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Home My WebLink About205-061• • 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. c~ ~~- ~ ~ ~ Well History File Identifier Organizing (done) RESCAN ,Color Items: ^ Greyscale items: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria _ Project Proofing BY: ! Maria i Scanning Preparation BY: Maria ~.~.,,a~ iuimiiiuiuiiii DIGITAL DATA ~iskettes, No. f ^ Other, No/Type: Date: Date Date: I ~ I oC ~' ©' ae.~.~~~ded iuuiiiiAiiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /sl ~!~~ IIIIIIIIIIIIII VIII /S/ ~.~ ` u =TOTAL PAGES (Count does not include cover sheet) /s/ Production Scanning J ~ IIIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: (count noes include co/ver sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: f' ~ ~~ ~© ~f /s/ 1 f / Stage ? 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 IIII I II II I I III ReScanned III IIIIII IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II'I III 10/6/2005 Well History File Cover Page.doc ~~ ~- ~~~7 DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 20506'!0 Well Name/No. KUPARUK RIV U WSAK 1J-168L1 Operator CONOCOPHILLIPS ALASKA INC MD 12967 TVD 3481 Completion Date 9/26/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name ED D Asc Directional Survey ~r~D D Lis 13444~nduction/Resistivity ,~pt Lis 13444 LIS Verification ,~.~-ED C Lis 15029.~1~nduction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? ~-~AI~ Analysis ~LLAI~- Received? Comments: Compliance Reviewed By: Interval Start Stop Samples No API No. 50-029-23260-60-00 UIC N Directional Survey Yes ~.,, (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH / CH Received Comments 7107 12967 Open 11/17/2005 Definitive 3670 12909 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT 3670 12909 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT ~ 3662 12967 Open 4/17/2007 LIS Veri, GR, ROP, FET ~ w/Graphics PDF, EMF, CGM Sample Set Sent Received Number Comments (~ Daily History Received? /v, N Formation Tops /C, / N Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9901 RE: MWD Formation Evaluation Logs: 1J-168, L1, L2 & L2 PB1, April 16, 2007 AK-'VIW-3877631 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-168, 1J-168 L1, 1J-168 L2 & 1J-168 L2 PBl: LIS & Digital Log Images: 50-029-23260-00, 60, 61, 70. ~«r, ~ ~ : ~ ~ ~, ,~ ~~, ~~, ~~ ~ ~ ~~ ~~~.~~ aos ~a ~ ~sba~ SOS =cam ~ ~ ~ So2~j aa5=o~~ ~ ,so3~ ~lSo3- 1 CD Rom • • WELL LOG TRANSMITTAL To: State of Alaska January 26, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-1.68 L1, o2d~-~~ ( AK-MW-3877631 ~~ 44~- 1 LDWG formatted Disc with verification listing. API#: 50-029-23260-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETIJItNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: 1 3 p Signed • • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-168 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,107.37' MD Window /Kickoff Survey: 7,145.00' MD (if applicable) Projected Survey: 12,967.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ IU~y ~,(}~1'` Signed _~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION v ~• ~ «~ ;, , ;~ ,3 ;~ 2~Q5 WELL COMPLETION OR RECOMPLETION REPORT AND. LO.C~.,:,~t, ~~~,~„~~;~~ 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: September 26, 2005 f 12. Permit to Drill Number: 205-061 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: 1 ~:, ~~ t~~3 , 2005 - ;~,. c ~ 13. API Number: 50-029-23260-60 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, 711 N, R10E, UM 7. Date TD Reached: September 6, 2005 ~ 14. Well Name and Number: 1J-168L1 At Top Productive Horizon: 2373' FSL, 1993' FEL, Sec. 34, 711 N, R10E UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2371' FNL, 2006' FEL, Sec. 27, 711 N, R10E, UM 9. Plug Back Depth (MD + TVD): 11888' MD / 3427' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 ° y- 5945653 ' Zone- 4 10. Total Depth (MD + TVD): f 12967 MD / 3481' TVD 16. Properly Designation: ADL 25661 & 25660 TPI: x- 553933 y- 5946149 Zone- 4 Total Depth: x- 553869 - 5951965 ° Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 470 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1855' MD 21. Logs Run: ...--r-~ GR/Res, DenslNeu ~ ~ /-~~ «. ~.oS' 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 163 sx AS 1 10.75" 45.5# L-80 28' 3694' 28' 2115' 13.5" 66o sx ASLite, 18o sx DeepCrete 7-5/8" 29.7# L-80 28' 8224' 28' 3472' 9-7/8" 490 sx DeepCrete 4.5" 12.6# L-80 7148' 12967' 3294' 3481' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6131' 7246' slotted liner from 7419'-12027', 12151'-12920' 13 constrictor packers 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production October 18, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-168 and 1J-168L2 Date of Test 10/21/2005 Hours Tested 4.5 hours Production for Test Period --> OIL-BBL 286 GAS-MCF 52 WATER-BBL 0 CHOKE SIZE not available GAS-OIL RATIO 210 Flow Tubing press. 241 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1477 GAS-MCF 310 WATER-BBL 1 OIL GRAVITY -API (corr) 20.8 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". • - ~~~ ~ . ~' ?; " 7005 NONE ~~ -~ ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL 2s. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-168L1 West Sak B Sand 7142' 3294' Base West Sak B sand 12967' 3481' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader `~ ~~t ~~ T ^~ Signature Phone Date 6-~ 3v INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct welt completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • • ConocoPhillips Alaska Page 1 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 13/2005 116:30 -18:30 I 2.00 I MOVE I DM08 I MOVE 18:30 - 20:00 ~ -1.50 MOVE I DMOB I MOVE 20:00 - 23:00 ~ 3.00 ~ MOVE ~ OTHR ~ MOVE 23:00 - 00:00 8/14/2005 00:00 - 02:30 1.001 MOVE MOVE I MOVE 2.50 MOVE I MOVE I MOVE 02:30 - 03:00 0.50 MOVE MOVE MOVE 03:00 - 08:00 5.00 MOVE MOVE MOVE 08:00 - 08:30 0.50 MOVE POSN MOVE 08:30 - 12:30 4.00 MOVE POSN MOVE 12:30 - 14:00 ~ 1.50 MOVE RURD I MOVE 14:00 -16:00 2.00 WELCT NUND SURFAC 16:00 -17:30 1.50 DRILL OTHR SURFAC 17:30 - 23:00 5.50 DRILL PULD SURFAC 23:00 - 23:15 0.25 WELCT ROPE SURFAC 23:15 - 00:00 0.75 DRILL PULD SURFAC 8/15/2005 00:00 - 00:15 0.25 DRILL PULD SURFAC 00:15 - 00:45 0.50 DRILL OTHR SURFAC 00:45 - 01:00 0.25 DRILL CIRC SURFAC 01:00 - 03:15 2.251 DRILL DRLG SURFAC 03:45-05:30 10.75IDRILL (PULD (SURFAC 05:30 - 06:15 0.75 DRILL SURV SURFAC 06:15 - 12:00 5.75 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC '.8/16/2005 00:00 - 07:45 I 7.751 DRILL DRLG SURFAC 07:45 - 10:15 2.50 DRILL I REAM SURFAC Description of Operations Prep rig for move and disconnected service loops and blow down water and steam lines Staged rig complex's on 1 E pad, pipe sheds, rock washer, boilers, motors and mud pumps Began to move mud pump complex off pad to access road and broke thru road, laid plywood and moved pumps to middle of road, laid add. plywood and matting boards down on road to 1 E's main road Began moving complex's from 1E to 1J pad, moving mud pumps, pits, motors and boiler complex's Cont to move rig's complex's from 1 E pad and spotted on 1 J pad,. moved pumps, pits, motors and boilers, trucks returned to 1 E pad Moved sub base off 1 E-117 Moved rock washer, pipe sheds and sub base 9 miles from 1 E pad and spotted on 1J pad Spotted sub base over well 1J-168 Spotted rig complex's, pits, mud pumps, motors, boilers, pipe shed and berated rock washer and set in same Connected rigs service loops, got steam and water around rig and began to mix spud mud, completed rig acceptance check list and ACCEPTED RIG at 14:00 hrs NU riser and knife valve onto 21 1/4" diverter Loaded pipe shed with 5" DP, HWDP and jars PU and stood back 28 stds of 5" DP, 10 stds 5" HWDP and jars, 1 std of 8" NMFDC's Function tested diverter, knife valve and accumulator, NOTE:, Chuck Scheve waived witnessing of test PU BHA from beaver slide to rig floor, MU 13 1/2" bit #1 onto 8" motor with 1.83 deg bend Fin MU float sub and XO onto motor RIH to 35' Flooded conductor checking lines for leaks, pressure tested mud line and standpipe to 2,500 psi and ck ok RIH from 35' and tagge~ cement inside conductor at 85', cleaned out to 108' Spudded well and drilled 13 1/2" hole from 108' to 180' (72') ART 1.61 hrs POOH from 180' to motor at 30' MU BHA #1 RIH to 163', MU MWD, oriented and uploaded same, MU UBHO sub and oriented same, RIH with 1 std of 8" NMFDC's to 163' Ran Sperry Suns surface read out Gyro at 163', RIH to 180' Drilled 13 1/2" hole from 180' to 478', (298') ART 1.77 hrs, AST 2.31 hrs, 10-12K wob, 40 rprr~s, 120 spm, 509 gpm, 850 psi, ran 3 Gyro's at 256', 348' and 435' and took 1- 1/4 hrs Directionally drilled 13 1/2" hole per directional plan from 478' to 1,270' MD/1,205' TVD (792') ART 7.98 hrs, AST 1.43 hrs, 10-25K wob, 40 rpm's, 120 spm, 509 gpm at 1,150 psi, off btm torque 1-5K ft-Ibs, on btm 1-4K ft-Ibs, rot wt 88K, up wt 85K, do wt 81 K, ran 2 Gyro's at 530' and 622' and took 1/2 hr, After Gyro at 622' RD unit at 16:30 hrs Continue Directional drill 13 1/2" hole from 1270' - 1936' (666'). TVD = 1552' Upweight = 95K, SO WT = 70K, Rot Wt = 81 K. TQ on btm = 5-8K TQ off btm = 2-6K. ART = 1.13 HRS. AST = 4.25 HRS ADT = 5.38 HRS. Jars = 86.78 HRS. WOB = 20-35K. 40 RPM's. Pumps @ 535 GPM's with 1600 PSI. BROOH from 1936' - 530' (1406'), to set mud motor @ 1.5 Degrees. Printed: 10/21/2005 2:52:30 PM • • ConocoPhillips Alaska Page 2 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code 8/16/2005 07:45 - 10:15 2.50 DRILL 10:15 - 11:00 0.75 DRILL 11:00 - 12:00 1.00 DRILL 12:00 - 13:30 1.50 DRILL 13:30 - 14:15 0.75 DRILL 14:15 - 00:00 9.75 DRILL 8/17/2005 00:00 - 07:30 7.50 DRILL 07:30 - 08:30 1.00 DRILL 08:30 - 09:30 1.00 DRILL 09:30 - 12:00 2.50 DRILL Sub .Phase Description of Operations Code REAM SURFAC Pumps @ 650 GPM's with 1650 PSI. TRIP SURFAC POOH on elevators from 530' - 51' (479'). PULD SURFAC POOH & lay down UBHO sub. POOH to surface. Clean & inspect bit and orient Mud motor to 1.5 Degrees. PULD SURFAC Make up Pressure Drop Sub.Observed that the Retaining orifice had fallen on top of Mud Motor Stator and damaged Motor. Change out 8" Mud Motors. New motor is Sperry Drill Lobe w/ 4/5 - 5.3 stage, at 1.5 degrees. MU 13 1/2" Hughes MX-1 Roller Cone Bit, with 1 x 13, and 3 x 20 for a TFA of 1.050". Continue MU MWD assembly, 1 -stand 8" NMFC's, crossover, 5" HWDP, JARS, and Ghost Reamer. TRIP SURFAC TIH from 1084' - 1890' (806'). Wash from 1890' - 1936'. (46'), at 623 GPM's with 1700 PSI. DRLG SURFAC Continue Directional drill 13 1/2" hole from 1936' - 3060' (1124'). TVD = 1892'. Upweight = 97K, SO WT = 66K, Rotate Wt = 79K. TQ on bottom = 7.5K off bottom = 6K. ART = 4.43 HRS, AST = 2.02 HRS, ADT = 6.45 HRS. Jars = 93.23 HRS Max Hydrates = 3788 Units @ 2890' MD TVD - 1838'. WOB = 5-20K, 80 RPM's .Pumps @ 708 GPM's with 2025 PSI. DRLG SURFAC Continue Directional drill 13 1/2" hole from 3060' - 3704' (644'). TVD = 2118.44'. Upweight = 125K, SO WT = 57K, Rotate Wt = 86K. TQ on bottom = 10K off bottom = 10-12K. ART = 3.33 HRS, AST = 1.88 HRS, ADT = 5.21 HRS. Jars = 98.44 HRS Max Hydrates = 3088 Units @ 3170' MD TVD - 1928'. WOB = 10-20K, 80 RPM's .Pumps @ 650 GPM's with 2000 PSI. Total Bit Hrs = 32.14. Total Footage = 3596' CIRC SURFAC POOH, rack back 1 stand. CBU @ 3652' while reciprocating string @ 177 SPM, 2150 PSI, 80 RPM's and 8-11 K Torque. REAM SURFAC Pick up 1 stand Dp, attempt to tag bottom, NO-GO. Wash l;< ream back to tag bottom at 3704' @ 181 SPM, 2350 PSI. 10-12K torque. REAM SURFAC BROOH, from 3704' - 2321' (1383'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TO @ 10-12K. 12:00 - 13:30 1.50 DRILL REAM SURFAC Continue BROOH, from 2321' - 1084' (1237'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TO @ 10-12K. 13:30 - 14:15 0.75 DRILL PULD SURFAC Rack Back 10 Stands of 5" HWDP and Jars. (917.06') 14:15 - 15:45 1.50 DRILL PULD SURFAC Breakout & lay down drilling BHA. Lay do crossover (2.52'), 3 - NMFC's ( 93.05'), Float sub (2.49'), MWD assembly (25.05'), Pressure drop sub ( 2.0'), NM Crossover (2.51'), Sleeve type stabilizer (5.08'), 8" Sperry Mud Motor (28.89'), and Hughes MX1 13 1/2" bit (1.00'). Gauge bit to 2/2/WT/A/0/I/NO/TD 15:45 - 17:45 2.00 CASE RURD SURFAC Rig Up to run 10 3/4" 45.5# casing. Held Pre- Job safety meeting. Discuss running order, centralizer placement, and make up torques. 17:45 - 20:15 2.50 CASE RUNC SURFAC Make up 10 3/4" shoe joint, w/ Weatherford Model 303 Sure Seal Float Shoe, 1 JNT 10 3/4" 45.5# casing, and Float collarjoint w/ Weatherford Model 402 Sure Seal Float Collar. Continue RIH with 10 3/4" casing as per running order palcing centralizers on 5' above Shoe, 10' Below Float collar, 10' above Float collar, and 1 each on every collar from jnt # 4 - 20.RIH to 1900' Make up Torque = 10K 20:15 - 21:00 0.75 CASE CIRC SURFAC CBU @ 2 BPM - 200 PSI, 3 BPM - 225 PSI, 4 BPM - 250 PSI, 5 BPM - 300 PSI while reciprcate string.. JNTS # 50 & 51 21:00 - 23:00 2.00 CASE RUNC SURFAC Continue RIH w/ 10 3/4" 45.5# casing from 1900' - 3693' (1793'). Make up Landing Joint &RIH to land hanger @ 29.99' RKB to spool. Upweight = 180K . SO weight = 68K 23:00 - 00:00 1.00 CASE CIRC SURFAC Circulate & condition mud while reciprocate string 10'. 3.5 BPM = 275 Printed: 10!212005 2:52:30 PM • • ConocoPhillips Alaska Page 3 of 29 Operations Summary Report Legal Well Name: 1J-168 Common W eII Name: 1J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLING Start: 8/13/2005 End: Contractor Name: n1334@ ppco.co m Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations 8/17/2005 23:00 - 00:00 1.00 CASE CIRC SURFAC PSI, 4 BPM = 275 PSI, 5 BPM = 300 PSI, and 6 BPM = 350 PSI. Upweight = 160K, SO Weight = 65K with pumps on. 8/18/2005 00:00 - 00:15 0.25 CEMEN CIRC SURFAC Continue circulate 8r condition mud while reciprocate string 10'. 6.5 BPM = 375 PSI, Upweight = 165K, SO Weight = 60K with pumps on. 00:15 - 00:45 0.50 CEMEN PULD SURFAC Breakout & lay down Franks Fill UP Tool. Load cement head & MU head and lines to Landing Joint. 00:45 - 02:00 1.25 CEMEN CIRC SURFAC Continue circulate & condition mud while reciprocate string 10'. 6.5 BPM = 325 PSI, Conditioned mud from a 9.5 PPG, Visc = 260, PV = 41, YP = 54, Gels @ 20/51 /70 with a PH of 8.6, to a 9.2 PPG, Visc = 40, PV = 18, YP = 9, Gel @ 1/2/2, with a PH of 8.4. Upweight = 165K, SO Weight = 60K with pumps on. Hold Pre-Job Safety Meeting with entire crew, truck drivers and Cementers. 02:00 - 05:15 3.25 CEMEN PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 at 8.35 ppg @ 4 13PM - 50 PSI, pressure tested lines to 3,500 psi, pumped additional 40 bbls of CW 100 (50 bbls Total) @ 5.4 BPM - 85 PSI, then pumped 50 bbls of 10.5 ppg XL Mudpush with Red Dye, avg 5 bpm at 110 psi, shut down and dropped btm plug, Mix and pump Lead cement, Pumped a total of 531 BBLs of 10.7 ppg Arctic set lite cement with a yield of 4.49, with additives,660 sacks, Avg pumping @ 6.6 BPM 140 PSI. Upweight = 175K, SO WT = 73K. Landed casing in hanger @ 485 BBLS into Lead as we observed reciprocatiion becoming "sticky". Upweight = 190K, SO WT = 65K. Mix 8~ pump 83.6 BBLS of 12.0 PPG Deepcrete Tail Slurry, Yield = 2.47, with additives, 180 sacks, avg 6.1 bpm at 200 psi, shut down and dropped top plug. Dowell pumped 20 bbls, 8.35 PPG FW for flush, and turned over to rig. Rig displaced cmt with 325 bbls of 9.2 ppg mud, ave 7 bpm, initial pressure 680 psi, max pressure 690 psi, slowed to 3 bpm and bumped plug on talc displacement of 325 BBLS = 3227 STKS to 1,000 psi, check floats and floats held, CIP at 05:15, Had 103.4 bbls of 10.7 ppg lead cmt back to surface. RKB to landing = 29.99' 05:15 - 06:30 1.25 CEMEN PULD SURFAC Rig down Cement Equipment. Backout 8~ lay down landing jnt. Flush stack. 06:30 - 09:30 3.00 WELCT NUND SURFAC Nipple down diverter system. 09:30 - 11:00 1.50 WELCT NUND SURFAC Nipple up wellhead as per Vetco rep. Test lower flange to 5000 PSI. 15 minutes. 11:00 - 12:00 1.00 WELCT NUND SURFAC Nipple up BOP stack, choke & kill lines. 12:00 - 13:00 1.00 WELCT NUND SURFAC Continue Nipple up BOP stack ,choke & kill lines. 13:00 - 14:00 1.00 WELCT NUND SURFAC Change out Lower pipe rams from 5" to 7 5/8" rams, 14:00 - 15:45 1.75 DRILL RIRD SURFAC Change out Top Drive saver sub, grabbers, & bell guide to 4". 15:45 - 21:45 6.00 WELCT ROPE SURFAC RU and tested ROPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC witnessed test, recorded on chart. 21:45 - 22:15 0.50 DRILL OTHR SURFAC Install wear bushing. RILDS. WB ID = 12 1/4" 22:15 - 00:00 1.75 DRILL PULD SURFAC Pick up ~ rack back 6 stands of "PUSH PIPE". Stands are made up of 2 jnts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. 8/19/2005 00:00 - 01:00 1.00 DRILL PULD SURFAC Continue to pick up & rack back 9 stands of "PUSH PIPE". (15 studs Total) Stands are made up of 2 juts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. 01:00 - 06:15 5.25 DRILL PULD SURFAC Pick up 180 Jnts, (60 studs) of 4" XT-39 drill pipe and rack back in Derrick. Printed: 10/21/2005 2:52:30 PM ~ • ConocoPhillips Alaska Page 4 of 29 Operations Summary Report Legal Well Name: 1J-168 Common W ell Name: 1J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLIN G Start: 8/13/2005 End: Contractor Name: n1334@ ppco.co m Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Phase Description of Operations Code 8/19/2005 06:15 - 07:30 1.25 DRILL PULD SURFAC Rig up and lay down 21 juts of 5" HWDP from derrick. lay down mousehole. 07:30 - 08:00 0.50 DRILL PULD SURFAC Clean floor area, pull BHA equipment to rig floor from beaver slide. 08:00 - 09:45 1,75 DRILL PULD SURFAC Hold PJSM. "Making up BHA #3 ". Make up 9 7/8" BHA as per Dir Driller. MU 9 7/8" Security FS2653 PDC bit (1.60') with a TFA of 1.845 sq in. 7600 Series Geo-Pilot (20.15'), 6 3/4" Non Mag GP Flex Pony collar (9.20'), 6.770" Smart Stabilizer (2.18'), 6 3/4" MWD GR / RES / PWD (20.93'), 6.770" Smart Stabilizer (2.16'), 6 3/4" MWD HCIM 6.83'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). 09:45 - 10:15 0.50 DRILL PULD SURFAC Plug in and upload MWD Equipment. 10:15 - 11:00 0.75 DRILL PULD SURFAC Continue making up BHA picking up 3 -Non Mag Flex Drill collars 91.66'), 4 -HWDP (123.4'), 6 1/4" Drilling jars w/ 98.43 Hrs (30.38'), 1 stnd 4" DP. 11:00 - 11:30 - 0.50 DRILL PULD SURFAC Perform Shallow pulse test MWD /Geo Span @ 538', at 550 GPM's - 1050 PSI. 11:30 - 12:00 0.50 DRILL PULD SURFAC Continue MU 18 JNTS 5" DP (571.29), 6 1/2" Ghost reamer (5.08'), 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer (6.34'). 12:00 - 13:30 1.50 DRILL PULD SURFAC Continue MU 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer 6.34'). RIH to tag Float Collar @ 3609' DPM. Pull up to position bit @ 3586'. 13:30 - 14:00 0.50 DRILL PULD SURFAC CBU @ 650 GPM's - 2050 PSI. Up weight = 115K, SO WT = 53K Rot WT = 79K TO = 6-8K 14:00 - 15:00 1.00 CASE DEQT SURFAC Rig up and test 10 3/4" casing to 3000 PSI. Held test 30 minutes and recorded on chart. Good test. Bleed Pressure and Rig down test lines. 15:00 - 15:15 0.25 DRILL REAM SURFAC Wash down from 3586' - 3609' (25'). 15:15 - 17:45 2.50 DRILL DRLG SURFAC Drill through float equipment. Float collar @ 3613', Shoe track, and Float Shoe @ 3693', Continue drill 20' of 9 7/8" new hole to 3724' MD at TVD of 2128'. ADT = .19 HRS. Up weight = 120K, SO WT = 52K, ROT WT = 80K, RPM's @ 100 Tq on btm = 6-8K, Pumps @ 600 GPM's - 1800 PSI. Obtain SPR's @ 3678' MD, TVD = 2112'. #1 pump 30 SPM - 220 PSI. 40 SPM - 290 PSI. Pump #2 - 30 SPM - 170 PSI, 40 SPM - 220 PSI 17:45 - 18:15 0.50 DRILL CIRC SURFAC Circulate & condition mud displacing well with re-conditioned 9.0 PPG mud, @ 600 GPM's - 1800 PSI. On btms up, Density = 9.0 PPG, Gels 10 min = 14 18:15 -19:00 0.75 DRILL LOT SURFAC RU lines and Perform LOT to Equivalent Mud Weight of 15.3 ppg, with 691 PSI, 9.0 ppg mud, Shoe TVD 2115' (EMW pick by computer). Record on chart. Bleed all pressures and rig down lines. 19:00 - 00:00 5.00 DRILL DRLG INTRM1 Directional drill 9 7/8" hole with Geo-Pilot from 3724' - 4184' MD (460'). TVD = 2294' ADT = 2.81 HRS. UP WT = 124K, SO WT = 50K, ROT WT = 75K. Torque on btm = 6-8K, off btm = 7-9K. 100 RPM's, WOB = 10-15K, Pumps @ 550 GPM's - 1500 PSI. Jars = 101.43 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD = 9.8 PPG Total Bit HRS = 3.0 8/20/2005 00:00 - 12:00 12.00 DRILL DRLG INTRMI Directional drill 9 7/8" hole with Geo-Pilot from 4184' - 5362' MD ~, 1178'). TVD = 2752' ART = 7.91 HRS. UP WT = 134K, SO WT = 59K, ROT WT = 81 K. Torque on btm = 9-12K, off btm = 11 K. 60 RPM's, WOB = 5-25K, Pumps @ 450 GPM's - 1250 PSI. Jars = 109.34 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 10.91 The drilling parameters were adjusted to directionally control assembly in the soft formation. 12:00 - 15:30 3.50 DRILL DRLG INTRM1 Directional drill 9 7/8" hole with Geo-Pilot from 5362' - 5642' MD 280'). TVD = 2842' ADT = 2.29 HRS. UP WT = 132K, SO WT = 55K, Printed: 1021/2005 2:52:30 PM • • ConocoPhillips Alaska Page 5 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code' Phase 8/20/2005 ~ 12:00 - 15:30 ~ 3.50 ~ DRILL ~ DRLG ~ INTRMI 15:30 - 19:00 3.501 DRILL STRIP ~ INTRMI 19:00 - 19:30 I 0.50 ~ DRILL CIRC l INTRM1 19:30 - 22:00 I 2.501 DRILL I TRIP I INTRMI 22:00 - 22:45 0.75 DRILL PULD INTRM1 22:45 - 23:15 0.50 DRILL OTHR INTRM1 23:15 - 00:00 0.75 FISH PULD INTRMI 8/21/2005 00:00 - 01:30 1.50 RIGMNT RSRV INTRM1 01:30 - 03:30 2.00 FISH PULD INTRM1 03:30 - 06:15 2.75 FISH TRIP INTRM1 06:15 - 11:00 4.751 FISH I WASH ~ INTRMI 11:00 - 12:00 I 1.001 FISH I FISH I INTRMI 12:00 - 13:00 I 1.001 FISH I PULL I INTRM1 13:00 - 14:00 1.00 FISH CIRC INTRM1 14:00 - 15:15 1.25 FISH PULL INTRM1 15:15 - 15:45 0.50 FISH CIRC INTRMI 15:45 - 18:30 2.75 FISH PULL INTRMI 18:30 - 19:30 I 1.001 FISH (TRIP I INTRMI Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations ROT WT = 80K. Torque on btm = 14K, off btm = 10-12K. 90 RPM's, WOB = 10-25K, Pumps @ 585 GPM's - 1900 PSI. Jars = 111.63 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 13.2. Lost MWD communication, could not regain it. Monitor well, BROOH from 5642' - 3693' Shoe depth (1949'), at 90-100 RPM's 650 GPM's - 1750 PSI. Observed 30 - 40% increase in cuttings over shakers while backreaming Pump Hi Visc sweep and CBU 2 -times @ 700 GPM's - 1750 PSI. 30 - 40% increase in cutting while circulating Monitor well -static. Pump Dry Job, POOH from 3682' -surface. Stand back HWDP, Jars, and NM Flex Collars. Breakout Float sub. Pull up & Observed MWD tool broke and parted at the crossover below MWD HCIM and above Smart Stabilizer. Total fish left in hole = 57.90'. The OD Of break = 6.223". Left in hole -Crossover top (1.68'); 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR / RES / PWD (20.93'), 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar (9.20'), 7600 Series Geo-Pilot (20.15'), and 9 7/8" Security bit (1.60'). Fishing neck looking up = 1.68' Breakout & lay down MWD TM HOC and HCIM assembly. Clean Rig floor area, and send tools down beaver slide. Load pipe shed with 6 - 6 3/4" Drill collars, strap same. PJSM, Slip & Cut 45 FT of Drilling line. Service Top Drive Make up BHA #1 Fishing Assembly. MU 9 5/8" Series 150 Overshot dressed with a 6 1/4" Grapple and Mill Control packoff, and Guide with tungsten carbide welded on (3.75"), 6 1/4" Pump out sub (2.02'), 6 1/4" Lubricated Bumper Sub (9.00'), 6 1/4" Oil Jar (11.23'), 3 - 6 3/4" Drill Collars (91.83'), and Accelerator Jar (12.91'). Total BHA lenght = 130.74. Trip in hole from 130' - 3732' (3602'). Shoe depth = 3693'. Tag up, taking 5K weight. Upweight = 85K SO WT = 35K Wash & ream through open hole from 3732' - 5575' (1843'). Observe minimal pressure increases and could not verify that we were pushing fish. Pumps @ 50 SPM - 250 PSI, Up Wt = 110K, SO WT = 40K, Rot WT = 70K, staging pumps up 75 SPM - 600 PSI, and 115 SPM - 800 PSI. Note: Held Pad evacuation drill along with Nordic 2, and Construction. Wash over top of fish at 5588' DPM. 60 SPM - 400 PSI. 40 RPM's. ,Observed little or no pressure increase, and no increase in up weight 'when set down 10k, and pull up. Repeat several times to attempt to catch fish. No indication of fish on. Up Wt = 125K, SO WT = 75K TO = 17K. Attempt to POOH- Hole swabbing, Pump out of hole from 5588' - 5040' ( 548'). Circulate Bottoms up @ 360 GPM's - 500 PSI. Continue Pump Out of hole into shoe from 5040' - 3600' (1440') @ 360 GPM's - 500 PSI. Note; Hole swabbed all the way to the shoe without pump. Circulate Bottoms up @ 420 GPM's - 400 PSI.. Momitor well -static. Pump Dry job. POOH from 3600' - 130' (3470'), on elevators. Observe overpull of 55K at shoe. (overshot at shoe) Stand back drill collars and pull 9 5/8" overshot to rig floor. NO-FISH. Breakout & lay down Overshot assembly. Inspect 6 1/4" grapple and mill control packoff. Observed packoff rubber gone, indication marks on P~intetl: 10/21/2W5 2:52:30 F'M • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From-To Hours Code Code', Phase 8/21/2005 ~ 18:30 - 19:30 ~ 1.00 ~ FISH ~ TRIP ~ INTRM1 19:30 - 20:15 20:15 - 20:30 20:30 - 00:00 18/22/2005 100:00 - 00:30 00:30 - 00:45 00:45 - 04:45 04:45 - 05:00 05:00 - 06:00 06:00 - 09:45 09:45 - 12:00 0.751 FISH I OTHR I INTRM1 0.251 FISH I PULD I INTRM1 3.501 FISH _ ITRIP I INTRM1 0.501 FISH (TRIP IINTRM1 0.251 FISH FISH I INTRMI 4.001 FISH (TRIP I INTRM1 0.25 FISH (PULD INTRM1 1.00 ~ FISH PULD INTRMI 3.751 FISH (TRIP INNTRMI 2.251 FISH (TRIP IINTRM1 Page 6 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations the mill control that we had been over top of fish, and the grapple had definite indications that we had been over the fish and had "spun" the grapple wickers to "DULL". The grapple was also spread open 1/2". The carbide on the guide indicated we were just to the top of the stabilizer, and had a full bite. Pictures were taken and sent to town. Clean rig floor area, lay do tools. Discuss options with town. Decision to run 8 1/8" Overshot with 6 1/4" Grapple, without 6 3/4" drill collars. Strap & make up fishing BHA #2. 8 1/8" Overshot assembly with 6 114" Grapple and Mill Control Packoff with carbide on the guide. This will swallow 1.84', length = 3.60'. Continue make up 6 1/4" Pump out sub 2.02'), 6 1/4" Lubricated Bumper Sub (9.0'), 6 1/4" Oil jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Top fish @ 5584' Trip in hole with BHA #2, from 223' - 5320' (5097). -Stop at the Shoe (3693') and obtain parameters. Up Wt - 84K, SO WT = 40K Pumps at 50 SPM - 300 PSI. Continue TIH to 5320' with no issues, and take weight @ 4950'. Screw into TD and wash & rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 130K, SO WT = 50K. Continue TIH from 5320' made up to TD and wash 8~ rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 125K, SO WT = 52K. Tag hard @ 5475' while washing through open hole with overshot. 30 RPM's. Stop rotating, and straight slackoff to engage fish. Pull up to 200K first pull and fire jars. (75K over) Straight pull to 250K, and fish pulling free with 60-120K drag. We engaged fish 113' higher than expected. Pumps @ 530 GPM's - 1400 PSI. Observe no pressure increase when engage fish. Pump out of hole from 5475', observing overpull of 60-100K. 530 Gpm's - 1400 PSI. Continue POOH pumps off checking well for swabbing, hole taking fluid. Continue pull on elevators to tight spot @ 5140', observe weight falling off to drag at 145K UP WT. Staright pull @ 200K, Slack off to break over free, and pull up to 145K, observed weight fall off, with Upweight now of 125K. Continue POOH to surface. Breakout & lay down Overshot assembly. NO FISH. Inspect 8 1/8" overshot. Observed wickers on 61/4" grapple still sharp, slivers of Monel steel in wickers, and good indications inside Top Sub showed overshot bottomed out over fish. Guide looked good but had minimal "flare" on the cut Irp. Discuss options with town. Clean floor area, Make up Fishing BHA #3, Strap & make up 8 1/8" Overshot assembly with 6 1/8" Grapple and Mill Control Packoff with carbide on the guide. This will swallow 1.84'. length = 3.60'.. Continue make up 6 1/4" Pump out sub (2.02'), 6 1/4" Lubricated Bumper Sub 9.0'), 6 1/4" Oil jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Suspected Top fish @ 5140' TIH to 3638', Break circulation. Up WT = 103K, SO WT = 50K. Pumps @ 530 GPM's - 1425 PSI. RIH to tag fish @ 5140' DPM, and push fish to 5563', then observed 200 PSI increase in pressure. Pull up to 250K 147K over), to observe drag @ 60-100K. Pump out of hole with fish on from 5563' - 4292' (1271') observing drag Printed: 10/21/2005 2:52:30 PM • • ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/22/2005 09:45 - 12:00 12:00 - 12:45 12:45 -15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 18:30 18:30 - 21:00 21:00 - 21:15 Page 7 of 29 Operations Summary Report 1 J-168 1 J-168 ROT -DRILLING Start: 8/13/2005 n1334@ppco.com Rig Release: Doyon 141 Rig Number: Hours Code I 2.25 FISH 0.75 FISH 2.75 FISH 1.50 FISH 0.50 DRILL 1.00 RIGMt 2.50 DRILL Spud Date: 8/13/2005 End: Group: Sub Phase Description of Operations Code TRIP ~ INTRMI up to 100K. Pumps @ 80 SPM - 700 PSI TRIP INTRM1 Continue Pump out of hole with fish on from 4292' - 3550' (742') TRIP INTRMI PULD INTRM1 PULD INTRMI RSRV INTRM1 PULD INTRM1 0.251 DRILL (PULD (INTRMI 21:15 - 21:45 0.50 DRILL PULD INTRM1 21:45 - 00:00 2.25 DRILL TRIP INTRM1 18/23/2005 ~ 00:00 - 02:30 02:30 - 10:30 2.501 DRILL (REAM IINTRM1 8.001 DRILL I DRLG I INTRM1 110:00 - 12:00 10.001 DRILLON REAM INTRM1 12:00 - 12:30 0.50 DRILL REAM INTRM1 12:30 - 15:15 2.75 DRILL TRIP INTRM1 15:15 - 16:30 I 1.25 I DRILL ~ PULD ~ INTRMI observing drag up to 100K, with drag falling off. Pumps @ 340 GPM - 600 PSI Monitor well -static. Pump Dry job, POOH on elevators to surface Breakout & lay down 8 1/8" Overshot assembly, releasing from fish. Lay down fish. Fish = 57.90'. Layed down Crossover top (1.68'), 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR /RES /PWD (20.93'), 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar { 9.20'), 7600 Series Geo-Pilot (20.15'), and 9 7/8" Security bit (1.60'). Fishing neck looking up = 1.68' x 6 1/8" Clean floor area, pull tools to rig floor. Insert Vortex jets in bit and orient them to point more ahead of the bit. Service Top Drive and Drawworks. Make up BHA #7. MU 9 7/8" Security FMFX653 Bit w/ TFA of .969 Sq in. (1.40'), Jet Nozzles = 3 x 14's, and 3 x 15's. Continue with 9 7/8" 7600 Geo-Pilot (23.22'), 6 3/4" Non-Mag Pony Collar (9.20'), 6.760" Smart Stabilizer { 2.18'), 6 3/4" MWD - GR /RES /PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4" MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). Plug in, Up Load MWD assembly. RIH from 68' - 540'. (472'), making up remaing BHA. 3 -Non Mag Flex collars (91.56'), 4 - jnts 5" HWDP (123.24'), 6 1/4" drilling jars with 98.43 HRS (30.38'), and 4 -jnts 5" HWDP (122.76'). Pick up 9 7/8" Ghost reamer( 5.08') on #6 stand of 5"HWDP. Total BHA length = 446.12' Break in Geo-Pilot and pulse test MWD tools. Good test. Pumps @ 500 GPM"S - 875 PSI. Trip in hole from 540' - 3704' (3164'), picking up 9 7/8" Ghost Reamer i (6.34'} on stand # 19 of 5" DP. UP WT = 115K, SO WT = 50K. Wash & Ream Open Hole from 3704' - 5642' (1938') @ 350 GPM's - 650 -800 PSI. 80 RPM's Torque = 8-10K. Directionally Drill 9 7/8" Intermediate hole from 5642' - 6205' (563'). TVD = 3056' Observe trouble controlling Geo-Pilot assembly, and could not maintain required direction. Pumps @ 450 - 530 GPM's - 1350 - 2150 PSI, UP WT = 163K, SO WT = 55K, ROT WT = 82K. WOB = 15-34K. 60-90 RPM's, TQ = 11-17K. Jars = 117.61 HRS Mud wt = 9.1 PPG. ECD = 9.82 PPG. Directional Drillers discuss with Co. Rep,and town. BROOH from 6205' - 5834' (371'). Pumps @ 650 GPM's - 2500 PSI. TQ = 10 -12K. Continue BROOH from 5834' - 5554' (371'). Pumps @ 650 GPM's - 2500 PSI. TQ = 10 -12K. POOH on elevators From 5554' - 4900' (654'). Pump dry job, Continue POOH to MWD. Plug in and download MWD. Breakout & lay down BHA #7. Layed down Non-Mag float sub (1.96'), 6 3/4" MWD TM HOC (9.96'), 6 3/4" MWD HCIM (6.97'), 6.70" Smart Stabilizer (2.17'), 6 3/4" MWD GR /RES/ PWD (21.02), 6.760" Smart Stabilizer (2.18'), 6 3/4" Non Mag GP Flex Pony (9.20'), 7600 GEO-Pilot (23.22), and the 9 718" Security FMFX653 bit (1.40'). Observed 9 7/8" bit had 15 cutters, worn or Ptintetl: 10/21/2005 2:52:30 PM L` Phase ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Start: 8/13/2005 Contractor Name: n1334@ppco.com Rig Release: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Code 8/23/2005 15:15 - 16:30 1.25 DRILL PULD 16:30 - 19:00 2.50 DRILL PULD 19:00 - 23:00 23:00 - 00:00 4.00 DRILL PULD 1.001 DRILL I DRLG 18/24/2005 100:00 - 12:00 12.00 ~ DRILL ~ DRLG 12:00 - 23:15 I 11.25 I DRILL I DRLG 23:15 - 00:00 0.75 DRILL CIRC 8!25/2005 00:00 - 04:30 4.50 DRILL TRIP 04:30 - 05:30 1.00 DRILL TRIP 05:30 - 06:00 I 0.501 DRILL CIRC 06:00 - 06:30 I 0.501 DRILL (TRIP 06:30 - 09:00 2.50 DRILL TRIP 09:00 - 10:15 1.25 DRILL PULD 10:15 - 10:45 0.50 DRILL PULD 10:45 - 12:00 1.25 DRILL PULD Page 8 of 29 Spud Date: 8/13/2005 End: Group: Description of Operations INTRM1 broken. INTRM1 Make up BHA #8, Bit #4. Make up 9 7/8" Hughes MXC1 bit with jets of 3 x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 3/4" Welded Blade Stabilizer (5.62'), 6 3/4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'). Up load MWD. INTRM1 TIH from 116' - 6205' (6089'). Make up remaining BHA, 3 -NON MAG Flex Collars (91.66'), 4 -JNTS 5" HWDP (123.24'), 6 1/4" Drilling Jars ( 30.38') with 98.43 HRS, 4 -JNTS 5" HWDP (122.76'). Perform shallow pulse test on MWD Assembly -good test @ 550', 525 GPM's - 1050 PSI. Continue TIH, install 9 7/8" Ghost reamer on stand # 6 5.08'), and9 7/8" Ghost Reamer on stand #19 (6.34'). Continue-TIH, observe no issues through Shoe @ 3693', continue to bottom @ 6205', Wash down last stand. INTRM1 Directional Drill 9 7/8" Hole from 6205' - 6253' (48') TVD = 3075'. Pumps @ 550 GPM's - 2050 PSI, WOB = 6-30K 60-80 RPM's. PU WT = 140K, SO WT = 59K, ROT WT = 87K. AST = .40 HRS. ECD = 9.86 PPG. INTRM1 Continue Directional Drill 9 7/8" Hole from 6253' - 7147' (894') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 25-33K, 60-80 RPM's. PU WT = 166K, SO WT = 58K, ROT WT = 85K. Torque on btm = 11 K, off bottom = 12K, ART =5.98 HRS, AST = 2.24 HRS. ADT = 8.4 HRS. ECD = 10.23 PPG.MAx GAS = 321 units. Jar Hrs = 127.45. SPR's #1 pump = 30 SPM - 370 PSI, 40 SPM - 450 PSI, Pump #2 - 30 SPM -370 PSI, 40 SPM - 450 PSI. Total BIT HRS = 8.8 Mud WT = 9.1 PPG INTRMI Continue Directional Drill 9 7/8" Hole from 7147' - 8229' (3073.80') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 10-30K, 80 RPM's. PU WT = 130K, SO WT = 65K, ROT WT = 88K. Torque on btm = 11 K, off bottom = 12K, ART =4.63 HRS, AST = 1.90 HRS. ADT = 6.53 HRS. ECD = 10.46 PPG.MAX GAS = 527 units. Jar Hrs = 133.20. Total Bit Hrs = 15.55 MUD WT = 9.1 PPG, Pump HI-VISC weighted sweep on last connection. INTRM1 Continue Circulate sweep out of hole @ 650 GPM's - 2950 PSI. INTRM1 Obtain last surveys at TD, as per DD. Monitor well -Static. BROOH from 8229' - 4627' (3602'). Pumps @ 650 GPM's, - 3000 PSI. UP WT = 135K, SO WT = 65K, ROT WT = 87K with 8K torque. Observed increase in cuttings across shakers 30-40%. We backreamed to get lower Ghost Reamer into shoe area, and saw hole cleaned up. INTRM1 POOH on elevators from 4627' - 3692' (935'). Observed clean hole conditions. UP WT = 110K, SO WT = 55K. Hole taking proper fill. INTRM1 Pump Hi-Visc weighted sweep 9.1 PPG, @ 650 GPM's-1700 PSI., while reciprocating drill string @ 50 RPM's. Observe 10 % increase in cuttings and hole cleaned up. INTRM1 Monitor well -static. Pump dry job, POOH from 3692' - 3130' (562') to stand back remaing 4" DP. INTRM1 POOH, lay down 84 Joints of 5" drill pipe. INTRM1 Breakout & lay down 8 joints 5" HWDP, and drilling jars, (276.38'). Lay down 3 Non-Mag flex drill collars (91.66'), Flush mud motor with water. INTRMI Plug in ,download MWD assembly. INTRM1 Continue breakout & lay down 9 7/8" Hughes MXC1 bit with jets of 3 Printed: 10!21/2005 2:52:30 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 18/25/2005 ~ 10:45 - 12:00 ~ 1.25 ~ DRILL ~ PULD ~ INTRM1 12:00 - 12:30 0.50 DRILL PULD INTRM1 12:30 - 13:00 0.50 CASE OTHR INTRMI 13:00 - 14:30 1.50 CASE RURD INTRM1 14:30 - 18:30 4.00 CASE RUNC INTRM1 18:30 -18:45 0.25 CASE CIRC INTRM1 18:45 - 20:15 1.50 CASE RUNC INTRM1 20:15 - 20:45 0.50 CASE CIRC INTRMI 20:45 - 00:00 3.25 CASE RUNC INTRM1 8/26/2005 00:00 - 03:00 3.00 CASE RUNC INTRM1 03:00 -04:45 1.75ICASE (CIRC INTRM1 04:45 - 05:15 I 0.501 CEMEN~ff PULD I INTRMI 05:15 - 07:30 2.251 CEMENl(CIRC INTRM1 07:30 - 08:30 I 1.001 CEMENlf PUMP I INTRM1 08:30 - 09:30 I 1.001 CEMENliPUMP I INTRM1 Page 9 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 3/4" Welded Blade Stabilizer (5.62'), 6 3/4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'). Inspect & grade bit to I / I / WT/A/E/I/NO/TD Clean floor area, and lay down all 5" handling tools. Rig up. BOLDS and pull wear ring. Rig up to run 7 5/8" 29.7# casing. Hold PJSM. Discuss "running detail as planned" and safety issues. Make up Float shoe joint, # 2 jint and Float collar joint- all baker locked, and check floats. Continue RIH with 7 5/8" casing installing tandem rise centralizers 10' from each end of joints #1-#9, then install 1 tantalizer on center of joints #10 -#80, and 1 each 10' from end on joints #81-#82. All centralizers are over "Stop Collars". RIH to 2100'. AVG make-up torque = 8500 FT/LBS Circulate bottoms up through Franks fill up tool @ 215 GPM's - 250 PSI. Continue RIH with 7 5/8" casing from 2100' - 3700' (1600'). Circulate bottoms up through Franks fill up tool @ 215 GPM's - 300 PSI. Continue RIH with 7 5/8" casing from 3700' - 6116', (2416'). Avg Make up Torque = 8500 FT/LBS. Continue RIH with 7 5/8" casing from 6116' - 8224, (2108'). AVG Make up torque = 8500 FT/LBS. We ran 7 5/8" Weatherford Model 303 Sure Seal Float Shoe (1.50'), 2 jts 7 5/8" BTC-M casing (85.25), 7 5/8" Weatherford Model 402 Sure Seal Float Collar (1.31'), 22 jts of 7 5/8" BTC-M casing (936.18'), 7 5/8" Casing Pup Jt (20.21'), 8 jts 7 5/8" Casing (339.79'), 7 5/8" Casing Pup Jt (21.46'), 158 Jts 7 5/8" BTC-M casing (6768.45'), and Jt # 191 to set in slips and cut off. RKB = 26.31'. The window Jts were spaced to allow tops of collars at 7136.45, and 6774.78. We ran a total of 82 Tandem Rise centralizers & stop rings. 2 per joint - 10' from each end on jts #1 -#9, 1 perjoint on center of each joint #10 -#80, and 2 per joint on each end of jnts # 81 - #82. Centralizer spacing from 4761' - 8224'. Circulate bottoms up through Franks Tool staging up to 5 BPM - 450 PSI, while reciprocating string. UP WT = 185K, SO WT = 68K. Mud wt = 9.2+ PPG, PV= 12, YP = 20. Breakout & lay down Franks Fill up tool. Make up crossover and Cement Head. Continue Circulate & condition while reciprocating string, and RU Dowell Cement crew. Condition mud to pre cement properties of 9.0 PPG, PV = 11, and YP of 11. Held PJSM with entire crew and truck drivers. Discuss Cement Job, Fluid transfers, and safety. Circulating @ 6 BPM - 500 PSI UP WT = 205K, SO WT = 68K. Turn over to Dowell. Pump 5 BBLS of 8.36 PPG water @ 5.1 BBUMIN, Pressure test lines to 3500 PSI. Good Test. Pump 40 BBLS of 8.35 PPG CVH100 @ 5 BBUMIN, 40 BBIs of 10.2 PPG MudPush @ 5 BBLS/MIN, Drop Bottom Plug, Pump 193 BBLS of 12.5 PPG Tail Slurry @ 6 BBLS/MIN, Drop Top Plug, and flush lines. While reciprocating string, Displace well with 9.0 PPG MOBM @ 7.5 Printed: 10212005 2:52:30 PM • • ConocoPhillips Alaska Page 10 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours .Code Code Phase 8/26/2005 108:30 - 09:30 I 1.00 CEMENl ~PUMP INTRMI 09:30 - 11:15 I 1.751 CEMEN1iRURD I INTRM1 11:15 - 12:00 0.75 CASE OTHR INTRMI 12:00 - 14:00 2.00 CASE OTHR INTRM1 14:00 - 14:30 0.50 CASE OTHR INTRM1 14:30 - 14:45 0.25 CASE NUND INTRMI 14:45 - 15:00 0.25 CASE OTHR INTRM1 15:00 - 16:00 1.00 CASE OTHR INTRMI 16:00 - 17:45 1.75 CMPLTN OTHR INTRM1 17:45 - 19:00 I 1.251 WELCTU BOPE I INTRM1 19:00 - 00:00 18/27/2005 100:00 - 03:00 03:00 - 06:30 06:30 - 10:45 5.00 ~ DRILL PULD ~ PROD 3.001 DRILL I PULD I INTRMI 3.501 DRILL PULD ~ INTRM1 4.251 DRILL (TRIP INTRMI 10:45 - 12:00 1.25 DRILL TRIP INTRMI 12:00 - 12:15 0.25 DRILL TRIP INTRM1 12:15 - 13:15 1.00 RIGMNT RSRV INTRM1 13:15 - 13:30 0.25 DRILL TRIP INTRM1 13:30 - 17:45 4.25 DRILL DEOT INTRMI Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations BBLS/MIN to 3500 stks. Parked casing at 307 BBL into displacement. LAst UP WT = 215K, SO WT = 40K. We then slow pumps to 3.5 BBLS/MIN @ 360 BBLS into displacement, to bump plug at calculated 3725 STKS (375.10 BBLS). Recorded Cement in place at 09:25 HRS. Circulating pressure before bump 600 PSI. Pressure to 1100 PSI, hold for 5 minutes. Open valves and check floats - OK. Float shoe @ 8224' MD 3472' TVD Rig down cement head and lines. Nipple down 8~ lift BOP stack for setting slips. Set 7 5/8" csg slips with 100K block wt, 65K set on slips. Rig up & make cold cut using WACHS casing cutter and POOH LD cut piece of 7 5/8" casing (17.59'), Dress stump, and install pack-off. Remaing casing jt #191 in slips = 23.54') Rig up and lower packoff on to stump. Nipple up BOP stack 8~ choke line. Rig up and pressure test 7 5/8" packoff to 4200 PSI. Hold for 10 Minutes. Good test. Rig up and perform Casing annulus infectivity test w 9.1 PPG Mud. Pump down 7 5/8" x 10 3/4" annulus to flush with 175 BBLS of water @ 2 BPM - 900 PSI. Rig up and test BOP's, and flange breaks. Test to 250 PSI for Low test, and 3000 PSI, recoreded on chart. Bleed pressures. Rig down all test equipment. Rig up and make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 41 of 65 stands needed. NOTE: Little Red Services rigged up and pumped 90 BBLS freeze protect diesel down 7 5/8" x 10 3/4" casing @ 1.9 BBLS/MIN. Final shut in pressure = 600 PSI. Diesel to 2267' Continue make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 24 of 65 stands needed. Note: Blind Ram Function test. Held PJSM. Discuss BHA & Safety. Make up BHA #9. Make up 6 3/4" SDBS FSF 2641 PDC bit (1.20') w! 3 x 15 Jets for a TFA of .518 sq in. 6 3/4" 5200 Geo-Pilot (16.22), 4 3/4" Non-Mag Flex (battery) (11.55'), 4 3/4" DM Collar (8.03'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/DGR (24.39'), 4 3/4" PWD Collar (10.77'), 4 3/4" TM HOC (11.28'), 4.710" Non-Mag Float Sub w/ valve(2.35'), 4 3/4" '.Non-mag IBS Stabilizer (5.33'), 3 - 4.630" Non-Mag Flex Drill Collars 93.17'), 4,90" - 4" XT 39 x 3 1/2" IF Crossover sub (1.72'), 1 -Jt 4" HWDP (30.33'), 4 3/4" Drilling jars (28.90, 4 - JTs 4" HWDP. Total BHA = 369.68'. Pulse test MWD @ 250 GPM"S - 1050 PSI. Break in Geo-Pilot bearings. PU WT = 45K, SO WT = 42K, ROT WT = 42K, 70 RPM"S Trip in hole picking up 165 joints of 4" DP from pipe shed. Fill every 20 stands. Checked MWD @ 2892' and 5507' with 180 GPM's - 800 PSI. Cont trip in hole from 5507' - 7537' (2030'). Continue trip in hole from 7537' - 8114' (577'). Slip & Cut Drilling line. Service Top Drive, while CBU. Wash down from 8114' - 8136' (22'), to tag Float Collar @ 8136'. Rig up & perform 7 5/8" casing test to 3000 PSI. Record on chart. Pressure bled off 150 PSI in 30 Minutes. Reposition drill string and repeat test. Pressure bled 150 psi in 30 Minutes. Change out "easy turn" valve & perform Re-test. Pressure bled 150 PSi in 30 Minutes. Rig Printed: 10/21!2005 2:52:30 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Start: 8/13/2005 Contractor Name: n1334@ppco.com Rig Release: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase ____ - - 8/27/2005 ~ 13:30 -17:45 ~ 4.25 ~ DRILL ~ DEQT ~ INTRM1 17:45 - 20:45 20:45 - 22:00 22:00 - 22:45 3.00 DRILL DRLG INTRMI 1.25 FRMTST CIRC INTRM1 0.751 FRMTST OTHR I INTRMI 22:45 - 00:00 , 1.251 DRILL I DRLG I PROD 18/28/2005 00:00 - 12:00 I 12.00 DRILL DRLG PROD 12:00 - 00:00 I 12.001 DRILL I DRLG I PROD 18/29/2005 100:00 - 12:00 I 12.00 I DRILL I DRLG I PROD 12:00 - 16:45 I 4.751 DRILL DRLG PROD 16:45 - 17:30 I 0.751 DRILL CIRC PROD Page 1 1 of 29 Spud. Date: 8/13/2005 End: Group: Description of Operations down test equipment. Circulate 15 minutes. Rig up test equipment. Perform Re-test to 3000 PSI.2850 psi after 30 min Test -Recorded on chart. Drill Float equipment. FC @ 8136', and Flaot shoe at 8224'. Drill 20' of new hole to 8249'. Pull up into shoe track, and circulate & condition mud @ 250 GPM's - 1950 PSI for LOT. Mud wt = 9.0 PPG, Visc = 75, YP = 14 Gels @ 18/28, in & out of hole. Rig up and fill all lines with mud. Pump at 7 strokes /minute to 66 stks. 5 1/2" Liners in pumps. Pump output = .085. Calculated Leak off @ 986 PSI for a calculated EMW = 14.46 PPG. Rig down all test equipment & lines. Recorded on chart. Directional Drill 6 3/4" hole from 8249' - 8308' (59'). TVD =3472". ADT _ .60 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 100 Rpm's. WOB = 6-10K. Pumps at 250 GPM's - 2000 PSI. Clean hole ECD = 10,37 PPG. Slow pump rates @ #1 pump 20 SPM - 380 PSI. 30 SPM - 680 PSI. #2 Pump , 20 SPM - 330 PSI, 30 SPM - 520 PSI. Directional Drill 6 3/4" hole from 8308 - 9408' (1100'). TVD = 3503". ADT = 7.67 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2600 PSI. ECD = 10.75 PPG. Max Gas = 90 Units. MOBM @ 9.0 PPG Vis = 75, YP = 19, Gels = 18/32, Total BIT HRS = 8.27 Continue Directional Drill 6 3/4" hole from 9408' - 10602' (1194'). TVD = 3583". ADT = 7.46 HRS. PU WT = 136K, SO WT = 54K, ROT WT = 86K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2825 PSI. ECD = 11.50 PPG. Max Gas = 189 Units.Jar = 15.73 HRS, Total Bit HRS = 15.73, MOBM @ 9.0 PPG Vis = 86, YP = 21, Gels = 19/31 **'"`Note: We drilled +/- 230 feet of shale out of shoe, then 150' of sand, and back into shale for +/- 200 ft. Geologist stopped and re-evaluated 3 times, discussing plan with town. Decision to keep drilling as per Geo. Also observed ABI tool readings 2.88 degrees avg, OFF from MWD surveys. DD's compensated for this. SPR's= Pump#1 - 20 SPM - 720 PSI, 30 SPM = 860 PSI. Pump #2 - 20 SPM = 530 PSI, 30 SPM = 700 PSI. Continue Directional Drill 6 3/4" hole from 10602' - 11705' (1103'). TVD = 3561 ". ADT = 7.15 HRS. PU WT = 150K, SO WT = 50K, ROT WT = 82K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 291 GPM's - 3050 PSI. ECD = 11.70 PPG. Max Gas = 264 Units.Jars = 22.88 HRS, Total Bit HRS = 22.88, MOBM @ 9.0 PPG Vis = 84, YP = 21, Gels = 25/33 104 BBLS fluid toss Pumping Hi-Visc weighted sweeps to clean hole & control ECD MAx ECD = 12.3 PPG. Continue Directional Drill 6 3/4" hole from 11705 - 12150'. (1075'). TVD = 3580' ADT = 3.63 HRS. PU WT = 158K, SO WT = 55K, ROT WT = 90K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 295 GPM's - 3400 PSI. ECD = 12.3 PPG. Max Gas = 264 Units, MOBM @ 9.0 PPG Con't to Pump Hi-Visc weighted sweep @ 295 GPM's - 3400 PSI to clean hole and control ECD's. Observed 250% increase in cuttings on shakers and hole parameters cleaned up. ECD @ 11.56 PPG Pflntetl: 10721/ZUUb Z:DZ:3U rm • • ConocoPhillips Alaska Operations Summary Report Lega! Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Start: 8/13/2005 Contractor Name: n1334@ppco.com Rig Release: Rig Name: Doyon 141 Rig Number: Date 'From - To Hours Code Sub „ Phase ~,~cae 18/29/2005 117:30 - 23:15 I 5.751 DRILL ~ DRLG ~ PROD 23:15 - 00:00 0.75 ~ DRILL CIRC ~ PROD 4.25 DRILL DRLG PROD 18/31 /2005 04:15 - 05:45 1.501 DRILL CIRC PROD 06:00 - 13:45 f 07.75 DRILL I REAM I PROD 13:45 - 15:30 I 1.751 DRILL I CIRC I PROD 18:30 - 19:45 1.251 DRILL IC RC PROD 19:45 - 21:30 1.75 DRILL CIRC PROD 21:30 - 21:45 0.25 DRILL OBSV PROD 21:45 - 00:00 2.25 DRILL TRIP PROD 00:00 - 04:00 4.00 DRILL TRIP PROD 04:00 - 06:30 I 2.501 DRILL I PULD I PROD 06:30 - 07:00 0.50 CASE RURD CMPLTN 07:00 - 07:15 0.25 CASE SFTY CMPLTN 07:15 - 12:30 5.25 CASE PULR CMPLTN 12:30 - 13:00 I 0.501 CASE I PULR I CMPLTN Page 12 of 29 Spud Date: 8/13/2005 End: Group: Description of Operations Continue Directional Drill 6 3/4" hole from 12150' - 12602' (452'). TVD = 3605' ADT = 4.14 HRS. PU WT = 173K, SO WT = 62K, ROT WT = 103K. Torque on bottom = 9K, off bottom = 10K. 120 Rpm's. WOB = 4-SK. Pumps at 295 GPM's - 3650 PSI. ECD = 11.74 PPG. Max Gas = 212 Units. Jars = 30.64 HRS, Total Bit HRS = 30.64, MOBM @ 9.0 PPG Vis = 78, YP = 21, Gels = 25/33 Pumping Hi-Visc weighted sweeps to clean hole & control ECD MAX ECD = 12.3 PPG. Slow pump Rates @ 12240'. TVD = 3585'. #1 = 20 SPM - 680 PSI, 30 SPM - 880 PSI. #2 = 20 SPM - 610 PSI, 30 SPM - 800 PSI. Con't to Pump Hi- Visc weighted sweep @ 295 GPM's - 3600 PSI to clean hole and control ECD's. Observed 300% increase in cuttings at shakers, and hole parameters cleaned up. ECD @ 11.74 PPG Drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 12,602' to 12,995' MD/ 3,654' TVD (393') (T.D:) ADT 2:89 hrs, 4=8K wob, 120 rpm's, 83 spm, 295 gpm at 3,800 psi, off btm torque t OK ft-Ibs, on btm 9K tt-Ibs, rot wt 105K, up wt 195K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 90 units, max gas 195 units Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ hole at 295 gpm, 3,800 psi and 120 rpm's with 10K ft-Ibs torque, ECD 11.8 ppg after circ out sweep Monitored well-static, took SPR's Backreamed out of hole from 12,995' to 8,214' with no problems (csg shoe @ 8,224'), BROOH at 120 rpm's, 9-10K ft-Ibs torque, 295 gpm, initial circ press 3,700 psi, final circ press 2,700 psi Pumped 35 bbl weighted hi vis sweep at csg shoe and circ hole clean, had 50% increase in cuttings back from sweep, circ a total of 3X btms up and was clean at shakers, circ at 295 gpm at 2,600 psi, monitored well-static RIH from 8,214' to btm at 12,995' with no problems Pumped 35 bbl weighted hi vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ hole at 295 gpm, 4,000 psi and 120 rpm's Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, rotated DP at 120 rpm's and circ at 295 gpm at 4,000 psi Monitored well-static, dropped 1 3/4" rabbit on a wire POOH on elevators with BHA #9 from 12,995' to 10,341' Cont POOH with BHA #9 from 10,431' to BHA at 370', monitored well at shoe, well-static Stood back HWDP and jars, downloaded MWD and LD same with Geo-pilot, cleared rig floor, talc fill on trip out of hole 91 bbls, actual fill 98 bbls RU Doyon's 4 1/2" liner running equipment Held PJSM on running of liner PU and ran 4 1/2" liner per well program to 5,673', ran 4 1/2" ROT silver bullet guide shoe with no float, 184 jts, (5,673') of 4 1/2" 12.6#, L-80, BTCM liner, placed blank liners across shale sections per geology, ran 90 jts (2,782') of blank liner and 94 jts (2,889') of slotted liner, ran 152- 4 1/2" x 6 1/4" spiralglide centralizers 1/jtjt #1 to Jt #165, ran 13 constrictor packers placed on blank liner to isolate shale sections per geology, did not run any centralizers on jts with constrictor packers. MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,741', st wt up 75K, do wt 55K (blk wt 35K) Printetl: 10/21/2005 2:52:30 PM • .7 ConocoPhillips Alaska Page 13 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/31/2005 13:00 - 14:15 1.25 CASE RUNL CMPLTN 14:15 - 14:30 0.25 CASE CIRC CMPLTN 14:30 -17:30 3.00 CASE RUNL CMPLTN 17:30 - 18:30 I 1.001 CASE I OTHR I CMPLTN 18:30 - 18:45 0.25 CASE DEOT CMPLTN 18:45 - 19:00 0.25 CASE OTHR CMPLTN 19:00 - 20:15 1.25 DRILL TRIP CMPLTN 20:15 - 21:15 1.00 RIGMNT RSRV CMPLTN 21:15 - 23:15 2.00 DRILL TRIP CMPLTN 23:15 - 00:00 0.75 DRILL PULD CMPLTN 19/1/2005 00:00 - 00:30 0.50 DRILL ~ PULD CMPLTN 00:30 - 01:00 0.50 WELCT OTHR CMPLTN 01:00 - 05:00 4.00 WELCT BOPE CMPLTN 05:00 - 05:30 0.50 WELCT OTHR CMPLTN 05:30 - 05:45 0.25 WINDO FTY CMPLTN 05:45 - 09:00 3.25 WINDO ULD PROD2 09:00 - 13:45 4.75 WINDO RIP PROD2 13:45 - 14:30 0.75 WINDO THR PROD2 14:30 - 15:15 I 0.751 WINDOWTRIP I PROD2 15:15 - 16:00 I 0.75 WINDOV'VSETW PROD2 16:00 - 17:00 I 1.001 WINDOWCIRC I PROD2 17:00 - 00:00 7.00 WINDOV'VSTWP PROD2 9/2/2005 100:00 - 01:00 1.001 WINDOV~/CIRC PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations RIH with liner on 4" XT-39 DP from 5,741' to 8,160' (7 5/8" Csg shoe @ 8,224') Circ a DP cap at csg shoe, pumped 40 bbls of 9.0 ppg SFMOBM at 180 gpm at 350 psi, st wt up 98K, do wt 55K Cont to run 4 1/2" liner in open hole, RIH from 8,160' and tagged btm at 12,995' with no problems, PU to 12,975', st wt up 160K, do wt 60K, Note: RIH with 65 stds of 4" DP with Lo-Tads, 13 stds of Hybrid push pipe and 1 std of slick DP to set 4 1/2" liner Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 300 psi, with ball on seat pressured up to 1,600 psi to set Flexlock hanger, slacked off 25K, cont to set packer, pressured up to 4,000 psi and set ZXP packer, no problems setting hanger/packer, set "A2" sand liner with TOL @ 7,246' MD/ 3,311' TVD and shoe at 12,975' MD 3,653' TVD, st wt up after setting liner 125K, lost 35K st wt RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck ok Monitored well-static POOH from 7,246' to 4,800' Slipped and cut 78' of drlg line Cont to POOH with liner running tool from 4,800' to 40' Made service breaks and LD Baker Liner running tool, calc fill on trip out of hole 51 bbls, actual 54 bbls Fin LD Baker liner running tool and cleared rig floor Pulled wear bushing RU 8~ Tested BOP's, tested annular, rams, valves and manifold to 250 psi low and 3,000 psi high, no problems, NOTE: Chuck Scheve with AOGCC waived witnessing of test Pulled test plug and installed wear bushing Held PJSM on PU & MU of whipstock milting assembly MU Baker 7 5/8" whipstock assembly BHA #10 and RIH to 389', MU milling assembly and LD same, PU seal assembly, locator sub, flex pup jt, 2-jts 3 1/2" DP and unloader sub for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 2-bumper subs and 2 stds 4" Hybrid push pipe to 389' RIH with whipstock assembly from 389' to 6,405' Made MADD pass from 6,405' to 6,483' (6,230' to 6,310' sensor depth) and correlated MWD to K-13 sand RIH with whipstock assembly from 6,483' to 7,200', st wt up 130K, do wt 82K Oriented whipstock to 6 deg left of high side, RIH, tagged TOL at 7,246', set whipstock and sheared off from same, set top of whipstock at 7,145' Displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM, circ at 250 gpm at 2,000 psi Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,145', btm of window at 7,157', drilled 6 3/4".hole to 7,187' MD/ 3,300' TVD (42'), 2-8K wob, 78-95 rpm's, 275 gpm, 2,500 psi, rot wt 92K, up wt 130K, do wt 82K, 5-8K ft-Ibs torque, pumped 2-15 bbl weighted hi vis sweeps while milling window with no increase in cuttings back. Pumped 35 bbl weighted hi vis sweep and circhole clean after milling window, worked mills thru window while circ hole clean, circ at 266 gpm at 2,200 psi, rot wt 95K, up wt 125K, do wt 83K, no increase in cuttings Printed: 1 WLt/lUUb t.bY:JU PM • ConocoPhillips Alaska Page 14 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours .Code Code Phase 9/2/2005 00:00 - 01:00 1.00 WINDO IRC PROD2 01:00 - 01:15 0.25 WINDO THR PROD2 01:15 - 04:00 2.75 WINDO RIP PROD2 04:00 - 05:30 I 1.50 I WINDOVIIPULD I PROD2 05:30 - 07:00 I 1.501 WINDOVVOTHR I PROD2 07:00 - 08:30 1.50 RIGMNT RSRV PROD2 08:30 - 11:45 3.25 DRILL PULD PROD2 15:00 -15:105 0.251 DRILL f REAM PROD2 15:15 - 00:00 I 8.751 DRILL I DRLG I PROD2 19/3/2005 100:00 - 12:00 12.00 I DRILL I DRLG (PROD2 12:00 - 00:00 I 12.00 DRILL DRLG ~ PROD2 19/4/2005 00:00 - 12:00 12.00 DRILL I DRLG PROD2 12:00 - 00:00 12.00 DRILL ~ DRLG PROD2 9/5/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations back from sweep Monitored well-static, took spr's and pumped dry job POOH with BHA #10 from 7,187', stood back hybrid push pipe POOH to MWD at 38' Downloaded MWD and LD same along with milling assembly, upper mill was in gauge Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing Changed out 4" XT-39 saver sub on top drive and serviced same MU 6 3/4" Geo-pilot BHA #11 and RIH to 370', MU new bit #6, Geo-pilot with MWD only, uploaded MWD and RIH with NMFDC's, HWDP and jars to 370' RIH with BHA #11 from 370' to 7,088' (TOW @ 7,145') Washed down from 7,088' thru top of window at 7,145' and conYto btm at 7,187', no problems going thru window, rot wt 79K, up wt 99K, do wt 65K Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,187' to 7,540' MD/ 3,317' TVD (353'), ADT 7.05 hrs, 5-14K wob, 120 rpm's, 83 spm, 295 gpm, 2,650 psi, off btm torque 7K ft-Ibs, on btm 6K ft-Ibs, rot wt 79K, up wt 122K, do wt 55K, 9.05 ppg MOBM, ave ECD 10.8 ppg, ave BGG 25 units, max gas 66 units, drilling thru numerous concretions ,Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,540' to 8,463' MD/ 3,338' TVD (923'), ADT 9.04 hrs, 5-8K wob, 120 rpm's, 84 spm, 298 gpm, 2,800 psi, off btm torque 8K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 125K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 25 units, max gas 83 units Drilled 6 3!4" hole in "B" sand lateral with Geo-pilot assembly from 8,463' to 9,081' MD/ 3,355' TVD (618'), ADT 10.08 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 2,900 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 78K, up wt 133K, do wt 53K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 40 units, max gas 105 units, cont to drill thru numerous concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,081' to 9,901' MD/ 3,383' TVD (820'), ADT 9.22 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,000 psi, off btm torque SK ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 135K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 30 units, max gas 403 units from apprx 9,470'. NOTE: Rig off highline at 02:00 hrs and back on highline at 10:00 hrs Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,901' to 10,895' MD/ 3,406' TVD (994'), ADT 8.99 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,150 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 77K, up wt 140K, do wt 53K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 166 units, pumped 30 bbl wt'd hi vis sweep at 10,532' with no increase in cuttings back from the sweep, cont to drill thru concretions, approx 15% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 10,895' to 11,531' MD/ 3,418' TVD (636'), ADT 9.62 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,125 psi, off btm torque 9K ft-ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 145K, do wt 48K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 204 units Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from Printed: 10!21/2005 2:52:30 PM • • ConocoPhillips Alaska Page 15 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/5/2005 ~ 12:00 - 00:00 ~ 12.00 DRILL ~ DRLG PROD2 19/6/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD2 12:00 - 12:15 0.251 DRILL OBSV I PROD2 12:15 - 20:45 8.501 DRILL REAM PROD2 20:45 - 22:15 I 1.50 I DRILL I CIRC I PROD2 22:15 - 23:15 I 1.001 RIGMNTI RSRV I PROD2 23:15 - 00:00 I 0.75 I DRILL I TRIP I PROD2 19/7/2005 100:00 - 04:30 I 4.501 DRILL I TRIP I PROD2 04:30 - 04:45 I 0.251 DRILL REAM PROD2 04:45 - 07:00 I 2.25 DRILL CIRC PROD2 07:00 - 09:00 2.001 DRILL ~ CIRC ~ PROD2 09:00 - 09:15 0.25 DRILL OBSV PROD2 09:15 - 13:45 4.50 DRILL TRIP PROD2 13:45 - 14:00 0.25 DRILL OBSV PROD2 14:00 - 16:00 2.00 DRILL TRIP PROD2 16:00 - 18:45 2.75 DRILL PULD PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 11,531' to 12,431' MD/ 3,456' TVD (900'), ADT 8.17 hrs, 4-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,450 psi, off btm torque 11 K ft-Ibs, on btm 9.5K ft-Ibs, rot wt 90K, up wt 163K, do wt 50K, 9.05 ppg MOBM, ave ECD 12.0 ppg, ave BGG 40 units, max gas 86 units, began using hybrid push pipe at 11,878', cont to drill thru concretions, approx 12% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 12,431' to 12,967' MD! 3,480' TVD (536'), (T.D.) ADT 8.2 hrs, 4-17K wob, 120 -130 rpm's, 79 spm, 281 gpm, 3,200 psi, off btm torque 11 K ft-Ibs, on btm 10K ft-Ibs, rot wt 95K, up wt 165K, do wt 50K, 9.0 ppg MOBM, ave ECD 11.75 ppg, ave BGG 30 units, max gas 75 units, TD well with hybrid push pipe, cunt to drill thru concretions, approx 11 % of "B" lateral was concretions (621'), pumped weight hi vis sweep on last std and had 20-30% increase in cuttings back from sweep, crossed fault at 12,050' and while drilling below 12,550' began to have slight mud losses slowed pump rate and losses decreased, Geo-pilot began having trouble holding tool face from 12,512' to TD, was able to TD well in the target ,Monitored well for 15 min, well breathed back 19 bbls of mud, initial rate 'Twas 5 bpm, final rate after 15 min .3 bpm Backreamed out of hole from 12,967 to 7,245', then pumped out of 'hole to 7,100' to above TOW at 7,145', no problems pulling thru 'window, BROOH at 120 rpm's and 225 gpm at 2,350 psi, no problems BROOH, monitored well every 1,000' and well was breathing Blighty up to 8,092' where well was static, talc fill 45.5 bbls actual fill 70 bbls Pumped 30 bbl weighted hi vis sweep and circ hole clean above TOW, circ at 265 gpm, 2,200 psi and 120 rpm's with 7K ft-Ibs torque, had no increase in cuttings back from sweep and circ an add. btms up after sweep was out of the hole and was clean at shakers, rot wt 79K, up wt 117K, do wt 64K Slip and cut 56' of drlg line and service top drive, monitored well while servicing rig and well was static RIH slow from 7,100' thru window at 7,145' with no problems and cont RIH to 7,440', lost 258 bbls of 9.0 ppg MOBM to hole last 24 hrs Cont RIH from 7,440' and set down at 12,602', washed down 1 std to 12,694' and cunt RIH to 12,879' with no problems Washed and reamed down from 12,879' to btm at 12,967' (88'), washed down at 62 spm, 220 gpm at 2,450 psi, 120 rpm' with 10K ft-Ibs torque Pumped 35 bbl weighted (1 Ib over) hi vis sweep and circ out of hole, had no increase in cuttings back from the sweep, circ an add. btms up and was clean at shakers, circ at 220 gpm at 2,500 psi, 120 rpm's with 10K ft-Ibs torque, rot wt 95K, up wt 170K, do wt 45K with pumps on, Held PJSM with rig crew and ASRC vac truck drivers on changing over to SFMOBM Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 220 gpm at 2,200 psi and 120 rpm's Monitored well-static, took SPR's POOH wet on elevators from 12,967' to 6,883', no problems pulling thru window at 7,145' Monitored well at 6,883' and well was static Cont POOH with BHA #11 from 6,883' to BHA at 369' POOH standing back HWDP, jars and NMFDC's, downloaded MWD and LD same along with Geo-pilot and bit, cleared rig floor, talc fill on rnnte°: iurnrzu~° za~:a~ rm • ConocoPhillips Alaska Page 16 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code; Phase __ 9/7/2005 16:00 -18:45 2.75 DRILL PULD PROD2 18:45 - 19:30 0.75 FISH PULD CMPLT2 19:30 - 22:30 3.00 FISH TRIP CMPLT2 22:30 - 00:00 1.501 FISH ~ FISH ~ CMPLT2 19/8/2005 00:00 - 00:45 0.75 (FISH ~ CIRC ~ CMPLT2 00:45 - 01:00 0.25 FISH OTHR CMPLT2 01:00 - 05:00 4.00 FISH TRIP CMPLT2 05:00 - 07:00 2.00 FISH PULD CMPLT2 07:00 - 07:45 0.75 CASE RURD CMPLT2 07:45 - 08:00 0.25 CASE SFTY CMPLT2 08:00 - 12:30 I 4.501 CASE I PULR I CMPLT2 12:30 - 13:15 0.75 CASE I PULR CMPLT2 13:15 - 17:45 ~ 4.501 CASE RUNL ~ CMPLT2 17:45 - 19:30 I 1.751 CASE OTHR CMPLT2 19:30 - 20:00 0.50 CASE OTHR CMPLT2 20:00 - 22:45 2.75 CASE RUNL CMPLT2 22:45 - 00:00 I 1.251 CASE OTHR ~ CMPLT2 9/9/2005 00:00 - 02:30 2.50 CASE RUNL CMPLT2 02:30 - 03:00 0.50 CASE OTHR CMPLT2 03:00 - 03:30 0.50 CASE RURD CMPLT2 03:30 - 11:30 8.00 CASE OTHR CMPLT2 11:30 - 12:30 I 1.001 CASE I RURD I CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations trip out of hole 87.75 bbls, actual 110.5 bbls MU whipstock retrieving BHA #12 and RIH to 60' RIH with BHA #12 from 60' to 7,100', st wt up 127K, do wt 71 K, RIH with BHA on 4 stds of hybrid push pipe, 65 stds of 4" DP with to-tads and 5 stds of hybrid push pipe Worked and rotated retrieving hook attempting to engage hook and after 16 attempts est. circ and washed around top of whipstock after 2nd attempt engaged whipstock slot at 7,144' and worked jars up to 200K, (73K over) then pulled up to 215K after jars went off and after 2nd hit on jars whipstock came free Circ btms up after pulling whipstock loose, circ at 242 gpm at 1,100 psi, st wt up 135K Monitored well-static, dropped 1 13/16" rabbit on a wire POOH with whipstock assembly from 7,145' to 60' LD whipstock retrieving BHA #12 then LD whipstock assembly with 2 jts of 3 1/2" DP and seal assembly, cleared rig floor, calc fill on trip out of '~ hole 39 bbls, actual 46 bbls RU Doyon's 4 1/2" liner running equipment Held PJSM with rig crew, tong operator and Baker Rep on liner running !detail and associated hazards PU &RIH with 4 1/2" liner per well plan to 5,768', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1 /2", ran 24 jts (738') of 4 1/2" 12.6#, L-80 slotted liner, 5 jts (155') of 4 1/2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 156 jts slotted (4,792') and 2 pups and 1 jt of 4 1/2" blank liner (50'), ran 1-4 1/2" x 6 1/4" x 8" straight blade aluminum centralizer perjt (184 total) total liner RIH 5,768'. MU Bakers 7 5/8" x 4 1/2" hook hanger assembly &RIH to 5,809', st wt up 78K, do wt 54K, RD liner running equip. RIH with 4 1/2" liner on 4" DP from 5,809', RIH thru window at 7,145' on 1st attempt, cont RIH and liner stopped at 11,044', st wt up 128K, do wt 35K (blk wt) Attempted to work liner thru hard spot at 11,044' with no success, POOH 5 stds with liner to 10,644' to PU add. wt pipe and Lo-tads PU add. Lo-tads to rig floor and strapped HWDP in pipe shed Cont RIH with 4 1/2" liner from 10,644' to 11,617', st wt up 165K, do wt 35-40K, PU a total of 8 stds of HWDP with 2 Lo-Tads per std while RIH to 11,617', having to work liner down, liner went thru spot at 11,044' ok then sat down solid at 11,170, worked thru and sat down again at 11,468' and worked thru after approx 15 min's, cont to work liner to 11,617', decision was made to POOH and inspect liner. POOH with 4 1/2" liner from 11,617' to 11,033', having to remove 1-Lo-tad per std of HWDP in order to set back NOTE: Rig off highline at 0800 hrs and back on highline at 18:15 hrs to install VSM's on J pad Conf POOH with 4 1/2" liner on 4" DP from 11,033' to 5,809' (hook hanger) LD excess Lo-tads from rig floor RU Doyon's 4 1/2" liner handling equip. and held PJSM on LD liner POOH LD Bakers 7 5/8" x 4 1/2" hook hanger and 186 jts of 4 1/2" liner, recovered 178 of 184 aliminum centralizers RIH, left in hole 3 full and 3 half pieces of centralizers (Total of 9 halfs), recovered both constrictor packers, they were in good condition and hadn't moved on the pipe RD Doyon's 4 1/2" liner handling equip. and cleared rig floor rnrnea: -i uicu~wo c[oco~ nvi ~ • ConocoPhillips Alaska Page 17 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date 'From - To Hours Code Code Phase __ 9/9/2005 ~ 12:30 - 14:15 ~ 1.75 ~ FISH ~ PULD ~ CMPLT2 14:15 - 16:45 2.50 FISH TRIP CMPLT2 16:45 - 17:15 0.50 FISH WASH CMPLT2 17:15 - 18:15 1.001 FISH ~ CIRC ~ CMPLT2 18:15 - 18:45 0.50 FISH CIRC CMPLT2 18:45 - 19:00. 0.25 FISH CIRC CMPLT2 19:00 - 21:15 2.25 FISH TRIP CMPLT2 21:15 - 22:30 1.25 FISH PULD CMPLT2 22:30 - 00:00 I 1.501 FISH I OTHR I CMPLT2 19/10/2005 00:00 - 00:30 0.50 CASE RURD CMPLT2 00:30 - 00:45 0.25 CASE SFTY CMPLT2 00:45 - 04:00 I 3.25 I CASE I PULR I CMPLT2 04:00 - 04:30 I 0.50 I CASE I PULR I CMPLT2 04:30 - 05:00 0.50 CASE RURD CMPLT2 05:00 - 09:45 4.75 CASE RUNL CMPLT2 09:45 - 11:30 I 1.75 I CASE I RUNL I CMPLT2 11:30 - 12:30 I 1.00 CASE ~ CIRC ~ CMPLT2 12:30 - 12:45 0.251 CASE RUNL ~ CMPLT2 12:45 - 13:30 0.75 CASE CIRC CMPLT2 13:30 - 13:45 0.25 CASE OTHR CMPLT2 13:45 - 16:00 2.25 CASE RUNL CMPLT2 16:00 - 16:30 0.50 CASE OTHR CMPLT2 16:30 - 17:30 1.00 RIGMNT RSRV CMPLT2 17:30 - 18:45 1.25 FISH PULD CMPLT2 Description of Operations MU Baker fishing BHA #13 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumper jars, 2-4 3/4" Dc's and 1 jt of HWDP RIH with BHA #13 from 137' and set down at btm of window at 7,157' Reamed thru tight spot at 7,157' to 7,159', 3-4K wob, 25 rpm's, 47 spm, 167 gpm at 600 psi, 4-5K torque, rot wt 75K, up wt 103K, do wt 63K Dropped 7/8" steel ball and cont to circ ball on seat while washing down from 7,159' and tagged top of A2 liner at 7,246', set 5K wt down on TOL with 25 rpm's and 4-7K torque and would not drill off, circ at 71 spm, 252 gpm at .1,600 psi Cont to circ hole working junk baskets, cycled pumps 8 times Pumped out of hole from 7,246' to 7,062' to work junk basket to above TOW at 7,145', circ at 252 gpm at 1,600 psi Monitored well-static, POOH with BHA #13 from 7,062' to BHA at 137' Stood back HDP and Dc's and LD BHA #13, recovered several large pieces of aluminum centralizers from rev junk basket, no recovery in boot baskets, junk weighted approx 8 Ibs or equivelant to 1 1/4 centralizer, cleared rig floor Pulled wear bushing and installed test plug, drained stack and ',functioned rams checking forjunk in stack and found none, pulled test 'plug and installed wear bushing RU Doyon's 4 1/2" liner running equipment '.Held PJSM with rig crew, tong operator and Baker rep on liner detail and potential hazards PU &RIH with 4 1/2" liner per well plan to 5,557', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1/2", ran 25 jts (769') of 4 1 /2" 12.6#, L-80 slotted liner, 4 jts (124') of 4 1 /2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 150 jts slotted (4,602') and 3 blank pups for spacing out, total liner RIH 5,557'. MU Baker 5 1/2" x 4 1/2" setting sleeve and RIH to 5,316', st wt up 74K, do wt 54K, rotated liner at 20 rpm's with 2K ft-Ibs torque RU Doyon's 4 1/2" liner running equipment and cleared rig floor RIH with 4 1/2" liner on 4" DP from 5,613' to 11,617', no problems RIH thru window, went thru on 1st attempt, cont RIH to 11,617', st wt up at TOW (7,136') 75K, do wt 54K, rotated liner at 20 rpm's with 3K ft-Ibs torque, Note: 11,617' was the deepest liner was ran on 1st trip. Cont RIH with liner from 11,617' to btm at 12,967', RIH with no problems or rotation, st wt up 165K, do 63K, NOTE: Held Pad Evacuation drill with rig and construction crews Dropped 29/32" ball and pumped down to seat, pumped down at 3 bpm at 525 psi, with ball on seat pressured up to 2,600 psi to release HR running tool, slacked off then pressured up to 3,900 psi to blow ball seat, PU and was released from liner, st wt up 135K, slacked off and tagged TOL at 7,362' POOH from 7,362' to 7,094', POOH thru window with no problems (TOW @ 7,145') Circ btms up at 7,094' above TOW, circ at 213 gpm at 1,000 psi Monitored well-static POOH with running tool from 7,094' to running tool at 28' LD liner running tool and cleared rig floor, calc fill on trip out of hole 48 bbls, actual 52 bbls Slip and cut 72' of drilling line and serviced top drive MU Baker fishing BHA #14 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumperjars, 2-4 3/4" Dc's and 1-jt of HWDP Pnntetl: 9021/2005 2:52:30 PM L • ConocoPhillips Alaska Page 18 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date ,From - To Hours Code Code Phase 9/10/2005 18:45 - 20:45 2.00 FISH TRIP CMPLT2 20:45 - 21:30 0.75 FISH WASH CMPLT2 21:30 - 21:45 0.25 FISH CIRC CMPLT2 21:45 - 22:00 0.25 FISH OTHR CMPLT2 22:00 - 00:00 2.00 FISH TRIP CMPLT2 9/11/2005 00:00 - 00:30 0.50 FISH TRIP CMPLT2 00:30 - 01:30 1.00 FISH PULD CMPLT2 101:30 - 03:00 I 1.50 FISH PULD CMPLT2 03:00 - 05:30 2.501 FISH TRIP CMPLT2 05:30 - 06:30 I 1.001 FISH I WASH I CMPLT2 06:30 - 06:45 0.25 FISH OTHR CMPLT2 06:45 - 09:30 2.75 FISH TRIP CMPLT2 09:30 - 12:00 2.50 FISH PULD CMPLT2 12:30 - 12:45 I 0.251 CASE I SFTY CMPLT2 12:45 - 15:00 I 2.251 CASE I PULR I CMPLT2 15:00 - 18:30 I 3.501 CASE I RUNL I CMPLT2 18:30 - 20:45 2.25 ~ CASE OTHR ~ CMPLT2 20:45 - 00:00 3.25 ~ CASE OTHR CMPLT2 9/12/2005 100:00 - 00:45 ~ 0.75 ~ CASE ~ CIRC ~ CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations RIH with BHA #14 from 137' to 7,070', (TOW @ 7,145') st wt up 108K, do wt 62K, rot wt 76K, 25 rpm's with 5K torque i Washed down from 7,070' and tagged top of liner at 7,246', didn't see anything at BOW at 7,157', worked reverse junk basket on TOL with 5K wob, 25 rpm's, 5-7K torque and wouldn't drill off, circ at 337 gpm at 2,800 psi Pumped out of hole from 7,246' to above TOW to 7,130' Monitored well-static POOH with BHA #14 from 7,130' to 2,425' Cont POOH with 6 3/4" rev junk basket on BHA #14 from 2,425' to 137' Stood back 1 std of hybrid push pipe and LD 6 3/4" reverse junk basket, had no recovery in basket, broke out 6 3/4" basket and LD same MU 4 5/8" reverse junk basket on BHA #15 and RIH to 197', MU reverse junk basket onto 2 jts of 2 7/8" PAC DP and RIH with 3-boot baskets, jars and 1 std of hybrid push pipe. RIH with BHA #15 from 197' to 7,220', est circ and rotation, circ at 163 gpm at 700 psi, 25 rpm's with 5K ft-Ibs torque, st wt up 110K, do wt 60K rot 76K Washed and rotated down from 7,220' thru TOL at 7,246' to 7,250', washed down only from 7,250' and started to take 2-3K wt down, PU to 7,250' and washed and rotated down from 7,250' and tagged XO below CSR at 7,297', set 3K wt down on XO and wouldn't drill off, washed down at 71 spm, 252 gpm at 1,450 psi, 25 rpm's with 4-6K torque, PU and washed down to XO again with no fill, pumped out of hole to 7,223' to above TOL at 7,246' Monitored well-static POOH with BHA #15 from 7,223' to BHA at 197' Stood back 1 std of hybrid push pipe and LD 4 5/8" reverse junk basket, had no recovery in basket, broke out and LD remaining BHA, recovered 2 cups of fine sand, small pieces of metal and aluminum in boot baskets, cleared rig floor RU Doyon's liner running equipment Held PJSM with rig crew and Baker rep on running of hook hanger assembly MU 7 5/8" x 4 1 /2" hook hanger assembly with ECP packer and 90' of 2 318" inner string RIH to 265' RIH with hook hanger assembly from 265' and tagged XO below A2 lateral CSR at 7,302.5', (5.49' low), wt up 130K, do wt 78K, PU to top of window at 7,145' Worked hook hanger and bent jt from top of window at 7,145' tagging up on XO of A2 lateral at 7,302.5', after 9 attempts worked hook hanger assembly thru window RIH with hook hanger assembly and tagged up on XO of 5 1/2" setting sleeve at 7,405' (0.13' low) PU and attempted to hook hanger on talc depth with no hook, RIH and hooked hanger 7.53' low after several attempts, after hooking hanger, unhooked and re-hooked 5 times while tagging up on XO each time after unhooking, set 40K down on hook leaving hook assembly bent joint spaced out 2.5' above fully located from 5 1/2" x 4 1/2" XO. Top of hook hanger at 7,148' with end of bentjt at 7,403' Began circ btms up with top of hook hanger at 7,148', circ at 23 spm, 82 gpm at 400 psi, circ while talking to town about setting hook and ECP packer, decision was made to set same. Prlntetl: 1U/Y7/ZWS 2:b23U YM • • ConocoPhillips Alaska Page 19 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 ` Date From - To Hours Code Code Phase 19/12/2005 ~ 00:45 - 01:30 ~ 0.75 ~ CASE ~ CIRC ~ CMPLT2 01:30 - 02:15 0.751 CASE OTHR CMPLT2 ', 9/13/2005 02:15 - 03:00 I 0.751 CASE I CIRC I CMPLT2 03:00 - 07:00 4.00 CASE RUNL CMPLT2 07;00 - 08:30 1.50 CASE RUNL CMPLT2 08;30 - 09:45 1.25 CASE PULR CMPLT2 09:45 - 10:15 0.50 CASE RURD CMPLT2 10:15 - 14:00 3.75 CASE RUNL CMPLT2 14:00 - 15:45 1.751 CASE RUNL CMPLT2 15;45 - 17:30 1.75 CASE CIRC CMPLT2 17:30 - 17:45 0.25 CASE OTHR CMPLT2 17:45 - 21:30 3.75 CASE RUNL CMPLT2 22:00 - 23:00 I 10.00 CASE (PULR CMPLT2 23;00 - 23:30 I 0.50 ~ CASE I RURD CMPLT2 23:30 - 00:00 0.50 WELCT EORP CMPLT2 00:00 - 04:30 4.50 WELCT BOPE CMPLT2 04:30 - 06:15 I 1.75 I CASE I OTHR I CMPLT2 06:15 - 07:00 0.75 CASE OTHR CMPLT2 07:00 - 09:45 2.75 CASE OTHR CMPLT2 09:45 - 10:15 I 0.501 CASE I OTHR I CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Dropped 29/32" ball and pumped down to seat, began circ at 105 gpm at 475 psi and slowed to 63 gpm at 175 psi, with ball on seat pressured up to 530 psi. Turned over to Dowell and pressure tested lines to 4,500 psi, then pressured up in 300 psi increments and opened up by-pass on ECP at 2,700 psi, pressure decreased to 1,600 psi and by pass closed, monitored for 5 min with no decrease in pressure, bled off to 530 psi and checked tank volume and took .75 bbls to inflate ECP, pressured up to 4,700 psi and blew the ball seat. PU to 7,140' and circ a btms up, circ at 400 gpm at 3,000 psi, monitored well-static POOH with hook hanger running tool from 7,140' to 121' POOH LD running tool and 2 3/8" tubing inner string and cleared rig floor MU "B" sand LEM assembly with ZXP packer, hanger, CSR, LEM and 2 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seats, RtH to 217' RD Doyon's 4 1/2" liner running tools RIH with LEM assembly on 4" DP from 217' and tagged up at 7,167', st wt up 135K, do wt 80K Attempted to RIH thru hook hanger and was unable to go deeper than 7,172', made 4 attempts by turning LEM 4 full turns and 2-3/4 turns and was able to work LEM down to 7,167', cont to work LEM by turning at 1/4 turn increments and after 10-1 /4 turns work down to 7,172' setting 30-40K st wt down, made 20 additional 1/8 turns and was unable to go deeper, Tagged up a couple times @ 7,153'. Decision was made to POOH with LEM PU to 7,170' and circ btms up at 30 spm, 106 gpm at 350 psi Monitored well-static POOH with LEM assembly from 7,170' to 217', SLM out with no correction, calc fill on trip out of hole 50 bbls, actual fill 52 bbls RU Doyon's 4 1/2" liner running tools POOH LD ZXP packer, hanger, CSR and LEM, LD 2 jts of 4 1/2" liner with seals, ZXP and LEM looked new, found mule shoe on seals to be damaged with gouges on OD 8~ ID, 4.71" OD mule shoe was egg shaped to approx 4.5", had scarring above mule shoe up into seal area to coincide with gouges on OD of shoe, jt above seals looked ok. RD Doyon's 4 1/2" liner running tools Pulled wear bushing Install test plug. Test BOP's, IBOP's, Floor & Dart Valves, & Choke Manifold Valves. Pull Test plug and install wear bushing. RILDS. Witness of test waived by AOGCC rep John Spaulding. Make up "DUMMY LATCH "assembly on MWD tools. Orient to latch. Make up LEM (14.94'), Crossover (1.42), 4 3/4"Integral Blade stabilizer (5.55'), NM Float sub (2.14'), NM Float Sub (2.35'), DM HOC ( 8.55'), MWD Gamma / RES (24.18'), TM HOC (11.28'), and Cross over (1.66). Plug in and upload MWD assembly, Trip in hole with Dummy Latch assembly from 205' - 7156' (6951'). UP WT = 127K. SO WT = 84K. 178 GPM - 1000 PSI. Orient to 86 degrees right, and slack off to observe latch up @ 7156' with 20K set down wt, with orientation reading 11 Degrees left of H.S. Pull up and unlatch @ 23K over, and orient to 107 degrees right of H.S. Slack off, observe latch up @ 7156' with orientation of 8 Degrees left of Printed; 10/21!2005 2:52:30 PM • ConocoPhillips Alaska Page 20 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1 J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code'. Phase 9/13/2005 09:45 - 10:15 0.50 CASE OTHR CMPLT2 10:15 - 11:00 0.75 CASE CIRC CMPLT2 11:00 - 12:00 1.00 CASE OTHR CMPLT2 12:00 - 13:45 1.75 CASE OTHR CMPLT2 13:45 - 14:30 I 0.751 CASE I OTHR I CMPLT2 14:30 - 14:45 0.25 CASE OTHR CMPLT2 14:45 - 17:00 2.25 CASE OTHR CMPLT2 17:00 - 17:30 0.50 CASE OTHR CMPLT2 17:30 - 18:00 0.50 CASE OTHR CMPLT2 18:00 - 20:45 2.75 CASE ~ OTHR ~ CMPLT2 20:45 - 00:00 I 3.251 CASE I OTHR ~ CMPLT2 19/14/2005 100:00 - 00:15 I 0.251 CASE I OTHR I CMPLT2 00:15 - 01:00. 0.75 CASE CIRC CMPLT2 01:00 - 04:30 3.50 CASE OTHR CMPLT2 04:30 - 06:30 2.00 CASE OTHR CMPLT2 06:30 - 07:00 0.50 CASE OTHR CMPLT2 07:00 - 07:30 0.50 CASE RURD CMPLT2 07:30 - 09:30 2.00 CASE RUNC CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations H.S. Pull up to unlatch with 23K overpull, and orient to 130 Degrees right of H.S., Slack off to observe latch up @ 7156'with a 5 degrees left of H.S, reading, and 20K set down wt. Pull up to 23K over and unlatch again. Total of 3 times with indication of proper orientation of Hook Hanger. Circulate Bottoms up @ 81 SPM, 288 GPM's - 2200 PSI. Obtain Slow pump rates. #1 pump - 20 SPM - 210 PSI, 30 SPM - 400 PSI. #2 Pump - 20 SPM - 190 PSI, 30 -SPM - 390 PSI. Moitor well -Static. POOH from 7156' - 6230' (926'). Observed proper hole fill. Continue POOH with Dummy Latch assembly from 6230' - 72' (6158'). Calculated hole fill = 50 BBLS, actual fill = 55 BBLS. Breakout & Lay down crossover, MWD assembly, and Dummy Latch assembly. BHA total = 72.07' Clean & clear floor area, from wet trip. Pull tools to rig floor: Make up 4 1/4" tapered mill assembly. Make up 4 1/4" Tapered mill 2.06'), Crossover (1,43'), 2 -jnts 2 7/8" PAC drill pipe (62.44'), crossover (3.58'), 4 3/4" String Mill (4.34'), 3 - jnts 2 7/8" PAC drill pipe 9 94.07'), crossover to 3 1/2 IF (1.78'), Crossover to 3 1/2 REG 1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumper jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 1.66') Total BHA = 205.61 Trip in hole from 205' - 1349' (1144'). Check pump pressures. ID of toots = 1 ". 30 SPM - 1000 PSI, then pressure climbed to 2600 PSI. Unplug jet in mill to observe pressure @ 3400 PSI w/ 48 SPM. TIH to pressure check @ 2992'. 55 SPM - 3300 PSI. TIH to 5023'. 55 SPM - 2800 PSI. TIH to 5893'. 55 SPM - 2900 PSt. TIH to 6815'. 55 SPM - 3400 PSI. Un plugged jet & 58 SPM - 2250 PSI. Tlh to 7162'. Tagged @ 7162 DPM. UP WT = 125K, SO WT = 80K, ROT WT = 95K. 25 RPM's w/ 4-5K torque. Rotate @ 25 rpm's to work through spot @ 7162' with no issues. Observe little or no torque increase and continue down to tag crossover in seal bore @ 7302' DPM. Work mills from 7302' - 7271', while circulate btms up. POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. UP WT = 130K, SO WT = 84K 252 GPM's - 3000 PSI. Circulate bottoms up @ 250 GPM's - 3000 PSI. Monitor well -Static POOH from 7302' - 205' (7097'). Hole taking proper fill. Break out and lay down BHA. Layed down 4 1/4" tapered mill assembly. 4 1/4" Tapered mill (2.06'), Crossover (1.43'), 2 -jnfs 2 7/8" PAC drill pipe (62.44'), crossover (3.58'}, 4 3/4" String Mill (4.34'), 3 -jnts 2 7/8" PAC drill pipe 9 94.07'), crossover to 3 1/2 IF (1.78'), Crossover to 3 1/2 REG (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumper jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 ( 1.66') Total BHA = 205.61 Observed Littie or no wear on mills. Clean and Clear floor area. Pull tools to rig floor. Rig up casing running equipment, tongs, elevators and slips. Make up B Lateral LEM assembly. Run #2. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.03'), 1 -jnt 4 1/2 12.6# tbg (30.09'), Camco "D" Nipple (1.52'), 1 -jnt 4 1/2 f'nntea: ~u¢vluuo e:ocsurnn • • ConocoPhillips Alaska Page 21 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date -From - To Hours Code Code Phase 9/14/2005 07:30 - 09:30 2.00 CASE RUNC CMPLT2 09:30 - 10:00 0.50 CASE RURD CMPLT2 10:00 -12:00 2.00 CASE RUNC CMPLT2 12:00 - 13:45 1.75 CASE RUNC CMPLT2 13:45 - 15:45 15:45 -19:30 19:30 - 21:30 2.00 I CASE RUNC CMPLT2 3.751 CASE I RUNC I CMPLT2 2.00 CASE RUNC CMPLT2 I 21:30 - 22:00 22:00 - 23:30 23:30 - 00:00 9/15/2005 100:00 - 02:45 02:45 - 05:00 05:00 - 08:00 08:00 - 09:45 09:45. 12:00 12:00 - 13:00 13:00 - 15:45 15:45 - 18:00 0.50 CASE RURD CMPLT2 1.50 RIGMNT RSRV CMPLT2 0.50 CASE OTHR CMPLT2 2.751 CASE I RURD I CMPLT2 2.251 CASE I OTHR I CMPLT2 3.00 CASE OTHR CMPLT2 1.75 CASE OTHR CMPLT2 2.251 CASE I OTHR I CMPLT2 1.00 CASE I OTHR CMPLT2 2.751 CASE I OTHR I CMPLT2 2.251 CASE I OTHR I CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 12.6# tbg (30.82'), 2 - 4 1/2" Pups (3.81', 7.80'), LEM assembly inside Hook Hnager (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1/2" Pup jnts (3.80', 3.82'), Baker casing Swivel (2.45'}, XO bushiing 5 1/2 Hydril x 4 112 IBT (1.33'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 1/2" x 7 5/8" Liner top Packer (19.05'), Baker Hydraulic setting tool (5.20'), Baker running tool (5.70'), and XO to DP XT39 1.66'). Rig down casing running Equipment, and clear Boor. RIH with LEM assembly on DP, from 218' - 3199' (2994'). Continue RIH with LEM assembly on DP from 3199' - 7166' (3967'). Tagged up @ 7166'. UP WT = 127K, SO WT = 82K. Work through spot @ 7166' and continue down to tag again at 7174' DPM. Attempt to work Mule shoe through, could not get down setting down to 25K. Repeat attempts several times to verify Mule Shoe would not pass through spot, while pumping 106 GPM's - 325 PSI. POOH with LEM assembly from 7172' - 217' (6955'). Hole took proper fill. Rig up casing Equipment. Tongs, elevators and slips. Lay down entire LEM assembly and breakout Casing Swivel form Packer assembly. Observe Mule shoe "pinched" down to 4 1/4" OD, egg shaped and little junk cut damage to OD of mule shoe, and seals. Pictures were taken and sent to town. Rig down casing running Equipment, and clear floor. Slip & cut drilling line, Service Top Drive and inspect saver sub. OK. Pull tools to rig floor and rig up to run 2 7/8 PAC DP for next BHA, Mill run. Clean & Clear rig floor area, Wait on mills from Baker, and pull tools to rig floor. Strap & make up BHA -Milling Assembly. Make up 4 1/4" Tapered mill ( 2.06'), Crossover (1.43'), 2 - jnts 2 7/8" PAC DP (62.44'), Crossover 3.58'), 5 1/4" String Mill (4.36'), Crossover (3.55'), 5 1/4" String Mill 4.75'), Crossover (1.78'), 4 3/4" Float Sub (2.14'), XT39 Crossover 1.65'), 3 - jnts DP (93.36'), Crossover (1.64'), Crossover (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover (2.85'), 4 3/4" Bumper jar 7.87'), 4 3/4" Oil Jar (11.14'), and Crossover (1.66'). Trip in hole from 218' - 7194' (6976'). Pump down @ 70 SPM - 1900 PSI, while rotating 20-100 RPM's multiple times tagging at 7164' .Observe torque @ 5-6K while rotating. Mill through spot @ 7164' until free. Work mills through spot until free travel with no pumps or rotation. Continue work mills through spot between 7228' - 7236' continuously until observed free travel with no pumps or rotation. Continue RIH to tag crossover in SBE @ 7302'. UP WT = 119 K, SO WT = 78K, ROT WT = 92K, TO = 4-6K. Continue work string up to 7116' and down to 7206', and tag Crossover at 7302'. UP WT = 125K, SO WT = 80K, ROT WT = 100K. TO = 5-6K, using pumps at 70 SPM - 1900 PSI. Work up and down with and without pump or rotation to verify clean hole conditions. Pull back to 7190', and RIH to tag crossover again @ 7302', observe clean hole, no tag. Monitor well -static. POOH from 7302' - 218' (7084'). Observe proper hole fill Breakout & lay down milling BHA. Lay down entire assembly as above, Printed: 102'1200b L:SL::iO F'M • • ConocoPhillips Alaska Page 22 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date .From - To Hours Code Code Phase __ _ -- 9/15/2005 ~ 15:45 - 18:00 ~ 2.25 ~ CASE OTHR CMPLT2 18:00 - 19:30 19:30 - 22:45 22:45 - 00:00 9/16/2005 00:00 - 00:15 1.501 CASE I RURD I CMPLT2 3.251 CASE RUNC CMPLT2 1.251 CASE I RUNC I CMPLT2 0.251 CASE I RUNC I CMPLT2 00:15 - 00:45 00:45 - 01:00 01:00 - 03:45 03:45 - 04:15 04:15 - 04:45 04:45 - 10:00 10:00 - 12:00 12:00 - 14:30 14:30 - 15:15 15:15 - 15:30 0.501 CASE RUNC ~ CMPLT2 0.25 CASE DEQT CMPLT2 2.75 CASE RUNC CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations and clean junk baskets. Recovered approximately 1/2 cup of metal shavings, and piece of twisted iron 2" long. Mills in gauge to 5 1/4" and in good shape. Clean floor area, RU casing running equipment. Makeup B Lateral LEM assembly. Run #3. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.47'), 1 - Int 4 g 30.12'), Camco "D" Nipple (1.52'), 1 - jnt 4 1/2 12.6# tbg (30.84'), 2 - 4 1/2" Pups (3.80', 7.80'), LEM assembly inside Hook Hanger (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1/2" Pup jnts (3.80', 3.82'), XO bushiing 5 1/2 Hydril x 4 1/2 IBT (1.43'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 1/2" x 7 5/8" Liner top Packer 19.05'), Baker Hydraulic setting tool (5.21'); Baker running tool (5.70'), and XO to DP XT39 (1.66'). Total BHA = 215.73' Rig down casing running equipmeht. Trip in hole with B lateral LEM assembly from 216' - 7174' (6958'). Tag up at 7164', and work mule shoe through spot setting down max weight of 20K to get through. Work approximately 1/2 hour. UP WT = 120K, SO WT = 79K. Continue work LEM assembly down to 7290' with no tagging issues. UP WT = 128K, SO WT = 80K. Pick up 1 single of DP to get to bottom. Continue RIH w/ LEM assembly to tag and latch up on Hook Hanger at 7154.56'. Observed this depth = 6' low. Pull up to 15K over upweight to verify good latch up. Slack off to neutral position. UP WT =128K, SO WT = 82K. Seals positioned @ 7299.86'. (3' above crossover). Rig up and drop 1 1/2" Ball down DP pumping @ 3 1/2 BPM - 250 PSI, until ball seated at 55 BBLS pumped. Continue pressure up to 4300 PSt as per BOT rep to set ZXP packer. Hold 5 minutes and bleed pressure. Rig up. Close Annular and test casing pumping down annulus to 1000 PSI for 10 minutes. Record on chart. Good test. Bleed pressure. Momitor well -static. Pick up above ZXP to allow dogs to kick out on running tool and then slack off to tag and verify top of ZXP @ 7096.70' DPM. Repeat tag. (ZXP = 6.63' Low) POOH. Observed proper hole fill. 0.50 CASE OTHR CMPLT2 Breakout & Lay down Baker Hydraulic Setting tool and Running tool. Inspect tools and all looked good. 0.50 CASE OTHR CMPLT2 Clean & Clear floor area, lay down tools. 5.25 WINDO ULD PROD3 Pull tools to rig floor and make up 7 5/8" Whipstock assembly with space out pipe. Made up Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 -juts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'), Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub w/ cup (2.02'), 7 5/8" Whipstock (14.36'), 6.125" Starting Mill (1.50'), 6 1/8" Lower Mill (5.52'), 6.750" Upper Mill (5.84'), 1 - Jnt 3 1/2 HWDP (29.83'), Float sub (2.35'), Float sub (2.14'), MWD assembly (44.01'), Bumper jar (7.87'), Bumper Jar (7.83'), Crossover 1.66'), and 2 stands Hybrid Coilars (179.70'). Up load MWD and perform shallow pulse test. 70 SPM -700 PSI. 2.00 WINDO RIP PROD3 Trip in hole at 2 minutes /stand as per BOT rep, from 601' - 2999' 2300'). Obatain SLM on TIH. 2.50 WINDO RIP PROD3 Continue trip in hole from 2999' - 6626' (3627'), at 2 minutes /stand. UP WT = 122K SO WT = 75K. 0.75 WINDO RIP PROD3 Perform MAD PASS Log from 6626' - 6712' (86'), AT 250 gpm's - 1650 PSI, at 250 FT/HR. 0.25 WINDO RIP PROD3 Continue trip in hole at 2 minutes /stand to 7098'. UP WT = 135K, SO Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 23 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 'From - To Phase Hours Code ' , Code 9/16/2005 15:15 - 15:30 0.25 WINDO RIP PROD3 ~ 15:30 - 16:15 0.75 WINDO ETW PROD3 16:15 - 17:00 0.75 WIN 17:00 - 20:00 3.00 WIN 20:00 - 21:30 1.50 WIN 21:30 - 00:00 2.50 WIN 9/17/2005 00:00 - 01:15 1.25 WIN 01:15 - 03:00 1.75 WIN 03:00 - 04:15 1.25 WEL 04:15 - 04:45 04:45 - 08:30 08:30 - 12:00 12:00 - 12:15 ICIRC PROD3 IOTHR PROD3 ICIRC PROD3 rrRIP PROD3 rrRIP PROD3 ~PULD PROD3 EORP I PROD3 0.50 RIGMNT RSRV PROD3 3.75 DRILL PULD PROD3 3.501 DRILL (TRIP IPROD3 0.251 DRILL (TRIP ~PROD3 12:15 - 00:00 I 11.75 DRILL ~ DRLG PROD3 9/18/2005 100:00 - 12:00 I 12.00 I DRILL I DRLH I PROD3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations WT = 84K. Orient whipstock face to 7 Degrees left of high side as per DD and BOT rep. Slack off and tag top of ZXP at 7098' and set down to set BTA at 10k. Pull up 10K over to verify set and slack off to shear bolt at 30K. Pick up to neutral position and rotate free of whipstock. Top of whipstock at 6784". The "D" sand top is at 6783". Displace well from SFMOBM to 9.0 PPG MOBM @ 250 GPM's - 1950 PSI. Mill window from 6785' - 6797' (12') in 1.66 HRS. Continue mill OPEN HOLE from 6797' - 6826' (29') in 1.34 HRS for a total milling time of 3.0 HRS, with 20' of gauged hole as per plan. 100 RPM's with torque at 6-8K avg. Pump Hi -Visc sweep at 250 GPM's - 1950 PSI, while dressing window area with mills until window looked clean. PU WT = 125K, SO WT = 80K, ROT WT = 92K. Obtain SPR's at 6787 MD TVD = 3215'. MW = 9.0 PPG. #2 pump - 20 SPM - 330 PSI, 30 SPM - 460 PSI. Monitor well -static, pump dry job. POOH with milling assembly. Continue POOH from 2255'-287' (1968'). Breakout & lay down last 10 Lo-Tads in hole for drilling run. Rack back 2 stands Push pipe. Breakout and lay down Milling BHA. Lay down Crossover (1.66'), 2 - 4 3/4" Bumper Jar (7.83', 7.87'), MWD assembly (44.01'), 2 -Float subs (2.14', 2.35'), 1 jnt 3 1/2" HWDP 29.83'), 6 3/4" Upper mill (5.84'), 6 1/8" Lower mill (5.52'), and starting mill (1.5'). Observed upper mill in full gauge of 6.750". BOLDS and pull wear bushing. Make up stack washer and RIH to flush BOP stack. Function test all rams. Install wear bushng and RILDS. Service Top Drive. Inspect saver sub. OK. Make up BHA #22. Make up 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar (8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR (24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub (2.35'}, NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), $ 3/4 rilling jars ( 28.90'), 4 - 4" HWDP (120.85'). Orient and perform shallow pulse test. OK. Trip in hole from 370' - 6565' (6195'). Change out bad Lo-tad on stand # 67. Continue TIH from 6565'-6814' (261'). Pass through window area with no issues. Wash & Ream down undergauge hole to 6826'. Clean hole ECD = 10.2 PPG Drill 6 3/4 D Lateral from 6826' - 7755' (929'). TVD = 3246'. ADT = 7.97 HRS. PU WT = 118K, SO WT = 55K, ROT WT = 80K. Torque on = 6K, off = 7K. RPM's = 120. Pump at 300 GPM's-2600 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 16, Visc = 77, Gels 21/28/29. Max gas units observed = 198 units. Jars = 111.87 HRS total. Total bit Hrs = 7.97. Slow pump rates #1 - 20 SPM - 340 PSI, 30 SPM - 560 PSI. #2 pump - 20 SPM - 350 PSI, 30 SPM - 530 PSI. Drill 6 3/4 "D" Lateral from 7755 - 9395' (1640'). TVD = 3289'. ADT = 7.78 HRS. PU WT = 145K, SO WT = 43K, ROT WT = 76K. Torque on = 7-8K, off = 6-8K. RPM's = 120. Pump at 300 GPM's-2720 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 21/28/33. Max gas units observed = 236 units. WOB = 5-14K. Jars = 119.95 HRS total. Total bit Hrs = 15.75. Slow pump rates #1 - 20 SPM - 400 PSI, 30 Printed: iuilvluus z:oz:su rm • • ConocoPhillips Alaska Page 24 of 29 Operations Summary Report Legal Well Name: 1J-168 Common W ell Name: 1J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLIN G Start: 8/13/2005 End: Contractor Name: n1334@ ppco.co m Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/18/2005 00:00 - 12:00 12.00 DRILL DRLH PROD3 SPM - 620 PSI. #2 pump - 20 SPM - 420 PSI, 30 SPM - 630 PSI. ECD @ 11.46 PPG. Pump Hi Visc sweep at 8275'. Observe minimal incresae in cuttings at shakers when sweep returned. 12:00 - 12:15 0.25 DRILL DRLH PROD3 Continue drill 6 3/4 "D" Lateral From 9395' - 9435' (40'). TVD -3293'. Stopped Drilling as we are out of zone as per Geologist. Observed Fault @ 8846' MD with throw 10 -12' down. ADT .45 HRS. 12:15 - 12:30 0.25 DRILL CIRC PROD3 Allow Hi Visc sweep to come back, circulating @ 300 GPM's 2720 PSI. while reciprocating drill string. 12:30 - 13:30 1.00 DRILL TRIP PROD3 BROOH 2 stands. Pull 5 stands out on elevators from 9435' - 8664' 771') 13:30 - 15:45 2.25 DRILL DRLH PROD3 Trough with 6 3/4" Geo-pilot assembly from 8664' - 8680 (16'). 15:45 - 21:45 6.00 DRILL DRLH PROD3 Perform sidetrack and drill 6 3/4" hole from 8680' - 9435' (755'). ADT = 5.16 HRS. UP WT = 127K, SO WT = 50K. ROT WT = 80K Torque On/OFF BTM = 8K. 21:45 - 00:00 2.25 DRILL DRLH PROD3 Drill 6 3/4 "D" Lateral from 9395' - 9629'. (234'). TVD = 3306'. ADT = 1.83 HRS. PU WT = 130K, SO WT = 50K, ROT WT = 77K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22/30/33. Max gas units observed = 223 units. WOB = 5-10K. Jars = 126.09 HRS total. Total bit Hrs = 22.19. Slow pump rates @ 9049'. TVD - 3281'. #1 - 20 SPM - 420 PSI, 30 SPM - 620 PSI. #2 pump - 20 SPM - 450 PSI, 30 SPM - 640 PSI. MAX ECD @ 11.8 PPG. Pump Hi Visc sweep. Observed 15 - 20 %incresae in cuttings at shakers. 9/19/2005 00:00 - 04:00 4.00 DRILL DRLH PROD3 Drill 6 3/4 "D" Lateral from 9629' - 10112' (483'). TVD = 3322'. ADT = 3.49 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 20, Visc = 77, Gels 21/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 129.58 HRS total. Total bit Hrs = 25.68. MAX ECD @ 11.8 PPG. Pump 35 BBL Hi Visc sweep. Observed 15 - 20 %incresae in cuttings at shakers. 04:00 - 04:30 0.50 DRILL CIRC PROD3 Complete circulating #2 Hi Visc sweep while reciprocating drill string at 300 GPM's - 2700 PSI. ECD's @ 11.8 PPG ,down to 11.3 PPG. Observed 20-30% increase in cuttings at shakers. 04:30 -12:00 7.50 DRILL DRLH PROD3 Drill 6 3/4 "D" Lateral from 10112' -10886'. (774'). TVD = 3324'. ADT = 4.21 HRS. PU WT = 144K, SO WT = 42K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2975 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22/30/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 133.89 HRS total. Total bit Hrs = 29.89. Slow pump rates @ 10209'. TVD - 3323'. #1 - 20 SPM - 520 PSI, 30 SPM - 710 PSI. #2 pump - 20 SPM - 530 PSI, 30 SPM - 720 PSI. MAX ECD @ 12.01 PPG. Pump Hi Visc sweep. Concretions @ 10013' - 10016' (3'). 12:00 - 17:45 5.75 DRILL DRLH PROD3 Continue Drill 6 3/4 "D" Lateral from 10886' - 11369'. (483'). TVD = 3348'. ADT = 2.95 HRS. PU WT = 146K, SO WT = 38K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3150 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25/37. Max gas units observed = 135 units. WOB = 5-15K. Jars = 136.84 HRS total. Total bit Hrs = 32.84. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep. Change out GEO -SPAN on rig floor, valve failed. 17:45 - 20:00 2.25 DRILL CIRC PROD3 Complete circulating Hi Visc sweep while BROOH and stand back 1 stand, at 300 GPM's - 3200 PSI. ECD's @ 12.2 PPG ,down to 11.8 PPG. Observed 20% increase in cuttings at shakers. 20:00 - 00:00 4.00 DRILL DRLH PROD3 Continue Drill 6 3/4 "D" Lateral from 11369' - 11709'. (340'). TVD = Printed: 10/21/2005 2:52:30 PM C7 • ConocoPhillips Alaska Page 25 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/19!2005 ~ 20:00 - 00:00 4.00 ~ DRILL I DRLH I PROD3 9/20/2005 ~ 00:00 - 12:00 I .12.00 ~ DRILL DRLH PROD3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations -- ___ 13365'. ADT = 2.12 HRS. PU WT = 148K, SO WT = 36K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3200 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25/37. Max gas units observed = 135 units. WOB = 5-15K. Jars = 138.96 HRS total. Total bit Hrs = 34.96. Slow pump rates @ 11274'. TVD - 3351'. #1 - 20 SPM - 710 PSI, 30 SPM - 890 PSI. #2 pump - 20 SPM - 720 PSI, 30 SPM - 930 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep as neede to control ECD. Concretions @ 11647'-11652' (5'), 11656'-11660' (4'). Continue Drill 6 3/4 "D" Lateral from 11709' - 12796. (1087'). TVD = 3416'. ADT = 7.95 HRS. PU WT = 174K, SO WT = 35K, ROT WT = 93K. Torque on = 11.5K, off = 10K. RPM's = 125. Pump at 300 GPM's-3900 PSI. 85 SPM. Mud weight = 9.0+ ppg, YP = 20, Visc = 74, Gels 22/29. Max gas units observed = 161 units. WOB = 5-15K. Jars = 146.91 HRS total. Total bit Hrs = 42.91. Stow pump rates @ 12297'. TVD - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Concretions @ 11735'-11737' (2'), 11780'-11781' (1'), 11881' - 11882' 1'), 12220' - 12240' (20'), 12583' - 12593' (10'), 12658' - 12686' (28'). 12:00 - 15:00 3.00 DRILL DRLH PROD3 Continue Drill 6 3/4 "D" Lateral from 12796 - 12959' MD (163'). TVD = 3424'. ADT = 2.0 HRS. PU WT = 165K, SO WT = 55K, ROT WT = 100K. Torque on = 10.5K, off = 11 K. RPM's = 125. Pump at 300 GPM's-2900 PSI. 70 SPM. Mud weight = 9.2 ppg, YP = 22, Visc = 83, Gels 22/32. Max gas units observed = 102 units. WOB = 2-5K. Jars = 148.91 HRS total. Total bit Hrs = 44.91. Slow pump rates @ 12297'. TVD - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc weighted sweep @ 12842' ECD @ 11.8 PPG Observe 20% increase in cuttings at shakers when sweep out of hole. 12959' = TD we TD'd the well with lower flow rates of 67 SPM (240 gpm)-due to losses. 132 BBLS total fluid loss. 15:00 - 00:00 9.00 DRILL WIPR PROD3 Obtain Surveys, Monitor well -Static. BROOH from 12959' - 7697' 5262'). Average back reamming speed @ 25 - 40 ft/minute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down upon reaching window. 9/21/2005 00:00 - 01:30 1.50 DRILL WIPR PROD3 Obtain Surveys, Monitor well -Static. BROOH from 7697'-6924' (773'). Average back reamming speed @ 25 - 40 ft/minute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down. upon reaching window. Observed no issues when BHA going through window area. While BROOH, calculated displacement = 47.3 BBLS. Hole fill was 80.3 BBLS. 01:30 - 03:00 1.50 DRILL CIRC PROD3 Pump Hi Visc weighted sweep @ 300 GPM's - 2300 PSI. Observed 25% increase in cuttings on shakers. Reciprocate drill string while circulating at 120 RPM's with torque @ 5K. UP WT = 112 K, SO WT = 60K. 03:00 - 04:15 1.25 RIGMNT RSRV PROD3 Slip & cut 72' od drilling line. Inspect and service Top Drive & Drawworks. 04:15 - 08:30 4.25 DRILL WIPR PROD3 POOH with last 3 stands of Lo-Tads on DP. Inspect and change out 8 Total Lo-Tads on stands # 66,68,69,70,71,73,86, and 87. Lo-Tads had flat rollers and plastic insert washed out. Trip in hole to 10974' (4340'). Printed: 10/21/2005 2:52:30 PM • • ConocoPhillips Alaska Page 26 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/21/2005 04:15 - 08:30 4.25 DRILL WIPR PROD3 08:30 - 12;00 3.50 DRILL WIPR PROD3 12:00 -12:15 I 0.25 I DRILL I W IPR I PROD3 12:15 - 15:00 I 2.75 DRILL ~ CIRC PROD3 15:00 - 16:45 I 1.751 DRILL CIRC PROD3 16:45 - 00:00 I 7.251 DRILL TRIP I PROD3 19/22/2005 00:00 - 00:45 0.75 DRILL TRIP PROD3 00:45 - 04:00 3.25 DRILL PULD PROD3 04:00 - 04:45 I 0.751 WINDOV'IIPULD I CMPLT3 04:45 - 07:15 I 2.501 WINDOWTRIP I CMPLT3 07:15 - 07:45 I 0.501 WINDOVVOTHR I CMPLT3 07:45 - 08:30 0.75 ~ WINDOV'WCIRC CMPLT3 08:30 - 09:15 0.75 WINDO RIP CMPLT3 09:15 - 09:45 0.50 WINDO RIP CMPLT3 09:45 - 12:00 2.25 WINDO RIP CMPLT3 12:00 - 14:30 I 2.501 WINDOV(ITRIP I CMPLT3 14:30 - 16:30 I 2.001 WINDOWPULD I CMPLT3 16:30 - 17:00 ~ 0.50 ~ WIND0INPULD ~ CMPLT3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Observed no downweight left. Wash & rotate down from 10974' - 12846' (1872'), with pumps at 64 SPM, 227 GPM - 2500 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Wash 8~ rotate down from 12846' - 12959' (113'), with pumps at 64 SPM, 230 GPM - 2825 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Pump Hi Visc weighted sweep and circulate out plus 1 bottoms up @ 230 GPM's - 2825 PSI, while reciprocate drill string @ 120 RPM's - 8K TO. Held PJSM, discuss Safety and Spill Prevention. RU and displace MOBM with SFMOBM @ 230 GPM's - 2825 PSI. Monitor well -static. POOH on elevators from 12959' - 2237' (10722'), with no swabbing observed. End of tour PU WT = 62K, SO WT = 52K. Total fluid loss this tour = 105 BBLS. Drop 1 3!4" Steel Hollow drift in DP on POOH. Continue POOH, from 2237' - 369' (1868'). Breakout & lay down BHA. Download MWD tools. Lay down BHA #22, 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar 8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR 24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub 2.35'), NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), 6 3/4 drilling jars (28.90'), 4 - 4" HWDP (120.85'). Gauge bit to I / I / CT / N / X / I / NO / TD MAke up BHA # 23, Whipstock retrieving assembly. Make up Retrieving Hook (7.5'), 1 -jnt 3 1/2 HWDP (29.85), 4 3/4" Float sub (2.35'), 4 3/4" Bumper jar (7.86'), 4 3!4" Oil Jar (11.13'), crossover (1.66), 3 - stands Hybrid Push Pipe (270.26). Retrieving slot @ 6789'. TIH from 330' - 6769' (6439'). UP WT = 107K, SO WT = 61 K. Pumps at 124 GPM's - 300 PSI. 35 SPM. Attempt to hook slot @ 6782' DPM. Work 1/4 turns in string 4 times to wash slot and hook whipstock slot. Slack off and confirm hook in slot with set down weight 10K. Pull up from 127K, up to 200K cocking and firing jars to release whipstock and observe 9K increase in upweight. Now UP WT = 116K. NOTE: Found slot @ 6782' = 7' higher. Circulate bottoms up @ 170 GPM's - 575 PSI @ 6764'. Monitor well - static. POOH from 6764' - 6302' (462'). Observed swabbed in 1 BBL. Close rams and pump 3 BBLS into DP. Pull 1 stand @ 5 FT/MIN with proper hole fill. Pull 4 stands @ 25 FT/MIN w/ proper hole fill. Continue POOH to 4004' observing proper hole fill. Continue POOH with whipstock asembly observing proper hole fill form 4004' - 330' (3674'). Calculated hole fill @ 89 BBLS, actual fill = 91 BBLS. POOH, breakoput & lay down Whipstock retrieving assembly as above. Continue POOH breakout and lay down 7 5/8" Whipstock assembly with space out pipe. Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 -jnts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'), Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub w/ cup (2.02'), 7 5/8" Whipstock (14.36'), Clean floor area, and lay down tools on beaver slide. Printed: 10/21/2005 2:52:30 PM w • ConocoPhillips Alaska Page 27 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/22/2005 117:00 - 22:00 ~ 5.00 ~ CASE ~ RUNC ~ CMPLT3 22:00 - 00:00 2.001 CASE RUNC CMPLT3 9/23/2005 00:00 - 00:30 0.50 CASE RURD CMPLT3 00:30 - 05:00 4.50 CASE RUNC CMPLT3 05:00- 09:30 4.501 CASE I RUNC CMPLT3 09:30 - 11:15 I 1.75 I CASE I RUNC I CMPLT3 11:15 - 12:00 0.75 CASE RUNC CMPLT3 12:00 - 15:00 3.00 CASE RUNC CMPLT3 15:00 - 15:45 I 0.751 CASE I RURD I CMPLT3 15:45 - 16:15 0.50 CASE RURD CMPLT3 16:15 - 17:15 1.00 CASE OTHR CMPLT3 17:15 - 00:00 I 6.751 CASE I OTHR I CMPLT3 19/24/2005 100:00 - 01:00 I 1.001 CASE I SFTY I CMPLT3 01:00 - 08:30 I 7.501 CASE I OTHR I CMPLT3 08:30 - 09:00 I 0.501 CMPLTN RURD I CMPLT3 Held PJSM, discuss Safety 8~ running detail. Rig up casing running tools. Make up 4 1/2" Bent joint with crossover (30.65'). Continue RIH with 4 1/2 L-80 IBT Slotted Liner assembly,Average MU torque = 5700 - 6000 FT/LBS. Held PJSM with entire crew.( New crew /Change out day) Discuss safety and procedure to make up 3 1/8" Super Slim MWD tool on inner string of Hook Hanger.BOT Hook Hanger BOT Model B1 Hook hanger to MWD to Hook (180 degrees out). MWD offset = 161.45 degrees. UP WT = 79K, SO WT = 52K. Pull Lo-Tads to floor to add to string. Rig down casing running equipment. TIH, installing 2 - Lo-Tads on stands #1- #7 as per TAD engineer. Perform Shallow pulse test on MWD at 6265' w/ 33 SPM -575 PSI, 120 GPM. Continue TIH to attempt getting bent joint through window, tagged up @ 339' down on crossover bushing @ 7135'. Pull up above window, putting 1/4 RH turns in string for a total of 6 attempts before finally rotating at 5 RPM's, 3K torque to observe bent joint through window. Continue trip in hole from bottom of 7 5/8" window @ 6796' - 12929' 6133'). We did not have to rotate string to get to bottom. Pumps on, attempt to orient with MWD tool, and we could not move pipe down. Rack back 1 stand, work pipe until verify free movement, and RIH w/ orientation of 8 Degrres left of high side. Hook Hanger. Pull free and orient to 180 degrees out, and run in hole past the window with Hook. Pull back and re-orient to 7 degrres left to hook, Hook Hanger. Good latch up, and several tool faces were pumped up to verify orientation. Drop 29/32" ball and allow to seat, pumping 2 BBIs a minute, 400 PSI .Pressure to 4190 PSI, to shear out ball seat 8 release from Hook Hanger. Pull up high enough to observe Setting tool released and 55K weight loss. Bottom of window = 6796'. Hook on depth. Monitor well -static. POOH from 6771' - 6423' (348'). PU WT = 137K, SO WT = 86K. Continue POOH from 6423'. Breakout & lay down Lo-Tads off of stands #1 -#7. Breakout & Lay down running and setting tools, inspect same. All good. Breakout & lay dowm 3 1/8" MWD assembly & crossovers. Clean & clear floor area. Remove Lo-Tads and Rig down all casing running equipment, and Baker tools. Rig up. Breakout & lay down 15 stands of Hybrid push pipe in derrick. Continue breakout and lay down 33 stands of 4" XT39 Drill Pipe. Making room in derrick for 4 1/2" completion tbg. Note: Held scheduled Safety Shutdown at rig camp with all drilling supervisors, rig hands, including service contractors. Topic: Pinch Points. Held safety Stand down with Kuparuk Team Leader and entire Rig Team, including service contractors, and HSE reps. Topic - "Pinch Points". Continue Lay down 32 stands of 4" DP, 8 stands of 4" HWDP w/ Lo-Tads, and 34 stands 4" DP w/ Lo-tads. 74 stands total and 42 Lo-Tads. Clear and clean Rig Floor area. Lay down all uneccessary tools. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 28 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours .Code .Code Phase 9/24/2005 09:00 - 09:30 0.50 CMPLTNI RUNT CMPLT3 09:30 - 12:00 2.50 CMPLTN RUNT CMPLT3 12:00 - 15:45 15:45 -16:45 16:45 - 17:15 3.75 CMPLTNI PULD CMPLT3 1.00 CMPLTN RURD CMPLT3 0.50 CMPLTN RURD CMPLT3 17:15 - 21:15 21:15 - 21:45 21:45 - 00:00 9/25/2005 100:00-01:30 01:30 - 03:30 03:30 - 06:45 06:45 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 12:45 12:45 - 17:00 4.00 CMPLTN PULD CMPLT3 0.50 CMPLTN RURD CMPLT3 2.25 CMPLTN RURD CMPLT3 1.50 ~ CMPLTNI RURD ~ CMPLT3 2.00 I CMPLTNI RUNT I CMPLT3 3.251 CMPLTNI RUNT CMPLT3 3.25 ~ CMPLTNI RUNT CMPLT3 0.50 CMPLTN RUNT CMPLT3 1.50 CMPLTN RUNT CMPLT3 0.75 CMPLTN RUNT CMPLT3 4.25 I CMPLTNI RUNT I CMPLT3 Description of Operations Rig up tubing running equipment, tongs, elevators etc.. Pick up singles of 4 1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 31 joints. Make up Torque = 3400 FT/LBS. Continue Pick up singles of 4 1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 155 joints. Total ran in hole = 186 or 62 stands. Make up Torque = 3400 FT/LBS. Rig Down tubing tongs and rig up Double stack tongs. Attempt to repair Double stack tongs. Could not repair gauge or Hydraulic hose. Lay down and replace tongs. POOH, stand back 62 stands of 4 1/2 tbg. 186 Joints total. Clear and clean rig floor area. Held PJSM, discuss rigging up Centrilift equipment,and running procedure. Load Centrilift Motor, Tandem Seal section, and TTC crossover with Screen Intake, GLM's, in pipe shed. Rig up Spooling Unit, and pull all tools to rig floor. Pull 100 Cannon Clamps, 3 -Flat Guards, and SS Flat bands to rig floor, and double check count. Double check count on 4 1/2" tubing in shed. 240 Joints total. Continue Rig up Centrilift equipment. Pull 100 Cannon Clamps to rig floor. Visually inspect and strap all equipment to be run. Hold PJSM with crew& Centrilift Rep.. Discuss Safety & Running Procedures and Installation Procedure of all Clamps. Pick up a 5.62" OD Motor 418 HP-KMFER - 2610/98 Serial # 21 K68696 (33.90') with an A-Well I Pump gauge 4.50" OD Seriat# 216 (2.09'). Make up a 6" OD Motor Centralizer Serial # 63569 (1.98') on bottom of A-Well Pump Gauge. Load motor with Centrilift CL-5 oil, and continue Make up 5.13" OD Tandem Seal Section GSB 3 DB AB/HSN (13.82'). Verify free rotation travel in Motor and load TSS with CL-5 oil. Make up TTC Crossover w/ Screen Intake 5.13" OD (10.60') with 4 1/2 12.6# L-80 IBTM SCC tubing pup (5.84'). Continue fill with oil and check all vent, construction & drain plugs, to be tight. Check resistivity in Motor @ .6 OHMS. After not being install pulled back up and Install 3 Flatguards on line and secure same, with 3 Proctetolizer guards. The Centrilift hand said he got ahead of himself. Rig up, and hang ESP line Sheave, Make up ESP line and 1/4" control line to A-Well Gauge and Motor using Stainless Steel Flat bands and Cannon Clamps for attachment. Meaure OD of of Cannon Clamps on Motor @ 5 7/8", on TSS @ 5 13/16", and on TTC @ 5 3/4". Measure OD of Cannon Clamp on tubing collars at 5 13/16". Run 2 -jnts 4 1/2" TBG, and Centrilift A-Well Discharge Pressure Sub. Attach 1/4" control line to same with Cannon Clamp and measure OD @ 5 13/16". RIH with 4 1/2" Tubing stands from derrick installing Cannon Clamps on every otherjoint. Run 8 stands (738.12'), and install Camco GLM KBG-2 4 1/2" x 1" w/ 1/4" Orifice Valve BK-5 Latch and pups (18.84'). Test ESP line evrey 1000'. Continue run 4 1/2" tbg from derrick. Test line on stand #20, and ESP line failed test. (2742'). Continue attempt to get good test on ESP line. No Good. POOH, looking for bad cable from 2742' - 2006'. Rack back 8 stands. Continue POOH looking for failed line, and observe "bad spot" in line at the first GLM. The ESP line was clamped improperly on the side of the GLM, and was dragging on low side of hole causing a wear spot causing ESP line to fail. . Centrilift hand cut and removed 120' of bad line, and spliced line back together. Test line to good test. Printed: 10/21/2005 2:52:30 PM • • ConocoPhillips Alaska Page 29 of 29 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To __ 9/25/2005 117:00 - 18:45 18:45 - 00:00 1 J-168 1 J-168 ROT -DRILLING n 1334@ppco.com Doyon 141 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Hours Code Code; Phase 1.751 CMPLTNI RUNT CMPLT3 5.251 CMPLTNI RUNT CMPLT3 9/26/2005 100:00 - 02:00 I 2.001 CMPLTNI RUNT I CMPLT3 02:00 - 02:30 I 0.501 CMPLTNI RUNT I CMPLT3 02:30 - 06:00 3.50 CMPLTNI RUNT CMPLT3 06:00 - 08:00 2.00 CMPLTNI RUNT CMPLT3 08:00 - 09:30 1.50 CMPLTN NUND CMPLT3 09:30 - 10:00 0.50 CMPLTN NUND CMPLT3 10:00 - 11:00 1.00 CMPLTN NUND CMPLT3 11:00 - 12:00 1.00 CMPLTN NUND CMPLT3 12:00 - 12:30 0.50 CMPLTN SEAT CMPLT3 12:30 - 13:00 ~ 0.501 CMPLTNI SEOT CMPLT3 13:00 - 16:00 3.00 CMPLTNI FRZP 1 CMPLT3 16:00 - 17:15 I 1.25 I CMPLTNI RURD I CMPLT3 17:15 - 19:15 I 2.00 I CMPLTNI RURD I CMPLT3 19:15 - 19:45 0.50 CMPLTN OTHR CMPLT3 19:45 - 20:30 0.75 CMPLTN RURD CMPLT3 20:30 - 22:30 I 2.001 CMPLTNI NUND I CMPLT3 22:30 - 00:00 1.501 CMPLTNI OTHR CMPLT3 Description of Operations Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on every otherjoint. Test ESP line at 20 stands. Good test. Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on every other joint. Test ESP line every 1000 feet. Good test. 55 stands total in hole at midnight. Continue RIH with 4 1/2" tbg from pipe shed installing Cannon Clamps on every otherjoint. Test ESP line. Good test. Run 2 - jnts 4 1/2" tbg, Camco GLM KBG-2 4 1/2" x 1" with Dummy and pups (18.91'), 1 - jnt 4 1/2" tbg (30.85'), Camco GLM KBG-2 4 1/2" x 1"with Dummy and pups (18.87'), 1 - jnt 4 1/2" tbg (31.05'), 2 - 4 1!2" tbg space out pups 5.76', 7.81'). Avg MU torque = 3400 FULBS Pick up landing joint, and Vetco Gray 11" x 4 1!2" hanger with a joint of 4 1 /2" tbg made up on it (32.57'). Make up joint and hanger. UP WT = 92K, SO WT = 60K. Lower hanger to rotary table, installing Stainless Steel Flat clamps. Install Penetration sub in hanger. Centrilift hand splicing ESP line,-and make up pigtail to hanger.Test same. Good Test. RIH land Tbg hanger as per Vetco Gray rep. UP VVT = 92K, SO WT = 60K. Run in lock down screws. Test hanger seals, upper and lower to 250 PSI -low test. 5000 PSI -high test for 15 minutes. Nipple down BOP stack Remove hold down cap on tubing hanger. Clear floor area, and test ECP cable with Centrilift. Good test. Hang Tree on tugger. Nipple up Tree as per Vetco rep. Rig up and test Tree void to 250 PSI low, 10 minutes. 5000 PSI high for 15 minutes. Tets Tree Flanges to 250 PSI low -10 minutes, 5000 PSI high - 15 minutes. Centrilift rep tested Penetrator Sub and ESP line. All good tests. Held PJSM. Discuss Safety and procedure to displace. Rig up Little Red Serices and pump 250 BBLS of Diesel @ 2.75 BBUMIN , 300 -500 PSI, down annulus for freeze protecting the well. Rig down Little Red and secure valves. Breakout & lay down last 21 stands of 4" XT39 DP in derrick with Lo-Tads. Lay down Bales form Top Drive. Change out Saver Sub, while rig up scaffolding in cellar area. Install BPV as per Vetco Rep. Begin cleaning pits and rockwasher pits. Continue Change out saver sub while break down and remove scaffolding from cellar area. Nipple up Actuator Valve on tree and secure well. Record shut in pressures. TBG Pressure = 225 PSI. Inner Annulus Pressure = 250 PSI. Outer Annulus Pressure = 0 PSI. Clean up cellar area, Suck out all fluids with super sucker truck, and wipe down tree. Rig Released @ 2400 HRS. Printed: 10/21/2005 2:52:30 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-168L 1 Job No. AK-ZZ-0003877631, Surveyed: 6 September, 2005 Survey Report 4 October, 2005 Your Ref.•500292326060 Surface Coordinates: 5945652.97 N, 558712.01 E (70° 15' 43.6408" N, 149° 31' 31.3352" N/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coo-tilinafes relative to Project H Reference: 945652.97 N, 58712.01E (Grid) Surface Coordinates relative to Structure: 266.05 S, 80.03 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~ ~ r i- ~+ _ ~ ~ ~ ~ Survey Ref svy2218 A t~aN&burfan GQntpany Ha/liburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-188L1 Your Ref.• 500292326060 Job No. AK-ZZ-0003877631, Surveyed: 6 September, 2005 Western North Slope Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth 7107.37 80.140 353.920 3178.68 3287.68 7145.00 80.150 354.910 3185.12 3294.12 -~ 7210.81 83.810 356.540 3194.30 3303.30 7304.11 89.060 358.820 3200.10 3309.10 7401.83 87.720 358.700 3202.85 3311.85 7498.03 87.610 359.270 3206.77 3315.77 7594.16 88.920 358.090 3209.68 3318.68 7690.90 87.100 358.980 3213.04 3322.04 7786.24 87.800 358.610 3217.28 3326.28 7883.78 86.930 357.940 3221.77 3330.77 7981.17 87.560 3.040 3226.45 3335.45 8079.16 89.230 6.510 3229.19 3338.19 8174.95 89.900 7.620 3229.92 3338.92 8272.43 90.700 4.620 3229.41 3338.41 8367.23 90.010 3.010 3228.82 3337.82 8465.69 89.830 2.650 3228.96 3337.96 8562.38 89.270 358.790 3229.72 3338.72 8659.04 88.970 357.360 3231.21 3340.21 8755.85 89.780 357.630 3232.26 3341.26 8852.40 90.330 359.760 3232.17 3341.17 8949.16 87.030 357.880 3234.40 3343.40 9046.45 8$.300 0.100 3238.36 3347.36 9141.67 88.470 1.460 3241.05 3350.05 9239.11 88.170 358.030 3243.90 3352.90 9335.55 87.350 0.080 3247.67 3356.67 Local Coordinates Northings Eastings (ft) (ft) 500.04 N 4771.07 W 536.94 N 4774.68 W 601.91 N 4779.53 W 694.91 N 4783.29 W 792.57 N 4785.41 W 888.67 N 4787.11 W 984.73 N 4789.32 W 1081.37 N 4791.80 W 1176.60 N 4793.80 W 1273.99 N 4796.73 W 1371.23 N 4795.90 W 1468.82 N 4787.75 W 1563.88 N 4775.96 W 1660.79 N 4765.57 W 1755.38 N 4759.27 W Global Coordinates Northings Eastings (ft) (ft) 5946115.79 N 553937.19 E 5946152.66 N 553933.29 E 5946217.59 N 553927.93 E 5946310.57 N 553923.44 E 5946408.20 N 553920.57 E 5946504.29 N 553918.12 E 5946600.33 N 553915.15 E 5946696.95 N 553911.93 E 5946792.15 N 553909.18 E 5946889.52 N 553905.49 E 5946986.76 N 553905.56 E 5947084.42 N 553912.96 E 5947179.57 N 553924.00 E 5947276.55 N 553933.63 E 5947371.19 N 553939.20 E Dogleg Vertical ConocoPhillips Rate Section Comment (°/100ft) 500.04 Tie-On Point 2.592 536.94 Window Point 6.078 601.91 6.133 694.91 1.377 792.57 0.603 888.67 1.834 984.73 2.094 1081.37 0.830 1176.60 1.125 1273.99 5.270 1371.23 3.929 1468.82 1.353 1563.88 3.185 1660.79 1.848 1755.38 1853.72 N 4754.41 W 5947469.56 N 553943.30E 0.409 1853.72 1950.38 N 4753.19 W 5947566.23 N 553943.76E 4.034 1950.38 2046.97 N 4756.44 W 5947662.79 N 553939.76E 1.511 2046.97 2143.68 N 4760.67 W 5947759.47 N 553934.77E 0.882 2143.68 2240.20 N 4762.87 W 5947855.96 N 553931.82E 2.278 2240.20 2336.90 N 4764.86 W 2434.08 N 4766.57 W 2529.25 N 4765.27 W 2626.63 N 4765.71 W 2722.98 N 4767.30 W 9432.04 86.550 0.680 3252. 81 3361.81 2819.33 N 4766.66 W 9528.96 87.800 1.070 3257. 58 3366 .58 2916.12 N 4765.18 W 9625.04 88.170 358.570 3260. 96 3369 .96 3012.13 N 4765.48 W 9720.05 87.610 357.850 3264. 46 3373 .46 3107.03 N 4768.45 W 9818.43 87.050 359.280 3269. 04 3378 .04 3205.27 N 4770.91 W 5947952.64 N 5948049.81 N 5948144.99 N 5948242.37 N 5948338.70 N 5948435.05 N 5948531.85 N 5948627.85 N 5948722.73 N 5948820.94 N 553929.08 E 553926.61 E 553927.16 E 553925.97 E 553923.63 E 553923.51 E 553924.24 E 553923.19 E 553919.48 E 553916.26 E 3.925 2.627 1.439 3.532 2.288 1.036 1.351 2.629 0.960 1.560 9917.17 86.860 359.590 3274. 29 3383.29 3303.87 N 4771.88 W 5948919.53 N 553914.51E 0.368 10013.98 86.740 1.640 3279. 69 3388.69 3400.51 N 4770.84 W 5949016.18 N 553914.80E 2.118 10109.88 87.490 0.850 3284. 52 3393.52 3496.27 N 4768.76 W 5949111.95 N 553916.13E 1.135 10206.59 86.810 359.550 3289. 33 3398.33 3592.86 N 4768.42 W 5949208.54 N 553915.72E 1.516 10303.14 88.860 359.140 3292. 98 3401.98 3689.33 N 4769.53 W 5949304.99 N 553913.86E 2.165 2336.90 2434.08 2529.25 2626.63 2722.98 2819.33 2916.12 3012.13 3107.03 3205.27 3303.87 3400.51 3496.27 3592.86 3689.33 C`. L.J 4 October, 2005 - 15:58 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-168L1 Your Ref.• 500292326060 Job No. AK-ZZ-0003877631, Surveyed: 6 September, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10397.89 87.600 0.340 3295.90 3404.90 3784.03 N 4769.96 W 5949399.69 N 553912.69E 1.836 3784.03 10496.71 89.290 357.960 3298.58 3407.58 3882.79 N 4771.42 W 5949498.44 N 553910.46E 2.953 3882.79 10593.44 89.030 358.870 3300.00 3409.00 3979.47 N 4774.10 W 5949595.09 N 553907.03E 0.978 3979.47 10689.74 91.140 0.080 3299.86 3408.86 4075.76 N 4774.98 W 5949691.37 N 553905.39E 2.526 4075.76 10787.23 90.570 0.860 3298.41 3407.41 4173.23 N 4774.18 W 5949788.85 N 553905.43E 0.991 4173.23 10882.68 90.700 0.430 3297.35 3406.35 4268.67 N 4773.11 W 5949884.29 N 553905.76E 0.471 4268.67 . 10978.24 89.890 1.480 3296.86 3405.86 4364.21 N 4771.51 W 5949979.85 N 553906.61E 1.388 4364.21 11075.95 88.410 355.850 3298.31 3407.31 4461.84 N 4773.79 W 5950077.46 N 553903.58E 5.957 4461.84 11173.31 88.910 358.110 3300.58 3409.58 4559.04 N 4778.92 W 5950174.61 N 553897.69E 2.377 4559.04 11269.57 88.900 357.500 3302.42 3411.42 4655.21 N 4782.60 W 5950270.75 N 553893.26E 0.634 4655.21 11366.42 88.170 355.270 3304.90 3413.90 4751.83 N 4788.71 W 5950367.31 N 553886.40E 2.422 4751.83 11462.20 88.600 354.290 3307.60 3416.60 4847.17 N 4797.42 W 5950462.59 N 553876.94E 1.117 4847.17 11560.18 88.410 356.980 3310.16 3419.16 4944.82 N 4804.87 W 5950560.18 N 553868.73E 2.751 4944.82 11655.84 88.600 359.870 3312.65 3421.65 5040.40 N 4807.50 W 5950655.74 N 553865.36E 3.027 5040.40 11751.26 88.290 359.160 3315.24 3424.24 5135.79 N 4808.31 W 5950751.11 N 553863.81E 0.812 5135.79 11841.86 89.220 0.700 3317.21 3426.21 5226.36 N 4808.42 W 5950841.68 N 553862.99E 1.985 5226.36 11932.91 88.410 359.900 3319.09 3428.09 5317.39 N 4807.94 W 5950932.71 N 553862.76E 1.250 5317.39 12019.95 88.480 2.960 3321.46 3430.46 5404.36 N 4805.77 W 5951019.69 N 553864.25E 3.515 5404.36 12112.23 86.600 0.990 3325.42 3434.42 5496.49 N 4802.59 W 5951111.85 N 553866.71E 2.949 5496.49 12204.07 85.930 1.070 3331.40 3440.40 5588.12 N 4800.94 W 5951203.49 N 553867.64E 0.735 5588.12 12295.36 85.440 1.970 3338.27 3447.27 5679.12 N 4798.53 W 5951294.50 N 553869.35E 1.120 5679.12 12382.82 86.440 0.620 3344.46 3453.46 5766.33 N 4796.56 W 5951381.73 N 553870.64E 1.918 5766.33 12474.54 87.560 1.450 3349.26 3458.26 5857.91 N 4794.90 W 5951473.32 N 553871.58E 1.519 5857.91 • 12566.19 88.230 359.680 3352.63 3461.63 5949.49 N 4794.00 W 5951564.90 N 553871.77E 2.064 5949.49 12653.27 87.670 0.720 3355.74 3464.74 6036.51 N 4793.70 W 5951651.92 N 553871.39E 1.356 6036.51 12747.52 87.370 359.830 3359.82 3468.82 6130.67 N 4793.25 W 5951746.08 N 553871.11E 0.996 6130.67 12838.35 87.240 0.020 3364.09 3473.09 6221.40 N 4793.36 W 5951836.81 N 553870.28E 0.253 6221.40 12932.58 86.500 359.880 3369.24 3478.24 6315.49 N 4793.45 W 5951930.89 N 553869.47E 0.799 6315.49 - 12967.00 86.500 359.880 3371.34 3480.34 - 6349.84 N 4793.52 W 5951965.25 N 553869.13E 0.000 6349.84 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12967.OOft., 4 October, 2005 - 15:58 Page 3 of 4 D-illQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kupa-uk 1J Pad -1J-168L1 Your Ref.• 500292326060 Job No. AK-ZZ-0003877631, Surveyed: 6 September, 2005 Western North Slope The Bottom Hole Displacement is 7956.03tt., in the Direction of 322.951° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 7107.37 3287.68 500.04 N 4771.07 W Tie-On Point 7145.00 3294.12 536.94 N 4774.68 W Window Point 12967.00 3480.34 6349.84 N 4793.52 W Projected Survey Survey toot program for 7J-168L1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 540.30 539.50 To Measured Vertical Depth Depth (ft) (ft) 540.30 539.50 12967.00 3480.34 Survey Tool Description CB-SS-Gyro (1J-168) MWD+IIFR+MS+SAG (1J-168) ConocoPhillips • 4 October, 2005 -15:58 Page 4 of 4 DrillQuest 3.03.06.008 #~ 3 ~ ; ~~ ~ ~d. ~ ~ ~ ~, ~ # ~~~ , FRANK H. MURKOWSK/, GOVERNOR 3 ~~~~ ~~~~++ ~~a~ ~ ~~+ ~-7~ OII/ ~ ~ ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA`1'IO1~T COMh'IISSI011T ~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAx (so7~ 27sasa2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0350 Re: Kuparuk 1J-168L1 ConocoPhillips Alaska, Inc. Permit No: 205-061 Surface Location: 1841' FSL, 2499' FEL, SEC. 35, Tl 1N, R10E, UM Bottomhole Location: 2370' FNL, 2027' FEL, SEC. 27, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-168, Permit No 205-060, API 50-029-23260-00. Production should continue to be reported as a fiznction of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commissio t witness any required test. Contact the Commission's petroleum field inspector at 907 -36 7 (pager). DATED this~day of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~0 ~1 ~L.~dT APR - 2005 1 a. Type of Work: Drill Q Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Develop S Qp~lti Q Stratigraphic Test ^ Service ^ Development Gas ^ Anchora gle Zone ^/ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-168L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12952' ' ND: 3512' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25660 s West Sak Oil Pool Top of Productive Horizon: FSL 2431', FEL 2018', Sec. 34, T11 N, R10E UM 8. Land Use Permit: ALK 471 & 470 13. Approximate Spud Date: 6/21/2005 Total Depth: 2370' FNL, 2027' FEL, Sec. 27, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to ) 5~ ~ ~/-/' Nearest Property: ,aS,~ucfacs~e~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 ~ y- 5945653 ' Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest ~~ _`~ C 1 Well within Poo1:,,,1J-i9~^TT1' ~j~ ~ 16. Deviated wells: Kickoff depth: 7227 ' ft. Maximum Hole Angle: gg° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1481 psig Surface: 1134 psig , °:.~ /3 18. Casing Program S if ti Setting Depth Quantity of Cement Size ons pec ica Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3527' 28' 28' 3555' 2118' 640 sx ASLite, 180 sx DeepCRETE 9-718" 7-5/8" 29.7# L-80 BTCM 8181' 28' 28' 8209' 3481' 480 sx DeepCRETE 6.75" 4.5" 12.6# L-80 BTCM 5767' 7185' 3310' 12952' 3512' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MO (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Cloninger @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ Phone 2G S'6-r?Sa Date Y ~Llo~ h n All Commission Use Only Permit to Drill Number: ~~ ~(~/ API Number:p /~ °~~~ 50- ~~./ "~~~;~'"S[:,~-~ Permit Approval Date: ~ , t~ ~ See cover letter for other requirements Conditions of approval les required Yes ^ No Mud log required Yes ^ No rogen sulfide measures Yes ^ No Directional survey required Yes '~ No ^ Other. APPROVED BY ~ ~ /"~ Approved THE COMMISSION Date: J\ Form 10-401 Revised 06/2004 ~ ~}~ s~ ~• ~-''"~~ ~~ Submit in Duplicate ~, ~~S ~~ ~ication for Permit to Drill, Well 1J-168L1 Revision No.O March 31, 2005 Permit- West Sak #1J-168L1 Producer ("B" Sand) Application for Permit to Drill Document 1Mell Vp1uE Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c) (12) ................................................................................................ 5 ORIG'NAL 1J-168L1 Producer Permit Page 1 of 6 Printed: March 31, 2005 ~lication for Permit to Drill, Well 1 J-168L1 Revision No.O March 31, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c) (14) ................................................................................................ 6 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (fl Each wet/must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a we/l with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated far the wei/ by the operator and to the number assigned to the well by the commis/an. The well for which this Application is submitted will be designated as iJ-168L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fir/e with the commission and identified in the application: (2) a plat identifying the property and the property's owners arnd showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at Iota/ depth, referenced to governmental section lines (B) the coordinates of the proposed location of the we/l at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we/l at the top of each objective formation and at total depth; Location at Surface FSL 1841' ,FEL 2499', Sec.35, T11N/R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5945653 Eastings: 558712 Pad E/evation 81' AMSL Location at Top of Productive Interval FSL 2431', FEL 2018', Sec. 34, T11 N/R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 7185 Northings: 5946207 Eastings: 553908 Total 1/ertical De th RKB: 3310 Total 1/ertical De th, SS.• 3201 Location at Total Depth FNL 2370', FEL 2027', Sec 27, T11 N/R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12952' Northings:5951965 Eastings: 553848 Total I/ertical De th, RKB: 3512' Tota/ ~ertica/ De th, SS.• 3403' and (D) other infom~ation required by 20 AAC 25, 050(6); Requirements of 20 AAC 25.050(6) If a we// is to be intentionally deviated, the application for a Pr~rmit to Dril/ (Form 10-401) must (I) inc/ude a plat, drawn to a suitable scale, showing the path of the proposed wellbore, inc/uding al/adjacent wellbores within 200 feet of any portion of the proposed we/% ORIGINAL 1 J-168L 1 Producer Permit Page 2 of 6 Printed: March 31, 2005 ~lication for Permit to Drill, Well 1J-168L1 Revision No.0 March 31, 2005 Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wel/s, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mai/; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-168L1. Due to the formation pressures being far less then the rating of the BOPE, CPAI would like to request that the stack be operated under the 3,000 psi BOP guidelines thereby allowing the use of one ram cavity for casing rams and negating an additional BOP test once the intermediate casing has been run. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J-168L1 area vary from 0.44 to 0.47 ~ psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1134 psi, calculated thusly: MPSP =(3150 ft)(0.47 - 0.11 psi/ft) =1134 psi (e) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% prob/ems such as abnorma/ly geo pressured strata, lost circv/ation zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(t); The parent wellbore,iJ-168, will be completed with 7 5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1 J-168L 1 Producer Permit Page 3 of 6 Printed: March 31, 2005 ORIGINAL ication for Permit to Drill, Well 1 J-168L1 Revision No.0 March 31, 2005 6. Casing and Cementing Program Requirements of 20 AAC 25.OO5(c)(6) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted /iner, pre- perforated /iner, or screen to be installed; C Casing and Cementing Program See also Attachment 3 APD for 1J-168L1: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TI/D MD/TVD OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 20" 40" 94 K55 Welded 80' 28' / 28' 108' / 108' Cemented to surface with 260 cf ArcticCRETE 10 3/4" 13 1/2" 45.5# L-80 BTC 3527' 28'/28' 3555'/2118' Cemented to Surface with 640sx ASLite Lead, 180sx Dee CRETE Tail 7 5/8" 9 7/8" 29.7# L-80 BTCM 8181' 28'/28' 8209'/3481' Cement Top planned @ 4778' MD/' Ti/D. Cemented w/ 480 sx Dee CRETE 4 1/2" 6 3/4" "A" 12.6# L-80 BTCM 4766' 8209'/3481' 12975'/3658' Slotted - no cement ed Later 4 1/2" 6 3/4" "B" 12.6# L-80 BTCM 5767' 7185'/3310' 12952'/3512' Slotted - no cement slotted Lateral 1J-168 L1 4 1 /2" 4" "D" L-80 BTCM 6107' 6835'/ 3229' 1 f X45 ' --Slottetl.-=-ne-Eer~nt slotted Lateral 1 J-168 L2 4 1/2 NA 12.6# L-80 IBTM 6807' 28'/28' 6835'/3300' Production Tubing tubin 7. Diverter System Information Requirements of 20 AAC 25.OO5(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, un/ess this requirement is waived by the commission under 20 AAC 25.035(h)(2),• A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of iJ-168L1. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 0~~~~ 1J-168L1 Producer Permit Page 4 of 6 Printed: March 31, 2005 • ~lication for Permit to Drill, Well 1J-168L1 Revision No.O March 31, 2005 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(S) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the dril/ing fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Pro erties Production Mud Type MI VersaPro Mineral Oil Base Density (ppg) 9.0 Funnel Viscosity (seconds) 60 Yield Point (cP) 18-28 Electric Stability 650-900 Chlorides (m /1) NA H NA API filtrate (cc / 30 min) <4 **HTHP filtrate (cc / 30 min) <10 Drilling fluid practices will be in accordance with regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Drill must be accompanied by e<3ch of the fol%wing items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratlgraphic test we/% a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel% a seismic ref,~adion or reflection ana/ysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (11) for a well dri/led from an offshore p/atfarm, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an ana/ysis ofseabed conditions as required by20 AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dri// must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (i2) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 1J-168L1 Producer Permit Page 5 of 6 Printed: March 31, 2005 ~~~v~ • ~lication for Permit to Drill, Well 1J-168L1 Revision No.0 March 31, 2005 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: The proposed drilling program for 1J-168L1 after the A-Sand has been completed is listed below: 1. Run and set Baker WindowMaster whipstock system, at window point of 7185' MD / 3310' TVD, the top of the "B" sand. 2. Mill 6 3/4" window. POOH. 3. Pick up drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of ~~B" sand lateral at 12952' MD / 3512' TVD, as per directional plan. 5. Back ream out of lateral to casing window. RIH to TD and change over to solids-free OBM. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool, POOH. 10. PU LEM, RIH and install same 11. POOH and prepare for drilling the °D" lateral. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Drill mustc be accompanied by e.~ach of the fol%wing items, except for an item already on file with the commission and identified In the app/ication: (i4) a general description of how the operator plans to dispose of dril/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1 J-168L 1 Producer Permit Page 6 of 6 Printed: March 31, 2005 ORIGINAL r~ ~-, -6000 -5500 -5000 -4500 -4000 -3500 West(-)/East(+) (1000 ftlin) -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 7000 M4LLIBURTON so...r a.xn~a.n~.• TD ~ 129528 MD, 3512ft TVD : 2370ft FNL & 2027ft FEL -Sec 27-T11N-R10E ~ .. - _, . - - - - - COI'1000Phillips 7000 6500 6500 1J-188 L1 Tce (v4) 1J-186 Lt T9 (v4) I `1J-168 L7 Fauk kKeraect 6000 - - LEGEND 6000 1J-188 L1 TB (v4) 35 ° Plan 1J-168 (L3), 1J-168, 1J-168 (wp08) 0 5500 1J-168 L1 (wp08) 5500 1J-166 u n (v4) 1J-168 Lt T6 (v4) , __ __ --__. 5000 . 36 , 5000 1J-168 L1 T5 (v4i Continue G_eoSteering in B-Lateral : 8082ft MD, 3336ft TVD 4500 - - - ~ _ - 4500 ~' Target Line - 8' TVD Below Top of BSand ' 4000 0 / 4000 ~ ~~ 1J-168 L1 T4 (v4) ' li Begin DIr ~ 4.0°/1008, 79628 MD, 33348 TVD 3500 - - - _ -_- 3500 3000 ~ 1J-168 L1 T3 (v4) ~ 3000 c 2500 0 0 60° 1J-166 L1 T2 (v4) Sail ~ 89.48°Inc & .54°Azi : 75628 MD, 3331 ft TVD_ -_. __- - - / 2500 + /, ~ , L 2000 0 360° 2000 Z ^ `Begin Dir LID 5.0°NOOR, 7227ft MD, 3316ft TVD L 1500 ~ 1500 1J-168 L1 T1 (v4) 5° _ - _. . Boltom of Whipstock : 7197ft MD, 331 N 1000 ~ _~ _ -_ -~ 1000 500 1 50° - -- --- Top of Wintlow : 7185ft MD, 3310ft TVD : 2431ft FSL 820188 FEL -Sec 34711 N-R10E _ - - 3 500 3~ /Q( T/K~T 0 p ~ ~ -500 -500 ~ `~; N -1000 -1000 -1500 -1500 -2000 -2000 -2500 ~ ~ ~ ~ ~ -2500 X0 00 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West(-)/East(+) (1000 ft/in) ORIGINAL 1000 Top of Window_ 7185ft MD, 3310ft ND : 2431ft FSL & 2018ft FEL -Sec 34-T11 N-R105 ~Qr~~Or 1 I~~~~ps Bottom of Whipstock : 7197ft MD, 3312ft ND, -500 i Begin Dir ~ 5.0°/100ft, 7227ft MD, 3316tt ND I / ~ Sail ~ 89.48°Inc 8 4.54°Azi : 7562ft MD, 3331 ft NDi 0 ~ / / Begin Dir ~ 4.0°I100ft, 7982ft MD, 3334ft ND~ i Continue GeoSteering in B-Lateral : 8082ft MD, 3336ft TVD 500 / ~ - ~ /Target Line - 8' TVD Below Top of B-Sand 1 1 C_ O O. O. L a 314" ~B-Sand ~- LEGEND Plan 1 J-168 (L3), 1 J-168, 1 J-168 (wp08) C 1J-168 L1 (wp08) TD ~ 12952ft MD, 3512ft ND : 2370ft FNL 82027(1 FEL -Sec 27-T11 N-R10F 1J-168 L1 Fault Intentect 11J-188 L1 T6 (v411 11J-168 L1 T81v411 1J-168 L1 T1 (v4) 1J-188 L7 T2 (v4) 1J-168 L1 T3 (v41 1J-166 L1 T4 (v4)l 1J-166 L1 T5 (v4)~ ~J-188 L1 T71v41 1J-188 Lt T9 (v4) 1J-188 L7 Toe (v4) 6000 NALLIBURTON 8psrry Drilling S~rviess -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Vertical Sedan at 0.00° (1000 ft/in) ' ~ ~- Halliburton Company COnoco Ph~llips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Cc-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-188 (L3) Survey Calculation Method: Wellbore: 1J-168 L1 Design: 1J-168 L1 {wp08) NALLIBURTON Sperry Drilling Ssrvices Wetl Plan 1J-188 (L3) 1J-188 (28+81) @ 109:OOft (Doyon 141 @ 28') 1 J-188 (28+81) @ 109.OOft (Doyon 141 @ 28') True Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-168 (L3) Well Position +N/-S 0.00 ft Northing: 6,946,663.00 ft Latitude: 70° 15' 43.641" N +E/-W 0.00 ft Easting: 668,712.00 ft Longitude: 149° 31' 31.338" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore 1J-188 L1 Magnetics Model Name Sample Date Declination Dip Angie Field Strength ' (°~ (°) (nT) BG GM2004 11 /24/2004 24.54 80.72 57, 579 Design 1J-188 L1 (wp08) Audit Notes: Version: Phase: PLAN Tie On Depth: 7,185.28 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction I 2s.oo o.oo o.oo o.oo i 3/30/2005 4:00:37PM Page 2 of 8 ~~0 4 ~ ~ h,F. .. - ~ . _ a _ COMPASS 2003.11 Build 48 Y ~ Halliburton Company ConocoPhillips Planning Report -Geographic Alaska :Database: EDM 2003.11 Single User Db < Local'Coordinate Reference: ,Company: ConocoPhillips Alaska (Kuparuk) TVD'Reference: Pro}ect: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1 J-168-(L3) Survey Cafcuiation Method: Wellbore: 1J-168 L1 Design: 1J-168 L1 (wp08) MALLIBURTQN Sperry Drilling Services Well Plan 1J-168 (L3) 1 J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') 1J-168 (28+g1) @ 109,OOft (Doyon 141 @ 28') True Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ff} (°/100ft) (°/100ft) (°/100ft) (°) 7,185.28 80.00 353.20 3,310.13 591.06 -4,799.90 0.00 0.00 0.00 0.00 7,197.28 81.91 353.20 3,312.02 602.83 -4,801.31 15.90 15.90 0.00 0.00 7,227.28 81.91 353.20 3,316.24 632.32 -4,804.82 0.00 0.00 0.00 0.00 7,370.68 88.85 355.00 3,327.79 774.40 -4,819.50 5.00 4.84 1.26 14.57 7,561.88 89.48 4.54 3,330.59 965.36 -4,820.26 5.00 0.33 4.99 86.32 7,962.38 89.48 4.54 3,334.25 1,364.59 -4,788.55 0.00 0.00 0.00 0.00 8,082.41 88.85 359.78 3,336.00 1,484.49 -4,784.03 4.00 -0.52 -3.97 -97.53 8,088.45 89.02 359.85 3,336.11 1,490.53 -4,784.05 3.00 2.79 1.10 21.60 9,132.73 89.02 359.85 3,354.00 2,534.64 -4,786.84 0.00 0.00 0.00 0.00 9,158.70 88.25 359.71 3,354.62 2,560.61 -4,786.95 3.00 -2.95 -0.54 -169.73 9,367.87 88.25 359.71 3,361.00 2,769.68 -4,788.01 0.00 0.00 0.00 0.00 9,383.16 87.90 360.00 3,361.51 2,784.96 -4,788.05 3.00 -2.31 1.91 140.50 10,132.48 87.90 360.00 3,389.00 3,533.78 -4,788.05 0.00 0.00 0.00 0.00 10,141.29 87.63 0.01 3,389.34 3,542.58 -4,788.05 3.00 -3.00 0.13 177.58 11,053.38 87.63 0.01 3,427.00 4,453.89 -4,787.88 0.00 0.00 0.00 0.00 11,062.44 87.59 359.74 3,427.38 4,462.94 -4,787.90 3.00 -0.53 -2.96 -100.21 12,196.49 87.59 359.74 3,475.15 5,595,97 -4,792.98 0.00 0.00 0.00 0.00 12,243.74 86.41 358.96 3,477.63 5,643.15 -4,793.51 3.00 -2.50 -1.67 -146.32 12,632.60 86.41 358.96 3,502.00 6,031.19 -4,800.59 0.00 0.00 0.00 0.00 12,706.87 89.32 358.40 3,504.77 6,105.37 -4,802.30 4.00 3.93 -0.75 -10.79 12,726.72 89.32 358.40 3,505.00 6,125.22 -4,802.85 0.00 0.00 0.00 0.00 12,801.53 88.00 356.59 3,506.75 6,199.93 -4,806.12 3.00 -1.77 -2.43 -126.10 12,952.30 88.00 356.59 3,512.00 6,350.34 -4,815.10 0.00 0.00 0.00 0.00 3/30/2005 4:00:37PM Page 3 of 8 ~~ COMPASS 2003.11 Build 48 ,~ i ConocoPhillips Alaska Database: EDM 2003:11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Weil: Plan 1J-168 (L3) Wellbore: 1J-188 L1 Design: 1J-168 L1 (wp08) Planned Survey 1J-168 L1 (wp08) Halliburton Company ~ HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Go-ordinate Reference: Well Plan 1J-t68 (L3) TVD Reference: 1J-188 (28+81) @ 109.OOft (Doyon 141 @ 28') MD Reference: 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') North Reference: True Survey Calculation Method: Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ftl (°I100ft) (ft) 7,185.28 80.00 353.20 3,310.13 3,201.13 591.06 -4,799.90 5,946,206.56 553,908.09 0.00 591.06 Top of Window : 7186ft MD, 33108 TVD : 24318 FSL 8: 2018ft FEL - Sec 34-T11 N -R10E - 7 6/8" Window Top 7,197.16 81.89 353.20 3,312.00 3,203.00 602.71 -4,801.29 5,946,218.20 553,906.61 15.90 602.71 7,197.28 81.91 353.20 3,312.02 3,203.02 602.83 -4,801.31 5,946,218.32 553,906.60 15.90 602.83 Bottom of Wh ipstock : 7197ft MD, 331 2k TVD I 7,200.00 81.91 353.20 3,312.40 3,203.40 605.50 -4,801.63 5,946,220.99 553,906.26 0.00 605.50 ', ' 7,227.28 81.91 353.20 3,316.24 3,207.24 632.32 -4,804.82 5,946,247.78 553,902.85 0.00 632.32 ', Bagin DIr ~ 6.0°I100ft, 7227ft MD, 331 68 TVD I 7,300.00 85.43 354.12 3,324.26 3,215.26 704.14 -4,812.80 5,946,319.53 553,894.31 5.00 704.14 ~~ 7,370.68 88.85 355.00 3,327.79 3,218.79 774.40 -4,819.50 5,946,389.73 553,887.08 5.00 774.40 7,400.00 88.94 356.46 3,328.35 3,219.35 803.64 -4,821.68 5,946,418.94 553,884.67 4.99 803.64 7,500.00 89.27 1.45 3,329.91 3,220.91 903.58 -4,823.49 5,946,518.86 553,882.07 5.00 903.58 7,561.88 89.48 4.54 3,330.59 3,221.59 965.36 -4,820.26 5,946,580.66 553,884.82 5.00 965.36 Sail ~ 89.48°I nc & 4.54°Azi : 7562ft MD, 3331 ft TVD 7,600.00 89.48 4.54 3,330.93 3,221.93 1,003.36 -4,817.24 5,946,618.67 553,887.54 0.00 1,003.36 ii 7,700.00 89.48 4.54 3,331.85 3,222.85 1,103.04 -4,809.33 5,946,718.41 553,894.65 0.00 1,103.04 7,800.00 89.48 4.54 3,332.76 3,223.76 1,202.72 -4,801.41 5,946,818.14 553,901.82 0.00 1,202.72 ~ 7,900.00 I 89.48 4.54 3,333.68 3,224.68 1,302.41 -4,793.49 5,946,917.87 553,908.96 0.00 1,302.41 I 7,962.38 89.48 4.54 3,334.25 3,225.25 1,364.59 -4,788.55 5,946,980.08 553,913.41 0.00 1,364.59 '~, Begin Dir ~ 4.0°/1008, 7962ft MD, 3334ft TVD 8,000.00 89.28 3.05 3,334.65 3,225.65 1,402.12 -4,786.07 5,947,017.63 553,915.61 4.00 1,402.12 8,082.41 88.85 359.78 3,336.00 3,227.00 1,484.49 -4,784.03 5,947,100.00 553,917.00 4.00 1,484.49 ~ Continue Geo-Steering in B-Lateral : 8082ft MD, 3336ft TVD -Target Line - 8' TVD Below Top of B-Sand -1J-168 L7 T7 (v4) ~ 8,088.45 89.02 359.85 3,336.11 3,227.11 1,490.53 -4,784.05 5,947,106.04 553,916.93 3.00 1,490.53 ~, 8,100.00 89.02 359.85 3,336.31 3,227.31 1,502.07 -4,784.08 5,947,117.58 553,916.81 0.00 1,502.07 8,200.00 89.02 359.85 3,338.02 3,229.02 1,602.06 -4,784.35 5,947,217.55 553,915.77 0.00 1,602.06 I 8,300.00 89.02 359.85 3,339.74 3,230.74 1,702.04 -4,784.62 5,947,317.52 553,914.72 0.00 1,702.04 8,400.00 89.02 359.85 3,341.45 3,232.45 1,802.03 -4,784.88 5,947,417.49 553,913.67 0.00 1,802.03 8,500.00 89.02 359.85 3,343.16 3,234.16 1,902.01 -4,785.15 5,947,517.46 553,912.62 0.00 1,902.01 ', 8,600.00 89.02 359.85 3,344.87 3,235.87 2,002.00 -4,785.42 5,947,617.43 553,911.58 0.00 2,002.00 8,700.00 89.02 359.85 3,346.59 3,237.59 2,101.98 -4,785.69 5,947,717.40 553,910.53 0.00 2,101.98 8,800.00 89.02 359.85 3,348.30 3,239.30 2,201.97 -4,785.95 5,947,817.37 553,909.48 0.00 2,201.97 8,900.00 89.02 359.85 3,350.01 3,241.01 2,301.95 -4,786.22 5,947,917.34 553,908.44 0.00 2,301.95 9,000.00 89.02 359.85 3,351.73 3,242.73 2,401.94 -4,786.49 5,948,017.31 553,907.39 0.00 2,401.94 9,100.00 89.02 359.85 3,353.44 3,244.44 2,501.92 -4,786.76 5,948,117.28 553,906.34 0.00 2,501.92 I 9,132.73 89.02 359.85 3,354.00 3,245.00 2,534.64 -4,786.84 5,948,150.00 553,906.00 0.00 2,534.64 1J-168 L7 T2 (vd) 9,158.70 88.25 359.71 3,354.62 3,245.62 2,560.61 -4,786.95 5,948,175.96 553,905.70 3.00 2,560.61 I 9,200.00 88.25 359.71 3,355.88 3,246.88 2,601.89 -4,787.16 5,948,217.24 553,905.16 0.00 2,601.89 ~I 9,300.00 88.25 359.71 3,358.93 3,249.93 2,701.84 -4,787.67 5,948,317.17 553,903.87 0.00 2,701.84 9,367.87 88.25 359.71 3,361.00 3,252.00 2,769.68 -4,788.01 5,948,385.00 553,903.00 0.00 2,769.68 ~', 1J-168 L1 T3 (v4) 9,383.16 87.90 360.00 3,361.51 3,252.51 2,784.96 -4,788.05 5,948,400.28 553,902.84 3.00 2,784.96 9,400.00 87.90 360.00 3,362.13 3,253.13 2,801.79 -4,788.05 5,948,417.10 553,902.71 0.00 2,801.79 9,500.00 87.90 360.00 3,365.80 3,256.80 2,901.72 -4,788.05 5,948,517.02 553,901.93 0.00 2,901.72 3/30/2005 4:00:3TPM Page 4 ofj/~{8 COMPASS 2003.118ui1d 48 + } ~ ~ _'~ a ^7°~'b ~ ~'. ~ BSc .mss ~ ~ / Halliburton Company 1-IALLIBURTON Conoco Phill~ps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003:11 Single UserDb :Local Co-ordinate Reference: Well Plan 1J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) TVD References 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference:, 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') Site: Kuparuk 1J Pad Narth Reference: .True Wefl: Plan 1J-468 (L3) Survey Calculation Msthod: Minimum Curvature Wellbore: 1J-168 L1 Design: 1J-168 L1 (wp08) Planned Survey 1J-16$ L1 (wp08) I Map Map I MD Inclination Azimuth TVD SSTVD +~/.$ +E!-W Northing Easting DLSEV Vert Section (ff) (°) (°) (ft) {$) (R) (ft) (ftl (ft) (°/100tt) (ff) 9,600.00 87.90 360.00 3,369.47 3,260.47 3,001.65 -4,788.05 5,948,616.94 553,901.15 0.00 3,001.65 9,700.00 87.90 360.00 3,373.14 3,264.14 3,101.59 -4,788.05 5,948,716.86 553,900.37 0.00 3,101.59 9,800.00 87.90 360.00 3,376.80 3,267.80 3,201.52 -4,788.05 5,948,816.78 553,899.59 0.00 3,201.52 9,900.00 87.90 360.00 3,380.47 3,271.47 3,301.45 -4,788.05 5,948,916.70 553,898.81 0.00 3,301.45 10,000.00 87.90 360.00 3,384.14 3,275.14 3,401.38 -4,788.05 5,949,016.62 553,898.03 0.00 3,401.38 10,100.00 87.90 360.00 3,387.81 3,278.81 3,501.32 -4,788.05 5,949,116.54 553,897.25 0.00 3,501.32 10,132.48 87.90 360.00 3,389.00 3,280.00 3,533.78 -4,788.05 5,949,149.00 553,897.00 0.00 3,533.78 1J-168 L7 T4(v4) 10,141.29 87.63 0.01 3,389.34 3,280.34 3,542.58 -4,788.05 5,949,157.80 553,896.93 3.00 3,542.58 !i 10,200.00 87.63 0.01 3,391.77 3,282.77 3,601.24 -4,788.04 5,949,216.45 553,896.49 0.00 3,601.24 it 10,300.00 87.63 0.01 3,395.90 3,286.90 3,701.15 -4,788.02 5,949,316.35 553,895.73 0.00 3,701.15 10,400.00 87.63 0.01 3,400.02 3,291.02 3,801.07 -4,788.00 5,949,416.26 553,894.97 0.00 3,801.07 10,500.00 87.63 0.01 3,404.15 3,295.15 3,900.98 -4,787.99 5,949,516.16 553,894.21 0.00 3,900.98 10,600.00 87.63 0.01 3,408.28 3,299.28 4,000.90 -4,787.97 5,949,616.06 553,893.45 0.00 4,000.90 10,700.00 87.63 0.01 3,412.41 3,303.41 4,100.81 -4,787.95 5,949,715.96 553,892.69 0.00 4,100.81 10,800.00 87.63 0.01 3,416.54 3,307.54 4,200.73 -4,787.93 5,949,815.87 553,891.93 0.00 4,200.73 I 10,900.00 87.63 0.01 3,420.67 3,311.67 4,300.64 -4,787.91 5,949,915.77 553,891.17 0.00 4,300.64 I 11,000.00 87.63 0.01 3,424.80 3,315.80 4,400.56 -4,787.89 5,950,015.67 553,890.41 0.00 4,400.56 i 11,053.38 87.63 0.01 3,427.00 3,318.00 4,453.89 -4,787.88 5,950,069.00 553,890.00 0.00 4,453.89 1J-168 L1 TS (v4) 11,062.44 87.59 359.74 3,427.38 3,318.38 4,462.94 -4,787.90 5,950,078.04 553,889.91 3.00 4,462.94 11,100.00 87.59 359.74 3,428.96 3,319.96 4,500.47 -4,788.07 5,950,115.57 553,889.45 0.00 4,500.47 11,200.00 87.59 359.74 3,433.17 3,324.17 4,600.38 -4,788.52 5,950,215.46 553,888.22 0.00 4,600.38 11,300.00 87.59 359.74 3,437.38 3,328.38 4,700.29 -4,788.96 5,950,315.36 553,887.00 0.00 4,700.29 11,400.00 87.59 359.74 3,441.60 3,332.60 4,800.20 -4,789.41 5,950,415.25 553,885.77 0.00 4,800.20 I 11,500.00 87.59 359.74 3,445.81 3,336.81 4,900.11 -4,789.86 5,950,515.15 553,884.54 0.00 4,900.11 11,600.00 87.59 359.74 3,450.02 3,341.02 5,000.02 -4,790.31 5,950,615.04 553,883.32 0.00 5,000.02 11,700.00 87.59 359.74 3,454.23 3,345.23 5,099.93 -4,790.75 5,950,714.93 553,882.09 0.00 5,099.93 ~ 11,800.00 87.59 359.74 3,458.45 3,349.45 5,199.84 -4,791.20 5,950,814.83 553,880.86 0.00 5,199.84 11,900.00 87.59 359.74 3,462.66 3,353.66 5,299.75 -4,791.65 5,950,914.72 553,879.64 0.00 5,299.75 12,000.00 87.59 359.74 3,466.87 3,357.87 5,399.66 -4,792.10 5,951,014.62 553,878.41 0.00 5,399.66 I~ 12,100.00 87.59 359.74 3,471.08 3,362.08 5,499.57 -4,792.54 5,951,114.51 553,877.18 0.00 5,499.57 12,169.20 87.59 359.74 3,474.00 3,365.00 5,568.71 -4,792.85 5,951,183.64 553,876.34 0.00 5,568.71 12,196.49 87.59 359.74 3,475.15 3,366.15 5,595.97 -4,792.98 5,951,210.89 553,876.00 0.00 5,595.97 Ali 1J-168 L1 T6 (v4) I 12,200.00 87.50 359.69 3,475.30 3,366.30 5,599.48 -4,792.99 5,951,214.40 553,875.96 2.96 5,599.48 ~', 12,243.74 86.41 358.96 3,477.63 3,368.63 5,643.15 -4,793.51 5,951,258.07 553,875.10 3.00 5,643.15 i 12,300.00 86.41 358.96 3,481.15 3,372.15 5,699.30 -4,794.54 5,951,314.19 553,873.64 0.00 5,699.30 12,400.00 86.41 358.96 3,487.42 3,378.42 5,799.08 -4,796.35 5,951,413.95 553,871.04 0.00 5,799.08 12,500.00 86.41 358.96 3,493.69 3,384.69 5,898.87 -4,798.17 5,951,513.71 553,868.44 0.00 5,898.87 12,536.88 86.41 358.96 3,496.00 3,387.00 5,935.67 -4,798.84 5,951,550.51 553,867.49 0.00 5,935.67 12,600.00 86.41 358.96 3,499.96 3,390.96 5,998.66 -4,799.99 5,951,613.47 553,865.85 0.00 5,998.66 ', 12,632.60 86.41 358.96 3,502.00 3,393.00 6,031.19 -4,800.59 5,951,646.00 553,865.00 0.00 6,031.19 1J-188 L1 T8 (v4) 12,700.00 89.05 358.45 3,504.67 3,395.67 6,098.51 -4,802.11 5,951,713.30 553,862.95 4.00 6,098.51 3/30/2005 4:00:37PM Page 5 of 8 COMPASS 2003.118ui1d 48 ~~~ ~i<,~ ' ~ • 1 - Halliburton Company [-1ALLIBURTON Conoco Phdlips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db LocaLCo-o~'dinate Reference: Well Plan 1J-168 (L3) Company: ConocoPhillipsAlaska (Kuparuk) TVD'Reference: 1J-168 (28+81) @ 109.o0ft{Doyon 141 @ 28') Project: Kuparuk River Unit MD Referenc®; 1J-168 (28+81j @ 109.OOft (Doyon 141 @ 28') Site: Kuparuk 1J$ad North Reference: True Well: Plan 1J-1`68{L3) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-188 L1 Design: 1J-168 L1 (wp08) Planned Survey 1J-168 L1 (wp08) Map Map MD Inclination Azimuth ND SSTVD +N/S }E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) lft- (ft) (ft)- (ft) Ift) {ft) (°I100ft) (ft) 12,706.87 89.32 358.40 3,504.77 3,395.77 6,105.37 -4,802.30 5,951,720.16 553,862.71 4.00 6,105.37 I 12,726.72 89.32 ~ 358.40 3,505.00 3,396.00 6,125.22 -4,802.85 5,951,740.00 553,862.00 0.00 6,125.22 ' 1J-168 L1 T9 (v4) 12,800.00 88.03 356.62 3,506.69 3,397.69 6,198.40 -4,806.03 5,951,813.15 553,858.25 3.00 6,198.40 12,801.53 88.00 356.59 3,506.75 3,397.75 6,199.93 -4,806.12 5,951,814.68 553,858.15 3.00 6,199.93 12,900.00 88.00 356.59 3,510.18 3,401.18 6,298.17 -4,811.99 5,951,912.85 553,851.52 0.00 6,298.17 12,952.30 88.00 r 356.59 3,512.00 ~ ' 3,403.00 6,350.34 -4,815.10 5,951,965.00 553,848.00 0.00 6,350.34 TD ~ 12952ft MD, 3512ft TVD : 2370ft FNL & 2027ft FEL -Sec 27-T11N-R10E - 4 1/2" -1J-168 L1 Toe (v4) 3/30/2005 4:00:37PM Page 8 of 8 COMPASS 2003.118ui1d 48 ~..,~ ~:..'~ .. v r r, b. 'e.,,,. 'u -. ~ i ' ~ ~ C ` Ph ll Halliburton Company HALLIBURTON onoco i ips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003:11 Single User: Db Local Ca-ordinate Reference: Well Plan 1 J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference:. 1J-168 (28+81) @ 109:OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference: 1 J-168 (28+81) ~ 109.OOft (Doyon 141 @ 28') Site: Kuparuk iJ Pad North Referenced True Well: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1J-168 L1 Design: 1J-168 L1 (wp08) Geologic Targets 1 J-168 L1 TVD Target Name +N!-S +EI-W Northing i Easting (ft) -Shape ft ft (ft) (ft) 3,468.00 1J-168 L1 T6 (v4) 5,596.08 -4,792.98 5,951,211.00 553,876.00 3,505.00 1J-168 L1 T9 (v4} 6,125.22 -4,802.85 5,951,740.00 553,862.00 3,336.00 1J-168 L7 T1 (v4) 1,484.49 -4,784.03 5,947,100.00 553,917.00 3,496.00 1J-168 L7 Fault Intersect 5,743.13 -4,797.83 5,951,358.00 553,870.00 3,474.00 1J-168 L1 T7 (v4) 5,746.11 -4,794.81 5,951,361.00 553,873.00 3,354.00 1J-168 L1 T2 (v4) 2,534.64 -4,786.84 5,948,150.00 553,906.00 3,512.00 1J-168 L1 Toe (v4) 6,350.34 -4,815.10 5,951,965.00 553,848.00 'i 3,361.00 1J-168 L1 T3 (v4) 2,769.68 -4,788.01 5,948,385.00 553,903.00 3,502.00 1J-168 L1 T8 (v4) 6,031.19 -4,800.59 5,951,646.00 553,865.00 3,427.00 1J-168 L1 TS (v4) 4,453.89 -4,787.88 5,950,069.00 553,890.00 ', 3,389.00 1J-168 L1 T4 (v4) 3,533.78 -4,788.05 5,949,149.00 553,897.00 3/30/2005 4:00:37PM Page 7 of 8 COMPASS 2003.11 Build 48 t i~~; ( ~' r~~ C Ph ll Halliburton Company ~ MALLIBURTQN onoco i ips Alaska Planning Report -Geographic Sperry Drilling Services Database: EDM 2003.11 Single User Db LocafCoordinate Reference: Well Plan°1J-168 (L3) Company: ConocoPhillipsAlaska (Kuparuk) TVD Reference:: 1 J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference:. 1 J-168 (28+81} ~0 109.OOft (Doyon 141 @ 28') Site: Kuparuk 1J Pad North ReferencB: True Well: Plan 1J-168. (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1J-168 L1 Design: 1J-168 L1 (wp08) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) _ (ftl ~..~ (..) 3,554.53 2,118.00 10-314 13-112 7,185.29 3,310.13 7-6/8 9-7/S 12,952.29 3,512.00 4-112 63/4 3/30/2005 4:00:37PM Page 8 of 8 COMPASS 2003.11 Build 48 ,~ L_..l ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-168 (L3) 1J-168 L1 1J-168 L1 (wp08) Anticollision Report 30 March, 2005 • HALLIBI~RT~N Sperry Drilling Services ORI61hA(. SURVEY PROGRAM Date: 2110.5-01JUTW°00:00 Validated: Yex Version: petNh From Depth To Suney/Plan Tool ~~ ~~ CB-CYRQ-SS NOU.110 716-5.28 MWD+tFR-AK-CAUSE. 71&5,28 12952.311 1J-168 LI (9ep01i) MWD+IFR-AK-CAUSC O V ~ ~/..~/y i~+~ ~~ 270 180 ConocoPhillips Alaska (KL Engineering West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder NoM Error Surface: Elliptical Conic Warning Method: Rules Based Travelling Cylinder Azimuth (TFO+AZI) I°I vs Centre to Centre Separation 1100 ft/in( ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 7185.28 To 12952.3 Maximum Range:5000 Reference: Plan: 1J-168 L1 (wp08) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-168 (L3), Tme Nonh VeAical (TVD) Reference: 1J-168 (28*81) ~ 109.OOft (Doyon 141 ~ 28~ Section NS) Reference: Slot - (0 OON, O.OOE) Measured Deplh Reference: 1J-166 (28+81) ~ 109.OOft (Doyon 141 LID 28~ WELL DETAILS: Plan 1J-168 (L3) Ground Level. 81.00 Slot +NI-S +EI-W Northing Easting Latittude Longitude 0.00 O.1S945653.00 558712.0070°15'43.641!!19°31'31.336W 90 From Colour To MO 0 100 100 200 200 300 300 550 550 800 800 1050 1050 ~--------~-- 1550 1550 2050 2050 2550 2550 ~-~-_----- --~- 3050 3050 3550 3550 5050 5050 - ~ 6550 6550 ------ ~- 8050 8050 9550 95r~0 11050 11050 - 12550 12550 13000 LEGEND --~-- tE~112, tE-112.1E-112 V1 ---#-- tE-112. tE-112L1, tE-112L1 V0 -~~-~ tE~t t2. tE-112L2. 1E~112L3 V1 $- tE~126. tE-126.1E-126 Vt -jF- tE~128. tE~126Lt.tE-128L1 V1 --~- 1E-126.1E-126L2,tE-128L2 V1 ---{-- 1E35. IE-35. tE-35V1 ---~- 1E35. tEJ5A. tE-3Si (wp02)VO .-.~.- 1J-10.1}10. 1J-10VI ~- %an 1J-111(M12). Pbn t}M12lat A.Pbn 1J-M12letA VO -~-- plan lJ-115 (L91, Pbn 11L9 Let A. Pbn 11L9 LetA VO ~_ Pbn t}1161L10), Ran 1J{10 Let A,Pbn IJ{tOlatA VO ~~- Plan 11120(L111.Pbn 1J{11 Let A.Pbn 1J111 Le1AV0 --~- Plen 1J-122(L12). %an lJ-L12 Let A.Pbn iJ{12 LalAVO 1 Pbn 1}124(Lt3). %an 1J~L13 Lal A. %en lJ{13 LatA VO Plan 1}121 (Lb). Pbn 1J-LB IaN. PYn 1J-Le LaU V0 -.~ Plen t}129101JI~Pbn 1J-0138LaL pbn lJ-013alat VO ~~ Plan 11156 (M97.Pbn 1J-Md ALet.Pbn 11M4A Lat VO Pbn 1J-15] (G-KUD). 1 J-C (KUP). 1JL (KUPI Ve9W.A Vd Pbn 1J-156 (M31. 11M3 A la[enI.1J#13 A Late9al Versf2! -..~-~ Pbn 1J-159 (M]). 1}159. 1}159 (wp03)VO ~- Pbn 1J-159(M>).1J-159L1.1J.159L1 (wp03)V0 -$- %an 1J-159 (MII. 1J-159 L2. 1J-15912 (wp031 V0 %an tJ-160 (M2). Pbn 1}M2 Let A, Pbn 1J-M2 Lat A VD _~ Plan 1J-162(Mtl.1J-162, tJ-163 (wp03.1 NOM Nea0 V0 ~~ Pbn l}162 /Mt).11162 L1.11162 L1 (wp3.11 V0 - PIen 1J-1621M11.11182 L2.1}162 L2 (wp3.1)VO Plan iJ-169 (Lel, 1J-169, 1J{fi A Let (wp03) V0 ...~- %an 11160 (L6). 1J-169 L1. 1J-164 L1 (wp03)VO -~- Plan 1J-184 (L6), 1J-169 L2, 1J-169 L21wp03)VD -$-- Pbn 11166 (L51,1}166,1}168 (wp031 VO _.Q Pbn 11166 (L51. iJ-166Lt, 1J-168 L1 (wpt13)VO __~'- Pbn 1J-166 (LS).1J~186 L2. 1J-186 L2 (wp03)VO _f-)'- %en 1y110 (LU, Pbn ilL9 La1A.Pbn ll{9laU VO $- Pbn 111]9 (O11.Pbn tJ-01 Blat.Pbn lJ-0t Blot VO %en 1J-175 (A-KUp),1}A (KUP). 1J-A IKUP) Var/OA V3 -~ Pbn 111]6 (p2), Plan 1J-02Bbt, WnlJ-02Blat VO "'~- Pbn 11116(03). Plan 1J-03BLat.Pbn 1J-D3B rat vo - Pbn 1J-1]9(&KUpl. 1}9 O<UP), 1J-B (KUPI Veri0.A V6 -~- Pbn 11160 (G9).Pbn iJ-0aelat.Pbn iJ-096 L.tvo ~~ WSP-03. W6P~03. WSP-03V1 $- WSP-04, W6P-09. WSP-01 V1 $- WSP-0S. WSPJ>S.WSP-05 VI _~- W6P-06. W6P-Ofi, W6P-OB VI WSP-0], W6P-0].WSP-01 V1 -~ WSP-08, W6P-OB.WSP-0B V1 ~-- WSP-20, W6P-20. WSP-ZO V1 $- 11166 L11wp06) 0 180 Travelling Cylinder Azimuth (TFO+AZp I°I vs Centre [o Centre Separation 140 fifinl • SECTION DETAILS Sec MD 1 7185.28 2 7197.28 3 7227.28 4 7370.68 5 7561.88 8 7962.38 7 8082 41 8 8088.45 9 9132.73 10 9158.70 11 9367.87 12 9383.16 13 10132.48 14 10141.29 15 11053.38 16 11062 44 17 12196.49 18 12243.74 19 12632 60 20 12706.87 21 12726.72 22 12801.53 23 12952.30 Inc Azi ND +N/-S +E/-W 80.00 353.20 3310.13 591.06 -4799.90 81.91 353.20 3312.02 602.83 -4801.31 81.91 353.20 3316.24 632.32 -4804.82 88.85 355.00 3327 79 774.40 -4819.50 89.48 4.54 3330.59 965.36 -4620.26 89.48 4.54 3334.25 1364.59 -4788.55 88.85 359.78 3338.00 1484.49 -4784.03 89.02 359.85 3336.11 1490.53 -4784.05 89.02 359.85 3354.00 2534.64 -4786.84 88.25 359.71 3354.62 2560.61 -4786.95 88.25 359.71 3361.00 2769.68 -4788.01 87 90 360.00 3361.51 2784.96 -4788.05 87.63 0.001 338934 354258 -4788.05 87 63 0.01 3427.00 4453.89 -4787.88 87.59 359.74 3427.38 4462.94 -4787.90 87.59 359.74 3475.15 5595.97 -4792.98 86 41 358.96 3477.63 5643.15 -4793.51 86.41 358.96 3502.00 6031.19 -4800.59 89.32 358.40 3504.77 6105.37 -4802 30 89.32 358.40 3505 00 6125.22 -4802 85 88.00 358.59 3506.75 6199.93 -4806.12 88 00 356.59 3512.00 6350.34 -4815.10 DLeg TFace VSec Target 0.00 0.00 591.06 15.90 0.00 602.83 0.00 0.00 632.32 5.60 14.57 774.40 5.00 86.32 965.36 0.00 0.00 1364.59 4.00 -97.53 1484.49 1J-188 Lt Tt (v4) 3.00 21.60 1490.53 0.00 0.00 2534.64 1J-168 L1 T2 (v4) 3.00 -189.73 2560.61 0.00 0.00 2769.68 1J-168 Lt T3 (v4) 3.00 140.50 2784.96 0.00 0.00 3533.78 1J-168 L7 T4 (v4) 3.00 177.58 3542.58 0.00 000 4453.89 1J-168 L1 TS (v4) 3.00 -100.21 4462.94 0.00 0.00 5595 97 1 J-168 Lt T6 (v4) 3.00 -146.32 5643.15 0.00 0.00 6031.19 1J-168 L1 TB (v4) 4 00 -10 79 6105.37 0.00 0 00 6125.22 1J-168 Lt T9 (v4) 3.00 -126.10 6199.93 0.00 0.00 6350 34 1J-166 Lt Toe (v4) ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk)` Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-168 (L3) Well Error. O.OOft Reference Wellbore 1J=168 L1 Reference Design: 1J-168 L1 (wp08) Halliburton Company Anticollision Report Loca6Co-ordinate Reference: TW Reference; MD Reference::. North Reference: Survey Calculation Method: Output errors-are at Database: Offset ND Reference: • HALLIBURTON Sperry Drilling Services WeIF Plan 1J-168 (L3) 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') 1J-168.(28+81 )'@ 109:OOft (Doyon 141 @ 28') True Minimum Curvature 1:96 sigma' EDM 2003.11 Single User Db Offset Datum sReference 1J-168 L1 (wp08) Filtertype: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 7,185.28 to 12,952.30ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 5,000.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3/3012005 From To (ft) (ft) Survey (Wellbore) Tool Name Descripti on I 28.00 800.00 1J-168 (wp08) (1J-168) CB-GYRO-SS Camera based gyro single shot 800.00 7,185.28 1J-168 (wp08) (1J-168) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,185.28 12,952.30 1J-168 L1 (wp08) (1J-168 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference :Offset. Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore -Design {ft) (ft) (ft) (ft) Kuparuk 1 E Pad 1E-35-1E-35-1E-35 12,887.34 10,625.00 2,178.98 155.98 2,023.00 Pass-Major Risk 1 E-35 - 1 E-35A - 1 E-35A (wp02) 12,893.14 10,499.96 1,468.24 146.23 1,322.01 Pass -Major Risk Kuparuk 1J Pad 1J-10-1J-10-1J-10 9,102.95 6,900.00 710.65 111.06 599.60 Pass-Major Risk Plan 1J-111 (M12) -Plan 1J-M12 Lat A -Plan 1J-M12 Out of range Plan 1 J-115 (L9) -Plan 1J-L9 Lat A -Plan 1 J-L9 Lat A Out of range Plan 1 J-118 (L10) -Plan 1 J-L10 Lat A -Plan 1 J-L10 Out of range Plan 1 J-120 (L11) -Plan 1J-L11 Lat A -Plan 1 J-L11 Out of range Plan 1J-122 (L12) -Plan 1J-L12 Lat A -Plan 1J-L12 Out of range Plan 1 J-124 (L13) -Plan 1 J-L13 Lat A -Plan 1 J-L13 Out of range Plan 1 J-127 (LS) -Plan 1J-L8 LatA -Plan 1 J-L8 LatA Out of range Plan 1J-157 (C-Kup) - 1J-C (KUP) - 1J-C (KUP) Ver# 10,341.24 10,849.03 3,024.12 116.92 2,907.20 Pass-Major Risk Plan 1J-164 (L6) - 1 J-164 - 1 J-L6 A Lat (wp03) 12,726.55 8,775.00 4,239.32 224.38 4,014.94 Pass -Major Risk Plan 1 J-164 (L6) - 1 J-164 L1 - 1 J-164 L1 (wp03) 12,706.87 8,725.00 4,232.97 207.86 4,025.10 Pass -Major Rlsk Plan 1 J-164 (L6) - 1 J-164 L2 - 1 J-164 L2 (wp03) 12,706.87 8,725.00 4,232.94 210.09 4,022.84 Pass -Major Risk Plan 1 J-166 (LS) - 1 J-166 - 1 J-166 (wp03) 12,460.08 9,350.00 2,935.06 215.92 2,719.15 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 L1 - 1J-166 L1 (wp03) 12,436.93 9,325.00 2,927.38 201.94 2,725.44 Pass -Major Risk Plan 1 J-166 (LS) - 1J-166 L2 - 1 J-166 L2 (wp03) 12,230.03 9,099.96 2,921.57 199.45 2,722.12 Pass -Major Risk Plan 1J-170 (L4) -Plan 1J-L4 LatA-Plan 1J-L4 LatA 12,758.52 12,081.58 1,457.76 240.84 1,216.92 Pass- Major Risk Plan 1J-175 (A-Kup) - 1J-A (KUP) - 1J-A (KUP) Ver# Out of range Plan 1J-179 (B-Kup) - 1J-B (KUP) - 1J-B (KUP) Ver# 7,299.97 13,399.95 2,911.72 121.15 2,790.57 Pass-Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/30/2005 3:13:10PM Page 2 of 56 COMPASS 2003.11 Build 48 • ~-168L1 Drillinc ~J za rd 6 3/4" Open Hole /4 1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, Shut-in drills, Increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD Tools, Hole 0 ever, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo , LCM Hole Swabbing on Trips Low Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1J-168L1 Drilling Hazards Summary prepared by Shane Cloninger {(/~~j! ~.nn~ ~ 6 ~ 4/5/2005 1 >:04 AM Tubing $trin9~ 4-112" Iing ', l 89 0 ODl SPeC• Clearance Coup w• s~ BakerBaker Oil Enu ,.... L_ tera ~ n Isolation Dre~r Wi h Pius Laterallsolation Installed Drift) Diverter tgre Lateral Access talled _ (2.50- ID Maa, Ins (3.00" Lateral Orift) GS Running TOOT StmB .Gg• Profile for lRetrievvn9 \ tor Runnin9 I Snap InISnaP Ou< -' coil Connec 00' Len91h) dng f Positiv~~00a 1 (1. '~ ssare Valve rBack Pre (1.60' Length) Lateral lsolation i SDK 1 / Fbw-Thru Swivel (1.25' Len9M1 Lateral Diverter I ,~ Ramp ~ i lwre i HYdraukc ~DisconneOt d`I n pnl Ma Isola< DiveM1er Sleeve '~ ti°n' ~ ~ (1.50• Len9 ' Laterel lsola I GS Spear r (1.50' Length) Seals 18.5' Sleeve LemJth RfKftP'~mx. OAL' 18.5' Diverter LemJth ~a-ulaN deviated (21 Gas Lift Mandrels, 4-112" X 1" bme~ible Pump, centralift 418 HP Motor, 10-314" Casing, L-80, BTC set @ +I- 3555' MD, 2118' ND, 13-112" hole 5-112" X 7-518" - Electric S L Deployed Pump l,.a Fcsooow rpr Sand p-sand WinMp 3229' ND at +I- 8835' 4-112" 12.6#, L"80• Slotted Liner \ 6-314" Lateral TD \~ ,_ ~~ 12942' MD, 3453' TVD 0 '~ 7b18" ZXP 5-112" X ker -e Pac Liner TOP with Hold Downs (~w~~) V LEM l '~ e Modu teral E ~ ° L a Ass mbl !v°~ . g 7.518" ZXP Liner 7oP s ' _r`~„n _ _ - 5-112 with Hold Down Packer ' Casing Sealbore RecePreOle " ID 4.75 Swivel, 4-112" ~-- Tubin9 _~__ Orienting Profile ment of LEM _ Automatic Align e Latching G°Ilet i v posit dicates Collect Location In Seal Bore for Lateral - 3.68" ID Isolation __ Access Ydindow e Lateral Access Via i v Posit .mru-Tubin9 Diverter Seal Bore for Lateral 68" ID 3 . Isolation - - Seal AsemblY Isolation aI ID 75" Seal OD 3.875' Se 4. i~ 'Jars may ce.c~ations l5' aPOpxw ° O 5 r.~ V or deep aPP' g-sand Window `f \./Br Sand Lateral at+1-7185' MD, 3310' TVD 1 • 12.6#. L-S0, Slotted Liner albore a-112' g-314" Lateral TD casing le 3512' T/D Fecep _ 12952' MD, 4-112" ~ 7.518'^^nPr ~ / nocophillips Co West Sak ~ J_168 produCeetion 7_518rr Tri-Lateral Comp 3.562" DB NlPple • Ensure LEM ~ifion #~ is used 12 6#. Tubin9•'I" wl seal from LEM to A2 Ll stem and 3.562" DB 5-112" X T-518" ZXP /v Liner Top Packer / with Hold Downs 5-112" X 7-518" Flex Lock er I Packer Liner Hanger Liner Hang Assembly 3323aT~D +I- 7261' MD, ansm~r m a amemee,mwoo,e ~~m w^~'" ye ane ~~~ a a. Ko.e~m~ ev am m,oM~~,M. mm m~M rW'MtxoDYin9~' hom Baker Baker W,9kH ~ e~ ionic o mec~anlul~'~ n'venteA, vn'tlaut vrtiMn P°n^iaa EQmanY~ tYa,em rrow kM'an or Mrea .Ar and Lateral Undulatin 4-112" 12 ~~ L$0, slots over sand, blank over shales, constrictors for isolation Casing, 7-518" 29.7#, L-80, gTCM, Set @ +I- 8306' MD, 3483' TVD, Set @ 80 deg, g-718" Hole. i m n ecification E , HDDK Hanger 4-112" X 7-518' Mainbore Drift: 5.3Y' Mainbore Drift, with diveRer: 4.63" no diveRer or LEM: 3.88 wl diverter, no LEM: 3.88" Lateral Drift, 6,75" Lateral Drift' piverter OD: LaterallMainbore Module 4-112" Lateral Entry 3,65" Mainbore Dri e:. 2 50" Mainbore DritL wl isolation slee Lateral Drift` wl toil diveRer: {i 3'85„ OD of Diverter and Slee h• «I-18.5' piverter and Sleeve Len9 - 8-314" Lateral TD 12975' MD, 3658' TvD' 1J-168 Tri-lateral producer t i 1E-28 l tE-31 -ag 1L-28 tE-38 ~~ i 1L-za4 I1 1L-zIDPN ~ f ~ 10-1 32 ~ ~ ,.,i, 1 -22 4~io-tz~,-~' 1D-131 10-12' ' • 1D-1sa ~ ~ ~ , to ~a I ~ 1D-0 D-08 nm~-nam.~ ' KRU 1 J-168L1 2 tE-tOSP81 2s ~, Proposed 1-Oil _ ,. ~~~~, West Sak "B" Sand ,E-74 '~-' 2050610 ~~_>'~~ IJ-168 Slotted Liner ~ ~ confidential wells are red /13/2005 12000 SFD 4 • 4tooa , ,, ioooo 34 ~ 35 f`~, ~ 7 p~ 00 ~ E-, ~ 7L! ro~° a O _ "75P-3 V `~~q N '1' rJ ~~ - I t ~ Pv~ 2 ASP-13 (~ ViSP-14 1D-38 I /// X T11 N, R10E, UM ~~ ~~-~ 1E-J2 T10N, R11 E, UM .y 1J-OJ Feet 0 1 ,~~'?,~~ 2,000 3,000 4,000 1J-154L1 • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER / WELL NAME ~~GL ~~! ~~~~-- l PTD# ~-C' ~ -~~ / CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well %~'~ I•J ' /~~ Permit No, API No. 5 y v Z`~"Z~ ~ ` (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 HOLE In accordance with 20 AAC 25.005(f), all (PIT) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). 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. U --~ Rev: 04/01/05 C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pcol KUPARUK RIVER, WEST SAKOlL-490150 - -Well Name: KUPARUK RIV U WSAK 1J•168L1 Program DEV Well bore seg ~ PTD#:2050610 Company CONOCOPHILLIPS ALASKA INC ~_ Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached- . - . _ _ - - _ _ - _ NA_ West Sak B Sand multilater_al_ well segment; fee waived per 20 AAC 25.005(e), 2 Lease number appropriate________-______________________ _________ Yes____-_ Top_productiveinterval and TD-inADl, 02.5660.------_-.-_____--_-.-.----__--__--_- 3 Uni_quewell_nameandnumber_ - ----------- -- ---- - -- -- Yes------ - - --- ------ -- ----- ------ -- ------- - ---------------------- 4 Well located in a-defined-pool- Yes KRU West_Sak Oil Pool, oyerned_b Conservation-Order No, 406B- 9 ~` - 5 Well located proper diskance from drilling unit_boundary- - -- - - --- - - - - - - -- - - - - Yes Well is mote-than_500 feet from an external property line. _ _ - _ - _ - - 6 Well located proper diskancefrom_otherwells---_--_____________ _________ Yes_-__-- -No[estrictionsas_to well spacing in CQ4066.___-__-_--__--______-__-___-___--_----- 7 Sufficient acreage_available in-drilling unit _ _ - _ ... _ - ... Yes - - - - No restrictions as_to well spacing except that no_p_ay shall be opened in a well closer 8 If deviated,is_wellboreplat-included-_____________ Yes _than500feetto_anexternal_propertyline._____________-_____--------__-__--__--__ 9 Operator only affected party_-----_-___-__________ Yes_--__ 10 Operatoihas-appropriate.bondinfQrce------------ -_.. - --- --- -- - Yes------ -- -- ---------- --- -- ------ - ~ - _.... ------------ ----- 11 Permit can be issued without conservation order Yes Appr Date 12 Permit_c_anbeissuedwithoutadministrative_approval________________ _________ Yes______ _____-__-______-___-__-____- - - -- -- - SFD 4/1212005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauthorfzedbylnjectionOrder-#(put1O#in-comments)_(For_ NA______ _____________________________________________________________________ 15 Allwellswithin114_mileateaofreyiewidentified(Forservicewellonly)__.._, _-„-__-_ NA_______ ___________________________________ 16 Pre-produced injector durakion_of pre production Less than 3 months. (For service well only) NA_ X 17 ACMP-Finding of Gonsistency_hasbeenissued_for-this project___________ _________ NA--_--__ ._---_--__--,_---_._ Engineering II 18 Conductorstring_pr4vided__---_---_______-_____ _____-- NA--_--_- .Conduetorset_inMotherbore1J-16$(2015-060)____________________________._ - -_- ~ 19 Surface ca&ingprQtectsallknown USDWs______________________ ___-__-- NA____-_ Allaqui_fersex_empted,40CFR_147.102_(b)(3).--__--__.__.---..--..-..-..-..--......-_ 20 CMT_v_ol_adequate-tocirculate_on conductor_&su_rf_csg_------------- --------- N_A_______ Surface casing set in_1J-1.68._________________-_______________-_______- 21 CMT_v_ol_adeguake-io tie-in long string tosurfcsg_ _ _ . - _ - _ _ NA_ Pr_oduction_casing se_tin_1J-168._All_hydrocarbon formations planned to-be_coyered. - _ - - _ _ - _ - - - 22 CMT-will coverall know_n_productiye horizons- _ _ _ No- - _ _ - _ -Slotted IinercomAletionplanned.- - . _ _ - _ _ _ _ _ , - _ ------------------------------- 23 Casing designs adequate for C,T,B&_permafrost__________________ __ ______ Yes______ ______________-__-__- ____---__.-__.-_---_-___---.----_---_--__-.,-- 24 Adequate tan_kage_o_r reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , - - _ _ - - Yes - - - - - _ .Rig is-equipped with steel_pits.. No reserve_pitplanned, All waste to an approved annlus_or disposal well.- - - - - 25 If_a_re-drill, has_a_ 1.0-403 for abandonment been approved _ : - - _ - . - NA- _ _ _ _ : _ . _ _ . ----------------------------------------------------------------- 26 Adequate wellbore separation-proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -------- _ _ _ ------ Yes - _ - - _ - -Proximity analyisperformed. Traveling_cylinderplotprovtded, Nearest wellbo[e-is A lateral -150' tyd below , _ _ , 27 Ifdiverterrequired,doesitmeetregulations_________________--.. --......- NA___-___ BOPstack_willalready_beinplace,__________________________________ Appr Date 28 Drilling fluid program schematic-& equip list adequate- - .. Yes - - - - - . .Maximum expected formation pressure 9,0_EMW._ Planned MW up to 9.0 in WS. TEM 4/1412005 29 B_OPES, do they rneetregulation - - - - - - - - Yes - - - - - - - - - - - - - ~4~.J` 30 BOPE.press rating appropriate; test to,(put prig in comments)- - Yes - _ _ _ _ _ - MASP calculated at 1134 psi, 3000-psi_appropriate. CPAI normally_tests_to 5000_psi.. - !(~• 31 Choke_manifoldcompliesw/API_RP-53(May84)___________________ _________ Yes______ ___-__- 32 Work willoccu[withoutoperationshutdown--___________________ ________ Yes______ _______-_______________________---________--__.__.-_-_____-_.----_ 33 Is presence-of H2S gas-probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ - NQ production_on_pad, but H2$has not been reported in WS production. -Rig has sensors-and alarms- _ - _ - _ _ _ 34 Mechanical condition of wells within AOR verified (Forservice well only) _ _ _ N_A_ _ - - -- - - - - - - - - - - - - - - Geology 35 Permiteanbeissuedwlohydrogen_sulfidemeasures________________ ___ _____ Yes______ _____________-________ - -- -- 36 Data_presented on potential overpressure zones- _ - . _ - - .. - Yes _ _ - _ _ - -Expected reservoirpressure is 8,6-• 9,0_ppg EMW; wiltbe drilled with 9.3ppg mud. Appr Date 37 Seismic.analysis-of shallow gaszones - - - - - - - - - - ~ - - - - - - - - - - - - - - - SFD 4H 212005 38 Seabed condition suryey_(if Off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - -- -- -- --- ----- - - - - 39 _Contactna_m_elphone-fgrweekly progress-reports[exploratoryonly]________ _________ NA-__-__- -_--__.____,___-__-__--_____--__-___-___-_ Geologic Engineering I' Commissioner: Date: Commissioner: Date om toner Date d~~ ~I ~~~ ~~ 4~15~ ~-~ /~ 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 History fife and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 25 11:23:00 2006 Reel Header Service name .............LISTPE Date .....................06/01/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/01/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: MW0003877631 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M. THORTON MWD RUN 7 JOB NUMBER: MW0003877631 LOGGING ENGINEER: P. ORTH pPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD i3 ~44-- ao5-o~• Scientific Technical Services Scientific Technical Services 1J-168 L1 500292326060 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-JAN-06 MWD RUN 4 MWD RUN 5 MW0003877631 MW0003877631 T. GALVIN P. ORTH M. THORTON D. GLADDEN MWD RUN 8 MW0003877631 P. ORTH D. GLADDEN 35 11N l0E 1841 2499 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3693.0 2ND STRING 6.750 7.875 7145.0 3RD STRING PRODUCTION STRING REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 7145'MD/3294'TVD WITHIN THE RUN 5 INTERVAL OF THE 1J-168 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,8 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) THE WHIPSTOCK WAS POSITIONED DURING MWD RUN 7, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 3-5,7,8 REPRESENT WELL 1J-168 L1 WITH API#:50-029-23260-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12967'MD / 3480'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPM 3662.0 12916 .5 RPX 3662.0 12916 .5 FET 3662.0 12916 .5 RPD 3662.0 12916 .5 RPS 3662.0 12916 .5 GR 3670.0 12909 .5 ROP 3704.5 12967 .0 • • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3662.0 4 5642.0 5 6205.0 7 7145.5 8 7187.0 REMARKS: MERGED MAIN PASS. MERGE BASE 5642.0 6205.0 7145.0 7187.0 12967.0 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 12967 8314.5 18611 3662 12967 RPD MWD OHMM 0.19 2000 82.5553 18510 3662 12916.5 RPM MWD OHMM 0.17 2000 90.1724 18510 3662 12916.5 RPS MWD OHMM 0.19 2000 69.0077 18510 3662 12916.5 RPX MWD OHMM 0.08 2000 99.2836 18510 3662 12916.5 FET MWD HOUR 0.12 219.92 2.33464 18510 3662 12916.5 GR MWD API 24.54 118.68 63.5132 18480 3670 12909.5 ROP MWD FT/H 0.1 679.83 156.648 18526 3704.5 12967 First Reading For Entire File..........3662 Last Reading For Entire File...........12967 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 • • Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB .001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3662.0 5600.0 FET 3662.0 5600.0 RPS 3662.0 5600.0 RPX 3662.0 5600.0 RPM 3662.0 5600.0 GR 3670.0 5607.5 ROP 3704.5 5642.0 LOG HEADER DATA DATE LOGGED: 20-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) 5642.0 TOP LOG INTERVAL (FT) 3704.0 BOTTOM LOG INTERVAL (FT) 5642.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.5 MAXIMUM ANGLE: 71.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG . RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE:. LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 52.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.910 91.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ..... ... ......Undefined Frame Spacing .. .......... ... ......60 .lIN Max frames per record .... ... ......Undefined Absent value ... .......... ... ......-999 Depth Units .... .......... ... ...... Datum Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 5642 4652 3961 3662 5642 RPD MWD030 OHMM 0.94 2000 41.1991 3877 3662 5600 RPM MWD030 OHMM 3.28 1809.23 18.3042 3877 3662 5600 RPS MWD030 OHMM 5.7 1112.47 14.3103 3877 3662 5600 RPX MWD030 OHMM 0.48 40.61 13.3675 3877 3662 5600 FET MWD030 HOUR 0.12 59.83 1.7642 3877 3662 5600 GR MWD030 API 24.54 118.68 65.9548 3876 3670 5607.5 ROP MWD030 FT/H 1.46 679.83 195.606 3876 3704.5 5642 First Reading For Entire File..........3662 Last Reading For Entire File...........5642 File Trailer Service name ............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .06/01/25 Maximum Physical Record. .65535 File Type ............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...:.......1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5600.5 6159.5 RPD 5600.5 6159.5 RPS 5600.5 6159.5 RPX 5600.5 6159.5 RPM 5600.5 6159.5 GR 5608.0 6167.5 ROP 5642.5 6205.0 • LOG HEADER DATA DATE LOGGED: 23-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6205.0 TOP LOG INTERVAL (FT) 5642.0 BOTTOM LOG INTERVAL (FT) 6205.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.4 MAXIMUM ANGLE: 70.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA R AY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 57.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.310 79.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .DOwn Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-typ e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 5600.5 6205 5902.75 1210 5600.5 RPD MWD040 OHMM 9.51 1 9.25 14.1124 1119 5600.5 Last Reading 6205 6159.5 • RPM MWD040 OHMM 8.72 20.31 13.8028 1119 5600.5 6159.5 RPS MWD040 OHMM 7.97 20.93 13.6461 1119 5600.5 6159.5 RPX MWD040 OHMM 7.67 20.72 13.4856 1119 5600.5 6159.5 FET MWD040 HOUR 0.19 60.1 5.1829 1119 5600.5 6159.5 GR MWD040 API 28.83 103.96 65.2015 1120 5608 6167.5 ROP MWD040 FT/H 11.54 552.69 145.563 1126 5642.5 6205 First Reading For Entire File..........5600.5 Last Reading For Entire File...........6205 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6160.0 7145.0 FET 6160.0 7145.0 RPX 6160.0 7145.0 RPD 6160.0 7145.0 RPM 6160.0 7145.0 GR 6168.0 7145.0 ROP 6205.5 7145.0 LOG HEADER DATA DATE LOGGED: 24-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7145.0 TOP LOG INTERVAL (FT) 6205.0 BOTTOM LOG INTERVAL (FT) 7145.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.8 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 • ~ BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERA TURE (MT) 3.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.560 109.4 MUD FILTRATE AT MT: 4.650 70.0 MUD CAKE AT MT: 3.150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6160 7145 6652.5 1971 6160 7145 RPD MWDO50 OHMM 7.23 179.22 29.2711 1971 6160 7145 RPM MWDO50 OHMM 6.86 217.08 27.772 1971 6160 7145 RPS MWDO50 OHMM 6.41 190.44 25.4391 1971 6160 7145 RPX MWDO50 OHMM 6.04 131.81 21.815 1971 6160 7145 FET MWDO50 HOUR 0.24 13.37 1.34075 1971 6160 7145 GR MWDO50 API 25.85 107.52 74.8029 1955 6168 7145 ROP MWDO50 FT/H 5.04 554.65 152.201 1880 6205.5 7145 First Reading For Entire File..........6160 Last Reading For Entire File...........7145 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 • Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7145.5 7187.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .Undefined O1-SEP-OS Insite 66.37 Memory 7187.0 7145.0 7187.0 .0 80.0 TOOL NUMBER 6.150 7145.0 Oil Based 9.00 82.0 .0 42000 3.0 .000 .0 .000 100.0 .000 .0 .000 .0 • Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Name Service Unit Min Max DEPT FT 7145.5 7187 ROP MWD070 FT/H 0.1 67.13 First Last Mean Nsam Reading Reading 7166.25 84 7145.5 7187 25.4699 84 7145.5 7187 First Reading For Entire File..........7145.5 Last Reading For Entire File...........7187 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header da ta for each bit r un in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 7145. 5 12916 .5 RPX 7145. 5 12916 .5 RPS 7145. 5 12916 .5 RPD 7145. 5 12916 .5 GR 7145. 5 12909 .5 FET 7145. 5 12916 .5 ROP 7187. 5 12967 .0 LOG HEADER DATA DATE LOGGED: 06-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12967.0 TOP LOG INTERVAL (FT) 7187.0 BOTTOM LOG INTERVAL (FT) 12967.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.8 MAXIMUM ANGLE: 91.1 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178513 EWR4 Electroma g Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 7145.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 99.0 MUD PH: .0 MUD CHLORIDES (PPM): 40500 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPE RATURE (DEGF) MUD AT MEASURED TEMPERAT URE (MT) .000 .0 MUD AT MAX CIRCULATING T ERMPERATURE : .000 115.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWDO80 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7145.5 12967 10056.3 11644 7145.5 12967 RPD MWD080 OHMM 0.19 2000 112.179 11543 7145.5 12916.5 RPM MWD080 OHMM 0.17 2000 132.37 11543 7145.5 12916.5 RPS MWD080 OHMM 0.19 2000 100.185 11543 7145.5 12916.5 RPX MWD080 OHMM 0.08 2000 149.686 11543 7145.5 12916.5 FET MWDO80 HOUR 0.26 219.92 2.41983 11543 7145.5 12916.5 GR MWD080 API 27.3 104.51 60.6139 11529 7145.5 12909.5 ROP MWD080 FT/H 5.82 335.28 146.342 11560 7187.5 12967 First Reading For Entire File..........7145.5 Last Reading For Entire File...........12967 File Trailer w Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date ..:..................06/01/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File