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Home My WebLink About205-037• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ ~ ~ Well History File Identifier Organizing (done> RE CAN Color Items: ^ Greyscale Items: [Two-sided IIIIIIIIIIIIIIIIIII DIGITAL DATA ~skettes, No. ^ Other, No/Type: Ae~~~e~e~ uiiuiiinuiiui p Poor Quality Originals: ^ Other: NOTES: BY Date: ~ ~30~~ OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Isl Project Proofing BY Date: /~ 3~I Q /s/ Scanning Preparation BY: Production Scanning ' IIIIIIIIilllll IIIII Stage 1 Page Count from Scanned File: _~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: f ~~O/ Og /s/ ~~/~, f YV ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO ~ x 30 = _~ + ~~ =TOTAL PAGES_~ (Count does not include cover sheet) Date: ~ 8' /s/ BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II IIIII ReScanned III (IIIII IIIII II III BY: Maria Date: /s/ Comments about this file: o~a~.~~e~kea iiiiiiimiiiiiiiu 10/6!2005 Well History File Cover Page.doc MtCRQFILMED o~~o~~zoos DC3 N4T PLACE ~ ANY NEW MATERIAL UNDER.THIS PAGE F:1LaserFichelCvrPgs_InsertslMicrofilm Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050370 Well Name/No. KUPARUK RIV U WSAK 1J-154L2 Operator CONOCOPHILLIPS ALASKA INC MD 10964 TVD 3358 Completion Date 10!3012005 Completion Status 1-OIL Current Status 1WINJ REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CBL Well Log Information: Log/ Electr Data Digital Dataset Typie MediFrmt Number Name __ API No. 50-029-23254-51-00 UIC Y 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 i.~b D Asc Directional Survey D Lis 13785 Induction/Resistivity I t 13785 LIS Verification p '~. C Lis 15016 Induction/Resistivity 4062 10964 Open 1!9!2006 2256 10898 Open 3/9/2006 ASLD GR EWR4 CNP SLD ROP ACAL PWD GeoPilot 2256 10898 Open 3/9/2006 ASLD GR EWR4 CNP SLD ROP ACAL PWD GeoPilot 2256 10964 Open 4/17/2007 LIS Veri, SGRC, SROP w/Graphics CGM, EMF, PDF Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~N Chips Received? ~C,~-PI-~~ Analysis ~ Received? Comments: Compliance Reviewed By: Daily History Received? ~ / N Formation Tops ~ / N Date: WELL LOG TRANS'~TITTAI. To: State of Alaska April 13, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-154, L1 & L2, AK-MW-3956462 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-154, 1J-154 Ll, 1J-154 L2: LIS & Digital Log Images: 50-029-23254-00, 60, 61. C,G~= U~~ aoS-o35~ ~ 15 d !~( :~, ~ 1 '~>~ -~: °~ l ?i ~-~ ail ~° 15 ~~~~ ?~ "t~~~4'~'"~'~. w ~ ~ u ~~ a as -03~ ~tS~~S 1 CD Rom i.J 1C° 2~G5 =03~ ~ 1 Sa~~ Iy .~ -r "®: , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~a~~ ~p~ ~s duns. LI"rfr!f1F~f. REPORT OF SUNDRY WELL OPERATIONS ~~lal:~eor~a 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Prod to WINJ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat: Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ . Exploratory ^ 205-037 - 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23254-61 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-154L2 8. Property Designation: 10. Field/Pool(s): ADL 25661'& 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 10964' - feet true vertical 3358' ' feet Plugs (measured) Effective Depth measured 10964' feet Junk (measured) true vertical 3358' feet 4-1l2" Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3/4" 2300' 2199' L2 WINDOW 1' 7-5/8" 4092' 3452' PROD. CASING 1' 7-5/8" 4371 3512' INTERMEDIATE 5056' 7-5/8" 5165 Perforation depth: Measured depth: 410T - 10881' true vertical depth: 3454' - 3364' Tubing (size, grade, and measured depth) 4-112" , L-80, 4047 MD . Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 490' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none ~F~.. ~p~ ~ ~ Zoos Treatment descriptions including volumes used and final pressur e: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure 7ubin Pressure Prior to well operation 2044 2851 750 335 Subsequent to operation 2649 437 332 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 3o~-d~fl Contact Robert W. Buchholz Printed Name Title Production Engineering Tec nician h ~ ~ ~ Signature i~~ts'~~,*^l%~~JG"" ~ /I~/ ~y Phone 907-659-7535 Date t ,L / l/ Form 10-404 Revised 04/2004 p ~ ~ ~ I ~ q L E~, sut5mit Orin y y g~g f~~rz 1J-154L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/10/2006 Commenced Water Injection Service r • WELL LOG TRANSMITTAL To: State of Alaska March 03, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-154 L2, AK-MW-3956460 1 LDWG formatted Disc with verification listing. API#: 50-029-23254-61 ~ `~ ~ ~ ,/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSNHTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Dater Signed: a ~~ jjii ~ ~ ~ , nI ~, '~' _ AI~sSA OaL A1QD GrAs co~s~RVgTaor~ corrrassao~ Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, 1J-154L2 Sundry Number: 306-068 Dear Mr. Buchholz: i i ~' t FRANK H. MURKOWSKI, GOVERNOR ~J 1' f ~~ ~' 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ay of February, 2006 Encl. Sincerely, ~ 2-23-°~ ~ ~-; s Z~z~~~ RECEIVED -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I ~~ FEB 2 1 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 252A0 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-037 `~ 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska-99510 50-029-23254-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-154L2 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11 • PRESENT WELL CONDtTlON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft) : Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10964' 3358' 10964' 3358' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3/4" 2300' 2199' ' L2 WINDOW 1' 7-5/8" 4092' 3452' L1 WINDOW 1' 7-5/8" 4371 3512' INTERMEDIATE 5056' 7-5/8" 5165 3649' D Sand Slotted Line 6774' 4-1/2" 10881' 3364' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4107' - 10881' 3454' - 3364' 4-1/2" L-80 4047' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 490' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^~ BOP Sketch ^ Exploratory ~ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 03/10/06 Oil ^ Gas. ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert W. Buchholz Printed Name Robert W. Buchhol z Title: Production Engineering Technician ~ ,~ Signature -~`"~ ~ Phone 659-7535 Date Oz / Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3U~j Plug Integrity ^ BOP Test ^ Mechanical Integrity Test (~( Location Clearance ^ Other: M\~S~CS~~D~.C~t'~V~C~G' ~1.3 ~k"'~..~~\V~Ct~~'~„`~, ~~, - Subsequent Form Required:- ~ ~ 67~6m ~E~ ~ `~ 2~~ - A oved b C I APPROVED BY ppr y: OMM SSIONER THE COMMISSION Date: Form 10-403 Revised 07/200 Submit in Duplicate • 1J-154L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-154. This well was pre-produced fora 52 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-154L2 will provide pressure support for the West Sak D sands. The 10-3/4" Surface casing (2300' and / 2199' tvd) was cemented with 470 sx AS Lite followed by 149 sx DeepCrete. The 7-5/8" Intermediate casing (5165' and / 3628' tvd) was cemented with 360 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer D- Lateral Hook Hanger LEM wlisolation Seal Bore located @ 4071' and / 3448' tvd. The top of West Sak D sand was found at 4107'md / 3454' tvd. The top of West Sak B sand was found at 4406'md / 3517' tvd. The top of West Sak A sand was found at 5412'md / 3661' tvd. ~~~P ' r'-~.C~.NICAL INTEGRITY REPORT ._~~3~ =?UD S-_:= ~ - Ctir"~.~~c~ OPER ~ FIELD ~„~(--~-~ ,` `'~~ ~~ -_,G r~~5~..~. ~~~-3c;°-~~ h~LL NUMBtR 1-, ~~~~ - ~~L "~~ f+ rr L L D A T ~_ TD : ~-t L ~ ~ . ?~.. `~(,'-t~j TVD ; ? B T D : ?~ID ~I'VD Casing : '~l ~ 1 ~, Shoe : ~i (~ ~~ MD ~~,'-{ TVD ~ i~ V : ~ ~-_ ?~ ~ ~ Tti~i c~ ...,e.: S~o~LC,y Shoe : ~ T`T~ ; ~'CP : '•~ ~'iD S~v~ c ~~. y ~~ o l e S. ~ e ~~ ~ and ; P e r f s l.. ~ .~..~ ~ , ~ c ~~.: y Q'l.~ .~ ~... ~ .,a<<~~c.~~ t o ~i 3'l ~-~_ w , \-~C:j`~~~i~ ~~~~ ~_~'~'C c?~?~ =C~_:.. ~ NTEGR?'TY - ~ a.RT # 1 ~Znul~:s ?ress Test: _? COQe:lt~ . ; 1S QlI: ; ~~ III1I1 `~'CH.QNIC~i, INTEGRIT`~ - PAF.T #2 ~---~ i~i~'~jhl~; Cement Volumes : r~~t. L iner ~ ~- Cs~ ~ ~ DV ~~ . C.~t Jol to cover per~s ~`1 ~j`j~ ~ S \-l~, ~ ~- `~7s a ~ L +~ ~- ~~' ~~f. t i'~E ~ C~' T ~^a i -. 7~ ` r~ 7/ ~. ~J`~`~ G` ~c .' e O r e t 1 C 31 T V C -~rfSl F ~\ C. \ ~\ V\ 1~frCi . - ~~l ~~C`Cs ~C: _ 7 Y ~J~ Cement Bond Log (Yes or No) ~~~ ; In AOGCC File_ CBL Evaluation, gone aBove perfs ~~,~~~~ `~ ~~~~`~~~-- ~r-~~~i ?roduction Log: '?'pie Evaluation CONC-L'JSZONS ? art #1 1 ?ar ~ fL: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 ~ 2006 WELL COMPLETION OR RECOMPLETION REPO 1a. Well Status: Oil a Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: ~nchorappe Development s EYCploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: October 30, 2005 12. Permit to Drill Number: 205-037 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:OG. f-~~. a~~ ~~- Se 0, 2005 f- [`~,• 13. API Number: ~ 50-029-23254-61 4a. Location of Well (Governmental Section): ~ Surface: 2133' FSL, 2569' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: ~ October 26, 2005 14. Well Name and Number: 1J-154L2 At Top Productive Horizon: 1558' FSL, 2179' FWL, Sec. 35, T11 N, R10E 8. KB Elevation (ft): ~ 28' RKB / 108' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 55' FNL, 2210' FWL, Sec. 11, T10N, R10E 9. Plug Back Depth (MD + ND): 10964' MD / 3358' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558640 y- 5945944 Zone- 4 10. Total Depth (MD + ND): f 10964' MD / 3358' TVD ~ 16. Property Designation:, ,, ADL 25661 & 25662 TPI: x- 558112 y- 5945365 Zone- 4 Total Depth: x- 558205 - 5938474 Zone- 4 11. Depth where SSSV set: Camco nipple @ 490' 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^/ No 19. Water Depth, if Offshore: feet MSL N /A 20. Thickness of Perma frost: 1582' MD ~ .~sv~ a / 1~ 21. Logs Run: ~/~ T 0 ~ ~ ~fr ,~ ,~~j!^~ ~ / • -V ~,(~ /' ~~ ' ~+~a GR/Res, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE I G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENT N RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 169 sx ASI 10.75" 45.5# L-80 28' 2300' 28' 2201' 13.5" 470 sx AS Lite, 149 sx DeepCrete 7-5/8" 29.7# L-80 28' 5165' 28' 3649' 9-7/8" 360 sx DeepCrete 4.5" 12.6# L-80 4107' 10918' 3454' 3362' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 4017' slotted liner from 4107'-10881' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 25, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1 J-154 and 1 J-154L1 Date of Test 12/28/2005 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1121 GAS-MCP 974 WATER-BBL 1 CHOKE SIZE 53 Bean GAS-OIL RATIO 869 Flow Tubing press. 319 ps Casing Pressure 1180 Calculated 24-Hour Rate -> OIL-BBL 2241 GAS-MCP 1948 WATER-BBL 3 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oit, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~m p r - "j ~'.SCS _=.. T..~ NONE q~ p V+w A6ii ~C Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~R1GI~IAL 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-154L2 Top West Sak D 4063' 3446' Base West Sak D 10964' 3358' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and ~rrect to the best of my knowledge. Contact: Mik Greener @ 263-4820 Printed Name , a omas Title: Greater Kuoaruk Area Drillino Team Leader ~ ~O ~~ Signature Phone Date / Prepared by Sharon Allsup-Drake ~- / ~`~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Mukiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ' Flours ' Code 'Sub 'Code 9/27/2005 00:00 - 03:00 3.00 MOVE DMOB 03:00 - 04:30 1.50 MOVE MOVE 04:30 - 05:00 ' 0.50 05:00 - 07:00 2.00 07:00 - 08:00 ~ 1.00 08:00 - 11:30 i 3.50 9/30/2005 10/1!2005 00:00 - 01:00 01:00 - 02:30 02:30 - 04:00 04:00 - 08:00 08:00 - 09:00 09:00 - 09:45 1.00 1.50 1.50 4.00 1.00 0.75 MOVE MOVE MOVE OTHR MOVE POSN MOVE iMOVE RIGMNT RSRV WELCT NUND DRILL OTHR DRILL 'PULD DRILL ;PULD WELCTL BOPE 09:45 - 11:00 1.25 DRILL PULD 11:00 - 12:00 ! 1.00 DRILL ' OTHR 12:00 - 12:45 0.75: DRILL DRLG 12:45 - 14:30 1.751 DRILL I OTHR 14:30 - 15:30 ~ 1.00 DRILL ~ DRLG 15:30 - 15:45 0.25, DRILL ,TRIP 15:45 - 17:45 2.00' DRILL PULD 17:45 - 21:00 3.25! DRILL 'DRLG 21:00 - 21:30 I 0.50 DRILL SURV 21:30 - 22:30 1.00 ~ DRILL 'TRIP 22:30 - 23:00 j 0.50 ~ DRILL DRLG 23:00 - 00:00 ' 1.00 00:00 - 12:00 12.00 DRILL SURV DRILL DRLG Page 1 of 21 Spud Date: 9/30!2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Phase Description of Operations MOVE Disconnected service loops between complex's and blow down lines MOVE Moved rigs complex's off well and spotted on pad, moved off boilers, motors, pumps, pits and pipe sheds MOVE Moved sub base off well 1J-168 MOVE i Removed steering arm and bracket aloud with spare tire on side of sub base, had to remove to set sub over well due to close proximity of well 1 J-09 MOVE ;Spotted sub base on well 1J-154 MOVE Set in rigs complex's and connected service loops, set rock washer by rig for maintenance and fin rigging up. NOTE: Rig off highline at 00:30 hrs and back on highline at 11:30 hrs Turnkey inline move. ""Special Note"' The Rig will now go on Summer Maintanace SURFAC Slip and cut 65' of drilling line. NOTE: Accepted rig at 00:01 hrs 19/30/2005 SURFAC Installed riser and hydraulic control lines to diverter, MU turnbuckles ,and knife valve SURFAC 'Loaded pipe shed with BHA and 5" DP and strapped same SURFAC PU and stood back out of pipe shed 10 stds of 5" HWDP and jars then 15 stds of 5" DP SURFAC PU 13 1/2" BHA tools to rig floor SURFAC ,Function tested diverter and Kommey unit, test witnessed by John Crisp ;with AOGCC, added 1 more jt of 16" diverter line to clear flow line manifold (105' total length) SURFAC MU 13 1/2" bit #1 on 8" motor with 1.5 deg bend and 1 std HWDP, RIH and tagged fill inside conductor at 9T SURFAC Flooded conductor checking for leaks and ck ok, pressure tested standpipe and manifold to 3,000 psi SURFAC I Cleaned out conductor from 9T to 108', spudded well and drilled 13 1/2" hole from 108' to 144'. ADT .76 hrs when flowline plugged off SURFAC ,Took apart flowline and unplugged same, loaded with large pieces of ~' cement and gravel SURFAC Drilled 13 1/2" hole from 144' to 219', ADT 1.08 hrs SURFAC 'POOH from 219' to 38' SURFAC MU 13 1/2" BHA #1 with 8" MWD and UBHO sub, oriented and i uploaded MWD, RIH with NMFDC's to 219', RU Gyro SURFAC ;Drilled 13 1/2" hole from 219' to 495' (276') ADT 2.4 hrs SURFAC Ran surface read out gyro at 495', (determined rig team had left out 1 NMFDC out of BHA) SURFAC ~ POOH from 495' to 133', PU additional NMFDC and RIH to 495' SURFAC Drilled 13 1/2" hole from 495' to 525' (30') ADT .3 hrs, drilled with 8-12K ,wob, 60-80 rpm's, 130 spm, 550 gpm at 1,050 psi, off btm torque 1K i ft-Ibs, on btm 1.5K ft-Ibs, rot wt 62K, up wt 60K, do wt 64K SURFAC Ran surface read out gyro's at 444', 344', 244', 144' and 50' SURFAC ',Directionally drilled 13 1/2" hole per directional plan from 525' to 1,458' MD/1 ,427' TVD (933') ART 2.94 hrs, AST 4.45 hrs, 15-25K wob, 80 ,rpm's, 144 spm, 610 gpm, off btm pressure 1,600 psi, on btm 1,800 psi, !off btm torque 2K ft-Ibs, on btm 3.5K ft-Ibs, rot wt 95K, up wt 93K, do wt 93K. NOTE: Took gyro survey's at 617', 709' and 801', took 85 minutes to gyro including RD 12:00 - 19:30 I 7.50! DRILL ',DRLG SURFAC 'Directionally drilled 13 1/2" hole per directional plan from 1,458' to ~ j ~ 12,302' MD/2,201' TVD (844') (10 3/4" Csg Pt.) ART 2.07 hrs, AST 2.95 Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ~ Hours ~ Code ", Code Phase 10/1/2005 ! 12:00 - 19:30 ' 7.50 19:30 - 20:15 ' 0.75 DRILL '~ DRLG I SURFAC DRILL CIRC I SURFAC 20:15 - 22:45 ~ 2.50' DRILL ~~ REAM SURFAC 22:45 - 00:00 1.25 DRILL ' TRIP ~ SURFAC 10/2/2005 I' 00:00 - 01:45 ' 1.75'' DRILL PULD SURFAC 01:45 - 03:15 i 1.50, CASE RURD SURFAC i 03:15 - 03:30 0.25 CASE SFTY ~ SURFAC 03:30 - 08:00 i I ~ 4.50 ~ I i 08:00 - 09:00 .00 CASE RUNC SURFAC j 09:00 - 09:30 ! 0.50 'I 09:30 - 11:00 1.50 1,11:00-13:151 2.25 13:15 - 14:00 ', 0.75 CEMENl~CIRC CEMENT RURD CEMENTCIRC CEMENTPUMP CEMENT DISP SURFAC SURFAC SURFAC SURFAC SURFAC Page 2 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations hrs, 4-20K wob, 80-85 rpm's, while sliding would pump at 147 spm, 625 ,gpm, off btm pressure 1,650 psi, on btm 1,900 psi, while rotating would increase pump rate to 650 gpm at 2,000 psi, off btm torque 2.5K ft-Ibs, on btm 4K ft-Ibs, rot wt 106K, up wt 110K, do wt 102K. No gas hydrates !seen on surface hole. Pumped weighted hi vis sweep and circ out of hole, had 15-20% increase in cuttings back from sweep, circ at 155 spm, 650 gpm at 1,825 psi and 85 rpm's Backreamed out of hole from 2,302' to HWDP at 1,070', BROOH at 85 ~, rpm's, 155 spm, 650 gpm at 1,825 psi, pumped out of hole 3 stds of HWDP to 795' at 530 gpm at 1,200 psi, no problems BROOH Cont to POOH standing back remaining 7 stds of HWDP and jars, POOH to BHA and NMFDC's at 163' Cont. POOH from 163' LD BHA #1, LD 3-NMFDC's, MWD and motor, ~ cleared rig floor RU Doyon's 10 3/4" csg equipment with Franks fill up tool and changed out elevator bales Held PJSM with rig crew and discussed running order and hazards, also discussed operation with new hands and people working in new ,positions ii Ran 10 3/4" csg 2,300' per well plan, MU 10 3/4 Weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker locked btm 3 corm. and pumped thru checking float equipment, cont RIH with 10 3/4" csg and tagged btm at 2,302', RIH with an add 55 jts (58 total) of 10 3/4", 45.5#, L-80, BTC csg, Total ran 2,309', ran 17 bow spring centralizers on 1st 17 jts. No problems RIH, st wt up 130K, down wt 103K Circ btms up thru Franks fill up tool while conditioning mud for cementing, reciprocated pipe 35' and staged pump rate up to 4 bpm at 200 psi RD Franks fill up tool and MU Dowell cement head Fin circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 380 psi, reciprocating pipe 35' with 160K up wt and 105K do wt, circ `and cond mud to 9.2 ppg and lowered PV to 13 and YP to 5, held PJSM on cement job with Dowell, ASRC and rig crew while circ and icond mud. Turned over to Dowell and cemented 10 3!4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and ;pumping Arcticset lead slurry, pumped 370.5 bbls (470 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, !followed with 66 bbls (149 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full returns, shut down and dropped top plug and 'Dowell pumped 5 bbls fresh water then turned over to rig. ~ Rig displaced cement with 206.5 bbls (2045 stks) of 9.2 ppg mud, displaced cmt at 6.5 bpm, initial circ pressure 350 psi, max pressure 640 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1000 psi, held 5 min, checked floats and held, CIP ,14:03 hrs, had full returns during job and had 46.5 bbls of 10.7+ ppg i cmt back to surface, reciprocated csg throught job, st wt up 140K, do ~ wt 100K, cont to tag btm at 2,302' while reciprocating pipe and PU and Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 3 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date 10/2/2005 10/3/2005 From - To ,Hours Code ' Code I Phase ', Description of Operations 16:15 - 17:00 '. 0.75 WELCTL~ EORP 17:00 - 18:30 I 1.50 WELCTU NUND 13:15 - 14:00 0.75 CEMENT` DISP ~ SURFAC landed csg with float shoe at 2,300' and float collar at 2,21 T 14:00 - 14:30 0.50 ~ CEMEN7~RURD SURFAC ' RD Dowell cement head and csg slips 14:30 - 16:15 j 1.75 WELCT~ NUND SURFAC Flushed out diverter and flowline, ND diverter and knife valve, PU on 18:30 - 21:00 21:00 - 00:00 00:00 - 04:15 04:15 - 04:30 04:30 - 05:45 05:45 - 08:30 08:30 - 16:15 2.50 WELCTL EORP 3.00 ~~ RIGMNT RSRV 4.25 WE 0.25' WE 1.25 WE 2.75 WE 7.75 WE EQRP OTHR NUND NUND BOPE 16:15 - 16:30 0.251, DRILL PULD 16:30 - 16:45 ; 0.25' DRILL PULD 16:45 - 17:15 ~ 0.50 RIGMNT' RSRV 17:15 - 20:15 3.00 DRILL PULD 20:15 - 21:00 0.75' DRILL OTHR 21:00 - 21:45 ' 0.75 DRILL ~' PULD 21:45 - 23:00 I 1.25 DRILL TRIP 23:00 - 23:45 ~ 0.75 DRILL I CIRC 23:45 - 00:00 10/4/2005 100:00 - 01:00 01:00 - 02:00 02:00 - 02:45 02:45 - 03:45 03:45 - 12:00 12:00 - 18:45 0.251 CASE RURD 1.00 CASE ; DEOT 1.00 CEMENliDSHO 0.751 DRILL I CIRC 1.00 DRILL I LOT 8.251 DRILL I DRLG 6.751 DRILL iDRLG 'diverter SURFAC PU on csg to 150K and set 10 3/4" emergecy slips with 50K over final :.down wt, made rough cut on csg and set diverter back down, LD landing jt and RD csg elevators and bales SURFAC ~ ND riser, diverter mud cross and conductor mud cross and set out 'diverter SURFAC Made final cut on 10 3/4" csg and welded on Vetco Gray 11" x 5M !wellhead adapter flange SURFAC While waiting on welhead to cool down, installed Totco's revolution counter for K-revs onto top drive and iron roughneck extensions, RU mousehole to PU 5" DP SURFAC PU 35 stds of 5" DP while waiting on 11" x 5M adapter flange to cool down SURFAC Tested weld on adapter flange to 2,000 psi for 10 min and ck ok (80% of collapse) SURFAC 'Oriented and NU Vetco Gray 11" x 5" MB 228 wellhead, tested seals to 5,000 psi for 10 min, good test SURFAC NU 13 5/8" x 5M BOP stack to 13 5/8" x 11" 5M adapter spool, had to adjust bell nipple SURFAC RU and tested BOPE, tested rams, valves, manifold and annular to 250 psi low and 3,000 psi high, tested rams with 4" and 5" DP along with 7 5/8" csg test jts. NOTE: John Crisp W/AOGCC witnessed test SURFAC ::Installed wear bushing SURFAC PU and stood back 3 additional stds of 5" DP SURFAC ;Leveled sub base SURFAC MU 9 7/8" BHA #2 RIH to 171, MU 9 7/8" bit #2 on 6 3/4" motor with 1.5 deg bend, oriented MWD and uploaded same, RIH with 2 NMFDC's and shallow tested MWD, did not get a signal SURFAC ~ Trouble shoot MWD signal, found problem in computer, tool ck'd ok SURFAC Fin MU BHA #2 RIH to 56T, MU 1 add. NMFDC, loaded radioactive sources and RIH with HWDP and jars SURFAC RIH with BHA #2 from 567' to 2,210' (above Flt Collar @ 2,217') SURFAC . Circ hole for casing test evening MW in and out at 9.4 ppg, circ at 550 gpm at 1,275 psi, 25 rpm's, 4-6Kft-Ibs off btm torque, rot wt 90K, up wt 98K, do wt 85K SURFAC RU to test 10 3/4" csg SURFAC ~ Tested 10 3/4" csg to 3,000 psi for 30 min, good test SURFAC ~! Drilled out float collar at 2,21 T, shoe track and float shoe at 2,300', cleaned out to TD at 2,302', drilled 20' of new formation to 2,322', drilled out at 10-12K wob, 30 rpm's, 454 gpm at 1,100 psi, rot wt 90K, up wt ' 98K, do wt 85K SURFAC Displaced out spud mud with re-conditioned 9.0 ppg mud, evened MW in and out at 9.0 ppg, circ hole at 454 gpm at 1,100 psi SURFAC ~ RU and performed LOT to 14.7 ppg EMW, 650 psi at 2,201' TVD with 19.0 ppg MW INTRM1 'Directionally Drilled 9 7/8" hole from 2,322' to 3,126' MD/2,976' TVD, (804'), ART 1.99 hrs, AST 3.72 hrs, 4-17K wob, 70-75 rpm's, 141 spm, ':598 gpm, off btm pressure 1,600 psi, on btm pressure 1,700 psi, off ~ btm torque 2-6K ft-Ibs, on btm 4-5K, rot wt 107K, up wt 117K, do wt 96K INTRM1 .Directionally drilled 9 7/8" hole from 3,126' to 3,816' MD/ 3,384' TVD, Printed: 12/9/2005 3:20:17 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code ;Code I, 10/4/2005 12:00 - 18:45 i 18:45 - 19:15 6.75 DRILL DRLG 0.50 RIGMNT RSRV ' ,19:15 - 00:00 ~ 4.75 ~ DRILL DRLG ~ 10/5/2005 100:00 - 12:00 12.00 12:00 - 14:45 2.75 ~ 14:45 - 16:30 ~ 1.75 16:30 - 18:30 ' 2.00 18:30 - 19:00 0.50 19:00 - 20:45 1.75 20:45 - 22:15 ! 1.50 22:15 - 00:00 , 1.75 10!6/2005 00:00 - 00:45 ! 0.75 00:45 - 01:15 0.50 01:15 - 02:45 I~ 1.50 02:45 -04:15 1.50 ' 04:15 - 04:30 0.25 04:30 - 05:45 ' 1.25 05:45 - 06:00 ' 0.25 06:00 - 06:45 0.75 DRILL DRLG DRILL DRLG DRILL ;CIRC DRILL !REAM DRILL I CIRC DRILL ~ REAM DRILL CIRC DRILL ~ TRIP DRILL PULD DRILL PULD DRILL I PULD DRILL PULD DRILL PULD CASE IRURD Phase INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRMI INTRMI INTRM1 INTRMI INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 I NTRM 1 INTRMI CASE SFTY INTRM1 CASE RUNC I INTRM1 Page 4 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations i _ _ _ _ _ ____ -__ (690') ART 2.37 hrs, AST 2.69 hrs Removed turnbuckle assembly used for centering of top drive torque tube, bolt on turnbuckle was snagging top drive blower duct work Directionally Drilled 9 718" hole from 3,816' to 4,102' MD/3,447' TVD, (286'), ART 1.39 hrs, AST 3.28 hrs, 4-20K wob, 80 rpm's, while sliding pumped at 600 gpm and while rotating circ at 650 gpm, off btm pressure 2,050 psi, on btm pressure 2,200 psi, off btm torque 4-7K tt-Ibs, on btm 5-6K, rot wt 107K, up wt 117K, do wt 98K, ave BGG 30 !units, max gas 137 units, 9.05 ppg MW, ave ECD 10.0 ppg Directionally Drilled 9 7/8" hole from 4,102' to 4,871' MD/3,604' TVD, (769'), ART 6.3 hrs, AST 3.01 hrs, 7-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm ;torque 4-7K tt-Ibs, on btm 5-6K, rot wt 106K, up wt 120K, do wt 96K, ave BGG 75 units, max gas 501 units, 9.2 ppg MW, ave ECD 10.2 ppg, ,pumped wt'd hi vis sweep at 4,102' with 10% increase in cuttings back from sweep Directionally Drilled 9 7/8" hole from 4,871' to 5,172' MD/3,651' TVD, (301'), (7 5/8" Csg Pt.) ART 1.45 hrs, AST .33 hrs, 10-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,250 psi, on btm pressure 2,400 psi, off btm torque 3-7K ft-Ibs, on btm 5-6K, rot wt 106K, up wt 124K, do wt 96K, ave BGG 100 units, max gas 433 units, 9.3 ppg MW, ave ECD 10.4 ppg Pumped weighted hi vis sweep and circ hole clean while geologist evaluated logs, geologist and town ok'd 5,172' as 7 5/8" csg pt. circ hole at 650 gpm, 2,300 psi, 80 rpm's with 4-5K ft-Ibs off btm torque, had no increase in cuttings back from sweep and circ a total of 3x btms up Monitored well-static, backreamed out of hole from 5,172' to 3,915', pumped weighted hi vis sweep on last std, BROOH at 80 rpm's, 153 spm, 650 gpm 2,250 psi Fin circ out sweep and had 100% increase in cuttings back from sweep, decided to cont BROOH to 10 3/4" csg shoe Cont to BROOH from 3,915' to inside 10 3/4" shoe to 2,285', BROOH at 80 rpm's, 650 gpm at 1,850 psi, BROOH at 20-25'/min at 35-40'/min would attempt to pack-off, no other problems BROOH Pumped weighted hi vis sweep at 2,285' and circ out of hole, had 50% increase in cuttings back from sweep, mainly silver dollar sized clay patties, mixed and pumped 2nd sweep and shakers were clean, circ sweep out of hole and had a 10% increase in cuttings, circ an add. btms up and shakers were clean, circ hole at 600 gpm at 1,825 psi and 80 rpm's, rot wt 95K up wt 97K, do wt 90K, 9.3 ppg MW Monitored well-static, POOH from 2,285' wet 5 stds and hole took talc fill, pumped dry job and cunt POOH to BHA #2 at 56T POOH from 567' to 140', POOH LD 11 jts of 5" HWDP and jars, LD 1-NMFDC Held PJSM and removed radioactive sources, POOH to 78' LD 2-NMFDC's Downloaded MWD Fin POOH from 78' LD BHA #2, MWD/LWD and motor, cleared rig floor Pulled wear bushing RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool, changed oul elevator bales .Held PJSM with rig crew and tong operator on running of 7 5/8" csg Ran 7 5/8" Csg to 21 T, MU 7 5/8" Weatherford float shoe, 2 jts 7 5/8", Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 16:00 - 17:00 Date From - To ~, Hours ' Code, Code 'I Phase 10/6/2005 ' 06:00 - 06:45 ~ 0.75 CASE ~ RUNC INTRM1 .06:45 - 07:45 ; 1.00 RIGMNT~ RGRP INTRM1 07:45 - 10:30 2.75 CASE RUNC INTRMI 10:30 - 10:45 0.25, CASE CIRC INTRM1 I 'I 10:45 - 13:45 ~ 3.00 CASE i RUNC INTRM1 13:45 - 14:15 . 0.50 14:15 - 15:00 , 0.75 15:00 - 16:00 ~I 1.00 10/7/2005 17:00 - 17:45 17:45 - 18:00 18:00 - 19:00 19:00 - 20:45 1 J-154 1 J-154 ROT -DRILLING n 1334@ppco.com Doyon 141 1.00 0.75'; CEMENT 'CIRC INTRM1 'RURD INTRMI }CIRC :INTRMI PUMP INTRMI IDISP INTRM1 0.25 CEMEN RURD INTRM1 1.00 CASE NUND INTRM1 1.75, CASE OTHR INTRMI 20:45 - 21:15 ! 0.50 CASE NUND 21:15 - 21:30 0.25 ! CASE i DEOT 21:30 - 21:45 25 ` 0 DRILL ' PULD 21:45 - 22:45 , . 1.00 CMPLTN OTHR 22:45 - 23:30 0.751 CMPLTN, OTHR 23:30 - 00:00 0.501 DRILL PULD 00:00 - 06:00 6.00 DRILL I PULD INTRMI INTRMI INTRM1 INTRMI INTRM1 I NTRM 1 INTRMI Page 5 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 conn, circ thru float equip and ck ok, RIH with 2 add jts csg to 217' and had problems with the pipe skate Repaired pipe skate, cable on traveling drum had gotten crossed Cont RIH with 7 5/8" csg from 217' to 2,278', (9 5/8" csg shoe at 2,300') Circ btms up at 2,278', circ at 5 bpm at 320 psi, st wt up 100K, do wt 86K Fin RIH with 7 5/8" csg from 2,278' and tagged btm at 5, 172', no problems RIH to btm, ran a total of 121 jts and 2-pup jts of 7 5/8", 29.7#, L-80, BTCM csg, total RIH including float equipment 5,165', ran 60 tandem rise centralizers on 1st 62 jts, 1st 3 over stops, the remaining over collars, did not run any centralizers on both window jts, st wt up 164K, do wt 102K Circ btms up thru Franks fill up tool while conditioning mud for cementing, staged pump rate up to 6.5 bpm at 525 psi, st wt up 145K, do wt 95K RD Franks fill up tool and MU Dowell's cement head Fin circ and cond mud for cementing, circ at 6.5 bpm at 375 psi, st wt up 165K, do 105K, initial MW out, 9.4 ppg, 66 vis, PV 18, YP 27, Conditioned mud to final MW of 9.05 ppg, 38 vis, 10 YP and 13 PV, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementing csg while circ hole Dowell pumped 5 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 35 add. bbls of CW 100 at rate of 5 bpm @ 320 psi, Pumped 40 bbls of MudPush at 10.5 ppg at rate of 4.6 bpm @ 160 psi, Dropped btm plug then pumped 144.2 bbls, (360 sxs - 25% over caliper} of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 330 psi, Reciprocated pipe with full returns. Drop top plug and Dowell kicked top plug out with 5 bbls fresh water. Rig displaced cement with 9.0 ppg OBM, Bumped plug on talc displacement after pumping 229.4 bbls OBM (Total of 234.4 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Max pressure 1050 psi, Slowed pump rate to 3 bpm (650 psi) with 10 bbls left to pump and bumped plug to 1150 psi, ck floats and held. CIP at 17:35 hrs, 10-6-05. Reciprocated pipe until 134 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 5165.00', Float Collar @ 5075', Calc TOC @ 2529', Had full returns thru out job with a trace of CW 100 back at surface. Well static after shut down. RD cement head ND Btm flange on BOP stack and lifted up same Installed 10 3/4" csg slips, set slips with 75K st wt, cut off csg and LD cut offjt and installed pack-off NU BOP stack Tested 7 5/8" pack-off to 3,500 psi for 10 min, good test Installed wear bushing RU on 10 3/4" x 7 5/8" annulus and performed Infectivity test /LOT to 13.8 ppg EMW, assuming 9.0 ppg MW at 2,201' TVD and 550 psi Began to flush 10 3!4" x 7 518" annulus, pumped 40 bbls water, ave 1 bpm at 850 psi Held PJSM and began LD 5" HWDP derrick LD 6 stds of HWDP and 53 stds of 5" DP down out of derrick thru Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 6 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To ', Hours ' Code , Code f Phase 10/7/2005 00:00 - 06:00 ~!, 6.00' DRILL PULD INTRM1 06:00 - 07:30 i 1.50 DRILL i RIRD i INTRM1 07:30 - 10:15 ~ 2.75' DRILL OTHR INTRM1 10:15 - 11:30 1.25 RIGMNT RSRV INTRM1 11:30 - 12:00 0.50 ~ WELCT BOPE INTRM1 12:00 - 12:15 0.25. DRILL SFTY INTRM1 12:15 - 17:15 5.001 DRILL PULD , INTRM1 17:15 - 20:30 3.25 20:30 - 00:00 3.50 10/8!2005 1 00:00 - 01:30 1.50 01:30 - 02:00 0.50 02:00 - 05:30 3.50 05:30 - 09:45 ' 4.25 09:45 - 10:15 0.50 DRILL I PULD ' INTRM1 DRILL ,PULD : INTRM1 DRILL PULD INTRM1 DRILL , PULD ~ INTRM1 DRILL PULD INTRM1 DRILL TRIP INTRMI DRILL I CIRC INTRMI 10:15 - 12:00 1.751 CASE ' DEOT ' INTRM1 12:00 - 14:30 2.50. CEMENlf DSHO INTRM1 14:30 - 15:00 10/9/2005 15:00 - 15:30 0.50 DRILL ICIRC 0.501 DRILL LOT 15:30 - 00:00 ' 8.50 I DRILL I DRLG 00:00 - 12:00 ; 12.00 i DRILL DRLG INTRMI INTRM1 PROD PROD 12:00 - 00:00 I 12.00; DRILL DRLG I PROD Description of Operations mousehole , at 01:45 hrs, 2 hrs from initial 40 bbl water flush, pumped an additional 10 bbls of water down 10 3/4" x 7 5/8" annulus at 1.5 bpm at 850 psi RU Sperry Sun's Geo-Span unit on rig floor, At 06:15 hrs (12.75 hrs after bumping plug) finished flushing annulus with 100 bbls of water, ave 2 bpm, max pressure 900 psi, ave 825 psi, flushed annulus with 154 bbls water total Changed over top drive saver sub to 4" XT-39 Slip and cut 38' of drilling line, serviced top drive and drawworks Tested 4" floor valve and dart valve to 250 psi low and 3,000 psi high, 1st dart valve test failed, tested back-up dart valve and tested ok Held PJSM on PU DP and installing Lo-Tads RIH with 90 jts of 4" DP, POOH installing 30 Lo-tads. At 13:30 RU little Red on 10 3/4" x 7 5/8" annulus and freeze protected same with 80 bbls diesel, ave 1 bpm at 1,050 psi. Strapped and stood back 6 stds of hybrid push pipe with 2-4 3/4" Dc's and 1 HWDP on top, then PU and stood back 7 stds of 4" HWDP PU out of pipe shed 138 jts of 4" DP and RIH, preparing to POOH & stand back same POOH and stood back 46 stds of 4" DP PU 6 3/4" BHA to rig floor MU 6 3/4" BHA #3 and RIH to 369', MU 6 3/4" bit#3 with 4 3/4" model 5200 Geo-pilot and MWD, uploaded MWD and RIH PU 3-NMFDC's, HWDP and jars, shallow tested MWD and broke in Geo-pilot RIH with BHA #3 from 369' PU 4" DP, PU 147 jts of DP RIH to 5,034' Circ btms up at 5,034', circ at 327 gpm at 2,800 psi, st wt up 96K, do wt 73K RU and tested 7 5/8" csg to 3,000 psi for 30 min, pressure bled down 130 psi in 30 min, bled off pressure and re-pressured up to 3,050 psi and held for 15 min and held ok Drilled out float collar at 5,075', shoe track and float collar at 5,165', cleaned out to TD at 5,172' then drilled 20' of new formation to 5,192', drilled out at 2-10K wob, 90 rpm's, 70 spm, 248 gpm, 1,850 psi Circ btms up for LOT, circ at 320 gpm at 2,900 psi, 90 rpm's and 4K ft-Ibs torque, rot wt 85K, up wt 97K, do wt 72K, 8.9 ppg MOBM MW in & out with 10.0 ppg clean hole ECD Performed LOT to 13.6 ppg EMW, 900 psi at 3,649' TVD with 8.9 ppg MOBM Directionally drilled 6 3/4" ho{e in A2 sand lateral with Geo-pilot assembly from 5,192' to 5,769' MD/3,652' TVD (577') ART 6.29 hrs, 4-10K wob, 120 rpm's, 84 spm, 300 gpm, off btm pressure 2,500 psi, on btm 2,600 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt 82K up wt 97K, do wt 68K, 8.95 ppg MOBM, ave ECD 9.9 ppg, ave BGG 25 units, max gas 66 units, drilled thru 8 concretions for a total of 50' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 5,769' to 7,043' MD/3,636' TVD (1,274') ADT 8.59 hrs, 5-15K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 81 K up wt 108K, do wt 62K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 25 units, max gas 118 units, drilled thru 10 concretions for a total of 80' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 7 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To 'Hours , Code Code i Phase 10/9/2005 112:00 - 00:00 ~, 12.0011 DRILL DRLG PROD 10/10/2005 100:00 - 07:00 07:00 - 07:30 07:30 - 08:00 08:00 - 09:30 i 09:30 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 19:30 ' 19:30 - 20:15 20:15 - 00:00 10/11/2005 00:00 - 00:30 .00:30 - 01:00 .01:00 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 03:45 7.00' DRILL i DRLG 0.50 DRILL CIRC 0.50 DRILL ~ DRLG 1.50 ~ DRILL i CIRC 5.50 ~I DRILL REAM PROD PROD PROD PROD PROD 1.00 DRILL CIRC PROD i 2.00 DRILL TRIP PROD 1.50 DRILL ~ CIRC PROD 0.75', DRILL CIRC PROD 3.75 ~ DRILL TRIP ~ PROD 0.50 DRILL 0.50; DRILL I 1.001 DRILL 1.001 DRILL TRIP 'PROD PULD (PROD PULD 'PROD PULD .PROD 0.50' DRILL 0.25 LOG PULD I~CMPLTN SFTY CMPLTN Description of Operations assembly from 7,043' to 8,321' MD/3,635' TVD (1,278') ADT 8.46 hrs, 4-10K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,125 psi, on btm 3,150 psi, off btm torque 5.5K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 80K up wt 110K, do wt 54K, 9.0 ppg MOBM, ave ECD 11.15 ppg, ave BGG 30 units, max gas 97 units, pumped weighted hi vis sweeps at 7,650' with a 50% increase in cuttings and 7,837' with 25% increase in 'cuttings Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot 'assembly from 8,321' to 8,997' MD/3,642' TVD (671') ADT 5.12 hrs, 5-12K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,150 psi, ' on btm 3,200 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 82K up wt 120K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.25 ppg, ave BGG ,i 30 units, max gas 76 units, pumped weighted hi vis sweep at 8,415' with a 10% increase in cuttings Trouble shoot problem with MWD computer, reboot same and ck ok Directionally drilled 6 3/4" hole from 8,997' to 9,063' MD/3,643' TVD (66') ADT .36 hrs, determined to have crossed fault at 8,370' and zone below fault was wet, decision was made to stop drilling on A2 lateral Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ at 330 gpm, 3,200 psi and 130 rpm's, rot wt 83K up wt 120K, do wt 55K, .monitored well-static Backreamed out of hole from 9,063' to to 5,130' (7 5/8" shoe @ 5,165') BROOH at 130 rpm's, 330 gpm, initial circ pressure 3,200 psi, final circ i pressure 2,800 psi, no problems BROOH to 5,130' rot wt 83K, up wt 110K, do wt 60K Pumped 35 bbl weighted hi vis sweep and circ hole clean at 5,130', had 5% increase in cuttings back from sweep, circ at 330 gpm, 2,550 psi 'and 130 rpm's with 3.5K ft-Ibs torque, circ 3X btms up and was clean at shakers, monitored well-static RIH from 5,103' to 9,000', washed 63' to btm at 9,063' with no problems Pumped weighted hi vis sweep and circ out of hole, had no increase in ,cuttings back from sweep and was clean at shakers, circ at 330 gpm, 3,200 psi, 130 rpm's with 5.5K ft-Ibs torque ,Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 330 gpm at 3,350 psi, 130 rpm's and 5.5K ft-Ibs torque, rot wt 85K, up wt 117K, do wt 57K gpm, monitored well-static POOH wet from 9,063' to 1,768', POOH 5 stds and hole took calc fill, dropped 1 7/8" rabbit on a wire and cont POOH to 1,768' Continue POOH from 1768' - 368' (1400'). POOH, breakout & lay down BHA. Rack Back HWDP with Jars and ' NMDC's. Download MWD assembly. Continue lay down 6 3!4" PDC Security FSF2641 bit w! .5591 restrictor (1.26') TFA = 1.015 Sq In, 4 3/4" 5200 Geo-Pilot (16.20'), GP Non-Mag Flex Pony Collar (11.54'), DM Collar (8.56'), 4 3/4" Smart Stabilizer 3.59'), 4 3/4" Slimphase 4 with DGR & EWR Phase (24.16'), PWD collar (10.76'), TM HOC (11.12'), Non-Mag Float sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'), 3 -Non Mag Flex drill collars (92.76'), ~ Crossover sub (1.07'), 2 -stands of 4" HWDP with jars (180.27'). Bit Gaugedat1/1/CT/G/0/I/EClTD !Clean Floor area, and lay down tools at beaver slide. Held PJSM with crew and Schlumberger hands. Discuss Safety and wireline PU/LD procedures. Printed: 12/92005 3:20:17 PM ConocoPhillips Alaska Page. 8 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours ' Code 'Sub ~"Code Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Spud Date: 9/30/2005 End: 10/31/2005 Group: 10/11 /2005 ~ 03:45 - 06:00 ~ 2.25 ~ LOG PULD 06:00 - 07:30 I 1.501 LOG I ELOG 07:30 - 12:00 4.50 LOG ELOG i 12:00 - 14:30 2.50; LOG OTHR ,14:30 - 15:00 0.50, LOG OTHR 15:00 -15:30 0.50 LOG ELOG 15:30 - 16:30 , 1.001 LOG ELOG i 16:30 - 17:00 0.50 LOG ELOG 17:00 - 18:00 1.00 LOG ELOG ' 18:00 - 00:00 6.00; LOG ELOG 10/12/2005 00:00 - 01:00 ' 1.00 LOG ELOG 01:00 - 01:30 0.50 LOG ELOG i 01:30 - 02:00 0.50 LOG ELOG 02:00 - 02:45 0.75 LOG ELOG ' 02:45 - 03:45 1.00 ~ LOG ELOG 03:45 - 05:00 I 1.25 LOG ELOG 05:00 - 06:30 ' 1.50' LOG ELOG 06:30 - 09:15 2.75 LOG ELOG 09:15 - 11:15 ; 2.00 ~ LOG ELOG 11:15 - 12:00 ' 0.75 CASE RURD 12:00 - 15:00 3.00 {CASE I RUNC 15:00 - 16:00 1.00 CASE ,RUNC i i ~ 16:00 - 19:30 3.50; CASE !RUNL 19:30 - 20:15 i 0.75 CASE 'RUNL Phase ' Description of Operations CMPLTN Rig up Schlumberger wireliners, and equipment. Pull tools to rig floor and make up same. CMPLTN Wireline in hole with USIT bond logging tools on Welltec tractor, to 4000' where observed tractor failure. Communication through tractor 'failed to logging tools. Could not "start" tractor. CMPLTN POOH with USIT logging tools and tractor. Lay down tractor and tools, and trouble shoot problem. Note: Make a trip in to Deadhorse to retrieve test cable. CMPLTN Continue troubleshoot Welltec tractor problem. Suspect oil viscosity not correct and observe burnt head. Install correct oil, and change head. CMPLTN Make up USIT bond logging tools with Welltec tractor. Perform surface !test and tools tested good. CMPLTN WLIH with tools and tractor to 5051'. Turn on Logging tools, all OK. CMPLTN ,Attempt to log from 5051' to 4010' (1041'), Tools failed (No log 'acquired). CMPLTN Unable to get Logging tools to work, trouble shoot and attempt to gain .communication. CMPLTN WLOH from 4010' to surface. Breakout and lay down tools. CMPLTN Change out transducer. Trouble shoot tractor. Observed wires were "damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. CMPLTN Continue change out transducer. Trouble shoot tractor. Observed wires were damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. CMPLTN PJSM with crew. Discuss Safety and handling procedures. Pull Well Tech tractor to rig floor. MU on wireline USIT logging tools and surface 'test same. Good test. CMPLTN WLIH from surface to 1700'. Observe tool failure. No Communication through tractor. CMPLTN WLOH, breakout & lay down Well Tech Tractor. CMPLTN Prep Schlumberger Tractor. CMPLTN .Pull tractor to floor and MU to E-Line tools. Surface test same. Good Test. CMPLTN WLIH to 5055' WLM. Tractor working fine. CMPLTN Locate 8~ perform USIT Bon Log from 5050' - 2200' (2850'). CMPLTN WLOH to surface, breakout & lay down E-Line USIT logging tools. CMPLTN I Rig up Liner running equipment, slips, power tongs etc... CMPLTN Make up 4 1/2" joint (30.83') blanked off on end with crossover (2.03') and Swell Packer with pups (19.55'), and crossover (2.07'). Pick up 4 1/2 slotted /blank liner assembly, RIH to 3610'. Run total of 57 blank joints, 59 slotted joints with a total of 7 constrictor packers spaced out to be at 7815', 7484', 7035', 6885', 6425', 6135', and 5415'. CMPLTN Make up 4 3/4" Casing Seal Bore Ext. and Crossover Bushing with ;pups (24.83'), Flexlock Liner Hanger 5.5" x 7.6" (9.82'), 5 1/2" "RS" packoff Seal Nipple (2.85'), and "HRD" ZXP Liner top Packer (19.05'), with Liner Running Tool and XO (11.04'). Add PAL mix as per BOT Rep. CMPLTN RIH with 4 1/2" Liner assembly on 4" DP from 3673' - 8125' {4452') ;with SLM, and 1 7/8" Drift in Drill Pipe. PU WT = 120K, SO WT = $OK. CMPLTN I Locate bottom of liner at 8126', drop b1 7/16" Ball, alloow to fall and 'pump down at 35 SPM, 375 PSI, until observed ball seated. Pressure up to 1300 PSI, set Liner Hanger, and continue Pressure up to 4000 Printed: 1219!2005 3:20:17 PM • ConocoPhillips Alaska Page 9 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date ,From - To ~ Hours !Code Code ~ Phase 10/12/2005 ~ 19:30 - 20:15 0.75 i CASE ~ RUNL CMPLTN f 20:15 - 21:00 0.75 21:00 - 21:30 0.50 21:30 - 23:30 2.00 23:30 - 00:00 ~ 0.50 10/13/2005 00:00 - 00:30 00:30 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 07:15 07:15 - 08:15 08:15 - 09:15 0.50 2.50 1.00 0.50 0.25 2.50 1.00 1.00 09:15 - 09:45 I 0.50 09:45 - 12:00 2.25 12:00 - 14:45 2.75 14:45 - 15:45 I 1.00 15:45 - 18:30 2.75 18:30 - 20:00 ~ 1.50 CASE !RUNG CMPLTN CASE ! CIRC I, CMPLTN CASE RUNG ; CMPLTN CASE RUNG CMPLTN WINDOVjlPULD I PROD2 WINDOV'iIPULD ~PROD2 P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 tC I~ PROD2 JVP PROD2 JVP PROD2 JVP I PROD2 IP ~, PROD2 LD PROD2 Description of Operations PSI to set ZXP PKR. Observe "bobble" on weight indicator at 3500 PSI. Bleed pressure. Rig up to test. Pump down annulus to pressure test to 1000 PSI for 10 minutes. Good test. All pressures and test recorded on chart. Pult out of ZXP PKR to allow "dogs" to kick out and Slack off to verify Top of Liner at 4464' DPM. Repeat. PU WT = 105K, SO WT = 90K. Pull out of Liner assembly with setting tools and CBU at 83 SPM - 1400 PSI. Monitor well -Static. POOH from 4394' - 15'. Observe well taking proper fill. Breakout & lay down running tool. Inspect seals and breaks, all looked good as per BOT rep. Clean floor area, Pull tools to rig floor. Held PJSM. Discuss Safety and Whipstock assembly make up procedure. Make up 7 5/8" Whipstock assmy. MU 5 11/16" Seal assmy with No-Go Locator Sub (4.76'), 4 5/8" Unloader sub (5.19'), 3 - 3 1/2" IF pup joints (4.72', 6.52', 16.46'), 1 -jnt 3 1/2 DP (31.21'), Blanking sub (1.28'), 7 5/8" Bottom Trip Anchor (3.23'), 4 5/8" Shear Disconnect Sub (2.69'), 4 3i4" Ported drain Sub (1.47'), 4 11/16" Debris Barrier sub with cup (1.86'), & 5/8" Whipstock Slide (14.42'), 6.156" Starting Mill (1.08'), 6.30" Lower Mill (5.46'), 6 3/4" Upper Milf (5.81'), 1 - jnt 3 1/2" HWDP (29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly (43.43'), 2 - 4 3!4" Bumper Jars (7.85', 7.86' ), 4 3/4" Crossover. Install 35K shear Bolt on starting mill. BTA shear setting = 14K. Plug In & Upload MWD assembly. Make up remaining BHA. PU 2 -stands Hybrid Push Pipe (178.98). Total BHA = 378.57. Screw into string with TD, and perform Sha{low pulse test. Good test. 300 GPM's - 1000 PSI. Trip in hole with whipstock assembly from 378' - 3622' (3244') at 2 minutes per stand as per BOT rep. PU WT = 92K, SO WT = 82K Perform MAD PASS log from 3622' - 3822 ' (200') @ 240' FT/HR Continue TIH from 3822' -4465' (643'). Orient Whipstock Face as per DD and Co. Rep to 10 Degrees Left of High Side. Slack off and tag Top of Liner with Seals @ 4465' DPM. Set BTA, and verify set by pulling 10K over up weight. Slack off and shear bolt @ 35K down weight. Pull to Neutral position and obtain free rotation. PU WT = 104K, SO WT = 87K, ROT WT = 82K, TO = 2-5K. Displace well from 9.0 PPG SFMOBM to 9.0 PPG MOBM @ 300 GPM's - 2100 PSI. Mill window from 4374' - 4381', @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mud Wt = 8.9 PPG, Visc = 74 and YP = 16 Continue mill window from 4381'- 4386'. Continue mill in open hole to 4416' allowing 20' of gauged hole out of bottom of window, @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mill 12' WINDOW IN 4.93 HRS for an avg ROP of 4.36 FTlHR Pump Hi Visc sweep @ 4416'. Circulate out while working mills through window until clean. Window looked good. Monitor well -static. Pump dry job. Pooh from 4416' - 378' (4038'). Breakout & lay down Milling BHA. Lay down 6.156" Starting Mill (1.08'), 6.30" Lower Mill (5.46'), 6 3/4" Upper Mill (5.81'), 1 -jnt 3 1/2" HWDP 29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly 43.43'), 2 - 4 3/4" Bumper Jars (7.85', 7.86' ), 4 3/4" Crossover. Gauge Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code ! Code I Phase 10/13/2005 18:30 - 20:00 20:00 - 20:15 20:15 - 20:45 20:45 - 00:00 10!14/2005 j 00:00 - 01:00 1.501 WINDOWPULD 0.25 WINDO~THR 0.50 WINDO THR 3.25 ~ WELCTLi BOPE PROD2 PROD2 PROD2 PROD2 1.00 WELCTL~ BOPE PROD2 01:00 - 01:30 0.50 WELCT BOPE PROD2 01:30 - 02:45 i 1.25 DRILL PULD I PROD2 02:45 - 03:30 0.75 ~ DRILL ' OTHR ' PROD2 03:30 - 04:30 1.00 DRILL OTHR PROD2 04:30 - 06:15 1.75' DRILL TRIP PROD2 06:15 - 06:45 ~ 0.50; DRILL ( TRIP PROD2 06:45 - 12:00 12:00 - 00:00 5.25!, DRILL j DRLG PROD2 12.001 DRILL ';DRLG I PROD2 Page 10 of 21 Spud Date: 9/30/2005 Start: 9!30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of_Operations --_ _ __ - _ Upper mlll to full gauge of 6 3/4". 'BOLDS and pull wear bushing. Make up stack washing tool and flush stack. Rig down same. j Install test plug. Test BOP stack and all choke manifold valves, Upper & lower IBOP on TD, HCR -, Choke and Kill, Manual Choke and Kill, Dart valve and floor safety valve. Perform Accumulator function test to 3:47 Minutes. All test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived ;witness of test. Chuck Sheave. Continue Perform Accumulator function test to recovery of 3:47 .Minutes. Test Annular, and Blind rams. All test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived witness of test. Chuck Sheave. Rig Down test equipment, Install Wear Bushing, RILDS PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA. Pull tools to floor. Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor (32.50'), 4 3/4" 'Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer (5.24'), DM HOC (8.49'), Slimphase 4 w/ DGR ~ RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'), 3 - 4 3/4" Non Mag Flex Drill Collars 92.76'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.13'), 4 3/4" Drilling jars (177.63 Hrs on 10/10/05) (28.90'), 4 - Jnts 4" HWDP 121.24'). Total BHA length = 369.32'. ,Plug in and upload MWD assembly. 'RIH & RU. Perform Shallow pulse test @ 86 SPM, 305 GPM's - 1700 PSI. !Trip in hole from 369' - 4290' (3921'). Orient bit & motor to High side 'above top of window area @ 4374'. Work 6 3/4" Bit and drilling assembly through window area from 4374' !to 4386' DPM. Observed tag at 9' down whipstock to take 8K in downweight. Pull up above window, RIH to observe little or no tag and continue in through window to open hole depth at 4400'. Suspect cement chunks on slide. Wash down from 4400' - 4416' (16'). PU WT = 91 K, SO WT = 75K. Baker rep on floor to witness Drilling assembly through whipstock. Directional drill 6 3/4" Hole from 4416' - 4508' MD (92'). TVD = 3514'. +ART = 1.94 HRS, AST = 2.64 HRS, ADT = 4.58 HRS. PU WT = 93K, SO WT = 72K, ROT WT = 81 K, Torque off btm = 3K, Torque on bottom = 4K. WOB = 2-10K, RPM's = 80, Pumps @ 85 SPM, 300 GPM's - 2300 PSI. Total Jar Hrs = 182.21. Total Bit Hrs = 4.58. Clean hole ECD at 9.8 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4400' MD, 3514' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 590 PSI. Pump #2 - 25 SPM - 430 PSI, 35 SPM - 650 PSI. Observed Drilling !through Concretion at 4453' - 4501' (48'). Continue Directional drill 6 3/4" Hole from 4508' - 5224' MD (716'). ND = 3516'. ART = 3.14 HRS, AST = 2.74 HRS, ADT = 5.88 HRS. PU WT = 100K, SO WT = 64K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-10K, RPM's = 80, Pumps @ 93 SPM, 330 I GPM's - 2300 PSI. Total Jar Hrs = 188.09. Total Bit Hrs = 10.45 ECD at 9.3 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 5029' MD, 3524' TVD. Pump #1 - 20 SPM - 360 PSI, 30 SPM -540 PSI. ~ Pump #2 - 20 SPM - 400 PSI, 30 SPM - 560 PSI. Observed Drilling Printed: 1219!2005 3:20:17 PM • ConocoPhillips Alaska Page 11 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To '..Hours Code Sub j Phase Description of Operations ''Code _ _ _ 10!14/2005 ~ 12:00 - 00:00 ~_ _ _ ___ - - __ _ _ -_ - - _._ _ - __ -. __ -- 12.00 ~ DRILL DRLG ~' PROD2 ~ through Concretions at 4602' - 44614' (12'), 4618' - 4628' (10'), 4633'-4640' (T), 5223' - 5231' (8'), 5236' - 5248' (12'), 5259' - 5268' 9'). Encountered Faun @ 4697 MD, with a 12' down throw. 10/15/2005 ~ 00:00 - 12:00 ' 12.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole from 5224' - 6130 MD (906'). TVD = 3501'. ART = 5.65 HRS, AST = 1.94 HRS, ADT = 7.59 HRS. PU WT = 105K, SO WT = 62K, ROT WT = 80K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-10K, RPM's = 80, Pumps @ 93 SPM, 330 i ~ GPM's - 2800 PSI. Total Jar Hrs = 195.68. Total Bit Hrs = 18.65 ECD at 10.2 PPG. Mud WT = 8.9 PPG Viscosity = 77, YP = 19. SPR's @ 5968' MD, 3512' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 580 PSI. Pump #2 - 25 SPM - 520 PSI, 35 SPM - 610 PSI. Observed Drilling i through no Concretions this tour. Survey @ 6014' MD ,'3506 TVD -Inc = 92.8 Deg. AZ = 176 Deg. ~' 12:00 - 00:00 ; 12.00 ~ DRILL ;DRLG ~ PROD2 'Continue Directional drill 6 3/4" Hole from 6130' - 7187 MD (1057). TVD = 3482'. ART = 6.77 HRS, AST = .47 HRS, ADT = 7.24 HRS. PU WT = 105K, SO WT = 60K, ROT WT = 83K, Torque off btm = 5K, ' Torque on bottom = 5K. WOB = 2-5K, RPM's = 80, Pumps @ 86 SPM, `302 GPM's - 2700 PSI. Total Jar Hrs = 202.92 Total Bit Hrs = 25.29 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 67, YP = 19. SPR's @ 6949' MD, 3484' TVD. Pump #1 - 25 SPM - 450 PSi, 35 SPM - 640 PSI. Pump #2 - 25 SPM - 480 PSI, 35 SPM - 690 PSI. Observed Drilling through concretions @ 7099' - 7110' (11'). Survey @ 7043' MD 3484 TVD -Inc = 91.1 Deg. AZ = 180 Deg. 10/16/2005 :00:00 - 07:45 7.75 DRILL DRLG ; PROD2 l Continue Directional drill 6 3!4" Hole from 718T - 7691' MD (504'). TVD = 3472'. ART = 4.4 HRS, AST = .97 HRS, ADT = 5.37 HRS. PU WT = 106K, SO WT = 56K, ROT WT = 80K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-18K, RPM's = 80, Pumps @ 86 SPM, 302 i GPM's - 2700 PSI. Total Jar Hrs = 208.29 Total Bit Hrs = 30.66 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 19. SPR's @ 7641' MD, 3474' TVD. Pump #1 - 25 SPM - 480 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 650 PSI. Observed Drilling through concretions @ 7261' - 7280' (19'),7299' - 7306' (T), 7312' - ' 7319' (T), 7339' - 7348' (9'), 7354' - 7360' (6'), 7457 - 7459' (2'), 7470'- ' i 7487 (1 T), 7524' - 7528' (4'), 7639' - 7655' (16'). Survey @ 7623' MD 3474 ND -Inc = 91.06 Deg. AZ = 180 Deg. Observed running out of down weight to Slide as per DD. Decision to POOH fo BHA change. 07:45 - 08:45 i 1.00 ;DRILL CIRC PROD2 i Pump Weighted sweep @ 93 SPM, 340 GPM's, 3100 PSI while reciprocating drill string at 80 RPM's with TQ @ 5K. Observed 15% ,increase in cuttings at shaker when sweep returned. 08:45 - 11:15 ' 2.50 DRILL TRIP PROD2 POOH from 7691' - 4374' (331 T). Added NRP Super Sliders to Lo-Tad ;stands on stands # 78,77,76,75,74,73. 1per joint as reccomended. ' ~ Pulled assembly through window area with no issues. Observed clean hole conditions while POOH and proper hole fill. 11:15 - 12:00 , 0.75 DRILL I TRIP PROD2 Monitor well -static. Pump dry job, and blow down TD. Continue POOH ~ ~ to 4289'. 12:00 - 13:30 ~~ 1.50 i DRILL ;TRIP PROD2 ~ Continue POOH from 4289' - 369' (3920') Monitor well. 13:30 - 14:00 0.50 DRILL TRIP PROD2 POOH stand back Drilling Jars, HWDP and NM Flex drill collars. Total Length = 274.10'. 14:00 - 14:30 I 0.50 DRILL OTHR PROD2 Plug in and down load MWD assembly. '~ 14:30 - 16:00 ~ 1.50 DRILL ; PULD ~ PROD2 'POOH, breakout & lay down remaining BHA. Layed down 4.60" TM i HOC (11.12'), PWD Collar (10.76'), 4 3!4" Slimphase 4 w/ DGR & I ' RES (23.82'), DM HOC (8.49'), 4 3/4" Integral Blade stabilizer (5.24'), 4 3/4" Non Mag Float sub (2.49'), 5" Sperry Drill lobe 7/8 -6.0 Stage Printed: 12/9/2005 3:20:17 PM ConocoPhillips Alaska .Page 12 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9!30/2005 End: 10/3112005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date ,From - To 10/16/2005 ~ 14:30 - 16:00 i 16:00 - 16:30 ,16:30 - 18:00 Hours ' Code 1.50 DRILL Sub ~ Phase ' Description of Operations Code_ i _ _ _ _ _ _ _ _ PULD PROD2 32.50) and 6 3/4" Reed Hycalog PDC CRXE1005 Bit. Gauge bit to 1 / 0.501 DRILL !PULD ' PROD2 1.50 ~ DRILL ~ PULD PROD2 18:00 - 18:30 I 0.50 DRILL OTHR PROD2 18:30 - 19:15 0.75 DRILL i PULD ; PROD2 i 19:15 - 20:00 0.751 DRILL OTHR t PROD2 20:00 - 21:30 1.50 DRILL TRIP PROD2 21:30 - 23:00 i 1.50 RIGMNT RSRV PROD2 23:00 - 00:00 ' 1.00 10/17/2005 00:00 - 01:15 1.25 i 01:15 - 02:00 0.75 02:00 - 12:00 12:00 - 00:00 10/18/2005 100:00 - 08:45 10.00 12.00 8.75 DRILL TRIP ; PROD2 DRILL iTRIP PROD2 DRILL ;REAM PROD2 DRILL I DRLG DRILL( DRLG PROD2 PROD2 DRILL 'DRLG i PROD2 ' 1 / NO /ALL / / 1/ NO / PR NOTE: Pictures of Bit sent to Engineer Clean & clear rig floor area, lay down tools. ' PJSM with crew. Discuss Safety Issues and BHA pick up procedure. MU BHA #6. Make up 6 3/4" SDBS FAF2641 Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non I Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 314" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR ~ EWR phase 4 { ' 23.82'), PWD Collar (10.76'), TM HOC (10.07), 4 314" Non Mag Float Sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). Plug in and down load MWD assembly. Continue MU BHA #6 picking up 3-jnts Non Mag Flex Drill Collars 92.76'), Crossover sub (1.07'), 1 - jnt 4" HWDP (30.13'), 4 3/4 Drilling .Jars (28.90'), and 4-jnts 4" HWDP (121.24'). Perform shallow pulse test and test Geo-Pilot. Trip in hole from 36T - 4288' (3921'). Fill DP every 25 stands. PJSM, RU and Slip & Cut 72' of Drilling line. Inspect and adjust brakes on draw works. Fill Drill string and RIH from 4288' - 4611' (323'). Pump to check Geo i -Pilot tools. Observed no issues with BHA assembly passing through (window area from 4374' - 4386'. 'Tag Spot @ 4611 DPM. MU Top Drive and rotate & pump through spot (with no issues. Continue TIH form 4611' - 7573' (2962'}, with little or no issues, ,Wash i~ Ream hole from 7573' -7691' (118'), to tag bottom on depth. Pumps @ 300 GPM's, 84 SPM -2650 PSI. 80 RPM's and 5K Torque.. !Down Link Geo -Pilot tool. Continue Directional drill 6 3/4" Hole from 7691' - 8691' MD (1000'). TVD = 3479'. ART = 6.56 HRS, PU WT = 116K, SO WT = 50K, ROT WT = 80K, Torque off btm = 5.5K, Torque on bottom = 6K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Total Jar Hrs = 213.85 Total Bit Hrs = 5.56 ECD at 11.03 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 7765' MD, 3469' TVD. Pump #1 - 25 SPM - 470 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 620 PSI. Observed Drilling through !concretions @ 7690' - 7702' (12'), 7712' - 7714' (2'), 7745' - 7750' (5'), 7764' - 7767' (3'), 8509' - 8514' (5'), 8526' - 8530' (5'), 8538' - 8540' ~ 2'), 8582' - 8591' (9'), 8621' - 8624' (3'). Survey @ 8698' MD , 3482 ~TVD -Inc = 88.4 Deg. AZ = 182.4 Deg. Pumping weighted sweeps to 'control ECD and clean hole. Continue Directional drill 6 3/4" Hole from 8691' - 10081' MD (1390'). TVD = 3470'. ART = 8.01 HRS, PU WT = 120K, SO WT = 45K, ROT WT = 80K, Torque off btm = 6K, Torque on bottom = 7K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3250 PSI. Total Jar Hrs = 221.86 Total Bit Hrs = 14.57 ECD at 11.04 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 8733' MD, 3483' TVD. Pump i #1 - 25 SPM - 480 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM - 740 PSI. Observed Drilling through concretions @ 8708' - 8720' (12'), 8732' - 8741' (9'), 8768' - 8772' (4'), 8797' - 8812' (15'). Survey @ 10045' MD ,3468.5 TVD -Inc = 89.10 Deg. AZ = 183.74 ~ Deg. Pumping weighted sweeps to control ECD and clean hole. Continue Directional drill 6 3/4" Hole from 10081' - 11285' MD (1204'). I, TVD =3455'. ART = 5.37 HRS, PU WT = 145K, SO WT = 40K, ROT Printed: 12/9/2005 3:20:17 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 08:45 - 10:15 ~ 1.50 10:15 - 12:00 1.75 12:00 - 14:00 2.00 Date Fram - To ' Hours 10/18/2005 ~ 00:00 - 08:45 I 8.75 10!19!2005 14:00 - 15:00 1.00 15:00 - 20:00 ~ 5.00 20:00 - 23:30 ~ 3.50 Code ' Sub I !Code DRILL ': DRLG Phase PROD2 DRILL ' CIRC ' PROD2 DRILL WIPR ' PROD2 DRILL i ( WIPR PROD2 DRILL CIRC PROD2 DRILL WIPR PROD2 DRILL i , REAM PROD2 23:30 - 00:00 I 0.501 DRILL I CIRC I PROD2 00:00 - 01:30 01:30 - 03:15 03:15 - 12:00 12:00 - 13:00 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon 141 1.50 DRILL CIRC PROD2 1.75; DRILL CIRC PROD2 8.75'. DRILL TRIP PROD2 1.00 DRILL I PULD PROD2 13:00 - 14:00 1.00',. DRILL OTHR 14:00 - 15:00 ! 1.00 I DRILL ,PULD PROD2 PROD2 Page 13 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations WT = 95K, Torque off btm = 8K, Torque on bottom = 8K. WOB = 5-10K, RPM's = 80 -120, Pumps @ 93 SPM, 330 GPM's - 3900 PSI. Total Jar Hrs = 227.23 Total Bit Hrs = 19.93 ECD at 11.55 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 18. SPR's @ 11262' MD, 3455' TVD. Pump #1 - 25 SPM - 650 PSI, 35 SPM - 840 PSI. Pump #2 - 25 SPM - 600 PSI, 35 SPM - 820 PSI. Survey @ 11285' MD , 3455.63 TVD -Inc = 90.53 Deg. AZ = 172.41 Deg. MAX GAS = 107 Units. Pumping weighted sweeps to control ECD and clean hole. Rack Back 1 stand DP. Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. Monitor well -static. POOH on elevators from 11285' - 10538' (747'). 'Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. ,Continue POOH on elevators from 10538' - 4350' (6188'). Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. Pull to above top of window @ 4374'. MU top Drive and Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. 'Monitor well -static. Trip back in hole from 4350' - 9123' (4773'). Observe clean hole conditions,no hanging up issues, but ran out of ;down weight to continue in on elevators. MU top drive on each stand and wash & ream from 9123' - 11284' .2161') @ 2-3 minutes per stand. Observed no hole condition issues and ~' string went to bottom good @ 62 SPM - 1600 PSI, 60 RPM's - 5K torque. Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate & rotate drill string. Rack back 1 stand. Continue circulate pumping Hi Visc .weighted sweep @ 11266' working string. 'Continue Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate 8~ rotate drill string, pumping Hi Visc weighted sweep + 1 Bottoms up @ :11266' working string. Observe 10% increase in cuttings across shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 88 SPM - 4150 PSI. Vac truck 'broke down and we slowed pumps to 60 SPM - 2200 PSI on last 70 ' BBIs of displacement. Obtain Slow pump rates @ 11266' MD 3455 TVD. Pump #1 - 25 SPM - 560 PSI. 35 SPM - 750 PSI. Pump #2 - 25 ' SPM - 510 PSI, 35 SPM - 670 PSI. PU WT = 145K, SO WT = 35K, ROT WT = 92K. 140 RPM's - 7.5K TO ;Monitor well -static. POOH from 11266' - 367' (10900'). Install Super Sliders in the middle of each joint of Lo-Tad stands on TOH. Total installed = 90. 'Change out drilling jars and rack back HWDP & NM Flex Drill collars. (181.27). 'Plug in and download MWD assembly. Breakout & lay down remaining BHA #7. 6 3/4" SDBS FAF2641Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR & EWR phase 4 .23.82'), PWD Collar (10.76'), TM HOC (10.07'), 4 3/4" Non Mag Float 'Sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). Bit Gaugedto3/1 /WT/N/X/I/ERlTD. Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 10/19/2005 1 J-154 1 J-154 ROT -DRILLING n1334@ppco.com Doyon141 From - To Hours Code ! Cade Phase __ _ _ 15:00-15:30 0.50~WINDO THR CMPLT2 15:30 - 18:30 ! 3.00 i WINDO~RIP I CMPLT2 18:30 - 19:00 I 0.50 19:00 - 19:30 19:30 - 00:00 10/20/2005 00:00 - 01:00 01:00 - 01:30 01:30 - 02:15 02:15 - 02:30 t 02:30 - 09:15 09:15 - 09:30 09:30 - 11:30 11:30 - 12:00 12:00 - 15:00 15:00 - 17:00 0.501 WINDOWCIRC 4.50 WINDO RIP 1.00 WINDOV~PULD 0.50, WINDOV~IPULD 0.75' CMPLTNI RURD 0.25 CMPLTN SFTY 6.75 ~ CMPLTNi RUNT 0.25 I CMPLTNI RUNT 2.001 CMPLTNI RUNT 0.501 CMPLTNI RUNT 3.001 CMPLTNI RUNT 2.00 ! CMPLTNI OTHR CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 Page 14 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10!31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations Clean & Clear Rig Floor area, lay down all tools. PJSM with crew. Discuss safety issues and procedure for BHA make up. Make up 7 5/8" Whipstock retrieving tools. Make up Fixed Lug retrieving tool (7.49'), 1 jnt 3 112 HWDP (29.84'), 4 3/4" Float sub ( 2.49'), 4 3/4" Bumper jar (7.85'), 4 3/4" Oil Jar (11.13'), Crossover sub ( 1.66'), and 18 juts 4" HWDP (543.62'). Total BHA = 604.08'. Trip in hole with BHA above top of whipstock. UP WT = 94K, SO WT = 73K. Slack off and locate slot washing down past slot to clean it up. Pull up to observe hooked whipstock slide. Located slot @ 4377' per BOT rep. Pull to 150K to observe jars fire and assembly free. Observe 5K increase in upweight. Pull up hole 30' verify swabbing. Circulate bottoms up @ 71 SPM - 920 PSI. Verify no gas and monitor well -static. POOH slow at 10-15 ft/minute for 15 stands with proper hole fill as we observed swabbing by pulling faster. Cup wore out and continue POOH at an increased rate observing hole taking proper hole fill. PuIlWhipstock slide to rotary table. PJSM with crew. Mill marks on slide indicated milling down to 10' on slide. Continue breakout & lay down 7 5/8" Whipstock assembly and space out pipe. Clean & Clear Rig floor area, and send tools down slide. Rig up Liner running equipment, power tongs, slips, elevators etc.. Pull 89 HydroFORM tantalizers to rig floor. PJSM with crew, and BOT reps. Discuss safety issues and procedure to run 4 1/2" IBT liner and Hook Hanger assembly. Verify joint placement in pipe shed in correct running order. Make up 3 1/2" Bent joint with Open guide shoe (20.42'). Breakout pack off bushing from top of joint. Install IBT Crossover (1.45'), and continue RIH making up 4 1/2" 12.6# IBT slotted !blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #96, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10750',10518',10010',9716', 9208',8974',8465',8170',7542',7313',6804',6 572',6065',5775',5360',5156',4865', and 4568'. RIH to 4353'. Rotate 3/4 turn to attempt to go through window @ 4374'. NOGO, tag up on A2 liner at 4496.5'. Pull back to 4353', rotate 3/4 turn to observe Guide shoe through window. Continue RIH with remaining liner to 6882'. Total BHA = 6894.41'. No issues in open hole. PU WT = 76K, SO WT = 56K. Make up Baker Casing Swivel & Pup Jnt Assembly with Baker Model 61 FHH Hook Hanger & Running tool (48.22'). Pull 2 718 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1/4" Slimhole MWD assembly on BOT Shear sub and Bal! seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. TIH from 6895' - 6950' (55'). Perform Shallow pulse test on MWD assembly. Good. Continue RIH with 4 112" 12.6# IBT slotted /blank liner assembly from 6950' - 11176' (4226'). RU and break circulation @ 11176'. 34 SPM - 700 PSI. UP WT = 143K, SO WT = 55K. Orient with MWD assembly to 10 Degrees left of high Printed: 12!9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours ' Code 'Code '~, Phase 10/20/2005 15:00 - 17:00 2.00 CMPLTNI OTHR CMPLT2 17:00 - 19:15 2.25 19:15 - 20:15 1.00 20:15 - 20:45 0.50 20:45 - 21:15 0.50 21:15-23:00 I 1.75 CMPLTN TRIP CMPLT2 CMPLTN; RURD CMPLT2 CMPLTN, RURD CMPLT2 CMPLTN RURD ~ CMPLT2 CMPLTNI RUNT i CMPLT2 23:00 - 00:00 I 1.00 10/21 /2005 ! 00:00 - 02:00 2.00 02:00 - 02:15 ~ 0.25 CMPLTNI RUNT CMPLT2 CMPLTN; TRIP ,CMPLTN CMPLTN, PCKR ,CMPLTN 02:15 - 02:45 0.50 CMPLTNI PCKR CMPLTN 02:45 - 05:15 2.50 ;CMPLTNI TRIP i CMPLTN 05:15 - 05:45 0.50 05:45 - 07:45 '. 2.00 WIN WIN PROD3 PROD3 Page 15 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations side. RIH to tag up @ 11253' DPM. Set down 30K. Pull up 20' and rotate string 90 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 10 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4386'. Drop 1 1/2" Ball and chase with 3 BPM - 700 PSI, slowing pumps to 1.5 BPM - 330 PSI to observe ball seated. Pressure to 3000 PSI to set Hook Hanger and shear with 4300 PSI. Pull up to observe weight loss and Runnng tool free. Monitor well -static. Open Guide shoe depth = 11252'. Top of Hook Hanger = 4370'. POOH to running tools. Observe well taking proper hole fill. Breakout, Visually Inspect and lay down Hook Hanger Running tools and MWD assembly. All Good. Clean & Clear Rig Floor area. Send tools outside. PJSM with crew. Discuss Safety Issues and procedure to make up LEM asembly. Double check running order in pipe shed. Make up LEM assembly. MU BOT Seal assembly (3.26'), and 4 1/2" 12.6# L80 XO joint to IBT (43.12').1 - jnt 4 1/2" tubing (30.12'), Camco "DB-6" nipple w/ 3.563" ID (1.52'), 1 -jnt 4 1/2" tubing (30.84').4 1/2" TBG pup (7.86', LEM assembly (35.13'), 4 -jnts 4 1/2" TBG (123.61'), 4 1/2" TBG pup (3.78'), Baker Casing Swivel (2.73'}, XO Bushing 5 1/2" Hydril 563 x 4 1/2" IBT (1.37'), 109-47 Casing Seal Bore Receptacle 6.26" x 4.75" (19.39'), 5 1 /2" x 7 5/8" ZXP Liner top PKR 19.0'), and Baker Hydraulic Setting tool (5.29'), Baker Running tool 6.16'), and XO to DP (1.66'). Total BHA = 334.84' Install Ball Catcher & Shear sub as per BOT rep. Rig down all tubing running equipment, and clear floor of tools. Trip in hole w/ Lem Assembly from 804' - 4225' (4216'). Fill DP. Continue TIH to tag top of Hook Hanger @ 4368' DPM. PU WT =105K, SO WT = 85K. Pull up 20', rotate 1/4 turn RH, and slack of to tag again. Pull up, rotate 1 /4 turn and observe shoe pass through top of Hook Hanger and RIH to observe LEM latch up to Hook Hanger on depth @ 4370'. Pull to 15K over upweight to verify latch up, slack off to neutral weight. Baker seal assembly @ 4511.20' RU & Drop 1 1/2" ball down drill string & chase with 3 BPM - 475 PSI, slowing pumps to 2 BPM to observe ball seat @ 335 Strokes pumped. Pressure up to 3000 PSI to set ZXP Packer, and continue to 4300 PSI to release from LEM. Hold 5 minutes. Bleed pressure. Close annular and fill all lines. Pressure test down annulus to test ZXP @ 1000 PSI f/ 10 Minutes. Record on chart. Good test. Bleed all pressure. PuH up to allow "dogs" to kick out & slack off to verify top of liner @ 4189'. Monitor well -static. UP WT = 100K, SO WT = 86K. POOH from 4189' to surface. Breakout, Inspect and lay down running and setting tools. Clean & clear rig floor area, send tools out. Pull tools to rig floor. PJSM with crew. Discuss Safety issues, and procedure to pick up Whipstock assembly. MU 5 3/4" Seal Assembly, 6 1/2" No-go sub 1.92'), 4 5/8" Unloader Sub (5.20'), 3 1/2" Pup Jnt (16.46'), 2 -juts of 3 1/2" Dp (.62.44'), Balanking Sub (1.08'), Bottom Trip Anchor (3.21'), Shear Disconnect sub (2.63'), Ported drain sub (1.02'), Debris Barrier Sub (1.71'), Whipstock Slide (15.49'), 6 3/16" Starting Mill (1.08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill (5.84'), 1 - jnt 3 1/2" HWDP (29.84'), 4 3/4" Float sub (2.49'), MWD assembly (42.45'), 4 3/4" Bumper Jar (7.85'), Crossover sub (1.66') and 6 stands of Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 16 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date 10/21 /2005 10/22/2005 From - To ,Hours Code ' Code I Phase 1 0 ~ PROD3 07:45 - 08:30 I 1 75 WINDO THR 0. PROD3 08:30 - 09:00 0.50' WINDORIP PROD3 X09:00 - 11:30 ~ I 2.50! WINDOV~ITRIP PROD3 11:30 - 12:00 0.50 WINDOV~ITRIP PROD3 12:00 - 12:30 j 0.50 ~ WINDOW SETW PROD3 i 12:30 - 13:30 I 1.00 I WINDOWCIRC ~ PROD3 13:30 - 17:15 ; 3.75 WINDOW STWP 17:15 - 18:15 ' 1.00 WINDOV ~CIRC 18:15 - 20:15 2.00: WINDOVI ITRIP 20:15 - 21:00 ' 0.75 WINDOV WOTHR 21:00 - 21:30 I 0.50 i WINDO ULD 21:30 - 22:00 0.50 WINDOWPULD 22:00 - 23:00 ; 1.001 RIGMNTI RGRP 23:00 - 00:00 00:00 - 01:15 01:15 - 02:30 1.001 RIGMNTI RGRP 1.25 RIGMNTI RGRP 1.25. DRILL i OTHR 02:30 - 03:30 03:30 - 04:30 04:30 - 05:15 05:15 - 05:30 05:30 - 06:15 06:15 - 06:45 1.001 DRILL i PULD 1.00 ~ DRILL OTHR 0.75 ;DRILL ;PULD PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 0.25 i DRILL ;TRIP I PROD3 0.75 DRILL TRIP PROD3 0.50, DRILL .PULD PROD3 Description of Operations push pipe (543.62'). Total BHA = 751.46'. Plug in and upload MWD assembly TIH to 895', and perform Shallow pulse test. Good pulses @ 78 SPM - 820 PSI. Trip in hole with Whipstock assembly from 895' - 3780' (2885'). Run @ 2 minutes per stand as per BOT rep. Fill drill pipe, perform MAD PASS for K13 from 3780' - 4018' (238'), @ 200 ft/hr. Pumps at 285 GPM's - 1750 PSI. UP WT = 105K, SO WT = 82K. Continue TIH to 4140'. Pump down drill string to Orient Whipstock face at 10 degrees left of high side as per DD. Tag top of ZXP @ 4190' DPM. Set BTA, Pull 10K over to verify set. Shear bolt @ 35K down weight,and pull to neutral positon. Obtain free rotation. Displace well with 8.9 PPG MOBM, from 9.0 SFMOBM. Pumps at 300 GPM's - 1800 PSI. Milt window from 4079' - 4091' (12'), and continue mill open hole from 4091' - 4107' (15'). Avg WOM = 2K, 295 GPM's - 1750 PSI. Work mills through window until clean. Pump Hi Visc weighted sweep until clean, while working window with no noticeable increase in cuttings across shakers. Momitor Well -static. Pump dry job. POOH with milling assembly from 4107' - 639' (3467'). Change elevators, Pull up and plug in to download MWD assembly. POOH, breakout & lay down Milling Asembly. Lay down 6 3116" Starting Mill (1.08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill 5.84'), 1 - jnt 3 1/2" HWDP (29.84'), 4 3/4" Float sub (2.49'), MWD assembly (42.45'), 4 3/4" umper Jar (7.85'), Crossover sub (1.66' ) and rack back 6 stands of push pipe (543.62'). Upper string mill in gauge @ 6.750". Clean & clear floor area. Send tools outside. BOT rep released. PJSM with crew. Discuss safet issues and procedure. Change out washpipe assembly on top drive. PJSM with crew. Discuss safety issues and procedure. Change out Saver Sub on top drive. Continue Change out Saver Sub on the Top Drive. PU 5" test joint -wear ring puller, BOLDS, pull wear bushing. Lay down same. MU 4" DP jnt with stack washer & RIH to flush BOP stack. Lay down stack washer & install WB. RILDS. PJSM with crew. Discuss Safety Issues and MU procedure for BHA. MU BHA #10, Pull tools to floor, Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor 32.44'), 4 3/4" Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer ( 5.24'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'). Plug in and upload MWD assembly. Continue Make up remaining BHA, 3 - 4 3/4" Non Mag Flex Drill Collars (92.76'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP 30.13'), 4 3/4" Drilling jars (28.59'), 4 - Jnts 4" HWDP (121.24'). Total BHA length = 369.61'. Perform Shallow pulse test @ 75 SPM - 1600 PSI. Good test. Trip in hole from 369' - 1956' (1587'). Make up 4 3i4" Andergauge Agitator sub (8.71), IF - XT39 Crossover IT /Sy LZ g.a6 Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 17 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1 J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date 10/22/2005 10/23/2005 From°- To ~ Hours Code 'Sub !Phase ' Code 06:15 - 06:45 I 0.50! DRILL I PULD ~ PROD3 , 06:45 - 07:30 0.75 ~ DRILL ~ TRIP PROD3 07:30 - 08:30 ~ 1.00 RIGMNT, RSRV PROD3 08:30 - 08:45 ~ 0.25 DRILL ~ TRIP PROD3 08:45 - 12:00 '', 3.25 ~ DRILL ~I DRLG ~ PROD3 12:00 - 00:00 12.00 DRILL DRLG ' PROD3 00:00 - 12:00 12:00 - 00:00 12.00 DRILL 12.00 DRLG I PROD3 DRILL DRLG I, PROD3 Description of Operations (1.64'), 4 3/4" Shock sub (7.00'), and Crossover XT39 - IF (1.07'). Continue TIH from 1974' - 4026' (2052'). Fill drill string with mud @ 2721'. 82 SPM - 3400 PSI. Slip & Cut 71' of drilling line. Inspect Brakes. Orient bit & motor to 10 Degrees left of high side. Pass through window area from 4079' - 4091' with no issues and tag at 4097' DPM. UP WT = 80K, SO WT = 76K, ROT WT 80K, 5K torque. Observed hole fill on trip = proper displacement, 24 BBLs. Directional Drill 6 3/4" hole in "D" Lateral from 4097' - 4308' MD (211'). TVD = 3458'. ADT = 1.54 HRS, AST =.92 HRS, ART = .62 HRS. Pumps @ 86 SPM (total) - 3500 PSI. Pump # 1 @ 45 SPM. Pump # 2 @ 41 SPM. UP WT = 90K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K RPM's = 90. Torque on bottom = 3K, Torque off bottom = 3K. MUD WT = 8.9 PPG, VISC = 77, YP = 18. Establish ECD Baseline @ 9.72 PPG EMW. Jar Hrs total = 1.54. Bit Hrs total = 1.54. Obtain SPR's @ 4168' MD, 3470 TVD. Pump #1 = 20 SPM - 420 PSI, 30 SPM - 720 PSI. Pump #2 = 20 SPM - 400, 30 SPM -720 PSI. Survey @ 4292' MD, 3456' TVD. INC = 93.13 DEG, AZ = 179.74 DEG. Continue Directional Drill 6 3/4" hole in "D" Lateral from 4308' - 4775' MD (467'). TVD = 3475'. ADT = 7.44 HRS, AST =4.62 HRS, ART = 3.41 HRS. Pumps @ 93 SPM - 3640 PSI. Pump # 1 @ 93 SPM. UP WT = 94K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K. RPM"S = 90. Torque on bottom = 5K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 9.92 PPG EMW. Jar Hrs total = 8.98. Bit Hrs total = 8.98 Obtain SPR's @ 4772' MD, 3468 TVD. Pump #1 = 20 SPM - 380 PSI, 30 SPM - 610 PSI. Pump #2 = 20 SPM - 390, 30 SPM -610 PSI. Survey @ 4633' MD, 3456' TVD. INC = 86.79 DEG, AZ = 181.16 DEG. Observed Concretions @ 4282' - 4284' (2'), 4395' - 4413' (18'), 4422' - 4446' (24'), 4450' - 4460' (10'), 4505' - 4508' (3'), 4722' - 4743' (21'), 4745' - 4756' (1'), 4760' - 4769' (9'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 4775' - 5969' MD (1194'). TVD = 3430'. ADT = 8.19 HRS, AST = 2.93 HRS, ART = 5.26 HRS. Pumps @ 88 SPM - 3450 PSI. Pump # 1 @ 88 SPM. Pump sweeps as needed to clean hole. UP WT = 92K, SO WT = 65K, ROT WT = 80K. WOB = 5-10K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD @ 10.4 PPG EMW. Jar Hrs total = 16.10. Bit Hrs total = 16.10 Obtain SPR's @ 5800' MD, 3446 TVD. Pump #1 = 20 SPM - 440 PSI, 30 SPM - 670 PSI. Pump #2 = 20 SPM - 460, 30 SPM -680 PSI. Survey @ 5844' MD, 3434' TVD. INC = 93.21 DEG, AZ = 179.78 DEG. Observed Concretions @ 4836' - 4839' (3'}, 4982' - 4987' (15'), 5787' - 5790' (3'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 5969' - 7138' MD (1169'). TVD = 3404'. ADT = 6.06 HRS, AST = 1.90 HRS, ART = 4.16 HRS. Pumps @ 85 SPM - 3250 PSI. Pump # 2 @ 85 SPM. Pump sweeps as needed to clean hole. UP WT = 103K, SO WT = 56K, ROT WT = 80K. WOB = 2-10K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 73, YP = 18. ECD @ 10.3 PPG EMW. Jar Hrs total = 22.16. Bit Hrs total = 22.16 Obtain SPR's @ 6828' MD, 3410 TVD. Pump #1 = 20 SPM - 460 PSI, 30 SPM - 780 PSI. Pump #2 = 20 SPM - 500, 30 SPM -780 PSI. Survey @ 6966' MD, 3406' TVD. INC = 90.84 DEG, AZ = 179.98 DEG. Observed Concretions @ 6624' - 6628' (4'), 6653' - 6657' (4'), 6768' - Printed: 12!9/2005 3:20:17 PM C~ ConocOPhillips Alaska Page 1s of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10!30/2005 Group: Rig Name: Doyon 141 Rig Number: Date 10/23/2005 10/24/2005 10/25/2005 From = To r Hours 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 10/26/2005 00:00 - 12:45 Code Code '~ Phase ', 12.00; DRILL DRLG 12.00 DRILL DRLG 12.00 DRILL I DRLG 12.00 DRILL !DRLG 12.00 DRILL 'DRLG PROD3 PROD3 PROD3 PROD3 PROD3 12.751 DRILL !DRLG PROD3 Description of Operations 6780' (12'). Max Gas units = 179. Observed 35% increase in cuttings at shakers when sweep returned. Continue Directional Drill 6 3/4" hole in "D" Lateral from 7138' - 8195' MD (1057'). ND = 3407'. ADT = 6.35 HRS, AST = 1.06 HRS, ART = 5.29 HRS. Pumps @ 86 SPM - 3800 PSI. Pump # 1 @ 86 SPM. Pump sweeps as needed to clean hole. UP WT = 107K, SO WT = 56K, ROT WT = 79K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.5 PPG EMW. Jar Hrs total = 28.51. Bit Hrs total = 28.51 Obtain SPR's @ 8173' MD, 3405 ND. Pump #1 = 20 SPM - 510 PSI, 30 SPM - 750 PSI. Pump #2 = 20 SPM - 520, 30 SPM -720 PSI. Survey @ 8027' MD, 3396' ND. INC = 87.5 DEG, AZ = 178.3 DEG. Observed Concretions @ 7449' - 7456' (7'), 7774' - 7780' (6'), 8132' - 8140' (8'). Max Gas units = 135. Observed 40% increase in cuttings at shakers when sweep returned from 7322'. Sweep @ 7883', 15% increase in cuttings. Continue Directional Drill 6 3/4" hole in "D" Lateral from 8195' - 8879 MD (784'). ND = 3404'. ADT = 7.21 HRS, AST = 2.52 HRS, ART = 4.69 HRS. Pumps @ 84 SPM - 3400 PSI. Pump # 1 @ 84 SPM. Pump sweeps as needed to clean hole. UP WT = 110K, SO WT = 52K, ROT WT = 82K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 6K, Torque off bottom = 5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.67 PPG EMW. Jar Hrs total = 35.72. Bit Hrs total = 35.72 Obtain SPR's @ 8850' MD, 3408 ND. Pump #1 = 20 SPM - 480 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 500, 30 SPM -810 PSI.Survey @ 8899' MD, 3408' ND. INC = 92.89 DEG, AZ = 181.25 DEG. Observed Concretions @ 8342' - 8349' (7'), 8381' - 8401' (20'), Max Gas units = 182. Observed 25% increase in cuttings at shakers when sweep returned from 8947'. Continue Directional Drill 6 3/4" hole in "D" Lateral from 8879' - 9721' MD (842'). ND = 3359'. ADT = 7.43 HRS, AST = 2.64 HRS, ART = 4.79 HRS. 309 GPM @ 3750 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 115K, SO WT = 45K, ROT WT = 80K. WOB = 2-15K. RPM"S = 90. Torque on bottom = 6.SK, Torque off bottom = 6.5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 43.77. Bit Hrs total = 43.77 Obtain SPR's @ 9524' MD, 3372 ND. Pump #1 = 20 SPM - 560 PSI, 30 SPM - 790 PSI. Pump #2 = 20 SPM - 550, 30 SPM -780 PSI. Observed Concretions @ 9288' - 9291' (3'), 9311' - 9318' (7'), 9331'-9343' (12'), 9380'-9394' (14'), 9421'-9429' (8'), 9435'-9440' (5'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 9721' - 10286' MD (565'). ND = 3379'. ADT = 6.42 HRS, AST = 2.07 HRS, ART = 4.35 HRS. 318 GPM @ 3850 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 125K, SO WT = 42K, ROT WT = 87K. WOB = 2-12K. RPM"S = 100. Torque on bottom = 6.OK, Torque off bottom = 5.4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 50.19. Bit Hrs total = 50.19 Obtain SPR's @ 10283' MD, 3379 ND. Pump #1 = 20 SPM - 570 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 570, 30 SPM -820 PSI. Observed Concretions @ 9940' - 9946' (6'), 10188' - 10195' (7'), 10230'-10250' (20'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 10286' - 10964' MD (TD) (678'). ND = 3356'. ADT = 9.36 HRS, AST = 4.49 HRS, ART Printed: 12/9(2005 3.20:17 PM • ConocoPhillips Alaska Page 19 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Weli Name: 1J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30!2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To 'Hours ' Code Code ~ Phase Description of Operations 10/26/2005 ~ 00:00 - 12:45 12.75 DRILL DRLG i PROD3 12:45 - 14:30 ! 1.75' DRILL i CIRC I PROD3 14:30 - 16:30 2.00; DRILL WIPR PROD3 16:30 - 19:45 3.25 DRILL WIPR ~ PROD3 19:45 - 22:45 f 3.00 DRILL ~ WIPR PROD3 22:45 - 00:00 1.25 10/27/2005 00:00 - 00:30 0.50 00:30 - 03:30 3.00 03:30 - 05:15 , 1.75 05:15 - 08:00 2.75 ! 08:00 - 09:45 ~ 1.75 DRILL I CIRC I PROD3 RIGMNT RSRV ~ PROD3 DRILL WIPR PROD3 DRILL ~ WIPR ~ PROD3 DRILL CIRC PROD3 DRILL CIRC PROD3 09:45 - 16:30 ~ 6.75 DRILL TRIP PROD3 16:30 - 17:00 0.50 DRILL PULD PROD3 17:00 - 18:00 1.00' DRILL 'TRIP PROD3 18:00 - 18:30 ' 0.50 DRILL PULD PROD3 18:30 - 19:45 1.25, DRILL ~ PULD PROD3 19:45 - 20:45 ' 1.00 DRILL PULD ' PROD3 ..20:45 - 21:15 0.50 i DRILL SFTY CMPLT3 21:15 - 22:00 0.75' WINDOW PULD .CMPLT3 22:00 - 00:00 ' 2.00 'I, WINDOvpI RIP CMPLT3 10/28/2005 00:00 - 00:30 0.50; WINDOWTRIP CMPLT3 00:30 - 01:00 i 0.50 ~ WINDOV!VOTHR ~ CMPLT3 01:00 - 01:30 01:30 - 04:00 04:00 - 06:30 06:30 - 07:00 07:00 - 11:00 0.50' WINDi 2.50 WIND 2.50,, WINDi 0.50 DRILL 4.00 WELC PULD SFTY BOPE CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 11:00 - 18:15 j 7.25 !CASE PULR CMPLT3 = 4.87 HRS. 309 GPM @ 4000 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 135K, SO WT = 45K, ROT WT = 89K. WOB = 2-15K. RPM"S = 100. Torque on bottom = 7.OK, Torque off bottom = 7.OK. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 60.55. Bit Hrs total = 60.55 Obtain SPR's @ 10851' MD, 3365 TVD. Pump #1 = 20 SPM - 610 PSI, 30 SPM - 860 PSI. Pump #2 = 20 SPM - 610, 30 SPM -850 PSI. Observed Concretions @ 10290' - 10299' (9'), 10319' - 10322' (23'), 10364'-10367' (3'), 10846- 10850 (4'). Pump Hi-vis weighted sweep around and 1 btm's up at rate of 300 gpm @ 3950 psi, Observe well, Pump up survey. POOH on elevators f/ 10,964' to 10,195', Pump dry job & continue to POOH to 9,543' (Pulled 20K over @ 9,543') Make up top drive). Back ream out of hole f/ 9,627' to 8,369' with no problems at rate of 330 gpm @ 3900 psi w! 100 RPM. POOH on elevators f/ 8,369' to 7,629', Pump dry job, Continue to POOH to 4,028' (Window @ 4,079'), No problems POOH or Pulling thru window. Pump Hi-vis weighted sweep & circ 3 times btm's up at rate of 330 gpm @ 3400 psi w/ 100 RPM. Service top drive RIH with no problems f/ 4,028' to 9,723' (Ran out of weight) Wash & Ream f/ 9,723' to 10,964' w/ 128 GPM @ 1200 PSI & 50 RPM. Pump 35 bbl Hi-vis weighted sweep &Circ 3 times btm's up at rate of 288 GPM @ 4100 PSI, 100 RPM. Change well over f/ MOBM to SFOBM at rate of 288 GPM @ 4100 PSI w/ 100 RPM, Obtain SPR's, Monitor well- OK. POOH on elevators with no problems. Lay down Agitator & Shock sub. Continue to POOH to BHA. Lay down DC's. Down load MWD tools. Finish laying down BHA. Clear & Clean rig floor, Bring Whipstock retrieving tools to rig floor. Make up Baker Whipstock retrieving tools. RIH w/ BHA to 2,539', Fill pipe - 50 SPM @ 550 PSI. Continue RIH to 4,083' Work & Hook whipstock @ 4,083', Pull loose w/ 70K over, Pull 1 stand drill pipe. Circ btm's up at rate of 6 bpm @ 1200 psi. Drop 1-3/4" rabbit, POOH to whipstock. Lay down whipstock & Baker retrieving tools. Clear tools from rig floor, Clean rig floor. Pull wear bushing, Rig i;< test all BOPE to 250 psi low & 3000 psi high, Test waived by AOGCC Jeff Jones, Install wear bushing. PJSM, Rig & Make up 3 1/2" Bent joint X 4-1/2" with Open guide shoe as shoe jt.. Breakout pack off bushing from top of joint, Continue RIH making up 4 1/2" 12.6# IBT slotted /blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #116, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10555', 10356', 9855', 9605', 9105', 8855', 8352', 8105', 7755', 7505', 7005', 6755', 6255', 6005', Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 'From - To '' Hours ' Code 'Sub _ ~ Code '~, 11:00 - 18:15 ' _ . -: _- ~ ___ 10/28/2005 7.25 C CASE ~ PULR 18:15 - 19:45 i 1.50 19:45 - 22:45 3.00 22:45 - 00:00 I 1.25 10/29/2005 10/30/2005 00:00 - 00:30 Phase CMPLT3 CASE PULR CMPLT3 CASE RUNL CMPLT3 ,I CASE ~ OTHR I CMPLT3 0.501 CASE OTHR I CMPLT3 00:30 - 01:00 1 0.50 01:00 - 03:45 ~ 2.75 03:45 - 04:15. 0.50 04:15 - 13:00 ! 8.75 13:00 - 14:15 1.25 14:15 - 14:45 0.50 14:45 - 16:15 ~ 1.50 16:15 - 19:00 ' 2.75 19:00 - 19:45 ~ 0.75 CASE ; CIRC 'CMPLT3 CASE RUNL CMPLT3 CASE OTHR ;CMPLT3 DRILL ' PULD CMPLT3 RIGMNT RSRV CMPLT3 CMPLTN; RURD CMPLT3 CMPLTN PULD CMPLT3 CMPLTN' TRIP CMPLT3 l CMPLTN'; CIRC i CMPLT3 19:45 - 22:15 2.50 CMPLTNI, TRIP 22:15 - 22:45 ! 0.50. CMPLTN' PULD 22:45 - 00:00 1.25 ~ CMPLTN RURD 00:00 - 03:30 3.50 CMPLTN: RUNT 03:30 - 04:30 1.00 CMPLTNI SOHO 04:30 - 06:00 1.50 •, CMPLTN NUND 06:00 - 07:30 1.50 ~ CMPLTN NUND CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 07:30 - 13:00 ! 5.50; CMPLTNI PULD 'CMPLT3 Page 20 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations 5557', 5302', 4805' and 4555'. RIH and enter btm of window @ 4091'. ;Continue RIH with remaining liner to 6,820'. Total BHA = 6,843.47'. No issues in open hole. PU WT = 75K, SO WT = 68K. Pull 2 7/8 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1/4" Slimhole MWD assembly on BOT Shear sub and Ball seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. RIH w/ 4-1/2" liner f/ 6843' to 10,877', Perform Shallow pulse test on !MWD assembly. Good. Break circulation @ 10,877'. 37 SPM - 1000 PSI. UP WT = 145K, SO WT = 65K. Orient with MWD assembly to 12 Degrees left of high side. RIH to tag up w/ shoe @ 10,917.80' -Hook btm of window @ 4,091' (Measurements exact), Toolface oriented to 4 Degress Left .Set down 30K. Pull up 20' and rotate string 180 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 12 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4,091' and Toolface again pulled around to 4 Degress left of high side. Top of Hook Hanger @ ,4,074.33', Shoe @ 10,917.80' Drop ball & pump down at rate of 130 gpm @ 1000 psi. Pressure up release f/ liner & shear out ball w/ 4400 psi. Pick up & circ btm's up at rate of 5 bpm @ 700 psi. POOH, Break 8~ lay down liner running tools &MWD. I Lay down tools from beaver slide, Clean rig floor. Rig & lay down 95 std's 4" drill pipe f/ off drillers side. Slip & cut drilling line 70', Service top drive. Rig casing tools to run LEM Assembly. PJSM, Make up LEM assembly as per detail, UP 37K, DN 40K, Rig down casingf tools. RIH to 4200', UP 110K, DN 92K, Slack off and latch LEM (On depth), ,Pull test latch 20K over twice-OK, Slack off 40K. Drop ball & pump down at 163 gpm @ 700 psi, Seat ball & pressure up to 4000, Bleed pressure, Test ZJCP to 1000 psi f/ 10 min-OK. Monitor well, POOH to running tools. 'Lay down running tools. Pull wear bushing, Rig to run 4-1/2" completion string, PSJM. ;Run Baker 4.75" Seal assembly, 1 jt. 4-1/2", 12.6#, L-80, IBT Tubing, Baker 4-1/2" CMU Sliding sleeve (In Open position), 6 jts. 4-1/2", 12.6#, L-80, IBT tubing, Camco 4-1/2"x 1"- KBMG GLM, 44 jts. tbg, Camco '4-1/2"x 1"-KBMG GLM, 62 jts. tbg, Camco 4-1/2" DB Nipple w/ 3.875" Profile, 15 jts tbg., Tag No-Go @ 4,025.13' w/ Tail @ 4,051.78' (2.75' ',High with tubing measurements). Note: Day Light savings time 1 hour back. Make up Vetco Gray 4-1 /2" x 11"Tubing hanger & land tubing 4.23' 'above fully located position w/ Tail @ 4,047.55', Attempt to test seals on hanger- No Good, Pull hanger, Change O-rings and reland hanger, Test hanger seals to 250 low and 5000 psi high- OK. Nipple down BOPE. ;Nipple up Vetco Gray Tree and test same to 250 psi low & 5000 psi 'high. Lay down all 4" HWDP, DC's, Drill pipe w/ Lo-Tad's & Sliders, Rig down i mouse hole. Printed: 12/9/2005 3:20:17 PM C~ CQnocoPhillips Alaska Page 21 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1 J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date 'From - To ' Hours Code Code j Phase L Description of Operations 10/30/2005 i 13:00 - 16:00 3.00 CMPLTN FRZP CMPLT3 Rig Little Red service and freeze protect well with 166 bbls diesel thru i 'sliding sleeve @ 3,971', Remove all tools and equip. from rig floor, " Change liners in pumps to 6 . 16:00 - 16:30 0.50; CMPLTN NUND CMPLT3 ;Rig lubricator and set BPV. 16:30 - 19:00 2.50 CMPLTN PULD : CMPLT3 Rig mouse hole finish laying down 4" drill pipe, Lo-Tad's & Sliders, Rig down mouse hole. 19:00 - 00:00 5.00 CMPLTN; OTHR ,CMPLT3 Clean pits, Rock washer, Cuttings boxes. Release rig @ 2400 hrs. 10/30/05 Printed: 12/9/2005 3:20:17 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-154L2 Job No. AK ZZ-0003956462, Surveyed: 26 October, 2005 Survey Report 9 November, 2005 Your Ref: AP1500292325461 . Surface Coordinates: 5945944.17 N, 558639.59E (70° 15' 46.5105" N, 149° 31' 33.3768" YID Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945944.17 N, 58639.59E (Grid) Surtace Coordinates relative to Structure: 25.70 N, 150.17 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~t"'~-'IJI"1 ~ ~ ~ €s ~t e~ ~ Survey Ref.• svy2133 A Ha#1#burta~ Cnte~pany Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-154L2 Your Ref: API 500292325461 Job No. AK-ZZ-0003956462, Surveyed: 26 October, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 4062.53 78.370 178.300 3337.21 3446.21 574.07 S 531.32 W 5945365.98 N 558112.76E 574.07 Tie-On Point 4079.00 78.020 178.270 3340.58 3449.58 -- 590.18 S 530.83 W 5945349.87 N 558113.37E 2.133 590.18 Window Point 4119.72 84.370 178.360 3346.81 3455.81 630.39 S 529.65 W 5945309.68 N 558114.86E 15.596 630.39 4164.55 88.490 178.420 3349.60 3458.60 675.10 S 528.40 W 5945264.97 N 558116.47E 9.191 675.10 4201.96 87.880 178.480 3350.78 3459.78 712.48 S 527.38 W 5945227.61 N 558117.77E 1.638 712.48 4232.79 89.790 178.470 3351.41 3460.41 743.29 S 526.56 W 5945196.80 N 558118.83E 6.195 743.29 • 4292.00 93.130 179.770 3349.90 3458.90 802.46 S 525.65 W 5945137.64 N 558120.20E 6.053 802.46 4352.62 94.300 181.100 3345.97 3454.97 862.95 S 526.11 W 5945077.15 N 558120.21E 2.919 862.95 4416.65 91.530 179.800 3342.72 3451.72 926.89 S 526.61 W 5945013.21 N 558120.21E 4.778 926.89 4447.45 88.970 180.280 3342.58 3451.58 957.69 S 526.64 W 5944982.41 N 558120.43E 8.457 957.69 4508.12 90.160 182.360 3343.04 3452.04 1018.34 S 528.03 W 5944921.75 N 558119.50E 3.950 1018.34 4539.87 89.940 182.470 3343.01 3452.01 1050.06 S 529.37 W 5944890.02 N 558118.41E 0.775 1050.06 4585.82 88.070 182.680 3343.81 3452.81 1095.95 S 531.44 W 5944844.11 N 558116.71E 4.095 1095.95 4633.00 86.790 181.120 3345.93 3454.93 1143.06 S 533.00 W 5944797.00 N 558115.51E 4.274 1143.06 4726.38 86.280 180.630 3351.57 3460.57 1236.25 S 534.42 W 5944703.79 N 558114.81E 0.757 1236.25 4817.95 87.510 179.280 3356.53 3465.53 1327.69 S 534.35 W 5944612.36 N 558115.60E 1.993 1327.69 4910.81 89.000 176.120 3359.36 3468.36 1420.41 S 530.62 W 5944519.67 N 558120.04E 3.761 1420.41 5004.19 90.150 176.060 3360.05 3469.05 1513.57 S 524.26 W 5944426.56 N 558127.14E 1.233 1513.57 5097.66 92.390 177.710 3357.98 3466.98 1606.87 S 519.18 W 5944333.30 N 558132.94E 2.976 1606.87 5191.34 93.580 178.140 3353.10 3462.10 1700.36 S 515.79 W 5944239.84 N 558137.06E 1.350 1700.36 5284.55 93.830 177.070 3347.08 3456.08 1793.29 S 511.90 W 5944146.94 N 558141.67E 1.177 1793.29 5377.86 92.340 177.140 3342.06 3451.06 1886.35 S 507.20 W 5944053.93 N 558147.10E 1.599 1886.35 5469.88 90.800 178.640 3339.54 3448.54 1978.26 S 503.81 W 5943962.04 N 558151.20E 2.336 1978.26 • 5565.14 91.350 179.530 3337.75 3446.75 2073.49 S 502.29 W 5943866.83 N 558153.46E 1.098 2073.49 5658.54 92.590 179.390 3334.54 3443.54 2166.83 S 501.41 W 5943773.50 N 558155.07E 1.336 2166.83 5749.54 93.120 179.020 3330.01 3439.01 2257.71 S 500.15 W 5943682.63 N 558157.04E 0.710 2257.71 5843.93 93.210 179.780 3324.80 3433.80 2351.95 S 499.16 W 5943588.40 N 558158.76E 0.810 2351.95 5939.95 91.850 180.620 3320.56 3429.56 2447.87 S 499.50 W 5943492.48 N 558159.17E 1.664 2447.87 6033.78 92.140 180.880 3317.29 3426.29 2541.64 S 500.73 W 5943398.71 N 558158.67E 0.415 2541.64 6126.85 91.650 179.790 3314.21 3423.21 2634.65 S 501.27 W 5943305.69 N 558158.85E 1.283 2634.65 6221.88 91.220 178.840 3311.83 3420.83 2729.65 S 500.13 W 5943210.71 N 558160.73E 1.097 2729.65 6315.66 90.250 178.430 3310.63 3419.63 2823.39 S 497.90 W 5943116.99 N 558163.69E 1.123 2823.39 6406.27 91.270 179.530 3309.43 3418.43 2913.98 S 496.29 W 5943026.42 N 558166.01E 1.656 2913.98 6500.66 92.190 178.480 3306.58 3415.58 3008.31 S 494.65 W 5942932.10 N 558168.38E 1.479 3008.31 6593.36 92.590 180.050 3302.71 3411.71 3100.91 S 493.46 W 5942839.51 N 558170.29E 1.746 3100.91 9 November, 2005 - 13:12 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1 J Pad - 1J-154L2 Your Ref.• API 500292325461 Job No. AK-ZZ-0003956462, Surveyed: 26 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 6687.48 92.190 181.010 3298.79 3407.79 3194.95 S 494.33 W 6781.46 88.020 181.250 3298.61 3407.61 3288.89 S 496.18 W 6875.39 91.330 181.640 3299.15 3408.15 3382.77 S 498.55 W 6966.69 90.840 179.980 3297.42 3406.42 3474.04 S 499.84 W 7061.34 90.710 179.470 3296.14 3405.14 3568.68 S 499.39 W 7156.97 91.390 179.470 3294.39 3403.39 7254.28 91.760 179.230 3291.71 3400.71 7350.81 90.910 178.590 3289.46 3398.46 7446.36 90.830 180.430 3288.01 3397.01 7543.67 90.180 179.780 3287.15 3396.15 7639.63 89.600 180.910 3287.34 3396.34 7736.18 89.980 180.330 3287.69 3396.69 7833.54 92.880 181.150 3285.26 3394.26 7932.23 88.450 178.700 3284.12 3393.12 8027.46 87.500 178.300 3287.48 3396.48 8123.83 86.340 178.730 3292.66 3401.66 8223.20 87.140 181.610 3298.31 3407.31 8321.29 87.640 181.420 3302.78 3411.78 8417.94 88.570 181.180 3305.97 3414.97 8513.67 88.640 181.090 3308.31 3417.31 8609.74 8706.62 8802.50 8899.85 8995.79 9092.06 9189.37 9286.11 9382.04 9479.43 9577.40 9676.00 9770.53 9868.36 9963.84 89.190 91.890 93.740 92.890 92.020 3664.29 S 3761.56 S 3858.05 S 3953.58 S 4050.88 S 4146.84 S 4243.38 S 4340.69 S 4439.34 S 4534.48 S 498.50 W 497.40 W 495.57 W 494.75 W 494.93 W 495.50 W 496.55 W 497.81 W 497.68 W 495.18 W Global Coordinates Northings Eastings (ft) (ft) 5942745.47 N 558170.15 E 5942651.52 N 558169.03 E 5942557.62 N 558167.40 E 5942466.34 N 558166.82 E 5942371.70 N 558168.01 E 5942276.10 N 558169.64 E 5942178.85 N 558171.50 E 5942082.38 N 558174.09 E 5941986.86 N 558175.65 E 5941889.56 N 558176.23 E 5941793.60 N 558176.40 E 5941697.05 N 558176.10 E 5941599.73 N 558175.60 E 5941501.09 N 558176.50 E 5941405.97 N 558179.73 E 4630.68 S 492.69 W 5941309.80 N 558182.98 E 4729.87 S 492.99 W 5941210.60 N 558183.45 E 4827.83 S 495.58 W 5941112.63 N 558181.63 E 4924.40 S 497.77 W 5941016.04 N 558180.19 E 5020.08 S 499.66 W 5940920.35 N 558179.04 E 5116.13 S 499.92 W 5940824.30 N 558179.53 E 5212.99 S 499.57 W 5940727.44 N 558180.63 E 5308.75 S 500.66 W 5940631.68 N 558180.29 E 5405.92 S 502.53 W 5940534.51 N 558179.18 E 5501.75 S 504.05 W 5940438.66 N 558178.40 E Dogleg Rate (°/100ft) 1.104 4.444 3.548 1.895 0.556 0.711 0.453 1.102 1.927 0.945 1.324 0.718 3.095 5.129 1.082 1.284 3.003 0.545 0.994 0.119 2.029 3.025 2.025 0.926 1.151 92.710 179.030 3290.79 3399.79 5597.94 S 503.71 W 5940342.48 N 558179.49E 1.752 95.190 177.370 3284.09 3393.09 5694.96 S 500.67 W 5940245.49 N 558183.29E 3.064 94.010 177.020 3276.33 3385.33 5791.27 S 495.95 W 5940149.21 N 558188.76E 1.272 92.210 177.410 3271.13 3380.13 5886.94 S 491.30 W 5940053.58 N 558194.16E 1.920 93.260 177.610 3266.48 3375.48 5984.13 S 487.07 W 5939956.43 N 558199.14E 1.097 93.810 179.320 3260.44 3369.44 6081.87 S 484.45 W 5939858.71 N 558202.52E 1.830 92.160 182.710 3255.30 3364.30 6180.30 S 486.20 W 5939760.27 N 558201.54E 3.819 91.650 181.320 3252.16 3361.16 6274.72 S 489.52 W 5939665.83 N 558198.95E 1.566 91.170 180.410 3249.75 3358.75 6372.51 S 490.99 W 5939568.03 N 558198.24E 1.051 88.510 179.450 3250.02 3359.02 6467.98 S 490.88 W 5939472.57 N 558199.10E 2.962 179.220 3310. 12 3419 .12 180.360 3309. 21 3418 .21 180.950 3304. 50 3413 .50 181.250 3298. 87 3407 .87 180.570 3294. 76 3403 .76 ConocoPhillips Vertical Section 3194.95 3288.89 3382.77 3474.04 3568.68 3664.29 3761.56 3858.05 3953.58 4050.88 4146.84 4243.38 4340.69 4439.34 4534.48 4630.68 4729.87 4827.83 4924.40 5020.08 5116.13 5212.99 5308.75 5405.92 5501.75 5597.94 5694.96 5791.27 5886.94 5984.13 6081.87 6180.30 6274.72 6372.51 6467.98 Comment • • 9 November, 2005 - 13:12 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-154L2 Your Ref.• API 500292325461 Job No. AK-ZZ-0003956462, Surveyed: 26 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10055.74 85.920 178.610 3254.48 3363.48 6559.75 S 489.32 W 5939380.81 N 558201.37 E 10144.75 85.920 178.990 3260.82 3369.82 6648.51 S 487.46 W 5939292.06 N 558203.92 E 10233.93 89.660 180.620 3264.25 3373.25 6737.61 S 487.16 W 5939202.97 N 558204.91 E 10325.95 88.360 179.610 3265.84 3374.$4 6829.61 S 487.35 W 5939110.97 N 558205.45 E 10416.54 87.150 179.520 3269.39 3378.39 6920.13 S 486.66 W 5939020.46 N 558206.84 E 10507.75 88.200 179.370 3273.09 3382.09 7011.25 S 485.78 W 5938929.34 N 558208.43 E 10597.70 90.530 178.970 3274.09 3383.09 7101.18 S 484.47 W 5938839.43 N 558210.43 E 10688.25 92.690 180.150 3271.55 3380.55 7191.69 S 483.78 W 5938748.93 N 558211.83 E 10779.47 95.590 181.830 3264.96 3373.96 7282.64 S 485.35 W 5938657.97 N 558210.97 E 10865.65 95.500 182.170 3256.63 3365.63 7368.37 S 488.34 W 5938572.22 N 558208.65 E 10916.07 94.480 182.920 3252.25 3361.25 7418.55 S 490.57 W 5938522.03 N 558206.81 E - 10964.00 94.480 182.920 3248.50 3357.50 7466.27 S 493.01 W 5938474.29 N 558204.74 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10964.OOft., The Bottom Hole Displacement is 7482.53ft., in the Direction of 183.778° (True). ConocoPhillips Dogleg Vertical Rate (°/100ft) 2.962 0.426 4.574 1.789 1.339 1.163 2.628 2.718 3.672 0.406 2.508 0.000 Section Comment 6559.75 6648.51 6737.61 6829.67 6920.13 7011.25 7101.18 7191.69 7282.64 7368.37 7418.55 7466.27 Projected Survey • • 9 November, 2005 - 13:12 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-154L2 Your Ref.• API 500292325461 Job No. AK ZZ-0003956462, Surveyed: 26 October, 2005 Western North Slope Comments Measured Station Coordinates Depth ND Northings Eastings Comment (ft) (ft) (ft) (ft) 4062.53 3446.21 574.07 S 531.32 W Tie-On Point 4079.00 3449.58 590.18 S 530.83 W Window Point 10964.00 3357.50 7466.27 S 493.01 W Projected Survey Survey tool program for 1J-154L2 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 719.00 718.67 To Measured Vertical Depth Depth (ft) (ft) 719.00 718.67 10964.00 3357.50 Survey Tool Description CB-SS-Gyro (1J-154) MWD+IIFR+MS+SAG (1J-154) ConocoPhillips ~J • 9 November, 2005 - 13:12 Page 5 of 5 DrillQuesf 3.03.06.008 • • 05-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-154 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,062.53' MD Window /Kickoff Survey: 4,079.00' MD (if applicable) Projected Survey: 10,964.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~~ ~ /~ Date (~lo~r.,~,~1 (n Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ ~~ ~ ~., it ~,. FRANK H. MURKOWSKI, GOVERNOR 1 ~t~~ ~~~~~~r+ ~~ OIL ~ V[~~ ~'~ 333 W. 7TM AVENUE. SUITE 100 C01~5ERQATIOIQ COMIrII5SI011T ~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 2767542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1J-154L2 ConocoPhillips Alaska, Inc. Permit No: 205-037 Surface Location: 2133' FSL, 2569' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 53' FNL, 2181' FWL, SEC. 11, T10N, R10E Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1J-154, Permit No. 205-035, API 50-029-23254-61. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t fitness any required test. Contact the Commission's petroleum field inspector at (907) 659~(pager). DATED this day of March, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~ ~~ ~/ I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL MAR 0 7 10D5 20 AAC 25.005 1 a. Type of Work: Drill / Redrill 1 b. Current Well Class: Exploratory Develop Ki ~ Re-entry ^ Stratigraphic Test ^ Service Q Development Gas ^ ~11Gh~1 ~QSngle Zone ^/ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-154L2 3. Address: 6. Proposed Depth: / 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 10970' ~ ND: 3366' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Properly Designation: ~ Surface: 2133' FSL, 2569' FEL, Sec. 35, T11N, R10E, UM ADL 25661 & 25662. West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1584' FSL, 2191' FWL, Sec. 35, T11N, R10E ALK 471 & 2177 4126/2005 Total Depth: 9. Acres in Property: 14. Distance to *-~ ~l~s .~,~,~~' 53' FNL, 2181' FWL, Sec. 11, T10N, R10E ~ 2560 Nearest Property: <3 miles bey: 3d ~~. 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest !l?!~Z- Surface: x- 558640 y- 5945944 Zone- 4 (Height above GL): 1 D8' AMSL feet Well within Pool: , 16. Deviated wells: - Kickoff depth: 4048 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) Maximum Hole Angle: 93° deg Downhole: 1562 psig Surface: 1180 psig ' 18. Casing Program S if ti Setting Depth Quantity of Cement Si pec ica ons T B tt ze op o om c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2273' 28' 28' 2301' 2203' 470 sx AS Lite, 140 sx DeepCrete 9- 29.7# L-80 BTCM 322' 3671' 360 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 6922' 4048' 3441' 10970' 6' o ed r 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 Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth ND {ft): 20. Attachments: Filing Fee BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane ClOninger @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` Phone ~6S'6$ ld Date yl3la.~ P h All D Commission Use Only Permit to Drill '^'~ ~ ~ r ~ ~ API Number: "^~~ ~ ~, Permit Approval See cover letter for other re uirements Number: / 50-~ ~ Date: q Conditions of approval Samples required Yes ^ No ~, Mud log required Yes ^ No ~„ H y d rogen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ e°~F-~fi~ ;~~ ~ i 7 Other: 3~ La ~i+ ~..,~..~ C ~'f-S~' , ~~~ ~'•~ `- `J~~ ~ -~ ~-~~ ~Y_'~.~~~C` i"~"'~~ ~C~L ~twQV"~'~'$ . APPROVED BY Approved bY: THE COMMISSION Date: r/sF.as' ~ ~ ~ i k Form 10-401 Revised 06/2004 ~ ~ ". ~"# ~' G f~°, Submit in Duplicate • ~lication for Permit to Drill, Well 1J-154 L2 Revision No.0 Saved: 1-Mar-05 Permit It -West Sak Well #1J-154 L2 •~°~ r.w +'t Application for Permit to Dri/1 Document,; f~1~~cV1~~ll nna~~mixe y~ell ~o~+~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 Information ....................................................................................3 Requirements of 20 AAC 25.005 (c}(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program .............................................................................3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ....................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ..............................................................................................4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ......................................................................................................5 Requirements of 20 AA C 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 7J-154L2 PERMIT IT.doc Page 1 of 6 Printed: 7-Mar-05 ORIG!N.AL • ~lication for Permit to Drill, Well 1 J-154 L2 Revision No.O Saved: 1-Mar-05 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 Pian ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ................................................................................................ 6 Attachment 3 Well Schematic ................................................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (t) 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 25.1140(6). For a welt with multiple wel! branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated far 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 13-154 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri// must be accompanied by each of the fol/owing items, except far an item a/ready on file with the commission and identifed in the application. (2) a p/at identifying the properly and the propertys owners and showing (A)the coordinates of the proposed location of the we/I at the surface, at the top of each objective formation, and at total depth, referenced to governmenta/section lines (B) the coordinates of the proposed location of the wet/ at the surface, referenced to the state plane coordinate system for this state as maintained by the Natrona/ Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective forn~ation and at total depth; Location at Surface 2 133' FSL 2 569' FEL Section 35 T11N R10E ' ASPZone 4NAD27Coordinates RKB Elevation 108.0' AMSL Northings: 5,945,944 Eastings: 558,640 Pad Elevation 80.0' AMSL Location at Top of Productive Interval West Sak ~~D" Sand 1,584' FSL, 2,191' FWL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB; 4 048 Northings: 5,945,391 Eastings: 558,124 Total ~ertica/De th RKB: 3 441 Total ~ertica/ De th SS.• 3 333 Location at Total De th 53' FNL 2 181' FWL Section 11 T10N R10E ASPZone 4 NAD 27 Coordinates Measured De th RKB.' 10 970 Northings; 5,938,475 Eastings: 558,175 Tota! f/ertical De th RKB; 3 366 Total vertical De th SS•' 3 258 and (D) other information required 6y 20 AAC 25.050(6),' ~ ~ °~.~ ~~~ 1J-154L2 PERMl7/T.doc Page 2 of 6 Printed: 1-Mar-05 ~lication for Permit to Drill, Well 1J-154. L2 Revision No.O Saved: 1-Mar-05 Requirements of 20 AAC 25.050(b) Ifa well is to be intentiona//y deviated, the app/ication for a Permit to Dri// (Form 10-401) must (I) inc/ude a plat, drawn to a suitable scale, showing the path of the proposed wel/bore, including all adjacent weUbores within 200 feet ofany portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wef/s, to the extent that those names are known or discoverable in pub/ic records, and show that each named operator has been furnished a copy of the application by certified mail; ar (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC25.035, 20 AAC25.035, 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 1J-54 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except far an item already an file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "D" sand formation is 1,180 psi, calculated thusly: MPSP =(3,470 ft TVD)(0.45 - 0.11 psi/ft) =1,180 psi , (&) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes ofha/e problems such as abnorma//y gea pressured strata, lost circulation zones, and zones that have a propensity far differential sticking; Please see Attachment 2: 1J-154 L2 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 accompany"ed by each of the following items, except for an item a/ready on Fi/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC25.030(t); The parent wellbore, iJ-154, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-154L2 PERMIT IT.doc Page 3 of 6 F~ ~ ~ ~ ~ Printed: 1-Mar-05 r~ ~lication for Permit to Drill, Well 1 J-154 L2 Revision No.O Saved: 1-Mar-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/icatron for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified m the appiicatian: (6} a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated finer, or screen to be installed; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft) ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 8,432 4,440 / 3,526 12,872 / 3,588 Slotted- no cement Slotted Lateral (1J-154) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 6,912 4,364/ 3,513 11,276 / 3,439 Slotted- no cement eral (SJ-154 Li) _-~__ 4-1/2 Slotted 6-3/4" D Sand Lateral (1J-154 L2) 12.6 L-80 IBTM 6,922 4,048/ 3,441 10,970 / 3,366 Slotted- no cement 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, vnfess this requirement is waived by the commission under 20 AAC25.035(h}(2}; No diverter system will be utilized during operations on 1J-154 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except far 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 20AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit ( ) 9.0 Plastic Viscostiy 15-25 (Ib/100 s fl Yield Point 18-28 (cP HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water Ratio 70 / 30 Electrical 650-900 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 1J-154L2 PERM/T IT:doc Page 4 of 6 ~~''~~ ~ ~ ~ Printed: 1-Mar-05 F i `~ J • ~lication for Permit to Drill, Well 1 J-154 L2 Revision No.O Saved: 1-Mar-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item already on fr/e with the commission and identified in the app/ication; (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnormally geo pressured strata as required by 20AAC25.033(l); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drit/ must be accompanied by each of the fo//awing items, except for an item already an fr/e with the commission and identified in the application: (10) for an exploratory or stratigraphic test wet/, a seismic refraction or reflection analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applcatian for a Permit to Drill must be accompanied by each of the fallowing items, except far an item already on fr/e with the commission and identified in the app/ication; (11) for a we// drilled fram an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed canditions as required by 20 AAC 25.061(6); 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 fol/owing items, except for an item already on file with the commission and identified in the app/ication; (12) evidence showing that the requirements of20 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 ofthe fol/owing items, except far an item already an file with the commission and identified in the applcation: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-154 Application for Permit to Drill. Run and set Baker WindowMaster whipstock system, at window point of 4,048' MD / 3,411' TVD, the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at 10,970' MD / 3,366' TVD, as per directional plan.' 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. ' 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. ~~~~. .,,~ ,. _ _ a .. 1J-154L2 PERMIT IT.doc Page 5 of 6 Printed: 1-Mar-05 • ~lication for Permit to Drill, Well 1J-154 L2 Revision No.0 Saved: 1-Mar-05 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days. (flowback cleanup}. Shut well in. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri/l music be accompanied by each of the fo/lowing items, except for an item a/ready on fr/e with the rnmrnission and identified in the application: (X4) a general description of how the operator plans to dispose ofdri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 2Q AAC 25.08f1 for an annular disposal operation in the well,; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ~~~. 1J-154L2 PERMIT IT.doc Page 6 of 6 Printed: 1-Mar-05 ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-154 (M6) 1J-154 L2 Plan: 1 J-154 L2 (wp06) Proposal Report 14 February, 2005 t'~t"~~-,~l~~'t DiR~L.LIIVG 5ERV~GES A Halliburton Company ~~~,r~e ~~ ConocoPhilli s p Alaska Well: Plan 1J-154 (M6) Wellbore: 1J-154 L2 A HaNWUrton Canpawy 7 518" TOW 1584'FSL & 2191'F WL -Sect 35 - T11 N - R10E :Drill out 6 3/4" Hole : 4048 ft MD, 3441 ft TVD Bottom Whipstock :Assume 15.90°/100ft : 4060 ft MD, 3444 ft TVD End of 30' Rathole :Build @ 6.25°/100ft , 4090 ft MD, 3450 ft TVD Begin Sail @94.55° Inc & 179.91 ° Azi, 4356 ft MD, 3467 ft TVD Continue Build (a 6.25°/100ft , 4441 ft MD, 3461 ft TVD °''O s~dJ ~.i~ -%~ •~~ ~' -~,~ l; Sin Undulations in D-Sand -Build @ 1 °/100 ft , 8297 ft MD, 3400 ft ND End Undulations in D-Sand , 10934 ft MD, 3368 ft TVD LEGEND $ Plan 1J-154 (M6), 1J-154, 1J-154 (wp06) VO -~ Plan 1J-154 (M6), 1J-154 L1, 1J-154 L1 (wp06) VO $ 1 J-154 L2 (wpO6) 4 1/2" Begin Geosteering in D-Lateral :Target 15' from top D : 4500.62 ft MD, 3457.94 ft TVD ~ BHL : 53' FNL & 2181' F WL -Sect 11 - T10N - R10E : 10970 R MD, 3366 ft TVD -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 8125 8750 9375 Vertical Section at 180.00° (1250 fUn) 10 3/4" Casing Pt 1875 ~ 2500 N L n -- ~ 3125 -- ~ -- - - C d d F 3750 ~ - r~v~cv... - gite: Kuparuk 1J Pad CpnpCp~'11~~I#?S Well: Plan 1J-154 (M6) Wellbore: 1J-154 L2 ~~~= k;, Plan: 1J-154 L2 (wp06) West(-)/East(+) (1250 ft/in) 4375 sooo 1250 1875 2500 3125 3750 p 625 -2500 -1875 -1250 -625 7 5/8" TOW -1584'FSL & 2191'FWL - Sed 35 - T11 N - R1 OE :Drill out 6 3/4" Hole : 4048 ft MD. 3441 ft ND 625 10 3l4" Casing Pt Bottom Whipstock :Assume 15.90°I100tt : 4060 ft MD, 3444 ft T ~~ 0 End of 30' Rathole : Build ~ 6.25°/100H , 4090 ft MD, 3450 ft TVD T -625 ~ M Azimuths to True Magnetic North:: -1250 Magnetic Strength: 575 Dip Angle. Date: 9/1: Motlel: BGGi -1675 I \ I J Begin Sail ~ 94 55 Inc & 179 91° Azi 4356 ft MD 3467 tt ND 80° Continue Build ~ 6.25°/100ft , 4441 ft MD, 3461 tt TV 160° in D-Lateral :Target 15' from iop D : 4500.62 ft MD, 3457.94 ft TVD c 0 u~ N L 1= O Z r 0 180° 180° ~ Begin Undulations in D-Sand -Build @ 1°/100 ft , 6297 ft MD, 3400 ft ND S 180° Z 0 3 t N CJr LEGEND ~ --~- Plan 1J-154 (M6), 1J-154, 1J-154 (wp06) VO `~ -~- Plan 1J-154 (M6), 1J-154 L1, 1J-154 L1 (wp06) VO $ 1 J-154 L2 (wp06) End Undulations in D-Sand , 10934 ft MD, 3368 ft TVD 4 112" 53' FNL 8 2181' FWL - Sed 11 - T10N - R10E : 10970 ft MD, 3366 ft TVD ii~~ll -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 West(-)/East(+) (1250 ft/in) ~ _ , 4375 5000 875 125 125 `'' Phitli C Halliburton Company ~p~P'~1,~-51..~~'1 onoco ps Planning Report -Geographic Alaska A Halllburton Company Database: EDM 2003.11,Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Wellhead(t08'} @ 108.OOft (Wellhead(108')}' Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 1'OS.OOft (Wellhead(108'}) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-154.(M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L2 Design: 1J-154 L2(wp06) Project Kuparuk"River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Wel! Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor i Well Plan 1J-154 (M6) Well Postion +N/-S 0.00 ft Northing: 5,945,944.10 ft ~ Latitude: +E/-W 0.00 ft Easting: 558,539.50 ft ~ Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: i Wellbore Magnetics I~- - Design Audit Notes: Version: Vertical Section: 1 J-154 L2 Model Name Sample Date bggm2004 9/13/2004 1J-154 i2 (wp06) Declination Dip Angle (°- 1°) 24.62 80.72 Phase: PLAN Tie On Depth: Depth From (TVD} +N/-S +FJ-W Ift) (ft1 (ftl zs.oo o.oo o.oo Direction (°) 1so.oo 70° 15' 46.510" N 149° 31' 33.379" W 0.00 ft i Field Strength (nT) s~,s7z_ 4,047.85 2/14/2005 12:44:42PM Page 2 of 8 COMPASS 2003.11 Build 50 ~~ t ! ~•' P!' illi C Halliburton Company ~p~-+,-,y_~u,", onoco t ps Planning Report -Geographic ~ f~[lSka A Haal6urton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154:(M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Wellhead(108') ~ 108.OOft:(Wellliead(1089} Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 148.OOft (Wellhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L2 Design: 1J-154 L2 (wp06) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/_yy Rate Rate Rate ~O (ft) (°) (°- (ftl lftl {ft) (°I100ft) (°/100ft) (°1100ft) {°) 4,047.85 76.00 179.97 3,441.00 -549.12 -519.84 0.00 0.00 0.00 0.00 4,059.85 77.91 179.97 3,443.71 -560.81 -519.84 15.90 15.90 0.00 0.00 4,089.85 77.91 179.97 3,449.99 -590.15 -519.82 0.00 0.00 0.00 0.00 4,356.14 94.55 179.91 3,467.44 -854.93 -519.54 6.25 6.25 -0.02 -0.21 4,440.58 94.55 179.91 3,460.74 -939.10 -519.41 0.00 0.00 0.00 0.00 4,500.61 90.80 179.97 3,457.94 -999.05 -519.35 6.25 -6.25 0.10 179.08 4,522.66 90.14 179.99 3,457.76 -1,021.11 -519.34 3.00 -3.00 0.08 178.43 5,250.84 90.14 179.99 3,456.00 -1,749.28 -519.19 0.00 0.00 0.00 0.00 5,286.24 91.20 180.06 3,455.59 -1,784.68 -519.20 3.00 2.99 0.21 4.09 5,696.98 91.20 180.06 3,447.00 -2,195.33 -519.66 0.00 0.00 0.00 0.00 5,717.27 91.81 180.03 3,446.47 -2,215.62 -519.68 3.00 2.99 -0.19 -3.57 6,652.57 91.81 180.03 3,417.00 -3,150.45 -520.10 0.00 0.00 0.00 0.00 6,688.56 90.73 179.93 3,416.20 -3,186.42 -520.08 3.00 -2.99 -0.28 -174.69 7,096.67 90.73 179.93 3,411.00 -3,594.51 -519.56 0.00 0.00 0.00 0.00 7,114.59 91.26 180.00 3,410.69 -3,612.43 -519.55 3.00 2.97 0.43 8.29 7,871.96 91.26 180.00 3,394.00 -4,369.61 -519.59 0.00 0.00 0.00 0.00 7,905.48 90.28 180.21 3,393.55 -4,403.12 -519.65 3.00 -2.94 0.61 168.35 8,097.11 90.28 180.21 3,392.62 -4,594.76 -520.35 0.00 0.00 0.00 0.00 8,204.34 87.09 179.75 3,395.08 -4,701.94 -520.31 3.00 -2.97 -0.43 -171.86 8,297.05 87.09 179.75 3,399.78 -4,794.53 -519.90 0.00 0.00 0.00 0.00 8,797.05 92.09 179.75 3,403.33 -5,294.35 -517.73 1.00 1.00 0.00 0.00 9,297.05 93.09 179.75 3,380.71 -5,793.83 -515.56 0.20 0.20 0.00 0.00 9,797.05 88.84 179.75 3,372.26 -6,293.64 -513.38 0.85 -0.85 0.00 180.00 10,297.05 89.34 179.75 3,380.17 -6,793,57 -St1.21 0.10 0.10 0.00 0.00 10,934.09 92.88 182.09 3,367.80 -7,430.26 -521.40 0.67 0.56 0.37 33.40 10,969.87 92.88 182.09 3,366.00 -7,465.97 -522.71 0.00 0.00 0.00 0.00 2/14/2005 12:44:42PM Page 3 of 8 COMPASS 2003.11 Build 50 ~ Halliburton Company ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11. Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1d Pad North Reference: Well; Plan 1J-154 (M6) Survey Calculation Method: Wellbore: SJ-154 t2 Design: 1J-154 L2 (wp06) ~~'1ry..~~ A Halllburton Company Well Plan 1J-154,(M6) Wellhead(108');@ 108.OOft (Wellhead(108')) Wellhead(108') @ 108:OOft(WeNhead(108')) True ~ Minimum Curvature ~ Planned Survey 1J-154 L2 (wp06) Map Map MD I nclination Azimuth TVD SSTVD +N!-S +E/-yy Northing Easting DLSEV Vert Section (ft) (°) (°) Iftl (ft) (ft) (ft) (ft) (ft) (°l100ft) (ftl ~ 4,047.85 76.00 179.97 3,441.00 3,333.00 -549.12 -519.84 5,945,391.00 558,124.00 0.00 549.12 75/8" TOW • 1ti84'PSL & 2191'FWL -Sect 35 - T71N - R 10E :Drill out 53/4" Bole : 4048 ft MD, 3441 ft TVD - 75/8" Window Top 4,059.85 77.91 179.97 3,443.71 3,335.71 -560.81 -519.84 5,945,379.31 558,124.10 15.90 560.81 Bottom Whipstock :Assume 15.90°l100ft : 4060 ft MD, 3444 ft TVD 4,089.85 77.91 179.97 3,449.99 3,341.99 -590.15 -519.82 5,945,349.98 558,124.34 0.00 590.15 End of 30' Rathoie : Build ~ 6.25°HOOft , 4090 ft MD, 3450 ft TVD 4,100.00 78.54 179.97 3,452.07 3,344.07 -600.08 -519.81 5,945,340.04 558,124.42 6.24 600.08 4,200.00 84.79 179.94 3,466.55 3,358.55 -698.98 -519.74 5,945,241.16 558,125.27 6.25 698.98 4,300.00 91.04 179.92 3,470.18 3,362.18 -798.86 -519.62 5,945,141.29 558,126.16 6.25 798.86 4,356.14 94.55 179.91 3,467.44 3,359.44 -854.93 -519.54 5,945,085.23 558,126.68 6.25 854.93 Begin Sail ~ 94.55° Inc 8179.91° Azi, 4366 ft MD, 3467 ft TVD 4,400.00 94.55 179.91 3,463.96 3,355.96 -898.65 -519.47 5,945,041.52 558,127.09 0.00 898.65 4,440.58 94.55 179.91 3,460.74 3,352.74 -939.10 -519.41 5,945,001.07 558,127.47 0.00 939.10 Continue Build ~ 6.25°NOOft , 4441 ft MD, 3461 ft TVD 4,500.00 90.84 179.97 3,457.95 3,349.95 -998.45 -519.35 5,944,941.74 558,127.99 6.25 998.45 4,500.61 90.80 179.97 3,457.94 3,349.94 -999.05 -519.35 5,944,941.13 558,128.00 6.25 999.05 Begin Geosteering In O-Lateral :Target 15' from top D : 4500.62 ft MD, 3457.94 ft TVD -1J-154 L2 T(.45) (v3) 4,522.66 90.14 179.99 3,457.76 3,349.76 -1,021.11 -519.34 5,944,919.08 558,128.18 3.00 1,021.11 4,600.00 90.14 179.99 3,457.57 3,349.57 -1,098.45 -519.32 5,944,841.75 558,128.80 0.00 1,098.45 4,700.00 90.14 179.99 3,457.33 3,349.33 -1,198.44 -519.30 5,944,741.76. 558,129.60 0.00 1,198.44 4,800.00 90.14 179.99 3,457.09 3,349.09 -1,298.44 -519.28 5,944,641.78 558,130.40 0.00 1,298.44 4,900.00 90.14 179.99 3,456.85 3,348.85 -1,398.44 -519.26 5,944,541.79 558,131.20 0.00 1,398.44 5,000.00 90.14 179.99 3,456.61 3,348.61 -1,498.44 -519.24 5,944,441.80 558,131.99 0.00 1,498.44 5,100.00 90.14 179.99 3,456.36 3,348.36 -1,598.44 -519.22 5,944,341,82 558,132.79 0.00 1,598.44 5,200.00 90.14 179.99 3,456.12 3,348.12 -1,698.44 -519.20 5,944,241.83 558,133.59 0.00 1,698.44 5,250.84 90.14 179.99 3,456.00 3,348.00 -1,749.28 -519.19 5,944,191.00 558,134.00 0.00 1,749.28 1J-154 L2 T1 (v3- 5,286.24 91.20 180.06 3,455.59 3,347.59 -1,784.68 -519.20 5,944,155.60 558,134.26 3.00 1,784.68 5,300.00 91.20 180.06 3,455.30 3,347.30 -1,798.44 -519.22 5,944,141.85 558,134.35 0.00 1,798.44 5,400.00 91.20 180.06 3,453.21 3,345.21 -1,898.42 -519.33 5,944,041.88 558,135.02 0.00 1,898.42 5,500.00 91.20 180.06 3,451.12 3,343.12 -1,998.39 -519.44 5,943,941.91 558,135.69 0.00 1,998.39 5,600.00 91.20 180.06 3,449.03 3,341.03 -2,098.37 -519.55 5,943,841.95 558,136.35 0.00 2,098.37 5,696.98 91.20 180.06 3,447.00 3,339.00 -2,195.33 -519.66 5,943,745.00 558,137.00 0.00 2,195.33 1J-154 L2 T2 (v3) 5,700.00 91.29 180.06 3,446.93 3,338.93 -2,198.35 -519.66 5,943,741.98 558,137.02 2.98 2,198.35 5,717.27 91.81 180.03 3,446.47 3,338.47 -2,215.62 -519.68 5,943,724.72 558,137.14 3.00 2,215.62 5,800.00 91.81 180.03 3,443.86 3,335.86 -2,298.30 -519.71 5,943,642.04 558,137.75 0.00 2,298.30 5,900.00 91.81 180.03 3,440.71 3,332.71 -2,398.25 -519.76 5,943,542.10 558,138.48 0.00 2,398.25 6,000.00 91.81 180.03 3,437.56 3,329.56 -2,498.20 -519.80 5,943,442.17 558,139.22 0.00 2,498.20 6,100.00 91.81 180.03 3,434.41 3,326.41 -2,598.15 -519.85 5,943,342.23 558,139.95 0.00 2,598.15 6,200.00 91.81 180.03 3,431.26 3,323.26 -2,698.10 -519.89 5,943,242.29 558,140.68 0.00 2,698.10 6,300.00 91.81 180.03 3,428.11 3,320.11 -2,798.05 -519.94 5,943,142.35 558,141.41 0.00 2,798.05 6,400.00 91.81 180.03 3,424.96 3,316.96 -2,898.00 -519.98 5,943,042.41 558,142.15 0.00 2,898.00 6,500.00 91.81 180.03 3,421.81 3,313.81 -2,997.95 -520.03 5,942,942.48 558,142.88 0.00 2,997.95 6,600.00 91.81 180.03 3,418.66 3,310.66 -3,097.90 -520.08 5,942,842.54 558,143.61 0.00 3,097.90 2!14/2005 12:44:42PM Page 4 0/ 8 COMPASS 2003.11 Build 50 ~~ ~~,~ ~' ~ C Philli Halliburton Company ~p~l"+~f-~~.N"1 onoco ps Punning Report -Geographic ~aS-Cc1 A HalllbuRan Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: WeII Plan 1J-154 (M6) Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: Wellhead(108') @ 108.OOft (Welihead(108')) Project: Kuparuk River Unit MD Reference: Weilhead(108') @ 108.OOft (Wellftead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Welibore: 1J-154 L7 Design: 1J-154 L2 (wp06) Planned Survey 1J-154 L2 (wp06) j Map Map MD inclination Azimuth TVD SSTVp +NI-g +E/-W Northing Easting DLSEV Vert Section Ift1 (°) (°) Ift1 Ift- (fC) (ft) (ft) (ft) (°HOOftI (ftl 6,652.57 91.81 180.03 3,417.00 3,309.00 -3,150.45 -520.10 5,942,790.00 558,144.00 0.00 3,150.45 1J-154 L2 T3 (v3) 6,688.56 90.73 179.93 3,416.20 3,308.20 -3,186.42 -520.08 5,942,754.03 558,144.30 3.00 3,186.42 6,700.00 90.73 179.93 3,416.06 3,308.06 -3,197.87 -520.07 5,942,742.59 558,144.40 0.00 3,197.87 6,800.00 90.73 179.93 3,414.78 3,306.78 -3,297.86 -519.94 5,942,642.61 558,145,31 0.00 3,297.86 6,900.00 90.73 179.93 3,413.51 3,305.51 -3,397.85 -519.81 5,942,542.63 558,146.21 0.00 3,397.85 7,000.00 90.73 179.93 3,412.23 3,304.23 -3,497.84 -519.68 5,942,442.65 558,147.12 0.00 3,497.84 7,096.67 90.73 179.93 3,411.00 3,303.00 -3,594.51 -519.56 5,942,346.00 558,148.00 0.00 3,594.51 1J-1li4 LZ T4 (v3) 7,100.00 90.83 179.94 3,410.95 3,302.95 -3,597.84 -519.55 5,942,342.67 558,148.03 2.97 3,597.84 7,114.59 91.26 180.00 3,410.69 3,302.69 -3,612.43 -519.55 5,942,328.08 558,148.15 3.01 3,612.43 7,200.00 91.26 180.00 3,408.81 3,300.81 -3,697.81 -519.55 5,942,242.71 558,148.81 0.00 3,697.81 7,300,00 91.26 180.00 3,406.60 3,298.60 -3,797.79 -519.56 5,942,142.75 558,149.58 0.00 3,797.79 7,400.00 91.26 180.00 3,404.40 3,296.40 -3,897.76 -519.56 5,942,042.78 558,150.35 0.00 3,897.76 7,500.00 91.26 180,00 3,402.20 3,294.20 -3,997.74 -519.57 5,941,942.82 558,151.13 0.00 3,997.74 7,600.00 91.26 180.00 3,399.99 3,291.99 -4,097.72 -519.58 5,941,842.86 558,151.90 0.00 4,097.72 7,700.00 91.26 180.00 3,397.79 3,289.79 -4,197.69 -519.58 5,941,742.89 558,152.67 0.00 4,197.69 7,800.00 91.26 180.00 3,395.59 3,287.59 -4,297.67 -519.59 5,941,642.93 558,153.44 0.00 4,297.67 7,871.96 91.26 180.00 3,394.00 3,286.00 -4,369.61 -519.59 5,941,571.00 558,154.00 0.00 4,369.61 1J-154 L2 T5 (v3) 7,900,00 90.44 180.17 3,393.58 3,285.58 -4,397.65 -519.64 5,941,542.96 558,154.18 3.00 4,397.65 7,905.48 90.28 180.21 3,393.55 3,285.55 -4,403.12 -519.65 5,941,537.49 558,154.20 3.00 4,403.12 8,000.00 90.28 180.21 3,393.09 3,285.09 -4,497.64 -519.99 5,941,442.98 558,154.59 0.00 4,497,64 8,097.11 90.28 180.21 3,392.62 3,284.62 -4,594.76 -520.35 5,941,345.87 558,155.00 0.00 4,594.76 1J-154 L2 T8 (v3) 8,100.00 90.19 180.19 3,392.61 3,284.61 -4,597.64 -520.36 5,941,342.99 558,155.01 2.97 4,597.64 8,200.00 87.22 179.77 3,394.86 3,286.86 -4,697.61 -520.32 5,941,243.04 558,155.82 3.00 4,697.61 8,204.34 87.09 179.75 3,395.08 3,287.08 -4,701.94 -520.31 5,941,238.70 558,155.88 3.00 4,701.94 8,297.05 87.04 179.75 3,399.78 3,291.78 -4,794.53 -519.90 5,941,146.13 558,157.00 0.00 4,794.53 Begin Undulations in DSand - Build ~ 1°I140 ft , 8297 ft MD, 3440 ft TVD -1J-154 L2 T7 (v3) 8,300.00 87.12 179.75 3,399.93 3,291.93 -4,797.48 -519.89 5,941,143.18 558,157.03 0.99 4,797.48 8,400.00 88.12 179.75 3,404.08 3,296.08 -4,897.39 -519.46 5,941,043.29 558,158.25 1.00 4,897.39 8,500.00 89.12 179.75 3,406.48 3,298.48 -4,997.36 -519.02 5,940,943.33 558,159.46 1.00 4,997.36 8,600.00 90.12 179.75 3,407.14 3,299.14 -5,097.35 -518.59 5,940,843.35 558,160.67 1.00 5,097.35 8,700.00 91.12 179.75 3,406.05 3,298.05 -5,197.34 -518.15 5,940,743.38 558,161.89 1.00 5,197.34 8,797.05 92.09 179.75 3,403.33 3,295.33 -5,294.35 -517.73 5,940,646.38 558,163.07 1.00 5,294.35 8,800.00 92.10 179.75 3,403.22 3,295.22 -5,297.30 -517.72 5,940,643.44 558,163.10 0.20 5,297.30 8,900.00 92.30 179.75 3,399.38 3,291.38 -5,397.23 -517.28 5,940,543.53 558,164.31 0.20 5,397.23 9,000.00 92.50 179.75 3,395.20 3,287.20 -5,497.14 -516.85 5,940,443.63 558,165.53 0.20 5,497.14 9,100.00 92.70 179.75 3,390.66 3,282.66 -5,597.03 -516.41 5,940,343.75 558,166.74 0.20 5,597.03 9,200.00 92.90 179.75 3,385.78 3,277.78 -5,696.91 -515.98 5,940,243.89 558,167.95 0.20 5,696.91 9,297.05 93.09 179.75 3,380.71 3,272.71 -5,793.83 -515.56 5,940,146.99 558,169.13 0.20 5,793.83 9,300.00 93.07 179.75 3,380.55 3,272.55 -5,796.78 -515.54 5,940,144.04 558,169.16 0.84 5,796.78 9,400.00 92.22 179.75 3,375.94 3,267.94 -5,896.67 -515.11 5,940,044.17 558,170.38 0.85 5,896.67 9,500.00 91.37 179.75 3,372.81 3,264.81 -5,996.62 -514.67 5,939,944.23 558,171.59 0.85 5,996.62 9,600.00 90.52 179.75 3,371.16 3,263.16 -6,096.60 -514.24 5,939,844.26 558,172.80 0.85 6,096.60 9,700.00 89.67 179.75 3,371.00 3,263.00 -6,196.60 -513.80 5,939,744.28 558,174.02 0.85 6,196.60 9,797.05 88.84 179.75 3,372.26 3,264.26 -6,293.64 -513.38 5,939,647.26 558,175.19 0.85 6,293.64 2/14/2005 12:44:42PM 44 Page 5 of 8 COMPASS 2003.11 Build 50 ~~ R ~a ~ L' P p. ~~ ; • / Halliburton Company Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-154 (M6} Survey Calculation Method: Wellbore: 1J-154 L2 Design: 1J-154 L2 (wp06) Planned Survey 1J-154 L2 (wp06) sp~-+ry-gun ~~fL.~.,ias ~sWV~ces A Halllburton Company Well Plan 1J-154 (M6) Wellhead(108') @ 108.OOft(Wellhead(108')) Wellhead(108'j@ 108.OOftjWellhead(108')), True Minimum Curvature Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E/.yy Northing Easting DLSEV Vert Section Iftl (°) (°) (ft) (ft) (ft) (ft) Iftl Iftl 1°/100ft1 (ftl li 9,800.00 88.85 179.75 3,372.32 3,264.32 -6,296.59 -513.37 5,939,644.31 558,175.23 0.10 6,296.59 9,900.00 88.95 179.75 3,374.24 3,266.24 -6,396.57 -512.93 5,939,544.34 558,176.44 0.10 6,396.57 10,000.00 89.05 179.75 3,376.00 3,268.00 -6,496.55 -512.50 5,939,444.38 558,177.66 0.10 6,496.55 10,100.00 89.15 179.75 3,377.57 3,269.57 -6,596.54 -512.06 5,939,344.41 558,178.87 0.10 6,596.54 10,200.00 89.25 179.75 3,378.98 3,270.98 -6,696.53 -511.63 5,939,244.43 558,180.08 0.10 6,696.53 10,297.05 89.34 179.75 3,380.17 3,272.17 -6,793.57 -511.21 5,939,147.41 558,181.26 0.10 6,793.57 10,300.00 89.36 179.76 3,380.20 3,272.20 -6,796.52 -511.19 5,939,144.46 558,181.30 0.66 6,796.52 10,400.00 89.92 180.13 3,380.84 3,272.84 -6,896.52 -511.10 5,939,044.47 558,182.17 0.67 6,896.52 10,500.00 90.47 180.49 3,380.50 3,272.50 -6,996.52 -511.64 5,938,944.48 558,182.41 0.67 6,996.52 10,600.00 91.03 180.86 3,379.19 3,271.19 -7,096.50 -512.82 5,938,844.50 558,182.00 0.67 7,096.50 10,700.00 91.58 181.23 3,376.92 3,268.92 -7,196.46 -514.64 5,938,744.55 558,180.96 0.67 7,196.46 10,800.00 92.14 181.59 3,373.67 3,265.67 -7,296.37 -517.10 5,938,644.62 558,179.28 0.67 7,296.37 10,900.00 92.69 181.96 3,369.46 3,261.46 -7,396.24 -520.20 5,938,544.75 558,176.96 0.67 7,396.24 10,934.09 92.88 182.09 3,367.80 3,259.80 -7,430.26 -521.40 5,938,510.72 558,176.02 0.67 7,430.26 i End Undulations in D-Sand , 10934 ft MD, 3388 ft TVD 10,969.87 92.88 182.09 3,366.00 ~ 3,258.00 -7,465.97 -522.71 5,938,475.00 558,175.00 0.00 7,465.97 BHL : 63' FNL & 2181' FWL -Sect 11 - T10N - R10E : 10970 ft MD, 3366 ft ND - 41 /2" -1J-154 L2 Toe (v3) 2/14/2005 12:44:42PM Page 6 of 8 COMPASS 2003.11 Build 50 4 ~ ~@ ~ t ~ • ti' Philli C Halliburton Company 5p~-,y_~(~,"', onoco ps Planning Report -Geographic Ak1Skc1 A Halliburton Company Database: EDM 2003.11 Sing le User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska fnc:(Kuparuk) TVD Reference: Wellhead(f 08') @ 108 .OOft (Wellhead(108')) Project: Kuparuk River Unit , MD Reference: Wetlhead(108') @ 108 .OOft (Wellhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L2 Design: 1J-154 L2 (wp06) GeologicTargets 1J-154 L2 ~i I TVD Target Name +NI-S +E!-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,394.00 1J-154 L2 T5 (v3) -4,369.61 -519.59 5,941,571.00 558,154.00 - Point 3,456.00 1J-154 L2 T1 (v3) -1,749.28 -519.19 5,944,191.00 558,134.00 - Point 3,411.00 1J-154 L2 T4 (v3) -3,594.51 -519.56 5,942,346.00 558,148.00 - Point 3,410.00 1J-154 L2 T7 (v3) -4,794.66 -519.90 5,941,146.00 558,157.00 - Point 3,387.00 1J-154 L2 T8 (v3) -5,493.73 -521.35 5,940,447.00 558,161.00 -Point 3,397.00 1J-154 L2 Prognosed Fault #1 -4,717.64 -521.30 5,941,223.00 558,155.00 - Point 3,381.00 1J-154 L2 T9 (v3) -6,086.80 -521.97 5,939,854.00 558,165.00 - Point 3,366.00 iJ-154 L2 Tce (v3) -7,465.97 -522.71 5,938,475.00 558,175.00 -Point 3,387.00 1J-154 L2 T6 (v3) -4,594.63 -520.35 5,941,346.00 558,155.00 - Point 3,447.00 1J-154 L2 T2 (v3) -2,195.33 -519.66 5,943,745.00 558,137.00 - Point 3,417.00 1J-154 L2 T3 (v3) -3,150.45 -520.10 5,942,790.00 558,144.00 - Point 3,449.00 1J-154 L2 T(.45j (v3) -999.18 -519.35 5,944,941.00 558,128.00 - Point j Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ftl l"1 ("1 2,301.04 2,203.00 10-314 13-112 4,047.86 3,441.00 7-518 8-112 10,969.86 3,366.00 4-112 8314 2/14/2005 12:44:42PM Page 7 of 8 COMPASS 2003.11 Build 50 4.~ ~ ~ c ~f 1 ~~~ ~ ~' g ~' r -,~ _ ~ - ~ ~-' Ph C ll Halliburton Company ~-,~,ry_~(,,, onoco i ips Panning Report -Geographic AI2SICa A HaI1lEUrton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-1.54 (M6j Company: ConocoPhillips Alaska Ina(Kuparuk) ND Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 708.OOft (Wellhead(108')j Site: Kuparuk 1J Pad North Reference: True Well: Plart-lJ-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 L2 Design; 1J-154 L2 (wp06) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E!-W i (ft) 1°1 1°) (ft) IfU Ift- Name 1,582.21 25.25 326.50 1,538.00 203.39 -134.62 Base of Permafrost 1,704.94 25.25 326.50 1,649.00 247.05 -163.52 T'3 2,016.52 23.68 326.17 1,934.00 351.69 -233.55 K76 2,301,04 14.23 295.08 2,203.00 415.85 -297.31 T3+560 2,427.38 12.59 268.50 2,326.00 422.07 -325.17 T3 + 676 3,031.91 32.17 197.57 2,890.00 263.23 -442.35 Ugnu C 3,314.57 45.39 189.50 3,110.00 91.38 -481.87 UgnuB 3,425.28 50.68 187.31 3,184.00 9.97 -493.84 Ugnu A 3,641.32 61.10 183.86 3,305.00 -167.81 -510.89 K73 4,047.85 76.00 179.97 3,441.00 -549.12 -519.84 West Sak D 2/14/2005 12:44:42PM Page 8 of 8 COMPASS 2003.11 Build 50 E • • Halliburton Company Anticollision Report " Company: ConOCOPhillips Alaska Inc. Date: 2/22/2005 Time.: 16:27:23 Page: 1 Field: Kuparuk River Unit I Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-154, True North Reference Well: Plan 1 J-154 Vertical (TVD) Reference: Plans: 108.0 Reference V1'ellpath: ~ 1J-154 L2 Db: Oracle J - _ NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: _ ___ Plan: 1 J-154 L2 (wp06) & NOT PLANNE Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 4364.24 to 11275.68 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Casing Points T MD TVD Diameter Hole Size Name ft ft in in -- 4047.85 3441.00 7.000 9.875 7 518 10969.87 3365.98 5.500 6.756 5112" Plan: 1 J-154 L2 (wp06) Date Composed: 2/13/2005 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary <------------------ Offset Weltpat6 ------------------~ Reference` Offset:. Cfr-Cfr No-C~o A!-owable Site W~U ~1'ellpath'~ MD Mb Distance Area Deviation Warning ft ft; ft ft ft Kuparuk 1J Pad Plan 1J-152 1J-152 L1 V1 Plan: 1J- 10951.19 12375.00 1227.10 255.07 972.03 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 L2 V1 Plan: 1J- 10900.99 12317.36 1236.66 255.35 981.31 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 V1 Plan: 1J-152 10955.97 12400.00 1258.04 267.77 990.27 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L1 V1 Plan: 1J- 10836.90 10150.00 1236.03 237.07 998.96 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L2 V1 Plan: 1J- 10838.46.10142.55 1231.47 241.17 990.29 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 VO Plan: 1J-159 10753.00 10075.00 1262.78 243.80 1018.97 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 L1 V1 Plan: 1J- 9506.52 6925.00 936.70 191.04 745.66 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 V0 Plan: 1J-182 9506.52 6925.00 936.70 191.04 745.66 Pass: Major Risk Kuparuk 1J Pad Plan 1J-184 1J-184 L1 VO Plan: 1J- 10947.90 8175.00 235.94 210.11 25.83 Pass: Major Risk Kuparuk 1J Pad Plan 1J-184 1J-184 V1 Plan: 1J-184 10947.90 8175.00 235.94 210.11 25.83 Pass: Major Risk Kuparuk 1 J Pad WSP-06 WSP-O6 V1 Out of range Kuparuk 1J Pad WSP-07 WSP-07 V1 Out of range Kuparuk 1J Pad WSP-10 WSP-10 V1 Out of range Kuparuk 1J Pad WSP-14 WSP-14 V1 4800.01 3600.00 657.86 116.54 541.31 Pass: Major Risk ROG w Date: 2U05-02-08TOU:W:W Validated: Yes Version: lh From Depth To Sunc~/Plan Tool O.W SW.W CB-CYR0.SS RW.W 10)7.85 MH'D+IFR-AK-CA7 SC JOJ7.85 10969.87 IJ-IG L2 (wp06) MW'D+IFR-AK-CAZSC EnBmeerln9 West Sak cakWae°n McMeB: MManum CVn6ve Ertw JysOyn: LBCNBA scan Method: T.ev china, Nona En°r Surtxe: E19p8u1 Lorac wame,9 Mearaa: wks Ev4ee ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 4047.85 To 10969.87 Maximum Range:1614.24 Reference: Plan: 1)-154 L2 (wp06) ~r ~' ~~ -~ ~,....,.a,.m..e~r _~.- -~6_- t r~ww -!- ..ruwrr 270 180 90 From Colour To MD Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X200 ft/in~ REFERENCE NFORMhTICM Coordrere(WEI Reference. WeIIPbn 1J-154 (M61. True NaM Venical(NDI Reference WalMad(100'~@ 1060011 ryVellhead0l ) SeNOn (VS)Relarerrce 6b1 (OOMr000E) MeasrxeCtla°epf~ReMeMOtl ~AMnimr~unl ~n ~108.0011(WelMedll 0 WELL DETAILS: Plan 1J-154 (M8) Ground Level: 80' +WS +EI-W Northing Easting Latittude Longitude Sbt 0.00 0.00 5945941.70 558639.50 70°15'46.51N 149°3['33.379W 180 0 100 100 - _" - 200 Travelling Cylinder Azimuth (TFO+A7.1) I°I vs Centre to C'entrc Separation I IS ftlnl 200 400 400 _ ---- - 800 800 1000 1000 1500 1500 - --- 2000 zooo zsao 2500 ~ -"--° 3000 sECna4 DEruLs 3000 3500 fiat MD k Pzl ND vW5 *E!-W Dle y TFxe VSac Terget 3500 4000 0 0 3 405985 7n.00 1]9.9) 3403 ~S60.B1 -519.84 1590 J 4089.85 T7.91 1]9.9) 3049.% -5%.15 -51982 000 000 560.81 000 5%.15 4000 4500 4 a3ss 14 9dss 179.91 3as7.44 -854E3 -s9s1 fits 5 4400.58 94.55 1]9.91 )460.]4 -939.10 51941 000 -0.31 as4s3 0.00 939.10 450D 5000 6 4500.61 %.W 1]991 345).94 -999.05 519.)5 fi25 ] 452266 9014 1)999 )45]76 1021.11 519 )d 300 1)906 999.05 1115012 Trdsl lv]I 1]8.43 1031.11 SDOD 6000 8 5250.&1 %11 1)9% 3456.00 1]4938 519.19 0.00 9 5266.34 91.20 160.06 3455.59 1184.60 51920 300 0.00 1]49.28 1115412 Tt /v3) 0.09 1]84.68 6000 7000 10 %%% 91.30 tBO.% YW]00 ~3195.J3 51968 000 11 5]1).2] 9181 180.0] 3406.0) 221563 -51968 300 12 66535] 9181 180.03 341]00 3150.45 -53010 000 000 3195.33 11151 L2 T2 (v3) -35] 231562 000 ]150 L.5 11151 L3 TJ (v]) 7000 BDDD 13 6689.56 907) 17993 341620 -3186.43 -530.08 300 1d )0%fi) 90.]3 1)9.93 341100 -359451 -519.56 000 -1]469 3166.13 000 3590.51 11151 L3 T4 (v3) B~D 9~0 15 )114.59 9126 18000 341069 -36134) -51955 300 I6 78]1% 9136 16000 3390.00 J3fi961 -519.59 000 829 361243 000 0369.fi1 11151 L2 TS Na) 9000 1D000 ]905.48 %2B 180.21 339355 )403.13 -519.65 300 18 809].11 %28 160.21 339262 )594.76 -520.35 000 16835 440313 0.00 4594]6 11150 L2 T6 (v3) 19 8301.34 8]09 1]9.]5 3395.081701.94 -520.31 300 % O ~1)1% 4701 94 11154 L2Ph3) 1 D000 11 Q00 M 88).05 9309 179)5 3403]3 5290.35 517 .OD 000 5290.35 1100D 12000 33 938).05 9309 1)9.)5 3380]1 ~5193.BJ -515.% 020 23 9]9).05 BB.B4 1)9.15 33]226 6293.64 -51338 085 0.00 5793.83 160.00 6293.64 1200D 0 2d 1039]05 89.31 1)9.)5 )38011 679357 51121 0.10 2510934.09 9288 182.09 J%180 -7430.26 521.10 067 2fi 10969.87 9288 18209 3366.00-7465.9] -532.]1 OOp 0.00 67935] 33.00 7430.26 000 74659] 11151 L3 Tee (v31 90 iJ-1541 Drilling Hazard Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3J4" Open Hole / 4-i/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-154L2 Drilling Hazards Summary.doc ~.,.~~ + I ~ ~; prepared by Shane Cloninger 2/28/2005 9:04 AM ~~ ~ ,. 'Tubing Head Assy, 13-5/8" X 4-1/2". 'Tubing Hanger, concentric, no penetrations. 10-314" Casing Shoe,D '+ set ~ 2301' MD, 2203' TVD Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Dri ~ ~ ~ 5-112" X 7518" ZXP Seal Assembl Liner Top Packer 4.75" Seal OD with Hold Downs 3.875" ID / ~° +f Tubing Swivel, 4-112 J Tubing, Special Drift to +/- 500' MD ConoeoPhi I I ips DB Nipple, for Possible SSSV, set at+/-500' MD West Sak 7-5/8" Injector GLM, Camco 1" KBG-2 1 J -154 GLM, Camco 1" KBG-2 Tri-Lateral Completion CMU Sliding Sleeve, w/ DB Nipple, set at 70 deg max inclination Casing Sealbore Receptacle ~ 4.75" ID, 6.25" OD ___...__ 20'Length ______.- Lateral Entry Mod M) Orienting Profile D-sand window 'D' Sand Lateral at 4048' MD, }}}~~~ 3441' TVD 4-112" 12.6# LSO Slotted ~~ C 1 y ~..vl~ Liner Swivel Liner Every Other Joint I3-112" Bent Joint Ill _ 1 1 ~ 3-112" Guide Shce / / /.. Seal Assembly 4.75" Seal OD 4-112" X 7518" Sea 3.875" ID Model'B' HOOK Hanger .68" ID _2' Length 5-112" X 7SI8" ZXP Liner Top Packer with Hold Downs Lateral Entry Module (LEM) Assembly ~~ 5-112" X 7518" 2XP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Tubing Swivel, 4-112" - - Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbor Receptacle 4.75" ID, 6.25" OD 20' Length 4-112" X 7-518" Model 'B' HOOK Fia racer Seal Bon 3.68" ID Packoff Bushing 4.1/2" Casing Shoe, 12.6#, L-80 IBTM Set ~ 10970' MD, 3366' TVD ~~~ BAKER KUIII.IIES Baker Oil Tools With Diverters and Isolation Lateral Access Diverter Lateral lsolatbn Diverter GS Running Tool SVing Installed Installed (3.00" Lateral Drury (2.50" ID Mainbor e Drift) 'GS' Pro51e for Cdl Connector ! Running/Retrieving ~ . ~ (1.00' Lergth) Snap In/Snap Out / Positive Locating ti ~~ Back Pressure Valve Cdlet (1.00' Length) Lateral IsoWtion ~' .~ Fbw-Thru SwNel Seals (1.25' Length) ~ f lateral Diverter ~ Hydraulic Ramp - D IsoWtioN MainlKxe~ 50' Length) D Diverter Sleeve _ GS Spear 's (1.50' Length) Lateral Isolation Seals 6.85 h Approx. OAL' Jars may be required in highly deviated 18.5' Diverter Length 1a.5' Sleeve Length v deen aonlieations Ifi' aooroz lenathl. ~.aterel Entry Module(LEM) Orienting Profile B-sand Window 'B' Sand Lateral fat 4364' MD, 3513' TVD 4-112" 12.6# L-80 Slohed Swivel Liner Every1 Other Joint 3-112"Bent Joint ~ ` r~ _. 3-112" Guide Shoe ' 4-112" Casing Shoe, 12.6#, L-80 IBTM DB Nipple Set ~ 11276' MD, 3439' TVD Packoff Bushing 4-112" 12.6# Tubin~~-- 3.633" Drift 3.958" ID /% 5-112" X 7SI8" ZXP Liner Top Packer with Hold Downs 5-112" X 7SI8" Liner Hanger 1 Packer Assembly at Flex Lock +1-4440' MD Liner Hanger Casing Sealbore Receptacle 4.75" ID, 6.25" OD 20' Length (> Baker Hughes Y0g5. This tlocument may not be reprotluced or distributed, In whole or In pan, In any Torm or by any means electronic or mechanical, Including photocopying, recording, or by any Informatlon storage and retrieval system now known or hereaner Inventetl, wlMOU[ written permission from Baker Hughes Inc. Seal Assembly 4.75" Seal OD l ' ' l i L 3.875"ID A Sand Undu at ng atera 2' Length 4-112" 12.6# L-80 Slotted \ Liner Every Other Joint / d-112" Eccentric .Guide Shce EJc uinment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with divener: 4.63" Lateral Drift, no diveAer or LEM: 3.88" Lateral Drift, wl divener, no LEM: 3.88" LaterallMainbore Divener OD: 6.75" 4-1 /2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drill, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +/- 16.5' 4-1/2" Casing Shoe, 12.6#, L-80 IBTM Set ~ 12872' MD, 3588' TVD Packoff Bushing 7-5/8" Casing Shoe, Set at ~ _ _ 5350' MD, 3670' TVD, 80 deg ~ T~"`~ eggs vwae saw Tsre^ Tdaatent eomvlenon - mleomr Dae. February 2a, 2005 Drawn ay Marc D. Kuck RMalan r • L` • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PA.RAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~' /J' ~~S~C. Z PTD# ~~ ~ - v ~ ~ Development ~/ Service Exploration Stratigraphic CHECK WHAT ADD-OHS "CLUE"• APPLIES OPTIONS MULTI The permit is !or a ~~ j~ oje segment of ~ ` LATERAL existing weU ~ f ;fi Permit No, Zo, ~?S~API No. ~~ ~~-~ -Z32S (If API number Production. should continue to be reported as last two. (2) digits a lunction'of the original API number stated are between 60-69) above. P1LOT I30LE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired. for the pilot . bole must be clearly differentiated 'in both • name (name on permit plna PIS and API number (50 - ~0/80) lrom records, data and logs acquired for well (name on permit). SPACDVG The permit is approved subject ~to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ exception. SCompany Name) assumes the liability of any protest to the spacing .e=ception that may occur. . DRY DITCH ~ All dry ditch sample sets submiried to the SAMPLE Commission muse be in no greaser than 30' sample intervals lrom below the permafrost or from where samples are first caught and ] 0' sample intervals through target zones. -~/ WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 __ _Well Name: KUPARUK RIV U WSAK iJ-154L2 Program SER Well bore seg ^ PTD#:2050370 Company CONOCOPHILLIPS ALASKA INC Initial Classfl'ype SER 1 PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permitfee attached_ _ - - _ _ - _ - - - - - - - - - - - - - - - - - - - NA_ West Sak D Sand multilateral well segment; fee_waived per 20 AAC 25.005(e), - 2 Lease number appropriate_________ _________________--_ __.-_---.Yes_ ______Top_prpductiveintervalinADL025661;_Tl)inADl.0256ti2.__________- -__--- 3 Un(quewel(nameandnumber__-.._______________________ _________Yes_ _____---_--_- 4 Well located in a_definedpool _ _ -Yes _ - KRU West_Sak Oil Pool, goyerned_by Conservation-Order No, 4066_ 5 Well located proper distance_ from drilling unit_boundary- - - - - - - - - - - - - - - - - - - - Yes - - No restrictions as_tp well spacing except that no_pay shall be peened in a well clpset - . - - - - - - - 6 Well Ipcated proper distance-from ether wells_ _ - _ - _ Yes - - - _ - - _ than 50Qfee1 to_an external_plppe[ty line._ - _ -- -- -- - 7 Sufficientacreageavailableindril_linqunit----------------------- ---------Yes_ _________.-- -- - - 8 If_deviated,is_wellbpreplat_included_________________ ___--_ _____._-Yes_ --___________'_- - - - - - 9 Operatorpnlyaffectedparty____________----------- ------.--Yes- -------- ------------ -- - 10 Ope[atothas.apprppriate-bond infgrpe---------------~-------- --- -----Yes. .------ ---- --------~--- ----------- -- ------------- ------------- - - 11 Permit can be issued without conservation order Yes Appr Date 12 Permitean be issued without administrative_approval - _ - - - - _ - - _ - - - - - - Yes - - - - - - - - - -- - - - SFD 3/1412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Orde[ # (put1O# in_comments)-(Fpr_ Yes Area Injection Order Np._ 2B_ _ _ - - _ _ - - - - - - - - - 15 All yells v~ith fn 1/4.mile area.of review identified (For service well pnly)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ WSP,14~W$P 12, WSP-13, W$P-10, WSP-01, WSP-7, WSP-6, WSP-5, WSP-2, WSP-15, WSP,4_ . - - . - _ _ _ 16 Pre-produced injector: dur_atipn of pre productipn Less than 3 mpnths.(Fpr service well pnly) Yes Well will be cleaned up for 30 - 60 days_pripr tp injeaion, _ _ 17 ACMP_Finding of Consistency-has been issued_fpr-this pro)ect- NA- - - - - - - - - - - - - - - - - -- - -- Engineering 18 Conductor sting ptpvided - - - - - - - - - - - - - - _ - _ _ _ _ _ _ _ _ _ _ _ _ - - NA- _ _ - _ _ _ - . Cpnductor set_in mptherbore,-1J,154 (205-035)._ _ _ _ _ - _ _ _ _ _ _ _ - _ _ _ 19 Surface casing protectsall_knpwnUSOWs-____________________ _________ NA-_ _--__-All aquifers exempted, 40CFR_147.102~b)(3).__--_ --.------____-__-----------.______ 20 CMTv_ol_adequate_tpcircul_ate_oncpnductpr&surf_csg_------------- --------- NA__ ______$urf_apecasingsetin1J-154.________-___-__-__---____--_ 21 _C_MT v_ol_ adequate-to tie-in long string tosurf csg_ - _ _ _ NA- _ _ - - _ - Pr_oductipn_casing set in-1 J-154. -Althydr_ocarbon zpnes planned tp be covered. _ - - - 22 CMT_will coverall known-productive hprizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ Slotted liner cgmpletion pl_anned._ - _ - - - - _ - -- 23 Casingdesigosadequateto[C,.T,B&_permaf[ost------------------ ---------Yes- ---------.---------- ------------------------------------------------- 24 Adequate iankage_or reserve pit _ _ _ _ . - _ Yes - Rig is_equippedwith steel_pits. Np reserve-pitplanned, All waste to an approved annulus or Class_II_ well. _ - _ - - 25 If_a_re-drill,has_a_10-403 for abandonment beenapproved______ ______ __-___._ NA_- -----__--_______-___-__.-----__- - -- 26 Adequate wellbore separation-proppsed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - - _ _ - Proximity_ analysis performed, Nearest "well" is Bsand lateral -75' tyd below. _ - - .... _ _ - - - - - _ - - . _ - - - 27 Ifdiverterrequired,doesitmeetregulatipns-------------_.______ __ NA__ _-__--BOP Stack_willalready_beinplace,--__________-_-__---__--__-- -- Appr Date 28 Drilling fluid-program schematic & equip list adequate- _ - - - - Yes _ _ - - _ - -Maximum expected formatipn pressure B.TEMW._ Planned MW 8.Oppg.- - - _ _ _ TEM 3115/2005 29 _B_OPEs,-do they meet_ regulation _ _ _ . Yes _ _ _ _ - _ _ _ - _ _ - _ _ - _ - - - - _ - - - - 30 BOPE-press rating appropriaie; test to (put psig in comments) Yes _ _ - MASP calculated at 1180psi. 3000-psi planned. _ _ _ _ - _ - - - 31 _C_hpke_manifpldcpmplieswlAPiRP-53(May84)___________________ _________Yes_ _-_-_-__________- - -- -- - 32 Wprkwillpccurwithputoperationshutdpwn___________ _,__.---_Yes_ __________________ -- - - 33 Is presence_pf H2S gas_prpbable - _ . - _ - . - _ - No_ H2S has nptbeQn repprted in_ WS Pilptproductipn. -Rig is equipped with sensors and alarms.- - - - 34 Mechanical-cpndition pf wells within AOR verified (Fpr service well Only) Yes _ _ - - - - -Examined all well_s,on W$ Pilot and W. Sak 05. _ Initial cementing and P&As acceptable._ No ex_ceptipns_noted, Geology 35 Permit_canbeissuedwlphyd[ogen-sulfidemeasures________________ _________Yes_ _----___-_________--__--_---___- ----------------------------------------- 36 _D_ata_presented pnpotential pverpressur_e zpnes_ _ - - - - - - -Yes - Expected reservoirpressure is 8,7_ppg EMW; will be drilled with 9.0 peg mud. - - . - _ - . - - _ - Appr Date 37 Seismic.analysispfshallpwgaszones__------------------_-- -_---_--_ NA-_ _-___--__--_---__ ----------------------------------------- ----- SFD 3114/2005 38 Seabed cpndition survey_(if off-shore) _ - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - ---------- 39 -Gpntact na_melphone fpr_weekly prpgressleports (explpratory only]_ NA_ Geologic Engineering is Commissioner: Date: Commissioner: Date om loner mate D1~S 3) rs/s lV z a~ u • Well Hisio[y File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify t'inding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 02 13:25:42 2006 Reel Header Service name .............LISTPE Date .....................06/03/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header ~ Service name .............LISTPE Date .....................06/03/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-154 L2 API NUMBER: 500292325461 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 02-MAR-06 JOB DATA MWD RUN 2 MWD RUN 8 MWD RUN 9 JOB NUMBER: MW-000395646 MW-000395646 MW-000395646 LOGGING ENGINEER: T. GALVIN P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2133 FEL: 2569 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2302.0 2ND STRING 6.750 7.875, 4079.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, ao>-Dl) u THE TOP OF WHICH WAS POSITIONED AT 4079'MD/3450'TVD WITHIN THE RUN 2 INTERVAL OF THE 1J-154 WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2 AND 9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED RECORDED ONLY COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND ACOUSTIC CALIPER (ACAL). THESE POROSITY DATA ARE PRESENTED FOR THE MAIN WELLBORE, AND ARE NOT INCLUDED HERE. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW MILLED DURING MWD RUN 8, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,8,9 REPRESENT WELL 1J-154 L2 WITH API#:50-029-23254-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10964'MD / 3357'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .......... ...STSLIB.001 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/03/02 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH SGRC 2256.5 10898.5 SFXE 2280.0 10905.5 SEDP 2280.0 10905.5 SESP 2280.0 10905.5 SEMP 2280.0 10905.5 SEXP 2280.0 10905.5 SROP 2302.5 10964.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 8 MWD 9 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2256.5 4079.0 4079.5 4107.0 4079.5 10964.0 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 10964 6610.25 17416 2256.5 10964 RPD MWD OHMM 2.92 2000 53.6646 17252 2280 10905.5 RPM MWD OHMM 4.01 1743.45 50.7336 17252 2280 10905.5 RPS MWD OHMM 3.85 2000 54.426 17252 2280 10905.5 RPX MWD OHMM 3.7 1791.24 58.6556 17252 2280 10905.5 FET MWD HOUR 0.2 418.48 1.6075 17252 2280 10905.5 GR MWD API 22.41 115.29 63.9076 17285 2256.5 10898.5 ROP MWD- FT/H 0.22 12512.5 178.235 17324 2302.5 10964 First Reading For Entire File..........2256.5 Last Reading For Entire File...........10964 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/03/02 Maximum Physical Record ..65535 File Type .............. ..LO • Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 2256.5 4079.0 SFXE 2280.0 4079.0 SEXP 2280.0 4079.0 SESP 2280.0 4079.0 SEMP 2280.0 4079.0 SEDP 2280.0 4079.0 SROP 2302.5 4079.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet O5-OCT-OS Insite 66.37 Memory 4079.0 2302.0 4079.0 12.2 81.4 TOOL NUMBER 132482 157645 126970 10509011 9.875 2302.0 Native/Spud Mud 9.05 61.0 9.9 200 4.4 3.300 67.0 2.390 95.0 4.500 67.0 3.000 67.0 Data Reference Point ...... . .......Undefined Frame Spacing .. ........... . .......60 .lIN Max frames per record ..... . .......Undefined Absent value ... ........... . .......-999 Depth Units .... ........... . ....... Datum Specifica tion Block sub-type...0 Name Service Order Units Siz e Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 4079 3167.75 3646 2256.5 4079 RPD MWD020 OHMM 2.92 2000 17.8366 3599 2280 4079 RPM MWD020 OHMM 4.01 1743.45 13.1621 3599 2280 4079 RPS MWD020 OHMM 3.85 2000 12.6112 3599 2280 4079 RPX MWD020 OHMM 3.7 1043.9 10.8146 3599 2280 4079 FET MWD020 HOUR 0.2 56.81 1.35087 3599 2280 4079 GR MWD020 API 22.41 115.29 65.8667 3646 2256.5 4079 ROP MWD020 FT/H 5.47 580.58 171.819 3554 2302.5 4079 First Reading For Entire File..........2256.5 Last Reading For Entire File...........4079 File Trailer Service name ............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .06/03/02 Maximum Physical Record. .65535 File Type ............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 06/03/02 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SROP 4079.5 4107.0 LOG HEADER DATA DATE LOGGED: 21-OCT-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory • TD DRILLER (FT) 4107.0 TOP LOG INTERVAL (FT) 4079.0 BOTTOM LOG INTERVAL (FT) 4107.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: ,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2302.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S): 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 79.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Of fset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4079.5 4107 40 93.25 56 4079.5 ROP MWD080 FT/H 0.22 32.58 15 .5866 56 4079.5 First Reading For Entire File..........4079.5 Last Reading For Entire File...........4107 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum .Physical Record..65535 Last Reading 4107 4107 • File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 4079.5 10905.5 SEDP 4079.5 10905.5 SGRC 4079.5 10898.5 SEMP 4079.5 10905.5 SFXE 4079.5 10905.5 SESP 4079.5 10905.5 SROP 4107.5 10964.0 LOG HEADER DATA DATE LOGGED: 26-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10964.0 TOP LOG INTERVAL (FT) 4107.0 BOTTOM LOG INTERVAL (FT) 10964.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2302.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 134.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): • • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4079.5 10964 7521.75 13770 4079.5 10964 RPD MWD090 OHMM 3.09 166.87 63.1091 13653 4079.5 10905.5 RPM MWD090 OHMM 7.87 176.58 60.6377 13653 4079.5 10905.5 RPS MWD090 OHMM 12.4 261.14 65.4485 13653 4079.5 10905.5 RPX MWD090 OHMM 10.08 1791.24 71.2667 13653 4079.5 10905.5 FET MWD090 HOUR 0.23 418.48 1.67515 13653 4079.5 10905.5 GR MWD090 API 37.68 99.58 63.3839 13639 4079.5 10898.5 ROP MWD090 FT/H 0.68 12512.5 180.562 13714 4107.5 10964 First Reading For Entire File..........4079.5 Last Reading For Entire File...........10964 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 .Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............ .LISTPE Date .................... .06/03/02 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN • i Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File