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Home My WebLink About205-085• • 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. o~ Q.'~ - ©$ s Well History File Identifier Organizing (aone> R SCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maui= ~ Scanning Preparation BY: _ Maria ~..o.,a,~ iuiiiiiiuiiuiiii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ,iuiiiiimiAliii ~' ~ _~ x 30 = + =TOTAL PAGES ~C/ Date: `t' ~q J~ /7 ~COUnt does not i ~ dude cover sheet) Production Scanning + •/ , IIIII'IIIIIII)VIII Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: !' /~,,,~/D ~7' /s/ `~ / ~1 Stage 1 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 II I II II I I III Rescanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked Date: Date: ae=~~~eed~ iuiuuiuuiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: P P 10/6/2005 Well History File Cover Page.doc • • Transmittal Form r~~ BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1D-36L1 & 1D-36L2 Anchorage GEOScience Center ,~ - -,. { Contains the following: 2 LDWG Compact Disc (Includes Graphic Image files) 2 LDWG lister summary ~~ 2 blueline - GR Measured Depth Log 2 blueline - GR TVD Log ti I aas -o~s~( ~ i 5 69 r ~ 2 ~cu'-o~SS ~ ~ s ~9a LAC Job#: 941648 Sent By: Cosette Todirica Date: Nov. 13, 2007 ~ d i '1 ~ 4 { Received By: Dater [ ~~~~~ ~` f ~~~` ~~ ~ ~~ °,a , ,~~ _.,i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING~&rt RETURNI~~G OR FAXING YOUR COPY FAX: (907) 2b7-6623 Baker Hughes INTEQ "7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 .~ ~1 ,... ti, ;~, ° . ,. i' A ,; ._. ;~ - ~~;; , _..._ _. i ~' ,; j _.. .. ; _...;-; 4~ !..:._ ~'. ~' _ ,: i, ` - , ... . __, }. ~ ~ ~.~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050850 Well Name/No. KUPARUK RIV UNIT 1D-36L2 Operator CONOCOPHILLIPS ALASKA INC MD 13302 TVD 6497 Completion Date 8/1/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Med/Frmt Number T Name ~ D Asc i l~ Directional Survey Rpt Directional Survey ~,og 14315 Gamma Ray i !-Cog 14315 Gamma Ray pt 14315 ~~~ rj~ED C -lies 14315~ InductionlResistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? ~-td~ Analysis ~'7'~1 Received? Completion Status 1-OIL Samples No Current Status 1-OIL API No. 50-029-22973-61-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments - 11275 13302 8/9/2005 11275 13302 8/9/2005 25 Blu 11360 13302 Open 1/10/2006 TVD GR 30-Jul-2005 w/Graphics 25 Blu 11360 13302 Open 1/10/2006 MD GR 30-Jul-2005 w/Graphics 11350 13302 Open 1/10/2007 LIS veri in a LAS Format w/Graphics 21-Dec-2006 11350 13302 Open 1/10/2007 LIS veri in a LAS Format w/Graphics 21-Dec-2006 Sample Interval Set Start Stop Sent Received Number Comments ((~~,, Daily History Received? ;-~ N Formation Tops ~ ' )N Comments: DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050850 Well Name/No. KUPARUK RIV UNIT 1D-36L2 MD 13302 TVD 6497 Completion Date 8/1/2005 Compliance Reviewed By: _____ __ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22973-61-00 Completion Status 1-OIL Current Status 1-OIL ,` ,UI~C,~ N Date: __~ ~ ~._~"=a~~LL~ • Transmittal Form BAKE`®R . _~ HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Anchorage GEOScience Center ~ ~ Reference: 1D-36L1 & 1D-36L2 ~ °~~~ ~,,, ;~~ Sent By: Cosette Todirica Date: Dee. 22, X006 r' ~ ~~ Received By: ~ : mil/ ~it .®--~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RE'TUIZ~IING OR FAXING YOUR COPY .___ FAX: (907) 267-6623 { faker Hughes INTEQ ~ bs _ ~~ ~~/ ~ j =/ 3! ~ f 7260 Homer Drive Anchorage, Alaska 99518 c~OJ'_d`6S ~~G~3f5~ Direct: (907) 267-6612 FAX: (907) 267-6623 STATE OF ALASKA ALASKA u L AND GAS CONSERVATION COM I ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 2oAAC as,~,o ^ GINJ ^ WINJ ^ WDSPL No, ofi Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco PhilAps Alaska Inc. 5. Date Comp., Susp., or Aband. 8!1/2005 12. Permit to Drill Number 2fl~085 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/25/2005 13. AP1 Number S0-029-22973-61-00 4a. Location of Well (Governmental Section): Surface: 47 ' F ' 7. Date T.D. Reached 7/30/2005 14. Well Name and Number: Kuparuk 1D-36L2 7 NL, 420 FEL, SEC. 23, T11N, R10E, UM Top of Productive Horizon: 2553' FNL, 2363' FWL, SEC. 25, T11N, R10E, UM g. KB Elevation (ft): 105.3 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 1548' FNL, 3551' FWL, SEC. 25, T11N, R10E, UM 9. Plug Back Depth (MD+TVD) 13302 + 6497 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 '' y- 5959189 ~ Zone- ASP4 10. Total Depth (MD+TVD) •• 13302 + 6497 Ft 16. Property Designation: ADL 025661 TPI: x- 563519 y- 5951857 Zone- ASP4 Total Depth: x- 564698 ~ Y- 5952872 • Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: -- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1870' 21. Logs Run: % ~lr~~.sc_; _ %l~ 35%'~t~l~~; ~~~~ /'rY!~ ~~ ~,~5%c,~` 2. ASING, LINER AND EMENTiNG ECORD CASING ETTING EPTH MD - ETTING' EPTH TVD HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENT{NG RECORD PULLED 20" 91.5# H-40 Surface 121' Surface 121' 30'" 14 cu ds ABI T e III 9-5/8" 40# L-80 Surface 7047 Surface 4297 12-114" 850 sx AS III Lite, 415 sx LiteCrete 7" 26# L-80 Surface 11038' Surface 6245' 8-1/2" 170 sx Class 'G' 3-112" 9.3# L-80 10885' 11360' 6170' 6401' 6-118" 174 sx Class 'G' 2-3/8" 4.6# L-80 11375' 13210' 6408' 6483' 3" Uncemented Slotted Liner 23. Perforations open to Production (MD + TV D of Top and ' " 24. TueIN~ RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 10918' N/A MD TVD MD TVD 11376' - 12005' 6409' - 6413' 12100' -12638' 6413' - 6449' 2~j, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12733' - 13176' 6459' - 6480' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11360' Set Retrieveable Whipstock (For L2) 26. PRODUCTION TEST Date First Production: August 6,2005 Method of Operation (Flowing, Gas Lift, etc.}: Gas Lift Date of Test 8/16/2005 Hours Tested 17 PRODUCTION FOR TEST PERIOD OIL-BBL 2,243 GAS-MCF 3,154 WATER-BBL 427 CHOKE S1ZE 176 GAS-OIL RATIO 1,406 Flow Tubing Press. 20 Casing Pressure 780 CALCULATED 24-HOUR RATE OIL-BBL 3,167 GAS-MCF 4,453 WATER-BBL 603 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attact~separa#e sh@et, if necessary). Submit core chips; if none, state "none". ; ~ ~ ' ` I~ S ~F~, ~~~ ~ ~ao~ ~ ~ ~ None ¢~ - #~j€ 5 YC"7ij: ~`LI~ E 5 ' A ~.1.>.sdairass+ldwti!+~3'+'.'. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~ ( ~ ~ 0-•x•1 ~~ 28. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk C (From 1 D-36) 11358' 6400' None (Nothing new penetrated) 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~ • ~ ~ • tJS Kuparuk 1 D-36L2 205-085 Prepared By Name/Number.• Terrie Hubble> 564-4628 Well Number Drilling Engineer: Scott Kolstad, 564-5347 Permit No. / A royal No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only KRU 'D-36L2 ConocvPhilli Alma Inc. ps " 1D-36L2 API: 500292297361 Well T e: PROD An le TS: de Tuea~c taloess, oD:3 soo SSSV Type: NIPPLE Orig Com tetion: Angle @ TD: deg , . n:2.es2) Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo : 29.22' RKB Ref L Date: Last U ate: 8/4/2005 Last Ta TD: 13210 ftK6 { Last Tag Date: Max Hole An le~ 0 deg @ I` Casin Strin -COMMON STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 121 121 72.00 H-40 WELDED SURFACE 9.625 0 7047 7047 40.00 L-80 BTCM I PRODUCTION 7A00 0 11038 11038 9.30 L-80 BTCM ~ WINDOW to L2 3.500 11360 11364 11364 9.30 L-80 SLHT , _ Gasin Strin - C31C4-SAND LINER Alternatin 2.375" blank i e w/2.375"slotted tubin ` Descri lion Size To Bottom TVD Wt Grade Thread C3/C4-SAND LINER 2.375 11374 13210 13210 4.60 L-80 STL Tobin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 10885 10885 9.30 L-80 BTCM Perforations Summa ~ Interval TVD Zone Status Ft SPF Date T e Comment ~ - ~. 11376 - 12005 11376 - 12005 629 40 7/22/2005 IPERFS SLOTTED TUBING 12100 - 12638 12100 - 12638 538 40 7/22/2005 IPERFS SLOTTED TUBING 12733 - 13176 12733 - 13176 443 40 7/22/2005 IPERFS SLOTTED TUBING Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt LNVER 10885-11374 1 3655 3655 CAMCO MMG OV 1.5 RK 0.250 0 8/3/2005 , oo:3.soo) 2 6481 6481 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 3 8237 8237 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 4 9706 9706 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 5 10819 10819 CAMCO MMG DMY 1.5 RK 0.000 0 9/16/2000 ' Other lu s e ui .etc. -JEWELRY ' n~..~ti T/n T....e nncrri n}inn In PACKER '1137x11371, OD:2.740) DePlor s~ee~e 11374-11375, Perf - - 11376-12005) =I II - Blardc Pipe - -_- - 12005-12100, OD:2.375) Perf =1 ~ I - .1210x12638) -' I ~ - - - - 81enk Pipe - - - 12636-12733, QD:2.375) Perf =I I i = 12733.13176) - = BIaNc Plpe 13176-13210, OD:2.375) 7ther Ill s, a ui ., etc. - G3/C4-SANti De th TVD T e 11374 11374 Deploy BTT SEAL BORE I Sleeve 11375 11375 XO BTT TORQ-SLEE\ 12005 12005 Blank Pi 12638 12638 Blank Pi 13176 13176 Blank PI e general Notes CKER set 8/1/2005 I 7.L5u Descri lion ID JT SLEEVE w/3" GS PROFILE 2.250 /ER ste 7/22/205 1.992 1.992 1.992 1.992 ! i Well: 1 D-36L1 ! L2 Accept: 07/16/05 Field: Kuparuk River Unit Spud: 07!19!05 API: 50-029-22973-60-00 / -61-00 Release: 08/01!05 Permit: 205-084 & 205-085 Rip: Nordic #2 PRE-RIG WORK 02/12/05 PPPOT-T AND IC PASSED, FUNCTION TESTED LDS'S (ALL MOVED FREELY). MIT-OA FAILED WITH A LLR OF 9 GPM AT 1500 PSI. PT MASTER AND SWAB VALVES, PASSED. 02/23/05 TIFL -PASSED. 03/06/05 DRAW DOWN TEST MASTER AND SWAB VALVES. PASSED. 04/30!05 GAUGED TBG TO 2.70" TO 11455' WL, NO SPANGS. LOGGED PDS CALIPER FROM 11454' MD TO 10060' MD; GOOD DATA. DRIFTED TBG WITH 2.74" X 10' DUMMY TO 11450' WLM, TIGHT SPOT AT 7033' W LM. 07/10/05 SET 2.81" XN PLUG AT 1097i' RKB. REPLACED OV W/ DV AT 10819' RKB. 07/11/05 PULLED GLV'S, RAN DV'S AT 9706' AND 8237' RKB. OPEN POCKETS AT 3655' AND 6481' RKB. 07/12/05 RAN DV'S AT 3655' AND 6481' RKB. PT TBG TO 2500#, HELD. PULLED 1.5" DV AT 10819' RKB. (OPEN POCKET) LOAD I/A W/ SEAWATER. 07/13/05 SET 1 1!2" DUMMY VALVE AT STA #5. MITIA-PASSED, PULLED 2.81" XN LOCK. JOB COMPLETE. B P Page 1 of 13 Operations- Summary Repor# Legal Well Name: 1 D-36 Common Wetl Name: 1D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 811/2005 Rig Name: NORDIC 2 Rig Number: Date From - To' Hours Task. Code ' NPT Phase Description of :Operations 7/16/2005 05:00 - 06:00 1.00 MOB P PRE Prepare to move rig off of well 1 D-42. 06:00 - 06:30 0.50 MOB P PRE Crew change and PJSM to move off well 06:30 - 07:00 0.50 MOB P PRE Pull off 1 D-42 07:00 - 07:30 0.50 MOB P PRE Lay out 30'x30' herculite 07:30 - 08:30 1.00 MOB P PRE Wait while Well Support removes hump in fron of 1D-36 08:30 - 09:00 0.50 MOB P PRE Remove tree cap. Install BOP equipment. Notify AOGCC of pending BOP test.Layout 100'x100' herculite. Position rig mats. 09:00 - 09:15 0.25 MOB P PRE PJSM review procedures for pulling over well. Call for rig water. 09:15 - 10:00 0.75 MOB P PRE Move onto 1 D-36 and level. Rig accepted at 0900hrs due to waiting on dirt work. 10:00 - 13:00 3.00 BOPSU P PRE NU BOPE 13:00 - 14:40 1.67 BOPSU P PRE Wait on water truck. 14:40 - 18:00 3.33 BOPSU P PRE Test BOPE 250psi low and 3500psi high. AOGCC rep Jeff Jones witnessing test. On initial body test found Peaks on newly installed kilt line. Replaced Greyloc ring. Proceed with testing okay. 18:00 - 19:00 1.00 BOPSU N WAIT PRE Shut down BOP test so that Well Site Leader can address some issues with respect to SIMOP's occuring on the pad. CPAI crew is excavating dirt around well 1 D-32 which is directly behind the rig. They are troubleshooting a reported casing leak to atmosphere. 19:00 - 22:30 3.50 SOPSU P PRE Finish BOP testing. 4 valves leaked. All were greased and held fine after greasing. 22:30 - 0.00 RIGU P PRE Stab injector. Pressure test inner reel valve. Pump slack management. 7/17/2005 00:00 - 01:00 1.00 RIGU P PRE Pump slack management. 01:00 - 03:30 2.50 RIGU N HMAN PRE Repair damage to spoke on Schlumberger coil reel. 03:30 - 07:00 3.50 RIGU P PRE Damage to spoke repaired. Cut coil to find end of aline. Cut 30' of coil to find aline. Dress end of coil tubing. Build coil aline head. Pull test to 35k PT connector to 3500psi. Circulate over bung hole 1 circulation while holding PJSM for pressure deployment of cleanout BHA. Checked WHP 675psi. 07:00 - 08:30 1.50 CLEAN P WEXIT Pressure deploy 2.74" mill and motor BHA. Pressure stack to 08:30 - 10:50 2.33 CLEAN P WEXIT RIH maintaining 700psi on well. Wt check at 10500' 32k RIH tagged at 11427' no pump seeing 3300psi annular pressure. 10:50 - 11:05 0.25 CLEAN P WEXIT Bring on pump 0=1.67 / 1.40 holding 400psi whp cleanout to 11502', taking returns to Tiger Tank. 11:05 - 13:30 2.42 CLEAN P WEXIT Displace wellbore fluids with 8.7ppg Flo-Pro while TOH following pressure schedule. Good mud to surface after displacing 102 bbls to TT. Take returns inside. Trapped 600 psi on well. Bleed down to 370psi prior to shutting in. 13:30 - 15:30 2.00 CLEAN P WEXIT Coil wt indicator showing i0k and should be zero or slightly negitive. Colt may be bent. Bleed down residual coil pressure through bleed port. (new mud) Coil is bent 3' above CTC. Undeploy BHA #1. 15:30 - 16:00 0.50 STWHIP P WEXIT Straighten coil. Install 3 RA tags in WE LSX whipstock 5.68' below TOW 16:00 - 17:25 1.42 STWHIP P WEXIT PU Weatherford LSX whipstock. MU to BHI tools and note tray face alignments. Pressure deploy. Stab injector. Surface test tools. PT lubricator to 500psi. Open well 370psi. Open EDC. 17:25 - 20:20 2.92 STWHIP P WEXIT RIH following pressure schedule. 20:20 - 20:35 0.25 STWHIP P WEXIT Log tie in pass over GR character at 11197'. Using Sperry Printed: 8/8/2005 7:43:10 AM BP Page 2 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1D-36 Spud Date: 911/2000 Event Name: REENTER+COMPLETE Start: 7121/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date' From - To Hours Task Code NPT Phase Description of Operations 7!17/2005 20:20 - 20:35 0.25 STWHIP P WEXIT MWD log as tie in tog as per geologist. Make up logging pass as per W F hand. Make -9' correction. 20:35 - 20:50 0.25 STWHIP P WEXIT RIH to 11440', pull up hole to 11419'. PU wt = 27 klbs. WS setting depth is 11419', WS is 9' long, top of WS will be at 11410'. Pressure up on coil to 3400 psi. Good indication of shear. Lost weight and pressure. Set down to confirm it is set. Good indication of weight loss on string wt and downhole WOB sensor. Open EDC. Pickup at 27 ktbs. 20:50 - 22:15 1.42 STWHIP P WEXIT POH to pick up window milling BHA. 22:15 - 22:30 0.25 STWHIP P WEXIT PJSM Re: undeployment and redeployment. Held meeting off of the critical path while POH with the whipstock setting BHA. 22:30 - 00:00 1.50 STWHIP P WEXIT Tag up at surface. Undeploy BHA following SOP. 7/18/2005 00:00 - 00:20 0.33 STWHIP P WEXIT Continue undeployment of WF setting tool BHA. All recovered ok, whipstock left in the hole as planned. 00:20 - 01:30 i.17 STWHIP P WEXIT Reconfigure BHI BHA for milling window. Check out on catwalk electrically. Replace packoffs in coil injector. Behead SLB slickline head. Slickline damaged during rig down. 01:30 - 01:50 0.33 STWHIP P WEXIT PJSM for deploying window milling BHA. 01:50 - 03:00 1.17 STWHIP P WEXIT Deploy window milling BHA. (BHA #3). 03:00 - 05:00 2.00 STWHIP P WEXIT RIH with BHA #3. Pumping at minimum rate thru an open EDC and following the pressure schedule. 05:00 - 05:15 0.25 STWHIP P WEXIT Log tie in pass down over GR marker. Make -13' correction. 05:15 - 06:00 0.75 STWHIP P WEXIT Tag top of WS at 11409.5'. Begin milling window. 1.63/1.29/3700 psi. lAP=550 psi, OAP=O psi. Pit vol = 331 bbls. 06:00 - 12:00 6.00 STWHIP P WEXlT Time milling window Q= 1.631 1.38 83°I° retums fs= 3650 200psi mw full open choke ECD= 11.65ppg slow pump to 1.5 fs= 3550 (new mud also contributing to high ECD's) ECD= 11.59 Q= 1.5 /1.32 88% returns 1100 hrs 11414.7' Q= 1.51 ! 1.44 seeing sand in samples Milled to 11415.8' (exit 14415.2') 12:00 - 12:30 0.50 STWHIP P WEXIT Drill fromation to 11423' 0= 1.511.47 12:30 - 14:15 1.75 STWHIP P WEXIT Ream window area. Run through wo motor. Clean 14:15 - 16:30 2.25 STWHIP P WEXIT TOH following pressure schedule. 16:30 - 17:20 0.83 STWHIP P WEXIT Pressure undeploy BHA. 370psi on well. 17:20 - 20:40 3.33 DRILL P PROD1 Coil appears to be bent just above coil conector. Cut 20' of coil and rehead. PT new CTC to 3500 psi. Pull test to 35 klbs. CTC weeped on first PT. Tighted connections and repeal. Tested at 3500, 1000, 5000, 200, 0, 200, 500, 3500 psi. Passed ok on all tests.. 20:40 - 21:00 0.33 DRILL P PROD1 PJSM Re: deployment of build section BHA. Emphasis placed on good coordination between SLB SL unit operator and Nordic DD. Discussed not getting in a hurry, but doing the job following the proceedure and working at a safe and efficient pace. 21:00 - 22:10 1.17 DRILL P PROD1 Deploy L1 lateral build section BHA. Can't get motor thru tubing hanger. PU, slack off numerous times. Try everything we can think of. Rock the lubricator. pump into the well, etc. Hard tag up right at the tubing hanger every time. Not going to be able to lubricate this BHA in the hole. Either need to drop motor bend and lubricate, or kill well and use the pipe wrench technique with this 2.8 degree motor. 22:10 -23:20 1.17 DRILL N WAIT PROD1 Discuss with DD and Geo reducing motor bend. Examine the Printed: 8/8/2005 7:43:10 AM gp Page 3 of t3 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21!2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code` NPT' Phase Description of Operations 7/18/2005 22:10 - 23:20 1.17 DRILL N WAIT PROD1 possibilty of going wide on the polygon while staying above the B shale. Discuss options with town engineer and Geo. Town geo confirms plan forward is ok. 23:20 - 00:00 0.67 DRILL P ~ PROD1 Adjust motor shims to 2.2 deg. Redeploy Build section BHA. 7/19/2005 00:00 - 00:30 0.50 DRILL P PROD1 Continue deploying BHA #4, Build section BHA for the L1 lateral. Made it past tubing hanger with this BHA with no trouble. 00:30 - 02:30 2.00 DRILL P PROD1 RIH with build section BHA. 02:30 - 02:45 0.25 DRILL P PROD1 Log tie in pass down over GR marker at 11197'. Make -14' correction. 02:45 - 06:00 3.25 DRILL P PROD! RIH thru window. Free spin 3520 psi at 1.6 bpm. Tag up at 11425'. Begin drilling. 1.6/1.d5/3700 psi. Losing about 20 bbls/hr. Pit volume = 450 bbls. IAP=600 psi. OAP=O psi. ECD=11.76 ppg, BHP=3844 psi. 06:00 - 09:30 3.50 DRILL P PROD1 Continue drilling build section f/ 11470' 0= 1.54 ! 1.44 ECD= 11.64 1-2k wob 20-30'lhr 09:30 - 09:45 0.25 DRILL P PROD1 Wiper trip to the shoe. 09:45 - 14:00 4.25 DRILL P PROD1 Resume drilling. 14:00 - 15:00 1.00 DRILL P PROD1 Drilling ahead. Build and tum coming in as plan. Getting better dog legs than expected with a 2.2 degree motor. ROP=15-40 fph and ratty. Drilling at 1.59/1.51!3700 psi. Free spin =3480 psi at 1.58 bpm. Pit Volume = 351 bbls. IAP=386 psi, OAP=O psi. 15:00 - 16:45 1.75 DRILL P PROD1 Build and turn section completed. POOH to pick up lateral section BHA. Ratty pickup, possibly due from siderite stringers in hole. ROP thru this section was ratty and slow, and we are seeing pulls at the same depths. 16:45 - 17:05 0.33 DRILL P PROD1 Hold PJSM Re: Undeployment. Discuss good communications between SLB SL operator and Nordic driller. Focus attention on moving the blocks and SL unit in unison, and staying off the radio when stripping the injector up. We reviewed the step by step proceedure in detail, and made job assignments. 17:05 - 18:30 1.42 DRILL P PROD1 Undeploy L1 build section BHA. (BHA #4). 18:30 - 20:15 1.75 DRILL P PROD1 Deploy L1 lateral BHA (#5) 20:15 - 22:00 1.75 DRILL P PROD1 Run in hole. Maintain BHP following WHP schedule.. 22:00 - 22:30 0.50 DRILL P PROD1 Log GR pass to tie in RA tag to main well bore. Subtract 15' correction. Log RA tag at 11,415.7. TOW: 11,410'. BOW: 11,415.4' . RIH to btm. Hole smooth. 22:30 - 00:00 1.50 DRILL P PRODi Drill ahead from 11,700'. 3550 psi fs C~4 1.56 in.1.38 out. 100-300 dpsi. DHWOB: 1k-2k#. WHP/BHP/ECD: 33/3940111.98 ppg. INCJAZM/TF: 92.1/75.8/90L. IA/OA/PVT: 292/0/332 bbls. 7/20/2005 00:00 - 06:00 6.00 DRILL P PROD1 Drill ahead from 11,757'. 3490 psi fs (~ 1.61!1.41. 100-3200 dpsi. DHWOB:1.5-2.5k#. WHP/BHP/ECD:33l3940l11.98 ppg. !NClAZMlrF: 92.ir/5.8/90L. fA/OAlPVT: 464/01277 bbls. ROP varying from 40 to 70 fph with numerous stalls. 06:00 - 07:40 1.67 DRILL P PROD1 11926'. Continue drilliing ahead. Fast ROP intervals with an occasional hard streak. Drilling at 1,.56!1.46/3880 psi. Pit volume =270 bbls. IAP~t80 psi, OAP=O psi. ECD=12.43 ppg, BHP=4083 psi. 07:40 - 08:15 0.58 DRILL P PROD1 Wiper trip to window. Clean pickup off bottom. Slight amount Printed: 8/8/2005 7:43:70 AM gp Page 4 of,13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1D-36 Spud Date: 9!1/2000 Event Name: REENTER+COMPLETE Start: 7!2112005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDIC 2 Rig Number: Date.. From - To Hours 'Task Code NPT Phase Description of Operations 7!20/2005 07:40 - 08:15 0.58 DRILL P ~ PROD1 of motor work from 11780'-11700'. Much less than we observed yesterday during the wiper trips after drilling the build section. 08:15 - 09:20 1.08 DRILL P PROD1 Resume drilling. Free spin 3850 psi at 1.55 bpm. Drilling at 1.56/1.51/3950 psi. Pit volume 245 bbis. Vac truck coming to shuttle fluid. 09:20 - 10:15 0.92 DRILL P PROD1 357 bbis in pits after vac truck delivery. Drilling ahead. 10:15 - 10:45 0.50 DRILL P I PROD1 Wiper trip to window. Clean PU off bottom at 26 klbs. Slight bobble of motor work at 11782'. Possibly cuttings beds at the I start of the build section. No real problem. 10:45 - 10:50 0.08 DRILL P PROD1 Log tie in pass over RA tag. Make +3' correction. 10:50 - 11:20 0.50 DRILL P I PROD1 Continue back in hole on wiper. 11:20 - 14:00 2.67 DRILL P I PROD1 Resume drilling. 14:00 - 15:00 1.00 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 25 kfbs. Clean to window except for 1 little blip of motor work at 11790'. 15:00 - 18:00 3.00 DRILL P PROD1 Drill ahead from 12325'. 18:00 - 18:45 0.75 DRILL P PROD1 Drill ahead from 12,466'. 3950 psi fs ~ 1.54!1.48 bpm. 100-300 dpsi. DHWOB: 0.5- 1.5k#. WHP/BHP/ECD: 33!4210/12.84 ppg. INC/AZMlrF: 87/23/1508. IA/OA/PVT: 154/327/206 bbis. ROP 30-70 fpm. 18:45 - 20:00 1.25 DRILL P PROD1 Wiper trip to 11,000'. Hole very smooth. 20:00 - 23:30 3.50 DRILL P PROD1 Drill ahead from 12,475'. Call for trucks to swap mud. Complete mud swap. OId mud: 4000 psi fs at 1.51/1.41 bpm. BHP: 4210 psi /ECD: 12.8 ppg. New mud: 3500 psi fs at 1.56/1.56 bpm. BHP: 3890 psi / ECD: 11.8 ppg. Big improvement. 23:30 - 00:00 0.50 DRILL P PRODi Drill ahead from 12600'. ROP varying from 10 to 155 fph. 7/21!2005 00:00 -00:15 0.25 DRILL P PRODi Drill ahead to 12650'. 00:15 - 00:45 0.50 DRILL P PROD1 Wiper trip to 11300'. Weld repair reel spoke. 00:45 - 01:00 0.25 DRILL P PROD1 Log gr tie in to RA tag. Add 4' correction. Oi:00 - 01:45 0.75 DRILL P PROD1 Wiper trip in hole. Hole very smooth in and out. 01:45 - 05:45 4.00 DRILL P PROD1 Drill ahead from 12,650'. 3800 psi fs ~ 1.61!1.61. 100-200 dpsi. DHWOB: 0.75 - 1.95k#. WHPlBHP/ECD: 33/3850111.8 ppg. 1 NC/AZM/T F: 92.2/39.4/908. IA/OA/PVT: 95/316/324 bbis. Very erratic ROP. Able to get good DHWOS 1 k-2k# 05:45 - 07:00 1.25 DRILL P PROD1 Wiper trip to window. Clean pickup. Clean to window and back down. No problems. 07:00 - 11:30 4.50 DRILL P PROD1 Free spin 3700 psi at 1.55 bpm. Drilling at 1.55!1.54/3750 psi. String wt = -500 lbs. WOB=1500 lbs. ECD=21.2 ppg, BHP=4024 psi. Pit Vol=322 bbis. IAP=171 psi. OAP=340 psi. 11:30 - 13:05 1.58 DRILL P PROD1 Wiper trip to the window. Clean PU off bottom at 27 klbs. 13:05 - 18:00 4.92 DRILL P PROD1 Resume drilling from 12950. 272 bbis in pits. Call for Vac truck to add new mud. 18:00 - 21:00 3.00 DRILL P PROD1 Drill ahead from 13005'. 4000 psi fs ~ 1.61/1.57. 100-200 dpsi. DHWOB: 0.50 - 1.35k#. WHP/BHP/ECD: 33/4200(12.7 Printed: 8!812005 7:43:10 AM BP Page 5 of 13 Operations Summary Report' Legal We11 Name: 1 D-36 Common Well Name: 1 D-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To 1 Hours ~ Task ~ Cotle 1 NPT .7/21/2005 118:00 - 21:00 I 3.001 DRILL I P 21:00 - 22:00 I 1.001 DRILL I P 22:00 - 23:45 I 1.751 DROLL I P II 7/22/2005 00:00 - 02:00 ~ 2.00 DRILL P 02:00 - 06:00 ~ 4.001 DRILL ~ P 06:00 - 07:20 ~ 1.331 DRILL ~ P 07:20 - 09:15 ~ 1.92 ~ DRILL ~ P 09:15 - 13:00 I 3.751 DRILL I P 13:00 - 14:00 I 1.00 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 16:45 1.75 DRILL P 16:45 -17:00 0.25 DRILL P 17:00 - 18:15 I 1.25 (DRILL I P Spud Date: 911 /2000 Start: 7/21 /2005 End: 8/1 /2005 Rig Release: 8/1/2005 Rig Number: Phase Description of Operations `' PROD1 ppg. INCIAZMlTF:87.3l87.5/45L. IA/OA/PVT:249/336/357 bbls. PROD1 Drill ahead from 13075'. DHWOB is 0.5k to 1.3k#, but very hard to keep pipe moving and get differential on motor. Decide to try Alpine glass beads. Mix 125 bbfs of 12 ppb inn flo pro mud. PROD1 Wiper trip to window. Log gr tie in across RA tag. Add 6.5' correction. Hole very smooth. PROD1 Drill ahead from 13,110'. PROD1 Drill ahead from 13,110'. 3900 psi fs ~ 1.52/1.42. 0-100 dpsi. DHWOB: 0.5 - 1.3k#. WHPIBHPIECD: 33/4180112.6 ppg. 1NC/AZM/TF: 86.5/75.9/105L. IA/OA/PVT: 270/334/307 bbls. Start 120 bbl glass bead pill. Mud density in: 8.7 ppg. DHWOB increased slowly as beads came up backside. Up wt 23k# with beads vs 26k# without at 13157' at 1.51 bpm ~ Dn wt 3.9k# with beads vs 2.3 k# without while RIH at 30 fpm ~ 1.51 bpm Max DHWOB increased from 1.2# to 1.5k#. Able to maintain a steady 20 fpm ROP for a while. No significant change in motor work. Shakers partially blinded off ,losing 0.1 bpm mud. PROD1 Drill ahead to 13215'. Stacking max weight. 1.25k# DHWOB. ROP: 15-20 fph. Slow going. PROD1 Continue drilling ahead with very slow ROP. 1.5611.52/4020 psi. Pit volume = 255 bbls. IAP=310 psi, OAP=334 psi. ECD=12.7 ppg, BHP=4220 psi. WOB=1000 lbs. PROD1 Wiper trip to window. Clean PU off bottom at 25 klbs. Clean up to window. Clean back in hole. Pump 30 bbl pill of mud with 10#lbbl of Alpine Glass beads to observe if there is any improvement in ROP. PROD1 Tag bottom at 13249'. Free spin 1.5711.5614000 psi. Drilling at 1.5811.5414100 psi. Glass beads just coming out. WOB=1260 Ibs prior to beads hittiing formation. W06= 1300 after hitting formation. No significant change in WOB or ROB with a 30 bbl sweep. ROP still 20-30 fph. PROD1 ROP continues to trend down. Not making much hole, and having difficulty getting weight to bit. PRODi Have only made 2' in last hour. ROP now unacceptable. Possibly a combination of siderite, worn bit, and low WOB. Need to either POH and pick up Agitator, or call this TD. Begin wiper trip. Call town and ask for orders. Clean PU off bottom. Clean in OH to window. PROD1 Town confirms plan forward is to drill additional footage. Continue trip OOH to pick up Agitator tool and Baker TT checks. PROD1 PJSM prior to undeploying BHA. Review proceedure. Focus on good coordination between driller and SLB slickline operator. PROD1 Undeploy BHA #5. LD motor and bit (HCC STR RWD bi-cent 1-1-I, in overall good shape with no broken nose cutters. Bit recovered balled up with clay. Motor checked out ok). SIWHP: 435 psi. Printed: 8/8/2005 7:43a0AM BP` Page 6 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9!1!2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1/2005 Rig Name: NORDlC 2 Rig Number: .Date From - To Hours Task 'Code NPT Phase Description of Operations 7/22/2005 18:15 - 19:30 1.25 DRILL P PROD1 Hold PJSM with night crew to review deploy procedure. Also discuss re-configured BHA with agitator & dart check valve. MU BHA #6 (1.0 deg mtr w! HYC DS 100 bicent bit). Stab coil. Test MWD. Get on well. 19:30 - 22:15 2.75 DRILL P PROD1 Run in hole. Shallow test agitator. Coil vibration indicates tool is working. Continue in hole. Circ at min rate with EDC open. 22:15 - 22:30 0.25 DRILL P PROD1 Log gr tie in from 11430'. Subtract 10' correction. 22:30 - 23:30 1.00 DRILL P PROD1 Continue to run in hole. Down wt near btm: 4500#. Noted 2500# without agitator yesterday. Tag TD at 13298'. 23:30 -00:00 0.50 DRILL P PROD1 Drill ahead from 13398'. 3900 psi fs (~ 1.44 in/1.42 out. 100-200 dpsi. DHWOB: 1.95k#. Initial ROP: 10-20 fph. WHP/BHP/ECD: 11!4148/12.48 ppg. IA/OAlPVT: 154/3581371 bbls. 7/23/2005 00:00 - 03:00 3.00 DRILL C PRODi Drill ahead from 13310'. 4000 psi fs ~ 1.52 in/1.52 out. 100-200 dpsi. DHWOB: 1.5k - 2.Ok#. INC/AZM/TF: 84.6/63.7/120L. IA/OA/PVT: 245/358!251 bbls ROP: 10-50 fph 03:00 - 03:45 0.75 DRILL C PROD1 Drill ahead from 13380'. Alternating hard spots with fast drilling intervals. Appear to be in a Iithology change. 03:45 - 05:00 1.25 DRILL C PROD1 Ciculate bottoms up to get sample. Wiper trip to clean hole. Wait on town to evaluate logs. 05:00 -06:00 1.00 DRILL C PROD1 Town decision is to drill up to 50 additional feet. We are close to, but not in B shale yet. 06:00 -06:45 0.75 DRILL C PRODi Resume drilling. Drilling at 1.49/1.45/4170 psi. ROP=70 fph. String wt = 500 lbs. WOB =1000 lbs. IAP=260 psi, OAP=350 psi. ECD=12.68 ppg, BHP=4220 psi. Agitator made a huge difference from yesterday. 06:45 - 07:15 0.50 DRILL C PROD1 BHI tool may be near falure. It keeps switching on and off. Possibly due to vibration from the Agitator? 07:15 - 07:25 0.17 DRILL X DFAL PRODi BHI equipment not working. Could be uphole or downhole. MWD engineer needs some time to sort it out. Make mini wiper trip to give him some time. Clean PU off bottom. Problem is downhole. BHA keeps shutting off. It is working intermittanly. Resume drilling and drill until it fails. 07:25 - 08:10 0.75 DRILL C PROD1 Free spin 4076 psi at 1.49 bpm. Drilling at 1.49/1.46/4200 psi. WOB=1500 lbs. String wt = -7000 lbs. ROP=26 fph. Possibly coming into the B shale that we are looking for. 08:10 - 08:15 0.08 DRILL X DFAL PROD1 BHI tool shut down. Need to make wiper trip to give MWD engineer time to sort out situation. MWD tool working again. 08:15 - 10:55 2.67 DRILL C PROD1 Resume drilling. ROP has slowed down, but we are able to gat 2500 !bs WOB with -76001bs string weight. This is significantly better than we were able to achieve yesterday when we were at lockup. 10:55 - 1 i:05 0.17 DRILL X DFAL PROD1 BHI MWD lost power again. Wiper to see if they can sort it out. 11:05 - 11:20 0.25 DRILL C PROD1 Power back on. Not sure what the problem it, but it appears to be downhole. Resume drilling. 11:20 - 14:00 2.67 DRILL P PROD1 Geo has seen the B shale on the GR log. Make wiper to window for final Tie in. Clean PU off bottom. Clean in open hole. Open EDC, pull thru the window. Pump at max rate, 1.92 bpm, 4240 psi. 14:00 - 14:40 0.67 DRILL N DFAL PROD1 Attempt to log tie in pass at RA tag. BHI having downhole Printed: 8/8!2005 7:43:10 AM gp Page 7 of #3 Operations Summary Report Lega{ Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1!2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8!1!2005 Contractor Name: NORDIC CALISTA Rig Release: 8/112005 Rig Name: NORDIC 2 Rig Number: Date from - To Hours Task Code NPT Phase Descrption'of Operations 7/23/2005 14:00 - 14:40 0.67 DRILL N DFAL PROD1 problems. Can't get GR log. MWD engineer can't get downhole BHA working again. Probably damaged by vibration from Agitator tool. It has been intermitant several times today, and finally gave up the ghost. 14:40 - 15:50 1,17 DRILL P PROD1 RIH blind to lay in KWF. Clean all the way to TD. 15:50 - 17:00 1.17 DRILL P PROD1 POOH, laying in 10.2# KWF. The first 30 bbls contained 6#/bbl of the large sized Alpine beads. They were pumped thru the BHI motor with no problems observed. Pulled up smooth in open hole. No problems. 17:00 - 19:30 2.50 DRILL P PROD1 Pull thru window, circulate bottoms up. Pull out of hole circulating at f .4 bpm. 19:30 - 21:00 1.50 DRILL P PROD1 At surface. Flow check for 15 minutes. Well stable. Get off well. Unstab coil. LD Inteq tools. 21:00 - 22:00 1.00 CASE P RUNPRD RU floor to run liner. Trouble shoot mwd failure from previous run. Tool surface check ok. Coil a-line cable check good. 'Fault found in cable from TL camp (mwd office} to rig. Weekly function test BOPs. 22:00 - 22:15 0.25 CASE P RUNPRD Hold PJSM with crew to discuss running liner. Review hazards, job assignments, running order and more. 22:15 - 00:00 1.75 CASE P RUNPRD MU 60 jts 2-3/8" 4.6# L-80 R2 STL slotted and solid liner w! indexing guide shoe. 7/24/2005 00:00 - 01:00 1.00 CASE P RUNPRD Continue to MU 2-3/8" liner assembly. 01:00 - 01:45 0.75 CASE P RUNPRD MU mwd tools and GS spear. Stab coil. 01:45 - 03:15 1.50 CASE P RUNPRD Run in hole with liner. 03:15 -04:15 1.00 CASE P RUNPRD At window. 7.3k# do wt, 29.7k# up wt. Subtract 12' correction. Continue in hole, log gr tie in from 13105' at 2.5 fpm. Sk# do wt at 2.5 fpm. Subtract 2.5' correction. Continue in hole. Liner btm at 13,310'. Liner top at 11,394'. Final do wt: 5k# at 30 fpm. Bring on pumps at 1.47 bpm at 4150 psi. Coil up wt 24.5k#. Released from liner. 04:15 -04:45 0.50 CASE P RUNPRD Pull up hole to 13,110'. Tie in to PDC log. Log GR and CCL down to 5' above TOL. 04:45 - 06:50 2.08 CASE P RUNPRD Pull out of hole. 06:50 - 07:30 0.67 CASE P RUNPRD Tag up at surface. Flow check. No flow observed. Rig down liner running BHA. 07:30 - 08:15 0.75 STWHIP P WEXIT Make up BHI MWD tool, Weatherford Alpha Fury setting tool and WS-R-BB packer anchor. Scribe orienting slot on anchor to MWD tool. 08:15 - 11:10 2.92 STWHIP P WEXIT RIH with BHA #8 to set whipstock anchor for L2 lateral window. RIH at 70 fph, pumping at 0.5 bpm thru an open EDC. 11:10 - 11:45 0.58 STWHIP P WEXIT Log tie in pass up with BHI MWD tools, accross GR marker around 11200'. Make -11.5' correction. Position W S anchor with top at 11370'. Shut EDC. Orient slot to low side. Bring on pumps, pressure tup to 4600 psi. Hold pressure for 2 minutes. PU, got good indication of shear. Set back down, tagged up on top of anchor at 11370.9'. Good indication of set. 11:45 - 13:30 1.75 STWHIP P WEXIT POOH to pick up WS tray. Note -Orienting slot is oriented straight down. Will need to make sure that WS tray orienting lug is 180 degrees out to WS tray face when we pick up WS Printed: 8/8/2005 7:43:10 AM BP Page 8 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9!1!2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8!112005 Contractor Name: NORDIC CALISTA Rig Release: 8hI2005 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Cotle ' NPT Phase Description of Operations 7/24/2005 11:45 - 13:30 1.75 STWHIP P WEXIT tray. 13:30 - 13:45 0.25 STWHIP P WEXIT Hold PJSM while POOH to discuss BHA swap out. 13:45 - 14:15 0.50 STWHIP P WEXIT Flow check well. Break off injector. Lay down WF Alpha Fury Settling tool. (BHA #8) 14:15 - 14:50 0.58 STWHIP P WEXIT Make up BHA #9, WF whipstock tray with RA tag. Distance from top of WS to RA tag is 2.04'. Orienter scribed to the orienting lug. Tray face 180 degrees out to the orienting lug. Need low side tool face when latching WS tray. 14:50 - 17:30 2.67 STWHIP P WEXIT RIH with BHA #9 to set whipstock tray. Pumping minimum rate, RfH at 70 fpm. 17:30 - 18:00 0.50 STWHIP P WEXIT Log GR tie in from 11200'. Subtract 15' correction. 18:00 - 18:30 0.50 STWHIP P WEXIT Orient to 180 deg. Up wt: 25.4k#. Dn wt: 7.3k#. RIH at 5 fpm. Circ at min rate: 1750 psi ~ .59 bpm. EDC open. Tag packer at 11371'. Set do 3k#. PU to 26k#. Set do again with 3k# dn. PU to 30K and jar off. Pressure well to 500 psi. Held ok. Pressure up to 970 psi. Held ok. Bleed off. WS appears to be set. 18:30 - 20:30 2.00 STWHIP P WEXIT Pull ou4 of hole. ' 20:30 - 21:45 1.25 STWHIP P WEXIT At surface. Flow check. Get off well. Unstab coil. LD WS running tools. (WS in hole). MU window milling assembly (#10). Stab coif. Test mwd. Get on well. 21:45 -00:00 2.25 STWHIP P WEXIT Run in hole. Prep to swap out 10.4 # mud for 8.6# flo-pro. 7/2512005 00:00 -00:15 0.25 STWHiP P WEXIT Tag WS at 1Log gr tie in from 11,210'. Subtract 15' correction. RIH. 00:15 - 06:00 5.75 STWHIP P WEXIT Tag whipstock at 11359'. Flag pipe. Continue to displace well from 10.4 to 8.6 ppg mud. Pump pressure & free spin varying as a result. 8.6# mud to surface. 3650 pis fs at 1.55 iN1.59 out. Several stalls getting started. DHWOB slowly increasing from 0.25k# up to 2.5k# Begin time milling at 1' per hr. WHP/BHP/ECD: 15/3908/12.0 PPg• Observe metal on magnets. 06:00 - 07:25 1.42 STWHIP P WEXIT Milling rathole at 10'/hr. 1 for 1 returns. Window depths (Prior to final tie in on build section run) Window Top = 11359' RA Tag = 11361' Window Bot = 11363.4' 07:25 - 09:25 2.00 STWHIP P WEXIT TD 10' of rathole at 11373'. Ream/Backream window. Make 3 passes. Had a slight over pull with dry drifting. Make an additional 2 passes. Dry drift window again. Smooth down but a slight bump on weight at top of window. Ream just the top 2' of window. Not getting any motor work. Ream for 30 minutes. Dry drift again. Again a slight bump on tension as we pull up thru it. Nothing additional we can do, if we don't get any motor work. 09:25 - 11:15 1.83 STWHIP P WEXIT POOH following back pressure schedule, and pumping thru an open EDC. 11:15 - 11:30 0.25 STWHIP P WEXIT Safety meeting prior to undeploying BHA. Reviewed proceedure, and job assignments. Discuss hazards. Assign the driller to read the checklist as he undeploy's the BHA. 11:30 - 12:45 1.25 STWHIP P WEXIT Undeploy BHA #10, L2 window milling BHA. Both mills Printed: 8/6/2005 7:43:10 AM gp Page 9 of i3 Operations Summary Report Legal Wel! Name: 1 D-36 Common Weli Name: iD-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8!1/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code' 'NPT Phase Description of Uperatjons 7!25(2005 11:30 - 12:45 1.25 5TWHIP P WEX1T recovered at 2.73" go, 2.72" no go. 12:45 - 15:50 3.08 DRILL P PROD2 Cut off CTC. Dress end of eline. Pump slack management. Cut off excess coil. Found eline 120' up inside coil. Build new eline head/CTC. Pull test to 35 klbs. Can't pressure test. Rig mud manifold torn apart. i 5:50 - 16:40 0.83 DRILL N RREP PROD2 Rig crew replacing a valve on rig floor manifold. Started job during slack management, and not finished yet. 16:40 - 17:45 1.08 DRILL P PROD2 Pressure test CTC to 4000 psi. Stab back on well. Pump 1 CT volume forward to complete slack management process. 17:45 - 18:15 0.50 DRILL P PROD2 PJSM prior to deploying Build section BHA. BHA #11. 18:15 - 19:30 1.25 DRILL P PROD2 Deploy BHA #11 (2.2 deg mtr w/ bi-cent). Stab coil. Test mwd tools. Get on well 390 psi SIWHP after opening swab & master. 19:30 - 21:00 1.50 DRILL P PROD2 Run in hole. Maintain 420 psi WHP while circ at min rate. 21:00 - 21:30 0.50 DRILL P PROD2 Log gr tie in from 11210'. Subtract 15' correction. RIH through window with HS TF. 21:30 - 00:00 2.50 DRILL ~ P PROD2 Orill ahead from 11376'. 3700 psi fs ®1.6 in/i.6 out. 100-200 dpsi. DHW06:1k#-2.5k#. WHP/BHP.ECD:15/3950/12.2 ppg. iA/OA/PVT: 0/332/381 bbls.TF: 30L 7!26!2005 00:00 -00:30 0.50 DRILL P PROD2 Drill ahead from 11,400'. 00:30 - Oi:00 0.50 DRILL P PROD2 Pull into cased hole and re-log main well bore from 11,210'. Add 1' correction to tie into PDC Iog.RIH to 11,380. tog RA tag. Found it at 11,362'. Final top of window: 11,360' Final RA tag: 11,362' Final bottom of window: 11,364.4'. 01:00 -06:00 5.00 DRILL P PROD2 Drill ahead from 11420'. 3700 psi fs ~ 1.6 iN1.6 out. 100-200 dpsi. DHWOB: 1k# -3.5k#. WHP/BHP.ECD: 15/3950/12.1 ppg. IA/OA/PVT: 77/375/376 bbls. Getting 35-40 deg dog leg in build. Landing shallower than needed. Roll TF to 285-310 to increase tum with build under control. Begin hitting hard streaks at 11,480'. ROP varying from 10 to 50 fph. 06:00 - 07:15 1.25 DRILL P PROD2 Continue drilling ahead. 1.65/1.68/4150 psi. W06=32001bs, String wt=600 lbs. BHP=4050 psi. ECD=12.48 ppg. IAP=115 psi, OAP=370 psi. Pit volume = 371 bbls. 07:15 - 09:15 2.00 DRILL P PROD2 Window landed at 11600'. POH to pick up lateral section BHA. PU weight was 25 klbs. A little ratty on pickup. Clean the rest of the way in OH. Got a slug of cuttings just as we tagged up. Did a job with coil to clean it up. 09:15 - 09:30 0.25 DRILL P PROD2 Stop at 500'. Hold PJWM with Nordic and SWS crews prior to undeploying BHA. Trap 450 psi on welt. 09:30 - 11:45 2.25 DRILL P PROD2 Undeploy BHA #11. Bit recovered 1,2, balled up. Adjust motor bend to 1.1 deg. Pick up rebuilt Hughes bi center bit, 2.7" x 3.0". Pressure deploy BHA #12. 11:45 - 13:50 2.08 DRILL P PROD2 RIH with BHA #121o begin drilling lateral section of L2 lateral. 13:50 - 14:05 0.25 DRILL P PROD2 Log tie in pass over RA tag in whipstock. Make -16' correction. 14:05 - 17:15 3.17 DRILL P PROD2 RIH. Free spin 3830 psi at 1.6 bpm. Tag up at 11597'. Begin drilling lateral section. 1.61!1.63/3950 psi. Drilling at 100 fph. Pit volume = 378 bbls. fAP=O, OAP=330 psi. BHP=3998 psi, ECD=12.18 PPg• 17:15 - 18:15 1.00 DRILL P PROD2 Wiper trip to window. PVT 384 18:15 - 00:00 5.75 DRILL P PROD2 Orill from 11750' 1.56/4000/85L w/ full returns w/ 100-300 psi Prirtttsd: 8(8!2005 7:43:10 AM gp :'Page 10 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1 D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1!2005 Rig Name: NORDIC 2 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of operations 7126/2005 18:15 -00:00 5.75 DRILL P PROD2 dill w/ 2-3k wob w/ 4000 psi DHPl12.25 ECD at 91 deg and 7/27/2005 00:00 - 01:00 1.00 ~ DRILL P PROD2 continue turn in mostly hard (slow) streaks PVT 372 Continue drilling from 11877' w/ slow ROP in siderite 01:00 - 01:50 0.83 DRILL P PROD2 Wiper to window, clean both ways 01:50 - 07:00 5.17 DRILL P PROD2 Drill from 11900' 1.56/3930/75L w! 100-300 psi dill, 2-3k wob w! 4040 psi DHP/12.37 ECD at 91 deg w/ slow penetration in siderite 07:00 - 10:00 3.00 DRILL P PROD2 Drill ahead from 11988'. 4000 psi fs ~ 1.6 in/1.6 out. 100-200 dpsi. DHWOB: 2k# -3.5k#. WHPlBHP.ECD: 15/4060/i2.4 ppg. IA/OA/PVT: 220/3251356 bbls. Continued slow drilling in C4 interval. Noting a lot of siderite in samples. Begin mud swap at 0845. ECD with old mud: 12.4, BHP 4060 psi, circ press fs: 4000 psi. ECD with new mud: 11.8, 8HP 3870 psi, circ press fs: 3750 psi 10:00 - 15:00 5.00 DRILL P PROD2 Drill ahead from 12,035'. ROP avg about 10 fph. 15:00 - 18:00 3.00 DRILL P PROD2 Drill ahead from 12,086'. PVT 403 18:00 - 21:40 3.67 DRILL P PROD2 Drill from 12125' 1.77/3900l110L w/ 100-250 psi dill, 2-2.5k wob w! 12.05 ECD at 90 deg at 6307' TVD. Swap TF to right at 12140'. Penetration rate incr at 12175' PVT 399 21:40 - 22:45 1.08 DRILL P PROD2 Wiper to window, clean both ways 22:45 - 00:00 1.25 DRILL P PROD2 Drill from 12200' 1.613600/1108 w/ 200-400 psi dill, 0.5-2.Ok wob w/ 12.0 ECD at 88 deg at 6309' TVD at 60'Rtr to 12220' and then back into siderite Gen 1 shut down. Change SCR assignment to use #2 & #3 7!2812005 00:00 - 06:00 6.00 DRILL P PROD2 Continue drilling in siderite from 12221' 1.613600/1208 w/ 100-300 psi dill, 1.5-2.5k wob at 3890 psi DHP/11.9 ECD at 88 deg at 6310' TVD 06:00 - 10:30 4.50 DRILL P PROD2 Drill ahead from 12,295'. 3600 psi fs ~ 1.6 in(1.6 out. 100-200 dpsi. DHWOB: 1.5k# -3.Ok#. WHP/BHP.ECD: 15/3940112.0 ppg. IA/OA/PVT: 250/3331382 bbls. I NC/AZMIf F: 88.1 / 14.7/65 R. Continued very stow drilling, attributed to siderite in C4 interval. 10:30 - 11:30 1.00 DRILL P PROD2 Wiper trip to 10,700'. Open EDC up inside casing. RIH to 11,286'. Hold 200 psi Whp at 0.53 bpm. 11:30 - 12:15 0.75 DRILL P PROD2 Trouble shoot Genset #1 problem while inside casing. 12:15 - 12:45 0.50 DRILL P PROD2 Log gr tie in from 11270'. Add A' correction. 12:45 - 13:15 0.50 DRILL P PROD2 Continue wiper trip back to bottom. 13:15 - 18:30 5.25 DRILL P PROD2 Drill ahead from 12,350'. PVT: 372 18:30 - 23:00 4.50 DRILL P PR002 Drill from 12440' 1.53/3450/758 w/ 100-300 psi dill, 1-3k wob at 12.1 ECD at 87 deg at 6320' TVD. Drill to 12500' (6324' TVD) PVT 379 23:00 -00:00 1.00 DRILL P PROD2 Wiper to window 7/29/2005 00:00 -00:15 0.25 DRILL P PROD2 Finish wiper from window, clean both ways 00:15 - 05:15 5.00 DRILL P PROD2 Drill from 12500' 1.52/36001808 w! 100-250 psi dill, 1-2k wob w/ 4000 psi DHP/12.2 ECD at 84 deg (6330' TVD) and miserably slow and still in siderite. Start losing 2 bph at 12520' PVT 349 05:15 -06:00 0.75 DRILL P PROD2 Wiper to window, clean 06:00 - 08:00 2.00 DRILL P PROD2 POOH for bit following pressure schedule 08:00 - 09:30 1.50 DRILL P PROD2 PJSM. Undeploy BHA. Blow down BHA on catwalk with new plumbing hook up to pits. Worked well. Bit pilot cutters not Printed: 8/812005 7:43:70 AM BP i?age t 1 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: i0-36 Spud Date: 9!1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8!1!2005 Rig Name: NORDIC 2 Rig Number: Date- From - To Hours Task Code NPT Phase 'Description of Operations 7/29/2005 08:00 - 09:30 1.50 DRILL P PROD2 chipped or missing, but significantly wom. {2-2-1) 09:30 - 14:00 4.50 BOPSU P PROD2 Bi-weekly BOP pressure test. Witness waived by AOGCC J. Crisp. 14:00 - 15:30 1.50 DRILL P PROD2 Hold PJSM. MU BHA #13 (1.1 mtr w( new HCC bi-cent). 385 psi SIWHP once master & swab were opened. Stab coil. Get on well. 15:30 - 17:45 2.25 DRILL P PROD2 Run in hole. Follow BHP pressure schedule and circ at minimum rate. 17:45 - 18:00 0.25 DRILL P PROD2 Log gr tie in from 11,210'. Corr -12' 18:00 - 18:30 0.50 DRILL P PROD2 Wiper to TD tagged at 12551', clean PVT 320 18:30 - 21:25 2.92 DRILL P PROD2 Drill from 12551' 1.53/1.48/3630/808 w! 100-300 psi dill, 1-2k wob, w/ 4080 psi DHP/12.4 ECD at 84 deg at 60'/hr. Losses increased at 12660' to 1.53!1.37 or about 10 bph, and then to 1.52/1.25 at 12695' {vicinity of C4/C3 interface as well as fault). Drill to 12700' (6348' TVD) 21:25 - 23:15 1.83 DRILL P PROD2 Wiper to window, clean both ways 23:15 - 00:00 0.75 DRILL P PROD2 Drill from 12700' 1.53/1.40/3580/85L w/ 100-500 psi dill, 0.5-1.5k wob w/ 12.3 ECD at 84 deg at 50-60'/hr. Drill to 12747 (6352' TVD} PVT 266 7/30/2005 00:00 - 00:10 0.17 DRILL P PROD2 100' wiper to remove TF change dogleg while swap pumps to change leaking swab 00:10 - 02:30 2.33 DRILL P PROD2 Drill from 12747' 1.5/1.38/3650/60L w/ 100-350 psi dill, 0.5-1.5k wob w! 4090 psi DHP/12.4 ECD at 85 deg to 12850' (6358' TVD) PVT 244 02:30 -04:20 i.83 DRILL P PROD2 Wiper to window, clean both ways PVT 225 04:20 - 06:00 1.67 DRILL P PROD2 Drill from 12850' 1.50/1.40/3700/85L w/ 100-350 psi dill, 0.5-1.5k wob w/ 12.5 ECD at 90 deg 06:00 - 08:15 2.25 DRILL P PROD2 Drill ahead from 12,920 3700 psi fs ~ 1.5 in/1.45 out. 100-200 dpsi. DHWOB: 0.5k# -2.Ok#. WHPJBHP.ECD: 15/4145/12.6 ppg. IA/OA/PVT: 1251339/209 bbls. I NC/AZM/TF: 86.5/44.7/85 L. 08:15 - 09:30 1.25 DRILL P PROD2 Wiper trip to 10,800'. Hole smooth. 09:30 - 09:45 0.25 DRILL P PROD2 Log gr tie in at RA tag. Add 5' correction. 09:45 - 10:45 1.00 DRILL P PROD2 Continue wiper Trip back to bottom. Hole smooth. 10:45 - 13:30 2.75 DRILL P PROD2 Drill ahead from 13,000'. PVT: 180 bbls. Begin displacement to new 8.6 ppg mud. Circ pressure dropped 400 psi f/ 3900 psi to 3500 psi. ECD dropped from 12.6 to 11.9 ppg. ROP and weight transfer improved as well. 13:30 - 15:15 1.75 DRILL P PROD2 Drill ahead from 13,100'. PVT: 377 bbls. 15:15 -17:15 2.00 DRILL P PROD2 Wiper trip to window. Hole smooth in both directions. PVT 371. 17:15 - 20:30 3.25 DRILL P PROD2 Drill ahead from 13,150' 1.60/1.58/3530/1108 w/ 200-400 psi dill, 0.5-1.Ok wob w/ 3950 psi DHP/12.0 ECD at 87 deg. Drill to initial TD of 13300' (6385' TVD) 20:30 - 21:45 1.25 DRILL P PROD2 Wiper to/thru window, clean 21:45 - 22:20 0.58 DRILL P PROD2 Wiper to 10800' to remove solids in high angle 1.5/3350 22:20 - 22:30 0.17 DRILL P PROD2 Log tie-in down from 11380', corr +5' 22:30 - 23:45 1.25 DRILL P PROD2 Wiper to TD. Start 10 bbls 10.4 ppg NaCI/NaBr KWF at 12500' followed by 40 bbls KWF w/ 6 ppb coarse plastic beads (yes, all beads have been plastic, not 'glass'). Tag TD at 13302' wl +4k surface string wt. Wiper up hole 30k while wo beads to get to bit 23:45 -00:00 0.25 DRILL P PROD2 Wiper thru OH while lay in KWF 0.9/2065 ~ 45'/min Printed: 8/8/2005 7:43:10 AM BP Page 12 of 13 Operations Summary Report Legal Well Name: 1 D-36 Common Well Name: 1D-36 Spud Date: 9/1/2000 Event Name: REENTER+COMPLETE Start: 7/21/2005 End: 8!1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8/1!2005 Rig Name: NORDIC 2 Rig Number: .Date 'From - To Hours Task Code NPT Phase Description of Operations 7/31/2005 00:00 - 00:30 0.50 DRILL P PROD2 Gontinue POOH thru OH laying in 10.4# KWF w/ beads 0.9/2080 00:30 - 02:40 2.17 DRILL P PROD2 POOH for liner while fin displ to KWF Flag CT at 11300' and 9400' EOP 02:40 - 02:55 0.25 DRILL P PROD2 Tag up, flow check. PVT 307 Safety mfg re: BHA 02:55 - 03:25 0.50 DRILL P PROD2 LD drilling BHA 03:25 - 03:35 0.17 CASE P RUNPRD Safety mfg re: run liner 03:35 - 03:55 0.33 CASE P RUNPRD RU to run liner 03:55 - 05:45 1.83 CASE P RUNPRD MU 58 jts 2-3/8" 4.6# L80 STL R2 solid and slotted finer w( BTT deployment sub 05:45 - 06:30 0.75 CASE P RUNPRD MU MWD asst'. Stab coil. Get on welt. PVT: 309 bbls. 06:30 - 08:00 1.50 CASE P RUNPRD Run in hole with L2 liner assembly. Tie into EOP flag at 9400'. Subtract i 9' correction. 31 k# up, 8.5k# do 08:00 - 09:30 1.50 CASE P RUNPRD Run through window ok. 5.1 k# surface/3.4k# DHWOB at 13,000' while RIH at 2 fpm. Log GR tie in from 11,185'. Add 7' correction. Continue to run in hole. tog RA tag. No correction. Cfrc at 1.35 bpm @ 4300 psi. PU and attempt to release. Unable to do so on depth. Repeat several times. No release. PU into casing. Release and push liner back on depth. 25k# up wt once released. Liner top at 11,375' Liner btm at 13,210'. Liner top RA tag at 11,377'. 09:30 - 11:30 2.00 CASE P RUNPRD Pull out of hole with running assembly. 11:30 - 13:00 1.50 CASE P RUNPRD At surface. Flow check. Unstab coil. Get off well. PVT; 298 bbls LD Baker tools. LD Inteq DPS & DGS. PJSM with Weatherford & crew. MU box tap, disc, motor, jars & Inteq tools. 13:00 - 15:00 2.00 CASE P RUNPRD Run in hole with WS recovery BHA #15 Kick while tripping drill. Nordic Pit watcher and SLB Supervisor responded immediately, and investigated source/nature of pit increase (accomplished manually by placing a cup of water under one of the pit level sensors). 15:00 - 16:00 1.00 STWHIP P WEXIT Wt check: 7k# dn, 28k# up. Close EDC. Correct -12' as per past runs. 3690 psi fs ~ 1.3 fn/.73 out. RIH at 10 fpm. Tag fish at 11,380'. Stall at 3-4k# dn. PU. No catch. Repeat while RIH at 5 fpm. PU. No catch. RIH slower (2 fpm. Take wt at 11366'. Work over fish with pump and wt. PU to 26k#. Have fish. Pull up to 43k#. Still latched. Cock jars and PU to 35k#. Fire jars. PU to 42k#. No release. Re-set jars. PU to 37k#. Jars fired. PU to 42k#. No release. Re-set jars. PU to 38k#. Jars fired. PU to 43k#. No release. 16:00 - 16:15 0.25 STWHIP P WEXIT Re-set jars. PU to 39k#. Jars fired. PU to 43k#. No release. Re-set jars. PU to 39k#. Jars fired. PU to 41 k#. RE-set jars. PU to 41 k#. Jars fired. PU to 42k#. No release. Re-set jars. PU to 43k#. Jars fired. PU to 43k#. No release. Re-set jars. PU to 43k# Jars fired. PU to 44k#. No release. Reset jars.PU to 45k#. Jars fired. Something came free. Cannot tell what. Open EDC. PVT 308 16:15 - 18:45 2.50 STWHIP P WEXIT Pull out of hole. Printed: 6/8!2005 7:43:10 AM BP' :Page 13 of 13 Operations Summary Report' Legal Well Name: 1 D-36 Common Well Name: iD-36 Spud Date: 9!1/2000 Event Name: REENTER+COMPLETE Start: 7!21!2005 End: 8/1/2005 Contractor Name: NORDIC CALISTA Rig Release: 8!1/2005 Rig Name: NORDIC 2 Rig Number: Date From'- To 'Hours Task Code NPT 'Phase Description of Operations 7!31!2005 18:45 - 19:00 0.25 STWHIP P WEXIT Tag up, flow check Safety mtg 19:00 - 19:30 0.50 STWHIP P WEXIT LD WIS WS and WS fishing tools. The lower 1" of external surface of box tap had scars from rotation on bottom of window 19:30 - 21:30 2.00 BOPSU P POST RIH w! nozzle asst' to displ weflbore circ 0.5/1250 w! KW F 21:30 - 23:15 1.75 BOPSU P POST POOH 25k displacing wellbore to SW 1.5/2950 while recover KWF following pressure schedule. POOH from 2500' displacing wellbore to diesel 23:15 - 23:25 0.17 BOPSU P POST Tag up w/ 1000 psi. Monitor WHP for 10 min and stabilized at 820 psi for 5 min 23:25 - 00:00 0.58 RIGD P POST Bleed off press. RU and pump SW thru all surface lines prior to maintenance Meanwhile, MIRU SWS N2 and cool down 8/1/2005 00:00 - 00:10 0.17 RIGD P POST Safety mtg re: N2 00:10 - 01:45 1.58 RIGD P POST PT SWS ~ 3500 psi. Blow down reel w/ N2 to tiger tank and bleed off 01:45 - 05:30 3.75 RIGD P POST Unstab CT from injector. Cut off CTC. Pull back onto reel and load out Clean pits, remove packoff from injector, general RD 05:30 - 06:00 0.50 RIGD P POST ND BOPE. 06:00 - 15:00 9.00 RIGD P POST Continue prep for move to 1 B Pad. Clean pits. Continue ND of BOPs. NU and test tree cap. Disconnect ESD from adjacent well. Lay down deployment lubricator. Remove PIP tags from whipstock. Unload pipe shed. Prep to pick up berm under rig (in place for painting). Finish cleaning pits and cuttings box. Extra thorough cleaning to prep for inspections & painting. SLB began to disassemble hard line in reel house for inspection. Release rig at 1500 hrs on 8-1-05. Printed: 8(8!2005 7:43:10 AM 'Conoc Phillips ~aker Hughes INTEQ ~ ~ ~'`~ Baker Hughes INTEQ Survey Report %ivr~t3 Company:' CorwcoPhiNips Alaska, Inc Date: 8/5/2005 Time: 11:57:30 Psge: 1 IFlield: Kuparuk River Unit Co-ordinate(NE) Reference: Wel(C 36, True North Site: Pad 1D Vertical (1'VD) Reference:. Wellhead(106') 106.0 Wep: 36 Section (VS) Refereracez User{t).OON,O.QOE',30.OOAzi) Wellpath: 1 D-3612 Snrvey Calcnlauoe Method: Minimum Curvature Db: Oracfe Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 36 Slot Name: Well Position: +N/-S -477.23 ft Northing: 5959188.94 ft Latitude: 70 17 56.622 N +E!-W -420.10 ft Easting : 560670.73 ft Longitude: 149 30 31.154 W Position Uncertainty: 0.00 ft Wellpath: 1 D-36L2 Drilled From: 1 D-36 Tie-on Depth: 11275.03 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/4/2005 Declination: 24.40 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +NhS +E1-W Direction ft ft ft deg 0.00 0.00 0.00 30.00 Survey Program for Definitive Wellpath Date: 8/1/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 202.80 11275.03 MWD w/IFR<0 - 11660'> (202.80-11660.00)N(ID'yD+SAG+IFR MWD+SAG+IFR (AK) 11300.00 13302.00 MWD (11300.00-13302.00) MWD MWD -Standard Annotation - - - - - MD TVD ft ft 11275.03 6359.88 TIP 11360.00 6401.27 KOP 13302.00 6496.70 TD Survey: MWD Start Date: 7/28/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD' Ind ; Atim TVD: SS TVD N/S EJW MspN 11~pE VS I)LS Tool " ft;, deg deg ft ft ft fl ft fl ft deg/100ft , 11275.03 60.85 170.00 6359.88 6253.88 -7283.92 2776.66 5951928.37 563505.84 -4919.73 0.00 MWD 11300.00 60.85 170.03 6372.04 6266.04 -7305.40 2780.44 5951906.93 563509.79 -4936.44 0.10 MWD 11360.00 60.85 170.12 6401.27 6295.27 -7357.01 2789.47 5951855.39 563519.24 -4976.62 0.13 MWD 11398.43 71.77 166.51 6416.69 6310.69 -7391.41 2796.63 5951821.06 563526.68 -5002.83 29.68 MWD 11432.75 87.62 163.68 6422.81 6316.81 -7423.92 2805.31 5951788.62 563535.61 -5026.65 46.89 MWD 11466.73 86.73 144.38 6424.50 6318.50 -7454.29 2820.10 5951758.37 563550.65 -5045.56 56.79 MWD 11497.58 89.09 131.04 6425.63 6319.63 -7477.04 2840.80 5951735.79 563571.53 -5054.91 43.88 MWD 11528;82 92.44 115.42 6425.21 6319.21 -7494.11 2$66.84 , 5951718.94 563597.70 , -5056.66 51.13 MWD 11559.98 89.19 104.87 6424.77 6318.77 -7504.82 2896.05 5951708.46 563626.99 -5051.34 35.42 MWD 11591.22 91:98 90.16 6424.45 6318.45 -7508.89 2926.93 5951704.64 563657.90 -5039.43 47:92 -MWD 11621.57 90.51 86.69 6423.79 6317.79 -7508.06 2957.26 5951705.72 563688.22 -5023.54 12.41 MWD ~~~~, ~u~ o ~oa~ ~ ~Q- ~, ~ ~`- C`~ n`~ ~ .~I ~ ~ S U ~ 1! A1s51~s Oil ~ ~; ~~~ts~ ~cart~,,;~.~~::_~ ~i ,y ~.l ll ~ ~i)Cl'id3PS$~ ~`Conoc Phillips .Baker Hughes INTEQ Baker Hughes INTEQ Survey Report ~~ it~rlirt~ Survey MD Iad Atiim ft deg deg 11649.46 92.50 83.86 11682.36 93.05 77.55 11711.04 93.82 71.09 11764.98 90.54 61.84 11794.38 91.92 56.88 11826.54 93.33 51.05 11855.07 89.28 47.39 11890.37 89.03 41.61 11919.37 91.77 37.93 11956.61 90.97 32.33 11984.26 91.80 26.07 12015.08 90.54 21.76 12045.13 90.44 18.16 12076.03 89.03 11.53 12108.09 88.24 3.53 12138.91 87.52 359.61 12173.37 89.49 4.42 12209.89 88.08 14.69 12247.79 85.87 21.49 12280.03 85.39 27.47 12311.24 87.53 32.83 12340:03 85.72 36.75 12374.35 90.17 40.87 12406.10 86.73 44.35 12446.58 83.78 50.27 12479.11 85.00 57.28 12507.57 83.71 61.51 12542.48 82.02 69.02 12575.84 85.19 72.86 12611.48 85.25 77.48 12652.16 83.71 81.43 12686.66 83.34 75.73 12718.24 85.32 71.80 12764.11 85.37 63.40 12794.77 87.71 58.57 12823.26 88.45 54.54 12859.58 89.65 49.52 12891.06 89.25 44.76 12920.35 86.08 40.14 12952.65 88.33 36.33 12982.38 86.20 31.62 13010.49 85.47 27.46 13040.90 86.14 23.12 13086.25 87.40 18.17 13116.04 87.83 12.93 13146.07 88.57 8.72 13182.36 85.81 12.40 13224.23 82.72 18.58 13261.43 80.53 23.14 13302.00 80.53 23.14 T~'D SS TtVD N/S R ft ft 6423.06 6317.06 -7505.76 6421.46 6315.46 -7500.46 6419.74 6313.74 -7492.73 6417.69 6311.69 -7471.23 6417.05 6311.05 -7456.25 6415.58 6309.58 -7437.36 6414.93 6308.93 -7418.74 6415.45 6309.45 -7393.57 6415.25 6309.25 -7371.29 6414.36 6308.36 -7340.85 6413.69 6307.69 -7316.74 6413.06 6307.06 -7288.58 6412.80 6306.80 -7260.34 6412.95 6306.95 -7230.49 6413.71 6307.71 -7198.74 6414.85 6308.85 -7167.96 6415.75 6309.75 -7133.54 6416.53 6310.53 -7097.59 6418.53 6312.53 -7061.63 6420.99 6314.99 -7032.39 6422.92 6316.92 -7005.46 6424.61 6318.61 -6981.87 6425.84 6319.84 -6955.15 6426.70 6320.70 -6931.80 6430.05 6324.05 -6904.46 6433.24 6327.24 -6885.34 6436.04 6330.04 -6870.93 6440.38 6334.38 -6856.44 6444.10 6338.10 -6845.62 6447.07 6341.07 -6836.53 6450.98 6344.98 -6829.12 6454.88 6348.88 -6822.34 6458.00 6352.00 -6813.55 6461.73 6355.73 -6796.15 6463.58 6357.58 -6781.31 6464.53 6358.53 -6765.62 6465.14 6359.14 -6743.28 6465.44 6359.44 -6721.88 6466.63 6360.63 -6700.29 6468.21 6362.21 -6674.96 6469.63 6363.63 -6650.34 6471.67 6365.67 -6625.95 6473.89 6367.89 -6598.54 6476.45 6370.45 -6556.18 6477.69 6371.69 -6527.52 6478.64 6372.64 -6498.04 6480.41 6374.41 -6462.42 6484.60 6378.60 -6422.30 6490.02 6384.02 -6387.91 6496:70 6390.70 -6351.12 E/W MapN MapE VS DLS Tool ft ft ft, ft deg/100ft 2985.04 5951708.24 563715.98 -5007.66 12.40 MWD 3017.45 5951713.80 563748.34 -4986.86 19.23 MWD 3045.00 5951721.76 563775.83 -4966.39 22.64 MWD 3094.35 5951743.65 563825.00 -4923.09 18.18 MWD 3119.64 5951758.83 563850.16 -4897.48 17.51 MWD 3145.60 5951777.93 563875.97 -4868.14 18.63 MWD 3167.19 5951796.72 563897.41 -4841.22 19.13 MWD 3191.92 5951822.08 563921.93 -4807.06 16.39 MWD 3210.47 5951844.51 563940.29 -4778.49 15.82 MWD 3231.88 5951875.12 563961.46 -4741.43 15.19 MWD 3245.36 5951899.34 563974.74 -4713.80 22.83 MWD 3257.85 5951927.60 563987.00 -4683.17 14.57 MWD 3268.10 5951955.92 563997.03 -4653.58 11.98 MWD 3276.02 5951985.83 564004.70 -4623.78 21.94 MWD 3280.21 5952017.61 564008.64 -4594.18 25.07 MWD 3281.06 5952048.39 564009.23 -4567.10 12.92 MWD 3282.27 5952082.81 564010.17 -4536.69 15.08 MWD 3288.32 5952118.81 564015.93 -4502.53 28.38 MWD 3300.06 5952154.86 564027.38 -4465.52 18.84 MWD 3313.38 5952184.20 564040.45 -4433.54 18.55 MWD 3329.02 5952211.25 564055.87 -4402.40 18.46 MWD 3345.41 5952234.98 564072.08 -4373.77 14.98 MWO 3366.90 5952261.86 564093.34 -4339.89 17.66 MWD 3388.38 5952285.38 564114.63 -4308.93 15.41 MWD 3418.01 5952312.96 564144.04 -4270.43 16.29 MWD 3444.11 5952332.28 564169.98 -4240.83 21.77 MWD 3468.48 5952346.90 564194.23 -4216.16 15.47 MWD 3499.92 5952361.63 564225.55 -4187.89 21.89 MWD 3531.24 5952372.70 564256.78 -4162.86 14.87 MWD 3565.57 5952382.07 564291.03 -4137.83 12.92 MWD 3605.36 5952389.80 564330.76 -4111.51 10.38 MWD 3638.95 5952396.85 564364.29 -4088.84 16.45 MWD 3669.12 5952405.88 564394.38 -4066.15 13.88 MWD 3711.35 5952423.63 564436.46 -4029.96 18.25 MWD 3738.10 5952438.68 564463.09 -4003.74 17.48 MWD 3761.85 5952454.56 564486.72 -3978.27 14.37 MWD 3790.47 5952477.12 564515.15 -3944.62 14.21 MWD 3813.54 5952498.71 564538.04 -3914.55 15.17 M W D 3833.28 5952520.45 564557.61 -3885.98 19.12 MWD 3853.24 5952545.95 564577.37 -3854.06 13.69 MWD 3869.84 5952570.70 564593.76 -3824.45 17.37 MWD 3883.65 5952595.19 564607.38 -3796.42 14.99 MWD 3896.61 5952622.71 564620.11 -3766.20 14.40 MWD 3912.57 5952665.19 564635.72 -3721.54 11.25 MWD 3920.54 5952693.91 564643.46 -3692.73 17.63 MWD 3926.18 5952723.43 564648.86 -3664.38 14.23 MWD 3932.82 5952759.10 564655.21 -3630.21 12.67 MWD 3943.93 5952799.31 564666.00 -3589.91 16.43 MWD 3957.03 5952833.79 564678.82 -3553.58 13.48 M W D 3972.75 5952870.71 564694.24 _3513.85 0.00 MWD a ~ ]~ r~~ ' ~ 4 ~ ' , "~ ~ ~ .r ' ~°°+ ~ ! ~ '°~ ' 3 ~ FRANK H. MURKOWSKI, GOVERNOR .r;; ~ ~~ ~~"" ~~ ~~++ a`~ ~~ OI~ ~ a7[0~7 ~ 333 W. T" AVENUE, SUITE 10D CO1~T5F.RQA'1`IOI1T CODIlrII55IOrIT ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Scott Kolstad CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1D-36L2 ConocoPhillips Alaska Inc. Permit No: 205-085 Surface Location: 477' FNL, 420' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 1640' FNL, 3569' FWL, SEC. 25, T11N, RlOE, UM Dear Mr. Kolstad: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 24, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please pr hours notice for a representative of the C Commission's petroleum field inspector at DATED this /~ day of June, 2005 wide at least twenty-four (24) any required test. Contact the cc: Department of Fish & Game, Habitat Section w/a encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION ~MMISSION PERMIT TO DRILL 20 AAC 25.005 lYVk v by °' `.~. i ~ ~n 1a. Type of work ^ Drill ®Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ®Development`Oil `[~ fiA«lRiple2one ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 1 D-36L2 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13375 ~ TVD 6377ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 477' SNL 420' WEL SEC T11N 23 R10E UM 7. Property Designation: ADL 025661 - River Pool , , . , , , Top of Productive Horizon: 2553' SNL, 2364' EWL, SEC. 25, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 10, 2005 Total Depth: 1640' SNL, 3569' EWL, SEC. 25, T11N, R10E, UM 9. Acres in Property: 2560 ' 14. Distance to Nearest Property: 4215' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 ~ - 5959189 Zone- ASP4 10. KB Elevation (Height above GL): 105.3 feet 15. Distance to Nearest Well Within Pool 1 D-37 is offset by 1780' 16. Deviated Wells: Kickoff Depth: 11366 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3264 ~ Surface: 2622 ' 18. asing rogram: Size Specifications Setting Depth To Bottom uantlty o ement c.f, or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 1900' 11376' 6304' 13300' 6370' Uncemented Slotted Liner i9. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations). Total Depth MD (ft): 11658 Total Depth TVD (ft): 6542 Plugs (measured): None Effective Depth MD (ft): 11589 Effective Depth TVD (ff): 6510 Junk (measured): None Casin Len th Size Cement Volume MD TVD r r on r 121' 20" 14 cu ds ABI T e III 121' 121' rf 7047' 9-5/8" 50 sx AS III Lite, 415 sx LiteCrete 7047' 4297' I 11038' 7" 170 sx Class 'G' 11038' 6245' Pro r 771' 3-1/2" 174 sx Class 'G' 10885' - 11656' 6170' - 6541' Liner 2-3/8" Uncemented Slotted Liner 11400' - 13300' 6315' - 6437' Perforation Depth MD (ft): 11410' - 11484' Perforation Depth TVD (ft): 6426' - 6461' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®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 Scott Kolstad, 564-5347 Printed Name S ott Kolstad Title CT Drilling Engineer Prepared By Name/Number: Si nature r Phone 564-5347 Date Terrie Hubble, 564-4628 Commission Use Only Permit To Drill _ ~i~. Number: Z-~=3 -~c7'S API Number: 50- 029-22973-61-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sample Required r i Yes ~~ No Mud Log Required ^ Yes ~ No Hyd ei Sulfide Measures Yes _'-; No Directional Survey Required 'Yes ~~J! No Other: ~ `r ~ ~3~~ -~'C. ~-t' , APPROVED BY A roved THE COMMISSION pate ~ ~~ Form 10-401 Revised o~l2'6oa Subrrfit In Duplicate KRU 1 D-36L1 and 1 D-36L2 Sidetracks -Coiled Tubing Drilling Summary of Operations: Coiled tubing drilling will drill 2 laterals in producer KRU 1 D-36 using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). These horizontal laterals will target Kuparuk C sand reserves for production. CTD Drill and Complete 1D-36L1 & 1D-36L2 program: Planned for ,Tiny 10, 2005 1. Pre CTD Positive pressure and drawdown tests on MV and SV 2. Pre CTD MTT-lA, MIT-OA 3. Pre CTD Caliper 3-1l2" liner 4. Pre CTD drift tubing/liner with dummy whipstock 5. MIRU Nordic 2. NU 7-1J16" BOPS, test. 6. Set 3-112" LSX whipstock C 11,410' md. `.~~G ~~„ 7. Mill 2.74" window and 10' of open hole. 8. Drill 3" bicenter hole horizontal lateral from window to 13,300' TD targeting Kuparuk C1/C2 sands. 9. Kill well w/brine & Complete with 2 3/8" slotted liner from TD up into the 3-112" liner to11,400'. 10. Set Weatherford packer -- 11,380' and 11. Stab into packer with retrievable 3-1i2" whipstock, targeting top of whipstock @ 11,366' md. ~4~L 2 12. Mill 2.74" window and 10' of open hole. 13. Dril13" bicenter hole horizontal lateral from window to -13,300' TD targeting Kuparuk C3/C4 sands. 14. Kill well w/ brine & Complete with 2 3/8" slotted liner from TD, to 5'-10' outside the 3-112" casing exit. 15. ND BOPE. RDMO Nordic 2. 16. Post CTD rig -Run GLVs. BOL. Mud Program: • Step 7: 8.b ppg chloride-based biozan brine • Steps 8, 10-13: chloride-based Flo-Pro (8.6 ppg) • Steps 9 & 14: Viscosified Naar KWF (10.6 ppg) Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1D-36L1: 2 3/8", 4.6#, L-80, STL slotted liner from 11,400' and to 13,300' and • 1D-36L2: 2 3/8", 4.6#, L-80, STL slotted liner from 11,376' and to 13,300' and Well Control: • Two well bore volumes (232 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1 D-36L 1 & 1 D-36L2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1D-36L1 is 1D-37 which is offset by 1735'. KPA boundary is 4250' away. • The nearest well to ID-36L2 is 1D-37 which is offset by 1780'. KPA boundary is 4215' away. la~• T"tj, ~ .~~ ~,c~tc~~'b'n ~.it~ h~ ~ ^to t ~~ ~ . W ~ ~ ~ ~-cc~.c.~.s KRU 1 D-36L1 and 1 D-36L2 Sidetracks -Coiled Tubing Drilling Logging • A MWD Gamma Ray log will be run. Hazards L1 & L2 will both cross one mapped fault. Lost circulation risk is moderate. High pressure is not expected. Well 1D-36 has a H2S reading of 36 ppm. 1D is an HZS pad, the highest H2S measurement on the pad is 120 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The latest Shut in bottom hole pressure was 3264 psi at 6425' TVD, 9.8 ppg EMW. Max. surface pressure with gas (0.l psi/ft) to surface is 2622 psi. DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to hel~with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPS choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipelslips (2-3/8" rams, see attached BOP configuration). This well does not have a tubing retrievable sub-surface safety valve. The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated reservoir pressure: 3264 psi at 6299' TVD, 10.0 ppg EMW. Expected annular friction losses while circulating: 1026 psi Planned mud density: 8.6 ppg equates to 2817 psi hydrostatic bottom hole pressure. While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3843 psi or 11.7 ppg ECD When circulation is stopped, a minimum of 1126 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (minimum weight = 10.3 ppg for 100 psi overbalance) KRU 1 D-36L1 & L2 Producer Proposed Completion 3-1/2" Camco DB nipple, 2.875" min ID at 545' MD 2-318" liner top ~ ~ +l-11,376' MD 3-1/2" 9.3# L-80 BTCM Tubing 3-'/s" Camco MMG GLM @ 3655', 6481', 8237', 9706', & 10,819' MD 9-5/8" 40# L-80 ~ 7047' 3-%i" Camco DS nipple, 2.813" min ID ~ 10,871' MD Baker ZXP Packer w/SBE @ 10,912' MD 7" 26# L-80 11038' MD L2 KOP 11,366' MD Window in 3-1l2" C3/C4 Sands C1/C2 Sand perfs L1 KOP 11,410' Mb C1/C2 Sands ~ 11,656' MD Fill 3" openhole -Weatherford retrievable whipstock ~ 11,366' and (with plug) ~' Packer, 1.25" ID +/-11,381' MD ConocoPhilli ps Alaska, Inc. T~~S~~~-~ ~~ 1 D-36L2 Lateral, TD C~3 13300' ~d " slotted liner ~~ 2-3l8" Baker deployment sub ~ 11,400' and 3" openhole 1 D-36L1, TD ~ 13,300' and --~ ~3-'~z" LSX WS 2-3/8" slotted liner 03/15/05 • ~ • KRU 1 D-36 ConocoPhiliips Alaska, Inc. 1D-36 API: 500292297300 Well T : PROD A le TS: 61 d 11358 SSSV Type: NIPPLE Orig 9/18/2000 Angle @ TD: 62 deg @ 11658 Com lesion: N1P (54s-sas, oD 3 soo Annular Fluid: Last W/O: Rev Reason: TAG FILL . . ) TUBING Reference L Ref L Date: Last U te: 8/3/2004 (aloaes, Last T : 11580 TD: 11658 ftK6 OD~3•500~ Last T Date: 8/2/2004 Max Hole A le: 62 d 11560 tD.z.s92) Casin Suin - ALL STRING S Descri tion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 121 121 72.00 H-40 Welded Gas Lift MandnlUVaPoe SURFACE 9.625 0 7047 4297 40.00 L-80 BTCM 1 PRODUCTION 7.000 0 11038 6245 26.00 L-80 BTCM t3ss5-as5s, LINER 3.500 10885 11656 6541 9.30 L-80 SLHT Tubin Stri -TUBING Size To Bottom ND Wt Grade Thread 3.500 0 10885 6170 9.30 L-80 BTCM Perforations Summa Gas Ltft MandrelNalve _. Interval ND Zone Status Ft SPF Date T e Comment 2 11410 - 11420 6425 -6430 C-2 10 4 10/28/2000 IPERF 2.5" BH HSD (sa91-sa92, 11420 - 11484 6430 -6461 C-2,C-1 64 6 7/12/2003 APERF 2.5" HSD 2506 PJ HMX, 60 D Phase Stimulations & Treatments Interval Date T Comment ~, 11410 - 11420 10/30/2000 FRAC INITAL 'C' SAND FRAC Gas Litt MandreWaloe _ Gas Lift Ma ndrel s Nalves D V 3 St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO ate iv (s237-e23s, - Mfr Run Cmnt 1 3655 2611 CAMCO GLM CAMCO GLV 1.5 RK 0.188 1270 7/14/2001 2 6481 4015 CAMCO GLM CAMCO GLV 1.5 RK 0.188 1278 7/14/2001 ~ 3 8237 4876 CAMCO GLM CAMCO GLV 1.5 RK 0.188 1276 7/14/2001 4 9706 5593 CAMCO GLM CAMCO GLV 1.5 RK 0.250 1311 7/14/2001 Gas Lift ManerelNalve 5 10819 6138 CAMCO GLM CAMCO OV 1.5 RK 0.250 0 7/14/2001 4 Oth er lu s ui .etc. -JEWELRY (97°s-s7°7, De th ND T Descri lion iD 545 544 NIP Camco'DS' Ni le w/No-Go Profile 2.875 10871 6163 NIP Camco'DS' Ni a w/No-Go Profile 2.813 10912 6183 SBE BAKER SBE'80-4ty wffKC ou lin s 4.000 i 10918 6186 SEAL Baker GBH-22 Seal Assembl • 1 T lon ; 15' stroke 3.000 Gas L ft MarMrewa~oe 10971 6212 NIP 'XN' Ni le w/2.75" No-Go 2.750 s ;70819.10620, OD:5.968) I NIP ~ ;10871-10872, I OD:3.500) 1 PRODUCTION (0.11038, ~:7.000, W 1:26.00) SEAL ;1091&10919, OD:5.125) NtP ;10971-10972, i OD:3.500) FRAC ;11410.11420) Perf 11410.11420) Pert 11420.11484) Conocot'hittips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~l%~ ~'~ ~ tNT~4 _~ .Company: ConocoPhillips Alaska, lnc - Date: 4!7!2005 Time: 09:21:41 Page: 1 Field: Kuparuk River-Unit Co-ordiaate(NE)Beference: Well: 36, True North Site: Pad 1b Vertical (TVD) Reference: Wellhead(1,06')106.0 WeIL• 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) Wellpath: Plan#8; 1D-36L2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Weil Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.318 N From: Map Easting: 561086 .90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 36 Slot Name: Well Position: +N/-S -477.23 ft Northing: 5959188 .94 ft ' Latitude: 70 17 56.622 N +E/-W -420.10 ft Easting : 560670 .73 ft ~ Longitude: 149 30 31.154 W Position Uncertainty: 0.00 ft Wellpath: Plan#8, 1D-36L2 Drilled From: 1D-36 Tie-on Depth: 11 275.03 ft Current Datum: Wellhead(106') Height 106 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 4!4/2005 Declination: 24.40 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 30.00 Plan: Plan #8 Date Composed: 4/4/2005 Version: 1 Principal: Yes Tied-to: From : Definitive Path Targets Map Map <-- Latitude --> <--- Longitude. ---> Name Description TVI) +N/-S +E/-Vy .Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1 D-36L2 Polygon 106.00 -7471.30 2774.31 5951741.00 563505.00 70 16 43.137 N 149 29 10.359 W -Polygan 1 106.00 -7656.73 2948.84 5951557.00 563681.00 70 16 41.313 N 149 29 5.278 W -Polygon 2 106.00 -7551.22 3259.73 5951665.00 563991.00 70 16 42.349 N 149 28 56.223 W -Polygon 3 106.00 -7334.09 3370.50 5951883.00 564100.00 70 16 44.484 N 149 28 52.994 W -Polygon 4 106.00 -7050.20 3388.79 5952167.00 564116.00 70 16 47.276 N 149 28 52.458 W -Polygon 5 106.00 -6812.06 3993.79 5952410.00 564719.00 70 16 49.616 N 149 28 34.834 W -Polygon 6 106.00 -6420.31 4155.97 5952803.00 564878.00 70 16 53.468 N 149 28 30.104 W -Polygon 7 106.00 -6152.64 4200.14 5953071.00 564920.00 70 16 56.100 N 149 28 28.813 W -Polygon 8 106.00 -5999.39 3924.34 5953222.00 564643.00 70 16 57.609 N 149 28 36.844 W -Polygon 9 106.00 -6225.20 3897.52 5952996.00 564618.00 70 16 55.388 N 149 28 37.629 W -Polygon 10 106.00 -6459.07 3753.61 5952761.00 564476.00 70 16 53.088 N 149 28 41.824 W -Polygon 11 106.00 -6671.97 3241.83 5952544.00 563966.00 70 16 50.997 N 149 28 56.733 W -Polygon 12 106.00 -7055.91 3104.71 5952159.00 563832.00 70 16 47.221 N 149 29 0.732 W -Polygon 13 106.00 -7381.59 3060.07 5951833.00 563790.00 70 16 44.019 N 149 29 2.035 W -Polygon 14 106.00 -7397.03 2866.92 5951816.00 563597.00 70 16 43.867 N 149 29 7.661 W -Polygon 15 106.00 -7471.30 2774.31 5951741.00 563505.00 70 16 43.137 N 149 29 10.359 W 1 D-36L2 Fault 1 106.00 -6172.37 3546.90 5953046.00 564267.00 70 16 55.909 N 149 28 47.841 W -Polygon 1 106.00 -6172.37 3546.90 5953046.00 564267.00 70 16 55.909 N 149 28 47.841 W -Polygon 2 106.00 -6992.82 3590.28 5952226.00 564317.00 70 16 47.840 N 149 28 46.589 W -Polygon 3 106.00 -7595.74 3694.43 5951624.00 564426.00 70 16 41.910 N 149 28 43.564 W 1 D-36L2 Target 2 6408.00 -7360.27 3268.27 5951856.00 563998.00 70 16 44.227 N 149 28 55.972 W 1 D-36L2 Target 1 6428.00 -7173.50 2927.74 5952040.00 563656.00 70 16 46.066 N 149 29 5.887 W 1 D-36L2 Target 3 6428.00 -6797.73 3581.85 5952421.00 564307.00 70 16 49.759 N 149 28 46.832 W ~~ ~~ ~.. ConocoPhill~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~~ _ ~_ INTEQ Company: ConocoPhillips Alaska, Inc Date: 4/7/2005 Time: 09:21:41 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeIC 36, True North Site: Pad 1D Verticaf(TVD}References Wellhead(106') 106.0 Weil: 36 Section (VS) Reference: User (O.OON,O.OOE,30.OOAzi) Wellpath: Plan#8, 1 D-36L2 Survey Calculation Method: Minimum Curvature Db: Oracfe Targets Map Map.. ~--- Latitude --> <- Longitude --> Name Description TVD ' +N/-S +E/-W Northing Easting Deg Min Sec Deg: Min Sec . Dip." - Dir. ft ft ft ft ft 1D-36L2 Target 4 6484.00 -6453.11 4006.69 5952769.00 564729.00 70 16 53.146 N 149 28 34.453 W Annotation MD TVD ft ft 11275.03 6359.88 TIP 11366.00 6404.19 KOP 11386.00 6413.66 End 9°1100' DLS 11456.56 6427.52 4 11581.56 6419.39 End 45°1100' DLS 11831.56 6410.04 6 12031.56 6407.10 End 20°1100' DLS 12216.56 6408.87 8 12741.56 6426.94 9 12816.56 6430.89 10 13375.00 0.00 TD Plan Section Information MD Incl Azim TYD +N/-5 +Ei-W DLS Build Turn TFO Target ft deg deg... ft ft ft deg/100ft deg1100ft deg/100ft deg 11275.03 60.85 170.00 6359.88 -7283.92 2776.66 0.00 0.00 0.00 0.00 11366.00 60.85 170.12 6404.19 -7362.17 2790.38 0.12 0.00 0.13 90.03 11386.00 62.65 170.12 6413.66 -7379.53 2793.40 9.00 9.00 0.00 0.00 11456.56 94,40 170.12 6427.52 -7446.78 2805.11 45.00 45.00 0.00 0.00 11581.56 92.44 113.79 6419.39 -7541.06 2878.97 45.00 -1.57 -45.06 270.00 11831.56 91.57 63.77 6410.04 -7535.88 3120.88 20.00 -0.35 -20.01 270.00 12031.56 90.05 23.79 6407.10 -7394.39 3256.43 20.00 -0.76 -19.99 268.20 12216.56 88.88 356.06 6408.87 -7213.95 3288.01 15.00 -0.63 -14.99 267.50 12741.56 87.82 74.85 6426.94 -6819.38 3568.85 15.00 -0.20 15.01 92.00 12816.56 86.17 85.99 6430.89 -6806.93 3642.58 15.00 -2.20 14.86 98.70 13375.00 85.12 1.93 6482.91 -6441.95 3995.00 15.00 -0.19 -15.05 265.50 Survey MD Incl Azim SS TVD N/S E/VV MapN MapE DLS' VS TFO Tool ft deg deg ft ft ft ft ft deg1100ft ft deg 11275.03 60.85 170.00 6253.88 -7283.92 2776.66 5951928.37 563505.84 0.00 -4919.73 0.00 MWD 11300.00 60.85 170.03 6266.04 -7305.40 2780.44 5951906.93 563509.79 0.12 -4936.44 90.03 MWD 11325.00 60.85 170.07 6278.22 -7326.90 2784.21 5951885.46 563513.74 0.12 -4953.18 90.01 M W D 11350.00 60.85 170.10 6290.40 -7348.41 2787.97 5951863.98 563517.67 0.12 -4969.92 90.00 MWD 11366.00 60.85 170.12 6298.19 -7362.17 2790.38 5951850.24 563520.18 0.12 -4980.64 89.98 MWD 11373.90 11375.00 61.56 61.66 170.12 170.12 6302.00 6302.52 -7369.00 -7369.95 2791.56 2791.73 5951843.42 563521.42 5951842.48 563521.60 9.00 -4985.96 9.00 -4986.70 0.00 360.00 1 D-36L2 MWD 11386.00 62.65 170.12 6307.66 -7379.53 2793.40 5951832.91 563523.34 9.00 -4994.16 360.00 MWD 11400.00 ~ 68.95 170.12 6313.39 -7392.10 2795.59 5951820.35 563525.63 45.00 -5003.96 0.00 MWD ? 11425.00 80.20 170.12 6320.03 -7415.81 2799.72 5951796.69 563529.95 45.00 -5022.42 360.00 MWD 11450.00 91.45 170.12 6321.85 -7440.33 2803.99 5951772.20 563534.42 45.00 -5041.52 0.00 MWD 11456.56 94.40 170.12 6321.52 -7446.78 2805.11 5951765.76 563535.60 45.00 -5046.55 0.00 MWD 11475.00 94.35 161.80 6320.11 -7464.61 2809.57 5951747.97 563540.20 45.00 -5059.75 270.00 MWD 11500.00 94.15 150.52 6318.25 -7487.37 2819.63 5951725.29 563550.44 45.00 -5074.44 269.36 MWD 11525.00 93.78 139.25 6316.51 -7507.74 2833.96 5951705.04 563564.93 45.00 -5084.92 268.53 MWD 11550.00 93.27 127.99 6314.97 -7524.92 2851.99 5951688.01 563583.10 45.00 -5090.78 267.74 MWD 11575.00 92.63 116.74 6313.68 -7538.27 2873.05 5951674,84 563604.26 45.00 -5091.81 267.05 MWD 11581.56 92.44 113.79 6313.39 -7541.06 2878.97 5951672.09 563610.21 45.00 -5091.27 266.47 MWD 11600.00 92.44 110.10 6312.61 -7547.95 2896.06 5951665.34 563627.35 20.00 -5088.68 270.00 MWD 11625.00 92.41 105.10 6311.55 -7555.50 2919.86 5951657.99 563651.21 20.00 -5083.32 269.84 MWD ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~L!~ _ e~ tN'I'~Q .~`~' ___ Company: ConocoPhillips Alaska, lnc Date: 4/7/2005 Time: 09:21:41 Page: 3 Field: Kuparuk River lJnit Co-ordinate(NE) References WeIL• 36, True North Site:. Pad 1 D Vertical (TVD) Reference: Wellhead(1 06')106.0 Well; 36 Section (VS}Reference: User (O.OON,I).OOE,30.OOAzi) Wellpath: Plan#6, 1 D-36L2 Survey Calculation Method:. Minimum CuNature Db OraCle Survey MD Incl Azim SS TVD N/S E/W MapN - ° MapE I)LS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11650. 00 92.37 100.09 6310.50 -7560.94 2944.23 5951652.74 563675.62 20.00 -5075.85 269.63 MWD 11675. 00 92.31 95.09 6309.48 -7564.24 2968.98 5951649.64 563700.40 20.00 -5066.33 269.42 MWD 11700. 00 92.24 90.08 6308.49 -7565.36 2993.93 5951648.72 563725.35 20.00 -5054.83 269.22 MWD 11725. 00 92,14 85.08 6307.53 -7564.31 3018.88 5951649.97 563750.29 20.00 -5041.45 269.02 M W D 11750. 00 92.03 80.08 6306.62 -7561.09 3043.65 5951653.40 563775.03 20.00 -5026.27 268.83 MWD 11775. 00 91.91 75.08 6305.76 -7555.71 3068.04 5951658.97 563799.37 20.00 -5009.42 268.64 MWD 11800. 00 91.77 70.08 6304.96 -7548.23 3091.87 5951666.64 563823.14 20.00 -4991.03 268.47 MWD 11825. 00 91.61 65.08 6304.22 -7538.70 3114.97 5951676.35 563846.15 20.00 -4971.23 268.31 MWD 11831. 56 91.57 63.77 6304.04 -7535.88 3120.88 5951679.23 563852.04 20.00 -4965.82 268.16 MWD 11850. 00 91.45 60.08 6303.55 -7527.20 3137.14 5951688.03 563868.23 20.00 -4950.17 268.20 MWD 11875. 00 91.28 55.08 6302.96 -7513.80 3158.23 5951701.60 563889.21 20.00 -4928.03 268.10 MWD 11900. 00 91.10 50.08 6302.44 -7498.62 3178.08 5951716.94 563908.93 20.00 -4904.96 267.98 MWD 11925. 00 90.91 45.08 6302.00 -7481.77 3196.52 5951733.94 563927.24 20.00 -4881.14 267.88 MWD 11950. 00 90.71 40.09 6301.65 -7463.37 3213.43 5951752.47 563944.00 20.00 -4856.75 267.79 MWD 11975. 00 90.51 35.09 6301.38 -7443.56 3228.68 5951772.40 563959.09 20.00 -4831.98 267.72 MWD 12000. 00 90.31 30.10 6301.20 -7422.51 3242.14 5951793.56 563972.38 20.00 -4807.01 267.67 MWD 12025. 00 90.10 25.10 6301.11 -7400.36 3253.72 5951815.80 563983.77 20.00 -4782.04 267.63 M W D 12031. 56 90.05 23.79 6301.10 -7394.39 3256.43 5951821.79 563986.44 20.00 -4775.52 267.61 MWD 12050. 00 89.93 21.03 6301.10 -7377.34 3263.46 5951838.89 563993.33 15.00 -4757.23 267.50 MWD 12075. 00 89.76 17.28 6301.17 -7353.73 3271.66 5951862.57 564001.34 15.00 -4732.69 267.50 MWD 12100. 00 89.60 13.53 6301.31 -7329.63 3278.30 5951886.71 564007.78 15.00 -4708.50 267.51 MWD 12125. 00 89.44 9.79 6301.52 -7305.15 3283.35 5951911.23 564012.64 15.00 -4684.77 267.53 MWD 12150. 00 89.28 6.04 6301.80 -7280.40 3286.79 5951936.01 564015.88 15.00 -4661.61 267.56 MWD 12175. 00 89.13 2.29 6302.15 -7255.47 3288.61 5951960.95 564017.49 15.00 -4639.12 267.61 MWD 12200. 00 88.97 358.54 6302.56 -7230.48 3288.79 5951985.94 564017.47 15.00 -4617.38 267.66 MWD 12216. 56 88.88 356.06 6302.87 -7213.95 3288.01 5952002.46 564016.56 15.00 -4603.45 267.72 MWD 12225. 00 88.83 357.33 6303.04 -7205.52 3287.53 5952010.89 564016.01 15.00 -4596.40 92.00 MWD 12250. 00 88.71 1.08 6303.58 -7180.53 3287.18 5952035.87 564015.46 15.00 -4574.93 91.97 MWD 12275. 00 88.59 4.83 6304.17 -7155.58 3288.47 5952060.83 564016.54 15.00 -4552.68 91.89 M W D 12300. 00 88.47 8.58 6304.81 -7130.76 3291.38 5952085.67 564019.26 15.00 -4529.73 91.81 M W D 12325. 00 88.36 12.33 6305.50 -7106.19 3295.92 5952110.27 564023.59 15.00 -4506.18 91.71 MWD 12350. 00 88.26 16.08 6306.24 -7081.97 3302.05 5952134.54 564029.52 15.00 -4482.14 91.61 MWD 12375. 00 88.17 19.83 6307.02 -7058.20 3309.75 5952158.37 564037.03 15.00 -4457.71 91.49 MWD 12400. 00 88.08 23.58 6307.84 -7034.99 3318.98 5952181.65 564046.08 15.00 -4432.99 91.38 MWD 12425. 00 88.00 27.33 6308.69 -7012.43 3329.72 5952204.29 564056.63 15.00 -4408.08 91.26 M W D 12450. 00 87.93 31.08 6309.58 -6990.63 3341.91 5952226.19 564068.64 15.00 -4383.11 91.13 MWD 12475. 00 87.87 34.83 6310.50 -6969.67 3355.50 5952247.26 564082.06 95.00 -4358.16 90.99 MWD 12500. 00 87.82 38.59 6311.44 -6949.64 3370.43 5952267.40 564096.83 15.00 -4333.35 90.86 MWD 12525. 00 87.78 42.34 6312.40 -6930.64 3386.64 5952286.53 564112.88 15.00 -4308.79 90.72 MWD 12550. 00 87.75 46.09 6313.37 -6912.74 3404.05 5952304.57 564130.15 15.00 -4284.58 90.57 MWD 12575. 00 87.72 49.84 6314.36 -6896.02 3422.61 5952321.44 564148.57 15.00 -4260.82 90.42 M W D 12600. 00 87.71 53.60 6315.36 -6880.54 3442.21 5952337.07 564168.05 15.00 -4237.62 90.28 M W D 12625. 00 87.71 57.35 6316.36 -6866.39 3462.79 5952351.39 564188.50 15.00 -4215.07 90.13 MWD 12650. 00 87.71 61.10 6317.36 -6853.61 3484.25 5952364.34 564209.86 -15.00 -4193.28 89.98 MWD 12675. 00 87.73 64.86 6318.35 -6842.26 3506.50 5952375.86 564232.01 15.00 -4172.33 89.83 MWD 12700. 00 87.76 68.61 6319.34 -6832.40 3529.44 5952385.91 564254.87 15.00 -4152.31 89.68 MWD 12725. 00 87.79 72.36 6320.31 -6824.05 3552.98 5952394.45 564278.35 15.00 -4133.31 89.53 MWD 12741. 56 87.82 74,85 6320.94 -6819.38 3568.85 5952399.24 564294.18 15.00 -4121.33 89.38 MWD 12750. 00 87.63 76.10 6321.28 -6817.27 3577.02 5952401.43 564302.33 15.00 -4115.42 98.70 M W D 12775. 00 87.07 79.81 6322.43 -6812.06 3601.44 5952406.83 564326.70 15.00 -4098.69 98.65 MWD 12800. 00 86.52 83.53 6323.83 -6808.44 3626.13 5952410.65 564351.36 15.00 -4083.22 98.48 MWD 12816. 56 86.17 85.99 6324.89 -6806.93 3642.58 5952412.29 564367.80 15.00 -4073.68 98.27 MWD 12825. 00 86.07 84.72 6325.46 -6806.25 3650.98 5952413.04 564376.19 15.00 -4068.89 265.50 MWD ConocoPhill~ps Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~~ >~ Company: ConocoPhillips Alaska, Inca Date: .4/7/2005 Time: 09:21:41 Page: 4 Field:. Kuparuk River Unit Co-ordinate(NE) Reference: '- WeIL• 36, True North Site: Pad 1 D Vertical (TVD) Reference: Wellhead(1 06') 106.0 Well: 36 Section (VS) Reference: User (O.OON,O.OOE,30. OOAzi) Wellpath: Plan#8, 1 D-36L2 Survey Calculation Method: Minimum Curvature Db: Aracle Survey MD Incl Azim _SS TVD N/5 E/W MapN MapE DLS VS TFO Tool. ft deg deg ft ft ft ft ft deg/100ft ft deg 12850.00 85.79 80.98 6327.23 -6803.15 3675.72 5952416.34 564400.90 15.00 -4053.84 265.59 M W D 12875.00 85.53 77.22 6329.13 -6798.43 3700.19 5952421.25 564425.33 15.00 -4037.52 265.85 MWD 12900.00 85.29 73.47 6331.13 -6792.13 3724.30 5952427.75 564449.38 15.00 -4020.01 266.14 MWD 12925.00 85.06 69.71 6333.23 -6784.26 3747.93 5952435.80 564472.95 15.00 -4001.38 266.44 MWD 12950.00 84.86 65.95 6335.43 -6774.87 3770.99 5952445.38 564495.93 15.00 -3981.72 266.75 MWD 12975.00 84.68 62.19 6337.71 -6763.99 3793.38 5952456.45 564518.22 15.00 -3961.10 267.08 MWD 13000.00 84.52 58.43 6340.06 -6751.66 3814.99 5952468.94 564539.74 15.00 -3939.61 267.43 MWD 13025.00 84.39 54.66 6342.47 -6737.95 3835.75 5952482.82 564560.38 15.00 -3917.36 267.78 MWD 13050.00 84.28 50.90 6344.94 -6722.90 3855.56 5952498.03 564580.07 15.00 -3894.43 268.14 M W D 13075.00 84.20 47.13 6347.45 -6706.59 3874.33 5952514.49 564598.70 15.00 -3870.91 268.52 MWD 13100.00 84.14 43.36 6349.99 -6689.08 3891.99 5952532.14 564616.22 15.00 -3846.92 268.89 MWD 13125.00 84.10 39.59 6352.56 -6670.45 3908.46 5952550.90 564632.53 15.00 -3822.56 269.28 M W D 13150.00 84.09 35.82 6355.13 -6650.78 3923.66 5952570.69 564647.58 15.00 -3797.92 269.66 MWD 13175.00 84.11 32.05 6357.70 -6630.16 3937.54 5952591.42 564661.29 15.00 -3773.11 270.05 M W D 13200.00 84.15 28.28 6360.26 -6608.66 3950.04 5952613.02 564673.61 15.00 -3748.25 270.44 M W D 13225.00 84.22 24.51 6362.79 -6586.38 3961.09 5952635.38 564684.48 15.00 -3723.43 270.82 M W D 13250.00 84.31 20.74 6365.29 -6563.43 3970.66 5952658.41 564693.87 15.00 -3698.77 271.21 M W D 13275.00 84.42 16.98 6367.74 -6539.89 3978.70 5952682.01 564701.72 15.00 -3674.36 271.58 M W D 13300.00 84.56 13.21 6370.14 -6515.87 3985.18 5952706.08 564708.00 15.00 -3650.32 271.95 M W D 13325.00 84.73 9.45 6372.48 -6491.47 3990.07 5952730.52 564712.69 15.00 -3626.74 272.31 M W D 13350.00 84.91 5.69 6374.74 -6466.79 3993.35 5952755.22 564715.77 15.00 -3603.73 272.67 M W D ~ 13375.00 85.12 1.93 6376.91 ~ -6441.95 3995.00 5952780.07 564717.23 15.00 -3581.39 273.01 M W D _ LEGEND T Plan: Plan #8 (36/Planlt8, 1 D-36L2) BP Amoco -r~~ - 36`10.36) Azimuths to True North ~! y 38 (Plenfl8. 10.38L7) M Magnetic North: 24.40° Created By: Bill Michaelson Date: s/62005 iaaKEiR _ 3911111 D-39) _ _- _ _ --___--_ HUGHiEg bit - PIanDB, 10.38L2 Magnetic Field ,,,,1;;~t Inrorn,.,rn~n w[ur4r11 Dnuu r./ - Pan p8 Streitgth:57597nT JamesOhlinger rN.a,lo-zou Dip Angle: 80.76° Drtecr (907) 267-6610 hn.twNp14 1oJ! 1, 1 L(~ Dale: 4/4/2005 Cell. (907) 250-7375 TN w MD1 110TlA0 Model: bggm2004 -inai james.ohlirger inleq.com [1n NMN z [OI. 001°1m w.ln°Nltosl 10{.0011 vA.°D.. orl~1. or1~~ s1..1w~ A°0N w rroro r -6000 '. - MAO' OAO 0.00 0.00 ~ ~ _. - - -__ _ _ _ _ I REFERENCE INFORMATION - -~ - - -- _6100 I ~~ C ~ F -1 + 1--'- I . ~- } 1 ~-.~'-: ~ { ~' ~. Co ord nate (N/E) Refers ce: W II Centre. 36. True Nonh i : I 1 I I ~ I Vertical (ND) Refers c Syste .Mean Sea Level ~ ' ~ (( ( '~ Secron (VS) Refers Us Delined (O.OON OOOE) -6200 -`{ 1 F i ~- T ~ ~' - 1 = } t - -°~ 1 Measuretl Deplh Retere W Ilhead(106) 106.00 ~ I I I I I ~ ~ I Calcularon Meth d. M' m Curvature 1 '' ' .. -6300 ~ - ~ r 1 I ' .. 1 ~ ~ ~--, ' + 1 ~ . ~ + . u ... rs !,. .,1 serve .ra caw os.! rrav r-[.1 I ~ 36 Ran718.~ 1Drr-3~61 1 m:S: -6400 . i ~ I i `.. ;. , ~ ~ -f-- -~ J . ---1 - ~L_ ~- '. ! _ • ~+ ..wau I t ~ % PlanpB t0.38L2 !,01.10 1--1-6500 t a: 1 m e io iv t u oaaen 'i.aa. ai ie~i ''m ~a 11 1l0I a 1 C1a 1 sw1 !vle.00 ~ ~ •~ I 1 - e! 1.a -6600 I 'I ~ i ,I I / ~ ( ..}. O (, t i j I I -erouno[o __ _-~_ w __ O -6700 i :1 I 1 ~_ _~ e°m° w ~ I : ~ I I ~. ~.- ~ ~ ' .~.: , Tw ro Y.w.De. °° s..! O[laAO 110]!.0] TM .w wP" ~ ~ 1 ~ I I oao.u nau.oo Kor ter„-.1„° eb -6800 -;} ~ ,1t':.. ~ II-++-. owTAO llsu.oo [w l~nw•DU sas i.,l.,i e"Bm '~ I I '~ t L2 Ta t3 10, 7_. ,o ~ a,a,n erlee .~. Z sazlAZ 114so.ss 4 ,oseu n-o•• ens oo .e..1 ,° amao w,,. L I 1 1 I ~ ~ ( ' 1 9 I [l1 a.l.1„n.x .,,a 10.N00•Dl[ _ ' l QDl.O! HON.lO . }-, I i t-f i _ . , I ~ ~: iaoiii iiiil6°i iw :o~n[D~DU ~ -6900 I ~- I - usias iii i w io O 000 1 ' ~ I • I~~ _' I ~ : / I . ;. T AOOA0100il.00 TD - ' r1.r I I i I _ 1 I~I 1 11 :: 14H } r -7100 L r ~ ,~ ,~ ~ , ,o-36LZ 9e1+1 ill! ~ ~ I I rn -7zoo .l 6 ~ ~ _, 5900. . ! . - . ~ I ! ~ i ..~ I `~ I I ~ I -7300 I -I . nP ~ {- ~ i i I( 5950 ~ ~ I I , .I ~ r r, „i._... I. ,.,... __ KoP 1 sLZra~1z ~.'./~. ~, '.,;. ' 1 u • 1 I 1 - I ErM 9'/tU0' DLS 20_/100 DLS ~ - -I _ , i 1 , - I -7400 1 1 6000 ; i -~ r ~ - ~ 7.+~... ~ 14 ~ I I' r I ~ ~ ~' ~ -7500 I ;:~ ' _ ~ _ I ~~ ~. ~ i.. C 6050 .. `+ 1'-'-~ 11 I f ~ 6 ~. 4 ; 1 1 a I 39 (1 D-39 t -7600 ~ ++f .. I ~ -_ ~ ~-' a7 6100 + -r1 }._,.I ~ :'~ # _7s1io-7s1~ '. ~ f. '.i ~ I.i! I I~~'~. O 11 !~ ~ I -7700 I End 455°n 00' DLS X6150 ~ 'T{ { :, x6200 _, I , ! ~ - 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3 ~0; 3300 3~0 ;SiO 3600 3700; 800 3900 4000 4100 4 J 200 4300 4400 4500 4600 4700 d West - /East + 100ft/in R~ 6250 .,. .. ... nP d R KOP 6 Erd 20°100' DLS 6 ', '. ' (n iJ 6300 -'- 70.38L2 Ta e12 i9 10 I • 3~ ErM 9°/100' DLS _ I - - -. ~ Ta et 1 ~ 1 _ _ y`6350 ~d5°n00'DlS .- .. ,,i ~ 10.36LYTa et4 1 r~ '~ 64(10 ' !+ -; I I ~ 10.38L2 +~ 3611D-36] : «_-. } ... ~ ,.. .. .. l ...-. I _. ~ . ~ f ~, } fl i ~ Plan#~~%anp8 1636L1 04 1 1;_ll ~. - I Ir ~{I .L / tl :,, . I 'r it I I + •_~ 6500 i :T ;I... ~I ,;. { ..;- } ,- ..t a .: + ! I ~~ 1 I .I , '. 3911639) ~. 1.~ I 1 :~ I I .I ~ I,I I ~ ~- ,~ ~ 1 - I~ 1 I 1 i -~' i 1. f 6550 f I ~ :.,I r.:' ~I t~:i fi , 1,.,'i I':il '~ I of ' ~'ll (.-t 1 ~ ; I ~ ;; ; ~ ~ ,1, ssoo -5150-5100-5050-5000-4950-4900-4850-4800-4750-4700-4650-4600-4550-4500-4450-4400-4350-4300-4250-4200-4150-4100-4050-4000-3950-3900-3850-3800-3750-3700-3650-3600-3550-3500-3450-3400-3350-3300-3250 Vertical Section at 30.00° [50ftlin] • • - ~ ~ Kuparuk DOBCTD BOP configuration 2" CT Weil 1 D-36L1, Rig Floor 3` 5000 psi ~ Lubricator ID = 6.375' with 6" Otis Unions ^ 71116' 5000 psi BOP's. ID = 7.06' 71/16' 5000 psi, RX-46~ 1/4 Tum LT Valve HCR H R Choke Line Kilf Line 21/16` 5000 psi , RX-24 71/16" 5000 psi (RX-46) or 4- 41116" 5000 psi (RX-39) Swab Valve Tree Size SSV ~~ ~ Master Valve ~J --- Base Flan e Page 1 CRU 1 D-36L2 'roposed 1-Oil Cuparuk "C" Sand !050850 onfidential wells are red FD 5/27!2005 '~--,--~ , o-, , t2 • ,o-,~, 30 29 • 10-72U Feet 1 ,000 2,000 3,000 4,000 Re: KRU 1D-36L1 and -36L2 Subject: Re: KRU 1D-36L1 and -36L2 From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 02 Jun 2005 09:07:50 -0800 To: "Kolstad, Scott R" <KolstaSR@BP.com> Hi Scott, I was looking at the tubular details section where the and is given to be 13300 for each lateral. You are correct that the and in box 6 is 13375. Only other question is, how much "flow area" does the LSX provide?? I will move the permits forward. Tom Maunder, PE AOGCC Kolstad, Scott R wrote: Tom, I'll answer your questions from the bottom up. - L1 is the lower lateral targeting the C1/C2 sands. It is not necessary to retrieve the LSX whipstock used for this window exit. The liner for L1 is planned to be just above the whipstock. - The LSX is a Weatherford permanent whipstock (LSX stands for low side exit, but the LSX is not exclusively a low side exit whipstock). This is not a flow through whipstock, but it does not seal against the casing so there is some fluid bypass. - The upper lateral, L2, will use a Weatherford retrievable whipstock stung into a flow through packer. You are correct that this whipstock tray will either need to be retrieved or perforated (depending on whipstock tray used) to gain production from L1. After step 14 of the planned program, please add: 14a. Retrieve whipstock tray. - The and of both laterals is 13,375'. My copy of form 401 has this number in box 6 for both permits. Is there another place? - The pressure deployment technique is a standard that has been used successfully at Kuparuk and Milne for the CTD Dynamically Overbalanced Drilling programs when there is not a SSSV in the well. Hope this answers your questions. Thanks, Scott 564-5347 -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin,state.ak.us Sent: Tuesday, May 31, 2005 9:05 AM To: Kolstad, Scott R Cc: Dan Venhaus Subject: Re: KRU 1D-36L1 and -36L2 Scott, Further to my earlier message. 1. The planned pressure deployment will use the BOP to control pressure. Has this technique been employed in Kuparuk before?? I presume that basically you are stripping the BHA into the well. 2. The directional plan for both wells shows 13375' and as the planned TD. The 401 only has 13300' and shown. Which is it?? Tom Maunder, PE AOGCC Re: KRU 1D-36L1 and -36L2 . Thomas Maunder wrote: Scott, On the procedure for -36L2, there is no step to retrieve the whipstock. That is necessary isn't it to gain access to -36L1 and the original completion interval?? I was also wondering if you might send some information on the LSX whipstock. As I understand this whipstock is "flow through". Is the upper whipstock also LSX?? Thanks in advance. Tom Maunder, PE AOGCC 6/2/2005 1:04 PM • PERMIT TO DRILL 20 AAC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ON5 "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~<~'~,~ ~~ "'~~ ° ~' ~ "'~~~~b c~ ~ . Permit No,2iV:r='~l3~API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT BOLE In accordance with 20 AAC 25.005(f), all (p)er records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PIS and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~~~v Rev: 04/01!05 C\j ody\tra ns m ittaf_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL -490100 _Well Name: KUPARUK RIV UNIT 1D-36L2 Program DEV Well bore seg ^~ PTD#:2050850 Company CONOCOPHILLIPS ALASKA INC Initial Classffype DEV! PEND GeoArea 890 Unit 11160 On/Off Share On Annular Disposal Administration 1 Permit fee attached________ _____________--_ ________-- -----. NA__ _ __-__Multilateralwellbore;f_eewaived-per2QAAC25,005(e)-__-__ _-_-_____-.-_-______ ------ 2 Lease number appropriate_ ______________________________________ Yes_ ____-Top_productiveintervaland TD inADL025661,---_____ -__ ___-_ __----,__----------_ 3 Uniquewell_nameandnumber_________________________--_-------.. Yes- __-__--_-.__--__-__- 4 Well located in.a-defined_pool_ - - _ - - Yes , Kuparuk River Oil_Pool, governed by Conservation Order No. 4320 - 5 Well located proper distance from drilling unit_boundary_ Yes - - - - -Conservation Order No. 4320 contains no spacing restrictions with respect-to drilling unit boundaries. _ 6 Well located proper distance_ from other wells- Yes - - - , Conservation Order No. 4320 has no inlerwell_spacing-restrictions, - . _ -- - 7 Sufficient acreage available in-drilling unit_ _ _ - _ - Yes _ Conservation Order No. 4320 has no interwell-spacingrestrictions, Wellbore will be_more than 500' from 8 If deviated, is-wellbore plat_inctuded - . Yes _ - an-external property line-where_ownership or_lan_downership changes. - - 9 Operator only affected party__---_____-------------------_ Yes- ----------------- _--.- -------------------------------------------------- 10 Operatorhas_appropriate-bond in force- -------- ------- ----- - - - Yes- ----- -- -- -- ----- - ----- --- - -- -- - -- -- - -- --- - -- 11 Permit_canbeissuedwithoutconservationorder____________________________ Yes_ _____--____-.__--__-----__-_____---_ Appr Date 12 Pe[mit_canbeissuedwithoutadministrative-appr_ova_I_________________________ Yes_ _--_-,__--__--__-__-__---,-__--- _ -_- _ _ _ SFD 5/27!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Order # (put_1O# in-comments)_ (For- NA- _ - _ _ - -- 15 All wells_within 1!4_mile area of [eyiew identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ _ .. _ _ - _ _ - - . - - - _ - _ _ - - - - - _ - - - - - _ . --------------------------------- 16 Pre-produced injector; duration_of pre Production less than_ 3 months, (For_service well only) NA_ _ _ - - _ - . - -- 17 ACMP-Finding of Consistency-hasbeenissued_for_thispcoiect____ _______________ _N_A-- __,____----___---__----.-_-----__ Engineering 18 Conductorstring_provided ______________________________--_------ NA__ ---___Coductors_etinmather-bore,1D-36 _(200,130),____-._-_________--___-__-_______, 19 Surface casing_prgtectsall-known_ USDWs - - _ - - _ - - - - NA- - _ All aquifers exempted, 40 CFR_147.1Q2-(b)(3)._ --------------------------- 20 CMT_vol adequate-io circulate_on conductor & su_rf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - _ _ _ - _ Surface casing set inmother-bore: - - _ _ _ _ _ _ - . _ _ _ _ _ - - - _ _ _ _ _ _ - - - _ - . --------------- 21 CMT-vol_adequate-to tie-in long string to surfcsg________________________ ___ NA, ___ _Production_casingse_tin_mother-bare._--____-.--_____---____-----__-----__------_-_ 22 CMT_will cover all knownproductive horizon_s_ _ - - _ _ _ _ _ - No_ Slatted liner completion planned... Production casing cemented in mother-bore. 23 Casing designs adequatefo[C,T,B&_permafrost_________________ ______ Yes_ -.____--______-__-___---, -_---_-___-----__------_--_ 24 Adequate tankage-or reserve pit _ _ - Yes Rig is_equipped with steel_pits. No rese_rve_pitplanned, All waste to_approvedannulus or disposal wells. 25 If a_re-dill, has_a_ 1.0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ - - - - - - 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ _ -Proximity analysis performed, Nearest wellbore-is L1_ lateral X11' tyd below at KOP, Sections are paralled _ _ - - _ 27 If diverterrequired, does it meet regula_tions_ _ - _ - - NA_ - _ - - - BOP stack_already inplace, - - and_70' tvd separated at TD. - - -------------- Appr Date 2B Drilling fluid-program schematic-& equip listadequate- - - - - - - - - - - - - Yes _ - , Maximum expected formation pressure 10.0 EMW._ Plan is to drill with dynamic overbalance and-8.6 ppg fluid._ _ TEM 6/2/2005 29 BOPEs, do they meet regulation - _ _ - Yes Two hole volumes of kill weyht_tluid will_ be-availaable atthe rig site.- - .. - ~G~ 30 BOPE-press rating appropriate, test to_(put prig in comments)- - . Yes - - - MASP calculated at 2622 psi 350QpsrBOPtwt-planned, 31 Choke.manifoldcomplieswlAPI_RP-53(May84)___________________________ Yes- ____----____---____------_---_--__--__ ------------------------------------ 32 Work will occur without operation shutdown- _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ - - , _ - - 33 Is presence-of H2$ gas-probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - -1 D pad_has reported H2S, Drilling-fluid shuld preclude_H2S on rig._ Rig has sensors and_alarms._ _ _ - - _ _ - . - 34 Mechanical cond~ion of wells within AOR verified (Fors_eruice well only NA- - _ - - - - - Geology ~ 35 _ Permit_can be issued wlo hyd[ogen, sulfide measures _ No- - _ - Original well bore,has measured 36 ppm H2S._ H2$ meas_ures required. - - _ - - - _ _ - 36 Data_presented on_ potential overpressure zones _ - . _ _ Yes - - - - - -Expected reservoirpressure is 10.0 ppg EMW; will be drilled with_ coiled_tubing, 8.6 ppg mud, and sufficient - - . - Appr Date 37 Seismic analysis of shallow gas-zones_____________ ____________ ______ NA_- __-___presseretomaintain1l.ZppgECD._---____________-----_____.----_ -_, _- SFD 5127/2005 38 Seabed condition survey-(ifoff-shore) _ _ - , _ _ _ NA -- - --__-- 39 Contact name/phone for weekly progress-reports [exploratory only)- _ _ - _ NA_ Geologic Commissioner: Engineering Public Date: Commissioner: Date Commissioner Date ~J>j S ~ ~ ~ ~~ ~~~~~v 6 -2-os • • 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 Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • **** REEL HEADER **** MWD 06/12/21 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/30 941648 O1 2.375" CTK *** LIS COMMENT RECORD *** • RECEIVED JAN 1 0 ZOO1 ~k80~ & GaS (',pt1S. (,p-~yit41SSI0t1 A~ !!!!!!!!!! !!!!!!!!! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11350.0000: Starting Depth STOP.FT 13302.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-36L2 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.622" N 149 deg 30' 31.154"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 30-Jul-05 API API NYUMBER: 500292291361 Parameter Information Block #MNEM.UNIT Value Description SECT. 23 Section TOWN.N 11N Township RANG. l0E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks ~ oS _ p~5~ ~' l~(315~ • • (1} All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for 1D-36L2 wellbore. (7) The wellbore 1D-36L2 was drilled from 1D-36 through a milled window in 3 1/2" liner. Top of Window 11360 ft.MD (6295.3 ft.SSTVD) Bottom of Window 11364 ft.MD (6297.4 ft.SSTVD) (8) The interval from 13278 ft.to 13302 ft.MD (6387 ft. to 6391 ft.SSTVD) was not logged due to sensor bit offset at TD. {9) Tied to 1D-36 at 11197 ft.MD (6516 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 64 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-36L2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-36L2 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO • • MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 47 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 56 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-36L2.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-36L2 • FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 93 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 102 Minimum record length: 54 Maximum record length: 4124 **** TAPE TRAILER **** MWD 05/07/30 941648 01 11350.000000 13302.000000 0.250000 feet records... bytes bytes • • **** REEL TRAILER **** MWD 06/12/21 BHI O1 Tape Subfile: 4 2 records... r ~ Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 11350.0000 -999.2500 -999.2500 11350.5000 134.5000 -999.2500 11400.0000 93.7400 31.8600 11500.0000 84.9100 48.9000 11600.0000 103.0000 76.6500 11700.0000 98.1500 141.4500 11800.0000 106.2000 16.3000 11900.0000 141.7700 14.2600 12000.0000 110.6200 18.3600 12100.0000 77.6400 12.5900 12200.0000 113.2100 78.5900 12300.0000 115.0300 10.9100 12400.0000 103.0900 13.4400 12500.0000 111.4000 22.7800 12600.0000 98.1500 80.2400 12700.0000 96.3400 42.6900 12800.0000 97.1200 49.6300 12900.0000 102.5700 30.5300 13000.0000 101.7900 27.9000 13100.0000 100.7500 53.5300 13200.0000 105.8150 71.9600 13300.0000 -999.2500 47.7800 13302.0000 -999.2500 -999.2500 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 11350.0000 -999.2500 -999.2500 11350.2500 140.2100 -999.2500 11400.0000 103.8700 25.7400 11500.0000 91.9200 50.6400 11600.0000 100.3200 51.7600 11700.0000 93.4800 144.2200 11800.0000 98.6700 19.7000 11900.0000 126.9700 13.0300 12000.0000 109.0600 19.1100 12100.0000 84.1400 12.7800 12200.0000 118.9200 82.0400 12300.0000 111.1400 15.8400 12400.0000 108.0200 14.4700 12500.0000 100.2300 32.0000 12600.0000 96.0800 78.1700 12700.0000 97.9000 40.1000 12800.0000 108.5400 40.3800 12900.0000 116.5900 27.1300 13000.0000 114.7700 30.8000 13100.0000 104.6500 52.8000 13200.0000 101.5300 74.0800 13300.0000 -999.2500 65.4100 13302.0000 -999.2500 -999.2500 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 07/11/13 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/30 941648 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!?!!!!!!!!?!?!?! Remark File Version 1.000 ?!!!!?!!!! !!!!!?!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11350.0000: Starting Depth STOP.FT 13302.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-36L2 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.622" N 149 deg 30' 31.154"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 30-Jul-05 API API NYUMBER: 500292297361 Parameter Information Block #MNEM.UNIT Value Description ----------------- SECT. -------------- 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks aos -©8S'~ tSG9a • n (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for 1D-36L2 wellbore. (7) The wellbore 1D-36L2 was drilled from 1D-36 through a milled window in 3 1/2" liner. Top of Window 11360 ft.MD (6295.3 ft.SSTVD) Bottom of Window 11364 ft.MD (6297.4 ft.SSTVD) (8) The interval from 13278 ft.to 13302 ft.MD (6387 ft. to 6391 ft.S5TVD) was not logged due to sensor bit offset at TD. (9) Tied to 1D-36 at 11197 ft.MD (6516 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 63 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-36L2 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-36L2 APIN FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ) Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 47 Tape File Start Depth = 11350.000000 Tape File End Depth - 13302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 56 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-36L2.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-36L2 APIN FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPS ROPS ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 8 Total Data Records: 93 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 102 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/07/30 941648 O1 **** REEL TRAILER **** MWD 07/11/13 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape 5ubfile 1 is type: LIS i ~ Tape Subfile 2 is type: LIS DEPTH GR ROP 11350.0000 -999.2500 -999.2500 11350.5000 134.5000 -999.2500 11400.0000 93.7400 31.8600 11500.0000 84.9100 48.9000 11600.0000 103.0000 76.6500 11700.0000 98.1500 141.4500 11800.0000 106.2000 16.3000 11900.0000 141.7700 14.2600 12000.0000 110.6200 18.3600 12100.0000 77.6400 12.5900 12200.0000 113.2100 78.5900 12300.0000 115.0300 10.9100 12400.0000 103.0900 13.4400 12500.0000 111.4000 22.7800 12600.0000 98.1500 80.2400 12700.0000 96.3400 42.6900 12800.0000 97.1200 49.6300 12900.0000 102.5700 30.5300 13000.0000 101.7900 27.9000 13100.0000 100.7500 53.5300 13200.0000 105.8150 71.9600 13300.0000 -999.2500 47.7800 13302.0000 -999.2500 -999.2500 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GRAX ROP5 11350.0000 -999.2500 -999.2500 11350.2500 140.2100 -999.2500 11400.0000 103.8700 25.7400 11500.0000 91.9200 50.6400 11600.0000 100.3200 51.7600 11700.0000 93.4800 144.2200 11800.0000 98.6700 19.7000 11900.0000 126.9700 13.0300 12000.0000 109.0600 19.1100 12100.0000 84.1400 12.7800 12200.0000 118.9200 82.0400 12300.0000 111.1400 15.8400 12400.0000 108.0200 14.4700 12500.0000 100.2300 32.0000 12600.0000 96.0800 78.1700 12700.0000 97.9000 40.1000 12800.0000 108.5400 40.3800 12900.0000 116.5900 27.1300 13000.0000 114.7700 30.8000 13100.0000 104.6500 52.8000 13200.0000 101.5300 74.0800 13300.0000 -999.2500 65.4100 13302.0000 -999.2500 -999.2500 Tape File Start Depth = 11350.000000 Tape File End Depth = 13302.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet n Tape Subfile 4 is type: LIS