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Home My WebLink About205-088Carlisle, Samantha J I From: Loepp, Victoria T (CED) Sent: Thursday, November 7, 2019 9:43 AM To: Carlisle, Samantha J (CED) Subject: FW: Request to Cancel 10-403 Approvals 318-068 and 318-069 Attachments: 1 E-1051_2 APPROVED 10-403 MARCIT D MBE Trtmnt Sundry App.pdf, 1 E-1261_2 APPROVED 10-403 MARCIT D MBE Trtmnt Sundry App.pdf Sam, Please handle. Thanx, Victoria From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Thursday, November 7, 2019 9:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-She rrod@ co ntractor.conocophilIips.com> Subject: Request to Cancel 10-403 Approvals 318-068 and 318-069 Hi Victoria, I wish to request that 10-403 Sundry Approvals #318-068 and #318-069 be canceled. These approvals were granted 2/26/18 for a proposed MARCIT MBE Treatment involving West Sak 1E-1051-2 and 1E-1261_2 which are connected by an open Matrix Bypass Event (aka: Void Space Conduit). The approved 10-403 Sundries to be canceled are attached for reference: The reason for the requested cancellation is based on accumulated treatment performance results data for MARCIT MBE vs. RPPG MBE treatments. Per our performance data to date, we now believe that we have a much better chance of obtaining a long term successful MBE treatment by treating 1E -105L2 MBE using RPPG rather than MARCIT. I will be sending new 1E -105L2 and 1E-1261-2 10-403's to AOGCC next week to request approval for an RPPG MBE treatment to be fullbore pumped into 1E-1051-2 as soon as possible. Regards, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office ABDMSI@) NOV 0 6 2019 ~' r:;? iT ~l i~ ',' q I iJ \ ¡, I i' '-v ~ ¡r,} U lb . rm~ :1 rE I H I," " Û, r',: ~u . AI..A!i1iA OIL Al'ft) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99519 Re: Kuparuk lE-108 ConocoPhillips Alaska, Inc. Permit No: 205-088 Surface Location: 311' FSL, 224' FEL, SEC. 16, TIIN, RI0E, UM Bottomhole Location: 851' FSL, 2708' FWL, SEe. 15, TUN, RI0E, 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 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 witness any required test. Contact the Commission's petroleum field inspector at (907) 59- 00 (pager). DATED this 10 day of June, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. .. ConocoPhillips Alaska .. Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 25, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Pennit to Drill, West Sak Injector, IE-I 08 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Pennits to Drill for a pre-produced onshore injection well, a conventional inj ector well in the West Sak sands. The well will be designated 1£-108. Please find attached for the review of the Commission fonns 10-401 and the infonnation required by 20 ACC 25.005 for each of these well bores. The expected spud date of IE-I 08 is June 7, 2005. If you have any questions or require any further infonnation, please contact Mike Greener at 263-4820. Sincerely, ~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ! ~- .. .. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSIOM!,:!<\ ,;",~.~.~ PERMIT TO DRILL 20 AAC 25.005 JUN 0:) .... ~"' 1 a. Type of Work: Drilll;j Re-entry D Redrill U 1 b. Current Well Class: Stratigraphic Test D Exploratory U Development Oil U Multiple Zone D Service [2] Development Gas D Single Zone [2] 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-108 .. 6. Proposed Depth: 12. Field/PooJ(s): MD: 5175'''' TVD: 3800' Kuparuk River Field 7. Property Designation: 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 311' FSL, 224' FEL, Sec. 16, T11N, R10E, UM Top of Productive Horizon: <" ADL 25651 / 8. Land Use Permit: 2560 West Sak Oil Pool 13. Approximate Spud Date: June 7, 2005 14. Distance to Nearest Property: 5056' at surface 15. Distance to Nearest 826' FSL, 2570' FWL, Sec. 15. T11 N, R10E, UM Total Depth: 851' FSL, 2708' FWL, Sec. 15, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): ALK 469 9. Acres in Property: 10. KB Elevation Surface: x- 550301'/ 16. Deviated wells: y- 5959901 ,/ Zone- 4 Kickoff depth: 450 / ft. Maximum Hole Angle: 60°' deg Specifications Hole 40" Casing 20" Weight Grade 62.5# H-40 29.7# L-80 15.5x9.3# L-80 Coupling Length MD TVD Welded 80' 28' 28' BTCM 3115' 28' 28' BTCMxEUE 5175' 28' 28' ~ D ~ .~~fr\'.-...... ~ Q;þ. '-....t' (Height above GL): 28' RKB feet Well within Pool: 700', to 1 E-1 03 17. Maximum Anticipated Pressures in psig (see 20 Me 25.035) Downhole: 1710 psig Surface: 1292 psig ,/ Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 108' 260 cf ArcticCrete 2457' 300 sx AS Lite, 150 sx DeepCrete 3800' 225 sx DeepCrete Top 18. Casing Program Size 9-7/8" 6-3/4" 7-5/8" MD 108' 3115' . 5175' , 5.5"x3.5" 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Length Size Cement Volume MD TVD Perforation Depth TVD (ft): 20. Attachments: Filing Fee [2] Property Plat D BOP Sketch D Diverter Sketch D Drilling Program 0 Seabed Report D Time v. Depth Plot D Drilling Fluid Program [2] Date: Shallow Hazard Analysis I:J. 20 MC 25.050 requirements [2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name R. Thomas Signature --'Y _~r' ~ ~ _ , ^' \ "^--' '~ Contact Mike Greener @ 263-4820 Title Kuparuk Drilling Team Leader Phon 265-6830 Date Ç( z...5" 10 r P C'h"mn AII.<mn-D""kF! Permit to Drill Number: 2...b5 - 088 Commission Use Only API Number: Permit APpro, J 50- D 2.-9 ,- z 32.b 7-DD Date: ~ 'I p / ~ , See cover letter for other requirements Conditions of approval: ~s required Yes D No ~ Mud log required Yes D No _ ,~/~en sulfide measures Yes ø No D Directional survey required Yes ~ No Other: V ) ~ L" ;¡~ ~~ 'N.. ßC ~ ~~ \.. \-\ (.\S) cg:.~ C'... \- ~(). \\ \-.( \ O~. <:.. f iJ';)í 't :c.C..J!;) rÐ '+-I t ~ \ 0 ~ ß APPROVED BY / / (/' Approved bj: Á V ~ íf/l THE COMMISSION Date: t::>/t () I ð::> - I / '-'" Form 10-401 Re~06/2004 ~. D ORIGINAL Is .~ D I· ubmlt In up Icate .. .tio.ermittoDrill, We1l1E-10B Revision No.O Saved: 25-May-05 Permit It - West Sak Well #lE-I08 Application for Permit to Drill Document M(I JI: i 1'1'1 i z E: We: II V gh,l e Table of Contents 1. Well Name .... ... ........... ........ .... .................... ............. .... .... ............. ................ .... ... ....... .... .... .... 2 Requirements of 20 AAC 25.005 (f) ........... .............. ..... ............. ........... ....... ............................... ....................... ...... ... 2 2. Loca ti 0 n Summary .. ........ ... ............. ....... ....... ... .... .... ... ............. .... ....... ...... .......... ... ... ......... ... 2 Requirements of 20 AA C 25.005 (c)(2)........................................................................................................................ 2 Requirements of 20 AAC 25. 050(b) ............... ...... ........... ............. ................... ..... ............................... ................. ....... 3 3. Blowout Prevention Equipment Information ......................................................................3 Requirements of 20 AA C 25.005 (c)(3)........................................................................................................................ 3 4. D rillin g Hazar ds In forma ti 0 n .. .... ............. .... ............. .... ... ... ....... .......... ... .... ... ....... ... ..... ... .... 3 Requirements of 20 AAC 25.005 (c)(4)....... ....... ................... ........................ ........................ ......................... ......... ....3 5. Procedure for Conducting Formation Integrity Tests ........................................................ 3 Requirements of 20 AAC 25.005 (c)(5)............ ...... ....... ..... ....... ................. ...... ....... .............................. ........ .... ..........3 6. Casing and Cementing Program .......................................................................................... 4 Requirements of 20 AAC 25. 005(c)(6)..... ........ ...... ........... ............ ...... ............. ............................................. .............. 4 7. Diverter System Informa tio n ................................................................................................ 4 Requirements of 20 AAC 25.005 (c)(7)........................................................................................................................ 4 8. D rillin g FI ui d Progr am......... ... .... ...... .............. ... .... ... .............. .................... ... .... ... ... .... .... ..... 4 Requirements of 20 AAC 25. 005(c)(8)... ...... ....... ...... ...... ............ ................... ........... .................... ...... ............... .........4 Surface Hole Mud Program (extended bentonite) ..................................................................................................... 4 Intermediate Hole Mud Program (extended bentonite).. ..... ....... ........... ....................................... ..... ............. .... ....... 5 9. Abnormally Pressured Formation Information .................................................................. 5 Requirements of20 AAC 25.005 (c)(9)..................... ...... ....... .......... ............ ....... ..... .............. ................. ........... .........5 1 o. Seis mi c An alysis ..... ......... ....... ... ................. .... ..... ..... .......... ... ........... .......... .......... ... ... .... ........ 5 Requirements of 20 AAC 25.005 (e)(] 0)..... ........ ..... .......... ......................... ............ ....................................................5 11. Seabed Con di ti on An al ysis. ... .......... ....... .... ....... ... .............. ... .... .... ... ...... ....... ....... ...... ..... ...... 5 Requirements of 20 AAC 25.005 (c)(]] )... ................... ...... ........... ................... .............................. ........... ............. .....5 12. E vi d en ce of Bo n din g ...... ...... .... .... ................ ....... .... ... .... ... .......... .... ......... ........... ...... .... ......... 5 ORIGINAL 1E-10B PERMIT IT. doc Page 1of? Printed: 25-May-05 .. .tioeermit to Drill, We1l1E-108 Revision No.O Saved: 25-May-05 Requirements of 20 AAC 25.005 (c)(12).... ....... ...... ..... ........ ........................ ...... ...................................................., ....5 13. Pro posed Drilling Program... ............. ........... .......... ....... ...... .... ... .... ... ... ....... ... ...................... 5 Requirements of 20 AAC 25.005 (c)(13).....................................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal...................................... 7 Requirements of 20 AAC 25.005 (c)(14)............ ........ .... ........................ ........ ........... ..................................... .............7 15. A ttach men ts .... ....... ................... ... ...................... ..... ....... ...... ........... ... ...... ....... ....... ........... ..... 7 Attachment 1 Directional Plan (14 pages) .................................................................................................................7 Attachment 2 Drilling Hazards Summary (1 page).................................................................................................... 7 Attachment 3 Cement Loads and CemCADE Summary (2 pagse) ........................................................................... 7 Attachment4 Well Schematic (1 pages) .................................................................................................................... 7 1. Well Name Requirements of20 AAC 25.005 (f) Each well mustlw identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AilC 25.1J40(b). For a well with multiple well branches. each hranl1l must similar/v he identified hy a unique name and API number by adding a suffix to the lIame designatedj;'r the well by the operator and to the number assigned ro the well by the commission. The well for which this Application is submitted will be designated as IE-108. 2. Location Summary Requirements of20 AAC 25.005(c)(2) An app/icationfár a Permit to Drill must he au'ompanied bv each o(thef;'¡/owing items. exceptfiir an item alrem!.v onfile with the commission and identified in the al,¡liication: (2) a fJlat idcntifi'ing the IJri'fJerty and the properry's owncrs and showing (A) the coordinates oj'the IJroposed location o/the well at the surface, at the top oteach oh¡ectivej;'rmation. and at total depth, reférenced to govern menial ,')'ccrio!1 line,,,,', (B) the ("oordinates of the proposed location of the well (/t the slIrfilC<'. refà-eneed t" the state plane ("oordinate systemjin·this state as maintained by the National Geodetic Survcv in the National Oceanic and Atmospheric Administration; (C; the proposed depth of the well at the top of each oh¡ectivefi>rmation and at lotal depth; Location at Surface I 311' FSL, 224' FEL, Section 16, TlIN, RI0E I RKB ElevationT 94.1' AMSL I Pad Elevation T 66.1' AMSL ,/ ASP Zone 4 NAD 27 Coordinates Northings: 5,959,901" Eastings: 550,301 " Location at Top of Productive Interval (West 826' FSL, 2570' FWL, Section 15, TlIN, RlOE Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4,802' Northings: 5,960,435 Eastings: 553,091 Total Vertical DeJJth, RKB: 3,455' Total Vertical Depth, SS: 3,348' Location at Total Depth I 851' FSL, 2708' FWL, Section 15, TlIN, RI0E ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5,175' Northings: 5,960,461 Eastings: 553,228 Total Vertical Depth, RKB: 3,800' Total Vertical Depth, SS: 3,693' and (Dì other infi1rmatiol1 required by 20 AAC 25.050(b): ORIGINAL 1E-10B PERMIT IT. doc Page 2 of 7 Printed: 25-May-05 .. .tioeermit to Drill, Well 1 E-108 Revision No.O Saved: 25-May-05 Requirements of20AAC 25.050(b) f{a ¡vefl is 10 he intentionaff)' devi{Jfed. Ihe app!icaTion/Ór a Permit to Drif[ (Form flJ·41J f) must ( f) include u pIa¡, drawn to a suitahfe scull', showing the path o{the proposed weffhore, incfuding off udjucent wefflJOres within 21J1J/èet o/any portion olihe proposed weff; Please see Attachment 1: Directional Plan and (2) fÓr atl weffs within 200jèet olthe proposed wetlhore (A) lisllhe names o{lhe operators o/'those weffs, to Ihe exlent thaI those names are known or disco)'aable in public records. and show that each named operator has heenfÚrl1l:\'hed a copy o/the application hI' certified mail; or (E) state that Ihe applicant is the onl), alkcled owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of20 AAC 25.005(c)(3) An uppticaTion/Ór a Permillo Dril! musl he accompanied hy each of'thefollowing ilems, exceplfÓi" an item alrea((1' on file with the commission and identified in the applicalion; (3) a diagram and descriplion o/Ihe Mowoul prevenlion equipment mOPL) as required hy 20 AAC 25.035.20 AAC 25.036, or 20 AAC 25.03ì. as applicahle; An API 13-5/8" X 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete welllE-l 08, Please see infonnation 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 /Ór a Permit 10 Drill tIIust hc accotllpanied hy each o/the/Úllowing ilems, exceplj;'r an ilem alreac(v onfíle with Ihe commission and identified in Ihe applicalion: (4) in/iif'ma!Îon on driffing hazurcl,. ineluding IA) the maximum downhole pressure Ihalmol' he encounlered. criteria uscd to dctermine iI, and maximum potenlial surtàce pressure hased Oil a methane gradicnt: The expected reservoir pressures in the West Sak sands in the lE-108 area vary rrom 0.43 to 0.45 psilft, or 8.3 to 8,6 ppg EMW (equivalent mud weight). ". The maximum potential surface pressure (MPSP) is 1,292 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand fonnation is 3,800', The MPSP is calculated thusly: MPSP = (3,800 ft)(0.45 - 0.11 psi/ft) =1,292 psi (E) dala on pOlenTial gas zones; The well bore is not expected to penetrate any gas zones. .. and (C) data concerning pou'l1tiaf cuUs'es (~lholc prohh'ms such as ahnormall.v geo-/wessured Sfra!a. lo.v[ circulation zones, and zones that have a IJ/"(¡{!ensityji¡r ditfèrenlial slicking; Please see Attachment 3: lE-108 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of20 AAC 25.005 (c)(5) An applicaTion/ilr a Permit /() Drill must he accompanied by each o/Ihe¡illfowing ilems, cX{"('Plfor an item alrea¿¿v onfí!e ,,:ith the commission and identified in the application: (5) (/ descriplion olthe procedure/ilr conduClingflmnatioll integritF tesfs. as required ullder 2/1 AAC 25./l3/1W; -' lE-I08 will be completed with 5-1/2" x 3-1/2" casing landed through the West Sak "A2" sand, The surface casing shoe will be drilled out and a fonnation integrity test will be perfonned in accordance with the "Ponnation Integrity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. ORIGINAL 1£-108 PERMIT IT. doc Page 3 of 7 Printed; 25-May-05 .. .tiOeermit to Drill, Well 1 E-108 Revision No.O Saved: 26-May-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application/ilr a Permit to Drill must be aU'ompanied hI' each ofthefÒllowing items. except!i!/" an item alreac(v on/lie with the commi.l"sion and identilled in the application: (6) a compleli' proposed casing and cementing program <is required by 211 AA(' 2.5.11311. and a description of any slotted liner. pre-perlÒrated liner. or screen to he installed: Casing and Cementing Program I See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/fi) Grade Connection (ft) (ft) (ft) Cement Proftram 20" 40" 62.5 H-40 Welded 80 28' /28' 80' / 80' Cemented to surface with 260 cf ArcticCRE1E Cement Top planned to Surface 7-5/8" 9-7/8" 29.7 L-80 BTCM 3,115 28' /28' 3,1 15' /2,457' with 300 sx ArcticSet Lite Lead, 150 sxDeepCRE1E Tail Cement Top planned @ 3,371' 5-II2" X 6-3/4" 15.5 L-80 BTCM X 5,175 28' /28' 5,175' /3,800' MD I 2,599' TVD. Cemented 3 - II2" X 9.3 EOB wi 225 sx DeepCRE1E 7. Diverter System Information Requirements of20 AAC 25.005(c)(7) An applicatÙm!Òr a Permit to Drill must he aeCof/1IHtI1ied hy eOl'h o{the following items, exeeptfÒr an item already ontíle with the cOf/1mission and identilled in the application: (í) a diagram and description o/the diverter ,\:vstem as required h1' 20 AA C 25, 035, unless this rùluirement is ,mived hy the comlnission under 211 AAC 25,035(h)(2). A 21-II4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE- 105, Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of20 AAC 25.005(c)(8) An application/Òr a Permit to Drill must he accompanied hy each ofthejÒllmving items, exceptjÒr (in item alreac(F on/ile with the commission and identified in the application. (8) a drillingj!uid program. including a diagram and description ,,{the drillingj!uidl:vsli'm. as required hy 20 AiI( 25.1133; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 7-5/8" Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 9.2 9.3 9.2 9.5 Funnel Viscosity 250 250 150 200 (seconds) Yield Point 35 45 30 35 (cP) Plastic Viscostiy 20-45 20-45 15-20 15-20 (1b/1 00 sf) pH 9 9.5 9 9.5 API Filtrate NC 6 4 6 (cc / 30 mini) / *9.6 ppg if hydrates are encountered 1E-108 PERMIT IT. doc Page 4 of7 Printed: 26-May-05 ORIGINAL .. eatio.ermit to Drill, We1l1E-108 Revision No.O Saved: 25-May-05 Production Hole ~Ud Program (LSND) 7-518" Casing Shoe to 5-1/2" x 3-112" Casing Point Initial Value Density (ppg) 9.0-9.2 Funnel Viscosity 45 - 60 (seconds) Plastic Viscostiy 10 (lhl100 sf) Yield Point 28 - 30 (cP) API Filtrate 4-6 (cc I 30 min)) Chlorides (mgll) 15.000 - 17,000 pH 9.0 - 9.5 DriUing fluid practices wiU be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see infonnation on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of20 AAC 25.005 (c)(9) An opplicolÍonf;'r a Permit to Drill/mist he accol/1panied by each o/the/i¡flowing items. exceptf;'r an item alreac{v onjile "'Jith the commission and idemified in the applicarion: (9)f;'r all e,\ploratOl)' or stratigraphic test well, a tahularion settillg out the depths o{predicted ahnormally geo·pressured strata as required hy 20 AAC 25.U33(f), Not applicable: Applícation is not for an exploratory or stratigraphic test well. / 10. Seismic Analysis Requirements of20 AAC 25.005 (c)(10) An applicationfin' a Permit to Drill mllst he accompanied hy each o{thefÓI!owing items, except/or an item already onfile with the commission and identified ill the application: (I OJ/ár (/II exploratOl} or stratigmphic test well, a seismic refiw'lion or reflection analysis as required hy 20 AAC 25.061 (a): Not applícable: Applícation is not for an exploratory or stratigraphic test well, 11. Seabed Condition Analysis Requirements of20 AAC 25.005 (c)(ll) An applicmionf;wa Permit 10 Drill must he accompanied hy each otthej;'l/owing items, exceptj;'r an item already onfile with the commission alld identified in the app/icalÍon: (flUor a well drilledji'ol11 an otfi'hore platlárm, l/1ohile hotlomjáunded structure, jack-up ri¡;, orf/oating drilling vessel. an ana{vsis o{seabed conditions as relluired hy 20 AA C 25.06/ (h): Not applícable: Applícation is not for an offshore well. 12. Evidence of Bonding Requirements of20 AAC 25.005 (c)(12) An applicationfár a Permit to Drillll1Ust he accompanied hI' each ofthejollowin¡; items. exceptjár an item {llreoc{v onfile with the commission {llld identi/ied in the application: (/2) evidence sho~víJ1g that the requirements' (~l2() A/IC 25.()]5 {Bonding/hare been met: Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of20 AAC 25.005 (c)(13) An applicalÍonfi¡r a Pcrmit to Drill must he ac("ompanied by each o{thefollowing items, exceptfár an item alreadv onfìle with the commission and identi/ied in the applicalÍon, The proposed driUing program is lísted below. Please refer also to Attachment 5, WeU Schematics. / 1, Excavate cellar, instaU cellar box, set and cement 20" x 34" insulated conductor to +f- 108' RKB, InstaU landing ring on conductor. 1E-108 PERMIT IT. doc Page 50f7 Printed: 25-May-05 ORIGINAL .. .tioeermittoDrill, We1l1E-108 Revision No.O Saved: 25-May-05 2, Move in / rig up Doyon Rig] 4], Insta1l 2] - ]/4" Annular with] 6" diverter line and function test. ./ 3. Spud and directiona1ly dri1l9-7/8" hole to casing point at +/- 3,1 ]5' MD / 2,457' TVD as per directional plan, Run MWD tools as required for directional monitoring. ~ 4. Run and cement 7-5/8", 29.7#, L80, BTCM casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results, Perfonn top job if required. 5, Remove diverter system, insta1l and test BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). NotifY AOGCC 24 hrs before test. ./ 6, PU 6-3/4" bit and dri1ling assembly, with MWD, L WD & PWD. RIH, clean out cement to top offloat equipment. Re-test casing if cement is tagged more than] 00 feet above the float co1lar, 7. Dri1l out cement and between 20' and 50' of new hole. Perfonn fonnation integrity test to leak off, recording results. (ECD's modeled to be less than] ].0 ppg) 8. Directiona1ly dri1l to 5-112" x 3-]/2" casing point at 5,] 75' MD / 3,800' TVD, the prognosed top of the A2 sand, 9. POOH and rig up logging crew and use wireline percussion sidewa1l cores to extract sample rrom +/- 2,700' - 3,300' TVDSS rrom the Ugnu. Run sonic log across West Sak, ./ ]0. Lay down logging tools and run to bottom to clean up we1l for running of5-]/2" x 3-112" tapered production casing, ] ]. POOH laying down dri1l pipe. Lay down BHA. Back ream tight spots as needed, at fu1l dri1ling circulation and rotation rates. ]2. Rig up and run 5-]/2" x 3-]/2" tapered production string to bottom, ] 3, Rig up Dowe1l. Test cement lines. Pump the cement job, ]4. Displace to brine/sodium citrate with rig pumps and continue to reciprocate dri1l pipe as long as possible. Slow displacement to 1-2 bpm when 300 feet above the 3 Yz" and maintain that rate until the end ofthe job. ]5, When the plug bumps, pressure the casing to +/- 500 psi over the final displacement pressure and ensure that string is holding pressure. Bleed pressure to zero, then increase pressure to 3000 psi and test casing for 30 minutes. Record test on chart recorder. Bleed off pressure and ensure floats are holding. ]6. Insta1l and test 5112" packoffin tubing head. Insta1l wear ring. ] 7, Rig up and clear the 7 5/8" x 5 ]/2" annulus with 20 bbls of water, ensuring there is no cement in the annulus and that fluid can be put away for future rreeze protection. ] 8. A cement bond log wi1l be run after the rig has left location. . - 'J- ] 9, Rig down cementers and prepare to run 3-112" tieback completion string. 20. RIH with tubing to just above seal bore at +/- 3,175'. Record pick up and slack off weights. Leave sliding sleeve in closed position, 2]. Circulate the we1l with brine/corrosion inhibitor around down the annulus with returns up tubing, switch over to diesel, pump 40 bbls down annulus, close we1l in, connect hose rrom tubing side to annulus and equalize diesel. 22, Pressure test annulus with chart to 3000 psi for 30 minutes ~ .ør:r 23. Lower the string while slowly circulating, looking for pressure increase as seals enter seal bore. When increase is detected shut down pumps, and open tubing to atmosphere. Continue RIH until locator tags up (strap pipe to verifY seals travel entire length of20 ft. seal bore). Pick up and space out with tubing pups, Space out should leave locator 2-3' above fu1ly located position when tubing hanger is landed in tubing spool. 24. Restab seals into PBR and land tubing hanger in tubing head. Run in a1l10ckdown screws. Confinn proper space out by pressure testing annulus to ] 000 psi for five minutes. 25. Insta1l BPV and nipple down stack. Nipple up tree. Orient tree and tree valves as shown on the attached. Insta1l tree test plug. Test tree to 250 and 5000 psi. Test packoffto 5000 psi. Pu1l tree test plug, remove BPV 26. Rig down and move off dri1ling rig, Prepare an accurate handover fonn and send to pad engineer. 1E-108 PERMIT IT. doc Page 6 ofl Printed: 25-May-05 ORIGINAL .. .tioeermit to Drill, Well 1 E-108 Revision No.O Saved: 25-May-05 Post Rig Work 1. RU and pull BPV. 2. RU slickline and pull RP shearout valve in GLM and replace with a dummy valve 3. RU wireline and run cement bond log 4. Perforate well as designated by production .. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements 0120 AAC 25.005 (c)(14) An application.!hr a l-'ermÌlto Drill mustc he accompanied hy each o/thejhllowing ilems. exceptf;'r an ilem alreaì¿v onjile with the commission and identified in the application: (14) a general description o(how the operator plans to dispose o/drilling mud and eUllings (lnd a statement 0/ whether the operator intendç to request authorizalÌonunder 20 AAC 25.080jor WI annutar disposal operation in the well,; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a pennitted annulus on IE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a pennitted annulus on IE 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 pennit 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 2 Directional Plan (10 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 CemCADE Summary (2 page) Attachment 5 Well Schematic (1 page) ORIGINAL 1E-10B PERMIT IT.doc Page 70f7 Printed: 25-May-05 .. .. y ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan: 1 E-108 (wp03) Proposal Report 25 April, 2005 HALLIBURTDN Sperry Drilling Services ORIGINAL '2 ~ 8 500 ~ +' 'E ð 250 ~ 'E :; o 0 en ê 1275 ~ o LO 00 :; 1700 15. Q) o ~ 2125 :e ~ Q) ~ 2550 .. .. I T MAzimuths to True North I ~ Magnetic North: 24,50' Magnetic Field I Dip Angle: 80,74' Date: 12/1012004 Model: BGGM2004 Strength: 57580,OnT y ConocòPhillips Alaska LBHL@851ftFSL2708ftFWL-See15-T11N-R10E 1000 I Sail @ 37.50'lne & 79.55'Azi: 17~~ft MD, 1613f!TVD I [1E-108 T1 (wp03)(~_~ 750 L!3_uild @3.75'/1~Oftt060' li~~- 1850ftM[)~_~732ftTVD I I Drop @4'/190ftt060'lne: 4039ftr.A~ 2919ft TV[)_J 175/8" CSG : 585ft F_~L& 1261ft FWL ~ail @ 60:I~e & 79.55'Azi_:~450ft MD, 2125ft T\,il:)] -250 KOP: Begin Build @ 3_.0'/100ft, 45~ft MD, 450ft TV[)I -500 o 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 West(-)/East(+) (500 ftlin) o -¡-¡- SHL @ 311ft FSL 224ft FEL - See 16 - T11N - R10E I ' --~,-" ~gin Build @ 3.0'/100ft, 450ft MDè_<l.50ft TVD I ' 425 ~,(@ 37.50'lne & 79.55'Azi: 170Oft_MD, 1613ft TVD 850 ~~_~ 3.75'/100ft to 60'!ine - 1850ft MD, 1732ft TV~ HALLIBURTON Sperry Drilling Service. I_Sail @ 60'Ine & _!~55'Azi : 2450ft r.AiJ, 2125ft TVD I [iJrop @ 4'/100ftto 6~:lne: 4039ft MD, 2919ft ~ Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1E-108 (C1) Wellbore: Plan 1E-108 (C1) Plan: 1E-108 (wp03) 2975 1E-108 T1 (wp03)(D-Sand) 3400 ~~/8" CSG: 585ft FS~1!.1261ft FWL :~eet 15 - T11N.:R10E (311~ft MD, 2457~_T'-'iJ)J 3825 I~HL @ 851ft ~~L 2708ft~~ - See 15 -2~ 1N - R10E : 1E-108 T4 (wp03)(BHL) -1275 -850 -425 o 425 850 1275 1700 2125 2550 Vertical Section at 79.55° (850 Win) 2975 3400 3825 4250 ORIGINAL y ConocoPhillips Alaska . . Halliburton Company Planning Report - Geographic .. HALLIBURTON Sperry Drilling Services EDM 2003.11 Single User Db ConocoPhiUips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1E-108 (C1) Plan 1E-108 (C1) 1E-108 (wp03) Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) " NAD 1927 (NADCON CONUS) , Alaska Zone 04 System Datum: Mean Sea Level ~ Using Well Reference Point Using geodetic scale factor Position Uncertainty 0.00 ft 0.00 ft 0.00 ft Northing: Easting: Wellhead Elevation: 5.959.901.00 ft / 550.301.00 ft ./ ft Latitude: Longitude: Ground Level: 700 18' 04.379" N 149035' 33.333" W 67.00ft Well Position +N/-5 +E/·W 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 0.00 1,700.00 37.50 79.55 1,612.65 71.58 388.12 3.00 3.00 0.00 79.55 1,850.00 37.50 79.55 1,731.65 88.15 477.92 0.00 0.00 0.00 0.00 2,450.00 60.00 79.55 2,124.72 169.44 918.70 3.75 3.75 0.00 0.00 4,038.59 60.00 79.55 2,919.02 418.97 2,271.64 0.00 3.75 0.00 0.00 4,802.05 29.46 79.53 3,455.00 515.36 2,793.78 4.00 -4.00 0.00 -179.98 5,175.20 14.54 79.53 3,800.00 540.70 2,930.84 4.00 -4.00 0.00 180.00 4/251200510:01:35AM Page 2 of 6 COMPASS 2003.11 Build 48 f,,\ ,\ iGI~~AL y ConocoPhillips Alaska .. Halliburton Company Planning Report - Geographic .. HALLIBURTDN Sperry Drilling Services 40.00 0.00 0.00 40.00 -67.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 SHL@311ftFSL224ftFEL·See 16 - T11N - R10E 100.00 0.00 0.00 100.00 -7.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 200.00 0.00 0.00 200.00 93.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 300.00 0.00 0.00 300.00 193.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 400.00 0.00 0.00 400.00 293.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 450.00 0.00 0.00 450.00 343.00 0.00 0.00 5,959,901.00 550,301.00 0.00 0.00 " KOP : Begin Build @ 3.00/100ft, 450ft MD, 450ft TVD 500.00 1.50 79.55 499.99 392.99 0.12 0.64 5,959,901.12 550,301.64 3.00 0.65 600.00 4.50 79.55 599.85 492.85 1.07 5.79 5,959,902.11 550,306.78 3.00 5.89 700.00 7.50 79.55 699.29 592.29 2.96 16.07 5,959,904.07 550,317.05 3.00 16.34 800.00 10.50 79.55 798.04 691.04 5.80 31.45 5,959,907.01 550,332.41 3.00 31.98 900.00 13.50 79.55 895.85 788.85 9.57 51.89 5,959,910.92 550,352.82 3.00 52.77 1,000.00 16.50 79.55 992.43 885.43 14.27 77.34 5,959,915.78 550,378.24 3.00 78.65 1,100.00 19.50 79.55 1,087.52 980.52 19.87 107.73 5,959,921.59 550,408.58 3.00 109.55 1,200.00 22.50 79.55 1,180.87 1,073.87 26.37 142.97 5,959,928.32 550,443.77 3.00 145.38 1,300.00 25.50 79.55 1,272.22 1,165.22 33.74 182.96 5,959,935.97 550,483.71 3.00 186.05 1,400.00 28.50 79.55 1,361.31 1,254.31 41.98 227.60 5,959,944.50 550,528.30 3.00 231.44 1,500.00 31.50 79.55 1,447.90 1,340.90 51.05 276.77 5,959,953.89 550,577.39 3.00 281.44 1,585.77 34.07 79.55 1,520.00 1,413.00 59.47 322.44 5,959,962.62 550,623.00 3.00 327.88 Base of Permafrost 1,600.00 34.50 79.55 1,531.76 1,424.76 60.92 330.32 5,959,964.13 550,630.88 3.00 335.89 1,700.00 37.50 79.55 1,612.65 1,505.65 71.58 388.12 5,959,975.17 550,688.59 3.00 394.67 Sail @37.S00Ine & 79.SS°Azi : 1700ft MD, 1613ft TVD 1,800.00 37.50 79.55 1,691.98 1,584.98 82.63 447.99 5,959,986.61 550,748.38 0.00 455.54 1,850.00 37.50 79.55 1,731.65 1,624.65 88.15 477.92 5,959,992.33 550,778.27 0.00 485.98 Build @ 3.7so/10Oft to 60° line . 1850ft MD, 1732ft TVD 1,854.22 37.66 79.55 1,735.00 1,628.00 88.61 480.45 5,959,992.82 550,780.80 3.75 488.56 T3 1,900.00 39.37 79.55 1,770.81 1,663.81 93.78 508.49 5,959,998.18 550,808.80 3.75 517.06 2,000.00 43.12 79.55 1,845.98 1,738.98 105.74 573.32 5,960,010.57 550,873.54 3.75 582.98 2,100.00 46.87 79.55 1,916.68 1,809.68 118.56 642.84 5,960,023.85 550,942.97 3.75 653.68 2,200.00 50.62 79.55 1,982.61 1,875.61 132.20 716.76 5,960,037.98 551,016.79 3.75 728.85 2,277.11 53.52 79.55 2,030.00 1,923.00 143.23 776.57 5,960,049.41 551,076.52 3.75 789.67 K1S 2,300.00 54.37 79.55 2,043.47 1,936.47 146.58 794.77 5,960,052.89 551,094.69 3.75 808.17 2,400.00 58.12 79.55 2,099.02 1,992.02 161.66 876.52 5,960,068.51 551,176.34 3.75 891.31 2,450.00 60.00 79.55 2,124.72 2,017.72 169.44 918.70 5,960,076.57 551,218.45 3.75 934.19 Sail @ 6Qolne & 79.SS°AzI : 24SOft MD, 2125ft TVD 2,500.00 60.00 79.55 2,149.72 2,042.72 177.30 961.28 5,960,084.71 551,260.98 0.00 977.49 2,600.00 60.00 79.55 2,199.72 2,092.72 193.00 1,046.45 5,960,100.98 551,346.03 0.00 1,064.09 2,700.00 60.00 79.55 2,249.72 2,142.72 208.71 1,131.61 5,960,117.26 551,431.08 0.00 1,150.70 2,800.00 60.00 79.55 2,299.72 2,192.72 224.42 1,216.78 5,960,133.54 551,516.13 0.00 1,237.30 2,900.00 60.00 79.55 2,349.72 2,242.72 240.13 1,301.94 5,960,149.81 551,601.18 0.00 1,323.90 3,000.00 60.00 79.55 2,399.72 2,292.72 255.83 1,387.11 5,960,166.09 551,686.23 0.00 1,410.51 3,100.00 60.00 79.55 2,449.72 2,342.72 271.54 1,472.28 5,960,182.36 551,771.28 0.00 1,497.11 4/251200510:01:35AM Page 3 of 6 COMPASS 2003.11 Build 48 ORIGINAL y ConocoPhillips Alaska . . Halliburton Company Planning Report - Geographic .. HALLIBURTON Sperry Drilling Services 3,114.56 60.00 79.55 2,457.00 2,350.00 273.83 1,484.68 5,960,184.73 551,783.67 0.00 1,509.72 75/8" CSG: 585ft FSL & 1261ft FWL: Sect 15 - T11N - R10E (3115ft MD, 2457ft TVD) 3,200.00 60.00 79.55 2,499.72 2,392.72 287.25 1,557.44 5,960,198.64 551,856.33 0.00 1,583.71 3,300.00 60.00 79.55 2,549.72 2,442.72 302.96 1,642.61 5,960,214.92 551,941.38 0.00 1,670.31 3,400.00 60.00 79.55 2,599.72 2,492.72 318.66 1,727.77 5,960,231.19 552,026.43 0.00 1,756.92 3,500.00 60.00 79.55 2,649.72 2,542.72 334.37 1,812.94 5,960,247.47 552,111.49 0.00 1,843.52 3,600.00 60.00 79.55 2,699.72 2,592.72 350.08 1,898.11 5,960,263.74 552,196.54 0.00 1,930.12 3,700.00 60.00 79.55 2,749.72 2,642.72 365.79 1,983.27 5,960,280.02 552,281.59 0.00 2,016.72 3,800.00 60.00 79.55 2,799.72 2,692.72 381.50 2,068.44 5,960,296.30 552,366.64 0.00 2,103.33 3,870.56 60.00 79.55 2,835.00 2,728.00 392.58 2,128.53 5,960,307.78 552,426.65 0.00 2,164.43 Ugnu C 3,900.00 60.00 79.55 2,849.72 2,742.72 397.20 2,153.60 5,960,312.57 552,451.69 0.00 2,189.93 4,000.00 60.00 79.55 2,899.72 2,792.72 412.91 2,238.77 5,960,328.85 552,536.74 0.00 2,276.53 4,038.59 60.00 79.55 2,919.02 2,812.02 418.97 2,271.64 5,960,335.13 552,569.56 0.00 2,309.95 Drop @ 4°/10Oft to 800lnc : 4039ft MD, 2919ft TVD 4,100.00 57.54 79.55 2,950.85 2,843.85 428.50 2,323.27 5,960,345.00 552,621.13 4.00 2,362.46 4,200.00 53.54 79.55 3,007.42 2,900.42 443.45 2,404.34 5,960,360.49 552,702.09 4.00 2,444.90 4,300.00 49.54 79.54 3,069.60 2,962.60 457.66 2,481.34 5,960,375.21 552,778.98 4.00 2,523.19 4,343.02 47.82 79.54 3,098.00 2,991.00 463.52 2,513.11 5,960,381.29 552,810.71 4.00 2,555.50 Ugnu B 4,400.00 45.54 79.54 3,137.09 3,030.09 471.05 2,553.88 5,960,389.09 552,851.42 4.00 2,596.95 4,428.15 44.42 79.54 3,157.00 3,050.00 474.66 2,573.44 5,960,392.83 552,870.96 4.00 2,616.85 Ugnu A 4,500.00 41.54 79.54 3,209.56 3,102.56 483.55 2,621.61 5,960,402.04 552,919.06 4.00 2,665.83 4,600.00 37.54 79.53 3,286.66 3,179.66 495.11 2,684.20 5,960,414.02 552,981.57 4.00 2,729.48 4,641.60 35.88 79.53 3,320.00 3,213.00 499.63 2,708.65 5,960,418.70 553,005.99 4.00 2,754.35 K13 4,700.00 33.54 79.53 3,368.01 3,261.01 505.67 2,741.36 5,960,424.96 553,038.64 4.00 2,787.60 4,800.00 29.54 79.53 3,453.21 3,346.21 515.18 2,792.79 5,960,434.81 553,090.01 4.00 2,839.91 4,802.05 29.46 79.53 3,455.00 3,348.00 515.36 2,793.78 5,960,435.00 553,091.00 4.00 2,840.92 West Sak D ·1E·108 T1 (wp03)(D-5and) 4,846.46 27.69 79.53 3,494.00 3,387.00 519.22 2,814.67 5,960,439.00 553,111.86 4.00 2,862.16 West Sak C 4,875.67 26.52 79.53 3,520.00 3,413.00 521.64 2,827.75 5,960,441.51 553,124.92 4.00 2,875.46 West Sak B 4,900.00 25.54 79.53 3,541.86 3,434.86 523.58 2,838.25 5,960,443.52 553,135.41 4.00 2,886.14 4,914.53 24.96 79.53 3,555.00 3,448.00 524.71 2,844.35 5,960,444.69 553,141.49 4.01 2,892.34 West Sak A4 4,976.79 22.47 79.53 3,612.00 3,505.00 529.26 2,868.97 5,960,449.40 553,166.09 4.00 2,917.38 West Sak A3 5,000.00 21.54 79.53 3,633.52 3,526.52 530.84 2,877.52 5,960,451.04 553,174.63 4.00 2,926.08 5,051.76 19.47 79.53 3,682.00 3,575.00 534.14 2,895.36 5,960,454.46 553,192.43 4.00 2,944.21 West Sak A2 5,100.00 17.54 79.53 3,727.74 3,620.74 536.92 2,910.41 5,960,457.34 553,207.47 4.00 2,959.52 4I251200510:01:35AM Page 4 of 6 COMPASS 2003.11 Build 48 ORIGINAL y ConocoPhillips Alaska .. Halliburton Company Planning Report - Geographic .. HALLIBURTON Sperry Drilling Services 5,173.13 14.62 79.53 3,798.00 3,691.00 540.61 2,930.33 5,960,461.16 553,227.36 4.00 2,979.78 West Sak A 1 .. 5,175.20 14.54 79.53 3,800.00 .. 3,693.00 540.70 2,930.84 5,960,461.25 553,227.87 4.00 2,980.30 BHL @ 851ft FSL 2708ft FWL. See 15· T11N· R10E. 41/2" 3,455.00 - Circle (radius 50.00) 11:·108 T1 (wp03)(D-Sand) 515.36 2,793.78 5,960,435.00 553,091.00 3,800.00 - Circle (radius 50.00) 1E·108 T4 (wp03)(BHL) 540.44 2,930.97 5,960,461.00 553,228.00 3,114.56 5,175.19 2,457.00 3,799.99 7·518 4·1/2 12·1/4 6-314 4/2512005 10:01:35AM Page 5 of 6 COMPASS 2003.11 Build 48 ORIGINAl. y ConocoPhillips Alaska · · Halliburton Company Planning Report - Geographic .. HALLIBURTON Sperry Drilling Services 1,585.77 34.07 79.55 1,520.00 59.47 322.44 Baae of Pennafrost 1,854.22 37.66 79.55 1,735.00 88.61 480.45 13 2,277.11 53.52 79.55 2,030.00 143.23 776.57 Ki6 3,114.56 60.00 79.55 2,457.00 273.83 1,484.67 13+660 3,870.56 60.00 79.55 2,835.00 392.58 2,128.53 Ugnu C 4,343.02 47.82 79.54 3,098.00 463.52 2,513.11 Ugnu B 4,428.15 44.42 79.54 3,157.00 474.66 2,573.44 Ugnu A 4,641.60 35.88 79.53 3,320.00 499.63 2,708.65 Ki3 4,802.05 29.46 79.53 3,455.00 515.36 2,793.78 West Sak D 4,846.46 27.69 79.53 3,494.00 519,22 2,814.67 West Sak C 4,875.67 26.52 79.53 3,520.00 521,64 2,827.75 West Sak B 4,914.53 24.96 79.53 3,555.00 524.71 2,844.35 West Sak A4 4,976.79 22.47 79.53 3,612.00 529.26 2,868.97 West Sak A3 5,051.76 19.47 79.53 3,682.00 534.14 2,895.36 West Sak A2 5,173.13 14.62 79.53 3,798.00 540.61 2,930.33 West Sak Ai 4/2512005 10:01:35AM Page 6 of 6 COMPASS 2003. 11 Build 48 ORIGINAL .. ConocJP'hillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan iE-i0S (Ci) Anticollision Summary 25 April, 2005 .. HALLIBURTON Sperry Drilling Services ORIGINAL Travelling Cylinder Azimutb (TFO+AZI) ¡oj vs Centre to Ceutre Separatioll100 Win] +Nt-5 +f3J·W Northing 0.00 0.00 5959901.00 Longitude 149"35'33.333W REFERENCE INFORMATION Co-on;!in¡rte (NIE) Reference: Wen PI~n 15-1(18 (C1), True North Vertical (TVD) Reference: 15.100· Doyon 15 @ 107.0011: (Doyon 15 (40+67)) Section ¡VS) Reference: Slot· «(1.001'1, 0.005) MeaslII"ed Depth Refel"el"!œ: 1E-1oo - Doyon 15@ 107.0011: (Doyon 15 (40+67)) Calcul~tion Method: Minimum Curvature ConocoPhillips Alaska (Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature 5rror System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based From Colour To MD 40 - 100 100 200 200 300 300 400 400 500 500 600 600 700 700 800 800 900 900 1000 1000 1500 1500 2000 2000 3000 3000 4000 4000 - 5000 5000 6000 270 90 Travelling Cylinder Azimuth (TFO+AZI) 1"1 vs Centre to Centre SepamtÎon 115 ft/in """""""" ---""",-",,-"."._._----- "_._-~"-------"" SECTION DETAilS See MD ... "" TVD .NI.s +EI-W TF¡¡çø VS¡¡C Target 1 40.00 0.00 0,00 40.00 0,00 0,00 0,00 0.00 2 45<),00 0,00 0,00 45<),00 0.00 0,00 0,00 0.00 3 1700.00 37,50 7;'1.55 1612.S? 71.5:8 3.88.12 79.55 39k67 4 1850.00 37,50 79.55 1731.65 88.15 477.92 000 485.00 5 2450.00 50.00 79.55 2124.n 169.44 91.:1-70 0,00 934.19 6 4038.59 00.00 79.55 2919.02 418.97 2271.64 0,00 2309.95 7 4002.05 29.46 7953 3455,00 515.36 2793.78 ·179.98 2840.92 Œ-108 Ti (wp03)(O-Sand) , 5175.20 14_54 79.53 3&10.00 540.70 2930.84 180.00 2000.30 .. .. y ConocoPhillips Alaska Halliburton Company Anticollision Report HALLIBURTON Sperry Drilling Services Well Plan 1E-108 (C1) 1E-108 - Doyon 15 @ 107.000 ( 1E-108 - Doyon 15 @ 107.00ft (D True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum 15 (40+67) 0.000 Plan 1 E-108 (C1) O.OOft Plan 1E-108 (C1) 1 E-1 08 (wp03) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00ft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center-center distance of 713.52ft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic KuparuK1EPad 1 E-03 - 1 E-03 - 1 E-03 2,242.54 2,650.00 431.36 35.82 395.54 Pass - Major Risk 1E-102-1E-102-1E-102 187.59 175.00 180.92 3.84 177.09 Pass - Major Risk 1E-102-1E-102L1 -1E-102L1 187.59 175.00 180.92 3.84 177.09 Pass - Major Risk 1E-102-1E-102L1PB1 -1E-102L1PB1 187.59 175.00 180.92 3.84 177.09 Pass - Major Risk 1E-102 -1E-102PB1 -1E-102PB1 187.59 175.00 180.92 3.71 177.22 Pass - Major Risk 1 E-1 02 - 1 E-102PB2 - 1 E-1 02PB2 187.59 175.00 180.92 3.71 177.22 Pass - Major Risk 1E-104-1E-104-1E-104 262.82 250.00 120.68 5.16 115.52 Pass - Major Risk 1E-112-1E-112-1E-112 684.78 675.00 121.40 13.51 107.89 Pass - Major Risk 1E-112 - 1E-112L 1 - 1E-112L1 684.78 675.00 121.40 13.48 107.92 Pass - Major Risk 1E-112-1E-112L2-1E-112L2 684.78 675.00 121.40 13.48 107.92 Pass - Major Risk 1 E-112 - 1 E-112PB1 - 1 E-112PB1 684.78 675.00 121.40 13.48 107.92 Pass - Major Risk 1 E-114 - 1 E-114 - 1 E-114 485.83 475.00 220.10 8.93 211.17 Pass - Major Risk 1E-114-1E-114L1 -1E-114L1 485.83 475.00 220.10 8.77 211.33 Pass - Major Risk 1 E-114 - 1 E-114L2 - 1 E-114L2 485.83 475.00 220.10 8.77 211.33 Pass - Major Risk 1E-126 - 1E-126 - 1E-126 2,005.82 2,225.00 204.80 72.41 132.39 Pass - Major Risk 1E-126-1E-126L1-1E-126L1 2,005.82 2,225.00 204.80 72.41 132.39 Pass - Major Risk 1E-126 - 1E-126L2 -1E-126L2 2,005.82 2,225.00 204.80 72.41 132.39 Pass - Major Risk 1E-18 -1E-18 -1E-18 877.84 875.00 219.19 15.50 203.69 Pass - Major Risk 1E-19 - 1E-19 - 1E-19 851.55 850.00 158.59 14.14 144.45 Pass - Major Risk 1 E-20 - 1 E-20 - 1 E-20 776.43 775.00 97.88 13.19 84.69 Pass - Major Risk 1 E-21 - 1 E-21 - 1 E-21 701.17 700.00 37.75 11.92 25.83 Pass - Major Risk 1 E-22 - 1 E-22 - 1 E-22 476.23 475.00 22.88 8.71 14.17 Pass - Major Risk 1 E-23 - 1 E-23 - 1 E-23 624.67 625.00 80.06 11.05 69.01 Pass - Major Risk 1 E-24 - 1 E-24 - 1 E-24 500.00 500.00 145.51 9.25 136.26 Pass - Major Risk 1 E-24 - 1 E-24A - 1 E-24A 506.53 500.00 145.61 9.35 136.26 Pass - Major Risk 1 E-25 - 1 E-25 - 1 E-25 598.11 600.00 201.50 11.35 190.15 Pass - Major Risk 1 E-26 - 1 E-26 - 1 E-26 524.33 525.00 260.37 12.34 248.03 Pass - Major Risk 1 E-33 - 1 E-33 - 1 E-33 522.67 525.00 186.20 9.18 177.02 Pass - Major Risk 1 E-33PB1 - 1 E-33PB1 - 1 E-33PB1 522.67 525.00 186.40 9.18 177.22 Pass - Major Risk Plan 1E-105- Plan 1E-105-1E-105 (wp05) 690.67 675.00 84.32 14.88 69.44 Pass - Major Risk Plan 1 E-105 - Plan 1 E-105 L 1 - 1 E-105 L 1 (wp05) 690.67 675.00 84.32 14.88 69.44 Pass - Major Risk Plan 1 E-105 - Plan 1 E-105 L2 - 1 E-105 L2 (wp05) 690.67 675.00 84.32 14.88 69.44 Pass - Major Risk Plan 1E-105- Plan 1E-105 PB1-1E-105 PB1 (wp05 690.67 675.00 84.32 14.88 69.44 Pass - Major Risk 4/2512005 10:01:56AM CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation Page 2 of 2 COMPASS 2003. 11 Build 48 ORIGINAL LEGEND 1E-168, 1E-168L2PB1, 1E-168L2PB1 V3 1E-168, 1E-168L 1, 1E-168L1 V3 1E-168, 1E-168, 1E-168 Vi 1E-168, 1E-168L2, 1E-168L2V1 1E-168, 1E-168PB1, 1E-168PB1 V3 1 E-03, 1 E-03, 1 E-03 Vi 1 1 E-20 Vi iE-iD8 Bottom West Sak E-i68L2PB 1 iE-D3, iE-D3, iE-D3 Vi G IGGO ~Oaa :'\IJIJIJ iE-iD8 Top West Sak iE-i68L 1 ~ & c:s I ....... & c:s C:) ....... & c:s ~~ West(-)/East(+) (600ft/in) 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 2400 2400 2100 2100 1800 1800 1500 1500 1200 1200 900 Base West Sak 900 (f) c I 0 ~ c 0 i 0 ~ 600 600 Z 0 ;:::¡. ::r 1: 300 300 Õ) 0 0 ¿ 2 0 0 -300 -300 -600 -600 -900 -900 -1200 -1200 -1500 -1500 -300 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 West( - )/East( +) (600 ft/in) lE-10fo~lin2 Hazards I.Aary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open Hole / 7-5/8" Casin2: Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate / Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out /' 6-3/4" Open Hole / 5-1/2" x 3-1/2" Casin2: Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low /' Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low / BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out ORIGtNAl~ 1E-10B Drilling Hazards Summary. doc prepared by Steve McKeever 5/18120052:53 PM Rig: Doyon 141 Location: West Sak Client: CPA!. Revision Date: 5/24/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 Emaìl: cakwukwaegbu@slb.com < TOC at Surface Previous Csg. < 16",62.6# casing at108'MD < Base of Permafrost at 1,586' MD (1,520' TV D) < Top of Tail at 2,115'MD < 75/8",29.7# casing in 9 7/8" OH TDat3,115'MD (2,457' TV D) Mark of Schlumberger .. .. Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,115' MD. Lead Slurry Minimum pump time: 170 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3fsk 3 0.9513 ft fft x (108') x 1.00 (no excess) = 0.2148 ft3fft x (1586' -108') x 3.50 (250% excess) = 0.2148 ft3fft x (2115' - 1586') x 1.35 (35% excess) = 102.7fe + 1111.2 ft3+ 153.4 ft3 = 1367.3 ft3f 4.45 ft3fsk = Round up to 310 sks 102.7 ft3 1111 .2 ft3 153.4 ft3 1367.3 ft3 307.3sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 130 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.2148 ft3fft x (3115' - 2115') x 1.35 (35% excess) = 0.2578 ft3fft x 80' (Shoe Joint) = 290 ft3 + 20.6 ft3 = 310.6 fef2.52 ft3fsk = Round up to 130 sks 290 ft3 20.6 ft3 310.6ft3 123.3 sks BHST = 54°F, Estimated BHCT = 6rF. (BHST calculated using a gradient of 2.6°Ff100 ft. below the permafrost) PUMP SCHEDULE Stage Pu mp Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 10 2.0 2.0 Pressure Test Lines 10.0 12.0 CW1001 5 40 8.0 20.3 MudPUSH II 6 50 8.3 28.3 Drop Bottom Plug 5.0 33.3 Lead Slurry 7 246 35.1 68.4 Tail Slurry 5 58 11.6 80.0 Drop Top Plug 5.0 85.0 Water 5 20 4.0 89.0 Switch to Rig 5.0 94.0 Displacement 7 104 14.9 108.9 Slow Rate 3 15 5.0 113.9 MUD REMOVAL Recommended Mud Properlies: 9 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. SpacerProperlies: 10.5 ppg MudPUSH* II, Pv::::: 17-21, Ty:::::20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/24/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 262-4247 Mobile: (907) 830-8168 Email: CAkwukwaegbu@slb.com A"evious Csg. < 75/8",29.7#, L-80 grade BTC, AB llibdified at 3,115 ft. MO < 51/2",15.5#, L-80 grade BTC, AB llibdified in 6 3/4" OH < Top of Tail at 3,371 ft. MO < X-over at 3,105 ft. MO < Top of Ugnu C Fm. at 3,871 ft. MD < 31/2",9.3#, L-80 grade EUE, 8rd llibdified in 6 3/4" OH IDat 5,175 ft. MO (3,800 ft. NO) Mark of Schlumberger .. .. Schlumb81'181' Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 55% excess. Top of tail slurry is designed to be 500' above the top of the Ugnu C formation, at 3371' MD. Tail Slurrv (minimum thickening time 136 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3fsk 0.0835 ft3fft x -266' x 1.55 (55% excess) = 0.1817 ft3/ft x (5175' - 3105') x 1.55 (55% excess) = 0.0488 ft3/ft x 60' (Shoe Joint) = o ft3 + 508.1 ft3 + 2.9 ft3 = 511.0 ft3f 2.26 ft3fsk = Round up to 227 sks o ft3 508.1 ft3 2.9 ft3 511.0ft3 226.1 sks BHST = 91°F, Estimated BHCT = 80°F. (BHST calculated using a gradient of 2.6°Ff100 ft. below the permafrost) PUMP SCHEDULE Stage Volume Cumulative Stage Time Time (min) Stage Pump Rate (bpm) (bbn lmin\ CW100 5 10 2.0 2.0 Pressure Test Lines 10.0 12.0 CW100 5 20 4.0 16.0 MudPUSH II 5 30 6.0 22.0 Tail Slurry 5 91 18.2 40.2 Drop Combo Plug 5.0 45.2 Displacement 5 76 15.2 60.4 Bump Plug 2 15 7.5 67.9 ~«'<l" «"I\C~\\ 'AO \t-~\~fè ,\S-/fs-<:.a<;.\t--..\ To <:.. ~ ~ 'Saa' ~'?V\t c.. MUD REMOVAL (...... Recommended Mud Properties: 8.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ~ 19-22, T y ~ 22-29 Centralizers: Recommend 2 per joint across the 15t 4 joints 1 per joint to 3105' MD ORIGINAL, West Sak IE-I08 Injector Proposed Completion Schematic 1/2" Completion String Top of Cement @ +1- 3,371' 3 W' 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 Yo" 9.3# L-80 EUE8RD Mod Tubing to Surface 20" X 16" 62.6# @ +1- 108' MD 3 W' Cameo 'DS' nipple w/2.875" No-Go Profile. 3 Yo" x 6' L-80 handling pups installed above and below, EUE 8RD Mod, set at +1- 500' MD 3 Yo" Baker 'CMU' sliding sleeve w/2.8I3" Camco DS profile, EUE 8RD Mod box x pin. 3 W' x 6' L-80 EUE 8RD Mod handling pup installed above Surtàce csg. 7-5/8" 29.7# L-80 BTCM +1- 3,115' MD /2,457' TVD 3 W' Baker 80-40 GBH-22 casing seal assembly wi 15' stroke, 3 Yo" L-80 EUE8RD Mod box up, 3 Yo" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 Yo" BTCM x 3 Y:," EUE8RD Mod SBE set at +/- 3,100' MD Production csg 5 Y2" 15.5# L-80 BTCM x 3 Yo" 9.3# L-80 EUE 8RD Mod +1- 5,175' MD /3,800' TVD (crossover +/- 3,100' MD I 3,115'TVD) 3 Otis X-nipples located at the tops of the three sands ( D, B, and A2) in the West Sak 5-19-2005 KRU RE: IE-108 .. .. Subject: RE: IE-108 From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Mon, 06 lun 2005 14:13:00 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> 1. The depth of the XO is supposed to be at ± 3,100'. The cementing sheet is incorrect. My fault. I should have caught it. The picture shows the cement above the XO. Cement only comes to ± 3,300' with the XO above it. The XO should not be below the surface casing shoe as the hole below the shoe is only 6-3/4" in diameter. The XO would act as a restriction to flow while cementing and therefore that is why it was set just above the shoe. 2. In reviewing the files the 1E-20 has a calculated cement (using 1.15 yield) top at 2,975' MD (2,600' TVD) with 30% washout. Top of the West Sak "D" sand is at 3,455' TVD. The 1E-03 cement top is at 3,700' TVD (using 1.15 yield and 30% washout). But, before they perforated the well, they pumped 250 sxs Arctic Set cement ahead of 114 bbls of Arctic Pack down the 10-3/4" x 7" annulus. Using 1.15 yield and 30% washout gives a ± 1,900' cement plug below the surface shoe at 3,227'. This would cover the annulus from the shoe to the top of the calculated cement at 5,140' MD. 3. With the current state of wells we have it looks like the 1E-108 won't be able to spud until mid July. Mike Greener 907.263.4820 (office) 907.440.5333 (cell) -----Original Message----- From: Thomas Maunder [mailto:tom Sent: Friday, June 03, 2005 3:36 To: Greener, Mike R. Cc: Thomas, Randy L Subject: 1E-108 maunder@admin.state.ak.us] PM Mike, I just started looking at 1E-108. Just a couple of questions. 1. What is the depth of the 5-1/2" x 3-1/2" XO?? On the cement sheet the XO is shown to be at 3105 which is above the surface casing shoe Based on the placement in the sketch, I would guess that the XO depth should be 3501 which allows you to place cement above the XO. 2. What is your assessment on the "1320 plot"?? It looks like 1E-20 is the closest with 1E-03 in there as well. Early wells on IE did not have casing set through the WS. What gives you confidence injected into 1E-108 will be contained and not find a will be researching the files, but I need a statement matter. 3. Is the June 7 spud date real?? Thanks, Tom Maunder, PE AOGCC that water "leak path"?? I from you on this ] of] 6/6/20053:49 PM SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 1103 PAY TO THE ORDER OF DATE 1vt'L (, ~2-14/311 $ ¡CO. tXJ . . .,.,- C~C· H A· S e· _._~-_."'<"' V"&k:'.d Up To oooD """ ., ~_..""-""-""",,,, ... 1// --;; / ;:;~ 1100 I~~I: 218~? l'IO?'i ;;b".~~o~~~n¿T~ "ÛN'vERš;¡i"'" . . ·. .. TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANS MITT AL LETTER WELL NAME KiCU IE--/()8 PTD# ZD~ - 038 CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well _, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produceliniect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01105 C\jody\trans m ittal_ checklist Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: WSAK 1E-108 Program SER Well bore seg 0 COPHILLlPS ALASKA INC nitial ClassfType SER LPEND GeoArea 890 Unit 11160 On/Off Shore ~._ Annular Disp~ 0 - Administration P~rmit feE\ attache,d. · Y~$ ~ - - - - - - - - - - 2 1eas~ .numbE\r .appropri<lte. Ye$ Entire we.!IIQcated in-ADL025651.. - - -- - - - - - - - - - - 3 .U.nlq\lewell.n.am~_and ou.mb_er . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ - -. - - - - - Y~$ - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 4 WE\I/ IQcat~d lna d_efinedpool. - - - - - - Ye$ KRU We$t Sak Qil Pool, goyeroed. byConseJllation_ Order No, 4066 _ _ 5 WE\IUQcat~d propE\rdistance from driJling \lnitb9\1ndary . Y~$ WelJ is more than_ 500 feet frQm an exteJnaJ property line. _ _ . . - - - - - 6 Wel/lQcat~d proper distance_ from otber wells _ - - - - - - . - Y~$ 1\10 restrictions as_ to well spaciog io CP_ 496B._ 7 _S_ufficient .acreage_ayail<lble in drilJiog u.njt_ - - - - - Ye$ 1\10 restrictions as to well SP<lCiog excepJ that no_p_ay shaJI be ope_ned inawe[J closer _ - - - - - 8 Ifd~viated, js weJlbQre platincluded _ - - - - -- Y~$ than 50_0JE\eJ to_anexternal.property'llne._ _ - - - - - - - 9 O.perator only. affected party _ - - - - - - - -- Y~$ - - - - - - - - - - - - - - - 10 .O.perator basapproprlateJ)9nd lnJorce _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . - - - - - - - Y~$ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P~rmit c_an be iS$u.ed wjtbout co_n$ervaJion order_ Ye$ - - - - - Appr Date 12 P~rmitc_an be iS$u.ed witbout administratilleapprovaJ _ _ _ - - - - - Y~$ - - -- SFD 6/2/2005 13 Can permit be approved before 15-day wait Yes . 14 WelUocated wiJhin area and_strata _authorized by_lnjectioo Ord~r # (Put lOti in_ comm~ots)_ (For _ Y ~s Area Injection Qrder No._2B - - - - - - - 15 AJI wells_within Jl4Joile_area_of reyiew jd~otified (For servj~)\le[J onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~$ KRU :lE-0:UE:2Q. tE_-10~, 11::.-10.5, 11::.-1l2.1~-1t4. ~tE~t2!3. tE-t613. tE_-16_8(.1,JE-J!36L_2, 1L_-2t _ _ _ - - - 16 _PfE~-produced injector; ,duratiQnof pre-.produçtionle$s tMn 3 mOntbs_ (For service well only) . No_ - - - - - - - - - - - - - . 17 _AÇMP F:indjngof Conststei1cy_h_a$ bee.nissueMor.thi$ proleçt . - - - - - NA Engineering 18 Conductor stringpfQvided _ - - - - - Y~$ 19 _Swfac~ _casing_ protecJs alLknown USDWs _ . . - - - - - - NA All aquifers exempìed,AOCFR1-47.:102. (b).(3). 20 _CMT v.ol adeq u_ate to circulate. oncooductor & $uJf <:$g _ . - - - - - - Y~$ - - - - - - - - - - - - - - - - 121 CMT vol adequ_ateJo tie-in JQngstring tosur:f çs.g_ . - - - - -- No - - - - - - - - - - - 122 _CMTwiIJ coveraJl known.productive bQril:ons_ _ Ye$ - - - - - 23 _Ca$iog de_signs ad_ec¡ua_tE\ for C,T, 6.& perroafrost . . - - - -- -... Y~$ - - - - - - - - - -- 24 _A~equatetan.kage_or reserve pit _ . . _ _ . - - - - -- Ye$ Rig jSßquippe_dwith steeLpjts. _ No reseJllepjt.planoed, AJI waste to approve_d_anouJu_s or di$posal welJs~ . 25 Jtare-drill~ has_a t0c403 fQr abandonme.nt beeo approved. - - - - - - NA - - - - - 26 A~equate _we[lbore separatjo_n _pro'pose,d _ _ _ _ _ _ _ . _ _ _ . _ _ _ . _ _ _ _ _ _ _ - - - - _ _Y_e$ I?ro~imtty. ana1Y$is PE\rf.orroe_d, Jraveling cy.lioder ploUncJuded. _ Gy'ros_po$sible $h_a[lQW. _ _ _ _ _ _ _ _ _ _ . 27 Itdiverter rE\quired. dQes jt meet reguJations_ Y~$ - - - - - - - - - - - - - -- Appr Date 28 _DriUiog flujd program $c.hematic_& E\q.uip Ji$tadequat~ _ _ . - - - - - - Ye$ Maximu.m expected formation pres_sure_8,6_EMW. MW planned 9.0 tQ 9.2 ppgjo WS~ _ TEM 6/7/2005 29 _BOPEs,d_o they meet reguJa_tion . - - - - -- · Y~$ - - - - - - - - - - - - - -- - - - - - . I£~ 30 _BOPE.pres$ ratiog appropriate; _test to _(put psig tn _comments) . Y~$ MASF.' calculated at 1292 þ$i, 30QOpst a'ppropriate_. _CPA! oQrmally tests to 50QOpst . 31 CMkemanjfOld cQmpJies w/APt RF'-53 (May 84) - - - - - Ye$ - - - - - 32 Work will occjJr withoutoperationshu.tdown_ _ . - - - - Y~$ - - - - - - . 33 Is presence_ of H2S gas_ prob_able . ... Y~s tf2S bas .been reported in some Ws. WE\II$._ Mud should preclude H2_S on rig. Righa$ SE\nsor$ and alarm$. 34 Mecba.nicaLC9odiUon 9t well$ within AOR YE\rified (Fo(s_ervice welJ only) _ . Y~$ 1 ~-03, 1 E-_20 and_ tE-16_8 _assessedJor _cement cov_erage. _ 1\10 COMeros identified, No other well$ inAQR. ~~ Geology 35 P~rmit can be iS$u.ed w/Q hYdrogen s.ulfide measures. - - - - - No_ KRU 1E-:l12, 1E-114 & :lE-126. measur~d 26,62lU2ppmH2S jn Oecember2004~ . . 36 _D_ata_preseoted on_ pote_ntial oveJpressure _zones _ _ Y~$ Expected re$ervojr .pre_S$ure is 8,3_ -8,6_p'pg EMW; wjllb~ .drilJed wjtb 9.5 _ RP9 mud.. Appr Date 37 S~tsmic_analysjs Qf sbaJlow gas_zooes_ . · NA tfydrates_may_be _encou(1tered._ Mitigatioo measuresdtscu.ssed_ io Drilling_Hazards Summary. - - - - - SFD 6/2/2005 38 _S~abedcondjtioo $u.rvey -<if Off-sh_ore) _ _ . NA - - - - - 39 _ CQnta_ct namelphoneJorweelsly progress_report$ [exploratory 9i1IY1- _ . . NA - Geologic Date: Engineering Date Public Date Commissioner Commissioner: 9i: fJ7J b17~ ~ b- 9-tJ5 ~týðr