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Home My WebLink About207-166• Image Project Well History File Gover Page XNVZE 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. - ~ ~ ~ Well History File Identifier Organizing (done) Two-sided III IIIIIIIIIII IIIII ^ Rescan Needed III IIIIIIIIII IIIIII RES AN DIGITAL 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 III IIIIIIIIIII IIIII BY: Maria Date: ~ /s/ l Scanning Preparation ~~ x 30 = ~ + 1 =TOTAL PAGES BY: F Maria Date: / ~ l ~ (~ (Count does not include cover shee ) /s/ ~~ J IIIIIIIIIIIIIIIIII Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~~YES NO BY: ana Date: ~ ~ ~' ~ /s/ ~~- Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /sl Scanning is complete at this point unless rescanning is required. IIIIIIIIIIIIII IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: Comments about this file: -F= /s/ o , ~e~k,a iuumuuumu 10/6/2005 Well History File Gover Page.doc ~~ .. ~~ ,~ ~`~y MICROFILMED .6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc -~ J TRANSMITTAL C®NF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Kuparuk River Unit 3K-102L1 DATE: 3/12/2009 TO: Christine Mahnken State of Alaska AOGCC 333 W. 7"' Ave, Suite 100 Anchorage, Alaska 99501-3539 ~Kuparuk River Unit, North Slope, Alaska i02L1 (500292337860} Report and CDROM Final Well Report, Mud Logging Data, 3K-102L1; Epoch, report date: 02/07/2008; table of contents, uipment and crew, well data, geological data, pressure/strength data, drilling data, daily reports, formation (logs; 3K-102L1 (500292337860) Formation log 6795.5-14081' MD LWD Combo 6795.5-14081' MD ~ N~.~~~~, ~r ~ ~. ti ~,; Gas Ratio 6795.5-14081' MD Drilling Dynamics 6795.5-14081' MD CDROM contains: 3K-102L1and well report, morning reports, LAS data, PDF and tiff format color log image files; DML files and lithology remarks. CC: Anna Belanger CPAI Geologist Receipt: Date: g..., .'.--+. Y, ~ ' e,. ~ "' 1 :.. v ~.'t : t i 1 a ~ '~ ~~, ; ~a'~r ay*? a '",^; ?e'~..y ~, `~,.1y "3 ~ ,.33 ''?.f3;#° i =.a~ '~ # ~~ ~ ~ "'; 'st~.~ '. 'S, ~^/dltl ~ Sandra..U. L~rnkeCc~Con~®,~hillips ~r~rrr ~1~;~--; `O`° DATA SUBMITTAL COMPLIANCE REPORT 1 /7/2009 Permit to Drill 2071660 Well Name/No. KUPARUK RIV U WSAK 3K-102L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23378-60-00 MD 6795 TVD 3449 Completion Date 3/13/2008 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR / RES /MUD LOG Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name __ ~D D Asc _ _ - - Directional Survey R pt Directional Survey a VED D Asc Directional Survey Rpt Directional Survey ~pt LIS Verification "ED C Lis 16136 /Resisti I tio it d n n v y uc ~Rpt LIS Verification `"; ED C Lis 16137/LIS Verification I ~D C 16230~See Notes ED C 16231~See Notes ~ g Induction/Resistivity / ,/ Lo InductionlResistivity Induction/Resistivity Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 40 14081 Open 3/28/2008 __ - 40 14081 Open 3/28/2008 40 12456 Open 3/28/2008 PB 1 40 12456 Open 3/28/2008 PB 1 3114 14081 Open 4/21/2008 LIS Veri, GR, RPM, RPS, RPX, FET, FCNT, NCNT, NPHI, DRHO, RHOB 3114 14081 Open 4/21/2008 LIS Veri, GR, RPM, RPS, RPX, FET, FCNT, NCNT, NPHI, DRHO, RHOB !i 3114 12452 Open 4/21/2008 P61 LIS Veri, GR, NPHI, RPM, NCNT, RPS, FCNT, i RPD, RPS, FET, RHOB, DRHO,ROP 3114 12452 Open 4/21/2008 P81 LIS Veri, GR, NPHI, RPM, NCNT, RPS, FCNT, '~, RPD, RPS, FET, RHOB, DRHO,ROP 0 0 Open 5/7/2008 MD and TVD in PDF, EMF and CGM for CT logs 0- 0 Open 5/7/2008 PB1 MD and TVD in PDF, ~' EMF and CGM for CT logs 25 Col 121 14081 Open 5/7/2008 MD ROP, DGR, EWR 25 Col 121 3569 Open 5/7/2008 TVD DGR, EWR 25 Col 121 12456 Open 5/7/2008 P61 MD ROP, DGR, EWR DATA SUBMITTAL COMPLIANCE REPORT 1 /7/2009 Permit to Drill 2071660 Well Name/No. KUPARUK RIV U WSAK 3K-102L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23378-60-00 MD 6795 TVD 3449 Completion Date 3/13/2008 Completion Status 1-OIL Current Status 1-OIL UIC N Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~1`#' Analysis ~~ Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops 1~N - -- - -- _ Compliance Reviewed By: _ _. _ _ __ ___ ___ Date: __ 0_~~n.,.~ o~ C~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, May 25, 2008 11:20 AM To: 'Ha-twig, Dennis D' Cc: Alisup-Drake, Sharon K Subject: RE: 3K-102 (207-165) an 3K-~(207-166) Dennis and Sharon, A new 407 is not necessary. I will make the hand corrections. Tom From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Thursday, May 15, 2008 4:27 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 3K-102 (207-165) and 3K-102L1 (207-166) Tom, Thank-you for the clarification and correction. The correct packer depth of 6,761' will be corrected in our records. Would you like a resubmitted/corrected copy of the 407 ? Regards, Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 r ~:~; Office : 907-265-6862 "'~' "~~~`°~ ' . . ~ ~~"~~`' Cell : 907-980-1433 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, May 09, 2008 1:09 PM To: Hartwig, Dennis D Cc: Allsup-Drake, Sharon K; Regg, James B(DOA) Subject: 3K-102 {207-165) and 3K-102L1 (207-166) Dennis and Sharon, I am reviewing the 407s for these wells. Regarding the packer information given in block 24, the packer being referred to at that point should be the packer where the tubing is landed. I know it can get confusing with multilaterals. The packer depth for both reports shoufd be 6761' What we are looking for is the packer that establishes the "bottom" of the inner annulus. This is especia!!y a needed piece of information for injection wells. Call or message with any questions. Tom Maunder, PE AOGCC 5/25/2008 • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, May 09, 2008 1:09 PM To: 'Hartwig, Dennis D' Cc: 'Allsup-Drake, Sharon K ; Regg, James B (DOA) Subject: 3K-102 (207-165) and 3K-102L1 (207-166) Dennis and Sharon, I am reviewing the 407s for these wells. Regarding the packer information given in block 24, the packer being referred to at that point should be the packer where the tubing is landed. I know it can get confusing with multilaterals. The packer depth for both reports should be 6761'. What we are looking for is the packer that establishes the "bottom" of the inner annulus. This is especially a needed piece of information for injection wells. Call or message with any questions. Tom Maunder, PE AOGCC SI9/2008 s WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-102+L 1+L 1 PB 1 AK-MW-547949 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-102+L1+L1PB1 2" x 5" MD TC Logs: 1 Color Log 5 0-029-23 3 78 -00, 60, 70 2" x 5" TVD TC Logs: 1 Color Log 50-029-23378-00,60 Digital Log Images 1 CD Rom 50-029-23378-00,60,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arc~ic,Bly~ ~ ~- ' hbra, ~A~askax99518 ;,~; ~ . Date. - ~] (.V -~ Signed Apri122, 2008 ~~~~~ ~t ~a 3 v WELL LOG TRANSMITTAL To: State of Alaska April 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3K-102 Ll AK-MW-547949 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23378-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ 1ii~' . Date: Signed: ~~-l ~o~O # ~ ~~~~ WELL LOG TRANSMITTAL • To: State of Alaska April 16, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3K-102 L1 PB1 AK-MW-547949 1 LDWG formatted CD Rom with verification listing. API#: 50-029-233 78-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ;~ ~, , ssa 'x fl P ~_ ~ n,~ Date: a; ~~[3 ~ ~~z x _ ~ .. y Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~C'~rY~ MAR 2 S 2008 WELL COMPLETION OR RECOMPLETION REPO~Q~, Cron 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Q( ~ Development / Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: February 13, 2008 ~ 12. Permit to Drill Number: 207-166 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 1, 2008 13. API Number: 50-029-23378-60 4a. Location of Well (Governmental Section): Surface: 910' FSL, 315' FWL, Sec. 35, T13N, R09E, UM 7. Date TD Reached: February 6, 2008 14. Well Name and Number. 3K-102L1 Top of Productive Horizon: 1563' FNL, 2492' FEL, Sec. 35, T13N, R09E, UM 8. KB (ft above MSL): 40' RKB Ground (ft MSL): 74.3' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2125' FNL, 543' FEL, Sec. 36, T13N, R09E, UM 9. Plug Back Depth (MD + ND): 14028' MD / 3569' ND West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 • y- 6007904 Zone- 4 10. Total Depth (MD + ND): .14081' MD / 3570' ND 16. Property Designation: ADL 25519 ' TPI: x- 531764 y- 6010721 Zone- 4 Total Depth: x- 538995 ~ - 6010193 ` Zone- 4 11. SSSV Depth (MD + ND): nipple @ 516' MD / 515' ND 17. Land Use Permit: 2555 16. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): Est. 162x' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 6795' MD ' GR/Res/Mud log ~SFS<<f ~?yD 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G CO AMOUNT CASING SIZE Wt. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RE RD PULLED 20" 94# H-40 40' 121' 40' 121' 40" pre-installed 13.375" 68# L-80 40' 3143' 40' 2190' 16" 653 sx AS Lite, 248 sx DeepCRETE 9.625" 40# L-80 40' 6795' 40' 3449' 12.25" 530 sx DeepCRETE 4.5" 11.6# L-80 6783' 14029' 3446' 3569' 8.5" slotted liner 23. Open to production or injection? Yes ^/ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top 8 Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 6768' 6761' 6914'-8412' MD 3463'-3488' TVD 32 spf 8624'-9301' MD 3499'-3501' ND 32 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9470'-10915' MD 3490'-3499' TVD 32 Spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11166'-11929' MD 3513'-3523' TVD 32 spf n/a 12187'-13388' MD 3506'-3522' ND 32 spf 13855'-13984' MD 3566'-3569' TVD 32 spf 26. PRODUCTION TEST Date First Production March 21, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil -shares production with 3K-102 Date of Test 3/24/2008 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1034 GAS-MCF 1115 WATER-BBL 0 CHOKE SIZE 112 Bean GAS-OIL RATIO 1133 Flow Tubing press. 262 psi Casing Pressure 908 Calculated 24-Hour Rate -> OIL-BBL 2004 GAS-MCF 2270 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^/ Sidewall Cores Acquired? Yes / - No ^ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. yy~~ li., .. `..GetViY ~~ SEE ATTACHMENT 2. ~'` ~ VI4"rtiFCER ~'' ~ ...-__~,,~-.m.~ I,.... Form 10-407 Revised 2/2007 CONTIN ED ON REVERSE SIDE ~~ rr1 28. GEOLOGIC MARKERS (List all formations and ma encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1843' 1629' needed, and submit detailed test information per 20 AAC 25.071. T3 1736' 1559' K15 2112' 1786' Ugnu C 4376' 2666' Ugnu B 5516' 3042' Ugnu A 5816' 3137' K13 6333' 3307' West Sak D 6796' 3449' West Sak C 14081' 3570' West Sak B 14081' 3570' N/A 3K-102L1 PB1 TD 12457' 3498' Formation at total depth: ~Kt~parkrkD'sand 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, core summary 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 c~~~~~... Printed Nam Rand Thom s Title: Drillino Team Leader Signature ~ ne Date ~ ~Zb ~~~ 6 -~ 3 26_S INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~~~ KRU 3K-102L1 C4n~ac~'h~M~wp~ ~fiaska, Enc- .... - - - _ '3K-y02L1 -- -- - _ - - - - - APi: 5002923378b0 Well T e: PROD An le w TS: d a HEAT TRACE SSSV T e: NIPPLE Ori Com letion: An le TD: 89 d (1-3008, r Annular Fluid: Last W/O: Rev Reason: NEW WELL OD:1.000) Reference Lo 41' RKB Ref Lo Date: Last U date: 2/19/2008 w, : : Last Ta TD: 14081 ftK6 TUBING i ' Laet Tag Date: Max Hole AnglP• 95 deq r7 12141 0799. ~I ~ Casing Strin -ALL STRINGS OD:4.500, Descri tion Size To Bottom TVD Wt Grade Thread ID:3.958) 20 9 00 H 40 WELDED ;:.R ,. E ~ PACKER (6761762, OD:8.210) PUP (6762786, OD:4.500) CONDUCTOR 20.000 0 120 1 4. SURFACE 13.375 0 3143 2190 68.00 L-80 BTC INTERMEDIATE 9.625 0 7595 3475 40.00 L-80 BTCM D-SAND SLOTTED LINER 4.500 6783 14029 3569 12.60 L-80 BTC-HYD 521 D-SAND WINDOW 9.625 6795 6745 3449 - 0.00 _ - Tubing String- TUBING ___ _ _ -- P S¢e ~To Bottom TVD Wt Grade Thread 4 500 it b'99 1-350 12.01 L ~i0 IG'TM i Parfnratinnc Crirrtirriarv Interval TVD Zone Status Ft SPF Date T Comment 6914 - 8412 3463 - 3488 WS D 1498 32 2/8/2008 Slots Alternating solid/slotted pipe 2.5" x .125" wide in 4 circumferential rows/ft 3" centers 8624 - 9301 3499 - 3501 WS D 677 32 2/8/2008 Slots Alternating solid/slotted pipe 2.5" x .125" wide in 4 circumferential rows/ft 3" centers 9470 - 10915 3490 - 3499 WS D 1445 32 2/8/2008 Slats Aternating solid/slotted pipe 2.5" x .125" wide in 4 circumferential rows/ft 3" centers 11166 -11929 3513 - 3523 WS D 763 32 2/8/2008 Slots Alternating solid/slotted pipe 2.5" x .125" wide in 4 circumferential rowsfft 3" centers 12187 - 13388 3506 - 3522 WS D 1201 32 2/8/2008 Slots Aternating solid/slotted pipe 2.5" x .125" wide in 4 circumferential rows/ft 3" centers 13855 - 13984 3566 - 3569 WS D 129 32 2/8/2008 Slots Alternating solidlslotted pipe 2.5" x .125" wide in 4 circumferential rows/ft 3" centers Vas Litt M andre ls/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 2316 1881 CAMCO KBMG DMY 1.0 BK-5 0.000 0 2/11/2008 2 4559 2732 GAMGO KBMG DMV 14 _ _B__K-5 OM10_ 0 2/1V20_0_R Other plugs, equip., etc.) -COMPLETION De h TVD T e Descn ion ID 1 1 HEAT HEAT TRACE FROM SURFACE TO 3008' 0.000 w/CAMCO TO TOP Perf (86249301) Perf (9470-10915) Pert 11166-11929) Perf 12187-13388) 6762 3441 PACKER D-SAND LEM BAKER TOROUEMASTER PACKER (NO-GO PROFILE INSIDE 4.750 TOROUEMASTER 6762 3441 ANCHOR XO BAKER ANCHORSEAL ASSEMBLY CROSSOVERS 3.860 6762 3441 PUP D-SAND LEM PUP 3.958 6764 3442 ANCHOR BAKER'ML' ANCHOR SEAL ASSEMBLY 3.860 6786 3447 WLEG D-SAND LEM TOP OF BAKER ENTRY GUIDE TO LEM COLLET 3.730 6786 3447 HANGER D-SAND LINER RAM HANGER/SEAL BORE DIVERTER 5.080 6791 3448 HANGER D-SAND LINER RAM HANGER/SEAL BORE DIVERTER 5.080r 6809 3451 WLEG D-SAND LINER LEM BAKER ENTRY GUIDE 3.730 14029 __ 3569 SHOE D-SAND LINER BTC BAKER GUIDE SHOE 4.950 (General Notes ~~ Perf :13855-13984) i Halliburton Company Survey Report ('ompan~: ConocoPhillips Alaska Inc. Date: 2119!2008 -Lime: 16:34:30 Pa£e: 1 Field: Kuparuk River Unit t:o-ordinate(1~h;) htefercnce: Weil: 3K-102. T rue North tiitc Kuparuk 3K Pad Vertical (TVD> Re ference: 3K-102 (33.84 0) 73-8 ~~ell: 3K-102 Section (VS)ltefer euce: Well (O.OON,O.O OE.76-93Azi) Wellpath: 3K-102L1 5un~e}~ Calculation Rlethod: Minimum Curva ture llb: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zoue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 3K-102 Slot Name: 50-029-23378-00 Well Position: +N/-S -524.80 ft Northing: 6007903.98 ft Latitude: 70 25 57.619 N ~ +E/-W -2.99 ft Easting : 529305.25 ft Longitude: 149 45 40.017 W Position Uncertainty: 0.00 ft Wellpath: 3K-102L1 Drilled From: 3K-102L1 P61 50-029-23378-60 Tie-on Depth: 12140.76 ft Current Datum: 3K-102 (33.8+40) Height 73.80 ft Above System Datum: Mean Sea Level Magnetic Data: 1/5/2008 Declination: 22.96 deg Field Strength: 57630 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 76.93 Survey Program for Definitive Wellpath Date: 2/19/2008 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 107.00 456.00 3K-102 Gyro (107.00-456.00) (0 CB-GYRO-SS Camera based gyro single shot 502.52 6745.33 3K-102 MWD+SAG+IIFR+CA+MS (502 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6795.32 12140.76 3K-102L1 PB1 MWD+SAG+IIFR+CA+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1 12200.00 14045.09 3K-102L1 MWD+SAG+IIFR+CA+MS (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Licl Azim T~'D S}s'f~D ~;ti E,~~' M11apN MapE "fool ft dey deg ft ft ft ft ft ft 40.00 0.00 0.00 40.00 -33.80 ___ 0.00 0.00 6007903.98 529305.25 TIE LINE 107.00 0.12 187.79 107.00 33.20 -0.07 -0.01 6007903.91 529305.24 CB-GYRO-SS 173.00 0.32 332.86 173.00 99.20 0.03 -0.10 6007904.01 529305.15 CB-GYRO-SS 264.00 1.71 326.92 263.98 190.18 1.39 -0.96 6007905.37 529304.28 CB-GYRO-SS 311.00 2.93 328.00 310.94 237.14 3.00 -1.98 6007906.97 529303.26 CB-GYRO-SS 360.00 3.60 325.07 359.86 286.06 5.32 -3.52 6007909.29 529301.71 CB-GYRO-SS 393.00 4.19 320.51 392.79 318.99 7.10 -4.88 6007911.06 529300.34 CB-GYRO-SS 456.00 5.02 315.48 455.58 381.78 10.84 -8.28 6007914.79 529296.93 CB-GYRO-SS 502.52 6.10 309.53 501.88 428.08 13.87 -11.61 6007917.80 529293.58 MWD+IFR-AK-CAZ-SC 597.51 9.81 301.38 595.95 522.15 21.29 -22.42 6007925.18 529282.75 MWD+IFR-AK-CAZ-SC 692.36 14.58 298.64 688.63 614.83 31.23 -39.81 6007935.05 529265.33 MWD+IFR-AK-CAZ-SC 788.03 17.23 300.42 780.63 706.83 44.18 -62.60 6007947.91 529242.49 MWD+IFR-AK-CAZ-SC 882.92 20.60 303.29 870.39 796.59 60.46 -88.68 6007964.09 529216.34 MWD+IFR-AK-CAZ-SC 977.62 24.32 309.27 957.90 884.10 81.96 -117.71 6007985.47 529187.23 MWD+IFR-AK-CAZ-SC 1073.47 25.15 315.91 1044.97 971.17 109.09 -147.17 6008012.48 529157.67 MWD+IFR-AK-CAZ-SC 1168.61 28.47 320.62 1129.88 1056.08 141.15 -175.64 6008044.42 529129.08 MWD+IFR-AK-CAZ-SC 1264.34 33.51 324.93 1211.93 1138.13 180.44 -205.32 6008083.60 529099.24 MWD+IFR-AK-CAZ-SC 1359.93 37.65 327.01 1289.66 1215.86 226.55 -236.39 6008129.58 529067.99 MWD+IFR-AK-CAZ-SC 1453.35 41.64 327.71 1361.58 1287.78 276.74 -268.52 6008179.63 529035.67 MWD+IFR-AK-CAZ-SC 1549.39 44.49 328.80 1431.74 1357.94 332.51 -303.01 6008235.26 529000.97 MWD+IFR-AK-CAZ-SC 1644.78 48.56 329.73 1497.36 1423.56 392.00 -338.36 6008294.61 528965.39 MWD+IFR-AK-CAZ-SC 1740.75 52.01 332.50 1558.68 1484.88 456.64 -373.97 6008359.10 528929.53 MWD+IFR-AK-CAZ-SC 1835.09 52.93 335.11 1616.15 1542.35 523.77 -406.98 6008426.09 528896.26 MWD+IFR-AK-CAZ-SC 1930.96 53.51 337.49 1673.56 1599.76 594.07 -437.83 6008496.27 528865.13 MWD+IFR-AK-CAZ-SC 2025.37 53.35 341.57 1729.83 1656.03 665.08 -464.34 6008567.16 528838.34 MWD+IFR-AK-CAZ-SC 2120.17 56.23 343.72 1784.48 1710.68 739.00 -487.42 6008640.99 528814.98 MWD+IFR-AK-CAZ-SC 2215.71 60.69 346.00 1834.45 1760.65 817.58 -508.64 6008719.48 528793.45 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc Date: 2;19/2008 I imc 16:34:30 Pa~c 2 Field: Kuparuk River Unlt Co-ordiuate(NE)Reference: Well: 3K-102. True North SItC: Kuparuk 3K Pad Vertical (TVDj Reference: 3K-102 (33.8+40) 73.3 ~~ cll: 3K-102 Section (VS) Reference: Weil {O.OON,O.OOE,76.93Azi) ~'v'cllpath: 3K-102L1 Surrey Calculation Alethod: Minimum Curvature Db: Oracle 1u~~c~ }ID Incl Azim ~t~'p SF~"f~~D ~A/S E/W ~tapN S1apt: Toul ft deg deg ft ft ft ft ft ft 2310.64 64.18 347.58 1878.38 1804.58 899.50 -527.85 6008801.31 528773.92 MWD+IFR-AK-CAZ-SC 2406.76 65.75 347.86 1919.05 T845.25 984.59 -546.37 6008886.32 528755.07 MWD+IFR-AK-CAZ-SC 2501.28 66.76 351.50 1957.12 1883.32 1069.69 -561.86 6008971.35 528739.25 MWD+IFR-AK-CAZ-SC 2596.49 68.92 354.77 1993.04 1919.24 1157.22 -572.37 6009058.83 528728.39 MWD+IFR-AK-CAZ-SC 2691.71 70.32 356.64 2026.20 1952.40 1246.22 -579.05 6009147.80 528721.37 MWD+IFR-AK-CAZ-SC 2787.46 70.50 1.44 2058.32 1984.52 1336.39 -580.56 6009237.94 528719.50 MWD+IFR-AK-CAZ-SC 2880.62 69.59 6.14 2090.13 2016.33 1423.73 -574.78 6009325.30 528724.93 MWD+IFR-AK-CAZ-SC 2976.89 67.70 10.24 2125.20 2051.40 1512.45 -562.04 6009414.06 528737.33 MWD+IFR-AK-CAZ-SC 3071.87 67.06 15.09 2161.75 2087.95 1597.96 -542.83 6009499.64 528756.20 MWD+IFR-AK-CAZ-SC 3109.84 67.16 17.28 2176.52 2102.72 1631.55 -533.08 6009533.26 528765.82 MWD+IFR-AK-CAZ-SC 3181.98 66.27 18.07 2205.04 2131.24 1694.69 -512.96 6009596.47 528785.69 MWD+IFR-AK-CAZ-SC 3223.71 65.97 20.36 2221.93 2148.13 1730.72 -500.41 6009632.55 528798.10 MWD+IFR-AK-CAZ-SC 3319.60 67.21 23.90 2260.04 2186.24 1812.21 -467.25 6009714.16 528830.93 MWD+IFR-AK-CAZ-SC 3414.26 67.01 28.08 2296.87 2223.07 1890.57 -429.05 6009792.66 528868.82 MWD+IFR-AK-CAZ-SC 3509.64 66.99 31.93 2334.15 2260.35 1966.58 -385.16 6009868.84 5289T2.41 MWD+IFR-AK-CAZ-SC 3603.77 67.71 35.99 2370.41 2296.61 2038.61 -336.64 6009941.05 528960.64 MWD+IFR-AK-CAZ-SC 3699.36 67.30 40.31 2407.00 2333.20 2108.05 -282.10 6010010.69 529014.90 MWD+IFR-AK-CAZ-SC 3795.09 67.98 44.22 2443.43 2369.63 2173.54 -222.57 6010076.42 529074.17 MWD+IFR-AK-CAZ-SC 3891.20 67.80 47.69 2479.61 2405.81 2235.44 -158.58 6010138.55 529137.91 MWD+IFR-AK-CAZ-SC 3986.01 67.14 49.23 2515.94 2442.14 2293.51 -93.04 6010196.88 529203.22 MWD+IFR-AK-CAZ-SC 4081.49 66.77 52.05 2553.33 2479.53 2349.22 -25.11 6010252.85 529270.91 MWD+IFR-AK-CAZ-SC 4175.56 67.16 56.38 2590.15 2516.35 2399.83 45.09 6010303.73 529340.91 MWD+IFR-AK-CAZ-SC 4270.61 67.61 60.75 2626.72 2552.92 2445.57 119.94 6010349.76 529415.57 MWD+IFR-AK-CAZ-SC 4365.65 68.59 65.69 2662.18 2588.38 2485.27 198.63 6010389.76 529494.10 MWD+IFR-AK-CAZ-SC 4462.06 68.66 71.07 2697.34 2623.54 2518.33 282.06 6010423.15 529577.38 MWD+IFR-AK-CAZ-SC 4556.93 69.47 76.38 2731.26 2657.46 2543.14 367.08 6010448.29 529662.30 MWD+IFR-AK-CAZ-SC 4652.49 69.97 80.09 2764.40 2690.60 2561.41 454.81 6010466.90 529749.95 MWD+IFR-AK-CAZ-SC 4747.29 7T.22 84.12 2795.90 2722.10 2573.68 543.36 6010479.52 529838.44 MWD+IFR-AK-CAZ-SC 4842.39 71.50 84.47 2826.30 2752.50 2582.63 633.02 6010488.83 529928.06 MWD+IFR-AK-CAZ-SC 4937.20 71.21 83.81 2856.61 2782.81 2591.81 722.39 6010498.35 530017.38 MWD+IFR-AK-CAZ-SC 5032.21 71.10 83.54 2887.30 2813.50 2601.71 811.76 6010508.60 530106.70 MWD+IFR-AK-CAZ-SC 5127.57 71.35 82.94 2917.99 2844.19 2612.34 901.41 6010519.58 530196.31 MWD+IFR-AK-CAZ-SC 5223.21 72.34 82.19 2947.79 2873.99 2624.10 991.53 6010531.70 530286.36 MWD+IFR-AK-CAZ-SC 5319.30 71.14 82.07 2977.90 2904.10 2636.59 1081.92 6010544.54 530376.69 MWD+IFR-AK-CAZ-SC 5413.30 70.70 82.72 3008.63 2934.83 2648.35 1169.97 6010556.65 530464.69 MWD+IFR-AK-CAZ-SC 5508.50 71.38 83.04 3039.56 2965.76 2659.51 1259.31 6010568.15 530553.98 MWD+IFR-AK-CAZ-SC 5603.67 71.28 83.19 3070.02 2996.22 2670.32 1348.82 6010579.31 530643.44 MWD+IFR-AK-CAZ-SC 5698.43 71.81 82.55 3100.02 3026.22 2681.48 1438.01 6010590.82 530732.58 MWD+IFR-AK-CAZ-SC 5793.63 71.47 81.46 3130.01 3056.21 2694.04 1527.49 6010603.74 530821.99 MWD+IFR-AK-CAZ-SC 5888.18 70.70 81.52 3160.66 3086.86 2707.28 1615.95 6010617.32 530910.39 MWD+IFR-AK-CAZ-SC 5983.93 70.63 81.11 3192.36 3118.56 2720.92 1705.26 6010631.31 530999.64 MWD+IFR-AK-CAZ-SC 6078.56 71.11 81.24 3223.37 3149.57 2734.64 1793.60 6010645.37 531087.92 MWD+IFR-AK-CAZ-SC 6173.94 70.52 81.45 3254.71 3180.91 2748.19 1882.66 6010659.28 531176.91 MWD+IFR-AK-CAZ-SC 6269.74 70.75 81.47 3286.48 3212.68 2761.62 1972.04 6010673.05 531266.23 MWD+IFR-AK-CAZ-SC 6364.36 71.01 82.04 3317.47 3243.67 2774.44 2060.51 6010686.21 531354.65 MWD+IFR-AK-CAZ-SC 6459.26 70.56 82.04 3348.71 3274.91 2786.85 2149.26 6010698.97 531443.34 MWD+IFR-AK-CAZ-SC 6554.55 71.45 84.24 3379.72 3305.92 2797.60 2238.71 6010710.08 531532.73 MWD+IFR-AK-CAZ-SC 6649.10 71.33 87.44 3409.91 3336.11 2804.10 2328.07 6010716.93 531622.06 MWD+IFR-AK-CAZ-SC 6745.33 75.46 88.89 3437.40 3363.60 2807.04 2420.22 6010720.23 531714.18 MWD+IFR-AK-CAZ-SC . 6795.32 77.85 89.35 3448.94 3375.14 2807.79 2468.85 6010721.17 531762.80 MWD+IFR-AK-CAZ-SC 6828.14 80.95 89.42 3454.97 3381.17 2808.13 2501.10 6010721.64 531795.05 MWD+IFR-AK-CAZ-SC 6858.34 82.94 89.49 3459.21 3385.41 2808.42 2531.00 6010722.04 531824.95 MWD+IFR-AK-CAZ-SC 6889.63 85.55 89.56 3462.34 3388.54 2808.68 2562.13 6010722.42 531856.07 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ~~' Companc: CanocoPhillips Alaska lnc- Uatc 2/19/2008 ~Iimc 16:34:30 F'aoc: 3 Field: Kuparuk River Unit Co-~irdinatc(NE) Refrrrncc: Well: 3K-102, True North Siir. Kuparuk 3K Pad Vertical ('I;VD}Rcfcrcncc: 3K-102 (33:8+40j 73.8 '- ~~ell: 3K-'102 Section (VS}Refemncc: Well (O.OON,O.OOE,76.93Azi) ~~cllpath: 3K-102L1 Survey Calculation ~1elhud: Minimum Curvature Db: Oracle Survey MD Intl ~zun C1'p ti~~~ I'U'D ~/S t:IW 11ap~1 ~1apF Tool ft dey deg ft ft ft ft ft ft 6957.57 90.06 89.71 3464.94 3391.14 2809.11 2630.00 6010723.12 531923.94 MWD+IFR-AK-CAZ-SC 7042.28 90.54 89.89 3464.50 3390.70 2809.40 2714.71 6010723.75 532008.63 MWD+IFR-AK-CAZ-SC 7098.30 91.42 90.01 3463.54 3389.74 2809.45 2770.72 6010724.02 532064.64 MWD+IFR-AK-CAZ-SC 7195.54 89.19 90.21 3463.03 3389.23 2809.27 2867.95 6010724.21 532161.86 MWD+IFR-AK-CAZ-SC 7288.60 87.28 90.13 3465.89 3392.09 2808.99 2960.96 6010724.30 532254.86 MWD+IFR-AK-CAZ-SC 7383.76 88.49 90.21 3469.40 3395.60 2808.71 3056.06 6010724.39 532349.95 MWD+IFR-AK-CAZ-SC 7478.90 88.76 92.26 3471.69 3397.89 2806.66 3151.14 6010722.72 532445.03 MWD+IFR-AK-CAZ-SC 7574.25 88.08 93.44 3474.32 3400.52 2801.92 3246.34 6010718.35 532540.23 MWD+IFR-AK-CAZ-SC 7668.48 89.24 97.20 3476.52 3402.72 2793.19 3340.12 6010709.99 532634.04 MWD+IFR-AK-CAZ-SC 7764.42 89.81 97.10 3477.32 3403.52 2781.25 3435.31 6010698.42 532729.26 MWD+IFR-AK-CAZ-SC 7859.36 89.93 96.20 3477.53 3403.73 2770.25 3529.61 6010687.80 532823.60 MWD+IFR-AK-CAZ-SC 7954.62 89.94 93.23 3477.64 3403.84 2762.42 3624.53 6010680.34 532918.54 MWD+IFR-AK-CAZ-SC 8050.15 89.25 90.46 3478.31 3404.51 2759.35 3720.00 6010677.64 533014.01 MWD+IFR-AK-CAZ-SC 8144.70 89.81 86.51 3479.09 3405.29 2761.85 3814.50 6010680.51 533108.49 MWD+IFR-AK-CAZ-SC 8239.26 87.09 86.90 3481.65 3407.85 2767.28 3908.86 6010686.32 533202.82 MWD+IFR-AK-CAZ-SC 8334.53 88.61 89.81 3485.22 3411.42 2770.01 4004.01 6010689.42 533297.95 MWD+IFR-AK-CAZ-SC 8423.16 86.60 88.08 3488.93 3415.13 2771.64 4092.54 6010691.40 533386.46 MWD+IFR-AK-CAZ-SC 8524.76 87.46 86.20 3494.19 3420.39 2776.70 4193.87 6010696.86 533487.76 MWD+IFR-AK-CAZ-SC 8619.82 87.47 85.53 3498.40 3424.60 2783.55 4288.59 6010704.08 533582.44 MWD+IFR-AK-CAZ-SC 8716.13 87.96 85.40 3502.24 3428.44 2791.16 4384.52 6010712.06 533678.34 MWD+IFR-AK-CAZ-SC 8810.43 90.36 86.38 3503.62 3429.82 2797.92 4478.56 6010719.19 533772.34 MWD+IFR-AK-CAZ-SC 8906.39 90.18 85.75 3503.17 3429.37 2804.50 4574.29 6010726.15 533868.04 MWD+IFR-AK-CAZ-SC 9000.79 90.31 86.05 3502.76 3428.96 2811.25 4668.45 6010733.27 533962.16 MWD+IFR-AK-CAZ-SC 9094.68 89.81 87.75 3502.66 3428.86 2816.33 4762.20 6010738.71 534055.87 MWD+IFR-AK-CAZ-SC 9189.94 89.87 88.63 3502.93 3429.13 2819.34 4857.41 6010742.10 534151.06 MWD+IFR-AK-CAZ-SC 9286.41 91.62 91.20 3501.68 3427.88 2819.48 4953.86 6010742.62 534247.50 MWD+IFR-AK-CAZ-SC 9382.34 94.25 89.12 3496.76 3422.96 2819.21 5049.65 6010742.72 534343.28 MWD+IFR-AK-CAZ-SC 9477.13 94.26 86.94 3489.73 3415.93 2822.46 5144.11 6010746.35 534437.73 MWD+IFR-AK-CAZ-SC 9565.29 90.79 87.70 3485.85 3412.05 2826.58 5232.08 6010750.81 534525.67 MWD+IFR-AK-CAZ-SC 9661.15 88.82 86.06 3486.17 3412.37 2831.79 5327.79 6010756.40 534621.35 MWD+IFR-AK-CAZ-SC 9666.36 88.76 85.83 3486.28 3412.48 2832.16 5332.98 6010756.79 534626.54 MWD+IFR-AK-CAZ-SC 9762.47 89.01 88.51 3488.15 3414.35 2836.90 5428.95 6010761.91 534722.48 MWD+IFR-AK-CAZ-SC 9858.59 90.22 91.69 3488.80 3415.00 2836.74 5525.05 6010762.12 534818.57 MWD+IFR-AK-CAZ-SC 9952.91 90.80 92.79 3487.96 3414.16 2833.05 5619.30 6010758.80 534912.82 MWD+IFR-AK-CAZ-SC 10048.56 88.57 91.50 3488.49 3414.69 2829.47 5714.87 6010755.60 535008.39 MWD+IFR-AK-CAZ-SC 10143.12 88.95 92.62 3490.53 3416.73 2826.07 5809.34 6010752.57 535102.87 MWD+IFR-AK-CAZ-SC 10238.68 89.68 93.05 3491.67 3417.87 2821.35 5904.78 6010748.22 535198.32 MWD+IFR-AK-CAZ-SC 10332.95 90.48 95.46 3491.54 3417.74 2814.35 5998.78 6010741.60 535292.34 MWD+IFR-AK-CAZ-SC 10429.01 90.06 98.43 3491.09 3417.29 2802.74 6094.12 6010730.36 535387.71 MWD+IFR-AK-CAZ-SC 10525.96 90.86 100.38 3490.31 3416.51 2786.90 6189.76 6010714.89 535483.41 MWD+IFR-AK-CAZ-SC 10618.92 88.45 99.63 3490.87 3417.07 2770.75 6281.30 6010699.11 535575.00 MWD+IFR-AK-CAZ-SC 10713.51 90.26 99.73 3491.94 3418.14 2754.85 6374.53 6010683.57 535668.28 MWD+IFR-AK-CAZ-SC 10809.37 87.27 100.32 3494.00 3420.20 2738.16 6468.90 6010667.26 535762.70 MWD+IFR-AK-CAZ-SC 10904.15 86.91 102.57 3498.81 3425.01 2719.38 6561.67 6010648.85 535855.53 MWD+IFR-AK-CAZ-SC 10998.75 85.98 102.70 3504.68 3430.88 2698.73 6653.80 6010628.56 535947.74 MWD+IFR-AK-CAZ-SC 11093.29 86.95 102.51 3510.51 3436.71 2678.14 6745.88 6010608.33 536039.89 MWD+IFR-AK-CAZ-SC 11189.67 88.48 101.54 3514.35 3440.55 2658.08 6840.07 6010588.64 536134.15 MWD+IFR-AK-CAZ-SC 11283.24 89.13 100.87 3516.30 3442.50 2639.90 6931.83 6010570.83 536225.97 MWD+IFR-AK-CAZ-SC 11379.26 87.65 99.88 3519.00 3445.20 2622.61 7026.24 6010553.91 536320.44 MWD+IFR-AK-CAZ-SC 11474.07 90.23 99.33 3520.75 3446.95 2606.80 7119.70 6010538.47 536413.95 MWD+IFR-AK-CAZ-SC 11569.65 88.51 98.18 3521.81 3448.01 2592.25 7214.15 6010524.29 536508.45 MWD+IFR-AK-CAZ-SC ~ 11664.69 88.76 97.30 3524.07 3450.27 2579.46 7308.30 6010511.87 536602.64 MWD+IFR-AK-CAZ-SC i ~- Halliburton Company Survey Report Companc: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 3K Pad 1Vell: 3 K-102 W ell p:rih : 3 K-102 L 1 Sur. c~ Date: 2/19/2COS 'f'imc 16:34:30 Page_ a Co-ordinate(NE) Reference: WeII: 3K-102, True North Vertical (TVD) Reference. 3K-102 (33.8+40j 73-3 Section (VS) Refereuce: Well (O.OON,O.OOE.76.93Azi) Survey Cakulation ~lcthod : Minimum Curvature Db: Oracle }1D Intl ,~zim ll U Svs TVD ft dey deg ft ft -- 11759 .83 89.20 ___ 96.70 3525. 76 _ 3451. 96 11855 .34 91.60 96.56 3525. 10 3451. 30 11950 .57 92.28 97.45 3521. 87 3448. 07 12046 .05 94.16 97.06 3516. 51 3442. 71 12140 .76 94.81 96.97 3509. 10 3435. 30 12200 .00 92.47 96.05 3505. 34 3431. 54 12237 .42 91.10 95.47 3504. 18 3430. 38 12330 .58 87.83 96.49 3505. 05 3431. 25 12427 .73 87.78 97.13 3508. 77 3434. 97 12522 .08 88.33 97.94 3511. 97 3438. 17 12616 .68 88.52 99.34 3514. 57 3440. 77 12712 .54 89.73 99.53 3516. 03 3442. 23 12808 .24 91.42 99.20 3515. 07 3441. 27 12903 .39 90.06 97.93 3513. 85 3440. 05 12997 .21 88.45 96.79 3515. 06 3441. 26 13093 .46 89.19 96.52 3517. 05 3443. 25 13187 .79 89.19 96.39 3518. 38 3444. 58 13282 .92 89.50 97.18 3519. 47 3445. 67 13378 .98 87.77 98.09 3521. 76 3447. 96 13474 .40 84.61 98.67 3528. 10 3454. 30 13568 .65 83.07 98.21 3538. 21 3464. 41 13664 .06 84.35 98.67 3548. 66 3474. 86 13757 .10 84.18 98.88 3557. 96 3484. 16 13854 .99 86.06 99.42 3566 .29 3492. 49 13950 .47 90.67 101.56 3569 .01 3495. 21 14045 .09 89.19 97.42 3569 .13 3495. 33 ` 14081 .00 89.19 97.42 3569 .63 3495. 83 N!S E/)1' ~tap~ ft ft ft 2567.86 7402.72 6010500.65 2556.84 7497.58 6010490.00 2545.23 7592.04 6010478.76 2533.19 7686.60 6010467.10 2521.66 7780.32 6010455.93 2514.96 7839.05 6010449.46 2511.20 7876.26 6010445.86 2501.50 7968.90 6010436.52 2489.99 8065.29 6010425.39 2477.62 8158.77 6010413.39 2463.42 8252.26 6010399.55 2447.71 8346.81 6010384.21 2432.14 8441.23 6010369.01 2417.97 8535.30 6010355.22 2405.95 8628.34 6010343.57 2394.80 8723.92 6010332.79 2384.19 8817.64 6010322.56 2372.96 8912.10 6010311.69 2360.20 9007.27 6010299.31 2346.32 9101.46 6010285.81 2332.57 9194.14 6010272.42 2318.65 9287.95 6010258.87 2304.53 9379.44 6010245.11 2289.02 9475.73 6010229.98 2271.65 9569.54 6010212.97 2256.05 9662.85 6010197.75 2251.41 9698.45 6010193.25 MapE tuo l ft 536697.09 MWD+IFR-AK-CAZ-SC 536791.98 MWD+IFR-AK-CAZ-SC 536886.48 MWD+IFR-AK-CAZ-SC 536981.08 MWD+IFR-AK-CAZ-SC 537074.83 MWD+IFR-AK-CAZ-SC 537133.58 MWD+IFR-AK-CAZ-SC 537170.81 MWD+IFR-AK-CAZ-SC 537263.47 MWD+IFR-AK-CAZ-SC 537359.90 MWD+IFR-AK-CAZ-SC 537453.42 MWD+IFR-AK-CAZ-SC 537546.95 MWD+IFR-AK-CAZ-SC 537641.55 MWD+IFR-AK-CAZ-SC 537736.02 MWD+IFR-AK-CAZ-SC 537830.14 MWD+IFR-AK-CAZ-SC 537923.22 MWD+IFR-AK-CAZ-SC 538018.83 MWD+IFR-AK-CAZ-SC 538112.58 MWD+IFR-AK-CAZ-SC 538207.08 MWD+IFR-AK-CAZ-SC 538302.29 MWD+IFR-AK-CAZ-SC 538396.52 MWD+IFR-AK-CAZ-SC 538489.25 MWD+IFR-AK-CAZ-SC 538583.10 MWD+IFR-AK-CAZ-SC 538674.64 MWD+IFR-AK-CAZ-SC 538770.98 MWD+IFR-AK-CAZ-SC 538864.85 MWD+IFR-AK-CAZ-SC 538958.20 MWD+IFR-AK-CAZ-SC 538993.82 • PROJECTED to TD Halliburton Company Survey Report Company: ConocePhillips Alaska Inc. Bate: 2/19/2003 'l'ime: 16:30:56 Page: 'I Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3K-102, True North Site: Kuparuk 3K Pad Ve rtical (TVD) Re ference: 3K-102 (33.8+40) 73.8 ~~ell: 3K-102 Section (VS) Reference: Well (O.OON D.OOE,72.94Azi) ~~ ellpath: 3K-102L1 P61 Su rvey Calculation Method: Minimum Curva ture 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 System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 3K-102 Slot Name: 50-029-23378-00 Well Position: +N/-S -524.80 ft Northing: 6007903.98 ft Latitude: 70 25 57.619 N +E/-W -2.99 ft Easting : 529305.25 ft Longitude: 149 45 40.017 W Position Uncertainty: 0.00 ft Wellpath: 3K-102L1 PB1 Drilled From: 3K-102 50-029-23378-70 Tie-on Depth: 6745.33 ft Current Datum: 3K-102 (33.8+40) Height 73.80 ft Above System Datum: Mean Sea Level Magnetic Data: 1!5/2008 Declination: 22.96 deg Field Strength: 57630 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.00 0.00 0.00 72.94 Survey Program for Definitive Wellpath Date: 2/19/2008 Validated: No V ersion: 3 Actual From To Survey Toolcode Tool Name ft ft 107.00 456.00 3K-102 Gyro (107.00-456.00) (0 C B-GYRO-SS Camera based gyro single shot 502.52 6745.33 3K-102 MWD+SAG+IIFR+CA+MS (502 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6795.32 12426.28 3K-102L1 PB1 MWD+SAG+IIFR+CA+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey --- _- -- - MD tncl brim 1l U wsTVD Nl5 E/1V )tapA MapN Tool ft deg dey ft ft ft ft ft ft 40.00 0.00 0.00 40.00 -33.80 0.00 0.00 6007903.98 529305.25 TIE LINE 107.00 0.12 187.79 107.00 33.20 -0.07 -0.01 6007903.91 529305.24 CB-GYRO-SS 173.00 0.32 332.86 173.00 99.20 0.03 -0.10 6007904.01 529305.15 CB-GYRO-SS 264.00 1.71 326.92 263.98 190.18 1.39 -0.96 &007905.37 529304.28 CB-GYRO-SS 311.00 2.93 328.00 310.94 237.14 3.00 -1.98 6007906.97 529303.26 CB-GYRO-SS 360.00 3.60 325.07 359.86 286.06 5.32 -3.52 6007909.29 529301.71 CB-GYRO-SS 393.00 4.19 320.51 392.79 318.99 7.10 -4.88 6007911.06 529300.34 CB-GYRO-SS 456.00 5.02 315.48 455.58 381.78 10.84 -8.28 6007914.79 529296.93 CB-GYRO-SS 502.52 6.10 309.53 501.88 428.08 13.87 -11.61 6007917.80 529293.58 MWD+IFR-AK-CAZ-SC 597.51 9.81 301.38 595.95 522.15 21.29 -22.42 6007925.18 529282.75 MWD+IFR-AK-CAZ-SC 692.36 14.58 298.64 688.63 614.83 31.23 -39.81 6007935.05 529265.33 MWD+IFR-AK-CAZ-SC 788.03 17.23 300.42 780.63 706.83 44.18 -62.60 6007947.91 529242.49 MWD+IFR-AK-CAZ-SC 882.92 20.60 303.29 870.39 796.59 60.46 -88.68 6007964.09 529216.34 MWD+IFR-AK-CAZ-SC 977.62 24.32 309.27 957.90 884.10 81.96 -117.71 6007985.47 529187.23 MWD+IFR-AK-CAZ-SC 1073.47 25.15 315.91 1044.97 971.17 109.09 -147.17 6008012.48 529157.67 MWD+IFR-AK-CAZ-SC 1168.61 28.47 320.62 1129.88 1056.08 141.15 -175.64 6008044.42 529129.08 MWD+IFR-AK-CAZ-SC 1264.34 33.51 324.93 1211.93 1138.13 180.44 -205.32 6008083.60 529099.24 MWD+IFR-AK-CAZ-SC 1359.93 37.65 327.01 1289.66 1215.86 226.55 -236.39 6008129.58 529067.99 MWD+IFR-AK-CAZ-SC 1453.35 41.64 327.71 1361.58 1287.78 276.74 -268.52 6008179.63 529035.67 MWD+IFR-AK-CAZ-SC 1549.39 44.49 328.80 1431.74 1357.94 332.51 -303.01 6008235.26 529000.97 MWD+IFR-AK-CAZ-SC 1644.78 48.56 329.73 1497.36 1423.56 392.00 -338.36 6008294.61 528965.39 MWD+IFR-AK-CAZ-SC 1740.75 52.01 332.50 1558.68 1484.88 456.64 -373.97 6008359.10 528929.53 MWD+IFR-AK-CAZ-SC 1835.09 52.93 335.11 1616.15 1542.35 523.77 -406.98 6008426.09 528896.26 MWD+IFR-AK-CAZ-SC 1930.96 53.51 337.49 1673.56 1599.76 594.07 -437.83 6008496.27 528865.13 MWD+IFR-AK-CAZ-SC 2025.37 53.35 341.57 1729.83 1656.03 665.08 -464.34 6008567.16 528838.34 MWD+IFR-AK-CAZ-SC 2120.17 56.23 343.72 1784.48 1710.68 739.00 -487.42 6008640.99 528814.98 MWD+IFR-AK-CAZ-SC 2215.71 60.69 346.00 1834.45 1760.65 817.58 -508.64 6008719.48 528793.45 MWD+IFR-AK-CAZ-SC 2310.64 64.18 347.58 1878.38 1804.58 899.50 -527.85 6008801.31 528773.92 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPt:illips Alaska Inc. Date: 2/19!200 Time: 16:30:5G P:i~c: 2 Field: Kuparuk River Unit Co-ordinate(NE) ltcferencc: WeIL' 3K-102. T rue North Site Ku paruk 3K Pad Vertical(TVD)Retereuce: 3K-102 (33 .5+4 0) 73.8 ~~ell: 3K-102 Sectio n (VS)Reference: Wetl(O.OON,O.OOEJ294Azi) ~~'ellpath: 3K-102L_1PB1 Survey Calc ulation Method: Minimum Curva ture llb: Grade Sur~c~ SID hul Azi~n T~~D Sys "L ~ D NlS F..n1" MapN MapE fool ft deg deg ft ft ft ft ft ft 2406. 76 65. 75 347.86 1919 .05 1845. 25 984 .59 -546. 37 6008886 .32 528755 .07 MWD+IFR-AK-CAZ-SC 2501. 28 66. 76 351.50 1957 .12 1883. 32 1069 .69 -561. 86 6008971 .35 528739 .25 MWD+IFR-AK-CAZ-SC 2596. 49 68. 92 354.77 1993 .04 1919. 24 1157 .22 -572. 37 6009058 .83 528728 .39 MWD+IFR-AK-CAZ-SC 2691. 71 70. 32 356.64 2026 .20 1952. 40 1246 .22 -579. 05 6009147 .80 528721 .37 MWD+IFR-AK-CAZ-SC 2787. 46 70. 50 1.44 2058 .32 1984. 52 1336 .39 -580. 56 6009237 .94 528719 .50 MWD+IFR-AK-CAZ-SC 2880. 62 69. 59 6.14 2090 .13 2016. 33 1423 .73 -574. 78 6009325 .30 528724 .93 MWD+IFR-AK-CAZ-SC 2976. 89 67. 70 10.24 2125 .20 2051. 40 1512 .45 -562. 04 6009414 .06 528737 .33 MWD+IFR-AK-CAZ-SC 3071. 87 67. 06 15.09 2161 .75 2087. 95 1597 .96 -542. 83 6009499 .64 528756 .20 MWD+IFR-AK-CAZ-SC 3109. 84 67. 16 17.28 2176 .52 2102. 72 1631 .55 -533. 08 6009533 .26 528765 .82 MWD+IFR-AK-CAZ-SC 3181. 98 66. 27 18.07 2205 .04 2131. 24 1694 .69 -512. 96 6009596 .47 528785 .69 MWD+IFR-AK-CAZ-SC 3223. 71 65. 97 20.36 2221. 93 2148. 13 1730 .72 -500. 41 6009632 .55 528798 .10 MWD+IFR-AK-CAZ-SC 3319. 60 67. 21 23.90 2260. 04 2186. 24 1812 .21 -467. 25 6009714 .16 528830 .93 MWD+IFR-AK-CAZ-SC 3414. 26 67. 01 28.08 2296. 87 2223. 07 1890 .57 -429. 05 6009792 .66 528868 .82 MWD+IFR-AK-CAZ-SC 3509. 64 66. 99 31.93 2334. 15 2260. 35 1966 .58 -385. 16 6009868 .84 528912 .41 MWD+IFR-AK-CAZ-SC 3603. 77 67. 71 35.99 2370. 41 2296. 61 2038 .61 -336. 64 6009941 .05 528960 .64 MWD+IFR-AK-CAZ-SC 3699. 36 67. 30 40.31 2407 .00 2333. 20 2108 .05 -282. 10 6010010 .69 529014 .90 MWD+IFR-AK-CAZ-SC 3795. 09 67. 98 44.22 2443 .43 2369. 63 2173 .54 -222. 57 6010076 .42 529074 .17 MWD+IFR-AK-CAZ-SC 3891. 20 67. 80 47.69 2479 .61 2405. 81 2235 .44 -158. 58 6010138 .55 529137 .91 MWD+IFR-AK-CAZ-SC 3986. 01 67. 14 49.23 2515 .94 2442. 14 2293 .51 -93. 04 6010196 .88 529203 .22 MWD+IFR-AK-CAZ-SC 4081. 49 66. 77 52.05 2553 .33 2479. 53 2349 .22 -25. 11 6010252 .85 529270 .91 MWD+IFR-AK-CAZ-SC 4175. 56 67. 16 56.38 2590 .15 2516. 35 2399 .83 45. 09 6010303 .73 529340 .91 MWD+IFR-AK-CAZ-SC 4270. 61 67. 61 60.75 2626 .72 2552. 92 2445 .57 119. 94 6010349 .76 529415 .57 MWD+IFR-AK-CAZ-SC 4365. 65 68. 59 65.69 2662 .18 2588. 38 2485 .27 198. 63 6010389 .76 529494 .10 MWD+IFR-AK-CAZ-SG 4462. 06 68. 66 71.07 2697 .34 2623. 54 2518 .33 282. 06 6010423 .15 529577 .38 MWD+IFR-AK-CAZ-SC 4556. 93 69. 47 76.38 2731 .26 2657. 46 2543 .14 367. 08 6010448 .29 529662 .30 MWD+IFR-AK-CAZ-SC 4652. 49 69. 97 80.09 2764 .40 2690. 60 2561 .41 454. 81 6010466 .90 529749 .95 MWD+IFR-AK-CAZ-SC 4747. 29 71. 22 84.12 2795 .90 2722. 10 2573 .68 543. 36 6010479 .52 529838 .44 MWD+IFR-AK-CAZ-SC 4842. 39 71. 50 84.47 2826 .30 2752. 50 2582 .63 633. 02 6010488 .83 529928 .06 MWD+IFR-AK-CAZ-SC 4937. 20 71. 21 83.81 2856 .61 2782. 81 2591 .81 722. 39 6010498 .35 530017 .38 MWD+IFR-AK-CAZ-SC 5032. 21 71. 10 83.54 2887 .30 2813. 50 2601 .71 811. 76 6010508 .60 530106 .70 MWD+IFR-AK-CAZ-SC 5127. 57 71. 35 82.94 2917 .99 2844. 19 2612 .34 901. 41 6010519 .58 530196 .31 MWD+IFR-AK-CAZ-SC 5223. 21 72. 34 82.19 2947 .79 2873. 99 2624 .10 991. 53 6010531 .70 530286 .36 MWD+IFR-AK-CAZ-SC 5319. 30 71. 14 82.07 2977. 90 2904. 10 2636 .59 1081. 92 6010544 .54 530376 .69 MWD+IFR-AK-CAZ-SC 5413. 30 70. 70 82.72 3008 .63 2934. 83 2648 .35 1169. 97 6010556 .65 530464 .69 MWD+IFR-AK-CAZ-SC 5508. 50 71. 38 83.04 3039 .56 2965. 76 2659 .51 1259. 31 6010568 .15 530553 .98 MWD+IFR-AK-CAZ-SC 5603. 67 71. 28 83.19 3070. 02 2996. 22 2670 .32 1348. 82 6010579 .31 530643 .44 MWD+IFR-AK-CAZ-SC 5698. 43 71. 81 82.55 3100. 02 3026. 22 2681 .48 1438. 01 6010590 .82 530732 .58 MWD+IFR-AK-CAZ-SC 5793. 63 71. 47 81.46 3130 .01 3056. 21 2694 .04 1527. 49 6010603 .74 530821 .99 MWD+IFR-AK-CAZ-SC 5888. 18 70. 70 81.52 3160 .66 3086. 86 2707 .28 1615. 95 6010617 .32 530910 .39 MWD+IFR-AK-CAZ-SC 5983. 93 70. 63 81.11 3192 .36 3118. 56 2720 .92 1705. 26 6010631 .31 530999 .64 MWD+IFR-AK-CAZ-SC 6078. 56 71. 11 81.24 3223 .37 3149. 57 2734 .64 1793. 60 6010645 .37 531087 .92 MWD+IFR-AK-CAZ-SC 6173. 94 70. 52 81.45 3254 .71 3180. 91 2748 .19 1882. 66 6010659 .28 531176 .91 MWD+IFR-AK-CAZ-SC 6269. 74 70. 75 81.47 3286 .48 3212. 68 2761 .62 1972. 04 6010673 .05 531266 .23 MWD+IFR-AK-CAZ-SC 6364. 36 71. 01 82.04 3317 .47 3243. 67 2774 .44 2060. 51 6010686 .21 531354 .65 MWD+IFR-AK-CAZ-SC 6459. 26 70. 56 82.04 3348 .71 3274. 91 2786 .85 2149. 26 6010698 .97 531443 .34 MWD+IFR-AK-CAZ-SC 6554. 55 71. 45 84.24 3379 .72 3305. 92 2797 .60 2238. 71 6010710 .08 531532 .73 MWD+IFR-AK-CAZ-SC 6649. 10 71. 33 87.44 3409 .91 3336. 11 2804 .10 2328. 07 6010716 .93 531622 .06 MWD+IFR-AK-CAZ-SC 6745. 33 75. 46 88.89 3437 .40 3363. 60 2807 .04 2420. 22 6010720 .23 531714 .18 MWD+IFR-AK-CAZ-SC 6795. 32 77. 85 89.35 3448 .94 3375. 14 2807 .79 2468. 85 6010721 .17 531762 .80 MWD+IFR-AK-CAZ-SC 6828. 14 80. 95 89.42 3454 .97 3381. 17 2808 .13 2501. 10 6010721 .64 531795 .05 MWD+IFR-AK-CAZ-SC 6858. 34 82. 94 89.49 3459 .21 3385. 41 2808 .42 2531. 00 6010722 .04 531824 .95 MWD+IFR-AK-CAZ-SC 6889. 63 85. 55 89.56 3462. 34 3388. 54 2808 .68 2562 .13 6010722 .42 531856 .07 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Compan}~: ConocoPhlllips Alaska Inc. Ikitc: 2la 9?2008 Time: 16:30-56 Page: 3 Field: Kuparuk River Unit ('o-ordinate(NE)Reference, Welly 3K-102;True North Site: Kuparuk 3K Pad ~~crtical('I'VD)Referenee: 3K-102 (33.8+40) 73.8 ~'Vell: 3K-102 Se~•tion (VS) Reference: Well (O.OON,O.OOE,72.94Azi) Wellpath: 3K-102L1 P61 tiurvey Cakiilation Method: Minimum Curvature Db: Oracle till YCC\ )1D Incl Azim l'~h 5;~7~!'D A!ti 4:.n~' tilapti" MapE fool ~ ft deg deg ft ft ft ft ft ft 6957.57 90.06 89.71 3464.94 3391.14 2809.11 2630.00 6010723.12 531923.94 MWD+IFR-AK-CAZ-SC i 7042.28 90.54 89.89 3464.50 3390.70 2809.40 2714.71 6010723.75 532008.63 MWD+IFR-AK-CAZ-SC 7098.30 91.42 90.01 3463.54 3389.74 2809.45 2770.72 6010724.02 532064.64 MWD+IFR-AK-CAZ-SC 7195.54 89.19 90.21 3463.03 3389.23 2809.27 2867.95 6010724.21 532161.86 MWD+IFR-AK-CAZ-SC 7288.60 87.28 90.13 3465.89 3392.09 2808.99 2960.96 6010724.30 532254.86 MWD+IFR-AK-CAZ-SC 7383.76 88.49 90.21 3469.40 3395.60 2808.71 3056.06 6010724.39 532349.95 MWD+IFR-AK-CAZ-SC 7478.90 88.76 92.26 3471.69 3397.89 2806.66 3151.14 6010722.72 532445.03 MWD+IFR-AK-CAZ-SC 7574.25 88.08 93.44 3474.32 3400.52 2801.92 3246.34 6010718.35 532540.23 MWD+IFR-AK-CAZ-SC 7668.48 89.24 97.20 3476.52 3402.72 2793.19 3340.12 6010709.99 532634.04 MWD+IFR-AK-CAZ-SC 7764.42 89.81 97.10 3477.32 3403.52 2781.25 3435.31 6010698.42 532729.26 MWD+IFR-AK-CAZ-SC 7859.36 89.93 96.20 3477.53 3403.73 2770.25 3529.61 6010687.80 532823.60 MWD+IFR-AK-CAZ-SC 7954.62 89.94 93.23 3477.64 3403.84 2762.42 3624.53 6010680.34 532918.54 MWD+IFR-AK-CAZ-SC 8050.15 89.25 90.46 3478.31 3404.51 2759.35 3720.00 6010677.64 533014.01 MWD+IFR-AK-CAZ-SC 8144.70 89.81 86.51 3479.09 3405.29 2761.85 3814.50 6010680.51 533108.49 MWD+IFR-AK-CAZ-SC 8239.26 87.09 86.90 3481.65 3407.85 2767.28 3908.86 6010686.32 533202.82 MWD+IFR-AK-CAZ-SC 8334.53 88.61 89.81 3485.22 3411.42 2770.01 4004.01 6010689.42 533297.95 MWD+IFR-AK-CAZ-SC 8423.16 86.60 88.08 3488.93 3415.13 2771.64 4092.54 6010691.40 533386.46 MWD+IFR-AK-CAZ-SC 8524.76 87.46 86.20 3494.19 3420.39 2776.70 4193.87 6010696.86 533487.76 MWD+IFR-AK-CAZ-SC 8619.82 87.47 85.53 3498.40 3424.60 2783.55 4288.59 6010704.08 533582.44 MWD+IFR-AK-CAZ-SC 8716.13 87.96 85.40 3502.24 3428.44 2791.16 4384.52 6010712.06 533678.34 MWD+IFR-AK-CAZ-SC 8810.43 90.36 86.38 3503.62 3429.82 2797.92 4478.56 6010719.19 533772.34 MWD+IFR-AK-CAZ-SC 8906.39 90.18 85.75 3503.17 3429.37 2804.50 4574.29 6010726.15 533868.04 MWD+IFR-AK-CAZ-SC 9000.79 90.31 86.05 3502.76 3428.96 2811.25 4668.45 6010733.27 533962.16 MWD+IFR-AK-CAZ-SC 9094.68 89.81 87.75 3502.66 3428.86 2816.33 4762.20 6010738.71 534055.87 MWD+IFR-AK-CAZ-SC 9189.94 89.87 88.63 3502.93 3429.13 2819.34 4857.41 6010742.10 534151.06 MWD+IFR-AK-CAZ-SC 9286.41 91.62 91.20 3501.68 3427.88 2819.48 4953.86 6010742.62 534247.50 MWD+IFR-AK-CAZ-SC 9382.34 94.25 89.12 3496.76 3422.96 2819.21 5049.65 6010742.72 534343.28 MWD+IFR-AK-CAZ-SC 9477.13 94.26 86.94 3489.73 3415.93 2822.46 5144.11 6010746.35 534437.73 MWD+IFR-AK-CAZ-SC 9565.29 90.79 87.70 3485.85 3412.05 2826.58 5232.08 6010750.81 534525.67 MWD+IFR-AK-CAZ-SC 9661.15 88.82 86.06 3486.17 3412.37 2831.79 5327.79 6010756.40 534621.35 MWD+IFR-AK-CAZ-SC 9666.36 88.76 85.83 3486.28 3412.48 2832.16 5332.98 6010756.79 534626.54 MWD+IFR-AK-CAZ-SC 9762.47 89.01 88.51 3488.15 3414.35 2836.90 5428.95 6010761.91 534722.48 MWD+IFR-AK-CAZ-SC 9858.59 90.22 91.69 3488.80 3415.00 2836.74 5525.05 6010762.12 534818.57 MWD+IFR-AK-CAZ-SC 9952.91 90.80 92.79 3487.96 3414.16 2833.05 5619.30 6010758.80 534912.82 MWD+IFR-AK-CAZ-SC 10048.56 88.57 91.50 3488.49 3414.69 2829.47 5714.87 6010755.60 535008.39 MWD+IFR-AK-CAZ-SC 10143.12 88.95 92.62 3490.53 3416.73 2826.07 5809.34 6010752.57 535102.87 MWD+IFR-AK-CAZ-SC 10238.68 89.68 93.05 3491.67 3417.87 2821.35 5904.78 6010748.22 535198.32 MWD+IFR-AK-CAZ-SC 10332.95 90.48 95.46 3491.54 3417.74 2814.35 5998.78 6010741.60 535292.34 MWD+IFR-AK-CAZ-SC 10429.01 90.06 98.43 3491.09 3417.29 2802.74 6094.12 6010730.36 535387.71 MWD+IFR-AK-CAZ-SC 10525.96 90.86 100.38 3490.31 3416.51 2786.90 6189.76 6010714.89 535483.41 MWD+IFR-AK-CAZ-SC 10618.92 88.45 99.63 3490.87 3417.07 2770.75 6281.30 6010699.11 535575.00 MWD+IFR-AK-CAZ-SC 10713.51 90.26 99.73 3491.94 3418.14 2754.85 6374.53 6010683.57 535668.28 MWD+IFR-AK-CAZ-SC 10809.37 87.27 100.32 3494.00 3420.20 2738.16 6468.90 6010667.26 535762.70 MWD+IFR-AK-CAZ-SC 10904.15 86.91 102.57 3498.81 3425.01 2719.38 6561.67 6010648.85 535855.53 MWD+IFR-AK-CAZ-SC 10998.75 85.98 102.70 3504.68 3430.88 2698.73 6653.80 6010628.56 535947.74 MWD+IFR-AK-CAZ-SC 11093.29 86.95 102.51 3510.51 3436.71 2678.14 6745.88 6010608.33 536039.89 MWD+IFR-AK-CAZ-SC 11189.67 88.48 101.54 3514.35 3440.55 2658.08 6840.07 6010588.64 536134.15 MWD+IFR-AK-CAZ-SC 11283.24 89.13 100.87 3516.30 3442.50 2639.90 6931.83 6010570.83 536225.97 MWD+IFR-AK-CAZ-SC 11379.26 87.65 99.88 3519.00 3445.20 2622.61 7026.24 6010553.91 536320.44 MWD+IFR-AK-CAZ-SC 11474.07 90.23 99.33 3520.75 3446.95 2606.80 7119.70 6010538.47 536413.95 MWD+IFR-AK-CAZ-SC 11569.65 88.51 98.18 3521.81 3448.01 2592.25 7214.15 6010524.29 536508.45 MWD+IFR-AK-CAZ-SC 11664.69 88.76 97.30 3524.07 3450.27 2579.46 7308.30 6010511.87 536602.64 MWD+IFR-AK-CAZ-SC 11759.83 89.20 96.70 3525.76 3451.96 2567.86 7402.72 6010500.65 536697.09 MWD+IFR-AK-CAZ-SC f Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/19/2008 Time: 1E:30:56 Page ~ Field: Kuparuk River Unit Co-ordinate(NE}Reference: Weil: 3K-102. True North Site: .Kuparuk 3K P ad Vertical (TVD) Reference: 3K-102 (33.8+40) 73.8 '~ Well: 3K-102 ~ Section (VS) Reference: Well (O.OON,O.OOE]2-94Azi) ' Wellpath: 3K-102L1 PB1 Survey Calculation Method: Minimum Cwvature Ilb: Oracle Survey ~~~ ~ ~ ~ MD Incl lzim f~'D Scs ~f~'D V/ti F./W ~1apN M11.apIC "foal ft deg deg ft ft ft ft ft ---. ft _ - 11855.34 91.60 96.56 3525.10 3451.30 2556.84 7497.58 6010490.00 ._ 536791.98 MWD+IFR-AK-CAZ-SC 11950.57 92.28 97.45 3521.87 3448.07 2545.23 7592.04 6010478.76 536886.48 MWD+IFR-AK-CAZ-SC 12046.05 94.16 97.06 3516.51 3442.71 2533.19 7686.60 6010467.10 536981.08 MWD+IFR-AK-CAZ-SC 12140.76 94.81 96.97 3509.10 3435.30 2521.66 7780.32 6010455.93 537074.83 MWD+IFR-AK-CAZ-SC 12236.37 91.04 95.48 3504.23 3430.43 2511.31 7875.22 6010445.96 537169.76 MWD+IFR-AK-CAZ-SC 12331.39 91.29 96.91 3502.29 3428.49 2501.06 7969.66 6010436.08 537264.24 MWD+IFR-AK-CAZ-SC 12426.28 92.68 98.48 3499.01 3425.21 2488.36 8063.64 6010423.75 537358.25 MWD+IFR-AK-CAZ-SC 12456.00 92.68 98.48 3497.62 3423.82 2483.98 8093.00 6010419.49 537387.63 PROJECTED to TD ~ ~ Time Lois _ __ _ _ _ Date _F_rom To Dur S._Depth E_ Doh Phase Code Subcode T _COM 01/30/2008 15:15 15:30 0.25 7,200 7,230 COMPZ CASIN OTHR P Orient Sperry Sun MWD with Baker MLZXP acker. RIH with same. 15:30 16:00 0.50 7,230 7,230 COMPZ CASIN RURD P Rig down Baker small tongs and tools. 16:00 16:15 0.25 7,230 7,230 COMPZ CASIN OTHR P Move a stand of drill collars and a stand of 5" HWDP from the off driller's side to the driller's side of derrick. 16:15 16:30 0.25 7,230 7,323 COMPZ CASINC RUNL P Make up a stand of 5" drill pipe to the running tool, then run in the hole. Shallow pulse test MWD w/ 100 gpm w/ 560 si. 16:30 21:00 4.50 7,323 12,947 COMPZ CASIN RUNL P Continue to run liner in the hole on 5" drill string. Record PU and SO weight's and rotating torque per Rig Engineer. Monitor displacement on the tri tank. 21:00 22:30 1.50 12,947 14,084 COMPZ CASIN( RUNL P Continue to run liner. Rabbit 5" HWDP with a 2.45" rabbit, and strap same. Ta bottom. 22:30 00:00 1.50 14,084 14,084 COMPZ CASIN OTHR P Pumping 100 gpm w/ 850 psi. Obtain tool face of 90 right, turn string 180 deg and work torque down and up to 38 deg left of high side at midnight. PU wt 245k, SO wt 125k. 01/31/2008 00:00 00:30 0.50 14,084 14,084 COMPZ CASIN( OTHR P Pumping 100 gpm w/ 850 psi. Tool face showing 38 deg left of high side @ setting depth. Apply a small amount of right hand turn and work until a 30 left is observed at setting de th. PU wt 245k, SO wt 125k. 00:30 00:45 0.25 14,084 14,050 COMPZ DRILL OTHR P Pickup and break, then set back a stand of 5" HWDP. Pickup a single of 5"drill pipe. Pipe was rabbitted with a 2.45" rabbit. 00:45 01:45 1.00 14,050 14,080 COMPZ CASIN OTHR P Working pipe from 14080' to 13985' while pumping 100 gpm w/ 850 psi. Obtain 30 de left of hi h side. 01:45 02:30 0.75 14,080 14,074 COMPZ CASINC CIRC P Break the single, drop a 1-3/4 ball to set hanger and packer. Circulate ball to seat pumping 100 gpm w/ 850 psi. Ball on seat after pumping 96.5 bbls. Note worked pipe two more times while pumping ball to seat. MWD showin 30 left of hi h side. 02:30 03:00 0.50 14,074 14,074 COMPZ CASIN OTHR P Pressure string to 2100 psi to set liner hanger. Slack off and set 45k on liner hanger to verify set. Continue to pressure to 3500 psi to activate pusher tool to set the MLZXP liner top packer. Continue to pressure to 4000 psi to release liner and neutralize the usher tool. P~t~ ~~ raf ~2 ~ ~ Time Logs -- Date From To Dur S De th E. De th Ph se Code Subcode T COM 01/31/2008 03:00 03:45 0.75 14,074 14,074 COMPZ CASIN( DHEQ P __ Test annulus to 2500 psi f/ 5 min, ok. Chart test. Pumped through the kill line, using the annular. Bleed off pressure. PU 9' and locate top of packer with the dog sub. Set 45k down on the top of liner with the dog sub. Verified top of liner depth using calculations from to with do sub. 03:45 04:00 0.25 6,908 6,889 COMPZ CASIN RUNL P Pickup and lay down the single of 5" drill pipe. Pickup wt 205k, SO wt 150k. 04:00 04:15 0.25 6,889 6,859 COMPZ CASIN CIRC P Pickup a single, then Break circulation. Monitor well- static. 04:15 04:30 0.25 6,859 6,859 COMPZ CASINC CIRC P Pump a 10 bbl dry job. Chase with 10 bbls of mud. 04:30 04:45 0.25 6,724 6,799 COMPZ CASINC OTHR P Stand back this stand. Blow down the to drive and kill line. 04:45 07:30 2.75 6,799 72 COMPZ CASIN RUNL P Pull out of the hole with liner running tools. Monitor well usin the tri tank. 07:30 08:00 .0.50 72 72 COMPZ CASINC RURD P Rig up Baker tongs for Sperry Sun slim MWD. 08:00 09:00 1.00 72 0 COMPZ CASINC OTHR P Break and lay down Sperry Sun Slim MWD. Break and lay down Baker liner running tools. Shut the blind rams. 09:00 09:30 0.50 0 0 COMPZ CASINC OTHR P Lay down Baker tongs for Sperry Sun slim MWD. 09:30 10:00 0.50 0 0 PROD2 STK OTHR P Rig up to pickup Baker whipstock. 10:00 10:15 0.25 0 0 PROD2 STK OTHR P Pre job safety meeting on picking up the whi stock. 10:15 10:30 0.25 0 0 PROD2 STK PULD P Pickup stand of 5" HWDP with the 'ars, break and la down the same. 10:30 13:30 3.00 0 174 PROD2 STK PULD P Make up Baker whipstock assembly. 13:30 14:00 0.50 174 174 PROD2 STK OTHR P Upload Sperry Sun MWD. 14:00 14:15 0.25 174 334 PROD2 STK PULD P Continue to make up the whipstock assembl BHA # 5 . 14:15 17:15 3.00 334 5,913 PROD2 STK TRIP P Trip in the hole w/ whipstock and milling assembly on 5" drill string. Fill pipe and shallow pulse test @ 1282'. Pumping 550 gpm w/ 1350 psi. Fill pipe @ 3662' pumping 515 gpm w/ 1600 si. 17:15 17:45 0.50 5,913 5,955 PROD2 STK OTHR P Madd pass interval 5913' to 5955' bottom of string). Gamma depth of 5776' to 5816' (Within 1' of matching up to depth of Ugnu-A). Pumping 575 gpm w/ 2360 psi. Log @ 3 foot per minute max runnin seed. 17:45 18:30 0.75 5,955 6,724 PROD2 STK TRIP P Continue to trip in w/ BHA #5 (Whipstock assembly), on 5" drill string. Pickup/make up a single after stand #68. ~'~~~ 29 ~rf 42 '. Time Logs _ _ Date From To ur S De th E. De th PhaSe Code Subcode T COM D 01/31/2008 18:30 __ 19:30 _ T 1.00 6,724 6,724 PROD2 STK OTHR P Orient whipstock from 68 deg right of high side to 15 deg left. Pumping 575 gpm w/ 2800 psi. PU wt 190k, SO wt 145k. Working stand from 6724' to 6629' 95' . 19:30 20:30 1.00 6,724 6,863 PROD2 STK TRIP P Make up another stand (#69). Pumping 575 gpm w/ 2800 psi, slack off to 6860', working whipstock to 20 deg left of highside. Shut down pumps, slack of 5k with collet @ 6862.58' (.20' high). Begin pumping again to squire survey, showing 17 deg left of highside to 14 deg left of t 190k SO t 145k hi h id PU , w w . s e. 20:30 20:45 0.25 6,863 6,795 PROD2 STK OTHR P Slack off 45k to shear bolt. Obtain new parameters: PU wt 185k, SO wt 14147k, rotating 70 rpm: rotating weight 162k w/ 10k ft Ibs of torque. Pumping 367 gpm w/ 1280 psi. i L f~ l Note: Top of window will be ' ' 6795.32 , bottom of window 6812.3 , upper mill @ bottom of window @ +~ 6831.02'. Total milled minimum 35.T= 7v-' 16.98' slide + 18.72' starter mill (8.5" OD to 8-5/8" u er mill. 20:45 00:00 3.25 6,795 6,809 PROD2 STK WPST P Mill window. Pumping 502 gpm w/ 2110 psi. Rotate 100 rpm w/ 11 k ft Ibs of torque. wt on bit 4k. Note: Pumped a 35 bbl sweep (10.3 ppg/ 230 vis) while milling window @ 6805'. 02/01/2008 00:00 00:15 0.25 6,809 6,812 PROD2 STK WPST P Mill window. Pumping 502 gpm w/ 2110 psi. Rotate 100 rpm w/ 11 k ft Ibs of torque. wt on bit 4k. Note: Pumped a 35 bbl sweep (10.3 ppg/ 230 vis) while milling window @ 6805'. 00:15 01:45 1.50 6,812 6,833 PROD2 STK WPST P Continue milling window to bottom of window @ 6812.30' (3452' TVD) Bottom mill depth 6831.02'). Then 2 upper mill 2' below bottom of window. Increase pump rate to 550 gpm w/ 2450 psi. Rotate 60 rpm w/ 11-12k ft Ibs of torque. Note: Pumped a 52 bbl sweep (10.3 ppg/ 2540 vis) while milling window @ 6833'. 01:45 02:30 0.75 6,833 6,833 PROD2 STK WPST P Ream window f/ 6833' to 6775'. Pumping 550 gpm w/ 2450 psi. Rotate 60 rpm w/ 11-12k ft Ibs of torque. Note: Pumped a 50 bbl weighted Hi vis swee + 2 BU. 02:30 03:00 0.50 6,833 6,833 PROD2 STK OIRC P Circulate hole clean. Pump a BU. 03:00 03:15 0.25 6,833 6,833 PROD2 STK OTHR P With pumps off: Slackoff thru window and PU. Noticed 20k over ull. ~~ E~~ts~e 3tJ of 42 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM ~ 02/01/2008 03:15 04:15 1.00 6,833 6,835 PROD2 STK WPST P Mill f/ 6833' to 6835'. Ream window f/ 6835' to 6775'. Pumping 550 gpm w/ 2450 psi. Rotate 110 rpm w/ 11-12k ft Ibs of torque. Note: Pumped a 51 bbl weighted Hi vis sweep (10.15 ppg/ 217 vis) surface to surface + while millin last 2'. 04:15 04:30 0.25 6,835 6,835 PROD2 STK OTHR P With pumps off: Slackoff thru window and PU. No overpull noticed. PU 205k, SO wt 150k.PU wt 04:30 04:45 0.25 6,835 6,709 PROD2 STK TRIP P Puil out of the hole one stand and a sin le. 04:45 05:00 0.25 6,709 6,709 PROD2 STK OTHR P Blow down the top drive. 05:00 05:15 0.25 6,709 6,709 PROD2 RIGMN SFTY P Pre job safety meeting on slip and cut drillin line. 05:15 06:00 0.75 6,709 6,709 PROD2 RIGMN SVRG P Hang the blocks. Slip and cut 114' of 1-3/8"drilling line. Monitor well on the tri tank. 06:00 07:30 1.50 6,709 6,709 PROD2 RIGMN SVRG P Change out the 4-1/2" IF saver sub on the to drive. 07:30 08:15 0.75 6,709 6,709 PROD2 RIGMN SVRG P Grease the drawworks. Service and ins ect the to drive. 08:15 08:30 0.25 6,709 6,620 PROD2 STK TRIP P Pull out of the hole on elevators with the Baker 8-5/8" millin assembl . 08:30 08:45 0.25 6,620 6,620 PROD2 STK OWFF P Monitor well- static. 08:45 09:00 0.25 6,620 6,620 PROD2 STK CIRC P Pump a 25 bbl dry job (11.3 ppg). 09:00 10:45 1.75 6,620 266 PROD2 STK TRIP P Continue to pull out of the hole with the millin assembl . 10:45 11:00 0.25 266 90 PROD2 STK TRIP P Work BHA. 11:00 11:45 0.75 90 90 PROD2 STK OTHR P Download Sperry Sun MWD. 11:45 12:30 0.75 90 0 PROD2 STK PULD P Lay down Mills. Mills guaged to be ood. 12:30 12:45 0.25 0 0 PROD2 STK OTHR P Clear floor of Baker milling BHA and handlin tools. Blinds were shut. 12:45 13:15 0.50 0 0 PROD2 WELCT OTHR P Makeup the stack washing tool. Wash stack working tool up and down while rotating to clean out the cavities of the BOP's. 13:15 13:30 0.25 0 0 PROD2 DRILL PULD P Pickup and makeup, then stand back in the derrick, the jars and 2 joints of 5" HWDP. 13:30 13:45 0.25 0 0 PROD2 DRILL SFTY P Pre job safety meeting for picking up BHA #6 Motor . 13:45 14:15 0.50 0 354 PROD2 DRILL PULD P Make up BHA #6. 14:15 14:30 0.25 354 1,306 PROD2 DRILL TRIP P Trip in the hole with BHA #6. 14:30 14:45 0.25 1,306 1,306 PROD2 DRILL OTHR P Shallow pulse test. Pumping 575 gpm w/ 1690 si. OK. Page 31 of ~2 ~ w Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 02/01/2008 14:45 17:00 2.25 1,306 6,734 PROD2 DRILL TRIP P Continue to trip in the hole with BHA #6. Fill pipe every 25 stands. Monitor well on the trip tank. Fill @ 6162' um in 600 m w/ 2760 si. 17:00 17:45 0.75 6,734 6,734 PROD2 DRILL CIRC P Circulate while working pipe from 6734' to 6638'. Pumping 600 gpm w/ 2830 psi. Rotate 40 rpm w/ 9k ft Ibs of torque. PU wt 185k, SO wt 125k. Circulate 500 bbls total. 17:45 19:00 1.25 6,734 6,734 PROD2 DRILL LOT P LQT• Pump through the kill line to fill, use top pipe rams (Variable 4-1/2" x 7") 9.3 ppg mud in the hole. TD was drilled to 6835' (3456' TVD), applied pressure of 900 psi =.14.3 ppg EMW. Rig down testing equipment. Blow down the kill line. 19:00 19:15 0.25 6,734 6,835 PROD2 DRILL TRIP P Trip in the hole to drill the "D" lateral. Did not notice anything going through the window. Note: Top of window 6795.32' (3448.9' TVD), bottom of window 6812.3' (3452.4' TVD). Oriented to 30 de left of hi hside. 19:15 00:00 4.75 6,835 7,114 PROD2 DRILL DDRL P Obtain parameters. Directional drill 8-1/2" "D" lateral with a motor with 1.5 de bend. 02/02/2008 00:00 00:30 0.50 7,114 6,915 PROD2 DRILL TRIP P Pull out of the hole with BHA #6 on elevators. 00:30 01:00 0.50 6,915 6,830 PROD2 DRILL REAM P Observed excess drag @ 6915' (25k over pull). Make up the top drive and ream w/ 50 rpm 11-14k ft Ibs of torque. Pumping 550 gpm w/ 2450 psi. Rot wt 145k, PU wt 205k, SO wt 125k. 01:00 01:15 0.25 6,830 6,726 PROD2 DRILL TRIP P Continue to pull out of the hole with BHA #6 on elevators. 01:15 01:30 0.25 6,726 6,726 PROD2 DRILL OWFF P Monitor well- static. Pump a 30 bbl dry job, chase with 10 bbl. Blow down the to drive. 01:30 03:45 2.25 6,726 452 PROD2 DRILL TRIP P Continue to pull out of the hole with BHA #6 on elevators. 03:45 04:45 1.00 452 80 PROD2 DRILL PULD P Work BHA #6. 04:45 05:45 1.00 80 80 PROD2 DRILL OTHR P Download Sperry Sun MWD. 05:45 06:15 0.50 80 0 PROD2 DRILL PULD P Lay down motor and bit. 06:15 06:30 0.25 0 0 PROD2 WELC OTHR P Drain BOP stack. Pull the wear bushin . 06:30 08:00 1.50 0 0 PROD2 WELCT OTHR P Rig up to test BOPE. Witness of test waived by AOGCC inspector Chuck Sheave. Make up testing tools. Fill stack with water. Page 32 of 42 Time Lois __ Date From To Dur S Depth E. th Phase Code Subcode T COM 02/02/2008 08:00 12:00 4.00 0 0 PROD2 WELCT BOPE P _ Test all componets to 250 psi low and 3000 psi high. Tested the annular with 4-1 /2" & 5" test jts. Tested upper pipe rams with 4-1/2" test joint. Hold each test for 5 min. Chart test. Perform Koomey test. Test and calibrate gas alarms. 12:00 13:30 1.50 0 0 PROD2 WELCT OTHR NP Rig Down BOPE Test Equipment and Set Wear Bushin 13:30 14:00 0.50 0 0 PROD2 DRILL RURD NP Rig Up to P/U BHA #7, Closed Blind Rams 14:00 14:45 0.75 0 0 PROD2 DRILL OTHR NP Clean & Clear Rig Floor 14:45 15:00 0.25 0 0 PROD2 DRILL SFTY P PJSM on P/U BHA #7 w/ Sperry Sun Re 15:00 17:30 2.50 0 75 PROD2 DRILL PULD NP P/U BHA #7 f/ 0 - 75' MD per Sperry Sun Re 17:30 18:00 0.50 75 0 PROD2 WELCT OTHR NP Stand Back BHA #7, Drain Stack and Pull Wear Bushing; R/U to Test U er Variable Rams w! 5" Test Jt. 18:00 18:30 0.50 0 0 PROD2 WELCT BOPE NP Test 4 1/2" X 7" Variable Upper Pipe Rams w/ 5" test Jt. to 250 PSI Low and 3,000 PSI High; Hold for 5 minutes; Test Good 18:30 19:15 0.75 0 0 PROD2 WELC OTHR NP Rig Down Test Equipment and Install Wear Bushin 19:15 19:30 0.25 0 75 PROD2 DRILL PULD NP P/U BHA #7 19:30 20:00 0.50 75 75 PROD2 DRILL DHEO P Upload Software to MWD Tools 20:00 20:30 0.50 75 356 PROD2 DRILL PULD P Continue P/U BHA#7 20:30 20:45 0.25 356 356 PROD2 DRILL DHEQ P Shallow Test BHA 20:45 21:00 0.25 356 372 PROD2 DRILL PULD P Complete P/U of BHA #7 21:00 22:15 1.25 372 2,749 PROD2 DRILL TRIP P RIH on Elevators f/ 372' - 2749' MD; Monitor Dis lacement Via Tri Tank 22:15 22:45 0.50 2,749 2,749 PROD2 DRILL DHEQ P Fill Pipe & Test MWD Tools 22:45 00:00 1.25 2,749 5,132 PROD2 DRILL TRIP P Cont RIH on Elevators f/ 2749 - 5132' MD 02/03/2008 00:00 02:00 2.00 5,132 6,918 PROD2 DRILL TRIP P RIH on Elevators f/ 5132' - 6918' MD; Hole Deviation "Check Shots" @ 6824', 6857', 6887', & 6918' MD Good 02:00 03:30 1.50 6,918 7,114 PROD2 DRILL REAM P Noted Increase in Drag @ 6918' MD; Reamed Down f/ 6918' - 7114' MD; 30 RPM, 550 GPM @ 2450 PSI, Torque 12 K, P/U 185, S/O 122, Rot 142; Took Hole Deviation "Check Shots" @ 6986,', 7014', 7071', & 7109' MD, All Shots Good 03:30 06:00 2.50 7,114 7,270 PROD2 DRILL DDRL P Ddrl "D" lateral f/ 7114' - 7270' MD; 600 GPM @ 2770 PSI, P/U 195, S/O 122, Rot 145; ECD = 10.82 PPG; Max EPOCH Gas 264 Units Pago ~3 caf 42 Time Logs ___ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 02/03/2008 06:00 12:00 6.00 7,270 8,079 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 7270' - 8079' MD; 700 GPM @ 3420 PSI; P/U 200, S/O 115, Rot 150; ECD = 11.15 PPG; Max EPOCH Gas 1111 Units 12:00 18:00 6.00 8,079 8,374 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8079' - 8374' MD; 700 GPM @ 3530 PSI; P/U 200, S/O 118, Rot 150; ECD = 11.02 PPG; Max EPOCH Gas 954 Units 18:00 00:00 6.00 8,374 8,965 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8347' - 8965' MD; 660 GPM @ 3290 PSI; P/U 205, S/O 120, Rot 150; ECD = 11.47; Max EPOCH Gas 1150 Units 02/04/2008 00:00 06:00 6.00 8,965 9,668 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 8965' - 9668' MD; 650 GPM @ 3360 PSI; P/U 215, S/O 112, Rot 148; ECD = 11.72; Max Gas 1343 Units 06:00 12:00 6.00 9,668 10,453 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 9668' - 10453' MD; 630 GPM @ 3220 PSI; P/U 215, S/O 105, Rot 155; ECD = 11.65; Max Gas 1673 Units 12:00 18:00 6.00 10,453 11,124 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 10453' - 11124' MD; 640 GPM @ 3390 PSI; P/U 215, S/O 105, Rot 148; ECD = 11.91; Max Gas 1834 Units 18:00 00:00 6.00 11,124 11,715 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 11124' - 11715' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 02/05/2008 00:00 04:45 4.75 11,715 12,200 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 11715' - 12200' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 04:45 06:45 2.00 12,200 12,457 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 12200' - 12457' MD; 650 GPM @ 3340 PSI; P/U 215, S/O 105, Rot 150; ECD = 11.91; Max Gas 1179 Units 06:45 07:30 0.75 12,457 12,175 PROD2 DRILL TRIP NP POOH f/ 12457' - 12175' MD for Side Track. 07:30 07:45 0.25 12,175 12,200 PROD2 DRILL DDRL NP Trough for Sidetrack f/ 12175' - 12200' MD; De artin Down and Ri ht 07:45 12:00 4.25 12,200 12,457 PROD2 DRILL DDRL NP Cont'd Ddrlg "D" Lateral f/ 12200' - 12457' MD; 615 GPM @ 3390 PSI; P/U 215, S/O 105, Rot 150; ECD = 12.14; Max as 738 Units 12:00 18:00 6.00 12,457 13,167 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 12457' - 13167' MD; 630 GPM @ 3710 PSI; P/U 220, S/O 98, Rot 150; ECD = 12.3; Max Gas 1501 Units 18:00 20:15 2.25 13,167 13,502 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 13167' - 13502' MD; 615 GPM @ 3670 PSI; P/U 225, S/O 95, Rot 150; ECD = 12.42; Max Gas 1839 Units 20:15 22:00 1.75 13,502 13,502 PROD2 DRILL CIRC P Rot & Recip While Pumping 43 Bbls of 11.1 PPG 249 Vis Sweep to Clean Hole; Take SPR's I~~~~ ~a ~~ ~z Time Logs _ _ ____ __ __ D e From To Dur S_pepth E. De th Pha e Code Su6code T COM ? 02/05/2008 22:00 00:00 2.00 13,502 13,694 PROD2 DRILL DDRL P Ddrl "D" Lateral f! 13502' - 13694' MD; 615 GPM @ 3800 PSI; P/U 225, S/O 95, Rot 150; ECD= 12.53; Max Gas 979 Units 02/06/2008 00:00 06:00 6.00 13,694 14,081 PROD2 DRILL DDRL P Ddrl "D" Lateral f/ 13694' - 14081' MD TD ~ 585 GPm @ 3490 PSI; P/U 250, S/O 85, Rot 150; ECD = 12.62 06:00 08:00 2.00 14,081 14,081 PROD2 DRILL CIRC P Rot &Recip While Pumping 50 Bbl 11.3 PPG 400 Vis Sweep; 595 GPm 3720 PSI 08:00 12:00 4.00 14,081 11,602 PROD2 DRILL REAM P BROOH f/ 14081' - 11602' MD; 640 GPM 3800 PSI; P/U 220, S/O 98 12:00 18:00 6.00 11,602 8,654 PROD2 DRILL REAM P BROOH f/ 11602' - 8654' MD; 650 GPM 3250 PSI; P/U 190, S/O 115 18:00 22:00 4.00 8,654 7,033 PROD2 DRILL REAM P BROOH f/ 8654' - 7003' MD; 600 GPM 2490 PSI 22:00 22:15 0.25 7,033 6,748 PROD2 DRILL TRIP P Pump Out-of-Hole f/ 7033' - 6748' MD; 600 GPM 2440 PSI 22:15 00:00 1.75 6,748 6,748 PROD2 DRILL CIRC P Rot &Recip While Circ 1- B/U, then Pump 50 Bbl 11.3 PPG 330 Vis Sweep at Shoe, and 3 - B/U After Swee 02/07/2008 00:00 00:15 0.25 6,748 6,748 PROD2 DRILL OWFF P Observe Well For Flow (Static) 00:15 00:30 0.25 6,748 6,748 PROD2 RIGMN SVRG P Inspect & Adjust Draw Works Brakes 00:30 04:00 3.50 6,748 13,980 PROD2 DRILL TRIP P RIH on Elevators f/ 6748' - 13980' MD; Filled Pi a e/ 25 Stds 04:00 04:15 0.25 13,980 14,075 PROD2 DRILL OTHR P Rotate & Wash in Hole f/ 13980' - 14075' MD; 195 GPM @ 850 PSI; P/U 220, S/O 100, Rot 150; 12 Bbl Loss for Whole Tri 04:15 06:00 1.75 14,075 14,081 PROD2 DRILL CIRC P CBU While Working Pipe f/ 14081' - 13983' MD; Staged Pumps Down f/ 600 GPM @ 3370 PSI to 375 GPM @ 1800 PSI Due to Hole Taking Fluid (30 bbl Loss 06:00 07:45 1.75 14,081 14,081 PROD2 DRILL CIRC P Pump 50 Bbl (9.3 PPG, 400 Vis) Sweep While Working Pipe f/ 14081' - 13983' MD; 450 GPM 2370 PSI 07:45 09:00 1.25 14,081 14,081 PROD2 DRILL CIRC P Displace Wellbore Fluid to 9.3 PPG SFOBM; 650 GPM 3800 PSI 09:00 09:45 0.75 14,081 14,081 PROD2 DRILL OWFF P Observe Well for Flow (Static) 09:45 15:30 5.75 14,081 6,179 PROD2 DRILL TRIP P POOH on Elevators f/ 14081' - 6179' MD; Dropped 2.36" Rabbit w/ 186' Tail @ 13409' MD; P/U 270 - 245, S/O 80 - 105 f/ 14081' - 11507' MD 15:30 15:45 0.25 6,179 6,179 PROD2 DRILL OWFF P Observe Well for Flow (Static) 15:45 18:00 2.25 6,179 657 PROD2 DRILL TRIP P POOH f/ 6179' - 657' MD; Rerieved Rabbit 18:00 18:30 0.50 657 371 PROD2 DRILL TRIP P POOH f! 657' - 371' MD 18:30 19:30 1.00 371 75 PROD2 DRILL PULD P UD BHA #7 f/ 371' - 75' MD, Break Out Bit; Well Static E~age 36 cxt ~2 Time Lois __ ____ __ Date . From To Dur S. De th E. Depth Phase Code Subcode T COM ___ 02/07/2008 19:30 20:45 1.25 75 75 PROD2 DRILL DHEO P Download MWD Tools; Well Static 20:45 22:00 1.25 75 0 PROD2 DRILL PULD P UD BHA #7 f/ 75' - 0' per Sperry Rep 22:00 22:15 0.25 0 0 PROD2 DRILL OTHR P Close Blind Rams ; Celan & Clear Rig Floor 22:15 23:45 1.50 0 149 COMPZ FISH PULD P M/U Whi stock Rerieval BHA per Baker Oil Tools Re 23:45 00:00 0.25 149 245 COMPZ FISH TRIP P RIH on Elevators f/ 149' - 245'; Circ @ 3 Bpm @ 1040 Psi Prior to Opening CCV 02/08/2008 00:00 00:15 0.25 245 245 COMPZ FISH CIRC P Drop 2 1/8" Ball to Open CCV, CCV Opened @ 2010 PSI; PSI Dropped to 50 PSI 3 BPM After Actuation 00:15 03:15 3.00 245 6,683 COMPZ FISH TRIP P RIH w/CCV Open f/ 245' - 6683' MD; P/U 210, S/O 150, Rot 170, Tor ue 9K 03:15 04:00 0.75 6,683 6,775 COMPZ FISH CIRC P Circulate Through Open CCV Staging Pumps Up f/ 450 GPM @ 1210 PSI - 900GPM @ 3450 PSI; P/U 210, S/O 150, Rot 175, Tor ue 12K 04:00 05:00 1.00 6,775 6,775 COMPZ RPCOh CIRC P Condition Mud to 3 % 776 Lube; 600 GPM @ 2010 PSI; P/U 210, S/O 150, Rot 175, Tor ue 10K 05:00 05:30 0.50 6,775 6,775 COMPZ FISH CIRC P Dropped 2 1/8" Ball to Close CCV; Ball on Seat early @ 486 Strokes; CCV Closed @ 2320 PSI; Pressure Increased f/ 180 PSI @ 30 Strokes to 480 PSI 30 Strokes 05:30 06:00 0.50 6,775 6,808 COMPZ FISH FISH P RIH f/ 6775' - 6808" MD; Washed Slot & Attempt to Engage Whipstock; En a ed Whi stock and Pulled Up to 280, Observed Unloader Shear Whi stock Free; P/U 210, 150 06:00 07:00 1.00 6,808 6,683 COMPZ FISH CIRC P POOH f/ 6808' - 6683' MD; CBU 450 GPM 2520 PSI 07:00 07:30 0.50 6,683 6,683 COMPZ FISH OTHR P Observe Well For Flow (Static) 07:30 10:45 3.25 6,683 215 COMPZ FISH TRIP P POOH f/ 6683' - 215' MD 10:45 12:00 1.25 215 0 COMPZ FISH PULD P Lay down Fishing Tools 12:00 14:30 2.50 0 0 COMPZ FISH PULD P Break Out /Lay Down Whipstock BHA 14:30 15:00 0.50 0 0 COMPZ RPCOh OTHR P Clean & Clear Rig Floor 15:00 15:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM for Seal Bore Diverter Run 15:15 16:15 1.00 0 0 COMPZ RPCOh DHEQ P Upload MWD Tools Page 3 of ~2~ Time Logs _ __ Date_ From To Dur 5- De th E. De th P hase Code Subcode T COM _ 02/08/2008 16:15 18:30 2.25 0 0 _ COMPZ RPCOti PULD P P/U Seal Bore Diverter Assy and MWD Tools; SBD Oriented 13.7 Degrees Right of Production Anchor at Surface Due to Evidence of Mill Walking to Right on Whipstock; Oriented MWD to SBD Lug; ** Note: MLZXP Set at 30 Degreees Left of High Side, w/ BOT Correction MWD Should Show 17 Degrees Left When Latched ** 18:30 18:45 0.25 0 0 COMPZ RPCOh DHEQ P Flow Test Baker Seal Bore Diverter Nozzle and Shallow Test MWD Tools: Gain MWD Detection - 270 GPM @ 580 PSI; Actuate (Release) SBD Collet 420 GPM 1340 PSI 18:45 23:00 4.25 0 6,743 COMPZ RPCO TRIP P RIH w/ Baker Seal Bore Diverter f/ 0.0 - 6888' MD 23:00 00:00 1.00 6,743 6,888 COMPZ RPCO OTHR P Worked Last Stand While Orienting SBD to 22 left of high side; Latched In to MLZXP Packer at 6888' MD; SBD Ramp Aligned @ 19 Deg Left When Latched; Verified Latch by Pulling to 260K; Slack off to 110k, Released Inner String while pumping 475 GPM w/ 2660 PSI; P/U 190, S/O 150 02/09/2008 00:00 00:15 0.25 6,888 6,839 COMPZ RPCO CIRC P After release of the Seal Bore Diverter, pull out of the hole from the top of the Seal Bore Diverter @ 6787.91' to 6739 while pumping 475 GPM w/ 2660 PSI; P/U 190, S/O 150. Continue to circulate to et a bottom's u . 00:15 00:30 0.25 6,839 6,839 COMPZ RPCOh OWFF P Monitor well (static). Install stripper rubber. 00:30 03:45 3.25 6,839 127 COMPZ RPCOh TRIP P Pull out of the hole w/ Seal Bore running tools. Record PU and SO wt's eve 10 stands. 03:45 04:15 0.50 127 104 COMPZ RPCOh PULD P Lay down BHA. 04:15 04:45 0.50 104 90 COMPZ RPCOh OTHR P Download Sperry Sun MWD. 04:45 05:30 0.75 90 0 COMPZ RPCOh PULD P Continue to lay down running tools for the Seal Bore Diverter 05:30 05:45 0.25 0 0 COMPZ RPCOh PULD P Pickup from the pipe shed the Centurian circulating valve. Break the ball catcher and remvoe (2) 2 1/8" balls. Screw back together hand tight and la back down. 05:45 07:15 1.50 0 0 COMPZ RPCOA RURD P Ri u to run the 4-1 /2" "D" al slot nk 11.6 f L-80 BTC liner. 07:15 07:30 0.25 0 0 COMPZ RPCOti SFTY P PJSM on running the liner. 07:30 12:30 5.00 0 7,116 COMPZ RPCOh TRIP P Run 4 1/2" Slotted/Blank Liner f/ 0' - 7116' MD; Obtain Torque and Drag Data Eve 5 Stds 12:30 13:45 1.25 7,116 7,168 COMPZ RPCO PULD P M/U Ram Hanger Assy per BOT Rep F~~~e 37 0# ~2 Time Logs ____. Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 02/10/2008 02:00 02:30 0.50 6,623 6,623 COMPZ RPCOh CIRC P CBU 340 GPM @ 870 PSI 02:30 03:00 0.50 6,623 6,623 COMPZ RPCOh OWFF P OWFF (Static) 03:00 05:15 2.25 6,623 0 COMPZ RPCOh TRIP P POOH f/ 6623' - 0' MD per BOT Rep; UD Baker RAM Han er Runnin Tools 05:15 06:00 0.75 0 0 COMPZ RPCOti OTHR P Clean & Clear Rig Floor 06:00 06:45 0.75 0 0 COMPZ RPCO RURD P Rig Up to Run LEM and Torque Master Packer per Sperry Sun & BOT re s: Close Blind Rams 06:45 07:00 0.25 0 0 COMPZ RPCO SFTY P PJSM for P/U LEM, Packer, and MWD Tools 07:00 08:15 1.25 0 0 COMPZ RPCOA PULD P P/U Type II (instead of Type I as planned)LEM, Torque Master Packer, and MWD 08:15 08:30 0.25 0 0 COMPZ RPCOh DHEQ P Pulse Test MWD 80 GPm @ 400 PSI; Blow Down To Drive 08:30 13:00 4.50 0 6,778 COMPZ RPCOh TRIP P RIH w/ Type II LEM on DP f/ 0' - 6778' MD 13:00 13:45 0.75 6,778 6,810 COMPZ RPCOh DHEQ P Orient Type II LEM Lug to RAM Hanger; 90 GPM @ 830 PSI; P/U 198, S/O 150 Note: LEM lug self oriented from 6 deg Right of highside to 85 deg Right of hi hside b MWD readin s. 13:45 15:30 1.75 6,810 6,810 COMPZ RPCOti PACK P Drop 29/32" Ball to Set Packer; Ball on Seat @ 1350 Strokes; 92 GPM @ 990 PSI; Pressured Up to 2500 PSI to Set Packer; Held Pressure for 5 Minutes (Good); Top of Packer @ D 15:30 16:00 0.50 6,810 6,810 COMPZ RPCO PACK P Pressure Up Annulus Through Kill Line t/ 2500 PSI and Hold f/ 5 Minutes Good 16:00 16:15 0.25 6,810 6,810 COMPZ RPCOh PACK P Pump down string, Pressured Up to 4380 PSI to Release Packer Setting Tool and blow ball seat. 16:15 17:30 1.25 6,810 6,810 COMPZ RPCOh CIRC P CBU: 340 GPM @ 900 PSI; Pump 26 Bbl "Dry Job" and chase w/ 10 Bbl Mud; Dro "Mud Do " 17:30 22:30 5.00 6,810 0 COMPZ RPCO TRIP P POOH f/ 6810' - 0' MD; Lay Down 5" DP 22:30 00:00 1.50 0 0 COMPZ RPCOR PULD P Break Out & UD BOT Packer Setting Tools & Slim Hole MWD Tools 02/11/2008 00:00 00:30 0.50 0 0 COMPZ RPCOh PULD P Continue to UD MWD and BOT Packer Settin Tools 00:30 01:00 0.50 0 0 COMPZ RPCOh OTHR P Clean Clear Rig Floor of LEM Running Tools 01:00 02:15 1.25 0 0 COMPZ RPCO RURD P Close Blind Rams, Drain Stack & Pull Wear Bushing; Pull Mousehole Remove Drain, Install Bull Plug & Install In Rotary Table; Prep U UD 5" DP f/ Derrick 02:15 02:30 0.25 0 0 COMPZ RPCOh SFTY P PJSM for UD 5" DP f/ Derrick Fade 33 raf 42 ~ Time Logs __ _ ___ __ Date From To Dur 5. De th E. De th Phase Code Subcode T COM 02/11/2008 _ 02:30 06:00 3.50 0 _ 0 _ COMPZ RPCOh PULD P UD 5" DP f/ Derrick 06:00 09:45 3.75 0 0 COMPZ RPCOh PULD P Continue t/ UD 5 " DP f/ Derrick 09:45 14:00 4.25 0 0 COMPZ RPCOti RURD P Clean & Clear Rig Floor; R/U Centerlift & GBR for 4 1/2" Tubing Run w/ Heat Trace & Gau a Cable 14:00 14:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM w/GBR, Centerlift, BOT, & Rig Crew for Runnin 4 1/2" Tubin Strin 14:15 18:00 3.75 0 1,205 COMPZ RPCO RCST P Run 4 1/2" Completion String f/ 0' - 1205' MD er Detail 18:00 22:00 4.00 1,205 3,457 COMPZ RPCOh RCST P Continue Running 4 1/2" Tubing f/ 1205' - 3757' MD 22:00 00:00 2.00 3,757 3,757 COMPZ RPCOh RURD P P/U Dual Channel Cross Clamps; R/U Heat Trace Sheave in Derrick 02/12/2008 00:00 01:00 1.00 3,757 3,757 COMPZ RPCO RURD P P/U Dual Channel Cross Clamps; R/U Heat Trace Sheave in Derrick 01:00 01:15 0.25 3,757 3,757 COMPZ RPC06 SFTY P Pre job safety meeting on running with both the heat trace and TEC wire. 01:15 01:45 0.50 3,757 3,757 COMPZ RPCOh DHEQ P Test heat trace (Megger wire) OK. 01:45 03:00 1.25 3,757 3,944 COMPZ RPCO RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 125 in the hole. Monitor well on the trip tank. 03:00 03:15 0.25 3,944 3,944 COMPZ RPCO DHEQ P Test heat trace (Megger wire) OK. Testin TEC wire for the ua e. OK. 03:15 05:00 1.75 3,944 4,314 COMPZ RPCO RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 137 in the hole. Monitor well on the trip tank. 05:00 05:30 0.50 4,314 4,314 COMPZ RPCO DHEQ P Test heat trace (Megger wire) OK. Testin TEC wire for the ua e. OK. 05:30 06:00 0.50 4,314 4,438 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Joint # 141 in the hole. Monitor well on the trip tank. 06:00 12:00 6.00 4,438 5,197 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 12:00 18:00 6.00 5,197 6,344 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 18:00 21:15 3.25 6,344 6,739 COMPZ RPCOh RCST P Continue to run 4-1/2" 12.6 ppf L-80 IBT-M tubing completion. Monitor well on the tri tank. 21:15 00:00 2.75 6,739 6,739 COMPZ RPCOh RCST T Attemoting to latch TorqueMaster n r sembl .Not latching. Call town and discuss options. Attempt to rotate tubing 90" & 180* with elevators. Can't hold torque. Continue attem is to latch anchor 02/13/2008 00:00 01:15 1.25 6,768 6,768 COMPZ RPCOfi RCST T TorqueMaster anchor not latching. Circulate bottoms ups while discussing options with town. Pumping 338 gpm, 480 psi, max gas 41 units. ~_~~_~~ __ww_.. es~_ fags 4~ ref 42 • l J Time Logs _____ Date From To Dur S. De th E. De th Ph e Code Subcode T COM 02/13/2008 01:15 01:45 0.50 6,768 6,768 COMPZ RPCO RCST T Continue working pipe attempting to latch anchor. Pumps on, rotate 90*, 180* holding torque with topdrive. Stop pumps, rotate 270* attempt to latch. 1st try saw bobble on weight indicator. 2ny{„11y__latch~d with 28' of joint 216 in 01:45 02:00 0.25 6,768 6,768 COMPZ RPCOh RURD T Rig down crossovers and blow down to drive. 02:00 02:15 0.25 6,768 6,768 COMPZ RPCO RCST P Pull with elevators to 55k over up wt of 130k to shear from seal assembl 02:15 03:30 1.25 6,768 6,679 COMPZ RPCO RCST P POOH and lay down 3 joints of tubing. Retest heat trace and control line, both ood. 03:30 04:45 1.25 6,679 6,768 COMPZ RPCOM1 HOSO P PU space out pups, hanger and landin 'oint and run in hole. 04:45 05:30 0.75 6,768 6,768 COMPZ RPCO PULD P Rig down sheves from derrick. 05:30 08:15 2.75 6,768 6,768 COMPZ RPCOh RCST P Splice heat trace and control cable. Sim ops clear rig rloor, clean drip pan and clean it #5. 08:15 10:15 2.00 6,768 6,768 COMPZ RPCO RCST P Land tubing in hanger, run in lock down screws, pull landing joint, blow down lines, clear ri floor. 10:15 14:30 4.25 0 0 COMPZ RPCO RURD P Lay down mouse hole, nipple down BOPE. 14:30 15:00 0.50 0 0 COMPZ RPCO NUND P Nipple up tubing adapter and tree. 15:00 15:30 0.50 0 0 COMPZ RPCOb RCST P Test heat trace and control cable, test ood. 15:30 17:00 1.50 0 0 COMPZ RPCOh NUND P Pressure test seals and tree to 5000 si, test ood 17:00 18:00 1.00 0 0 COMPZ RPCO RURD P PJSM -freeze protect. Rig up to freeze protect 9-5/8" x 4-1 /2" annulus and 4-1/2" tubing. Pressure test lines and ull 2 wa check valve. 18:00 19:00 1.00 0 0 COMPZ RPCO FRZP P Freeze protect 9-5/8" x 4-1l2" annulus and 4-1 /2" tubing. Pump 160 bbls at 3 b m, 675 si. 19:00 20:30 1.50 0 0 COMPZ RPCOti FRZP P Put 9-5/8" x 4-1/2" annulus and 4-1/2" tubing in communication and u-tube freeze protect diesel. Sim ops -blow down lines & clear cellar for ri move. 20:30 22:00 1.50 0 0 COMPZ RPCOh RURD P Shut in well, rig up lubricator, install back pressure valve and gauges. Tubing pressure 350 psi, 9-5/8" x 4-1/2"annulus pressure 350 psi, 13-3/8" x 9-5/8" annulus pressure 150 si 22:00 00:00 2.00 0 0 COMPZ RPCOM1 OTHR P Clean cellar box, blow down steam and water lines. Disconnect lines between modules. Move cuttings boxes and re rockwasher for move. 02/14/2008 00:00 01:15 1.25 0 0 COMPZ RPCOh OTHR P PJSM -removing beaver slide. Lay down beaver slide €'~ge 41 of 42 C~ Time Logs Date From To Dur 5 Depth E. De th Phase Code Subcode T COM 02/14/2008 01:15 03:00 1.75 0 0 COMPZ RPCOh OTHR P PJSM -skidding rig floor. Skid rig floor and function test moving system. Release ri at 03:00 P~~~ 4~ ~~ ~2 • West Sak 3K-102 SWC.xIs Sidewall Cores 3K-102 Geochem SWC Preliminary Actual Actual Formation MD MD ssTVD • Inches Recovery 1 West Sak B 7557 7557 -3472.12 2" 2 West Sak B 7534 7534 -3471.42 1-1/2" 3 West- Sak B 7508 7508 -3470.44 1-1 /2" 4 West Sak B 7488 7488 -3469.51 2" 5 West Salo B 7480 7480 -3469.08 2" 6 West Sak B 7458 7458 -3467.73 1-3/4" 7 West Sak B 7435. 7435 -3466.07 2" 8 West Sak B 7400: 7406 -3463.59 2" 9 West Sak Df 7029. 7029 -3414.87 1-3/4" 10 West Sak DI 7025- 7025 -3414.26 2" 11 West Sak Dl 7002 7002 -3410.72 1-1 /2" 12` West Sak DI 6980 6980 -3407.25 1-7/8" 13 West Sak DI 6977 6977 -3406.77 2" 14 West Salo DI 6963 6963 -3404.51 1-5/8" 15 West Sak Du- 6876 6876 -3389.90_ 1-7/8" 16 West Sak Du 6862 6862 -3387.50 1-5/8" 17 West Salo Du 6855 6855 -3386.29 1-7/8" 18 West Sak. Du 6850' 6850 -3385.43 1-5/8" 19 West Sak Du 6839 - 6839 -3383.52 2" 20 West Sak Du 6818 6818 -3379.68 2" 21 N Sand 6302 6302 -3223.29 2" 22 N Sand 6298. 6298. -3221.98 No Sam le 23° N Sand 6294 6294 -3220.66 2" 24 N Sand 6285- 6285 -3217.70 1-3/4" 25 U nu A 5926 5926- -3099.36 2" 26 U nu A 5916- 5916 -3096.06 1-3/4" 27 U nu A 5905`: 5905 -3092.42 2" 28 U nuA 5895. 5895 -3089.11 1-1/2" 29 U nu A 5882-" 5882' -3084.82 1-7/8" 3Q U nu B 5769: 5769 -3048.40 1-7/8" 31 U nu B 5765 5765 -3047.13- 1-5/8" 32 U nu B 5740 5740 -3039.25 1-1/2" 33 U nu B 5720 5720 -3032.97 2" 34 U nu B 5680 5680 -3020.45 1-3/4" 35 U nu B 5655 5655 -3012.57 1-7/8" 36: U nu B 5637 5637 -3006.87 1-5/8" 37 U nu B 5619 5619: -3001.13 1-1/2" 3& U na B 5605 5605 -2996.65 1-3/8" 39 U nu B 5580 5580- -2988.63 2" 40 U nu B 5568 5568 -2984.78 1-7/8" 41 U nu B 5555 5555 -2980.62 1-1/2" 42 U nu C 5476 5476 -2955.32 1-1/2" 43 U nu C 5470- 5470 -2953.38 2" 44 U nu C 5448 5448 -2946.22 1-3/4" 45 U nu C 5428 5428 -2939.67 1-3/4" Oil Quality SWC Formation Count West Sak B 8 West Sak D .Lower 6 West Sak D Upper 6 N Sand 3 Ugnu A 5 Ugnu B 12 Ugnu C 4 Total 44 (Misfired) • 27-Mar-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-102 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 12,140.76' MD Window /Kickoff Survey: 12,200.00' MD (if applicable) Projected Survey: 14,045.00' 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 _/1 ~ , ~, ~ , Date ~(~ /"lM oi~p Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~2c.~ ~ - ((~ C~ 27-Mar-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-102 L1 PB1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 6,745.33' MD Window /Kickoff Survey: 6,795.00' MD (if applicable) Projected Survey: 12,456.00' 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 ,~~ A ,~ / , Date ~, ~ l"(~.dA'6`~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~-c~c~ 3K-102 L1 1st Geologic Sidetr~ Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Tuesday, February 05, 2008 11:13 AM To: 'Hartwig, Dennis D' Subject: RE: 3K-102 L1 (207-166) 1st Geologic Sidetrack Dennis, Thanks for the information. I will place a copy of this message in the file. Nothing further is needed. One request, please include the permit # in the message line. It helps filing. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, February 05, 2008 10:26 AM To: Maunder, Thomas E (DOA) Subject: 3K-102 L1 1st Geologic Sidetrack Tom, Details of the 1st sidetrack in the 3K-102 L1 (D-Sand) are as follows; • Well: 3K-102 L1 • Rig: Doyon 15 • Date: 2/5/08 • Time: 0800 hrs • Last Casing: 9-5/8° Intermediate Window Tap (6,796') MD of abandoned section: 12,200' -12,457' Page 1 of 1 While drilling in the D-sand, the well trajectory brought up to a shallower TVD in search of getter pay and drilled out of zone into the overlying claystone. The well was sidetracked to optimize the time spent in pay. Please contact me if question arise... Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 2/5/2008 3K-102L1 Leak-off Test Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Monday, February 04, 2008 10:27 AM To: Maunder, Thomas E (DOA) Subject: RE: 3K-102L1 Leak-off Test ~Q~ " Page 1 of 2 Tom -You're not missing anything. My New Years resolution was to be more proactive with communication so if we change anything on reports after the fact I will communicate it in a more timely manner. Dennis From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Monday, February 04, 2008 10:22 AM To: Hartwig, Dennis D Subject: RE: 3K-102L1 Leak-off Test Thanks Dennis. From what I understand, either MWE is more than sufficient to allow drilling the lateral. Is there something 1 am missing here? Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, February 04, 2008 10:20 AM To: Maunder, Thomas E (DOA) Subject: 3K-102L1 Leak-off Test Tom, On 2/1/2008 we conducted aLeak-off Test on Doyon 15. The Leak-off test was conducted in the D- Sand Lateral after milling a window out of 9-5/8" casing. The report for 2/1/08 refers to a L.O.T. result of 975psi or 14.7ppg MWE. After reviewing the L.O.T this morning it appears the actual Leak-off value is 900psi or 14.3 MWE. (conducted at 3449'TVD with a 9.3ppg mud) The report has been updated to reflect the 14.3ppg value. Regards...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-980-1433 2/5/2008 ~ ~ SARAH PAUN, GOVERNOR CO~T~~~ ~~O O ~ I~1a~ 333 W. 7th AVENUE, SUITE 100 1~ •••~~'~~aiii~~•~~iiii---777 ~o111fs ANCHORAGE, ALASKA 99501-3539 Randy Thomas PHONE (907) 279-1433 FAX (907) 276-7542 Drilling Team Leader Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 3K-102L1 Conoco Phillips Alaska, Inc. Permit No: 207-166 Surface Location: 910' FSL, 315' FWL, SEC. 35, T13N, R09E, UM Bottomhole Location: 3154' FSL, 4736' FWL, SEC. 36, T13N, R09E, 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 3K-102, Permit No 207-165, API 50-029-23378-00. 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, contact the Commission's petroleum field inspector at 5907) 659-3607 (pager). DATED this ~~ day of December, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ~~~i~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ®~ 007 PERMIT TO DRILL ,~ ~raska 0~! ~ Gas Caffs. Gflmmssiof? 20 AAC 25.005 AF:CFi9f8r~~ 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 ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well .Bond No. 59-52-180 11. Well Name and Number: 3K-102L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14070' ~ ND: 3564' ~ 12. Field/PO01(S): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 910' FSL, 315' FWL, Sec. 35, T13N, R09E, UM 7. Property Designation: ADL 25519 West Sak Oil Pool Top of Productive Horizon: 3711' FSL, 3002' FWL, Sec. 35, T13N, R09E, UM 8. Land Use Permit: ALK 2555 13. Approximate Spud Date: 1/7/2008 Total Depth: 3154' FSL, 4736' FWL, Sec. 36, T13N, R09E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 544' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 y- 6007904' Zone- 4 10. KB Elevation ~~ / ~' •.SL 7 ~ ~y' s~ (Height above GL): 40' RKB eet 15. Distance to Nearest ~~ell within Pool: 3K-20 , 363' @ 8865' 16. Deviated wells: Kickoff depth: 6975 ~ ft. Maximum Hole Angle: 98° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1568 psig - Surface: 1176 psig '" 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 BTC 3100' 40' 40' 3100' 2187 670 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7800' 40' 40' 7800' . 3576' 660 sx DeepCrete 8.5" 4.5" 11.6# L-80 Hydril 521 7094' 6975' 3458' 14069' . 3564' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis ^/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature ~. ~~~~ Phone ;~~~- ~~ ~~ Date t 2.-r`;~~Q 7 '"""~"~' Sh r n All k Commission Use Only Permit to Drill Number: ~,~~ ~~CL/ API Number: ~7 -7Q 50-~G..g- lr~ !V ~~ 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 me ane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ M og req'd: Yes ^ No Other: ~~ ~ ~ ~~~5~ H2S measures: Yes ^ No ^ Direc ' req'd: Yes [~ No ^ ~~!//~ D~ ROVED BY THE COMMISSION DATE: I ,COMMISSIONER Form 10-401 Revised 12/2005 ' Submit in Duplicate a 7 ~~ ii ~ ~ •07 Appl~n for Permit to Drill, Well 3K-102 L1 Revision No.0 Saved: 30-Nov-07 Permit It -West Sak Well #3K-102 L1 a°~ .., ~k Application for Permit to Drill Document,, x~ll M4xintia~ W~ii +141t~e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards lnformation ................................................................................... 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 Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 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 3K-102 L1 PERMIT IT.doc Page 1 of 6 Printed: 30-Nov-07 ORIGINAL U Appli~ for Permit to Drill, Well 3K-102 L1 Revision No.O Saved: 30-Nov-07 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 (f) 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(6). 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 3K-102 L1. 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 cf 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. (e) 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 910' FSL, 315' FWL Section 35, T13N, R09E ASP Zone 4 NAD 27 Coordinates RKB Elevation 74.3' AMSL Northings: 6,007,904 Eastings: 529,306' Pad Elevation 34.3' AMSL Location at Top of Productive Interval 3,711' FSL, 3,002' FWL, Section 35, T13N, R09E West Sak ~~D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 7,011' Northings: 6,010,716' Eastings: 531,978' Total Vertical De th RKB: 3,464' Total Vertical De th, SS: 3 390' Location at Total De th 3 154' FSL 4,736' FWL Section 36, T13N R09E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 14,070' Northings: 6,010,192' Eastings: 538,994' Total Vertical De th, RKB: 3 564' Total Vertical De th SS: 3,490' and (D) other information required by 20 AAC 25.050(6); 3K-102 L1 PERMIT /T.doc ~, 7 ~ Page 2 of 6 ~ § ~ ~ ~ Printed: 30-Nov-07 "'~~~/// App~n for Permit to Drill, Well 3K-102 L1 Revision No.O Saved: 30-Nov-07 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 3K-102 Li 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 (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) 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 well 3K-102 Ll. Please see information on Doyon 15 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 0.44 psi/ft, or 8.4 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 1,176 psi, calculated thusly: MPSP = (3,564 ft TVD)(0.44 - 0.11 psi/ft) = 1,176 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: 3K-102 L1 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(f); The parent wellbore, 3K-102, will be completed with a 9-5/8" intermediate casing landed in the West Sak B-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. No formation integrity test will be performed in the drilling of the 3K-102 L1. 3K-102 L1 PERMIT /T.doc Page 3 of 6 Printed: 30-Nov-07 Applic~ for Permit to Drill, Well 3K-102 L1 Revision No.O Saved: 30-Nov-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a ~°ermit 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 MDlTVD MDlTVD OD (in) (in) t (Ib/ft) Grade Connection (ft) ft) ft Cement Pro ram 4-1/2 s 1/z" D Sand 11.6 L-80 BTC 7,094 6,975 / 3,458 14,070 / 3,564 Slotted- no cement slotted Lateral (3K-102 Ll) 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 3K-102 Ll. 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 mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.4 - 8.5 Plastic Viscostiy (Ib/100 s 15 - 25 Yield Point cP) 15 - 20 HTHP Fluid loss (ml/30 min 200 si & 150° <4 0 Oil /Water Ratio 80 / 30 Electrical Stabili 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 15. 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(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 3K-102 L1 PERMIT IT.doc f'~ ~ ~ Page 4 of 6 `' ' ~ Printed: 30-Nov-07 App~n for Permit to Drill, Well 3K-102 L1 Revision No.0 Saved: 30-Nov-07 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); 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: (ii) 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: (i2) 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 3K-102 Application for Permit to Drill. 1. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 6,975' MD / 3,458' TVD, the top of the D sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 4. Drill to TD of B sand lateral at +/- 14,069 MD / 3,564' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. Pump out of hole. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. RIH and set Baker Seal Bore diverter 8. PU and run 4-1/2" slotted liner with Baker Oil Tools RAM Hangar system. 9. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH 10. Make up junction isolation / re-entry (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly (Torquemaster packer) and release from assembly. Pull out of hole laying down drillpipe as required. 11. PU Gas Lift completion as required and RIH to depth. Land tubing. Set BPV 12. Nipple down BOPE, nipple up tree and test. Pull BPV. 13. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 3K-102 L1 PERMIT IT.doc Q ~ ~ ~ ~, ' Page 5 of 6 ~~ Printed: 30-Nov-07 r~ 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. 16. Set gas lift valves in mandrels. 17. Place well on Production/ Appli~ for Permit to Drill, Well 3K-102 L1 Revision No.O Saved: 30-Nov-07 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: (14) a general descr,~ption 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 3K 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 3K 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 3K--102 L1 PERMIT IT.doc ,~ ~.: Page 6 of 6 `. ,` - Printed: 30-Nov-07 ~ ~ 3K-102 L1 Drilling Hazards ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8-1/2" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Moderate ~ Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud wei ht Lost Circulation Moderate Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumpin out, backreamin 3K-102 L1 Drilling Hazards Summary.doc prepared by Dennis Hartwig 11/30/2007 1:02:00 PM Plan: 3K-102 L1 (wp06) Sperry Drilling Services Proposal Report -Geographic 09 November, 2007 ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 3K Pad Plan 3K-102 3K-102 L1 Local Coordinate Origin: Centered on Well Plan 3K-102 Viewing Datum: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) / TVDs to System: N North Reference: True , Unit System: API - US Survey Feet Sperry Drilling 8~rvicss OR161NAL Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-102 Wellbore: 3K-102 L1 Plan: 3K-102 L1 (wp06) WEf.L UETAl1.S: Plan 3K-102 NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 34.30 +N/-S +F/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 6007903.69 529305.84 70°25'S7.616N 149°45'40W .~,i ~On~Op~~II'~~ F-fALLlE3LJRTON ~~~~ 11 B(»MY ~Iling ®~Yio~~ 654 981 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 7011.65 80.00 89.22 3464.30 2802.15 2683.08 0.00 0.00 2863.08 2 7026.15 82.24 88.22 3486.85 2802.37 2699.38 13.60 0.00 2699.38 3 7058.15 82.24 89.22 3470.90 2802.78 2729.10 0.00 0.00 2729.10 4 7258.41 88.14 90.36 3487.67 2803.50 2928.56 3.00 10.92 2928.56 5 7581.13 88.14 90.36 3498.12 2801.49 3251.11 0.00 0.00 3251.11 6 7625.56 88.81 89.20 3499.30 2601.66 3295.52 3.00 -60.25 3295.52 3K-102 L7 Tt 7 7626.28 88.81 09.22 3499.32 2801.67 3296.24 3.00 90.00 3296.24 8 8825.12 88.81 89.22 3524.30 2817.95 4494.71 0.00 0.00 4494.71 3K-102 L7 T2 9 8868.77 89.57 90.29 3524.92 2818.14 4538.36 3.00 54.50 4538.36 1010108.29 89.57 90.29 3534.30 2811.91 5777.82 0.00 0.00 5777.82 3K-102 L1 T3 1110407.80 89.47 99.27 3536.82 2786.98 6075.98 3.00 90.65 6075.98 1211325.12 89.47 99.27 3545.30 2639.17 6981.27 0.00 0.00 6981.27 3K-102 L1 T4 1311369.12 88.92 98.07 3545.92 2632.53 7024.76 3.00 -114.74 7024.76 1412024.94 88.92 98.07 3558.30 2540 44 7673.98 0.00 0.00 7673.96 3K-102 L1 TS 1512067.62 90.20 98.14 3558.63 2534.42 7716.22 3.00 2.86 7718.22 1813325.45 90.20 98.14 3554.30 2356.36 8961.37 0.00 0.00 8961.37 3K-102 L1 T6 1T3358.45 89.21 88.18 3554.47 2351.68 8994.04 3.00 177.46 8994.04 1814069.76 89.21 98.18 3564.30 2250.45 9698.04 0.00 0.00 9696.04 3K-102 L1 T7 ANNOTATIONS TVD MD Annotation 3464.30 7011.65 Li 9-5/8" TOW: 7011.65' MD. 3465.3' ND - 3711.31 FSL, 3001.91' FWL -SEC 35 - T13N - R09E _56490 I40G970 L1 BHL: 140694'MD. 3564.3'TVD-3153.78 FSL, 4736.10 FWL-SEC 36-T13N- R09E ~,I~ `~ i FORMATION TOP DETAILS No. NDPath TVDSS MDPath Formation 1 1559.30 1485 1736.04 T3 2 1629.30 1555 1843.41 Permafrost 3 1786.30 1712 2111.89 K15 4 2379.30 2305 3615.10 T3+800 5 2658.30 2584 4364.32 Ugnu C 6 2998.30 2924 5394.09 Ugnu B 7 3094.30 3020 5692.32 Ugnu A 8 3298.30 3224 6326.05 K13 9 3464.30 3390 7011.65 W Sak D CASING DETAILS No hID TVD TVDSS Name Size I 3615.10 2379.30 2305 13 3/8" 13-3/8 2 14069.70 3564.30 3490 41/2" 4-I/2 3 7011.65 3464.30 3390 9 S/8" 9-S/8 O 1308 /~1635 ------------------------------- -------------------------------- --------------- ------------------ --------------------------------------------- ---------------------------------------------- / -------------- i.i 1962 .~~ L1 9-518" TOW: 7011.65' MD, 3465.3' ND - 3711.31 FSL, 3001.91' FWL -SEC 35 - T13N - R09E ' L1 BHL: 14069.4' MD, 3564.3' ND - 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - R09E `~°~~ 2288 : 2615 t~ o 2942 ___________ t'_ - -- -------------------- ---------'~_--------~-- 3269 ~ o O ___a_--- O_- _ _ _ - _ _ _ _ _.~ f'_ _ _ O- _ _Q _ O --0_____~____D-_-_ O _O_____O__---d____ O ---------------0',_`;___ O- ~ O ~ O ~ ~~ f~;' n ~ ~ ~ _ _ _ ~'4i _ ~ _ _ ~ - ~ W p _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ p ~ N M ~ Y - - _ _ _ - - - _ _ _ _ - - ~ _ _ S - - - _ _ _ _ _ - _ - - _ _ _ - m - -L7_ _ _ T f D d ' ~ 3596 op o san 9 5/6" - 4 1/2" I i ~ v, 0 II o o ~ 1 I ~ 3923 ' i I / ~ 3 ' I / I / / / ' ~ N ~ ' 4250 I ' I ' I ' / I I ~ / Y / ' c~ / I ' 3K-102 L1 T1 3K-102 L1 T2 r 3K-102 L1 T3 ' l 3K-102 Li T4 3K-102 L1 T5 3K-102 L1 T6 3K-102 L1 T7 4577 1962 2288 2615 2`x42 3265 3596 3923 4250 4577 4904 5231 5553 6835 6212 6538 6865 7192 7519 7846 8173 8500 8827 9154 9481 9808 Vertical Section at 90.00° (850 ft/in) Project: Kuparuk River Unif Site: Kuparuk 3K Pad Well: Plan 3K-102 Wellbore: 3K-102 L1 Plan: 3K-102 L1 (wp06) i ConocoPhillips SECTION DETAILS Sec MO Inc Azi TVD +NI-S *E/-W DLeg TFace VSec Target 1 7011.65 80.00 89.22 3464.30 2802.15 2883.08 0.00 0.00 2683.08 2 7028.15 82.24 89.22 3466.85 2802.37 2899.38 1 3.60 0.00 2699.38 3 7058.15 82.24 89.22 3470.90 2802.78 2729.10 0.00 0.00 2729.10 4 7258.41 88.14 90.36 348767 2803.50 2928.58 3.00 10.92 2928.58 5 7581.13 88.14 90.38 3498.12 2801.49 3251.11 0.00 0.00 3251.11 6 7825.56 88.81 89.20 3499.30 2801.88 3295.52 3.00 -80.25 3295.52 3K-102 L7 T7 7 7828.28 88.81 89.22 3499.32 2801.87 3298.24 3.00 90.00 3296.24 8 8825.12 68.81 89.22 3524.30 2817.95 4494.71 0.00 0.00 4494.71 3K-102 L7 T2 9 8868.77 69.57 90.29 3524.92 2818.14 4538.38 3.00 54.50 4538.38 1010108,29 89.57 90.29 3534.30 2811.91 5777.82 0.00 0.00 5777.82 3K-102 Li T3 1110407.80 89.47 99.27 3538.82 2788.98 6075.98 3.00 90.85 6075.98 1211325.12 89.47 99.27 3545.30 2639.17 8981.27 0.00 0.00 6981.27 3K-102 L7 T4 1311389.12 88.92 98.07 3545.92 2632.53 7024.78 3.00- 114.74 7024.78 1412024.94 88.92 98.07 3558.30 2540.44 7673.96 0.00 0.00 7873.98 3K-102 Li TS 1912067,62 90.20 98.14 3558.63 2534.42 7718.22 3.00 2.86 7716.22 1813325.45 90.20 98.14 3554.30 2356.38 8961.37 0.00 0.00 8961.37 3K-102 L1 TB 1713358.45 89.21 98.18 3554.47 2351.68 8984.04 3.00 177.48 8994.04 1814089.76 89.21 98.18 3584.30 2250.45 9898.04 0.00 0.00 9898.04 3K-102 L7 T7 i<'i""~q.. ,.. ~ , ., Sporry Orllling 8ervlees REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 3K-102, True NoAh Vedical (TVD) Reference: 74.3' RKB (34.3+40) @ 74.30fl (Doyonl5) Measured Depth Reference: 74.3' RKB (34.3+40) ~ 74.30fl (Doyonl5) Calculation Method: Minimum Curvature WELL DETAllS: Plan 3K-102 Ground Level: 34.30 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 6007903.69 529305.84 7U°25'S7.616N 149°4S'40W CASING DETAllS No MD TVD T'VDss Name Size 1 3615.10 2379.30 2305 13 3/8" I3-3/8 2 14069.70 3564.30 3490 41/2" 4-I/2 3 7011.65 3464.30 3390 9 S/8" 9-5/8 ANNOTATIONS 4857 4571 3143 + 2571 C 2286 r 2000 0 1714 1429 1143 857 571 286 LI 9-S/8" TOW: 7011.65' MD, 3465.3' TVD - 371 L3l FSL, 3001.91' FWL -SEC 35 - T13N - R09 Top of D sand e ~ i I 95/8" i~ i~ 31:-I tl? LI'1~1 it i/ i~ 'i it 31h-IU2 Ll 1Y i~ i~ i~ ri /i i~ i 3K-IU2 LI T3 ~~~~ i/ i /~ ~~ i~ i~ i~ i~ 3K-IU2 Ll "C4 TVD MD Annotation 3464.30 7011.65 L1 9-5/8" TOW: 7011.65' MD, 3465.3' TVD - 3711.31 FSL, 3001.91' FWL -SEC 35 - T13N - R09E 3564.3014069.70 L1 BHL: 14069.4' MD, 3564.3' TVD - 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - R09E LI BHL: 14069.4' MD, 3564.3' TVD - 3153.79 FSL, 4736.10 FWL- SEC 36 - T13N - R09 t 1 111 1 1 0 t 3 t .J t 0 1 ~' M ~ ~" 1 r / r ' `\ / ~ 41n"' ~ o ~ ' ~ ~ ' - r "i i / i r i ~ / r I n / r I r r ~ r / i i r r r r i 3K-0U2 Ll T5 ~ ~ 3K-102 LI TB 3K-IU2 LI'1"7 1429 1714 2000 2286 2571 2857 3143 3429 3714 4000 4286 4571 4857 5143 5429 5714 6000 6286 6571 6857 7143 7429 7714 8000 8286 8571 8857 9143 9429 9714 10000 1028G IOS71 1O8S7 11143 West(-)/East(+) (1000 ft/in) • Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3K-102 Company: GonocoPhillips Alaska Inc. ND Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: k:uparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: k;uparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: 'Minimum Curvature Wellbore: 3K-102 L1 Design: ~K-102 L1 (wp06) Project Kuparuk River Unit North Slope Alaska. U nited States Map System: Geo Datum: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) System Datum: Mean Sea Level Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 3K-102 Well Position +N/-S 0.00 ft Northing: 6,007,903.69 ft Latitude: 70° 25' 57.616" N +E/-W 0.00 ft Easting: 529,305.84 ft Longitude: 149° 45' 40.000" W Position Uncertainty O.OOft Wellhead Elevation: ft Ground Level: 34.30ft Wellbore ~K-102 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 10/10/2007 23.09 80.88 57,623 Design ~K-102 L1 Iwp06) Audit Notes: Version: 10 Phase: PLAN Tie On Depth: 7,011.65 Vertical Section: Depth From (TVD) +NIS +EI-W Direction (ftl lft) (ft) (°) 40.00 0.00 0.00 90.00 11/92007 11:43:56AM Page 2 of 9 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: FDM 2003.11 Single User Db Local Co-ordinate Reference: ~^Jell Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: ~ 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: P:-1inimum Curvature Wellbore: 3K-102 L1 Design: 3K-102 L1 (wp06) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (ft) {°I100ft) (°1100ft) (°I100ft) (°) 7,011.65 80.00 89.22 3,464.30 3,390.00 2,802.15 2,683.08 0.00 0.00 0.00 0.00 7,028.15 82.24 89.22 3,466.85 3,392.55 2,802.37 2,699.38 13.60 13.60 0.00 0.00 7,058.15 82.24 89.22 3,470.90 3,396.60 2,802.78 2,729.10 0.00 0.00 0.00 0.00 7,258.41 88.14 90.36 3,487.67 3,413.37 2,803.50 2,928.56 3.00 2.95 0.57 10.92 7,581.13 88.14 90.36 3,498.12 3,423.82 2,801.49 3,251.11 0.00 0.00 0.00 0.00 7,625.56 88.81 89.20 3,499.30 3,425.00 2,801.66 3,295.52 3.00 1.49 -2.61 -60.25 7,626.28 88.81 89.22 3,499.32 3,425.02 2,801.67 3,296.24 3.00 0.00 3.00 90.00 8,825.12 88.81 89.22 3,524.30 3,450.00 2,817.95 4,494.71 0.00 0.00 0.00 0.00 8,868.77 89.57 90.29 3,524.92 3,450.62 2,818.14 4,538.36 3.00 1.74 2.44 54.50 10,108.29 89.57 90.29 3,534.30 3,460.00 2,811.91 5,777.82 0.00 0.00 0.00 0.00 10,407.80 89.47 99.27 3,536.82 3,462.52 2,786.98 6,075.98 3.00 -0.03 3.00 90.65 11,325.12 89.47 99.27 3,545.30 3,471.00 2,639.17 6,981.27 0.00 0.00 0.00 0.00 11,369.12 88.92 98.07 3,545.92 3,471.62 2,632.53 7,024.76 3.00 -1.26 -2.73 -114.74 12,024.94 88.92 98.07 3,558.30 3,484.00 2,540.44 7,673.96 0.00 0.00 0.00 0.00 12,067.62 90.20 98.14 3,558.63 3,484.33 2,534.42 7,716.22 3.00 3.00 0.15 2.86 13,325.45 90.20 98.14 3,554.30 3,480.00 2,356.36 8,961.37 0.00 0.00 0.00 0.00 13,358.45 89.21 98.18 3,554.47 3,480.17 2,351.68 8,994.04 3.00 -3.00 0.13 177.46 .14,069.76 89.21 98.18 3,564.30 ~ 3,490.00 2,250.45 9,698.04 0.00 0.00 0.00 0.00 11/9/2007 11:43:56AM Page 3 of 9 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: K:uparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: 'True Well: Flan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: ~K-102 L1 , Design: 3K-102 L1 (wp06) ' Planned Survey 3K-102 L1 (wp06) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/-S +E/-Vy Northing Easting DLSEV Vert Section (ft) (') (~) (ft) Ift) (ft) lft) (ft) (°1100ft) (ft) 100.00 0.00 0.00 100.00 25.70 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 200.00 0.00 0.00 200.00 125.70 0.00 0.00 6,007,903.69 529,305.84 0.00 0.00 300.00 1.00 310.00 300.00 225.70 0.22 -0.27 6,007,903.91 529,305.57 1.00 -0.27 400.00 3.60 310.00 399.91 325.61 2.76 -3.29 6,007,906.44 529,302.54 2.60 -3.29 500.00 6.60 310.00 499.50 425.20 8.47 -10.10 6,007,912.12 529,295.71 3.00 -10.10 600.00 9.60 310.00 598.50 524.20 17.53 -20.89 6,007,921.13 529,284.88 3.00 -20.89 700.00 12.60 310.00 696.61 622.31 29.90 -35.64 6,007,933.45 529,270.09 3.00 -35.64 800.00 16.48 313.28 793.40 719.10 46.60 -54.32 6,007,950.08 529,251.34 3.96 -54.32 900.00 20.42 315.43 888.24 813.94 68.76 -76.90 6,007,972.14 529,228.68 4.00 -76.90 1,000.00 24.38 316.90 980.68 906.38 96.27 -103.25 6,007,999.55 529,202.22 4.00 -103.25 1,100.00 28.35 317.98 1,070.26 995.96 129.00 -133.26 6,008,032.15 529,172.08 4.00 -133.26 1,200.00 32.33 318.81 1,156.55 1082.25 166.77 -166.78 6,008,069.79 529,138.42 4.00 -166.78 1,300.00 36.31 319.48 1,239.12 1164.82 209.42 -203.64 6,008,112.29 529,101.40 4.00 -203.64 1,400.00 40.16 320.30 1,317.58 1243.28 256.74 -243.65 6,008,159.45 529,061.21 3.88 -243.65 1,500.00 42.35 324.17 1,392.77 1318.47 308.87 -283.97 6,008,211.42 529,020.69 3.36 -283.97 1,600.00 44.66 327.73 1,465.31 1391.01 365.91 -322.46 6,008,268.30 528,981.98 3.36 -322.46 1,700.00 47.07 330.99 1,534.96 1460.66 427.66 -358.99 6,008,329.89 528,945.21 3.36 -358.99 1,736.04 47.96 332.11 1,559.30 1485.00 451.03 -371.64 6,008,353.21 528,932.46 3.36 -371.64 T3 1,800.00 49.56 334.01 1,601.46 1527.16 493.90 -393.42 6,008,395.99 528,910.52 3.36 -393.42 1,843.41 50.67 335.25 1,629.30 1555.00 524.00 -407.69 6,008,426.03 528,896.13 3.36 -407.69 Permafrost 1,900.00 52.13 336.81 1,664.61 1590.31 564.41 -425.65 6,008,466.37 528,878.02 3.36 -425.65 2,000.00 54.76 339.42 1,724.16 1649.86 638.95 -455.56 6,008,540.78 528,847.82 3.36 -455.56 2,100.00 57.45 341.86 1,779.93 1705.63 717.25 -483.05 6,008,618.97 528,820.02 3.36 -483.05 2,111.89 57.77 342.14 1,786.30 1712.00 726.80 -486.15 6,008,628.50 528,816.89 3.36 -486.15 K15 2,200.00 60.17 344.16 1,831.72 1757.42 799.05 -508.02 6,008,700.66 528,794.74 3.36 -508.02 2,300.00 62.94 346.33 1,879.35 1805.05 884.07 -530.39 6,008,785.58 528,772.04 3.36 -530.39 2,400.00 65.74 348.40 1,922.65 1848.35 972.02 -550.08 6,008,873.44 528,752.00 3.36 -550.08 2,500.00 68.00 350.79 1,961.58 1887.28 1,062.56 -566.95 6,008,963.91 528,734.78 3.15 -566.95 2,600.00 68.00 354.79 1,999.04 1924.74 1,154.52 -578.58 6,009,055.82 528,722.79 3.71 -578.58 2,700.00 68.00 358.79 2,036.50 1962.20 1,247.08 -583.77 6,009,148.34 528,717.23 3.71 -583.77 2,800.00 68.00 2.79 2,073.96 1999.66 1,339.77 -582.49 6,009,241.03 528,718.15 3.71 -582.49 2,900.00 68.00 6.79 2,111.42 2037.12 1,432.14 -574.75 6,009,333.42 528,725.53 3.71 -574.75 3,000.00 68.00 10.79 2,148.88 2074.58 1,523.75 -560.58 6,009,425.08 528,739.33 3.71 -560.58 3,100.00 68.00 14.79 2,186.34 2112.04 1,614.15 -540.06 6,009,515.55 528,759.50 3.71 -540.06 3,200.00 68.00 18.79 2,223.80 2149.50 1,702.90 -513.28 6,009,604.39 528,785.93 3.71 -513.28 3,300.00 68.00 22.79 2,261.26 2186.96 1,789.56 -480.38 6,009,691.18 528,818.49 3.71 -480.38 3,400.00 68.00 26.79 2,298.72 2224.42 1,873.72 -441.51 6,009,775.48 528,857.02 3.71 -441.51 3,500.00 68.00 30.79 2,336.18 2261.88 1,954.96 -396.86 6,009,856.88 528,901.34 3.71 -396.86 3,600.00 68.00 34.79 2,373.65 2299.35 2,032.89 -346.66 6,009,935.00 528,951.23 3.71 -346.66 3,615.10 68.01 35.39 2,379.30 2305.00 2,044.34 -338.61 6,009,946.49 528,959.24 3.71 -338.61 T3+800 - 3,700.00 68.00 38.79 2,411.11 2336.81 2,107.13 -291.14 6,010,009.45 529,006.45 3.71 -291.14 3,800.00 68.00 42.79 2,448.57 2374.27 2,177.31 -230.58 6,010,079.86 529,066.73 3.71 -230.58 11/9/2007 11:43:56AM ~`~-; ri~age ~~of ,, COMPASS 2003.11 Build 48 >. `~'tt8~f~ 6~.~ Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: ~^Jell Plan 3K-102 Company: ConocoPhillips Alaska Inc. ND Reference: ~ 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: ~ 4.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: P,linimum Curvature Wellbore: 3K-102 L1 Design: 3K-102 L1 (wp06) Planned Survey 3K-102 L1 (wp06j Map Map MD Incl Azimuth ND (ft) NDSS +N/-S +E1-W Northing Easting DLSEV Vert Section Ift) (°) (°) (ftl (ft) (ft) lft) (ftl (°1100ft) (ft) 3,900.00 68.00 46.79 2,486.03 2411.73 2,243.10 -165.27 6,010,145.90 529,131.78 3.71 -165.27 4,000.00 68.00 50.85 2,523.49 2449.19 2,304.16 -95.53 6,010,207.23 529,201.27 3.77 -95.53 4,100.00 68.08 55.16 2,560.90 2486.60 2,359.95 -21.47 6,010,263.30 529,275.10 4.00 -21.47 4,200.00 68.26 59.47 2,598.10 2523.80 2,410.05 56.64 6,010,313.71 529,353.01 4.00 56.64 4,300.00 68.56 63.76 2,634.91 2560.61 2,454.24 138.42 6,010,358.21 529,434.61 4.00 138.42 4,364.32 68.81 66.51 2,658.30 2584.00 2,479.44 192.78 6,010,383.62 529,488.86 4.00 192.78 Ugnu C 4,400.00 68.97 68.03 2,671.15 2596.85 2,492.30 223.48 6,010,396.60 529,519.50 4.00 223.48 4,500.00 69.48 72.27 2,706.64 2632.34 2,524.03 311.40 6,010,428.67 529,607.29 4.00 311.40 4,600.00 70.09 76.48 2,741.21 2666.91 2,549.28 401.75 6,010,454.28 529,697.53 4.00 401.75 4,700.00 70.80 80.66 2,774.69 2700.39 2,567.94 494.09 6,010,473.30 529,789.79 4.00 494.09 4,800.00 71.22 82.87 2,807.06 2732.76 2,580.65 587.84 6,010,486.37 529,883.48 2.13 587.84 4,900.00 71.22 82.87 2,839.25 2764.95 2,592.40 681.78 6,010,498.49 529,977.37 0.00 681.78 5,000.00 71.22 82.87 2,871.44 2797.14 2,604.16 775.73 6,010,510.62 530,071.25 0.00 775.73 5,100.00 71.22 82.87 2,903.63 2829.33 2,615.91 869.67 6,010,522.74 530,165.14 0.00 869.67 5,200.00 71.22 82.87 2,935.82 2861.52 2,627.67 963.62 6,010,534.87 530,259.03 0.00 963.62 5,300.00 71.22 82.87 2,968.01 2893.71 2,639.43 1,057.56 6,010,546.99 530,352.92 0.00 1,057.56 5,394.09 71.22 82.87 2,998.30 2924.00 2,650.49 1,145.95 6,010,558.40 530,441.26 0.00 1,145.95 Ugnu B 5,400.00 71.22 82.87 3,000.20 2925.90 2,651.18 1,151.51 6,010,559.12 530,446.81 0.00 1,151.51 5,500.00 71.22 82.87 3,032.39 2958.09 2,662.94 1,245.45 6,010,571.24 530,540.70 0.00 1,245.45 5,600.00 71.22 82.87 3,064.58 2990.28 2,674.70 1,339.39 6,010,583.36 530,634.58 0.00 1,339.39 5,692.32 71.22 82.87 3,094.30 3020.00 2,685.55 1,426.12 6,010,594.56 530,721.26 0.00 1,426.12 Ugnu A 5,700.00 71.22 82.87 3,096.77 3022.47 2,686.45 1,433.34 6,010,595.49 530,728.47 0.00 1,433.34 5,800.00 71.22 82.87 3,128.96 3054.66 2,698.21 1,527.28 6,010,607.61 530,822.36 0.00 1,527.28 5,900.00 71.22 82.87 3,161.15 3086.85 2,709.97 1,621.23 6,010,619.74 530,916.25 0.00 1,621.23 6,000.00 71.22 82.87 3,193.34 3119.04 2,721.72 1,715.17. 6,010,631.86 531,010.14 0.00 1,715.17 6,100.00 71.22 82.87 3,225.53 3151.23 2,733.48 1,809.12 6,010,643.99 531,104.03 0.00 1,809.12 6,200.00 71.22 82.87 3,257.72 3183.42 2,745.24 1,903.06 6,010,656.11 531,197.92 0.00 1,903.06 6,300.00 71.22 82.87 3,289.91 3215.61 2,756.99 1,997.01 6,010,668.23 531,291.80 0.00 1,997.01 6,326.05 71.22 82.87 3,298.30 3224.00 2,760.06 2,021.48 6,010,671.39 531,316.26 0.00 2,021.48 K13 6,400.00 71.22 82.87 3,322.10 3247.80 2,768.75 2,090.95 6,010,680.36 531,385.69 0.00 2,090.95 6,500.00 71.22 82.87 3,354.29 3279.99 2,780.51 2,184.90 6,010,692.48 531,479.58 0.00 2,184.90 6,600.00 74.23 85.12 3,384.17 3309.87 2,790.62 2,279.77 6,010,702.96 531,574.40 3.70 2,279.77 6,700.00 77.51 87.48 3,408.58 3334.28 2,796.86 2,376.52 6,010,709.59 531,671.12 4.00 2,376.52 6,800.00 80.00 89.22 3,427.55 3353.25 2,799.31 2,474.66 6,010,712.42 531,769.24 3.02 2,474.66 6,900.00 80.00 89.22 3,444.91 3370.61 2,800.65 2,573.13 6,010,714.15 531,867.70 0.00 2,573.13 7,000.00 80.00 89.22 3,462.28 3387.98 2,801.99 2,671.61 6,010,715.88 531,966.15 0.00 2,671.61 7,011.65 80.00 89.22 3,464.30 3390.00 2,802.15 2,683.08 6,010,716.08 531,977.62 0.00 2,683.08 L1 9-518" TOW: 7011. 65' RAD, 3465.3' TVD - 3711.31 FSL, 3001.91' FWL -SEC 35 - T13N - R09E - W Sa k D - 9 5/8 7,028.15 82.24 89.22 3,466.85 3392.55 2,802.37 2,699.38 6,010,716.37 531,993.92 13.60 2,699.38 7,058.15 82.24 89.22 3,470.90 3396.60 2,802.78 2,729.10 6,010,716.89 532,023.64 0.00 2,729.10 7,100.00 83.48 89.46 3,476.10 3401.80 2,803.25 2,770.62 6,010,717.53 532,065.15 3.00 2,770.62 7,200.00 86.42 90.03 3,484.90 3410.60 2,803.70 2,870.22 6,010,718.36 532,164.74 3.00 2,870.22 11/9x1007 11:43:56AM Page 5 of 9 COMPASS 2003.11 Build 48 i • Halliburton Company Compass Proposal Report -Geographic Database: FDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: 3K-102 L1 Design: 3K-102 L1 (wp06) Planned Survey 3K-102 L1 (vdp06) Map .....Map MD Incl Azimuth TVD (ft) TVDSS +NI-S +El-W Northing Easting DLSEV Vert Section Iftl l°) l°) (ft) (ft) lft) (ft) (ft) (°1100ft) (ft) 7,258.41 88.14 90.36 3,487.67 3413.37 2,803.50 2,928.56 6,010,718.40 532,223.08 3.00 2,928.56 7,300.00 88.14 90.36 3,489.01 3414.71 2,803.24 2,970.13 6,010,718.30 532,264.64 0.00 2,970.13 7,400.00 88.14 90.36 3,492.25 3417.95 2,802.62 3,070.08 6,010,718.07 532,364.58 0.00 3,070.08 7,500.00 88.14 90.36 3,495.49 3421.19 2,802.00 3,170.02 6,010,717.84 532,464.52 0.00 3,170.02 7,581.13 88.14 90.36 3,498.12 3423.82 2,801.49 3,251.11 6,010,717.65 532,545.60 0.00 3,251.11 7,600.00 88:42 89.87 3,498.68 3424.38 2,801.46 3,269.97 6,010,717.69 532,564.46 3.00 3,269.97 7,625.56 88.81 89.20 3,499.30 3425.00 2,801.66 3,295.52 6,010,718.00 532,590.00 3.00 3,295.52 3K-102 L1 T1 7,626.28 88.81 89.22 3,499.32 3425.02 2,801.67 3,296.24 6,010,718.01 532,590.72 3.00 3,296.24 7,700.00 88.81 89.22 3,500.85 3426.55 2,802.67 3,369.94 6,010,719.30 532,664.41 0.00 3,369.94 7,800.00 88.81 89.22 3,502.94 3428.64 2,804.03 3,469.91 6,010,721.05 532,764.36 0.00 3,469.91 7,900.00 88.81 89.22 3,505.02 3430.72 2,805.39 3,569.88 6,010,722.80 532,864.31 0.00 3,569.88 8,000.00 88.81 89.22 3,507.10 3432.80 2,806.75 3,669.85 6,010,724.56 532,964.27 0.00 3,669.85 8,100.00 88.81 89.22 3,509.19 3434.89 2,808.11 3,769.81 6,010,726.31 533,064.22 0.00 3,769.81 8,200.00 88.81 89.22 3,511.27 3436.97 2,809.46 3,869.78 6,010,728.06 533,164.17 0.00 3,869.78 8,300.00 88.81 89.22 3,513.36 3439.06 2,810.82 3,969.75 6,010,729.81 533,264.13 0.00 3,969.75 8,400.00 88.81 89.22 3,515.44 3441.14 2,812.18 4,069.72 6,010,731.56 533,364.08 0.00 4,069.72 8,500.00 88.81 89.22 3,517.52 3443.22 2,813.54 4,169.69 6,010,733.31 533,464.03 0.00 4,169.69 8,600.00 88.81 89.22 3,519.61 3445.31 2,814.90 4,269.66 6,010,735.06 533,563.99 0.00 4,269.66. 8,700.00 88.81 89.22 3,521.69 3447.39 2,816.26 4,369.63 6,010,736.81 533,663.94 0.00 4,369.63 8,800.00 88.81 89.22 3,523.78 3449.48 2,817.61 4,469.60 6,010,738.56 533,763.89 0.00 4,469.60 8,825.12 88.81 89.22 3,524.30 3450.00 2,817.95 4,494.71 6,010,739.00 533,789.00 0.00 4,494.71 3K-102 L1 T2 8,868.77 89.57 90.29 3,524.92 3450.62 2,818.14 4,538.36 6,010,739.36 533,832.64 3.00 4,538.36 8,900.00 89.57 90.29 3,525.16 3450.86 2,817.98 4,569.58 6,010,739.32 533,863.87 0.00 4,569.58 9,000.00 89.57 90.29 3,525.91 3451.61 2,817.48 4,669.58 6,010,739.21 533,963.85 0.00 4,669.58 9,100.00 89.57 90.29 3,526.67 3452.37 2,816.98 4,769.57 6,010,739.10 534,063.84 0.00 4,769.57 9,200.00 89.57 90.29 3,527.43 3453.13 2,816.48 4,869.57 6,010,739.00 534,163.83 0.00 4,869.57 9,300.00 89.57 90.29 3,528.18 3453.88 2,815.97 4,969.57 6,010,738.89 534,263.81 0.00 4,969.57 9,400.00 89.57 90.29 3,528.94 3454.64 2,815.47 5,069.56 6,010,738.78 534,363.80 0.00 5,069.56 9,500.00 89.57 90.29 3,529.70 3455.40 2,814.97 5,169.56 6,010,738.67 534,463.79 0.00 5,169.56 9,600.00 89.57 90.29 3,530.45 3456.15 2,814.47 5,269.55 6,010,738.56 534,563.78 0.00 5,269.55 9,700.00 89.57 90.29 3,531.21 3456.91 2,813.96 5,369.55 6,010,738.45 534,663.76 0.00 5,369.55 9,800.00 89.57 90.29 3,531.97 3457.67 2,813.46 5,469.55 6,010,738.34 534,763.75 0.00 5,469.55 9,900.00 89.57 90.29 3,532.72 3458.42 2,812.96 5,569.54 6,010,738.23 534,863.74 0.00 5,569.54 10,000.00 89.57 90.29 3,533.48 3459.18 2,812.46 5,669.54 6,010,738.12 534,963.72 0.00 5,669.54 10,100.00 89.57 90.29 3,534.24 3459.94 2,811.95 5,769.53 6,010,738.01 535,063.71 0.00 5,769.53 10,108.29 89.57 90.29 3,534.30 3460.00 2,811.91 5,777.82 6,010,738.00 535,072.00 0.00 5,777.82 3K-102 L1 T3 10,200.00 89.54 93.04 3,535.02 3460.72 2,809.25 5,869.48 6,010,735.70 535,163.66 3.00 5,869.48 10,300.00 89.50 96.04 3,535.86 3461.56 2,801.34 5,969.15 6,010,728.18 535,263.35 3.00 5,969.15 10,400.00 89.47 99.04 3,536.75 3462.45 2,788.22 6,068.27 6,010,715.45 535,362.51 3.00 6,068.27 10,407.80 89.47 99.27 3,536.82 3462.52 2,786.98 6,075.98 6,010,714.24 535,370.22 3.00 6,075.98 10,500.00 89.47 99.27 3,537.67 3463.37 2,772.12 6,166.97 6,010,699.74 535,461.26 0.00 6,166.97 10,600.00 89.47 99.27 3,538.60 3464.30 2,756.01 6,265.65 6,010,684.02 535,560.00 0.00 6,265.65 10,700.00 89.47 99.27 3,539.52 3465.22 2,739.90 6,364.34 6,010,668.29 535,658.74 0.00 6,364.34 10,800.00 89.47 99.27 3,540.45 3466.15 2,723.78 6,463.03 6,010,652.57 535,757.48 0.00 6,463.03 11/92007 11:43:56AM Page 6 of 9 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: .DM 2003.11 Single User Db Local Co-ordinate Reference: `~^Jell Plan 3K-102 Company: ConocoPhillips Alaska Inc. ND Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: ~Cuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: ~Cuparuk 3K Pad North Reference: True Well: ?Ian 3K-102 Survey Calculation Method: P:4inimum Curvature Wellbore: 3K-102 L1 Design: 3K-102 L1 (wp06) Planned Survey 3K-102 L1 (wp06) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/-S +E/-W Northing Easting DLSEV Vert Section (ftl (~) (~) fft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,900.00 89.47 99.27 3,541.37 3467.07 2,707.67 6,561.72 6,010,636.85 535,856.22 0.00 6,561.72 11,000.00 89.47 99.27 3,542.30 3468.00 2,691.56 6,660.41 6,010,621.12 535,954.97 0.00 6,660.41 11,100.00 89.47 99.27 3,543.22 3468.92 2,675.44 6,759.10 6,010,605.40 536,053.71 0.00 6,759.10 11,200.00 89.47 99.27 3,544.14 3469.84 2,659.33 6,857.79 6,010,589.67 536,152.45 0.00 6,857.79 11,300.00 89.47 99.27 3,545.07. 3470.77 2,643.22 6,956.48 6,010,573.95 536,251.19 0.00 6,956.48 11,325.12 89.47 99.27 3,545.30 3471.00 2,639.17 6,981.27 6,010,570.00 536,276.00 0.00 6,981.27 3K-102 L1 T4 11,369.12 88.92 98.07 3,545.92 3471.62 2,632.53 7,024.76 6,010,563.54 536,319.51 3.00 7,024.76 11,400.00 88.92 98.07 3,546.50 3472.20 2,628.20 7,055.33 6,010,559.32 536,350.09 0.00 7,055.33 11,500.00 88.92 98.07 3,548.39 3474.09 2,614.15 7,154.32 6,010,545.67 536,449.13 0.00 7,154.32 11,600.00 88.92 98.07 3,550.28 3475.98 2,600.11 7,253.31 6,010,532.02 536,548.16 0.00 7,253.31 11,700.00 88.92 98.07 3,552.17 3477.87 2,586.07 7,352.30 6,010,518.36 536,647.20 0.00 7,352.30 11,800.00 88.92 98.07 3,554.05 3479.75 2,572.02 7,451.29 6,010,504.71 536,746.23 0.00 7,451.29 11,900.00 88.92 98.07 3,555.94 3481.64 2,557.98 7,550.28 6,010,491.06 536,845.27 0.00 7,550.28 12,000.00 88.92 98.07 3,557.83 3483.53 2,543.94 7,649.27 6,010,477.40 536,944.30 0.00 7,649.27 12,024.94 88.92 98.07 3,558.30 3484.00 2,540.44 7,673.96 6,010,474.00 536,969.00 0.00 7,673.96 3K-102 L1 T5 12,067.62 90.20 98.14 3,558.63 3484.33 2,534.42 7,716.22 6,010,468.15 537,011.28 3.00 7,716.22 12,100.00 90.20 98.14 3,558.52 3484.22 2,529.83 7,748.27 6,010,463.69 537,043.34 0.00 7,748.27 12,200.00 90.20 98.14 3,558.17 3483.87 2,515.68 7,847.26 6,010,449.93 537,142.38 0.00 7,847.26 12,300.00 90.20 98.14 3,557.83 3483.53 2,501.52 7,946.25 6,010,436.16 537,241.42 0.00 7,946.25 12,400.00 90.20 98.14 3,557.49 3483.19 2,487.37 8,045.24 6,010,422.39 537,340.45 0.00 8,045.24 12,500.00 90.20 98.14 3,557.14 3482.84 2,473.21 8,144.24 6,010,408.63 537,439.49 0.00 8,144.24 12,600.00 90.20 98.14 3,556.80 3482.50 2,459.05 8,243.23 6,010,394.86 537,538.53 0.00 8,243.23 12,700.00 90.20 98.14 3,556.45 3482.15 2,444.90 8,342.22 6,010,381.10 537,637.57 0.00 8,342.22 12,800.00 90.20 98.14 3,556.11 3481.81 2,430.74 8,441.21 6,010,367.33 537,736.60 0.00 8,441.21 12,900.00 90.20 98.14 3,555.76 3481.46 2,416.59 8,540.21 6,010,353.57 537,835.64 0.00 8,540.21 13,000.00 90.20 98.14 3,555.42 3481.12 2,402.43 8,639.20 6,010,339.80 537,934.68 0.00 8,639.20 13,100.00 90.20 98.14 3,555.08 3480.78 2,388.27 8,738.19 6,010,326.03 538,033.72 0.00 8,738.19 13,200.00 90.20 98.14 3,554.73 3480.43 2,374.12 8,837.18 6,010,312.27 538,132.75 0.00 8,837.18 13,300.00 90.20 98.14 3,554.39 3480.09 2,359.96 8,936.18 6,010,298.50 538,231.79 0.00 8,936.18 13,325.45 90.20 98.14 3,554.30 3480.00 2,356.36 8,961.37 6,010,295.00 538,257.00 0.00 8,961.37 3K-102 L1 Tfi 13,358.45 89.21 98.18 3,554.47 3480.17 2,351.68 8,994.04 6,010,290.45 538,289.68 3.00 8,994.04 13,400.00 89.21 98.18 3,555.05 3480.75 2,345.76 9,035.16 6,010,284.69 538,330.82 0.00 9,035.16 13,500.00 89.21 98.18 3,556.43 3482.13 2,331.53 9,134.13 6,010,270.85 538,429.84 0.00 9,134.13 13,600.00 89.21 98.18 3,557.81 3483.51 2,317.30 9,233.10 6,010,257.01 538,528.85 0.00 9,233.10 13,700.00 89.21 98.18 3,559.19 3484.89 2,303.07 9,332.08 6,010,243.17 538,627.87 0.00 9,332.08 13,800.00 89.21 98.18 3,560.57 3486.27 2,288.84 9,431.05 6,010,229.33 538,726.89 0.00 9,431.05 13,900.00 89.21 98.18 3,561.95 3487.65 2,274.61 9,530.02 6,010,215.49 538,825.91 0.00. 9,530.02 14,000.00 89.21 98.18 3,563.34 3489.04 2,260.38 9,628.99 6,010,201.65 538,924.93 0.00 9,628.99 14,069.76 89.21 98.18 3,564.30 3490.00 2,250.45 9,698.04 6,010,192.00 538,994.00 0.00 9,698.04 i L1 BHL: 140&4.4' MD, 35&4.3' TVU - 3153.79 FSL, 4736.10 FWL -SEC 36 - T13N - R09E - 41/2" - 3K-102 L1 T7 11/9/2007 11:43:56AM Page 7 of 9 COMPASS 2003.11 Build 48 ~~~` ~ ~~ Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: 'Well Plan 3K-102 Company: ConocoPhillips Alaska Inc. ND Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: flan 3K-102 Survey Calculat ion Method : Minimum Cu rvature Wellbore: 'K-102 L1 Design: 3K-102 L1 (wp06) Geologic Targets 3K-102 L1 ND NDSS Ta rget Name +N/-S +E!-W Northing Easting (ft) (ft) - Shap® ft ft (ft) (ft) 3,524.30 3K-102 L1 T2 2,817.95 4,494.71 6,010,739.00 533,789.00 - Point 3,564.30 3K-102 L1 T7 2,250.45 9,698.04 6,010,192.00 538,994.00 - Point 3,534.30 3K-102 L1 T3 2,811.91 5,777.82 6,010,738.00 535,072.00 - Point 3,554.30 3K-102 L1 T6 2,356.36 8,961.37 6,010,295.00 538,257.00 - Point 3,464.30 Top of D sand 2,801.06 2,684.45 6,010,715.00 531,979.00 - Point 3,558.30 3K-102 L1 TS 2,540.44 7,673.96 6,010,474.00 536,969.00 - Point 3,545.30 3K-102 L1 T4 2,639.17 6,981.27 6,010,570.00 536,276.00 - Point 3,499.30 3K-102 L1 T1 2,801.66 3,295.52 6,010,718.00 532,590.00 - Point Prognosed Ca sing Points Measured Vertical Casing Hole Depth Depth Diameter D iameter (ft) Ift1 ("1 (") 3,100 2,187 13-3/8 17-1/2 14,069.70 3,564.30 4-1/2 6-3/4 7,011.65 3,464.30 9-5/8 12-1 /4 Prognosed Fo rmation Intersection Points Measured Depth (ft) Inclination Azimuth 1°1 1`1 ND NDSS + (ftl Ift) N!-E (ft) +Ei-W (ft) Name 1,736.04 47.96 332.11 1,559.30 451.03 -371.64 T3 1,843.41 50.67 335.25 1,629.30 524.00 -407.69 Permafrost 2,111.89 57.77 342.14 1,786.30 726.80 -486.15 K15 3,615.10 68.01 35.39 2,379.30 2,044.34 -338.61 T3+800 4,364.32 68.81 66.51 2,658.30 2,479.44 192.78 Ugnu C 5,394.09 71.22 82.87 2,998.30 2,650.49 1,145.95 Ugnu B 5,692.32 71.22 82.87 3,094.30 2,685.55 1,426.12 Ugnu A 6,326.05 71.22 82.87 3,298.30 2,760.06 2,021.48 K13 7,011.65 80.00 89.22 3,464.30 2,802.15 2,683.08 W Sak D 11/9/2007 11:43:56AM Page 8 of 9 COMPASS 2003.11 Build 48 ,~ ,.. - ~=1~6 ~. Halliburton Company Compass Proposal Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: \'Jell Plan 3K-102 Company: ConocoPhillips Alaska Inc. TVD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Project: Kuparuk River Unit MD Reference: 74.3' RKB (34.3+40) @ 74.30ft (Doyon15) Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-102 Survey Calculation Method: Minimum Curvature Wellbore: 3K-102 L1 Design: 3K-102 L1 (wp06) Plan Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +E/-W Comment lft) (ft) lft) (ft) 7,011.65 3,464.30 2,802.15 2,683.08 L1 9-5/8" TOW: 7011.65' MD, 3465.3' TVD - 3711.313 FSL, 3001.91' FWL - SE 14,069.70 3,564.30 2,250.46 9,697.98 L1 BHL: 14069.4' MD, 3564.3' TVD - 3153.79 FSL, 4736.10 FWL -SEC 36 - T 11/9/2007 11:43:56AM Pa e 9 of 9 COMPASS 2003.11 Build 48 V F .. r- ~ ~ Y ~ f E '~ 5 X ~ ^ ' ~ - sg 3 ~ap~~ ~ ~ F ~~~r,.... ~ x~a ~ e~ ~ 4`9'~ ~ R.- ..,cam. 4o. o C ~ ~ o. z ~ .Vrrrv .M~3e~~:.~~~=ma r a Z 7 ~ F _ v.~'~ _ _ - z ~ o y ? h -----_ ~~h - ~~~~~r~rr~rr~ ~~r~ ~ T 9 C vv~n v..n ~nv~n ~n v~v~~n ~r~M, r~R ~n~~ mmmmnnr.mrmm.•m C R e ~ ~& ~~ aaaaaa H ~ r ~ msaamzwxxxwxxxxaowm Q ~ - =a~ee~ E t ~_~ G N -n ,can soh wc---~~~~-~ `"oooo~nov, O~ O~ O N v'i r F-'N~nr------ U I I I I I ~OOOOOO O N~nr :~i~ ! ~ OOOOOO0V~OOOOOOOOOOOOOO _ oooo~no~no~noro~nooooo0000000 ,.~ F'^N~r~~--~.r .~NNNNNNMef ~ ~O~~O~~ V~ N d-~h ~M~Illilllllli +~~Y, ~•: ~ i ~ ~~ ~ `~~~,~~ ~ a z ~-r o00000ooooov~oo 3'S"~~e "" N^ a O N~ r O N~~ O N~ N~ S ~~~~ '~ F" Y ~ ~-• ~--~ ~--~ ~--~ N N N N ~ ~ ~~~i~~~. _ Gai •• ~ +~~ C i=`~` ~ Z ~ L ~~i d Q w 4.. / = i~~i j ~ O V Off' ~~ ~ C~ G '~" o ~-+ O V' ter- O O . ~ ai L b0 ~ ~i. L' CC ~x ~x ~~ R o °$$i f oAB~~ O ~y xE _ ~m~mE 3~-tea ~~~~s g~zv~ a--- :=9 4~N ~-I "__~=aia Iulll I I IIII i ~~/~//T//-"_ //~/ ~ ',' O ~ \ `\^ ~ ~ ~~ ~ ~ ~' °-~^^~~~o~ooalo--N ~--~ ~--~ N N N l hi 1 1 1 1 1 1 1 O OG! 0 0 0 0 0 0 0 0 0 0 0 ~. 0 0 0 0 0 0 0 0 O O O O O O O O O O s 010--NM\ ^~ ~0001O€~+ ~~ o ~ ~ G `\. \ ~ `.~ n ,` ~ ~~ ^ o \~ \~\ U U o O N M ou 00 -~ '~~ % / / l l rFi ~ L ~' ., i E ~`/~/ jY\~ ~N / ~ 9 /~ ~~ / E U \ N ~ /1 ~ ~"' O 00 N ~~ ~ i ~, x o _ ~ - „ ~ ~ , r, ~, ~ ~ ~ ;\ `~` ~ O M . ~ N ; ~ 2.5 t z`q u ~~~ ~_ -3~` M O O O N O O O M "- ~_~_x N ~ ~ N N ~ ~ ~ ~ ~ o f ~sE-3~ c3 ..,. ~ . . a C C C C O O C C C C C O 00 01 O ~--~ N ~~NNNO N ~-- i Halliburton Com an • P Y Anticollision Report Company: ConoCOPhillips Aiaska Inc. Date: 11/9/2007 Time: 11:50:49 Yage: 1 i Field: Kuparuk River Unit Reference Site: Kuparuk 3K Pad Co-ordinate(NF.) Reference: Well: Plan 3K-102, True North Reference ~4'ell: Plan 3K-102 Vertical (TVD) Reference: 74.3' RKB (34.3+40) 74.3 Reference yi'ellpath: 3K-102 L1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 7011.65 to 14069.78 ft Scau Method: Trav Cylinder North Maximum Radius: 1602.98 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 10!11/2007 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft 40.00 1000.00 Planned: 3K-102 (wp06) V34 (0) CB-GYRO-SS Camera based gyro single shot 1000.00 7011.6 5 Planned: 3K-102 (wp06) V34 (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7011.65 14069.78 Planned: 3K-102 L1 (wp06) V12 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points 111D T~'D Diameter hole Size Name ft ft in in 2418.72 1930.2 7 13.375 16.000 13 3/8" 14069.44 3564.30 4.500 8.500 4 1 /2" 7011.65 3464.4 9 9.625 12.250 9 5/8" TOW Summary __ _ _ _. < ------ ------ Offset yy'ellpath ----------------------> Reference Offset Ctr-Ctr So-Go Allowable i Site V~'ell yy'ellpath MD N1D Distance Area Deviation Warning ft ft ft ft ft Kuparuk 3K Pad 3K-01 3K-01 V1 Out of range Kuparuk 3K Pad 3K-02 3K-02 V1 Out of range Kuparuk 3K Pad 3K-04 3K-04 V1 Out of range Kuparuk 3K Pad 3K-05 3K-05 V1 Out of range Kuparuk 3K Pad 3K-O6 3K-06 V1 Out of range Kuparuk 3K Pad 3K-07 3K-07 V1 Out of range Kuparuk 3K Pad 3K-08 3K-08 V1 Out of range Kuparuk 3K Pad 3K-09 3K-09 V4 Out of range Kuparuk 3K Pad 3K-09 3K-09A V1 Out of range Kuparuk 3K Pad 3K-10 3K-10 V1 Out of range Kuparuk 3K Pad 3K-11 3K-11 V1 Out of range Kuparuk 3K Pad 3K-12 3K-12 V1 Out of range Kuparuk 3K Pad 3K-13 3K-13 V1 Out of range Kuparuk 3K Pad 3K-14 3K-14 V1 Out of range Kuparuk 3K Pad 3K-15 3K-15 V1 Out of range Kuparuk 3K Pad 3K-16 3K-16 V1 Out of range Kuparuk 3K Pad 3K-17 3K-17 V1 Out of range Kuparuk 3K Pad 3K-18 3K-18 V1 Out of range Kuparuk 3K Pad 3K-19 3K-19 V6 7013.58 5800.00 446.82 105.08 341.73 Pass: Major Risk Kuparuk 3K Pad 3K-20 3K-20 V14 9005.26 6700.00 340.51 160.57 179.94 Pass: Major Risk Kuparuk 3K Pad 3K-22 3K-22 V3 Out of range Kuparuk 3K Pad 3K-22 3K-22A V1 Out of range Kuparuk 3K Pad 3K-23 3K-23 V2 Out of range Kuparuk 3K Pad 3K-24 3K-24 V12 7015.15 6175.00 1116.09 162.16 953.93 Pass: Major Risk Kuparuk 3K Pad 3K-25 3K-25 V1 Out of range Kuparuk 3K Pad 3K-26 3K-26 V1 Out of range Kuparuk 3K Pad 3K-27 3K-27 V2 Out of range Kuparuk 3K Pad 3K-30 3K-30 V1 7153.16 5625.00 766.66 163.38 603.28 Pass: Major Risk Kuparuk 3K Pad 3K-31 3K-31 V4 Out of range Kuparuk 3K Pad 3K-32 3K-32 V1 Out of range Kuparuk 3K Pad 3K-34 3K-34 V2 Out of range Kuparuk 3K Pad 3K-35 3K-35 V2 Out of range Kuparuk 3K Pad Plan 3K-102 3K-102 V4 Plan: 3K-102 7025.00 7025.00 0.21 96.14 -95.93 FAIL: Major Risk Kuparuk 3K Pad Plan 3K-D10 3K-D10 Pilot Hole V1 P Out of range Kuparuk 3K Pad Plan 3K-D10 3K-D10 V1 Plan: 3K-D10 Out of range Kuparuk 3K Pad Plan 3K-D11 3K-D11 V2 Plan: 3K-D11 Out of range Kuparuk 3K Pad Plan 3K-D12 Plan 3K-D12 V1 Plan: 3 7414.54 5450.00 287.40 115.87 171.53 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D13 3K-D13 V2 Plan: 3K-D13 7228.49 5150.00 889.44 109.33 780.11 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D14 3K-D14 V1 Plan: 3K-D14 8013.40 5750.00 907.01 118.53 788.48 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D15 3K-D15 V1 Plan: 3K-D15 8383.39 5975.00 1025.64 118.22 907.42 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D16 3K-D16 V1 Plan: 3K-D16 9793.93 7275.00 833.11 142.67 690.43 Pass: Major Risk ~~~~~q~ • H lliburton Com an • a p y Anticollision Report Compam~: ConocoPhdlips Alaska Inc. Date: 11/9/2007 Timc. 11:50.49 Yage: 2 Field Kuparuk River Unit Reference Site: Kuparuk 3K Pad Co-ordinate(NE) Reference: 1Nell'. Plan 3K-102, True North Reference Well: Plan 3K-102 Vertical (TVD) Reference: 74.3' RKB (34.3+40) 74.3 Reference Wellpath: 3K-102 L1 Db: Oracle Summary _ _. <---------------------- __ Offset Wellpath ----------------------> Reference Offset Ctr-Ctr . No-Go Allowable Site Nell Wellpath MD MD Distance Arca De~~iation ~'arning ft ft ft ft ft Kuparuk 3K Pad --__ Plan 3K-D17 __ 3K-D17 V1 Plan: 3K-D17 12899.36 10075.00 411.05 224.15 186.90 Pass: Major Risk Kuparuk 3K Pad Plan 3K-D8 3K-D8 V1 Plan: 3K-D8 w Out of range Kuparuk 3K Pad Plan 3K-E12 3K-E12 L1 VO Plan: 3K- 7037.30 5525.00 858.35 222.28 636.07 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E12 3K-E12 V1 Plan: 3K-E12 7037.30 5525.00 858.35 132.56 725.78 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E14 3K-E14 L1 V2 Plan: 3K- 13985.07 11650.00 1248.71 288.22 960.49 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E14 3K-E14 V4 Plan: 3K-E14 13978.90 11650.00 1249.73 304.95 944.77 Pass: Major Risk Kuparuk 3K Pad Plan 3K-E15 3K-E15 L1 V1 Plan: 3K- Out of range Kuparuk 3K Pad Plan 3K-E15 3K-E15 V2 Plan: 3K-E15 Out of range Kuparuk 3K Pad Plan 3K-E16 3K-E16 L1 VO Plan: 3K- Out of range Kuparuk 3K Pad Plan 3K-E16 3K-E16 V1 Plan: 3K-E16 Out of range Kuparuk 3K Pad Plan 3K-E6 3K-E6 V1 Plan: 3K-E6 ( Out of range Kuparuk 3K Pad Plan 3K-E7 3K-E7 V1 Plan: 3K-E7 ( Out of range Kuparuk 3K Pad Plan 3K-E8 3K-E8 V1 Plan: 3K-E8 w Out of range Kuparuk 3K Pad Plan 3K-E9 3K-E9 V1 Plan: 3K-E9 ( Out of range E~~~ ~~;acv • Wellhead /Tubing /Tree: 13-3/8" x 4112", 5,000 psi -~.~'~ Insulated Conductor: 20" 94# K-55x34" 0.312 WT +/- 80' ConOCOPIIi I li ps 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMTM) System 3875'DBNlpple ~500'MD Dual lateral Completion Heat Trace Cabte to 3,000' MD 3 K-10 2 H B D L P GLM, Camco, 41/2" x 1" KBMG, WP Oii GLM, Camco, 4112" x 1" KBMG, 13-3/8" Casing Shoe, 68#, L-80, BTC Gauge Carrier wl TEC Ilne W surface 3600' MD, 2373' TVD Tubing String 4112" 12.6#, LAO, IBTM 3.958" ID, 3.873" Drift PBR Seal Assembty wl TorqueMaster Production Anchor 4.75" Seal OD 7" X 35/5" RAM Hanger 5.960" Lateral Dritt ID 3.688" Mainbore Drift ID Equipment SDecifications 7" X 9-518" RAM Junction Mainbore Drift: 3.68" Lateral Drift: 5.80" RAM Hanger/Seal Bore Divener OD: 6.375" Overall Length of RAM Junction: 38.3 h Seal Bore Divener Running Tool: FJD RAM Hanger Running Tool: HRD-E 4112" Lateral Entry Module LEM OD: 6.99" Mainbore Drift wlo Diverters: 3.68" Mainbore Dritt wl Isolation Divener: 2.50" Lateral Ddh wl "FB" Divener: 3.68' OD of Diverters: 1.68" CMD Sliding Sleeve, wl 3.81" DB Nipple, +/- ~ jt above seals TorqueMaster Packer 4K" Lateral Entry Module (LEM) with 3.68" Seal Bore D-Sand Casing Exit 6975' MD, 345x• rvD, 'D' Sand Lateral 83 deg inc / 4112" 11.6#, BTL, LAO Slotted Liner ~~ ~~- Baker Oil Tools ,mbly Laeral Acc t n ess "FB" Divener c lke ~ IEMI ~ aa a n eDrL 9.618" ML TorgueMaeter Packer Positive Latching Collet Inabales coned Lour Snap In/Snap Out Orkntkg Protik Poaaive Locating Collet IAUw„unc Ugmxnt orlEMb Lateral Divener Latenllwktion M MHargerl BarnP Upper Seals Seal sore for Lateral Isolatbn Divener " Snap INSnap Out 7.69 ID Positive Lo<ating covet Lateral Access WIIIaOW - l%ovMes PwMVe lakrtl Accera VY TluuTUW,p ONwtxl _ Lateral IsoW bn S l L ower ea s ~J l.eala ~nsia<nAM seal Bore oivened 9 Spear used for running and pulling diverters - 4112" Guide Shce, B.00" OD 3.562" OB NIppN 4Y,":3518" RAM Seal Bore Divener (SBDI with 3.89" Seal Bore ~ ML Protluction Anchor 41/2" Casing Shce, 11.6#, L-80 BTCM ~ 14069' MD, 3564' rvD 41/2" 128# IBTM Tubing' Seal ASSembty 'B' Sand Lateral T' % 35/8" MLZ%P 4.75" Seal OD Licer Hanger Packer 3.875' ID Set at *I- 7825' 5112" 15.Sa, BTC, LAO Slatted Liner Sealbore Receptacle 4.75" ID 9-5/8" Casing Shoe, 40.0#, L-80 BTC ~ 7800' M D, 3576' rvD 89 deg inc 5-112" Casing Shoe, 15.5#, L-80 BTCM 14076' MD, 3628' TVD As Planned 51/2" Eccentric Guitle Shce ___.1 W 0 TRANSMITTAL~~LETTER CHECKLIST WELL NAME ~~/~~s?ZS~ '" ~~Z ~. PTD# ~? ~ ~tiO Ste' 1/ 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 weiibore segment of existing welt K/2L~ .3'~' -- X02.-~ , (If last two digits in Permit No. Zo ~/~ S" , API No. 50- OZ9_ ~.3 3 7 - ~. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PII,OT HOLE In accordance with 20 AAC 25.045(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 welt SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and p uce / 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 allow Well for (nname of weld until after jComp~v Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompa~ y Name) must contact the Commission to obtain advance approval of such water well testing ro m. Rev: 7/132007 ^~^ a' , , ~ N' > d a .. 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Y > o, 1°m, c, °'' m m' ~, v q ~} m m , G m. m - °~~ o ' o ~ ~' ~; ~, m, v , m v c ~ a O O ~, ~ d; ~ ' ~' m, io m, m ~ o, v D ---~ V , ~ a, ~, ~, ~; 3; ~; cn, ~-; o, o, a; a; v, ~, ¢; a, z v; cn; v; v, v, v, ¢; ;; d, ~- o m; m; v, , ~ ; , ~ m, m; ~-, , eJ ~. O r N M st ~ (O A OD O O r N r r r M ~t lA tp 1~ r r r r r CO 01 O r N M er r r N N N N (V to !O !~ CO N N N N - 01 O N M M - N M M M~ ~ (O t~ CO M M M M O M_ ~ V - -- ~ - _ - r r 0 ~:. tt pp O C W ~ N ~ ~ NeC ~ N ~ V o O ~ a t p n •+ ~ ~ r ~ ~ N r N T' W °y .. . ~ ~ J ..I N ~ • m ~ d U Q f- £ v °' Q ~ ~ a H $ a~ C9 d Q W Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 3k-10211.tapx Sperry-Sun Driliin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 10 09:48:34 2008 Reel Header Service name .............LISTPE Date . ...................08/04/10 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/04/10 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw-000547949 B. HENNINGSE M. THORNTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 8 MW-000547949 R. WILSON F. HERBERT Scientific Technical Services 3K-102L1 500292337860 ConocoPhillips Alaska, Inc Sperry Sun 10-APR-08 MWD RUN 6 MWD RUN 7 Mw-000547949 Mw-000547949 R. WILSON R. WILSON F. HERBERT F. HERBERT 35 13N 9E 910 314 Page 1 ~ o`er-l ~( ~l ~ l~ 3k-10211.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 73.80 GROUND LEVEL: 33.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3143.0 2ND STRING 8.500 9.625 6795.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE EXITED 3K-102L1 PB1 FROM A OPENHOLE SIDETRACK AT 12200' MD, 3505' TVD. 5. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (GP), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 4 WAS TO SET PACKER FOR WHIPSTOCK. MWD RUN 5 WAS TO SET WHIPSTOCK AND MILL A WINDOW. NO DATA ARE PRESENTED FOR MWD RUN 4. SROP DATA FROM MWD RUN 5 MERGED WITH MWD RUN 6. 7. MWD RUN 6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), AND PRESSURE WHILE DRILLING (PWD). 8. MWD RUN 7-8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPiLOT ROTARY-STEERABLE BHA (G P), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 9. GAMMA RAY DATA FROM AT-BIT GAMMA (ABG) MERGED ONTO BOTTOM OF SGRC AT THE END OF MWD RUN 8. NOTE DUE TO MEMORY FILL THE AT-BIT GAMMA DATA IS REAL-TIME DATA. GAPS IN DATA DUE TO INCOMPLETE MPT DETECTION. Page 2 3k-10211.tapx 10. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 11. MWD RUNS 1-2 AND 4-8 REPRESENT WELL 3K-102L1 WITH API#: 50-029-23378-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14081'MD, 3569'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR. (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12 1/4" FIXED AVG OFFSET: 0.3~~ FIXED MUD WEIGHT: 8.8 - 9.2 PPG MUD SALINITY: 650 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 12000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 Page 3 3k-10211.tapx 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 3114.5 14069.5 RPM 3133.0 14036.0 RPS 3133.0 14036.0 RPX 3133.0 14036.0 PEF 3133.0 6795.0 FET 3133.0 14036.0 FONT 3133.0 6795.0 NCNT 3133.0 6795.0 NPHI 3133.0 6795.0 RPD 3133.0 14036.0 DRHO 3144.0 6795.0 RHOB 3144.0 6795.0 OP 3150.0 14081.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 3114.5 6 6795.0 7 7114.0 8 12200.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6795.0 7114.0 12200.0 14081.0 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 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 Page 4 • 3k-10211.tapx ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 14081 8597.75 21934 3114.5 14081 FCNT MWD CP30 489.79 2025.31 891.005 7325 3133 6795 NCNT MWD CP30 123681 181094 146761 7325 3133 6795 RHOB MwD G/cc 1.422 2.739 2.11642 7303 3144 6795 DRHO MWD G/CC -0.052 0.371 0.0264013 7303 3144 6795 RPD MWD OHMM 0.81 2000 34.3782 21807 3133 14036 RPM MWD OHMM 3.34 2000 34.621 21807 3133 14036 RPS MWD OHMM 0.06 2000 32.5131 21807 3133 14036 RPX MWD OHMM 4.26 2000 29.3246 21807 3133 14036 FET MWD HR 0.12 485.36 1.04686 21807 3133 14036 GR MWD API 20.55 136.44 74.8682 21881 3114.5 14069.5 PEF MWD B/E 0.92 15.64 2.1368 7325 3133 6795 ROP MWD FPH 0 1044.96 259.719 21863 3150 14081 NPHI MWD PU 18.14 102.82 41.3894 7325 3133 6795 First Reading For Entire File..........3114.5 Last Reading For Entire File...........14081 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 GR 3114.5 PEF 3133.0 FET 3133.0 RPD 3133.0 STOP DEPTH 6795.0 6795.0 6795.0 6795.0 Page 5 • 3k-10211.tapx FCNT 3133.0 6795.0 NCNT 3133.0 6795.0 NPHI 3133.0 6795.0 RPM 3133.0 6795.0 RPS 3133.0 6795.0 RPx 3133.0 6795.0 RHOB 3144.0 6795.0 DRHO 3144.0 6795.0 ROP 3150.0 6795.0 LOG HEADER DATA DATE LOGGED: 13-JAN-O8 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.0 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 77613 CTN COMP THERMAL NEUTRON 158417 ALD Azimuthal L itho-Den 239330 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER's CASING DEPTH (FT): 3143.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 45.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 6.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.329 114.8 MUD FILTRATE AT MT: 2.200 74.0 MUD CAKE AT MT: 2.100 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type ................ ..0 Page 6 • • 3k-10211.tapx 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 FONT MWD020 cP30 4 1 68 4 2 NCNT MWD020 cP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 B/E 4 1 68 44 12 ROP MWD020 FPH 4 1 68 48 13 NPHI MwD020 Pu 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 6795 4954.75 7362 3114.5 6795 FONT MwD020 CP30 489.79 2025.31 891.005 7325 3133 6795 NCNT MWD020 CP30 123681 181094 146761 7325 3133 6795 RHOB MWD020 G/CC 1.422 2.739 2.11642 7303 3144 6795 DRHO MWD020 G/CC -0.052 0.371 0.0264013 7303 3144 6795 RPD MWD020 OHMM 0.81 2000 23.9777 7325 3133 6795 RPM MWD020 OHMM 3.8 2000 23.1452 7325 3133 6795 RPS MWD020 OHMM 0.06 147.36 16.9021 7325 3133 6795 RPX MWD020 OHMM 4.26 61.22 12.2621 7325 3133 6795 FET MwD020 HR 0.12 157.53 1.1823 7325 3133 6795 GR MWD020 API 20.55 132.74 67.547 7362 3114.5 6795 PEF MwD020 B/E 0.92 15.64 2.1368 7325 3133 6795 ROP MWD020 FPH 1.53 504.35 245.348 7291 3150 6795 NPHI MWD020 Pu 18.14 102.82 41.3894 7325 3133 6795 First Reading For Entire File..........3114.5 Last Reading For Entire File...........6795 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Page 7 • 3k-10211.tapx File Header Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.002 comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6795.5 ROP 6795.5 RPD 6795.5 FET 6795.5 RPS 6795.5 GR 6795.5 $PM 6795.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: header data for each bit run in separate files. 6 .5000 STOP DEPTH 7066.0 7114.0 7066.0 7066.0 7066.0 7078.0 7066.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (5): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: Page 8 3 O1-FEB-08 Insite 74.11 Memory 81.1 91.5 TOOL NUMBER 245697 228269 8.500 3143.0 Mineral oil Base 9.30 85.0 27500 89.4 • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 3k-10211.tapx 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 u Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6795.5 7114 6954.75 638 6795.5 7114 RPD MWD060 OHMM 6.35 2000 55.7787 542 6795.5 7066 RPM MwD060 OHMM 9.75 1245.84 52.6316 542 6795.5 7066 RPS MWD060 OHMM 7.23 92.72 50.4032 542 6795.5 7066 RPX MWD060 OHMM 8.44 94.2 51.6685 542 6795.5 7066 FET MWD060 HR 0.2 485.36 8.70917 542 6795.5 7066 GR MWD060 API 54.04 92.16 69.134 566 6795.5 7078 ROP MWD060 FPH 0.59 1002.33 259.022 638 6795.5 7114 First Reading For Entire File..........6795.5 Last Reading For Entire File...........7114 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Page 9 • 3k-10211.tapx Physical EoF File Header Service name... .......STSLIB.004 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 7066.5 RPx 7066.5 RPS 7066.5 RPD 7066.5 RPM 7066.5 GR 7078.5 ROP 7114.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA EWR4 ELECTROMAG. header data for each bit run in separate files. 7 .5000 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 12200.0 12200.0 12200.0 12200.0 12200.0 12200.0 12200.0 RAY RESIS. 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) Page 10 4 05-FEB-08 Insite 74.11 Memory 77.9 94.8 TOOL NUMBER 245697 228269 8.500 3143.0 Mineral oil Base 9.35 73.0 25000 • • 3k-10211.tapx MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 134.6 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined 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 MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7066.5 12200 9633.25 10268 . 7066.5 12200 RPD MWD070 OHMM 11.65 2000 39.7075 10268 7066.5 12200 RPM MWD070 OHMM 12.02 2000 40.7249 10268 7066.5 12200 RPS MWD070 OHMM 6.54 2000 39.7303 10268 7066.5 12200 RPX MWD070 OHMM 9.79 2000 36.887 10268 7066.5 12200 FET MWD070 HR 0.13 29.1 0.703454 10268 7066.5 12200 GR MWD070 API 47.3 109 78.4121 10244 7078.5 12200 ROP MWD070 FPH 0.19 4 79.56 278.851 10172 7114.5 12200 First Reading For Entire File..........7066.5 Last Reading For Entire File...........12200 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................Lo Page 11 • i 3k-10211.tapx Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 12200.5 14036.0 RPX 12200.5 14036.0 RPM 12200.5 14036.0 FET 12200.5 14036.0 RPS 12200.5 14036.0 GR 12200.5 14069.5 ROP 12200.5 14081.0 LOG HEADER DATA DATE LOGGED: 06-FEB-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.1 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 228269 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7595.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 84.0 MUD PH: Page 12 • • 3k-10211.tapx MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 134.6 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined 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 MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12200.5 14081 13140.8 3762 12200.5 14081 RPD MWDO80 OHMM 7.14 2000 37.0752 3672 12200.5 14036 RPM MWD080 OHMM 3.34 2000 37.7946 3672 12200.5 14036 RPS MWD080 OHMM 5.06 2000 40.8458 3672 12200.5 14036 RPX MWD080 OHMM 6.35 2000 38.9416 3672 12200.5 14036 FET MwD080 HR 0.13 3.51 0.528295 3672 12200.5 14036 GR MWD080 API 44.13 136.44 80.5659 3709 12200.5 14069.5 ROP MWD080 FPH 0 1044.96 235.957 3762 12200.5 14081 First Reading For Entire File..........12200.5 Last Reading For Entire File...........14081 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number...........1.0.0 Page 13 t 3k-10211.tapx Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/10 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/04/10 Origin ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 14 3k-10211pbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 10 11:03:04 2008 Reel Header Service name .............LISTPE Date . ...................08/04/10 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................08/04/10 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF comment Record TAPE HEADER Kuparuk River unit, west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000547949 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • scientific Technical services scientific Technical services 3K-102L1 PB1 500292337870 ConocoPhillips Alaska, Inc Sperry Sun 10-APR-08 MWD RUN 6 MWD RUN 7 Mw-000547949 Mw-000547949 R. WILSON R.WILSON F.HERBERT F. HERBERT 35 13N 9E 910 314 .00 73.80 33.80 Page 1 2 a~-c ~ ~ ~ t ~, r 3'~. ~. 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-10211pbl.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3143.0 8.500 9.625 6795.0 • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. THIS WELLBORE EXITED 3K-102 FROM A WHIPSTOCK AT 6795' MD, 3449' TVD. 5. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (G P), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUN 4 WAS TO SET PACKER FOR WHIPSTOCK. MWD RUN 5 WAS TO SET WHIPSTOCK AND MILL A WINDOW. NO DATA ARE PRESENTED FOR MWD RUN 4. SROP DATA FROM MWD RUN 5 MERGED WITH MWD RUN 6. 7. MWD RUN 6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), AND PRESSURE WHILE DRILLING (PWD). 8. MWD RUN 7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTRONMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), GEOPILOT ROTARY-STEERABLE BHA (GP), AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 9. GAMMA RAY DATA FROM AT-BIT GAMMA (ABG) MERGED ONTO BOTTOM OF SGRC AT THE END OF MWD RUN 7. 10. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 11. MWD RUNS 1-2 AND 4-7 REPRESENT WELL 3K-102L1PB1 WITH API#: 50-029-23378-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12456'MD, 3497'TVD. Page 2 3k-10211pbl.tapx 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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12 1/4~~ FIXED AVG OFFSET: 0.3" FIXED MUD WEIGHT: 8.8 - 9.2 PPG MUD SALINITY: 650 - 1000 PPM CHLORIDES FORMATION WATER SALINITY: 12000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR NPHI RPM NCNT 1 clipped curves; all bit runs merged. .5000 START DEPTH 3114.5 3133.0 3133.0 3133.0 STOP DEPTH 12452.5 6795.0 12411.5 6795.0 Page 3 3k-10211pbl.tapx RPS 3133.0 12411.5 FCNT 3133.0 6795.0 RPD 3133.0 12411.5 RPS 3133.0 12411.5 FET 3133.0 12411.5 PEF 3133.0 6795.0 RHOB 3144.0 6795.0 DRHO 3144.0 6795.0 ROP 3150.0 12456.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 3114.5 6795.0 MwD 6 6795.0 7114.0 MwD 7 7114.0 12456.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ........,.0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 12456 7785.25 18684 3114.5 12456 FONT MwD CP30 489.79 2025.31 891.005 7325 3133 6795 NCNT MWD CP30 123681 181094 146761 7325 3133 6795 RHOB MWD G/CC 1.422 2.739 2.11642 7303 3144 6795 Page 4 3k-10211pbl.tapx DRHO MWD G/CC -0.052 0.371 0.0264013 7303 3144 6795 RPD MWD OHMM 0.81 2000 33.5058 18558 3133 12411.5 RPM MWD OHMM 3.8 2000 33.6253 18558 3133 12411.5 RPS MWD OHMM 0.06 2000 30.5358 18558 3133 12411.5 RPX MWD OHMM 4.26 2000 27.1504 18558 3133 12411.5 FET MWD HR 0.12 485.36 1.1186 18558 3133 12411.5 GR MWD API 20.55 132.74 74.1532 18677 3114.5 12452.5 PEF MWD B/E 0.92 15.64 2.1368 7325 3133 6795 RoP MWD FPH 0.19 1002.33 263.749 18613 3150 12456 NPHI MWD PU 18.14 102.82 41.3894 7325 3133 6795 First Reading For Entire File..........3114.5 Last Reading For Entire File...........12456 File Trailer Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF Fire Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 3114.5 6795.0 FET 3133.0 6795.0 FONT 3133.0 6795.0 PEF 3133.0 6795.0 NCNT 3133.0 6795.0 RPM 3133.0 6795.0 RPx 3133.0 6795.0 NPHI 3133.0 6795.0 RPD 3133.0 6795.0 RPS 3133.0 6795.0 RHOB 3144.0 6795.0 DRHO 3144.0 6795.0 ROP 3150.0 6795.0 Page 5 3k-10211pbl.tapx LOG HEADER DATA DATE LOGGED: 13-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.0 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 77613 CTN COMP THERMAL NEUTRON 158417 ALD Azimuthal Litho-Den 239330 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3143.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 45.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 6.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.329 114.8 MUD FILTRATE AT MT: 2.200 74.0 MUD CAKE AT MT: 2.100 70.0 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 Page 6 3k-10211pbl.tapx DEPT FT 4 1 68 0 1 FONT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MwD020 API 4 1 68 40 11 PEF MWD020 B/E 4 1 68 44 12 ROP MWD020 FPH 4 1 68 48 13 NPHI MwD020 PU 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3114.5 6795 4954.75 7362 3114.5 6795 FCNT MWD020 CP30 489.79 2025.31 891.005 7325 3133 6795 NCNT MWD020 CP30 123681 181094 146761 7325 3133 6795 RHOB MWD020 G/CC 1.422 2.739 2.11642 7303 3144 6795 DRHO MWD020 G/CC -0.052 0.371 0.0264013 7303 3144 6795 RPD MWD020 OHMM 0.81 2000 23.9777 7325 3133 6795 RPM MWD020 OHMM 3.8 2000 23.1452 7325 3133 6795 RPS MWD020 OHMM 0.06 147.36 16.9021 7325 3133 6795 RPX MWD020 OHMM 4.26 61.22 12.2621 7325 3133 6795 FET MWD020 HR 0.12 157.53 1.1823 7325 3133 6795 GR MWD020 API 20.55 132.74 67.547 7362 3114.5 6795 PEF MwD020 B/E 0.92 15.64 2.1368 7325 3133 6795 ROP MWD020 FPH 1.53 504.35 245.348 7291 3150 6795 NPHI MwD020 Pu 18.14 102.82 41.3894 7325 3133 6795 First Reading For Entire File..........3114.5 Last Reading For Entire File...........6795 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER Page 7 3k-10211pbl.tapx FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6795.5 7114.0 GR 6795.5 7078.0 FET 6795.5 7066.0 RPx 6795.5 7066.0 RPS 6795.5 7066.0 RPM 6795.5 7066.0 RPD 6795.5 7066.0 LOG HEADER DATA DATE LOGGED: O1-FEB-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.1 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 228269 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 6795.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Bas MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 85.0 MUD PH: MUD CHLORIDES (PPM): 27500 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 89.4 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 8 3k-10211pbl.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin 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 MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MwD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6795.5 7114 6954.75 638 6795.5 7114 RPD MWD060 OHMM 6.35 2000 55.7787 542 6795.5 7066 RPM MWD060 OHMM 9.75 1245.84 52.6316 542 6795.5 7066 RPS MWD060 OHMM 7.23 92.72 50.4032 542 6795.5 7066 RPX MWD060 OHMM 8.44 94.2 51.6685 542 6795.5 7066 FET MwD060 HR 0.2 485.36 8.70917 542 6795.5 7066 GR MWD060 API 54.04 92.16 69.134 566 6795.5 7078 ROP MWD060 FPH 0.59 1002.33 259.022 638 6795.5 7114 First Reading For Entire File..........6795.5 Last Reading For Entire File...........7114 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Page 9 3k-10211pbl.tapx comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 7066.5 12411.5 FET 7066.5 12411.5 RPX 7066.5 12411.5 RPM 7066.5 12411.5 RPD 7066.5 12411.5 GR 7078.5 12452.5 ROP 7114.5 12456.0 LOG HEADER DATA DATE LOGGED: 05-FEB-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.9 MAXIMUM ANGLE: 94.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 245697 EWR4 ELECTROMAG. RESIS. 4 228269 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 6795.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Bas MUD DENSITY (LB/G): 9.35 MUD VISCOSITY (S): 73.0 MUD PH: MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 134.6 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 10 3k-10211pbl.tapx 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 MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7066.5 12456 9761.25 10780 7066.5 12456 RPD MWD070 OHMM 9.29 2000 38.9049 10691 7066.5 12411.5 RPM MWD070 OHMM 9.59 2000 39.8422 10691 7066.5 12411.5 RPS MWD070 OHMM 6.54 2000 38.8697 10691 7066.5 12411.5 RPX MWD070 OHMM 9.18 2000 36.1083 10691 7066.5 12411.5 FET MWD070 HR 0.13 29.1 0.690132 10691 7066.5 12411.5 GR MWD070 API 47.3 114.49 78.942 10749 7078.5 12452.5 ROP MWD070 FPH 0.19 479.56 276.589 10684 7114.5 12456 First Reading For Entire File..........7066.5 Last Reading For Entire File...........12456 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB,005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/10 Origin ...................STS Tape Name ................UNKNOWN Page 11 3k-10211pbl.tapx Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................08/04/10 Ori 9in ...................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 Page 12