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Home My WebLink About206-107• Image Projeet 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(Q - ~ ~ Well History File Identifier Organizing (aone> Two-sided III II'III (I II(II ICI RE CAN DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: Ae,~,~~tta~a iuuiuuiiiuiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ^ Other:: /s/ Project Proofing II I II N II I I III I I III BY: Maria Date: iJ ~ /s/ Scanning Preparation x 30 = + =TOTAL PAGES~3 _ f (Count does not include cover sheet) BY: Maria Date:"~3 / f~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: 0~-1-- (Count does include cover heet) Page Count Matches Number in Scan ing Preparation: I/ YES NO BY: Maria Date: ~ ~ 3 ~~ /s! Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III IIII II III II I I III Rescanned III IIIIIIIIIII IIIII Maria Date: /s/ Comments about this file: o~, ~.~.e«ea iuimiimiuuii 10/6/2005 Well History File Cover Page.doc ~- ~~ ~~ .... ~~ ~; ++.~ "yy,. r a + '~t ~ ,r. ~ ~,"~M' ~i~:T~ ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc t Conoc~illips August 31, 200fi Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1J-133 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling 8~ Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RE~EtVED SEP 0 ~ 2006 Alaska Oil & Gas Gona. Corrirnission Ancharage see ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent driNing operations of the Kuparuk West Sak wells 1J-133. We have installed a kill string and intend to return to this well in the future. . If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ~~~ ~1 R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~ ~ a w L.3 3~ + ~ ~ 1 ~ ~~ ~ ~'"~~ ~~ '~,~ ~~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~7~ OII/ ~ ~ ~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQA'1'IO1Q COl-iDIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 I PHONE 907 279 i ~ ( ) 1433 FAX 90 276-7542 ~ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-133L 1 ConocoPhillips Alaska, Inc. Permit No: 206-107 Surface Location: 1622' FSL, 2296' FEL, SEC. 35, Tl 1N, R10E, UM Bottomhole Location: 1301' FNL, 2446' FWL, SEC. 13, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new welbore segment of existing well KRU 1J-133, Permit No. 206- 106, API No. 50-029-23315-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field insp~or at (907) 659-3607 (pager). DATED this"l~day of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL fad 20 AAC 25.005 JUI~ 2 4 2006 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1 b. Current Welt Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone Q 1c. Specify if ~Ia~a3~R~Ga$ Cons. 0 ISSI Coalbed Methane ^ ~~I~Gµp~~ Shale Gas ,I~uJ++,p~~ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-133L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 16356' TVD: 3622' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1622' FSL, 2296' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 ~ 380058 West Sak Oil Pool Top of Productive Horizon: 13' FNL, 2120' FWL, Sec. 12, T10N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 8/5/2006 Total Depth: 1301' FNL, 2446' FWL, Sec. 13, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558917 y- 5945436 Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance two Nearest ..~~~ ~~ witli'(n t bo~none , 16. Deviated wells: Kickoff depth: 9775 ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 Anc 25.035) ~1 Downhole: 1646 psig Surface: 1243 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 40' 40' 108' 108' 282 sx AS 1 16" 13.375" 68# L-80 BTC 3666' 40' 40' 3706' 2225' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10650' 40' 40' 10690' 3703' 810 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 6581' 9775' 3590' 16356" 3622' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Stru ctu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): ~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~_ B P Sketch Drilling Program ^ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ " Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature~,~,~_~ Phone 265-~2,~o Date '7rLeft'©~ Pr ar haron Alisu r k Commission Use Only Permit to Drill r Number: aQ~ ~ C ©~ API Number: 2 (' rr~~ 50- ~~ a~~` S'-`~ V Permit Approval Date: ~ ~ • O ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: 300 p~`~ '~d~ ~S~ ~-S ~~~~ ,Samples req'd: Yes ^ No .L!r~Jf u log req'd: Yes ^ No Other: H2S measures: Yes ^ No ~ Dire n s y req'd: Yes ~ No ^ P1 ~T U~~t~~ o~ccs.~~oe~S ~~ a~~~ `~ I I~-~ Z / ~ ~~ P OVED BY THE COMMISSION SATE: ~~ (, ~~~/// / ,COMMISSIONER Form 10-401 Revised 12/2005 /'y n' ~ ~ ~ Submit in Duplicate -04' Conoco~illips Alaska Post once sox 100360 And~orage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas(~conocophiAipscom July 14, 2006 Alaska Qil and Gas Conservation Commission 333 West 7"' Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, iJ-133 and 1J-133 Ll ~~~~-v~ JUt 14 2t~(~~ ~Iaska Oil & Gas 1± A~~ °~ ~'~118&ti2f~ Dear Commissioners: 4 =~ ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a dual lateral horizontal weH in the West Sak "B"and "D" sands. The main bore of the well will be designated 1J-133, and the lateral bore of the well wiA be designated 1J-133Lr1.~ ~vSp~ ~~~ ~ y~~~la-5" After we set intermediate casing, we will move to another well and return to this well in the next two years. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bares. The expected spud date of 1J-133 is July 31, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader • RECEIVE~J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 JULY 4 ZOGti Alaska Dil ~ Gas Cons, ~;~~;~;, Ancho~e 1 a. Type of Work: Drill ^ Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Single Zone Q , 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. W Name and Number: 1J-133L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: 'MD: 16356' TVD: 3622' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1622' FSL, 2296' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25662 & 3800 West Sak Oil Pool • Top of Productive Horizon: 13' FNL, 2120' FWL, Sec. 12, T10N, R10E, UM 8. Land Use Permit: ALK 471 & 217 13. Approximate Spud Date: 8/5/2006 Total Depth: 1301' FNL, 2446' FWL, Sec.13, T10N, R10E, UM 9. Acres in Property: 60 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558917 y- 5945436 Zone- 4 10. KB Eley~n ~/ (tieig a ve ): 40' RKB 15. ~ is a~s~ Nearest ,~-~p9~, Well within Poo J yam' 9. ~ . 16. Deviated wells: Kickoff depth: 9775 ft. Maximum Hole Angle: 92° deg 17. Anticipated Pressures in psig (see zo nAC 25.os5) ow ole: 1646 psig - Surface: 1243 psig ' 16. Casing Program if S ti Setting Depth Quantity of Cement Size pec ica ons op Bottom c. f. or sacks Hole Casing Weight Grade Coupling Le h TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 0' 40' 108' 108' 282 sx AS 1 16" 13 3/8" 68# L-80 BTC 36 40' 40' 3706' 2225' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10 40' 40' 10690' 3703' 810 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 9775' 3590' 16356' 3622' slotted liner 19 PRESENT WELL CONDITION SU (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs a red) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program Q 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 Repres tative: Date: 22. I hereby certify that the foregoing is tr a and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Ran y Thomas Title Greater Kuparuk Area Drilling Team Leader Signature p l Phone °~,S (~~g~ Date 7 //Yt'0~6 P a Sh r All u Drak Commission Use Only Permit to Drill / Number: 2.~Ip ' ~ ~ API Number: 2 c^ / 7~ 50- U Zg- ,~ 3 J ~ J " TG V Permit Approval Date: See cover letter for other requirements Conditions of approva Samples required Yes ^ No [~ Mud log required Yes ^ No L~!f Hydrogen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ Other. (~~~ APPROVED BY Approved by: ~ THE COMMISSION Date: Form 10-401 Revised 06/2004 ~ ¢ 6 ~~ ~~~p~ Submit in Duplicate . Applicator Permit to Drill, Well 1 J-133 L1 Revision No.O Saved: 14-Jul-06 Permit It -West Sak Well #1J-133L1 ""~ r.~ +'~ Application for Permit to Drill Document r C~~~~~ Mpxin7ia~ 'V~~II V~1~~ Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ .................................................................. ........................... ................ 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) .................................................................~-~---.................................. 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................:........ 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ...............................................................~-~---........................---........ 3 5. Procedure for Conducting Formation Integrity Tests .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 3 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.OOS(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 Re uirements o 20 AAC 25.005 c 10 ................................... q )( ) ................................................................... 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... 5 12. Evidence of Bonding ................................................................................................... 5 1J-133 L1 PERMIT IT Page 1 of 6 Printed: 14-Jul-06 ORIGINAL Applic~or Permit to Drill, Well 1 J-133 L1 Revision No,O Saved: 14-Jul-O6 Re uirements o 20 AAC 25.005 c 12 ........ 5 9 .f ()( ) .............................................................................................. 13. Proposed Drilling Program ......................................................................................... 5 Re uirements o 20 AAC 25.005 c 13 ............ 5 q .f ()( ) .......................................................................................... 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 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) .. Error! Bookmark not defined, Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ....................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (~ Eacla well must be identified Uv a unique name designated by tlae operator and a arnique A1'f nurrther assigned l~v the commission under 20 AAC 25.040(h). fbr a tivetl with multiple well branches, each branch must simr.'larly be identified by a unigare rutme and API ratetnber' f>v adding a suffix to the raarne designated for the x~ell Lv the operator and to the number assigned to the well by the cornneission. The well for which this Application is submitted will be designated as 1J-133 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An ap~ilication for a Per-rnit to DrilX must be accompanied by each of the following items, except fi,r an item already on file with the cnrttrnissivn and idettt~ed in the applicafion: {2) a plat iraeratifying the propert)~ and the property s ow~tter-s and shntving (A)che coordinates of the proposed location of the Lvell at the surface, at the top of each abjective formation, and at total depth, referenced to governtnerttal section lines. ($) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate s~~sterra for this state as mairatairaed by thc: National Geodetic Survev in the National Oceanic and Atmospheric Administratiort; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,623' FSL, 2,296' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,435 Eastings: 558,916 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "B" Sand 13' FNL, 2,120' FWL, Section 12, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9,775 Northings: 5,938,557 Eastings: 563,393 Total Vertical Depth, RKB: 3,590 Total Vertical Depth, SS: 3,469 Location at Total De th 1,301' FNL, 2,446' FWL, Section 13, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 16,356 Northings: 5,931,993 Eastings: 563,777 Total Vertical Depth, RKB: 3,622 Total Vertical Depth, SS: 3,501 and (D) other information required lty 20 AAC 25.050(hj; Requirements of 20 AAC 25.050(b) Ij'a well is to be itstentior-tally deviated, the application for a Permit to Drill (Form 10-401) rnusi 1J-133 L1 PERMIT IT Page 2 of 6 Printed: 14-Jul-O6 OR161N.AL • Applicator Permit to Drill, Well 1J-133 L1 Revision No.O Saved: 14-Jul-06 (I) include a plat, drawn to a suitable scale, showing the patio gfthe proposed wellbore, inclzzdirzg afl adfacentwellbores within 1(1(1 feet ofany portion of the proposed well; Please see Attachment 1: Directional Plan and (1) for• all wells within 200 feet of the pr"oposed tivellbore (4) list the names of the operators of ilzose r~,=ells, to the e<ztent that those names are k°nawn or discoverable in pztblic records, arad shotiv that each Warned operator lzas been furnished a copy of the application by certified mail; or (13) state tltat the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c) (3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item alrecact}= ort fr,le with tfte commissionz aru/identified in the application: (3) a diagram and descr"iptian of the blowout prevention equipment (BOPF.) as required by lt) AA.C 25.©35, 20 t2~3C' 25.03b, or 10 ~9AC 15.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-133 L1. Please see information on the Doyon Rig 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 moist be accompanied by each of the following items, except for arz item already nn file with the commission grad identified in the appliccttinrz: (4) information on drilling hazards, iraclaidirag (A) the maximum dou=nDtole pressure that may be encourzterecl. criteria used to determine it, grad maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-133 Ll is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,243 psi. 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 3,657'. The MPSP is: MPSP = (3,657 ft)(0.45 - 0.11 psi/ft) =1,243 psi {I1 data on poteratical gas zones; The well bore is not expected to penetrate any gas zones. .4nd (C) data concerning potential causes of hole problems such as abnorrnatly geo presszrred strata, last circ;;°relcation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An applr.`cation,for aPermit to Drill roust be accompanied by each of the follotiving items, except for an item already on file witlt the commission and identified in the application: (.5) ca descr• ption of the procedure for conducting formation integrity tests, as reguired zincler 2O A.%fC ? E.03(>(f); No formation integrity test will be performed in the drilling of 1J-133 L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) .An application for za Perrrzit Go Drill must be uccornpunied by each ofthe f+~llowing items, exc~epPfor an item already on file with the cnmrnission and identified in thetatrphcation: 1J-133 L1 PERMIT IT Page 3 of 6 Printed: 14-Jul-O6 OR161NAL Applic~or Permit to Drill, Well 1J-133 L1 Revision No.O Saved: 14-Jul-06 lb,) a complete proposed casing arxd cementing program as required by 2(3.440 24.1130, and a description ofany slotted liner, pre prerforated diner, or screen to be installed,• Casing and Cementing Program See also Attachment 3: Cement Summar L Hole Top Btm Csg/Tbg Size Weight Length MD/TVD 1LID/TVD OD (in) (in) Qb/ t) Grade Connection (ft) (ft) (ft) Cement Pro ram 20" 40" 62.5 H-40 Welded 80 40' / 40' 108' / 108' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,666 40' / 40' 3,706' / 2,225 700 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 6,140' 9-5/8" 12-1/4" 40 L-80 BTCM 10 650 40' / 40' 10 690' / 3 703' MD / 2,898' TVD. Cemented , , , w/ 810 sx DeepCRETE 5-1/2 lotted 8-1/2" B Sand Lateral 1J-133) 15.5 L-80 BTCM 5,675 9,875' / 3,607' 16,365' / 3,688 Slotted-no cement - lotted 8-1/2" D Sand Lateral (1J-133 Ll) 15.5 L-80 BTCM 6,581 9,775' / 3,590' 16,356' / 3,622 Slotted- no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Art applicatiorzfor a Permit to Drill must be aaccompanied by each o_f the following items, except for an item already on file with the comrrzission and ideratifred in the application: (7) a diagram arrtl description of the diverter,rysterra as required by 2tJ <L4£' 25.035, unless this reyuirernerat r,"s waived by the commission under 204~IC25.035(h){2); No diverter system will be used during operations on 1J-133 Ll 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 4.n rxpplicatior2 for a Peranit to Drill must be accompanied by each of the following items, except for an item already on file with the cornrnission and identified in the alrplicatiora (~) a drilling fluid program, includin,4 a diagram and description of the drilling fluid system, as required by 2Cl A_4C 2.5.1133; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (pp) 9.0 Plastic Viscostiy 15-25 (lb/100 s~ Yield Point (cP) 18 28 HTHP Flu-id loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical Stability >600 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. ORIGINAL 1J-133 L1 PERMIT IT Page 4 of 6 Printed: 14-Jul-06 Applic~or Permit to Drill, Well 1J-133 L1 Revision No.O Saved: 14-Jul-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application.}r a Permit to Drill must be accompanied by each of the fbllowirzg items, except for• an item already on t'zle witFa the commission and identifed in the applrcation: {9) for an exploratory or stratigraplaic test well, a tabulation setting oul the depths of predicted abnormally geo-pressured strata as t•eguired by 2U AA.C 25.O33(x; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill rmrst be accompanied by each of the following sterns, cxeept for an item ah-ezufy oat file with the commission and identified in the application: (1 C1), for an exploratory ar stratigraphic test well, a seisvaic refraction or r•eJlec°tion analysis as r•egteired by 24 fLAC 23. f161(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) Art application, fir a Permit to Drill must be accompanied liy each of the follotivirag items, except for• an item already. ara file wiifa the commission and identified in the application: (11) for ca wedZ drilled from an offshore plaiform, naohtte bottom-founded suzrcture, jack-up rig, or^ floating drzllinn i~essel, an artalvsis of seabed condztioru as reguired by 20 AAC 25.0G1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An upplicutlnn for• a Permit to Drill must be accompanied fly each of the_followfng items, except for an item ab°eady oft lrle sviPh tlae commission marl identified in the application: (12) evideraee showing that the r°eguirernents of 2~ AAC 2~. (125 {Bonding}hm~e 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) Art application for a Permit to C?rill must he accompanied by each of the following items, except far an item already on fzle wiih the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. Note: Previous operations are covered under the 1J-133 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 9,775' MD / 3,590' TVD, the top of the "D" sand. ' 2. Mi118-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. /G 3S~ ' 3 G u.' ~ 7. z~~ ~ 4. Drill to TD of "D" sand lateral atl~r~''1GID /~8'8' TV , as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. 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. POOH. 11. POOH, laying down drill pipe as required. 1J-133 L1 PERMIT IT Page 5 of 6 g p ~ Printed: 14-Jul-O6 Applicator Permit to Drill, Well 1J-133 L1 Revision No.O Saved: 14-Jul-06 12. PU injection 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 by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 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 +/- 180 days. 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) .4ra applr`catzora.far a Permit to Drill naustc he accompanied by each of the f~llalving items, except far an item already an file with the corrirnission and ident~ed in the apptication,~ (I4J a beneral description of laow the operator plans to dispose ofdrillirag mud acrd cuttir2~?s arul ca stcaterraent of whether the operator zntencds to request authari~atign under 2D AJC 2~.(?80 far an annular disposal operatiat; 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 lE 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-133 L1 PERMIT IT Page 6 of 6 ~ ' ~ Printed: 14-Jul-06 ~'1 ``' ~\~~ttg ~~~.r vet . r s.... • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-133 -Slot 1J-133 1J-133 L1 Plan: 1J-133 L1 (wp06) Proposal Report 17 January, 2006 11-1A~L..~~J Ci Sperry Drilling Services ,.A, ~~~~~~~ • H llib t E i S • ' ' a ur on nergy erv ces ~a~tl~Lt>~tua~r~~l ~at 1C3C© ~ 11~~i S ~ .__~_ Planning Report -Geographic A1 a g~ny priilfng services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1 J-133 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Doyon 15 - RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 - RKB @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1J-133 L1 Design: 1J-133 L1 (wp06) 'roject Kuparuk River Unit, North Slope Alaska, United States dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level 9eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor Web Plan 1J-133 -Slot 1J-133 I Well Position +N/-S 0.00 ft Northing: 5,945,435.87 ft Latitude: 70° 15' 41.490" N +E/-W 0.00 ft Easting: 558,916.79 ft Longitude: 149° 31' 25.425" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-133 L1 ~ - 'Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2004 9/14/2004 24.62 80.72 57,572 Design 1J-133 L1 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 9,775.01 Vertical Section: Depth From (TVD) +N/S +E/-W Direction 40.00 0.00 0.00 180.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) {°) 9,775.01 80.00 175.86 3,590.00 -6,914.34 4,422.67 0.00 0.00 0.00 0.00 9,791.51 82.24 175.86 3,592.55 -6,930.60 4,423.85 13.60 13.60 0.00 0.00 9,821.51 82.24 175.86 3,596.59 -6,960.25 4,426.00 0.00 0.00 0.00 0.00 10,056.04 89.28 175.86 3,613.92 -7,193.38 4,442.87 3.00 3.00 0.00 0.00 10,485.52 89.57 177.99 3,618.22 -7,622.19 4,465.92 0.50 0.07 0.50 82.23 11,467.44 89.57 177.99 3,625.58 -8,603.48 4,500.39 0.00 0.00 0.00 0.00 11,605.70 88.88 177.96 3,627.45 -8,741.65 4,505.28 0.50 -0.50 -0.02 -177.70 12,261.22 88.16 171.44 3,644.41 -9,393.78 4,565.76 1.00 -0.11 -0.99 -96.40 12,361.96 88.16 171.44 3,647.65 -9,493.36 4,580.74 0.00 0.00 0.00 0.00 13,109.04 90.40 178.57 3,657.06 -10,237.01 4,645.71 1.00 0.30 0.95 72.60 13,281.70 91.26 178.57 3,654.55 -10,409.60 4,650.02 0.50 0.50 0.00 0.00 14,436.41 91.26 178.57 3,629.09 -11,563.67 4,678.83 0.00 0.00 0.00 0.00 14,609.07 90.40 178.57 3,626.59 -11,736.26 4,683.14 0.50 -0.50 0.00 -180.00 14,816.09 89.89 177.67 3,626.06 -11,943.16 4,689.93 0.50 -0.24 -0.44 -119.22 15,875.88 89.89 177.67 3,628.01 -13,002.07 4,733.08 0.00 0.00 0.00 0.00 16,109.12 90.98 177.24 3,626.23 -13,235.07 4,743.44 0.50 0.47 -0.18 -21.46 16,356.15 90.98 177.23 3,622.00 -13,481.77 4,755.35 0.00 0.00 0.00 -89.56 1/17/2006 4:Oti:15PM Page 2 of 5 COMPASS 2003.11 Build 48 n . ~ y , '~ a~a_ ~' ~H llib E S i ~ t ` w ~' a ur on nergy erv ces HALt,.IBURTON ~i~~ 1dCt3 ~ 11~~1~35 Planning Report -Geographic °°~-------~~-TM---~~~--------~-- Alaska n'Y t~~il!!ng :iervtces Database: EDM 2003.11 Single U ser Db Local Co-ordinate Reference: Well Plan 1 J-133 -Slot 1 J-133 Company: ConocoPhillips Alaska (Kuparuk). TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 421.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True , Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature , Wellbore: 1J-133 L1 Design: 1J-133 L1 (wp06) Planned Survey 1J-133 L1 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9,775.01 80.00 175.86 3,590.00 3,469.00 -6,914.34 4,422.67 5,938,557.00 563,393.00 0.00 6,914.34 L1:Top of Window : 13ft FNL & 2120ft FWL - Sec 12 - T10 N - R10W : 9775ft MD, 3590ft TVD - 9 5/8" . 9,791.51 82.24 175.86 3,592.55 3,471.55 -6,930.60 4,423.85 5,938,540.75 563,394.30 13.60 6,930.60 9,800.00 82.24 175.86 3,593.69 3,472.69 -6,938.99 4,424.46 5,938,532.37 563,394.98 0.00 6,938.99 9,821.51 82.24 175.86 3,596.59 3,475.59 -6,960.25 4,426.00 5,938,511.13 563,396.68 0.00 6,960.25 9,900.00 84.60 175.86 3,605.59 3,484.59 -7,038.01 4,431.63 5,938,433.42 563,402.92 3.00 7,038.01 10,000.00 87.60 175.86 3,612.39 3,491.39 -7,137.51 4,438.83 5,938,333.99 563,410.90 3.00 7,137.51 10,056.04 89.28 175.86 3,613.92 3,492.92 -7,193.38 4,442.87 5,938,278.15 563,415.38 3.00 7,193.38 10,100.00 89.31 176.08 3,614.46 3,493.46 -7,237.23 4,445.96 5,938,234.34 563,418.81 0.50 7,237.23 10,200.00 89.38 176.57 3,615.60 3,494.60 -7,337.02 4,452.37 5,938,134.61 563,426.00 0.50 7,337.02 10,300.00 89.45 177.07 3,616.63 3,495.63 -7,436.86 4,457.92 5,938,034.83 563,432.32 0.50 7,436.86 10,400.00 89.51 177.56 3,617.54 3,496.54 -7,536.74 4,462.60 5,937,934.99 563,437.79 0.50 7,536.74 10,485.52 89.57 177.99 3,618.22 3,497.22 -7,622.19 4,465.92 5,937,849.58 563,441.77 0.50 7,622.19 10,500.00 89.57 177.99 3,618.33 3,497.33 -7,636.67 4,466.42 5,937,835.11 563,442.40 0.00 7,636.67 10,600.00 89.57 177.99 3,619.08 3,498.08 -7,736.60 4,469.94 5,937,735.22 563,446.69 0.00 7,736.60 10,700.00 89.57 177.99 3,619.83 3,498.83 -7,836.54 4,473.45 5,937,635.32 563,450.98 0.00 7,836.54 10,800.00 89.57 177.99 3,620.58 3,499.58 -7,936.47 4,476.96 5,937,535.42 563,455.27 0.00 7,936.47 10,900.00 89.57 177.99 3,621.33 3,500.33 -8,036.41 4,480.47 5,937,435.53 563,459.57 0.00 8,036.41 11,000.00 89.57 177.99 3,622.08 3,501.08 -8,136.34 4,483.98 5,937,335.63 563,463.86 0.00 8,136.34 11,100.00 89.57 177.99 3,622.83 3,501.83 -8,236.28 4,487.49 .5,937,235.74 563,468.15 0.00 8,236.28 11,200.00 89.57 177.99 3,623.58 3,502.58 -8,336.21 4,491.00 5,937,135.84 563,472.44 0.00 8,336.21 11,300.00 89.57 177.99 3,624.32 3,503.32 -8,436.15 4,494.51 5,937,035.95 563,476.74 0.00 8,436.15 11,400.00 89.57 177.99 3,625.07 3,504.07 -8,536.09 4,498.03 5,936,936.05 563,481.03 0.00 8,536.09 11,467.44 89.57 177.99 3,625.58 3,504.58 -8,603.48 4,500.39 5,936,868.68 563,483.92 0.00 8,603.48 11,500.00 89.41 177.98 3,625.87 3,504.87 -8,636.02 4,501.54 5,936,836.16 563,485.32 0.50 8,636.02 11,600.00 88.91 177.96 3,627.34 3,506.34 -8,735.95 4,505.08 5,936,736.27 563,489.65 0.50 8,735.95 11,605.70 88.88 177.96 3,627.45 3,506.45 -8,741.65 4,505.28 5,936,730.57 563,489.89 0.50 8,741.65 1J-133 L1 T1 Peak 1 (wp05) 11,700.00 88.78 177.02 3,629.38 3,508.38 -8,835.83 4,509.41 5,936,636.43 563,494.76 1.00 8,835.83 11,800.00 88.66 176.03 3,631.61 3,510.61 -8,935.62 4,515.47 5,936,536.70 563,501.59 1.00 8,935.62 11,900.00 88.55 175.03 3,634.04 3,513.04 -9,035.29 4,523.26 5,936,437.11 563,510.16 1.00 9,035.29 12,000.00 88.44 174.04 3,636.66 3,515.66 -9,134.80 4,532.77 5,936,337.69 563,520.46 1.00 9,134.80 12,100.00 88.33 173.05 3,639.47 3,518.47 -9,234.12 4,544.01 5,936,238.46 563,532.47 1.00 9,234.12 12,200.00 88.22 172.05 3,642.48 3,521.48 -9,333.23 4,556.98 5,936,139.47 563,546.21 1.00 9,333.23 12,261.22 88.16 171.44 3,644.41 3,523.41 -9,393.78 4,565.76 5,936,078.99 563,555.46 1.00 9,393.78 12,300.00 88.16 171.44 3,645.66 3,524.66 -9,432.11 4,571.53 5,936,040.71 563,561.53 0.00 9,432.11 12,361.96 88.16 171.44 3,647.65 3,526.65 -9,493.36 4,580.74 5,935,979.55 563,571.22 0.00 9,493.36 12,400.00 88.27 171.81 3,648.83 3,527.83 -9,530.97 4,586.28 5,935,941.98 563,577.06 1.00 9,530.97 12,500.00 88.57 172.76 3,651.59 3,530.59 -9,630.02 4,599.70 5,935,843.05 563,591.25 1.00 9,630.02 12,600.00 88.87 173.71 3,653.82 3,532.82 -9,729.30 4,611.48 5,935,743.87 563,603.80 1.00 9,729.30 12,700.00 89.17 174.67 3,655.53 3,534.53 -9,828.77 4,621.59 5,935,644.49 563,614.70 1.00 9,828.77 12,800.00 89.47 175.62 3,656.71 3,535.71 -9,928.41 4,630.06 5,935,544.94 563,623.94 1.00 9,928.41 12,900.00 89.77 176.58 3,657.37 3,536.37 -10,028.17 4,636.86 5,935,445.24 563,631.52 1.00 10,028.17 13,000.00 90.07 177.53 3,657.51 3,536.51 -10,128.04 4,642.00 5,935,345.43 563,637.44 1.00 10,128.04 13,100.00 90.37 178.48 3,657.12 3,536.12 -10,227.98 4,645.48 5,935,245.53 563,641.70 1.00 10,227.98 13,109.04 90.40 178.57 3,657.06 3,536.06 -10,237.01 4,645.71 5,935,236.50 563,642.00 1.00 10,237.01 1J-133 L1 T2 Trough 1 (wp06) 13,200.00 90.85 178.57 3,656.06 3,535.06 -10,327.94 4,647.98 5,935,145.60 563,644.98 0.50 10,327.94 13,281.70 91.26 178.57 3,654.55 3,533.55 -10,409.60 4,650.02 5,935,063.96 563,647.66 0.50 10,409.60 1/17/2006 4:06:15PM Page 3 of 5 COMPASS 2003.11 Build 48 ORI~'~~~."~ • Hallib rt n E S i • . f C4C14COPI1I~Il~'t5 u o nergy erv ces Hp-~.~~BUR-rc~N Plannin R t G hi -- - - -- g epor - eograp c Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1 J-133 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Doyon 15 -RKB @ 121:OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 -RKB @ 121.DOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Wellbore: 1J-133 L1 Design: 1J-133 L1 (wp06) ,Planned Survey 1J-133 L1 (wp06) -- - - - -- Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 13,300.00 91.26 178.57 3,654.15 3,533.15 -10,427.89 4,650.47 5,935,045.68 563,648.26 0.00 10,427.89 13,400.00 91.26 178.57 3,651.94 3,530.94 -10,527.83 4,652.97 5,934,945.77 563,651.54 0.00 10,527.83 13,500.00 91.26 178.57 3,649.74 3,528.74 -10,627.78 4,655.46 5,934,845.86 563,654.81 0.00 10,627.78 13,600.00 91.26 178.57 3,647.54 3,526.54 -10,727.72 4,657.96 5,934,745.94 563,658.09 0.00 10,727.72 13,700.00 91.26 178.57 3,645.33 3,524.33 -10,827.67 4,660.45 5,934,646.03 563,661.37 0.00 10,827.67 13,800.00 91.26 178.57 3,643.13 3,522.13 -10,927.61 4,662.95 5,934,546.12 563,664.64 0.00 10,927.61 13,900.00 91.26 178.57 3,640.92 3,519.92 -11,027.56 4,665.44 5,934,446.21 563,667.92 0.00 11,027.56 14,000.00 91.26 178.57 3,638.72 3,517.72 -11,127.50 4,667.94 5,934,346.29 563,671.20 0.00 11,127.50. 14,100.00 91.26 178.57 3,636.51 3,515.51 -11,227.45 4,670.43 5,934,246.38 563,674.47 0.00 11,227.45 14,200.00 91.26 178.57 3,634.31 3,513.31 -11,327.39 4,672.93 5,934,146.47 563,677.75 0.00 11,327.39 14,300.00 91.26 178.57 3,632.10 3,511.10 -11,427.33 4,675.42 5,934,046.56 563,681.02 0.00 11,427.33 14,400.00 91.26 178.57 3,629.90 3,508.90 -11,527.28 4,677.92 5,933,946.64 563,684.30 0.00 11,527.28 14,436.41 91.26 178.57 3,629.09 3,508.09 -11,563.67 4,678.83 5,933,910.26 563,685.49 0.00 11,563.67 14,500.00 90.95 178.57 3,627.87 3,506.87 -11,627.23 4,680.41 5,933,846.73 563,687.58 0.50 11,627.23 14,600.00 90.45 178.57 3,626.66 3,505.66 -11,727.19 4,682.91 5,933,746.80 563,690.86 0.50 11,727.19 14,609.07 90.40 178.57 3,626.59 3,505.59 -11,736.26 4,683.14 5,933,737.73 563,691.15 0.50 11,736.26 1J-133 L1 T3 Peak 2 (wp06) 14,700.00 90.18 178.17 3,626.13 3,505.13 -11,827.15 4,685.72 5,933,646.88 563,694.45 0.50 11,827.15 14,800.00 89.93 177.74 3,626.03 3,505.03 -11,927.08 4,689.29 5,933,546.98 563,698.80 0.50 11,927.08 14,816.09 89.89 177.67 3,626.06 3,505.06 -11,943.16 4,689.93 5,933,530.91 563,699.57 0.50 11,943.16 14,900.00 89.89 177.67 3,626.21 3,505.21 -12,027.00 4,693.35 5,933,447.11 563,703.64 0.00 12,027.00 15,000.00 89.89 177.67 3,626.39 3,505.39 -12,126.92 4,697.42 5,933,347.24 563,708.49 0.00 12,126.92 15,100.00 89.89 177.67 3,626.58 3,505.58 -12,226.83 4,701.49 5,933,247.36 563,713.34 0.00 12,226.83 15,200.00 89.89 177.67 3,626.76 3,505.76 -12,326.75 4,705.56 5,933,147.49 563,718.20 0.00 12,326.75 15,300.00 89.89 177.67 3,626.95 3,505.95 -12,426.67 4,709.63 5,933,047.62 563,723.05 0.00 12,426.67 15,400.00 89.89 177.67 3,627.13 3,506.13 -12,526.58 4,713.71 5,932,947.75 563,727.90 0.00 12,526.58 15,500.00 89.89 177.67 3,627.31 3,506.31 -12,626.50 4,717.78 5,932,847.87 563,732.75 0.00 12,626.50 15,600.00 89.89 177.67 3,627.50 3,506.50 -12,726.42 4,721.85 5,932,748.00 563,737.61 0.00 12,726.42 15,700.00 89.89 177.67 3,627.68 3,506.68 -12,826.34 4,725.92 5,932,648.13 563,742.46 0.00 12,826.34 15,800.00 89.89 177.67 3,627.87 3,506.87 -12,926.25 4,729.99 5,932,548.26 563,747.31 0.00 12,926.25 15,875.88 89.89 177.67 3,628.01 3,507.01 -13,002.07 4,733.08 5,932,472.47 563,750.99 .0.00 13,002.07 15,900.00 90.01 177.62 3,628.03 3,507.03 -13,026.17 4,734.07 5,932,448.38 563,752.17 0.50 13,026.17 16,000.00 90.47 177.44 3,627.61 3,506.61 -13,126.07 4,738.38 5,932,348.52 563,757.26 0.50 13,126.07 16,100.00 90.94 177.26 3,626.38 3,505.38 -13,225.96 4,743.01 5,932,248.69 563,762.67 0.50 13,225.96 16,109.12 90.98 177.24 3,626.23 3,505.23 -13,235.07 4,743.44 5,932,239.58 563,763.18 0.50 13,235.07 1J-133 L1 T4 Trough 2 (wp06) 16,200.00 90.98 177.24 3,624.67 3,503.67 -13,325.83 4,747.82 5,932,148.87 563,768.26 0.00 13,325.83 16,300.00 90.98 177.24 3,622.96 3,501.96 -13,425.70 4,752.64 5,932,049.05 563,773.87 0.00 13,425.70 • 16,356.15 90.98 177.23 3,622.00 3,501.00 -13,481.77 4,755.35 5,931,993.01 563,777.01 0.00 13,481.77 . BHL @ 130 1ft FNL 8 2446ft FWL -Sec 13 - T10N - R10E : 16357ft MD, 3622ft TVD - 1J-133 L1 T5 Toe (wp06) 1/17/2006 4:06:15PM Page 4 of 5 COMPASS 2003.11 Build 48 ~~t~:~ • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-133 1J-133 L1 Anticollision Summary 17 January, 2006 • Sperry drilling Services ~!~!~INAl.. % y, CanacaPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk Project: KuparufcRiver Unit Site: Kuparuk 1J Pad Well: Plan 1J-133 Wellbore: iJ-133 L1- Design: 1J-133 L1 (wp06) Geologic Targets 1J-133 L1 Halliburton Energy Services. ~,q,~,L~B~~..~-oN Planning Report -Geographic ~--~--~--- ~--~--~-°- Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 TVD Reference: Doyon 15 -RKB @ 121 a)Oft (Doyon 15 (81+40)} MD Reference: Doyon 15 -RKB Q,121:OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature TVD Target Name (ft) -Shape 3,626.59 1J-133 L1 T3 Peak 2 (wp06) - Point 3,622.00 1J-133 L1 T5 Toe (wp06) - Point 3,627.45 1J-133 L1 T1 Peak 1 (wp06) - Point 3,626.23 1J-133 L1 T4 Trough 2 (wp06) - Point 3,657.06 1J-133 L1 T2 Trough 1 (wpO6y - Point Prognosed Casing Points Measured Vertical Depth Depth (ft) (ft) 3,706.03 2,225.00 9,775.02 3,590.00 16,356.61 3,621.99 +N/-S +E/-W Northing Easting ft ft (ft) (ft) -11,736.26 4,683.14 5,933,737.73 563,691.15 -13,481.77 4,755.35 5,931,993.01 563,777.01 -8,741.65 4,505.28 5,936,730.57 563,489.89 -13,235.07 4,743.44 5,932,239.58 563,763.18 -10,237.01 4,645.71 5,935,236.50 563,642.00 Casing Diameter (") 13-3/8 9-518 5-112 Hole Diameter (") 16 12-1 /4 8-1/2 1/17/2006 4:06:15PM Page 5 of 5 COMPASS 2003.11 Build 48 0~~~~~w. ~ C °cd ~ ~ ? Ehv mm $ ~ 3.E ~A GNU C~ dy c ° _ i oh LNC'C^ ~ L c ~ O ~ y ~ ` O O U o c o_ w ~ _ ~ W 3 N U O ~ H ~ O O tD ~ I ~ N O n ~ 3 ° 3- r 3 t n rn `~ ay3 ~ ~ ~ v O a r` n rr ~ ~ ~ ~~ J J J J J a N ~ o ~ ~ b >~~ oammn bbNl~l~gmmm~ ~M ~oee o ^ rv~ ~ ~ouoowowooov~ionv~iono J F 00~ nooo~o~ooooo0 W ° 3^~ '°a~ ^~^e~~ O ~r,".~nHho~v~ie au°~~wwnaw F ~~~~~~aaevavvaaeaa U W ~ ~e~b ~du o{~ V o 0o 00 } ~ O V ~ O N d vii rv V >0 ov~iNmHh~a F o rvyd OVAi vii PiHrv n n g q m m m< O N N N h 1~0 u N N ddaDnnro~O ~O C O ~v rv rv N yN b ~ ~ d N N< amo b ~ O N N O N d n ~y yy A ~ O~~ n V O V N ~ ~ ~ ~ ~ ~ ~ tl1~tV rfdN~Onmm~~e-~~~~- P „ O ~ J r C a uj' °o aq o ~_~ 6 qy W J ~ O J 9 ~ OAT C acn N ~~' a wm y N Q ~m c 2 N 3$ e g • O O «P e "~ ~ - ^ ~ ; Z .~pNJ y~N W _Fn'^. H O 00 H ~ ~ ~ A ~ ca O ° ~ £ E ~ d F f LL ~ c z E~ a o or'- `w m ~ x ~ o~~ at .`: fi c $i N V`i ti~ C~+ Y :{ y<Q ~ ~~~ e j. -V GC C v FUSE V C ~ a S 5 _~ > ~ H ~ ~ ~ ~ 1-~_' ^ G y z - E~38o ~,~QK y~ =^ O 0 M ~ ` I J N m 0 N 0 N CD C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O r O O~ N N N M cN') V V~~ fop N~ r aOD O~ r .- ~- r r r ~- .- ~ r ~-- i r ~- r ~- r V I I( I I ., I I I I( i 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O^i O O O N N N tO') t+Ni ~ O b N N N~ r C W 0 C O .~ Q L L' U r i C U y 0 e 'i.. t. Q .b C U b0 C v L F" °a °a c~ 2~ O O r o 0 vi O O ~t ~~ ~owo `on y~z~~ ~yoY~ O ~~,^y~V a q~~~E C a ~ `o E O c o c c z 3GNOf W N ai d d V C C C C L ~ ~ 1 r2 W CCKCp R' ~OyG g »4~ A~g~ m~L~~ c C y ~ b~ A U ~ ~-` ~ Halliburton Energy Services HAL.t..lBURTt~tV C0110Ct?PI11I~~5 Anticollision Report - --- Sperry CrillYng Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-133 -Slot 1J-133 Project: Kuparuk River Unit TVD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Reference Site: Kuparuk 1J Pad MD Reference: Doyon 15 -RKB @ 121.OOft (Doyon 15 (81+40)) Site Error: O:OOft North Reference: True Reference Well: Plan 1J-133 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-133 L1 Database: EDM 2003.11 Single User Db Reference Design: 1J-133 L1 (wp06) OffsetTVD Reference: Reference Datum Reference 1J-133 L1 (wp06) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 9,775.01 to 16,357.06ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,831.71ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1/17/2006 From To (ft) (ft) Survey (Wellbore) 40.00 800.00 1J-133 (wp06) (1J-133) 800.00 9,775.01 1J-133 (wp06) (1J-133) 9,775.01 16,356.15 1J-133 L1 (wp06) (1J-133 L1) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _._-_~ Summary Site Name Offset Well -Wellbore -Design Kuparuk 1 J Pad 1 J-14 - 1 J-14 - 1 J-14 Plan 1J-129 -Plan 1J-129 - 1J-129 (wp02) Plan 1 J-130 -Plan 1 J-130 - 1 J-130 (wp02) Plan 1J-132 -Plan 1J-132 - 1J-132 (wp02) Plan 1J-133 - 1J-133 - 1J-133 (wp06) Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) Plan 1J-136- 1J-136- 1J-136 (wp03) Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp03) Plan 1J-137- 1J-137- 1J-137 (wp03) Plan 1J-137- 1J-137 L1 - 1J-137 L1 (wp03) Plan 1J-174 -Plan 1J-174 - 1J-174(wp01) Plan 1J-176 -Plan 1J-176 - 1J-176 (wp01) Plan 1J-178 -Plan 1J-178 - 1J-178 (wp01) Plan 1J-180 -Plan 1 J-180 - 1 J-180 (wp01) Plan 1J-182 - 1J-182 - 1J-182 (wp05) Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) Plan 1J-184 - 1J-184 - 1J-184 (wp09) Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09) Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 15,518.44 16,799.16 1,060.55 9,799.95 9,799.96 0.65 9,804.71 9,450.00 1,292.76 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) Out of range Out of range 413.51 647.04 Pass -Major Risk Out of range 3.80 -3.15 FAIL - No Errors 265.25 1,027.51 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17/2006 4:19:36PM Page 2 of 2 COMPASS 2003.11 Build 48 ORIGINAL 1J-133L1 drilling Hazards~mmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure 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-133L1 Drilling Hazards Summary 7/14/2006 10:36 AM ~~ V ^~ Y l~ Tubing, Special Drift to +l- 500' MD DB Nipple, set at +l- 500' MD GLM, Camco, 4112" x 1" KBMG 13-3I8" Casing Shoe, ~ GLM, Camco, 4-112" x 1" KBMG 68#, L-80, BTC set 3706' MD, 2225' ND ~ CMD Sliding Sleeve, w/ DB Nipple Tubing String / 4712" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift Locating seal Assembly 4.75" Seal OD 7" X 9-518" ZXP Liner Top Piker wkh Hold Downs ~~ Casing Sealbore F 4.75" ID Lateral Entry Module ILEM- Assembly ~__ 7" X 9-518" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ezt. ID 6.278" Tool Body ID '` Casing Sealbore Receptacle 4.75" ID, 5.75" OD 20' Length F_~-- Orienting Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID \ Access Window Positive Lateral Access Via Thru-Tubing Divener Seal Bore for Lateral Isolation - 9.fi88" ID ~\ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Lenglh ,.. ConocaPhillips West Sak 9-5/8" Injector 1 J-133 Dual Lateral Completion OrEntry Motlu M) 1 - ~ `~~-S ~~ B-sand Window \` 'D' Sand LateralSand` 'Lateral at 9775' MD, 3590' ND / 5112" 15.5#, BTC, L~80 Slotted Liner / Eery Donor Joint Liner Swivel y~~ -.. .,_ 7~ arcs 3.562" DB Nipple ID 5112" Bent Jdnt I or deep aPPnW ( PP 5712" Guide Shoe --- 5-112" Casing Shoe, 15.5#, L-80 BTCM Set @ 16356' MD, 3622' ND 4112" t2.fi#Tubing 1 3.893" Drill 1 3.958" ID 7" %9-518" ZXP Seal Assemby Liner Top Packer 4.75" Seal OD ~ 3.875"ID '13' Sand Lateral 5712" 75.5#, BTC, 7" X 9-518" Flex Lock L-80 Slotted Liner Liner Hangar /Packer Assembly at Liner Hanger Every Ot er Joint 51/2" Eccentric +/-9750'MD Casing Sealbore Receptacle 4.75"ID ~ i Guide Shce ~ ' ~.~ ,.~_..,-.,~ , 9-518" Casing Shoe, 40.0#, L-80 BTC ~ 10690' MD, 3703' ND (84 deg inc) esker Huenes tool. rnis do<umem may not 6e revroavicee or a~sn~nwee, .n wnoi<o. in pan, in any roan or ray any means elecvonic or mecnanirat induain9 p~orocopr~ng, ,e o~nv, or nv air inrormauon amrape and rerieval ardem now known ar nereaner invenrea, wanom wre,eorpermias.on Dom sake. Huenea inc. As Planned With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverkr GS Running Tool String Insfalletl Insfalkb (3.00" Lateral Drill) (2.50" ID Mainbore Drgt) 'GS' Profile for Coil Connector f RunninglRetrieving \ i (1.00' Lenglh) I Snap In/Snap Out r Hack Pressure Valve /Positive Locating ll t C (1.60' Length) o e l I l ti ~~ L t ~ Flow-Thru Swivel era so a on a Seals ~ ~ (1.25' Length) Lateral Diverter ' ~ ~ / Hydraulk Ramp ~ Disconnect , 1- IsolatioN Mainbore (1.50' Length) Diverter Sleeve r l_5p•Len Lateral lsda8on ~~ sees 6.85 ft Approx OAL' Jars may be required in highly devia bons 6' a ox lana 19' Divener Length 79' Sleeve Lergth ' i 5-112" Casing Shoe, 15.5#, BTCM Set ~ 16365' MD, 3688' ND Equipment Specifications 7" X 9-518" HOOK Hanger Mainbore Driff: 7.00" Mainbore Driff, whh diverter: 6.25" Lateral Drift, no diverter or LEM: 6.28" Lateral Drift, wl diverter, no LEM: 5.72" LateraOMainbore Diverter OD: 8.50" 4112" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Driff, wl isolation sleeve: 2.50" Lateral Driff, wl coil diverter: 9.00" OD of Diverter and Sleeve:+I- 3.60" Diverter and Sleeve Length: +I- 19' n.. wuc;xEs Baker Oil Tools i • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~~ ~ 3'3 ~- PTD# Z ~ (~ "` ~D Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /C12G~ / ~/ ' X33 , (If last two digits in permit No.2D(p- /v,6 , API No. 50-Q2'g Z.3 3 /5" G'e~S API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: ~ Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Company Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25x06 C:\jody\transmittal_checklist WELL PE MIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-133L1 Program SER Well bore seg ^ PTD#:2061070 Company CONOCOPHILLIPS ALASKA INC Initial Classll-ype SER 1 PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached- - - - - - - - - - - - - - - - _ NA- - - - - -West Sak D Sand multilateral well branch; fee_wa_ived per 20 AAC 25.005(e)._ _ - - 2 Lease number appropriate - - Yes - - - - - 3 Unique well-name andnumbe[ ___ ________ _____ ___ __ _ _ Yes__ _-. ---__ _ -_____ __ ------------------------------------------------ 4 Well located in a-defined_pool_--_- -_____----------------- ---- Yes_- _____KuparukRiver,West_SakOilPool-490150,-goyemed-byC0406B__---_____-----___-_-__--_- 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - --- Yes - WeU is mare than-500 feet from an externs! properfyline. - _ _ _ _ - _ _ _ _ - - _ - - - - _ - _ _ _ - _ _ - - - 6 Well located proper distance from other wells_ - Yes - - - - - . CO 4068, Rule 3:_ no restrictions as_to well spacing except that no_pay shall be opened in a well closer 7 Sufficient acreage available in_drillingunit- - - - - - - - - - - - - - - - - - - - - - - - - Yes - than 500 feet to_an external_property line where ownership_or landownership changes. - , _ - - - _ _ . _ _ - 8 If deviated, is_wellbore platincluded _ _ _ _ _ Yes 9 Operator only affected party_---------------------- --- ____ Yes --------------------------------------------------------------------- 10 Ope[atorhas_appCOpriatebondin-force ------------- -- ------ - - -.Yes--- --------- - - ----- -- ------- -- ------ ------ -- ---------- 11 Permit can be issued without conservation order - - - - Yes - Appr Date 12 Permit-can be issued without administ[ativ_e_approval---------------- ----__-_Yes-_- .__.._-_..____..___-_---..__.-.-_.----_.._--____.---. ----------------- SFD 7121/2006 13 Can permit be approved before 15-daywait Yes 14 Well located within area and strata authorized by Injection Order # (put10# in_comments)_(For Yes Area Injection Order No._ 2B _ _ - _ _ 15 A)Iwells-wRhin114-mileareaofreyiewidentified(Forcervicewellonly)______ _________Yes___ ___.Nowellswithin 114 mi1e--__-_._________-__-__-____-____--___-______-._.._-___ 16 Pre-produced injector; duration of pre production less than 3 months_ (For_senrice well only) Yes - KRU 1J-Pad_ injection wells are_typicallypre-produced 30-45 days for cleanup._ _ - - _ 17 Nonconven,gasconformstoAS31,05,030([.1.A),(~.2.A-D)_-_--------- --------- NA--_- ---_-__-_---__--__---._..-__- Engineering 18 Conductor string_provided _ _ - - - - - - - - -- - - -- - - - - - - -- - - - - - - NA- - - _ - _ _ - Conductor satin motherbore,-1J-133 (206-106).- - . - - . - - - - _ _ - _ _ - _ _ - - - -- 19 Surface casingprotects all known USDWs _ . . . . . ..... . . . . . . . . . . .. . . . . .. NA- - _ _ _ _ _ -All aquifers exempted, 40 CFR.147.102_ (b)~3)._ _ - . - _ . - - - - _ _ - _ _ - - - - . _ ------------------- 20 CMT-voladequate-toci[culate_on conductor&su_rf_csg_____-_-- _..-__.. NA--__ __--Surface casing set in 1J-133_______________________________-__-___ 21 CMT-vol-adequate_totie-in)ongstringto surfcsg------------------- -------- NA--__ ._--Productioncasingsetin-1J-133.__-___--_--.-------__- - -- - 22 CMT-willcoyerall known-productivehorizon_s___________________ __ N_o-__- ___-Slotted liner completion pl_anned,___-____________________-__________________-_--- 23 Casing designs adequate fo[G,T,B&_pe[mafrost________________ ________ NA____ ____1J-133metdesignspecifications,NAfQrslotted_liner,_____ ____________- _________--_--.- 24 Adequate tankage-or reserve pit Yes - _ _ _ _ - -Rig is-equipped with steel_pits. No_ rese_n!e_pitplanned, All waste to approved annulus or disposal well. 25 Ifa_re-drill,has_a_1.0-403forabandonmentbeenaRproved_____________ _____-_._N_A--__ _--- --__-_---___._ 26 Adequate wellbore separationproposed- - - - - - - - - - - - - - - - -- - - - - - - - -- - - - - - -Yes _ - - . - - _ Proximity analysis performed: Neare&t well segment is motherbore about 50' tyd deeper:. _ _ - - - _ _ _ _ - _ _ - _ 27 Ifdiverterlequired,doesitmeetregulations______ _____________ __________N_A____ ____BOPstack_willalready_beinplace,_-_____________________-____ ----------------- Appr Date 28 Drilling fiujd program schematic-& equip list adequate- Yes Maximum expected formation presscre 8.6_EMW._ Planned MW up to 9.0 ppg, TEM 7!2512006 29 BOPEs,-d9 they meet regulation_-__--------------------- ---------Yes.__ -__--__-.__--__--_--___--__--_------_--__-__--__----.---------- 30 BOPE_press rating appropriate; test to_(put prig in comments)_ - - - _ Yes MASP calculated at 1270 psi. 3K equipment arrangement and test pressure_planned. . 31 Choke_manifoldcomRliesw/APLRP-53(May84)__________________ _________Yes__- .___-__.____._ 32 Workwifloccurwithoutoperationshu-tdown_____________________ ____-_--_Yes.__ ___..___.___.--__..-__-.._-_-___.._..-_.--._-__-._. 33 Is presence-ofH2Sgas-probable-------------- ------______ -.------- No--_- __-H2Shasnctbeenreportedat1J_pad...___---.. 34 Mechanical condition of wells withinAORverifed(For_servicewellcnlyJ_____ _________Yes___ _-__NQwells withinll4mile._____________________-___-___-___ __- _-__-__________- Geology 35 Permitcan be issued wlo hydrogen_sulfide measures Yes No H2S has been measured in W Sak wells drilled south from 1J-Pad. 36 Data-presented on poteniia_I overpressure zones- - Yes - - - Expected res._pressure is 8,6-ppg EMW; will be drilled with 9.Oppg cil-based_mud. - - . - _ - - _ Appr Date 37 Seismicanalysis_ofshallowgaszones------------------------- -_..._.. NA-__ ___-.-_-.----__.-_--.-___-_-___--_--_-----__---__-._ ------------------- SFD 7!21/2006 38 Seabed conditionsurvey_(ifoff-shore)_________________________ ____-_-- NA--- - 39 Contactnamelphoneforweekly_progressreports[exploratoryonly]________ _________ NA___ _______ _-__-__-__-________-__________-________________________-________ Geologic Engineering P 'c Date: Date Date West Sak D Sand multilateral well branch; in actor 1 Commissioner: Commissioner: Co r DTs ~0~~ ~~ ~~'~;~~~ ~ ~'Z,6' ~ ~