611.5 11611.5 11611.5 11611.5 11611.5 11604.0 11661.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuth. Litho-Den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 03-MAY-06 Insite 68.18 Memory 11661.0 11232.0 11661.0 33.1 38.2 TOOL NUMBER 064004 1844674407370955 167218 1050894 6.125 11223.0 Polymer 12 .0 0 44.0 8.3 600 FT.TTTT1 T.(1RR ((''71 ~ d Z RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.050 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.160 138.0 MUD FILTRATE AT MT: 1.540 75.0 MUD CAKE AT MT: 4.000 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (TN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HOUR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 BARN 4 1 68 44 12 ROP MWD060 FT/H 4 1 68 48 13 NPHI MWD060 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11148.5 11661 11404.8 1026 11148.5 11661 FCNT MWD060 CNTS 81.25 613.17 239.186 855 11148.5 11575.5 NCNT MWD060 CNTS 13003.9 29699.4 19576.2 855 11148.5 11575.5 RHOB MWD060 G/CM 0.768 2.851 2.27857 868 11152 11585.5 DRHO MWD060 G/CM -3.032 0.264 -0.0866693 868 11152 11585.5 RPD MWD060 OHMM 1.25 2000 171.484 850 11187 11611.5 RPM MWD060 OHMM 1.25 2000 139.746 850 11187 11611.5 RPS MWD060 OHMM 1.28 1269.21 11.2034 850 11187 11611.5 RPX MWD060 OHMM 1.24 975.27 8.93281 850 11187 11611.5 FET MWD060 HOUR 0.81 169.01 24.6422 850 11187 11611.5 GR MWD060 API 43.91 293.07 106.724 820 11194.5 11604 PEF MWD060 BARN 4.48 19.49 10.0969 868 11152 11585.5 ROP MWD060 FT/H 0.4 243.19 45.5757 858 11232.5 11661 NPHI MWD060 PU-S 23.74 75.52 42.955 855 11148.5 11575.5 First Reading For Entire File..........11148.5 Last Reading For Entire File...........11661 • File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/08/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF • Scientific Technical Services Scientific Technical Services End Of LIS File