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Home My WebLink About206-116• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~J - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided II I IIlI II I) II I II III ^ Rescan Needed II I ll I+I~ II i I Ili iit RES N DIGIT L DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: , ^ Other:: BY: ~ _ Maria Date:., -'~ ~ (~ ~ ~") ~~' /s/ Project Proofing r~~ f~ BY: Maria Date: ~ ~ ' /s/ (' Scanning Preparation _~,_ x 30 = _!~~. + ___!~ =TOTAL PAGES. (Count does not include cover sheet) BY; `Maria Date: ~~ ~ ~ ~ /s/ ~; Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover heet) Page Count Matches Number in Scannin/g Preparation: YES NO BY: Maria Date: ~ ~ ~ ~ /s/ U-r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. Il l Il Il (I I (l II l l Ill ReScanned III II~IIIIIII) VIII BY: Maria Date: /s/ Comments about this file: a~.~, ~e~.~ iuuiiiuuuiiui P 10/6/2005 Well History File Cover Page.doc i • ~- _ ~~- -. . f ~ ~...~ -~ ` a ~ ~ ~~~ 1'` E, ~ ~ ~ ~~~ `; ~~~~ ~' MICROFILMED 6/30!2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc a~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Driil 2061160 Well Name/No. KUPARUK RIV U WSAK 1J-103L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23318-61-00 MD 13866 TVD 13662 Completion Date 1/29/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Asc Directional Survey 5912 13867 Open 3/27/2007 C Lis 15057 Induction/Resistivity 2889 13866 Open 4/20!2007 LIS Veri, GR, FET, ROP ~Qpt 15057 LIS Verification 2889 13866 Open 4/20/2007 LIS Veri, GR, FET, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y I© Daily History Received? ~N Chips Received? 'S'~hP~-~ Formation Tops Q/ N Analysis Y %~\ Received? Comments: - 1~ ~-- ---_-- ~ Compliance Reviewed By: Date: J WELL L®G T12Al~1Sli'IITTAL To: State of Alaska December 5, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-103+L1+L1PB1+L2+PB1+PB2+PB3 AK-MW-4725792 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-103+L1+L1PB 1+L2+PBl+PB2+PB3 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-2 3 318 - 00, 60, 61, 70, 71, 72, 73 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23318-00,61 Digital Log Images 1 CD Rom 50-029-23 318-00,60,61,70,71,72,73 L1, L1PB1, PB1, PB2, AND PB3 HAVE NO TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed: ~~ ~ ~ ~CJ~ /I~j~1~~~ aa~-tr5- t ~-~~ `3 ~~ G~(a ~t ~ 3~ RE I~IE~ STATE OF ALASKA APR 2 2 2008 ALASKA OIL AND GAS CONSERVATION C SI mission REPORT OF SUNDRY WE~~`~~~~~' 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 ESP to Gt_ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ Exploratory ^ 206-116 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23318-61 7. KB Elevation (tt): 9. Well Name and Number: RKB 110' 1 J-103L2 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25862 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Totat Depth measured 13867' feet true vertical 3663' feet Plugs (measured) Effective Depth measured 13556' feet Junk (measured) true vertical 3579' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2815' 10-3/4" 2925' 2243' PRODUCTION 7020' 7-5/8" 7130' 3791' D-SAND WINDO\ 1' 7-5/8" 5992' 3612' D-SaND sl_OTTE 7550' 4-112" 13556' 3579' Perforation depth: Measured depth: 6301'-11414', 11712'-13470' true vertical depth: 3613'-3573', 3600'-3565' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5015' MD. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~y ~ i~~ ~~ =` - GI s ~ ~ 2GO8 Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to welt operation 515 115 19 212 188 Subsequent to operation 253 61 8 673 194 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. F~cempt: Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technicia n Signature ~~ /' ~°Y / r -L~!G~ ~~` hone 659-7535 Date i f~j( ~~D ~j' g ~ y/~a~ Form 10-404 Revised 04/2004 ~ R ~ ~ ~ A ~ "~-~ Submit Original Only 1J-103L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/17/08 Well returned to production as a gas lifted oil producer. 04/16/08 Pulled 48' 3" TTC ESP from 4900' RKB. ~'~~ ` KR U Cary P ~ t~~c~ ~>il~>ip~ A~a~~ ~~~ _. _ 1J=103L2 ~ - API: 500292331861 Well T e: PROD Ar ~ _ SSSV Type: NONE Orig 1/29/2007 Af Com letion: - Annular Fluid: Last W/O: Re Reference Lo : 29.81' RKB Ref Lo Date: La Last Ta TD: 13867 ftK6 Last Tack Date: ~ __ Max Hole Angle: 96 deg n 12312 _ Casing String -ALL STRINGS I Descri lion Size To Bottom TVD TUBING SURFACE 10.750 0 2925 2243 (0-5015, PRODUCTION 7.625 0 7130 3579 OD:4.500, ID:3s5e) ~' CONDUCTOR 20.000 0 108 108 ('''',~ ~ ~ D-SAND WINDOW .7.625 5991 5992 3611 [~ ~ D-SAND SLOTTED LINER 4.500 6006 13556 3580 Tubing String -TUBING Size Top Bottom T VD Wt Grade xoINTAKE rag53~3963 ~ ~-~~0 ~ 0 perforations Summary i 5015 311 12.60 L-80 OD:5.130) -SEAL (4963-4977, OD:5.130) MOTOR (49775011, OD:5.620) Pump Gauge (50115013, OD:4.500) ''i 'RODUCTION (0-7130, OD:7.625, Wt:29.70) Pert (6301-11414) 1 J-103L2 TS: _de _ @ TD: 71 deg @ 13867 eason: C/O SOV iodate: 11/5/2007 L-RO I BTC ~ Thread 16Tt~.~-BCC Interval ND Zone Status Ft SPF Date Type Comment 6301 - 11414 3613- 3572 WS D 5113 32 12~i2007 SLOTS Alternating solldslotted p 11712 - 13470 3598 - 3565 WS D 158 32 1;25'200 SLOTS Alternating solldslotted pipe I 'iGas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Pon TR© Date Run Vlv Cmnt 1 3257 2416 CAMCO KBMG SOV 1.0 BK 0.000 0 0/19/200 2 4295 2954 CAMCO Other (plugs, equip., et De h TVD 7 e KBMG DMY 1.0 BK-5 OA00 0 1/28/2007 c.) -COMPLETION Descn lion Ip 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 4874 3247 Discharge Sub A-WELL DISCHARGE SUB 0.000 4900 .3259 PUMP ESP PUMP PACKOFF ASSEMBLY & TBG LOCK set 1/29/2007 0.000 4953 3283 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 4963 3288 SEAL TANDEM SEAL BECTON GSB 3 DB AB/HSN PFSA 0.000 4977 3294 MOTOR 418 HP KMHFER 2610 / 98 0.000 5011 3310 Pump Gau e A-WELL 1 PUMP GAUGE 0.000 5013 3311 Centralizer. MOTOR CENTRALIZER 0.000 5989 Other ( De th 3611 plugs, TVD HANGER equip., etc T e D-SAND LINER BAKER MODEL B-1 HH FOR LEM /INSIDE GASINGI .) - D-SAND LINER DETAIL Descn lion 4.020 ID 6006 3613 HANGER BDSAND LINER BAKER MODEL B-1 HH FOR LEM OUTSIDE CASING 4.020 6064 3617 PACKER D-SAND LINER BAKER PAYZONE EXTERNAL CASING PACKER 3.952 6193 3618 SLEEVE D-SAND LINER BAKER'HR' LINER SETTING SLEEVE 5.750 6219 3617 SHOE D-SAND LINER MULE SHOE 4.040 6257 3615 XO Bushing D-SAND LINER CROSSOVER BUSHING 3.930 13513 3572 SHOE D-SAND LINER ORANGE PEELED SHOE JOINT 3.930 (aen~fal NOt@S Date_ _ Note 1/29/2007 NOTE: MULTILATERAL WELL- 1J-103 (A-SAND), 1J-103L1 (B-SAND), 1J-103L2 (D-SAND1 Perf ;11712-13470) WELL LOG TRANSMITTAL To: State of Alaska April 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'h Avenue, Suite 100 Anchorage, Alaska RE: iVIWD Formation Evaluation Data: l,f-103, PB1, PB2, PB3, L1 PB1, L1 & L2, AK-NIW-4725877 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23318-00, 70, 71, 72, 73, 60 & 61 PLEASE ACI{NOWLEDGE RECEIPT BY SIGNING AND RETUIti~1ING A COPY OF THE TIZANSNIITTAL LET"TER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~'~~~~~ ~ ~ 20~? Date. Signed: ?t! j(~c7 ~ t5 053 ao(~ ~~ ~ 5 ~ t 5'o5S Zr' ~~-try ~sos-~ # ~SO~<~ • i 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-103L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and'`.PDF files. Tie-on Survey: 5,912.60' MD Window /Kickoff Survey 5,991.00' MD (if applicable) Projected Survey: 13,866.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~7 Si ned D 7 g Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) aa~-~~~~ MAR 0 5 ~uiil STATE OF ALASKA ALASKA OIL. AND GAS CONSERVATION COMMISSIka Oil & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT d''!~'OG 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 ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 29, 2007 ~ 12. Permit to Drill Number: 206-116 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ,.Qers'2996 , e,'! 13. API Number: ~, 50-029-23318-61 4a. Location of Well (Governmental Section): Surface: 2225' FSL,~2441' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: ~ January 24, 2007 14. Well Name and Number: 1J-103L2 At Top Productive Horizon: 2313' FSL, 620' FWL, Sec. 36, T11 N, R10E, UM 8. KB Elevation (ft): 30' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 244' FNL, 745' FWL, Sec. 12, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 13556' MD / 3578' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 i y- 5946037 ~ Zone- 4 10. Total Depth (MD + TVD): . 13866' MD / 3662' TVD ~ 16. Property Designation: , t ADL 25661 & 25662 TPI: x- 561826 y- 5946149 Zone- 4 Total Depth: x- 562021 ~ - 5938315 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes 0 No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: '~W ~o~ y"~GfZ„ !/N~~ .358/ ~~'1/p GR/Res 3 ^~/G • 0 7 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" x 34" 62.6# H-40 30' 108' 30' 108' 42" 40o sx AS 1 10.75" 45.5# L-80 30' 2925' 30' 2243' 13.5" 545 sx AS Lite, 177 sx DeepCRETE 7-5/8" 29.7# L-80 30' 7130' 30' 3790' 9-7/8" 418 sx Class G 4.5" 11.6# L-80 6192' 13556' 3613' 3578' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 5015' 6064' slotted liner from 13470'-11712', 11413'-6301' and 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) Oil Producer -shares production with 1J-103 and 1J-103L1 ~ Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE Ga,s-OIL RATIO Flow Tubing press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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". C.__ _ ,. NONE ~'1~"~"~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~`~~ ~~~ ~ goof ~3~z~ ~'' 3 ~G•v7 ~`l7 ~ 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-103L2 Top Kuparuk D 5991' 3611' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Na Randv Thomas Title: Greater Kuoaruk Area Drilling Team Leader ~ ~ c^~ '~ ~ , r ~~' ~ r Signature =~--hone Date '-~ °L C S ~ ~ c- 5 t INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Aiaska. 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 Y~'~ ~: ` Ct~npct~l~hillips Alaska, Inc. i.i-1f1'kl ~ U KRU 1J-103L2 Casing Detail Report 1J-103 - - ___ Casing Casing Description Set Depth (ftK6) Run Date D-Lat Liner 13,556.2 1/25/2007 Centralizers Scratchers 170 Hydraform Cent W/stop rings in middle ofjt iCasing Components - - - ~ item Descnption OD (in) ~~ Wt (Ibs/ft) ~ Grade Top Thread. Jts Baker "H R" Liner 6.42 _ 1 Setting Sleeve, 5 1/2" ID 5.01" Blank Liner 5.55 15.50 L80 1 5 1/2" Hydril 521, 5.55 15.50 L80 1 15.5 ppf L-80 Receptacle Jt ID 5-1/2" H521 x4-1/2" 6 1 BTC Crossover Bushing ID 3.9 4-1/2", 12.6ppf, L-80 4.52 12.60 L80 1 BTC ID 3.98" Slotted Liner 4 1/2 11.60 L80 BTC 12 4 1/2 11.60 L80 BTC 41/2 11.60 L80 BTC Blank Liner (Orange peeled shoe) D-Lat Liner Set Fension (kips) j Mk-up Ty ~ 't0 '~ Top (ftK@) BGn (ftl<B) (ft-Ibs) Class Max OD (ip) ' Ip (in) 15.20 6,192.81 6,208.0 - ~ 5.750 1.411 6,256.7 6,258.1 0 5,112.73 6,300.9 11,413.6 7 298.46 11,413.6 11,712.1 2 1,758.29 11,712.1 13,470.4 2 85.81 13,470.4 13,556.2 7 3.980 4.000 4.000 Page 1/1 Report Printed: 2/28/2007 C~ Halliburton Company Survey Report i __ _ Company: ConocoPhillips Alaska Inc. __ Date: 2/7/2007 Time: 16:33:12 Page: 1 Field: Kuparuk RiverUnit Co-ordinate(NE) Reference: We1L' 1 J-103, Tru e North Site: KuparuklJ?ad Ve rtical (TVD)Re ference: 1J-103L2:109.7 Well: 1J-103 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103L2 Su nny Calculation Method: Minimum Curvat ure Db: Oracle ~ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Well: 1J-103 Slot Name: Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N +E/-W -22.57 ft Easting : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft Wellpath: 1J-103L2 Drilled From: 1J-103P61 500292331861 Tie-on Depth: 5912.60 ft Current Datum: 1 J-10312: Height 109.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angl e: 80.81 deg Vertical Section: Depth From (TVD ) +N/-S +E/-W Direction ft ft ft deg ~ 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 2/7/2007 Validated: No V ersion: 1 Actual From To Survey ft ft Toolcode Tool Name '~ 50.70 632.70 1J-103P61 gyro (50. 70-632.70) C B-GYRO-SS Camera based gyro single shot 662.65 5912.60 1J-103P61 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5991.70 13828.24 1J-103L2 (5991.70-13828.24) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ SID Incl .Azim TVD Sys"I'VD ~/S E/W AIapN MapE "Cool ', ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.70 0.00 0.00 5946037.60 ~' 558766.46 ° TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS ~ 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC I 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC I 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC j 1905.12 50.63 35.76 1693.74 1584.04 553.95 347.13 5946594.19 559109.23 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2!7/2007 Time: 16:33:12 Yager. 2 Field: Kuparuk River Unit Co-ordinate(NE)Reference:' Well: 1J-103, True North Site: KuparuklJPad Vertical (TVD)Reierence: 1J-103L2:109.7 WeIL• 1.1-163 Section (VS) Keference: Well (O.OON,O.OOE,180.OOAzi) ~~ ellpath: 1 J-103L2 Survey Calculation Method: Minimum Curvature Db: Oracle __ __ tiurtiev MD [ncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 1936.93 51.49 36.82 1713.74 1604.04 573.89 361.78 5946614.24 559123.71 MWD+IFR-AK-CAZ-SC i 2000.86 51.87 39.61 1753.38 1643.68 613.29 392.80 5946653.88 559154.43 MWD+IFR-AK-CAZ-SC 2093.95 53.72 45.46 1809.70 1700.00 667.85 442.92 5946708.82 559204.11 MWD+IFR-AK-CAZ-SC 2191.18 56.62 51.14 1865.26 1755.56 720.85 502.51 5946762.28 559263.28 MWD+IFR-AK-CAZ-SC 2284.31 58.44 55.15 1915.27 1805.57 767.94 565.37 5946809.85 559325.77 MWD+IFR-AK-CAZ-SC 2380.32 59.72 60.12 1964.62 1854.92 811.99 634.92 5946854.44 559394.97 MWD+IFR-AK-CAZ-SC 2419.46 59.50 61.37 1984.42 1874.72 828.48 664.38 5946871.16 559424.29 MWD+IFR-AK-CAZ-SC 2475.95 58.92 62.59 2013.34 1903.64 851.28 707.21 5946894.29 559466.94 MWD+IFR-AK-CAZ-SC 2571.00 59.73 61.27 2061.83 1952.13 889.75 779.34 5946933.32 559538.76 MWD+IFR-AK-CAZ-SC 2611.14 59.76 60.92 2082.06 1972.36 906.51 809.70 5946950.32 559568.98 MWD+IFR-AK-CAZ-SC 2666.51 59.94 60.73 2109.87 2000.17 929.85 851.50 5946973.98 559610.60 MWD+IFR-AK-CAZ-SC 2695.63 59.05 61.06 2124.65 2014.95 942.06 873.42 5946986.35 559632.42 MWD+IFR-AK-CAZ-SC i 2761.59 57.83 60.61 2159.17 2049.47 969.44 922.50 5947014.12 559681.28 MWD+IFR-AK-CAZ-SC 2828.92 58.92 61.14 2194.48 2084.78 997.35 972.58 5947042.41 559731.14 MWD+IFR-AK-CAZ-SC 2857.58 59.64 60.94 2209.12 2099.42 1009.27 994.14 5947054.51 559752.60 MWD+IFR-AK-CAZ-SC 2968.32 59.14 61.42 2265.51 2155.81 1055.22 1077.64 5947101.10 559835.73 MWD+IFR-AK-CAZ-SC 3038.11 58.93 61.21 2301.41 2191.71 1083.94 1130.14 5947130.23 559888.00 MWD+IFR-AK-CAZ-SC I 3064.31 58.53 60.89 2315.01 2205.31 1094.78 1149.74 5947141.22 559907.51 MWD+IFR-AK-CAZ-SC 3159.47 58.15 61.48 2364.96 2255.26 1133.82 1220.71 5947180.81 559978.16 MWD+IFR-AK-CAZ-SC ~ ~ 3253.03 58.77 61.25 2413.90 2304.20 1172.04 1290.69 5947219.56 560047.84 MWD+IFR-AK-CAZ-SC 3349.29 59.73 61.83 2463.12 2353.42 1211.46 1363.42 5947259.54 560120.25 MWD+IFR-AK-CAZ-SC 3443.96 59.44 65.76 2511.06 2401.36 1247.50 1436.65 5947296.16 560193.19 MWD+IFR-AK-CAZ-SC ~ 3537.78 59.12 70.40 2559.01 2449.31 1277.60 1511.44 5947326.84 560267.73 MWD+IFR-AK-CAZ-SC 3633.89 58.32 74.65 2608.92 2499.22 1302.27 1589.75 5947352.12 560345.85 MWD+IFR-AK-CAZ-SC 3728.68 58.19 80.31 2658.83 2549.13 1319.74 1668.40 5947370.19 560424.34 MWD+IFR-AK-CAZ-SC 3822.92 58.63 85.34 2708.22 2598.52 1329.75 1748.00 5947380.83 560503.86 MWD+IFR-AK-CAZ-SC 3920.15 58.75 90.21 2758.77 2649.07 1332.97 1830.97 5947384.69 560586.80 MWD+IFR-AK-CAZ-SC 4016.73 57.89 96.43 2809.52 2699.82 1328.24 1912.96 5947380.60 560668.81 MWD+IFR-AK-CAZ-SC 4109.70 58.93 105.03 2858.29 2748.59 1313.48 1990.65 5947366.45 560746.61 MWD+IFR-AK-CAZ-SC 4205.49 58.97 109.97 2907.72 2798.02 1288.82 2068.88 5947342.40 560825.02 MWD+IFR-AK-CAZ-SC ii 4302.30 59.16 115.17 2957.51 2847.81 1256.96 2145.52 5947311.14 560901.90 MWD+IFR-AK-CAZ-SC 4396.10 58.94 118.87 3005.76 2896.06 1220.43 2217.16 5947275.17 560973.82 MWD+IFR-AK-CAZ-SC 4489.53 58.62 122.32 3054.20 2944.50 1179.77 2285.93 5947235.06 561042.89 MWD+IFR-AK-CAZ-SC 4586.40 58.36 128.27 3104.86 2995.16 1132.09 2353.29 5947187.91 561110.61 MWD+IFR-AK-CAZ-SC 4680.37 58.90 131.04 3153.79 3044.09 1080.89 2415.05 5947137.20 561172.77 MWD+IFR-AK-CAZ-SC 4775.85 61.69 130.15 3201.10 3091.40 1026.94 2478.02 5947083.75 561236.15 MWD+IFR-AK-CAZ-SC 4868.62 62.42 130.01 3244.57 3134.87 974.18 2540.72 5947031.48 561299.26 MWD+IFR-AK-CAZ-SC 4966.54 63.06 130.13 3289.42 3179.72 918.14 2607.34 5946975.98 561366.30 MWD+IFR-AK-CAZ-SC 5060.87 62.79 132.90 3332.36 3222.66 862.48 2670.22 5946920.81 561429.61 MWD+IFR-AK-CAZ-SC 5156.49 63.60 136.59 3375.49 3265.79 802.41 2730.81 5946861.22 561490.67 MWD+IFR-AK-CAZ-SC '~ 5251.33 64.45 139.73 3417.04 3307.34 738.90 2787.67 5946798.16 561548.01 MWD+IFR-AK-CAZ-SC 5346.95 67.81 145.86 3455.76 3346.06 669.27 2840.45 5946728.95 561601.33 MWD+IFR-AK-CAZ-SC 5442.23 69.73 151.57 3490.28 3380.58 593.40 2886.52 5946653.45 561647.99 MWD+IFR-AK-CAZ-SC 5537.26 73.47 156.74 3520.29 3410.59 512.27 2925.77 5946572.64 561687.86 MWD+IFR-AK-CAZ-SC 5631.47 77.44 159.97 3543.95 3434.25 427.53 2959.37 5946488.18 561722.12 MWD+IFR-AK-CAZ-SC 5693.55 78.30 162.00 3557.00 3447.30 370.16 2979.15 5946430.96 561742.34 MWD+IFR-AK-CAZ-SC 5723.72 78.56 161.64 3563.05 3453.35 342.07 2988.37 5946402.95 561751.78 MWD+IFR-AK-CAZ-SC 5820.08 79.35 163.42 3581.51 3471.81 251.87 3016.76 5946312.98 561780.87 MWD+IFR-AK-CAZ-SC 5912.60 79.95 165.42 3598.14 3488.44 164.20 3041.20 5946225.51 561805.99 MWD+IFR-AK-CAZ-SC 5991.70 80.66 165.34 3611.46 3501.76 88.75 3060.88 5946150.23 561826.26 MWD+IFR-AK-CAZ-SC 6013.94 83.51 165.89 3614.52 3504.82 67.42 3066.35 5946128.94 561831.90 MWD+IFR-AK-CAZ-SC 6106.29 89.81 168.15 3619.90 3510.20 -22.37 3087.04 5946039.33 561853.28 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 'l'ime: 16:33:12 Page: 3 Ficld: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-103, True North Sitr. Kuparuk 1J Pad Vertical (TV D) Reference: 1J-103L2: 109.7.. Well: 1J-103 Section(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-103L2 Survey Calculation Alethod: Minimum Curvature Db: Oracle Survc} MD Incl Azim TVD SysT~D N/S EIVV MapN b1apE Tnnl ft deg deg ft ft ft ft ft ft 6149.04 91.67 169.19 3619.35 3509.65 -64.28 3095.44 5945997.49 561862.01 MWD+IFR-AK-CAZ-SC 6200.08 92.72 170.44 3617.39 3507.69 -114.48 3104.46 5945947.37 561871.42 MWD+IFR-AK-CAZ-SC ~ 6294.71 91.98 170.04 3613.51 3503.81 -207.66 3120.48 5945854.32 561888.17 MWD+IFR-AK-CAZ-SC 6387.84 88.95 170.67 3612.76 3503.06 -299.46 3136.09 5945762.66 561904.49 MWD+IFR-AK-CAZ-SC 6481.23 92.66 174.79 3611.44 3501.74 -392.05 3147.90 5945670.17 561917.02 MWD+IFR-AK-CAZ-SC 6574.12 92.16 178.30 3607.54 3497.84 -484.67 3153.49 5945577.60 561923.33 MWD+IFR-AK-CAZ-SC 'I 6667.48 91.86 180.00 3604.26 3494.56 -577.96 3154.87 5945484.33 561925.45 MWD+IFR-AK-CAZ-SC 6761.00 94.08 181.40 3599.42 3489.72 -671.34 3153.73 5945390.95 561925.04 MWD+IFR-AK-CAZ-SC 6854.24 90.99 178.11 3595.29 3485.59 -764.47 3154.14 5945297.85 561926.16 MWD+IFR-AK-CAZ-SC j 6948.96 94.64 175.33 3590.64 3480.94 -858.89 3159.54 5945203.47 561932.31 MWD+IFR-AK-CAZ-SC 7040.96 94.20 175.59 3583.55 3473.85 -950.33 3166.80 5945112.10 561940.28 MWD+IFR-AK-CAZ-SC 7133.63 91.73 176.21 3578.76 3469.06 -1042.63 3173.42 5945019.87 561947.62 MWD+IFR-AK-CAZ-SC 7227.05 90.62 179.34 3576.84 3467.14 -1135.95 3177.05 5944926.59 561951.97 MWD+IFR-AK-CAZ-SC j 7320.65 91.11 182.63 3575.43 3465.73 -1229.51 3175.44 5944833.03 561951.09 MWD+IFR-AK-CAZ-SC 7414.35 90.74 184.85 3573.91 3464.21 -1322.99 3169.33 5944739.51 561945.71 MWD+IFR-AK-CAZ-SC 7508.16 90.99 186.45 3572.50 3462.80 -1416.33 3160.09 5944646.11 561937.21 MWD+IFR-AK-CAZ-SC 7604.11 90.62 186.89 3571.15 3461.45 -1511.62 3148.95 5944550.74 561926.81 MWD+IFR-AK-CAZ-SC II 7701.96 90.93 184.76 .3569.83 3460.13 -1608.95 3139.02 5944453.35 561917.64 MWD+IFR-AK-CAZ-SC 7798.98 90.74 181.03 3568.41 3458.71 -1705.82 3134.12 5944356.45 561913.50 MWD+IFR-AK-CAZ-SC 7894.05 90.68 178.94 3567.23 3457.53 -1800.88 3134.15 5944261.41 561914.26 MWD+IFR-AK-CAZ-SC 7991.23 90.56 177.73 3566.18 3456.48 -1898.01 3136.97 5944164.31 561917.84 MWD+IFR-AK-CAZ-SC 8087.78 90.81 176.49 3565.03 3455.33 -1994.43 3141.84 5944067.94 561923.46 MWD+IFR-AK-CAZ-SC j 8184.28 90.37 174.68 3564.03 3454.33 -2090.64 3149.26 5943971.81 561931.64 MWD+IFR-AK-CAZ-SC 8277.81 89.70 175.95 3563.98 3454.28 -2183.85 3156.90 5943878.66 561940.01 MWD+IFR-AK-CAZ-SC 8377.34 90.06 178.51 3564.18 3454.48 -2283.26 3161.71 5943779.31 561945.59 MWD+IFR-AK-CAZ-SC 8475.05 90.19 181.57 3563.97 3454.27 -2380.95 3161.64 5943681.62 561946.29 MWD+IFR-AK-CAZ-SC 8571.44 90.93 183.00 3563.03 3453.33 -2477.26 3157.80 5943585.30 561943.20 MWD+IFR-AK-CAZ-SC 8668.11 90.31 183.11 3561.98 3452.28 -2573.79 3152.65 5943488.74 561938.80 MWD+IFR-AK-CAZ-SC ICI 8764.74 90.50 182.71 3561.30 3451.60 -2670.29 3147.74 5943392.22 561934.65 MWD+IFR-AK-CAZ-SC 8861.52 89.94 182.33 3560.93 3451.23 -2766.97 3143.49 5943295.51 561931.15 MWD+IFR-AK-CAZ-SC 8957.71 90.44 182.28 3560.61 3450.91 -2863.08 3139.62 5943199.38 561928.03 MWD+IFR-AK-CAZ-SC 9054.77 90.07 181.94 3560.18 3450.48 -2960.08 3136.05 5943102.37 561925.21 MWD+IFR-AK-CAZ-SC 9151.51 90.13 180.41 3560.01 3450.31 -3056.79 3134.06 5943005.65 561923.98 MWD+IFR-AK-CAZ-SC 9247.90 90.56 179.44 3559.43 3449.73 -3153.18 3134.19 5942909.28 561924.86 MWD+IFR-AK-CAZ-SC 9344.68 90.50 180.94 3558.53 3448.83 -3249.95 3133.87 5942812.51 561925.30 MWD+IFR-AK-CAZ-SC I i 9439.91 90.13 177.84 3558.01 3448.31 -3345.17 3134.88 5942717.32 561927.05 MWD+IFR-AK-CAZ-SC iii 9537.48 89.63 176.36 3558.21 3448.51 -3442.61 3139.82 5942619.93 561932.75 MWD+IFR-AK-CAZ-SC 9634.44 90.31 176.25 3558.26 3448.56 -3539.36 3146.07 5942523.24 561939.75 MWD+IFR-AK-CAZ-SC 9730.33 90.37 175.65 3557.70 3448.00 -3635.01 3152.84 5942427.65 561947.27 MWD+IFR-AK-CAZ-SC I 9826.92 90.44 176.36 3557.01 3447.31 -3731.37 3159.57 5942331.36 561954.75 MWD+IFR-AK-CAZ-SC 9924.99 90.37 177.55 3556.32 3446.62 -3829.29 3164.78 5942233.49 561960.72 MWD+IFR-AK-CAZ-SC 10020.37 89.26 177.40 3556.63 3446.93 -3924.58 3168.98 5942138.25 561965.67 MWD+IFR-AK-CAZ-SC 10117.38 89.39 177.60 3557.77 3448.07 -4021.49 3173.21 5942041.38 561970.65 MWD+IFR-AK-CAZ-SC 10214.25 90.38 177.91 3557.96 3448.26 -4118.28 3177.01 5941944.63 561975.20 MWD+IFR-AK-CAZ-SC 10311.53 89.20 179.53 3558.32 3448.62 -4215.53 3179.18 5941847,41 561978.14 MWD+IFR-AK-CAZ-SC 10407.87 90.75 180.12 3558.36 3448.66 -4311.87 3179.47 5941751.09 561979.18 MWD+IFR-AK-CAZ-SC 10505.31 89.02. 179.83 3558.56 3448.86 -4409.31 3179.52 5941653.67 561979.98 MWD+IFR-AK-CAZ-SC 10601.65 88.58 179.25 3560.58 3450.88 -4505.62 3180.29 5941557.37 561981.51 MWD+IFR-AK-CAZ-SC 10697.76 90.07 180.41 3561.71 3452.01 -4601.72 3180.57 5941461.28 561982.54 MWD+IFR-AK-CAZ-SC 10793.17 90.37 183.74 3561.34 3451.64 -4697.05 3177.12 5941365.94 561979.83 MWD+IFR-AK-CAZ-SC 10891.60 90.56 183.60 3560.54 3450.84 -4795.28 3170.82 5941267.68 561974.30 MWD+IFR-AK-CAZ-SC 10988.82 90.31 183.10 3559.81 3450.11 -4892.33 3165.14 5941170.59 561969.38 MWD+IFR-AK-CAZ-SC 11028.99 88.40 181.83 3560.26 3450.56 -4932.46 3163.41 5941130.46 561967.96 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2!7!2007 Time: 16:33:12 Yage: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-103, True North ' Site: Kuparuk 1J Pad Vertical'(TVD)Reference: 1J-103L2: 109.7 yVellc 1J-103 Section (VS)Reference: .Well (O.OON,O.OOE,180.OOAzi) VI'ellpath: 1J-103L2 Survey Calculation Method: Minimum Curvature Db: C~racle- - _ __ Survey 14ID Inc! Azim TVD Sys TVD N/S E/1V M11ap:Y biapF Tool ft deg deg ft ft ft ft ft ft 11085.10 87.04 180.06 3562.49 3452.79 -4988.51 3162.49 5941074.40 561967.48 MWD+IFR-AK-CAZ-SC 11182.02 88.15 178.28 3566.56 3456.86 -5085.33 3163.89 5940977.61 561969.64 MWD+IFR-AK-CAZ-SC 11278.31 89.08 180.80 3568.89 3459.19 -5181.58 3164.66 5940881.37 561971.16 MWD+IFR-AK-CAZ-SC 11375.78 87.97 180.15 3571.39 3461.69 -5279.01 3163.85 5940783.95 561971.11 MWD+IFR-AK-CAZ-SC 11472.25 88.89 175.62 3574.04 3464.34 -5375.35 3167.41 5940687.65 561975.42 MWD+IFR-AK-CAZ-SC 11568.67 82.89 174.09 3580.95 3471.25 -5471.09 3176.03 5940591.99 561984.78 MWD+IFR-AK-CAZ-SC 11665.78 81.83 172.65 3593.86 3484.16 -5566.69 3187.14 5940496.49 561996.64 MWD+IFR-AK-CAZ-SC 11762.38 86.67 176.13 3603.54 3493.84 -5662.30 3196.52 5940400.96 562006.76 MWD+IFR-AK-CAZ-SC 11858.35 90.07 177.70 3606.27 3496.57 -5758.08 3201.68 5940305.24 562012.67 MWD+IFR-AK-CAZ-SC 11948.06 93.84 180.20 3603.21 3493.51 -5847.70 3203.32 5940215.64 562015.01 MWD+IFR-AK-CAZ-SC 12038.60 90.93 180.83 3599.44 3489.74 -5938.15 3202.51 5940125.20 562014.91 MWD+IFR-AK-CAZ-SC 12130.43 92.79 179.76 3596.46 3486.76 -6029.92 3202.04 5940033.43 562015.15 MWD+IFR-AK-CAZ-SC 12222.35 93.03 182.09 3591.79 3482.09 -6121.70 3200.55 5939941.65 562014.38 MWD+IFR-AK-CAZ-SC 12312.43 95.94 177.64 3584.74 3475.04 -6211.48 3200.76 5939851.89 562015.29 MWD+IFR-AK-CAZ-SC 12365.61 95.14 179.79 3579.61 3469.91 -6264.39 3201.95 5939798.99 562016.89 MWD+IFR-AK-CAZ-SC ' 12402.15 93.77 180.44 3576.77 3467.07 -6300.82 3201.87 5939762.57 562017.10 MWD+IFR-AK-CAZ-SC ', 12492.94 93.15 183.75 3571.29 3461.59 -6391.37 3198.56 5939672.00 562014.49 MWD+IFR-AK-CAZ-SC 12581.59 92.29 186.12 3567.08 3457.38 -6479.58 3190.94 5939583.74 562007.57 MWD+IFR-AK-CAZ-SC 12671.38 91.98 185.58 3563.74 3454.04 -6568.84 3181.80 5939494.42 561999.12 MWD+IFR-AK-CAZ-SC 12763.17 91.05 184.67 3561.31 3451.61 -6660.23 3173.60 5939402.98 561991.64 MWD+IFR-AK-CAZ-SC 12854.00 90.81 187.35 3559.84 3450.14 -6750.54 3164.09 5939312.60 561982.83 MWD IFR-AK-CAZ-SC 12945.17 1 3558.65 344 5 -6841.2 3154.63 5939221.88 561974.09 MWD IFR-AK-CAZ-SC 90.68 84 56 8 9 0 I 13035.15 90.87 181.84 3557.43 3447.73 -6931.03 3149.61 5939132.03 561969.77 MWD+IFR-AK-CAZ-SC 13126.37 91.05 180.16 3555.90 3446.20 -7022.22 3148.02 5939040.84 561968.89 MWD+IFR-AK-CAZ-SC 13218.38 93.28 177.81 3552.43 3442.73 -7114.14 3149.65 5938948.95 561971.23 MWD+IFR-AK-CAZ-SC I 13306.87 88.83 176.64 3550.80 3441.10 -7202.48 3153.93 5938860.64 561976.20 MWD+IFR-AK-CAZ-SC ~I 13328.89 87.90 177.29 3551.43 3441.73 -7224.46 3155.10 5938838.67 561977.54 MWD+IFR-AK-CAZ-SC I 13419.93 83.69 173.65 3558.10 3448.40 -7314.94 3162.26 5938748.27 561985.40 MWD+IFR-AK-CAZ-SC 13510.89 79.89 174.70 3571.09 3461.39 -7404.48 3171.40 5938658.80 561995.24 MWD+IFR-AK-CAZ-SC 13601.28 77.63 177.23 3588.71 3479.01 -7492.91 3177.64 5938570.44 562002.18 MWD+IFR-AK-CAZ-SC 13691.85 75.54 175.98 3609.72 3500.02 -7580.84 3182.85 5938482.56 562008.07 MWD+IFR-AK-CAZ-SC 13782.45 71.62 176.23 3635.33 3525.63 -7667.53 3188.76 5938395.93 562014.65 MWD+IFR-AK-CAZ-SC i 13828.24 70.66 176.00 3650.13 3540.43 -7710.76 3191.69 5938352.72 562017.93 MWD+IFR-AK-CAZ-SC ! 13866.70 70.66 176.00 3662.87. 3553.17 -7746.96 3194.23 5938316.54 ~ 562020.74 ~ PROJECTED to TD I ! ~ I Tirne Logs -- _- I Date From To Dur S Depth _E_ iJepth Phase Code Subcode T CORM 01/18/2007 19:30 22:30 3.00 61 6,180 COMPZ RPCOh TRIP T Trip in hole with packer assembly from 61' - to locate & spot top. of setting sleeve @ 6119' DPM. Running speed at 60 ft/min as per BOT rep. Observed pro erhole fill 22:30 23:30 1.00 6,180 6,180 COMPZ RPCOh DHEQ T Obtain Parameters. UP WT - 97K, SO WT = 73K, 36 SPM - 450 PSI. Drop 1 3/4" ball down drill string. Pump down Drill string @ 36PM -450 PSI. Observe ball seat at 436 BBIs pumped, andcontinue pressure to 4000 PSI to set packer. Hold pressure 5 minutes. Bleed pressures. Record on chart. 23:30 00:00 0.50 6,180 6,180 COMPZ RPCOA DHEQ T Pump down annulus to 1000 PSI, for 10 minutes, record. on chart. Bleed all ressures. Crew Chan e 01/19/2007 00:00 01:45 1.75 6,119 0 COMPZ RPCOti TRIP NP Continue POOH from 6119'to surface. 01:45 02:00 0.25 0 0 COMPZ RPCOh PULD NP Inspect, Breakout & lay down running & settin tools. 02:00 02:45 0.75 0 0 PRODS STK PULD P Clear & clean rig floorof OBM. Pull tools to floor. Held PJSM with crew & BOT rep. Discuss safety issues and procedure for making up whipstock assembl . 02:45 03:45 1.00 0 0 PRODS STK PULD P Make up Whipstock assembly as per BOT rep, with space out pipe & seal assembl . 03:45 04:15 0.50 0 0 PRODS STK PULD P Make up MWD assembly. Orient to whi stock face. 04:15 04:45 0.50 0 0 PRODS STK PULD P Plug irrand upload MWD assembly. 04:45 05:30 0.75 0 506 PRODS STK PULD P Continue Make up remaining whi stock BHA. Total len th = 506.14' 05:30 07:30 2.00. 506 5,346 PRODS STK TRIP P Trip in hole from 506' - 5346'. 07:30 08:30 1.00 5,346 5,528 PRODS STK OTHR P Perform MAD PASS log from 5210' - 5320'. Sensor depths. 08:30 09:00 0.50. 5,528 6,072. PRODS STK TRIP P Continue trip in hole from 5528' - 6072'. 09:00 09:30 -0.50 6,072 6,119 PRODS 8TK WPST P Establish parameters. UP WT = 115K, SO WT = 91 K. Orient whipstock face with MWD to 12 left of high side as per DD. Set whipstock. Observe anchor set with 10k, and verify set. Shear off bolt with 45Kset down. Pick up to neutral position.. Rotate free with 4K free torque. Top of whipstock @ 5991' DPM. 09:30 12:00 2.50 5,991 5,998. PRODS STK WPST P Mill window from 5991' - 5998'. ROT WT = 96K. 100 RPM's 4K TQ. Crew Chan e ~a~~ ~1 of ~7 LZ ~D a•iG-oT i Tirne Logs _ _ - _ _ -- _ _ --- - -- _ _ - ~~ Date _Frc~~~ To Dur S- D Fth_ E. L1:~pth_-Phase bode Subcode T (OM_ 1 01/19/2007 12:00 13:30 1.50 5,998 6,004 PROD3 STK WPST P Continue mill window from 5998' - 6004'. Pump 30 BBL Hi Visc weighted sweep. Observe 20% increase in cuttings upon sweep returned to surface.. 13:30 15:15 1.75 6,004 6,031 PROD3 STK WPST P Continue mill open hole from 6004' - 6031'. Gauged hole to 6023'. Pump 30 BBLS Hi Visc wei hted swee 15:15 16:00 0.75 6,031 6,031 PROD3 STK WPST P Dress window with. mills allowing sweep to return. Monitor well -static. Pump dry jab. Blow down top drive & lines. 16:00 18:30 2.50 6,031 0 PROD3 STK TRIP P POOh with milling assembly from 6031' to the BHA.` 18:30 19:30 1.00 0 0 PROD3 STK PULD P Plug in and download MWD assembly. Breakout & lay down mills. Gau a mills to full au e. 19:30 20:30 1.00 0 0 PROD3 STK OTHR P BOLDS. Pu11 wear bushing. Rig up & flush BOP stack. Install wear bushing. RILDS. 20:30 22:00 .1.50 0 0 PROD3 DRILL PULD P Held PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for making up BHA. Make u 6 3/4" drillin BHA with Geo ilot. 22:00 23:15 1.25 0 367 PROD3 DRILL PULD P Plug in and upload MWD assembly. Continue make up remaining BHA Total len th = 367.74'. 23:15 00:00 0.75 367. 1,300 PROD3 DRILL TRIP P Trip in hole with-BHA. Perform shallow ulse test. Break in Geo ilot. 01/20/2007 00:00 00:15 0.25 1,300 1,300 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco- nition issues. 00:15 01:00 0.75 1,300 5,962 PROD3 DRILL TRIP P Continue trip in holefirom 1300' - 5962'. Observed roper hole fill: 01:00 01:15 0.25 5,962 6,031 PROD3 DRILL TRIP P Fill drill string with mud. Check Geo-Pilot deflection. Trip in hole through window area with no issues to 6023'. PU WT = 98K, SO WT = 75K, ROT WT = 84K. TO 4K. 01:15 12:00 10.75 6,031 6,288 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6031' - 6288' MD. ADT = 8.0 HRS. Drilled 86' + of concretions. Crew Chan e 12:00 12:15 0.25 6,288 6,288 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 00:00 11.75 6,288 7,246 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6288' - 7246' MD. ADT = 7.6 HR5: Drilled 46' of concretions. Crew Chan e 01/21/2007 00:00 00:15 0.25 7,246 7,246 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 7,246 8,424 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 7246' - 8424' MD. ADT = 7.1 HRS. Pump Hi Visc weightred sweeps as needed. Crew Chan e 12:00 12:15 0.25 8,424 8,424 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. ... ~ ~ ~ ~ -s~'~ ~f 37 Tirne Lo~c s - _ - -- --- -- - - - - ---- _ - __ __ I Date From To Dur S_ D P_h_ [__ D Ffh Phz e_ _ Code Subeode T COP,1 __ 01/21/2007 12:15 00:00 11.75 8,424 9,724 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 8424' - 9724' MD. ADT = 7.3 HRS. Pump Hi Visc weightred sweeps as needed. Crew Chan e 01/22/2007 00:00 00:15 0.25 9,724 9,724 PRODS DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 9,724 10,953 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 9724' - 10953' MD. ADT = 6.9 HRS. Pump Hi Visc weightred sweeps as needed. Crew Chan e 12:00 12:15 0.25 10,953 10,953 PRODS DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 00:00 11.75 10,953 11,895 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 10953' - 11895' MD. ADT = 7.8 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 01/23/2007 00:00 00:.15. 0.25 11,895 11,895 PRODS DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 11,895 13,072 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 11895' to 13072' MD. ADT = 6.9 HRS. UP 170K, DN N/A, ROT 95K, TQ 13K On / 10K Off, ECD's 11.1 ppg, Max Gas 128 Units, Pump Hi Visc weightred sweeps as needed. Crew Chan e 12:00 12:15 0.25 13;072 13,072 PRODS RPCOh SFTY P PJSM with crew. Discuss safety issues and hazard recognition issues. of Back reamin . 12:15 13:45 1.50 13,072 13,344 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13072' to 13344' MD. ADT = 1.4 HRS. UP 175K, DN N/A, ROT 100K, TQ 13K On / 10K Off, ECD's 11.1 ppg, Max Gas 128 Units, Pump Hi Visc wei htred swee s as needed 13:45 14:30 0.75 13,344 13,344 PRODS DRILL CIRC P Circ sweep out of hole w/ 307 gpm @ 3750 psi & 110 RPM, Had 10% Increase in cuttings, ECD's 10.92 ppg, Monitor well - OK 14:30 00:00 9.50 13,344 6,428 PRODS DRILL REAM P Back ream out of hole w/ 300 gpm & 110 RPM at rate of 30 to 40 fpm f/ 13,344' to 6,428'. 01/24/2007 00:00 00:15 0.25 6,428 5,961 PRODS DRILL REAM P Back ream out of hole to 6100' w/ 300 gpm & 110 RPM at rate. of 30 to 40 fpm, Pull thru window @ 5991' (No roblem). Pull to 5961'. 00:15 01:15 1.00 5,961 5,961 PRODS DRILL CIRC P Monitor well -Static, Pump Hi-vis sweep w/ 315 gpm @ 2400 psi & 130 RPM, Up 105K, Dn 70K, Rot 82K, Tq 3.5K, Circ hole clean. 01:15 02:45 1.50 5,961 5,961 PRODS RIGMN SVRG P Slip & Cut drilling line 71.5', Service top drive. 02:45 03:30 0.75 5,961 8,015 PRODS DRILL TRIP P RIH to 8015' (Ran out of down weight) 03:30 09:45 6.25 8,015 13,344 . PRODS DRILL REAM P Wash & Ream to bottom due to no down wt. f/ 8015' to 1.3,344' w/ 135 m 1070 si & 80 RPM, T 10K. - -- - - - - - r _- - -- i i ~a ~~_ _ ~~ Time LocJs __ _- - -- D~.~ From Tc Du: S Det~th E Depth Phase ~~~_'e ~ueode T COI~1 ___ _ 01/24/2007 09:45 12:00 2.25 13,344 13,366 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13344' to 13366' MD. ADT 0.5 HRS. UP 175K, DN N/A, ROT 100K, TQ 11 K On / 11 K Off, ECD's 11.0 p ,Max Gas 128 Units. 12:00 12:15 0.25 13,366 13,366 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 12:15 18:00 5.75 13,366 13,866 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 13366' to 13866' MD (TD) / 3661' TVD. ADT = 5.3 HRS. UP 188K, DN N/A, ROT 100K, TQ 10K On / 11 K Off, ECD's 11.6 ppg, Max Gas 192 Units. 18:00 18:30 0,50 13,866 13,866 PROD3 DRILL CIRC P Circ & Survey, Down link to Geo-Pilot, Obtain SPR's, Monitor well 18:30 19:30 1.00 13,866 13,366 PROD3 DRILL REAM P Back ream out of hole to 13366' w/ 300 gpm & 100 RPM at rate of 40 to 50 fpm. 19:30 22:45 3.25 13,366 13,366 PROD3 DRILL CIRC P Pump Hi-vis weighted sweep, Circ & reciprocate pipe. at rate of 300 gpm @ 3500 psi & 110 RPM pump total of 3 times BTM's up, Had 5% increase in cuttings w/ sweep, Held PJSM on SFOBM Chan a over. 22:45 00:00 1.25 13,366 13,366 PROD3 DRILL CIRC P Change over to 8.4 ppg SFOBM. 01/25/2007 00:00 00:15 0.25 13,366 13,366 PROD3 DRILL SFTY P PJSM; Tripping out of the hole (Hazard Reco nitioh . 00:15 06:45 6.50 13,366 368 PROD3 DRILL TRIP P Monitor well- Static, Blow down top drive, Drop 1-7/8" Rabbit, POOH on elevators f/ 13,344' to 368' (Had tight spot @ 6,380' w/ 45K over -Wiped thru twice to wipe out). 06:45 07:45 1.00 368 68 PROD3 DRILL PULD P Lay down BHA #11, HWDP, Jars, Flex collars, Stabs, Float sub. 07:45 08:45 1.00 68 68 PROD3 DRILL PULD P Down load MWD. 08:45 10:00 1.25 68 0 PROD3 DRILL PULD P Finish laying down remainder of BHA, MWD, Geo-Pilot, Bit, Agitator & Shock sub. 10:00 10:15 0.25 0 PROD3 DRILL PULD P Clean & Clear floor of tools. 10:15 11:00 0.75 COMPZ CASIN( KURD P Rig to run 4-1/2" Slotted liner: 11:00 15:30 4.50 0 7,256 COMPZ .CASIN( PUTS P PJSM on running liner (Held with both crews), Run total of 170 jts liner plus welded orange peeled shoe joint (9 jts Blank= 384.2T & 162 'ts= 6,871.02' . 15:30 16:15 0.75 7,256 7,370 COMPZ CASIN( PUTB P Pick up Baker "HR" Setting tools (Up 86K, Dn 53K), Pump thru tools & Blow down to drive. 16:15 22:00 5:75 7,370 13,556 COMPZ CASIN( RUNL P RIH w/ liner on drill pipe, Lost down weight @ 10,410', Rotate liner at 20 RPM w/ 8 to 11 K torque to 13,556' (Up 175K, Dn 88K). ( ~ _ _~~ c~~0y 34 ~sf ~~' ~ , ~~ • Time Logs __ _ _- Da'.~ Fm~~ To Dur S_ Decth ~ D~p`h Pease C,u~e S~I~~,ode T ~~ON1 ~ - - -- 01/25l2007 22:00 22:45 0.75 13,556 6,192 COMPZ CASIN( CIRC P Drop ball & Pump down same, Release from liner w/ 2800 psi, Shear. out ball w/ 4300 psi. Liner tail @ 13,556.19', To of finer 6,192.76'. 22:45 23:15 0.50 6,192 5,991 COMPZ CASIN ( CIRC P POOH to 5,991', Circ btm's up at rate of 305 gpm @ 1100 psi, Wsah whi stock slide f/ 5,991' to 6,002'. 23:15 00:00 0.75 5,991 5,029 COMPZ DRILL TRIP P Monitor well- OK, Blow down top drive, POOH to 5,029' 01!2612007 00:00 00:15 0.25 5,029 5,029 COMPZ DRILL SFTY P PJSM; Tripping out of the hole (Hazard Reco nition). 00:15 02:15 2:00 5,029 31 COMPZ DRILL TRIP P Continue to POOH to liner running tool 02:15 03:00 0.75 31 0 COMPZ DRILL PULD P Lay down Baker liner running tool,. Clean & clear ri floor. 03:00 03:30 0.50 0 239 COMPZ STK PULD P Make up Baker Whipstock retrieving tools. 03:30 05:45 2.25 239 5,997 COMPZ STK TRIP P RIH to 5997 Up 120K, Dn 75K. 05:45 06:15 0.50 5,997 5,971. COMPZ STK TRIP P Hook Whipstock (On depth), PuR 105K over to pull free, Pull up 26' (Mud in hole dro ed 1' . 06:15 07:.00 0.75 5,971 5,971 COMPZ STK CIRC P Circ Btm's up at rate of 252 gpm @ 1200 psi, Monitor well, Blow down top drive. 07:00 09:30 2.50 5,971 113 COMPZ STK TRIP P POOH w/ Whipstock (Good hole fill - 2 bbls over . 09:30 11:30 2.00 113 0 COMPZ STK PULD P Lay down whipstock retrieving tools and whi stock assembl . 11:30 12:00 0.50 0 COMPZ STK OTHR P Clean & Clear rig floor of tools. 12:00 14:00 2.00 267 COMPZ CASIN( PUTB P PJSM, Rig casing tongs, Pick up .Hook hanger assembly, Pick up & Orient MWD, Surface test MWD tools. 14:00 17:00 3.00 267 6,004 COMPZ CASIN( RUNL P RIH w/ Hook Hanger assembly, Tag main bore crossover @ 6149' 3 times,- ExiTwindow on 3rd. attempt (Up 117K, Dn 75K . 17:00 17:30 0.50 6,004 6,248 COMPZ CASIN( RUNL P Orient Hook assembly to 16R & Hook window 2' low @ 6006',. Turn Hook 180 deg. & Go past window 10', Pick back up and obtain 16R and Hook window 2 times, Stack out 30K down weight. Hook assembly tail @ 6248.69', Top of Hook Hanger @ 5989.27, Found window 6006' when hooked. 17:30 18:00 0.50 6,248 6,248 COMPZ CASIN( CIRC P Drop ball & pump down at rate of 3 bpm @ 750 psi, Pressure up to 1800 psi hold 1 min., Pressure up to 2800 psi, ECP opened and dropped to 890 psi, Pressure back up to 2800 psi w/ 6 stokes (1/2 bbl), Bled off and pick up and observed tool released. 18`00 19:00 1.00 6,248 6,248 COMPZ CASIN( CIRC P Circ Btm's up, Monitor well, Blow down to drive. 19:00 23:00 4.00 6,248 0 COMPZ DRILL TRIP P POOH (Good hole fill - 9 bbls over), Break & La down liner runnin tools. ~_ ~ _~.__ ~ - ~~ ~ __. ~ - ~ ~ - t i~ _. .....~ '-.__,_-_ ._...._... .~~..._. ~, Time Logs - _ ___ n..~e _ Fro~~~ To D~~~r S Depth E Deoth Pease Code Sut~ode T COM _ 01/26/2007 23:00 00:00 1.00 0 COMPZ DRILL OTHR P Clear & Clean rig floor. 01!27/2007 00:00 09:45. 9.75 COMPZ DRILL PULD P PJSM, Lay down 90 stands 4" slick drill pipe, 15 stands Hybrid Push pipe, 7 stands HWDP. 09:45 12:00 2.25 COMPZ DRILL PULD P PJSM, Lay down 9 stands 4" drill pipe & remove super sliders and Lo-Tad's. Hole took 3 bbls in 12 hour period. 12:00 12:15 0.25 COMPZ DRILL SFTY P PJSM; Removing super sliders and Lo-Tad's. 12:15 18:30 6.25 COMPZ DRILL KURD P Continue laying down 4"drill pipe with super sliders and Lo-Tad's. 18:30 19:30 1.00 COMPZ DRILL OTHR P Clear & Clean rig floor.. 19:30 20:15 0.75 COMPZ RPCOh RURD P PJSM on rigging up & picking up tubin Ri to run 4-1/2" Tubin . 20:15 00:00 3.75 3,420 COMPZ RPCOh PULD P Pick up & run 114 jts. 4-1 /2" tubing from i e shed. 01!28/2007 00:00 01:00 1.00 3,420 4,590 COMPZ RPCOh PULD P Continue to Pick up & run total of 1.53 "ts. 4-1/2" tubin from i e shed. 01:00 03:15 2.25 4,590 0 COMPZ RPCOh TRIP P POOH & Rack back tubing on off driller side. 03:15 03:30 0.25 0 COMPZ RPCOh PULD P Rig & pull wear bushing, Clear rig floor. 03:30 03:45 0.25 COMPZ RPGOh SFTY P Held PJSM with Halliburton wire line, Centrilift and rig crew on running ESP Completion rocedures. 03:45 04:45 1.00 COMPZ RPCOh RURD P Rig up Centrilift equipment. 04:45 05:30 0.75 COMPZ RPCOR PULD P Pick up Screen Intake, 2 jts. Completion tubing, A-Well Discharge sub, Pick u Pum sections. 05:30 06:00. 0.50 COMPZ RPCOh RURD P Rig up Halliburton wire lihe. 06:00 07:30 1.50 COMPZ RPCOh PULD P Set Pump,. Set pack off, Attempt to test same to 1000 psi- No good, Pull & inspect pack off- Showed. to be brittle and in poor sha e. 07:30 09:30 2.00 COMPZ RPCOh WOEQ T Wait on new Pack off for ESP Pump. 09:30 12:30 3.00 COMPZ RPCOh DHEO T . Set new pack off, Attempt to test pack. off- No good, Pull Discharge sub up to floor and found plug out of A-Well Discharge sub, Replace same, Run back down and test pack off to 1000 psi f/ 5 min.- OK, Rig down wire line equipment, POOH & Stand back Screen assembl . 12:30 16:30 4.00 33 COMPZ RPCOh PULD P Pick up Motor & Seal assemb-y, Fill with oil, Hang cable sheave, Make up cable & Capillary line to Discharge sub. 16:30 22:30 6.00 33 4,903 COMPZ RPCOh RCST P RIH w/ ESP Completion string, Check cable every 10 stands, Pickup 2 GLM's as er tall , -- - ---- -- -- { ' l'~c~e ;, of 37 ~~._ ___._._~_ ___--_ ~___ _. _~ ___~ ...~-____ ~ 'm. ~~_______ ~~ Time Logs _- -- Da'.e _ Frori To Dur S Depth E_Dc~_±h Ph~_= ~> ode b~~bcode T Cl)P/1 01/28/2007 22:30 23:00 0.50 4,903 4,993 COMPZ RPCOh PULD P Pick up 2 more joints tubing, Make up tubing hanger. (Used 83 Cannon clamps, 3 Protectolizers, 2 Flat Guards, No Flat bands as yet but may use some on s lice) 23:00 00:00 1.00 4,993. 4,993 COMPZ RPCOh PULD P Make up Penetrator to Hanger, Measure & slice cable to Penetrator. 01/29/2007 00:00 01:45 1.75 4,993 4,993 COMPZ RPCO[v PULD P Continue to splice cable to penetrator. 01:45 02:00 0.25 4,993 4,993 COMPZ RPCON PULD P Check cable thru penetrator. 02:00 02:30 0.50 4,993 5,015 GOMPZ RPCOh PULD P Land Hanger, RILDS, Test upper & Lower han er seals to 5000 si- OK. 02:30 03:00 0.50 5,015 COMPZ WELCT NUND P Nipple down BOPE. 03:00 04:15 1.25 COMPZ RPCOti NUND P Nipple up Tree, Test ESP cable thru Tree - OK, test Tree void to 5000 psi - OK, Install Upper & LowerAccuator valves. 04:15 04:45 0.50 COMPZ RPCOh NUND P Test Tree to 250 low and 5000 psi f/ 10 min.- OK. 04:45 05:00 0.25 COMPZ RPCOh NUND P Pull 2 way check. 05:00 06:30 1.50 COMPZ RPCOh RURD P Rig to change over well to deisel using Little Red. 06:30 06:45 0.25 COMPZ RPCOh SFTY P Held PJSM w/ Little Red and Rig crew. 06:45 09:15 .2.50 COMPZ RPCOh FRZP P Test lines to 2500 psi, Displace well over to deisel at rate of 3.5 bpm w/ 40% returns, Slow rate to 2.5 bpm w/ 70% returns, Slow rate to 1.5 bpm 1/ 100% returns @ 600 psi, Pump total of 250 bbls, Lost 38 bbls, Total returns 212 bbls SFOBM to surface. 09:15 09:30 0.25 COMPZ RPCOti RURD P Rig down Little Red. 09:30 10:45 1.25 COMPZ RPCOh NUND P Remove working flanges from Wellhead, Install blind flanges, Clean Pit #5, Pill it, Rock washer. 10:45 11:15 .0.50 COMPZ RPCOh RURD P Rig up Scaffolding. 11:15 12:00 0.75 COMPZ RPCOh NUND P Rig up lubricator, Set BPV, Rig down lubricator, Rig down Scaffolding. Release ri at 12:00 on 1/29/2007 f~ ~,j s w f ~rf .~.9 ~~Q~[~ 0~ Q~~la~~{Q i Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-103L2 ConocoPhillips Alaska, Inc. Permit No: 206-116 (revised) Surface Location: 2225' FSL, 2441' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 169' FNL, 693' FWL, SEC. 12, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for the revised permit to drill the above referenced development well. The Commission previously issued Permit to Drill No. 206-116 for well 1J-102L2 on August 4, 2006. The enclosed revision is necessary due to ConocoPhillips' desire to extend the planned lateral length of this horizontal well branch an additional 2,775' along the same azimuth and within the same reservoir sand, since oil was confirmed after crossing a fault. This permit supersedes and replaces Permit to Drill No. 206-116 issued on August 4, 2006. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-103, Permit No. 206-114, API No. 50-029-23318-00. Production should continue to be reported as a function of the original API number stated above. 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 the permit. When providing notice for a representative of the Commission to w' es any required test, contact the Commission's petroleum field inspector a~7.~ 9- 07 (pager). DATED thi~~ay of January, 2007 ALASSA OIL A11jD GA5 ~e~ ~eN COI~TSERQ,A7`I011T COriNII55IO1~T cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~2ECEIVED ~~~ JAN 2 3 200) ~a~~a iii ~ ~~s duns. Gixnrr2~ssi ~rsrl•,rfit!~ra~s - -- 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone Q 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-103L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13782' ~ TVD: 3633' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2225' FSL, 2441' FEL, Sec. 35, T11N, R10E, UM 7. Property Designation: ADL 25661•& 25662 ~ West Sak Oil Pool Top of Productive Horizon: 2553' FSL, 554' FWL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 1!23/2007 Total Depth: 169' FNL, 693' FWL, Sec. 12, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 ~ y- 5946037 • Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-102 , 1260' 16. Deviated wells: Kickoff depth: ~ tuft,. Maximum Hole Angle: 2° deg 17. Maximum Anticipated Pressures in psig (see 20 Aa.C 25.oa5) ~ Downhole: 1614 psig Surface: 1220 psig . 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6.75" 4.5" 11.6# L-80 BTC 8112' 5670' 3587' 13782' 3633' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 12450' Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20"x34" 400 sx AS 1 108' 108' Surface 2897' 10.75" 545 sx AS Lite, 177 sx DeepCRETE 2925' 2240' Intermediate 7102' 7.625" 164.5 bbls DeepCRETE 7130' 3785' Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program O 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature '~~ ~~,`'~--- Phone `~~• ~` ~ ~ S0 Date j ~~~ ~~ ~"~~ s..L..~„~' \ ~^c° i`i`~_-~'-°.'- ="~ Pr h All Dr k Commission Use Only Permit to Drill-~ T Number: .C.s~-~.~p "' ~ f ~ API Number: / 50- (~~~ - 2 ~3 ~~ -~ J Permit Approval Date: See cover letter for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m han ,gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [v]im Other: ~~ tpSo r-~~~~v-~~~ ~.~~'- H2S measures: Yes ^ No, [v]im Tonal svy req'd: Yes [V]~ No ^ _ APPROVED BY THE COMMISSION DATE: ~•~` ~ ,COMMISSIONER Form 10-401 Revised 12/2005 S bmit in Duplicate ~ ~ ~~ wr, ~>, ,. z.,,.a~ • ConocoPhillips Alaska • Plan: 1J-103 L2 Pilot Toe (wp11) Sperry Drilling Services Proposal Report -Geographic 23 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Rig: 1 J-103 -Slot 1 J-103 1J-103 L2 Pilot Toe Local Coordinate Origin: Centered on Well Rig: 1J-103 -Slot 1J-103 Viewing Datum: Doyon 141 (28+g1.7) @ 109.7ft (Doyon 141 (28+81.7)) TVDs to System: N North Reference: True Unit System: API ill T Sperry Drilling Services ORIGINAL Sperry Qrilling Sarv€cers Project: Kuparuk River Unit Site: Kuparuk 1J Pad WeIL Rig; 1J-103 ellbore: 1J-103 L2 Pilot Toe Plan: 1J-103 L2 Pilot Toe (wp1 1) WELL DETAIIS: Rig: 1J-103 Ground Level: 81.0 +N/-S +E/_W Northing Pasting Latittude Longitude Slot 0.0 0.01812355.89 17031236 70°15'47.42N 149°31'29.663W D-103 FORMATION TOP DETAILS No.NDPath NDSS MDPath Formation 1 1518.9 1409.20 1632.7 Base Perm 2 1663.5 1553.80 1857.7 T3 3 1955.4 1645.70 2362.0 K15 4 2242.5 2132.80 2923.2 T3 t 550 5 2903.2 2793.50 4196.7 Ugnu C 6 3154.3 3044.60 4681.3 Ugnu B 7 3227.5 3117.80 4831.9 Ugnu A 8 3369.6 3259.90 5143,2 K13 9 3567.$ 3458.10 5747.6 WSAK D I CASING DETAILS No MD TVD TVDss Name Size 1 2925.7 2243.7 2134.00 IO 3/4" 10.75 2 5990.7 3611.3 3501.60 7 5/8" TOW 7.6 3 13405.6 3551.3 3441.60 41/2 4.5 2000 2500 3000 ~ 3500 O O O aaoo- L _ a _ d O - c~ 4500-- 0 al F- 5000 ~?S, Pilot: Continue Geosteering in D-Sand @ 12228' MD, 3569' ND ~O ' ------------------- ------------..-----------Pilot: End Dir@11978'MD,3576'ND ------'-------------------- Pilot: Begin Dir 3°/100' @ 11942' MD, 3577' ND ~ ,' Pilot: BHL @ 13782' MD, 3633' ND ~ i Pilot: End Dir @ 11532' MD, 3582' N~~ , ~ ~ , Pilot Tie-On to 1J-103 L2 @ 11084' MD, 3562' ND -Hold Inc & Azm to.Fault -`~r~--- __-_--_-_-_--_-_-_-_-_--_-_-_-_-_--_--_--_--_-__-------- -~__ _ __~°=~--D- -':o--~------'----- _-_~_~J!103L2PiIntTc~~~~r~~1?1 - o ~ o ~ o ~ 103 L2 0 0 u~ ~ .o , o ~ ~~ i ............r /Ai ~~ WSAK D I 0 ~ CO~i I N O i ,- - ~ - ~ ~ , 1J-103 1J-103 L1 -- ~~ ~ ~~ I Pilot: Proposed Fault- Begin Dir 3°/100' @ 11410' MD, 3579' ND ,' ~ ~~ ~~ ~ ~ .~ ~ 1J-103 L2 T12 (wp10 ,' ; \~ -_ - = 1J-103 L2 (wp11) To C ~ 1J-103 L2 (wp11) Pilot-Tae, 1J-103 L2 T13 (wp18} ,~ ~ P- ~ ___--__ _ ---._~ 1J-103 L2 T14 (wp10) D-Toe ~ 1J-103 L2 (wp11) Top-B 6000 1000 -500 --1-f~T~TrTI 1 ~i I ~f~TI ~-"i ~I~~-I_T-I~T~1~Tl~~T-r."I _I_ i T~.._ ~ _I_._.i"_t__f-_i _T_ 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8 1500 Vertical Section at 180.00° (1000 ft/in) ~""~ ~C)!"ipCt7P~ I I i p5 + „~ ; ~,h ~ ? µ i.^,~ ~ ^~' ~ ~ ~~ ~ WELL DETAII-S: Rig: IJ-103 Ground Level: 81.0 $(,T0#`f`j/ ~ ?i`1111(11't~$ ~^jE~1'vIQ@$ +N/-S +E/-W Northing Easting Latittude Longitude Slo[ 0,0 0.0 1812355.89 17031236 70°l5'47.42N149°31'29.663W IJ-103 Project: Kuparuk River Unit Site: Kuparuk 1J Pad ~~' Well: Rig: 1J-103 Wellbore: 1J-103 L2 Pilot Toe ~,° 's5~ Plan: 1J-103 L2 Pilot Toe (wp11) 500 ,~_ 7 5/8" TOW ly1° , - - ~ (66° 0 170° 172° -500 ~ 180° 178° -1000 j 178° 7 184° -1500 184° 178° -2000- 178° -2500 FORMATION TOP DETAILS .g -3000-- No.TVDPath TVDSS MDPath Formation ~ - 180° 1 1518.9 1409.20 1632.7 Base Perm 2 1663.5 1553.80 1857.7 T3 c 3 1955.4 1845.70 2362.0 K15 178° 4 2242.5 2132.80 2923.2 T3 + 550 -3500 + 5 29D3.2 2793.50 4196.7 Ugnu C 3D44 60 681 3 U B .176° . . gnu 6 3154.3 4 ~ 7 3227.5 3117.80 4831.9 Ugnu A c $ 3369.6 3259.90 5143.2 K13 9 3567.8 3458.10 5747.6 WSAK D .~ -4000 ~ 178° CASING DETAILS 0 rn 180° No MD TVD TVDss Name Size 1 2925.7 2243.7 2134.00 10 3/4" 10.750 -0500 2 5990.7. 3611.3 3501.60 7 5/8" TOW 7.625 3 13405.6 3551.3 3441.60 41/2 4.500 182° -5000 - - - - - - - - - -Pilot Tie-On to 1J-103 L2 @ 1 1084' MD, 3562' TVD -Hold Inc & Azm to Fault 1J-103- - - 180° _ _ _ _ Pilot: Proposed Fault -Begin Dir 3°/100' @ 11410' MD, 3579' TVD -5500 Pilot End Dir @ 11532' MD, 3582' TVD T Pito[: Begin Dir 3°/100' @ 11942' MD, 357T TVD M Azimuths ro True North Magnetic North: 23.65° - - - - - - - - - -Pilot: End Dir @ 11978' MD, 3576' TVD -6000 __ 80° ~ Magnetic Field ~~ 'I1J-143 L2 TI2 (wp101'~~,- - - - - - -- -- Pilot Continue Geosteering in D-Sand @ 12228' MD, 3569' TVD SVength: 57616.2nT ° Dip Angle: 80.81 - Date: 1/23/2007 1J-103 Ll "" - - 180° - -1J-103 LZ Model: BGGM2006 -6500 1J-103 L21'13 {wg10) ------ 7000 ~ ] 80° I 1J-10'3 L'- TI4 (wp10} D-Toe~ - - - - - - ~4 1/2 -7500 i,1J-103 u (wpn) ropr~ - - - - _ _ " __ -- I1J-203 LZ (wpl l) Top-B - _ _ _ _ _-- - ~ - - - - - -Pilot: BHI, @ 13782' MD, 3633' TVD: 169' FNL, 693' FWL - Sec12-T10N-RlOE 1J-103 I.2 (wp] I) Pilot-Toe 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 West(-)/East(+) (1000 ff/in) ''~'""~ ~t~l"1€3GE)~"41~ ~i p5 AiBSka ORIGINAL iw' ConocoPhillips Alaska Halliburton Company Planning Report -Geographic Sperry Drilling 'Services Database: Compass 2003.11 Local Co-ordinate Reference: 'Nell Rig: 1J-103 -Slot 1J-103 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 141 (28+81.7) @ 109.7ft (Doyon 141 (28+81.7)) Project: Kuparuk River Unif MD Reference: Doyon 141 (28+g1.7) @ 109.7ft (Doyon 141 (28+81.7)) Site: :Kuparuk 1J Pad North Reference: True Welt: 'Rig: 1J-103 Survey Calculation Method: M nimum Curvature Wellbore: 1J-103 L2 Pilot Toe Design: 1J-103 L2 Pilot Toe (wp11) ' oject Kuparuk River Unit, North Slope Alaska, United States ~p System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ~o Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ~p 2one: Alaska Zone 04 Using geodetic scale factor Well Rig:1J-103-Slot 1J-103 Well Position +N/-S 0.0 ft Northing: 1,812,355.89 m Latitude: 70° 15' 47.420" N +E/-W 0.0 ft Easting: 170,312.36 m Longitude: 149° 31' 29.663" W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 81.0 ft Welll>ore tJ-103 L2 Pilot Toe Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (°) (nTl BGGM2006 1 /23/2007 23.65 80.81 57,616 - __ Design 1 J-103 L2 Pilot Toe (wpt 1) ' Audit Notes: Version: Phase: PLAN Tie On Depth: 11,084.4 ~, Vertical Section: Depth From (TVD) +W-S +FJ-W Direction (ftl lft) (ft) l°) ~- ~~~o o~, ,~o~~ ~ Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-yy Rata Rata Rate TFO Ift) (') (°l IfU Ift) Ift) ('1100ft) (°I100ft} (°1100ft) (°) 11,084.4 87.06 180.08 3,562.5 -4,987.8 3,162.5 0.00 0.00 0.00 0.00 11,410.0 87.06 180.08 3,579.2 -5,313.0 3,162.0 0.00 0.00 0.00 0.00 11,531.6 90.66 180.68 3,581.6 -5,434.5 3,161.2 3.00 2.96 0.49 9.37 11,942.4 90.66 180.68 3,576.9 -5,845.3 3,156.4 0.00 0.00 0.00 0.00 11,978.3 91.71 180.45 3,576.2 -5,881.2 3,156.0 3.00 2.93 -0.63 -12.20 12,228.3 91.71 180.45 3,568.7 -6,131.1 3,154.0 0.00 0.00 0.00 0.00 12,250.7 91.49 180.45 3,568.1 -6,153.4 3,153.9 1.00 -1.00 0.00 180.00 12,828.0 91.49 180.45 3,553.1 -6,730.6 3,149.4 0.00 0.00 0.00 0.00 12,952.5 90.24 180.45 3,551.2 -6,855.0 3,148.4 1:00 -1.00 0.00 -179.95 13,337.6 90.24 180.45 3,549.6 -7,240.1 3,145.4 0.00 0.00 0.00 0.00 13,646.0 74.82 180.45 3,589.6 -7,544.9 3,143.0 5.00 -5.00 0.00 180.00 13,764.7 68.89 180.45 3,626.5 -7,657.7 3,142.1 5.00 -5.00 0.00 180.00 13,782.3 68.01 180.45 3,633.0 -7,674.1 3,142.0 5.00 -5.00 0.00 180.00 1/23/2007 11:27:29AM Page 2 of 8 COMPASS 2003.11 Build 48 OR161NAL • C coPhilli HalFiburton Company ono ps Planning Report -Geographic Alaska ' Database: Compass 2003.11 Local Co-ordinate Reference: i Company: ConocoPhillips Alaska. Inc. 7VD Reference: Project Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: 'Rig'. 1J-103 Survey Calculation Method: Wellbore: 1J-103 L2 Pilot Toe Design: 1J-103 L2 Pilot Toe (wp11) ~__ Planned Survey -- 1J-~03 LZ Pilot Toe (wp1~) - • Sperry Drilling Services Wall Rig: 1 J-103 -Slot 1 J-103 Doyon 141 (28+81.7) @ 109.7ft (Doyon 141 (28+81.7)) Doyon 141 (28+81.7) @ 109.7ft (Doyon 141 (28+81.7)) True Minimum Curvature Map Map MD Inclination Azimuth ND SSTVD +N/-S +E/-W Northing Easting Ift) P) 1`) lft) (ftl Ift) fft) Im) Im) 100.0 0.27 229.78 100.0 -9.70 -0.1 -0.2 1,812,355.85 170,312.29 200.0 0.23 19.39 200.0 90.30 -0.1 -0.3 1,812,355.86 170,312.25 300.0 1.10 35.71 300.0 190.29 0.7 0.1 1,812,356.09 170,312.39 400.0 3.38 39.40 399.9 290.22 3.6 2.4 1,812,356.98 170,313.07 500.0 6.07 40.57 499.6 389.86 9.9 7.7 1,812,358.93 170,314.70 600.0 8.40 41.36 598.8 489.06 19.5 16.0 1,812,361.86 170,317.19 700.0 11.02 37.06 697.4 587.67 32.3 26.5 1,812,365.79 170,320.36 800.0 13.53 35.79 794.9 685.24 49.9 39.4 1,812,371.18 170,324.26 900.0 14.04 34.69 892.0 782.30 69.5 53.4 1,812,377.20 170,328.45 1,000.0 16.94 30.36 988.4 878.71 91.9 67.6 1,812,384.04 170,332.75 1,100.0 22.60 30.16 1,082.5 972.76 121.1 84.7 1,812,392.98 170,337.90 1,200.0 25.44 29.57 1,173.7 1,064.02 156.6 104.9 1,812,403.87 170,343.94 1,300.0 30.93 29.26 1,262.3 1,152.61 196.9 127.7 1,812,416.19 170,350.82 1,400.0 37.40 28.67 1,344.8 1,235.14 246.2 155.0 1,812,431.29 170,359.01 1,500.0 40.71 30.13 1,422.1 1,312.36 301.7 185.9 1,812,448.27 170,368.30 1,600.0 44.54 30.60 1,495.9 1,386.16 359.8 220.2 1,812,466.05 170,378.62 1,632.7 46.14 30.92 1,518.9 1,409.20 379.8 232.1 1,812,472.18 170,382.19 Base Perm 1,700.0 50.04 32.65 1,563.8 1,454.12 422.3 258.5 1,812,485.20 170,390.12 1,800.0 50.76 33.99 1,626.7 1,517.03 487.5 300.8 1,812,505.16 170,402.88 1,857.7 50.19 34.85 1,663.5 1,553.82 524.1 326.0 1,812,516.39 170,410.46 T3 1,900.0 50.58 35.66 1,690.5 1,580.80 550.7 344.8 1,812,524.54 170,416.13 2,000.0 51.86 39.57 1,752.9 1,643.15 612.7 392.4 1,812,543.56 170,430.48 2,100.0 53.89 45.83 1,813.3 1,703.57 671.2 446.4 1,812,561.52 170,446.81 2,200.0 56.79 51.53 1,870.1 1,760.40 725.4 508.3 1,812,578.18 170,465.53 2,300.0 58.64 55.97 1,923.5 1,813.76 775.5 576.4 1,812,593.59 170,486.18 2,362.0 59.46 59.18 1,955.4 1,845.67 804.0 621.3 1,812,602.39 170,499.80 K15 2,400.0 59.61 60.75 1,974.6 1,864.86 820.3 649.7 1,812,607.44 170,508.40 2,500.0 59.12 62.25 2,025.7 1,916.02 860.8 725.5 1,812,619.95 170,531.41 2,600.0 59.75 61.02 2,076.4 1,966.75 901.8 801.3 1,812,632.63 170,554.41 2,700.0 58.97 61.03 2,126.9 2,017.20 943.8 876.7 1,812,645.62 170,577.29 2,800.0 58.45 60.91 2,179.4 2,069.75 985.4 951.0 1,812,658.45 170,599.83 2,900.0 59.45 61.12 2,230.6 2,120.92 1,027.0 1,026.1 1,812,671.31 170,622.64 2,923.2 59.34 61.22 2,242.5 2,132.75 1,036.6 1,043.6 1,812,674.29 170,627.95 T3 + 550 2,925.7 59.33 61.23 2,243.7 2,134.01 1,037.6 1,045.5 1,812,674.60 170,628.52 10 314" 3,000.0 59.04 61.32 2,281.8 2,172.08 1,068.2 1,101.5 1,812,684.06 170,645.51 3,100.0 58.39 61.11 2,333.7 2,223.98 1,109.5 1,176.3 1,812,696.82 170,668.22 3,200.0 58.42 61.38 2,386.3 2,276.57 1,150.3 1,251.0 1,812,709.43 170,690.87 3,300.0 59.23 61.53 2,438.1 2,328.40 1,191.3 1,326.0 1,812,722.10 170,713.64 3,400.0 59.56 63.93 2,488.8 2,379.06 1,231.4 1,402.3 1,812,734.50 170,736.81 3,500.0 59.23 68.53 2,539.7 2,429.96 1,266.2 1,481.0 1,812,745.30 170,760.71 3,600.0 58.59 73.14 2,591.2 2,481.51 1,294.2 1,562.0 1,812,754.04 170,785.31 DLSEV Vert Section (°1100ft) (ft) 0.00 0.13 0.48 0.09 0.89 -0.69 2.28 -3.56 2.69 -9.94 2.33 -19.47 2.72 -32.28 2.53 -49.88 0.57 -69.52 3.12 -91.85 5.66 -121.05 2.86 -156.63 5.49 -196.87 6.48 -246.22 3.43 -301.70 3.85 -359.77 4.94 -379.79 6.11 -422.31 1.26 -487.47 1.52 -524.11 1.74 -550.72 3.31 -612.75 5.38 -671.24 5.51 -725.44 4.19 -775.49 4.64 -804.00 3.57 -820.35 1.38 -860.81 1.24 -901.82 0.78 -943.85 0.53 -985.36 1.01 -1,026.97 0.59 -1,036.61 0.59 -1,037.63 0.40 -1,068.22 0.68 -1,109.51 0.23 -1,150.29 0.83 -1,191.29 2.09 -1,231.38 3.97 -1,266.20 4.00 -1,294.24 1/23/2007 11:27:29AM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGINAL • • ConocoPhillips Alaska Halliburton Company Planning Report -Geographic Sperry Drilling Services Database: Compass 2003.11 Company: ConocoPhillips Alaska, Inc. ~ Project: Kuparuk River Unit Site: .Kuparuk 1J Pad ~ Well: ,Rig: 1J-103 re: J-103 L2 Pilot Toe ` ' g Desi ; J-103 L2 Pilot Toe (wp11) Planned Survey 1J-103 L2 Pilot Toe iwpl t~ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing EasUng DLSEV Vert Section Iftl (°I (°I (ft) Iftl IR) fftl (m) (ml (,110oft) Ift) 3,700.0 58.20 78.60 2,643.7 2,534.02 1,315.3 1,644.4 1,812,760.64 170,810.38 4.66 -1,315.26 3,800.0 58.50 84.12 2,696.3 2,586.58 1,327.9 1,728.5 1,812,764.70 170,835.98 4.71 -1,327.94 3,900.0 58.71 89.20 2,748.3 2,638.62 1,332.9 1,813.7 1,812,766.41 170,861.94 4.34 -1,332.87 4,000.0 58.02 95.34 2,800.7 2,690.96 1,329.7 1,898.8 1,812,765.64 170,887.89 5.27 -1,329.68 4,100.0 58.79 104.14 2,853.3 2,743.59 1,315.6 1,982.6 1,812,761.53 170,913.45 7.53 -1,315.56 4,196.7 58.96 109.51 2,903.2 2,793.48 1,291.4 2,061.7 1,812,754.35 170,937.62 4.76 -1,291.36 Ugnu C 4,200.0 58.96 109.69 2,904.9 2,795.20 1,290.4 2,064.4 1,812,754.06 170,938.45 4.42 -1,290.40 4,300.0 59.15 115.05 2,956.3 2,846.65 1,257.8 2,143.7 1,812,744.31 170,962.68 4.60 -1,257.78 4,400.0 58.92 119.01 3,007.8 2,898.09 1,218.8 2,220.1 1,812,732.61 170,986.05 3.41 -1,218.79 4,500.0 58.58 122.96 3,059.7 2,949.97 1,174.9 2,293.4 1,812,719.42 171,008.51 3.39 -1,174.94 4,600.0 58.43 128.67 3,112.0 3,002.30 1,124.9 2,362.3 1,812,704.32 171,029.63 4.87 -1,124.87 4,681.3 58.93 131.03 3,154.3 3,044.57 1,080.4 2,415.6 1,812,690.89 171,045.97 2.55 -1,080.37 Ugnu B 4,700.0 59.47 130.85 3,163.9 3,054,16 1,069.8 2,427.8 1,812,687.70 171,049.70 3.03 -1,069.83 4,800.0 61.88 130.11 3,212.5 3,102.83 1,013.2 2,494.3 1,812,670.61 171,070.10 2.49 -1,013.21 4,831.9 62.13 130.07 3,227.5 3,117.79 995.1 2,515.8 1,812,665.14 171,076.71 0.80 -995.09 Ugnu A 4,900.0 62.63 130.05 3,259.1 3,149.36 956.3 2,562.0 1,812,653.41 171,090.89 0.73 -956.26 5,000.0 62.96 131.11 3,304.6 3,194.92 898.7 2,629.9 1,812,636.04 171,111.73 1.00 -898.72 5,100.0 63.11 134.42 3,350.2 3,240.47 838.4 2,695.4 1,812,617.81 171,131.82 2.95 -838.41 5,143.2 63.48 136.08 3,369.6 3,259.91 811.0 2,722.6 1,812,609.52 171,140.17 3.55 -810.98 K13 5,200.0 63.98 138.04 3,394.7 3,285.03 773.7 2,757.3 1,812,598.24 171,150.82 3.21 -773.71 5,300.0 66.13 142.89 3,437.4 3,327.70 704.4 2,815.3 1,812,577.25 171,168.67 4.90 -704.38 5,400.0 68.86 149.06 3,475.4 3,365.67 627.7 2,866.9 1,812,554.00 171,184.60 6.32 -627.70 5,500.0 71.99 154.74 3,509.2 3,399.55 544.7 2,911.1 1,812,528.81 171,198.26 6.20 -544.70 5,600.0 76.11 158.90 3,536.8 3,427.07 456.2 2,948.6 1,812,501.93 171,209.89 5.75 -456.21 5,700.0 78.36 161.92 3,558.3 3,448.62 364.1 2,981.1 1,812,473.95 171,220.01 3.70 -364.14 5,800.0 79.18 163.05 3,577.8 3,468.09 270.7 3,011.0 1,812,445.56 171,229.36 1.38 -270.75 5,900.0 79.87 165.15 3,595.9 3,486.25 176.2 3,038.0 1,812,416.81 171,237.81 2.17 -176.19 5,990.7 80.65 165.34 3,611.3 3,501.61 89.7 3,060.6 1,812,390.50 171,244.90 0.89 -89.70 / /7518"TOW 6,000.0 81.72 165.55 3,612.7 3,503.05 80.8 3,062.9 1,812,387.80 171,245.63 11.72 -80.81 6,100.0 89.38 168.00 3,619.9 3,510.17 -16.2 3,085.7 1,812,358.28 171,252.81 8.04 16.22 6,200.0 92.72 170.44 3,617.4 3,507.72 -114.4 3,104.4 1,812,328.40 171,258.74 4.14 114.41 6,300.0 91.81 170.08 3,613.4 3,503.66 -212.9 3,121.4 1,812,298.43 171,264.14 0.98 212.87 6,400.0 89.43 171.21 3,612.9 3,503.25 -311.5 3,138.0 1,812,268.43 171,269.43 2.63 311.47 6,500.0 92.56 175.50 3,610.6 3,500.91 -410.7 3,149.5 1,812,238.20 171,273.17 5.31 410.74 6,600.0 92.08 178.77 3,606.6 3,496.90 -510.5 3,154.1 1,812,207.80 171,274.83 3.30 510.54 6,700.0 92.63 180.49 3,603.0 3,493.31 -610.5 3,154.7 1,812,177.34 171,275.25 1.80 610.47 6,800.0 92.79 180.02 3,597.1 3,487.40 -710.3 3,153.2 1,812,146.92 171,275.03 0.49 710.28 6,900.0 92.75 176.77 3,593.8 3,484.12 -810.2 3,156.2 1,812,116.49 171,276.16 3.25 810.16 7,000.0 94.40 175.47 3,586.6 3,476.94 -909.6 3,163.6 1,812,086.19 171,278.67 2.09 909.62 7,100.0 92.63 175.99 3,580.1 3,470.35 -1,009.1 3,171.1 1,812,055.89 171,281.19 1.84 1,009.11 7,200.0 90.94 178.43 3,577.2 3,467.53 -1,108.9 3,176.5 1,812,025.49 171,283.07 2.97 1,108.91 1/23/2007 11:27:29AM Page 4 of 8 COMPASS 2003.11 Build 48 Local Co-ordinate Reference: 'Nell Rig: 1J-103 -Slot 1J-103 TVD Reference: Doyon 141 (28+g1.7) @ 1097ft (Doyon 141 (28+g1.7)) MD Reference: Doyon 141 (28+gt7) @ 109.7ft (Doyon 141 (28+81.7)) North Reference: True Survey Calculation Method: Minimum Curvature ~41GINAL • • `/ ConocoPhillips Alaska Halliburton Company Planning Report-Geographic (..~ Sperry Drilling Services Database: 'Compass 2003.11 Local Co-ordinate Reference: '`.'ell Rig: 1J-103 -Slot 1 J-103 I Company; `ConocoPhillips Alaska, Inc. ND Reference: Doyon 14 1 (28+81.7) @ 109.7 ft (Doyon 141 (28+81.7)) Project ' Kuparuk River Unit MD Reference: Doyon 14 1 (28+g1 ]) @ 109.7 ft (Doyon 141 (28+81.7)) Site: `' Kuparuk 1J Pad North Reference: True Well: Rig: 1J-103 Survey Calculat ion Method: Minimum Curvature Wellbore: 1J-103 L2 Pilot Toe Design; 1J-103 L2 Pilot Toe (wp11) - --- - __- - - __ _ 1 Planned Survey 1 J-103 L2 Fil ot Toe ~wp1 I I 1 Map Map MD Inclination Azimuth ND SSND +NI-S +EI_yy Northing Easting DLSEV Vert Section (ftl 1°) (°) Iftl Ift) Ift) Iftl (m) ("') (°nooft) (ft) j 7,300.0 91.00 181.90 3,575.8 3,466.13 -1,208.9 3,176.2 1,811,995.02 171,283.23 3.47 1,208.89 7,400.0 90.80 184.51 3,574.1 3,464.43 -1,308.7 3,170.5 1,811,964.59 171,281.71 2.61 1,308.70 7,500.0 90.97 186.31 3,572.7 3,462.96 -1,408.2 3,161.0 1,811,934.23 171,279.05 1.81 1,408.23 7,600.0 90.64 186.87 3,571.2 3,461.51 -1,507.6 3,149.4 1,811,903.93 171,275.77 0.65 1,507.55 7,700.0 90.92 184.80 3,569.9 3,460.18 -1,607.0 3,139.2 1,811,873.60 171,272.88 2.09 1,607.01 7,800.0 90.74 181.01 3,568.4 3,458.72 -1,706.9 3,134.1 1,811,843.16 171,271.57 3.80 1,706.85 7,900.0 90.67 178.87 3,567.2 3,457.48 -1,806.8 3,134.2 1,811,812.69 171,271.85 2.14 1,806.84 8,000.0 90.58 177.62 3,566.1 3,456.41 -1,906.8 3,137.3 1,811,782.23 171,273.02 1.25 1,906.78 8,100.0 90.75 176.26 3,564.9 3,455.18 -2,006.6 3,142.6 1,811,751.82 171,274.87 1.37 2,006.63 8,200.0 90.26 174.89 3,564.0 3,454.27 -2,106.3 3,150.7 1,811,721.46 171,277.57 1.46 2,106.30 8,300.0 89.78 176.52 3,564.1 3,454.40 -2,206.0 3,158.3 1,811,691.09 171,280.15 1.70 2,206.00 8,400.0 90.09 179.22 3,564.2 3,454.47 -2,305.9 3,162.1 1,811,660.65 171,281.54 2.72 2,305.92 8,500.0 90.38 181.94 3,563.9 3,454.17 -2,405.9 3,160.9 1,811,630.18 171,281.39 2.74 2,405.90 8,600.0 90.75 183.03 3,562.6 3,452.93 -2,505.8 3,156.3 1,811,599.73 171,280.23 1.15 2,505.78 8,700.0 90.37 182.98 3,561.8 3,452.11 -2,605.6 3,150.9 1,811,569.28 171,278.84 0.38 2,605.64 8,800.0 90.30 182.57 3,561.1 3,451.38 -2,705.5 3,146.1 1,811,538.83 171,277.61 0.41 2,705.52 8,900.0 90.14 182.31 3,560.9 3,451.22 -2,805.4 3,141.9 1,811,508.37 171,276.57 0.30 2,805.43 9,000.0 90.28 182.13 3,560.4 3,450.66 -2,905.4 3,138.0 1,811,477.91 171,275.60 0.23 2,905.35 9,100.0 90.10 181.22 3,560.1 3,450.43 -3,005.3 3,134.8 1,811,447.44 171,274.87 0.92 3,005.30 9,200.0 90.35 179.92 3,559.8 3,450.13 -3,105.3 3,133.9 1,811,416.97 171,274.84 1.33 3,105.29 9,300.0 90.53 180.25 3,559.0 3,449.25 -3,205.3 3,134.3 1,811,386.49 171,275.20 0.37 3,205.29 9,400.0 90.29 179.14 3,558.2 3,448.47 -3,305.3 3,133.8 1,811,356.02 171,275.29 1.13 3,305.28 9,500.0 89.82 176.93 3,558.1 3,448.35 -3,405.2 3,137.6 1,811,325.58 171,276.68 2.26 3,405.20 9,600.0 90.07 176.29 3,558.4 3,448.70 -3,505.0 3,143.8 1,811,295.17 171,278.81 0.69 3,505.01 9,700.0 90.35 175.84 3,557.9 3,448.21 -3,604.8 3,150.6 1,811,264.78 171,281.11 0.53 3,604.78 9,800.0 90.42 176.16 3,557.2 3,447.53 -3,704.5 3,157.8 1,811,234.40 171,283.54 0.33 3,704.51 9,900.0 90.39 177.25 3,556.5 3,446.80 -3,804.3 3,163.6 1,811,204.00 171,285.56 1.09 3,804.34 10,000.0 89.50 177.43 3,556.4 3,446.73 -3,904.2 3,168.0 1,811,173.56 171,287.14 0.91 3,904.24 10,100.0 89.37 177.56 3,557.6 3,447.90 -0,004.1 3,172.5 1,811,143.13 171,288.73 0.19 4,004.13 10,200.0 90.23 177.86 3,558.1 3,448.36 -0,104.1 3,176.5 1,811,112.68 171,290.18 0.92 4,104.05 10,300.0 89.34 179.34 3,558.2 3,448.49 -4,204.0 3,179.0 1,811,082.23 171,291.21 1.72 4,204.01 10,400.0 90.62 180.07 3,558.5 3,448.78 -4,304.0 3,179.5 1,811,051.75 171,291.58 1.48 4,304.01 10,500.0 89.11 179.85 3,558.5 3,448.79 -4,404.0 3,179.5 1,811,021.28 171,291.82 1.53 4,404.00 10,600.0 88.59 179.26 3,560.6 3,450.85 -0,504.0 3,180.3 1,810,990.81 171,292.29 0.79 4,503.98 10,700.0 90.08 180.49 3,561.7 3,452.03 -4,604.0 3,180.5 1,810,960.34 171,292.62 1.93 4,603.97 10,800.0 90.38 183.73 3,561.3 3,451.62 -4,703.9 3,176.7 1,810,929.88 171,291.67 3.26 4,703.88 10,900.0 90.54 183.56 3,560.5 3,450.78 -0,803.7 3,170.3 1,810,899.45 171,289.96 0.23 4,803.67 11,000.0 89.78 182.75 3,559.8 3,450.12 -4,903.5 3,164.6 1,810,869.01 171,288.46 1.11 4,903.50 11,084.4 87.06 180.08 3,562.5 3,452.77 -0,987.8 3,162.5 1,810,843.31 171,288.02 4.51 4,987.84 Pilot TieAn to 1J-103 L2 ~ 11084' MD, 3562' ND -Hold Inc 8 Aun to Fault 11,100.0 87.06 180.08 3,563.3 3,453.57 -5,003.4 3,162.4 1,810,838.57 171,288.05 0.00 5,003.40 11,187.3 87.06 180.08 3,567.8 3,458.06 -5,090.6 3,162.3 1,810,811.99 171,288.22 0.00 5,090.61 WSAK D 11,200.0 87.06 180.08 3,568.4 3,458.71 -5,103.3 3,162.3 1,810,808.13 171,288.25 0.00 5,103.27 11,300.0 87.06 180.08 3,573.5 3,463.84 -5,203.1 3,162.2 1,810,777.69 171,288.44 0.00 5,203.13 11,400.0 87.06 180.08 3,578.7 3,468.98 -5,303.0 3,162.0 1,810,747.26 171,288.63 0.00 5,303.00 1/23/2007 11:27:29AM Page 5 of 8 COMPASS 2003.11 Build 48 OR161NAL ~- s ' P~' ~~ ~ Halliburton Company ~,., Ot lUC 11 IEJS Alaska Planning Report -Geographic Sperry Drilling Services D O ate Reference: ~ell Ri9 1 Company: ' ConocoPhil ps Alaska, Ina ND Reference ~ o 41 (28 81 7 ) @ 109.7ft (Doyon 141 (28+81.7)) Project: "" ruparuk River Unit MD Reference: Doyon 141 (28+g1.7) @ 109.7ft (Doyon 141 (28+81.7)) '~ Site: Kuparuk 1J Pad North Reference: True ' Well: Rig: 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-103 L2 Pilot Toe Design: ~ J-103 L2 Pilot Toe (wp11) Planned Survey 1J-103 L2 Pilot Toe (wp11) MD Inclination Azimuth ND SSTVD +N/-S +FJ-W Iftl (°) 1°1 Ift) lft) (ft) Ift) 11,410.0 87.06 180.08 3,579.2 3,469.49 -5,313.0 3,162.0 Pilot: Proposed Fault -Begin Dir 3°/700 ' ~ 11410' M D, 3579' TVD 11,500.0 89.72 180.52 3,581.7 3,472.02 -5,402.9 3,161.5 11,531.6 90.66 180.68 3,581.6 3,471.92 -5,434.5 3,161.2 Pilot: End Dir ~ 17532' MD, 3582' TVD 11,600.0 90.66 180.68 3,580.8 3,471.13 -5,502.9 3,160.4 11,700.0 90.66 180.68 3,579.7 3,469.99 -5,602.9 3,159.2 11,800.0 90.66 180.68 3,578.5 3,468.84 -5,702.9 3,158.0 11,900.0 90.66 180.68 3,577.4 3,467.69 -5,802.9 3,156.9 11,942.4 90.66 180.68 3,576.9 3,467.21 -5,845.3 3,156.4 Pilot Begin Dir 3°N00' @ 11942' MD, 3577' TVD 11,978.3 91.71 180.45 3,576.2 3,466.47 -5,881.2 3,156.0 Pilot End Dir ~ 11978' MD, 3578' TVD 12,000.0 91.71 180.45 3,575.5 3,465.82 -5,902.9 3,155.8 12,100.0 91.71 180.45 3,572.5 3,462.84 -6,002.8 3,155.1 12,200.0 91.71 180.45 3,569.6 3,459.85 -6,102.8 3,154.3 12,228.3 91.71 180.45 3,568.7 3,459.01 -6,131.1 3,154.0 Pilot: Continue Geosteering in D-Sand ~ 12228' MD, 3569' TVD - 7J-703 LZ T72 (wp10) 12,250.7 91.49 180.45 3,568.1 3,458.38 -6,153.4 3,153.9 12,300.0 91.49 .180.45 3,566.8 3,457.10 -6,202.7 3,153.5 12,400.0 91.49 180.45 3,564.2 3,454.51 -6,302.7 3,152.7 12,500.0 91.49 180.45 3,561.6 3,451.92 -6,402.7 3,151.9 12,600.0 91.49 180.45 3,559.0 3,449.32 -6,502.6 3,151.1 12,700.0 91.49 180.45 3,556.4 3,446.73 -6,602.6 3,150.4 12,800.0 91.49 180.45 3,553.8 3,444.13 -6,702.5 3,149.6 12,828.0 91.49 180.45 3,553.1 3,443.41 -6,730.6 3,149.4 1J-103 L2 T1 3 (wp10) 12,900.0 90.77 180.45 3,551.7 3,441.99 -6,802.5 3,148.8 12,952.5 90.24 180.45 3,551.2 3,441.53 -6,855.0 3,148.4 13,000.0 90.24 180.45 3,551.0 3,441.33 -6,902.5 3,148.0 13,100.0 90.24 180.45 3,550.6 3,440.91 -7,002.5 3,147.2 13,200.0 90.24 180.45 3,550.2 3,440.49 -7,102.5 3,146.5 13,300.0 90.24 180.45 3,549.8 3,440.07 -7,202.5 3,145.7 13,337.6 90.24 180.45 3,549.6 3,439.91 -7,240.1 3,145.4 1J-103 L2 T1 4 (wp10) D-Toe 13,400.0 87.12 180.45 3,551.0 3,441.34 -7,302.5 3,144.9 13,405.6 86.84 180.45 3,551.3 3,441.64 -7,308.0 3,144.9 4 112 13,500.0 82.12 180.45 3,560.4 3,450.71 -7,402.0 3,144.1 13,600.0 77.12 180.45 3,578.4 3,468.72 -7,500.3 3,143.4 13,646.0 74.82 180.45 3,589.6 3,479.87 -7,544.9 3,143.0 1J-103 L2 (wp17j Top-C 13,700.0 72.12 180.45 3,604.9 3,495.23 -7,596.7 3,142.6 Map Map Northing Easting OLSEV Vert Section lml Im) (°It0oft) Iftl 1,810,744.21 171,288.65 0.00 5,312.99 1,810,716.80 171,288.72 3.00 5,402.94 1,810,707.16 171,288.70 3.00 5,434.55 1,810,686.32 171,288.61 0.00 5,502.93 1,810,655.85 171,288.49 0.00 5,602.92 1,810,625.37 171,288.37 0.00 5,702.91 1,810,594.90 171,288.25 0.00 5,802.89 1,810,581.99 171,288.20 0.00 5,845.25 1,810,571.04 171,288.18 3.00 5,881.17 1,810,564.43 171,288.17 0.00 5,902.87 1,810,533.96 171,288.17 0.00 6,002.82 1,810,503.50 171,288.17 0.00 6,102.77 1,810,494.88 171,288.17 0.00 6,131.05 1,810,488.06 171,288.17 1.00 6,153.41 1,810,473.03 171,288.17 0.00 6,202.73 1,810,442.57 171,288.17 0.00 6,302.69 1,810,412.10 171,288.17 0.00 6,402.66 1,810,381.63 171,288.17 0.00 6,502.62 1,810,351.17 171,288.17 0.00 6,602.58 1,810,320.70 171,288.17 0.00 6,702.55 1,810,312.15 171,288.17 0.00 6,730.58 1,810,290.23 171,288.17 1.00 6,802.52 1,810,274.22 171,288.17 1.00 6,855.04 1,810,259.75 171,288.17 0.00 6,902.51 1,810,229.28 171,288.17 0.00 7,002.51 1,810,198.80 171,288.17 0.00 7,102.51 1,810,168.32 171,288.17 0.00 7,202.50 1,810,156.86 171,288.17 0.00 7,240.10 1,810,137.85 171,288.17 5.00 7,302.47 1,810,136.16 171,288.17 5.00 7,308.03 1,810,107.52 171,288.17 5.00 7,402.00 1,810,077.55 171,288.17 5.00 7,500.33 1,810,063.95 171,288.17 5.00 7,544.94 1,810,048.17 171,288.17 5.00 7,596.71 1/23/2007 11:27:29AM Page 6 of 8 COMPASS 2003.11 Build 48 OR!61NAL • • ~~ C PE' Halliburton Company Ot100 tl lp5 0 Planning Report -Geographic Alaska Database: Compass 2003.11 Local Co-ordinate Reference: Company: `.' ConocoPhillips Alaska, Inc. TVD Reference: Project: Kuparuk River Und MD Reference: Sfte: Kuparuk 1J Pad North Reference: Well: Rig: 1J-103 Survey Calculation Method: Welltmre: 1J-103 L2 Pilot Toe Design: 1J-103 L2 Pilot Toe (wp11) Planned Survey 1J-103 L2 Pilot Toe (wp11) Map Map MD Inclination Azimuth ND SSTV^ +W-S +E/-W Northing Fasting OLSEV Vert Section (ft) (°I (') lft) (ft) (ftl (ft) lm) (ml (°110oft) (ft) 13,764.7 68.89 180.45 3,626.5 3,516.82 -7,657.7 3,142.1 1,810,029.59 171,288.17 5.00 7,657.68 1J-103 L2 (wp11) Top-B 13,782.3 68.01 180.45 3,633.0 3,523.30 -7,674.1 3,142.0 1,810,024.59 171,288.17 5.00 7,674.09 Pilot BHL ~ 13782' MD, 3633' TVD: 169' FNL, 693' FWL - Sec12-T10N-R10E -1J-1 03 L2 (wp11) Pilot-Toe Geology Targets 1 J-103 L2 Pilot Toe TVD Target Name +W-S +El-W Northing Fasting (f~ -Shape ft ft (m) (m) 3,568.7 1J-103 LZ T12 (wp14) -6,131.1 3,154.0 1,810,494.88 171,288.17 - Point 3,549.6 1J-103 L2 T74 (wp10) D-Toe -7,240.1 3,145.4 1,810,156.86 171,288.17 - Point 3,626.5 1J-103 L2 (wpli) Tap-B -7,657.7 3,142.1 1,810,029.59 171,288.17 -Point 3,633.0 1J-103 L2 (wp11} Pilot-Toe -7,674.1 3,142.0 1,810,024.59 171,288.17 -Point 3,553.1 1J-103 L2 T13 (wp10) -6,730.6 3,149.4 1,810,312.15 171,288.17 -Point 3,589.6 1J-103 L2 (wp11}Top-C -7,543.9 3,143.0 1,810,064.26 171,288.17 - Point I Prognosed Casing Points I~ Measured i Vertical Caaing Hole t Depth Depth Diameter Diameter (ft) (~ fnl lint 2,925.7 2,243.7 10.750 13.500 5,990.7 3,611.3 7.625 9.875 13,405.6 3,551.3 4.500 6.750 ~. 1 !J Sperry Drilling Services Wetl Rig: 1 J-103 -Slot 1 J-103 Doyon 141 (28+81.7) ~ 109.7ft (Doyon 141 (28+81.7)) Doyon 141 (28+81.7) ~ 109.7ft (Doyon 141 (28+81.7)) True Minimum Curvature 1/23/2007 11:27:29AM Page 7 of 8 COMPASS 2003.11 Build 48 '~~1.... • ConocoPhillips Alaska Halliburton Company Planning Report -Geographic • ~. Sperry Drilling Services Database: Compass 2003 11 Local Co-ordinate Reference: ' Well Rig: 1J-103 -Slot 1J-103 Company: r ConocoPhillips Alaska, Inc ND Reference: Doyon 141 (28+g1.7) @ 109.7ft (Doyon 141 (28+81.7)) Project: Kuparuk River Unit MD Reference: Doyon 141 (28+g1 ]) @ 109.7ft (Doyon 141 (28+81.7)) Site: 'i Kuparuk 1 J Pad North Reference: True Well: `Rig: 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: ` 1J-103 L2 Pilot Toe Design: ' 1J-103 L2 Pilot Toe (wp11) Prognosed Formati on Intersection Points Measured Vertical Depth Inclination Azimuth Depth +Nl-E +E/-W ! (ftl (°) (°1 (ftl fftl Iftl Name 1,632.7 46.14 30.92 1,518.9 379.79 232.09 Base Perm 1,857.7 50.19 34.85 1,663.5 524.11 326.00 T3 2,362.0 59.46 59.18 1,955.4 804.00 621.31 K15 2,923.2 59.34. 61.22 2,242.5 1,036.61 1,043.64 l'3+550 4,196.7 58.96 109.51 2,903.2 1,291.36 2,061.73 UgnuC 4,681.3 58.93 131.03 3,154.3 1,080.37 2,415.61 Ugnu 8 4,831.9 62.13 130.07 3,227.5 995.09 2,515.79 Ugnu A 5,143.2 63.48 136.08 3,369.6 810.98 2,722.61 K73 5,747.6 78.75 162.08 3,567.8 319.86 2,995.62 WEAK D Plan Annotations Measured Vertical Depth Depth lft) (ft) 11,084.4 3,562.5 11,410.0 3,579.2 11,531.6 3,581.6 11,942.4 3,576.9 11,978.3 3,576.2 12,228.3 3,568.7 13,782.3 3,633.0 Local Coordinates +NI-S +E/-W (ft) (~ -4,987.8 3,162.5 -5,313.0 3,162.0 -5,434.5 3,161.2 -5,845.3 3,156.4 -5,881.2 3,156.0 -6,131.1 3,154.0 -7,674.1 3,142.0 Comment Pilot: Tie-On to 1J-103 L2 @ 11084' MD, 3562' ND -Hold Inc & Azm to Fault Pilot: Proposed Fault -Begin Dir 3°/100' @ 11410' MD, 3579' ND Pilot: End Dir @ 11532' MD, 3582' ND Pilot: Begin Dir 3°/100' @ 11942' MD, 3577' ND Pilot: End Dir @ 11978' MD, 3576' ND Pilot: Continue Geosteering in D-Sand @ 12228' MD, 3569' ND Pilot: BHL @ 13782' MD, 3633' ND: 169' FNL, 693' FWL - Sec12-T10N-R10E 1/23/2007 11:27:29AM Page 8 of 8 COMPASS 2003.11 Build 48 o, i ~~ ~~ • ConocoPhillips Alaska Plan: 1J-103 L2 Pilot Toe (wp11) Sperry Drilling Services Anticollision Summary 23 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Rig: 1J-103 1J-103 L2 Pilot Toe Local Coordinate Origin: Centered on Well Rig: 1J-103 -Slot 1J-103 Viewing Datum: Doyon 141 (28+81.7) @ 109.7ft (Doyon 141 (28+81.7)) TVDs to System: N North Reference: True Unit System: API ~i Sperry Drilling Services ~~~' ~~~ • • ConocoPhillips Alaska Halliburton Company Anticollision Report L Sperry drilling Services Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Srte Error: O.Oft I Reference Well: Rig: 1J-103 l Well Error: QOft Reference Wellbore 1J-103 L2 Pilot Toe Reference Design: 1J-103 L2 Pilot Toe (wp11) Loca! Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Rig: 1J-103 -Slot 1J-103 Doyen 141 (28+g1.7) @ 109.7ft (Doyon 141 (28+81.7)) Doyon 141 (28+81.7) @ 109.7ft (Doyon 141 (28+81.7)) True Minimum Curvature 2.00 sigma Compass 2003.11 Offset Datum Reference 1J-~ 03 L2 Pilot Toe (wp11) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.Oft Error Model: ISCWSA Depth Range: 11,084.4 to 13,782.3ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,575.4ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1!23;2007 From To (ft) (ft) Survey (Welltmre) Tool Name Description 50.7 632.7 1J-103 Gyros (1J-103PB1) CB-GYRO-SS Camera based gyro single shot 662.7 5,912.6 1J-103 MWD (1J-103PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,991.7 11,084.4 1J-103 L2 MWD (1J-103 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,084.4 13,782.3 1J-103 L2 Pilot Toe (wp11) (1J-103 L2 Pil ot To~ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/232007 1:09:45PM Page 2 of 3 COMPASS 2003.11 Build 48 i.~ [Fwd: Re: Changes in 1J-103] Subject: [Fwd: Re: Changes in 1 J-10 ~] From: Thomas Maunder <tommaunderC;admin.state.ak.us> Date: Tue, 23 Jan 2007 09:17:45 -0900 ~['o: h~ulcl~ ~I~h~,ina~ < I::~ncl~,.I..~I~hon~a,~ u~~~<>n~~c~~hlullips.c~>>Z~ ..brume Eggei7ie~~r -~Ier~~mc.C.L~~~~n~c~ci ~r;~~~nuc~~phillii~~.cc~r» ~~. C'IliT~ :~1~-or~l "(~hi~~..~~l~~~rci~~rcon~~coi~llillii~;.cc~~7i Gentlemen, Here is a message I exchanged with one of CPAI's engineers regarding a currently operating West Sak well. It appears that the L2 lateral of 1J-103 has been drilled well beyond the presently permitted depth (11007') plus 500'. While I realize that operations are subject to change based on data obtained while drilling, CPAI should have contacted the Commission some time back regarding the changed plans for this lateral. It appears that the reasons for changing the permitted plans are valid and a successful outcome has been realized, however that does not relieve CPAI as operator from the obligations imposed by the regulations. I would appreciate if you would remind your engineers and the asset of the regulatory requirements. In this case it looks like there was a "foul" but no harm and the matter will not likely be pursued further. Please advise me when the notifications have been made. Call or message with any questions. Tom Maunder, PE AOGCC ------- Original Message...-------= Subject:Re: Changes in 1J-.103 Date:Tue, 23 Jan 2007 09:05:12 -0900 From:Thomas Maunder <tozx~ r...aunder~;adrnitl.state.ak.us> Organization:State of Alaska To:Greener, Mike R. <M1~e.R.Gree~~er~ci;'conoco illi s,con~=> CC:Steve Davies <steve da~~iesra?admin.state.ak.us= References:<=C)F..28~9Ci7C()D=1F7~3F352ED171 I30273A295I3F..,11 C(ca.:aneexnih2.conoco.net> Mike, I have spoken to the Commissioners. CPAI needs to get the revised paperwork for 1J-103L2 to us as soon as possible. Please refer to 20 AAC 25.015 (b). The outcome of this will be a the issuing of a revised permit for 1J-103L2. So far as I know the PTD and API number will not change. I look forward to receiving the paperwork. Tom. Maunder, PE AOGCC Greener, Mike R. wrote, On 1/23/2007 8:56 AM: rat tl~ presel~lt time :1.2,707' -----Original Message----- From: Thomas Maunder [mailta:tam maunder~~admin.state.ak.us] Sent: Tuesday, January 23, 2007 8:52 AM To: Greener, Mike R. ~ "` ~ ~~ ~~~ 1 of 3 3/20/2007 10:13 AM Sub]ect: RE: Changes in 1J-103 ~+rom: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Tue, 23 Jai 2007 09:12:9 -0900 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: Steve Davies <stave davies~a)admut.state.ak.us> I have the directional planner working the directional plan now and the geo has provided him with the proposed X-Y for where the tail would end in the `B" sand. Sharon will put die paperwork together and you should have it this after~~oon. Sorry for this late notice. 1VIy fault, I should havelet you know over the weekend. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, January 23, 2007 9:05 AM Yo: Greener, Mike R. Cc: Steve Davies Sulbject: Re: Changes in 1J-103 Mike, I have spoken to the Comrnissioz~ers. CPAI needs to get the revised paperwork for 1J-103L2 to us as soon as possible. Fleaseref~r to 20 AAC 25.015 (b). The outcome of this will be a the issuing of a revised permit for'IJ-103L2. So far as I know the PTD and API number will not change. I look forward to receiving the paperwork Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 1/23/2007 8:56 AM: At the present time 12,707' -----Original Message----- Frort~: Thomas Maunder [maiito:tom maunder@admin.state ak us] Sent: Tuesday, January 23, 2007 8:52 AM 1'0: Greener, Mike R. Cc: stave Davies Subject: Re: Changes in 1J-103 Mike, What is your present TD? 1J-103L2 is permitted to 11007' and which without further authorization limits TD to 11507'. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 1/23/2007 8:34 AM: There are two items to report to you about. • • 1. The LEM and hook assembly for the "B" lateral ran into problems which required us to attempt to retrieve the LEM. {The LEM got twisted during the setting attempt) We were unsuccessful in retrieving the LEM after spending $1.8 MM and about 12 days. The asset determined that we would continue on with the well and drill and complete the "D" lateral. If, through GeoChem analysis, it was determined later that the "A" or "B" lateral were not producing, then one or two windows would be cut above the "D" window and lateral would be drilled into the non-producing zone. These additional windows, if required, would be placed directly above the "D" sand and would be in the bottom of the K 13 interval and would not be in the Ugnu sand. 2. The Asset decided for the "D" lateral that they wanted to check to see if the sand south of the fault located at +/- 11,400' would be wet as it was when we crossed the same fault on the "B" lateral If the sand is not wet, then we would drill to a depth +/- 13,400' to then drill a tail down into the "B" sand to see if the "B" sand was no longer wet. If the "B" sand proved to be not wet then the 1 J-13 5, directly south of the 1 J-103, could then be drilled as a dual lateral producer. If the "B" was still wet then the 1J-135 would likely become just a single lateral producer. Otherwise, if the "D" sand is wet after crossing the fault then we would TD the well there and it would be highly likely that the 1 J-135 would not be drilled. Status of the well this morning: We have crossed the fault on the "D" lateral and the sand is not wet. So the plan forward is to drill to 13,400' and then check the "B" sand. Please let me know our process forward for the state in amending the permit as the TD of the "D" sand will be past the 500' allowance. Mike Greener «Greener, Mike R..vcf» • • TRANSIVTITTAI, LET'T'ER CFIECKLIST VVEGG YAIVtE K2,~.C. /.?"- /U3 L 2- ~~~ - ~s s~~~ PTD# ZD~.- /l~ Develo meat Service Ex lorato ~ Strati ra hic Test P P ry g P IYon-Conventional Well Circle Appropriate Getter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER 1~'HAT l {OPTIONS) I APPLIES ~ ' L I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing I well K.2L~ ~~" ~~~ (If [act two digits in ~ Permit No. Z~o ~~ , API No. 30-~-J~3~>~,lt~ -G~ API number are ,' between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ~ In accordance with 20 AAC 23.003(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number j ~ ~ (30- - -_~ from records, data and logs i ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION 123.0». Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing i ~ exception. assumes the i ~ liability of any protest to the spacing exception that may occur. ~ ,DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in ; i i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or i ~ I from where samples are first caught and 10' sample intervals j through target zones. ;Please note the following special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after ~Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the !Commission to obtain advance approval of such water wel! testing I program. 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N N __--_ _---._ N ._ N N _.__ N N -_ N N _. _-___ N M M M M M_~ . M M_ M M_ M_ ~ V ~ O 1 O O N O C N ~ N aN-. m N N O m U O . .- ~ w ~ N ~ ~ ~ N~ ~ N O ~ N! _ W ~ L r , i C i I ~ ° N ~ C ~ a ~ ~ c a ~ I ° ° a o U W ~ ~ ~ a ~- ~' ~ d ¢ w F- a i ~ Q' ~ a a s W ~~ ;a, - ,, ~LASS~i OIL A1~TD G~5 CO1~T5ERQATIOI~T COMhII5SIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 7 ~„ o Re: Kuparuk River Field, West Sak Oil Pool, 1J-103L2 ConocoPhillips Alaska, Inc. Permit No: 206-116 Surface Location: 2226' FSL, 2441' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 2517' FSL, 717' FEL, SEC. O1, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-103, Permit No. 206-114, API No. 50-029-23318-00. Production should continue to be reported as a function of the original API number stated above. 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. When providing notice for a representative of the Commission to witness any required test, cont field inspector at (907) 659-3607 (pager). DATED this~day of August, 2uuc~ • FRANK H. MURKOWSKi, GOVERNOR cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 DECEIVED JUL 2 8 2006 ~lasi~a Qii ~ Gas Cons. Commission Anctlarage 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone Q 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydr s ^ Shale Gas 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 , 11. Well Name d Number: 1J-103L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11007' ND: 3523' 12. eld/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2226' FSL, 2441' FEL, Sec. 35, T11 N, R10E, UM• 7. Property Designation: • ADL 25661 & 25662 West Sak Oil Pool ' Top of Productive Horizon: 2553' FSL, 554' FWL, Sec. 36, T11 N, R10E, UM ~ 8. Land Use Permit: ALK 471 & 21 13. Approximate Spud Date: 11/27/2006 Total Depth: 2517' FSL, 717' FWL, Sec. 01, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles i 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 y- 5946037 ~ Zone- 4 10. KB Eleva ' n (Fleignt a ve GL): 28' RKB feet 15. Distance to a est / ~ Well within Pool: 1J-14 , 9454' 16. Deviated wells: Kickoff depth: 5670. ft. Maximum Hole Angle: 93° deg 17. imum Anticipated Pressures in psig (see 20 AAC 25.035) 7 3i• ownhole: 1614 psig Surface: 1220 psig • 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size pec ons ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' . 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 80' 28' 28' 2880' • 2242' 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 6805' 28' 28' 6805' 3790' 410 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 5337' 5670' 3587' 11007' 3523' see above 19 PRESENT WELL CONDITI SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): lugs (measured) Effective Depth MD (ff): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural ,~ Surface Intermediate Production ,( Liner Perforation Depth MD (ft): G., Perforation Depth TVD (ft): 20. Attachments: Filin Fee ~ BOP Sketch Drilling Program^/ Time v. Depth Plot Shallow Hazard Analysis ~ Prop Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: ommission Representative: Date: 22. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Na a Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signatur \ ~ ~ Phone 26 S _G~3t~ Date 2 ~Z 7 Ctis1~ P h ron Drak Commission Use Only Permit to Drill Number: ~p " ~~~ API Number: p r~7'Q 50- ~Z / ' 2 ~7 ~/ O - ~p ` Permit Approval Date: v~ , See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No Q• I g req'd: Yes ^ No [a/ Other: ~d ~~~~~~c,~-~,5 ~`Qh~~ H2S measures: Yes ^ No Dire na y req'd: Yes [[]~ No ^ ROVED BY THE COMMISSION DATE: ~• ~ O~ ,COMMISSIONER J• Form 10-401 Revised 12/2005 ~ ~.~~ ~ ~ ~~ ~ ~ / ~ Submi in Duplicate C~ Applic~or Permit to Drill, Well 1 J-103 L2 Revision No.0 Saved: 27-Jul-06 Permit It -West Sak Well #1J-103 L2 ~~~~~ r.~ ~k Application for Permit to Drill Document *~; Ala III M d x i m i x E Vlel I yvlu e 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) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil ease) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1J-103L2 PERMIT IT Page 1 of 6 Printed: 27-Jul-06 ORIr,IN.AL • Applic~or Permit to Drill, Well 1 J-103 L2 Revision No.O Saved: 27-Jul-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-103 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property`s owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,226' FSL, 2 441' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,946,037 Eastings: 558,766 Pad Elevation 81.0' AMSL Location at Top of Productive interval 2,553' FSL, 554' FWL, Section 36, T11N, R10E West Sak ~~D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 5,670 Northings: 5,946,389 Eastings: 561,758 Total Vertical De th, RKB: 3,587 Total Vertical De th, SS: 3,478 Location at Total De th 2,517' FSL, 717' FWL, Section 01, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 11, 007 Northings: 5,941,075 Eastings: 561,968 Total Vertical De th, RKB: 3 523 Total Vertical De th, SS: 3,414 and (D) other information required by 20 AAC 25.050(b); ;IGINAL 1J-103L2 PERMIT IT Page 2 of 6 Printed: 27-Jul-O6 Applici~or Permit to Drill, Well 1J-103 L2 Revision No.O Saved: 27-Jul-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only afi-ected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. 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 following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. 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 "D" sand formation is 1,220 psi, calculated thusly: MPSP = (3,587 ft TVD)(0.45 - 0.11 psi/ft) = 1,220 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); The parent wellbore, iJ-103, 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. 1J-903L2 PERMIT !T Page 3 of 6 Printed: 27-Jul-06 Applic~or Permit to Drill, Well 1J-103 L2 Revision No.O Saved: 27-Jul-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/T-/D OD (in (in) t Ib/ft Grade Connection ft) ft) ft Cement Pro ram 4-1/2 ~~ 6-3/4 A Sand 11.6 L-80 BTC 9,040 6,054 / 3,659 15,094 / 3,749 Slotted- no cement slotted Lateral (1J-103) 4-1/2 6-3/4" 13 Sand 11.6 L-80 BTC 5,054 5,954 / 3,647 11,008 / 3,596 Slotted- no cement d La - ~ _-~ 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 5,337 5,670 / 3,587 11,007 / 3,523 Slotted- no cement slotted Lateral (1J-103 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on 1)-103 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density ) 8.6 Plastic Viscostiy (Ib/100 sf) 15 - 25 Yield Point (cP) 18 - 28 HTHP Fluid loss (ml/30 min @ 200 si 8 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stability 650-900 Drilling fluid practices will be in accordance with appropriate 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 Rig 141. 1J-103L2 PERMIT lT Page 4 of 6 Printed: 27-Jul-O6 OR161NAL • Applic~or Permit to Drill, Well 1J-103 L2 Revision No.0 Saved: 27-Jul-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); 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 following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.06i(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 application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-103 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,670' MD / 3,587' TVD, the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 11,007' MD / 3,523' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 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. 1J-103L2 PERMIT IT Page 5 of 6 Printed: 27-Jul-06 Q~~GlNAL • Applic~or Permit to Drill, Well 1 J-103 L2 Revision No.0 Saved: 27-Jul-06 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down ROPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-103L2 PERMIT IT Page 6 of 6 ~ R I G I f~ A L Printed: 27-Jul-06 • • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-103 -Slot 1 J-103 1 J-103 L2 Plan: 1J-103 L2 (wp06) Proposal Report 26 July, 2006 u r ,$t: Sperry Drilling services OR!61NAL w N ~ b N C hone} ~ ~_ F ° L ~ N ~ d J > N J ~ d N p .n Y c 0 - r p O ~° 'MM 3 r O O v 3 r W cu°'i u~+c cM¢ N O mw~e-M OI Of O~~ >Y3 m Y N J dv- OD N ~ M~ V/~ a 3 Y Yr~N ^ LL r F-» Q mO Z~nv o 3 i~~J L (O t- M C O Q Q ap r Z Anooc'o.~y.M--°a m~°c a~ f l r• I~ G N t~ N 0~ 0 p W n ~0 M N O vl O r w ~ ~ ~ a 0 i 0< ~ '. ~ 8 '~ ~ r ~ . 7 / C d r ~~ L O f D 0 0 M W O N ~D m~ D 'L r~NNO<OON Z O O n a0 n 0 ', ~ ', ', ; : : t O O O O Y Yd O~ r r Q sooooo000o 000000000 y Nn °r ~~ N ~~ 3 ~ i+ ~ A N U'~im a0°eu~'ie m u' U ~ '~ ' V s~+ d C ~! ~ . ~ O v i p N 0Of N W e-NMN be-~-~- NMMMM 0000 ~Nnt") ~ O ' ', N r O a L Z ~ N M v~ n c o n W m I C O N . A d N M M -- _-- - t- N p _ p N N ~ ~~, ~~, y. o ' Q 3 0 Mo fn ~ ~~ n ; ~ ' ~ , ~ N O O J M O J M O N eT N > ~~ ~ m m 0000 L ' O o '~ M v 0 o a Z ~ o ~ I ~ O N W m I~ d J ~ o 2 O O N ~ J ~ CN'] J O FQ- a oio - ___ _ N ~ N _ J ~ W ~ '. ~ O 3 ~ ' ° m °v 0006- o c+~ L I~ v Z ~ rn O N ~ p O ~ ' o O + ij N IB N Zo ~ 3 0 +o : '. v U F- N . _ _ _ _ _ _ _ _ _ _ _ - N J N O 0008 o ~ o N v V1 ~ Q. M ', 2° n 3 M N ~ Q N L a i o - ~ - ~ ~ ° ° V 0 n 3 O _ _ N r V OOOL J o ° °o 0 3 1° N J M O O ° N I 10009 3~ ° I I ,O6 . I o08 p o o ~ ~ Q 3 ° Q! C] ~° y tY i ~ps ~ n ~ i g m o o J a o r "~ ° ° ° °o °o °o Q o o o T i N M M V ~ u1 t ui da eai a ana ORIGINAL 1-' Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Inc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1JPad North Reference: Well: Plan 1 J-103 Survey Calculation Method: Wellbore: 1J-103 L2 Design: 1J-103 L2 (wp06) Sperry Drilling S®rvices 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 1 J-103 - SIot1 J-103 Well Position +N/-S 0.00 ft Northing: +E/-W 0.00 ft Easting: Position Uncertainty 0.00 ft Wellhead Elevation: Wellbore 1J-103 L2 Magnetics Model Name Sample Date BGGM2005 8/1/2006 ~_ Desil gn A 1J-103 L2 (wp06) - Audit Notes: 5,946,037.40 ft Latitude: 558,766.50 ft Longitude: ft Ground Level: Declination Dip Angle (°) (°) 24.01 80.78 Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/-S i (ft) (ft) I 28.00 0.00 Tie On Depth: +EI-W (ft) 0.00 70° 15' 47.418" N 149° 31' 29.659" W 81.00 ft Field Strength (n'r) i 57,564 5,670.64 Direction (°) 180.00 7/26/2006 9:56:31AM 'l Page 2 of 7l~A~1 COMPASS 2003.118ui1d 50 t ° i i F.J ~ ~ ! ~ / Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Ina ND Reference: Project: Kuparuk River Unite. MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-103 Survey Calculation Method: Wellbore: 1 J-103 12 Design: 1J-103 L2 (wp06) 1 Sperry Drilling Service Well Plan 1J-103 -Slot 1J-103 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/_yy Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°MOOft) (°/100ft) (°) 5,670.64 77.00 165.03 3,587.00 328.27 2,994.34 0.00 0.00 0.00 0.00 5,682.64 78.91 165.03 3,589.50 316.94 2,997.37 15.90 15.90 0.00 0.00 5,712.64 78.91 165.03 3,595.28 288.50 3,004.98 0.00 0.00 0.00 0.00 5,877.81 93.20 169.14 3,606.62 128.33 3,041.66 9.00 8.65 2.49 16.18 6,196.60 93.20 169.14 3,588.81 -184.26 3,101.66 0.00 0.00 0.00 0.00 6,385.22 90.58 178.20 3,582.58 -371.41 3,122.41 5.00 -1.39 4.81 105.95 7,035.22 90.58 178.20 3,576.00 -1,021.06 3,142.83 0.00 0.00 0.00 0.00 7,085.23 91.74 179.15 3,574.99 -1,071.05 3,143.98 3.00 2.32 1.90 39.36 7,282.42 91.74 179.15 3,569.00 -1,268.12 3,146.90 0.00 0.00 0.00 0.00 7,302.28 91.95 179.71 3,568.36 -1,287.97 3,147.10 3.00 1.05 2.81 69.51 7,430.53 91.95 179.71 3,564.00 -1,416.14 3,147.75 0.00 0.00 0.00 0.00 7,445.75 91.64 179.38 3,563.52 -1,431.36 3,147.87 3.00 -2.06 -2.18 -133.34 8,130.00 91.64 179.38 3,544.00 -2,115.29 3,155.29 0.00 0.00 0.00 0.00 8,239.33 90.67 183.64 3,541.80 -2,224.53 3,152.41 4.00 -0.88 3.90 102.69 9,332.55 90.67 183.64 3,529.00 -3,315.46 3,082.93 0.00 0.00 0.00 0.00 9,510.00 90.28 176.56 3,527.52 -3,492.80 3,082.61 4.00 -0.22 -3.99 -93.11 10,835.30 90.28 176.56 3,521.00 -4,815.69 3,162.22 0.00 0.00 0.00 0.00 10,980.91 88.64 182.15 3,522.37 -4,961.22 3,163.87 4.00 -1.13 3.84 106.39 11,007.43 88.64 182.15 3,523.00 -4,987.71 3,162.88 0.00 0.00 0.00 0.00 7/26/2006 9:56:31AM Page 3 of 7 COMPASS 2003.11 Build 50 ~~ `/ Halliburton Energy Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska,,lnc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Pian 1J-103 Wellbore: 1J-103 L2 Design: 1J-103 L2 (wp06) Planned Survey 1J-103 L2 (wp06) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: - -_ - -~ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) ~ 1,655.78 47.14 45.00 1,518.00 1,409.00 346.97 346.97 5,946,387.03 559,110.82 0.00 -346.97 Base Perm 1,871.03 50.39 46.00 1,663.00 1,554.00 459.11 459.75 5,946,500.04 559,222.71 1.55 -459.11 T3 2,367.82 55.60 58.03 1,955.00 1,846.00 722.31 762.47 5,946,765.57 559,523.34 2.20 -722.31 K15 2,880.89 56.00 60.00 2,242.00 2,133,00 935.36 1,130.53 5,946,981.47 559,889.69 0.33 -935.36 T3+850-10 314" 4,022.47 54.57 93.33 2,892.00 2,783.00 1,284.43 1,984.30 5,947,337.15 560,740.63 2.39 -1,284.43 Ugnu C 4,507.13 60.71 121.19 3,155.00 3,046.00 1,161.69 2,367.94 5,947,217.42 561,125.18 5.00 -1,161.69 Ugnu B 4,652.4D 63.10 127.45 3,223.00 3,114.00 1,088.31 2,473.16 5,947,144.88 561,230.96 4.14 -1,088.31 Ugnu A 4,949.82 64.77 134.14 3,356.00 3,247.00 921.49 2,680.14 5,946,979.69 561,439.21 2.10 -921.49 K13 5,670.64 77.00 165.03 3,587.00 3,478.00 328.27 2,994.34 5,946,389.00 561,758.00 4.38 -328.27 L2 : TOW 7 5/8" - 5871' MD, 3587' TVD - 2553' FSL & 554' FWL - WSAK D - 7 518" TOW 5,682.64 78.91 165.03 3,589.50 3,480.50 316.94 2,997.37 5,946,377.69 561,761.12 15.90 -316.94 L2 : Btm of Window - 568 3' MD, 3590' TVD 5,700.00 78.91 165.03 3,592.84 3,483.84 300.48 3,001.77 5,946,361.27 561,765.65 0.00 -300.48 5,712.64 78.91 165.03 3,595.28 3,486.28 288.50 3,004.98 5,946,349.31 561,768.94 0.00 -288.50 L2 : Being D ir ~ 9°/100', TFO 16.18: 5713' MD, 3595' TVD 5,800.00 86.46 167.22 3,606.39 3,497.39 204.44 3,025.73 5,946,265.43 561,790.35 9.00 -204.44 5,877.81 93.20 169.14 3,606.62 3,497.62 128.33 3,041.66 5,946,189.45 561,806.87 9.00 -128.33 L2 : Sail ~ 93.20° Inc: 5878' MD, 3507' TVD 5,900.00 93.20 169.14 3,605.38 3,496.38 106.57 3,045.84 5,946,167.73 561,811.22 0.00 -106.57 6,000.00 93.20 169.14 3,599.79 3,490.79 8.52 3,064.66 5,946,069.83 561,830.80 0.00 -8.52 6,100.00 93.20 169.14 3,594.21 3,485.21 -89.54 3,083.48 5,945,971.94 561,850.38 0.00 89.54 6,196.60 93.20 169.14 3,588.81 3,479.81 -184.26 3,101.66 5,945,877.37 561,869.30 0.00 184.26 L2 : Being Dir ~ 5°l100', TFO 105.95°: 6197' MD, 3589' TVD 6,200.00 93.15 169.30 3,588.63 3,479.63 -187.59 3,102.29 5,945,874.04 561,869.96 4.96 187.59 6,300.00 91.77 174.11 3,584.33 3,475.33 -286.42 3,116.70 5,945,775.34 561,885.14. 5.00 286.42 6,385.22 90.58 178.20 3,582.58 3,473.58 -371.41 3,122.41 5,945,690.40 561,891.52 5.00 371.41 L2 : Sail ~ 90.5$° Inc: 6385' MD, 3583' TVD 6,400.00 90.58 178.20 3,582.43 3,473.43 -386.19 3,122.88 5,945,675.63 561,892.10 D.00 386.19 6,500.00 90.58 178.20 3,581.42 3,472.42 -486.13 3,126.02 5,945,575.72 561,896.02 0.00 486.13 6,600.00 90.58 178.20 3,580.41 3,471.41 -586.08 3,129.16 5,945,475.82 561,899.94 0.00 586.08 6,700.00 90.58 178.20 3,579.39 3,470.39 -686.02 3,132.30 5,945,375.91 561,903.86 0.00 686.02 6,800.00 90.58 178.20 3,578.38 3,469.38 -785.97 3,135.44 5,945,276.00 561,907.78 0.00 785.97 6,900.00 90.58 178.20 3,577.37 3,468.37 -885.91 3,138.58 5,945,176.09 561,911.70 0.00 885.91 7,000.00 90.58 178.20 3,576.36 3,467.36 -985.86 3,141.72 5,945,076.18 561,915.62 0,00 985.86 7/26/2006 9:56:31AM Page 4 of 7 COMPASS 2003. ? 1 Build 50 {P ~ ~ t 3 f ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic Database: EDM 2003.11 Single. User Db Company: ConocoPhillipsAlaska, lna Project: KuparukRiver Unit.. Site: Kuparuk 1J Pad Well: Plan 1J-103 Wellbore: 1J-103 L2 Design: 1J-103 L2 (wp06) Planned Survey 1J-103 L2 (wp06) Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: L~ Sperry Drilling Services Well Plan 1 J-103 -Slot 1 J-103 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature ___ Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) (ft) lft) (ft) (ft) (ft) (°I100ft) (ft) 7,035.22 90.58 178.20 3,576.00 3,467.00 -1,021.06 3,142.83 5,945,041.00 561,917.00 0.00 1,021.06 L2 : Being D ir @ 3°/100', TFO 39.36°: 7035' MD, 3576' ND -1J-103 L2 T1 (wp06) 7,085.23 91.74 179.15 3,574.99 3,465.99 -1,071.05 3,143.98 5,944,991.02 561,918.55 3.00 1,071.05 L2 : Sail @ 9 1.74° Inc: 7085' MD, 3575 ND 7,100.00 91.74 179.15 3,574.54 3,465.54 -1,085.81 3,144.20 5,944,976.27 561,918.88 0.00 1,085.81 7,200.00 91.74 179.15 3,571.50 3,462.50 -1,185.75 3,145.68 5,944,876.35 561,921.14 0.00 1,185.75 7,282.42 91.74 179.15 3,569.00 3,460.00 -1,268.12 3,146.90 5,944,794.00 561,923.00 0.00 1,268.12 L2 : Being D ir @ 3°/100', TFO 69.51°: 7282' MD, 3569' TVD - 1J-103 L2 T2 (wp06) 7,300.00 91.92 179.65 3,568.44 3,459.44 -1,285.69 3,147.09 5,944,776.43 561,923.32 3.00 1,285.69 7,302.28 91.95 179.71 3,568.36 3,459.36 -1,287.97 3,147.10 5,944,774.16 561,923.35 3.00 1,287.97 L2 : Sail ~ 9 1.95° Inc: 7302' MD, 3568' TVD 7,400.00 91.95 179.71 3,565.04 3,456.04 -1,385.63 3,147.59 5,944,676.51 561,924.61 0.00 1,385.63 7,430.53 91.95 179.71 3,564.00 3,455.00 -1,416.14 3,147.75 5,944,646.00 561,925.00 0.00 1,416.14 L2:Being D ir ~ 3°/100', TFO -133.34 °: 7431' MD, 3564' ND -1J-10 3 L2 T3 (wp06) I 7,445.75 91.64 179.38 3,563.52 3,454.52 -1,431.36 3,147.87 5,944,630.79 561,925.24 3.00 1,431.36 L2 : Sail ~ 91.64° Inc: 7446' MD, 3564 ND 7,500.00 91.64 179.38 3,561.98 3,452.98 -1,485.58 3,148.46 5,944,576.58 561,926.25 0.00 1,485.58 7,600.00 91.64 179.38 3,559.12 3,450.12 -1,585.54 3,149.54 5,944,476.64 561,928.12 0.00 1,585.54 7,700.00 91.64 179.38 3,556.27 3,447.27 -1,685.49 3,150.63 5,944,376.71 561,929.98 0.00 1,685.49 7,800.00 91.64 179.38 3,553.42 3,444.42 -1,785.44 3,151.71 5,944,276.78 561,931.85 0.00 1,785.44 7,900.00 91.64 179.38 3,550.56 3,441.56 -1,885.40 3,152.80 5,944,176.85 561,933.71 0.00 1,885.40 8,000.00 91.64 179.38 3,547.71 3,438.71 -1,985.35 3,153.88 5,944,076.91 561,935.58 0.00 1,985.35 8,100.00 91.64 179.38 3,544.86 3,435.86 -2,085.30 3,154.97 5,943,976.98 561,937.44 0.00 2,085.30 8,130.00 91.64 179.38 3,544.00 3,435.00 -2,115.29 3,155.29 5,943,947.00 561,938.00 0.00 2,115.29 L2 : Being D ir ~ 4°/100', TFO 102.69°: 8130' MD, 3544' ND -1J-103 L2 T4 (wp06) 8,200.00 91.02 182.11 3,542.38 3,433.38 -2,185.26 3,154.38 5,943,877.04 561,937.64 4.00 2,185.26 8,239.33 90.67 183.64 3,541.80 3,432.80 -2,224.53 3,152.41 5,943,837.75 561,935.97 4.00 2,224.53 L2 : Sail ~ 90.67° Inc: 8239' MD, 3542' TVD 8,300.00 90.67 183.64 3,541.09 3,432.09 -2,285.08 3,148.55 5,943,777.19 561,932.59 0.00 2,285.08 8,400.00 90.67 183.64 3,539.92 3,430.92 -2,384.87 3,142.20 5,943,677.36 561,927.01 0.00 2,384.87 8,500.00 90.67 183.64 3,538.75 3,429.75 -2,484.66 3,135.84 5,943,577.53 561,921.43 0.00 2,484.66 8,600.00 90.67 183.64 3,537.58 3,428.58 -2,584.45 3,129.48 5,943,477.70 561,915.86 0.00 2,584.45 8,700.00 90.67 183.64 3,536.41 3,427.41 -2,684.24 3,123.13 5,943,377.87 561,910.28 0.00 2,684.24 8,800.00 90.67 183.64 3,535.23 3,426.23 -2,784.03 3,116.77 5,943,278.05 561,904.71 0.00 2,784.03 8,900.00 90.67 183.64 3,534.06 3,425.06 -2,883.82 3,110.42 5,943,178.22 561,899.13 0.00 2,883.82 9,000.00 90.67 183.64 3,532.89 3,423.89 -2,983.61 3,104.06 5,943,078.39 561,893.55 0.00 2,983.61 9,100.00 90.67 183.64 3,531.72 3,422.72 -3,083.40 3,097.71 5,942,978.56 561,887.98 0.00 3,083.40 9,200.00 90.67 183.64 3,530.55 3,421.55 -3,183.19 3,091.35 5,942,878.73 561,882.40 0.00 3,183.19 9,300.00 90.67 183.64 3,529.38 3,420.38 -3,282.99 3,084.99 5,942,778.91 561,876.82 0.00 3,282.99 9,332.55 90.67 183.64 3,529.00 3,420.00 -3,315.46 3,082.93 5,942,746.41 561,875.01 0.00 3,315.46 L2 : Being Dir ~ 4°/100', TFO -93.11° : 9333' MD, 3529' TVD -1J-103 L2 T5 (wp06) 9,400.00 90.52 180.95 3,528.30 3,419.30 -3,382.85 3,080.22 5,942,679.01 561,872.83 4.00 3,382.85 9,500.00 90.30 176.96 3,527.57 3,418.57 -3,482.81 3,082.05 5,942,579.08 561,875.44 4.00 3,482.81 9,510.00 90.28 176.56 3,527.52 3,418.52 -3,492.80 3,082.61 5,942,569.10 561,876.08 4.02 3,492.80 L2 : Sait ~ 90.28° Inc: 95 10' MD, 3528' ND 7/26/2006 9:56:31AM Page 5 of 7 COMPASS 2003.11 Build 50 '?RIGINgL ConocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-103 Wellbore: 1J-103 L2 Design: 1J-103 L2 (wp06) Planned Survey 1J-103 L2 (wp06) Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Map Map MD Inclination Azimuth ND SSND +N/-S +EI-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/ 100ft) (ft) 9,600.00 90.28 176.56 3,527.08 3,418.08 -3,582.63 3,088.02 5,942,479.32 561,882.19 0.00 3,582.63 9,700.00 90.28 176.56 3,526.59 3,417.59 -3,682.45 3,094.03 5,942,379.56 561,888.97 0.00 3,682.45 9,800.00 90.28 176.56 3,526.10 3,417.10 -3,782.27 3,100.03 5,942,279.80 561,895.76 0.00 3,782.27 9,900.00 90.28 176.56 3,525.60 3,416.60 -3,882.09 3,106.04 5,942,180.04 561,902.54 0.00 3,882.09 10,000.00 90.28 176.56 3,525.11 3,416.11 -3,981.91 3,112.05 5,942,080.28 561,909.33 0.00 3,981.91 10,100.00 90.28 176.56 3,524.62 3,415.62 -4,081.73 3,118.05 5,941,980.53 561,916.11 0.00 4,081.73 10,200.00 90.28 176.56 3,524.13 3,415.13 -4,181.54 3,124.06 5,941,880.77 561,922.90 D.00 4,181.54 10,300.00 90.28 176.56 3,523.63 3,414.63 -4,281.36 3,130.07 5,941,781.01 561,929.68 0.00 4,281.36 10,400.00 90.28 176.56 3,523.14 3,414.14 -4,381.18 3,136.07 5,941,681.25 561,936.47 0.00 4,381.18 10,500.00 90.28 176.56 3,522.65 3,413.65 -4,481.00 3,142.08 5,941,581.49 561,943.25 0.00 4,481.00 10,600.00 90.28 176.56 3,522.16 3,413.16 -4,580.82 3,148.08 5,941,481.73 561,950.04 0.00 4,580.82 10,700.00 90.28 176.56 3,521.67 3,412.67 -4,680.63 3,154.09 5,941,381.97 561,956.82 0.00 4,680.63 10,800.00 90.28 176.56 3,521.17 3,412.17 -4,780.45 3,160.10 5,941,282.21 561,963.61 0.00 4,780.45 10,835.30 90.28 176.56 3,521.00 3,412.00 -4,815.69 3,162.22 5,941,247.00 561,966.00 0.00 4,815.69 L2 : Being Dir @ 4.00 TFO 106.39 - 1J-103 L2 T6 (wp06) 10,900.00 89.55 179.04 3,521.09 3,412.09 -4,880.34 3,164.70 5,941,182.38 561,968.99 4.00 4,880.34 10,980.91 88.64 182.15 3,522.37 3,413.37 -4,961.22 3,163.87 5,941,101.50 561,968.79 4.00 4,961.22 L2 : Sail ~ 88.64° Inc: 10981' MD, 3522' ND 11,000.00 88.64 182.15 3,522.82 3,413.82 -4,980.29 3,163.95 5,941,082.42 561,968,22 0.00 4,980.29 11,007.43 88.64 182.15 3,523.00 3,414.00 -4,987.71 3,162.88 5,941,075.00 561,968.00 0.00 4,987.71 L2 : BHL ~ 11007' MD, 3523' ND - 2577' FSL 8~ 717' FWL - Sec01-T1 0N-R10E - 4 1/2 -1J-103 L2 T7 (Toe) (wp06) Geologic Targets 1J- 103 L2 ND Target Name +N/-S +EI-W Northing Easting (ft) -Shape ft ft (ft) (ft) ~ 3,544.00 1J-103 L2 T4 (wp06) -2,115.29 3,155.29 5,943,947.00 561,938.00 - Point 3,523.00 1J-103 L2 T7 (Toe} (wp06) -4,987.71 3,162.88 5,941,075.00 561,968.00 - Point 3,529.00 1J-103 L2 T5 (wp06) -3,315.46 3,082.93 5,942,746.41 561,875.01 - Point 3,569,00 1J-103 L2 T2 (wp06) -1,268.12 3,146.90 5,944,794.00 561,923.00 - Point 3,576,00 1J-103 L2 T1 (wp06) -1,021.06 3,142.83 5,945,041.00 561,917.00 - Point 3,564.00 1J-103 L2 T3 (wp06) -1,416.14 3,147.75 5,944,646.00 561,925.00 - Point 3,521.00 1J-103 L2 T6 (wp06) -4,815.69 3,162.22 5,941,247.00 561,966.00 - Point 7/26/2006 9:56:31AM Page 6 of 7 COMPASS 2003.11 Build 50 ~~ `w. " ~ ~ '/` -~,~ ~ Halliburton Energy Services ~,,~ ~JF~ ConocoP hillips Alaska Planning Report -Geographi c Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-103 -Slot 1 J-103 Company: ConocoPhilNpsAlaska, Ina ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: 1J-103 L2 Design: 1J-103 L2 (v/p06) - - - _ Prognosed Casing Points --- _ _ _ I I Measured Vertical Casing Hole Depth Depth Diameter Diameter Ift) (ft) P7 (") 2,880.89 2,242.00 10-3!4 13-1/2 5,670.65 3,587.00 7-5/8 9-7/8 11,007.42 3,523.00 4-112 6-3l4 Prognosed Formation Intersection Points Measured Vertical Depth (ft) Inclination Azimuth (°) (°) Depth +N/-E +E/-W Ift) (ft) (ft) Name 1,655.78 47.14 45.00 1,518.00 346.97 346.97 Base Perm 1,871.03 50.39 46.00 1,663.00 459.11 459.75 T3 2,367.82 55.60 58.03 1,955.00 722.31 762.47 K15 2,880.89 56.00 60.00 2,242.00 935.36 1,130.53 T3+550 4,022.47 54.57 93.33 2,892.00 1,284.43 1,984.30 Ugnu C 4,507.13 60.71 121.19 3,155.00 1,161.69 2,367.94 Ugnu B 4,652.40 63.10 127.45 3,223.00 1,088.31 2,473.16 Ugnu A 4,949.82 64.77 134.14 3,356.00 921.49 2,680.14 K13 5,670.64 77.00 165.03 3,587.00 328.27 2,994.34 WSAK D 7/26/2006 9:56:31AM Page 7 of 7 COMPASS 2003.11 Build 50 ~~~~ • • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-103 1 J-103 L2 1 J-103 L2 (wp06) Anticollision Report 26 July, 2006 ~. v x a Sperry Drilling Services. SURVEY PROGRA31 Dale: ?lM1(07-14TW:W:W Validate): 1'es Version: Ucplh Fnnn Dcplh Tu SuncT/Plea T1gl ?N.INI II.W CR-GYRO-SS NINLINI 5670.W MWD*IFR-.4K-CAZSC %7U.W IIIN17.25 IJ-1113 L21x1NK) MN'D+IFR-AK-CAZSC ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 60Stations Depth Range From: 6670.64 To 16094.7 261 51 9101 Maximum Range:1706.6 7 2 61 51 91 01 Reference: Plan: 1J-103 L2 (wp06) NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-103 Grountl Level: 81.00 +WS +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5946037.40 558766.60 70°15'47.418N 149°31'29.659W iJ-103 0 U V r~ 1 0 From Colour To MI 0 250 250 500 500 750 750 '~~~~ _~~~--'- 1000 1000 1250 1250 1500 1500 - --~- 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 - ----- 8000 8000 9000 270 9000 10000 10000 11000 Plan 1J-13 1J-14 ConocoPhillips Alaska, Inc. Drilling 8. Wells West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error SUrtace: Elliptical Canic Warning Method: Rules Based Sec M° Inc Au TVD +WS +EI-W DLeg TFxe Vsec Tv8e1 1 %10.fid 7].00 1650] 358].00 320.3] 29%.3A 0.00 2 %83.6d 78.91 165.03 3509.50 316.90 2%].J] 1590 0.00]30.27 0.00 -31690 J 6112.60 78.91 165.0] 3695.10 280.50 )00198 e00 d 507].01 9120 169.10 )606.62 128.]3 )061.66 900 6 61%60 9].20 169.td ]588.01 -186.16 3101.66 0.00 0.00 -30650 16.10 -128.)] 0.00 184.M 6 6385.22 90.58 1]8.20 3502.58 -)71.61 111261 500 7 7035.22 90.50 1]8.20 ]516.00 -1021.06 316]83 0.00 105.95 ]71.41 0.00 1021.06 1J-10J L2 T11wp06) 8 ]005.23 91.Td 119.15 3510.99 -10]1.05 3163.98 100 9 ]IBIA1 91.Id 1]9.15 356900 1268.12 J16fi.% 000 39.36 10]1.05 0.00 1160.11 1J~10]L3 T31wp06) 10 ]303.28 91.95 119.]1 3568.36 -1287.9] )16].10 3.00 11 ]1)0.53 91.95 179 ]i 3566.00 -161619 ]16].]5 0.00 6951 1301.97 000 1016.16 iJ-103 L2 T]IwF061 12 ]665.]5 91.66 1]9.38 366152 1031.36 Ji6].8] 100 - 1J 81)0.00 9164 179.38 )566.00 -211539 )15539 13J% 10)116 0.00 111629 iJ~103 L2 T41em961 1d 8239.33 90.6] 18].66 )561.00 5226.53 1152.61 6.00 15 9333.55 90.fi] 181.61 3529.00 -3315.66 300293 0.00 101.69 2116.53 0.00 3]15.d6 1J-103 L3 T61H'P%( 1fi 9510.00 9038 116.56 3527.52 -3491.80 300361 d.00 1] 10835.]0 90.10 116% 352100 -0815.69 3161.22 0.00 -93.11 92.00 0.00 481569 1J-103 L1 T61wp06) 18 10980.91 86.66 103.15 3522]] 3961.22 )16387 6.00 19 1100].6] 88.61 182.15 352].00 )987.71 3162.88 0.00 10619 696112 0.00 698]]1 1J~103 L2 T7 (TOellwp%I 180 't'ravelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Cenh•c Separation ~ ISII ft/ink REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan iJ-103 - Slof 1J-103, True North Vertical (ND) Reference: Plan RKB @ 109.OOtt (Doyon 141 (28+81)) Section (VS) Reference: Slot - iJ-10310.OON, O.OOE) Measured Depth Reference: Plan RKB @ 109.OOR (Doyon 141 (26+81)) Calculation Method: Minimum Curvature J 180 Travelling Cylinder azimuth (TFO+AZI) I°I vs Centre to Centre Separation r __ ~'' ConocoPhilli s p Halliburton Energy Services Anticollision Re ort L ~ A~~~ p if ' rvices Sperry Dr ling Se Company: ConocoPhillips Alaska,Jnc. Local Co-ordinate Reference: Well Plan 1J-103 -Slot 1J-103 Project: Kuparuk River Unit TVD Reference: Plan RKB @ 109.OOft (Doyen 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 9J-103 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore 1J-103 L2 Database: EDM 2003.11 Single User Db Reference Design: 1J-103 t2 (wp06} Offset ND Reference: Offset Datum Reference 1J-103 L2 (wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 5,670.64 to 11,007.43ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,297.94ft Error SurFace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program From (ft) 28.00 800.00 5,670.64 Date 7/24/2006 To (ft) Survey (Wellbore) 0.00 1J-103 (wp06) (1J-103) 5,670.64 1J-103 (wp06) (1J-103) 11,007.25 1J-103 L2 (wp06) (1J-103 L2) Tool Name CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/28/2006 10;25;39AM Page 2 of 4 COMPASS 2003.11 Build 50 >~ J d / ` ~OhOCO~~i~1ps Halliburton Energy Services Anticollision Re ort (.. '~' Alaska p Sperry Drilling S®rvices Company: GonocoPhillips Alaska, Ina Local Co-ordinate Reference: Well Plan 1J-103 -Slot 1J-103 Project: Kuparuk River Unit ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore tJ-103 L2 Database: EDM 2003:11 Single User Db Reference Design: 1J-103L2 (wp06) Offset ND Reference: Offset Datum Summary Site Name Offset Well -Wellbore -Design Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 1 J-14 - 1 J-14 - 1 J-14 1 J-152 - 1 J-152 - 1 J-152 1J-152 - 1J-152 L1 - 1J-152 L1 1 J-152 - 1 J-152 L2 - 1 J-152 L2 1J-152 - 1J-152 PB1 - 1J-152 P61 1J-152- 1J-152 PB2- 1J-152 PB2 1 J-154 - 1 J-154 - 1 J-154 1J-154- 1J-154 L1 - 1J-154 L1 i J-154 - 1 J-154 L2 - 1 J-154 L2 1 J-159 - 1 J-159 - i J-159 1 J-159 - 1 J-159 L1 - 1 J-159 L1 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 1J-159- 1J-159 L1 P62- 1J-159 L1 P62 1 J-159 - 1 J-159 L2 - 1 J-159 L2 1J-159 - 1J-159 P61 - 1J-159 P61 Plan 1 J-102 - 1 J-102 - 1 J-102 (wp07) Plan 1J-102 - 1J-102 - 1J-102 Rig Surveys Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp07) Plan 1 J-103 - 1 J-103 - 1 J-103 (wp06) Plan 1J-103 - 1J-103 L1 - 1J-103 L1 (wp06) Plan 1J-105 - 1J-105 - 1J-105 (wp03) Plan 1J-105 - 1J-105 L1 - iJ-105 L1 (wp03) Plan 1J-105- 1J-105 L2- 1J-105 L2 (wp03) Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) Plan 1 J-109 -Plan 1 J-109 - 1 J-109 Project Ahead Plan 1J-109 -Plan 1J-109 - 1J-109 Rig Surveys Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Plan 1J-115 -Plan 1J-115 - 1J-115 (wp05) Plan 1J-115- Plan 1J-115 L1 - 1J-115 L1 (wp05) Plan 1J-115 -Plan 1J-115 L2 - 1J-115 L2 (wp05) Plan 1 J-118 - 1 J-118 - 1 J-118 (wp03) Plan 1J-118 - 1J-118 L1 - 1J-118 L1 (wp03) Plan 1 J-118 - 1 J-118 L2 - 1 J-118 L2 (wp03) Plan 1 J-120 - 1 J-120 - 1 J-120 (wp02) Plan 1 J-130 - 1 J-130 - 1 J-130 (wp02) Plan 1J-133 - D141 - 1J-133 - 1J-133 (wp06) Plan 1J-133 - D141 - 1J-133 L1 - 1J-133 L1 (wp06 Plan 1 J-135 - 1 J-135 -Plan 1 J-135 (wp01) Plan 1J-156 - 1J-156 - 1J-156 Rig Surveys Plan 1J-156- 1J-156 L1 - 1J-156 L1 Plan 1J-156- 1J-156 L1 PB1 - 1J-156 L1 P61 Plan 1 J-156 - 1 J-156 L2 - 1 J-156 L2 (wp05) Plan 1J-156 - 1J-156 L2 - 1J-156 L2 Rig Surveys Plan 1 J-158 - 1 J-158 - 1 J-158 (wp03) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI WSP-1 S -WSP-1 S -WSP-1 S Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) {ft) 9,454.09 5,950.00 202.22 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 171.84 5,684.96 4,599.98 1,158.59 104.57 9,465.12 8,099.97 1,251.64 201.06 9,454.46 8,075.00 1,250.76 201.57 5,699.96 5,699.98 0.78 3.42 5,699.96 5,699.98 0.78 3.41 5,671.76 6,275.00 1,224.33 112.30 10,675.95 11,533.66 1,265.10 243.66 10,637.39 11,489.11 1,263.85 244.24 6,064.99 5,175.00 466.21 111.21 6,064.99 5,175.00 466.21 111.21 6,064.99 5,175.00 466.21 111.21 6,538.96 4,875.00 792.55 111.75 6,538.96 4,875.00 792.55 111.75 6,538.96 4,875.00 792.55 111.75 6,980.54 4,799.98 1,107.99 116.72 9,067.95 5,625.00 895.88 163.69 10,993.33 6,850.00 610.17 221.79 10,993.33 6,850.00 610.17 221.79 10,998.14 6,700.00 240.85 .221.51 Out of range 51.35 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 1,062.17 Pass -Major Risk Out of range 1,051.49 Pass -Major Risk 1,050.79 Pass -Major Risk -1.74 FAIL - No Errors -1.74 FAIL - No Errors 1,124.35 Pass -Major Risk 1,024.77 Pass -Major Risk 1,021.48 Pass -Major Risk Out of range Out of range Out of range Out of range 356.13 Pass -Major Risk 356.13 Pass -Major Risk 356.13 Pass -Major Risk 683.68 Pass -Major Risk 683.68 Pass -Major Risk 683.68 Pass -Major Risk 997.60 Pass -Major Risk 759.04 Pass -Major Risk 457.82 Pass -Major Risk 457.82 Pass -Major Risk 107.97 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/28/2006 10.~25:39AM Page 3 of 4 COMPASS 2003.11 Build 50 1J-1O3L2~rillin~ Hazards S~mmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 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 weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming ~"'j ~ ~ ~ ~/~ 1J-103L2 Drilling Hazards Summary ~°~ °!_~~ prepared by Shane Cloninger 5/12/2006 1:16 PM 0 rD 1 Insulated Conductor Casing, 20", 94#, K55 x ~f 34", 0.312" WT l~ +/_ 8a MD T ~~. z ~ H r~ wm rn ~ rn " s T ~ B 3 n ~ o o ~ o "- ""e S A to ~ ` C <Z "' ~..~ W 10-3/4", 45.5#, L-80, BTC, R3 ~ @ 2,880' MD / 2,242' TVD ~7 56 degrees TD t3-I/2" hole Top of [lgnu C (a? 4,022' MU / 2,892' TVU ~ Top of West Sak B (a7 5,955' AID / 3,647 TVD -~ Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. a a' ~o ;~ ~i3~ ~c", Tubing, 4-'/:" IBTM, from LEM to - A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and Z?tP packer for A2 liner +/- 90' below "B" window Top of West Sak A an, G,805' MD / 3,790'CVD ~ Wellhead /Tubing Head /Tree, 10-3/4" x 4-'/:", 5,000 ksi Tubing String- 4-1/2", 12.6 #, L-80, [BTM 7-5/8", 29.7#, L-80, BTCM, R3 Csg @ 6,805' MD / 3,790' TVD @ 85 degrees TD 9-7/8" hole (I) Gas Lift Alandrel, CAA1CO 4-I/2" x I" Model KhIBG w/ dwnmy valve @, one (I) set @2,400' D1D, 1,973' TVD- (l) Gas Lift Mandrel, CAMC'O 4-l/2" x I" Model KMBG w/ dummy valve, @ < 72 deg, 5,300' MD, 3,489' TVD. Electric Submersible Pump, Cenlrilift 418 HP motor, with FC6000 wireline deployed pump. Bottom at 5,600' MU, 3,571"1'VD 103 L2 "U" Sand Window @ 5,670' MD / 3,58T TVD 77 degrees 103 Ll "B" Sand Window @ 5,955' MD / 3,647' TVD 80 degrees "D" Liner, 4-1/2" I Lti#, L80, BTC, R3 (0.125" x 2.5" slots, 32 per fwt, 5.9% open area) 'lO~ ~~ "B" Liner, 4-1/2", 11.6#, L8Q, BTC, R3 (0.125" x 2.5" slots, 32 per (oot, 5.9 % open area) AZ Sand Liner, 4-1/2", 11.6#, L80, BTC, ~~ R3 slotted, coesi icrorsfar iso/arir n 11-103 L2 6-3/4" D sand lateral TD 11,007' MD / 3,523' TVD `ogle 88 degrees `-~ ~ IJ-103 LI. 6-3/4" "B" sand lateral TD 11,008' MD / 3,596' TVD Angle 89 degrees I1-103. 6-3/4 A2 sand lateral TD 15,095' MD / 3,749' TVD Angle 89 degrees • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~(i(, ~~-- /y 3 (_., Z PTD# L~ ^' l Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~~~. •.~" ~~ 3 (If last two digits in Permit No.ZU~' // , API No. 50-G~ - ~ =~~-Qa. API number are ~ ~ between 60-69) ~ Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: ~ Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Compan NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25106 C:\jody\transmittal_checklist • • 00 0 0 , a~ N a y , , o, 3 ~ _ ~ Q , , , ri c C, .n w ~, Y p ~ ° r o c p L, c. m. a a i c, c m a> > N, ~, c . °- W N -° o, - a N p, w, m a m, ~°, °~ v ~ D ~ O y 4 t t, o N v. a ~ ° `~~ L of m ~° m rn ~ N. n c m, o a ~ m $ o, n 4 m n ~, 'o ~, ° a, n a~ o . o, c' ~, ~, t ~ ao ~ ~ ~, n m QQ p N~ N• ~ ~, ~ L ~~ ~, ~ ~ ~ ~ •~ 3, ~~ ~ V~~ m~~ ~ ~ C. °~ L. ~ O co m' ~ ~ ~ m' t ~ Q, m, c' ~ o' ~, 3. w r ~ t N. O, `~ >. O p ~ ~ ~ ~ ~ ~ ~ p j~ ~, ~ C. ~ ~, C, ~ ~ ?~~ y, M c 3' cr o ~ ~ ~ ~ ~ E, ~ ~~ ' ~ a~ ~~ ~ o ~~ ~ ~ ~ ~ ~ ~ ~ _ a~ _ ~ ~ O, _~ O G ~ j ~ ~ ~ ~i Vl' >: c' m. ~ ~ ~ ~ ~ ~ ~ N~ .~ ° N, p, 7, ~, ~ N, ~ in, ~ N~ uJ, U, a ~ p y 3. o. °o ° c, a ~ ~ ~ ai v. Z, m, ~' ~ Y, r ~, a o d °~ Z O N C' N' tq N' '°' O' T N Y , ~ ~ ~, c, m ~, a ~ rn n a. ,~, ~, ay c, c, `, as v O Y~ 7, d', ° , '~, ~ ~ ~' N c' N' ~~ d N• Y N. O' ~ °c. O, N, N _ _ fl. N, O. ~, ~ ~i ~ ~, ~, ~~ ~~ N ~, N. ~~ d' ~ L, N, U' N ~ ~ Z a~ ° 3, m, O. a _, ° o, o. rn ` o, ` O' m. ¢ N o, x v ~ W ~' H, ~, Y ~, U U, Q' cn a, ~' O ' ~, n , cp g g. _, z~ W °, a „ w , a~ d N, f/Y N~ N~ y~ y~ y~ N~ U} N~ N~ N ' ~ y, N, N} UD N~ N~ N~ ~ y~ tlH a z, } }. } ~- ~-, } ~-, r, ~, r, ~ , r z z z z z z z z z z ~ z r z ~- r r r z z >- } ~ z z z T , , , , , , , , , , , , , , , , , , , , , , , ' , c N, °~ , o, o, ~, ~ v 3; ~, 3. ~ O ° ~ - o _ Z c, , ° , , N Ol ~ ~ O>' ~ ~, Q: ~ ~ c' y c, o, ~, ~ °: ca v, ~ ~ u W "' ~ ~ N ` O M N N' C ~ ~ O 3 -O ~ , ~ O C ~ ~ p. ~ ° N ~ L flr O N, ~ U, 0 d , N '° , • Q py ~ , ~, ~ O N, ~ 7 y ~ . ~, ~ ~ ~ O, f0 ~ T , + .+ . ~ N ~ ~, ~ w ~ 0, ~ ~ ~ ~ ~, . . O ~ M, , O' , , 7 Ul ~ W ~ U , ~ ~ _~ «, ~ ~ of ` Z' ar m 3 3' , ~ o ~ tn' c' rn L' , c' p' °' ¢ ~ 0, _ 'Q' p' ¢' w' y' ar a~ m .. N ~ ~ ~ w O ~ ¢ Q Y ~ O~ O, ~ 7~ ~ ~ ," ~ ~ C~ Q~ .p, p ~~ ~ ~ ~ l`~ ~, ~ o ~, ~~ o, ¢ ~ 3~ 0 V, ° ai p, , ~,~ ~ j, 'fl, ~~ a Q ~, a~, , _~ , o ~, a, ~ N, a, ~3 • l ~ 0 >, N, y, p ~, T Y ~ O y •~ a U g s, a c, o ~ ~~ m ~ o > > ° a' m' a m Y ~, a o, ~ p, o m. o ~' ~, ~ '~ p, ¢, 3 m, ~, ~ ~ >: o, w °, a~' a~ ~ y ~ ~ Y a?, ~, . , 4 A m ~, ° ° m ~ c' o, p ° - , o: ~ , Z' p o w •m , ._, as ° ' , o , a ~ ' ° L m' • 3' w, o. ~- 3. c ¢ U ° m' ~ ~ p N • ~ ._o 3 L_, 3 m m. ~ m; p ' , a. o ~' ~ . ~ ~, ~ `~ ' o, ~, , o a ~, ~ N rn m. °r ~~ a 3 o , ~ 0 ~, o' 3 ~ t ~ ° E W U o a a °, , ~, c, , ~ ~ a c, w, v, `a > a> ~ . .Q a . a > _ a i , .> ~, ... ° v ~ a v' o ' ° ' ~ ' a> °- °,~ ' ~ o, m c, , v ° p ~, w ' ° a ~ a n , m a~ m o' . , ~, ~, ~ ~i o, m ° ° , m' ~~ ' ° o ~' ° :?' °' °' ~; a a i ~' o N ' E ° ' E m f6 rn o' ' L o, U a~ °= ' ' ~... N; c p °. a o, d °. ° °, ' ' ° a ° ° a ° c ~, ' N p, a ai m - ' a ai ' r ~; ' m -d ' , c p, E ~. N, 3 ~ ° c ' ° ° otS = cLi °, °, ° oS a~ ~ E, ia 3' a ,~ a °, m w r •~, °, m d io m is rn f6 m o ~ oS • >, 2. ° ~ ° ~ •° '~ o v N 4. O :°.. ~, ~, ~, o. d ~, x N m y. N p, p ° 3; c, L ~~ rn =' c a, or ~, > • c. Y; m ~~ ~~ N ~ ° N D. ~~ ~, a ' - ' ~ o ° V U p~ a i~ >, '' ~, ii U c0' ~' ~, -' ~' v ~ p' c' ~, a>, d, a> m, .a o, L~ °' L, c Q, . c, , v' u~ ~3, p' c, ~ N~ N, N, , ~'' v v o ' p, ~, . rn ' L. 3' , -o . - ~ y, u~ c' , p a , ' m' o L, p ~, ~ ~, ~ o. ~~ m, ~" O Z ~' c' 3, m `~' cmi' ~' °3' `o' `o' ~ ~, E ~ y a~ -o' m o v, m , a~ «; ~° _ ~; v 3 p p a ~ c, ~, a~ c ~ U v v ' c ~ ~ ' O, °, °, °~ y, O, • ~ ~ ~ • N • °~ a 0 O. 7, ~, ~, ~ •3 ~, m ~' -C~ ~ ui~ a i' 3, y' p' ' n • °, a~ ~, m i J ~ ~ y f6 ~, , 6 -, -, - v, °~~ °~~ ° ~ • ~ , ~, ~, a -, ~, ~ 3, n u' ~ v' m' H; H H; ~ c. p. ~ ty. ~ c. ' - a a, Y _ ~ U, ° °' ~, ~ ~ ~ ° • , ~ Y >, c °, a i a ~ c, , 4 ~ w O cn ~; ~; ~' ~ 4 ai a O ai m a; U ~; ¢; o a z o , ~, ~, ~ U cn U U U ~ v. U; ¢ ca a, - ¢ ~ v = o; O, O, m m U ~ ~' ~' ~; a~, ~ o a i a~, a U U 4 U ~ W , , , , , , , , , , , , , , , , , . . , , , = n O N M a~ O n O O O N M V ~ c0 f~ a0 O> O N M V to O r M m O ~ N M t1• LL7 f° I~ O O ~ r- N N N N N N N N N N M M M M M M M M M M U f- U o w N r o O o r N V= m o p ~ G N ~ om ° W w M ~ M to o y p C5 O o J N •C p a i ~ G U a s Q a ~' ~ w a a ~ ~ a~ acn 3 i Well I-iistory 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 Wefl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 13 07:30:32 2007 Reel Header Service name .......... ...LISTPE Date. ................. ...07/04/13 Origin ................ ...STS Reel Name ............. ...UNKNOWN Continuation Number... ...01 Previous Reel Name.... ...UNKNOWN Comments .............. ...STS LIS Writing Library Tape Header Service name .......... ...LISTPE Date .................. ...07/04/13 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 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. GALVIN OPERATOR 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 • Scientific Technical Services Scientific Technical Services 1J-103 L2 500292331861 ConocoPhillips Alaska, Inc Sperry Drilling Services 13-APR-07 MWD RUN 12 MWD RUN 13 W-0004725792 W-0004725792 P. ORTH P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 5991.0 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 DRILLED FROM A WHIPSTOCK, THE TOP • OF WHICH WAS AT 5991' MD/3611'TVD, WITHIN THE RUN 2 INTERVAL OF 1J-103 PB1. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 12. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED FOR RUN 1. 5. MWD RUNS 2,13 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 13 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1,2,12,13 REPRESENT WELL 1J-103 L2 WITH API#: 50-029-23318-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13866'MD/3662'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). 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.......07/04/13 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 GR 2889.0 13808.5 FET 2910.0 13815.5 RPD 2910.0 13815.5 RPS 2910.0 13815.5 RPM 2910.0 13815.5 RPX 2910.0 13815.5 ROP 2935.5 13866.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 12 MWD 13 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2889.0 5991.0 5991.5 6031.0 6031.0 13866.0 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 13866 8377.5 21955 2889 13866 RPD MWD OHMM 1.56 2000 55.0542 21812 2910 13815.5 RPM MWD OHMM 1.29 1645.31 43.5663 21812 2910 13815.5 RPS MWD OHMM 1 1010.47 45.2718 21812 2910 13815.5 RPX MWD OHMM 3.39 1741.36 45.3458 21812 2910 13815.5 FET MWD HOUR 0.14 761.77 1.24119 21812 2910 13815.5 GR MWD API 19.57 123.41 67.8723 21840 2889 13808.5 ROP MWD FT/H 0.43 527.52 188.423 21862 2935.5 13866 First Reading For Entire File..........2889 Last Reading For Entire File...........13866 File Trailer Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/13 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.... ...07/04/13 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2889.0 5991.0 FET 2910.0 5991.0 RPX 2910.0 5991.0 RPS 2910.0 5991.0 RPM 2910.0 5991.0 RPD 2910.0 5991.0 ROP 2935.5 5991.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5991.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 5991.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA R AY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERM PERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 74.0 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 5991 4440 6205 2889 5991 RPD MWD020 OHMM 1.56 2000 22.5288 6163 2910 5991 RPM MWD020 OHMM 1.29 1645.31 12.2609 6163 2910 5991 RPS MWD020 OHMM 1 180.57 11.6398 6163 2910 5991 RPX MWD020 OHMM 3.39 166.05 11.2208 6163 2910 5991 FET MWD020 HOUR 0.14 55.89 1.79996 6163 2910 5991 GR MWD020 API 19.57 123.41 74.0869 6205 2889 5991 ROP MWD020 FT/H 1.63 527.52 187.558 6112 2935.5 5991 First Reading For En tire Fil e.... ......2889 Last Reading For Ent ire File ..... ......5991 File Trailer Service name ..... ........ STSLI B.002 Service Sub Level Name... Version Number... ........ 1.0.0 Date of Generation....... 07/04 /13 Maximum Physical Record.. 65535 File Type ........ ........ LO Next File Name... ........ STSLI B.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name.,. Version Number.........,.1.0.0 Date of Generation.......07/04/13 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5991.5 6031.0 LOG HEADER DATA DATE LOGGED: 19-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6031.0 TOP LOG INTERVAL (FT) 5991.0 BOTTOM LOG INTERVAL (FT) 6031.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 80.7 ~~ 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 TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: TOOL NUMBER 6.750 5991.0 • Mineral Oil Base 8.40 102.0 .0 27000 3.2 000 .0 000 82.4 000 .0 000 .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 ROP MWD120 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 5991.5 6031 6011.25 80 5991.5 ROP MWD120 FT/H 0.68 38.91 14.0306 80 5991.5 First Reading For Entire File..........5991.5 Last Reading For Entire File...........6031 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number.........,.1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 6031 6031 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......07/04/13 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: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5991.5 13815.5 RPD 5991.5 13815.5 RPM 5991.5 13815.5 GR 5991.5 13808.5 RPS 5991.5 13815.5 FET 5991.5 13815.5 ROP 6031.5 13866.0 LOG HEADER DATA DATE LOGGED: 24-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13866.0 TOP LOG INTERVAL (FT) 6031.0 BOTTOM LOG INTERVAL (FT) 13866.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 95.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resi s. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5991.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S): 97.0 MUD PH: .0 MUD CHLORIDES (PPM): 26500 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPER ATURE: .000 107.2 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 Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5991.5 13866 9928.75 15750 5991.5 13866 RPD MWD130 OHMM 5.61 1008.55 67.8636 15649 5991.5 13815.5 RPM MWD130 OHMM 5.11 1001.2 55.8952 15649 5991.5 13815.5 RPS MWD130 OHMM 4.95 1010.47 58.517 15649 5991.5 13815.5 RPX MWD130 OHMM 4.81 1741.36 58.7852 15649 5991.5 13815.5 FET MWD130 HOUR 0.14 761.77 1.02113 15649 5991.5 13815.5 GR MWD130 API 39.76 119.33 65.406 15635 5991.5 13808.5 ROP MWD130 FT/H 0.43 445.97 189.651 15670 6031.5 13866 First Reading For Entire File..........5991.5 Last Reading For Entire File...........13866 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/13 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 .....................07/04/13 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